Downhole tool, well system, and method for ammonia or methanol production

Abstract

Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof. The downhole tool, in another aspect, includes an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing there through to form methanol. The downhole tool, in another aspect, includes a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing.

Description

BACKGROUND

[0001] In pursuit of a clean energy transition, substantial resources are being devoted to the development of green processes for difficult to de-carbonize processes, such as steel production, cement production and ammonia production. Ammonia (“NH3”) is traditionally produced using the Haber-Bosch process, which combines nitrogen (“N2”) gas and hydrogen (“H2”) gas into ammonia at high pressure and temperature (e.g., at least 200 bar and 500° C.) by passing it over a suitable (e.g., iron) catalyst.

[0002] Unfortunately, significant energy is required to operating at such high gas pressures and temperatures results in high compression and heating energy consumption, making this challenging to decarbonize, particularly the heating requirements. While research has shown that increasing the reactor pressure can result in a lower operating pressure, increasing the pressure ratings of processing equipment can be costly to maintain and dangerous to operate.BRIEF DESCRIPTION

[0003] Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

[0004] FIGS. 1A through 1K depict various different views of a well system including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed; and

[0005] FIGS. 2A through 2K depict various different views of an alternative embodiment of a well system including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed.DETAILED DESCRIPTION

[0006] In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

[0007] Unless otherwise specified, use of the terms “connect,”“engage,”“couple,”“attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. Furthermore, unless otherwise specified, use of the terms “up,”“upper,”“upward,”“uphole,”“upstream,” or other like terms shall be construed as generally toward the surface of the subterranean formation; likewise, use of the terms “down,”“lower,”“downward,”“downhole,”“downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Additionally, unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

[0008] Various values and / or ranges are explicitly disclosed in certain embodiments herein. However, values / ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited. Similarly, values / ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited. In the same way, values / ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited. Similarly, an individual value disclosed herein may be combined with another individual value or range disclosed herein to form another range.

[0009] The term “approximately XYZ,” as used herein, means that it is within plus or minus 20 percent of perfectly XYZ. The term “substantially XYZ,” as used herein, means that it is within plus or minus 10 percent of perfectly XYZ. The term “significantly XYZ,” as used herein, means that it is within plus or minus 5 percent of perfectly XYZ. The term “ideally XYZ,” as used herein, means that it is within plus or minus 1 percent of perfectly XYZ. The monicker “XYZ” could refer to parallel, perpendicular, alignment, or other relative features disclosed herein.

[0010] The present disclosure is based, at least in part, on the manufacture of ammonia downhole, for example while addressing the clean energy issues discussed above. The present disclosure has recognized that one method for manufacturing ammonia, including creating the needed reaction pressure using minimal energy consumption desired to address the clean energy issues, includes using the pressure induced by a column of working fluid (e.g., H2O) to compress gas bubbles containing a mixture of N2 and H2. The column of fluid including the mixture of N2 and H2 can be circulated from surface down to depth (e.g., total depth, or TD) in a completion (e.g., cased hole completion) with the pumping horsepower tied primarily to the frictional losses, which requires much less energy than the traditional compression of the mixture of N2 and H2 uphole.

[0011] In the present disclosure, in at least one embodiment, the N2 gas could be produced using traditional means. In the present disclosure, in at least one embodiment, the H2 gas could be obtained from naturally producing geologic H2 formations or stimulated geologic H2 formations, among other possible places. For example, in at least one embodiment, the H2 gas is derived from excess CH4 (e.g., methane), as might be found in flue gas (e.g., the natural gas product of oil / gas wells), which may be obtained at a low cost in certain locations, such as the Permian Basin. In another example, the H2 gas is produced through the separation of water into oxygen and hydrogen such as through electrolyzation.

[0012] The N2 and H2 gas mixture, for example having been obtained using one or more of the processes disclosed above, could then be injected into a working fluid, such as H2O, increasing in pressure and temperature as it approached total depth (TD) (e.g., 2400 m to 3200 m). In at least one embodiment, a temperature differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 50° C. In yet another embodiment, the temperature differential of the gas mixture between the injection point into the wellbore and the location of the downhole tool is at least 100° C. In even yet another embodiment, the temperature differential of the gas mixture between the injection point into the wellbore and the location of the downhole tool is at least 250° C., if not at least 250° C. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 7 bar. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 34 bar. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 68 bar, if not 170 bar, if not 344 bar. The initial N2 and H2 gas laden fluid (e.g., ammonia working fluid mixture) could then pass through an array of pre-packed screens filled with an ammonia catalyst to induce the formation of ammonia. The ammonia worked fluid mixture (e.g., resulting gas laden fluid) could then be produced back to surface, the ammonia worked fluid mixture containing the worked fluid (e.g., H2O), N2, H2, and ammonia, for example along with heat (e.g., thermal energy). Once at surface the thermal energy can be harvested from the resulting ammonia worked fluid mixture (e.g., resulting gas laden fluid), along with the individual gasses being separated for storage (e.g., in the case ammonia) or re-injection (e.g., in the case of N2 and H2) along with the working fluid (e.g., H2O). Assuming for the moment that the ammonia worked fluid mixture (e.g., resulting gas laden fluid) reaches the surface at about 200° C., the chemical energy in the ammonia should equate to roughly 10× the energy per unit volume of the thermal energy contained in the ammonia worked fluid mixture (e.g., resulting gas laden fluid), which would traditionally be the only energy harvested from such a geothermal well.

[0013] While the above has been discussed with regard to the generation of ammonia, the same could be applied to the generation of methanol (CH3OH). For example, rather than the ammonia worked fluid mixture (e.g., resulting gas laden fluid) including N2 and H2, the methanol worked fluid mixture (e.g., resulting gas laden fluid) would include CO2 and H2. Accordingly, the methanol worked fluid mixture (e.g., resulting gas laden fluid) could then pass through an array of pre-packed screens filled with a methanol catalyst, thereby inducing the formation of methanol.

[0014] Turning now to FIGS. 1A through 1K, depicted are various different views of a well system 100 including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed. For example, the well system 100 could use a downhole tool designed, manufactured and / or operated according to one or more embodiments of the disclosure, for instance to produce ammonia or methanol, as disclosed in the following paragraphs. The embodiment of FIGS. 1A through 1K will be discussed as if the well system 100 were an ammonia producing well system. Nevertheless, as will be further understood below, the well system 100 could be configured as a methanol producing well system and remain within the scope of the disclosure.

[0015] The well system 100 illustrated in FIG. 1A includes a wellhead 102 (e.g., including an inlet 104 and an outlet 106) extending over and around a wellbore 108 formed through one or more subterranean formations 110. As those skilled in the art appreciate, the wellbore 108 may be fully cased, partially cased, or an open hole wellbore. In the illustrated embodiment of FIG. 1A, the wellbore 108 is partially cased, and thus includes a cased region 112a and an open hole region 112b. The cased region 112a, as depicted in the embodiment of FIG. 1A, may employ casing 114 that is held into place by cement 116.

[0016] The well system 100 illustrated in FIG. 1A additionally includes a downhole conveyance 118 deploying a downhole tool 130 within the wellbore 108. The downhole conveyance 118 can be, for example, tubing-conveyed, wireline (e.g., including spoolable line, such as multi-conductor, single conductor, slickline, braided line, sandline, etc.), coiled tubing, work string, or any other suitable means for conveying the downhole tool 130 into the wellbore 108. Nevertheless, in one or more exemplary embodiments, the downhole conveyance 118 is one of wireline or coiled tubing, but is not jointed tubing-conveyed, and thus for example is not being conveyed in this embodiment with American Petroleum Institute “API” pipe. The well system 100, in one or more embodiments, further includes a hydrogen generation unit 160 coupled to the inlet 104, as well as an ammonia extraction unit 180 coupled to the outlet 106.

[0017] Turning to FIG. 1B, illustrated is an enlarged view of one embodiment of the hydrogen generation unit 160 of FIG. 1A. In the illustrated embodiment, CH4 is provided to the hydrogen generation unit 160. In one or more embodiments, this CH4 may be obtained from the flue gas of an existing wellbore, but in other embodiments the CH4 is obtained from another source. In the illustrated embodiment, the CH4 is provided to a partial oxidation section 162 of the hydrogen generation unit 160, wherein the partial oxidation section 162 causes the CH4 to undergo partial oxidation to form CO+2H2. In one or more embodiments, the CO+2H2 is provided to a water / gas shift section 164, wherein the water / gas shift section 164 causes the CO+2H2 to form CO2+H2. In one or more embodiments, the CO2+H2 is provided to a separator section 166, the separator section 166 separating off the CO2 from the CO2+H2. In at least one embodiment, the well system 100 further includes a carbon capture section 168 (e.g., carbon capture, utilization, and storage (CCUS) section), which may entitle the owner / operator of the well system 100 to receive one or mor tax credits for carbon sequestration. The embodiment of FIG. 1B illustrates that the carbon capture section 168 forms a portion of the hydrogen generation unit 160, but in other embodiments the carbon capture section 168 forms another portion of the well system 100.

[0018] The hydrogen generation unit 160, in the illustrated embodiment, may further include a mixer section 170. In one or more embodiments, particularly when the hydrogen generation unit 160 is being employed for the production of ammonia, the mixer section 170 mixes the H2 from the separator section 166 and N2 to form ammonia reactive gas. As those skilled in the art appreciate, this ammonia reactive gas, when provided under suitable temperature and pressure and supplied to an ammonia reaction catalyst, produces ammonia. A suitable temperature and pressure depends on the acceptable rate of reaction and the acceptable percentage of ammonia at equilibrium. The equilibrium percentage of ammonia at 200° C. and 344 bar is approximately 100%, however the slow reaction rate results in a low production of ammonia. Operating at 425° C. at 100 bar yields a conversion rate of approximately 10% at a much higher rate of ammonia production. As a result, the operating temperature can range from approximately 100° C. to approximately 500° C. and is preferably between approximately 225° C. and approximately 400° C. The operating pressure can range from approximately 34 bar to approximately 550 bar and is preferably between approximately 69 bar and approximately 344 bar. The conversion rate into ammonia will vary from approximately 5% to approximately 100% and is preferably between approximately 10% and 50%. The N2 may be obtained from many different sources and / or processes, but as will be understood further below, the N2 may be obtained from excess N2 that is re-directed from the ammonia extraction unit 180.

