US3882937A - Method and apparatus for refrigerating wells by gas expansion - Google Patents
Method and apparatus for refrigerating wells by gas expansion Download PDFInfo
- Publication number
- US3882937A US3882937A US393892A US39389273A US3882937A US 3882937 A US3882937 A US 3882937A US 393892 A US393892 A US 393892A US 39389273 A US39389273 A US 39389273A US 3882937 A US3882937 A US 3882937A
- Authority
- US
- United States
- Prior art keywords
- gas
- casing
- permafrost
- refrigeration chamber
- high pressure
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Lifetime
Links
- 238000000034 method Methods 0.000 title claims description 20
- 238000005057 refrigeration Methods 0.000 claims abstract description 88
- 239000012530 fluid Substances 0.000 claims abstract description 78
- 238000004519 manufacturing process Methods 0.000 claims description 59
- 239000003208 petroleum Substances 0.000 claims description 23
- 238000002844 melting Methods 0.000 claims description 14
- 230000008018 melting Effects 0.000 claims description 14
- 239000004020 conductor Substances 0.000 claims description 11
- 238000007789 sealing Methods 0.000 claims description 6
- 238000004891 communication Methods 0.000 claims description 4
- 238000007599 discharging Methods 0.000 claims description 4
- 230000000149 penetrating effect Effects 0.000 claims description 2
- 238000012546 transfer Methods 0.000 claims description 2
- 239000003507 refrigerant Substances 0.000 abstract description 26
- 238000010257 thawing Methods 0.000 abstract description 12
- 239000007789 gas Substances 0.000 description 164
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 12
- 229910001868 water Inorganic materials 0.000 description 12
- 238000001816 cooling Methods 0.000 description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 6
- 238000009413 insulation Methods 0.000 description 6
- 239000004568 cement Substances 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- 238000005755 formation reaction Methods 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 4
- 150000002430 hydrocarbons Chemical class 0.000 description 4
- 239000000203 mixture Substances 0.000 description 4
- 238000013461 design Methods 0.000 description 3
- 238000005553 drilling Methods 0.000 description 3
- 238000007710 freezing Methods 0.000 description 3
- 230000008014 freezing Effects 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 238000009434 installation Methods 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 2
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000004907 flux Effects 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- 150000004677 hydrates Chemical class 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000003921 oil Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
- 241000196324 Embryophyta Species 0.000 description 1
- 244000187656 Eucalyptus cornuta Species 0.000 description 1
- 241001387976 Pera Species 0.000 description 1
- 229920005830 Polyurethane Foam Polymers 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 239000002274 desiccant Substances 0.000 description 1
- 239000002283 diesel fuel Substances 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 238000011221 initial treatment Methods 0.000 description 1
- 239000011810 insulating material Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- VUZPPFZMUPKLLV-UHFFFAOYSA-N methane;hydrate Chemical compound C.O VUZPPFZMUPKLLV-UHFFFAOYSA-N 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 239000011496 polyurethane foam Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 239000001294 propane Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000002441 reversible effect Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 230000001932 seasonal effect Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/001—Cooling arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/003—Insulating arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/38—Arrangements for separating materials produced by the well in the well
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S166/00—Wells
- Y10S166/901—Wells in frozen terrain
Definitions
- PATENTEB MAY 1 3 i875 SHEE? 20$ 2 METHOD AND APPARATUS FOR REFRIGERATING WELLS BY GAS EXPANSION
- This invention relates to wells for recovering earth fluids, and more particularly to wells for transporting hot fluids through a permafrost zone.
- Permafrost is perennially frozen ground found in the Arctic regions.
- the permafrost zone contains some layers of gravel free of ice known as dry permafrost, but the bulk of the zone is composed of rocks or of unconsolidated aggregates of sand, silt and gravel in which the interstitial water is frozen to ice.
- Permafrost is formed by cooling from the surface during the Arctic winters, particularly in regions of low snow fall. Cooling of the upper earth strata to below freezing temperatures to form permafrost continues until an equilibrium is reached with the heat flow from the earths interior. There is seasonal thawing and freezing at the surface, but thawing rarely penetrates more than 18 inches where the permafrost is protected by tundra or vegetation.
- the permafrost zone consists of frozen earth, the bulk of which remains permanently frozen unless some external source of heat is introduced that alters the temperature equilibrium.
- the thickness of the permafrost zone varies with latitude and with the particular geographic location
- Permafrost generally has sufficient strength to support oil exploration and recovery operations, so long as it remains frozen. However, when melted, unconsolidated permafrost shrinks and subsides causing a downdrag force on well casings passing through the permafrost zone. Drilling operations can generally be conducted without causing any substantial melting of the permafrost. However, melting of the permafrost is experienced around wells conducting hot fluids through the permafrost zones, and this melting must be prevented or retarded sufficiently so that subsidence does not occur during the life of the well.
- Heat loss from a hot fluid transported through the permafrost can be substantially reduced by insulating the conduit carrying the hot fluid.
- insulation alone reduces heat loss to the permafrost sufficiently to avoid melting the permafrost.
- insulation alone is generally not sufficient where the heat loss is relatively high or where the permafrost is initially relatively warm, i.e., where the permafrost is at a temperature only slightly below the freezing point of water.
- Various mechanical means such as slip joint casing and the like, which would not be damaged by subsidence, have been proposed for use in transporting hot fluids through permafrost.
- such devices are expensive to construct and install, and are not yet reliable.
- Another object of the invention is to provide a method for preventing thawing of the permafrost adjacent to a well transporting hot fluid through a permafrost zone.
- Still another object of the invention is to provide a method for producing hot oil from a reservoir underlying a permafrost zone that prevents thawing of the permafrost surrounding the well.
- a further object of the invention is to provide a method for injecting hot fluids into an earth formation underlying a permafrost zone without thawing the permafrost surrounding the injection well.
- a still further object of the invention is to provide an improved method for operating a refrigerated well conducting hot fluids through a permafrost zone.
- An even further object is to provide a refrigerated well for transporting hot fluids through a permafrost zone.
- this invention concerns a method and apparatus for preventing thawing of the permafrost around a well transporting hot fluids through a permafrost zone. Thawing is prevented by expanding a gas into a well annulus extending through a substantial part of the permafrost.
- the refrigerant gas can be a portion of the produced gas separated from the produced fluids at the surface or in a downhole separator.
- FIG. 1 is a schematic vertical sectional view illustrating one embodiment of the well assembly of this invention installed in a permafrost zone;
- FIG. 2 isan enlarged schematic vertical sectional view of another embodiment of the. invention employing a downhole gas separator installed in a permafrost zone.
- FIG. 1 of the drawings there is illustrated a well completed in an earth formation comprised of an upper permanently frozen permafrost zone 10 and'a lower earth strata 12 that overlies a petroleum reservoir, not shown.
- the well is comprised of surface conductor 14 cemented in the upper strata of permafrost zone 10 with cement 16.
- Surface conductor 14 is run to eliminate the possibility of a wash out or severe melting around the cellar area directly adjacent to the well bore.
- surface conductor 14 is comprised of a length of relatively large diameter pipe, such as a 30-inch diameter casing, 20 to feet in length, and preferably about 40 feet in length.
- Casing 20 is set in permafrost 10 to the depth at which refrigeration of the well is to be maintained and is cemented to the surface by means of cement 22.
- the permafrost surrounding casing 20 is maintained permanently frozen over substantially its entire length to provide the necessary support for the well.
- casing 20 extends to a depth of about 200 to 700 feet, and most typically to a depth of about 300 feet, and can extend completely through the permafrost, if desired. Maintaining the permafrost frozen to a depth of at least about 200 feet should provide adequate support for the well, and any thawing below this point is considered harmless.
- the diameter and weight of casing employed in this string will depend upon the targeted drilling depth, the types of formations traversed, and the total number of casing strings to be run; in a typical installation for many wells, casing is a 20-inch diameter casing.
- Surface casing 24 is the primary pressure string and provides an anchor for blowout preventer equipment, and is run deep enough for protection of fresh-water sands and deep enough to extend through the entire permafrost section.
- Casing 24 is cemented back to the bottom of casing 20 with cement 26 which forms a sheath surrounding casing 24. While the use of casing 24 is optional unless required by a regulatory authority, and may be omitted where the well can be drilled from the bottom of the permafrost through the producing in terval without intermediate casing, in most instances it is preferred to employ a surface casing terminating shortly below the bottom of the permafrost. Also, additional intermediate strings of casing may be installed where necessitated by conditions encountered in the drilling operation.
- Production casing 28 extends from the surface to the producing strata and is cemented back to the bottom of casing 24, or alternatively, if casing 24 is omitted, to the bottom of casing 20, with cement 30 which forms a sheath surrounding casing 28.
- the well is completed in conventional manner by extending casing 28 through the productive zones and perforating at selected intervals, or by terminating the casing above the productive zone and hanging a preslotted or pre-perforated liner in these zones.
- Production tubing 32 conveys produced fluids from the producing zone to the surface, or flow from the surface to the producing zones in the case of an injection well.
- Insulation 34 can be any type of thermal insulating material, such as polyurethane foam and the like, that is suitable for installation in a well. Insulation 34 extends at least the length of casing 20, and preferably extends from the surface to the bottom of permafrost zone 10.
- FIG. 1 illustrates the practice of the invention in conjunction with a producing well.
- produced fluids consisting of a mixture of oil, gas and water flow from tubing 32 through valve and conduit 52 to field separator 54.
- High pressure gas is separated from the fluid mixture and withdrawn through conduit 56, produced oil is withdrawn through conduit 58, and water is produced through conduit 60.
- This production equipment can receive the production of a single well, or the produced fluids from a number of wells can be combined and processed.
- the annulus between surface casing 24 and production casing 28 can be filled with gelled diesel oil, or similar packing fluid, in conventional manner.
- the annulus between casing 20 and surface casing 24 is closed at the bottom by cement 26, or by a mechanical packer, not shown, to provide a closed refrigeration chamber 62 surrounding surface casing 24 and extending from the surface to a substantial depth in permafrost zone 10.
- the well is refrigerated over the length of annular chamber 62 by expanding high pressure gas into the chamber in an amount sufficient to maintain the temperature in the chamber below the melting temperature of the surrounding permafrost. Fail safe pressure control and/or over pressure safety devices, not shown, must be provided to assure that the casing strings forming annulus 62 will not be subjected to excessive pressure.
- the high pressure refrigerant gas from separator 54 is conducted through conduit 64 and introduced into the well through valve 66 and small diameter tubing 68 which extends to the bottom of annular chamber 62 and terminates in expansion nozzle 70.
- High pressure refrigerant gas is expanded into chamber 62 and the expanded and cooled gas flows upwardly through annular chamber 62 around the exterior of casing 24.
- Low pressure gas is exhausted from refrigeration chamber 62 through valve 72 communicating with low pressure gas conduit 74.
- the well can be fitted with a temperature measuring instrument 76, such as a thermometer or temperature recorder, responsive to a temperature detecting element 78 extending into refrigeration chamber 62.
- FIG. 1 The embodiment of the invention illustrated in FIG. 1 can be employed to refrigerate either producing wells or injection wells penetrating a permafrost zone, the only requirement being that a suitable supply of refrigerant gas is available for expansion in the refrigeration chamber of the well.
- a downhole separator is employed to separate high pressure gas from the produced fluids to provide a source of refrigerant gas.
- the high pressure gas is conducted to the gas expansion nozzle and discharged into the annular refrigerant chamber to effect cooling of the refrigerant gas to a temperature below the permafrost temperature.
- gas separator 80 is installed in production tubing 32 and positioned adjacent to the bottom of'annular refrigerant chamber 62.
