System and method for increasing a storage capacity of an underground storage reservoir using an electrical submersible pump

Abstract

A system and method for increasing a storage capacity of a first underground storage reservoir includes a first well having perforations within the first underground storage reservoir, a second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir, and an electrical submersible pump. The first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir. The electrical submersible pump is located within the second well and increases the storage capacity of the first underground storage reservoir by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir.

Description

SYSTEM AND METHOD FOR INCREASING A STORAGE CAPACITY OF AN UNDERGROUND STORAGE RESERVOIR USING AN ELECTRICAL SUBMERSIBLE PUMPCROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application claims priority to U.S. Provisional Application Serial No. 63 / 619,362, filed January 10, 2024, the entire contents of which are incorporated herein by reference.TECHNICAL FIELD OF THE INVENTION

[0002] The present invention relates in general to the field of carbon capture and storage, and more particularly, to a system and method for increasing a storage capacity of an underground storage reservoir using an electrical submersible pump.STATEMENT OF FEDERALLY FUNDED RESEARCH

[0003] This invention was made with government support under Grant / Contract No. DE- FE0031892 awarded by the U.S. Department of Energy as part of the Illinois Storage Corridor Carbon SAFE project. The government has certain rights in the invention.BACKGROUND OF THE INVENTION

[0004] Without limiting the scope of the invention, its background is described in connection with carbon capture and storage.

[0005] Carbon Capture & Storage (CCS) is a proven technology supported by regulatory policies to mitigate climate change. The extremely large volumes of carbon dioxide (CO2) need to be removed from the atmosphere to make an impact and prevent global warming. In CCS, anthropogenic CO2 is captured at the source location and transported to a storage site where it is safely stored in deep saline sedimentary basins referred to as storage reservoirs. Overlying low permeability shale formations referred to as primary seals prevent the leakage of CO2 to overlying formations and / or surface. CO2 is stored in the pore space previously occupied by brine which gets displaced away as large volumes of CO2 is injected. The subsurface area impacted due to CO2 injection activity is referred to as Area of Review (AoR)

[0018] , Several simulation studies have been conducted to evaluate the impact of brine extraction on reduction of the size of AoR [1-3,7,9-10,14], Along with reduction of AoR size, brine extraction also helps in reducing the stress on primary seals, geosteering of the injected fluidsto keep them in permitted boundaries, improving injectivity, capacity, and storage efficiency. Brine extraction from the storage reservoir and injection into a brine storage reservoir has proved to be beneficial and feasible [8], However, there is additional cost associated with brine extraction, treatment, and re-injection into a brine storage reservoir [4],

[0006] Accordingly, there is a need for a system and method for increasing a storage capacity of an underground storage reservoir using an electrical submersible pump.SUMMARY OF THE INVENTION

[0007] Various embodiments described herein use an electrical submersible pump (ESP) to transfer fluid, such as brine, from an underground gas storage reservior to an underground fluid storage reservoir. The fluid transfer increases a storage capacity of the underground gas storage reservoir, and reduces the size of the area of review (AoR) associated with an injection well. This process eliminates the major cost associated with the extraction, treatment, and reinjection of the brine.

[0008] One embodiment of the present disclosure provides a system for increasing a storage capacity of a first underground storage reservoir. The system includes: a first well having perforations within the first underground storage reservoir, wherein the first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir; a second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir; and an electrical submersible pump located within the second well, wherein the electrical submersible pump increases the storage capacity of the first underground storage reservoir by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir.

[0009] In one aspect, the gas, liquefied gas or supercritical fluid comprises CO2 and the fluid comprises brine. In another aspect, transferring the fluid from the first underground storage reservoir to the second underground storage reservoir also decreases an area of review associated with the first well. In another aspect, the first underground storage reservoir is a saline aquifer or a depleted petroleum reservoir and the second underground storage reservoir is a porous basin or layer. In another aspect, the second storage reservoir is not a producing petroleum reservoir. In another aspect, the first underground storage reservoir is located above the second underground storage reservoir; and the electrical submersible pump is inverted. In another aspect, the first underground storage reservoir is located below the second underground storage reservoir. In another aspect, the electrical submersible pump is located in the second well near the first perforations or the second perforations. In another aspect, thesystem includes a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump. In another aspect, the first well comprises two or more first wells. In another aspect, the second well comprises two or more second wells.

