|Publication number||US3759328 A|
|Publication date||Sep 18, 1973|
|Filing date||May 11, 1972|
|Priority date||May 11, 1972|
|Publication number||US 3759328 A, US 3759328A, US-A-3759328, US3759328 A, US3759328A|
|Inventors||Brew J, Ueber R, Van Meurs P|
|Original Assignee||Shell Oil Co|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (9), Referenced by (194), Classifications (14)|
|External Links: USPTO, USPTO Assignment, Espacenet|
United States Patent [1 1 Ueber et al.
[111 3,759,328 [4 1 Sept. 18, 1973 LATERALLY EXPANDING OIL SHALE PERMEABILIZATION  Inventors: Russell C. Ueber; Peter Van Meurs;
. Jerke R. Brew, all of Houston, Tex.
 Assignee: Shell Oil Company, Houston, Tex.
 Filed: May 11, 1972  Appl. No.: 252,448
Related US. Application Data  Continuatiomin-part of Ser. No. 57,209, July 22,
Primary Examiner-Stephen J. Novosad Attorney-H. L. Denkler et al.
[5 7] ABSTRACT An improved process of permeabilizing and recovering water soluble and/or heat sensitive minerals and hydrocarbons from an oil shale formation containing said minerals by forming a cavern and vertically expanding it by contacting the cavern roof with a hot aqueous fluid while also causing horizontal expansion of the cavern by contacting the oil shale therein with the same or different hot aqueous fluid at a relatively shallow depth and flowing down along a vertical section while dissolving said minerals and rubbling the oil' shale and producing from a relatively deep location in the cavern an aqueous liquid containing dissolved minerals therein and subsequently or simultaneously injecting a pyrolyzing fluid into the rubbled oil shale cavern to effect pyrolysis of the oil shale and recovery of hydrocarbons therefrom.
6 Claims, 3 Drawing Figures INFLOWING HOT '4 FLUID HORIZONTAL EXPANSION VERTICAL FLUID Patented Sept. 18, 1973 3,759,328
OUTFLOWING INFLOWING HOT COOL FLUID I INFLOWING I INERT LIGHT FLUID FLU'D HOT FLUID FLUID OUTFLOWING COOL I I5 I I I I I VERTICAL l EXPANSION INFLOWING OUT- OUTFLOWING STEAM FLOWING LIQUID INVENTORS:
RUSSELL C. UEBER PETER VAN MEURS JERE R. BREW LATERALLY EXPANDING OIL SHALE PERMEABILIZATION CROSS REFERENCES TO RELATED APPLICATIONS This application is a continuation-in-part of copending patent application Ser. No. 57,209 filed July 22, 1970, now abandoned.
BACKGROUND OF THE INVENTION The present invention relates to production of hydrocarbons and/or water soluble and/or heat sensitive minerals from underground oil shale formations by controlled circulation of a hot aqueous fluid through said oil shale formation so as to vertically and horizontally expand a permeable zone of rubbled oil shale within said formation by leaching and recovering said miner als from a relatively deep location within the treated area of the formation and thereafter injecting a pyrolyzing fluid into the rubbled oil shale to effect pyrolysis and recovery of hydrocarbons therefrom.
Various methods have been proposed for imparting permeability to underground oil shale formations such as fracturing by hydraulic or explosive means and/or acidization but they have proven to be ineffective and- /or too expensive to use. Thus, oil shale formations which have been fractured on subsequent pyrolysis with pyrolyzing fluid to effect oil recovery, such fractures tend to close unless high pyrolyzing fluid circulation pressures at least equal to the overburden pressure, are maintained and this is difficult to do. Acidizato control.
SUMMARY OF THE INVENTION The present invention is directed to an improved method of recovering hydrocarbons and water-soluble carbonates and/or heat sensitive materials from underground oil shale formations containing substantial amounts of said carbonate and/or minerals by forming a cavern therein by leaching with an aqueous fluid said carbonates and/or minerals and imparting permeability while effecting rubbling of the oil shale in said treated area by contacting and flowing a hot aqueous fluid downward from a relatively shallow depth along a vertical interval of said treated oil shale to cause horizontal expansion and-recovering from a relatively deep depth an aqueous liquid containing dissolved therein watersoluble'carbonates and/or heat sensitive minerals and subsequently injecting a pyrolyzing fluid or solvent to effect recovery of hydrocarbons from the rubbled oil shale.
DESCRIPTION OF THE DRAWING FIG. 1 is a vertical section showing a subterranean oil shale and downhole equipment for practicing the present invention.
FIG. 2 is a schematic illustration of a flow path for circulating fluid in accordance with the present invention.
FIG. 3 is a vertical section showing an alternative arrangement of downhole equipment of the type shown in FIG. 1.
DESCRIPTION OF THE INVENTION The present invention is in part premised on a discovery that, in a cavern in an oil shale that contains a significant amount of heat sensitive minerals and/or water soluble carbonates a hot aqueous fluid can be caused to flow along a path that causes a horizontal expansion of the cavern. In a cavern within such an oil shale, the rate at which a hot aqueous fluid is segregated into layers having increasing densities, has been found to be related to the rate at which heat can be transferred into the walls of the cavern in a manner conducive to the establishing and maintaining of the flow path described above, and the resultant heating and leaching along substantially vertical portions of the walls of such a cavern has been found to cause a horizontal expansionof the cavern.
The term cavern is used to refer to any relatively solids free opening, such asa cave, void, tunnel, borehole, or interconnected fractures, etc., in which the rate of gravity segregation of fluids is not significantly impeded by a lack of permeability.
In the present process, the fluid circulation and cavern expansion operations can be initiated by opening at least a single well into an interval of oil shale that contains heat sensitive minerals and/or water soluble carbonates, inflowing hot fluid into contact with an upper portion of the borehole wall, flowing the hot fluid down along the borehole wall, and removing liquid containing dissolved minerals and/or water-soluble carbonates from a lower portion of the borehole. Alternatively, a plurality of wells can be used to provide flow paths into a horizontally extensive cavern in or adjacent to oil shale that contains heat sensitive minerals and/or water-soluble carbonates and the wells and the cavern can be utilized to cause a concurrent horizontal and vertical expansion of a permeable zone by inflowing hot aqueous fluid into contact with a upper portion of such oil shale, flowing fluid downward along a vertical interval of such oil shale, flowing fluid horizontally along the roof of the cavern, and removing liquid containing dissolved minerals and/or water-soluble carbonates from within the cavern.
As used herein, the term heat sensitive and/or water-soluble carbonate refers to materials that decompose relatively rapidly at a relatively low temperature, such as one between about 250 F to about 700 F to yield carbon dioxide and water. Examples of heat sensitive carbonate minerals include nahcolite, dawsonite, trona, and the like minerals, which are usually inclusive of saline carbonate and/or bicarbonate molecular structures or moities.
In a preferred embodiment of the present invention, a borehole is drilled into a relatively low-lying portion of oil shale which contains or is adjacent to a layer or region that is relatively rich in water soluble mineral.
Such water soluble minerals (generally saline minerals) are frequently encountered in oil shale formations in the United States, such as the Green River formation in Colorado, in the form of beds, lenses, nodules, nodes, veins or the like. Examples of such water soluble minerals include the alkali metal chloride salts such as halite minerals and/or water soluble heat sensitive carbonate minerals such as nahcolite, trona, or the like.