- Packers 82 and 84 are set in the annulus between tubing 32 and production casing 28, above and below separator 80, respectively, so as to define a closed annular chamber 86.
- Packers and 92 are set in the annulus between production casing 28 and surface casing 24, above and below separator 80, respectively, so as to define closed annular chamber 94.
- Apertures 96 in the production casing communicate chambers 86 and 94, and nozzles 70 are mounted on conduits 98 which connect the inlets of the nozzles to chamber 94.
- Separator 80 is comprised of a closed cylindrical member 100 having a lower inlet connection and an upper outlet connection adapted for mounting between joints of tubing 32.
- An internal standpipe 102 extends upwardly from the inlet into cylindrical member 100, and inverted cap 104 is mounted above standpipe 102 so as to extend downwardly around the open end of the standpipe.
- Inverted cup-shaped diverter 106 is mounted immediately above the open end of standpipe 102 by a suitable mounting bracket, not shown, and apertured baffle plate 108 is provided within cap 104 to define upper gas chamber 110.
- Float-type valve 112 is mounted in gas chamber 110 and connected to the exterior of cylindrical member 100 by conduit 114. Valve 112 closes upon the raise of liquid to a level above the valve, thereby preventing the discharge of liquid through the gas conduit.
- produced fluids passing upwardly through production tubing 32 are introduced into separator 80 through inlet standpipe 102.
- a portion of the gas contained in the produced fluids is disengaged and flowed around diverter 106 and through the aperture in baffle 108 into upper gas chamber 110.
- the liquid portion of the produced fluid and the remainder of the gas flows around the bottom lip of cup 104 and upwardly through the annular passage between cylindrical member 100 and cup 104.
- the disengaged gas exits chamber 110 and through valve 112 and conduit 114 and passes into annular chamber 86. This gas flows from chamber 86 through apertures 96 and into chamber 94, from where it is subsequently discharged through conduits 98 and gas expansion nozzles 70 into annular refrigeration chamber 62.
- the temperature of the expanded gas discharged into refrigeration chamber 62 is affected by the temperature and pressure of the high pressure gas supplied to the nozzle, the rate of gas flow through the nozzle, the pressure in refrigeration chamber 62 at the exit of the nozzle, the composition of the refrigerant gas, the nozzle efficiency, the temperature of the permafrost, and the rate of heat flow from the hot oil.
- the amount of gas expanded into refrigeration chamber must be sufficient to prevent refrigerant gas from being warmed in refrigeration chamber 62 to a temperature above the melting point of the permafrost, i.e., the refrigerant gas exiting the refrigeration chamber should be at a temperature below about 32 F.
- the refrigerant gas can be any of a wide variety of gases that cool upon expansion, such as air, nitrogen, oxygen, or mixtures of these gases; as a practical matter, it is most advantageous to employ produced gas as the refrigerant gas.
- Produced gas consists primarily of methane, and contains lesser amounts of ethane, propane, and higher molecular weight hydrocarbons. It also can contain varying amounts of hydrogen sulfide, carbon dioxide, water, and minor amounts of other impurities. This gas can be used directly as produced in the field or after processing through gas absorption plants for the removal of various of the high molecular weight hydrocarbons and other constituents to produce a pipeline grade natural gas.
- the produced field gas, or natural gas, employed in the well refrigeration technique of this invention generally exhibit specific gravities between about 0.60 and 1.0, and most typically between about 0.65 and 0.80.
- water content of the gas be maintained below that amount that will condense to form liquid water.
- the water content of a produced gas can be reduced by contacting the gas with ethylene glycol or other desiccant material that preferentially absorbs water from the gas. The dry gas having a reduced water content can then be employed to refrigerate the well.
- the high pressure gas employed as the refrigerant gas must be available at a pressure sufficiently high that the 6 requisite cooling can be obtained by expansion of the gas.
- the gas must be available at a pressure of at least about 200 psig, and preferably at a pressure of about 400 to 800 psig
- the temperature of the high pressure gas is usually between about 50 F. and 150 F.
- the low pressure gas exhausted from the refrigeration chamber is collected and employed as a boiler or internal combustion engine fuel, or for other uses, or the low pressure gas can be recompressed for pipeline delivery. Also, where the produced gas available in a particular field is not sufficient to provide the necessary refrigeration, it is within the scope of this invention to recompress the low pressure gas and recycle this gas through the expansion nozzle.
- the pressure to which the refrigerant gas is expanded and the utilization of the refrigerant gas in any particular oil field will depend upon the availability of produced gas in that field, the utilization of the low pressure gas, and the particular economics involved. In typical applications, the refrigerant gas will be expanded to a pressure of about 100 to 300 psig, although this pressure will depend upon the particular circumstances of each application.
- nozzle can be any gas expansion nozzle
- the amount of cooling obtained and the efficiency of the process is dependent upon the design of the nozzle.
- Maximum cooling is obtained when the gas passing through the nozzle expands isentropically, i.e., expands by a reversible process at constant entropy. This is an idealized condition that cannot be attained in practice.
- the efficiency of a nozzle can be characterized by the nozzle coefficient nn, which is defined as V (actual) v, (ideal) in which V ,(actual) is the actual gas velocity attained in the nozzle and V (ideal) is the ideal velocity theoretically attained by a gas isentropically expanding through the nozzle.
- V (actual) v, (ideal) in which V ,(actual) is the actual gas velocity attained in the nozzle and V (ideal) is the ideal velocity theoretically attained by a gas isentropically expanding through the nozzle.
- substantially isentropic as used herein is meant to define a gas expansion through a nozzle having a nozzle coefficient of 0.95 or higher, and more preferably 0.98 or higher.
- the nozzle design and operating conditions must be selected so that the expanded refrigerant gas is introduced into the refrigeration chamber at a temperature sufficiently below the melting temperature of the permafrostthat the gas does not warm to a temperature above the melting temperature during passage through the refrigeration chamber.
- the amount of the refrigerant gas expanded into the refrigeration chamber will depend upon the magnitude of the heat flux from the hot fluid flowing through the tubing string. in a typical well having a well insulated tubing string, the heat flux is generally about 10 to 30 BTU/Hr per foot of well. Depending upon the particular conditions encountered, this amount of heat can be removed by expanding about 900 to 1,800 pounds per hour of refrigerant gas into the refrigeration chamber.
- the refrigeration obtained with any particular system can be controlled by adjusting either the inlet pressure of the gas supplied to the nozzle, the exhaust pressure in the refrigeration chamber, or both of these pressures.
- An increase in inlet pressure and a decrease in exhaust pressure result in additional cooling, with an opposite effect being obtained by a reduction in inlet pressure or an increase in the exhaust pressure.
- EXAMPLE 1 This example illustrates the application of the well refrigeration method of this invention to a producing well completed in a petroleum reservoir underlying a frozen permafrost zone approximately 2,000 feet thick.
- the well is completed substantially as illustrated in FIG. 1, with refrigeration chamber 62 extending from the surface to a depth of approximately 300 feet.
- Fluids are produced from the underlying reservoir at a temperature of 125 F. and transported to the surface.
- Primary treatment includes separation of the gas, oil and water phases.
- High pressure gas is produced from the separator at 125 F. and 485 psig. This gas consists primarily of methane and contains ethane and other light hydrocarbons, and exhibits a specific gravity of 0.70.
- Refrigeration of the well is accomplished by recycling a portion of the produced high pressure gas to the well and substantially isentropically expanding this gas into the refrigeration chamber through a single gas expansion nozzle having a nozzle efficiency of 0.98.
- the refrigerant gas is dried by contact with ethylene glycol prior to recycle to the well to avoid the formation of hydrates in the refrigeration chamber.
- Approximately 500 MSCF/D of the high pressure gas at 125 F. and 485 psig is expanded to 185 psig in the refrigeration chamber to provide cooling for the well.
- the expanded gas exits the expansion nozzle at a temperature of 20 F., and is warmed to about 30 F. during its passage through the refrigeration chamber.
- the refrigerant gas removes sufficient heat from the well to prevent thawing of the permafrost adjacent to the well.
- EXAMPLE 2 This example illustrates another embodiment of the invention in which the well is cooled by expanding a high pressure refrigerant gas separated from the produced fluids in a downhole separator located 300 feet below the surface. Approximately 500 MSCF/D of gas is separated from the produced fluids at a temperature of 125 F. and a pressure of 485 psig. This gas is expanded, without drying, into the refrigeration chamber of a well completed substantially as illustrated in FIG. 2. The refrigerant is cooled to a temperature of about 20 F. on expanding to a pressure of 175 psig., and is warmed about F. on passage through the refrigeration zone. The pressure in the refrigeration chamber is controlled to maintain the temperature of the gas exiting the refrigeration chamber below about 32 F.
- a refrigerated well extending from the surface to an underlying petroleum reservoir for conducting hot fluids through a permafrost zone, which comprises:
- a closed annular refrigeration chamber defined by inner and outer concentric casings extending a substantial distance into said permafrost zone, said refrigeration chamber lying between said hot fluids conducted through said well and said permafrost;
- At least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber;
- gas conduit means to conduct high pressure gas from a source of high pressure gas to said gas expansion nozzle; and Y means for exhausting low pressure gas from said refrigeration chamber;
- annular refrigeration chamber has a length of about 200 to 700 feet.
- the apparatus defined in claim 1 including a gas separator located at the surface to separate high pressure gas from fluids produced from said underlying petroleum reservoir, wherein said gas conduit means conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle.
- the apparatus defined in claim 1 including a downhole gas separator in fluid communication with said production tubing to separate high pressure gas from fluids produced from said underlying petroleum reservoir, said separator being located adjacent to the bottom of said refrigeration chamber, and wherein said gas conduit means conducts high pressure gas from said gas separator to said gas expansion nozzle.
- a refrigerated well for conducting hot fluids through a permafrost zone which comprises:
- sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber
- At least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber;
- gas conduit means to conduct high pressure gas' from a source of high pressure gas to' said gasexp'a'nsion nozzle;
- the apparatus defined in claim 6 including a gas separator located at the surface separate high pressure gas from fluids produced from said underlying producing strata, wherein said gas conduit means 'conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle.
- a refrigerated well for conducting hot fluids through a permafrost zone which comprises:
- a first casing placed concentrically within said sur-* face conductor and extending about 200 to 700 feet into said permafrost zone, said first casing being cemented to the surface;
- sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber
- a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing;
- a production tubing within said production casing to convey fluids from an underlying petroleum reservoir to the surface, or vice versa, said tubing being insulated through said permafrost zone;
- At least one gas expansion nozzle located with said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber;
- a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing;
- a production tubing within said production casing to convey fluids from said underlying petroleum reservoir to the surface, said tubing being insulated through the permafrost zone;
- a downhole gas separator in said production casing adjacent to the bottom of said refrigeration chamber to receive produced fluids flowing upwardly through said production tubing, disengage a portion of the gas from said produced fluids, and discharge the residual produced fluids up said production tubing;
- At least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber;
- gas conduit means to conduct gas from said downhole gas separator to said gas expansion nozzle; and means to exhaust low pressure gas from said refrigeration chamber.
- said gas conduit means includes (1) first and second packers set in the annulus between said production tubing and said production casing, above and below said downhole gas separator, respectively, to define an enclosed annular first chamber; (2) third and fourth packers set in the annulus between said production casing and said second casing to define an enclosed second annular chamber surrounding said first annular chamber; (3) an aperture in said production casing communicating said first and second annular chambers; and (4) a conduit communicating said second annular chamber to the inlet of said gas expansion nozzle.