[0010] Another embodiment of the present disclosure provides a method for increasing a storage capacity of a first underground storage reservoir comprising: providing a first well having perforations within the first underground storage reservoir, wherein the first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir; providing a second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir; and increasing the storage capacity of the first underground storage reservoir by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir using an electrical submersible pump located within the second well.

[0011] In one aspect, the gas, liquefied gas or supercritical fluid comprises CO2 and the fluid comprises brine. In another aspect, transferring the fluid from the first underground storage reservoir to the second underground storage reservoir also decreases an area of review associated with the first well. In another aspect, the first underground storage reservoir is a saline aquifer or a depleted petroleum reservoir and the second underground storage reservoir is a porous basin or layer. In another aspect, the second storage reservoir is not a producing petroleum reservoir. In another aspect, the first underground storage reservoir is located above the second underground storage reservoir, and the electrical submersible pump is inverted. In another aspect, the first underground storage reservoir is located below the second underground storage reservoir. In another aspect, the electrical submersible pump is located in the second well near the first perforations or the second perforations. In another aspect, the method further comprises installing the electrical submersible pump within the second well near the first perforations or the second perforations. In another aspect, the method further comprises installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump. In another aspect, the method further comprises injecting the gas, liquefied gas or supercritical fluid into the first underground storage reservoir using the first well. In another aspect, providing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir comprises: drilling and completing thesecond well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir; installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump. In another aspect, providing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir comprises: converting an existing well into the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir; installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

[0012] Note that the invention is not limited to the embodiments described herein, instead it has the applicability beyond the embodiments described herein. The brief and detailed descriptions of this disclosure are given in the following.BRIEF DESCRIPTION OF THE DRAWINGS

[0013] For a more complete understanding of the features and advantages of the present invention, reference is now made to the detailed description of the invention along with the accompanying figures and in which:

[0014] FIG. 1 depicts a system for increasing a storage capacity of a first underground storage reservoir in accordance with one embodiment of the present disclosure;

[0015] FIG. 2 depicts a system for increasing a storage capacity of a first underground storage reservoir in accordance with another embodiment of the present disclosure;

[0016] FIG. 3 depicts a flow chart of a method for increasing a storage capacity of an underground storage reservoir using an electrical submersible pump in accordance with another embodiment of the present disclosure; and

[0017] FIGS. 4A-4B are non-limiting examples of a second well or transfer well in accordance with various embodiments of the present disclosure.DETAILED DESCRIPTION OF THE INVENTION

[0018] While the making and using of various embodiments of the present invention are discussed in detail below, it should be appreciated that the present invention provides many applicable inventive concepts that can be embodied in a wide variety of specific contexts. The specific embodiments discussed herein are merely illustrative of specific ways to make and use the invention and do not delimit the scope of the invention.

[0019] To facilitate the understanding of this invention, a number of terms are defined below. Terms defined herein have meanings as commonly understood by a person of ordinary skill in the areas relevant to the present invention. Terms such as “a”, “an” and “the” are not intended to refer to only a singular entity but include the general class of which a specific example may be used for illustration. The terminology herein is used to describe specific embodiments of the invention, but their usage does not limit the invention, except as outlined in the claims.

[0020] Various methods are described below to provide an example of each claimed embodiment. They do not limit any claimed embodiment. Any claimed embodiment may cover methods that are different from those described above and below. The drawings and descriptions are for illustrative, rather than restrictive, purposes.

[0021] Carbon Capture & Storage (CCS) has gained a lot of importance in the last two decades due to the successful implementation of the technique in pilot projects across the globe. It is one of the most promising techniques developed to address the climate change issue. In simple terms, CCS refers to capturing the anthropogenic CO2 at the source followed by injecting and permanently storing it safely in the subsurface.

