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Fluid Flow And Heat Transfer In Wellbores. Download multimedia files (txt, html, PDF). Title: Numerical Heat Transfer and Fluid Flow.tif Author: Takahashi Created Date: 7/8/2009 10:52:46 PM. John Conyers announced his retirement from. 40 Dias En La Palabra Pdf To Excel - Bolt Browser Download For Blackberry Curve 9300 Manual - Drudge Blogger Template Designer - Download Free Fluid Flow And Heat Transfer In Wellbores Pdf Editor - Party Rock Anthem Marching Band Arrangement Pdf To Jpg. Formulation for fully coupled subsurface heat and mass transfer equations was developed while the author was a post-doctoral fellow at the University of Auckland, New Zealand. Here, motivated by the need to solve the two–phase coupled subsurface heat and fluid flow equations for geothermal applications, Zyvoloski et al. (1979) formulated the heat.

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US7882707B2

US7882707B2US12/534,798US53479809AUS7882707B2US 7882707 B2US7882707 B2US 7882707B2US 53479809 AUS53479809 AUS 53479809AUS 7882707 B2US7882707 B2US 7882707B2

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comprises

fluid

US20100024451A1 (en

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Lawrence Dean Leabo

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Criticalpatent/US20100024451A1/en

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Description

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NKWPZUCBCARRDP-UHFFFAOYSA-LCalcium bicarbonateChemical 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F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25B40/00—Subcoolers, desuperheaters or superheaters

F25—REFRIGERATION OR COOLING; COMBINED HEATING AND REFRIGERATION SYSTEMS; HEAT PUMP SYSTEMS; MANUFACTURE OR STORAGE OF ICE; LIQUEFACTION SOLIDIFICATION OF GASES

F25B2341/00—Details of ejectors not being used as compression device; Details of flow restrictors or expansion valves

F25B2341/0014—Ejectors with a high pressure hot primary flow from a compressor discharge

Abstract

A system for desuperheating hot gaseous refrigerant using both a heat exchanger and a dispersed Venturi-driven injection of liquid refrigerant is disclosed. Further, a system, relating to cooling at least one compressed superheated refrigerant fluid prior to condensing, relating to extending the life of at least one condenser is disclosed.

Description

CROSS REFERENCE TO RELATED APPLICATION

The present application is related to and claims priority from prior provisional application Ser. No. 61/085,911, filed Aug. 4, 2008, entitled “REFRIGERATION HOT GAS DESUPERHEATER SYSTEMS”, and is also related to and claims priority from prior provisional application Ser. No. 61/114,880, filed Nov. 14, 2008, entitled “REFRIGERATION HOT GAS DESUPERHEATER SYSTEMS”, the contents all of which are incorporated herein by this reference and are not admitted to be prior art with respect to the present invention by the mention in this cross-reference section.

BACKGROUND

This invention relates to providing a system for improved refrigeration hot-gas desuperheating. More particularly, this invention relates to providing a system for desuperheating hot gaseous refrigerant using an injection of liquid refrigerant.

Mechanical refrigeration is typically accomplished by circulating, evaporating, and condensing a supply of chemical refrigerant in a continuous thermodynamic cycle. In a typical refrigeration cycle, low pressure vapor refrigerant is compressed by a mechanical compressor and discharged as a pressure superheated vapor. The high pressure refrigerant flows to the condenser by way of a “discharge line”. The condenser is used to change the high pressure refrigerant from a high temperature vapor to a lower temperature liquid that exits the condenser through a “liquid runoff line”. The liquid refrigerant then flows to a thermal expansion valve where the high pressure liquid is changed to a low-pressure, low-temperature vapor. The low-pressure, low-temperature vapor enters the evaporator where a useful heat exchange typically occurs. The low pressure vapor is then returned to the mechanical compressor and the cycle then repeats.

The chemical refrigerant absorbs heat at several points in the refrigeration cycle. Heat is initially absorbed in the evaporator. Further, heat is absorbed by the refrigerant during the compression, such that superheated gaseous refrigerant is discharged from the compressor to the discharge line.

Superheating is a major drawback in refrigeration systems utilizing commercial water-cooled condensers in that passage of the superheated gas through such a condenser can result in the development of detrimental scale deposits (scaling) on the heat-exchanging surfaces. The water used in these condensers typically contains traces of calcium bicarbonate and other dissolved salts that can form water-insoluble deposits when exposed to excessive heat. It would be useful to provide a means for desuperheating of the gaseous refrigerant prior to condensing would reduce such scaling through a proportional reduction of water temperature. Such a method might beneficially extend the time the condenser may operate without maintenance (de-scaling of the coils, coil replacement, etc.), and may further benefit operation by reducing the amount of scale-inhibiting chemicals that must be added to such systems.

It is clear from the above discussion that improved methods of desuperheating gaseous refrigerant prior to movement through such condensers would be of benefit to those whose commerce is dependent on such mechanical systems.

OBJECTS AND FEATURES OF THE INVENTION

A primary object and feature of the present invention is to provide a system addressing the above-described problems.

It is a further object and feature of the present invention to provide such a system comprising at least one fitting adapted to desuperheat refrigerant gas by mixing superheated gas refrigerant with a cooler liquid refrigerant.

It is a further object and feature of the present invention to provide a system comprising at least one fitting adapted to desuperheat refrigerant gas through a multistage process, with at least one heat exchange and at least one injection.

Another object and feature of the present invention is to provide a system adaptable to a range of “discharge line” sizes.

A further object and feature of the present invention is to provide a system with passive drawing of liquid refrigerant to inject into superheated gas refrigerant.

Yet another object and feature of the present invention is to provide a system designed to be able to operate level with the condenser of a refrigeration cycle.

It is a further object and feature of the present invention to provide a system using the “Venturi Effect” to passively suction liquid refrigerant to inject into superheated gas refrigerant.

A further object and feature of the present invention is to provide such a system, which, when used, may extend the life of at least one water cooled condenser in a refrigeration cycle through assisting prevention of “flash vaporization” of water in such water cooled condenser.

Another object and feature of the present invention is to provide such a system, which can also be used in the defrost cycle of a refrigeration cycle to extend the life of at least one evaporator in such refrigeration cycle by assisting prevention of excessive thermal shock.

A further primary object and feature of the present invention is to provide such a system that is efficient, inexpensive, and handy. Other objects and features of this invention will become apparent with reference to the following descriptions.

SUMMARY OF THE INVENTION

In accordance with a preferred embodiment hereof, this invention provides a system, relating to cooling at least one superheated refrigerant fluid during at least one heat cycle, such system comprising: at least one heat exchanger structured and arranged to exchange heat between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between such at least one cooling fluid and such at least one superheated refrigerant fluid; at least one injector, structured and arranged to inject such at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in such at least one heat exchanger; and at least one fluid mixer structured and arranged to mix such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state; wherein such at least one heat exchanger comprises at least one suction creator structured and arranged to create suction to draw such at least one cooling fluid into such at least one heat exchanger by decreasing localized pressure near such at least one injector; and wherein such at least one suction creator assists injection by such at least one injector.

Moreover, it provides such a system wherein such at least one suction creator comprises at least one separator structured and arranged to physically separate such at least one cooling fluid from the at least one superheated refrigerant fluid, while allowing exchange of heat in such at least one heat exchanger by transmitting heat through such at least one separator. Additionally, it provides such a system wherein such at least one suction creator comprises at least one tube. Also, it provides such a system wherein such at least one tube is structured and arranged to: contain flow of the at least one superheated refrigerant fluid inside such at least one tube; and separate flow of such at least one cooling fluid substantially around at least one perimeter of such at least one tube.

In addition, it provides such a system wherein such at least one injector is structured and arranged to inject such at least one cooling fluid into the at least one superheated refrigerant fluid substantially evenly around at least one perimeter of flow of the at least one superheated refrigerant fluid. And, it provides such a system wherein such at least one injector comprises at least one injector port. Further, it provides such a system wherein such at least one injector comprises a plurality of such at least one injector ports evenly spaced about the perimeter of the flow of the at least one superheated refrigerant fluid. Even further, it provides such a system wherein: when connected to at least one discharge line, the diameter of such at least one injector port multiplied by the quantity of such plurality of such at least one injection ports comprises about the diameter of at least one discharge line. Moreover, it provides such a system wherein the diameter of such at least one injector port comprises between about ⅛ inch and about ½ inch. Additionally, it provides such a system wherein the diameter of such at least one injector port comprises about ⅜ inch.

Also, it provides such a system wherein the diameter of such at least one injector port comprises about ¼ inch. In addition, it provides such a system further comprising at least one outer container structured and arranged to contain such at least one cooling fluid substantially near such at least one separator. And, it provides such a system further comprising at least one discharge line structured and arranged to fit at least one discharge line. Further, it provides such a system wherein such at least one suction creator is substantially cylindrical. Even further, it provides such a system wherein such at least one outer container is substantially cylindrical. Moreover, it provides such a system wherein the difference between the diameter of such at least one discharge line and the diameter of such at least one suction creator comprises between about ½ inch and about ¼ inch.

Additionally, it provides such a system wherein the difference between the diameter of such at least one outer container and the diameter of such at least one suction creator comprises between about 2 inches and about 1 inch. Also, it provides such a system wherein the diameter of such at least one outer container comprises about 2⅝ inches. In addition, it provides such a system wherein the diameter of such at least one discharge line comprises about ⅞ inches. And, it provides such a system wherein the diameter of such at least one suction creator comprises about ⅝ inches. Further, it provides such a system wherein the diameter of such at least one discharge line comprises about 1⅛ inches. Even further, it provides such a system wherein the diameter of such at least one suction creator comprises about ⅞ inches. Moreover, it provides such a system wherein the diameter of such at least one discharge line comprises about 1⅜ inches. Additionally, it provides such a system wherein the diameter of such at least one suction creator comprises about 1⅛ inches. Also, it provides such a system wherein the diameter of such at least one outer container comprises about 3⅛ inches. In addition, it provides such a system wherein the diameter of such at least one discharge line comprises about 1⅝ inches. And, it provides such a system wherein the diameter of such at least one suction creator comprises about 1⅜ inches.

Further, it provides such a system wherein the diameter of such at least one discharge line comprises about 2⅛ inches. Even further, it provides such a system wherein the diameter of such at least one suction creator comprises about 1⅝ inches. Moreover, it provides such a system wherein the diameter of such at least one discharge line comprises about 2⅝ inches. Additionally, it provides such a system wherein the diameter of such at least one suction creator comprises about 2⅛ inches. Also, it provides such a system wherein the diameter of such at least one outer container comprises about 3⅝ inches. In addition, it provides such a system wherein the diameter of such at least one discharge line comprises about 3⅛ inches. And, it provides such a system wherein the diameter of such at least one suction creator comprises about 2⅝ inches. Further, it provides such a system wherein such at least one injector comprises metal.

Even further, it provides such a system wherein such at least one injector comprises brass. Even further, it provides such a system wherein such at least one injector comprises copper. Even further, it provides such a system wherein such at least one heat exchanger comprises metal. Even further, it provides such a system wherein such at least one heat exchanger comprises copper.

In accordance with another preferred embodiment hereof, this invention provides a method, relating to cooling at least one superheated refrigerant fluid during at least one heat cycle, such method comprising the steps of: exchanging heat, in at least one heat exchanger, between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between such at least one cooling fluid and the at least one superheated refrigerant fluid; injecting, using at least one injector, such at least one cooling fluid into the at least one superheated refrigerant fluid after the step of exchanging heat; mixing such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state; and creating suction to draw such at least one cooling fluid into such at least one heat exchanger by decreasing localized pressure near such at least one injector; wherein such suction assists injection by such at least one injector.