The locations of portions of subterranean oil shales which contain specific mineral components, such as heat sensitive carbonate minerals and/or water soluble minerals, can be determined by means of known geological investigation procedures and equipment. In a preferred embodiment of the present invention, geological investigation procedures are utilized to locate a portion of oil shale that contains heat sensitive carbonate mineral and is underlain by a portion or layer that contains water soluble mineral. The water soluble mineral is solution mined or leached for example, by means of a process of the type described in copending patent application Ser. No. 770,964; filed Oct. 28, 1968, now abandoned, and Ser. No. 860,349; filed Sept. 23, 1969, now abandoned. Those applications describe procedures for utilizing a water soluble mineral-rich portion of an oil shale to form a cavern that can be expanded before or during the recovery of shale oil from the oil shale exposed in and around the cavern. Such a solution mined cavern in or adjacent to an oil shale that contains heat sensitive carbonate mineral can advantageously be utilized as a horizontally extensive cavern that is expanded vertically during the horizontal expansion of a vertically extensive cavernous zone, such as a section of a borehole.
Referring to the drawing, FIG. 1 shows a portion of a well borehole 1 which has been drilled through an overburden 2, comprising successively shallower earth formations, and opened into an oil shale formation 3 that contains a heat sensitive carbonate mineral. The oil shale formation that is placed in fluid communication with a portion of the borehole to be used in practicing the present invention, should be a formation containing a significant proportion, e.g., greater than 5 percent by weight, of heat sensitive carbonate mineral. Borehole 1 is equipped with a string of casing 4, which is bonded to the surrounding earth formations by cement 5.
Separate conduits for conveying fluids between a surface location and, respectively, relatively shallow and relatively deep depths within the oil shale are provided by tubing strings 7 and 8. Alternatively, such conduits may comprise two or more parallel strings of tubing and may be located in two or more well boreholes that intersect or extend into a common cavern within the oilshale. Such conduits can be installed and equipped by means of known procedures and devices and heat insulation (not shown) is preferably installed around at least those of such conduits that are used for the inflowing of hot fluid.
As indicated by FIG. 1, the vertically extensive cavern or opening that is expanded by the present process can comprise the borehole of a well that extends into an interval of oil shale that contains heat sensitive carbonatematerial. Such an interval preferably has a vertical thickness of at least about 100 feet. In the initial stages, such a borehole may have a generally cylindrical form, such as indicated by the dotted line 1a, and may comprise a relatively slender, generally vertical cavern within the oil shale. In operating the process with the equipment shown in FIG. 1, a hot aqueous fluid is flowed into contact with the wall of the cavern by inflowing hot aqueous gas and/or liquid through the annulus within pipe 8 (i.e., the space between pipes 7 and 8) and through adjacent perforations 6 at a relatively shallow depth within the carbonate mineralcontaining portion of the oil shale. The inflowing fluid such as hot water and/or steam flows downward along the face of the vertical interval of oil shale (along the wall of the borehole) and decomposes and dissolves the heat sensitive carbonate mineral material. The dissolving of water soluble material forms a liquid solution 9. This solution, which is usually mixed with at least some gas, such as carbon dioxide and gaseous hydrocarbon,
is out-flowed through pipe 7, which extends to a relatively low level within the borehole. The decomposing and dissolving of carbonate mineral components of the oil shale causes the spalling and caving in of particles 10 of the oil shale and causes a generally horizontal expansion of a rubble-containing cavernous zone of permeability within the oil shale.
Where the oil shale being treated contains a significant proportion of a mineral, such as a halite, which is water soluble in its natural form, the inflowing of hot aqueous fluid can advantageously be preceded by a circulation of aqueous liquid at a relatively low temperature, such as the wellhead temperature, the temperature of the source of the liquid or the like. In such a pretreatment, the circulating liquid may leach out significant portions of distributed layers or particles of the soluble mineral. This increases the surface area of exposed oil shale and/or weakens the support for layers or chunks of the oil shale. such a pretreatment circulation can advantageously be continued while the rate of dissolution is high, e.g., as indicated by the proportion of solute in the outflowing liquid. The so-circulated aqueous liquid can then be gradually or rapidly heated to the temperature selected for the inflowing hot aqueous liquid used to decompose heat sensitive carbonate material, with or without an interruption of the flow through the cavern.
When necessary or desirable the vertical expansion of the cavern can be inhibited by spotting and maintaining a relatively light and cool fluid 13 along the roof of the cavern. Such a fluid is preferably a gas and can in inflowed, or maintained substantially stationary, in and around the annulus within casing 4 (i.e., the space between pipe 8 and casing 4) and the upper portion of borehole 1 (below cement 5) to extend along the roof of the horizontally expanding cavern as the walls of the cavern more radially outward to and beyond the location shown at 1b.
The hot aqueous fluid used in the present cavernenlarging procedure is preferably steam, hot aqueous liquid (hot water) or a mixture of such fluids. The hot fluid is preferably inflowed at a temperature, e.g., at least about 250 F, that is significantly higher than the normal temperature of the subterranean oil shale formation. The heat transported by such a hot fluid converts the heat sensitive carbonate material to carbon dioxide and water vapor within portions of the normally impermeable oil shale matrix. Such a generation of gas causes localized fracturing and/or spalling of the oil shale.
The aqueous liquid component of the inflowing hot fluid dissolves water soluble mineral material and creates additional solid-free void space. This occurs along most, if not all, of the vertical extent of the flow path used in the present process. The spalling and dissolution causes a horizontal expansion of a rubblecontaining cavern. The inflowing hot aqueous fluid can comprise super heated, dry, or wet steam, or a mixture of such a steam with substantially any gas vapor or liquid, such as carbon dioxide, phenols, hydrocarbons, alcohols, halogenated hydrocarbons, acids, or the like, or with substantially any aqueous solution, such as an aqueous acid or base or solution or neutral salt. Where the inflowing fluid is substantially completely gaseous it should contain sufficient steam to provide a significant amount of aqueous liquid as it condenses within.
The inflowing hot aqueous fluid can be heated by means of surface located and/or downhole located, steam generators, water heaters, or the like. Alternatively, or additionally, such heating can be effected or supplemented in an insitu combustion within the oil shale formation. The temperature of the inflowing hot aqueous fluid can range from about 250? F to one sufficient to cause a relatively rapid oil shale pyrolysis, e.g., a temperature of from about 600 to 1000F.
The inflowing aqueous liquid phase of the hot aqueous fluid dissolves naturally water soluble minerals such as nahcolite, trona, halite, or the like, and/or water soluble decomposition products from a heat sensitive carbonate material, such as nahcolite, etc., to create solid-free space within the oil shale. Various water soluble minerals, such as nahocolite (NaI-ICO may dissolve prior to any thermal decomposition, if the pressure is sufficiently high at the temperature of the inflowing fluid. Alternatively, such minerals may be partially or wholly decomposed to gaseous fluids and sodium carbonate before dissolution.
