METHODS AND SYSTEMS FOR LARGE SCALE CARBON DIOXIDE UTILIZATION FROM LAKE KIVU VIA A CO2 INDUSTRIAL UTILIZATION HUB INTEGRATED WITH ELECTRIC POWER PRODUCTION AND OPTIONAL CRYO-ENERGY STORAGE

Abstract

Lake Kivu contains ˜50 million tonnes (MT) dissolved biomethane. Efficient use is problematic from massive associated CO.sub.2: ˜600 MT. Conventional extraction scrubs CO.sub.2 with ˜50% overall CH.sub.4 loss, and returns ˜80% CO.sub.2 into the deep lake, preserving a catastrophe hazard threatening >2 M people. Methods and systems are disclosed coupling: (1) efficient CH.sub.4+CO.sub.2 degassing; (2) optional oxyfuel power generation and CO.sub.2 power cycle technologies; and (3) CO.sub.2 capture, processing, storage and use in a utilization hub. The invention optimally allows power production with >2× improved efficiency plus cryo-energy storage and large-scale greentech industrialization. CO.sub.2-utilizing products can include: Mg-cements/building materials, algal products/biofuels, urea, bioplastics and recycled materials, plus CO.sub.2 for greenhouse agriculture, CO.sub.2-EOR/CCS, off-grid cooling, fumigants, solvents, carbonation, packaging, ores-, biomass-, and agro-processing, cold pasteurization, frack and geothermal fluids, and inputs to produce methanol, DME, CO, syngas, formic acid, bicarbonate and other greentech chemicals, fuels, fertilizers and carbon products.

Claims

1. A method for obtaining and utilizing carbon dioxide gas from a body of water containing dissolved carbon dioxide gas and methane gas, said method comprising the steps of: (a) extracting water from at least one extraction depth of the body of water to obtain extracted water; (b) degassing the extracted water in at least one stage of degassing so as to provide degassed water and extracted gases comprising carbon dioxide gas and methane gas in at least one flow; (c) optionally combusting the extracted gases with oxygen to provide an exhaust gas comprising carbon dioxide and water; and (d) feeding to a utilization hub the carbon dioxide gas from at least one of step (b) and step (c), wherein the utilization hub is configured to collect the carbon dioxide gas for storage, distribution, processing and/or utilization.

2. The method of claim 1, further comprising utilizing the carbon dioxide collected by the utilization hub to perform at least one process selected from the group consisting of fertilizing growth of plants, fertilizing a biozone of Lake Kivu, lowering a pH of water returned into Lake Kivu, adjusting a pH of water exiting from a vacuum degassing system, adjusting a pH of water fed to an algal growth sector, cultivating algae, supplying a cryogenic energy storage reservoir, heating or cooling a supercritical CO.sub.2 power cycle heat engine power generator, delivering pressurized carbon dioxide by pipeline, delivering pressurized carbon dioxide by tanks including by pressurized tank trucks, producing dry ice, storing, producing and distributing refrigerated liquefied and/or solidified carbon dioxide, producing a magnesium-based cement or concrete, producing urea, producing formic acid, producing oxalic acid, producing acetic acid, producing a solvent, producing carbon monoxide, producing a pyrethrum pesticide, producing an asphyxiant, producing a food packaging gas, pasteurizing milk, beer or an agricultural juice, processing an agricultural, food, forest, textile, waste or biofuel product, cleaning a textile, treating leather, extracting geothermal energy, producing a fuel, producing a syngas, producing a chemical via a formate and/or by an oxalic acid platform, producing a chemical by gas fermentation based on a microbial Wood Ljundahl pathway, producing a chemical by a synthetic pathway including carbon dioxide as a reactant, producing a plastic including carbon dioxide as an ingredient, producing carbonic acid, producing a carbonated and/or CO.sub.2 pressurized beverage, producing sodium bicarbonate, producing a fracking fluid, producing silicic acid, producing microsilica, producing iron, producing nickel, processing an ore to produce a plant and/or aquatic fertilizer, processing an ore by solution extraction of one or more metals using supercritical carbon dioxide optionally injected into an ore zone, producing an elemental carbon product, producing oxygen gas, and injecting carbon dioxide via drillholes into subterranean strata for geostorage.

3. The method of claim 1, wherein step (c) is conducted and the carbon dioxide collected in step (d) is solely from the exhaust gas provided in step (c).

4. The method of claim 1, further comprising generation of electrical power.

5. The method of claim 1, wherein deep gas trapping layers of the body of water possess in their volume average a CO.sub.2/CH.sub.4 ratio greater than 4, and more than 98 wt. % of the CH.sub.4 dissolved in the water is extracted by the extracting step.

6. The method of claim 5, wherein the body of water is Lake Kivu and the method reduces a risk of a limnic eruption.

7. The method of claim 1, further comprising extracting from the extracted water at least one product selected from the group consisting of ammonium, ammonia, phosphorous, magnesium and calcium.

8. The method of claim 4, further comprising: supplying the electrical power to a compression and refrigeration system; cooling with the compression and refrigeration system at least one gas to form at least one liquefied gas, wherein the at least one gas is at least one of oxygen, nitrogen, carbon dioxide that has been extracted from the extracted water, carbon dioxide that has been formed in a combustion of associated methane and methane that has been degassed from the extracted water; storing the at least one liquefied gas in at least one insulated storage tank; releasing from the at least one insulated storage tank a liquid flow of the at least one liquefied gas; optionally increasing a pressure of the liquid flow of the at least one liquefied gas; heating the liquid flow to form a subcritical gas flow or a supercritical fluid flow, wherein at least a portion of the heating is optionally conducted by heat exchange with a closed system heat engine; driving a turbine with a subcritical gas flow or with a supercritical fluid flow to generate electricity; and optionally driving a turbine within a closed system heat engine to generate electricity.

9. The method of claim 1, wherein the degassed water provided in step (b) is transported for water treatment, and the method further comprises the steps of: (i) photosynthetic treatment of the degassed water by growth of an algal biomass to convert bicarbonate anions to carbon fixed by photosynthesis into biomass and hydroxyl anions in the degassed water, such that the pH of the degassed water is increased and bicarbonate anions are converted into carbonate anions and magnesium and calcium precipitate out of the degassed water onto algal cells to provide de-densified water and flocculated biomass precipitate; (ii) separating the de-densified water from the flocculated biomass precipitate; (iii) optionally additionally treating the degassed water by electrochemical methods such that the pH of the degassed water is further increased and additional magnesium and calcium precipitate out of the degassed water to provide further de-densified water and magnesium and calcium precipitate; (iv) optionally separating the further de-densified water from magnesium and calcium precipitate; (v) optionally adjusting the pH of the de-densified water or further de-densified water by adding thereto a volume of the carbon dioxide gas collected by the utilization hub from at least one of step (b) and step (c); and (iv) reinjecting into Lake Kivu a return flow of the de-densified water or further de-densified water separated from the biomass and precipitate, wherein the return flow is reinjected into Lake Kivu at a reinjection depth which is shallower than the extraction depth and which is density matched with the de-densified water or further de-densified water.

10. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide into the biozone of Lake Kivu as a carbon fertilizing source supporting photoautotrophic bioproductivity.

11. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide which is injected into: (i) post-degassing return flow water containing nutrients that are being diffused into a biozone of Lake Kivu; (ii) de-densified high-pH post-degassing return flow water that is being injected into Lake Kivu underneath the biozone; and/or (iii) post-degassing return flow water for pH control.

12. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide to a horticultural greenhouse.

13. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide which is injected into algal growth biocultures.

14. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide to a compressor to provide compressed carbon dioxide, the compressed carbon dioxide is optionally stored in a storage tank, and the compressed carbon dioxide is distributed through pipelines.

15. The method of claim 1, wherein the utilization hub supplies a stream of carbon dioxide gas to a compression and refrigeration system to provide compressed refrigerated liquid carbon dioxide and/or solid carbon dioxide, and wherein the method optionally comprises at least one of the additional steps of: (i) storing the compressed refrigerated liquid and/or solid carbon dioxide; (ii) further cooling the compressed refrigerated liquid carbon dioxide to provide dry ice; (iii) storing the dry ice; (iv) using the stored dry ice as cryogenic energy with recovery to generate power; and (v) distributing the dry ice.

16. A system configured to perform the method of claim 1.

17. The system of claim 16, which comprises: a water degassing system; and a carbon dioxide utilization hub in fluid communication with the water degassing system.

18. The system of claim 17, wherein the water degassing system comprises: an intake pipe system; at least one bubble capture unit positioned upwards along a system of degassing pipes; at least one degassing catalyst unit positioned further upwards along the system of degassing pipes; a bubbly flow turbine configured to capture and recycle power from jetting foam flow at a top of the system of degassing pipes, wherein the bubbly flow turbine is also configured to function as a foam separator; at least one vacuum degassing unit positioned at the top of the system of degassing pipes; and a water flow turbine capturing and recycling power in a downward outflow of degassed water from the vacuum degassing unit.

19. The system of claim 16, which comprises: a water degassing system; an oxyfuel power generation system in fluid communication with the water degassing system; and a carbon dioxide utilization hub in fluid communication with the oxyfuel power generation system.

20. The system of claim 19, wherein the oxyfuel power generation system comprises a power generator and an air separation unit configured to provide oxygen for combustion.

21. The system of claim 20, wherein the water degassing system comprises: an intake pipe system; at least one bubble capture unit positioned upwards along a system of degassing pipes; at least one degassing catalyst unit positioned further upwards along the system of degassing pipes; a bubbly flow turbine configured to capture and recycle power from jetting foam flow at a top of the system of degassing pipes, wherein the bubbly flow turbine is also configured to function as a foam separator; at least one vacuum degassing unit positioned at the top of the system of degassing pipes; and a water flow turbine capturing and recycling power in a downward outflow of degassed water from the vacuum degassing unit.

22. The system of claim 21, further comprising a return flow system which comprises: an outflow pipe from the water degassing system; pipe systems connecting flow to at least one water treatment system; a return flow pipe system and horizontal diffuser to reinject degassed water into the body of water at a specified depth; and flow control valve systems with emergency shut-off capabilities.

23. The system of claim 22, which further comprises: flow connection by pipes and channels to and from at least one surface water treatment system that decreases water density in the degassed water flow; and an inlet system configured to allow admixture of relatively low density near-surface water from the body of water into the return flow for reinjection at a specified depth.

24. The system of claim 23, which further comprises a system configured for combustion preparation processing and transfer of degassed gas into the oxyfuel power generation system.

25. The system of claim 24, which further comprises a control system configured for physical monitoring, system-wide functional integration and emergency response safety assurance.

26. The system of claim 25, which is configured to extract more than 98 wt. % of CH.sub.4 dissolved in a body of water having a CO.sub.2/CH.sub.4 ratio greater than 4.

27. A carbon dioxide utilization hub comprising: (a) pipes and control valves configured for transferring exhaust gases; (b) pumps configured for compressing and transferring the exhaust gases into at least one of a storage tank, a gas processing tank and a heat exchange system; (c) at least two of a storage tank for pressurized gas, a gas dehydration system and a heat exchange system; (d) at least one compressor for compressing dehydrated carbon dioxide; (e) at least one storage tank for storing compressed dehydrated carbon dioxide; (f) at least one dispensing valve for dispensing compressed dehydrated carbon dioxide from at least one storage tank storing compressed dehydrated carbon dioxide; (g) at least one refrigeration system for compressing and refrigerating dehydrated carbon dioxide gas into liquefied refrigerated carbon dioxide; (h) at least one of: (i) at least one insulated tank for storing dehydrated liquefied refrigerated carbon dioxide, (ii) at least one insulated tank for storing liquefied refrigerated nitrogen, (iii) at least one insulated tank for storing liquefied refrigerated oxygen, and (iv) at least one dispensing valve for dispensing at least one cryogenic refrigerated liquids selected from the group consisting of carbon dioxide, nitrogen and oxygen; (i) power generation cryoenergy recovery systems utilizing at least one of the following cryoenergy storing inputs: (i) liquefied refrigerated carbon dioxide, (ii) liquified refrigerated nitrogen and (iii) liquefied refrigerated oxygen; (j) gas dispensing valves and pipes for transferring and dispensing at least one warmed gas emerging from cryoenergy recovery systems; and (k) at least one pressurizable reaction chamber configured to provide a mixture of carbon dioxide and water vapor under controlled and time-varying conditions of pressure, mixing ratio, temperature and time and admitting product producing forms containing at least one of the following carbon dioxide and water vapor absorbing substances: magnesium hydroxide, calcium carbonate, hydrated magnesium carbonates, concrete-forming aggregate, pozzolans, steel rebar, microsilica and plant materials.

28. The method of claim 1, wherein the utilization hub supplies at least one of liquefied natural gas, compressed natural gas and adsorbed natural gas.

29. The method of claim 4, further comprising supplying the electrical power to a compression and refrigeration system; cooling with the compression and refrigeration system at least one gas to form at least one liquefied gas, wherein the at least one gas is at least one of oxygen, nitrogen, carbon dioxide that has been extracted from the extracted water, carbon dioxide that has been formed in a combustion of associated methane and methane that has been degassed from the extracted water; and cooling a server with the at least one liquefied gas.

30. A process for generating data, said process comprising: providing a server; cooling the server with at least one liquefied gas; and generating the data from the server, wherein the at least one liquefied gas comprises at least one of oxygen, nitrogen, carbon dioxide and methane from Lake Kivu water.

Description

BRIEF DESCRIPTION OF SEVERAL VIEWS OF THE DRAWINGS

[0247] The invention will be described in conjunction with the following drawings in which reference numbers and their corresponding component names are identified in a listing herein (this listing also indicating like items according to like names across the set of figures), and referenced in descriptive discussions in the text according to a convention “X.Y”, where “X” is the figure number, and “Y” represents numerical component item labels appearing within figure X, and wherein:

[0248] FIG. 1 is a simplified schematic and conceptual representation of the method and system of the invention shown as a process flow divided into five boxes representing different functional groupings of different components of the whole such as may be present in various embodiments. A representation of the Modified Staged Degassing System (MSDS) submethod and subsystem is shown by items 13 and 14. (See FIG. 8 for an overview of the MSDS.)

[0249] FIG. 2 is a schematic representation of an embodiment of the invention shown with additional detail relative to FIG. 1. Only the modality utilizing a Total Degassing System (TDS) is shown. The variant modality utilizing a Modified Staged Degassing System (MSDS) is not shown. FIG. 2 represents the invention in the context of some aspects present in other related disclosures by the inventor involving the utilization of Lake Kivu deepwater resources and relating especially to the return flow of degassed water into the lake (34, 35, 36a,b,c). The figure is shown partly in vertical plane perspective: for Lake Kivu represented with three water layers, 23a,b,c. Otherwise, the figure is shown in non-spatially oriented representation of process flows. Box 1 is an inset showing the invention overall in its combinative aspect as a combination of submethods and subsystems (for the TDS modality only), where numerical labels correspond to identical labels elsewhere in FIG. 2. Box 2 illustrates aspects of the operations of the CO.sub.2 Utilization Hub (CO.sub.2-UH) and its twenty “main modes” of CO.sub.2 utilization. Box 3 is another inset. It illustrates adjunct utilization of excess liquid nitrogen and/or oxygen (via flow vectors 39 and/or 40 and/or 42) to cool one or more large refrigeration utilization facilities, such as, for example, a digital data center (43).

[0250] FIG. 3 is a schematic representation of an embodiment of the receiving (1, 2), processing, storage, and purveying aspects of the CO.sub.2 Utilization Hub (CO.sub.2-UH), with additional inclusion of the storage and utilization of liquefied nitrogen and oxygen in certain preferred embodiments. Most production flows (“process trains”) proceed from left to right. Five types of production flows are illustrated as horizontal sequences, left-to-right, stacked vertically (22, 23, 24, 25, 26). An additional dashed box (36) represents optional cryo-energy storage capacities utilizing liquefied gases.

[0251] FIG. 4 is a symbolic representation of an embodiment of the invention disclosed herein construed as a method and system of jobs-creation via greentech industrialization (7) in the Lake Kivu region measured by performance metrics reporting upon these factors symbolized by icons within item 8.

[0252] FIG. 5 is a comparative representation shown mostly in vertical plane schematic representation. The figure compares basic aspects of an embodiment of the invention (shown in Box 2) in with existing practiced technology, (as shown in Box 1), for extracting methane and generating power from Lake Kivu deepwater (circa 2015: SDS). Only the modality of the invention utilizing a TDS (rather than a MSDS) is shown in Box 2.

[0253] FIG. 6 is a schematic representation of cryogenic aspects of the invention including energy storage.

[0254] FIG. 7 is a purely symbolic “hub-&-spokes” representation of embodiments of the CO.sub.2-UH (and, more broadly, of the invention overall) located at Lake Kivu functioning as a hub (1) center for a global network (2: large circle plus associated box containing icons). The network can connect together many and various worldwide collaborations (3, 4, 5, 6, 7, 8, 9, 10, 11, 12 . . . ) with companies, research institutions and philanthropic agendas attracting talent into the overall venture. Entities work together in concert with respect to addressing the challenge to create business-scalable innovations in CO.sub.2 utilization recycling. Icons inside the dashed box represent multiple types of aspects of such a hub-and-spokes global network.

[0255] FIG. 8 is a schematic representation in vertical plane of: (i) in Box 1: a 2-stage representation of the Staged Degassing System (SDS) method invented by Belgian engineers in the 1950's and later practiced on Lake Kivu; and (ii) in Box 2: a modification of this staged method (MSDS, shown for 2-stages). The MSDS provides a means for separated degassing of CO.sub.2, thereby allowing CO.sub.2 utilization by adaptation of conventional operations. Box 3 illustrates a schematic representation of several pH control options utilizing CO.sub.2 inputs (21a,b, 22, 25, 27) and removals: 21a,b, 23, 24) in two different modalities of return flow: (15) and (16-through-20). These modalities of return flow (15, 20) into shallow layers of Lake Kivu are different from (deep) return flow according to the standard modality of the SDS method (9a, 9b, 13). Both represent modes of CO.sub.2 utilization by injection into Lake Kivu (for a range of various reasons).

[0256] FIG. 9 republishes FIG. 1 except with addition of detail within Box 4. This extra detail shows several ways by which embodiments of the invention utilize CO.sub.2 via a range of (optional) modes of injection-dissolution into return flow, as well as by (optional) direct diffusion into the lake. (Such injection of dissolution-absorbed CO.sub.2 into higher-level layers does not enhance threat risks of limnic eruption).

LISTING AND BRIEF DISCUSSION OF REFERENCE NUMBERS APPEARING IN THE FIGURES

[0257] A listing of reference numbers and their corresponding component names follows. These are provided according to the convention “X.Y” noted above. X represents the figure number. Y represents the component or item number label within figure X. References to numbered boxes in the figures sometimes differ from numbered items, but always in a simple and clear manner. In FIGS. 2 and 8 only, box numbers are differentiated from item label numbers. For example, FIG. 2 contains three boxes labeled “Box 1,” “Box 2,” and “Box 3,” but also contains separate items numbered 1, 2 and 3. These clearly are illustrated as distinct entities. In such cases (also in FIG. 8), “X.BoxY” in the text is used to reference “Box Y” in the figure, these being different from items in the same figure labeled “Y” (referenced “X.Y” in the text). Boxes sometimes are labeled simply by numerals as ordinary items, (though as boxes indicating associated operationally integrated collections of items). Boxes also sometimes are identified with numerical labels surrounded by a small solid line box possessing rounded corners. Use of such small boxes with rounded corners surrounding number labels is a form of highlighting for purposes of clarity. Such highlighted labels always identify larger boxes. This highlighting can be seen in an obvious way in FIG. 1 for boxes labeled one through five. A listing follows upon this basis. The listing lists all labeling reference numbers in the figures. These are ordered via the “X.Y” convention. Label numbers are provided by item-component names and/or brief descriptions:

[0258] 1. Aspects of FIG. 1 that are not shown within Box 4 are illustrated in FIG. 9. These are left out of FIG. 1 to avoid excessive complication. FIG. 1 mainly illustrates the process flow of degassing into oxy-fuel combustion into utilization of CO.sub.2 representing an invention that, overall, creates an integrated method and/or system for Lake Kivu Carbon Capture Utilization (CCU) in combination with the “traditional” agenda of electric power production, while also increasing lake safety over time.

[0259] 1.Box1. Box 1 represents a Total Degassing System (TDS, as labeled), generating efficient degassing of both methane and carbon dioxide together.

[0260] 1.Box2. Box 2 represents an Oxy-Fueled Combustion Power System, (OXFCPS, as labeled). The Box contains icons representing methane combustion driving turbine blades.

[0261] 1.Box3. Box 3 represents a CO.sub.2 Utilization Hub, (CO.sub.2-UH), as labeled. This generates product flows indicated by the black rightwards arrows jointly within Box 3 and Box 8.

[0262] 1.Box4. Box 4 contains and thereby groups together a variety of useful outflows of pipe-delivered CO.sub.2 (shown by arrows) from the CO.sub.2-UH. These outflows are into injection-dissolution Lake Kivu in a range of modes, including integration of injection into a Return Flow System (7), and serving a variety of purposes. Details are provided in FIG. 9.

[0263] 1.Box5. The dashed box labeled (5) connects together boxes 2 and 3. This connection represents a capacity for systems-integrative cryogenic energy storage utilizing refrigerated-liquified gases. Details are provided in FIG. 6.

[0264] 1.6. Deepwater extraction method and/or system.

[0265] 1.7. Return Flow System (sometimes labeled with the acronym RFS) as a main vector (7), also showing different plumbing options (7a, 7b) as well as integration into methods and/or systems for density reduction by removal of dissolved substances and also by removal of CO.sub.2 by degassing.

[0266] 1.Box8. Box 8 represents the set of product flows out of the CO.sub.2-UH. Icons indicate different product transport modes applicable at Lake Kivu (which lacks a railway link at present). Air transport is not shown, but is available.

[0267] 1.9. Labels 9a,b,c represent Lake Kivu according to three different layers. (The actual density structure of the lake is more complicated than shown by three layers.) 9a represents the biozone. 9c represent the resources-rich deepwater zone. 9b represents (a combination of) intermediate layers.

[0268] 1.10. Arrow 10 most directly represents an oxygen input for oxy-fueled combustion of methane in the OXFCPS (Box 2). Arrow 10 also may be construed to include an Air Separation Unit (ASU, not shown. See FIG. 2) for the production of O.sub.2 as well as co-production of N.sub.2 both in liquid (LN.sub.2) and gaseous (N.sub.2) forms.

[0269] 1.11. Arrow 11 indicates a method and/or system of mass transfer of degassed gas (containing both methane and carbon dioxide) from the TDS (Box 1) into the OXFCPS (Box 2).

[0270] 1.12. Arrow 12 indicates a method and/or system of mass transfer of postcombustion gas (containing both carbon dioxide and water vapor) from the OXFCPS (Box 2) into the CO.sub.2-UH (Box 3).

[0271] 1.13. A small dashed box 13 (within Box 1 and labeled MSDS) represents an optional embodiment of the invention described as the Modified Staged Degassing System (and/or method). It is further illustrated in detail in FIG. 8. The MSDS method and/or system lacks an OXFCPS. Hence the CO.sub.2 flux obtained from it is shown being provided directly (14) into the CO.sub.2-UH (Box 3).

[0272] 1.14. Item 14 is a CO.sub.2 transfer line specific to the MSDS, as noted above.

[0273] 1.15. Item 15 represents one or more CO.sub.2 transfer lines (typically pipes) exporting CO.sub.2 from the CO.sub.2-UH (Box 3), as product flows (8), into Lake Kivu via a range of possible and optional sub-methods and/or sub-systems. (See FIG. 9 for detail for items not shown in FIG. 1: 15a, 15b, 15c, 15d, 15e, 16, 17, 18, and 19.)