In accordance with another preferred embodiment hereof, this invention provides a system, relating to cooling at least one superheated refrigerant during at least one heat cycle, such system comprising: heat exchanger means for exchanging heat between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between such at least one cooling fluid and the at least one superheated refrigerant fluid; injector means for injecting such at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in such at least one heat exchanger; fluid mixer means for mixing such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state; wherein such heat exchanger means comprises suction creator means for creating suction to draw such at least one cooling fluid into such heat exchanger means by decreasing localized pressure near such injector means; and wherein such suction creator means assists injection by such injector means.

In accordance with another preferred embodiment hereof, this invention provides a method, relating to cooling at least one superheated refrigerant batch during at least one heat cycle, such method comprising the steps of: creating suction to draw at least one cooler refrigerant batch into heat exchange relationship with such at least one superheated refrigerant batch; exchanging heat between such at least one superheated refrigerant batch and at least one cooler refrigerant batch to decrease temperature differential between such at least one superheated refrigerant batch and such at least one cooler refrigerant batch and form at least one cooler superheated refrigerant batch; injecting such at least one cooler refrigerant batch into the at least one cooler superheated refrigerant batch after the step of exchanging heat; and mixing such at least one cooler refrigerant batch and such at least one cooler superheated refrigerant batch to produce at least one desuperheated refrigerant batch having at least one portion substantially near at least one saturated state.

And it provides for each and every novel feature, element, combination, step and/or method disclosed or suggested by this patent application.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows a schematic diagram, illustrating the primary components of a refrigeration cycle utilizing at least one hot-gas desuperheater circuit, according to a preferred embodiment of the present invention.

FIG. 2 shows a longitudinal cross-sectional view through the hot-gas desuperheater fitting, according to the preferred embodiment of FIG. 1.

FIG. 3 shows an exploded view of the hot-gas desuperheater fitting of FIG. 2.

FIG. 4 shows a schematic diagram, illustrating the primary components of a refrigeration cycle utilizing at least one defrosting injection circuit, according to another preferred embodiment of the present invention.

FIG. 5 shows a longitudinal cross-sectional view, through another hot-gas desuperheater fitting, according to an alternately preferred embodiment of the present invention.

DETAILED DESCRIPTION OF THE BEST MODES AND PREFERRED EMBODIMENTS OF THE INVENTION

FIG. 1 shows a schematic diagram, illustrating the primary components of a refrigeration cycle 101 at least one utilizing hot-gas desuperheater circuit 102, according to a preferred embodiment of the present invention.

In the refrigeration cycle depicted in FIG. Ganesh aarti mp3 free download dj. 1, at least one mechanical compressor 106 preferably compresses low-pressure vapor refrigerant 130, preferably to form a high-temperature vapor 140, which preferably discharges into at least one discharge line 110. High-temperature vapor 140 enters discharge line 110 superheated as high-temperature superheated vapor 132, as shown. Discharge line 110 preferably transports high-temperature vapor 140 to at least one condenser 108, as shown.

Condenser 108 preferably comprises at least one water-cooled condenser 408. Condenser 108 preferably condenses high-temperature vapor 140 to form a lower-temperature liquid 136 that preferably exits condenser 108 through at least one liquid runoff line 112, as shown. Liquid runoff line 112 preferably transports lower-temperature liquid 136 to expansion valve 124, as shown.

Expansion valve 124 preferably rapidly lowers the pressure in liquid runoff line 112, preferably causing a portion of lower-temperature liquid 136 to vaporize, preferably forming a mixed vapor/liquid refrigerant 138, as shown. At least one evaporator feed line 142 preferably carries mixed vapor/liquid refrigerant 138 to at least one evaporator 146, as shown.

Evaporator 146 preferably vaporizes the remaining liquid in mixed vapor/liquid refrigerant 138, preferably through the transfer of heat, preferably from the environment around evaporator 146, to mixed vapor/liquid refrigerant 138, preferably forming low-pressure vapor refrigerant 130, as shown. At least one suction line 144 preferably transports low-pressure vapor refrigerant 130 to mechanical compressor 106 where refrigeration cycle 101 may repeat, as shown.

Refrigerant, cycled through refrigeration cycle (low-pressure vapor refrigerant 130, high-temperature vapor 140, lower-temperature liquid 136, and mixed vapor/liquid refrigerant 138.), preferably comprises Freon. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as cost, future industry regulations, future technology, etc., other refrigerants, such as, for example, water, glycol, coolant mixtures, etc., may suffice.

Hot-gas desuperheater circuit 102 is preferably added to refrigeration cycle 101 to desuperheat high-temperature vapor 140, preferably forming high-temperature desuperheated vapor 134, preferably prior to entering condenser 108, as shown. More specifically, at least one liquid refrigerant transfer line 114 preferably connects between liquid runoff line 112 and discharge line 110, preferably to divert a portion of lower-temperature liquid 136, exiting water-cooled condenser 108, to discharge line 110, as shown. Hot-gas desuperheater circuit 102 preferably comprises to at least one check valve 404, as shown, in liquid refrigerant transfer line 114, preferably to prevent backflow of high-temperature vapor 140 into liquid refrigerant transfer line 114.

Hot-gas desuperheater circuit 102 preferably comprises hot-gas desuperheater fitting 104 in fluid communication with liquid runoff line 112 by means of liquid refrigerant transfer line 114, as shown. Hot-gas desuperheater fitting 104 is preferably cut into discharge line 110 between mechanical compressor 106 and condenser 108, as shown. Liquid refrigerant transfer line 114 preferably couples to liquid runoff line 112 at a point preferably between condenser 108 and thermal expansion valve 124, preferably at an elevation between about level with, to about 24 inches above, hot-gas desuperheater fitting 104, preferably between about 12 inches and about 24 inches above hot-gas desuperheater fitting 104. The above described method embodies herein A method, relating to cooling at least one superheated refrigerant batch during at least one heat cycle, such method comprising the steps of: creating suction to draw at least one cooler refrigerant batch into heat exchange relationship with such at least one superheated refrigerant batch; exchanging heat between such at least one superheated refrigerant batch and at least one cooler refrigerant batch to decrease temperature differential between such at least one superheated refrigerant batch and such at least one cooler refrigerant batch and form at least one cooler superheated refrigerant batch; injecting such at least one cooler refrigerant batch into the at least one cooler superheated refrigerant batch after the step of exchanging heat; and mixing such at least one cooler refrigerant batch and such at least one cooler superheated refrigerant batch to produce at least one desuperheated refrigerant batch having at least one portion substantially near at least one saturated state. A batch being defined as a portion of the fluid as it flows through the refrigeration system.

FIG. 2 shows a longitudinal cross-sectional view through hot-gas desuperheater fitting 104 according to the preferred embodiment of FIG. 1.

Hot-gas desuperheater fitting 104 preferably comprises an outer conduit 116, preferably defining an interior passage 118 having an interior diameter, and preferably capable of coupling to refrigerant discharge line 110. Diameter of refrigerant discharge line 110 preferably comprises about ⅞ inch, alternately preferably about 1⅛ inch, alternately preferably about 1⅜ inch, alternately preferably about 1⅝ inch, alternately preferably about 2⅛ inch, alternately preferably about 2⅝ inch, alternately preferably about 3⅛ inch. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future technology, size standards, regulations etc., other discharge line diameters, such as, for example, 5 cm, 7.5 cm, 3 inch, greater than 3⅛ inch, smaller than ⅞ inch, etc., may suffice.

Outer conduit 116 preferably comprises at least one outer housing 416, at least one intake-side coupler 418 and at least one outlet-side coupler 445, as shown. Intake-side coupler 418 and outlet-side coupler 445 preferably adapt diameter of outer housing 416 to refrigerant discharge line 110, as shown.

For diameters of refrigerant discharge line 110 ranging from about ⅞ inch to about 1⅜ inches, outer diameter of outer housing 416 preferably comprises about 2⅝ inches. For diameters of refrigerant discharge line 110 ranging from about 1⅜ inches to about 2⅝ inches, outer diameter of outer housing 416 preferably comprises about 3⅛ inches. For diameters of refrigerant discharge line 110 of about 3⅛ inches, outer diameter of outer housing 416 preferably comprises about 3⅝ inches. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future technology, manufacturing methods, regulations etc., other outer housing diameter discharge line diameter pairings, such as, for example, ⅞ inch to 2⅛ inches, 1⅜ inches to 1⅞ inches, etc., may suffice.

Hot-gas desuperheater fitting 104 preferably comprises at least one Venturi structure 150, preferably comprising at least one interior channel 120, preferably comprising a diameter less than discharge line 110, preferably located within interior passage 118. Venturi structure 150 (at least embodying herein wherein said at least one heat exchanger comprises at least one suction creator structured and arranged to create suction to draw such at least one cooling fluid into said at least one heat exchanger by decreasing localized pressure near said at least one injector; and at least embodying herein wherein said heat exchanger means comprises suction creator means for creating suction to draw such at least one cooling fluid into heat exchanger means by decreasing localized pressure near said injector means), utilizing the “Venturi Effect”, preferably induces the formation of at least one low-pressure region 145, preferably within interior passage 118, from the increased axial velocity of high-temperature superheated vapor 132 through interior channel 120.

Outer diameter of interior channel 120, as shown, preferably comprises between about ¼ inch less than refrigerant discharge line 110 (for smaller diameters of refrigerant discharge line 110) and preferably about ½ inch less than refrigerant discharge line 110 (for larger diameters of refrigerant discharge line 110). More particularly, for diameter of refrigerant discharge line 110 comprising about ⅞ inch, outer diameter of interior channel 120 preferably comprises about ⅝ inch. Additionally, for diameter of refrigerant discharge line 110 preferably comprising about 1⅛ inches, outer diameter of interior channel 120 preferably comprises about ⅞ inch. Further, for diameter of refrigerant discharge line 110 comprising about 1⅝ inches, outer diameter of interior channel 120 preferably comprises about 1⅜ inches. Even further, for diameter of refrigerant discharge line 110 comprising about 2⅛ inches, outer diameter of interior channel 120 preferably comprises about 1⅝ inches. Additionally, for diameter of refrigerant discharge line 110 comprising about 2⅝ inches, outer diameter of interior channel 120 preferably comprises about 2⅛ inches. Also, for diameter of refrigerant discharge line 110 comprising about 3⅛ inches, outer diameter of interior channel 120 preferably comprises about 2⅝ inches. Essentially, outer diameter of interior channel 120 preferably comprises about one standard size smaller than refrigerant discharge line 110 (this arrangement at least embodying herein wherein the diameter of such at least one discharge line is larger than the diameter of said at least one suction creator). Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as standard sizing, flow requirements, etc., other size differentials between interior channel and discharge line may suffice.

Lower-temperature liquid refrigerant 136 preferably enters hot-gas desuperheater fitting 104 through at least one side inlet 126 in fluid communication with at least one internal pre-injection chamber 122, as shown. Side inlet 126 preferably receives lower-temperature liquid refrigerant 136 from liquid refrigerant transfer line 114 (see FIG. 1), as shown. Diameter of side inlet 126 preferably comprises about ⅞ inch.

Pre-injection chamber 122 is preferably positioned circumferentially around interior channel 120, preferably within interior passage 118, as shown. Pre-injection chamber 122 preferably runs the length of interior channel 120, preferably comprising between about 4 inches and about 10 inches. Length of interior channel 120 preferably comprises about 5 inches, alternately preferably about 7 inches. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as cost, temperature differential, refrigerant, etc., other lengths may suffice.