[0019] It should be noted that while the embodiment of FIG. 1B illustrates that the H2 and N2 are mixed in the mixer section 170 uphole, other embodiments may exist wherein the H2 and N2 are provided within the wellbore 108 via separate conduits, and thus are mixed within the wellbore 108. For example, each of the H2 and N2 could be provided within the wellbore 108 via separate conduits such that the relative amounts of the H2 and N2 may be adjusted during the ammonia (methanol) production process. In at least one embodiment, the relative amounts of the H2 and N2 are adjusted based upon based on the downhole conditions proximate the downhole tool 130 (e.g., downhole temperature, downhole pressure, health of the catalyst, etc.) or alternatively adjusted based upon a measurement of the produced ammonia (e.g., and methanol in those embodiments).

[0020] In at least one embodiment, the ammonia reactive gas is heated and pressurized outside of the wellbore 108 (e.g., uphole) to a suitable temperature and pressure as disclosed above, and then provided downhole to the downhole tool 130. In yet another embodiment, however, the well system 100, and particularly the hydrogen generation unit 160, further includes a working fluid inlet section 172, the working fluid inlet section 172 including a gas diffuser 174 configured to diffuse the N2+H2 obtained from the hydrogen generation unit 160 within a working fluid (e.g., H2O) provided to the working fluid inlet section 172 to create a working fluid mixture, such as ammonia working fluid mixture 176.

[0021] The ammonia working fluid mixture 176, in the embodiment shown, may be provided to the downhole tool 130. In at least one embodiment, the aforementioned suitable temperature and pressure is achieved using minimal energy consumption. For example, as the ammonia working fluid mixture 176 approaches the downhole tool 130, the suitable temperature may be achieved. Similarly, as the ammonia working fluid mixture 176 approaches the downhole tool 130, the suitable pressure may be achieved, for example as the column of fluid continues to compresses the gas bubbles containing the N2+H2 obtained from the hydrogen generation unit 160. As discussed above, and will be discussed more below, the ammonia working fluid mixture 176 will then pass through the downhole tool 130, which includes the ammonia reaction catalyst in this embodiment, to induce the formation of ammonia.

[0022] Turning to FIG. 1C, illustrated is an enlarged view of one embodiment of the ammonia extraction unit 180 of FIG. 1A, as might receive ammonia worked fluid mixture 182 leaving the downhole tool 130, for example via the outlet 106. The ammonia worked fluid mixture 182, in the illustrated embodiment, includes worked fluid (e.g., H2O)+N2+H2+Ammonia+Heat, as illustrated in FIG. 1C. In at least one embodiment, the ammonia extraction unit 180 includes an energy extractor section 184, the energy extractor section 184 extracting energy (e.g., thermal energy) from the ammonia worked fluid mixture 182. Those skilled in the art understand the myriad of different processes that might be used to extract and / or harvest the energy from the ammonia worked fluid mixture 182. In at least one embodiment, the ammonia extraction unit 180 additionally includes a worked fluid separator 186, the worked fluid separator 186 separating the worked fluid (e.g., H2O in the disclosed embodiment) from the formed ammonia or methanol (e.g., ammonia in the disclosed embodiment). In at least one embodiment, the ammonia extraction unit 180 additionally includes an H2 separator 188, the H2 separator 188 separating excess H2 from the formed ammonia or methanol (e.g., ammonia in the disclosed embodiment). In at least one embodiment, the ammonia extraction unit 180 additionally includes an N2 separator 190, the N2 separator 190 separating excess N2 from the formed ammonia. It should be noted that the relative positioning of the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 may vary, although it may be advantageous for the ammonia worked fluid mixture 182 to first encounter the energy extractor section 184. Additionally, while the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 are illustrated as separate features, one or more of the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 may be combined into a single feature.

[0023] The resulting ammonia, in the illustrated embodiment, has been formed using much less energy. For example, by employing the downhole tool 130, and the inherent properties of the wellbore 108 to achieve the suitable temperatures and / or pressures, the resulting ammonia may be manufactured using a greatly reduced amount of energy. Additionally, the excess working fluid, H2, and N2 separated from the ammonia worked fluid mixture 182 may be recirculated back to the hydrogen generation unit 160, thereby saving additional resources and / or energy.

[0024] Turning to FIG. 1D, illustrated is a zoomed in view of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. FIG. 1D illustrates how the ammonia working fluid mixture 176 (e.g., received from the hydrogen generation unit 160) may travel to the downhole tool 130. In the illustrated embodiment, the ammonia working fluid mixture 176 initially travels down the wellbore 108 in an annulus 122 between a wellbore tubular 124 and the downhole tool 130 (e.g., a wireline retrievable inner string of the downhole tool 130 or coiled tubing of the downhole tool 130). At some point, likely after the ammonia working fluid mixture 176 has passed one or more isolation elements 126, the ammonia working fluid mixture 176 exits the annulus 122 through one or more flow ports 127a, into an annulus 128 between the wellbore tubular 124 and the casing 114. In the illustrated embodiment, the ammonia working fluid mixture 176 may then re-enter the annulus 122 via one or more re-entry ports 127b and encounter the downhole tool 130, for example below a point where the downhole tool 130 and the wellbore tubular 124 engage one another. In at least one embodiment, a plurality of re-entry ports 127b may be used, the plurality of re-entry ports 127b aiding in ensuring a consistent heat transfer from the formation into the ammonia working fluid mixture 176 and a consistent fluid transfer from the annular region into the other annular region and a distributed inlet of the working fluid into the catalysts. The one or more re-entry ports 127b may also contain a membrane or a catalyst in order to prepare the ammonia working fluid mixture 176 for the ammonia reaction.

[0025] In at least one embodiment, as shown, the downhole tool 130 includes a latch member 132 (e.g., coupled to the screen assembly of the downhole tool 130), the latch member 132 configured to allow the downhole tool 130 (e.g., including the wireline retrievable inner string of the downhole tool 130 or coiled tubing of the downhole tool 130) to be run within the wellbore tubular 124 via wireline or coiled tubing and couple with the wellbore tubular 124 to fix the downhole tool 130 (e.g., screen assembly of the downhole tool 130) at depth. In the illustrated embodiment, the latch member 132 includes a screen assembly landing nipple / screen assembly seal profile 134 configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile 129 of the wellbore tubular 124. In at least this one embodiment, the screen assembly landing nipple / screen assembly seal profile 134 and wellbore tubular landing nipple / wellbore tubular seal profile 129 engage one another to fix and seal the downhole tool 130 within the wellbore tubular 124. Thus, in one or more embodiments, the ammonia working fluid mixture 176 exits the annulus 122 into the annulus 128 above the latch member 132 and renters the annulus 122 from the annulus 128 to encounter the downhole tool 130 below the latch member 132, wherein the ammonia worked fluid mixture 182 may head to a surface of the wellbore (e.g., via the wireline retrievable inner string of the downhole tool 130).

[0026] Turning now to FIGS. 1E and 1F, illustrated are additional zoomed in views of one embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. In the illustrated embodiment of FIGS. 1E and 1F, the downhole tool 130 includes a screen assembly 136 (e.g., multi-stage screen assembly as shown in FIG. 1D). In one or more embodiments, the screen assembly 136 includes a screen 138 and screen tubular 140 concentrically placed. In the illustrated embodiment, the screen tubular 140 is concentrically placed about the screen 138, but the opposite could hold true in one or more embodiments.

[0027] Further to the embodiment of FIGS. 1E and 1F, the screen tubular 140 includes a plurality of spaced openings 142 coupling an inside surface and an outside surface thereof. In one or more embodiments, the plurality of spaced openings 142 are a plurality of inflow control devices. In one or more other embodiments, the plurality of inflow control devices are a plurality of fixed flow restrictors. For example, in one or more embodiments, the screen tubular 140 has an uphole end 144a and a downhole end 144b defining a length (L), and the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L). In at least one embodiment, the two or more rows of fixed flow restrictors increase in flow rate as they move from the uphole end 144a to the downhole end 144b.

[0028] In yet another embodiment, however, the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs). For example, in at least one embodiment, the plurality of inflow control devices are two or more rows of electronic inflow control devices (E-ICDs), and the downhole tool 130 further includes one or more poisoning / fouling sensors 146 associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors 146 configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof. In at least one embodiment, the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst. In yet another embodiment, the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst. In yet another embodiment, at least one of the one or more poisoning / fouling sensors 146 is a pressure sensor or a flow rate sensor that detects the flow restrictions that are indicative of poisoning and fouling. In yet another embodiment, yet other types of poisoning / fouling data is measured and / or used. In at least one embodiment, the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices.

[0029] In at least one other embodiment, the one or more poisoning / fouling sensors 146 may be used to provide poisoning / fouling data to a user of the well system. In at least one embodiment, the one or more poisoning / fouling sensors 146 may be used to determine when to remove / replace the removable / replaceable inflow control devices. For example, the one or more poisoning / fouling sensors 146 may be used to indicate that the removable / replaceable inflow control devices are fully or partially blocked, for example because of the poisoning / fouling of the ammonia or methanol reaction catalyst. In at least one other embodiment, the one or more poisoning / fouling sensors 146 may be used to determine when to remove / replace the ammonia or methanol reaction catalyst.