Although the portion of oil shale formation which is treated in accordance with the present invention must contain a significant amount of heat sensitive carbonate material, it may contain sections, or vertical intervals of as much as several tens of feet thick, which are substantially devoid of heat sensitive and/or water soluble minerals. In such heterogeneous regions, the heat sensitive or soluble minerals are converted or dissolved and removed. Portions of the so-converted oil shale materials become incompetent and break into pieces under the existing local stress field. Such pieces, or chunks, of oil shale mineral materials tend to accumulate on top of ledges of oil shale that contains little or no heat sensitive or soluble material. The accumulation of weight from such chunks, together with the existing stress field, cause such ledges to break into pieces and fall to a lower level. The action of converting kerogen into shale oil materials such as gaseous and liquid hydrocarbons enhances such an operation and, where the oil shale is relatively lean with respect to heat sensitive and soluble materials, the use of hot aqueous fluid heat to a kerogen-pyrolyzing temperature is desirable. Also hydrocarbons can be extracted from the rubbled oil shale by solvent means such as by use of phenols, aromatic solvents, e.g., benzene, xylene, etc.
Due to mechanisms such as those mentioned above, the application of the present process causes a generally vertical cavernous zone to grow in a horizontal direction. The rate of growth will vary depending upon the heat sensitive and water soluble mineral content of the particular zone. The outer boundary of the zone will generally be very irregular with portions extending several tens of feet further than others. In order to enhance horizontal growth while injecting a hot aqueous fluid that is predominantly liquid, it is generally desirable to maintain most or all of the rubble-containing cavern full of liquid. Alternatively, when the injected hot aqueous fluid is steam, it is generally preferably to keep much of the rubble-containing kerogen filled with steam and/or gas.
A particularly suitable arrangement of flow paths to be used in the present process is shown in FIG. 2. At least two horizontally separated wells are opened into a region of oil shale that contains heat sensitive carbonate mineral and is located immediately above a layer or zone of oil shale or other earth formation material that is rich in water soluble mineral and/or heat sensitive carbonate mineral. Such wells are used to form an inflow path 14 and an outflow path 15 that are interconnected by a path extending through an areally extensive cavern 6. As indicated by the arrows, hot aqueous fluid is inflowed into contact with oil shale containing heat sensitive carbonate material at a relatively shallow depth, flowed down along a vertical section of such oil shale, flowed along the roof of a horizontally extensive cavern within such oil shale, and, liquid containing dissolved mineral material is removed from within the horizontally extensive cavern. Such a horizontally extensive cavern can advantageously be formed by means of mechanical fracturing, and/or solution mining techniques, for example, by one or more of such techniques described in the above mentioned copending patent applications.
A principle advantage of a flow path of the type shown in FIG. 2 is the heat economy and the fact that much larger volumes of oil shale can be rubbled per unit time than could be achieved by either a horizontal or vertical rubbling by itself. Relative to horizontal rubbling from a single well, the concurrent vertical and horizontal rubbling is capable of providing much higher oil production rates, particularly in the early stages of the process. Such a flow path can be utilized to produce a relatively cool fluid with much of the produced hydrocarbon and injected fluid being outflowed in the liquid phase. I I
A flow path of the type shown in FIG. 2 can be initiated between one or more pairs of wells. Initial communication is preferably achieved by fracturing or dissolving within the layer of water soluble material until fluid injected in one well can be produced from another. Hot aqueous fluid is then injected at the top of an injected well and fluid is produced from within a generally horizontal cavern or flow path through a production well. The upper portion of the injection well will enlarge laterally and the lower portion or rubble-containing cavern will enlarge vertically so that the permeable zone is expanded both laterally and vertically. It is in the lower region of the rubble-containing cavern that heat improvements are made. With such a flow path, the inflowing fluid preferably has a temperature below one at which the pyrolysis of kerogen is rapid. Where it is desired to rubble large volumes of oil shale while removing solid materials and preheating the shale for later pyrolysis, such a use of a relatively low temperature results in significant heat economy. If communication between different patterns of injection and production wells is desired the depth of the location from which liquid is produced can be kept relatively deep within the soluble layer so that the circulating fluid will containue to enlarge the areal extent of the dissolved zone.
Where communication between different well patterns is not desired, the production point and production rate can be adjusted to leave a substantially saturated liquid solution in the soluble layer in order to prevent its further growth.
Such a versatility with respect to the size and shape of the cavernous zones that are formed before and/or during a recovery of shale oil is a unique advantage of the present process. For example, where the oil shale is thick, large amounts of shale oil can be recovered from a series of zones that are vertically extensive but are horizontally spaced so that problems due to subsidence are avoided. For example, wells in a plurality of horizontally separated patterns that each contain one or more wells opening into a layer rich in water soluble minerals can be operated as described in connection with FIG. 2 to form horizontally expanding permeable zones and produce shale oil. The sizes of the permeable zones can be monitored by means of acoustic, electromagnetic the like measurements of the extents of the substantially void space and/or measurements of the volume of fluids that are contained into caverns. The horizontal expansion of the caverns can be controlled to provide an efficient recovery of oil from nonintersecting, generally vertically extensive zones that are spaced so that undisturbed columns capable of supporting the overburden are left between the depleted zones.
During the initial stages of expanding a rubblecontaining cavern in accordance with the present process, it is not necessary and is generally undesirable to use a temperature high enough to decompose a predominant proportion of the fluid-contacted heat sensitive carbonate material. It is preferable to keep the cavern substantially full of aqueous liquid in which the carbonate material is soluble. This tends to provide the best heat economy since it minimizes the decomposition reaction (which is an endothermic reaction that comsumes heat). In order to keep the cavern substantially filled with aqueous liquid it is preferable to maintain the pressure within the cavern above the decomposition pressure of the heat sensitive carbonate material at the temperature within the cavern. In general the pressure within the cavern cannot be kept high enough to prevent such a decomposition during an oil recovering stage. The retorting and hydrocarbon recovery is preferably conducted at a temperature above about 500 F, and at the depths at which oil shale is usually encountered, the pressure in the cavern cannot be high enough to prevent decomposition of heat sensitive carbonate material at such a temperature, without a danger of creating large scale fractures which are extended into locations in which fractures are undesirable.
When one or a plurality of generally vertically extensive permeable zones have been expanded horizontally to substantially the extent desired, the circulation of fluid within throne zones or caverns is preferably adjusted to minimize the rate of horizontal growth and/or maximize the rate of oil recovery. Such an adjustment can be effected by increasing the temperature and/or decreasing the aqueous liquid content of the fluid within the cavern. A higher temperature tends to increase the rate of oil recovery (particularly with respect to the gaseous components of shale oil). Altematively, a decrease in the aqueous liquid content tends to reduce the rate of dissolution of soluble mineral. Where the removal of solid material from the oil shale is confined to a removal of the fluid products of the pyrolysis reaction and/or the CO and water vapor produced by the decomposition of heat sensitive carbonates, the volume of the depleted oil shale tends to be sufficient, relative to the volume of solids that are removed, to terminate the growth of the permeable zone (unless the oil shale is one that contains an exceptionally large proportion of heat sensitive carbonate mineral). The aqueous liquid content of the fluid within the cavern can be reduced by, for example, circulating substantially dry steam, or a mixture of a dry steam and e. g., carbon dioxide, at a rate and temperature at which the outflowing fluid is predominately gaseous and the aqueous liquid lift within the cavern contains a relatively high proportion of inert inorganic solute.