Custom Heat Transfer

Pre-injection chamber 122 preferably serves to provide an initial heat exchange between lower-temperature liquid refrigerant 136 and high-temperature vapor 140, preferably through the wall of interior channel 120 (at least embodying herein at least one heat exchanger structured and arranged to exchange heat between at least one cooling fluid and the at least one superheated refrigerant fluid, to decrease temperature differential between such at least one cooling fluid and such at least one superheated refrigerant fluid; and at least embodying herein heat exchanger means for exchanging heat between at least one cooling fluid and the at least one superheated refrigerant fluid, to decrease temperature differential between such at least one cooling fluid and the at least one superheated refrigerant fluid). The wall of interior channel 120 (at least embodying herein wherein at least one wall of said at least one suction creator comprises at least one separator structured and arranged to physically separate such at least one cooler fluid from the at least one superheated refrigerant fluid, while allowing exchange of heat in said at least one heat exchanger by transmitting heat through said at least one separator) preferably prevents the immediate mixing of lower-temperature liquid refrigerant 136 with high-temperature vapor 140, preferably allowing initial heat exchange to diminish the temperature variation between lower-temperature liquid refrigerant 136 and high-temperature vapor 140. This initial heat exchange preferably begins vaporization of lower-temperature liquid refrigerant 136, preferably prior to injection, preferably allowing rapid mixing, of lower-temperature liquid refrigerant 136 with high-temperature vapor 140 preferably without thermal shock (this arrangement at least embodying herein exchanging heat, in at least one heat exchanger, between at least one cooling fluid and the at least one superheated refrigerant fluid, to decrease temperature differential between such at least one cooling fluid and the at least one superheated refrigerant fluid).

At least two spacers 425 preferably axially center interior channel 120 inside interior passage 118, as shown. Spacers 425 preferably define spacing of internal pre-injection chamber 122, as shown. Spacer 425, near inlet side of hot-gas desuperheater fitting 104, preferably comprises at least one sealing spacer 426, as shown, preferably sealing against passage of high-temperature vapor 140 into internal pre-injection chamber 122, thereby preferably forcing flow of high-temperature vapor 140 into interior channel 120 (this arrangement at least embodies herein wherein the at least one superheated refrigerant fluid flows inside said at least one tube and such at least one cooler fluid may substantially surround the exterior perimeter of said at least one tube). Spacer 425, near outlet side of hot-gas desuperheater fitting 104, as shown, preferably comprises at least one injection portal spacer 428, as shown, preferably allowing passage of lower-temperature liquid refrigerant 136 into interior passage 118 from internal pre-injection chamber 122 (this arrangement at least embodies herein injecting, using at least one injector, such at least one cooling fluid into the at least one superheated refrigerant fluid after the step of exchanging heat).

Pre-ejection chamber 122 preferably uniformly distributes the liquid refrigerant around interior channel 120 prior to downstream discharge into interior passage 118. In preferred operation, lower temperature liquid refrigerant 136 is passively suctioned from liquid runoff line 112, preferably through liquid refrigerant transfer line 114, and is preferably injected into discharge line 110 at hot-gas desuperheater fitting 104, as shown.

Low-pressure region 145 preferably forms, as shown, preferably at the exit of Venturi structure 150 due to the Venturi Effect (this arrangement at least embodies herein creating suction to draw such at least one cooling fluid into such at least one heat exchanger by decreasing localized pressure near such at least one injector). Lower-temperature liquid refrigerant 136 is preferably drawn, by low-pressure region 145, preferably from pre-injection chamber 122 into interior channel 120, preferably through at least one injection port 128 (at least embodying herein wherein said at least one injector comprises at least one injector port) preferably passing through injection portal spacer 428 (at least embodying herein at least one injector structured and arranged to inject such at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in said at least one heat exchanger; and at least embodying herein injector means for injecting such at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in said at least one heat exchanger) near the exit of interior channel 120, as shown. This arrangement at least embodies herein wherein said at least one suction creator assists injection by said at least one injector; and this arrangement at least embodies herein wherein such suction assists injection by such at least one injector; and this arrangement at least embodies herein wherein said suction creator means assists injection by said injector means.

Additionally, at least one mixing chamber 450 preferably uses turbulence, at the exit of interior channel 120, to inject lower-temperature liquid refrigerant 136 preferably around the entire circumference of interior passage 118 (this arrangement at least embodies herein mixing such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state).

In the depicted preferred embodiment of the present invention, lower-temperature liquid refrigerant 136 injects through preferably about eight injection ports 128 (at least embodying herein wherein said at least one injector comprises a plurality of said at least one injector ports evenly spaced about the perimeter of the flow of the at least one superheated refrigerant fluid), preferably evenly spaced, arranged circumferentially about interior channel 120, as shown in FIG. 3, thus preferably maximizing mixing and preferably injection efficiency in mixing chamber 450 (at least embodying herein at least one fluid mixer structured and arranged to mix such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state; and this arrangement at least embodying herein wherein said at least one injector injects such at least one cooler fluid into the at least one superheated refrigerant fluid substantially evenly around the perimeter of flow of the at least one superheated refrigerant fluid; and at least embodying herein fluid mixer means for mixing such injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state). As a result, high-temperature vapor 140, which had previously been above the saturation temperature (high-temperature superheated vapor 132), is preferably brought near to the saturation temperature (becoming high-temperature desuperheated vapor 134), as shown. Saturation temperature is the temperature at which a gas begins to condense into a liquid.

Hot-gas desuperheater fitting 104 is preferably atmosphere-tight bonded silver soldered to form an assembly, as shown. Further, hot-gas desuperheater fitting 104 is preferably atmosphere-tight bonded silver soldered to discharge line 110 and liquid refrigerant transfer line 114, when installed. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future materials, thermal expansion variations, etc., other atmosphere tight bondings, may suffice.

Hot-gas desuperheater fitting 104 preferably is installed vertically with outlet-side coupler 445 higher in elevation than 418. This vertical arrangement preferably allows lower-temperature liquid 136 to preferably pool in internal pre-injection chamber 122, preferably allowing for the initial heat exchange prior to injection.

It is noted that hot-gas desuperheater circuit 102 preferably does not require a mechanical pump or gravity-assisted fluid pressure to operate. Rather, hot-gas desuperheater circuit 102 preferably uses the Venturi Effect to create suction. Further, hot-gas desuperheater circuit 102 preferably does not require injecting fluids from sources external to refrigeration cycle 101. Rather, hot-gas desuperheater circuit 102 preferably utilizes a portion of lower-temperature liquid refrigerant 136 already in refrigeration cycle 101, as shown.

Additionally, by using both the initial heat exchange and injecting lower-temperature liquid 136, less of lower-temperature liquid 136 is preferably needed to desuperheat high-temperature vapor 140. Since any amount of lower-temperature liquid 136 diverted from refrigeration cycle 101 results in reduced efficiency of refrigeration cycle 101, utilizing less of lower-temperature liquid 136 decreases loss of efficiency required to extend the life of condenser 108.

Also, applicant has determined, through testing, that temperatures of high-temperature superheated vapor 132 in refrigeration cycle 101, running about 190 degrees Fahrenheit, were reduced to about 90 degrees Fahrenheit in high-temperature desuperheated vapor 134.

Further, applicant has determined, through testing, that hot-gas desuperheater fitting 104 self-regulates the amount of lower-temperature liquid 136 injected based on the volume of high-temperature superheated vapor 132 flowing through hot-gas desuperheater fitting 104. When the flow volume of high-temperature superheated vapor 132 decreases the suction created by Venturi structure 150 likewise decreases drawing less of lower-temperature liquid 136 into internal pre-injection chamber 122. This behavior allows hot-gas desuperheater fitting 104 to adjust, in multi-loop heating systems, to changes in flow of high-temperature superheated vapor 132 caused by a loop shutting off or running in defrost mode. By self-regulating, high-temperature superheated vapor 132 is not over-cooled but maintains approximately the same cooling rate.

FIG. 3 shows an exploded view of hot-gas desuperheater fitting 104 of FIG. 2. As shown, intake-side coupler 418 and outlet-side coupler 445 preferably comprise diameter-reducing couplers sized to couple discharge line 110 and outer housing 416. Outer housing 416 (at least embodying herein wherein said at least one outer container is substantially cylindrical) preferably comprises at least one cylinder, preferably at least one section of pipe, comprising sizes as discussed in relation to FIG. 2. Likewise, interior channel 120 (at least embodying herein wherein said at least one suction creator comprises at least one tube; and at least embodying herein wherein said at least one suction creator is substantially cylindrical) and side inlet 126 preferably each comprise, as shown, at least one cylinder, preferably at least one section of pipe, comprising sizes as discussed in relation to FIG. 2. Intake-side coupler 418, outlet-side coupler 445 (at least embodying herein at least one discharge line adapter structured and arranged to adapt the perimeter of at least one discharge line, from at least one compressor, to the perimeter of said at least one outer container), outer housing 416 (at least embodying herein at least one outer container structured and arranged to contain such at least one cooler fluid substantially near said at least one separator), interior channel 120, and side inlet 126 preferably comprise metal, preferably copper. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future materials, equipment integrated with, thermal expansion variations, etc., other materials, such as for example, ceremets, metal alloys, future plastics, other than copper metals, etc., may suffice.

Spacers 425 preferably comprise at least one ring preferably with at least one inner diameter substantially matching the outer diameter of interior channel 120 and at least one outer diameter preferably substantially matching interior diameter of outer housing 416, as shown. Injection portal spacer 428 preferably further comprises injection ports 128, preferably between about ⅛ inch and about ½ inch in diameter (at least embodying herein wherein the diameter of said at least one injector port comprises between about ⅛ inch and about ½ inch).

Diameter of injection ports 128 preferably comprises about ¼ inch (at least embodying herein wherein the diameter of said at least one injector port comprises about ¼ inch), alternately preferably about ⅜ inch (at least embodying herein wherein the diameter of said at least one injector port comprises about ⅜ inch).

Variation in diameter of injection ports 128 may preferably be used to control the rate of lower-temperature liquid 136 injected. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as fitting sizes, cost, flow rates, etc., other injection port diameters, may suffice.

In selecting the number and size of injection ports 128, the diameter of injection ports 128 times the number of injection ports 128 preferably comprises approximately the diameter of discharge line 110. Applicant has theorized that this relationship achieves optimal injection rates.

Spacers 425 preferably comprise metal, preferably brass. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future materials, equipment integrated with, thermal expansion variations, etc., other materials, such as for example, ceremets, other than brass metal alloys, future plastics, other metals, etc., may suffice.

In order to make installation and use easier, intake-side coupler 418 and outlet-side coupler 445 preferably further comprise at least one temperature indicator 435, as shown, preferably indicia 438, preferably indicating the “hot” side and the “cool” side of hot-gas desuperheater fitting 104, preferably effectively indicating flow direction across hot-gas desuperheater fitting 104, as shown. Temperature indicator 435 preferably comprises at least one color indicator, preferably red on the “hot” side and blue on the “cool” side. For purposes of illustration, FIG. 3 denotes preferred such at least one color indicator with the characters “H” and “C”, as shown. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as industry regulations, cost, manufacturing methods, etc., other temperature variation indicators, such as, for example, characters, symbols, graphics, color patterns, etc., may suffice.

FIG. 4 shows a schematic diagram illustrating the primary components of a refrigeration cycle 501 utilizing at least one defrosting injection circuit according to another preferred embodiment of the present invention. Although most features of Hot-gas desuperheater circuit 402 are repeated from preferred Hot-gas desuperheater circuit 102, in Hot-gas desuperheater circuit 402, rather than transferring high-temperature desuperheated vapor 134 to condenser 108, high-temperature desuperheated vapor 134 is preferably used to defrost evaporator 146, as shown.