[0030] The downhole tool 130, in at least one embodiment, further includes an ammonia or methanol reaction catalyst 148 positioned in an annular space defined between the screen 138 and the screen tubular 140. In at least one embodiment, the ammonia reaction catalyst is configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst is configured to engage with methanol reactive gas passing there through to form methanol. In line with that disclosed above, the ammonia or methanol reaction catalyst 148 is an ammonia reaction catalyst in the embodiment of FIGS. 1A through 1K, and therefor may be used for the production of ammonia. Nevertheless, other embodiments exist wherein the ammonia or methanol reaction catalyst 148 is a methanol reaction catalyst (e.g., See FIGS. 2A through 2K). In at least one embodiment, the ammonia reaction catalyst employs an iron based catalyst such as Fe3O4-based catalyst, Fe1-xO based catalyst, or other parts of a fused-iron catalyst. In at least one other embodiment, the ammonia reaction catalyst employes an osmium based catalyst, cobalt-based catalyst, a metal nitride catalyst, a magnesium oxide based catalyst, an aluminum oxide based catalyst, or a ruthenium based catalyst. In another embodiment, the catalyst (such as 7% Fe / CeO2) has an electric field applied in order to increase the reaction rate and to allow significant production at a lower reactor temperature of approximately 100° C. In yet at least one other embodiment, the methanol reaction catalyst employs a copper based catalyst, a metal oxide based catalyst (such as zinc oxide, aluminum oxide, or magnesium oxide), a noble metal based catalyst (such as palladium platinum, zirconium, or rhodium). It should further be noted that in certain embodiments multiple different suitable catalysts are employed, whether in different stages or combined in a single stage.

[0031] In at least one embodiment, the ammonia catalysts and / or the methanol catalysts may be multi-promoted with promoters such as K2O, BaO, LiH, ZnO, and Al2O3. The promoters can be present in quantities of a few weight percentage, approximately 1% to 10%. Promoters are catalyst modifiers that provide the catalyst with structural and electronic promotion, such as preventing the aggregation of the iron catalyst particles, and increase the rate of the ammonia synthesis reaction. Multiple promoter compositions may be used.

[0032] In yet another embodiment, the downhole tool 130 further includes a wireline engagement member 150 coupled to the screen assembly 136. In at least this one embodiment, the wireline engagement member 150 is configured to engage with the wireline to run the downhole tool 130 within the wellbore 108. For example, the wireline engagement member 150 and the wireline could be used to remove a spent downhole tool 130 from the wellbore 108 (e.g., a downhole tool 130 no longer suitable for producing ammonia or methanol) and replace it with a new downhole tool 130 in the wellbore (e.g., a downhole tool 130 the is suitable for producing ammonia or methanol).

[0033] Turning now to FIGS. 1G and 1H, illustrated are additional zoomed in views of an alternative embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. The downhole tool 130 of FIGS. 1G and 1H is similar in many respects to the downhole tool 130 of FIGS. 1E and 1F. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole tool 130 of FIGS. 1G and 1H differs, for the most part, from the downhole tool 130 of FIGS. 1E and 1F, in that the screen 138 of the screen assembly 136 is a first screen, and the screen tubular 140 is a second screen. In at least this one embodiment, the ammonia or methanol reaction catalyst 148 is positioned in an annular space defined between the first screen (e.g., screen 138) and the second screen (e.g., screen tubular 140).

[0034] Turning now to FIGS. 1I and 1J, illustrated are additional zoomed in views of an alternative embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. The downhole tool 130 of FIGS. 1I and 1J is similar in many respects to the downhole tool 130 of FIGS. 1G and 1H. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole tool 130 of FIGS. 1I and 1J differs, for the most part, from the downhole tool 130 of FIGS. 1G and 1H, in that the downhole tool 130 of FIGS. 1I and 1J includes a guard catalyst 152 positioned upstream of one or more of the plurality of spaced openings 142 in the screen tubular 140. In one or more embodiments, the guard catalyst 152 is configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst. For example, in the embodiment of FIGS. 1I and 1J, the downhole tool 130 further includes a guard catalyst screen 154 positioned radially about the screen assembly 136, the guard catalyst 152 positioned in a second annular space defined between the guard catalyst screen 154 and the screen assembly 136. It should be noted that while the embodiment of FIGS. 1I and 1J illustrates the guard catalyst 152 and guard catalyst screen 154 employed with the screen assembly 136 of FIGS. 1G and 1H, the guard catalyst 152 and guard catalyst screen 154 could have easily been employed with the screen assembly 136 of FIGS. 1E and 1F. Furthermore, other embodiments may exist wherein the guard catalyst 152 is located at a different location inside or outside of the wellbore 108.

[0035] Turning briefly to FIG. 1K, illustrated is a zoomed in view of the ammonia working fluid mixture 176 of FIGS. 1A through 1J. As shown, bubbles of N2+H2 are surrounded by the column of working fluid, the column of working fluid pressurizing the bubbles of N2+H2 to the suitable pressure needed for the production of ammonia.

[0036] Turning now to FIGS. 2A through 2K, depicted are various different views of a well system 200 including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed. The well system 200 of FIGS. 2A through 2K is similar in many respects to the well system 100 of FIGS. 1A through 1K. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The well system 200 of FIGS. 2A through 2K differs, for the most part, from the well system 100 of FIGS. 1A through 1K, in that the well system 200 is configured for the production of methanol. Accordingly, the well system 200 employs a different hydrogen generation unit 260, a different downhole tool 230, and a different methanol extraction unit 280. For example, the hydrogen generation unit 260 does not require the separator section 166 or carbon capture section 168, as the hydrogen generation unit 260 employs the CO2 for the production of the methanol reaction gas. Accordingly, once the CO2 and H2 of the methanol reaction gas combine with the working fluid, the methanol working fluid mixture 276 results. Moreover, the downhole tool 130, in at least one embodiment, further includes a methanol reaction catalyst 248 positioned in an annular space defined between the screen 138 and the screen tubular 140, resulting in a methanol worked fluid mixture 282. Similarly, the methanol extraction unit 280 does not require the N2 separator 190, but requires a CO2 separator 290. The above changes result in the production of methanol, as opposed to ammonia.

[0037] Aspects disclosed herein include:

[0038] A. A downhole tool, the downhole tool including: 1) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; 2) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and 3) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth.

[0039] B. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; 2) a wellbore tubular position within the wellbore; 3) a downhole tool positioned within the wellbore tubular, the downhole tool, including: a) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; b) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and c) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; and 4) an inlet coupled to the wellbore, the inlet configured to provide the ammonia reactive gas or the methanol reactive gas to the downhole tool.

[0040] C. A method, the method including: 1) inserting a downhole tool within a wellbore tubular positioned within a wellbore extending through one or more subterranean formations, the downhole tool including: a) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; b) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and c) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; and 2) supplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, the wellbore providing the ammonia reactive gas or methanol reactive gas to the downhole tool to form ammonia or methanol.