[0022] Commercial scale CCS projects require maximum utilization of the available pore space in CO2 storage reservoirs for permanent storage of CO2 while operating at minimum cost. Large volumes of CO2 storage in the storage reservoir increases the challenges as the size of the subsurface area impacted due to CO2 injection activity, which is referred to as the Area of Review (AoR), increases. Although pre-inj ection brine production and / or brine extraction while CO2 injection have proved to be beneficial in avoiding some of the challenges highlighted above there is additional cost associated with it. Electrical submersible pumps (ESP) have been used in the oil and gas industry for enhanced oil recovery and dump flooding operations [5-6,11-13,15-17],

[0023] The methodology described herein uses the ESP to have all the benefits associated with pre-inj ection and / or simultaneous brine extraction while eliminating the major cost ofbrine extraction, treatment, and re-injection into brine storage reservoir. Appropriate use of the ESP and seals, such as packers, will transfer the brine from CO2 storage reservoir to the brine storage reservoir without having to extract brine to surface treat and re-inject it.

[0024] Now referring to FIG. 1, a system 100 for increasing a storage capacity of a first underground storage reservoir in accordance with one embodiment of the present disclosure is shown. Storage reservoirs are layers of porous and permeable rock, within a geologic formation, which are confined by impermeable rock, characterized by a single pressure system, and suitable for long-term storage of a fluid, gas, liquefied gas or supercritical fluid. A first well 102, or injection well, has perforations 104 within the first underground storage reservoir 106 and is configured to inject a gas, liquefied gas or supercritical fluid 108 into the first underground storage reservoir 106. A second well 110, or transfer well, has first perforations 112 within the first underground storage reservoir 106 and second perforations 114 within a second underground storage reservoir 116. In this non-limiting example, the first underground storage reservoir 106 is located above the second underground storage reservoir 116. An electrical submersible pump 118 is located within the second well 110. The electrical submersible pump 118 increases the storage capacity of the first underground storage reservoir 106 by transferring a fluid 120 from the first underground storage reservoir 106 to the second underground storage reservoir 116. The first underground storage reservoir 106 can be a saline aquifer, a depleted petroleum reservoir or other suitable porous and permeable underground formation. The second underground storage reservoir 116 can be a porous basin or layer or other suitable porous and permeable underground formation. In some embodiments, the second storage reservoir 116 is not a producing petroleum reservoir (i.e., a reservoir producing oil, gas or both). This process also decreases an AoR associated with the first well 102. In this non-limiting example, the electrical submersible pump 118 is inverted, and is located in the second well 110 near the first perforations 112 within the first underground storage reservoir 106 or the second perforations 114 within the second underground reservoir 116. Seal(s) 122, such as packer(s), are installed between a casing 124 of the second well 110 and a tubing 126 of the second well 110 above the electrical submersible pump 118 to prevent fluid 120 from going to the surface, or below the electrical submersible pump 118 to prevent the fluid 120 from flowing back into the first underground reservoir 106, or both above and below the electrical submersible pump 118. Moreover, in this non-limiting example, the gas, liquefied gas or supercritical fluid 108 is primarily CO2, and the fluid 120 is primarily brine. Note that other gases, liquefied gases, supercritical fluids and fluids can be used. In addition,the first well 102 may include two or more first wells, and the second well 110 may include two or more second wells.

[0025] The CO2 injection well or first well 102 is referred to as UIC Class VI well because it needs to be permitted, drilled, and perforated for permanent storage of CO2 108 in the subsurface formation termed as the CO2 storage reservoir or first underground storage reservoir 106 while protecting the underground sources of drinking water (USDW) 128. The CO2 injection well or first well 102 can be a new or properly configured existing well. The CO2 storage reservoir or first underground storage reservoir 106 is a sedimentary basin, which are mainly the saline aquifers and / or the depleted oil and gas reservoirs. Class VI wells include wells that penetrate both the primary geologic seal 130 and the CO2 storage reservoir or first underground storage reservoir 106. A geologic seal is a low-permeability sedimentary or structural unit, such as shale or a sealing fault, which provides a physical barrier to upward or lateral migration of CO2 or brine out of a reservoir. The USDW 128 and primary geologic seal 130 are penetrated and protected by the cement 132 surrounding the casing 134 and the casing 134 itself. The CO2 storage reservoir or first underground storage reservoir 106 is penetrated and not protected. In some cases, cement plug(s) or seals 122 (e.g., packers) can provide further protection.