[0274] 1.20. Label 20 indicates a set of icons on top of Box 3 as well as to its right. These indicate various exemplary aspects of greentech industrialization in the CO.sub.2-UH (top), including product export (side).

[0275] 2.Box1. Box 1 is a symbolic inset indicating the invention as a combination of submethods and subsystems (specifically for the TDS-to-OXFCPS modality embodiment) with numbers corresponding to labeled items elsewhere in the diagram.

[0276] 2.Box2. Box 2 contains a core aspect of the invention, Carbon Capture Utilization (CCU) via greentech industrial processing and manufacturing using CO.sub.2 and consequent productive outputs/outflows. Specifically, Box 2 encloses an illustration of the CO.sub.2-UH (21) incorporating twenty different modes of CO.sub.2 distribution and Carbon-Capturing product production and export. Productive flows exiting the CO.sub.2-UH are shown as black arrows.

[0277] 2.Box3. Box 3 is a symbolic inset illustrating optional adjunct utilization of liquefied nitrogen and oxygen (LN.sub.2, LO.sub.2) for provision of cooling in a Digital Data Center (43: DDC), where items 39, 40 and 42 reference storage-directed flow vectors illustrated in the main part of the figure. (Note: A cryogenic ASU {item 27} produces LN.sub.2, LO.sub.2.) Such provision of cryogenic LN.sub.2 and LO.sub.2 is a capacity of some embodiments of the invention via adjunct capacities of the CO.sub.2-UH.

[0278] NB: Items 2.1 through 2.20 are all CO.sub.2 utilization modes described in Table 2.

[0279] 2.1. One (1) represents (CO.sub.2 provided to) local greenhouse horticulture.

[0280] 2.2. Two (2) represents (CO.sub.2 provided to) Lake Kivu Biozone fertilization (with two different injection-dissolution options noted as 2a and 2b).

[0281] 2.3. Three (3) represents (CO.sub.2 provided to) Return Flow System (RFS) for purposes of pH lowering.

[0282] 2.4. Four (4) represents (CO.sub.2 provided to) return flow water treatment of a variety of types involving CO.sub.2 injection for pH control.

[0283] 2.5. Five (5) represents (CO.sub.2 provided to) algal production (including bicarbonate).

[0284] 2.6. Six (6) represents (CO.sub.2 provided by) high-pressure pipeline delivery.

[0285] 2.7. Seven (7) represents (CO.sub.2 provided by) refrigerated delivery (as liquid and/or solid).

[0286] 2.8. Eight (8) represents CO.sub.2 incorporated into production of eco-cements and concretes and related materials.

[0287] 2.9. Nine (9) represents (CO.sub.2 utilized in) urea production from ammonia.

[0288] 2.10. Ten (10) represents (CO.sub.2 input into) production of formic acid.

[0289] 2.11. Eleven (11) represents (CO.sub.2 input into) production of carbon monoxide.

[0290] 2.12. Twelve (12) represents (CO.sub.2 input into) production of pyrethrum biopesticide. (Compressed CO.sub.2 is a diluent carrier fluid in canisters for spraying.)

[0291] 2.13. Thirteen (13) represents (CO.sub.2 use in various processes of) forest products processing and production.

[0292] 2.14. Fourteen (14) represents CO.sub.2 use in geothermal energy extraction (typically by pipeline delivery).

[0293] 2.15. Fifteen (15) represents various CO.sub.2 uses in fuels and chemicals production.

[0294] 2.16. Sixteen (16) represents CO.sub.2 uses as an input into syngas production.

[0295] 2.17. Seventeen (17) represents CO.sub.2 use as an input into syngas manufacturing of fuels and chemicals.

[0296] 2.18. Eighteen (18) represents CO.sub.2 use in gas fermentation production of various products (typically with hydrogen gas inputs).

[0297] 2.19. Nineteen (19) represents plastics production incorporating CO.sub.2 in various modalities.

[0298] 2.20. Twenty (20) represents production of a variety of high-value carbon products by reduction of CO.sub.2. (For example C-nanotubes.)

[0299] 2.21. Label 21 identifies a stippled box containing a combination of elements that together an example of a (large-scale multi-product example embodiment of a CO.sub.2-Utilization Hub: CO.sub.2-UH). Note that a CO.sub.2-UH in some embodiments includes large areas of algal/phytoplanktonic production which additionally may include zooplanktonic as well as fish production in various embodiments, and where injection can function as a CO.sub.2-fertilizing carbon source for photosynthesis.

[0300] 2.22. Item 22 is a method and/or system of upward extractive flux of gas-rich deepwater into a Total Degassing System (24: TDS) 2.23. Labels 23a, 23b, and 23c together identify Lake Kivu in upper, middle, and lower layers, respectively, as shown.

[0301] 2.24. Item 24 is a Total Degassing System (TDS) receiving deepwater flux (22) and splitting its output into fluxes of degassed gas (25) and degassed water (34).

[0302] 2.25. Item 25 is a method and/or system and/or apparatus of gas transfer (with hydrogen sulfide scrubbing if/as needed and gas compression and/or gas dehydration if/as needed). The transfer couples the flow of gas exiting from degassing and coordinates it to be fed into the Oxy-Fueled Combustion Power System (OXFCPS) and/or method.

[0303] 2.26. Item 26 is an Oxy-Fueled Combustion Power System (OXFCPS) and/or method. The OXFCPS receives transferred gas from item 25. It exhausts a mixture of nominally pure carbon dioxide and water vapor into a gas transfer exhaust system and/or method (28) transferring gas into an exhaust receiving and gas processing unit (30) within the CO.sub.2-UH (21).

[0304] 2.27. Item 27 is a method and/or system of oxygen transfer into the Oxy-Fueled Combustion Power System (26: OXFCPS) and/or method. In FIG. 2, as shown, the source is an Air Separation Unit (27: ASU); however other types of sources may provide input oxygen into combustion.

[0305] 2.28. Item 28 is a method and/or system and/or apparatus of gas (CO.sub.2+H.sub.2O) transfer for directing post-combustion hot exhaust gases from the Oxy-Fueled Combustion Power System (26: OXFCPS) into a gas-receiving processing, storage and purveying unit (30) within the OXFCPS (21).

[0306] 2.29. Item 29 is the transfer of power provided by the OXFCPS (26). This may be mechanical power or electrical power. An associated icon indicates production of electric power into a distribution grid.

[0307] 2.30. Item 30 is a gas-receiving processing, storage and purveying/distribution unit (30) within the OXFCPS (21).

[0308] 2.31. Item 31 indicates an optional transfer flux of oxygen from the CO.sub.2-UH into the oxygen supply for combustion in the OXFCPS. Such a flow, for example, might be sourced as waste from electrolytic hydrogen production from water operating within the CO.sub.2-UH, and/or from CO.sub.2 splitting or other processes of CO.sub.2 deoxygenation.

[0309] 2.32. Item 32 identified a generic flux of inputs (including power) into the CO.sub.2-UH (21) other than the gas inputs specified by specific labels (28, 39, 42).

[0310] 2.33. Item 33 is an arrow representing the accumulation of all of the flux of product outputs out of the CO.sub.2-UH.

[0311] 2.34. Item 34 is a connecting method and/or system for transferring degassed deepwater from a Total Degassing System (24: TDS) into a Return Flow System (RFS: 35, 36a,b,c). Typically this involves pipes, pumps and valves.

[0312] 2.35. Item 35 represents the reception, storage, coordinating delivery and water-treatment parts of the overall Return Flow System (RFS: 35, 36a,b,c). In some embodiments, item 35 will include extensive operations for water treatment. As shown (2, 3, 4), these may involve connections with CO.sub.2 export from the CO.sub.2-UH (21).

[0313] 2.36. As shown, item 36 has three distinct modalities: 36a, 36b, and 36c. The differences are for different return flow water densities corresponding to different depth of reinjection into Lake Kivu. Differences correspond mostly to whether or not de-densification water treatment occurs, and if so, to what degree. Reinjection flux vector 36c represents diffusive fertilizing injection of post-degassing deepwater, (which may be without de-densification water treatment).

[0314] 2.37. Item 37 represents flows of CO.sub.2 proceeding from treatment and storage (in unit 30) into forms of production that transform CO.sub.2 into carbon-containing products. Types of processed CO.sub.2 are obtained from treatment of OXFCPS exhaust (in unit 30) with storage and disposition of it (in unit 30) into utilizing production activities within the wider parts of the overall CO.sub.2-UH (21).

[0315] 2.38. Item 38 is labeled within the Box 1 inset. It is the large circle that also is labeled as “Lake Kivu.” It represents both the domain of operations specific to Lake Kivu as well as the combinative domain of the invention as an integration of component sub-methods and/or sub-systems.

[0316] 2.39. Item 39 is a flux vector representing transfer of nitrogen gas, typically in liquefied form, into storage within unit 30. Typically, embodiments will include cryogenic methods and/or systems for transfer of liquefied nitrogen.

[0317] 2.40. Item 40 is a flux vector representing general production and use of liquefied nitrogen (LN.sub.2), for example, for use in Digital Data Center (43) cooling, or more generally for sale.

[0318] 2.41. Item 41 represents input of air or air-like gas into the Air Separation Unit (ASU: 27). “Air-like gas” here refers to gas obtained from canopies over areas of photosynthetic activity such as, for example, covered algal growth operations producing oxygen.

[0319] 2.42. Item 42 is a flux vector representing transfer of oxygen gas, typically in liquefied form, into storage within unit 30. Typically, embodiments will include cryogenic methods and/or systems for transfer of liquefied oxygen.

[0320] 2.43. Item 43 is a small box labeled within the inset Box 3. It represents a Digital Data Center (DDC) receiving cooling flows labeled 39, 40 and 42, these numbers referring to items shown elsewhere in the figure (all three associated with the ASU, 27).

[0321] 2.44. Item 44 is a flux vector representing the potential of utilization of flows of gaseous nitrogen after use in cooling a Digital Data Center (DDC: 43), for various purposes, for example in algal production operations and/or in horticultural uses.

[0322] 2.45. Item 45 is a flux vector representing the potential of utilization of flows of gaseous oxygen after use in cooling a Digital Data Center (DDC: 43), for example for oxyfuel combustion operations.

[0323] 3.1. Item 1 is identical to item 12 in FIG. 1 and item 28 in FIG. 2. It is a transfer flux of exhaust from the OXFCPS into the CO.sub.2-UH (which is detailed in FIG. 3). The flux is comprised of a hot and nominally pure mixture of carbon dioxide and water vapor.

[0324] 3.2. Item 2 is an optional component present in some high efficiency embodiments: a Heat Exchanger Power Production Unit (HEPPU) obtaining post-combustion power from heat present in the OXFCPS exhaust. Such units also can function as water separators by condensation of water vapor upon cooling (3, illustrated by an icon).

[0325] 3.3. Item 3 represents a water separation capacity by condensation. This water separation capacity also is shown as first stages within a process trains labeled 22 and 24. It also is shown as a stage within process train 23.

[0326] 3.4. Item 4 is a 3-way valve allowing input of CO.sub.2 into a treatment chamber (5) possessing pressurization (10) capacity for pressurized “carbonization” (CO.sub.2 absorption) into the production of eco-cements and concretes and other building materials.

[0327] 3.5. Item 5 is a treatment chamber described immediately above.

[0328] 3.6. Item 6 represents post-production product storage for carbonated building materials, as indicated by icons.

[0329] 3.7. Item 7 represents building materials product export/delivery by truck.

[0330] 3.8. Item 8 represents building materials product export/delivery by ship.

[0331] 3.9. Item 9 represents a storage capacity within process train 23. It is for storage, along with cooling and dehydration (3), of moderately compressed (10) carbon dioxide prior to further compression (10) prior to pipeline export (11a, 11b).

[0332] 3.10. The label 10 and an associated icon represents a CO.sub.2 compressor. This label and icon appears in several locations in the figure.

[0333] 3.11a,b. Pipe-&-valve icons labeled 11a and 11b indicate a range of pipeline delivery systems at various pressures and pipeline diameters for local distribution/delivery of relatively low-pressure (non-supercritical) CO.sub.2.

[0334] 3.12. Tank icons labeled 12 represent a tank farm storage depot for pre-delivery storage of relatively high-pressure (typically supercritical) non-refrigerated CO.sub.2.

[0335] 3.13. Pipe-&-valve icon labeled 13 represents pipeline(s) delivery of relatively high-pressure (typically supercritical) non-refrigerated CO.sub.2.

[0336] 3.14. Pipe-&-valve icon labeled 14 represents by-truck delivery of relatively high-pressure (typically supercritical) non-refrigerated CO.sub.2.

[0337] 3.15 a,b. Items 15a and 15b represent pipeline connections within the CO.sub.2-UH that supply high pressure CO.sub.2 into refrigeration stages for liquification (15a) and dry ice production (15b).

[0338] 3.16. The icon set labeled 16 indicates a cryogenic capacity for liquification of CO.sub.2 with associated insulated tank storage (17). This capacity may be identical with or supplementary to an Air Separation Unit (ASU, illustrated in other figures). In relation to the dashed box labeled 36, this cryogenic capacity may include refrigeration of other gases: oxygen and nitrogen, along with insulated tank storage (30, 31).

[0339] 3.17. Insulated tank storage for refrigerated liquid CO.sub.2.

[0340] 3.18. Insulated by-truck transport of refrigerated liquid CO.sub.2.

[0341] 3.19. The icon set labeled 19 indicates a cryogenic capacity for solidification of CO.sub.2 into dry ice, with associated cool storage (20).

[0342] 3.20. Icon 20 represents dry ice storage.

[0343] 3.21. Icon 21 represents by-truck transport/delivery of dry ice. Transport/delivery additionally may be by any other means as well, including boat and motorcycle.

[0344] 3.22. Label 22 (inside a highlighting circle) indicates a process train for CO.sub.2 utilization for the production of eco-cement and concrete products produced with absorption of CO.sub.2 (and also water vapor for hydration).

[0345] 3.23. Label 23 (inside a highlighting circle) indicates a process train for CO.sub.2 utilization as relatively unprocessed gas delivered at relatively low pressures.

[0346] 3.24. Label 24 (inside a highlighting circle) indicates a process train for CO.sub.2 production/delivery as relatively high pressure gas.

[0347] 3.25. Label 25 (inside a highlighting circle) indicates a process train for CO.sub.2 production/delivery as refrigerated liquified gas.

[0348] 3.26. Label 26 (inside a highlighting circle) indicates a process train for CO.sub.2 production/delivery as dry ice.

[0349] 3.27. Label 27 represents crossover transfer if/as needed from high-pressure CO.sub.2 storage to low-pressure delivery.

[0350] 3.28. Label 28 represents control over the temperature and water vapor content of CO.sub.2 input into carbonation and hydration facilities for eco-cement and concrete and related products production (=process train 22).

[0351] 3.29. Label 29 identifies a cryogenic energy storage method, system, capability or unit utilizing liquefied liquefied nitrogen and/or liquefied oxygen (and/or CO.sub.2 linkage, not shown except as two-sided vector 34).

[0352] 3.30. Label 30 indicates an icon representing tank (or tank farm) storage of refrigerated liquefied oxygen.

[0353] 3.31. Label 31 indicates an icon representing tank (or tank farm) storage of refrigerated liquefied nitrogen.

[0354] 3.32. Label 32 indicates connectivity of the cryogenic energy storage capacity (29) with tank(s) for insulated storage of liquid oxygen.

[0355] 3.33. Label 33 indicates connectivity of the cryogenic energy storage capacity (29) with tank(s) for insulated storage of liquid nitrogen.

[0356] 3.34. Label 34 indicates that in some embodiments, there can be connectivity of cryogenic energy storage methods and/or systems (29) with production and storage of solid CO.sub.2.

[0357] 3.35. Label 35 of a two-sided arrow represents a gas transfer linkage between cryogenic energy storage capacities (29) connecting (32) to liquid oxygen storage (30). The transfer linkage connects (outside of the figure) into the intake oxygen supply into oxyfuel combustion (OXFCPS) and to the Air Separation Unit (ASU, not shown) oxygen supply that produces liquid oxygen in cases where oxygen separation from air is via cryogenic methods.

[0358] 3.36. Label 36 represents the overall capacity of the linkage with the cryogenic capabilities of the ASU to provide refrigeration into process trains 25 and 26. In some embodiments this capacity includes and integrates cryogenic energy storage (29).

[0359] 3.37. Icon 37 indicates a general capacity for provision/sales of refrigerated liquid oxygen.

[0360] 3.38. Icon 38 indicates a general capacity for provision/sales of refrigerated liquid nitrogen.

[0361] 3.39. Label 39 indicates a transfer capacity for connecting stored refrigerated liquefied CO.sub.2 into specialized cryogenic energy storage for CO.sub.2 (40).

[0362] 3.40. Item 40 indicates options for inclusion in some embodiments of specialized cryogenic energy storage utilizing liquid CO.sub.2.

[0363] 3.41. Item 41 indicates embodiments that include integration of cryogenic CO.sub.2 energy storage into cryogenic energy storage methods and/or systems utilizing LN.sub.2 and/or LO.sub.2 (29). (NB: As indicated by item 40, cryogenic energy storage methods and/or systems utilizing CO.sub.2 may be separate from cryogenic energy storage utilizing LN.sub.2 and/or LO.sub.2 (29).)

[0364] 4.1. Item 4.1 is a schematic flux vector representing methods and/or system of extraction and separation of Lake Kivu deepwater (12). Deepwater is directed into several components (2) for utilization operations, shown involving, for CO.sub.2, a CO.sub.2-Utilization Hub (CO.sub.2-UH) utilizing combined CO.sub.2 (10, 11) from deepwater degassing (3) as well as combustion (9) of co-extracted deepwater methane (6).

[0365] 4.2. Dashed box 2 represents the cumulate of utilizable resource components of Lake Kivu deepwater (12).

[0366] 4.3. Box 3 represents one component: degassed deepwater CO.sub.2.

[0367] 4.4. Box 4 represents another component: deepwater bicarbonate ion.

[0368] 4.5. Box 5 represents additional chemically dissolved resource components such as dissolved Mg and Ca cations as well as NPK fertilizers and additional important fertilizing trace elements.

[0369] 4.6. Box 6 represents degassed deepwater biomethane.

[0370] 4.7. Box 7 represents a CO.sub.2-Utilization Hub (CO.sub.2-UH), with icons indicating its aspect as a basis for jobs-creating greentech industrialization.

[0371] 4.8. Box 8 represents the outcomes of greentech industrialization exemplified by jobs, economic growth and increased per capita GDP.

[0372] 4.9. Box 9 represents power production via combustion with efficient carbon capture.

[0373] 4.10. Arrow 10 represents efficient carbon (CO.sub.2) capture with transfer into a CO.sub.2-Utilization Hub (CO.sub.2-UH).

[0374] 4.11. Arrow 11 represents capture and transfer of deepwater CO.sub.2 into a CO.sub.2-Utilization Hub (CO.sub.2-UH). NB: This capture and transfer can be routed through combustion (9) in the case of a Total Degassing System (TDS) combined with oxyfueled combustion.

[0375] 4.12. Label 12 indicates resource-rich Lake Kivu deepwater.

[0376] 5.1. Box 1 encloses a representation of the standard, practiced “Staged Degassing System” (SDS) of methane extraction and power production on Lake Kivu showing both the return of CO.sub.2 into the deepwater layer, and loss of postcombustion CO.sub.2 to the atmosphere.

[0377] 5.2. Box 2 encloses a representation of one mode of Lake Kivu deepwater resource extraction and utilization disclosed herein: the method and/or system of total degassing (TDS) combined with CO.sub.2 utilization.

[0378] 5.3. Label three (3) marks the a-depth inlet of Lake Kivu deepwater for methane extraction in the Staged Degassing System (SDS) method and/or system.

[0379] 5.4. A stippled box labeled four (4) indicates a two-staged degassing system.

[0380] 5.5. The numerical label five (5) represents the reinjection of dissolved CO.sub.2 (from Stage-1) into Lake Kivu's deepwater reservoir after degassing by the SDS method.

[0381] 5.6. The numerical label six (6) represents the reinjection of dissolved CO.sub.2 (from Stage-2, dissolved in “washing water”) into Lake Kivu's biozone after degassing by the SDS method.

[0382] 5.7. Label seven (7) marks a gas (methane-rich gas) transfer line from an offshore floating platform (12a) to an onshore power-generating facility (8).

[0383] 5.8. Label eight (8) marks an icon representing an onshore power-generating facility. (Placed onshore due to the very large sizes and weights of piston engine power generators utilized in the SDS method.)

[0384] 5.9. Label nine (9) indicates that CO.sub.2 formed from combustion in the SDS method is not captured. This CO.sub.2 is released into the atmosphere.

[0385] 5.10. Label ten (10) marks a depth inlet of Lake Kivu deepwater for methane extraction in the Total Degassing System (TDS) method and/or system.

[0386] 5.11. Label eleven (11) indicates a floating platform (also icon 12b) in the TDS-OXFCPS method and/or system (Box 2). As shown, the figure in Box 2 shows the possibility that the platform could include power plant operations (13). OXFCPS turbines utilizing a CO.sub.2 power cycle are much smaller than power generation operations utilizing large and heavy piston-type gas burning engines (8).

[0387] 5.12. Labels 12a and 12b both indicate icons representing floating offshore platforms.

[0388] 5.13. Label 13 indicates an icon representing power generation, in this case situated on a floating platform (11, 12b).

[0389] 5.14. Label 14 indicates that degassed CO.sub.2 is captured and enters a CO.sub.2-UH in the TDS-OXFCPS method (Box 2).

[0390] 5.15. Label 15 indicates that combustion-formed CO.sub.2 is captured and enters a CO.sub.2-UH in the TDS-OXFCPS method (Box 2).

[0391] 5.16. Label sixteen (16) indicates a CO.sub.2-UH, shown with icons representing greentech industrialization.

[0392] 5.17. Label seventeen (17) indicates a transition depth in Lake Kivu separating a resource-rich deepwater reservoir below an upper reservoir without concentrated resources. (This is a simplified representation. The actual situation is multi-layered.) For comparison, Box 2 indicates that this transition depth can move downwards (from 17 to 18) over time in some embodiments of the TDS method and other advanced methods of utilizing Lake Kivu deepwater resources (when return flow water can be de-densified so that it can be returned in higher-level layers and “push down” the depth of the transition later over time, as shown by arrows: 17 to 18).

[0393] 5.18. Label eighteen (18) indicates the time trend of deepening of a transition layer boundary in some embodiments of the TDS method and other advanced methods of utilizing Lake Kivu deepwater resources.

[0394] 5.19. Label nineteen (19, located in Box 1) indicates one aspect of methane loss or “slip” occurring in the SDS method. This loss is due to non-total degassing at the stage-1 transition wherein gas is degassed at a depth typically of ˜20 meters.

[0395] 5.20. Label twenty (20, located in Box 1) indicates another aspect of methane loss or “slip” in the SDS method. This loss is due to re-dissolution of methane degassed in Stage-1 into “washing water” degassed gas is bubbled through in Stage-2 operations for the purpose of CO.sub.2 separation.

[0396] 5.21. Label twenty-one (21) indicates a set of icons representing products output and transport from the CO.sub.2-UH (16).

[0397] 5.22. Label twenty-two (22) is a dashed circle within Box 1. It circles Stage-1 degassing operations whereby an upflow of deepwater (3) is separated into two fractions. These are: (i) a gas fraction which proceeds upward (23), and (ii) a water fraction containing most of the CO.sub.2 in solution (5) and some of the methane remaining in solution (19).

[0398] 5.23. Label twenty-three (23) indicates the upflow of degassed gas proceeding upwards into Stage-2 separation by means of bubbling up through an intensely showered downflow of near surface “washing water” (24).