Hot-gas desuperheater fitting 104 is preferably also useful in providing improved hot-gas defrosting, which may be used on a single or multiple evaporator system, and is particularly useful on multiplexed systems with evaporators at different temperatures. In this preferred embodiment, high-temperature vapor 140 is preferably routed to the outlet of evaporator 146, as shown. This preferably warms evaporator 146 to thaw any frost that has accumulated.

Defrost cycle 401 preferably uses at least one solenoid valve 406 and at least one solenoid valve 444 to reverse fluid flow across evaporator 146, as shown. Solenoid valve 444 preferably opens to allow flow of high-temperature vapor 140 to outlet-side of evaporator 146, while solenoid valve 406 preferably closes to prevent flow of high-temperature vapor 140 back into mechanical compressor 106. Likewise, at least one check valve 424 preferably bypasses expansion valve 124, as shown.

High-temperature vapor 140 preferably flows through evaporator 146, as shown, exchanging heat to defrost evaporator 146, and preferably condenses to form lower-temperature liquid 136. Lower-temperature liquid 136 preferably bypasses expansion valve 124, using check valve 424, and feeds back into liquid runoff line 112, as shown. By using hot-gas desuperheater fitting 104 in defrost cycle 401, thermal shock preferably is significantly reduced on evaporator 146, which preferably leads to a longer life of evaporator 146.

FIG. 5 shows a longitudinal cross-sectional view through another hot-gas desuperheater fitting 504 according to an alternately preferred embodiment of the present invention. Although most features of hot-gas desuperheater fitting 504 are repeated from preferred hot-gas desuperheater fitting 104, in hot-gas desuperheater fitting 504, rather than spacers 425, at least two spacers 525 are preferably used to reduce the diameter, as shown.

Spacer 525 preferably comprises at least one diameter-reducing coupler, as shown. Spacer 525 preferably comprises metal, preferably copper. Upon reading this specification, those skilled in the art will now appreciate that, under appropriate circumstances, considering such issues as future materials, equipment integrated with, thermal expansion variations, etc., other materials, such as for example, ceremets, metal alloys, future plastics, other than copper metals, etc., may suffice.

Injection portal spacer 545, similarly to injection portal spacer 428, preferably comprises at least one injection port 528, preferably eight injection ports 528, preferably substantially similar to injection port 128 in size and distribution. Injection port 528 preferably is preferably positioned on beveled portion of injection portal spacer 545, as shown.

Sealing spacer 526, similarly to sealing spacer 426, preferably seals off internal pre-injection chamber 122 at inlet-side of interior channel 120. Sealing spacer 526, however, also provides a beveled entrance to interior channel 120 for flow of high-temperature vapor 140.

Although applicant has described applicant's preferred embodiments of this invention, it will be understood that the broadest scope of this invention includes modifications such as diverse shapes, sizes, and materials. Such scope is limited only by the below claims as read in connection with the above specification. Further, many other advantages of applicant's invention will be apparent to those skilled in the art from the above descriptions and the below claims.

Claims (42)

1. A system, relating to cooling at least one superheated refrigerant fluid during at least one heat cycle, the system comprising:

a) at least one heat exchanger structured and arranged to exchange heat between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between the at least one cooling fluid and the at least one superheated refrigerant fluid;

b) at least one injector, structured and arranged to inject the at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in said at least one heat exchanger; and

c) at least one fluid mixer structured and arranged to mix the injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state;

d) wherein said at least one heat exchanger comprises at least one suction creator structured and arranged to create suction to draw the at least one cooling fluid into said at least one heat exchanger by decreasing localized pressure near said at least one injector; and

e) wherein said at least one suction creator assists injection by said at least one injector.

2. The system according to claim 1 wherein said at least one suction creator comprises at least one separator structured and arranged to physically separate the at least one cooling fluid from the at least one superheated refrigerant fluid, while allowing exchange of heat in said at least one heat exchanger by transmitting heat through said at least one separator.

3. The system according to claim 2 wherein said at least one suction creator comprises at least one tube.

4. The system according to claim 3 wherein said at least one tube is structured and arranged to:

a) contain flow of the at least one superheated refrigerant fluid inside said at least one tube; and

b) separate flow of the at least one cooling fluid substantially around at least one perimeter of said at least one tube.

5. The system according to claim 4 wherein said at least one injector is structured and arranged to inject the at least one cooling fluid into the at least one superheated refrigerant fluid substantially evenly around at least one perimeter of flow of the at least one superheated refrigerant fluid.

6. The system according to claim 4 wherein said at least one injector comprises at least one injector port.

7. The system according to claim 6 wherein said at least one injector comprises a plurality of said at least one injector ports evenly spaced about the perimeter of the flow of the at least one superheated refrigerant fluid.

8. The system according to claim 7 wherein, when connected to at least one discharge line, the diameter of said at least one injector port multiplied by the quantity of said plurality of said at least one injection ports comprises about the diameter of at least one discharge line.

9. The system according to claim 7 wherein the diameter of said at least one injector port comprises between about ⅛ inch and about ½ inch.

10. The system according to claim 9 wherein the diameter of said at least one injector port comprises about ⅜ inch.

11. The system according to claim 9 wherein the diameter of said at least one injector port comprises about ¼ inch.

12. The system according to claim 4 further comprising at least one outer container structured and arranged to contain the at least one cooling fluid substantially near said at least one separator.

13. The system according to claim 12 further comprising at least one discharge line structured and arranged to fit at least one discharge line.

14. The system according to claim 13 wherein said at least one suction creator is substantially cylindrical.

15. The system according to claim 13 wherein said at least one outer container is substantially cylindrical.

16. The system according to claim 15 wherein the difference between the diameter of the at least one discharge line and the diameter of said at least one suction creator comprises between about ½ inch and about ¼ inch.

17. The system according to claim 16 wherein the difference between the diameter of said at least one outer container and the diameter of said at least one suction creator comprises between about 2 inches and about 1 inch.

18. The system according to claim 17 wherein the diameter of said at least one outer container comprises about 2⅝ inches.

19. The system according to claim 18 wherein the diameter of the at least one discharge line comprises about ⅞ inches.

20. The system according to claim 19 wherein the diameter of said at least one suction creator comprises about ⅝ inches.

21. The system according to claim 18 wherein the diameter of the at least one discharge line comprises about 1⅛ inches.

22. The system according to claim 21 wherein the diameter of said at least one suction creator comprises about ⅞ inches.

23. The system according to claim 17 wherein the diameter of the at least one discharge line comprises about 1⅜ inches.

24. The system according to claim 23 wherein the diameter of said at least one suction creator comprises about 1⅛ inches.

25. The system according to claim 17 wherein the diameter of said at least one outer container comprises about 3⅛ inches.

26. The system according to claim 25 wherein the diameter of the at least one discharge line comprises about 1⅝ inches.

27. The system according to claim 26 wherein the diameter of said at least one suction creator comprises about 1⅜ inches.

28. The system according to claim 25 wherein the diameter of the at least one discharge line comprises about 2⅛ inches.

29. The system according to claim 28 wherein the diameter of said at least one suction creator comprises about 1⅝ inches.

30. The system according to claim 25 wherein the diameter of the at least one discharge line comprises about 2⅝ inches.

31. The system according to claim 30 wherein the diameter of said at least one suction creator comprises about 2⅛ inches.

32. The system according to claim 17 wherein the diameter of said at least one outer container comprises about 3⅝ inches.

33. The system according to claim 32 wherein the diameter of the at least one discharge line comprises about 3⅛ inches.

34. The system according to claim 33 wherein the diameter of said at least one suction creator comprises about 2⅝ inches.

35. The system according to claim 1 wherein said at least one injector comprises metal.

36. The system according to claim 35 wherein said at least one injector comprises brass.

37. The system according to claim 35 wherein said at least one injector comprises copper.

38. The system according to claim 1 wherein said at least one heat exchanger comprises metal.

39. The system according to claim 38 wherein said at least one heat exchanger comprises copper.

40. A method, relating to cooling at least one superheated refrigerant fluid during at least one heat cycle, the method comprising the steps of:

a) exchanging heat, in at least one heat exchanger, between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between the at least one cooling fluid and the at least one superheated refrigerant fluid;

b) injecting, using at least one injector, the at least one cooling fluid into the at least one superheated refrigerant fluid after the step of exchanging heat;

c) mixing the injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state; and

d) creating suction to draw the at least one cooling fluid into the at least one heat exchanger by decreasing localized pressure near the at least one injector;

e) wherein the suction assists injection by such at least one injector.

41. A system, relating to cooling at least one superheated refrigerant during at least one heat cycle, the system comprising:

a) heat exchanger means for exchanging heat between at least one cooling fluid and the at least one superheated refrigerant fluid to decrease temperature differential between the at least one cooling fluid and the at least one superheated refrigerant fluid;

b) injector means for injecting the at least one cooling fluid into the at least one superheated refrigerant fluid after exchange of heat in said at least one heat exchanger;

c) fluid mixer means for mixing the injected cooling fluid and the at least one superheated refrigerant fluid to produce at least one desuperheated refrigerant fluid having at least one state substantially near at least one saturated state;

d) wherein said heat exchanger means comprises suction creator means for creating suction to draw the at least one cooling fluid into said heat exchanger means by decreasing localized pressure near said injector means; and

e) wherein said suction creator means assists injection by said injector means.

42. A method, relating to cooling at least one superheated refrigerant batch during at least one heat cycle, such method comprising the steps of:

a) creating suction to draw at least one cooler refrigerant batch into heat exchange relationship with such at least one superheated refrigerant batch;

b) exchanging heat between the at least one superheated refrigerant batch and at least one cooler refrigerant batch to decrease temperature differential between the at least one superheated refrigerant batch and the at least one cooler refrigerant batch and form at least one cooler superheated refrigerant batch;

c) injecting the at least one cooler refrigerant batch into the at least one cooler superheated refrigerant batch after the step of exchanging heat; and

d) mixing the at least one cooler refrigerant batch and such at least one cooler superheated refrigerant batch to produce at least one desuperheated refrigerant batch having at least one portion substantially near at least one saturated state.