[0026] The brine transferring well or second well 110 needs to be permitted, drilled, and perforated to transfer the brine fluid 120 from the CO2 storage reservoir or first underground storage reservoir 106 to the brine storage reservoir or second underground storage reservoir 116 while protecting the underground sources of drinking water (USDW) 128. The brine transferring well or second well 110 can be a new or properly configured existing well. The USDW 128 and primary geologic seal 130 are penetrated and protected by the cement 136 surrounding the casing 124 and the casing 124 itself. The CO2 storage reservoir or first underground storage reservoir 106 and brine storage reservoir or second underground storage reservoir 116 are penetrated and not protected. In some cases, cement plug(s) can provide further protection. The seals 122 (e.g., packer assemblies) prevent the brine or fluid 120 flow to other formations and helps transfer the brine or fluid 120 to the brine storage reservoir or second underground storage reservoir 116. The brine transferring wells or second wells 110, and their locations need to be evaluated on a case basis that also affects the geosteering of the injected CO2.

[0027] The injected gas, liquefied gas or supercritical fluid 108, such as CO2, displaces the already present in-situ fluids (mainly brine) 120 occupying the pore space in the storage reservoir or first underground storage reservoir 106 and forms a CO2 plume 138. The displacedbrine or fluid 120 gets pressurized due to injection activity and limits the amount of injected gas, liquefied gas or supercritical fluid 108, such as CO2, to be permanently stored in the storage reservoir or first underground storage reservoir 106 as increased injection might fracture the primary geologic seal 130 that acts as a barrier and prevents upward migration of injected gas, liquefied gas or supercritical fluid 108, such as CO2, into overlying formations. The second well or brine transferring well 110 needs to be drilled and completed with tubing 126 conveyed ESP 118 to avoid extraction of brine or fluid 120 to surface, treatment, and reinjection of it in the brine storage reservoir or second underground storage reservoir 116. The ESP 118 can be run normally as shown in FIG. 2 or inverted (up-side down) as shown in FIG. 1 depending upon the location of the brine storage reservoir or second underground storage reservoir 116 with respect to the CO2 storage reservoir or first underground storage reservoir 106.

[0028] Referring now to FIG. 2, a system 200 for increasing a storage capacity of a first underground storage reservoir 106 in accordance with another embodiment of the present disclosure is shown. The system 200 in FIG. 2 is similar to system 100 in FIG. 1, except that the brine storage reservoir or second underground storage reservoir 116 is located above the CO2 storage reservoir or first underground storage reservoir 106, and the ESP 118 is run normally instead of inverted.

[0029] A first well 102, or injection well, has perforations 104 within the first underground storage reservoir 106 and is configured to inject a gas, liquefied gas or supercritical fluid 108 into the first underground storage reservoir 106. A second well 110, or transfer well, has first perforations 112 within the first underground storage reservoir 106 and second perforations 114 within a second underground storage reservoir 116. In this non-limiting example, the first underground storage reservoir 106 is located below the second underground storage reservoir 116. An electrical submersible pump 118 is located within the second well 110. The electrical submersible pump 118 increases the storage capacity of the first underground storage reservoir 106 by transferring a fluid 120 from the first underground storage reservoir 106 to the second underground storage reservoir 116. The first underground storage reservoir 106 can be a saline aquifer, a depleted petroleum reservoir or other suitable porous and permeable underground formation. The second underground storage reservoir 116 can be a porous basin or layer or other suitable porous and permeable underground formation. In some embodiments, the second storage reservoir 116 is not a producing petroleum reservoir (i.e., a reservoir producing oil, gas or both). This process also decreases an AoR associated with the first well 102. In this non-limiting example, the electrical submersible pump 118 is not inverted, and is locatedin the second well 110 near the first perforations 112 within the first underground storage reservoir 106 or the second perforations 114 within the second underground reservoir 116. Seal(s) 122, such as packer(s), are installed between a casing 124 of the second well 110 and a tubing 126 of the second well 110 above the electrical submersible pump 118 to prevent fluid 120 from going up to the surface as well as making sure the fluid 120 flows into the second underground reservoir 116, or below the electrical submersible pump 118 to prevent the fluid 120 from flowing back into the first underground reservoir 106, or both above and below the electrical submersible pump 118. Moreover, in this non-limiting example, the gas, liquefied gas or supercritical fluid 108 is primarily CO2, and the fluid 120 is primarily brine. Note that other gases, liquefied gases, supercritical fluids and fluids can be used. In addition, the first well 102 may include two or more first wells, and the second well 110 may include two or more second wells.