[0041] Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: wherein the latch member includes a screen assembly landing nipple / screen assembly seal profile configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile of the wellbore tubular. Element 2: wherein the plurality of spaced openings are a plurality of inflow control devices. Element 3: wherein the plurality of inflow control devices are a plurality of fixed flow restrictors. Element 4: wherein the screen tubular has an uphole end and a downhole end defining a length (L), and further wherein the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L), the two or more rows of fixed flow restrictors increasing in flow rate as they move from the uphole end to the downhole end. Element 5: wherein the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs). Element 6: wherein the plurality of autonomous inflow control devices (A-ICDs) or the plurality of electronic inflow control devices (E-ICDs) are two or more rows of electronic inflow control devices (E-ICDs), and further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof. Element 7: wherein the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst. Element 8: wherein the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst. Element 9: wherein the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices. Element 10: further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to a user to determine when to remove / replace the removable / replaceable inflow control devices. Element 11: wherein the screen is a first screen and further wherein the screen tubular is a second screen placed radially about the first screen. Element 12: further including a guard catalyst positioned upstream of one or more of the plurality of spaced openings in the screen tubular, the guard catalyst configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or configured to remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst. Element 13: further including a guard catalyst screen positioned radially about the screen assembly, the guard catalyst positioned in a second annular space defined between the guard catalyst screen and the screen assembly. Element 14: wherein the screen assembly is a multi-stage screen assembly configured to promote geothermal energy harvesting. Element 15: wherein the latch member is configured to allow the screen assembly to be run within wellbore tubular via the wireline. Element 16: further including a wireline engagement member coupled to the screen assembly, the wireline engagement member configured to engage with the wireline to run the downhole tool within the wellbore tubular. Element 17: wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an iron based catalyst. Element 18: wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an osmium based catalyst, a uranium based catalyst, or a ruthenium based catalyst. Element 19: wherein the ammonia or methanol reaction catalyst is methanol reaction catalyst employing a copper based catalyst. Element 20: further including a hydrogen generation unit coupled to the inlet, the hydrogen generation unit configured to provide H2 of the ammonia reactive gas or the methanol reactive gas to the downhole tool. Element 21: wherein the hydrogen generation unit includes: a partial oxidation section, the partial oxidation section configured to form CO+2H2 from CH4; and a water / gas shift section, the water / gas shift section configured to form CO2+H2 from the CO+2H2. Element 22: further including a working fluid inlet section, the working fluid inlet section including a gas diffuser configured to diffuse the H2 obtained from the hydrogen generation unit within working fluid provided to the working fluid inlet section to create a working fluid mixture, such that the working fluid mixture may then be provided to the downhole tool. Element 23: wherein the hydrogen generation unit further includes: a separator section, the separator section configured to separate the CO2 from the CO2+H2; and a mixer section, the mixer section configured to mix the H2 from the separator section and N2 to form the ammonia reactive gas, the gas diffuser configured to diffuse the mixed H2 and N2 within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be provided to the downhole tool. Element 24: wherein the well system further includes a carbon capture section, the carbon capture section configured to capture the CO2 from the separator section. Element 25: wherein the gas diffuser is configured to diffuse the CO2+H2 comprising the methanol reactive gas within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be provided to the downhole tool. Element 26: wherein the working fluid inlet section is configured to provide H2O as the working fluid. Element 27: further including an outlet coupled to the wellbore, the outlet configured to allow ammonia worked fluid mixture or methanol worked fluid mixture to exit the wellbore. Element 28: further including an ammonia or methanol extraction unit coupled to the outlet. Element 29: wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 30: wherein the formed ammonia or methanol is at least partially diffused within the ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 31: wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol. Element 32: wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol. Element 33: wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia. Element 35: wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol. Element 36: wherein supplying H2 generated outside of the wellbore, includes supplying H2 generated with a hydrogen generation unit coupled to the inlet. Element 37: wherein the hydrogen generation unit includes: a partial oxidation section, the partial oxidation section forming CO+2H2 from CH4; and a water / gas shift section, the water / gas shift section forming CO2+H2 from the CO+2H2. Element 38: further including diffusing the H2 obtained from the hydrogen generation unit within a working fluid provided to a working fluid inlet section of the wellbore to create a working fluid mixture, such that the working fluid mixture may then be provided to the ammonia reaction catalyst or the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia or methanol. Element 39: wherein the hydrogen generation unit further includes: a separator section, the separator section separating the CO2 from the CO2+H2; and a mixer section, the mixer section mixing the H2 from the separator section and N2 to form the ammonia reactive gas. Element 40: wherein the hydrogen generation unit further includes a carbon capture section, and further including capturing the CO2 from the separator section using the carbon capture section. Element 41: wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and N2 obtained from the hydrogen generation unit within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be supplied to the ammonia reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia. Element 42: wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and CO2 obtained from the hydrogen generation unit within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be supplied to the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the methanol. Element 43: further including an outlet coupled to the wellbore, the outlet configured to allow the formed ammonia or methanol to exit the wellbore. Element 44: further including an ammonia or methanol extraction unit coupled to the outlet. Element 45: wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract thermal energy from the formed ammonia or methanol. Element 46: wherein the formed ammonia or methanol is at least partially diffused within the ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 47: wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol. Element 48: wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol. Element 49: wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia. Element 50: further including recirculating the excess H2 as a source for the supplying the H2. Element 51: wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol. Element 52: wherein supplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, includes supplying the ammonia reactive gas or methanol reactive gas to the inlet at an initial inlet temperature and pressure, and further wherein the wellbore increases the initial inlet temperature and pressure of the ammonia reactive gas or methanol reactive gas to the necessary temperature and pressure as the ammonia reactive gas or methanol reactive gas approach the downhole tool.

[0042] Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.

Examples

Embodiment Construction

[0006]In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

[0007]Unless otherwise specified,...

BACKGROUND

[0001] In pursuit of a clean energy transition, substantial resources are being devoted to the development of green processes for difficult to de-carbonize processes, such as steel production, cement production and ammonia production. Ammonia (“NH3”) is traditionally produced using the Haber-Bosch process, which combines nitrogen (“N2”) gas and hydrogen (“H2”) gas into ammonia at high pressure and temperature (e.g., at least 200 bar and 500° C.) by passing it over a suitable (e.g., iron) catalyst.

[0002] Unfortunately, significant energy is required to operating at such high gas pressures and temperatures results in high compression and heating energy consumption, making this challenging to decarbonize, particularly the heating requirements. While research has shown that increasing the reactor pressure can result in a lower operating pressure, increasing the pressure ratings of processing equipment can be costly to maintain and dangerous to operate.BRIEF DESCRIPTION

[0003] Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

[0004] FIGS. 1A through 1K depict various different views of a well system including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed; and

[0005] FIGS. 2A through 2K depict various different views of an alternative embodiment of a well system including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed.DETAILED DESCRIPTION

[0006] In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

[0007] Unless otherwise specified, use of the terms “connect,”“engage,”“couple,”“attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. Furthermore, unless otherwise specified, use of the terms “up,”“upper,”“upward,”“uphole,”“upstream,” or other like terms shall be construed as generally toward the surface of the subterranean formation; likewise, use of the terms “down,”“lower,”“downward,”“downhole,”“downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Additionally, unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

[0008] Various values and / or ranges are explicitly disclosed in certain embodiments herein. However, values / ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited. Similarly, values / ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited. In the same way, values / ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited. Similarly, an individual value disclosed herein may be combined with another individual value or range disclosed herein to form another range.

[0009] The term “approximately XYZ,” as used herein, means that it is within plus or minus 20 percent of perfectly XYZ. The term “substantially XYZ,” as used herein, means that it is within plus or minus 10 percent of perfectly XYZ. The term “significantly XYZ,” as used herein, means that it is within plus or minus 5 percent of perfectly XYZ. The term “ideally XYZ,” as used herein, means that it is within plus or minus 1 percent of perfectly XYZ. The monicker “XYZ” could refer to parallel, perpendicular, alignment, or other relative features disclosed herein.

[0010] The present disclosure is based, at least in part, on the manufacture of ammonia downhole, for example while addressing the clean energy issues discussed above. The present disclosure has recognized that one method for manufacturing ammonia, including creating the needed reaction pressure using minimal energy consumption desired to address the clean energy issues, includes using the pressure induced by a column of working fluid (e.g., H2O) to compress gas bubbles containing a mixture of N2 and H2. The column of fluid including the mixture of N2 and H2 can be circulated from surface down to depth (e.g., total depth, or TD) in a completion (e.g., cased hole completion) with the pumping horsepower tied primarily to the frictional losses, which requires much less energy than the traditional compression of the mixture of N2 and H2 uphole.

[0011] In the present disclosure, in at least one embodiment, the N2 gas could be produced using traditional means. In the present disclosure, in at least one embodiment, the H2 gas could be obtained from naturally producing geologic H2 formations or stimulated geologic H2 formations, among other possible places. For example, in at least one embodiment, the H2 gas is derived from excess CH4 (e.g., methane), as might be found in flue gas (e.g., the natural gas product of oil / gas wells), which may be obtained at a low cost in certain locations, such as the Permian Basin. In another example, the H2 gas is produced through the separation of water into oxygen and hydrogen such as through electrolyzation.

[0012] The N2 and H2 gas mixture, for example having been obtained using one or more of the processes disclosed above, could then be injected into a working fluid, such as H2O, increasing in pressure and temperature as it approached total depth (TD) (e.g., 2400 m to 3200 m). In at least one embodiment, a temperature differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 50° C. In yet another embodiment, the temperature differential of the gas mixture between the injection point into the wellbore and the location of the downhole tool is at least 100° C. In even yet another embodiment, the temperature differential of the gas mixture between the injection point into the wellbore and the location of the downhole tool is at least 250° C., if not at least 250° C. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 7 bar. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 34 bar. In yet another embodiment, a pressure differential of the gas mixture between an injection point into the wellbore and a location of the downhole tool is at least 68 bar, if not 170 bar, if not 344 bar. The initial N2 and H2 gas laden fluid (e.g., ammonia working fluid mixture) could then pass through an array of pre-packed screens filled with an ammonia catalyst to induce the formation of ammonia. The ammonia worked fluid mixture (e.g., resulting gas laden fluid) could then be produced back to surface, the ammonia worked fluid mixture containing the worked fluid (e.g., H2O), N2, H2, and ammonia, for example along with heat (e.g., thermal energy). Once at surface the thermal energy can be harvested from the resulting ammonia worked fluid mixture (e.g., resulting gas laden fluid), along with the individual gasses being separated for storage (e.g., in the case ammonia) or re-injection (e.g., in the case of N2 and H2) along with the working fluid (e.g., H2O). Assuming for the moment that the ammonia worked fluid mixture (e.g., resulting gas laden fluid) reaches the surface at about 200° C., the chemical energy in the ammonia should equate to roughly 10× the energy per unit volume of the thermal energy contained in the ammonia worked fluid mixture (e.g., resulting gas laden fluid), which would traditionally be the only energy harvested from such a geothermal well.

[0013] While the above has been discussed with regard to the generation of ammonia, the same could be applied to the generation of methanol (CH3OH). For example, rather than the ammonia worked fluid mixture (e.g., resulting gas laden fluid) including N2 and H2, the methanol worked fluid mixture (e.g., resulting gas laden fluid) would include CO2 and H2. Accordingly, the methanol worked fluid mixture (e.g., resulting gas laden fluid) could then pass through an array of pre-packed screens filled with a methanol catalyst, thereby inducing the formation of methanol.

[0014] Turning now to FIGS. 1A through 1K, depicted are various different views of a well system 100 including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed. For example, the well system 100 could use a downhole tool designed, manufactured and / or operated according to one or more embodiments of the disclosure, for instance to produce ammonia or methanol, as disclosed in the following paragraphs. The embodiment of FIGS. 1A through 1K will be discussed as if the well system 100 were an ammonia producing well system. Nevertheless, as will be further understood below, the well system 100 could be configured as a methanol producing well system and remain within the scope of the disclosure.

[0015] The well system 100 illustrated in FIG. 1A includes a wellhead 102 (e.g., including an inlet 104 and an outlet 106) extending over and around a wellbore 108 formed through one or more subterranean formations 110. As those skilled in the art appreciate, the wellbore 108 may be fully cased, partially cased, or an open hole wellbore. In the illustrated embodiment of FIG. 1A, the wellbore 108 is partially cased, and thus includes a cased region 112a and an open hole region 112b. The cased region 112a, as depicted in the embodiment of FIG. 1A, may employ casing 114 that is held into place by cement 116.