FIG. 3 shows downhole equipment of the type shown in FIG. 1 arranged to effect a downhole separation of the gaseous and liquid phases of the fluid being produced. Particularly when the concentration of heat sensitive carbonate material is relatively high, and/or the temperature of the inflowing hot aqueous fluid is relatively high, a significant amount of gaseous carbon dioxide and water will be formed. However, to the extent that it is feasible, it is desirable to produce a relatively cool liquid phase fluid that contains a significant proportion of produced shale oil hydrocarbon. In the arrangement shown in FIG. 3, borehole 20 is equipped with pipe strings 21, 22 and 23. Some or all of such pipes are preferably thermally insulated, as indicated by coatings 24 on pipes 21 and 22. Pipe 21, through which the hot aqueous fluid is inflowed, opens into the borehole at a relatively shallow depth. Pipe 22 extends to an intermediate depth and is used to outflow fluid that is relatively cool but is predominately gaseous. Pipe 23 extends to a relatively deep depth, is preferably equipped with downhole pumping means (not shown), and is used to outflow fluid that is predominately liquid. The vertical section of borehole between the ends of pipes 22 and 23 serves as a downhole gravity of separation chamber.
Steam or a mixture of steam and hot aqueous liquid (hot water) is inflowed through pipe 21. The inflowing hottest and lightest gas tends to remain above the cooler and heavier gas and in situ generated carbon dioxide. The cooler gases outflow through pipe 22 while the hotter and lighter inflowing gases tend to flow along the walls of the cavern. Where desirable a relatively light and cool gas, such as methane, hydrogen, etc., can be maintained substantially static, or slowly injected, through and around the upper portion of the borehole and cavern.
Once the rubbled oil shale cavern has been established and the heat sensitive minerals and water-soluble carbonates removed as an aqueous solution, the hydrocarbons (oil) can be recovered by suitable means such as by contacting the rubbled oil shale within the cavern with a pyrolyzing fluid to effect decomposition of the kerogens to hydrocarbon which is removed from the formation. .In recovering the hydrocarbons, the pyrolyzing fluid can be injected (FIG. 1) via 7 and recovered via tubing 8 visa versa and in a dual sytem as shown in FIG. 3 the pyrolyzing fluid such as steam can be injected via tubing string 21 and the hydrocarbons recovered via 22 or the process can be reversed.
It is understood that various changes in the detailed described to explain the invention can be made by per sons skilled in the art within the scope of the invention as expressed in the appended claims.
I claim as my invention: 7 1. In a process for expanding a zone of permeability within a subterranean oil shale by forming a permeable zone within a portion that contains heat sensitive carbonate mineral and circulating hot aqueous fluid within the permeable zone, the improvement which comprises:
inflowing hot aqueous fluid into contact with a subterranean portion of oil shale that contains heat sensitive carbonate mineral at a relatively shallow depth, the temperature of said inflowing fluid being high enough to pyrolyze oil shale;
flowing hot aqueous fluid downward along a vertically extensive portion of oil shale that contains heat sensitive carbonate mineral, from said relatively shallow depth to a deeper depth;
outflowing an aqueous solution of mineral material from a relatively deep depth, in order to cause a horizontal expansion of rubble-containing cavemous zone within said oil shale;
adjusting the rate of said fluid inflows and outflows so as to keep a substantial proportion of the rubble containing cavern filled with fluid; and recovering shale oil with said outflowing fluid.
2. In a process for expanding a zone of permeability within a subterranean oil shale by forming a cavern within a portion-that contains heat sensitive carbonate mineral and circulating hot aqueous fluid within the cavern, the improvement which comprises:
inflowing hot aqueous fluid into contact with a subterranean portion of oil shale that contains heat sensitive carbonate mineral at a relatively shallow depth, the temperature of said inflowing fluid being high enough to pyrolyze oil shale; flowing hot aqueous fluid downward along a vertically extensive portion of oil shale that contains heat sensitive carbonate mineral, from said relatively shallow depth to a deeper depth;
outflowing an aqueous solution of mineral material from a relatively deep depth, in order to cause a horizontal expansion of a rubble-containing cavernous zone within said oil shale;
outflowing a substantially gaseous fluid from the rubble-containing cavern at an intermediate depth between the depth of said inflow of hot aqueous fluid and said outflow of aqueous liquid solution; and recovering shale oil with said outflowing fluid.
3. In a process for expanding a zone of permeability within a subterranean oil shale by forming a cavern within a portion that contains heat sensitive carbonate mineral and circulating hot aqueous fluid within the cavern, the improvement which comprises:
inflowing hot aqueous fluid into contact with a subterranean portion of oil shale that contains heat sensitive carbonate mineral at a relatively shallow depth, the temperature of said inflowing fluid being high enough to pyrolyze oil shale;
flowing a mixture of a hot aqueous fluid, gaseous carbon dioxide and hydrocarbon downward along a vertically extensive portion of oil shale that contains heat sensitive carbonate mineral, from said relatively shallow depth to a deeper depth;
outflowing an aqueous solution of mineral material from a relatively deep depth, in order to cause a horizontal expansion of a rubble-containing cavernous zone within said oil shale; and
recovering shale oil with said outflowing fluid.
4. A process of expanding a fluid permeable opening within a subterranean oil shale formation, comprising:
establishing separate paths of fluid communication between a surface location and upper and lower portions of a relatively solids-free opening within a subterranean oil shale formation that contains heat sensitive carbonate material;
inflowing relatively hot and relatively low density aqueous fluid into contact with the oil shale around the upper portion of said opening at a temperature sufiicient to cause a localized removal of solid material from the oil shale;
removing cooler and heavier fluid from the lower portion of the opening within said oil shale formation at a rate correlated with the rate of fluid inflow to maintain a layer of relatively hot and low density aqueous fluid above a layer of relatively cooler and higher density aqueous solution of mineral material; and
continuing said fluid circulation to cause a generally horizontal expansion of the opening within said oil shale formation due to a decomposition dissolution of solid components of the oil shale.
5. The process of claim 4 in which said subterranean oil shale formation contains at least about 5 percent by weight of heat sensitive carbonate material.