- said downhole separator includes (1) an outer cylindrical shell having an inlet at its bottom and an outlet at its top for connection, respectively, to said production tubing; (2) an internal standpipe extending above said inlet; (3) an inverted cap extending downwardly below the lip of said standpipe; (4) an inverted cup-shaped diverter supported immediately above said standpipe; (5) an apertured baffle separating said cap into a lower section and an upper gas chamber; and (6) a float-type valve in said gas chamber having an outlet connected to the exterior of said cylindrical shell.
- a method for conducting hot fluids through a well traversing a permafrost zone without melting the permafrost surrounding the well which comprises:
Abstract
Thawing of the permafrost around a well transporting hot fluids through a permafrost zone is prevented by refrigerating a section of the well to prevent the flow of heat from the well to the surrounding permafrost. Refrigeration is provided by expanding gas into a well annulus extending through a substantial part of the permafrost. The refrigerant gas can be a portion of the produced gas separated from the produced fluids at the surface or in a downhole separator.
Description
United States Patent 11 1 Robinson 1451 May 13,1975
[ METHOD AND APPARATUS FOR REFRIGERATING WELLS BY GAS EXPANSION [75] Inventor: Joel P. Robinson, Los Angeles,
Calif.
[73] Assignee: Union Oil Company of California,
Brea. Calif.
[22] Filed: Sept. 4, 1973 [21] Appl. No.: 393,892
[52] US. Cl. 166/267; 61/36 A; 62/260;
l66/DlG. l; 166/57; 165/45 [51] Int. Cl E2lb 43/24; E2lb 43/00 [58] Field of Search 61/5, 36 A; 62/260;
3,581,513 6/1971 Cranmer et al 61/.5 3,662,832 5/1972 Keeler et a1. 166/57 3.674.086 7/1972 Foster 166/4'5 3,735,769 5/1973 Miller 137/13 $138,424 6/1973 Osmun et 211.. 166/57 3.763.935 10/1973 Perkins 166/57 3.766985 10/1973 Willhite 166/302 3,774,701 11/1973 Weaver 175/17 3,777,502 Mich1e et a1 62/55 Primary Examiner-Ernest R. Purser Assistant Examiner-Jack E. Ebel Attorney, Agent, or Firm-Dean Sandford; Richard C. Hartman; Lannas S. Henderson 571 ABSTRACT Thawing of the permafrost around a well transporting hot fluids through a permafrost zone is prevented by refrigerating asection of the well to prevent the flow of heat from the well to the surrounding permafrost.
[ 1 References Cied Refrigeration is provided by expanding gas into a well UNITED STATES PATENTS annulus extending through a substantial part of the 1,798,774 3/1931 Yates 166/167 Permafrost The refrigerant gas can be a Portion Of the 2,033,560 3/1936 Wells 166/57 produced gas separated from the produced fluids at 2,753,700 7/1956 Morrison 62/260 the surface or in a downhole separator. 2,772,737 12/1956 Bond et al. 166/57 3,564,862 2 1971 Hashemi et al. 61/36 A 19 Clalms 2 Drawlng Figures H/GH PRESSURE 5a 7% 42 4a 52 58 41 52 2'2 2 L 69 :a r n- 0/2 y F an pleas. M fiw AKV A Q? Y A '-..Y/
PERA tat/R057 ZO/VE saw 1 0:
PRMAFR057 nub m. ..I .v
I. I In b.
PATENTEB MAY 1 3 i875 SHEE? 20$ 2 METHOD AND APPARATUS FOR REFRIGERATING WELLS BY GAS EXPANSION This invention relates to wells for recovering earth fluids, and more particularly to wells for transporting hot fluids through a permafrost zone.
Permafrost is perennially frozen ground found in the Arctic regions. The permafrost zone contains some layers of gravel free of ice known as dry permafrost, but the bulk of the zone is composed of rocks or of unconsolidated aggregates of sand, silt and gravel in which the interstitial water is frozen to ice. Permafrost is formed by cooling from the surface during the Arctic winters, particularly in regions of low snow fall. Cooling of the upper earth strata to below freezing temperatures to form permafrost continues until an equilibrium is reached with the heat flow from the earths interior. There is seasonal thawing and freezing at the surface, but thawing rarely penetrates more than 18 inches where the permafrost is protected by tundra or vegetation. Thus, the permafrost zone consists of frozen earth, the bulk of which remains permanently frozen unless some external source of heat is introduced that alters the temperature equilibrium. The thickness of the permafrost zone varies with latitude and with the particular geographic location.
Permafrost generally has sufficient strength to support oil exploration and recovery operations, so long as it remains frozen. However, when melted, unconsolidated permafrost shrinks and subsides causing a downdrag force on well casings passing through the permafrost zone. Drilling operations can generally be conducted without causing any substantial melting of the permafrost. However, melting of the permafrost is experienced around wells conducting hot fluids through the permafrost zones, and this melting must be prevented or retarded sufficiently so that subsidence does not occur during the life of the well.
Heat loss from a hot fluid transported through the permafrost can be substantially reduced by insulating the conduit carrying the hot fluid. In some cases, insulation alone reduces heat loss to the permafrost sufficiently to avoid melting the permafrost. However, insulation alone is generally not sufficient where the heat loss is relatively high or where the permafrost is initially relatively warm, i.e., where the permafrost is at a temperature only slightly below the freezing point of water. Various mechanical means such as slip joint casing and the like, which would not be damaged by subsidence, have been proposed for use in transporting hot fluids through permafrost. However, such devices are expensive to construct and install, and are not yet reliable. Mechanical refrigeration, usually in conjunction with insulation of the conduit carrying the hot fluid, can be employed to effectively prevent heat loss from the well to the surrounding permafrost. Although various methods of refrigerating the well have been proposed which are effective in preventing melting of the permafrost, mechanical refrigeration equipment is expensive to install and operate, requires a source of power at the well site, and requires at least the periodic attention of an operator. Thus, need exists for a simpler and less costly method for refrigerating wells traversing a permafrost zone.
Accordingly, it is a principal object of this invention to provide a simple, low cost method for conducting hot fluids through a well traversing a permafrost zone that substantially prevents thawing of the permafrost around the well.
Another object of the invention is to provide a method for preventing thawing of the permafrost adjacent to a well transporting hot fluid through a permafrost zone.
Still another object of the invention is to provide a method for producing hot oil from a reservoir underlying a permafrost zone that prevents thawing of the permafrost surrounding the well.
A further object of the invention is to provide a method for injecting hot fluids into an earth formation underlying a permafrost zone without thawing the permafrost surrounding the injection well.
A still further object of the invention is to provide an improved method for operating a refrigerated well conducting hot fluids through a permafrost zone.
An even further object is to provide a refrigerated well for transporting hot fluids through a permafrost zone.
Other objects and advantages of the invention will be apparent from the following description.
In brief, this invention concerns a method and apparatus for preventing thawing of the permafrost around a well transporting hot fluids through a permafrost zone. Thawing is prevented by expanding a gas into a well annulus extending through a substantial part of the permafrost. The refrigerant gas can be a portion of the produced gas separated from the produced fluids at the surface or in a downhole separator.
The manner of accomplishing the foregoing objects as well as other objects and advantages of the invention will be apparent from the following description taken in conjunction with the drawings, wherein like numerals refer to corresponding parts, and in which:
FIG. 1 is a schematic vertical sectional view illustrating one embodiment of the well assembly of this invention installed in a permafrost zone; and
FIG. 2 isan enlarged schematic vertical sectional view of another embodiment of the. invention employing a downhole gas separator installed in a permafrost zone.
Referring specifically to FIG. 1 of the drawings, there is illustrated a well completed in an earth formation comprised of an upper permanently frozen permafrost zone 10 and'a lower earth strata 12 that overlies a petroleum reservoir, not shown. The well is comprised of surface conductor 14 cemented in the upper strata of permafrost zone 10 with cement 16. Surface conductor 14 is run to eliminate the possibility of a wash out or severe melting around the cellar area directly adjacent to the well bore. Typically, surface conductor 14 is comprised of a length of relatively large diameter pipe, such as a 30-inch diameter casing, 20 to feet in length, and preferably about 40 feet in length.
The well is fitted with a conventional well head including means to seal the annulus between tubing 32 and producing casing 28, means 42 to seal the annulus between production casing 28 and surface casing 24, and means 44 to seal the annulus between surface casing 24 and casing 20. FIG. 1 illustrates the practice of the invention in conjunction with a producing well. In the conventional operation of a producing oil well, produced fluids consisting of a mixture of oil, gas and water flow from tubing 32 through valve and conduit 52 to field separator 54. High pressure gas is separated from the fluid mixture and withdrawn through conduit 56, produced oil is withdrawn through conduit 58, and water is produced through conduit 60. This production equipment can receive the production of a single well, or the produced fluids from a number of wells can be combined and processed.
The annulus between surface casing 24 and production casing 28 can be filled with gelled diesel oil, or similar packing fluid, in conventional manner. The annulus between casing 20 and surface casing 24 is closed at the bottom by cement 26, or by a mechanical packer, not shown, to provide a closed refrigeration chamber 62 surrounding surface casing 24 and extending from the surface to a substantial depth in permafrost zone 10. The well is refrigerated over the length of annular chamber 62 by expanding high pressure gas into the chamber in an amount sufficient to maintain the temperature in the chamber below the melting temperature of the surrounding permafrost. Fail safe pressure control and/or over pressure safety devices, not shown, must be provided to assure that the casing strings forming annulus 62 will not be subjected to excessive pressure.
In the embodiment of the invention illustrated in FIG. 1, the high pressure refrigerant gas from separator 54 is conducted through conduit 64 and introduced into the well through valve 66 and small diameter tubing 68 which extends to the bottom of annular chamber 62 and terminates in expansion nozzle 70. High pressure refrigerant gas is expanded into chamber 62 and the expanded and cooled gas flows upwardly through annular chamber 62 around the exterior of casing 24. Low pressure gas is exhausted from refrigeration chamber 62 through valve 72 communicating with low pressure gas conduit 74. The well can be fitted with a temperature measuring instrument 76, such as a thermometer or temperature recorder, responsive to a temperature detecting element 78 extending into refrigeration chamber 62.
The embodiment of the invention illustrated in FIG. 1 can be employed to refrigerate either producing wells or injection wells penetrating a permafrost zone, the only requirement being that a suitable supply of refrigerant gas is available for expansion in the refrigeration chamber of the well.
In another embodiment of the invention applicable to producing wells, a downhole separator is employed to separate high pressure gas from the produced fluids to provide a source of refrigerant gas. The high pressure gas is conducted to the gas expansion nozzle and discharged into the annular refrigerant chamber to effect cooling of the refrigerant gas to a temperature below the permafrost temperature.
Downhole apparatus for separating gas from the produced fluids is illustrated in FIG. 2. In the illustrated embodiment, gas separator 80 is installed in production tubing 32 and positioned adjacent to the bottom of'annular refrigerant chamber 62. Packers 82 and 84 are set in the annulus between tubing 32 and production casing 28, above and below separator 80, respectively, so as to define a closed annular chamber 86. Packers and 92 are set in the annulus between production casing 28 and surface casing 24, above and below separator 80, respectively, so as to define closed annular chamber 94. Apertures 96 in the production casing communicate chambers 86 and 94, and nozzles 70 are mounted on conduits 98 which connect the inlets of the nozzles to chamber 94.