[0030] Now referring to FIG. 3, a flow chart of a method 300 for increasing a storage capacity of an underground storage reservoir using an electrical submersible pump in accordance with another embodiment of the present disclosure is shown. A first well having perforations within the first underground storage reservoir, wherein the first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir, is provided in block 302. A second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir is provided in block 304. The storage capacity of the first underground storage reservoir is increased in block 306 by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir using an electrical submersible pump located within the second well.

[0031] In one aspect, the gas, liquefied gas or supercritical fluid comprises CO2 and the fluid comprises brine. In another aspect, transferring the fluid from the first underground storage reservoir to the second underground storage reservoir also decreases an area of review associated with the first well. In another aspect, the first underground storage reservoir is a saline aquifer or a depleted petroleum reservoir and the second underground storage reservoir is a porous basin or layer. In another aspect, the second storage reservoir is not a producing petroleum reservoir. In another aspect, the first underground storage reservoir is located above the second underground storage reservoir, and the electrical submersible pump is inverted. In another aspect, the first underground storage reservoir is located below the second underground storage reservoir. In another aspect, the electrical submersible pump is located in the second well near the first perforations or the second perforations. In another aspect, themethod further comprises installing the electrical submersible pump within the second well near the first perforations or the second perforations. In another aspect, the method further comprises installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump. In another aspect, the method further comprises injecting the gas, liquefied gas or supercritical fluid into the first underground storage reservoir using the first well. In another aspect, providing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir comprises: drilling and completing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir; installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump. In another aspect, providing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir comprises: converting an existing well into the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir; installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

[0032] Referring now to FIG. 4A, a non-limiting example of a second well 110A, or transfer well, in accordance with one embodiment of the present disclosure is shown. The second well 110A has first perforations 112 within the first underground storage reservoir 106 and second perforations 114 within a second underground storage reservoir 116. The first underground storage reservoir 106 is located above and separated from the second underground storage reservoir 116 by a low permeability formation 402. An electrical submersible pump 118 is located within the second well 110A and is electrically connected to a power source 404 above the surface 406 via a power cable 408. The electrical submersible pump 118 increases the storage capacity of the first underground storage reservoir 106 by transferring a fluid 120 from the first underground storage reservoir 106 to the second underground storage reservoir 116. In this non-limiting example, the electrical submersible pump 118 is inverted, and is locatedin the second well 110A near the first perforations 112 within the first underground storage reservoir 106 or the second perforations 114 within the second underground reservoir 116. A seal 122, such as a packer, is installed between a casing 124 of the second well 110 and a tubing 126 of the second well 110A below the electrical submersible pump 118 to make sure that the fluid 120 goes into the second underground storage reservoir 116 and does not go back up to the first underground storage reservoir 106.

[0033] Now referring to FIG. 4B, a non-limiting example of a second well HOB, or transfer well, in accordance with one embodiment of the present disclosure is shown. The second well HOB has first perforations 112 within the first underground storage reservoir 106 and second perforations 114 within a second underground storage reservoir 116. The first underground storage reservoir 106 is located below and separated from the second underground storage reservoir 116 by a low permeability formation 402. An electrical submersible pump 118 is located within the second well 110B and is electrically connected to a power source 404 above the surface 406 via a power cable 408. The electrical submersible pump 118 increases the storage capacity of the first underground storage reservoir 106 by transferring a fluid 120 from the first underground storage reservoir 106 to the second underground storage reservoir 116. In this non-limiting example, the electrical submersible pump 118 is located in the second well 110B near the first perforations 112 within the first underground storage reservoir 106 or the second perforations 114 within the second underground reservoir 116. Seals 122, such as packers, are installed between a casing 124 of the second well 110B and a tubing 126 of the second well 110B above the electrical submersible pump 118 to make sure that the fluid 120 goes into the second underground storage reservoir 116 and does not go back down to the first underground storage reservoir 106, and above the second perforations 114 and second underground storage reservoir 116 to prevent fluid 120 from going up to the surface 406 as well as making sure the fluid 120 flows into the second underground reservoir 116.