6. The process of claim 4 in which:
said solids-free opening and at least one of said paths of fluid communication is extended into an areally extensive opening within an adjacent underlying zone that is rich in water soluble mineral; and said fluid circulation is adjusted to cause a generally vertical expansion of said underlying opening concurrent with said generally horizontal expansion.
|Cited Patent||Filing date||Publication date||Applicant||Title|
|US2969226 *||Jan 19, 1959||Jan 24, 1961||Pyrochem Corp||Pendant parting petro pyrolysis process|
|US2979317 *||Aug 12, 1959||Apr 11, 1961||Fmc Corp||Solution mining of trona|
|US3050290 *||Oct 30, 1959||Aug 21, 1962||Fmc Corp||Method of recovering sodium values by solution mining of trona|
|US3309140 *||Nov 28, 1962||Mar 14, 1967||Utah Construction & Mining Co||Leaching of uranium ore in situ|
|US3405974 *||Feb 21, 1966||Oct 15, 1968||Intermountain Res & Dev Corp||Process of underground salt recovery|
|US3455383 *||Apr 24, 1968||Jul 15, 1969||Shell Oil Co||Method of producing fluidized material from a subterranean formation|
|US3501201 *||Oct 30, 1968||Mar 17, 1970||Shell Oil Co||Method of producing shale oil from a subterranean oil shale formation|
|US3516495 *||Nov 29, 1967||Jun 23, 1970||Exxon Research Engineering Co||Recovery of shale oil|
|US3572838 *||Jul 7, 1969||Mar 30, 1971||Shell Oil Co||Recovery of aluminum compounds and oil from oil shale formations|
|Citing Patent||Filing date||Publication date||Applicant||Title|
|US3880238 *||Jul 18, 1974||Apr 29, 1975||Shell Oil Co||Solvent/non-solvent pyrolysis of subterranean oil shale|
|US3888307 *||Aug 29, 1974||Jun 10, 1975||Shell Oil Co||Heating through fractures to expand a shale oil pyrolyzing cavern|
|US4026360 *||Aug 12, 1976||May 31, 1977||Shell Oil Company||Hydrothermally forming a flow barrier in a leached subterranean oil shale formation|
|US4059308 *||Nov 15, 1976||Nov 22, 1977||Trw Inc.||Pressure swing recovery system for oil shale deposits|
|US4065183 *||Nov 15, 1976||Dec 27, 1977||Trw Inc.||Recovery system for oil shale deposits|
|US4083604 *||Nov 15, 1976||Apr 11, 1978||Trw Inc.||Thermomechanical fracture for recovery system in oil shale deposits|
|US4545891 *||Mar 30, 1982||Oct 8, 1985||Trw Inc.||Extraction and upgrading of fossil fuels using fused caustic and acid solutions|
|US4688637 *||Feb 27, 1987||Aug 25, 1987||Theis Ralph W||Method for induced flow recovery of shallow crude oil deposits|
|US4815790 *||May 13, 1988||Mar 28, 1989||Natec, Ltd.||Nahcolite solution mining process|
|US5059307 *||Oct 11, 1989||Oct 22, 1991||Trw Inc.||Process for upgrading coal|
|US5085764 *||Dec 19, 1989||Feb 4, 1992||Trw Inc.||Process for upgrading coal|
|US5588713 *||Dec 20, 1995||Dec 31, 1996||Stevenson; Tom D.||Process for making sodium bicarbonate from Nahcolite-rich solutions|
|US7040397||Apr 24, 2002||May 9, 2006||Shell Oil Company||Thermal processing of an oil shale formation to increase permeability of the formation|
|US7100994 *||Oct 24, 2002||Sep 5, 2006||Shell Oil Company||Producing hydrocarbons and non-hydrocarbon containing materials when treating a hydrocarbon containing formation|
|US7207395||Jan 30, 2004||Apr 24, 2007||Cdx Gas, Llc||Method and system for testing a partially formed hydrocarbon well for evaluation and well planning refinement|
|US7222670||Feb 27, 2004||May 29, 2007||Cdx Gas, Llc||System and method for multiple wells from a common surface location|
|US7264048||Apr 21, 2003||Sep 4, 2007||Cdx Gas, Llc||Slot cavity|
|US7360595 *||May 8, 2002||Apr 22, 2008||Cdx Gas, Llc||Method and system for underground treatment of materials|
|US7571771||May 31, 2005||Aug 11, 2009||Cdx Gas, Llc||Cavity well system|
|US7640987||Aug 17, 2005||Jan 5, 2010||Halliburton Energy Services, Inc.||Communicating fluids with a heated-fluid generation system|
|US7644765||Oct 19, 2007||Jan 12, 2010||Shell Oil Company||Heating tar sands formations while controlling pressure|
|US7644993||Mar 22, 2007||Jan 12, 2010||Exxonmobil Upstream Research Company||In situ co-development of oil shale with mineral recovery|
|US7673681||Oct 19, 2007||Mar 9, 2010||Shell Oil Company||Treating tar sands formations with karsted zones|
|US7673786||Apr 20, 2007||Mar 9, 2010||Shell Oil Company||Welding shield for coupling heaters|
|US7677310||Oct 19, 2007||Mar 16, 2010||Shell Oil Company||Creating and maintaining a gas cap in tar sands formations|
|US7677314||Oct 19, 2007||Mar 16, 2010||Shell Oil Company||Method of condensing vaporized water in situ to treat tar sands formations|
|US7681647||Oct 19, 2007||Mar 23, 2010||Shell Oil Company||Method of producing drive fluid in situ in tar sands formations|
|US7683296||Apr 20, 2007||Mar 23, 2010||Shell Oil Company||Adjusting alloy compositions for selected properties in temperature limited heaters|
|US7703513||Oct 19, 2007||Apr 27, 2010||Shell Oil Company||Wax barrier for use with in situ processes for treating formations|
|US7717171||Oct 19, 2007||May 18, 2010||Shell Oil Company||Moving hydrocarbons through portions of tar sands formations with a fluid|
|US7730945||Oct 19, 2007||Jun 8, 2010||Shell Oil Company||Using geothermal energy to heat a portion of a formation for an in situ heat treatment process|
|US7730946||Oct 19, 2007||Jun 8, 2010||Shell Oil Company||Treating tar sands formations with dolomite|
|US7730947||Oct 19, 2007||Jun 8, 2010||Shell Oil Company||Creating fluid injectivity in tar sands formations|
|US7735935||Jun 1, 2007||Jun 15, 2010||Shell Oil Company||In situ thermal processing of an oil shale formation containing carbonate minerals|
|US7770643||Oct 10, 2006||Aug 10, 2010||Halliburton Energy Services, Inc.||Hydrocarbon recovery using fluids|
|US7785427||Apr 20, 2007||Aug 31, 2010||Shell Oil Company||High strength alloys|
|US7793722||Apr 20, 2007||Sep 14, 2010||Shell Oil Company||Non-ferromagnetic overburden casing|
|US7798220||Apr 18, 2008||Sep 21, 2010||Shell Oil Company||In situ heat treatment of a tar sands formation after drive process treatment|
|US7798221||May 31, 2007||Sep 21, 2010||Shell Oil Company||In situ recovery from a hydrocarbon containing formation|
|US7809538||Jan 13, 2006||Oct 5, 2010||Halliburton Energy Services, Inc.||Real time monitoring and control of thermal recovery operations for heavy oil reservoirs|
|US7831134||Apr 21, 2006||Nov 9, 2010||Shell Oil Company||Grouped exposed metal heaters|
|US7832482||Oct 10, 2006||Nov 16, 2010||Halliburton Energy Services, Inc.||Producing resources using steam injection|
|US7832484||Apr 18, 2008||Nov 16, 2010||Shell Oil Company||Molten salt as a heat transfer fluid for heating a subsurface formation|