In operation, produced fluids passing upwardly through production tubing 32 are introduced into separator 80 through inlet standpipe 102. A portion of the gas contained in the produced fluids is disengaged and flowed around diverter 106 and through the aperture in baffle 108 into upper gas chamber 110. The liquid portion of the produced fluid and the remainder of the gas flows around the bottom lip of cup 104 and upwardly through the annular passage between cylindrical member 100 and cup 104. The disengaged gas exits chamber 110 and through valve 112 and conduit 114 and passes into annular chamber 86. This gas flows from chamber 86 through apertures 96 and into chamber 94, from where it is subsequently discharged through conduits 98 and gas expansion nozzles 70 into annular refrigeration chamber 62.
The temperature of the expanded gas discharged into refrigeration chamber 62 is affected by the temperature and pressure of the high pressure gas supplied to the nozzle, the rate of gas flow through the nozzle, the pressure in refrigeration chamber 62 at the exit of the nozzle, the composition of the refrigerant gas, the nozzle efficiency, the temperature of the permafrost, and the rate of heat flow from the hot oil. The amount of gas expanded into refrigeration chamber must be sufficient to prevent refrigerant gas from being warmed in refrigeration chamber 62 to a temperature above the melting point of the permafrost, i.e., the refrigerant gas exiting the refrigeration chamber should be at a temperature below about 32 F.
Although the refrigerant gas can be any of a wide variety of gases that cool upon expansion, such as air, nitrogen, oxygen, or mixtures of these gases; as a practical matter, it is most advantageous to employ produced gas as the refrigerant gas. Produced gas consists primarily of methane, and contains lesser amounts of ethane, propane, and higher molecular weight hydrocarbons. It also can contain varying amounts of hydrogen sulfide, carbon dioxide, water, and minor amounts of other impurities. This gas can be used directly as produced in the field or after processing through gas absorption plants for the removal of various of the high molecular weight hydrocarbons and other constituents to produce a pipeline grade natural gas. The produced field gas, or natural gas, employed in the well refrigeration technique of this invention generally exhibit specific gravities between about 0.60 and 1.0, and most typically between about 0.65 and 0.80.
Under certain conditions of temperature and pressure, hydrocarbon gases containing liquid water form solid hydrates that could cause plugging of the refrigeration chamber and other gas flow passages. Accordingly, it is preferred that the water content of the gas be maintained below that amount that will condense to form liquid water. The water content of a produced gas can be reduced by contacting the gas with ethylene glycol or other desiccant material that preferentially absorbs water from the gas. The dry gas having a reduced water content can then be employed to refrigerate the well.
The high pressure gas employed as the refrigerant gas must be available at a pressure sufficiently high that the 6 requisite cooling can be obtained by expansion of the gas. Generally, the gas must be available at a pressure of at least about 200 psig, and preferably at a pressure of about 400 to 800 psig The temperature of the high pressure gas is usually between about 50 F. and 150 F.
The low pressure gas exhausted from the refrigeration chamber is collected and employed as a boiler or internal combustion engine fuel, or for other uses, or the low pressure gas can be recompressed for pipeline delivery. Also, where the produced gas available in a particular field is not sufficient to provide the necessary refrigeration, it is within the scope of this invention to recompress the low pressure gas and recycle this gas through the expansion nozzle. The pressure to which the refrigerant gas is expanded and the utilization of the refrigerant gas in any particular oil field will depend upon the availability of produced gas in that field, the utilization of the low pressure gas, and the particular economics involved. In typical applications, the refrigerant gas will be expanded to a pressure of about 100 to 300 psig, although this pressure will depend upon the particular circumstances of each application.
Although nozzle can be any gas expansion nozzle, the amount of cooling obtained and the efficiency of the process is dependent upon the design of the nozzle. Maximum cooling is obtained when the gas passing through the nozzle expands isentropically, i.e., expands by a reversible process at constant entropy. This is an idealized condition that cannot be attained in practice. However, it is within the skill of the nozzle art to design highly efficient gas nozzles for expanding gases substantially isentropically. The efficiency of a nozzle can be characterized by the nozzle coefficient nn, which is defined as V (actual) v, (ideal) in which V ,(actual) is the actual gas velocity attained in the nozzle and V (ideal) is the ideal velocity theoretically attained by a gas isentropically expanding through the nozzle. The term substantially isentropic" as used herein is meant to define a gas expansion through a nozzle having a nozzle coefficient of 0.95 or higher, and more preferably 0.98 or higher.
The nozzle design and operating conditions must be selected so that the expanded refrigerant gas is introduced into the refrigeration chamber at a temperature sufficiently below the melting temperature of the permafrostthat the gas does not warm to a temperature above the melting temperature during passage through the refrigeration chamber. The amount of the refrigerant gas expanded into the refrigeration chamber will depend upon the magnitude of the heat flux from the hot fluid flowing through the tubing string. in a typical well having a well insulated tubing string, the heat flux is generally about 10 to 30 BTU/Hr per foot of well. Depending upon the particular conditions encountered, this amount of heat can be removed by expanding about 900 to 1,800 pounds per hour of refrigerant gas into the refrigeration chamber.
In operation, the refrigeration obtained with any particular system can be controlled by adjusting either the inlet pressure of the gas supplied to the nozzle, the exhaust pressure in the refrigeration chamber, or both of these pressures. An increase in inlet pressure and a decrease in exhaust pressure result in additional cooling, with an opposite effect being obtained by a reduction in inlet pressure or an increase in the exhaust pressure.
The improved well refrigeration method of this invention is further demonstrated by the following examples which are presented by way of illustration, and are not intended as limiting the spirit and scope of the invention as defined by the appended claims.
EXAMPLE 1 This example illustrates the application of the well refrigeration method of this invention to a producing well completed in a petroleum reservoir underlying a frozen permafrost zone approximately 2,000 feet thick. The well is completed substantially as illustrated in FIG. 1, with refrigeration chamber 62 extending from the surface to a depth of approximately 300 feet. Fluids are produced from the underlying reservoir at a temperature of 125 F. and transported to the surface. Primary treatment includes separation of the gas, oil and water phases. High pressure gas is produced from the separator at 125 F. and 485 psig. This gas consists primarily of methane and contains ethane and other light hydrocarbons, and exhibits a specific gravity of 0.70.
Refrigeration of the well is accomplished by recycling a portion of the produced high pressure gas to the well and substantially isentropically expanding this gas into the refrigeration chamber through a single gas expansion nozzle having a nozzle efficiency of 0.98. The refrigerant gas is dried by contact with ethylene glycol prior to recycle to the well to avoid the formation of hydrates in the refrigeration chamber. Approximately 500 MSCF/D of the high pressure gas at 125 F. and 485 psig is expanded to 185 psig in the refrigeration chamber to provide cooling for the well. The expanded gas exits the expansion nozzle at a temperature of 20 F., and is warmed to about 30 F. during its passage through the refrigeration chamber. The refrigerant gas removes sufficient heat from the well to prevent thawing of the permafrost adjacent to the well.
EXAMPLE 2 This example illustrates another embodiment of the invention in which the well is cooled by expanding a high pressure refrigerant gas separated from the produced fluids in a downhole separator located 300 feet below the surface. Approximately 500 MSCF/D of gas is separated from the produced fluids at a temperature of 125 F. and a pressure of 485 psig. This gas is expanded, without drying, into the refrigeration chamber of a well completed substantially as illustrated in FIG. 2. The refrigerant is cooled to a temperature of about 20 F. on expanding to a pressure of 175 psig., and is warmed about F. on passage through the refrigeration zone. The pressure in the refrigeration chamber is controlled to maintain the temperature of the gas exiting the refrigeration chamber below about 32 F.
Various embodiments and modifications of this invention have been described in the foregoing specification, and further modifications will be apparent to those skilled in the art. Such modifications are included within the scope of this invention as defined by the following claims.
Having now described the invention, 1 claim:
1. A refrigerated well extending from the surface to an underlying petroleum reservoir for conducting hot fluids through a permafrost zone, which comprises:
a closed annular refrigeration chamber defined by inner and outer concentric casings extending a substantial distance into said permafrost zone, said refrigeration chamber lying between said hot fluids conducted through said well and said permafrost;
a production tubing within said inner casing to conduct fluids from said underlying petroleum reservoir to the surface, or vice versa;
at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber;
gas conduit means to conduct high pressure gas from a source of high pressure gas to said gas expansion nozzle; and Y means for exhausting low pressure gas from said refrigeration chamber;
whereby high pressure gas discharged through said gas expansion nozzle into said refrigeration chamber is cooled to a temperature below the permafrost temperature and flowed upwardly through said refrigeration chamber to prevent the transfer of heat from said hot fluids conducted through said well to the surrounding permafrost.
2. The apparatus defined in claim 1 wherein said annular refrigeration chamber has a length of about 200 to 700 feet.
3. The apparatus defined in claim 1 wherein said gas expansion nozzle substantially isentropically expands gas into said refrigeration chamber.
4. The apparatus defined in claim 1 including a gas separator located at the surface to separate high pressure gas from fluids produced from said underlying petroleum reservoir, wherein said gas conduit means conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle. I
5. The apparatus defined in claim 1 including a downhole gas separator in fluid communication with said production tubing to separate high pressure gas from fluids produced from said underlying petroleum reservoir, said separator being located adjacent to the bottom of said refrigeration chamber, and wherein said gas conduit means conducts high pressure gas from said gas separator to said gas expansion nozzle.
6. A refrigerated well for conducting hot fluids through a permafrost zone, which comprises:
a first casing extending a substantial distance into said permafrost zone and cemented therein;
a second casing placed concentrically within said first casing, said second casing extending below said first casing and said second casing being cemented below the bottom of said first casing;
sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber;
a production tubing within said second casing to convey fluids from an underlying producing strata to the surface, or vice versa, said tubing being insulated through said permafrost zone;
at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber;
gas conduit means to conduct high pressure gas' from a source of high pressure gas to' said gasexp'a'nsion nozzle; and
means for exhaustinglow pressure gas from said refrigeration chamber.. I
7. The apparatus defined in claim 6 including a gas separator located at the surface separate high pressure gas from fluids produced from said underlying producing strata, wherein said gas conduit means 'conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle. t
8. The apparatus defined in claim 6 including a downhole gas separator in fluid communication with said production tubing to separate a portion of the gas from the fluids produced from said underlying producing strata, said separator being located in said second casing adjacent to the bottom of said refrigeration chamber, and wherein said gas conduit means conducts high pressure gas from said gas separator to said gas expansion nozzle.
9. The apparatus defined in claim 6 wherein said gas expansion nozzle expands the gas passing therethrough substantially isentropically.
10. The apparatus defined in claim 6 including a production casing placed concentrically within said second casing, said production casing extending from the surface to said underlying producing strata and said production casing being cemented below the bottom of said second casing.
11. The apparatus defined in claim 6 wherein said second casing extends at least to the bottom of said permafrost zone.
12. A refrigerated well for conducting hot fluids through a permafrost zone, which comprises:
a surface conductor cemented in the permafrost;
a first casing placed concentrically within said sur-* face conductor and extending about 200 to 700 feet into said permafrost zone, said first casing being cemented to the surface;
a second casing placed concentrically within said first casing, said second casing extending at least through said permafrost zone and said second casing being cemented below the bottom of said first casing;
sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber;
a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing;
a production tubing within said production casing to convey fluids from an underlying petroleum reservoir to the surface, or vice versa, said tubing being insulated through said permafrost zone;
at least one gas expansion nozzle located with said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber;
a gas conduit in said refrigeration chamber to conduct high pressure gas from the surface to said gas expansion nozzle; and
" means to exhaust low pressure g as from said refrigerfor producing hot fluids from an underlying petroleum reservoir, which co mprisesf a surface conductor eenientedin the permafrost;
a first casing placed concentrically vvithin said surface conductor and extending about ZOO'to 700 .feet. into said permafrost zone, said first casing being cemented .t o surface; I
a secondsca sing placedconcent rically within said first casing, said second. casing extending at least through said permafrost zone and said second casing being,cemen'ted below the bottomof said first casing; s v 1 sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber;
a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing;
a production tubing within said production casing to convey fluids from said underlying petroleum reservoir to the surface, said tubing being insulated through the permafrost zone;
a downhole gas separator in said production casing adjacent to the bottom of said refrigeration chamber to receive produced fluids flowing upwardly through said production tubing, disengage a portion of the gas from said produced fluids, and discharge the residual produced fluids up said production tubing;
at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber;
gas conduit means to conduct gas from said downhole gas separator to said gas expansion nozzle; and means to exhaust low pressure gas from said refrigeration chamber.