[0034] It is understood that particular embodiments described herein are shown by way of illustration and not as limitations of the invention. The principal features of this invention can be employed in various embodiments without departing from the scope of the invention. Those skilled in the art will recognize or be able to ascertain using no more than routine experimentation, numerous equivalents to the specific procedures described herein. Such equivalents are considered to be within the scope of this invention and are covered by the claims.

[0035] All publications and patent applications mentioned in the specification are indicative of the level of skill of those skilled in the art to which this invention pertains. Allpublications and patent applications are herein incorporated by reference to the same extent as if each individual publication or patent application was specifically and individually indicated to be incorporated by reference.

[0036] The use of the word “a” or “an” when used in conjunction with the term “comprising” in the claims and / or the specification may mean “one,” but it is also consistent with the meaning of “one or more,” “at least one,” and “one or more than one.” The use of the term “or” in the claims is used to mean “and / or” unless explicitly indicated to refer to alternatives only or the alternatives are mutually exclusive, although the disclosure supports a definition that refers to only alternatives and “and / or.” Throughout this application, the term “about” is used to indicate that a value includes the inherent variation of error for the device, the method being employed to determine the value, or the variation that exists among the study subjects.

[0037] As used in this specification and claim(s), the words “comprising” (and any form of comprising, such as “comprise” and “comprises”), “having” (and any form of having, such as “have” and “has”), “including” (and any form of including, such as “includes” and “include”) or “containing” (and any form of containing, such as “contains” and “contain”) are inclusive or open-ended and do not exclude additional, unrecited features, elements, components, groups, integers, and / or steps, but do not exclude the presence of other unstated features, elements, components, groups, integers and / or steps. In embodiments of any of the compositions and methods provided herein, “comprising” may be replaced with “consisting essentially of’ or “consisting of’. As used herein, the term “consisting” is used to indicate the presence of the recited integer (e.g., a feature, an element, a characteristic, a property, a method / process step or a limitation) or group of integers (e.g., feature(s), element(s), characteristic(s), property(ies), method / process steps or limitation(s)) only. As used herein, the phrase “consisting essentially of’ requires the specified features, elements, components, groups, integers, and / or steps, but do not exclude the presence of other unstated features, elements, components, groups, integers and / or steps as well as those that do not materially affect the basic and novel characteristic(s) and / or function of the claimed invention.

[0038] The term “or combinations thereof’ as used herein refers to all permutations and combinations of the listed items preceding the term. For example, “A, B, C, or combinations thereof’ is intended to include at least one of: A, B, C, AB, AC, BC, or ABC, and if order is important in a particular context, also BA, CA, CB, CBA, BCA, ACB, BAC, or CAB. Continuing with this example, expressly included are combinations that contain repeats of one or more item or term, such as BB, AAA, AB, BBC, AAABCCCC, CBB AAA, CAB ABB, andso forth. The skilled artisan will understand that typically there is no limit on the number of items or terms in any combination, unless otherwise apparent from the context.

[0039] As used herein, words of approximation such as, without limitation, “about”, “substantial” or “substantially” refers to a condition that when so modified is understood to not necessarily be absolute or perfect but would be considered close enough to those of ordinary skill in the art to warrant designating the condition as being present. The extent to which the description may vary will depend on how great a change can be instituted and still have one of ordinary skill in the art recognize the modified feature as still having the required characteristics and capabilities of the unmodified feature. In general, but subject to the preceding discussion, a numerical value herein that is modified by a word of approximation such as “about” may vary from the stated value by at least ±1, 2, 3, 4, 5, 6, 7, 10, 12 or 15%.

[0040] All of the compositions and / or methods disclosed and claimed herein can be made and executed without undue experimentation in light of the present disclosure. While the compositions and methods of this invention have been described in terms of preferred embodiments, it will be apparent to those of skill in the art that variations may be applied to the compositions and / or methods and in the steps or in the sequence of steps of the method described herein without departing from the concept, spirit and scope of the invention. All such similar substitutes and modifications apparent to those skilled in the art are deemed to be within the spirit, scope and concept of the invention as defined by the appended claims.

