Abstract: In a well production management and storage system having at least one collecting tank and the well pump and a control panel with a timing trigger for activating the well pump and deactivating the well pump for a first predetermined run cycle and a first predetermined rest cycle, the improvement is a controller for adjusting at least one of the first predetermined run cycle and the predetermined rest cycle. This controller detects either changes in rate of rise in liquid in the collecting tank and/or water level in the well when the pump is in a run cycle. When these parameters change, by a predetermined increment, the pump run cycle and/or rest cycle is automatically adjusted.

Abstract: A pumpjack speed control system includes a user interface, a controller and a variable speed drive. The user interface includes a mathematical representation of the pumpjack geometry which permits the conversion of rod speed profiles to crank speed profiles.

Abstract: A method and apparatus for the separation of the water from the oil/gas in the well itself, down-hole, in which gravity is allowed to work on the mixture in a non-vertical section of the well, and then, using separated flow paths, the gravity-separated components pumped to the surface or into a subterranean discharge zone. Detectors are used to control the pumping so as to keep the unsettled/unseparated mixture away from the flow paths. Preferably the discharge zone is chosen to have a formation pressure which is lower than the pressure of the producing zone.

Abstract: A method of using an everting borehole liner to perform fluid conductivity measurements in materials surrounding a pipe, tube, or conduit, such as a borehole below the surface of the Earth. A flexible liner is everted (turned inside out) into the borehole with an internal pressurized fluid. As the liner displaces the ambient fluid in the borehole into the surrounding formation, the rate of descent of the liner is recorded. As the impermeable liner covers the flow paths in the wall of the hole, the descent rate slows. From the measured descent rate, the flow rates out discrete sections of the borehole are determined.

Abstract: This invention provides a method for controlling production operations using fiber optic devices. An optical fiber carrying fiber-optic sensors is deployed downhole to provide information about downhole conditions. Parameters related to the chemicals being used for surface treatments are measured in real time and on-line, and these measured parameters are used to control the dosage of chemicals into the surface treatment system. The information is also used to control downhole devices that may be a packer, choke, sliding sleeve, perforating device, flow control valve, completion device, an anchor or any other device. Provision is also made for control of secondary recovery operations online using the downhole sensors to monitor the reservoir conditions. The present invention also provides a method of generating motive power in a wellbore utilizing optical energy. This can be done directly or indirectly, e.g., by first producing electrical energy that is then converted to another form of energy.

Abstract: A gas-lift well having a controllable gas-lift valve is provided. The well uses the tubing and casing to communicate with and power the controllable valve from the surface. Induction chokes at the surface and downhole electrically isolate the tubing from the casing. A high band-width, adaptable communication system is used to communicate between the controllable valve and the surface. Additional sensors, such as pressure, temperature, and acoustic sensors, may be provided downhole to more accurately assess downhole conditions. The controllable valve is varied opened or closed, depending on downhole conditions, oil production, gas usage and availability, to optimize production and assist in unloading. While conventional, bellows-type, gas-lift valves frequently fail and leak—often undetected—the controllable valve hereof permits known precise operation and concomitant control of the gas-lift well.

Abstract: A subterranean well completion has a tubular structure in which a remote controlled robot is permanently disposed. The robot is self-propelled, programmable, receives instructions from and communicates data to the surface, and is adapted to receive power from a downhole source and perform a variety of well tasks such as, for example, positioning valves and other well tools and sensing the values of predetermined downhole parameters and relaying the sensed information to the surface. The robot, which is operable without physical intervention through the tubular structure to the robot, propels itself to a location in the tubular structure at which a desired well task is to be performed, performs the task and then parks itself in the tubular structure until another well task is to be performed by the robot.

Abstract: The current invention provides methods for determining the sand production rate from unconsolidated and poorly consolidated subterranean formations under varying drawdown pressures. The current invention also allows for immediate production of fluid from the subterranean formation upon determination of the sand production rate. Additionally, the current invention provides a method for determining the detrimental sand production rate and/or the maximum sand free production rate for a subterranean formation. Finally, the current invention is applicable in vertical, horizontal, deviated and multi-lateral boreholes.

