Abstract: Formation stability surrounding a deviated wellbore penetrating a hydrocarbon reservoir is improved by alternately injecting higher and lower density consolidating materials, the higher density material improving stability in the formation primarily on the low side of the wellbore and the lower density material improving stability in the formation primarily on the high side of the wellbore.

Abstract: A method for repairing damaged sections of an oil well includes the use of a combination of two fluids, pumped simultaneously to allow treatment of a specific part of a portion of an oil producing zone. A first fluid is pumped down a coiled tubing and a second fluid is pumped down the annulus formed by the coiled tubing and the production tubing. Because of density differences in the two fluids, diversion is facilitated, treating the lower part of the pay zone with the first fluid and the second fluid to keep the first fluid away from the upper section of the open hole. The coiled tubing could be raised or lowered during this procedure to help ensure desired zone coverage.

Abstract: A process for obtaining decomposition products from a slurry of municipal waste by use of a geothermal reservoir. The process comprises placing the slurry of municipal waste into a geothermal reservoir; sealing the opening of the geothermal reservoir; and retorting the municipal waste slurry in the geothermal reservoir for a time sufficient to liberate methane, ammonia, urea, nitrites, nitrates, and phosphates from said slurry. Thereafter, the liberated products are removed from the geothermal reservoir and separated.

Abstract: A method for improving the efficiency of horizontal wellbore cleanout of a horizontal wellbore drilled from a vertical wellbore, having a perforated liner cemented across the horizontal wellbore. The method includes running a coiled tubing into the horizontal wellbore. A first cleanup fluid is injected down the coiled tubing and a second cleanup fluid is injected down an annulus formed by the coiled tubing and the wellbore. The injection rates of the cleanup fluids in the coiled tubing and the annulus are balanced. The coiled tubing is moved back and forth over the horizontal wellbore.

Abstract: A well completion process for improved cement placement in a horizontal wellbore where dual density cleaning fluids are circulated down the wellbore for conditioning and cleaning it. Afterwards, a production tube containing centralizers is positioned centrally within the wellbore. Next, "spacer fluids" of higher and lower densities are circulated within an annulus formed by the space between the tube and the wellbore so as to more substantially clean the annulus out. Subsequently, a cement having a density greater than the spacer fluid is pumped into the annulus. Thereafter, a light weight cement is pumped into the annulus thereby overriding the heavier cement and removing voids in the annulus resulting in more efficient cement placement.

Abstract: A method for completing a horizontal wellbore in a loosely consolidated or unconsolidated formation. To minimize collapse of the wellbore and minimize sand production while providing for greater flexibility in the placement of a sand control device in a horizontal wellbore, a slotted liner with a flexible sand control device affixed thereto is positioned into the horizontal wellbore. After positioning, the liner with sand control device attached, high permeability of openings within the liner is maintained when producing hydrocarbonaceous fluids from the formation.

Abstract: A method for enhanced hydraulic fracturing which comprises injecting a proppant laden fracturing fluid into a formation or reservoir at a rate and pressure sufficient to fracture said formation. Next, a thin spacer fluid is injected into the created fracture. Afterwards, a proppant laden fracturing fluid is injected into the formation at a rate and pressure sufficient to hold the created fracture open which allows proppant to be more evenly distributed throughout the created fracture as proppant falls through the spacer fluid thereby avoiding proppant convection in the created fracture while obtaining substantially improved propping of the fracture.

Abstract: A method for increasing the efficiency by which fracture fluids are produced back from a hydrocarbonaceous fluid bearing formation. To remove said fracture fluid, agglomerated particles or granules containing a chemical blowing agent are placed into the formation. After placement of the agglomerated particles and granules containing the blowing agent and fracturing the formation, the blowing agent decomposes thereby providing a driving force for fluid load removal from the formation matrix. Increased porosity enhances communication between the formation and the fracture, thus increasing the efficiency of fracture fluid production. Gas liberation within the matrix establishes communication pathways for subsequently removing hydrocarbonaceous fluids by displacing load fluids into the fracture and the well.

Abstract: A well completion process for improved cement placement in a horizontal wellbore. Initially, a cleaning fluid is circulated down the wellbore for conditioning and cleaning it. Afterwards, a production tube containing centralizers is positioned centrally within the wellbore. Next, "spacer fluids" of higher and lower densities are circulated within an annulus formed by the space between the tube and the wellbore so as to more substantially clean the annulus out. Subsequently, a cement having a density greater than the spacer fluid is pumped into the annulus. Thereafter, a light weight cement is pumped into the annulus thereby overriding the heavier cement and removing voids in the annulus resulting in more efficient cement placement.

Abstract: An improved method for hydraulically fracturing a formation or reservoir where a thermo-setting gellable mixture is utilized. This thermo-setting mixture is foamed either at the surface or in situ under fracturing pressures and conditions. The mixture and carrier fluid is of a composition such that the foamed mixture has a viscosity of sufficient magnitude to cause a created fracture to grow while the foamed mixture is kept under fracturing pressure and conditions. Once a fracture of a desired size and length has been generated, the resin is ignited and thermally set thus forming a porous hardened solid within the fracture thereby holding the fracture open. Once combustion is finished, no spent fracturing fluids or load fluids remain to be recovered. This porous solid props the fracture open thereby increasing the conductivity of the formation or reservoir and fluid flow therefrom.