|US7841401||Oct 19, 2007||Nov 30, 2010||Shell Oil Company||Gas injection to inhibit migration during an in situ heat treatment process|
|US7841408||Apr 18, 2008||Nov 30, 2010||Shell Oil Company||In situ heat treatment from multiple layers of a tar sands formation|
|US7841425||Apr 18, 2008||Nov 30, 2010||Shell Oil Company||Drilling subsurface wellbores with cutting structures|
|US7845411||Oct 19, 2007||Dec 7, 2010||Shell Oil Company||In situ heat treatment process utilizing a closed loop heating system|
|US7849922||Apr 18, 2008||Dec 14, 2010||Shell Oil Company||In situ recovery from residually heated sections in a hydrocarbon containing formation|
|US7860377||Apr 21, 2006||Dec 28, 2010||Shell Oil Company||Subsurface connection methods for subsurface heaters|
|US7866385||Apr 20, 2007||Jan 11, 2011||Shell Oil Company||Power systems utilizing the heat of produced formation fluid|
|US7866386||Oct 13, 2008||Jan 11, 2011||Shell Oil Company||In situ oxidation of subsurface formations|
|US7866388||Oct 13, 2008||Jan 11, 2011||Shell Oil Company||High temperature methods for forming oxidizer fuel|
|US7912358||Apr 20, 2007||Mar 22, 2011||Shell Oil Company||Alternate energy source usage for in situ heat treatment processes|
|US7931086||Apr 18, 2008||Apr 26, 2011||Shell Oil Company||Heating systems for heating subsurface formations|
|US7942197||Apr 21, 2006||May 17, 2011||Shell Oil Company||Methods and systems for producing fluid from an in situ conversion process|
|US7942203||Jan 4, 2010||May 17, 2011||Shell Oil Company||Thermal processes for subsurface formations|
|US7950453||Apr 18, 2008||May 31, 2011||Shell Oil Company||Downhole burner systems and methods for heating subsurface formations|
|US7986869||Apr 21, 2006||Jul 26, 2011||Shell Oil Company||Varying properties along lengths of temperature limited heaters|
|US8011451||Oct 13, 2008||Sep 6, 2011||Shell Oil Company||Ranging methods for developing wellbores in subsurface formations|
|US8027571||Apr 21, 2006||Sep 27, 2011||Shell Oil Company||In situ conversion process systems utilizing wellbores in at least two regions of a formation|
|US8042610||Apr 18, 2008||Oct 25, 2011||Shell Oil Company||Parallel heater system for subsurface formations|
|US8070840||Apr 21, 2006||Dec 6, 2011||Shell Oil Company||Treatment of gas from an in situ conversion process|
|US8082995||Nov 14, 2008||Dec 27, 2011||Exxonmobil Upstream Research Company||Optimization of untreated oil shale geometry to control subsidence|
|US8083813||Apr 20, 2007||Dec 27, 2011||Shell Oil Company||Methods of producing transportation fuel|
|US8087460||Mar 7, 2008||Jan 3, 2012||Exxonmobil Upstream Research Company||Granular electrical connections for in situ formation heating|
|US8104537||Dec 15, 2009||Jan 31, 2012||Exxonmobil Upstream Research Company||Method of developing subsurface freeze zone|
|US8113272||Oct 13, 2008||Feb 14, 2012||Shell Oil Company||Three-phase heaters with common overburden sections for heating subsurface formations|
|US8122955||Apr 18, 2008||Feb 28, 2012||Exxonmobil Upstream Research Company||Downhole burners for in situ conversion of organic-rich rock formations|
|US8146661||Oct 13, 2008||Apr 3, 2012||Shell Oil Company||Cryogenic treatment of gas|
|US8146664||May 21, 2008||Apr 3, 2012||Exxonmobil Upstream Research Company||Utilization of low BTU gas generated during in situ heating of organic-rich rock|
|US8146669||Oct 13, 2008||Apr 3, 2012||Shell Oil Company||Multi-step heater deployment in a subsurface formation|
|US8151877||Apr 18, 2008||Apr 10, 2012||Exxonmobil Upstream Research Company||Downhole burner wells for in situ conversion of organic-rich rock formations|
|US8151880||Dec 9, 2010||Apr 10, 2012||Shell Oil Company||Methods of making transportation fuel|
|US8151884||Oct 10, 2007||Apr 10, 2012||Exxonmobil Upstream Research Company||Combined development of oil shale by in situ heating with a deeper hydrocarbon resource|
|US8151907||Apr 10, 2009||Apr 10, 2012||Shell Oil Company||Dual motor systems and non-rotating sensors for use in developing wellbores in subsurface formations|
|US8162059||Oct 13, 2008||Apr 24, 2012||Shell Oil Company||Induction heaters used to heat subsurface formations|
|US8162405||Apr 10, 2009||Apr 24, 2012||Shell Oil Company||Using tunnels for treating subsurface hydrocarbon containing formations|
|US8172335||Apr 10, 2009||May 8, 2012||Shell Oil Company||Electrical current flow between tunnels for use in heating subsurface hydrocarbon containing formations|
|US8177305||Apr 10, 2009||May 15, 2012||Shell Oil Company||Heater connections in mines and tunnels for use in treating subsurface hydrocarbon containing formations|
|US8191630||Apr 28, 2010||Jun 5, 2012||Shell Oil Company||Creating fluid injectivity in tar sands formations|
|US8192682||Apr 26, 2010||Jun 5, 2012||Shell Oil Company||High strength alloys|
|US8196658||Oct 13, 2008||Jun 12, 2012||Shell Oil Company||Irregular spacing of heat sources for treating hydrocarbon containing formations|
|US8200072||Oct 24, 2003||Jun 12, 2012||Shell Oil Company||Temperature limited heaters for heating subsurface formations or wellbores|
|US8220539||Oct 9, 2009||Jul 17, 2012||Shell Oil Company||Controlling hydrogen pressure in self-regulating nuclear reactors used to treat a subsurface formation|
|US8224163||Oct 24, 2003||Jul 17, 2012||Shell Oil Company||Variable frequency temperature limited heaters|
|US8224164||Oct 24, 2003||Jul 17, 2012||Shell Oil Company||Insulated conductor temperature limited heaters|
|US8224165||Apr 21, 2006||Jul 17, 2012||Shell Oil Company||Temperature limited heater utilizing non-ferromagnetic conductor|
|US8225866||Jul 21, 2010||Jul 24, 2012||Shell Oil Company||In situ recovery from a hydrocarbon containing formation|
|US8230927||May 16, 2011||Jul 31, 2012||Shell Oil Company||Methods and systems for producing fluid from an in situ conversion process|
|US8230929||Mar 17, 2009||Jul 31, 2012||Exxonmobil Upstream Research Company||Methods of producing hydrocarbons for substantially constant composition gas generation|
|US8233782||Sep 29, 2010||Jul 31, 2012||Shell Oil Company||Grouped exposed metal heaters|
|US8238730||Oct 24, 2003||Aug 7, 2012||Shell Oil Company||High voltage temperature limited heaters|
|US8240774||Oct 13, 2008||Aug 14, 2012||Shell Oil Company||Solution mining and in situ treatment of nahcolite beds|
|US8256512||Oct 9, 2009||Sep 4, 2012||Shell Oil Company||Movable heaters for treating subsurface hydrocarbon containing formations|
|US8261832||Oct 9, 2009||Sep 11, 2012||Shell Oil Company||Heating subsurface formations with fluids|
|US8267170||Oct 9, 2009||Sep 18, 2012||Shell Oil Company||Offset barrier wells in subsurface formations|