14. The apparatus defined in claim 13 wherein said gas conduit means includes (1) first and second packers set in the annulus between said production tubing and said production casing, above and below said downhole gas separator, respectively, to define an enclosed annular first chamber; (2) third and fourth packers set in the annulus between said production casing and said second casing to define an enclosed second annular chamber surrounding said first annular chamber; (3) an aperture in said production casing communicating said first and second annular chambers; and (4) a conduit communicating said second annular chamber to the inlet of said gas expansion nozzle.
15. The apparatus defined in claim 14 wherein said downhole separator includes (1) an outer cylindrical shell having an inlet at its bottom and an outlet at its top for connection, respectively, to said production tubing; (2) an internal standpipe extending above said inlet; (3) an inverted cap extending downwardly below the lip of said standpipe; (4) an inverted cup-shaped diverter supported immediately above said standpipe; (5) an apertured baffle separating said cap into a lower section and an upper gas chamber; and (6) a float-type valve in said gas chamber having an outlet connected to the exterior of said cylindrical shell.
16. A method for conducting hot fluids through a well traversing a permafrost zone without melting the permafrost surrounding the well, which comprises:
flowing the hot fluid through an insulated first tubular member within said well, said fluid being either injected into or produced from an underlying petroleum reservoir;
introducing and expanding a high pressure gas in the bottom of an annular refrigeration chamber defined by inner and outer concentric casings surrounding said first tubular member and lying between said first tubular member and said permafrost, to provide a cooled, low pressure gas having a temperature below the melting point of said perchamber at a temperature below about 32 F.
Claims (19)
1. A refrigerated well extending from the surface to an underlying petroleum reservoir for conducting hot fluids through a permafrost zone, which comprises: a closed annular refrigeration chamber defined by inner and outer concentric casings extending a substantial distance into said permafrost zone, said refrigeration chamber lying between said hot fluids conducted through said well and said permafrost; a production tubing within said inner casing to conduct fluids from said underlying petroleum reservoir to the surface, or vice versa; at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber; gas conduit means to conduct high pressure gas from a source of high pressure gas to said gas expansion nozzle; and means for exhausting low pressure gas from said refrigeration chamber; whereby high pressure gas discharged through said gas expansion nozzle into said refrigeration chamber is cooled to a temperature below the permafrost temperature and flowed upwardly through said refrigeration chamber to prevent the transfer of heat from said hot fluids conducted through said well to the surrounding permafrost.
2. The apparatus defined in claim 1 wherein said annular refrigeration chamber has a length of about 200 to 700 feet.
3. The apparatus defined in claim 1 wherein said gas expansion nozzle substantially isentropically expands gas into said refrigeration chamber.
4. The apparatus defined in claim 1 including a gas separator located at the surface to separate high pressure gas from fluids produced from said underlying petroleum reservoir, wherein said gas conduit means conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle.
5. The apparatus defined in claim 1 including a downhole gas separator in fluid communication with said production tubing to separate high pressure gas from fluids produced from said underlying petroleum reservoir, said separator being located adjacent to the bottom of said refrigEration chamber, and wherein said gas conduit means conducts high pressure gas from said gas separator to said gas expansion nozzle.
6. A refrigerated well for conducting hot fluids through a permafrost zone, which comprises: a first casing extending a substantial distance into said permafrost zone and cemented therein; a second casing placed concentrically within said first casing, said second casing extending below said first casing and said second casing being cemented below the bottom of said first casing; sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber; a production tubing within said second casing to convey fluids from an underlying producing strata to the surface, or vice versa, said tubing being insulated through said permafrost zone; at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, and discharging into said chamber; gas conduit means to conduct high pressure gas from a source of high pressure gas to said gas expansion nozzle; and means for exhausting low pressure gas from said refrigeration chamber.
7. The apparatus defined in claim 6 including a gas separator located at the surface to separate high pressure gas from fluids produced from said underlying producing strata, wherein said gas conduit means conducts said high pressure gas from said gas separator to said gas expansion nozzle, and wherein said gas conduit means includes a high pressure gas conduit in said refrigeration chamber extending from the surface to said gas expansion nozzle.
8. The apparatus defined in claim 6 including a downhole gas separator in fluid communication with said production tubing to separate a portion of the gas from the fluids produced from said underlying producing strata, said separator being located in said second casing adjacent to the bottom of said refrigeration chamber, and wherein said gas conduit means conducts high pressure gas from said gas separator to said gas expansion nozzle.
9. The apparatus defined in claim 6 wherein said gas expansion nozzle expands the gas passing therethrough substantially isentropically.
10. The apparatus defined in claim 6 including a production casing placed concentrically within said second casing, said production casing extending from the surface to said underlying producing strata and said production casing being cemented below the bottom of said second casing.
11. The apparatus defined in claim 6 wherein said second casing extends at least to the bottom of said permafrost zone.
12. A refrigerated well for conducting hot fluids through a permafrost zone, which comprises: a surface conductor cemented in the permafrost; a first casing placed concentrically within said surface conductor and extending about 200 to 700 feet into said permafrost zone, said first casing being cemented to the surface; a second casing placed concentrically within said first casing, said second casing extending at least through said permafrost zone and said second casing being cemented below the bottom of said first casing; sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber; a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing; a production tubing within said production casing to convey fluids from an underlying petroleum reservoir to the surface, or vice versa, said tubing being insulated through said permafrost zone; at least one gas expansion nozzle located with said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber; a gaS conduit in said refrigeration chamber to conduct high pressure gas from the surface to said gas expansion nozzle; and means to exhaust low pressure gas from said refrigeration chamber.
13. A refrigerated well penetrating a permafrost zone for producing hot fluids from an underlying petroleum reservoir, which comprises: a surface conductor cemented in the permafrost; a first casing placed concentrically within said surface conductor and extending about 200 to 700 feet into said permafrost zone, said first casing being cemented to the surface; a second casing placed concentrically within said first casing, said second casing extending at least through said permafrost zone and said second casing being cemented below the bottom of said first casing; sealing means at the top of said first casing to provide a fluid-tight closure between said first and second casings so as to form a closed annular refrigeration chamber; a production casing placed concentrically within said second casing and extending from the surface to an underlying petroleum reservoir, said production casing being cemented below the bottom of said second casing; a production tubing within said production casing to convey fluids from said underlying petroleum reservoir to the surface, said tubing being insulated through the permafrost zone; a downhole gas separator in said production casing adjacent to the bottom of said refrigeration chamber to receive produced fluids flowing upwardly through said production tubing, disengage a portion of the gas from said produced fluids, and discharge the residual produced fluids up said production tubing; at least one gas expansion nozzle located within said refrigeration chamber and adjacent to the bottom thereof, to substantially isentropically expand high pressure gas into said chamber; gas conduit means to conduct gas from said downhole gas separator to said gas expansion nozzle; and means to exhaust low pressure gas from said refrigeration chamber.
14. The apparatus defined in claim 13 wherein said gas conduit means includes (1) first and second packers set in the annulus between said production tubing and said production casing, above and below said downhole gas separator, respectively, to define an enclosed annular first chamber; (2) third and fourth packers set in the annulus between said production casing and said second casing to define an enclosed second annular chamber surrounding said first annular chamber; (3) an aperture in said production casing communicating said first and second annular chambers; and (4) a conduit communicating said second annular chamber to the inlet of said gas expansion nozzle.
15. The apparatus defined in claim 14 wherein said downhole separator includes (1) an outer cylindrical shell having an inlet at its bottom and an outlet at its top for connection, respectively, to said production tubing; (2) an internal standpipe extending above said inlet; (3) an inverted cap extending downwardly below the lip of said standpipe; (4) an inverted cup-shaped diverter supported immediately above said standpipe; (5) an apertured baffle separating said cap into a lower section and an upper gas chamber; and (6) a float-type valve in said gas chamber having an outlet connected to the exterior of said cylindrical shell.
16. A method for conducting hot fluids through a well traversing a permafrost zone without melting the permafrost surrounding the well, which comprises: flowing the hot fluid through an insulated first tubular member within said well, said fluid being either injected into or produced from an underlying petroleum reservoir; introducing and expanding a high pressure gas in the bottom of an annular refrigeration chamber defined by inner and outer concentric casings surrounding said first tubular member and lying between said first tubular member and said permafrost, to provide a cooled, low pressure Gas having a temperature below the melting point of said permafrost; flowing said cooled gas upwardly through said annular refrigeration chamber; and withdrawing said low pressure gas from the upper end of said refrigeration chamber.
17. The method defined in claim 16 wherein said high pressure gas is produced gas separated from fluids produced from a petroleum reservoir.
18. The method defined in claim 16 wherein said high pressure gas is substantially isentropically expanded into said refrigeration chamber.
