176 results about "Well stimulation" patented technology

The present Invention relates to hydrocarbon well stimulation, and more particularly to methods and compositions to remove (or more generally to transfer) fluid introduced into the subsurface. For instance, preferred methods involve creating then exploiting a capillary pressure gradient at the fracture face to induce fluid flow from the fracture into the formation thereby increasing effective fracture length, and then improving fracture conductivity.

A neural lead and method of treating neurological disorders by stimulation of the cerebral cortex of the brain is provided. The lead is designed for reduction of strain between the lead body and the lead paddle caused by the position of the lead body above the cranium and the lead paddle beneath the cranium. The lead is also designed to include a two dimensional chronic electrode array for better stimulation coverage of the target area of the cerebral cortex. A method of treating a neurological disorder by stimulating the cerebral cortex is also presented.

The present invention relates to subterranean well stimulation. More particularly, the present invention relates to improved methods of stimulating subterranean formations during drilling operations. In some embodiments, the present invention discloses methods of stimulating a section of a subterranean formation comprising (a) forming at least a portion of a well bore that at least penetrates a section of the subterranean formation using a drilling operation; (b) stimulation a section of the subterranean; and (c) continuing the drilling operation. In other embodiments, the present invention discloses methods of stimulation a section of a subterranean formation comprising (a) forming at least a portion of a well bore that at least penetrates a section of the subterranean formation using a drilling operation; (b) stimulating a section of the subterranean formation; and (c) continuing the drilling operation.

A high-pressure wear resistant cylinder that utilizes a high-pressure field for strength is an economical method of, or device for, handling very high pressures and the pumping of abrasive and corrosive fluids. The economic considerations are so favorable, that the invention may be considered a replacement part. The invention is suitable for a variety of applications, particularly a reciprocating flow work exchanger in the well stimulation or hydraulic fracturing industry. Using a high pressure field to strengthen the external surface (outside) of a pipe that is precision honed and plated or sleeved internally (inside), it is now possible to construct various high pressure machines in a relatively inexpensive manner. This invention makes it possible to use pipe with internal operating pressures greater than their nominal operating pressure ratings permit. This invention will be used in various high pressure piping and machinery applications.

Adapters for connecting to a double-locking casing mandrel of an independent screwed wellhead include a lockdown flange with an adapter pin, and a retainer flange that may be used with or without the adapter pin. The retainer flange has a top surface with circumferentially-spaced threaded bores that permit well stimulation equipment to be mounted thereto. The retainer flange threadedly connects to a pin thread at a top of the casing mandrel, and therefore provides a low profile mounting flange for well stimulation equipment.

A casing mandrel for an independent screwed wellhead includes a pin thread adapted for engagement with a box thread of a well stimulation tool lockdown nut for securing the well stimulation tool against the casing mandrel top end. A well stimulation tool and a tubing head spool for use with the casing mandrel are also provided. Safety of well stimulation procedures is thereby improved and well completion time is significantly reduced.

A method for designing acid treatments provides for the selection of optimal treatment for well stimulation wherein reservoir characteristics are obtained to further select the reaction kinetic data on the minerals of interests, the treatment to the reservoir is scaled up using a mathematical model and real time damage are computed based on bottomhole pressure and injection rate and compared to that predicted by the mathematical model to adjust the treatment. The model generated facilitates optimization of matrix treatments by providing a rapid quantitative evaluation of various treatment strategies for a formation. Stimulation with non-traditional fluid recipes containing mixtures of inorganic and organic acids, and chelating agents can be readily computed. The computed values can then be used in an economic model to justify the additional costs associated with the use of the non-traditional fluids. Apart from optimizing matrix treatments, the method can be used as a development tool for new fluid systems, as a tool for prediction and removal of inorganic scale and for fluid compatibility testing such as that required in water flooding projects.

The improved system allows an operator overseeing a well stimulation hydraulic fracturing operation to bring frac pumps online and offline as necessary. A control panel allows the operator to remain at a safe distance from high-pressure equipment, including the frac pumps and respective remotely actuated isolation valves, yet allows monitoring and operation of same. The operating condition of the frac pumps and the isolation valves is monitored by an automated processing device, which prevents operation of same during certain pump and valve conditions. A wireless operator interface is also provided.

A lockdown flange for use with an independent screwed wellhead includes an annular body having a center passageway with an internal diameter at least as large as a passageway through the wellhead. The lock down flange may be used to construct a multi-lock adapter for connecting a high pressure valve, a blowout preventer or a well stimulation tool to the independent screwed wellhead. The lockdown flange ensures that stress on connection points to the screwed independent wellhead due to elevated fluid pressures used for well stimulation procedures does not exceed engineered specifications.

An engineered composite system designed to be passive or inert under one set of conditions, but becomes active when exposed to a second set of conditions. This system can include a dissolving or disintegrating core, and a surface coating that has higher strength or which only dissolves under certain temperature and pH conditions, or in selected fluids. These reactive materials are useful for oil and gas completions and well stimulation processes, enhanced oil and gas recovery operations, as well as in defensive and mining applications requiring high energy density and good mechanical properties, but which can be stored and used for long periods of time without degradation.