|US8267185||Oct 9, 2009||Sep 18, 2012||Shell Oil Company||Circulated heated transfer fluid systems used to treat a subsurface formation|
|US8272455||Oct 13, 2008||Sep 25, 2012||Shell Oil Company||Methods for forming wellbores in heated formations|
|US8276661||Oct 13, 2008||Oct 2, 2012||Shell Oil Company||Heating subsurface formations by oxidizing fuel on a fuel carrier|
|US8281861||Oct 9, 2009||Oct 9, 2012||Shell Oil Company||Circulated heated transfer fluid heating of subsurface hydrocarbon formations|
|US8291974||Oct 31, 2007||Oct 23, 2012||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8297350||Oct 31, 2007||Oct 30, 2012||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface|
|US8297377||Jul 29, 2003||Oct 30, 2012||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8316966||Oct 31, 2007||Nov 27, 2012||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8327681||Apr 18, 2008||Dec 11, 2012||Shell Oil Company||Wellbore manufacturing processes for in situ heat treatment processes|
|US8327932||Apr 9, 2010||Dec 11, 2012||Shell Oil Company||Recovering energy from a subsurface formation|
|US8333245||Sep 17, 2002||Dec 18, 2012||Vitruvian Exploration, Llc||Accelerated production of gas from a subterranean zone|
|US8353347||Oct 9, 2009||Jan 15, 2013||Shell Oil Company||Deployment of insulated conductors for treating subsurface formations|
|US8355623||Apr 22, 2005||Jan 15, 2013||Shell Oil Company||Temperature limited heaters with high power factors|
|US8371399||Oct 31, 2007||Feb 12, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8376039||Nov 21, 2008||Feb 19, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8376052||Nov 1, 2001||Feb 19, 2013||Vitruvian Exploration, Llc||Method and system for surface production of gas from a subterranean zone|
|US8381815||Apr 18, 2008||Feb 26, 2013||Shell Oil Company||Production from multiple zones of a tar sands formation|
|US8434555||Apr 9, 2010||May 7, 2013||Shell Oil Company||Irregular pattern treatment of a subsurface formation|
|US8434568||Jul 22, 2005||May 7, 2013||Vitruvian Exploration, Llc||Method and system for circulating fluid in a well system|
|US8448707||Apr 9, 2010||May 28, 2013||Shell Oil Company||Non-conducting heater casings|
|US8459359||Apr 18, 2008||Jun 11, 2013||Shell Oil Company||Treating nahcolite containing formations and saline zones|
|US8464784||Oct 31, 2007||Jun 18, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8469119||Oct 31, 2007||Jun 25, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8479812||Oct 31, 2007||Jul 9, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8485252||Jul 11, 2012||Jul 16, 2013||Shell Oil Company||In situ recovery from a hydrocarbon containing formation|
|US8505620||Oct 31, 2007||Aug 13, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8511372||Oct 31, 2007||Aug 20, 2013||Vitruvian Exploration, Llc||Method and system for accessing subterranean deposits from the surface|
|US8536497||Oct 13, 2008||Sep 17, 2013||Shell Oil Company||Methods for forming long subsurface heaters|
|US8540020||Apr 21, 2010||Sep 24, 2013||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|
|US8555971||May 31, 2012||Oct 15, 2013||Shell Oil Company||Treating tar sands formations with dolomite|
|US8562078||Nov 25, 2009||Oct 22, 2013||Shell Oil Company||Hydrocarbon production from mines and tunnels used in treating subsurface hydrocarbon containing formations|
|US8579031||May 17, 2011||Nov 12, 2013||Shell Oil Company||Thermal processes for subsurface formations|
|US8596355||Dec 10, 2010||Dec 3, 2013||Exxonmobil Upstream Research Company||Optimized well spacing for in situ shale oil development|
|US8606091||Oct 20, 2006||Dec 10, 2013||Shell Oil Company||Subsurface heaters with low sulfidation rates|
|US8608249||Apr 26, 2010||Dec 17, 2013||Shell Oil Company||In situ thermal processing of an oil shale formation|
|US8616279||Jan 7, 2010||Dec 31, 2013||Exxonmobil Upstream Research Company||Water treatment following shale oil production by in situ heating|
|US8616280||Jun 17, 2011||Dec 31, 2013||Exxonmobil Upstream Research Company||Wellbore mechanical integrity for in situ pyrolysis|
|US8622127||Jun 17, 2011||Jan 7, 2014||Exxonmobil Upstream Research Company||Olefin reduction for in situ pyrolysis oil generation|
|US8622133||Mar 7, 2008||Jan 7, 2014||Exxonmobil Upstream Research Company||Resistive heater for in situ formation heating|
|US8627887||Dec 8, 2008||Jan 14, 2014||Shell Oil Company||In situ recovery from a hydrocarbon containing formation|
|US8631866||Apr 8, 2011||Jan 21, 2014||Shell Oil Company||Leak detection in circulated fluid systems for heating subsurface formations|
|US8636323||Nov 25, 2009||Jan 28, 2014||Shell Oil Company||Mines and tunnels for use in treating subsurface hydrocarbon containing formations|
|US8641150||Dec 11, 2009||Feb 4, 2014||Exxonmobil Upstream Research Company||In situ co-development of oil shale with mineral recovery|
|US8662175||Apr 18, 2008||Mar 4, 2014||Shell Oil Company||Varying properties of in situ heat treatment of a tar sands formation based on assessed viscosities|
|US8701768||Apr 8, 2011||Apr 22, 2014||Shell Oil Company||Methods for treating hydrocarbon formations|
|US8701769||Apr 8, 2011||Apr 22, 2014||Shell Oil Company||Methods for treating hydrocarbon formations based on geology|
|US8739874||Apr 8, 2011||Jun 3, 2014||Shell Oil Company||Methods for heating with slots in hydrocarbon formations|
|US8752904||Apr 10, 2009||Jun 17, 2014||Shell Oil Company||Heated fluid flow in mines and tunnels used in heating subsurface hydrocarbon containing formations|
|US8770284||Apr 19, 2013||Jul 8, 2014||Exxonmobil Upstream Research Company||Systems and methods of detecting an intersection between a wellbore and a subterranean structure that includes a marker material|
|US8789586||Jul 12, 2013||Jul 29, 2014||Shell Oil Company||In situ recovery from a hydrocarbon containing formation|
|US8791396||Apr 18, 2008||Jul 29, 2014||Shell Oil Company||Floating insulated conductors for heating subsurface formations|
|US8813840||Aug 12, 2013||Aug 26, 2014||Efective Exploration, LLC||Method and system for accessing subterranean deposits from the surface and tools therefor|
|US8820406||Apr 8, 2011||Sep 2, 2014||Shell Oil Company||Electrodes for electrical current flow heating of subsurface formations with conductive material in wellbore|
|US8833453||Apr 8, 2011||Sep 16, 2014||Shell Oil Company||Electrodes for electrical current flow heating of subsurface formations with tapered copper thickness|
|US8851170||Apr 9, 2010||Oct 7, 2014||Shell Oil Company||Heater assisted fluid treatment of a subsurface formation|