Fluid Flow And Heat Transfer In Wellbores Pdf Creator Online

US12/534,7982008-08-042009-08-03Refrigeration hot gas desuperheater systems Expired - Fee RelatedUS7882707B2 (en)

Priority Applications (3)

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US11488008Ptrue	2008-11-14	2008-11-14
US12/534,798US7882707B2 (en)	2008-08-04	2009-08-03	Refrigeration hot gas desuperheater systems
US12/909,018US7958739B1 (en)	2008-08-04	2010-10-21	Refrigeration hot gas desuperheater systems

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US20100024451A1US20100024451A1 (en)	2010-02-04
US12/534,798Expired - Fee RelatedUS7882707B2 (en)	2008-08-04	2009-08-03	Refrigeration hot gas desuperheater systems

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FR2957949B1 (en) *	2010-03-24	2012-10-26	Wws	Device for water contained in the air extraction system and machine for producing drinking water

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  On-site mass spectrometry for liquid and extracted gas analysis of drilling fluids Download PDF

  Info

  Publication number

  US20160160641A1

  US20160160641A1US14/906,511US201414906511AUS2016160641A1US 20160160641 A1US20160160641 A1US 20160160641A1US 201414906511 AUS201414906511 AUS 201414906511AUS 2016160641 A1US2016160641 A1US 2016160641A1

  Authority

  US

  United States

  Prior art keywords

  fluid sample

  system

  Mathew Dennis Rowe

  Halliburton Energy Services Inc

  Original Assignee

  Priority to PCT/US2013/056297priorityApplication filed by Halliburton Energy Services IncfiledPriority to PCT/US2014/021114prioritypatent/WO2015026394A1/en

  ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS).Publication of US20160160641A1publicationApplication status is Pendinglegal-status238000005553drillingMethods0ClaimsTitle215

• AbstractDescription230000015572biosynthetic processEffects0Claims238000005755formationMethods0Claims239000007789gasesSubstances0Claims239000000203mixturesSubstances0Claims239000000126substancesSubstances0Claims238000004868gas analysisMethods0Title2
• Description239000000969carrierSubstances0Description6
• Claims238000004891communicationMethods0Description21
• Claims238000004821distillationMethods0Description5
• Claims239000011499joint compoundSubstances0Description20
• Claims238000000197pyrolysisMethods0Description9
• Claims239000011257shell materialsSubstances0Description10
• Claims238000003786synthesisMethods0Description9
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Images

Classifications

• E—FIXED CONSTRUCTIONS
• E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
• E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
• E—FIXED CONSTRUCTIONS
• E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
• E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
• E—FIXED CONSTRUCTIONS
• E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
• E21B21/06—Arrangements for treating drilling fluids outside the borehole
• E21B21/067—Separating gases from drilling fluids
• E—FIXED CONSTRUCTIONS
• E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
• E21—EARTH DRILLING; MINING
• E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• E21B49/086—Withdrawing samples at the surface
• H—ELECTRICITY
• H01J—ELECTRIC DISCHARGE TUBES OR DISCHARGE LAMPS
• H01J49/0027—Methods for using particle spectrometers
• H—ELECTRICITY
• H01J—ELECTRIC DISCHARGE TUBES OR DISCHARGE LAMPS
• H01J49/26—Mass spectrometers or separator tubes
• H—ELECTRICITY
• H01J—ELECTRIC DISCHARGE TUBES OR DISCHARGE LAMPS
• H01J49/26—Mass spectrometers or separator tubes
• H01J49/40—Time-of-flight spectrometers

Abstract

An example method for analyzing drilling fluid used in a drilling operation within a subterranean formation may include receiving a drilling fluid sample from a flow of drilling fluid at a surface of the subterranean formation. A chemical composition of the drilling fluid sample may be determined using a mass spectrometer. A formation characteristic of the subterranean formation may be determined using the determined chemical composition. Determining the chemical composition of the drilling fluid sample may include determining the chemical composition of at least one of extracted gas from the drilling fluid sample and a liquid portion of the drilling fluid sample.