[0016] The well system 100 illustrated in FIG. 1A additionally includes a downhole conveyance 118 deploying a downhole tool 130 within the wellbore 108. The downhole conveyance 118 can be, for example, tubing-conveyed, wireline (e.g., including spoolable line, such as multi-conductor, single conductor, slickline, braided line, sandline, etc.), coiled tubing, work string, or any other suitable means for conveying the downhole tool 130 into the wellbore 108. Nevertheless, in one or more exemplary embodiments, the downhole conveyance 118 is one of wireline or coiled tubing, but is not jointed tubing-conveyed, and thus for example is not being conveyed in this embodiment with American Petroleum Institute “API” pipe. The well system 100, in one or more embodiments, further includes a hydrogen generation unit 160 coupled to the inlet 104, as well as an ammonia extraction unit 180 coupled to the outlet 106.

[0017] Turning to FIG. 1B, illustrated is an enlarged view of one embodiment of the hydrogen generation unit 160 of FIG. 1A. In the illustrated embodiment, CH4 is provided to the hydrogen generation unit 160. In one or more embodiments, this CH4 may be obtained from the flue gas of an existing wellbore, but in other embodiments the CH4 is obtained from another source. In the illustrated embodiment, the CH4 is provided to a partial oxidation section 162 of the hydrogen generation unit 160, wherein the partial oxidation section 162 causes the CH4 to undergo partial oxidation to form CO+2H2. In one or more embodiments, the CO+2H2 is provided to a water / gas shift section 164, wherein the water / gas shift section 164 causes the CO+2H2 to form CO2+H2. In one or more embodiments, the CO2+H2 is provided to a separator section 166, the separator section 166 separating off the CO2 from the CO2+H2. In at least one embodiment, the well system 100 further includes a carbon capture section 168 (e.g., carbon capture, utilization, and storage (CCUS) section), which may entitle the owner / operator of the well system 100 to receive one or mor tax credits for carbon sequestration. The embodiment of FIG. 1B illustrates that the carbon capture section 168 forms a portion of the hydrogen generation unit 160, but in other embodiments the carbon capture section 168 forms another portion of the well system 100.

[0018] The hydrogen generation unit 160, in the illustrated embodiment, may further include a mixer section 170. In one or more embodiments, particularly when the hydrogen generation unit 160 is being employed for the production of ammonia, the mixer section 170 mixes the H2 from the separator section 166 and N2 to form ammonia reactive gas. As those skilled in the art appreciate, this ammonia reactive gas, when provided under suitable temperature and pressure and supplied to an ammonia reaction catalyst, produces ammonia. A suitable temperature and pressure depends on the acceptable rate of reaction and the acceptable percentage of ammonia at equilibrium. The equilibrium percentage of ammonia at 200° C. and 344 bar is approximately 100%, however the slow reaction rate results in a low production of ammonia. Operating at 425° C. at 100 bar yields a conversion rate of approximately 10% at a much higher rate of ammonia production. As a result, the operating temperature can range from approximately 100° C. to approximately 500° C. and is preferably between approximately 225° C. and approximately 400° C. The operating pressure can range from approximately 34 bar to approximately 550 bar and is preferably between approximately 69 bar and approximately 344 bar. The conversion rate into ammonia will vary from approximately 5% to approximately 100% and is preferably between approximately 10% and 50%. The N2 may be obtained from many different sources and / or processes, but as will be understood further below, the N2 may be obtained from excess N2 that is re-directed from the ammonia extraction unit 180.

[0019] It should be noted that while the embodiment of FIG. 1B illustrates that the H2 and N2 are mixed in the mixer section 170 uphole, other embodiments may exist wherein the H2 and N2 are provided within the wellbore 108 via separate conduits, and thus are mixed within the wellbore 108. For example, each of the H2 and N2 could be provided within the wellbore 108 via separate conduits such that the relative amounts of the H2 and N2 may be adjusted during the ammonia (methanol) production process. In at least one embodiment, the relative amounts of the H2 and N2 are adjusted based upon based on the downhole conditions proximate the downhole tool 130 (e.g., downhole temperature, downhole pressure, health of the catalyst, etc.) or alternatively adjusted based upon a measurement of the produced ammonia (e.g., and methanol in those embodiments).

[0020] In at least one embodiment, the ammonia reactive gas is heated and pressurized outside of the wellbore 108 (e.g., uphole) to a suitable temperature and pressure as disclosed above, and then provided downhole to the downhole tool 130. In yet another embodiment, however, the well system 100, and particularly the hydrogen generation unit 160, further includes a working fluid inlet section 172, the working fluid inlet section 172 including a gas diffuser 174 configured to diffuse the N2+H2 obtained from the hydrogen generation unit 160 within a working fluid (e.g., H2O) provided to the working fluid inlet section 172 to create a working fluid mixture, such as ammonia working fluid mixture 176.

[0021] The ammonia working fluid mixture 176, in the embodiment shown, may be provided to the downhole tool 130. In at least one embodiment, the aforementioned suitable temperature and pressure is achieved using minimal energy consumption. For example, as the ammonia working fluid mixture 176 approaches the downhole tool 130, the suitable temperature may be achieved. Similarly, as the ammonia working fluid mixture 176 approaches the downhole tool 130, the suitable pressure may be achieved, for example as the column of fluid continues to compresses the gas bubbles containing the N2+H2 obtained from the hydrogen generation unit 160. As discussed above, and will be discussed more below, the ammonia working fluid mixture 176 will then pass through the downhole tool 130, which includes the ammonia reaction catalyst in this embodiment, to induce the formation of ammonia.

[0022] Turning to FIG. 1C, illustrated is an enlarged view of one embodiment of the ammonia extraction unit 180 of FIG. 1A, as might receive ammonia worked fluid mixture 182 leaving the downhole tool 130, for example via the outlet 106. The ammonia worked fluid mixture 182, in the illustrated embodiment, includes worked fluid (e.g., H2O)+N2+H2+Ammonia+Heat, as illustrated in FIG. 1C. In at least one embodiment, the ammonia extraction unit 180 includes an energy extractor section 184, the energy extractor section 184 extracting energy (e.g., thermal energy) from the ammonia worked fluid mixture 182. Those skilled in the art understand the myriad of different processes that might be used to extract and / or harvest the energy from the ammonia worked fluid mixture 182. In at least one embodiment, the ammonia extraction unit 180 additionally includes a worked fluid separator 186, the worked fluid separator 186 separating the worked fluid (e.g., H2O in the disclosed embodiment) from the formed ammonia or methanol (e.g., ammonia in the disclosed embodiment). In at least one embodiment, the ammonia extraction unit 180 additionally includes an H2 separator 188, the H2 separator 188 separating excess H2 from the formed ammonia or methanol (e.g., ammonia in the disclosed embodiment). In at least one embodiment, the ammonia extraction unit 180 additionally includes an N2 separator 190, the N2 separator 190 separating excess N2 from the formed ammonia. It should be noted that the relative positioning of the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 may vary, although it may be advantageous for the ammonia worked fluid mixture 182 to first encounter the energy extractor section 184. Additionally, while the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 are illustrated as separate features, one or more of the energy extractor section 184, worked fluid separator 186, H2 separator 188, and N2 separator 190 may be combined into a single feature.

[0023] The resulting ammonia, in the illustrated embodiment, has been formed using much less energy. For example, by employing the downhole tool 130, and the inherent properties of the wellbore 108 to achieve the suitable temperatures and / or pressures, the resulting ammonia may be manufactured using a greatly reduced amount of energy. Additionally, the excess working fluid, H2, and N2 separated from the ammonia worked fluid mixture 182 may be recirculated back to the hydrogen generation unit 160, thereby saving additional resources and / or energy.

[0024] Turning to FIG. 1D, illustrated is a zoomed in view of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. FIG. 1D illustrates how the ammonia working fluid mixture 176 (e.g., received from the hydrogen generation unit 160) may travel to the downhole tool 130. In the illustrated embodiment, the ammonia working fluid mixture 176 initially travels down the wellbore 108 in an annulus 122 between a wellbore tubular 124 and the downhole tool 130 (e.g., a wireline retrievable inner string of the downhole tool 130 or coiled tubing of the downhole tool 130). At some point, likely after the ammonia working fluid mixture 176 has passed one or more isolation elements 126, the ammonia working fluid mixture 176 exits the annulus 122 through one or more flow ports 127a, into an annulus 128 between the wellbore tubular 124 and the casing 114. In the illustrated embodiment, the ammonia working fluid mixture 176 may then re-enter the annulus 122 via one or more re-entry ports 127b and encounter the downhole tool 130, for example below a point where the downhole tool 130 and the wellbore tubular 124 engage one another. In at least one embodiment, a plurality of re-entry ports 127b may be used, the plurality of re-entry ports 127b aiding in ensuring a consistent heat transfer from the formation into the ammonia working fluid mixture 176 and a consistent fluid transfer from the annular region into the other annular region and a distributed inlet of the working fluid into the catalysts. The one or more re-entry ports 127b may also contain a membrane or a catalyst in order to prepare the ammonia working fluid mixture 176 for the ammonia reaction.