[0041] To aid the Patent Office, and any readers of any patent issued on this application in interpreting the claims appended hereto, applicants wish to note that they do not intend any of the appended claims to invoke paragraph 6 of 35 U.S.C. § 112, U.S.C. § 112 paragraph (f), or equivalent, as it exists on the date of filing hereof unless the words “means for” or “step for” are explicitly used in the particular claim.

[0042] For each of the claims, each dependent claim can depend both from the independent claim and from each of the prior dependent claims for each and every claim so long as the prior claim provides a proper antecedent basis for a claim term or element.

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Claims

CLAIMSWhat is claimed is:

1. A system for increasing a storage capacity of a first underground storage reservoir comprising: a first well having perforations within the first underground storage reservoir, wherein the first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir; a second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir; and an electrical submersible pump located within the second well, wherein the electrical submersible pump increases the storage capacity of the first underground storage reservoir by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir.

2. The system of claim 1, wherein the gas, liquefied gas or supercritical fluid comprises CO2 and the fluid comprises brine.

3. The system of claim 1, wherein transferring the fluid from the first underground storage reservoir to the second underground storage reservoir also decreases an area of review associated with the first well.

4. The system of claim 1, wherein: the first underground storage reservoir comprises a saline aquifer or a depleted petroleum reservoir; and the second underground storage reservoir comprises a porous basin or layer.

5. The system of claim 1, wherein the second storage reservoir is not a producing petroleum reservoir.

6. The system of claim 1, wherein: the first underground storage reservoir is located above the second underground storage reservoir; and the electrical submersible pump is inverted.

7. The system of claim 1 , wherein the first underground storage reservoir is located below the second underground storage reservoir.

8. The system of claim 1, wherein the electrical submersible pump is located in the second well near the first perforations or the second perforations.

9. The system of claim 1, further comprising a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

10. The system of claim 1, wherein: the first well comprises two or more first wells; or the second well comprises two or more second wells.

11. A method for increasing a storage capacity of a first underground storage reservoir comprising: providing a first well having perforations within the first underground storage reservoir, wherein the first well is configured to inject a gas, liquefied gas or supercritical fluid into the first underground storage reservoir; providing a second well having first perforations within the first underground storage reservoir and second perforations within a second underground storage reservoir; and increasing the storage capacity of the first underground storage reservoir by transferring a fluid from the first underground storage reservoir to the second underground storage reservoir using an electrical submersible pump located within the second well.

12. The method of claim 11, wherein the gas, liquefied gas or supercritical fluid comprises CO2 and the fluid comprises brine.

13. The method of claim 11, wherein transferring the fluid from the first underground storage reservoir to the second underground storage reservoir also decreases an area of review associated with the first well.

14. The method of claim 11, wherein: the first underground storage reservoir comprises a saline aquifer or a depleted petroleum reservoir; and the second underground storage reservoir comprises a porous basin or layer.

15. The method of claim 11 wherein the second storage reservoir is not a producing petroleum reservoir.

16. The method of claim 11, wherein: the first underground storage reservoir is located above the second underground storage reservoir; and the electrical submersible pump is inverted.

17. The method of claim 11, wherein the first underground storage reservoir is located below the second underground storage reservoir.

18. The method of claim 11, wherein the electrical submersible pump is located in the second well near to the first perforations or the second perforations.

19. The method of claim 11, further comprising installing the electrical submersible pump within the second well near the first perforations or the second perforations.

20. The method of claim 11, further comprising installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

21. The method of claim 11, further comprising injecting the gas, liquefied gas or supercritical fluid into the first underground storage reservoir using the first well.

22. The method of claim 11, wherein providing the second well having first perforations within the first underground storage reservoir and second perforations within the second underground storage reservoir comprises: drilling and completing the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir;installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

23. The method of claim 11, wherein providing the second well having first perforations within the first underground storage reservoir and second perforations within the second underground storage reservoir comprises: converting an existing well into the second well having the first perforations within the first underground storage reservoir and the second perforations within the second underground storage reservoir; installing the electrical submersible pump within the second well near the first perforations or the second perforations; and installing a seal between a casing of the second well and a tubing of the second well above the electrical submersible pump, or below the electrical submersible pump, or both above and below the electrical submersible pump.

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