A well stimulation tool includes a well stimulation tool mandrel with an axial bore having an internal diameter large enough to permit a backpressure plug to be run through the mandrel into a tubing mandrel, such as a tubing hanger or a casing mandrel, to which the well stimulation tool mandrel is secured. This permits well stimulation to be performed through a tubing string suspended in the well by the tubing mandrel, without requiring wireline services.

The invention relates to a gravity-assisted steam flooding mining method for exploiting thick-bed ordinary heavy oil reservoirs. In the thick-bed ordinary heavy oil reservoirs, the methods of steam injection in vertical wells and production in horizontal wells or steam injection in horizontal wells and production in horizontal wells are adopted . For the oil reservoir blocks that have been developed by vertical wells, the combination of vertical wells and horizontal wells can be used to drill horizontal production wells along the lower part of the oil layer in the known oil reservoir blocks, so that the vertical steam injection wells are obliquely above the horizontal wells, and the production wells and injection wells Simultaneous huff and puff of steam wells for 2-4 cycles or thermal communication between steam injection wells and production wells or formation of reservoir pressure down to 3-4MPa, transfer to steam injection wells and steam injection production wells for production and production; or steam injection wells and production wells have formed thermal communication , After the newly drilled horizontal production well huffs and puffs for one cycle and removes the pollution near the wellbore, the steam injection production well is transferred to the steam injection well for production and production. The invention can exert the sweeping effect of the displacement fluid in both vertical and horizontal directions, increase the sweeping range of the driving fluid, and increase the crude oil recovery rate of the thick common heavy oil reservoir.

A composition in the form of an emulsion having: (i) a continuous oil phase comprising: (a) an oil; (b) an emulsifier; and (c) a particulate comprising an oxide selected from the group consisting of metal oxides, metalloid oxides, and any combination thereof, wherein the particulate is hydrophobically modified, would not dissolve in oil or 28% hydrochloric acid, and has a surface area in the range of 700 m2 / g to 30 m2 / g; and (ii) an internal aqueous phase comprising water having a pH of less than zero. A method of acidizing a treatment zone of a subterranean formation in a well includes the steps of: (A) forming a treatment fluid comprising such a composition; and (B) introducing the treatment fluid into a well, wherein the design temperature is at least 275° F. Preferably, the particulate is hydrophobically modified silica.

The present invention relates to improved methods for well stimulation and completion. More particularly, the present invention relates to methods of stimulating and completing well bores while controlling formation sand migration and proppant flowback. One embodiment of the present invention provides a method of stimulating a formation surrounding a well bore comprising the steps of: (a) hydraulically fracturing a formation to create or enhance at least one fracture; (b) placing proppant coated with a tackifying agent into the far-well bore area of the fracture; and, (c) placing an agent capable of controlling particulate flowback into the well bore or near-well bore area of the fracture.

The invention discloses a method for coal bed methane mining by multi-element thermal fluid foam displacement. Multi-element thermal fluid is injected into a coal bed of an injection-production well group through an injection well, and foaming agent is injected at intervals. A multi-element thermal fluid foam slug is formed in the coal bed to displace the coal bed methane in order to improve the recovery efficiency of the coal bed methane. The method specifically includes that extracted coal bed methane is compressed and mixed with compressed air, and then the mixture is injected into a multi-element thermal fluid generation device for ignition, extracted processed ground water is mixed to produce the multi-element thermal fluid mainly with high-temperature and high-pressure water vapor and mixed gas of carbon dioxide and nitrogen, the produced multi-element thermal fluid is injected into the underground coal bed through the injection well, a foaming system composed of preferred alkyl ether sulfonate and corrosion inhibitor is injected from an oil jacket annulus at intervals, the multi-element thermal fluid foam slug is formed under the ground to displace the coal bed methane, and water is drained and gas is recovered from a production well. The method has the advantages that fuel is easy to obtain, principles are clear and distinct, and the like, and can provide guidance for implementation of well stimulation of the coal bed methane.

A method and apparatus for controlling inflation and deflation of spaced inflatable packer elements of a straddle stimulation tool within a well casing of a well. A straddle stimulation tool is positioned by tubing at a desired location within the well casing. Fluid is pumped through the tubing and tool at a rate inflating the spaced inflatable packer elements within the well casing and establishing an annulus interval. The inflation control retains pressure within the inflated packer elements and permits the flow of stimulation fluid into the annulus interval for stimulation of the formation. After completion of well stimulation, the packer element pressure control is moved to a packer equalizing position by tension applied via the tubing to equalize packer pressure with casing annulus pressure, deflating the packer elements and permitting conveyance of the straddle stimulation tool within the well casing by the tubing string.