[0025] In at least one embodiment, as shown, the downhole tool 130 includes a latch member 132 (e.g., coupled to the screen assembly of the downhole tool 130), the latch member 132 configured to allow the downhole tool 130 (e.g., including the wireline retrievable inner string of the downhole tool 130 or coiled tubing of the downhole tool 130) to be run within the wellbore tubular 124 via wireline or coiled tubing and couple with the wellbore tubular 124 to fix the downhole tool 130 (e.g., screen assembly of the downhole tool 130) at depth. In the illustrated embodiment, the latch member 132 includes a screen assembly landing nipple / screen assembly seal profile 134 configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile 129 of the wellbore tubular 124. In at least this one embodiment, the screen assembly landing nipple / screen assembly seal profile 134 and wellbore tubular landing nipple / wellbore tubular seal profile 129 engage one another to fix and seal the downhole tool 130 within the wellbore tubular 124. Thus, in one or more embodiments, the ammonia working fluid mixture 176 exits the annulus 122 into the annulus 128 above the latch member 132 and renters the annulus 122 from the annulus 128 to encounter the downhole tool 130 below the latch member 132, wherein the ammonia worked fluid mixture 182 may head to a surface of the wellbore (e.g., via the wireline retrievable inner string of the downhole tool 130).

[0026] Turning now to FIGS. 1E and 1F, illustrated are additional zoomed in views of one embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. In the illustrated embodiment of FIGS. 1E and 1F, the downhole tool 130 includes a screen assembly 136 (e.g., multi-stage screen assembly as shown in FIG. 1D). In one or more embodiments, the screen assembly 136 includes a screen 138 and screen tubular 140 concentrically placed. In the illustrated embodiment, the screen tubular 140 is concentrically placed about the screen 138, but the opposite could hold true in one or more embodiments.

[0027] Further to the embodiment of FIGS. 1E and 1F, the screen tubular 140 includes a plurality of spaced openings 142 coupling an inside surface and an outside surface thereof. In one or more embodiments, the plurality of spaced openings 142 are a plurality of inflow control devices. In one or more other embodiments, the plurality of inflow control devices are a plurality of fixed flow restrictors. For example, in one or more embodiments, the screen tubular 140 has an uphole end 144a and a downhole end 144b defining a length (L), and the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L). In at least one embodiment, the two or more rows of fixed flow restrictors increase in flow rate as they move from the uphole end 144a to the downhole end 144b.

[0028] In yet another embodiment, however, the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs). For example, in at least one embodiment, the plurality of inflow control devices are two or more rows of electronic inflow control devices (E-ICDs), and the downhole tool 130 further includes one or more poisoning / fouling sensors 146 associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors 146 configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof. In at least one embodiment, the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst. In yet another embodiment, the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst. In yet another embodiment, at least one of the one or more poisoning / fouling sensors 146 is a pressure sensor or a flow rate sensor that detects the flow restrictions that are indicative of poisoning and fouling. In yet another embodiment, yet other types of poisoning / fouling data is measured and / or used. In at least one embodiment, the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices.

[0029] In at least one other embodiment, the one or more poisoning / fouling sensors 146 may be used to provide poisoning / fouling data to a user of the well system. In at least one embodiment, the one or more poisoning / fouling sensors 146 may be used to determine when to remove / replace the removable / replaceable inflow control devices. For example, the one or more poisoning / fouling sensors 146 may be used to indicate that the removable / replaceable inflow control devices are fully or partially blocked, for example because of the poisoning / fouling of the ammonia or methanol reaction catalyst. In at least one other embodiment, the one or more poisoning / fouling sensors 146 may be used to determine when to remove / replace the ammonia or methanol reaction catalyst.

[0030] The downhole tool 130, in at least one embodiment, further includes an ammonia or methanol reaction catalyst 148 positioned in an annular space defined between the screen 138 and the screen tubular 140. In at least one embodiment, the ammonia reaction catalyst is configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst is configured to engage with methanol reactive gas passing there through to form methanol. In line with that disclosed above, the ammonia or methanol reaction catalyst 148 is an ammonia reaction catalyst in the embodiment of FIGS. 1A through 1K, and therefor may be used for the production of ammonia. Nevertheless, other embodiments exist wherein the ammonia or methanol reaction catalyst 148 is a methanol reaction catalyst (e.g., See FIGS. 2A through 2K). In at least one embodiment, the ammonia reaction catalyst employs an iron based catalyst such as Fe3O4-based catalyst, Fe1-xO based catalyst, or other parts of a fused-iron catalyst. In at least one other embodiment, the ammonia reaction catalyst employes an osmium based catalyst, cobalt-based catalyst, a metal nitride catalyst, a magnesium oxide based catalyst, an aluminum oxide based catalyst, or a ruthenium based catalyst. In another embodiment, the catalyst (such as 7% Fe / CeO2) has an electric field applied in order to increase the reaction rate and to allow significant production at a lower reactor temperature of approximately 100° C. In yet at least one other embodiment, the methanol reaction catalyst employs a copper based catalyst, a metal oxide based catalyst (such as zinc oxide, aluminum oxide, or magnesium oxide), a noble metal based catalyst (such as palladium platinum, zirconium, or rhodium). It should further be noted that in certain embodiments multiple different suitable catalysts are employed, whether in different stages or combined in a single stage.

[0031] In at least one embodiment, the ammonia catalysts and / or the methanol catalysts may be multi-promoted with promoters such as K2O, BaO, LiH, ZnO, and Al2O3. The promoters can be present in quantities of a few weight percentage, approximately 1% to 10%. Promoters are catalyst modifiers that provide the catalyst with structural and electronic promotion, such as preventing the aggregation of the iron catalyst particles, and increase the rate of the ammonia synthesis reaction. Multiple promoter compositions may be used.

[0032] In yet another embodiment, the downhole tool 130 further includes a wireline engagement member 150 coupled to the screen assembly 136. In at least this one embodiment, the wireline engagement member 150 is configured to engage with the wireline to run the downhole tool 130 within the wellbore 108. For example, the wireline engagement member 150 and the wireline could be used to remove a spent downhole tool 130 from the wellbore 108 (e.g., a downhole tool 130 no longer suitable for producing ammonia or methanol) and replace it with a new downhole tool 130 in the wellbore (e.g., a downhole tool 130 the is suitable for producing ammonia or methanol).

[0033] Turning now to FIGS. 1G and 1H, illustrated are additional zoomed in views of an alternative embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. The downhole tool 130 of FIGS. 1G and 1H is similar in many respects to the downhole tool 130 of FIGS. 1E and 1F. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole tool 130 of FIGS. 1G and 1H differs, for the most part, from the downhole tool 130 of FIGS. 1E and 1F, in that the screen 138 of the screen assembly 136 is a first screen, and the screen tubular 140 is a second screen. In at least this one embodiment, the ammonia or methanol reaction catalyst 148 is positioned in an annular space defined between the first screen (e.g., screen 138) and the second screen (e.g., screen tubular 140).

[0034] Turning now to FIGS. 1I and 1J, illustrated are additional zoomed in views of an alternative embodiment of the downhole tool 130 of FIG. 1A, as might be included within the wellbore 108. The downhole tool 130 of FIGS. 1I and 1J is similar in many respects to the downhole tool 130 of FIGS. 1G and 1H. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole tool 130 of FIGS. 1I and 1J differs, for the most part, from the downhole tool 130 of FIGS. 1G and 1H, in that the downhole tool 130 of FIGS. 1I and 1J includes a guard catalyst 152 positioned upstream of one or more of the plurality of spaced openings 142 in the screen tubular 140. In one or more embodiments, the guard catalyst 152 is configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst. For example, in the embodiment of FIGS. 1I and 1J, the downhole tool 130 further includes a guard catalyst screen 154 positioned radially about the screen assembly 136, the guard catalyst 152 positioned in a second annular space defined between the guard catalyst screen 154 and the screen assembly 136. It should be noted that while the embodiment of FIGS. 1I and 1J illustrates the guard catalyst 152 and guard catalyst screen 154 employed with the screen assembly 136 of FIGS. 1G and 1H, the guard catalyst 152 and guard catalyst screen 154 could have easily been employed with the screen assembly 136 of FIGS. 1E and 1F. Furthermore, other embodiments may exist wherein the guard catalyst 152 is located at a different location inside or outside of the wellbore 108.

[0035] Turning briefly to FIG. 1K, illustrated is a zoomed in view of the ammonia working fluid mixture 176 of FIGS. 1A through 1J. As shown, bubbles of N2+H2 are surrounded by the column of working fluid, the column of working fluid pressurizing the bubbles of N2+H2 to the suitable pressure needed for the production of ammonia.

[0036] Turning now to FIGS. 2A through 2K, depicted are various different views of a well system 200 including an exemplary operating environment that the apparatuses, systems and methods disclosed herein may be employed. The well system 200 of FIGS. 2A through 2K is similar in many respects to the well system 100 of FIGS. 1A through 1K. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The well system 200 of FIGS. 2A through 2K differs, for the most part, from the well system 100 of FIGS. 1A through 1K, in that the well system 200 is configured for the production of methanol. Accordingly, the well system 200 employs a different hydrogen generation unit 260, a different downhole tool 230, and a different methanol extraction unit 280. For example, the hydrogen generation unit 260 does not require the separator section 166 or carbon capture section 168, as the hydrogen generation unit 260 employs the CO2 for the production of the methanol reaction gas. Accordingly, once the CO2 and H2 of the methanol reaction gas combine with the working fluid, the methanol working fluid mixture 276 results. Moreover, the downhole tool 130, in at least one embodiment, further includes a methanol reaction catalyst 248 positioned in an annular space defined between the screen 138 and the screen tubular 140, resulting in a methanol worked fluid mixture 282. Similarly, the methanol extraction unit 280 does not require the N2 separator 190, but requires a CO2 separator 290. The above changes result in the production of methanol, as opposed to ammonia.

[0037] Aspects disclosed herein include:

[0038] A. A downhole tool, the downhole tool including: 1) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; 2) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and 3) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth.