Abstract: A method for removing a viscous hydrocarbonaceous fluid or oil from a formation where carbon dioxide is utilized. Gaseous carbon dioxide is injected, by a pre-set time interval or a computer actuated valve means, into a well near a productive interval. Injection continues for a time sufficient for the carbon dioxide and oil to mix thereby decreasing the oil's viscosity and facilitating gas lift of an oil of reduced viscosity to the surface.

Abstract: A method for placement of a long life scale inhibitor into a formation where variable density scale inhibitors are utilized. A substantially low density non-reactive fluid is loaded into an interval of the formation to be treated. Afterwards, a high density first stage scale inhibitor is injected into the interval. Thereafter, a low density spacer fluid is injected into the interval being treated. Next, a second stage high density scale inhibitor having a density lower than the first stage inhibitor is injected into said interval. Subsequently, a low density spacer is injected into the interval. Volume increments are repeatedly injected with decreasing fluid densities until a desired zone has been treated. The entire treatment is then overflushed with an inert high density fluid. Use of this method allows even inhibitor distribution in intervals of a formation with permeability variations thereby preventing scale build-up.

Abstract: A method to improve the efficiency of scale dissolution in a formation containing multiple productive intervals where variable density liquids are utilized. Initially, a liquid composition sufficient to solubilize an alkaline-earth metal sulfate scale deposit is directed into a wellbore thereby contacting scale in one productive interval of the formation. Thereafter, a second scale solubilizing liquid having a density of about 0.1 wt % less than the first liquid is directed into the wellbore thereby contacting additional perforations and a higher interval. These scale solubilizing liquids with varying densities are allowed to remain in contact with perforations and productive intervals communicating therewith for a time sufficient to solubilize the scale deposit thereby efficiently removing said scale deposit from perforations and productive intervals at two different levels.

Abstract: A method of producing high water-cut gas via in situ water-disposal. Initially, a well is drilled and cased. The casing is perforated at an upper gas producing interval. Next, a tubing is run down through the casing and its lower end is perforated so as to fluidly communicate with a lower non-productive interval. The tubing is also perforated at a location below the producing interval and a production packer is placed between the casing's lower end and the tubing thereby forming an annulus. A slidable sleeve is positioned in the annulus to selectively open and close perforations on the tube side of the annulus. As gas is produced, water separated from the gas collects in the annulus and falls through perforations in the tubing where it is disposed of in the non-productive interval.

Abstract: Two spaced apart zones of a formation are simultaneously hydraulically fractured. A lower density fracturing fluid is injected into an upper zone of the formation via an annulus of a perforated wellbore communicating with the upper zone thereby causing a fracture to propagate. Simultaneously therewith, a higher density fracturing fluid is injected into a lower spaced apart zone via a tube within the wellbore which fluidly communicates with the lower zone thereby causing simultaneously the propagation of a second fracture. Neither fracture contacts the other although complete fracture growth is obtained.

Abstract: An oxygenated foam is injected into a loosely consolidated, clay-containing sandstone formation surrounding a well penetrating a hydrocarbon-bearing reservoir. Combustion is initiated between the oxygenated foam and hydrocarbons within the reservoir to burn the formation and form said consolidated zone around the well that acts as a barrier to the passage of sand into the well along with produced hydrocarbons.

Abstract: An oxygenated foam is injected into a hydrocarbon-bearing reservoir within a diatomite-containing subsurface formation to hydraulically form a fracture within the reservoir. Combustion is initiated between the oxygenated foam and hydrocarbons within the reservoir to burn the formation and alter diatomite within the burned area into a hardened, more highly permeable material. The reservoir may again be fractured to shatter the hardened diatomite to further increase reservoir permeability and form a self-propped fracture within the reservoir.

Abstract: A steam, carbon dioxide, or solvent injection method is used in combination with a cased well completed to have an upper vertical section, a lower vertical section and a horizontal section which connects the two vertical sections. Steam, carbon dioxide, or solvent is injected down tubing in the well and through perforations near the lower portion of the lower vertical section of the well and into an oil-bearing formation that is penetrated by the well. Oil is produced from the formation via perforations in the casing in the upper vertical section and thence upward through the annulus formed between the tubing and the casing to the surface of the earth for recovery.

Abstract: A method where gaseous carbon dioxide is used to provide gas lift of a thinned oil. Carbon dioxide is injected in intermittent slugs via an injection tubing that terminates in a productive interval of a formation. Carbon dioxide mixes with thinned oil in the productive interval thereby increasing gas lift and facilitating production of the oil to the surface.

Abstract: A process for acidizing a formation where variable density acids are utilized. A substantially low density non-reactive fluid is loaded into an interval of the formation to be treated. Afterwards, a high density first stage acid is injected into the interval. Thereafter, a low density spacer fluid is injected into the interval being treated. Next, a second stage high density acid having a density lower than the first stage acid is injected into said interval. Subsequently, a low density spacer is injected into the interval. Volume increments are repeatedly injected with decreasing fluid densities until a desired zone has been treated. The entire treatment is then overflushed with an inert high density fluid.