[0399] 5.24. Label twenty-four (24) represents a “washing water” flow of near-surface water (which absorbs CO.sub.2 into solution) through Stage-2 “water washing” within Stage-2 (25). This water flows out of Stage 2 (25) and is reinjected into Lake Kivu's upper (above 17) Biozone (vector 6 carrying a load of re-dissolved CO.sub.2).

[0400] 5.25. Label twenty-five (25) indicated a sector secured to a floating platform (4, 12a) within which Stage-2 “water washing” occurs. Typically this is in an above-water tower supported on top of a floating platform.

[0401] 5.26. Label twenty-six (26) labels an upflow vector indicating an upward flow of Lake Kivu deepwater containing water (unfilled outer arrow), dissolved CO.sub.2 (black inner vector) and methane (thin stippled core vector).

[0402] 5.27. Label twenty-seven (27) indicates a total degassing separator wherein water is shown being separated into a return flow (28, 29, 30), while degassed gas flows upwards into oxyfueled combustion (13) for power generation (as indicated by icons).

[0403] 5.28. Label twenty-eight (28) indicates an early pre-treatment part of a Return Flow System (RFS).

[0404] 5.29. Label twenty-nine (29) indicates a water treatment phase in flow through a Return Flow System (RFS)

[0405] 5.30. Label thirty (30) indicates relatively shallow injection of return flow into the water column (causing “push down” 17 to 18) of the transition layer.

[0406] 5.31. Label 31 indicates reinjection of CO.sub.2-carrying (5) return flow water into the deepwater reservoir from which the methane-bearing deepwater (3) was obtained. Methane loss or “slip” (5) also is shown.

[0407] 6.1. Box 1 identifies/contains the OXFCPS and its intersections with various cryogenic energy storage components (Boxes 2, 3, 4, 22, and 23).

[0408] 6.2. Box 2 identifies/contains an Air Separation Unit (ASU) integrated with part of a CRyogenic Processing Unit (Box 22: CRPU) and liquefied gases storage units (Box 4, Box 28).

[0409] 6.3. CRyo-Energy Recovery Unit (Box 3: CRERU) showing its various interconnections with other components.

[0410] 6.4. CO.sub.2-UH (Box 4) with LN.sub.2, LO.sub.2, LCO.sub.2 and LNG storage capacities (Box 28).

[0411] 6.5. Item 5 represents a Digital Data Center (DDC) with capacities for being cooled by inputs of either or both cold gaseous N.sub.2 (12) and LN.sub.2 (11).

[0412] 6.6. Item 6 represents a flow transfer of liquified oxygen (LO.sub.2) from a cryogenic condenser source (29) in an Air Separation Unit-Cryo-Production Unit (Box 2: ASU-CRPU) into one or more storage tanks (23) within a cryo-storage domain for liquefied gases (28) obtained from air (or air-like) inputs (14).

[0413] 6.7. Item 7 represents a flow transfer of liquified nitrogen (LN.sub.2) from a cryogenic condenser source (29) in an Air Separation Unit-Cryo-Production Unit (Box 2: ASU-CRPU) into one or more storage tanks (24) within a cryo-storage domain for liquefied gases (28) obtained from air (or air-like) inputs (14).

[0414] 6.8. Item 8 represents a flow transfer of gaseous CO.sub.2 and/or liquified carbon dioxide (LCO.sub.2) from a cryogenic condenser source (30) intersecting (via Box 22: CESSI) with CO.sub.2-carrying post-combustion exhaust created in the OXFCPS (Box 1) and stored into one or more storage tanks (25) within a cryo-storage domain for liquefied gases (28) possessing general cryogenic capacities or integration into other cryogenic capacities within the overall system (27b, as indicated by the icon), and existing as a part of the CO.sub.2-UH (Box 4 and detailed in FIG. 3).

[0415] 6.9. Item 9 represents a flow transfer of liquified carbon dioxide (LCO.sub.2) from storage (25) into a CO.sub.2-specific heat exchanger turbine system (within Box 22: CESSI, as indicated by icons) that converts the cryogenic energy stored in liquefied CO.sub.2 into mechanical, then electric power (18a).

[0416] 6.10. Item 10 represents a flow transfer of liquified oxygen (LO.sub.2) from storage (23) into an O.sub.2-specific heat exchanger turbine system (within Box 22: CESSI, as indicated by icons) that converts the cryogenic energy stored in liquefied O.sub.2 into mechanical, then electric power (18b).

[0417] 6.11. Item 11 represents a flow transfer of liquified nitrogen (LN.sub.2) from storage (24) into an N.sub.2-specific heat exchanger turbine system (within Box 22: CESSI, as indicated by icons) that converts the cryogenic energy stored in liquefied N.sub.2 into mechanical, then electric power (18c).

[0418] 6.12. Item 12 is a captured flow of cold gaseous nitrogen from the outflow of the part of the Cryo-Energy Recovery Unit (Box 3: CRERU) that recovers cryo-energy stored in LN.sub.2. This cold gas is directed as a coolant flow into a Digital Data Center (5: DDC).

[0419] 6.13. Item 13 represents a flow transfer of (utilizable) warmed-up nitrogen gas out of the Digital Data Center (5) after absorbing heat.

[0420] 6.14. Input of air (or air-like gas) into the Air Separation Unit—Cryogenic Processing Unit (Box 2: ASU-CRPU).

[0421] 6.15. Black arrow 15 indicates inflow of electric power from the grid (33) into an electricity handling nexus (Box 41) integrated into the OXFCPS (Box 1).

[0422] 6.16. The black arrow labeled 16 indicates outflow of electric power into the grid (33) from an electricity handling nexus (Box 41) that is integrated into the OXFCPS (Box 1).

[0423] 6.17. Black arrow 17 indicates deployment of electric power from the electricity handling nexus (Box 41) into the ASU-CRPU (Box 2) to power cryogenic condensation of gases.

[0424] 6.18. Black arrows 18, 18a, 18b, and 18c indicate power inputs into the electricity handling nexus (Box 41) from in the Cryo-Energy Recovery Unit (Box 3: CRERU).

[0425] 6.19. Black arrow 19 indicates power provision from the electricity handling nexus (41) in the OXFCPS (Box 1) into the CO.sub.2-UH (Box 4) with its cryogenic capacities (27b) integrated with those (27a) in the Air Separation Unit—Cryogenic Processing Unit (Box 2: ASU-CRPU).

[0426] 6.20. Item 20 represents electrical power input from solar and/or wind power arrays. Typically these will be situated at remote locations with respect to Lake Kivu.

[0427] 6.21. Item 21 represents the connection of electric power inputs from solar and/or wind power arrays into the electricity handling nexus (Box 41) integrated with the OXFCPS (Box 1). The invention's optional inclusion of cryo-energy storage capacities allows energy storage of irregular inputs of renewable energy and consequently an important potential function in grid-balancing.

[0428] 6.22. Box 22 (“CESSI”) represents systems/methods of integration described as, “Cryogenic Energy Storage Systems Integration” (CESSI) coupling together an Oxy-Fuel Combustion Power System (Box 1: OXFCPS), an integrated Air Separation Unit —Cryo-Production Unit (Box 2: ASU-CRPU), a Cryo-Energy Recovery Unit (Box 3: CRERU), as well as a cryo-storage domain for liquefied gases (Box 28) functioning as a cryo-energy power-storage battery (26, as indicated by the battery icons).

[0429] 6.23. Liquefied oxygen (LO.sub.2) storage in a tank or tank farm.

[0430] 6.24. Liquefied nitrogen (LN.sub.2) storage in a tank or tank farm.

[0431] 6.25. Liquefied carbon dioxide (LCO.sub.2) storage in a tank or tank farm.

[0432] 6.26. Iconic representation of liquefied gases storage as a power battery.

[0433] 6.27. Items/icons 27a and 27b represent integrated cryogenic systems serving the ASU-CRPU (Box 2) and the cryo-storage domain (Box 28) within the CO.sub.2-UH (Box 4)

[0434] 6.28. Box 28 (dashed box) contains the cryo-storage domain within the CO.sub.2-UH (Box 4)

[0435] 6.29. Item 29 is a refrigerating heat exchanging air condensing unit within the ASU-CRPU (Box 2).

[0436] 6.30. Item 30 represents refrigerating heat exchanging condensing unit for refrigeration of CO.sub.2 to liquid within the CESSI (Box 22), exporting liquefied CO.sub.2 (8) into tank storage (25). This capacity may be considered to be identical to capacities labeled 27a and 27b for the specific case of the refrigeration-liquification of CO.sub.2.

[0437] 6.31. Item 31 is a captured flow of cold gaseous oxygen from the outflow of the part of the Cryo-Energy Recovery Unit (Box 3: CRERU) that recovers cryo-energy stored in LO.sub.2. This cold gas is directed as a coolant flow into input into oxy-fueled combustion in the OXFCPS (Box 1).

[0438] 6.32. Flux arrow 32 is a flow of post-combustion exhaust from the OXFCPS (Box 1) into the CO.sub.2-UH (Box 4). A note below the label clarifies an important matter that is not otherwise shown in the figure: that the exhaust flow is connected to heat exchange capacities within the CRERU-CESSI.

[0439] 6.33. An icon labeled thirty-three (33) represents connectivity with the grid. [Arrows fifteen (15) and sixteen (16) represent power flows into and out of the electricity handling nexus (Box 41) from and to the grid (33), respectively, indicating (cryogenic) power storage capacities as well as the conventional powerplant power production capacities.]

[0440] 6.34. The tank icon is labeled representing both LNG storage as well as a capacity for use of LNG in cryo-processing CH.sub.4—CO.sub.2 mixtures to obtain additional LNG and extracted dry ice (e.g., Baxter: WO2013062922A1, “System and Methods For Integrated Energy And Cryogenic Carbon Capture.”) Interconnection details are not shown in FIG. 6 (or in other figures).

[0441] 6.35. Cryogenic production capacity for LNG as well as for separation of CO.sub.2 as noted immediately above

[0442] 6.36. Box thirty-six (36) represents specialized cryogenic operations for LNG production as well as for separation of CO.sub.2 as noted for item 6.34.

[0443] 6.37. Flux vector representing inflow of biomethane with CO.sub.2 into LNG-specialized operations noted above.

[0444] 6.38. Source of biomethane with CO.sub.2 (=Lake Kivu deepwater via degassing operations).

[0445] 6.39. Flux vector representing the flow of separated biomethane with CO.sub.2 from LNG-specialized operations.

[0446] 6.40. Flux vector representing a general capacity for Natural Gas (NG) production (LNG, CNG, and ANG). This production follows cryogenic CO.sub.2 separation within LNG (item 35, by means of the elegant methods pioneered by Larry Baxter and colleagues). Output flux vector 40 also can indicate an output into energy storage via both LNG cryoenergy and LNG fuel energy (though icon/item 34 itself indicates this capacity).

[0447] 6.41. Label forty-one, (Box) 41, represents an electricity handling nexus whereby grid (33) power inputs (15) and outputs (16), as well as special inputs (21) of renewable power sources (20), are integrated into the OXFCPS (Box 1) NB: Label thirty-three (33) indicates the grid in connection to the electric power producing powerplant component of the OXFCPS.

[0448] 7. FIG. 7 is purely conceptual representing the invention in terms of its potential for global network creation by offering an attractive opportunity for the coordinated realization of many CO.sub.2-utilizing technologies.

[0449] 7.1. Item one (1) is the CO.sub.2-Utilization Hub (1: CO.sub.2-UH) represented as the hub of a wheel-like hub-&-spokes network in which each spoke (3, 4, 5, 6, 7. 8, 9, 10, 11, 12 . . . ) is a specific collaboration for a type of CO.sub.2 utilization.

[0450] 7.2. Item two (2) is the larger circle representing the outer wheel hosting spokes at a (global) distance from the hub but connecting into it. A box connecting to this large circle on the lower left represents by icons various aspects or types of collaborations. Also represented is its worldwide global aspect, attracting talent into the project as well as possessing an openness to host new inventive modes of CO.sub.2 utilization.

[0451] 7.3 through 7.12 are described in section 7.1 above.

[0452] 8. FIG. 8 provides a systems comparison. The comparison is focused on the modification of a conventional Staged Degassing System (SDS, Box 1). An SDS is shown with two stages as practiced on Lake Kivu. It is compared with a Modified Staged Degassing System (Box 2) allowing carbon (CO.sub.2) capture as well as utilization of non-degassed resources in the degassed return flow water. FIG. 8 contains Box 1 enclosing a Staged Degassing System (SDS), Box 2 enclosing a Modified Staged Degassing System (MSDS), and Box 3, (which is within Box 2), enclosing two modes of Return Flow Systems. These two RFS modes are different from deep reinjection modes indicated (depth not to scale) in items 9a, 9b, and 13. Note that in FIG. 8, the three box numbers noted above are distinct from item numbers 1, 2 and 3.

[0453] 8.Box1. Box 1 encloses a representation of a Staged Degassing System (SDS).

[0454] 8.1. Item 1 (shown in both boxes 1 and 2) represents a deepwater extraction pipe or riser.

[0455] 8.Box2. Box 2 encloses a representation of a Modified Staged Degassing System (MSDS).

[0456] 8.2. Item 2 (shown in both boxes 1 and 2) represents a stage-1 degassing and separation chamber, with a degassing surface positioned at depth D (10), showing how water flows up into the chamber, over a barrier, and then down reinjection pipes or risers (9a and 9b)

[0457] 8.Box3. Box 3, (which is within Box 2), encloses two modes of Return Flow Systems. One (15) is for diffusive admixing of degassed deepwater into the biozone as a mode of (carefully monitored and controlled) lake fertilization with controlled CO.sub.2 injection (27, 28). The other (proceeding along the surface, 16) is a water treatment water de-densification bioproduction and Mg, Ca-precipitation system, also with controllable CO.sub.2 input (e.g., 22, 25) and removal (e.g., 25) capacities.

[0458] 8.3. Item three (3), (shown in both boxes 1 and 2) represents a gas transfer line transferring degassed gas upwards from Stage-1 degassing into Stage-2 gas cleaning operations (4, 5, 6, 7, 8).

[0459] 8.4. Item four (4) represents an enclosed chamber, typically a tower, wherein gas flow from Stage-1 rises upwards through either via a bubbling upflow or upwards through a showered and/or packing-mediated trickling (6) downflow of water obtained from a near-surface location (5). The “washing water” is then expelled (7) into the biozone carrying absorbed CO.sub.2 that has been “cleaned” during the upwards gas flow. Cleaned methane gas consequently containing a reduced amount of CO.sub.2 is extracted at the top of the tower (8) for use in combustion. Bubble flow is indicated in the diagram. However, as noted herein, such a gas-cleaning tower may not use bubbling gas flow. It may contain packing materials promoting large area trickle flow interaction between the percolating down-flowing water and the up-flowing gas that is in close contact with the down-flowing water within the tower.

[0460] 8.5. Item five (5) represents near-surface extraction of water to supply gas “washing water” with pumped flow (6) to the top of the gas-washing tower (4).

[0461] 8.6. Item six (6) represents a pumped near-surface extraction of water to supply “washing water” with pumped flow (6) to the top of the gas-washing tower (4).

[0462] 8.7. Item seven (7) represents return flow (typically via one or more pipes) of the flow of gas-washing water into the biozone.

[0463] 8.8. Item eight (8) represents the gas extractor area (including gas extraction line) at the top of the gas-cleaning tower. In a bubbled flow, this is a gas zone above the surface of the mixed flow. In a tower operating by trickling flow, it is simply the area where the upward-flowing gas is extracted (in combination with the extraction line, and typically but not necessarily involving pumped control of gas flow).

[0464] 8.9a,b. Items nine (9a and 9b) represent return flow reinjection pipes. Depths are not shown to scale. Reinjection in the modes illustrated by necessity must be in the deepwater layer due to the density of the water (changed only to a modest degree by degassing).

[0465] 8.10. Double-sided arrow ten (10, shown within Box 1) represents a depth, D, for a degassing surface within the Stage-1 degassing chambers shown in Boxes 1 and 2.

[0466] 8.11. Item eleven (11) shown within Box 2 represents a key modification of the SDS method and/or system. This modification ports water after Stage-1 degassing upwards into a second stage of degassing, thereby allowing degassing and capture of CO.sub.2 as well as utilization of additional resources present in return flow water, by modification (such as of existing systems or designs).

[0467] 8.12. Item twelve (12) represents a second degassing chamber for separation of CO.sub.2 from the return flow. As illustrated, valves (indicated by bow tie icons) allow directing of return flow into different types of systems.

[0468] 8.13. Item thirteen (13) represents one such return flow system: conventional reinjection at depth similar to 9a and 9b.

[0469] 8.14. Item fourteen (14) represents extraction of CO.sub.2 out of the top of the second degassing chamber for separation of CO.sub.2 from the return flow (12).

[0470] 8.15. Item fifteen (15) represents (an array of) pipe diffusers for diffusive admixing of degassed return flow deepwater into Lake Kivu's biozone (as a mode of controlled lake fertilization).

[0471] 8.16. Item sixteen (16) represents a mode of water treatment of return flow.

[0472] 8.17a,b. Item seventeen (17a,b) represents a capacity for CO.sub.2 content control corresponding to vectors 21a,b. Capacity 17a represents control for CO.sub.2 input into the return flow. Capacity 17b represents control for CO.sub.2 removal such as by sparging and/or vacuum extraction of dissolved gas the return flow. Such capacities also are pH control capacities.

[0473] 8.18. Item eighteen (18) indicates a water biotreatment zone (typically involving algal growth in some embodiments). In some embodiments, as shown, CO.sub.2 inputs (22) are staged along the flow.

[0474] 8.19. Item nineteen (19) represents a capacity for two functions. The first is for CO.sub.2 extraction (as indicated by vector 24), such as by sparging and/or by vacuum extraction of dissolved gas the return flow. The second is for precipitation of Mg and Ca from solution according to a variety of possible methods and/or systems.

[0475] 8.20. Item twenty (20) represents return flow reinjection at a lesser depth than in the cases of return flow without de-densifying water treatment (that is: 9a, 9b, 13).

[0476] 8.21a,b. Item twenty-one (21a,b) is a double-sided arrow representing a capacity for either CO.sub.2 input (21a), or CO.sub.2 extraction (21b), with directionality specified as needed.

[0477] 8.22. Item twenty-two (22) indicates a capacity for input of CO.sub.2 into water treatment operations (18), typically involving algal growth.

[0478] 8.23. Item twenty-three (23) represents modes of CO.sub.2 removal from solution prior to entry into unit/process/method/system 19.

[0479] 8.24. Item twenty-four (24) indicates a capacity for CO.sub.2 removal from unit 19.

[0480] 8.25. Item twenty-five (25) indicates a capacity for CO.sub.2 injection into unit 26.

[0481] 8.26. Item twenty-six (26) represents a capacity for CO.sub.2 dissolution into the return flow (20).

[0482] 8.27. Item twenty-seven (27) indicates a capacity for pumping CO.sub.2 into the return flow modality shown as item 15, via a CO.sub.2 injection-dissolution unit labeled 28.

[0483] 8.28. Item twenty-eight (28) represents a CO.sub.2 injection-dissolution unit for return flow being diffused in a carefully controlled manner into the biozone via (typically an array of) pipe diffusers (15).

[0484] 9. FIG. 9 adds detail to FIG. 1. It does so within Box 4 (that is left empty in FIG. 1). Boxes 1 through three, and items 1 through 14, excepting items 7a and 7b, are identical to those displayed in FIG. 1. Therefore, below, names of items and brief associated contextual descriptions are provided only for the following labeled items: 7a and 7b, and items 15a,b,c,d,e, 16, 17, 18 and 19. (The set of icons labeled as item 20 is identical in FIG. 9 as in FIG. 1.)

[0485] 9.7 a,b. Items labeled seven (7a and 7b) indicate different modalities of return flow. Flow vector 7a corresponds to a method and/or system similar to item 15 in the previous figure (8.15). Flow vector 7b corresponds to return flow input entering into a water treatment method and/or system (as is shown, for example, in FIG. 8, items 17a.b, 18, 19, and 26).

[0486] 9.15 a,b,c,d,e. Items fifteen (15 a through e) indicate CO.sub.2 input flows from a CO.sub.2 Utilization Hub (1: CO.sub.2-UH) into a range of components of return flow operations (15a,b,d, e) as well as by direct diffusion-dissolution (15c) into the lake's biozone via an array of gas diffusers. Item 15a indicates pH-controlling CO.sub.2 injection-dissolution into return flow after “total degassing” via a TDS method and/or system (Box 1: TDS). Item 15b indicates CO.sub.2 injection-dissolution into return flow water treatment operations similar to those shown in FIG. 8, box 3 in a flow series beginning with item 16 (8.16). Item 15c indicates CO.sub.2 injection-dissolution directly into Lake Kivu's biozone by gas diffuser pipes as noted above. Item 15d indicates CO.sub.2 injection-dissolution into return flow directed into a water diffusion system diffusing return flow water into Lake Kivu's biozone. Item 15e indicates injection of CO.sub.2 into reinjection pipe systems (18) carrying water out from water treatment (16). This form of CO.sub.2 injection-dissolution is a mode of pH control (de-alkalization).

[0487] 9.16. Item sixteen (16) represents a water treatment sector utilizing biological processes such as algal photosynthesis. Such operations are known as Biological Production Units (BPUs).

[0488] 9.17. Item seventeen (17) represents a water treatment unit for precipitation of Mg and Ca. In some embodiments, this involves algal flocculation and harvesting.

[0489] 9.18. Item eighteen (18) represents return flow reinjection pipe systems carrying water out from water treatment (16) and in some embodiments utilizing CO.sub.2 injection-dissolution (15e) as a mode of pH control (de-alkalization).

[0490] 9.19. Item/vector nineteen (19) represents materials extractions supporting products production (8) modes based upon de-densifying water treatment of the return flow of degassed deepwater. Flow vector 19 should be considered as delivering materials into the CO.sub.2 Utilization Hub (CO.sub.2-UH: Box 1), for example Mg and Ca precipitates and algal biomass.

DETAILED DESCRIPTION OF PREFERRED EMBODIMENTS OF THE INVENTION

[0491] The disclosure of the invention presented herein is a teaching. It reveals to the Republic of Rwanda, and more broadly to the Kivu region of the DRC, an unprecedented possibility and opportunity for global leadership in advanced greentech industrialization, specifically in productive utilization of CO.sub.2 in amounts equal to the world's largest industrial flows of CO.sub.2. The location of Lake Kivu close to the geographical center of the African continent offers an economically favored opportunity for CO.sub.2-utilizing industrial production of products that are expensive to import from the coast. CO.sub.2 utilization also offers ways to produce a large number of high-value export products. The scale of the opportunity is very large within its context. A doubling of Rwanda's rate of per capita economic growth is possible.

[0492] Carbon dioxide has never been extracted from a lake for industrial use. No prior art exists in this specific category of activity. Carbon dioxide has been vented from lakes in Cameroon and in Spain (Halbwachs et al., 2004; Kling et al., 2005; Sanchez-Espana et al., 2014) for safety purposes using auto-siphoning pipe-jet fountains. There has been no capture and utilization of the gas.

[0493] Lake Kivu's dissolved gases trapped at depth are a mixture of methane and CO.sub.2. This situation presents a difficulty: too much CO.sub.2 is present for efficient combustion such that gas-cleaning stages are required, causing substantial efficiency losses. This problem has been solved by the inventor in a previous disclosure documented herein presenting a method and system of “total gas” extraction into an oxyfuel combustion heat engine that exhausts nominally pure CO.sub.2 (excepting water vapor which can be removed easily if desired). The situation also presents a difficulty for the use of the CO.sub.2 present, as noted, in a vast store in Lake Kivu of approximately 600 million tonnes. The invention disclosed herein discloses a method and system that allows hyper-efficient utilization and effective separation of both methane and CO.sub.2. This is via two variant processes: one involving modification of existing methane degassing methods, systems, designs and apparatus, and the other in conjunction with the oxyfuel method of power generation which utilizes unseparated “total gas” degassed by deepwater extraction degassing without a separation method separating CO.sub.2 from methane. It is surprising that it can be possible to unlock Lake Kivu's resources in such efficient ways without wasting either CO.sub.2 or methane. In the present disclosure, the primary focus is on unlocking Lake Kivu's CO.sub.2 resource in coordination with efficient capture and use of Lake Kivu's biomethane reserve. Degassing CO.sub.2 additionally can secure lake safety against a limnic eruption mega-catastrophe. This is a vital associated goal.