[0039] B. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; 2) a wellbore tubular position within the wellbore; 3) a downhole tool positioned within the wellbore tubular, the downhole tool, including: a) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; b) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and c) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; and 4) an inlet coupled to the wellbore, the inlet configured to provide the ammonia reactive gas or the methanol reactive gas to the downhole tool.

[0040] C. A method, the method including: 1) inserting a downhole tool within a wellbore tubular positioned within a wellbore extending through one or more subterranean formations, the downhole tool including: a) a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof; b) an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing therethrough to form methanol; and c) a latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; and 2) supplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, the wellbore providing the ammonia reactive gas or methanol reactive gas to the downhole tool to form ammonia or methanol.

[0041] Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: wherein the latch member includes a screen assembly landing nipple / screen assembly seal profile configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile of the wellbore tubular. Element 2: wherein the plurality of spaced openings are a plurality of inflow control devices. Element 3: wherein the plurality of inflow control devices are a plurality of fixed flow restrictors. Element 4: wherein the screen tubular has an uphole end and a downhole end defining a length (L), and further wherein the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L), the two or more rows of fixed flow restrictors increasing in flow rate as they move from the uphole end to the downhole end. Element 5: wherein the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs). Element 6: wherein the plurality of autonomous inflow control devices (A-ICDs) or the plurality of electronic inflow control devices (E-ICDs) are two or more rows of electronic inflow control devices (E-ICDs), and further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof. Element 7: wherein the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst. Element 8: wherein the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst. Element 9: wherein the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices. Element 10: further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to a user to determine when to remove / replace the removable / replaceable inflow control devices. Element 11: wherein the screen is a first screen and further wherein the screen tubular is a second screen placed radially about the first screen. Element 12: further including a guard catalyst positioned upstream of one or more of the plurality of spaced openings in the screen tubular, the guard catalyst configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or configured to remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst. Element 13: further including a guard catalyst screen positioned radially about the screen assembly, the guard catalyst positioned in a second annular space defined between the guard catalyst screen and the screen assembly. Element 14: wherein the screen assembly is a multi-stage screen assembly configured to promote geothermal energy harvesting. Element 15: wherein the latch member is configured to allow the screen assembly to be run within wellbore tubular via the wireline. Element 16: further including a wireline engagement member coupled to the screen assembly, the wireline engagement member configured to engage with the wireline to run the downhole tool within the wellbore tubular. Element 17: wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an iron based catalyst. Element 18: wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an osmium based catalyst, a uranium based catalyst, or a ruthenium based catalyst. Element 19: wherein the ammonia or methanol reaction catalyst is methanol reaction catalyst employing a copper based catalyst. Element 20: further including a hydrogen generation unit coupled to the inlet, the hydrogen generation unit configured to provide H2 of the ammonia reactive gas or the methanol reactive gas to the downhole tool. Element 21: wherein the hydrogen generation unit includes: a partial oxidation section, the partial oxidation section configured to form CO+2H2 from CH4; and a water / gas shift section, the water / gas shift section configured to form CO2+H2 from the CO+2H2. Element 22: further including a working fluid inlet section, the working fluid inlet section including a gas diffuser configured to diffuse the H2 obtained from the hydrogen generation unit within working fluid provided to the working fluid inlet section to create a working fluid mixture, such that the working fluid mixture may then be provided to the downhole tool. Element 23: wherein the hydrogen generation unit further includes: a separator section, the separator section configured to separate the CO2 from the CO2+H2; and a mixer section, the mixer section configured to mix the H2 from the separator section and N2 to form the ammonia reactive gas, the gas diffuser configured to diffuse the mixed H2 and N2 within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be provided to the downhole tool. Element 24: wherein the well system further includes a carbon capture section, the carbon capture section configured to capture the CO2 from the separator section. Element 25: wherein the gas diffuser is configured to diffuse the CO2+H2 comprising the methanol reactive gas within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be provided to the downhole tool. Element 26: wherein the working fluid inlet section is configured to provide H2O as the working fluid. Element 27: further including an outlet coupled to the wellbore, the outlet configured to allow ammonia worked fluid mixture or methanol worked fluid mixture to exit the wellbore. Element 28: further including an ammonia or methanol extraction unit coupled to the outlet. Element 29: wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 30: wherein the formed ammonia or methanol is at least partially diffused within the ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 31: wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol. Element 32: wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol. Element 33: wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia. Element 35: wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol. Element 36: wherein supplying H2 generated outside of the wellbore, includes supplying H2 generated with a hydrogen generation unit coupled to the inlet. Element 37: wherein the hydrogen generation unit includes: a partial oxidation section, the partial oxidation section forming CO+2H2 from CH4; and a water / gas shift section, the water / gas shift section forming CO2+H2 from the CO+2H2. Element 38: further including diffusing the H2 obtained from the hydrogen generation unit within a working fluid provided to a working fluid inlet section of the wellbore to create a working fluid mixture, such that the working fluid mixture may then be provided to the ammonia reaction catalyst or the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia or methanol. Element 39: wherein the hydrogen generation unit further includes: a separator section, the separator section separating the CO2 from the CO2+H2; and a mixer section, the mixer section mixing the H2 from the separator section and N2 to form the ammonia reactive gas. Element 40: wherein the hydrogen generation unit further includes a carbon capture section, and further including capturing the CO2 from the separator section using the carbon capture section. Element 41: wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and N2 obtained from the hydrogen generation unit within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be supplied to the ammonia reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia. Element 42: wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and CO2 obtained from the hydrogen generation unit within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be supplied to the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the methanol. Element 43: further including an outlet coupled to the wellbore, the outlet configured to allow the formed ammonia or methanol to exit the wellbore. Element 44: further including an ammonia or methanol extraction unit coupled to the outlet. Element 45: wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract thermal energy from the formed ammonia or methanol. Element 46: wherein the formed ammonia or methanol is at least partially diffused within the ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture. Element 47: wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol. Element 48: wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol. Element 49: wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia. Element 50: further including recirculating the excess H2 as a source for the supplying the H2. Element 51: wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol. Element 52: wherein supplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, includes supplying the ammonia reactive gas or methanol reactive gas to the inlet at an initial inlet temperature and pressure, and further wherein the wellbore increases the initial inlet temperature and pressure of the ammonia reactive gas or methanol reactive gas to the necessary temperature and pressure as the ammonia reactive gas or methanol reactive gas approach the downhole tool.

[0042] Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.

Examples

Embodiment Construction

[0006]In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms. Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

[0007]Unless otherwise specified,...

Claims

1. A downhole tool, comprising:a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof;an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing there through to form methanol; anda latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth.

2. The downhole tool as recited in claim 1, wherein the latch member includes a screen assembly landing nipple / screen assembly seal profile configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile of the wellbore tubular.

3. The downhole tool as recited in claim 1, wherein the plurality of spaced openings are a plurality of inflow control devices.

4. The downhole tool as recited in claim 3, wherein the plurality of inflow control devices are a plurality of fixed flow restrictors.

5. The downhole tool as recited in claim 4, wherein the screen tubular has an uphole end and a downhole end defining a length (L), and further wherein the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L), the two or more rows of fixed flow restrictors increasing in flow rate as they move from the uphole end to the downhole end.

6. The downhole tool as recited in claim 3, wherein the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs).

7. The downhole tool as recited in claim 6, wherein the plurality of autonomous inflow control devices (A-ICDs) or the plurality of electronic inflow control devices (E-ICDs) are two or more rows of electronic inflow control devices (E-ICDs), and further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof.

8. The downhole tool as recited in claim 7, wherein the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst.

9. The downhole tool as recited in claim 7, wherein the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst.

10. The downhole tool as recited in claim 3, wherein the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices.

11. The downhole tool as recited in claim 10, further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to a user to determine when to remove / replace the removable / replaceable inflow control devices.

12. The downhole tool as recited in claim 1, wherein the screen is a first screen and further wherein the screen tubular is a second screen placed radially about the first screen.

13. The downhole tool as recited in claim 1, further including a guard catalyst positioned upstream of one or more of the plurality of spaced openings in the screen tubular, the guard catalyst configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or configured to remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst.

14. The downhole tool as recited in claim 13, further including a guard catalyst screen positioned radially about the screen assembly, the guard catalyst positioned in a second annular space defined between the guard catalyst screen and the screen assembly.

15. The downhole tool as recited in claim 1, wherein the screen assembly is a multi-stage screen assembly configured to promote geothermal energy harvesting.

16. The downhole tool as recited in claim 1, wherein the latch member is configured to allow the screen assembly to be run within wellbore tubular via the wireline.

17. The downhole tool as recited in claim 16, further including a wireline engagement member coupled to the screen assembly, the wireline engagement member configured to engage with the wireline to run the downhole tool within the wellbore tubular.

18. The downhole tool as recited in claim 1, wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an iron based catalyst.

19. The downhole tool as recited in claim 1, wherein the ammonia or methanol reaction catalyst is an ammonia reaction catalyst employing an osmium based catalyst, a uranium based catalyst, or a ruthenium based catalyst.

20. The downhole tool as recited in claim 1, wherein the ammonia or methanol reaction catalyst is methanol reaction catalyst employing a copper based catalyst.

21. A well system, comprising:a wellbore extending through one or more subterranean formations;a wellbore tubular position within the wellbore;a downhole tool positioned within the wellbore tubular, the downhole tool, including:a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof;an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing there through to form methanol; anda latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; andan inlet coupled to the wellbore, the inlet configured to provide the ammonia reactive gas or the methanol reactive gas to the downhole tool.

22. The well system as recited in claim 21, wherein the latch member includes a screen assembly landing nipple / screen assembly seal profile configured to couple with a wellbore tubular landing nipple / wellbore tubular seal profile of the wellbore tubular.