Description

CROSS REFERENCE TO RELATED APPLICATION
• The present application claims priority to International Application Number PCT/US2013/56297, filed on 22 Aug. 2013 and entitled “DRILLING FLUID ANALYSIS USING TIME-OF-FLIGHT MASS SPECTROMETRY,” which is incorporated by reference herein in its entirety for all purposes.
BACKGROUND
• During the drilling of subterranean wells, a fluid is typically circulated through a fluid circulation system comprising a drilling rig and fluid treatment/storage equipment located substantially at or near the surface of the well. The fluid is pumped by a fluid pump through the interior passage of a drill string, through a drill bit and back to the surface through the annulus between the well bore and the drill string. As the well is drilled, gasses and fluids from the formation may be released and captured in the fluid as it is circulated. In some instances, the gasses may be wholly or partially extracted from the fluid for analysis, and the fluids may otherwise be analyzed. The gas and fluid analysis may be used to determine characteristics about the formation. The sensitivity and speed of the gas and fluid analysis may affect the accuracy and reliability of the analysis data and, therefore, the accuracy of the formation characteristics determined using the analysis data.
FIGURES
• Some specific exemplary embodiments of the disclosure may be understood by referring, in part, to the following description and the accompanying drawings.
• FIG. 1 is a diagram of an example drilling system, according to aspects of the present disclosure.
• FIG. 2 is a block diagram of an example information handling system, according to aspects of the present disclosure.
• FIG. 3 is a block diagram of an example drilling fluid analyzer that extracts and analyzes gasses from a drilling fluid sample, according to aspects of the present disclosure
• FIG. 4 is a diagram of an example drilling fluid analyzer that prepares and analyzes liquids from a drilling fluid sample, according to aspects of the present disclosure
• FIG. 5 is a block diagram of an example mass spectrometer, according to aspects of the present disclosure.
• FIG. 6 is a diagram of an example time-of-flight mass spectrometer, according to aspects of the present disclosure.
• FIG. 7 is a chart of example mass spectra, according to aspects of the present disclosure.
• FIG. 8 is a diagram of an example offshore drilling system, according to aspects of the present disclosure.
• FIG. 9 is a diagram of an example offshore drilling system, according to aspects of the present disclosure.
• While embodiments of this disclosure have been depicted and described and are defined by reference to exemplary embodiments of the disclosure, such references do not imply a limitation on the disclosure, and no such limitation is to be inferred. The subject matter disclosed is capable of considerable modification, alteration, and equivalents in form and function, as will occur to those skilled in the pertinent art and having the benefit of this disclosure. The depicted and described embodiments of this disclosure are examples only, and not exhaustive of the scope of the disclosure.
DETAILED DESCRIPTION
• The present disclosure relates generally to well drilling operations and, more particularly, to on-site mass spectrometry for liquid and extracted gas analysis of drilling fluids.
• For purposes of this disclosure, an information handling system may include any instrumentality or aggregate of instrumentalities operable to compute, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for business, scientific, control, or other purposes. For example, an information handling system may be a personal computer, a network storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. The information handling system may include random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, ROM, and/or other types of nonvolatile memory. Additional components of the information handling system may include one or more disk drives, one or more network ports for communication with external devices as well as various input and output (I/O) devices, such as a keyboard, a mouse, and a video display. The information handling system may also include one or more buses operable to transmit communications between the various hardware components. It may also include one or more interface units capable of transmitting one or more signals to a controller, actuator, or like device.
• For the purposes of this disclosure, computer-readable media may include any instrumentality or aggregation of instrumentalities that may retain data and/or instructions for a period of time. Computer-readable media may include, for example, without limitation, storage media such as a direct access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and/or flash memory; as well as communications media such wires, optical fibers, microwaves, radio waves, and other electromagnetic and/or optical carriers; and/or any combination of the foregoing.
• Illustrative embodiments of the present disclosure are described in detail herein. In the interest of clarity, not all features of an actual implementation may be described in this specification. It will of course be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the specific implementation goals, which will vary from one implementation to another. Moreover, it will be appreciated that such a development effort might be complex and time-consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of the present disclosure.
• To facilitate a better understanding of the present disclosure, the following examples of certain embodiments are given. In no way should the following examples be read to limit, or define, the scope of the disclosure. Embodiments of the present disclosure may be applicable to drilling operations that include, but are not limited to, target (such as an adjacent well) following, target intersecting, target locating, well twinning such as in SAGD (steam assist gravity drainage) well structures, drilling relief wells for blowout wells, river crossings, construction tunneling, as well as horizontal, vertical, deviated, multilateral, u-tube connection, intersection, bypass (drill around a mid-depth stuck fish and back into the well below), or otherwise nonlinear wellbores in any type of subterranean formation. Embodiments may be applicable to injection wells, stimulation wells, and production wells, including natural resource production wells such as hydrogen sulfide, hydrocarbons or geothermal wells; as well as borehole construction for river crossing tunneling and other such tunneling boreholes for near surface construction purposes or borehole u-tube pipelines used for the transportation of fluids such as hydrocarbons. Embodiments described below with respect to one implementation are not intended to be limiting.
• Modern petroleum drilling and production operations demand information relating to parameters and conditions downhole. Several methods exist for downhole information collection, including logging-while-drilling (“LWD”) and measurement-while-drilling (“MWD”). In LWD, data is typically collected during the drilling process, thereby avoiding any need to remove the drilling assembly to insert a wireline logging tool. LWD consequently allows the driller to make accurate real-time modifications or corrections to optimize performance while minimizing downtime. MWD is the term for measuring conditions downhole concerning the movement and location of the drilling assembly while the drilling continues. LWD concentrates more on formation parameter measurement. While distinctions between MWD and LWD may exist, the terms MWD and LWD often are used interchangeably. For the purposes of this disclosure, the term LWD will be used with the understanding that this term encompasses both the collection of formation parameters and the collection of information relating to the movement and position of the drilling assembly.
• The terms “couple” or “couples” as used herein are intended to mean either an indirect or a direct connection. Thus, if a first device couples to a second device, that connection may be through a direct connection or through an indirect mechanical or electrical connection via other devices and connections. Similarly, the term “communicatively coupled” as used herein is intended to mean either a direct or an indirect communication connection. Such connection may be a wired or wireless connection such as, for example, Ethernet or LAN. Thus, if a first device communicatively couples to a second device, that connection may be through a direct connection, or through an indirect communication connection via other devices and connections. The indefinite articles “a” or “an,” as used herein, are defined herein to mean one or more than one of the elements that it introduces. The terms “gas” or “fluid,” as used herein, are not limiting and are used interchangeably to describe a gas, a liquid, a solid, or some combination of a gas, a liquid, and/or a solid.
• FIG. 1 is a diagram illustrating an example drilling system 100, according to aspects of the present disclosure. In the embodiment shown, the system 100 comprises a derrick 102 mounted on a floor 104 that is in contact with the surface 106 of a formation 108 through supports 110. The formation 108 may be comprised of a plurality of rock strata 108a-e, each of which may be made of different rock types with different characteristics. At least some of the strata may be porous and contain trapped liquids and gasses 108a-e. Although the system 100 comprises an “on-shore” drilling system in which floor 104 is at or near the surface, similar “off-shore” drilling systems are also possible and may be characterized by the floor 104 being separated by the surface 106 by a volume of water.
• The derrick 102 may comprise a traveling block 112 for raising or lowering a drill string 114 disposed within a borehole 116 in the formation 108. A motor 118 may control the position of the traveling block 112 and, therefore, the drill string 114. A swivel 120 may be connected between the traveling block 112 and a kelly 122, which supports the drill string 114 as it is lowered through a rotary table 124. A drill bit 126 may be coupled to the drill string 114 and driven by a downhole motor (not shown) and/or rotation of the drill string 114 by the rotary table 124. As bit 126 rotates, it creates the borehole 116, which passes through one or more rock strata or layers of the formation 108.
• The drill string 114 may extend downwardly through a bell nipple 128, blow-out preventer (BOP) 130, and wellhead 132 into the borehole 116. The wellhead 132 may include a portion that extends into the borehole 116. In certain embodiments, the wellhead 132 may be secured within the borehole 116 using cement. The BOP 130 may be coupled to the wellhead 132 and the bell nipple 128, and may work with the bell nipple 128 to prevent excess pressures from the formation 108 and borehole 116 from being released at the surface 106. For example, the BOP 130 may comprise a ram-type BOP that closes the annulus between the drill string 114 and the borehole 116 in case of a blowout.
• During drilling operations, drilling fluid, such as drilling mud, may be pumped into and received from the borehole 116. In certain embodiments, this drilling fluid may be pumped and received by a fluid circulation system 190 at the surface 106 of the formation 108. As used herein, a fluid circulation system 190 may be positioned at the surface if it is arranged at or above the surface level. In the embodiment shown, the fluid circulation system 190 may comprise the fluid circulation, processing, and control elements between the bell nipple 128 and the swivel 120, as will be described below. Specifically, the fluid circulation system 190 may include a mud pump 134 that may pump drilling fluid from a reservoir 136 through a suction line 138 into the drill string 114 at the swivel 120 through one or more fluid conduits, including pipe 140, stand-pipe 142, and hose 144. Once introduced at the swivel 120, the drilling mud then may flow downhole through the drill string 114, exiting at the drill bit 126 and returning up through an annulus 146 between the drill string 114 and the borehole 116 in an open-hole embodiments, or between the drill string 114 and a casing (not shown) in a cased borehole embodiment. While in the borehole 116, the drilling mud may capture fluids and gasses from the formation 108 as well as particulates or cuttings that are generated by the drill bit 126 engaging with the formation 108.
• In certain embodiments, the fluid circulation system 190 further may comprise a return line 148 coupled to the bell nipple 128. Drilling fluid may flow through the return line 148 as it exits the annulus 146 via the bell nipple 128. The fluid circulation system 190 further may comprise one or more fluid treatment mechanisms coupled to the return line 148 that may separate the particulates from the returning drilling mud before returning the drilling mud to the reservoir 136, where it can be recirculated through the drilling system 100. In the embodiment shown, the fluid treatment mechanisms may comprise a mud tank 150 (which may also be referred to as a header box or possum belly) and a shale shaker 152. The mud tank 150 may receive the flow of drilling mud from the annulus 146 and slow it so that the drilling mud does not shoot past the shale shaker 152. The mud tank 150 may also allow for cuttings to settle and gasses to be released. In certain embodiments, the mud tank 150 may comprise a gumbo trap or box 150a, which captures heavy clay particulates before the drilling mud moves to the shale shaker 152, which may separate fine particulates from the drilling mud using screens. The drilling mud may flow from the fluid treatment mechanisms into the reservoir 136 through fluid conduit 154.
• According to aspects of the present disclosure, the system 100 may further include a drilling fluid analyzer 158 that receives drilling fluid samples from the drilling system 100 and analyzes the liquid portions of the drilling fluid or extracts and analyzes gases within the drilling fluid, which can in turn be used to characterize the formation 108. The drilling fluid analyzer 158 may comprise a stand-alone machine or mechanism or may comprise integrated functionality of a larger analysis/extraction mechanism. The drilling fluid analyzer 158 may be in fluid communication with and take drilling fluid samples from the fluid circulation system 190, including, but not limited to, access point 160a on the return line 148, access point 160b on the mud tank 150, access point 160c on the gumbo box 150a, access point 160d on the shale shaker 152, access point 160e on the suction line 138, access point 160f on the pipe 140, and access point 160g on the stand pipe 142. Fluid communication may be provided via at least one probe in fluid communication with the flow of drilling fluid at any one of the access points. In other embodiments, the drilling fluid analyzer 158 may coupled to one or more of the fluid channels such that the flow of drilling fluid passes through the drilling fluid analyzer 158.
• At least some of the strata 108a-e may contain trapped fluids and gasses that are held under pressure. As the borehole 116 penetrates new strata, some of these fluids may be released into the borehole 116. The released fluids may become suspended or dissolved in the drilling fluid as it exits the drill bit 126 and travels through the borehole annulus 146. Each released fluid and gas may be characterized by its chemical composition, and certain formation strata may be identified by the fluids and gasses it contains. As will be described below, the drilling fluid analyzer 158 may take periodic or continuous samples of the drilling fluid, for example, by pumping, gravity drain or diversion of flow, or other means. The drilling fluid analyzer 158 may generate corresponding measurements of the fluid sample or extracted gas from the fluid sample that may be used to determine the chemical composition of the drilling fluid. This chemical composition may be used to determine the types of fluids and gasses that are suspended within the drilling fluid, which can then be used to determine a formation characteristic of the formation 105.
• The drilling fluid analyzer 158 may include or be communicably coupled to an information handling system 160. In the embodiment shown, the information handling system 160 comprises a computing system located at the surface that may receive measurements from the drilling fluid analyzer 158 and process the measurements to determine at least one formation characteristic based on the drilling fluid sample. In certain embodiments, the information handling system 160 may further control the operation of the drilling fluid analyzer 158, including how often the drilling fluid analyzer 158 take measurements and fluid samples. In certain embodiments, the information handling system 160 may be dedicated to the drilling fluid analyzer 158. In other embodiments, the information handling system 160 may receive measurements from a variety of devices in the drilling system 100 and/or control the operation of other devices.
• The output of the drilling fluid analyzer 158 may comprise electrical signals or data that corresponds to measurements taken by the drilling fluid analyzer 158 of liquids and/or extracted gases from the drilling fluid samples. In certain embodiments, the information handling system 160 may receive the output from the drilling fluid analyzer 158 and determine characteristics of the liquid and/or extracted gas is the drilling fluid sample, such as corresponding chemical compositions. The chemical compositions of the drilling fluid may comprise the types of chemicals found in the drilling fluid sample and extracted gasses from drilling fluid sample and their relative concentrations. The information handling system 160 may determine the chemical composition, for example, by receiving an output from drilling fluid analyzer 158, and comparing the output to a first data set corresponding to known chemical compositions. In certain embodiments, the information handling system 160 may fully characterize the chemical composition of the drilling fluid sample based on the output from the drilling fluid analyzer 158. The information handling system 160 may further determine the types of fluids and gasses suspended within the drill fluid based on the determined chemical composition. Additionally, in certain embodiments, the information handling system 160 may determine a characteristic of the formation 108 using the determined types and concentrations of fluids and gasses suspended within the drill fluid by comparing the determined types and concentrations of fluids and gasses suspended within the drill fluid to a second data set the includes types and concentrations of fluids and gasses suspended within the drilling fluid of known subterranean formations.
• For example, the information handling system 160 may determine a formation characteristic using the determined chemical composition. An example determined chemical composition for the liquid portion of a drilling fluid may be 15% chemical/compound A, 20% chemical/compound B, 60% chemical/compound C, and 5% other chemicals/compounds. Example downhole characteristics include, but are not limited to, the type of rock in the formation 108, the presences of hydrocarbons in the formation 108, the production potential for a strata 108a-e of the formation 108, and the movement of fluid within a strata 108a-e. In certain embodiments, the information handling system 160 may determine the formation characteristic using the determined chemical composition characteristics by comparing the determined chemical composition to a second data set the includes chemical compositions of known subterranean formations. For example, the determined chemical composition may correspond to a drilling fluid with suspended fluid from a shale layer in the formation 108.
• FIG. 2 is a block diagram showing an example information handling system 200, according to aspects of the present disclosure. A processor or CPU 201 of the information handling system 200 is communicatively coupled to a memory controller hub or north bridge 202. Memory controller hub 202 may include a memory controller for directing information to or from various system memory components within the information handling system, such as
• RAM 203, storage element 206, and hard drive 207. The memory controller hub 202 may be coupled to RAM 203 and a graphics processing unit 204. Memory controller hub 202 may also be coupled to an I/O controller hub or south bridge 205. I/O hub 205 is coupled to storage elements of the computer system, including a storage element 206, which may comprise a flash ROM that includes a basic input/output system (BIOS) of the computer system. I/O hub 205 is also coupled to the hard drive 207 of the computer system. I/O hub 205 may also be coupled to a Super I/O chip 208, which is itself coupled to several of the I/O ports of the computer system, including keyboard 209 and mouse 210. In certain embodiments, the Super I/O chip may also be connected to and receive input from a liquid and/or extracted gas analyzer, similar to drilling fluid analyzer 158 from FIG. 1. Additionally, at least one memory component of the information handling system 200, such as the hard drive 207, may contain a set of instructions that, when executed by the processor 201, cause the processor 201 to perform certain actions with respect to outputs received from a drilling fluid analyzer, such as determine a chemical composition of a drilling fluid sample or a characteristic of a corresponding formation.
• FIG. 3 is a diagram of an example drilling fluid analyzer 300 that extracts and analyzes gasses from a drilling fluid sample, according to aspects of the present disclosure. The analyzer 300 may be included with a drilling system at the surface of a formation, and may be in selective fluid communication with a flow of drilling fluid through the drilling system, such as at access points similar to those described above. In the embodiment shown, the analyzer 300 may receive a drilling fluid sample 302 through a fluid conduit or pipe 304 that is in selective fluid communication with the flow of drilling fluid. As described above, drilling fluid samples may be taken periodically or continuously from the flow of drilling fluid through a drilling system, and the drilling fluid sample 302 may comprise one of those continuous or periodic samples. The analyzer 300 may comprise a pump 306 that pushes the drilling fluid sample toward a sample-temperature control unit 308 of the analyzer 300. The sample-temperature control unit 308 may be configured to alter or maintain the temperature of the drilling fluid sample 302 at a set temperature, which may be hotter, cooler, or the same as the temperature of the sample 302 as it enters the analyzer 300. In the embodiment shown, the sample-temperature control unit 308 comprises a shell and tube heat exchanger with two sets of fluid inlets and outlets: first inlet and outlet 312 and 314, respectively, and second inlet and outlet 316 and 318, respectively. Each set of fluid inlets and outlets may correspond to a different, segregated fluid pathway through the shell 310. For example, the second inlet and outlet 316 and 318 may correspond to a fluid pathway comprising a system of sealed tubes (not shown) located within the shell 310, and the first inlet and outlet 312 and 314 may correspond to a fluid pathway in which fluid flows around the system of sealed tubes. The system of sealed tubes may comprise u-tubes, single-pass straight tubes, double-pass straight tubes, or other configurations that would be appreciated by one of ordinary skill in the art in view of this disclosure.