An apparatus for controlling vertical movement of a tubular within a wellhead includes an anchor spool connected atop the wellhead, and a detachable superstructure supporting the tubular. The anchor spool provides connectors for detachably connecting bottom ends of at least two piston cylinders of the detachable superstructure. The tubular may be a landing joint or a high-pressure mandrel of either a well stimulation tool, or a well isolation tool. The apparatus provides unobstructed access to a top end of the tubular. The anchor spool includes an elongated sidewall and an axial passage through which a tubing hanger can be reciprocated. The height of the sidewall permits the apparatus to be used for landing / removing a tubing string even if the anchor spool is mounted directly to a blowout preventer (BOP).

Methods and systems that may be employed to dynamically test the effect of fluids (e.g., well treatment chemicals such as well stimulation treatment chemicals, enhanced oil recovery “EOR” chemicals, etc.) on hydrocarbon recovery from crushed reservoir formation materials under conditions of applied stress. The disclosed methods and systems may be used in one embodiment to dynamically test types of low permeability formations (e.g., such as shale, limestone, quarried rock, etc.).

A method for designing acid treatments provides for the selection of optimal treatment for well stimulation wherein reservoir characteristics are obtained to further select the reaction kinetic data on the minerals of interests, the treatment to the reservoir is scaled up using a mathematical model and real time damage are computed based on bottomhole pressure and injection rate and compared to that predicted by the mathematical model to adjust the treatment. The model generated facilitates optimization of matrix treatments by providing a rapid quantitative evaluation of various treatment strategies for a formation. Stimulation with non-traditional fluid recipes containing mixtures of inorganic and organic acids, and chelating agents can be readily computed. The computed values can then be used in an economic model to justify the additional costs associated with the use of the non-traditional fluids. Apart from optimizing matrix treatments, the method can be used as a development tool for new fluid systems, as a tool for prediction and removal of inorganic scale and for fluid compatibility testing such as that required in water flooding projects.

The present invention provides an insertion, deletion and / or substitution mutein of wild-type Trichoderma reesei β-mannanase having enhanced thermostability, proteolytic stability, specific activity and / or stability at low pH, a nucleic acid molecule encoding said mannanase mutein, a composition comprising said mannanase mutein; a method for its preparation, and its use for food and feed processing, for coffee extraction and the processing of coffee waste, as a supplement to food and feed, for enzyme aided bleaching of paper pulps, as bleaching and / or desizing agent in textile industry, for oil and gas well stimulation by hydraulic fracturing, as detergent, for removal of biofilms and in delivery systems, or for the processing of renewable resources intended for the production of biological fuels.

In a well stimulation method, a subsurface formation is fractured by freezing a water-containing zone within the formation in the vicinity of a well, thereby generating expansive pressures which expand or created cracks and fissures in the formation. The frozen zone is then allowed to thaw. This freeze-thaw process causes rock particles in existing cracks and fissures to become dislodged and reoriented therewithin, and also causes new or additional rock particles to become disposed within both existing and newly-formed cracks and fissures. The particles present in the cracks and fissures act as natural proppants to help keep the cracks and fissures open, thereby facilitating the flow of fluids from the formation into the well after the formation has thawed. Preferably, the freeze-thaw steps are carried out on a cyclic basis. Optionally, propagation of the freezing front into the formation may be enhanced by the introduction of low-frequency wave energy into the formation.

A well stimulation fluid includes water, a polymer, and a biocide consisting of 2,5-dimethyl-1,3,5-thiadiazinane-2-thione in an amount effective to inhibit bacterial growth.

The invention discloses a shock-wave fracture forming device and system. The device includes a ground control terminal, a perforation cable and a high-energy shock wave generator, wherein the control terminal is connected with a shell of the high-energy shock wave generator through the perforation cable, and a cable core body of the perforation cable is connected with a energy storage component of the high-energy shock wave generator. According to the shock-wave fracture forming device and system, high-voltage strong-current electric energy is released instantly in a liquid environment of an oil well, high-temperature plasmas can be generated, are spread in the radial direction in a high-pressure shock wave form and act on oil layers through perforation tunnels of the oil well, a large number of fractures free of crustal-stress control are formed near wellbore areas, at the same time, various pollution blockages near the perforation tunnels are cleaned away. The permeability near the wellbore areas is greatly improved, the pressure conductive ability is reduced, crude oil smoothly flows into a wellbore, and the production increase of the oil well and the injection increase of a water well are achieved.

A method of determining the suitability of a surfactant for use in a formation can include sampling water in the formation, providing at least two surfactants, and mixing each of the surfactants with the formation water to form surfactant / water samples. The method can further include determining the solubility of each surfactant with the formation water, comparing the solubility of each surfactant with the other surfactant, and assigning a solubility performance value for each surfactant based on its solubility in the formation water sample compared to the other surfactant.

Method for modeling acidification within a porous medium as a result of the injection of an acid. A dual-medium model is constructed, considering a first sub-medium favourable to dissolution breakthroughs and a second sub-medium not favourable to dissolution breakthroughs. For each one of these sub-media, a metric-scale description of the acid transport, of the sub-medium and acid mass conservation and of the acid transfer from one sub-medium to the other sub-medium is achieved. This dual-medium model is then initialized from experimental calibrations. Finally, acidification of the medium is modelled by means of this dual-medium model.