|US8857506||May 24, 2013||Oct 14, 2014||Shell Oil Company||Alternate energy source usage methods for in situ heat treatment processes|
|US8863839||Nov 15, 2010||Oct 21, 2014||Exxonmobil Upstream Research Company||Enhanced convection for in situ pyrolysis of organic-rich rock formations|
|US8875789||Aug 8, 2011||Nov 4, 2014||Exxonmobil Upstream Research Company||Process for producing hydrocarbon fluids combining in situ heating, a power plant and a gas plant|
|US8881806||Oct 9, 2009||Nov 11, 2014||Shell Oil Company||Systems and methods for treating a subsurface formation with electrical conductors|
|US9016370||Apr 6, 2012||Apr 28, 2015||Shell Oil Company||Partial solution mining of hydrocarbon containing layers prior to in situ heat treatment|
|US9022109||Jan 21, 2014||May 5, 2015||Shell Oil Company||Leak detection in circulated fluid systems for heating subsurface formations|
|US9022118||Oct 9, 2009||May 5, 2015||Shell Oil Company||Double insulated heaters for treating subsurface formations|
|US9033042||Apr 8, 2011||May 19, 2015||Shell Oil Company||Forming bitumen barriers in subsurface hydrocarbon formations|
|US9051829||Oct 9, 2009||Jun 9, 2015||Shell Oil Company||Perforated electrical conductors for treating subsurface formations|
|US9080441||Oct 26, 2012||Jul 14, 2015||Exxonmobil Upstream Research Company||Multiple electrical connections to optimize heating for in situ pyrolysis|
|US9127523||Apr 8, 2011||Sep 8, 2015||Shell Oil Company||Barrier methods for use in subsurface hydrocarbon formations|
|US9127538||Apr 8, 2011||Sep 8, 2015||Shell Oil Company||Methodologies for treatment of hydrocarbon formations using staged pyrolyzation|
|US9129728||Oct 9, 2009||Sep 8, 2015||Shell Oil Company||Systems and methods of forming subsurface wellbores|
|US9181780||Apr 18, 2008||Nov 10, 2015||Shell Oil Company||Controlling and assessing pressure conditions during treatment of tar sands formations|
|US9309755||Oct 4, 2012||Apr 12, 2016||Shell Oil Company||Thermal expansion accommodation for circulated fluid systems used to heat subsurface formations|
|US9347302||Nov 12, 2013||May 24, 2016||Exxonmobil Upstream Research Company||Resistive heater for in situ formation heating|
|US9394772||Sep 17, 2014||Jul 19, 2016||Exxonmobil Upstream Research Company||Systems and methods for in situ resistive heating of organic matter in a subterranean formation|
|US9399905||May 4, 2015||Jul 26, 2016||Shell Oil Company||Leak detection in circulated fluid systems for heating subsurface formations|
|US9512699||Jul 30, 2014||Dec 6, 2016||Exxonmobil Upstream Research Company||Systems and methods for regulating an in situ pyrolysis process|
|US9528322||Jun 16, 2014||Dec 27, 2016||Shell Oil Company||Dual motor systems and non-rotating sensors for use in developing wellbores in subsurface formations|
|US9551209||Jun 6, 2014||Jan 24, 2017||Effective Exploration, LLC||System and method for accessing subterranean deposits|
|US9644466||Oct 15, 2015||May 9, 2017||Exxonmobil Upstream Research Company||Method of recovering hydrocarbons within a subsurface formation using electric current|
|US9739122||Oct 15, 2015||Aug 22, 2017||Exxonmobil Upstream Research Company||Mitigating the effects of subsurface shunts during bulk heating of a subsurface formation|
|US20020029885 *||Apr 24, 2001||Mar 14, 2002||De Rouffignac Eric Pierre||In situ thermal processing of a coal formation using a movable heating element|
|US20020038069 *||Apr 24, 2001||Mar 28, 2002||Wellington Scott Lee||In situ thermal processing of a coal formation to produce a mixture of olefins, oxygenated hydrocarbons, and aromatic hydrocarbons|
|US20020038711 *||Apr 24, 2001||Apr 4, 2002||Rouffignac Eric Pierre De||In situ thermal processing of a hydrocarbon containing formation using heat sources positioned within open wellbores|
|US20020040780 *||Apr 24, 2001||Apr 11, 2002||Wellington Scott Lee||In situ thermal processing of a hydrocarbon containing formation to produce a selected mixture|
|US20020043365 *||Apr 24, 2001||Apr 18, 2002||Berchenko Ilya Emil||In situ thermal processing of a coal formation with a selected ratio of heat sources to production wells|
|US20020056551 *||Apr 24, 2001||May 16, 2002||Wellington Scott Lee||In situ thermal processing of a hydrocarbon containing formation in a reducing environment|
|US20020057905 *||Apr 24, 2001||May 16, 2002||Wellington Scott Lee||In situ thermal processing of a hydrocarbon containing formation to produce oxygen containing formation fluids|
|US20020077515 *||Apr 24, 2001||Jun 20, 2002||Wellington Scott Lee||In situ thermal processing of a hydrocarbon containing formation to produce hydrocarbons having a selected carbon number range|
|US20020084074 *||Sep 24, 2001||Jul 4, 2002||De Rouffignac Eric Pierre||In situ thermal processing of a hydrocarbon containing formation to increase a porosity of the formation|
|US20030102124 *||Apr 24, 2002||Jun 5, 2003||Vinegar Harold J.||In situ thermal processing of a blending agent from a relatively permeable formation|
|US20030102125 *||Apr 24, 2002||Jun 5, 2003||Wellington Scott Lee||In situ thermal processing of a relatively permeable formation in a reducing environment|
|US20030102130 *||Apr 24, 2002||Jun 5, 2003||Vinegar Harold J.||In situ thermal recovery from a relatively permeable formation with quality control|
|US20030131994 *||Apr 24, 2002||Jul 17, 2003||Vinegar Harold J.||In situ thermal processing and solution mining of an oil shale formation|
|US20030155111 *||Oct 24, 2002||Aug 21, 2003||Shell Oil Co||In situ thermal processing of a tar sands formation|
|US20030205378 *||Oct 24, 2002||Nov 6, 2003||Wellington Scott Lee||In situ recovery from lean and rich zones in a hydrocarbon containing formation|
|US20030209348 *||Apr 24, 2002||Nov 13, 2003||Ward John Michael||In situ thermal processing and remediation of an oil shale formation|
|US20050051327 *||Apr 23, 2004||Mar 10, 2005||Vinegar Harold J.||Thermal processes for subsurface formations|
|US20070137857 *||Apr 21, 2006||Jun 21, 2007||Vinegar Harold J||Low temperature monitoring system for subsurface barriers|
|US20100147521 *||Oct 9, 2009||Jun 17, 2010||Xueying Xie||Perforated electrical conductors for treating subsurface formations|
|CN101313126B||Oct 20, 2006||Jan 16, 2013||国际壳牌研究有限公司||Solution mining systems and methods for treating hydrocarbon containing formations|
|U.S. Classification||166/272.1, 299/4, 166/272.6|
|International Classification||E21B36/00, E21B43/28, E21B43/00, E21B43/16, E21B43/24|
|Cooperative Classification||E21B43/24, E21B36/00, E21B43/281|
|European Classification||E21B43/24, E21B43/28B, E21B36/00|