19. The method defined in claim 16 wherein said low temperature gas is withdrawn from said refrigeration chamber at a temperature below about 32* F.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US393892A US3882937A (en) | 1973-09-04 | 1973-09-04 | Method and apparatus for refrigerating wells by gas expansion |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US393892A US3882937A (en) | 1973-09-04 | 1973-09-04 | Method and apparatus for refrigerating wells by gas expansion |
Publications (1)
Publication Number | Publication Date |
---|---|
US3882937A true US3882937A (en) | 1975-05-13 |
Family
ID=23556673
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US393892A Expired - Lifetime US3882937A (en) | 1973-09-04 | 1973-09-04 | Method and apparatus for refrigerating wells by gas expansion |
Country Status (1)
Country | Link |
---|---|
US (1) | US3882937A (en) |
Cited By (70)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4195487A (en) * | 1975-07-01 | 1980-04-01 | Nippon Concrete Industries Co., Ltd. | Concrete piles suitable as foundation pillars |
US4479546A (en) * | 1983-01-28 | 1984-10-30 | Bresie Don A | Method and apparatus for producing natural gas from tight formations |
US4784528A (en) * | 1986-02-25 | 1988-11-15 | Chevron Research Company | Method and apparatus for piled foundation improvement with freezing using down-hole refrigeration units |
US5265677A (en) * | 1992-07-08 | 1993-11-30 | Halliburton Company | Refrigerant-cooled downhole tool and method |
US5560220A (en) * | 1995-09-01 | 1996-10-01 | Ecr Technologies, Inc. | Method for testing an earth tap heat exchanger and associated apparatus |
US5561985A (en) * | 1995-05-02 | 1996-10-08 | Ecr Technologies, Inc. | Heat pump apparatus including earth tap heat exchanger |
US5706888A (en) * | 1995-06-16 | 1998-01-13 | Geofurnace Systems, Inc. | Geothermal heat exchanger and heat pump circuit |
US5937665A (en) * | 1998-01-15 | 1999-08-17 | Geofurnace Systems, Inc. | Geothermal subcircuit for air conditioning unit |
US5983660A (en) * | 1998-01-15 | 1999-11-16 | Geofurnace Systems, Inc. | Defrost subcircuit for air-to-air heat pump |
US20030010499A1 (en) * | 2000-02-18 | 2003-01-16 | Qvam Helge Andreas | Method for thermally protecting subsea installations, and apparatus for implementing such thermal protection |
US20080087426A1 (en) * | 2006-10-13 | 2008-04-17 | Kaminsky Robert D | Method of developing a subsurface freeze zone using formation fractures |
US20080173443A1 (en) * | 2003-06-24 | 2008-07-24 | Symington William A | Methods of treating a subterranean formation to convert organic matter into producible hydrocarbons |
US20090183872A1 (en) * | 2008-01-23 | 2009-07-23 | Trent Robert H | Methods Of Recovering Hydrocarbons From Oil Shale And Sub-Surface Oil Shale Recovery Arrangements For Recovering Hydrocarbons From Oil Shale |
US7669657B2 (en) | 2006-10-13 | 2010-03-02 | Exxonmobil Upstream Research Company | Enhanced shale oil production by in situ heating using hydraulically fractured producing wells |
US20100101793A1 (en) * | 2008-10-29 | 2010-04-29 | Symington William A | Electrically Conductive Methods For Heating A Subsurface Formation To Convert Organic Matter Into Hydrocarbon Fluids |
US7775281B2 (en) * | 2006-05-10 | 2010-08-17 | Kosakewich Darrell S | Method and apparatus for stimulating production from oil and gas wells by freeze-thaw cycling |
US20100282460A1 (en) * | 2009-05-05 | 2010-11-11 | Stone Matthew T | Converting Organic Matter From A Subterranean Formation Into Producible Hydrocarbons By Controlling Production Operations Based On Availability Of One Or More Production Resources |
WO2011056171A1 (en) * | 2009-11-04 | 2011-05-12 | Halliburton Energy Services, Inc. | Open loop cooling system and method for downhole tools |
US20110200516A1 (en) * | 2010-02-13 | 2011-08-18 | Mcalister Technologies, Llc | Reactor vessels with transmissive surfaces for producing hydrogen-based fuels and structural elements, and associated systems and methods |
US20110203776A1 (en) * | 2009-02-17 | 2011-08-25 | Mcalister Technologies, Llc | Thermal transfer device and associated systems and methods |
US20110206565A1 (en) * | 2010-02-13 | 2011-08-25 | Mcalister Technologies, Llc | Chemical reactors with re-radiating surfaces and associated systems and methods |
US20110209848A1 (en) * | 2008-09-24 | 2011-09-01 | Earth To Air Systems, Llc | Heat Transfer Refrigerant Transport Tubing Coatings and Insulation for a Direct Exchange Geothermal Heating/Cooling System and Tubing Spool Core Size |
US20110220040A1 (en) * | 2008-01-07 | 2011-09-15 | Mcalister Technologies, Llc | Coupled thermochemical reactors and engines, and associated systems and methods |
US8082995B2 (en) | 2007-12-10 | 2011-12-27 | Exxonmobil Upstream Research Company | Optimization of untreated oil shale geometry to control subsidence |
US8087460B2 (en) | 2007-03-22 | 2012-01-03 | Exxonmobil Upstream Research Company | Granular electrical connections for in situ formation heating |
US8122955B2 (en) | 2007-05-15 | 2012-02-28 | Exxonmobil Upstream Research Company | Downhole burners for in situ conversion of organic-rich rock formations |
US8146664B2 (en) | 2007-05-25 | 2012-04-03 | Exxonmobil Upstream Research Company | Utilization of low BTU gas generated during in situ heating of organic-rich rock |
US8151877B2 (en) | 2007-05-15 | 2012-04-10 | Exxonmobil Upstream Research Company | Downhole burner wells for in situ conversion of organic-rich rock formations |
US8151884B2 (en) | 2006-10-13 | 2012-04-10 | Exxonmobil Upstream Research Company | Combined development of oil shale by in situ heating with a deeper hydrocarbon resource |
US8230929B2 (en) | 2008-05-23 | 2012-07-31 | Exxonmobil Upstream Research Company | Methods of producing hydrocarbons for substantially constant composition gas generation |
US20130094909A1 (en) * | 2011-08-12 | 2013-04-18 | Mcalister Technologies, Llc | Systems and methods for collecting and processing permafrost gases, and for cooling permafrost |
US8596355B2 (en) | 2003-06-24 | 2013-12-03 | Exxonmobil Upstream Research Company | Optimized well spacing for in situ shale oil development |
US8616280B2 (en) | 2010-08-30 | 2013-12-31 | Exxonmobil Upstream Research Company | Wellbore mechanical integrity for in situ pyrolysis |
US8616279B2 (en) | 2009-02-23 | 2013-12-31 | Exxonmobil Upstream Research Company | Water treatment following shale oil production by in situ heating |
US8622127B2 (en) | 2010-08-30 | 2014-01-07 | Exxonmobil Upstream Research Company | Olefin reduction for in situ pyrolysis oil generation |
US8624072B2 (en) | 2010-02-13 | 2014-01-07 | Mcalister Technologies, Llc | Chemical reactors with annularly positioned delivery and removal devices, and associated systems and methods |
US8622133B2 (en) | 2007-03-22 | 2014-01-07 | Exxonmobil Upstream Research Company | Resistive heater for in situ formation heating |
US8641150B2 (en) | 2006-04-21 | 2014-02-04 | Exxonmobil Upstream Research Company | In situ co-development of oil shale with mineral recovery |
US8669014B2 (en) | 2011-08-12 | 2014-03-11 | Mcalister Technologies, Llc | Fuel-cell systems operable in multiple modes for variable processing of feedstock materials and associated devices, systems, and methods |
US8671870B2 (en) | 2011-08-12 | 2014-03-18 | Mcalister Technologies, Llc | Systems and methods for extracting and processing gases from submerged sources |
US8673509B2 (en) | 2011-08-12 | 2014-03-18 | Mcalister Technologies, Llc | Fuel-cell systems operable in multiple modes for variable processing of feedstock materials and associated devices, systems, and methods |
US8734546B2 (en) | 2011-08-12 | 2014-05-27 | Mcalister Technologies, Llc | Geothermal energization of a non-combustion chemical reactor and associated systems and methods |
US8771636B2 (en) | 2008-01-07 | 2014-07-08 | Mcalister Technologies, Llc | Chemical processes and reactors for efficiently producing hydrogen fuels and structural materials, and associated systems and methods |
US8770284B2 (en) | 2012-05-04 | 2014-07-08 | Exxonmobil Upstream Research Company | Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material |
US8821602B2 (en) | 2011-08-12 | 2014-09-02 | Mcalister Technologies, Llc | Systems and methods for providing supplemental aqueous thermal energy |
US8826657B2 (en) | 2011-08-12 | 2014-09-09 | Mcallister Technologies, Llc | Systems and methods for providing supplemental aqueous thermal energy |
US8863839B2 (en) | 2009-12-17 | 2014-10-21 | Exxonmobil Upstream Research Company | Enhanced convection for in situ pyrolysis of organic-rich rock formations |
US8875789B2 (en) | 2007-05-25 | 2014-11-04 | Exxonmobil Upstream Research Company | Process for producing hydrocarbon fluids combining in situ heating, a power plant and a gas plant |
US8888408B2 (en) | 2011-08-12 | 2014-11-18 | Mcalister Technologies, Llc | Systems and methods for collecting and processing permafrost gases, and for cooling permafrost |
US8911703B2 (en) | 2011-08-12 | 2014-12-16 | Mcalister Technologies, Llc | Reducing and/or harvesting drag energy from transport vehicles, including for chemical reactors, and associated systems and methods |
US8926719B2 (en) | 2013-03-14 | 2015-01-06 | Mcalister Technologies, Llc | Method and apparatus for generating hydrogen from metal |
US9080441B2 (en) | 2011-11-04 | 2015-07-14 | Exxonmobil Upstream Research Company | Multiple electrical connections to optimize heating for in situ pyrolysis |
US9243485B2 (en) | 2013-02-05 | 2016-01-26 | Triple D Technologies, Inc. | System and method to initiate permeability in bore holes without perforating tools |
US9256045B2 (en) | 2006-12-13 | 2016-02-09 | Halliburton Energy Services, Inc. | Open loop cooling system and method for downhole tools |
US9302681B2 (en) | 2011-08-12 | 2016-04-05 | Mcalister Technologies, Llc | Mobile transport platforms for producing hydrogen and structural materials, and associated systems and methods |
US9309741B2 (en) | 2013-02-08 | 2016-04-12 | Triple D Technologies, Inc. | System and method for temporarily sealing a bore hole |
US9394772B2 (en) | 2013-11-07 | 2016-07-19 | Exxonmobil Upstream Research Company | Systems and methods for in situ resistive heating of organic matter in a subterranean formation |
US9512699B2 (en) | 2013-10-22 | 2016-12-06 | Exxonmobil Upstream Research Company | Systems and methods for regulating an in situ pyrolysis process |
US9522379B2 (en) | 2011-08-12 | 2016-12-20 | Mcalister Technologies, Llc | Reducing and/or harvesting drag energy from transport vehicles, including for chemical reactors, and associated systems and methods |
US9644466B2 (en) | 2014-11-21 | 2017-05-09 | Exxonmobil Upstream Research Company | Method of recovering hydrocarbons within a subsurface formation using electric current |
US20190048549A1 (en) * | 2017-08-10 | 2019-02-14 | Ralf Schmand | Device and method for ground freezing |
US20190277111A1 (en) * | 2018-03-07 | 2019-09-12 | Saudi Arabian Oil Company | Removing scale from a wellbore |
US10450839B2 (en) | 2017-08-15 | 2019-10-22 | Saudi Arabian Oil Company | Rapidly cooling a geologic formation in which a wellbore is formed |
US11215032B2 (en) | 2020-01-24 | 2022-01-04 | Saudi Arabian Oil Company | Devices and methods to mitigate pressure buildup in an isolated wellbore annulus |