[0494] As noted herein, industrial sources of CO.sub.2, when obtained from natural occurrences, typically are nominally pure. A particularly pertinent example is the Kereita Forest spring source (actually a drilled fountaining jet of water and CO.sub.2) used by the Kenyan company Carbacid (CO.sub.2) Limited (www.carbacid.co.ke). Carbacid (CO.sub.2) Limited provides and sells CO.sub.2 from this source for use in beverage carbonation all over East Africa. It is ironic that businesses operating on the shores of Lake Kivu buy Carbacid CO.sub.2 obtained from the distant Kereita Forest while 600 million tonnes is trapped nearby, and when nearby volcanoes and mazuku vents bordering the lake naturally emit perhaps as much as 30 million tonnes CO.sub.2 per year into the local atmosphere. Another ironic aspect is the way the standard technology practiced on Lake Kivu returns CO.sub.2 into the depths of the lake (and thereby extends the mortal danger from a possible limnic eruption). As the MSDS method and system disclosed herein shows, CO.sub.2 can de degassed by a relatively simple design modification. However, when the standard design was created, it was not obvious how such large amounts of degassed CO.sub.2 could be used, whereas it generally is well understood that venting CO.sub.2 to the atmosphere is environmentally problematic. The present disclosure provides the surprising insight that many useful uses exist. These sum together to a very large scale of potential CO.sub.2 utilization. Unlocking Lake Kivu's trapped mega-source of CO.sub.2 offers a transformation by the creation of a massive flux of purified, naturally-sourced CO.sub.2 herein estimated roughly as ˜9 million tonnes per year. That is a surprise.

[0495] Separating CO.sub.2 by means of modifying the traditional staged degassing system design (SDS to MSDS as shown in FIG. 8) yields CO.sub.2 with residual methane present. It does not yield a purified CO.sub.2. (Avoiding methane wastage is one of the efficiency gains of the variant process based on total degassing followed by oxyfuel combustion.) This type of methane-laced CO.sub.2 has a special utility as an aquatic carbon source. When carbon dioxide in injected into the biozone, any accompanying methane can be utilized by oxidizing bacteria present in the biozone. Such bacteria can utilize methane as an energy source and also as a carbon source. Their growth can increase overall bioproductivity.

[0496] A particular challenge the invention addresses is CO.sub.2 utilization on a scale sufficient to match the scale of CO.sub.2 degassed in power plant operations obtaining Lake Kivu's methane and degassing its deepwater CO.sub.2. For the Rwandan side of the lake this scale is roughly 10 million tonnes of CO.sub.2 per year. That approximately equals the largest single source CO.sub.2 extraction flux in the world (from a CO.sub.2 well used to supply CO.sub.2 for EOR in west Texas, USA). Herein it is shown that at least ⅓.sup.rd of powerplant (OXFCPS) CO.sub.2 flux can be utilized valuably in direct connection with treatment of powerplant return flow reinjection into the lake. It is shown that this fraction increases to over ½ with inclusion of related CO.sub.2 utilization processes set by levels of different resources present in the deepwater. Several other CO.sub.2 utilization processes can boost the overall level of CO.sub.2 utilization to match the total level of flux. The invention demonstrates that it is possible to utilize the full scale of CO.sub.2 flux in an industrially productive manner. This is shown in Table 2.

[0497] The Lake Kivu region is magnificently attractive. The area has strong eco-tourism potential. It could be spectacular for real estate development. Accelerated development of the area will require concrete and other building materials for roads, culverts, bridges, runways, dams, buildings, tunnels, piers, docks and walkways. Magnesium-mineralized CO.sub.2 can provide a source of mineral carbonate mass for advanced construction materials sourced from CO.sub.2 combining with precipitated magnesium hydroxide, and also via carbonation of additional pozzolanic materials from abundant local volcanic ash sources. The region possesses densely populated hyper-fertile lands with a strong farming tradition. It is a situation likely to be enthusiastic for the development of CO.sub.2-boosted very-high-yield greenhouse horticulture. Farmers can utilize urea made with deepwater CO.sub.2 and bio-ammonium to intensify crop yields in the region, and to expand agro-production for exporting flowers, high-value specialty foods, plant extracts and other exports. These can include a wide variety of potential nutraceutical and pharmaceutical products linked with CCU. Pyrethrum production offers a substantial opportunity for organic biopesticide production linked with CO.sub.2 because it is a longstanding crop in the region. The wider region also has huge potential for minerals/metals extraction with value-add ore processing. A low-cost CO.sub.2 supply can assist several modes of metals extraction and value-add processing, as noted herein. These range from use of carbon monoxide in smelting tin to new technologies of coltan value-add refining, to dunite-olivine carbonation for production of silicon-, magnesium-, and iron-rich plant fertilizers, as well as eco-nickel from Mg-carbonate mineralization of CO.sub.2. The wider Lake Kivu region has huge potential for dry ice distribution. Dry ice can provide efficient off-grid refrigeration linked with beverage and food distribution. To the west, the great Congo forests have substantial potential for sustainable forestry products development. Production possibilities exist in many areas of CO.sub.2-utilizing industrial technology, ranging from bioplastics to biochemicals to biosynthetic textiles, to paper, xylitol, wallboard production and biofuels. All of these types of forest biomass-related products utilize CO.sub.2, and some use formic acid that can be produced from CO.sub.2. To the east are huge reserves of alkaline brines and soda ash already being used for sodium bicarbonate production. Sodium bicarbonate can be used in high-value algal products production. It also is useful in biomass and mineral ores processing. To the north, multi-billion barrel opportunities exist for extraction of oils supported by CO.sub.2-EOR technologies. Oil fields exist in the range 150 to 400 km distant from Lake Kivu. To the east, radiation-optimal locations for solar power arrays in NW Tanzania, NW Kenya and NE Uganda. These areas are attractive for solar power generation for the purpose of powering production of CO.sub.2-utilizing “solar fuels”/“electrofuels” production. High voltage wires can transport solar power from these regions to the CO.sub.2 supply at Lake Kivu. Lake Kivu biomethane can be used with CO.sub.2 input to produce Gas-to-Liquids (GTL) biomethanol for transport fuel admixing. Large-scale algae production utilizing CO.sub.2 as a carbon source offers opportunities for high-value nutraceuticals and pharmaceuticals production as well as biofuels, bio-asphalt, bio-nitrogen and bio-char fertilizers, CO.sub.2-utilizing bioplastics, and other green chemicals. In the future, many attractive commercialized technologies will emerge for large-scale CO.sub.2 utilization, for example, high-value carbon nanofiber and nanotubes production from CO.sub.2.

[0498] Numbers describing resource abundances in Lake Kivu deepwater and deepwater inflows are provided in Table 1 scaled to 100 MW for electric power output. Estimates of potential practical scales for the examples provided of 20 “main mode” possibilities for CO.sub.2 utilization shown in Table 2. These are scaled to roughly a 400 MW power output. The comparison shows that CO.sub.2 output at this scale (˜9 MTA CO.sub.2) can be utilized practically.

TABLE-US-00001 TABLE 1 LAKE KIVU DEEPWATER RESOURCES & ANNUAL FLUXES Kivu Total MRZ conc. 100 MW scale* Resource (Resource zone, tonnes) (per 1000 litres) (T: tonnes/yr) Methane ~47 Million T*** ~250 grams ~132,000 T/yr CO.sub.2 (from CH4 ~363,000 T/yr combustion): CO.sub.2 (gas) ~400 Million T** ~3.5 kg ~1.9 Million T/yr CO.sub.2 (total degassed + ~2.3 Million T/yr combustion): HCO.sub.3.sub.− ~500 Million T** ~4.2 kg ~2.2 Million T/yr Ammonium ~12 MT (UE)** ~60 g (NH.sub.4.sup.+) ~53,000 T (UE)/yr Phosphorus ~0.6 MT (P)** ~5 g (P) ~2,600 T (P)/yr Magnesium ~35 MT (Mg)** ~300 g (Mg) ~156,000 T (Mg)/yr MRZ = Main Resource Zone. MRZ volume: ~118 km3 deepwater. *Deepwater extraction/use scaled to 100 MW power output for the method and system disclosed herein: 0.53 cubic km deepwater/yr **Main Resource Zone (MRZ) only. ***Methane total estimate for Lake Kivu for all zones reported by Wuest et al., (2012). Other concentrations from Tassi et al., (2009). UE = Urea Equivalent mass.

TABLE-US-00002 TABLE 2 CO.sub.2 UTILIZATION MODES & ESTIMATES Scale Potential (MTA) (Million Tonnes Mode of CO.sub.2 Utilization CO2 per Annum) Notes  1. Local greenhouse horticulture ~2 area: ~5,000 hectares  2. Lake Kivu biozone CO.sub.2-fertilization ~2 scaled to ~400 MW  3. Lake Kivu return flow pH-lowering ~1 scaled to ~400 MW  4. pH control, return flow water treatment n.e. Precip. control & algal C-source  5. Algal production (incl. bicarbonate): ~0.5 to 5 >35 tonnes dryweight/ha/yr  6. High-pressure CO.sub.2 pipeline delivery ~1 to 4 mostly for CO.sub.2-EOR  7. Refrigerated CO.sub.2 delivery: ~0.1 liquid CO.sub.2 & dry ice  8. Eco-concrete & related materials: ~0.7 scaled to Mg-hydroxide flux  9. Urea production from NH.sub.3: ~0.3 scaled to NH.sub.4.sup.+ flux 10. CO.sub.2 to formic acid: ~0.01 many & various uses 11. CO.sub.2 to carbon monoxide (CO): ~0.01 for example tin smelting 12. CO.sub.2-pyrethrum biopesticide: ~0.02 e.g., BRA: Botan. Res. Austr. 13. Forest products CO.sub.2 processing: n.e. e.g., Chempolis (formic acid) 14. CO.sub.2-geothermal energy extraction: n.e. emerging technology 15. Fuels & chemicals production: n.e. many companies 16. CO.sub.2 + H.sub.2O to syngas: MeOH, DME: n.e. e.g., Haldor Topsoe 17. CO.sub.2 to oxalic acid platform: n.e. e.g., LiquidLight 18. CO.sub.2 + H.sub.2 into gas fermentation: n.e. e.g., LanzaTech 19. CO.sub.2 into plastics: n.e. e.g., Covestro, Novomer 20. CO.sub.2 into high-value C-products n.e. e.g., C-nanotubes TOTAL, ESTIMATED SOURCES: ~>9 MTA CO.sub.2 output, 400 MW power plant:  ~9 MTA n.e. = not estimated

[0499] A reasonable scale for application of the invention disclosed herein is ˜400 MW of total electrical power generation. This scale is based on combustion efficiency optimization suggested by a business partnership that manufactures advanced oxyfuel turbine systems. A reference scale target for CO.sub.2 utilization therefore is set by the sum of degassed CO.sub.2 and combustion-created CO.sub.2 for 400 MW on power output. This result is: 9 MT CO.sub.2/yr. Input data for this calculation are provided in Table 1. A rough maximum scale for CO.sub.2 utilization corresponds to degassing of the entire budget of CO.sub.2 in Lake Kivu (˜600 million tonnes) in ˜30 years plus 50 MT biomethane converted to CO.sub.2 mass (=138 MT CO.sub.2). This amounts to a production of roughly 700 to 750 MT CO.sub.2 in 30 years, hence up to: ˜25 MTA CO.sub.2. This maximum CO.sub.2 utilization opportunity scale is close to the world's largest scale of CO.sub.2 utilization in the context of a CO.sub.2 pipelines hub: ˜30 MTA CO.sub.2 through the West Texas Denver City hub for CO.sub.2-EOR. Note that removal of Lake Kivu's deepwater CO.sub.2 is essential for long-term human safety in the Lake Kivu basin involving millions of human lives as well as the ecological survival of Lake Kivu's fauna (which periodically has been destroyed by past limnic eruptions).

[0500] The system of the invention comprises subsystems including a carbon dioxide utilization hub (CO.sub.2-UH). In certain embodiments, the system comprises two or three coupled subsystems shown in FIG. 1: (i) TDS or MSDS variant; (ii) OXFCPS (not present in the MSDS variant); and (iii) CO.sub.2-UH. Other embodiments additionally comprise other subsystems such as at least one CO.sub.2 utilization subsystem expressed as a specific modality or associated set of modalities of production and output operating via the CO.sub.2-UH. Certain embodiments of the invention differ from one another only in the nature and quantity of these CO.sub.2 utilization subsystems supplied with CO.sub.2 by the CO.sub.2-UH.

[0501] CO.sub.2 utilization subsystems suitable for use in the invention are not particularly limited in scope or quantity. The hundreds of possibilities for CO.sub.2 utilization described herein are exemplary rather than exclusive. The twenty different subsystems or main modes of CO.sub.2 utilization described below and in Table 2 above exemplify a wide spectrum of embodiments of the invention. Potential CO.sub.2 utilization scales are cited where it has seemed reasonable to do so, but such scales are not intended to have a limiting effect on the scope of the invention. Certain preferred embodiments presented under the categories of the twenty main modes of CO.sub.2 utilization included in the following sections are not exclusive of one another. They may be performed independently or in any of a large number of combinations. The listing and illustration of twenty main modes is not meant to be delimiting. The general concept of a CO.sub.2 Utilization Hub is that it is open to the incorporation of new modality types (as is illustrated in FIG. 7). This aspect of openness is a preferred embodiment of the invention.

[0502] The invention disclosed herein solves a major unsolved technological problem of practical CO.sub.2 utilization on a large scale in the context of a developing economy remote from railway connections and oceanic ports. Specifically, the major challenge is CO.sub.2 utilization: to degas and then productively utilize Lake Kivu's huge (˜600 million tonnes) supply of deepwater dissolved CO.sub.2. Simultaneously, certain embodiments of the invention solve five additional big problems and challenges: (i) efficient power production utilizing Lake Kivu's deepwater methane with avoidance of wastage of a limited resource; (ii) insuring lake safety (as well as resource loss) against the possibility of mega-catastrophe from CO.sub.2 asphyxiation via a runaway “limnic eruption” degassing event; (iii) building-up regional development on a large scale via industrialization; (iv) power load balancing in various contexts including load balancing for the local and national power grid and for intake and industrial utilization of solar power; and (v) creating a globally strategic demonstration of large scale CO.sub.2 industrial utilization as a major contribution towards solving problems of rapid and accelerating CO.sub.2 accumulation in the atmosphere.

[0503] FIG. 1, shows a novel method and system based upon linking specific opportunities of Lake Kivu power production to a large and diverse body of technological insight and innovation on CO.sub.2 utilization such as is documented very extensively herein as a teaching. This teaching clarifies the background and nature of the invention, especially in the context of generic conventional beliefs that CO.sub.2 is useless in the context of Lake Kivu and, if degassed, would be vented and hence an environmental nuisance.

[0504] The inventive embodiment shown in FIG. 1 integrates insight on CO.sub.2 utilization into an overall method and system for Lake Kivu deepwater gas extraction and use via a core combination of three submethods and subsystems. These are shown within boxes 1, 2 and 3 as represented in the figure: (i) degassing in a total degassing system (TDS: 1) that includes extracting (6) gas-rich deepwater (9c) from Lake Kivu (9a,b,c); (ii) power production and CO.sub.2-dominated exhaust creation by means of an oxyfuel combustion power system (OXFPCS: 2) which intakes (and includes production of) pure oxygen for oxy-combustion (10); and (iii) receiving, processing and utilizing CO.sub.2 in a CO.sub.2 utilization hub (CO.sub.2-UH: 3), with the overall activity generating electrical power as well as various types of product streams from various modalities of CO.sub.2 utilization (8). Flow vectors, (11, 12) are shown connecting these boxes with flow compositions as identified. In addition to the three core submethods and subsystems (1, 2, 3), two additional boxes are shown in dashed outline (4, 5). These represent non-core aspects of the process flow of the invention. Box 4 includes a set of five modalities of CO.sub.2 utilization, but these are shown in detail only in FIG. 9 (FIG. 9: 15a,b,c,d,e). These are abbreviated as a single flow-designating arrow (15) in FIG. 1. Box 5 represents cryo-energy storage capacities linking the OXFCPS (2) to the CO.sub.2-UH (3) where cryogenically liquefied gases are stored. Embodiments with this capacity are included and preferred. They allow the powerplant to provide electric power load-balancing services for its own output as well as for solar power inputs into the operations of the CO.sub.2-UH. Further expansion of cryo-energy storage capacities, included as a preferred embodiment, also may allow load-balancing services to be provided to the grid. This is done via the powerplant's (included) Air Separation Unit (ASU), which is shown in FIG. 1 only as item 10 providing oxygen gas for oxyfueled combustion. Thus, in the full modality of incorporation of the capacity indicated by box 5 within the invention, the ASU operates in an expanded modality embodiment as a Cryo-Production Unit (ASU-CRPU. FIG. 6 and associated text provide further detail). Note, however, that the ASU providing oxygen into oxyfueled combustion is not limited to a cryogenic method. Non-cryogenic modalities of provision of oxygen herein are included as embodiments such as, for example, ion transport membranes (ITMs) and other oxygen-selective membrane separation methods.

[0505] The modalities of CO.sub.2 utilization shown in FIG. 1, box 4 are aspects of the extended function (8) of the CO.sub.2-UH (box 3). They are shown as a separate box because they all recycle CO.sub.2 from one part of Lake Kivu (9c) to a variety of uses within, and floating on, the lake's biozone (9a). These uses provide a means to utilize CO.sub.2 in a substantial fraction of the total flow

[0506] FIG. 1 represents the core aspect of the invention as a combinative integration of three submethods and subsystems represented by the three boxes labeled 1, 2 and 3, with their interconnections 11 and 12. A variant of this core is represented wherein a modification of the standard degassing method (SDS: Staged Degassing System: see FIG. 8) is shown identified by the acronym MSDS (10, 14). This variant represents a modification of the Belgian method (of methane purification by staged separation/removal of CO.sub.2 using gas-water partitionings differentiating between methane and CO.sub.2) that has been designed and deployed on Lake Kivu ever since it was created in the 1950s. The MSDS method is illustrated in FIG. 8 and described in associated text.

[0507] In FIG. 1, the MSDS is indicated by item 13 (representing a CO.sub.2 degasser within a MSDS) connecting (14) into the CO.sub.2-Utilization Hub (3). Item 13 transfers CO.sub.2 flux into a CO.sub.2-UH from a MSDS-type degassing system and method that degasses deepwater CH.sub.4 and CO.sub.2 separately. (For details see FIG. 8.)

[0508] The invention does not subsist in its constituent submethods and subsystems. FIG. 1 describes the invention in its aspect of being an integrative combination of submethods and subsystems. Shown for the TDS variation is an integration of three submethods and subsystems. These are labeled 1, 2 and 3 described by the acronyms, TDS (for: Total Degassing System), OXFCPS (for: Oxy-Fuel Combustion Power System) and CO.sub.2-UH (CO.sub.2 Utilization Hub), respectively. Vertical plane perspective is employed only for Lake Kivu (9) with gas-rich water extraction (6) from deep in the lake (9c), and degassed water flow return (7) connecting via the TDS (1) located partly above the surface of the lake.

[0509] Embodiments of the TDS and the OXFCPS suitable for use in the present invention are disclosed by the inventor in U.S. Patent Application No. 62/007,912, filed Jun. 4, 2014. The present invention is not limited to such embodiments, however.

[0510] The OXFCPS is a submethod and/or subsystem which combusts methane present within the degassed gas transferred from the TDS. It transforms released energy into mechanical power extracted via a heat engine. Typically, but not always, this power is transformed into electricity. The central aspect of oxyfuel combustion is that the method and system inputs nominally pure oxygen into combustion rather than air (with its associated large component of nitrogen gas accompanying oxygen gas). The OXFCPS here defined incorporates sourcing of separated oxygen in some form of Air Separation Unit (ASU), but is open with respect to the specific technologies employed for oxygen separation. Methods and systems used may be traditional cryogenic air separation or newer ion transport membrane (ITM) processes, or any effective method. All are herein included in embodiments: any separation process or processes such as may provide nominally pure oxygen into oxyfuel combustion. It is not necessary for atmospheric air to be input. Other input gas sources are possible.

[0511] The OXFCPS defined herein may or may not include one or more supercritical CO.sub.2 power cycles. The OXFCPS facilitates efficient use of a total gas input from the TDS, containing methane efficiently extracted, modified only as needed for H.sub.2S removal and/or removal of water vapor, and efficiently combusted under oxyfuel conditions forming an exhaust stream of easily separable CO.sub.2+H.sub.2O. A strong efficiency advantage may optionally be supplied by intake compression of the “total gas” inflow into a supercritical CO.sub.2 power cycle.

[0512] The CO.sub.2-UH is a submethod and/or subsystem of the invention described and defined in its basic attributes as follows. Detailed physical specifications for components may be many and varied such as correspond to matters of design at a level of detail unrelated to the inventive art disclosed herein. Such matters are known to those skilled in the art. The CO.sub.2-UH: (i) receives exhaust either from the OXFCPS comprised of a nominally two-component mixture of CO.sub.2 and steam, or in the variant MSDS-based method and system as CO.sub.2 and water vapor; (iii) processes this gas flow initially, if and as needed, for example in some embodiments via heat exchange energy capture, and in some other embodiments by gas dehydration, or with combination of both; (iv) partitions and directs the resulting gas flow into one or more process trains; (v) prepares and produces such flows through one or more of these process trains for utilization in one or more ways, for example as a mode of raw gas (in some process trains), or in various grades and forms of CO.sub.2 (in other process trains), and/or uses the resulting gas flows from one or more of these process trains to produce products requiring CO.sub.2 inputs (in other process trains) and/or requiring the use of CO.sub.2 in their production (in other process trains). In certain preferred embodiments, one or more process trains may share cryogenic functions with the ASU component of the OXFCPS. In certain preferred embodiments, process trains purposed for CO.sub.2 refrigeration are co-utilized for cryogenic gas processing, storage and dispersing of liquid nitrogen and liquid oxygen and/or liquefied natural gas (LNG). In summary, the CO.sub.2-UH in its operation transforms the flow of CO.sub.2-containing exhaust from the OXFCPS into flows of various CO.sub.2 products, and/or CO.sub.2-containing products, and/or products manufactured with the use of CO.sub.2. In some preferred embodiments, these features are supplemented by add-on capabilities for receiving, storing and dispensing pressurized and/or liquefied nitrogen and pressurized and/or liquefied oxygen and pressurized and/or liquefied natural gas. Sometimes these supplemented capacities support the storage and recovery of cryo-energy such as can be useful for varying power output to the grid and/or for grid balancing, sometimes involving cryogenically storing inputs of time-varying power inputs from the grid such as renewable power sources (see FIG. 6). Production of purified NG and LNG also opens up possibilities, herein included as preferred embodiments, for conventional energy storage as well as providing the capacity for sales of LNG, Compressed Natural Gas (CNG), and Absorbed Natural Gas (ANG) if/as desired. Production of LNG also offers a mode of dry ice production as a byproduct of CO.sub.2 separation from biogas (Fazlollahi and Baxter, 2017). Such dry ice also can be used for cryo-energy storage via the methods developed by Larry Baxter and colleagues (explanations and publications posted on https://sesinnovation.com)

[0513] FIG. 2 provides further detail to illuminate the representation made in FIG. 1 but does not include illustration of the MSDS-based variant shown in FIGS. 1 and 8. FIG. 2 shows in schematic representation the invention as an industrial process arising out of Lake Kivu's layered structure represented by arrows, circles and boxes. Deepwater resources of dissolved gases are extracted (22), and then utilized (26, 21, 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20). These deepwater resources are present principally, (but not exclusively), in Lake Kivu's so-called Main Resource Zone (23c). FIG. 2, box 2 encloses schematically the method and system of a CO.sub.2-UH (21) organizing the transformation of inputs (28; 32; 39), especially CO.sub.2 plus water vapor (28), into outputs (item 33), comprising twenty or more main modes (represented in FIG. 2 by vectors 1 through 20). The industrial process creates products that include electric power (29) produced by an oxyfuel combustion power production method and/or system (26; 27; 28; 29) including an air separation unit (27). In the TDS-based variant of the invention, the power production method and system is the OXFCPS. It is shown as a circle (26) linking together a nexus of inflows (25; 27) of fuel gases (25; 27) and outflows of power (29) and post-combustion exhaust (28). The main carbon source input into the CO.sub.2-UH is the post-combustion exhaust (28) expelled by the OXFCPS. The CO.sub.2-UH receives, stores, dispenses and utilizes this exhaust, which is comprised mostly of carbon dioxide and water, either in the form of vapor or condensed liquid water. It uses electric power, either internally produced by the powerplant (as represented by output vector 29), or from any other source. Inputs of any type needed for production are represented by vector 32. These inputs enter into the CO.sub.2-UH. The industrial process (and method and/or system) also produces a suite of carbon-containing (and hence carbon-capturing) industrial products [1 through 20 as outputs (33) of CO.sub.2-UH (21)]. Outputs are created by means of submethods and/or subsystems organized within an integrated CO.sub.2-UH submethod and/or subsystem (21) shown with outputs (1 to 20) within box 2. The CO.sub.2-UH is defined herein to include within its domain any modality and combination of modalities of CO.sub.2 utilization and associated product outflow based upon CO.sub.2 inflows obtained from Lake Kivu in the course of deepwater methane-based power production, including both deepwater CO.sub.2 and CO.sub.2 formed from combustion of deepwater methane (or, in the case of the MSDS method and/or system, deepwater CO.sub.2 only).