23. The well system as recited in claim 21, wherein the plurality of spaced openings are a plurality of inflow control devices.

24. The well system as recited in claim 23, wherein the plurality of inflow control devices are a plurality of fixed flow restrictors.

25. The well system as recited in claim 24, wherein the screen tubular has an uphole end and a downhole end defining a length (L), and further wherein the plurality of fixed flow restrictors are two or more rows of fixed flow restrictors positioned along the length (L), the two or more rows of fixed flow restrictors increasing in flow rate as they move from the uphole end to the downhole end.

26. The well system as recited in claim 23, wherein the plurality of inflow control devices are a plurality of autonomous inflow control devices (A-ICDs) or a plurality of electronic inflow control devices (E-ICDs).

27. The well system as recited in claim 26, wherein the plurality of autonomous inflow control devices (A-ICDs) or the plurality of electronic inflow control devices (E-ICDs) are two or more rows of electronic inflow control devices (E-ICDs), and further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to the two or more rows of electronic inflow control devices (E-ICDs) for adjustment thereof.

28. The well system as recited in claim 27, wherein the poisoning / fouling data is a measure of an amount of poison or fouling agent in the ammonia or methanol reaction catalyst.

29. The well system as recited in claim 27, wherein the poisoning / fouling data is a measure of a drop off in reaction rate of the ammonia or methanol reaction catalyst.

30. The well system as recited in claim 23, wherein the plurality of inflow control devices are a plurality of removable / replaceable inflow control devices.

31. The well system as recited in claim 30, further including one or more poisoning / fouling sensors associated with the ammonia or methanol reaction catalyst, the one or more poisoning / fouling sensors configured to provide poisoning / fouling data to a user to determine when to remove / replace the inflow control devices.

32. The well system as recited in claim 21, wherein the screen is a first screen and further wherein the screen tubular is a second screen placed radially about the first screen.

33. The well system as recited in claim 21, further including a guard catalyst positioned upstream of one or more of the plurality of spaced openings in the screen tubular, the guard catalyst configured to remove poisons / fouling agents from the ammonia reactive gas prior to the poisons / fouling agents encountering the ammonia reaction catalyst or configured to remove poisons / fouling agents from the methanol reactive gas prior to the poisons / fouling agents encountering the methanol reaction catalyst.

34. The well system as recited in claim 33, further including a guard catalyst screen positioned radially about the screen assembly, the guard catalyst positioned in a second annular space defined between the guard catalyst screen and the screen assembly.

35. The well system as recited in claim 21, wherein the screen assembly is a multi-stage screen assembly.

36. The well system as recited in claim 21, wherein the latch member is configured to allow the screen assembly to be run within wellbore tubular via the wireline.

37. The well system as recited in claim 36, further including a wireline engagement member coupled to the screen assembly, the wireline engagement member configured to engage with the wireline to run the downhole tool within the wellbore tubular.

38. The well system as recited in claim 21, further including a hydrogen generation unit coupled to the inlet, the hydrogen generation unit configured to provide H2 of the ammonia reactive gas or the methanol reactive gas to the downhole tool.

39. The well system as recited in claim 38, wherein the hydrogen generation unit includes:a partial oxidation section, the partial oxidation section configured to form CO+2H2 from CH4; anda water / gas shift section, the water / gas shift section configured to form CO2+H2 from the CO+2H2.

40. The well system as recited in claim 39, further including a working fluid inlet section, the working fluid inlet section including a gas diffuser configured to diffuse the H2 obtained from the hydrogen generation unit within working fluid provided to the working fluid inlet section to create a working fluid mixture, such that the working fluid mixture may then be provided to the downhole tool.

41. The well system as recited in claim 40, wherein the hydrogen generation unit further includes:a separator section, the separator section configured to separate the CO2 from the CO2+H2; anda mixer section, the mixer section configured to mix the H2 from the separator section and N2 to form the ammonia reactive gas, the gas diffuser configured to diffuse the mixed H2 and N2 within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be provided to the downhole tool.

42. The well system as recited in claim 41, wherein the well system further includes a carbon capture section, the carbon capture section configured to capture the CO2 from the separator section.

43. The well system as recited in claim 40, wherein the gas diffuser is configured to diffuse the CO2+H2 comprising the methanol reactive gas within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be provided to the downhole tool.

44. The well system as recited in claim 40, wherein the working fluid inlet section is configured to provide H2O as the working fluid.

45. The well system as recited in claim 44, further including an outlet coupled to the wellbore, the outlet configured to allow ammonia worked fluid mixture or methanol worked fluid mixture to exit the wellbore.

46. The well system as recited in claim 45, further including an ammonia or methanol extraction unit coupled to the outlet.

47. The well system as recited in claim 46, wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract energy from the ammonia worked fluid mixture or methanol worked fluid mixture.

48. The well system as recited in claim 47, wherein the formed ammonia or methanol is at least partially diffused within the ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture.

49. The well system as recited in claim 46, wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol.

50. The well system as recited in claim 46, wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol.

51. The well system as recited in claim 46, wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia.

52. The well system as recited in claim 46, wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol.

53. A method, comprising:inserting a downhole tool within a wellbore tubular positioned within a wellbore extending through one or more subterranean formations, the downhole tool including:a screen assembly, the screen assembly including a screen and screen tubular concentrically placed, the screen tubular including a plurality of spaced openings coupling an inside surface and an outside surface thereof;an ammonia or methanol reaction catalyst positioned in an annular space defined between the screen and the screen tubular, the ammonia reaction catalyst configured to engage with ammonia reactive gas passing there through to form ammonia and the methanol reaction catalyst configured to engage with methanol reactive gas passing there through to form methanol; anda latch member coupled to the screen assembly, the latch member configured to allow the screen assembly to be run within wellbore tubular via wireline or coiled tubing and couple with the wellbore tubular to fix the screen assembly at depth; andsupplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, the wellbore providing the ammonia reactive gas or methanol reactive gas to the downhole tool to form ammonia or methanol.

54. The method as recited in claim 53, wherein supplying H2 generated outside of the wellbore, includes supplying H2 generated with a hydrogen generation unit coupled to the inlet.

55. The method as recited in claim 54, wherein the hydrogen generation unit includes:a partial oxidation section, the partial oxidation section forming CO+2H2 from CH4; anda water / gas shift section, the water / gas shift section forming CO2+H2 from the CO+2H2.

56. The method as recited in claim 55, further including diffusing the H2obtained from the hydrogen generation unit within a working fluid provided to a working fluid inlet section of the wellbore to create a working fluid mixture, such that the working fluid mixture may then be provided to the ammonia reaction catalyst or the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia or methanol.

57. The method as recited in claim 56, wherein the hydrogen generation unit further includes:a separator section, the separator section separating the CO2 from the CO2+H2; anda mixer section, the mixer section mixing the H2 from the separator section and N2 to form the ammonia reactive gas.

58. The method as recited in claim 57, wherein the hydrogen generation unit further includes a carbon capture section, and further including capturing the CO2 from the separator section using the carbon capture section.

59. The method as recited in claim 57, wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and N2 obtained from the hydrogen generation unit within the working fluid to create an ammonia working fluid mixture, such that the ammonia working fluid mixture may then be supplied to the ammonia reaction catalyst of the downhole tool under the necessary temperature and pressure to form the ammonia.

60. The method as recited in claim 55, wherein diffusing the H2 obtained from the hydrogen generation unit within a working fluid further includes diffusing the H2 and CO2 obtained from the hydrogen generation unit within the working fluid to create a methanol working fluid mixture, such that the methanol working fluid mixture may then be supplied to the methanol reaction catalyst of the downhole tool under the necessary temperature and pressure to form the methanol.

61. The method as recited in claim 53, further including an outlet coupled to the wellbore, the outlet configured to allow the formed ammonia or methanol to exit the wellbore.

62. The method as recited in claim 61, further including an ammonia or methanol extraction unit coupled to the outlet.

63. The method as recited in claim 62, wherein the ammonia or methanol extraction unit includes an energy extractor section, the energy extractor section configured to extract thermal energy from the formed ammonia or methanol.

64. The method as recited in claim 63, wherein the formed ammonia or methanol is at least partially diffused within an ammonia worked fluid mixture or methanol worked fluid mixture, and further wherein the energy extractor section is configured to extract thermal energy from the ammonia worked fluid mixture or methanol worked fluid mixture.

65. The method as recited in claim 64, wherein the ammonia or methanol extraction unit further includes a worked fluid separator, the worked fluid separator configured to separate worked fluid from the formed ammonia or methanol.

66. The method as recited in claim 62, wherein the ammonia or methanol extraction unit further includes an H2 separator, the H2 separator configured to separate excess H2 from the formed ammonia or methanol.

67. The method as recited in claim 66, wherein the ammonia or methanol extraction unit further includes an N2 separator, the N2 separator configured to separate excess N2 from the formed ammonia.

68. The method as recited in claim 67, further including recirculating the excess H2 as a source for the supplying the H2.

69. The method as recited in claim 66, wherein the ammonia or methanol extraction unit further includes a CO2 separator, the CO2 separator configured to separate excess CO2 from the formed methanol.

70. The method as recited in claim 53, wherein supplying H2 generated outside of the wellbore as a portion of the ammonia reactive gas or methanol reactive gas through an inlet coupled to the wellbore to the downhole tool located within the wellbore tubular, includes supplying the ammonia reactive gas or methanol reactive gas to the inlet at an initial inlet temperature and pressure, and further wherein the wellbore increases the initial inlet temperature and pressure of the ammonia reactive gas or methanol reactive gas to the necessary temperature and pressure as the ammonia reactive gas or methanol reactive gas approach the downhole tool.

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