738 results about "Injection rate" patented technology

An apparatus, system, and method are disclosed for generating a gas. One or more liquid permeable pouches each define a cavity that contains a solid anhydrous reactant, such as a chemical hydride. A reaction chamber made of a heat, chemical and/or pressure resistant material receives the one or more pouches from a pouch feeder that transfers the one or more pouches into the reaction chamber successively at a feed rate. One or more liquid sources inject a liquid reactant into the reaction chamber so that the liquid reactant contacts a portion of the one or more pouches. The one or more liquid sources inject the liquid reactant at an injection rate that corresponds to the feed rate. A gas outlet releases a gas, such as hydrogen, oxygen, ammonia, borazine, nitrogen, or a hydrocarbon, that is produced by a reaction between the solid reactant and the liquid reactant.

An injectable substance delivery device comprising a pen device body, a cartridge, a plunger, a drive mechanism, and at least one of a lock-out mechanism and a rate-limiting mechanism. The lock-out mechanism is provided through a ratchet engagement between the body and the plunger to restrict plunger movement and to ensure that the required needle puncture depth is realized prior to injection by locking out the injection mechanism from advancing until a specified force is applied to the skin. A rate-limiting mechanism is also provided through a user compressed plunger drive spring to ensure that a specific rate of injection is realized during the injection of a medicament.

A system and method for supplying an additive into a well is disclosed that includes estimating injection rates for the additives and setting of one or more fluid flow control devices in the well based on a computer model. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

A method for optimizing the rate at which a given acid should be injected into a carbonate-containing rock formation during an acid injection process. The first step of the method calculates the Damkohler numbers for regimes in which kinematic force, diffusion rate and reaction rate control. The Damkohler numbers are then used to calculate the rate of growth of wormholes as a function of flux, taking into account compact dissolution, wormholing, and uniform dissolution. The calculated function is used to calculate an optimum flux for the formation. The optimum flux is then used to calculate an optimum injection rate at a given point in the acid injection process.

The control of emissions from fossil-fired boilers wherein an injection of substances above the primary combustion zone employs multi-layer feedforward artificial neural networks for modeling static nonlinear relationships between the distribution of injected substances into the upper region of the furnace and the emissions exiting the furnace. Multivariable nonlinear constrained optimization algorithms use the mathematical expressions from the artificial neural networks to provide the optimal substance distribution that minimizes emission levels for a given total substance injection rate. Based upon the optimal operating conditions from the optimization algorithms, the incremental substance cost per unit of emissions reduction, and the open-market price per unit of emissions reduction, the intelligent emissions controller allows for the determination of whether it is more cost-effective to achieve additional increments in emission reduction through the injection of additional substance or through the purchase of emission credits on the open market. This is of particular interest to fossil-fired electrical power plant operators. The intelligent emission controller is particularly adapted for determining the economical control of such pollutants as oxides of nitrogen (NOx) and carbon monoxide (CO) emitted by fossil-fired boilers by the selective introduction of multiple inputs of substances (such as natural gas, ammonia, oil, water-oil emulsion, coal-water slurry and/or urea, and combinations of these substances) above the primary combustion zone of fossil-fired boilers.

A distributed computer system includes links and routing devices coupled between the links and routing frames between the links. Each of the routing devices includes a congestion control mechanism for detecting congestion at the routing device and responding to detected congestion by gradually reducing an injection rate of frames routed from the routing device.

Systems, program product, and methods for providing real-time reservoir management of one or more reservoirs across one or more fields are provided. A system can include multiple monitoring wells and at least one injection well in communication with a central facility including a reservoir management computer or server positioned to provide real-time reservoir management of the one or more reservoirs. The computer can include, stored in memory, reservoir management program code, which when executed, can cause the computer to perform the operations of calibrating an injection well model for each of one or more injection wells positioned in a reservoir responsive to real-time injection rate and wellhead pressure data associated therewith, calculating static reservoir pressure for each of the injection wells responsive to the respective calibrated injection well model and responsive to respective surface injection rate and wellhead pressure data, and generating real-time automated isobaric pressure maps.

A method for operating a downhole oil water separator and electric submersible pump includes measuring fluid pressure proximate one of the pump intake, separator intake and a bottom of a wellbore. At least one of flow rate and pressure is measured at the separator water outlet. Pump and a water outlet restriction are controlled to maintain an optimum fluid pumping rate and an optimum injection rate of separated water. A flow control system includes a controllable valve disposed in a water outlet of the separator. At least one of a pressure sensor and a flowmeter is operatively coupled to the water outlet. A controller is in signal communication with the at least one of a pressure sensor and flowmeter and in operative communication with the valve. The controller operates the valve to maintain at a selected pressure and/or a selected flow rate through the water outlet.