[0514] FIG. 2 shows Lake Kivu on the bottom left in vertical slice perspective in three layers (23 a, b, c). These are: the bottom “Main Resource Zone” (23c: MRZ: ˜250 to ˜485 meters depth), the near-surface “BioZone” (23a: BZ, 0 to ˜80 meters depth) and a middle zone (23b: ˜250 to ˜80 meters depth). The middle zone as shown is a combination of two zones: the “Potential Resource Zone” (PRZ) and the “Intermediate Zone” (IZ), represented in scientific and engineering reports describing the gas resources and limnological structure of the lake (Descy et al., 2012; Wuest et al., 2012a,b). The industrial process begins with the extraction of deepwater in a system of flow organized by one or more riser pipe submethods and subsystems (22). See, e.g., US 2015/0354451 A1. These submethods and/or subsystems transport deepwater rich in dissolved methane and CO.sub.2 into a degassing submethod and/or subsystem (24). This should be considered to include the riser or risers (22) themselves. The degassing submethod and/or subsystem (22, 24) separates the inflow of gas-rich water (22) into outflows of separated degassed water (34) and separated gases (25). Separated degassed water is transferred by a submethod and/or subsystem of return flow pipes, pumps and containing reservoirs (34, 35) that variously control the reinjection of return flow waters into Lake Kivu via various options (36a, 36b, 36c). These reinjection options are not exclusive of one another. Preferred embodiments thereof are described, as noted herein, in other disclosures focused on Lake Kivu made by the inventor. The variant MSDS-based form of the invention is shown in FIG. 1.

[0515] As shown in FIG. 2, separated gas from the TDS (22, 24, 25, as shown in box 1) comprised mostly of CO.sub.2 plus methane plus water vapor is transported and processed, if and as needed, for input into an oxyfuel combustion system (26, 27) into which oxygen is added via an air separation unit (27) which is a component of the powerplant (26, 27). Combustion of methane with pure oxygen transforms the input gases (25, 27, 31) into mechanical power used to generate electric power (29) and an output exhaust stream (28) comprised of mostly CO.sub.2 plus condensable water vapor. FIG. 2 shows a post-combustion exhaust stream (28). It provides oxyfuel powerplant combustion exhaust of carbon dioxide and steam as input into a CO.sub.2 utilization hub (CO.sub.2-UH, item: 21). In the variant MSDS-based form of the invention, the connection between the degassing system and the CO.sub.2-UH is simpler, as represented by item 14 in FIG. 1.

[0516] CO.sub.2 is provided in post-combustion exhaust expelled by the OXFPCS (which may or may not be a combined cycle). It also is provided by degassed CO.sub.2 from a MSDS. These sources of CO.sub.2 initially enter a processing, storage and purveying/distribution unit (30), shown in FIG. 3. This unit (30) processes, handles and stores input exhaust (28) and disperses the flow into different streams. (It is the subject of FIG. 3, which in part displays its components, methods, systems and activities.) These streams are comprised of CO.sub.2 products in different forms symbolized by eight specific arrows corresponding to modalities of use (1, 2, 3, 4, 5, 6, 7, 8). A flux vector labeled as item 37 represents the use of any of these CO.sub.2 product streams internally within the CO.sub.2 utilization hub for additional modes of product manufacture utilizing CO.sub.2 (8 through 20). (Note that arrow number 8 is intermediate. It is both a mode of CO.sub.2 product and a mode of creating products utilizing CO.sub.2.) Overall, in the sum of any to all of its preferred embodiments, the CO.sub.2-UH can produce an overall output of products shown as vector 33. This output is comprised of one or more of a suite of carbon-containing and purified and non-purified CO.sub.2 products, plus products produced using CO.sub.2 in some way but not incorporating its carbon. One non-purified CO.sub.2 product is a stream of “raw” (unprocessed or relatively unprocessed) CO.sub.2 and steam or condensed water (vectors 1, 2, 3 and 4). It may be disseminated and diffused into the biozone (23a: BZ) of Lake Kivu in order to provide a carbon source for photoautotrophic bioproductivity, as shown for vectors 2a and 2b. Or this form of CO.sub.2 may be provided to local greenhouses, as shown by vector 1.

[0517] As shown in FIG. 2 by flux vector 31, oxygen gas output may be obtained as a byproduct of chemical production and/or bio- or artificial-photosynthetic processes and/or water electrolysis in the CO.sub.2-UH (21). Such oxygen may be used for increased power production efficiency by supplying a component of oxygen otherwise provided by the Air Separation Unit (27, utilizing atmospheric air input shown as vector 41).

[0518] As shown in FIG. 2, the ASU (27) also produces liquefied nitrogen gas, (LN.sub.2) separated from oxygen gas (39, 40). Some of this LN.sub.2 is used internally within the ASU for cryogenic energy recovery by means of cooling incoming air via a heat exchange process. In certain preferred embodiments, excess LN.sub.2 from the ASU is provided (42) into the gas processing, storage and handling unit (30) of the CO.sub.2-UH, as shown by vector 39. Or it may be provided otherwise for other purposes, as shown by vector 40.

[0519] FIG. 2, Box 3, illustrates adjunct utilization of excess liquid nitrogen and/or oxygen (via flow vectors 39 and/or 40 and/or 42) to cool one or more large refrigeration utilization facilities (43), such as, for example, a digital data center. Flow vectors 39 and 42 flow into the liquefied gas storage units within the gas-processing (30) sector of the CO.sub.2-UH (21), (see process train 25, units 30 and 31 in FIG. 3). In FIG. 2, box 3, the vectors labeled 39 and 42 indicate either direct flow from the ASU (27) or flow from LN.sub.2 and LO.sub.2 storage facilities as shown in FIG. 3. (In FIG. 3, LO.sub.2 and LN.sub.2 storage units 30 and 31 connect via insulated pipe transfer systems labeled 37 and 38, respectively.) Post-cooling flows of gasified N.sub.2 (44) are available for various uses such as, for example, can be engaged to pH control and related algae culturing operations as illustrated partially in FIG. 8, Box 3, return flow water treatment (flow direction 16). Post-cooling flows of gasified LO.sub.2 (45) are provided into oxyfuel combustion (item 27). Aspects of such gas plumbing associated with utilization of cryo-energy for cooling as well as for cryo-storage of energy are represented in FIG. 6 and explained in accompanying text describing the utilization of LO.sub.2 and/or LN.sub.2 and/or refrigerated liquefied O.sub.2 (LCO.sub.2 or LCO.sub.2) for this purpose. For reasons of already considerable complexity, FIG. 2 avoids representing these aspects of the invention. They are reserved for FIG. 6 and its explanations.

[0520] In certain preferred embodiments, LN.sub.2 is utilized for cryoenergy storage for load balancing purposes, facilitating the operation of the OXFCPS (shown in FIGS. 1 and 2). This stored energy is released by heat exchange with atmospheric air and/or powerplant exhaust, whereby the phase-changed expanding gas drives a power-producing turbine heat engine. See FIG. 6.

[0521] In certain preferred embodiments, storage of liquefied oxygen (LO.sub.2) similarly provides stored cryo-energy. Similarly, this cryo-energy is released by heat exchange with the atmosphere, and/or powerplant exhaust, whereby the phase-changed expanding gas drives a power-producing turbine heat engine wherewith and whereby the warmed-up O.sub.2 emerging is fed into oxy-combustion in the OXFCPS. See FIG. 6.

[0522] In certain preferred embodiments, refrigerated liquid CO.sub.2 is utilized for cryoenergy storage for load balancing purposes, thereby facilitating the operation of the OXFCPS powerplant (shown in FIGS. 1 and 2). Stored cryo-energy present in the CO.sub.2-UH as stored refrigerated liquid CO.sub.2 is releasable by conversion into electricity by heat exchange with atmospheric air and/or by heat exchange with the exhaust of the powerplant. The phase-changing expanding gas drives a power-producing turbine. In this way, refrigeration-liquefaction of CO.sub.2 is used as a CO.sub.2 storage mechanism for energy storage. (Of course refrigerated-liquefied CO.sub.2 also is sold into the market as a product of the CO.sub.2-UH.) The refrigeration-liquefaction process requires input of power from the powerplant, typically at night when power demand from the grid is low. In a day-night cycle, a substantial fraction of this cryogenically stored energy is recovered, typically during the day, when power demand from the grid is high. Phase-changing expanding CO.sub.2 gas is warmed by heat exchange. For best system efficiency, this heat exchange is via cooling the intake of air fed into the ASU and/or by utilizing exhaust heat from the powerplant as a higher temperature heat source. After the phase-changing expansion of CO.sub.2 drives a power-producing turbine engine, the warmed-up gas then is fed into various modes of utilization via the CO.sub.2-UH. Further representation and discussion of this capacity for CO.sub.2 utilization is provided in FIG. 6 and its accompanying discussion.

[0523] In certain preferred embodiments, the CO.sub.2-UH, and/or the ASU cryosystem, and/or both working in concert, receives inputs of solar power transmitted by one or more long-distance transmission wires, transmitted to support various modes of production utilizing CO.sub.2 inputs, or transmitted in the context of a need for load balancing. Cryogenic energy storage using practically liquefiable gases, N.sub.2, and/or O.sub.2, and/or CO.sub.2 allows balancing of the irregularity of flows of solar power into the grid such that a continuous regularized flow of power input may be sustained into CO.sub.2-utilizing modes of production. Additionally, the cryogenic energy manipulation and storage capabilities of the overall method and system of the invention provides capacities suitable to serve load-balancing needs that are generic for solar power provision into the grid. Turn-around power storage efficiencies by such methods are expected to be >60% (power out/power in), and possibly as high as 95%, as described in references cited herein (cf, Park et al., 2017). Certain preferred embodiments include this capability to receive solar power and provide energy storage for load balancing to regularize the input of solar power to the grid.

[0524] In certain preferred embodiments, the CO.sub.2-UH, and/or the ASU cryosystem, and/or both working in concert, provide(s) cryogenic energy storage load-balancing services for the management of one or more electrical power grids connecting into the invention as implemented (in the same manner as described for the input of solar power in the section immediately above).

[0525] FIG. 2, box 1 is a schematic representation showing the delimitation of the invention in relation to Lake Kivu and in respect to various elements diagrammed within the figure and the names of the submethods and subsystems indicated by their acronyms. (An equivalent diagram is not shown for the simpler case of the MSDS-based variation of the invention. FIG. 1, box 13 and CO.sub.2 flow line 14 are sufficient for this purpose in combination with detail provided in FIG. 8.) The invention has specific applicability to problems and challenges of Lake Kivu (represented by the circle labeled number 38 which also represents the combinative domain of the invention), specifically to safe, efficient, optimally productive deepwater resources utilization. The invention solves problems and challenges of Lake Kivu such as efficient power production, securing long-term lake safety, environmental responsibility, and economic innovativeness and productivity by utilizing CO.sub.2. It does so by combining submethods and/or subsystems within three subdomains operating in inter-coordination. These are shown as circles within the larger circle marked “Lake Kivu” (38) in Box 1: (i) deepwater extraction (22), degassing (22, 24), and gas transfer and processing for dehydration and/or H.sub.2S removal (25), if and as needed, preparatory to oxyfuel combustion; (ii) oxyfuel combustion (26, 27) with inputs of separated deepwater gases (25) and oxygen (27, 31), and outputs of electric power (29) and exhaust comprising nearly pure CO.sub.2 with condensable H.sub.2O (28); and (iii) a CO.sub.2-UH submethod and/or subsystem (21) which produces, in the limited set of examples provided for purposes of description, a suite of twenty main modes of carbon-containing product production (1 through 20, and in sum: 33) including CO.sub.2 for biozone input (vectors 2a, 2b and 3), utilizing the input of exhaust (28) expelled from the oxyfuel power plant (26, 27). Note that 20 modes are provided only for reasons of limiting the discussion to a reasonable package of examples, whereas the invention is generically open to any modes of CO.sub.2 utilization such as might support realistic business activities or at least developmental research and development in order to create business activities via developmental investment.

[0526] FIG. 2, box 2 shows aspects of the operation of the CO.sub.2 utilization hub (21: CO.sub.2-UH). The CO.sub.2-UH (21) transforms the exhaust (28) from the OXFCPS (26, 27) plus additional inputs (32), into horticultural, aquacultural, and industrial output main modes (1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 33). Table 2 lists them and provides additional information.

[0527] FIG. 3 provides detail on five types of gas processing trains present within the CO.sub.2-UH (as shown in FIG. 2 as item 30 without any detail). Note that the process shown in process train 22 is different from processing trains that produce CO.sub.2 products. Train 22, however, demonstrates production utilizing relatively “raw” CO.sub.2 with respect to the exhaust output of the OXFCPS. These trains and their various combinations are all preferred embodiments. In FIG. 3, the five processing trains are labeled 22, 23, 24, 25 and 26. Horizontal dashed lines separate these five processing trains. FIG. 3 exhibits four cases of the production of CO.sub.2 products (rows marked by circles numbered 23, 24, 25, 26), and one case of manufacturing a product incorporating CO.sub.2 (22). The five different submethods and subsystems of receiving, processing, storing and purveying CO.sub.2 (rows 23, 24, 25, 26), and CO.sub.2-incorporating products (row 22) are referred to herein as “process trains.” A dashed box (dashed box 36) encloses a representation of subsystems and submethods present in certain preferred embodiments. These connect and integrate cryogenic capacities of the OXFCPS involving liquefied nitrogen (31) and oxygen (30), with cryogenic capacities of process trains 25 and 26.

[0528] FIG. 3 shows the initial reception of raw exhaust (1) from the OXFCPS or MSDS (as shown in FIGS. 1 and 2). Initial processing of OXFCPS raw exhaust gas, in certain preferred embodiments, includes capture of heat energy by a heat exchanger connected to a power production unit. Such a submethod and/or subsystem, a Heat Exchanger Power Production Unit (2: HEPPU) is represented by (and/or identical to) a fence-like symbol within box 2. A drain, shown as an icon labeled 3 (present in four locations within the figure), drains condensed water from the HEPPU (2). In some embodiments, this heat exchanger power unit is a part of the OXFCPS. In other embodiments, the HEPPU (2) is included within the CO.sub.2-UH. FIG. 3 shows it as the latter. The distinction is simply a definitional choice. FIG. 3 shows five different modalities of CO.sub.2 handling, processing and disposition for use (22, 23, 24, 25, 26). In one case (22), CO.sub.2 is directly utilized. This utilization is in a sense referring to the transformation of CO.sub.2 into a product that is not itself CO.sub.2, or otherwise more broadly refers to any industrial process that utilizes CO.sub.2 but that is not overlapping with CO.sub.2 processing into other forms of CO.sub.2. In the others cases (23, 24, 25, 26), CO.sub.2 in various forms is modified and made available for delivery as a CO.sub.2 product. Thus four of the five modalities are for CO.sub.2 products as shown for process trains 23, 24, 25, and 26.

[0529] In FIG. 3, the process train modality, labeled 23, is production of relatively unprocessed gas into short-term process storage (9). This storage (9) is shown as a pressurizable chamber allowing condensation and removal of water (icon: 3) prior to pumping (10) of stored CO.sub.2 for use. The next flow stage in this process train is low-pressure pipeline delivery (11a, b). The double representation (11a and 11b) indicates a multiplicity of uses, but does not indicate either a necessity of multiple uses or an absence of multiplicity for outputs of the other process trains shown. CO.sub.2 in this relatively low-pressure form delivered by pipelines is for local and/or semi-local horticultural and/or aquacultural and/or return-flow-modifying uses, as shown in FIG. 2.

[0530] In FIG. 3, the process train modality labeled 24 is production of dehydrated pressurized gas. Dehydration steps (icon 3: shown in four locations) may in some embodiments precede compression (10), as shown. (High pressure is indicated by two compressor symbols.) CO.sub.2 processed in this modality typically is stored in one or more tanks, or in a farm or farms of such tanks (12) prior to export by one or more high-pressure pipelines (13) or by pressurized tank truck (14). Distribution of high pressure CO.sub.2 internally within the CO.sub.2-UH is shown by item 15 showing two uses: 15a and 15b. Flow vector 15a represent transfer from pressure storage of CO.sub.2 into refrigeration processing into refrigerated liquefied CO.sub.2, whereas the extension (15b) represents a transfer directly into refrigeration for dry ice production, if desired. Flow vector 27 indicates that compressed CO.sub.2 may be supplied into outputs of process train 23.

[0531] In FIG. 3, the process train labeled 25 is refrigerated liquefied CO.sub.2 production, storage and disposition (18, 22, 39). Storage is in one or more thermally insulated liquid CO.sub.2 tanks (17), or in a farm or farms of such tanks (17), prior to export by refrigerated tank trucks (18), or transfer by insulated pipeline (22) into dry ice production (process train 26), storage (20) and delivery (21).

[0532] In FIG. 3, flow vector 39 represents transfer of stored refrigerated liquid CO.sub.2 by insulated pipeline for recovery of cryo-energy. One of the functions of the CO.sub.2-UH facility is storage of refrigerated liquid CO.sub.2 (17: “LCO.sub.2”) by means of refrigeration energy input. This energy can be recovered such that storage of LCO.sub.2 acts as a battery. For recovery of energy stored in this way, the cold liquid is transferred through an insulated pipeline (39) to a heat exchanger and turbine energy extraction system (represented by item 40). Heat exchange with the atmosphere (preferably via the air intake of the ASU), or with powerplant exhaust, causes a phase-changing expansion of CO.sub.2. This flow of expanding gas drives a turbine generating electrical power for export into the grid, typically for load balancing purposes. (An overview of this cryo-system for energy storage is provided in FIG. 6.) In some embodiments, this capacity for cryogenic energy storage in the CO.sub.2-UH facility includes additional storage of liquefied N.sub.2 (31, “LN2”) or liquefied O.sub.2 (30, “LO2”), or both, as shown. These additional capacities for LN.sub.2, LO.sub.2 and LCO.sub.2 handling for cryo-energy storage are described in subsequent sections. They have the capacity to provide load-balancing services for three uses. These uses are: (i) for energy storage internally to allow variable power output into the grid for the powerplant (OXFCPS); (ii) to provide energy storage capacity for the grid, if desired; and (iii) to provide energy storage capacity to handle irregular renewable power inputs for CO.sub.2-UH production modes (such as “solar fuels” and/or “wind fuels” and/or “hydro fuels” production using CO.sub.2 as a carbon source), if desired.

[0533] The process train modality labeled 26 in FIG. 3 is dry ice production by refrigeration (19) of CO.sub.2 supplied by other process trains (15b, 22). Dry ice is stored in an insulated storage warehouse (20) prior to delivery by truck (21), typically with thermal insulation storage and/or packaging. In some embodiments, dry ice is used for cryogenic energy storage. (Note that specific system linkages are not illustrated for this use).

[0534] In FIG. 3, the process train labeled 22 shows CO.sub.2 utilized for transformation of CO.sub.2 into CO.sub.2-containing products and/or more broadly for production utilizing CO.sub.2 in conditions that may require time-varying steps of CO.sub.2 input in different conditions of temperature, pressure and steam and/or water vapor content according to production recipes. This may occur within the CO.sub.2-UH defined within a local or semi-local geographical domain. Process train 22 provides an example of a type of CO.sub.2 utilization via a pressure chamber for carbonation. Gas proceeds by a choice (28, typically determined and directed by means of a valve) for processing with or without, a dehydration step (3). The gas flow proceeds though a valve disposition subsystem (4). This valve disposes flow to proceed without or with degrees of compression (10) into a processing chamber unit (5). The unit shown (5) is meant to be representative of many different modalities of CO.sub.2 utilization involving many different types of industrial CO.sub.2 use. Simply for example, in FIG. 3 it (5) is shown by icons representing a carbonation-reaction chamber appropriate for the carbonation of cementitious building materials. After a suitable period of carbonation, materials created in a processing unit (5) are stored and/or possibly cured under gas composition, temperature and humidity controls in a warehouse (6), before being purveyed by means of any appropriate mode of transportation, as represented in the figure symbolically by truck (7) and ship (8) icons. Again, many other modalities of industrial processing for utilizing CO.sub.2 could be represented for this modality of CO.sub.2 utilization involving a process recipe of scheduled inputs with variability of composition and state. The carbonation pressure chamber mode, as shown (5), is one example only. It includes the main processing steps of gas preparation by purification and/or compression followed by one or more processes of product manufacture utilizing CO.sub.2, a large number of which are referenced herein.

[0535] In FIG. 3, box 36 represents an integrative linkage of cryogenic capacities between the OXFCPS (not shown) and the two cryogenic process trains labeled 25 and 26. This linkage exists in certain preferred embodiments. A double-sided arrow (35) represents a capacity for flow in both directions between the ASU-OXFCPS complex (as shown in FIG. 2) and process train 25 for liquefied nitrogen and/or oxygen and/or carbon dioxide. This linkage adds handling, storage and disposition of liquid oxygen (30, 32) and liquid nitrogen (31, 33) to process train 25, which otherwise is a process train with cryogenic capacities specialized only in the freezing, handling, storage and dispersal of liquefied CO.sub.2 (17, 18). As shown by icons within box 29, the linkage also included the capacity to generate electric power by releasing cryo-energy by venting LN.sub.2 to the atmosphere or to various uses via a heat engine (33) and similarly via a heat engine by gasifying LO.sub.2 into the OXFCPS (32 via 35). An icon representing refrigeration within box 29 represents the capacity of the linkage (represented by box 36) to provide refrigeration into process trains 25 and 26, drawing from the cryogenic capabilities of the ASU (if the ASU is of the cryogenic modality). In certain preferred embodiments, the linkage (36, 29, 32) also gasifies stored liquefied oxygen (30) via a heat engine power generator (represented by icons within 29) connecting to the O.sub.2 intake supply for oxyfuel combustion (via 35). The linkage labeled as number 34 offers the possibility to contribute cryogenic cooling into the cryogenic capacity of the process train dedicated to produce dry ice (26). Overall, in certain preferred embodiments, this integration (symbolized by box 29 and box 36) connects (35) the CO.sub.2-UH to the Air Separation Unit (ASU) within the OXFCPS. The linkage makes cryogenic cooling available to be used in the cryogenic process trains 25 and 26, specifically to the cooling units labeled 16 and 19. Further detail is provided in FIG. 6.