• In certain embodiments, the sample 302 may enter the shell 310 through fluid inlet 312 and exit through fluid outlet 314. A second fluid or gas may enter the shell 310 through fluid inlet 316 and exit through outlet 318. Either the second fluid or the sample 302 may flow through the system of sealed tubes. The second fluid may be at or near a desired set temperature for the sample 302, and energy transfer may occur between the sample 302 and the second fluid through the tubes, which may conduct thermal energy, until the sample 302 has reached the desired set temperature. Notably, although a shell and tube heat exchanger is described herein, the sample-temperature control unit 308 may comprise other types of heat exchangers, including, but not limited to, thermoelectric, electric, and finned tube heat exchanger that are driven by electricity, gas, or liquid; u-tube heat exchangers; and other heat exchangers that would be appreciated by one of ordinary skill in the art in view of this disclosure. Once at or near the set temperature, the sample 302 may be received at a gas extractor 320 of the analyzer 300, the gas extractor 320 being in fluid communication with the sample-temperature control unit 308. Example gas extractors include, but are not limited to, continuously stirred vessels, distillation columns, flash columns, separator columns, or any other vessel that allows for the separation and expansion of gas from liquids and solids. In the embodiment shown, the gas extractor 320 comprises a vessel 322 that receives the sample 302 through a fluid inlet 324 and further comprises a fluid outlet 326 through which a portion of the sample 302 will flow after a gas extraction process. The gas extractor 320 may further comprise an impeller 332 within the vessel 322 to agitate the sample 302 as it enters the vessel 322. The impeller 332 may be driven by a motor 334 that rotates the impeller to create a turbulent flow of the sample 302 within the vessel, which causes gasses trapped within the solids and liquids of the sample 302 to be released into the vessel 322. Although an impeller 332 is shown it is possible to use other agitators that would be appreciated by one of ordinary skill in the art in view of this disclosure.
• Gasses within the vessel 322 that are released from the sample 302 through the agitation process may be removed from the vessel through a gas outlet 330. In certain embodiments, the vessel 322 may comprise a gas inlet 328, and at least one carrier gas may be introduced into the vessel 322 through the gas inlet 328. Carrier gasses may comprise atmospheric or purified gasses that are introduced into the vessel 322 to aide in the movement of the extracted gasses to the outlet 330. The carrier gasses may have known chemical compositions such that their presence can be accounted for when the extracted gasses are analyzed.
• Although the sample-temperature control unit 308 and gas extractor 320 are shown as separate devices, it may be possible to combine the functionality into a single device. For example, heat exchange may be accomplished through the vessel 322, bringing the sample 302 to a set temperature while it is in the vessel 322. In other embodiments, the sample-temperature control unit 308 may be optional, and the sample 302 may be directed to the extractor 320 without flowing through a sample-temperature control unit 308.
• In certain embodiments, the gas outlet 330 of the extractor 320 may be coupled to a pump 336 which may deliver the extracted gas sample from the extractor 320 to a mass spectrometer 338 either constantly or at specified intervals. The pump 336 may comprise a piston pump, positive displacement pump or other type of pump. The mass spectrometer 338 may determine mass-to-charge ratios for the extracted gas sample, which may be communicated to an information handling system 340 that is communicatively coupled to the mass spectrometer. The information handling system 340 may comprise an information handling system dedicated to the analyzer 300, or may comprise the information handling system for a drilling system, as described above. In certain embodiments, the information handling system 340 may be communicatively coupled to other elements of the analyzer 300 (e.g., the pump 306, sample-temperature control unit 308, extractor 320, and pump 346) and may receive data from the elements and/or generate control signals to the elements.
• FIG. 4 is a diagram of an example drilling fluid analyzer 400 that analyzes liquids from a drilling fluid sample, according to aspects of the present disclosure. The analyzer 400 may be included with a drilling system at the surface of a formation, and may be in selective fluid communication with a flow of drilling fluid through the drilling system, such as at access points similar to those described above. The analyzer 400 may be included or used in conjunction with an analyzer for extracting and analyzing gas from a drilling fluid sample, such as the analyzer described above with respect to FIG. 3.
• In the embodiment shown, the analyzer 400 may receive a drilling fluid sample 402 through a fluid conduit or pipe 404 that is in selective fluid communication with the flow of drilling fluid. As described above, drilling fluid samples may be taken periodically or continuously from the flow of drilling fluid through a drilling system, and the drilling fluid sample 402 may comprise one of those continuous or periodic samples. The drilling fluid sample 402 may be moved within the analyzer 400 using pump 406 in fluid communication with fluid conduit 404 and in selective fluid communication with a sample preparation unit 408, a pyrolysis unit 410, and a mass spectrometer 412 through a network of fluid conduits and valves 450a-h.
• Once past the pump 406, the sample may be sent to the sample preparation unit 408 by closing valve 450b; to the pyrolysis unit 410 by closing valves 450a, 450e, and 450g, and opening valves 450b, 450c, 450d and 450f; and directly to the mass spectrometer 412 by closing valves 450a, 450c, and 450h, and opening valves 450b and 450g. The sample preparation unit 408 may comprise systems and mechanisms that alter the liquid portion of the drilling fluid sample for analysis. The liquid preparations may include, but are not limited to, dilution of the liquid in a solvent, contact between the liquid with an immiscible solvent, aeration by atmospheric or purified gasses, or other liquid preparation techniques that would be appreciated by one of ordinary skill in the art in view of this disclosure. The pyrolysis unit 410 may thermochemically decompose organic material within the drilling fluid sample, which may aide in the analysis of the liquid portion of the drilling fluid sample at the mass spectrometer. Notably, in the embodiment shown, liquid that passes through sample preparation unit 408 may either be sent through the pyrolysis unit 410 before reaching the mass spectrometer by opening valves 450e and 450f and closing valve 450d, or sent directly to the mass spectrometer by closing valves 450b, 450f, and 450h and opening valves 450e, 450d, 450c, and 450g.
• As described above, the mass spectrometer 412 may determine mass-to-charge ratios for the liquid portion of the drilling fluid sample, which may be communicated to an information handling system 414 that is communicatively coupled to the mass spectrometer 412. The information handling system 414 may be dedicated to the analyzer 400, or may comprise the information handling system for a drilling system, as described above. In certain embodiments, the information handling system 414 may be communicatively coupled to other elements of the analyzer 400 (e.g., the sample preparation unit 408, pyrolysis unit 410, and valves 450a-h) and may receive data from the elements and/or generate control signals to the elements to control the fluid pathway for the liquid sample.
• The mass spectrometer described any mass spectrometer appreciated by one of ordinary skill in the art in view of this disclosure, including, but not limited to, a Time-of-Flight Mass Spectrometer (TOF-MS) and a Quadrupole Mass Spectrometer (QMS). FIG. 5 is a block diagram illustrating an example mass spectrometer 500, according to aspects of the present disclosure. The mass spectrometer 500 may be in fluid communication with a fluid or gas source 510, which may comprise, for example, one of the systems described above with respect to FIGS. 3 and 4. The mass spectrometer 500 may comprise a TOF-MS 501 and a pump 502. The TOF-MS 301 may comprise an ion creator 505, an ion separator 504, and an ion detector 503. In certain embodiments, the TOF-MS 501 may further comprise a control unit 508 communicably coupled to at least one of the ion creator 505, the ion separator 504, and the ion detector 503. The control unit 508 may comprise an information handling system with at least a processor and a memory device, and may direct commands to and/or receive measurements from at least one of the ion creator 505, the ion separator 504, and the ion detector 503. In certain embodiments, the control unit 508 may comprise or be communicably coupled to an information handling system similar to information handling system unit 160 in FIG. 1. The pump 502 may be coupled to and/or in fluid communication with at least a portion of the TOF-MS 501, and may create a vacuum chamber within the TOF-MS as will be described below. In certain embodiments, the pump 502 may comprise at least one of a roughing pump, a turbomolecular pump, and a molecular diffusion pump. Other ultra-high or high vacuum pumps may be used, as would be appreciated by one of ordinary skill in the art in view of this disclosure.
• FIG. 6 is a diagram of an example TOF-MS 600, according aspects of the present disclosure. The TOF-MS 600 may receive molecules 660 from the fluid source 650 at the ion creator 601. The ion creator 601 may then create ions 470 out of the molecules by either adding charge to or removing charge from the molecules. In certain embodiments, the ion creator 601 may create ions out of the molecules using at least one of electron impact ionization, chemical ionization, electrospray ionization, matrix-assisted laser desorption/ionization, inductively coupled plasma, glow discharge, field desorption, fast atom bombardment, thermospray, desorption/ionization on silicon, direct analysis in real time, atmospheric pressure chemical ionization, secondary ion mass spectrometry, spark ionization, and thermal ionization. The above list is not intended to be limiting, and other ionization techniques may be used, as would be appreciated by one of ordinary skill in the art in view of this disclosure.
• After the ions 670 are created in the ion creator 601, the ions 670 may be passed into an ion separator 604. The ion separator 604 may separate the ions 670 according to their mass-to-charge ratio. In certain embodiments, the ion separator 604 may comprise, for example, a linear flight tube 605 and a grid plate 606. The grid plate 606 may be coupled to a power source and may generate an electric field. As the ions 670 pass through the grid plate 606/electric field, an equal amount force may be imparted onto each of the ions 670, accelerating the ions 670 into the flight tube 605, toward the ion detector 607. Because the force applied to each ion 670 is the same, the acceleration of each ion 670 and its resulting velocity depends on the mass of the ion. Lighter ions will be accelerated more and travel faster than heavier ions when the same force is applied. Likewise, ions of the same mass will be accelerated at the same rate and travel the same speed. Accordingly, the ions 670 will are effectively separated according to their mass, because the net charge of each ion 670 will be the same.
• The accelerated ions 670 will travel within the flight tube 605 until they contact the ion detector 607. The ion detector 607 may generate an output that identifies when the ions 670 contact the ion detector 670. In certain embodiments, the ion detector 607 may generate current or voltage each time an ion 670 contacts the ion detector 607. The output may comprise the resulting electrical signal from the ion detector 670, which includes a series of voltage or current spikes spaced apart in time. The time between the voltage or current spikes in the output signal may correspond to the time between when certain of the ions 670 struck the ion detector 607. The amplitude of the voltage or current spikes may correspond to the number of ions 670 that struck the ion detector 607 at a given time. Example ion detectors include, but are not limited to, secondary emission multipliers, faraday cups, and multichannel plate detectors.
• In certain embodiments, the flight tube 605 may comprise a vacuum chamber and a pump 680 may be in fluid communication with the flight tube 605 to generate the vacuum. By removing air from the flight tube 605, the possibility that one of the ions 670 strikes an air molecule is reduced. If the ions 670 strike extraneous molecules while they are traveling within the flight tube 605, they will be deflected, increasing the time it takes from the ions 670 to reach to ion detector 607 (if they do at all) and negatively affecting the accuracy of the output. In certain embodiments, the pump 680 may comprise at least one of a turbomolecular pump and a molecular diffusion pump. The turbomolecular pump and/or the molecular diffusion pump may generate a primary vacuum within the flight tube 605. In certain embodiments, the turbomolecular pump and/or the molecular diffusion pump may be connected in series with a roughing pump that may increase or improve the vacuum within the flight tube 605.
• In certain embodiments, the output of the ion detector 607 may comprise the output of the TOF-MS 600. In certain other embodiments, though, the output of the ion detector 607 may be processed before it leaves the TOF-MS 600. For example, an information handling system 608 may be coupled to the ion detector 607 and may convert the output of the ion detector 607 into mass spectra. In certain embodiments, the information handling system 608 may also be coupled to the ion generator 601 and the grid plate 606. The information handling system 608 may receive an indication of the time at which the ions 670 are accelerated and may correlate the time to the time signature of the output of the ion detector 607, and particularly the time at which the various voltage or current spikes occurred. By correlating the time of acceleration with the time when the ions 670 contacted the ion detector 607, the information handling system may determine the mass of the ions 470 that contacted the ion detector 607 at a given time, because the strength of the accelerating force (the electric field) and the distance the ions 670 traveled (the length of the flight tube 605) are known. The resulting output may comprise mass spectra of the ions 670.
• FIG. 7 illustrates example mass spectra 700, with the mass-to-charge ratio of the received ions on the x-axis, and the amount of ions of a particular mass-to-charge ratio as a percentage of the ions received on the y-axis. The mass-to-charge ratio on the x-axis may correspond to the masses of various chemicals and compounds by their atomic mass units (AMU). As can be seen, the mass spectra may identify chemicals with AMUs above 140. In certain embodiments, the mass by AMU of the various ions may be extracted from the mass spectra 500, and the type of each ion may be determined by comparing its AMU to the known AMU of any chemical on the periodic table. The mass may be extracted, for example, using one or more deconvolution algorithms that would be appreciated by one of ordinary skill in view of this disclosure. Once the chemical composition of the drilling fluid is known, the fluids and gasses suspended within the drilling fluid may be determined by excluding those chemicals known to have been in the drilling fluid before the drilling fluid was introduced downhole. Additionally, once the types of fluid suspended within the drilling fluid are known, those fluids and gasses and corresponding chemical compositions may be correlated to a data set corresponding to known chemical compositions of subterranean formations, allowing for formation characteristics about the subterranean formation to be determined.
• Although the fluid analyzer/TOF-MS has been described herein in the context of a conventional drilling assembly positioned at the surface, the fluid and gas analyzer/TOF-MS may similarly be used with different drilling assemblies (e.g., wirelines, slickline, etc.) in different locations. FIG. 8 is a diagram of an offshore drilling system 800, according to aspects of the present disclosure. As can be seen, portions of the drilling system 800 may be positioned on a floating platform 801. A tubular 802 may extend from the platform 801 to the sea bed 803, where the well head 804 is located. A drill string 805 may be positioned within the tubular 802, and may be rotated to penetrate the formation 806. Drilling fluid may be circulated downhole within the drill string 805 and return to the surface in an annulus between the drill string 805 and the tubular 802. A proximal portion of the tubular 802 may comprise a fluid conduit 807 coupled thereto. The fluid conduit 807 may function as a fluid return, and a drilling fluid analyzer with a mass spectrometer 808, according to aspects of the present disclosure, may be coupled to the fluid conduit 807 and/or in fluid communication with a drilling fluid within the fluid conduit 807. Likewise, the fluid analyzer with mass spectrometer 808 may be communicable coupled to an information handling system 809 positioned on the platform 801.
• FIG. 9 is a diagram of a dual gradient offshore drilling system, according to aspects of the present disclosure. As can be seen, portions of the drilling system 900 may be positioned on a floating boat or platform 901. A riser 902 may extend from the platform 901 to the sea bed 903, where the well head 904 is located. A drill string 905 may be positioned within the riser 902 and a borehole 950 within the formation 906. The drill string 905 may pass through a sealed barrier 980 between the riser 902 and the borehole 905. The annulus 992 surrounding the drill string 905 within the riser 902 may be filled with sea water, and a first pump 952 located at the surface may circulate sea water within the riser 902. A second pump 954 positioned at the platform 901 may pump drilling fluid through the drill string 905. Once the drilling fluid exits the drill bit 956 into annulus 958, a third pump 960, located underwater, may pump the drilling fluid to the platform 901. A mass spectrometer may be incorporated at various locations within the system 900, including within pumps 954 and 960, in fluid communication with fluid conduits between pumps 954 and 960, or in fluid communication with fluid conduits between the pumps 954 and 960 and the drill string 905.
• According to aspects of the present disclosure, an example method for analyzing drilling fluid used in a drilling operation within a subterranean formation may include receiving a drilling fluid sample from a flow of drilling fluid at a surface of the subterranean formation. A chemical composition of the drilling fluid sample may be determined using a mass spectrometer. A formation characteristic of the subterranean formation may be determined using the determined chemical composition. Determining the chemical composition of the drilling fluid sample may include determining the chemical composition of at least one of extracted gas from the drilling fluid sample and a liquid portion of the drilling fluid sample.
• In certain embodiments, the method may include extracting gas from the drilling fluid sample using at least one of a continuously stirred vessel, distillation column, flash column, and separator column. The method further may include altering a temperature of the drilling fluid sample using at least one of a shell and tube heat exchanger, a thermoelectric heat exchanger, an electric heat exchanger, a finned tube heat exchanger, and a u-tube heat exchanger. Extracting gas from the drilling fluid sample may comprise introducing a carrier gas into the extracted gas. In certain embodiments, the method may further comprise altering the liquid portion of the drilling fluid sample. Altering the liquid portion of the drilling fluid sample may comprise at least one of diluting of the liquid portion in a solvent, contacting the liquid portion with an immiscible solvent, aerating the liquid portion with atmospheric or purified gasses, or performing pyrolysis on the liquid portion.
• Determining the formation characteristic using the determined chemical composition may comprise comparing the determined chemical composition to known chemical compositions of subterranean formations. The formation characteristics may comprise at least one of a type of rock in the subterranean formation, the presence of hydrocarbons in the subterranean formation, the production potential for a stratum of the subterranean formation, and the movement of fluid within the strata. Receiving the drilling fluid sample from the flow of drilling fluid at the surface of the subterranean formation may comprise receiving the drilling fluid sample from at least one of a return line, a mud tank, a gumbo box, a shale shaker, a suction line, and a stand pipe.
• According to aspects of the present disclosure, an example system for analyzing drilling fluid used in a drilling operation within a subterranean formation may include a fluid circulation system positioned at the surface of the subterranean formation and configured to pump a flow of drilling fluid into and receive the flow of drilling fluid from a borehole in the subterranean formation. A drilling fluid analyzer may be in fluid communication with the fluid circulation system to receive and analyze a drilling fluid sample from the flow of drilling fluid. The system may further include an information handling system comprising a processor and a memory device containing a set of instructions that, when executed by the processor, cause the processor to receive an output from the drilling fluid analyzer; determine a chemical composition of the drilling fluid sample; and determine a formation characteristic of the subterranean formation based, at least in part, on the determined chemical composition of the drilling fluid sample.
• In certain embodiments, the drilling fluid analyzer may analyze at least one of extracted gas from the drilling fluid sample and a liquid portion of the drilling fluid sample, and the set of instructions that causes the processor to determine the chemical composition of the drilling fluid sample may further cause the processor to determine the chemical composition of at least one of the extracted gas and the liquid portion. The drilling fluid analyzer may comprise at least one of a continuously stirred vessel, distillation column, flash column, and separator column. The drilling fluid analyzer may further comprise at least one of a shell and tube heat exchanger, a thermoelectric heat exchanger, an electric heat exchanger, a finned tube heat exchanger, and a u-tube heat exchanger. In certain embodiments, the drilling fluid analyzer may comprise a sample preparation unit that at least one of dilutes the liquid portion in a solvent, contacts the liquid portion with an immiscible solvent, aerates the liquid portion with atmospheric or purified gasses, and performs pyrolysis on the liquid portion.
• In certain embodiments, the set of instructions that causes the processor to determine the formation characteristic based, at least in part, on the determined chemical composition further may cause the processor to compare the determined chemical composition to known chemical compositions of subterranean formations. The formation characteristic may comprise at least one of a type of rock in the subterranean formation, the presence of hydrocarbons in the subterranean formation, the production potential for a stratum of the subterranean formation, and the movement of fluid within the strata. The drilling fluid analyzer may receive the drilling fluid sample at least one of continuously or periodically from the flow of drilling fluid. The fluid circulation system may comprise at least one of a return line, a mud tank, a gumbo box, a shale shaker, a suction line, and a stand pipe. And he drilling fluid analyzer may comprise a mass spectrometer
• Therefore, the present disclosure is well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular embodiments disclosed above are illustrative only, as the present disclosure may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. It is therefore evident that the particular illustrative embodiments disclosed above may be altered or modified and all such variations are considered within the scope and spirit of the present disclosure. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. The indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the element that it introduces.