A method for optimizing the production of a petroleum well is provided. The petroleum well includes a borehole, a piping structure (24) positioned within the borehole, and a tubing string (26) positioned within the borehole for conveying a production fluid. Production of the well is optimized by determining a flow rate of the production fluid within the tubing string (26) and determining a lift-gas injection rate for the gas being injected into the tubing string. The flow rate and injection rate data is communicated along the piping structure of the well to a selected location (44), where the data is collected and analyzed. After analysis of the data, an optimum operating point (152) for the well can be determined

The invention relates to a microorganism enhanced oil recovery method, in particular to a method for improving oil well yields by means of oil pool indigenous microorganisms. The method includes the following steps of (1) screening of a test oil well, (2) screening of activating agents, (3) confirming of the injection rate of the activating agents, (4) confirming of well closing time and (5) on-site testing. By means of the indigenous microorganisms existing in the activated oil well, on-site test cost is thereby saved, different formulas of the activating agents are chosen according to the different indigenous microorganisms, activating effects and on-site test effects are effectively improved, the stratum cannot be damaged and the environment cannot be polluted when nutrient substances are injected, and therefore the method can be widely used for microorganism enhanced oil recovery.

Disclosed are a method and apparatus for controlling the injection rate of an anesthetic solution in a cartridge type motor-driven injection syringe for dental use, particularly beginning with the “Low” rate injection at the outset, and switching to the “Medium” or “High” injection rate at an arbitrarily selected time in the course of injection.

The speed of revolution of the electric motor is changed among the low, medium and high speed, and a two-step operable type of switch is used as a starter switch 13. The first depression of the starter switch makes the electric motor 9 start at the low speed, thereby making the plunger rubber 5 initially move at the “Low Speed” in the cartridge 6 via the plunger rod 12, and the second depression of the switch makes the electric motor 9 run at the low, medium or high speed, and accordingly the plunger rod moves at the selected “Low Speed”, “Medium Speed” or “High Speed”.

The invention discloses a digital underground layering water injection testing and adjusting process pipe column and an operation method thereof. According to the purpose, the instantaneous flow rate and the accumulative total injection rate of a single reservoir stratum can be monitored and recorded in real time underground, pressure of the reservoir stratum is monitored in real time, underground well shut-in layering pressure drop is tested, and bi-directional transmission of data and orders between a down-hole and the ground is carried out in a wireless mode. The process pipe column is formed by connecting a multistage digital water distributor and an Y344 water injection packer through an oil pipe, and eliminates steps of testing and allocating steel wires of the flow rate compared with an existing water distributor and a packer used for layering water injection. Meanwhile, the instantaneous flow rate and the accumulative total injection rate of the single reservoir stratum can be monitored and recorded in real time underground, the pressure of the reservoir stratum is monitored in real time, and the underground well shut-in layering pressure drop is tested. The pipe column can greatly reduce workloads of matching tests and pressure-drop tests of an oil field layering water injection well, provides the true and reliable accumulative total injection rate of the single stratum, and provides reliable evidence for policy adjustment of the oil field development technology.

A modular injection system enables a user to control the dilution ratio of mixed injectable fluid. In one embodiment, modular injection system includes a handheld injection device operatively connected to a separate control device. In one embodiment, the control device includes a drive unit configured to apply extrusion forces to fluids. In another embodiment, the handheld injection device includes the drive unit. In one embodiment, the modular injection system produces the mixed injectable fluid based on a selected dilution ratio. In one embodiment, the modular injection system produces the mixed injectable fluid based on selected injection rates.

The present invention generally provides an inexpensive method for drilling a multilateral wellbore where the pressure exerted on a formation of interest by a column of drilling fluid may be controlled. In one aspect, a method for drilling a lateral wellbore from a main wellbore is provided, including running a string of casing with an injection line connected thereto into the main wellbore, wherein the injection line is disposed along an outer side of the casing and a portion of the casing corresponding to a starting depth of the lateral wellbore is made from a drillable material; running a drillstring through the casing to the starting depth of the lateral wellbore, wherein the drillstring comprises a drill bit; injecting drilling fluid through the drill sting; and injecting a second fluid, having a density less than that of the drilling fluid, through the injection line at a rate corresponding to an injection rate of the drilling fluid to control hydrostatic pressure exerted by a column of the drilling fluid and the second fluid returning through the casing.

A dental syringe (10) has a needle (11) affixed to a carpule holder (12), which carpule holder (12) is affixed to a power drive unit (13). A harpoon (20) is provided to affix the drive unit to the carpule plunger (32). The harpoon (20) is made of stainless steel or other hard, corrosion resistant, sterilizable, material. Harpoon 20 has a unique barb geometry and hardened, knife-like, edges (21). The syringe (10) may operate to divide the delivery of anesthesia into two phases. According to the method, during the first about 10 seconds of the injection, anesthetic is delivered at an extremely slow rate to maximize patient comfort. The injection rate then automatically increases to the preprogrammed rate associated with the injection type selected.