[0536] The linkage represented within box 36 plus items 39 and 40 establish a cryo-energy storage capability for the invention overall, connecting with the ASU-OXFCPS complex. A capacity to store cryogenic energy is a method of storage for electric power. Cryogenic energy storage allows the capacity to vary the level of electricity export into the receiving grid while from the oxyfuel powerplant operates at a constant optimal rate of internal power production. It can also provide additional energy storage grid services as noted above. For natural gas oxyfuel turbines, a connected oxygen-supplying (14) ASU typically draws ˜10% of the powerplant's internal power production when operated continuously at a constant level of production of oxygen. The use of cryogenic energy storage is valuable to powerplant operations. It allows diurnal modulation of power export output to be by up to a scale of a roughly 20% spread between high and low output to the grid with constant continuous internal power production by the central turbine(s) system burning degassed Lake Kivu methane. That is to say, a 20% spread would be the difference in power export to the grid for a daily cycle with 12 hours of ASU oxygen production on, followed by 12 hours with ASU oxygen production off. The operation of such a modality of energy storage is dependent upon the operational capacity of the ASU. Operating by cryogenic energy storage in this 12-hours-on, 12-hours-off mode requires capacity to operate the ASU at a level of production ˜2× the rating for round-the-clock continuous oxygen production. As noted above, additional cryo-energy storage may be obtained by operating separate power-generating heat engine turbines utilizing cryo-energy stored in insulated reservoirs of liquefied nitrogen and oxygen (as shown in FIG. 3, items 30 and 31). LCO.sub.2 also may be used in cryogenic energy storage (17, 39, 40). The method and system of these cryo-energy-tapping heat engine turbines and their heat exchangers are represented by two icons placed in the upper sector of Box 29 shown in FIG. 3. (The system of item 40 recovering cryo-energy stored in LCO.sub.2 is not shown extensively in FIG. 3. It is shown in FIG. 6.) This box represents a part of the interconnections between the ASU (as shown in FIG. 2: item 27) and the component of the CO.sub.2-UH identified by item 30 in FIG. 2. (In FIG. 2, these connections are labeled 33 for LN.sub.2, 32 for LO.sub.2 and 41 and 40 for LCO.sub.2). Generalized sales/delivery of LO.sub.2 and LN.sub.2 is shown by pipeline icons (37 and 38). Flow vector 34 shows interconnection of cryogenic systems storing LCO.sub.2 with dry ice storage and manufacture (the process train labeled 26).

[0537] FIG. 4 represents the invention disclosed herein as a method and system for industrializing economic development. According to the invention, Lake Kivu deepwater processing creates a multiplicity of outputs that can be described by economic metrics. Such economic metrics are causally linked to the product flows shown in FIGS. 1, 2 and 3 as measures of economic output. Shown on the left side of the diagram are extracted (1) Lake Kivu deepwater (12) resource flows (labeled: 3, 4, 5, 6, and altogether: 2). These, variously in the middle of the diagram (9, 10, 11), are shown inputting CO.sub.2 (that would otherwise be waste) into a productive, jobs-creating, CO.sub.2 utilization Hub (7, illustrated with exemplary, non-limiting icons), while simultaneously efficiently combusting methane (6) to produce power (9) in an optimal manner with efficient carbon capture (10). Lake Kivu deepwater (12) contains (Box 2) several types of useful resources (sub-boxes: 3, 4, 5, 6). Lake Kivu's deepwater is extracted (1) with its dissolved resources flowing into separation operations (Box 2, which encloses Boxes 3, 4, 5 and 6). Each sub-box represents different types of utilizable substances, as noted. All can be directed into useful industrial production. The invention disclosed herein pertains primarily to the utilization of methane (Box 6) and CO.sub.2 (Box 3), both degassed from Lake Kivu deepwater via transformation into a stream of CO.sub.2 and steam exhaust entering a CO.sub.2-UH (item 7), whereby the submethods and subsystems of oxyfuel combustion, or MSDS in the variant form of the invention (both as described herein but not shown in FIG. 4) provides means for transformation. The flux of CO.sub.2 from degassing (11) joins together with a flow of CO.sub.2 produced (10) by methane combustion (9) in the TDS modality. This provides (as represented by transfer vector 10) a material basis for CO.sub.2 utilization in a CO.sub.2 utilization hub (CO.sub.2-UH, item 7). As indicated by representative icons, the CO.sub.2-UH (7) creates jobs, industrial production, and consequent economic growth (item 8). Note that dissolved magnesium (Mg) may be co-utilized with CO.sub.2 in the production of materials containing Mg-carbonates. Also, ammonium ion (NH.sub.4+) may be co-utilized with CO.sub.2 both in the production of urea as well as in the nutrient fertilization of algal biocultures which may co-fertilized with CO.sub.2. These resources are identified together in Box 5 labeled “other substances.” Utilizations of dissolved magnesium and/or NH.sub.4+ are, however, optional features of the invention disclosed herein. The utilization of dissolved magnesium is described in an independent disclosure by the inventor in U.S. Patent Application Publication No. 20160257577 A1.

[0538] FIG. 5 illustrates and summarizes several benefits of the invention disclosed herein, shown in Box 2, in comparison with existing (circa 2016) technology shown in box 1. The figure highlights aspects whereby the invention offers substantial contributions to power production efficiency, lake safety, environmental stewardship and economic development. The invention is indicated in Box 2 only its TDS-based modality. TDS refers to the method of a Total Degassing System. The MSDS (Modified Staged Degassing System) variant is not shown in FIG. 5. (FIG. 8 provides details.) Black vectors illustrate CO.sub.2 flux through systems. (Except for vector 24 which represents flow of near-surface water.) These, in comparison, highlight the CO.sub.2-utilizing aspect of the invention via a CO.sub.2 Utilization Hub (16). The existing technology practiced on Lake Kivu utilizes the method of staged degassing” (SDS) for gas extraction and cleaning prior to combustion. As illustrated (Box 1), the SDS method proceeds in (minimally) two stages. A first stage of separation is enclosed by a dashed oval (22). Item 22 is a gas-water separator. It is located at a specified depth corresponding to a useful pressure for fractionation to optimize the CH.sub.4/CO.sub.2 ratio and minimize CH.sub.4 retention losses in solution through the degassing process. Typically the preferred depth is ˜20 meters. A substantial fraction (˜>20%) of methane remains in solution and is returned to the deep lake (19) in the return flow of water (31) which also contains ˜80% of the initial concentration of CO.sub.2 (5). A second stage (25) utilizes scrubbing with water to absorb CO.sub.2. The process uses near-surface water that is not saturated in CO.sub.2. The scrubbing process acts by gas-water equilibrium between gas bubbles and/or gas flow of stage-1 interacting/equilibrating with CO.sub.2-undersaturated near-surface water. Gas bubbles and/or flows upwards through a platform-supported (4, icon 12a) scrubbing device (25). This process preferentially resorbs CO.sub.2 (with respect to CH.sub.4) back into solution. Some methane is absorbed into solution in stage-2 and plumbed back into the lake (20). Hence methane is lost in both stages so that the flux of methane piped (7) into conventional piston engines (8) is substantially reduced. This “slip” wastage is shown for both stages: 19 and 20. One aspect of the comparison shows that utilization of CO.sub.2 in a CO.sub.2-UH (16) creates a basis for large-scale industrial development (16, 21), represented by icons. Another aspect is securing lake safety against limnic eruption such as may be triggered by sub lacustrine volcanism or other types of triggering phenomena. Lake Kivu's main density discontinuity is presently located at ˜260 meters depth. It is represented by a dashed horizontal line (17). CO.sub.2 flux is represented with black vectors in both boxes in the figure (3, 5, 6, 9, 10, 14, 15, 25). CH.sub.4 flux is represented with stippled vectors in both boxes in the figure (3, 7, 10, 19, 20, 23). Water flux is shown as flow vector 3-to-31 in box 1. In Box 2, water flux is shown as flow via a deepwater inlet (10) to intake (26) into a gas-water separator (27). Water flow proceeds out of the separator via directed flow (28) into de-densifying water treatment (29). Flow then continues back into the lake (30) where it is released well above the main density discontinuity (17). The de-densifying water treatment method and system (29) have been disclosed by the inventor in U.S. Patent Application Publication No. 20160257577 A1.

[0539] In Box 2 (which represents the invention) of FIG. 5, utilization of CO.sub.2 is facilitated by an initial process of total degassing. This is via a total degassing system, TDS (27), hosted in a floating structure (11), linked with an icon representing a water-borne platform (12b). Return flow in the TDS-based method, as noted above, does not return CO.sub.2 and CH.sub.4 into the lake. By contrast, in the SDC-method (Box 1), most of the CO.sub.2 flowing upwards into the intake (3) is returned into Lake Kivu (5, 6). Most is being returned (5) into to the gas-rich deepwater reservoir existing below the main density discontinuity (17). Such a situation preserves and extends a dangerous condition due to limnic eruption catastrophe hazard. In Box 2 (representing the invention), return flow can be de-densified (in item 29) such that it can be reinjected into the lake above the main density discontinuity (30). This increases lake safety. It does so by drawing down the volume of the gas-rich deep layer. This drawing down “deflation” is illustrated in Box 2 as a time transition. It is shown by small downward arrows illustrating movement of line 17 to a later situation identified by line 18.

[0540] FIG. 5 illustrates a key factor of inefficiency in the standard (SDS-based) method. This is the loss or “slip” of methane shown as vectors 19 and 20. Methane returned via stage-2 into Lake Kivu's bio-zone upper layer (20) is irrevocably lost by biological capture and metabolism, typically by bacteria. Methane “slip” lost into the lake's deeper resource zone (19) remains extractable in principle. However, in practice, this methane is not extractable. This is for two reasons. First, return of this “slip” methane into the deep layer is associated with dilution of the methane concentration in the deepwater reservoir over time. Dilution increases extraction inefficiency. Late in the extraction, inefficiency increases drastically. Effectively this means that the returned methane is lost. Second, some actual operations are not returning the flow (indicated as 31, 5, 19) into the deep lake below the main density discontinuity (17). Water is being mixed with near surface water and reinjected at a higher level in a depth range where it is not extractable by the SDS method. Mixing-in near-surface water also oxygenates the flow such that methane is lost by bacterial uptake. Direct methane losses in the SDS-based method are roughly one third. Indirect methane losses via the effect of dilution of the deep layer add additional degrees of inefficiency.

[0541] Overall, the invention disclosed herein and in the related disclosures of U.S. Patent Application Publications Nos. 20150354451 A1 and 20160257577 A1 creates an efficiency gain of approximately ×2.4 in terms of total power produced by an OXFCPS (13) from the lake in comparison to the SDS-based method. The use of supercritical CO.sub.2 power cycle technology can increase this factor to ˜×3.0.

[0542] FIG. 6 illustrates special cryogenic aspects of the invention. These aspects are diverse and powerfully versatile. They include cryo-energy storage (23, 24, 25, 28) and recovery (3, 18, 29, 30), as well as provision of coolant flows of liquid (11) and/or cold (12) nitrogen to a Digital Data Center (5, DDC). Cryogenic aspects also include capacities for powerplant (1, 33) temporal load-balancing (18), provision of grid balancing services (15, 16), utilization of remote solar and/or wind power (20) inputs (21), and production and utilization of LNG (36, see below) and other forms of NG (40), such as CNG and ANG. Irregular solar and wind power inputs may be stored and used in power-absorbing modes of production within the CO.sub.2-UH (Box 4), for example production of H.sub.2, O.sub.2 and “solar chemicals,” including carbon-recycling, hydrogen-binding “solar fuels” such as methanol and/or DME. FIG. 6 illustrates detail that is not provided in Box 5 shown in FIG. 1. Cryogenic aspects of the invention are illustrated in all modalities based upon the three different available gases: N.sub.2, O.sub.2 and CO.sub.2. These are all present in preferred embodiments of the invention, as is any subset using only one or only two of these gases. A particular utilization of nitrogen gas also is shown. It is for cooling of a Digital Data Center (DDC, 5). Cryogenic equipment for air separation and other gas cooling tasks exists within an Air Separation Unit (2). This unit is shown functioning with expanded capacities as a CRyogenic Processing Unit (2, ASU-CRPU). This expanded capacity may be shared with the CO.sub.2-UH (box 4), as shown (via same number labeling of the cryo-production icons: 27a and 27b, however not represented spatially in connection in the figure). Or separate cryogenic facilities may exist within the CO.sub.2-UH (Box 4) supplied with power (17, 19) from the powerplant (icon in Box 1) and/or from the grid (15, 33), if desired. Open arrows with single ends (such as, for example, 6 through 13) represent matter flows. Solid black arrows represent flows of electric power. (Power may be mechanically transmitted and/or more typically transmitted by wires as electric power. Of course power is supplied into (16) the grid (33).) Two double-ended arrows appear within Box 22 (CESSI). These connect to heat exchanger icons labeled 29 and 30. They represent options of connectivity shared by a CRyo-Energy Recovery Unit (Box 3: CRERU), which is adjunct to both the Air Separation Unit (ASU, Box 2) and the OXyFuel Combustion Power System (Box 1, OXFCPS). These options of connectivity of the CRERU (Box 3) connect cryogenic heat engine power generator systems (shown within Box 22) with the heat sources of the air intake (14) of the Air Separation Unit's CRyo-Production Unit (Box 2: ASU-CRPU), and/or with the CO.sub.2 and water vapor exhaust (32) of the OXyFuel Combustion Power System (Box 1: OXFCPS). Again, these connections are symbolized by heat exchanger icons 29 and 30, respectively, linked to the center of Box 22 (CESSI) by the double-ended arrows. The power generator systems are symbolized by icons shown in the inner part of Box 22 (CESSI) within the CRERU (Box 3). These icons are shown as three pairs. They illustrate power sources connecting to power transmission wires (18a, 18b and 18c). These power sources tapping stored cryo-energy provide recovered stored power (18) into a nexus of electrical power regulation and disposition (dashed Box 41) connecting the powerplant (Box 1) to the grid (33, 15, 16). These systems (18a, 18b, 18c) extract stored cryo-energy, respectively, from flows of stored (25) refrigerated liquid CO.sub.2 (9, LCO.sub.2), stored (23) liquid oxygen (6, 10, LO.sub.2), and stored (24) liquid N.sub.2 (7, 11, LN.sub.2). Liquified Natural Gas (LNG) also optionally is stored (34) within the CO.sub.2-UH (Box 4). LNG provides very high efficiency cryo-energy storage with efficiencies above 90% for round trip energy storage. LNG also of course provides efficient storage of chemical energy that can be transported as well as sold in various forms, LNG, CNG and ANG (40). Inclusion of cryogenic capacities for LNG production additionally provides the basis for a method and/or system for LNG production via cryo-separation of methane from carbon dioxide, (with CO.sub.2 separating in the form of dry ice according to elegant methods patented and demonstrated by Larry Baxter and colleagues). Dashed Box 36 indicates a specialized domain for such LNG-based operations, possessing LNG-specialized cryo-capacities (35) with CO.sub.2 separation capacity. This domain (35) intakes a mixed gas inflow (37), degassed from a Lake Kivu deepwater source (38). It produces outflows of separated solidified and/or liquified CO.sub.2 (39) and LNG (40). LNG cryo-energy production and storage therefore also serves as a mode of CO.sub.2 processing appropriate as a valuable capacity of a CO.sub.2-UH for the production of dry ice and/or LCO.sub.2 as well as for cryo-energy storage. Storage of cryogenic liquids is provided within a cryo-storage domain (28) within the CO.sub.2-UH (Box 4). This domain (within dashed Box 28) functions both for liquefied gases storage generally as well as in the capacity of a power-storage battery as indicated by an icon (26). Cryogenic energy storage systems can possess attractively high round trip efficiency and flexibility, as has been well demonstrated. As shown by the icons, heat engine power generator systems (within Box 22, CESSI) are comprised of heat exchange equipment combined with gas flow turbine generators. The Air Separation Unit (2, ASU-CRPU) produces liquid oxygen (6: LO.sub.2) and liquid nitrogen (7: LN.sub.2) for energy storage as well as O.sub.2 gas for direct intake into combustion in the OXFCPS (1). After passing through heat exchangers linked to power generating turbines, gas flows are distributed as follows. Cold nitrogen gas (12) is distributed as a cooling flow (to 5: a Digital Data Center, DDC, or other facility requiring large cooling flows), and may be otherwise directed (13) for additional uses after serving its function. Warmed-up nitrogen (13) exiting the DDC (5) may be utilized for various purposes. Oxygen gas (31) is fed into oxyfuel combustion (1). Carbon dioxide gas (8) is returned to the CO.sub.2-UH for disposition for utilization (4).

[0543] Such cryo-processing and cryo-energy storage capabilities are expanded and used, if desired, for load balancing of solar power (20) and/or wind power and/or hydropower inputs (21) flowing into the electricity handling nexus (Box 41) of the powerplant (Box 1), or some adjunct electrical facility if/as needed. Cryogenic energy storage capabilities present in some preferred embodiments thereby allow power storage as well as utilization of inputs (21) of solar and/or other sources of renewable power (20) plus CO.sub.2 within the CO.sub.2-UH (4) for production of “solar chemicals,” including “solar fuels.” Efficiency factors are reported within research reports incorporated into this disclosure. The development of such capabilities for solar power utilization in support of CO.sub.2 utilization is very highly desirable. This is from the perspective of the global need for economically useful innovations in the development of solar and/or other renewable sources of power, for example, demonstrating economically viable large-scale cases of “artificial photosynthesis” based upon solar power inputs. The invention offers this possibility utilizing carbon dioxide both as a cryo-energy storage liquid and as a carbon source.

[0544] FIG. 7 introduces a perspective of the invention as a collaboration and talent attractor. This perspective is based upon the international strategic significance of large scale CO.sub.2 utilization combined with national economic development in a region that has suffered massive catastrophes and that also is extraordinarily beautiful as well as subject to a pleasantly attractive climate year round. FIG. 7 shows a preferred embodiment of the invention in its aspect being an open hub attracting the development of a global network. The focus of the invention is the internationally strategic goal to create commercially viable new examples of very large scale CO.sub.2 utilization. The NRG Cosia carbon X-Prize competition (http://carbon.xprize.org) exemplifies this situation. The invention creates an opportunity to attract talent, capital, interest, publicity, and innovative new ideas and technologies. The CO.sub.2-UH (Box 1), representing the invention overall, provides a global focus hub for the growth of an international network represented by the large peripheral circle (2) and its connected box (“Box”) containing a group of icons representing several different modalities of collaboration. This network structures collaborations with companies, research institutions, financing institutions, non-profit funders and philanthropic agendas. Each collaboration is represented by a spoke (double-ended arrow) connecting to a numbered ball situated on the network circle. There is no closed number of collaborations. (Each collaboration is represented by a ball and spoke combination: 3, 4 5, 6, 7, 8, 9, 10, 11, 12.) This openness is shown by the “ . . . ” following the number identifying the twelfth ball-and-spoke. Components of the hub work in concert on the challenge of creating business-scalable innovations in carbon utilization recycling. The icons inside the dashed box represent the multiple aspects of the network: research, training, e-platformed networking and knowledge dissemination, for-profit business and non-profit charitable involvements, new ventures formation, technology pilot projects, networked brainstorming, etc. The hub-structured open aspect of the CO.sub.2-UH (1) creates an intrinsic attractiveness with an open modularity for adding and developing specific modalities of CO.sub.2 utilization within a common framework.

[0545] FIG. 8 shows a system, method and apparatus concept that modifies the standard “staged” gas extraction technology presently utilized on Lake Kivu (Box 1: SDS), as shown by items 13 and 14 in FIG. 1. The modification is into a system, method and apparatus concept (Box 2) possessing the capability to degas CO.sub.2 in a flow sequence following after stages 1 and 2. This method and system of modification makes it possible to create a CO.sub.2-UH connected to an existing conventional staged gas extracting and powerplant operation/apparatus. This type of modification, and/or method, and/or system is an embodiment of the invention. This method and system of modification also makes it possible to design and develop a staged extraction powerplant system that degasses CO.sub.2 and therefore that can be constructed with addition of a CO.sub.2-UH. The present disclosure is a method and system that links a CO.sub.2-UH to a Lake Kivu deepwater degassing system. The latter may be either of both known types: (i) a modification (MSDS) of the conventional “staged” degassing technology; or (ii) a “total degassing technology” (TDS). Both types of degassing system (MSDS & TDS) are variant sub-components of the invention. Both can connect to a CO.sub.2-UH, as shown in FIG. 1. Both can connect to return flow systems as shown in Box 3 of FIG. 8.

[0546] FIG. 8, Box 1 illustrates the conventional staged method (SDS) as follows. Deepwater enters a riser system (1) via auto-siphoning flow, and/or with pumping assistance. Flowing upwards, it enters a degassing system (1, 2). Degassed gas is collected at a depth (10) below the surface of Lake Kivu indicated as “D.” This depth typically is selected to optimize both CH.sub.4 yield and the CH.sub.4/CO.sub.2 ratio in a situation of a divergence of two factors: (i) maximizing the degree of methane extraction by degassing (which increases with decreasing D); and (ii) minimizing the degree of CO.sub.2 extraction by degassing (which also increases with decreasing D). Gas obtained by stage-1 degassing is separated from the deepwater flow (2, 9a) and directed to flow upward (3) in a contained gas transfer riser system. In some designs, this gas enters into a 2.sup.nd stage gas-cleaning process positioned near to the lake's surface. (Some designs clean gas in a 2.sup.nd stage below the surface. Others clean gas above the surface in bubble or trickle towers.) As shown, the gas-cleaning process utilizes near surface water (5, 6, 7). This water is pumped (5) upwards (6) and released downwards to flow downwards inside a bubble or trickle tower (4), then out of it (7) and back into the lake. This method and system absorbs and removes CO.sub.2 preferentially from the gas flow (3). Cleaned gas is collected and extracted at the top of the chamber by exit flow (8, which may be pumped in some embodiments) at the completion of the gas-cleaning process. It is then provided by pipeline into combustion (not shown). The 2.sup.nd-stage “water washing” method is designed to minimize methane “slip” loss and maximize the CH.sub.4/CO.sub.2 ratio of the gas exiting the overall multi-stage system (8). However, methane slip from both stages may be as high or higher than 30%, whereas power output utilization for the water pumping process (5) may be as high higher than 12% of total power output. For this and other reasons, the standard staged method and system shown in FIG. 8, Box 1 is only ½ to ⅓rd as efficient in power production efficiency relative to the “total degassing oxyfuel combustion” method and system disclosed in US 2015/0354451. Despite these limitations, it may be modified as shown in Box 2 to degas CO.sub.2 for utilization and in order to degas the deep lake to increase lake safety. Bow tie symbols represent flow valves. If flow is directed away from conventional return flow (9b) and into a diversion line (11), then the redirected flow auto siphons into a degassing chamber (12). This process degasses a substantial fraction of degassable CO.sub.2 into the gas phase as an extraction flow (14). (The remainder remains in solution.) Thus, a conventional Staged Degassing System (SDS, Box 1) is modifiable, as shown, into a modified system that degasses a substantial faction of CO.sub.2 (MSDS, Box 2, with or without the additional modifications shown in Box 3). The CO.sub.2 degasser separates a flow of CO.sub.2 gas (14) out of solution in the return flow (11). The resulting doubly degassed return flow may be injected into the deep lake in the conventional manner (13). Otherwise it may be diverted into additional modifications as shown in Box 3.