Claims (20)

What is claimed is:1. A method for analyzing drilling fluid used in a drilling operation within a subterranean formation, comprising:
receiving a drilling fluid sample from a flow of drilling fluid at a surface of the subterranean formation;
determining a chemical composition of the drilling fluid sample using a mass spectrometer; and
determining a formation characteristic of the subterranean formation using the determined chemical composition.
2. The method of claim 1, wherein determining a chemical composition of the drilling fluid sample comprises determining the chemical composition of at least one of extracted gas from the drilling fluid sample and a liquid portion of the drilling fluid sample.
3. The method of claim 2, further comprising extracting gas from the drilling fluid sample using at least one of a continuously stirred vessel, distillation column, flash column, and separator column.
4. The method of claim 3, further comprising altering a temperature of the drilling fluid sample using at least one of a shell and tube heat exchanger, a thermoelectric heat exchanger, an electric heat exchanger, a finned tube heat exchanger, and a u-tube heat exchanger.
5. The method of claim 3, wherein extracting gas from the drilling fluid sample comprises introducing a carrier gas into the extracted gas.
6. The method of claim 2, further comprising altering the liquid portion of the drilling fluid sample.
7. The method of claim 6, wherein altering the liquid portion of the drilling fluid sample comprises at least one of diluting of the liquid portion in a solvent, contacting the liquid portion with an immiscible solvent, aerating the liquid portion with atmospheric or purified gasses, or performing pyrolysis on the liquid portion.
8. The method of claim 1, wherein determining the formation characteristic using the determined chemical composition comprises comparing the determined chemical composition to known chemical compositions of subterranean formations.
9. The method of claim 1, wherein the formation characteristic comprises at least one of a type of rock in the subterranean formation, the presence of hydrocarbons in the subterranean formation, the production potential for a strata of the subterranean formation, and the movement of fluid within the strata.
10. The method of claim 1, wherein receiving the drilling fluid sample from the flow of drilling fluid at the surface of the subterranean formation comprises receiving the drilling fluid sample from at least one of a return line, a mud tank, a gumbo box, a shale shaker, a suction line, and a stand pipe.
11. A system for analyzing drilling fluid used in a drilling operation within a subterranean formation, comprising:
a fluid circulation system positioned at the surface of the subterranean formation and configured to pump a flow of drilling fluid into and receive the flow of drilling fluid from a borehole in the subterranean formation;
a drilling fluid analyzer in fluid communication with the fluid circulation system to receive and analyze a drilling fluid sample from the flow of drilling fluid; and
an information handling system comprising a processor and a memory device containing a set of instructions that, when executed by the processor, cause the processor to
receive an output from the drilling fluid analyzer;
determine a chemical composition of the drilling fluid sample; and
determine a formation characteristic of the subterranean formation based, at least in part, on the determined chemical composition of the drilling fluid sample.
12. The system of claim 11, wherein
the drilling fluid analyzer analyzes at least one of extracted gas from the drilling fluid sample and a liquid portion of the drilling fluid sample; and
the set of instructions that causes the processor to determine the chemical composition of the drilling fluid sample further causes the processor to determine the chemical composition of at least one of the extracted gas and the liquid portion.
13. The system of claim 12, wherein the drilling fluid analyzer comprises at least one of a continuously stirred vessel, distillation column, flash column, and separator column.
14. The system of claim 13, wherein the drilling fluid analyzer further comprises at least one of a shell and tube heat exchanger, a thermoelectric heat exchanger, an electric heat exchanger, a finned tube heat exchanger, and a u-tube heat exchanger.
15. The system of claim 12, wherein the drilling fluid analyzer comprises a sample preparation unit that at least one of dilutes the liquid portion in a solvent, contacts the liquid portion with an immiscible solvent, aerates the liquid portion with atmospheric or purified gasses, and performs pyrolysis on the liquid portion.

Fluid Flow And Heat Transfer In Wellbores Pdf Creator Free

16. The system of claim 11, wherein the set of instructions that causes the processor to determine the formation characteristic based, at least in part, on the determined chemical composition further causes the processor to compare the determined chemical composition to known chemical compositions of subterranean formations.
17. The system of claim 11, wherein the formation characteristic comprises at least one of a type of rock in the subterranean formation, the presence of hydrocarbons in the subterranean formation, the production potential for a strata of the subterranean formation, and the movement of fluid within the strata.
18. The system of claim 11, wherein the drilling fluid analyzer receives the drilling fluid sample at least one of continuously or periodically from the flow of drilling fluid.
19. The system of claim 11, wherein the fluid circulation system comprises at least one of a return line, a mud tank, a gumbo box, a shale shaker, a suction line, and a stand pipe.
20. The system of claim 11, wherein the drilling fluid analyzer comprises a mass spectrometer.
US14/906,5112013-08-222014-03-06On-site mass spectrometry for liquid and extracted gas analysis of drilling fluids PendingUS20160160641A1 (en)

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PCT/US2014/021114WO2015026394A1 (en)	2013-08-22	2014-03-06	On-site mass spectrometry for liquid and extracted gas analysis of drilling fluids

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• 2014-03-06WOPCT/US2014/021114patent/WO2015026394A1/enactiveApplication Filing
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GB2531447A (en)	2016-04-20
WO2015026394A1 (en)	2015-02-26

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