RU2779073C1 (en) * | 2021-09-24 | 2022-08-31 | Публичное акционерное общество "Газпром" | Method for complex thermal stabilization of permafrost rocks in the impact zones of producing wells of neocomian-jurassic deposits |
US11454068B1 (en) * | 2021-03-23 | 2022-09-27 | Saudi Arabian Oil Company | Pressure-dampening casing to reduce stress load on cement sheath |
US11555658B2 (en) * | 2014-11-19 | 2023-01-17 | University of Alaska Anchorage | Methods and systems to convert passive cooling to active cooling |
US11585176B2 (en) | 2021-03-23 | 2023-02-21 | Saudi Arabian Oil Company | Sealing cracked cement in a wellbore casing |
US11867012B2 (en) | 2021-12-06 | 2024-01-09 | Saudi Arabian Oil Company | Gauge cutter and sampler apparatus |
US11867028B2 (en) | 2021-01-06 | 2024-01-09 | Saudi Arabian Oil Company | Gauge cutter and sampler apparatus |
Citations (14)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1798774A (en) * | 1930-06-19 | 1931-03-31 | Sinclair Oil & Gas Company | Method and apparatus for recovering pressure gas from oil wells |
US2033560A (en) * | 1932-11-12 | 1936-03-10 | Technicraft Engineering Corp | Refrigerating packer |
US2753700A (en) * | 1952-03-27 | 1956-07-10 | Constock Liquid Methane Corp | Method for using natural gas |
US2772737A (en) * | 1954-12-21 | 1956-12-04 | Pure Oil Co | Fracturing oil and gas producing formations |
US3564862A (en) * | 1969-09-12 | 1971-02-23 | Hadi T Hashemi | Method and apparatus for supporing a pipeline in permafrost environment |
US3581513A (en) * | 1969-04-23 | 1971-06-01 | Inst Gas Technology | Method and system for freezing rock and soil |
US3662832A (en) * | 1970-04-30 | 1972-05-16 | Atlantic Richfield Co | Insulating a wellbore in permafrost |
US3674086A (en) * | 1970-08-07 | 1972-07-04 | Alden W Foster | Method of transporting oil or gas in frozen tundra |
US3735769A (en) * | 1971-04-08 | 1973-05-29 | J Miller | Method for pumping oil through terrain containing permafrost |
US3738424A (en) * | 1971-06-14 | 1973-06-12 | Big Three Industries | Method for controlling offshore petroleum wells during blowout conditions |
US3763935A (en) * | 1972-05-15 | 1973-10-09 | Atlantic Richfield Co | Well insulation method |
US3766985A (en) * | 1971-12-01 | 1973-10-23 | Univ Kansas State | Production of oil from well cased in permafrost |
US3774701A (en) * | 1971-05-07 | 1973-11-27 | C Weaver | Method and apparatus for drilling |
US3777502A (en) * | 1971-03-12 | 1973-12-11 | Newport News Shipbuilding Dry | Method of transporting liquid and gas |
-
1973
- 1973-09-04 US US393892A patent/US3882937A/en not_active Expired - Lifetime
Patent Citations (14)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US1798774A (en) * | 1930-06-19 | 1931-03-31 | Sinclair Oil & Gas Company | Method and apparatus for recovering pressure gas from oil wells |
US2033560A (en) * | 1932-11-12 | 1936-03-10 | Technicraft Engineering Corp | Refrigerating packer |
US2753700A (en) * | 1952-03-27 | 1956-07-10 | Constock Liquid Methane Corp | Method for using natural gas |
US2772737A (en) * | 1954-12-21 | 1956-12-04 | Pure Oil Co | Fracturing oil and gas producing formations |
US3581513A (en) * | 1969-04-23 | 1971-06-01 | Inst Gas Technology | Method and system for freezing rock and soil |
US3564862A (en) * | 1969-09-12 | 1971-02-23 | Hadi T Hashemi | Method and apparatus for supporing a pipeline in permafrost environment |
US3662832A (en) * | 1970-04-30 | 1972-05-16 | Atlantic Richfield Co | Insulating a wellbore in permafrost |
US3674086A (en) * | 1970-08-07 | 1972-07-04 | Alden W Foster | Method of transporting oil or gas in frozen tundra |
US3777502A (en) * | 1971-03-12 | 1973-12-11 | Newport News Shipbuilding Dry | Method of transporting liquid and gas |
US3735769A (en) * | 1971-04-08 | 1973-05-29 | J Miller | Method for pumping oil through terrain containing permafrost |
US3774701A (en) * | 1971-05-07 | 1973-11-27 | C Weaver | Method and apparatus for drilling |
US3738424A (en) * | 1971-06-14 | 1973-06-12 | Big Three Industries | Method for controlling offshore petroleum wells during blowout conditions |
US3766985A (en) * | 1971-12-01 | 1973-10-23 | Univ Kansas State | Production of oil from well cased in permafrost |
US3763935A (en) * | 1972-05-15 | 1973-10-09 | Atlantic Richfield Co | Well insulation method |
Cited By (104)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4195487A (en) * | 1975-07-01 | 1980-04-01 | Nippon Concrete Industries Co., Ltd. | Concrete piles suitable as foundation pillars |
US4479546A (en) * | 1983-01-28 | 1984-10-30 | Bresie Don A | Method and apparatus for producing natural gas from tight formations |
US4784528A (en) * | 1986-02-25 | 1988-11-15 | Chevron Research Company | Method and apparatus for piled foundation improvement with freezing using down-hole refrigeration units |
US5265677A (en) * | 1992-07-08 | 1993-11-30 | Halliburton Company | Refrigerant-cooled downhole tool and method |
US5561985A (en) * | 1995-05-02 | 1996-10-08 | Ecr Technologies, Inc. | Heat pump apparatus including earth tap heat exchanger |
US5706888A (en) * | 1995-06-16 | 1998-01-13 | Geofurnace Systems, Inc. | Geothermal heat exchanger and heat pump circuit |
US5875644A (en) * | 1995-06-16 | 1999-03-02 | Geofurnace Systems, Inc. | Heat exchanger and heat pump circuit |
US5560220A (en) * | 1995-09-01 | 1996-10-01 | Ecr Technologies, Inc. | Method for testing an earth tap heat exchanger and associated apparatus |
US5937665A (en) * | 1998-01-15 | 1999-08-17 | Geofurnace Systems, Inc. | Geothermal subcircuit for air conditioning unit |
US5983660A (en) * | 1998-01-15 | 1999-11-16 | Geofurnace Systems, Inc. | Defrost subcircuit for air-to-air heat pump |
US20030010499A1 (en) * | 2000-02-18 | 2003-01-16 | Qvam Helge Andreas | Method for thermally protecting subsea installations, and apparatus for implementing such thermal protection |
US6889770B2 (en) * | 2000-02-18 | 2005-05-10 | Abb Offshore Systems As | Method for thermally protecting subsea installations, and apparatus for implementing such thermal protection |
US8596355B2 (en) | 2003-06-24 | 2013-12-03 | Exxonmobil Upstream Research Company | Optimized well spacing for in situ shale oil development |
US20080173443A1 (en) * | 2003-06-24 | 2008-07-24 | Symington William A | Methods of treating a subterranean formation to convert organic matter into producible hydrocarbons |
US7631691B2 (en) | 2003-06-24 | 2009-12-15 | Exxonmobil Upstream Research Company | Methods of treating a subterranean formation to convert organic matter into producible hydrocarbons |
US20100078169A1 (en) * | 2003-06-24 | 2010-04-01 | Symington William A | Methods of Treating Suberranean Formation To Convert Organic Matter Into Producible Hydrocarbons |
US8641150B2 (en) | 2006-04-21 | 2014-02-04 | Exxonmobil Upstream Research Company | In situ co-development of oil shale with mineral recovery |
US20100263869A1 (en) * | 2006-05-10 | 2010-10-21 | Kosakewich Darrell S | Method and apparatus for stimulating production from oil and gas wells by freeze-thaw cycling |
US7775281B2 (en) * | 2006-05-10 | 2010-08-17 | Kosakewich Darrell S | Method and apparatus for stimulating production from oil and gas wells by freeze-thaw cycling |
US7516785B2 (en) | 2006-10-13 | 2009-04-14 | Exxonmobil Upstream Research Company | Method of developing subsurface freeze zone |
US7647971B2 (en) | 2006-10-13 | 2010-01-19 | Exxonmobil Upstream Research Company | Method of developing subsurface freeze zone |
US7647972B2 (en) | 2006-10-13 | 2010-01-19 | Exxonmobil Upstream Research Company | Subsurface freeze zone using formation fractures |
US7669657B2 (en) | 2006-10-13 | 2010-03-02 | Exxonmobil Upstream Research Company | Enhanced shale oil production by in situ heating using hydraulically fractured producing wells |
US20090107679A1 (en) * | 2006-10-13 | 2009-04-30 | Kaminsky Robert D | Subsurface Freeze Zone Using Formation Fractures |
US20090101348A1 (en) * | 2006-10-13 | 2009-04-23 | Kaminsky Robert D | Method of Developing Subsurface Freeze Zone |
US7516787B2 (en) | 2006-10-13 | 2009-04-14 | Exxonmobil Upstream Research Company | Method of developing a subsurface freeze zone using formation fractures |
US8104537B2 (en) | 2006-10-13 | 2012-01-31 | Exxonmobil Upstream Research Company | Method of developing subsurface freeze zone |
US20080087426A1 (en) * | 2006-10-13 | 2008-04-17 | Kaminsky Robert D | Method of developing a subsurface freeze zone using formation fractures |
US20100319909A1 (en) * | 2006-10-13 | 2010-12-23 | Symington William A | Enhanced Shale Oil Production By In Situ Heating Using Hydraulically Fractured Producing Wells |
US8151884B2 (en) | 2006-10-13 | 2012-04-10 | Exxonmobil Upstream Research Company | Combined development of oil shale by in situ heating with a deeper hydrocarbon resource |
US9256045B2 (en) | 2006-12-13 | 2016-02-09 | Halliburton Energy Services, Inc. | Open loop cooling system and method for downhole tools |
US8622133B2 (en) | 2007-03-22 | 2014-01-07 | Exxonmobil Upstream Research Company | Resistive heater for in situ formation heating |
US8087460B2 (en) | 2007-03-22 | 2012-01-03 | Exxonmobil Upstream Research Company | Granular electrical connections for in situ formation heating |
US9347302B2 (en) | 2007-03-22 | 2016-05-24 | Exxonmobil Upstream Research Company | Resistive heater for in situ formation heating |
US8122955B2 (en) | 2007-05-15 | 2012-02-28 | Exxonmobil Upstream Research Company | Downhole burners for in situ conversion of organic-rich rock formations |
US8151877B2 (en) | 2007-05-15 | 2012-04-10 | Exxonmobil Upstream Research Company | Downhole burner wells for in situ conversion of organic-rich rock formations |
US8875789B2 (en) | 2007-05-25 | 2014-11-04 | Exxonmobil Upstream Research Company | Process for producing hydrocarbon fluids combining in situ heating, a power plant and a gas plant |
US8146664B2 (en) | 2007-05-25 | 2012-04-03 | Exxonmobil Upstream Research Company | Utilization of low BTU gas generated during in situ heating of organic-rich rock |
US8082995B2 (en) | 2007-12-10 | 2011-12-27 | Exxonmobil Upstream Research Company | Optimization of untreated oil shale geometry to control subsidence |
US9188086B2 (en) | 2008-01-07 | 2015-11-17 | Mcalister Technologies, Llc | Coupled thermochemical reactors and engines, and associated systems and methods |
US8771636B2 (en) | 2008-01-07 | 2014-07-08 | Mcalister Technologies, Llc | Chemical processes and reactors for efficiently producing hydrogen fuels and structural materials, and associated systems and methods |
US20110220040A1 (en) * | 2008-01-07 | 2011-09-15 | Mcalister Technologies, Llc | Coupled thermochemical reactors and engines, and associated systems and methods |
US7832483B2 (en) * | 2008-01-23 | 2010-11-16 | New Era Petroleum, Llc. | Methods of recovering hydrocarbons from oil shale and sub-surface oil shale recovery arrangements for recovering hydrocarbons from oil shale |
US20090183872A1 (en) * | 2008-01-23 | 2009-07-23 | Trent Robert H | Methods Of Recovering Hydrocarbons From Oil Shale And Sub-Surface Oil Shale Recovery Arrangements For Recovering Hydrocarbons From Oil Shale |
US8230929B2 (en) | 2008-05-23 | 2012-07-31 | Exxonmobil Upstream Research Company | Methods of producing hydrocarbons for substantially constant composition gas generation |
US20110209848A1 (en) * | 2008-09-24 | 2011-09-01 | Earth To Air Systems, Llc | Heat Transfer Refrigerant Transport Tubing Coatings and Insulation for a Direct Exchange Geothermal Heating/Cooling System and Tubing Spool Core Size |