[0547] Box 3 within Box 2 shows how a MSDS can connect by additional modification into submethods and subsystems for organizing deepwater return flow as have been disclosed by the inventor in U.S. Patent Application Publication No. 20160257577 A1. The method and system and apparatus design concept illustrated within Box 2 is applicable to both types of deepwater degassing method and system: staged degassing as shown in FIG. 8, and the total degassing,” as disclosed by the inventor in U.S. Patent Application Publication No. 20150354451 A1. As specified in FIG. 1 and in FIG. 2, Box 1, the invention does not include a return flow system in its most basic form of definition. However, certain preferred embodiments connect “main modes” of CO.sub.2 utilization in the CO.sub.2-UH connect into types of return flow system. Therefore these modalities and the return flow systems they connect into are described in the following sections.

[0548] Three non-exclusive options are shown within Boxes 2 and 3 of FIG. 8 for the fully degassed return flow of deepwater. These are: (i) conventional deep reinjection (13), identical to that shown as 9a and 9b; (ii) admixing into the biozone of Lake Kivu (15) as a means of fertilization to boost ecosystem output; and (iii) return flow with inclusion of de-densifying water treatment by algal growth (18) and mineral precipitation (19), thereby allowing reinjection of the de-densified return flow into the Intermediate Zone (IZ) of Lake Kivu, (as disclosed by the inventor in U.S. Patent Application Publication No. 20160257577 A1).

[0549] FIG. 8, Box 3 shows various different modalities for CO.sub.2 utilization in the context of the return flow options shown. Two of these involve CO.sub.2 injection diffusers into the return flow. These diffusers are indicated as 28 and 26. Item 28 represents a diffuser for CO.sub.2 input (27 into 28) into a component of return flow directed into Lake Kivu's biozone (0 to ˜80 meters depth) for biozone fertilization (as shown in item 15, a diffuser). This flux of CO.sub.2 corresponds to CO.sub.2 injection vector 2b in FIG. 2. (Vector 2a in FIG. 2 represents a CO.sub.2 diffusion system separate from that for nutrient-rich return flow water.) CO.sub.2 diffusion into Lake Kivu's biozone via flux (27) released into diffuser(s) (28) corresponds to mode 2 in Table 1. Item 26 represents a pH-balancing diffuser. It diffuses CO.sub.2 input (25) into the flows of de-densified return flow reinjected into Lake Kivu. This is for (optional) “recarbonation” to conversion of carbonate anions to bicarbonate anions associated with sodium and potassium. This flux of CO.sub.2 (25 via 26) corresponds to CO.sub.2 injection vector 3 in FIG. 2. It also corresponds to mode 3 in Table 1.

[0550] FIG. 8, Box 3 includes a 3rd additional modality for CO.sub.2 utilization by diffusion into return flow. This is in a surface flow (16) method and system for return flow water treatment (18, 19) prior to reinjection into Lake Kivu (26, 20). This method and system of de-densifying water treatment is disclosed by the inventor in U.S. Patent Application Publication No. 20160257577 A1. CO.sub.2 utilizing inputs are shown in FIG. 8 for pH control (21a, 22). Related CO.sub.2 inputs also provide carbon feeding for algal biomass growth in a biological water treatment system method (21a into 17a, and 22 into 18). Items 17a and 17b represent different possible modalities. These correspond, respectively, to CO.sub.2 flux into (17a) and CO.sub.2 flux out of (17b) the flow, as shown by the double arrow (21a,b). These different modalities are: (i) first, CO.sub.2 injection into the flow (21a, 17a) representing a pH-controlling submethod and subsystem for avoiding mineral precipitation; and (ii) second, CO.sub.2 removal out of the flow (17b, 21b). The latter modality is not described herein. It only is illustrated as an option included in some embodiments.

[0551] In FIG. 8, item 18 in Box 3 represents a photosynthetic method and/or system for growing algae within the return flow over an extended period of time. Arrows 21b, 23 and 24 represent CO.sub.2 removal as a means of pH-raising associated with processes for precipitation of Mg and Ca. Arrows 21a and 22 represent CO.sub.2 input into a photosynthetic method and system for growing algae in the return flow over an extended period of time. CO.sub.2 input provides carbon for photosynthesis. Its photosynthetic utilization raises pH. Arrows (21 a and 22) represent a method and system of pH control by provision of CO.sub.2 for algal carbon source supply and in order to suppress high-pH conditions such as would precipitate magnesium and calcium. Flux of CO.sub.2 into the bioculture method and system (21a and 22 into 17b and 18) corresponds to CO.sub.2 injection vector 4 in FIG. 2. It also corresponds to mode 4 in Table 1.

[0552] FIG. 9 is quasi-identical to FIG. 1. The labeling in FIG. 9 is identical to that in FIG. 1 excepting that additional detail has been provided within dashed Box 4. Therefore the labeling is not repeated in this section, except for items within box 4. For other items, refer to the items list and to sections discussing FIG. 1. The focus of FIG. 9 Box 4 is upon illuminating distinct modes in the utilization of CO.sub.2 “going back” to be used within Lake Kivu (9 a,b,c) for several different purposes. Some modes of CO.sub.2 utilization into Lake Kivu (15c, 15d, place CO.sub.2 into the biozone (9a) for use in C-fertilizing aquatic photosynthesis. Mode 15d does this by injection of CO.sub.2 into return flow diffused into the biozone (7a) as a C-fertilizing flux (as shown in FIG. 8, item 15). Mode 15c does this by direct diffusion into the biozone without connection with admixture of return flow water. Mode 15e places CO.sub.2 into the Intermediate Zone (9b) in a context of pH-balancing of de-densified return flow (18) that has become high in pH via bioproduction (16) followed by harvesting and mineral precipitation processes (17). Injecting CO.sub.2 into this return flow (18) after completion of de-densifying processes (16, 17) transforms its alkaline chemistry rich in (Na- and K-complexed) carbonate anions at high-pH into bicarbonate anions at a lesser pH. The flux of CO.sub.2 labeled 15a injected into return flow (7) flowing out of the Total Degassing System (Box 1) is for purposes of acidification, if and as needed, to avoid and/or control precipitation of Mg and Ca in this flow. The flux of CO.sub.2 labeled 15b is provided as a carbon source into photosynthesis in (typically floating) algal growth operations (16) positioned on the surface of Lake Kivu but not communicating with it. The open arrow labeled 19 represents extractive flows from algal harvesting and from the capture of Ma and Ca precipitates.

[0553] Twenty “main mode” selected examples of CO.sub.2 utilization are described in following. These correspond to CO.sub.2 flux vectors labeled 1 through 20 shown in FIG. 2. These represent product flows (FIG. 2, Box 8) exiting the CO.sub.2-UH (FIG. 2, Box 21). Use of CO.sub.2 for cryo-energy storage is not included in this list of “main modes” because it mainly is not a mode whereby CO.sub.2 flows out of the CO.sub.2-UH (21) as a product stream. The first seven of the twenty “main modes” all are CO.sub.2 flows. The eighth mode is a transitional type. It represents a modality of CO.sub.2 flow connecting into a building materials production flow based upon absorption of CO.sub.2 flow and hydration into cementitious carbonating mineralization. The eighth mode (FIG. 2, arrow or vector 8) represents a time-varying and properties-varying flow of CO.sub.2 input corresponding to a production recipe. CO.sub.2 products of the CO.sub.2-UH are represented in FIG. 2 by arrows or vectors 1 through 7, and transitionally by arrow or vector 8. All provide flows of CO.sub.2, with or without associated steam, with or without a high degree of compression, and with or without cryo-preparation to states of liquid CO.sub.2 and dry ice. Such product flows of CO.sub.2 can be categorized into five types. (NB: “Types” of CO.sub.2 flows are different from “main modes” of CO.sub.2 utilization.) Each type corresponds to a different process train shown in FIG. 3 (22, 23, 24, 25, 26). They are as follows. The first type of flow corresponds to process train 23 in FIG. 3. It is relatively “raw” CO.sub.2 exhaust gas. The flow is not dehydrated or compressed to high pressure for long-distance pipeline transport. It is compressed only, if and as needed, to pressures sufficient for local pipeline transport. In FIG. 2, vectors 1, 2a, 2b, 3, 4 and 5, (the last having to do with local algal biomass feeding), are CO.sub.2 flows of this type. The second type of CO.sub.2 flow is CO.sub.2 exhaust gas that has been dehydrated and compressed to pressures that are sufficient for long-distance pipeline transport. This flow is directed into pipeline transport as needed. It corresponds to process train 24 in FIG. 3. In FIG. 2, arrow or vector 6, and sometimes arrow or vector 5 (having to do with algal biomass carbon source feeding, when the CO.sub.2 transport distance is large), are CO.sub.2 flows of this second type. The third type of CO.sub.2 flow is refrigerated CO.sub.2 in the form of liquefied CO.sub.2. This type corresponds to process train 25 in FIG. 3. In FIG. 2, vector 7 includes liquefied CO.sub.2. The fourth type of CO.sub.2 flow is of frozen CO.sub.2 “dry ice.” This type of flow corresponds to process train 26 in FIG. 3. In FIG. 2, arrow or vector 7 includes solidified CO.sub.2. The fifth type of CO.sub.2 flow is a flow with properties that vary in time according to a product production recipe. It corresponds to process train labeled 22 in FIG. 3. Process train 22 is drawn to display the specific case of cement-based eco-concretes and building materials involving cementitious carbonation and hydration. This is as an example appropriate to display in time-varying production flow with changing properties. In FIG. 2, arrow or vector 8 corresponds to this specific option. In the case of eco-concrete and related building materials, it represents a transitional situation from a CO.sub.2 product (delivery of a CO.sub.2 and steam flow according to a time-varying recipe) to a product created by utilizing CO.sub.2. However, this type of CO.sub.2 flow is not limited only to production of eco-concretes and related building materials. Other products may require time-varying recipes for the input of CO.sub.2 with or without associated steam, and at various pressures and temperatures, for example involving pressure-temperature-gas-composition variation schedules. The remaining arrows or vectors, 9 through 20, represent additional “main modes” of CO.sub.2 utilization. In these, CO.sub.2 is used as an input ingredient or otherwise as a processing substance utilized for production of products within the domain of the CO.sub.2-UH (FIG. 2, 21), shown in FIG. 2.

[0554] The first “main mode” of CO.sub.2 utilization (FIG. 2, arrow 1) is CO.sub.2 fertilization in greenhouse horticulture for plant growth acceleration and yield boosting. This mode of CO.sub.2 utilization is a preferred embodiment. In FIG. 2, arrow 1 is shown for this use locally. Unprocessed gas may be used for this purpose. Modest compression only is needed for distribution via a local network of pipes. If an areal extent of 5,000 hectares (a square area, 5 km×10 km) is chosen, then the approximate CO.sub.2 utilization will be ˜2 MTA CO.sub.2 (based on calculations given herein). The amount of CO.sub.2 utilization scales roughly as the area of greenhouse horticulture using CO.sub.2. The provision of large amounts of CO.sub.2 for use in distant greenhouse horticulture on a large scale requires dehydration and pressurization of CO.sub.2 for long-distance pipeline transportation.

[0555] The second “main mode” of CO.sub.2 utilization is Lake Kivu biozone fertilization. This mode of CO.sub.2 utilization is a preferred embodiment. It is represented as flow arrow 2 in FIG. 2. This vector split into two sub-vectors, 2a and 2b. This mode of CO.sub.2 utilization requires only unprocessed gas (as shown in the process train labeled 23 in FIG. 3). It is approximately pure CO.sub.2, except with no need for it to be dehydrated or highly pressurized. The CO.sub.2 is injected into Lake Kivu in two ways. First, it can be disseminated by a system of diffusers directly into the biozone of the Lake. This is shown in FIG. 2 as vector 2a. Second, it can be disseminated into a return flow of degassed deepwater diffused into the biozone of Lake Kivu as a nutrient source. This is shown in FIG. 2 as vector 2b, (with CO.sub.2 dissolving into the return flow water disseminated into the biozone shown as vector 2b connecting into the return water flow vector labeled number 36c). Doing so under ecosystem feedback monitoring and control boosts the lake's biological productivity and fish yield. Inventive details will be disclosed elsewhere. An estimate for an appropriate scale of CO.sub.2 utilization for diffusion into Lake Kivu's biozone is as follows. The natural scale of deepwater upflux from Lake Kivu's Main Resource Zone (MRZ) has been roughly estimated to be ˜0.15 km.sup.3/yr across an areal extent of ˜1000 km.sup.2 by Schmid and Wuest, (2012). This flux corresponds to an influx volume from deep springs emitting CO.sub.2-rich high-density water into the MRZ. It provides a minimum determination of natural CO.sub.2 flux into the base of the biozone. Using the CO.sub.2 concentration reported in Table 1 (from Wuest et al., 2012), this determines a CO.sub.2 upflux of ˜0.5 MTA (million tonnes per year). A more precise estimate has been obtained from NH.sub.4.sup.+ data in the analysis of Pasche et al., (2011, 2012). Pasche's analysis determines an upflux of ˜0.7 MTA CO.sub.2. This natural upward flux of CO.sub.2 nutrient from below into Lake Kivu's biozone is shut-off or diluted by some return flow injection schemes. In such circumstances, the upward flux of CO.sub.2 into the biozone can be replaced by artificial diffusion into the return flow flux being reinjected into the lake. In general, increasing the CO.sub.2 flux from below boosts the ecological productivity of the lake. It acts as a carbon source for algal photosynthesis. Pending input-response testing in test areas in the lake, a scientifically informed rough estimate for a reasonable boost is at least a factor-of-three increase. This indicates a target delivery at least ˜2 MTA of CO.sub.2 into the biozone.

[0556] The third “main mode” of CO.sub.2 utilization (FIG. 2, arrow 3) is diffusion-dissolution of CO.sub.2 into high-pH (pH >10) return flow water following water treatment processing by pH-raising methods. This mode of utilization of CO.sub.2 relates the return flow water treatment process disclosed in U.S. Patent Application Publication No. 20160257577 A1. This disclosure presents a method for treating nutrient-rich dense deepwater from Lake Kivu in such a way that the outflow of the process yields a de-densified water at a high pH. Addition of CO.sub.2 by injective dissolution may be used to treat this water for purposes of pH reduction prior to reinjection into Lake Kivu at a depth level below the biozone, most desirably within the so-called Intermediate Zone (IZ). This mode of CO.sub.2 utilization for pH reduction of high-pH return flow treated water is a preferred embodiment. It is shown in FIG. 2 as CO.sub.2 flow vector 3 connecting into return water flow vector 36b. Sourcing for this CO.sub.2 in the CO.sub.2-UH is shown in FIG. 3 as process train 23. This offers an opportunity to sequester CO.sub.2 in Lake Kivu in a non-dangerous situation more than 100 meters above the ˜260 meter deep main density discontinuity. Utilizing CO.sub.2 for pH-balancing may be ecologically prudent even though the injection level is under the biozone rather than within it. Lowering of pH involves dissolving CO.sub.2 into alkaline solution causing transformation of doubly charged carbonate anions, each associated with two sodium cations, into singly charged bicarbonate anions, each associated with one sodium cation. The scale of CO.sub.2 utilization via this modality depends on the sodium concentration and the total flow of return flow water processed according to the bio-treatment and Mg+Ca-precipitation method. A simple rough estimate is to assume that CO.sub.2 absorption into the high pH solution will convert all sodium-associated ions (2Na.sup.+::1CO.sub.3.sup.2−) into sodium-associated bicarbonate ions (2Na.sup.+::2HCO.sub.3.sup.−). This will be by addition into solution of CO.sub.2 in the molar ratio: CO.sub.2/Na=0.5, with respect to the sodium concentration of the water. For clarity, this assumption is coupled with the additional simplifying assumptions that all initial sodium associated anions at pH˜10.5 are carbonate (CO.sub.3.sup.2−), and all final sodium-associated anions are bicarbonate (HCO.sub.3.sup.−) at lower pH, and that sodium (Na) is the predominant cation active in the carbonate-bicarbonate equilibrium. (The last assumption follows from the prior precipitative removal of both calcium and magnesium by pH ˜10.5.) Using input data for sodium at 300 meters depth in Lake Kivu's main basin from Tassi et al., (2009), Na ˜0.0175 moles/l, a rough estimate for CO.sub.2 absorption into the high-pH solution is: ˜0.0088 moles/l (=˜0.39 grams per liter). This may be compared to the initial CO.sub.2 concentration in the deepwater at 300 meters depth prior to degassing: CO.sub.2˜0.055 moles/l, ˜2.42 g/l. Therefore if all of the return flow is bio-processed and de-densified, then ˜16%, roughly one sixth of the CO.sub.2 degassing flux, is absorbable for pH-balancing prior to reinjection into Lake Kivu (at an appropriate density-matched depth in the interval ˜90 meters to ˜150 meters). Adjustments for the addition of combustion-derived CO.sub.2 and other corrections suggests that a reasonable expectation for CO.sub.2 utilization in pH-balancing is ˜12% of the total flux out of the OXFCPS. For an output of ˜400 MW, this is roughly 1 MTA (Million Tonnes per Annum) of CO.sub.2. Together therefore, biozone fertilization and return flow pH-balancing represent the second and third “major modes” of CO.sub.2 utilization, shown in FIG. 2 as vectors 2a, 2b and 3, respectively. The simple estimates provided herein indicate it is possible to utilize quite a large fractional component of CO.sub.2 exhaust locally by shallow injection in Lake Kivu for biozone fertilization and return flow pH-balancing: altogether roughly one third of the total degassing flux of CO.sub.2. (Note there is no increased limnic eruption risk by these methods because the chemical state of the absorbed CO.sub.2 would be in the form of bicarbonate anion in a chemical state close to that of water in the biozone.)

[0557] The fourth “main mode” of CO.sub.2 utilization (FIG. 2, arrow 4) is a pH-controlling modality preparatory to return flow into an algal growth sector. This mode of CO.sub.2 utilization is a preferred embodiment. CO.sub.2 input in this modality is shown in FIG. 8 as flow vector 12a providing CO.sub.2 in item 17a. Item 17a is a diffuser. It adds CO.sub.2 into solution prior to flow into an algal growth sector identified as item 18. No estimate for this modality is provided in table 2. The scale of CO.sub.2 input is dependent on a range of factors having to do with the specific conditions of degassing and specifications for control over Mg and Ca precipitation.

[0558] The fifth “main mode” of CO.sub.2 utilization (FIG. 2, arrow 5) is local algal production. This mode of CO.sub.2 utilization is a preferred embodiment. CO.sub.2 is disseminated into algal biocultures both by direct CO.sub.2 dissolution into biocultures and indirectly by addition of sodium bicarbonate (which may be formed by water absorbing carbonation of alkaline brine or sodium carbonate molecules, Na.sub.2CO.sub.3, into two bicarbonate molecules NaHCO.sub.3). Degassed Lake Kivu deepwater carries dissolved inorganic carbon accessible for algal carbon fixation in the form of bicarbonate anion. It also carries NPK bionutrients. A substantial crop of algae therefore can be grown to certain concentration levels without adding any additional carbon source. However, with addition of extra nutrients (as may be accessed by various methods of nutrient recycling in algal production and processing), further algal biomass can be grown if a new source of carbon is provided. CO.sub.2 can be used as a carbon source for this purpose. It may be utilized via a pH-lowering input chemistry, as noted herein, converting doubly-charged carbonate anions to singly-charged bicarbonate anions. Algal production can follow a two-step focus: (i) first, initial separation of very high value nutraceutical compounds, followed by (ii) high-pressure hydrothermal processing of residues with nutrient recycling for production of biofuels, bio-asphalt and bio-fertilizers. The production of high-value nutraceutical products depends on the species mix of algae grown. It therefore depends on the biotechnological set-up, controls and inputs. Many options are possible. For example, CO.sub.2 may be used to grow diazotrophic cyanobacteria algae via P-only nutrient feeding into biocultures. Such biocultures also may be grown under various low-oxygen N.sub.2:CO.sub.2 canopy conditions to optimize cyanobacterial growth and dominance conditions (Smith and Evans, 1971; Fay, 1992; Thomas et al., 2005; Berman-Frank et al., 2005; Molot et al., 2014). This produces cyanobacteria biomass harvestable as NP-rich biofertilizers where nitrogen has been fixed by the diazotrophic activity of the cyanobacteria, and where carbon has been fixed by photosynthesis from the CO.sub.2. CO.sub.2 additionally may be utilized as a coagulation-flocculation agent in harvesting, as noted herein. CO.sub.2 may be used for post-harvest processing to separate algal oil, including high-value nutraceutical/pharmaceutical components. Algal biomass production can utilize CO.sub.2 in many and different ways.

[0559] Two estimates for CO.sub.2 utilization follow relating to algal production. If 0.5 MTA CO.sub.2 is utilized for carbonation of (1.2 MTA of) sodium carbonate, (Na.sub.2CO.sub.3), to sodium bicarbonate, (NaHCO.sub.3), then the amount of sodium bicarbonate produced at 100% efficiency is: ˜1.9 MTA. Some fraction of this sodium bicarbonate production may be used for large-scale algal production, for example growing spirulina as a high-value protein and nutrients source for mother and child nutritional supplement feeding addressing widespread regional dietary protein deficiency. Second, if 1.0 MTA CO.sub.2 is directly diffused into algal bioculture, then if ˜½ of that carbon is harvestable in algal biomass, and if ˜½ of that carbon is convertible into (for example) transportation biofuel carbon (therefore a carbon mass of: 1MTA×12/44×0.25˜80,000 tonnes/yr), then the amount of refined biofuel (assuming an average molecular formula: C.sub.12H.sub.23) produced is ˜93,000 tonnes per year, or ˜110 million liters at a density of ˜0.83 tonnes per 1,000 liters. For comparison, Rwanda's total annual consumption of transportation fuel is roughly 400 million liters. Overall, ambitious target scales for algal bioproduction utilization for Lake Kivu CO.sub.2 ranges roughly from 0.5 to 5 MTA. The scale of direction of CO.sub.2 utilization is dependent on the techno-economics of developing appropriate engineering biosystems for algal growth and harvesting integrated with biomaterials processing (such as for high-value nutraceutical/pharmaceutical oil production followed by high-pressure hydrothermal residue processing into fertilizers, biofuels, syngas and other products).

[0560] The sixth “main mode” of CO.sub.2 utilization is pressurized CO.sub.2 delivery by pipeline. This mode of CO.sub.2 utilization is a preferred embodiment. Typically, pressurized CO.sub.2 delivery by pipeline is in high volumes over substantial distances. As this “main mode” specifies a gas specification and associated delivery technology, several specific “main modes” of CO.sub.2 utilization are referenced together under this mode. All are included as preferred embodiments. Five specific types of CO.sub.2 utilization by means of this method of CO.sub.2 delivery are included. The first example of a potential large-scale use of high-pressure CO.sub.2 delivered by a long pipeline is CO.sub.2 delivered for Enhanced Oil Recovery (EOR) to the Albertine Rift of the Uganda-DRC border region, or to any future area in the region found to be oil-rich, including locations within the Lake Kivu basin itself. This mode of CO.sub.2 utilization is a preferred embodiment. Oil-bearing formations are known to exist roughly from south of Lake Edward north along the border rift through to the northern boundary of Lake Albert. At present, the entire extractable oil resource is estimated to be ˜2 billion barrels. Initial oil extraction operations have been developed on Lake Albert. This location is roughly 400 km northeast of the northern boundary of Lake Kivu.

[0561] The second example of a potentially large-scale use of high-pressure dehydrated CO.sub.2 delivered at a distance by CO.sub.2 pipeline is large-scale olivine carbonation. This use of CO.sub.2 for this purpose typically would be associated with mining activity, typically involving dunite-containing nickel-rich ore bodies. Such bodies exist in the NE of Rwanda as well as in Tanzania and Burundi close to their borders with Rwanda. Olivine carbonation can be a greentech method of nickel mining when dunite deposits are available with high nickel contents and/or that contain nickel-concentrating sulfides. Olivine carbonation also can be used as a way to produce silicic acid together with iron and magnesium carbonates. This mix is useful for plant feeding as a mineral fertilizer. Uses include algal biomass fertilization focused on diatom species (many of which require silicon feeding). Utilization of CO.sub.2 for the production of mineral fertilizers for diatom algal production within a Lake Kivu CO.sub.2-UH is an attractive prospect in view of associated high-value nutraceuticals and pharmaceuticals export potential. This mode of CO.sub.2 utilization is a preferred embodiment.

[0562] The third example is delivery of CO.sub.2 for distant greenhouse horticultural utilization, (for example in Kenya). This mode of CO.sub.2 utilization is a preferred embodiment.

[0563] The fourth example is delivery of CO.sub.2 for use in “solar fuels” and/or “solar chemicals” (or, more generally, “renewables-based” fuels and chemicals) manufacture in connection with renewable electric power provided by solar arrays and/or by wind farms, and/or from hydropower. Pipeline export of CO.sub.2 may be combined with CO.sub.2-EOR, for example, in eastern components of the East African rift in both Kenya and Tanzania where there are rift oil sectors as well as zones of very high average solar radiation intensity suitable for large solar power generation arrays (see: Solargis, 2011). This mode of CO.sub.2 utilization is a preferred embodiment.

[0564] The fifth example is delivery of high-pressure pipeline CO.sub.2 to areas in Kenya and Tanzania where sodium carbonate and sodium carbonate-rich brines are mined and processed, and where CO.sub.2 carbonation can produce a sodium bicarbonate product, and where solar radiation conditions are excellent for high-value algal biomass production in alkaline biocultures, for example spirulina farming. This mode of CO.sub.2 utilization is a preferred embodiment.

[0565] The seventh “main mode” of CO.sub.2 utilization involves cryogenic treatment to create CO.sub.2 products by refrigeration, both liquid and solid CO.sub.2. This mode of CO.sub.2 utilization is a preferred embodiment. It is a mode of CO.sub.2 preparation and delivery rather than a specified mode of CO.sub.2 utilization. Therefore several specified sub-modes are included within this section as preferred embodiments. Again, refrigerated CO.sub.2 may be in the form of liquefied CO.sub.2 and/or as dry ice. Both of these modes are shown in FIG. 3 as process trains labeled 25 and 26, respectively. Liquefied CO.sub.2 is transported across long distances in large amounts typically in thermally insulated tanker trucks and large ships similar to those used for LNG transportation. In central Africa, liquid CO.sub.2 may be transported by insulated tanker truck. It may be delivered for many uses. These uses do not depend on the CO.sub.2 being in a liquid form in so far as liquefaction simply can be an efficient mode for transporting CO.sub.2 utilized in other forms. Uses include, for example, beverage carbonation, insect protection and fumigation (for example in grain storage), horticultural use (including algal production), wastewater pH-lowering, tank re-filling for example for local dry ice manufacturing, food product packaging, use in supercritical extraction processing, supercritical CO.sub.2 dry cleaning, medical gas mixing, waterless textiles dyeing, charging of fire extinguishing systems and refrigeration systems using CO.sub.2 as a thermal transfer fluid, cold pasteurization of milk, beer and juices, humane animal slaughtering, CO.sub.2 fracking or frack fluid mixing, and lithium processing. Liquid CO.sub.2 also may be transported by means of short-distance insulated pipelines, for example within a geographically disseminated CO.sub.2-UH. An estimate for potential CO.sub.2 utilization of liquid CO.sub.2 in the region is ˜50,000 tonnes per year.

[0566] Dry ice typically is transported in insulated and/or refrigerated delivery trucks. It also can be sub-delivered in insulated packages via motorbikes to remote off-grid locations. It is generally used as a coolant. In the area of Lake Kivu, dry ice can be utilized to supply needs for off-grid refrigeration. An example is delivery as a refrigerant with beverages served chilled and/or with spoilable meats, including fish. If beverages are supplied in kegs or other tanks, then off-grid dry ice refrigeration makes it possible to avoid the high cost of bottles and bottling. Dry ice also can be used as a non-wetting refrigerant to be used within coolers and other insulated packaging for truck transport of perishables (such as fish, milk, flowers and fruits) in trucks otherwise not equipped for cargo refrigeration. An estimate for potential CO.sub.2 utilization as dry ice in the region may be as high as 50,000 tonnes per year for such uses. Altogether, therefore, a rough estimate under this sixth “main mode” of CO.sub.2 utilization is ˜100,000 tonnes per year in total. Dry ice production is a preferred embodiment of the invention.

[0567] The eighth “main mode” of CO.sub.2 utilization is provision of unprocessed or mildly processed hot and wet (steam-rich) exhaust from oxyfuel combustion into cementing mineral carbonation in the production of concrete products and other building materials that include mineral cements. This mode of CO.sub.2 utilization is a preferred embodiment. It is shown in FIG. 2 as vector 8. It also is shown in FIG. 3 as the example displayed for the representation of the process train labeled as 22. This process can use magnesium hydroxide (brucite) as the main reactant with CO.sub.2 for mineralization into various Mg-carbonates. Or it can remineralize pre-carbonated nesquahonite to generate various output carbonated and hydrated mineralogies. Or it can involve CO.sub.2 carbonation of conventional Portland cements in various ways. The use of magnesium is of special interest for Lake Kivu. This is because it can be obtained as a precipitated product of de-densifying return flow water treatment according to the method disclosed by the inventor in U.S. Patent Application Publication No. 20160257577 A1. The scale of CO.sub.2 use by this method can be estimated at a minimum scale via the flux of precipitated magnesium associated with treatment or degassed return flow deepwater according to the above-noted method. Magnesium hydroxide stoichiometry is used as the example. Scaled to a 400 MW power output, the dissolved Mg flux through the degassing system is close to 0.6 MTA of magnesium. Given assumptions of (for example) ˜90% Mg capture and ˜70% partitioning of return flow into an Mg-precipitating water treatment mode, the captured Mg flux estimate is: ˜0.4 MTA Mg. Using a nesquahonite composition, (MgCO.sub.3.3H.sub.2O), for a carbonation target composition, the mass flow of the associated Mg-based component of carbonated and hydrated cement is ˜2.3 MTA for the hydrated Mg-based cement component. (For comparison, Rwanda's dominant cement producer, CIMERWA, produces ˜0.6 MTA of dryweight Portland cement. Bateta, 2015). The rate of CO.sub.2 consumption for cementitious mineralization in this process is ˜0.7 MTA CO.sub.2. For concrete with a mass ratio of >5 for aggregate-to-cement, this corresponds to in excess of 12 million tonnes of concrete production per year. Moreover, in concretes cementing with Mg-hydroxide (“brucite”) carbonation reactions, CO.sub.2 additionally can be mineralized by carbonation reactions within pozzolanic aggregates. And, as an alternative, CO.sub.2 can be mineralized into ordinary cementing reactions with Portland-type cement chemistries using pressure chambers for setting and curing. Overall, there are many opportunities across a range of cementitious chemistries and pozzolan addition situations. A rough estimate of utilizable CO.sub.2 from cementitious mineralization-incorporation is: ˜1 MTA CO.sub.2. This scale of CO.sub.2 utilization represents a gigantic capacity for CO.sub.2-mineralizing eco-concrete production. It represents more than a doubling of Rwanda's circa 2015 cement production capacity. CO.sub.2-mineralizing eco-concrete and related building materials may be factory-made as pre-cast molded stock. Advanced CO.sub.2-mineralizing eco-concretes may be developed that can be poured and set (and process remineralized) in the field. CO.sub.2-mineralizing eco-concrete production are included as embodiments of the invention, capturing degassed (and post methane combustion) Lake Kivu CO.sub.2 into building materials.

[0568] The ninth “main mode” of CO.sub.2 utilization is urea manufacture. This mode of CO.sub.2 utilization is a preferred embodiment. The potential for urea production in the context of the invention disclosed herein follows from the availability of CO.sub.2 and also from the fact that a large flux of ammonium ion is present in Lake Kivu deepwater passing through the TDS. Additionally, the Air Separation Unit (ASU) component of the OXFCPS generates a large flux of purified nitrogen gas. This can be used for ammonia (NH.sub.3) production, combining with H.sub.2. Algal biomass processing also can use methods that allow nutrient recycling that allows capture of ammonia. At a power production level of 400 MW, the mass of urea equivalent for 100% capture and conversion of NH.sub.4+ flux present in the extracted deepwater stream is 212,000 tonnes per year. This is equivalent to ˜200,000 tonnes per year of ammonia (NH.sub.3). This number provides a useful reference point. For urea synthesis, CO.sub.2 is used on a molar ratio basis of CO.sub.2/NH.sub.3=1.0. Therefore a flux of ˜200,000 tonnes of ammonia determines an intake of ˜518,000 tonnes of CO.sub.2. Assuming, for example, a situation of capture and conversion of ˜60% of the ammonium flux through deepwater processing, then CO.sub.2 utilization is ˜300,000 tonnes per year and urea production is ˜400,000 tonnes per year. No disclosure of a method or system for removal of this ammonium from Lake Kivu deepwater is included herein.

[0569] The tenth “main mode” of CO.sub.2 utilization is formic acid production. This mode of CO.sub.2 utilization is a preferred embodiment. As referenced herein, there are many possibilities for modes of production utilizing CO.sub.2 to produce formic acid. These include production with electrolytic hydrogen as a “solar chemical” or “solar fuel,” and hydrothermal production using water as the hydrogen source linked with zero-valent metals redox cycling. Both CO.sub.2 and formic acid also can be used for animal hide processing and as tanning agents in developing a leather products industry. A reasonable target for CO.sub.2 utilization to produce formic acid is 10,000 tonnes per year. A much larger scale of production would be possible if formic acid fuel cell technologies were to become widespread.

[0570] The eleventh “main mode” of CO.sub.2 utilization is production of carbon monoxide (CO). This mode of CO.sub.2 utilization is a preferred embodiment. Carbon monoxide has use in metals smelting, especially tin (Sn), zinc (Zn) and iron (Fe). Several modes for CO production from CO.sub.2 have been described herein, such as, for example, that of Igor Lubomirsky and his Weitzmann Institute colleagues. Lubomirsky's method creates both CO and a separated stream of O.sub.2 gas useful for input into oxyfuel combustion as shown in FIG. 2, flow vector 31. Rwanda has long been a tin-producing country utilizing cassiterite-rich ores. Rwandan cassiterite (SnO.sub.2) production circa 2015 is approximately 5,000 tonnes per year. Potential production capacity is much higher. A rough estimate of the amount of CO.sub.2 needed to smelt cassiterite from CO is a molar ratio of ˜2CO.sub.2/SnO.sub.2, corresponding to a mass ratio of ˜0.58. Consequently, a rough estimate of CO.sub.2 potential for CO production for cassiterite smelting is ˜3,000 tonnes per year scaled to Rwandan production. Much larger amounts of carbon monoxide could be utilized for scaled-up tin production as well as for smelting of other metal oxide ores and for metals processing.

[0571] The twelfth “main mode” of CO.sub.2 utilization is input of CO.sub.2 into the manufacture of pyrethrum biopesticide. This mode of CO.sub.2 utilization is a preferred embodiment. Pyrethrum biopesticide is sold in returnable pressurized tank bottles of CO.sub.2. CO.sub.2 functions in a dual mode as a greentech solvent and non-toxic propellant. Pyrethrum-in-CO.sub.2 “organic” biopesticide can be used in greenhouses as a form of insecticide that additionally provides CO.sub.2 plant fertilization. Organic biopesticides have a potentially very large market. In the region of Lake Kivu, this market can scale with the growth of high-intensity greenhouse cultivation with CO.sub.2 yield boosting. A rough estimate for CO.sub.2 utilization in this eleventh category is included as 20,000 tonnes per year.

[0572] The thirteenth “main mode” of CO.sub.2 utilization is for CO.sub.2 use in forest products production. This mode of CO.sub.2 utilization is a preferred embodiment. This is a wide category. Many types of inputs are possible. An example is using supercritical CO.sub.2, formic acid and sodium carbonate chemicals for pulping of bamboo to produce bamboo-based chemicals (such a xylitol), paper, viscose-type bamboo textiles and lignocellulosic biofuels. No estimate for a scale of utilization is presented. Bioprocessing of forest products using CO.sub.2 and derivative chemicals represents a huge opportunity in the Lake Kivu region. This is in view of the great forests of the DRC existing to the west of the Lake.

[0573] The fourteenth “main mode” of CO.sub.2 utilization is CO.sub.2 Plume Geothermal (CPG) (and/or mixed CO.sub.2—H.sub.2O plume) extraction of geothermal energy, possibly connected with CO.sub.2 geosequestration. This mode of CO.sub.2 utilization is a preferred embodiment. Lake Kivu is situated in a region with huge geothermal resources. No estimate for a scale of utilization is presented.

[0574] The fifteenth “main mode” of CO.sub.2 utilization is fuels production by reaction of CO.sub.2 with hydrogen, and/or water, and/or methane in various production processes, with or without electric power inputs, yielding methanol, dimethyl ether (DME) and other fuels and chemicals, including those produced by mini-GTL processes. This mode of CO.sub.2 utilization is a preferred embodiment. Many such methods are referenced and briefly reviewed herein. Many additional methods will be developed in the future as relatively small scale GTL technologies develop and grow, and as new economically viable turnkey plant options are developed to use stranded and/or otherwise flared natural gas, and also as CO.sub.2-utilizing transport fuels production options become commercially viable based on the need for energy storage from intermittent supplies of renewable electric power (that is: “solar-” or “electro-” fuels and chemicals). Methanol and DME are of particular interest in the location of Lake Kivu. They both can be utilized as a transport fuel fuels and fuel additives. DME also could be used as a cost-lowering substitute for imported bottled propane gas used in home cooking and by businesses. DME additionally can be useful for algal products processing utilizing wet algal biomass, as noted herein. Both methanol and DME also are of special global environmental interest. They represent the CO.sub.2-recycling “methanol economy” vision of George Olah and colleagues. No estimate for a scale of utilization is presented.

[0575] The sixteenth “main mode” of CO.sub.2 utilization is a special case of the previous main mode. It is input of hot CO.sub.2 plus steam exhaust from the OXFCPS into syngas production of methanol and DME. This mode of CO.sub.2 utilization is a preferred embodiment. It aims to capture heat energy from combustion for CO.sub.2 utilization purposes using the outflow of the OXFCPS exhaust directly. It includes, for example, application of methods and systems of technologies of the type being developed by the Danish company Haldor Topsoe for the transformation of inputs of CO.sub.2, steam and mechanical and/or electric power into outputs of methanol and oxygen gas (Hansen, 2014ab, 2015a,c,f). These methods involve designs that incorporate Solid Oxide Electrolysis Cell (SOEC) technologies into production of syngas from CO.sub.2 and steam mixtures. The OXFCPS submethod and subsystem described as a part of the invention disclosed herein generates exhaust outputs of CO.sub.2, steam and electric power. OXFCPS exhaust and power production therefore matches inputs to the new technology being developed by Haldor Topsoe, though not necessarily with the correct range of H.sub.2O/CO.sub.2 input ratios. However, heat capture within the system can modulate steam addition to reach targets for the input ratio of H.sub.2O to CO.sub.2 into the reactor system. Extra power for CO.sub.2 plus steam electrolysis via SOEC can be obtained additionally from renewable energy inputs transmitted by high-voltage wires. An extra bonus is that in an integrated system, co-produced O.sub.2 can be fed into the input into oxyfuel combustion. No estimate for a scale of utilization is presented.

[0576] The seventeenth “main mode” of CO.sub.2 utilization is another special case of a previous main mode. It is inputs of CO.sub.2 and water into electrosynthesis of various chemicals via formate and oxalic acid (H.sub.2C.sub.2O.sub.4) platforms such are being developed by the company Liquid Light, for example for the production on mono-ethylene glycol (MEG) for use in production of PET plastic bottles. This mode of CO.sub.2 utilization is a preferred embodiment. Use of these methods with solar power inputs generates “solar chemicals” (including “solar fuels”). This displaces the use of petroleum by utilizing waste CO.sub.2 as an alternate carbon source. No estimate for a scale of utilization is presented.

[0577] The eighteenth “main mode” of CO.sub.2 utilization is deployment of gas fermentation biotechnologies based on the microbial Wood-Ljundahl pathway to produce acetate and other chemicals. This mode of CO.sub.2 utilization is a preferred embodiment. It is done via inputs of either mixtures of CO.sub.2 and H.sub.2 mixtures, or CO.sub.2 alone with electrons provided to the microbes (“electrobiosynthesis”). As noted herein, the company LanzaTech is developing these methods commercially. No estimate for a scale of utilization is presented.

[0578] The nineteenth “main mode” of CO.sub.2 utilization is plastics manufacture with chemical incorporation of CO.sub.2. This mode of CO.sub.2 utilization is a preferred embodiment. Examples of technologies include the processes of CO.sub.2 incorporation into CO.sub.2-polyols developed by companies such as Novomer, Bayer/Covestro and Econic Technologies. CO.sub.2-utilizing plastics can be produced in synergy with the production of CO.sub.2-utilizing bioplastics, for example using algal biomass and/or separated algal oils. No estimate for a scale of utilization is presented.

[0579] The twentieth “main mode” of CO.sub.2 utilization is high-value carbon products production. What is referred to by “carbon products” is products composed mostly (though not strictly only) of forms of elemental carbon. This mode of CO.sub.2 utilization is a preferred embodiment. Examples of attractive possibilities are dense nanoporous graphene used in supercapacitors, carbon nanotubes used in new battery technologies, and carbon nanofibers used in high-strength composites. Byproduct oxygen gas can feed O.sub.2 into the ASU oxygen supply for oxyfuel (as shown by flow vector 31 in FIG. 2). Using an oxygen stream that otherwise might be vented as a waste can provide an efficiency boost in cases where large quantities of CO.sub.2 are utilized to produce carbon products by splitting CO.sub.2 into C and O.sub.2.

[0580] An additional preferred embodiment of the invention disclosed herein pertains to a co-product adjunct to CO.sub.2. This is purified nitrogen in both gaseous (N.sub.2) and liquefied forms (LN.sub.2). Purified nitrogen is co-produced with pure oxygen gas in the submethod and subsystem of an Air Separation Unit (ASU). As shown in FIG. 2, box 1, the OXFCPS overall is defined to be an integrative combination of items 26, 27, 28 and 29, with item 27 being an ASU. An ASU is herein defined to be any technology that can obtain a supply of separated O.sub.2 for infeed into oxyfuel combustion. A cryogenic air separation unit is the conventional (but by no means the only) technology component of the overall OXFCPS. If implemented in a specific design as an option within the overall scope of the invention disclosed herein, a cryogenic ASU produces an adjunct supply of liquefied nitrogen gas (N.sub.2). This is shown in FIG. 2 as a part of item 27, yielding flows of liquid (or gaseous) nitrogen. These flows are shown as flow vectors 39 and 40. Flow vector 39 enters the CO.sub.2-UH (via item 30 where cryo-capacities are present).

[0581] Production of cryo-liquefied nitrogen (LN.sub.2 or LN2) by the ASU also is shown in FIG. 6. FIG. 6 shows a preferred embodiment utilizing this LN.sub.2 both for cryo-energy storage and for cooling of a Digital Data Center (DDC). Cryogenic energy provided by the ASU in the form of LN.sub.2 (or LO.sub.2) can be used in the production of liquefied and/or solidified CO.sub.2 within the CO.sub.2-UH (FIG. 2, item 21). Also it can be utilized independently of the CO.sub.2-UH, as shown by flow vector 40 in FIG. 2. The capacity of the overall system to produce and store liquefied N.sub.2 in excess of that used within the ASU (for energy recycling efficiency) can be considered as an adjunct capacity assisting powerplant efficiency as well as CO.sub.2 utilization. Utilization of cold nitrogen gas also can supply Digital Data Center (DDC) cooling. This is illustrated herein in FIG. 6 and its accompanying text. Both cold N.sub.2 and LN.sub.2 also may be used for DDC cooling. Use of cold nitrogen produced by OXFCPS operations as a utilization of otherwise wasted material and associated cryo-energy can assist realization of DDC industrialization by lessening the (often very substantial) electric power draw of such a facility. Nitrogen gas also has numerous other productive uses, for example in algal production where it provides a N.sub.2 source for diazotrophic (nitrogen-fixing) cyanobacteria. It also is useful for algal culture sparging and related uses for removal of growth-inhibiting O.sub.2. Nitrogen gas also may provide basic chemical inputs for various purposes into a large number of types of chemical synthesis reactions. FIG. 6 shows a preferred embodiment (as item 13) providing a source of “warm” nitrogen gas as an outflow of cold nitrogen into DDC cooling. This cooling is fed either directly from stored LN.sub.2 (FIG. 6, item 11) or from cold nitrogen gas after being used in recovery of stored cryo-energy (cf, FIG. 6, item 18c feeding an outflow as item 12). More generally, the overall method and system provides nitrogen gas as outflow (FIG. 6, item 12) that is available for utilization for any purposes.

[0582] An additional adjunct capacity of the invention is production of Liquefied Natural Gas (LNG) and associated forms of Natural Gas (NG) that can be produced and sold as a consequence of the capability to separate natural gas (see FIG. 6, item 40) from an inflow of mixed NG and CO.sub.2 from Lake Kivu (FIG. 6, item 38). (NB: NG deriving from Lake Kivu is biogas.) These associated forms of NG are highly useful for various purposes. These can be produced and sold as adjunct capacities of the invention in preferred embodiments. They are: (i) Compressed Natural Gas (CNG, see Wikipedia entry: https://en.wikipedia.org/wiki/Compressed_natural_gas), and Adsorbed Natural Gas (ANG, see Wikipedia entry: https://en.wikipedia.org/wiki/Adsorbed_natural_gas). The capacity to produce NG in any of these forms (LNG, CNG, ANG) derives from a CO.sub.2 separation processing function within the CO.sub.2-UH (FIG. 6, Box 4). This CO.sub.2 separation processing function produces dry ice and/or LCO.sub.2. It is indicated in FIG. 6 circumscribed within Box 36 (and including items 35, 37, 39 and 40). This adjunct capacity for NG production is a part of the cryogenic capacities, including the cryogenic fluids and cryo-energy storage capacities, of the invention (FIG. 6, Box 28), and is a preferred embodiment. Such an adjunct capacity has potent potential in the locus of Lake Kivu for purposes such as: (i) providing bottled NG (CNG and/or ANG) for home and business cooking and other similar uses of heat energy from NG combustion; (ii) providing bottled NG (CNG and/or ANG) as a source of fuel for internal combustion engines such as, for example, those in motorcycles, cars and trucks modified to run on NG. Of course, the capacity to produce LNG for CO.sub.2 separation processing and cryo-energy storage also allows LNG to be sold as well as used as a stored energy “backup” reservoir of both cryo-energy and chemical energy for powerplant operations backup purposes such as may be necessary, for example, in situations of maintenance and improvements of extractive degassing equipment.

[0583] While the invention has been described in detail and with reference to specific examples thereof, it will be apparent to one skilled in the art that various changes and modifications can be made therein without departing from the spirit and scope thereof.

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