US20100101793A1 (en) * | 2008-10-29 | 2010-04-29 | Symington William A | Electrically Conductive Methods For Heating A Subsurface Formation To Convert Organic Matter Into Hydrocarbon Fluids |
US20110203776A1 (en) * | 2009-02-17 | 2011-08-25 | Mcalister Technologies, Llc | Thermal transfer device and associated systems and methods |
US8616279B2 (en) | 2009-02-23 | 2013-12-31 | Exxonmobil Upstream Research Company | Water treatment following shale oil production by in situ heating |
US8540020B2 (en) | 2009-05-05 | 2013-09-24 | Exxonmobil Upstream Research Company | Converting organic matter from a subterranean formation into producible hydrocarbons by controlling production operations based on availability of one or more production resources |
US20100282460A1 (en) * | 2009-05-05 | 2010-11-11 | Stone Matthew T | Converting Organic Matter From A Subterranean Formation Into Producible Hydrocarbons By Controlling Production Operations Based On Availability Of One Or More Production Resources |
WO2011056171A1 (en) * | 2009-11-04 | 2011-05-12 | Halliburton Energy Services, Inc. | Open loop cooling system and method for downhole tools |
US8863839B2 (en) | 2009-12-17 | 2014-10-21 | Exxonmobil Upstream Research Company | Enhanced convection for in situ pyrolysis of organic-rich rock formations |
US20110200516A1 (en) * | 2010-02-13 | 2011-08-18 | Mcalister Technologies, Llc | Reactor vessels with transmissive surfaces for producing hydrogen-based fuels and structural elements, and associated systems and methods |
US20110206565A1 (en) * | 2010-02-13 | 2011-08-25 | Mcalister Technologies, Llc | Chemical reactors with re-radiating surfaces and associated systems and methods |
US9206045B2 (en) | 2010-02-13 | 2015-12-08 | Mcalister Technologies, Llc | Reactor vessels with transmissive surfaces for producing hydrogen-based fuels and structural elements, and associated systems and methods |
US8673220B2 (en) | 2010-02-13 | 2014-03-18 | Mcalister Technologies, Llc | Reactors for conducting thermochemical processes with solar heat input, and associated systems and methods |
US8624072B2 (en) | 2010-02-13 | 2014-01-07 | Mcalister Technologies, Llc | Chemical reactors with annularly positioned delivery and removal devices, and associated systems and methods |
US9103548B2 (en) | 2010-02-13 | 2015-08-11 | Mcalister Technologies, Llc | Reactors for conducting thermochemical processes with solar heat input, and associated systems and methods |
US9541284B2 (en) | 2010-02-13 | 2017-01-10 | Mcalister Technologies, Llc | Chemical reactors with annularly positioned delivery and removal devices, and associated systems and methods |
US8926908B2 (en) | 2010-02-13 | 2015-01-06 | Mcalister Technologies, Llc | Reactor vessels with pressure and heat transfer features for producing hydrogen-based fuels and structural elements, and associated systems and methods |
US8616280B2 (en) | 2010-08-30 | 2013-12-31 | Exxonmobil Upstream Research Company | Wellbore mechanical integrity for in situ pyrolysis |
US8622127B2 (en) | 2010-08-30 | 2014-01-07 | Exxonmobil Upstream Research Company | Olefin reduction for in situ pyrolysis oil generation |
US9039327B2 (en) * | 2011-08-12 | 2015-05-26 | Mcalister Technologies, Llc | Systems and methods for collecting and processing permafrost gases, and for cooling permafrost |
US8673509B2 (en) | 2011-08-12 | 2014-03-18 | Mcalister Technologies, Llc | Fuel-cell systems operable in multiple modes for variable processing of feedstock materials and associated devices, systems, and methods |
US8911703B2 (en) | 2011-08-12 | 2014-12-16 | Mcalister Technologies, Llc | Reducing and/or harvesting drag energy from transport vehicles, including for chemical reactors, and associated systems and methods |
US9617983B2 (en) | 2011-08-12 | 2017-04-11 | Mcalister Technologies, Llc | Systems and methods for providing supplemental aqueous thermal energy |
US8826657B2 (en) | 2011-08-12 | 2014-09-09 | Mcallister Technologies, Llc | Systems and methods for providing supplemental aqueous thermal energy |
US8821602B2 (en) | 2011-08-12 | 2014-09-02 | Mcalister Technologies, Llc | Systems and methods for providing supplemental aqueous thermal energy |
US8669014B2 (en) | 2011-08-12 | 2014-03-11 | Mcalister Technologies, Llc | Fuel-cell systems operable in multiple modes for variable processing of feedstock materials and associated devices, systems, and methods |
US9309473B2 (en) | 2011-08-12 | 2016-04-12 | Mcalister Technologies, Llc | Systems and methods for extracting and processing gases from submerged sources |
US8734546B2 (en) | 2011-08-12 | 2014-05-27 | Mcalister Technologies, Llc | Geothermal energization of a non-combustion chemical reactor and associated systems and methods |
US9522379B2 (en) | 2011-08-12 | 2016-12-20 | Mcalister Technologies, Llc | Reducing and/or harvesting drag energy from transport vehicles, including for chemical reactors, and associated systems and methods |
US9222704B2 (en) | 2011-08-12 | 2015-12-29 | Mcalister Technologies, Llc | Geothermal energization of a non-combustion chemical reactor and associated systems and methods |
US8888408B2 (en) | 2011-08-12 | 2014-11-18 | Mcalister Technologies, Llc | Systems and methods for collecting and processing permafrost gases, and for cooling permafrost |
US8671870B2 (en) | 2011-08-12 | 2014-03-18 | Mcalister Technologies, Llc | Systems and methods for extracting and processing gases from submerged sources |
US9302681B2 (en) | 2011-08-12 | 2016-04-05 | Mcalister Technologies, Llc | Mobile transport platforms for producing hydrogen and structural materials, and associated systems and methods |
US20130094909A1 (en) * | 2011-08-12 | 2013-04-18 | Mcalister Technologies, Llc | Systems and methods for collecting and processing permafrost gases, and for cooling permafrost |
US9080441B2 (en) | 2011-11-04 | 2015-07-14 | Exxonmobil Upstream Research Company | Multiple electrical connections to optimize heating for in situ pyrolysis |
US8770284B2 (en) | 2012-05-04 | 2014-07-08 | Exxonmobil Upstream Research Company | Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material |
US9243485B2 (en) | 2013-02-05 | 2016-01-26 | Triple D Technologies, Inc. | System and method to initiate permeability in bore holes without perforating tools |
US9309741B2 (en) | 2013-02-08 | 2016-04-12 | Triple D Technologies, Inc. | System and method for temporarily sealing a bore hole |
US8926719B2 (en) | 2013-03-14 | 2015-01-06 | Mcalister Technologies, Llc | Method and apparatus for generating hydrogen from metal |
US9512699B2 (en) | 2013-10-22 | 2016-12-06 | Exxonmobil Upstream Research Company | Systems and methods for regulating an in situ pyrolysis process |
US9394772B2 (en) | 2013-11-07 | 2016-07-19 | Exxonmobil Upstream Research Company | Systems and methods for in situ resistive heating of organic matter in a subterranean formation |
US11555658B2 (en) * | 2014-11-19 | 2023-01-17 | University of Alaska Anchorage | Methods and systems to convert passive cooling to active cooling |
US9644466B2 (en) | 2014-11-21 | 2017-05-09 | Exxonmobil Upstream Research Company | Method of recovering hydrocarbons within a subsurface formation using electric current |
US9739122B2 (en) | 2014-11-21 | 2017-08-22 | Exxonmobil Upstream Research Company | Mitigating the effects of subsurface shunts during bulk heating of a subsurface formation |
US10655293B2 (en) * | 2017-08-10 | 2020-05-19 | Linde Aktiengesellschaft | Device and method for ground freezing |
US20190048549A1 (en) * | 2017-08-10 | 2019-02-14 | Ralf Schmand | Device and method for ground freezing |
US10724338B2 (en) | 2017-08-15 | 2020-07-28 | Saudi Arabian Oil Company | Rapidly cooling a geologic formation in which a wellbore is formed |
US10724337B2 (en) | 2017-08-15 | 2020-07-28 | Saudi Arabian Oil Company | Rapidly cooling a geologic formation in which a wellbore is formed |
US10450839B2 (en) | 2017-08-15 | 2019-10-22 | Saudi Arabian Oil Company | Rapidly cooling a geologic formation in which a wellbore is formed |
US10677020B2 (en) | 2018-03-07 | 2020-06-09 | Saudi Arabian Oil Company | Removing scale from a wellbore |
US10677021B2 (en) | 2018-03-07 | 2020-06-09 | Saudi Arabian Oil Company | Removing scale from a wellbore |
US20190277111A1 (en) * | 2018-03-07 | 2019-09-12 | Saudi Arabian Oil Company | Removing scale from a wellbore |
US10508517B2 (en) * | 2018-03-07 | 2019-12-17 | Saudi Arabian Oil Company | Removing scale from a wellbore |
US11215032B2 (en) | 2020-01-24 | 2022-01-04 | Saudi Arabian Oil Company | Devices and methods to mitigate pressure buildup in an isolated wellbore annulus |
US11867028B2 (en) | 2021-01-06 | 2024-01-09 | Saudi Arabian Oil Company | Gauge cutter and sampler apparatus |
US11454068B1 (en) * | 2021-03-23 | 2022-09-27 | Saudi Arabian Oil Company | Pressure-dampening casing to reduce stress load on cement sheath |
US20220307331A1 (en) * | 2021-03-23 | 2022-09-29 | Saudi Arabian Oil Company | Pressure-dampening casing to reduce stress load on cement sheath |
US11585176B2 (en) | 2021-03-23 | 2023-02-21 | Saudi Arabian Oil Company | Sealing cracked cement in a wellbore casing |
RU2779073C1 (en) * | 2021-09-24 | 2022-08-31 | Публичное акционерное общество "Газпром" | Method for complex thermal stabilization of permafrost rocks in the impact zones of producing wells of neocomian-jurassic deposits |
US11867012B2 (en) | 2021-12-06 | 2024-01-09 | Saudi Arabian Oil Company | Gauge cutter and sampler apparatus |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US3882937A (en) | Method and apparatus for refrigerating wells by gas expansion | |
Bily et al. | Naturally occurring gas hydrates in the Mackenzie Delta, NWT | |
US3613792A (en) | Oil well and method for production of oil through permafrost zone | |
US3439744A (en) | Selective formation plugging | |
US3017168A (en) | In situ retorting of oil shale | |
US3559737A (en) | Underground fluid storage in permeable formations | |
CA2537930C (en) | Production of natural gas from hydrates | |
US5085275A (en) | Process for conserving steam quality in deep steam injection wells | |
US4099568A (en) | Method for recovering viscous petroleum | |
US7784533B1 (en) | Downhole combustion unit and process for TECF injection into carbonaceous permeable zones | |
US5653287A (en) | Cryogenic well stimulation method | |
CA2641596A1 (en) | Managed pressure and/or temperature drilling system and method | |
CA1099301A (en) | Mine enhanced hydrocarbon recovery technique | |
US3766985A (en) | Production of oil from well cased in permafrost | |
US3880236A (en) | Method and apparatus for transporting hot fluids through a well traversing a permafrost zone | |
CA1242139A (en) | Foam and impedance-guided steam injection | |
US3160208A (en) | Production well assembly for in situ combustion | |
US4615388A (en) | Method of producing supercritical carbon dioxide from wells | |
CA1076552A (en) | Process and installation for drilling holes in the earth's crust under freezing conditions | |
US3438442A (en) | Low-temperature packer | |
US4901796A (en) | Well packing system | |
US3796265A (en) | Method for producing high hydrogen sulfide content gas wells | |
US3703929A (en) | Well for transporting hot fluids through a permafrost zone | |
US4444263A (en) | Permanent thermal packer method | |
CA2073415A1 (en) | Oil well production system |