Abstract: The main problem area this invention is solving, is concerning reservoirs containing gas with to low well-head pressure. It is therefore desirable to increase the well-head pressure by applying downhole pumps, however this is not possible if gas is present. The core idea in this present invention, is to place a pump (5) in a “bath” of oil (14), in which oil “bath” (14) makes a gas seal (11), assuring the pump only to be imposed to oil without gas. Oil and gas from the reservoir (1) flows trough perforations (2), into a ring-space (3). This creates a significantly pressure drop of the mixture, in which creates turbulence so the gas content will separate from the oil. The pressure drop is regulated by the gas pressure valve (4).

Abstract: A fluid flow control device (60) for use in a wellbore to control the inflow of production fluids comprises a sand control screen (62) having a base pipe (64) with a first set of openings (66) that allows the production fluids to flow therethrough and a sleeve (74) coaxially disposed adjacent to the base pipe (64). The sleeve (74) has a second set of openings (76) that allows the production fluids to flow therethrough. The sleeve (74) is selectively positionable relative to the base pipe (64) such that a pressure drop in the production fluids is selectively controllable by adjusting an alignment of the first set of openings (66) relative to the second set of openings (76).

Abstract: An electric submersible pumping system having a downhole gauge section. The electric submersible pumping system comprises a submersible motor powered by a submersible pump. The submersible pump may be located below the submersible motor when in operation, while the downhole gauge section is disposed above the submersible motor. A power cable is coupled to the submersible motor through the downhole gauge section.

Abstract: A method and apparatus for remediation of non-aqueous phase liquids (NAPL), including the use of a prior art hydrophobic adsorption system including a continuous loop of adsorptive material, with a weighted pulley on the free end of the loop to allow for the loop to be placed within a well being deeper than it is wide.

Abstract: This invention relates to a mechanical oil recovery method and system with a sucker-rod pump. The method calculates the lowest power loss or the lowest cost. The method comprises sequentially arranging internal diameter, steel grade of rod, pump diameter, pumping depth and stroke amplitude, searching the combinations of rods to calculate pump efficiency and the number of strokes, on the basis of Pinput=Pactive−Pexpansion+Ploss, and calculating, corresponding to the input power Pinput, active power Pactive, expansion power Ppeng, ground power loss Pd, sliding power loss Ph and viscose power loss Pv and the sum of losses Ploss. The mechanical oil-recovering cost is then calculated for each combination, and each mechanical oil-recovering parameter is chosen.

Abstract: Plunger lift operations are difficult to optimize due to lack of knowledge of tubing pressure, casing pressure, bottom-hole pressure, liquid accumulation in the tubing and location of the plunger. Monitoring the plunger position in the tubing helps the operator (or controller) to optimize the removal of liquids and gas from the well. The plunger position can be tracked from the surface by monitoring acoustic signals generated as the plunger falls down the tubing. When the plunger passes by a tubing collar recess, an acoustic pulse is generated that travels up the gas within the tubing. The acoustic pulses are monitored at the surface, and are converted to an electrical signal by a microphone. The signal is digitized, and the digitized data is stored in a computer. Software processes this data along with the tubing and casing pressure data to display plunger depth, plunger velocity and well pressures vs. time.

Abstract: The present invention comprises tools (20) for deployment downhole in a wellbore for aiding in the production of hydrocarbons. In an exemplary embodiment, the tools (20) comprise a tool body (24); an electrically powered device (22) disposed proximate the tool body (24); a removable power source (26) for providing power to the device disposed in the tool body (24), the power source connected to or mounted into or about the tool body (24), the power source (26) further being fixed or replaceable downhole; and a wireless communications device (57) operatively connected to the electrically powered device.

Abstract: An oil well pumping system includes a small positive displacement pump below the fluid interface in a low volume oil well which pumps at a rate to maintain approximately constant fluid level in the well. The system includes at least a pair of sensors in a sensor array that is positioned above the pump and near the fluid interface to unambiguously determine liquid level. By maintaining the pumping rate of the positive displacement pump below that required to lower the liquid level to the pump, the pump will not unload and pump power requirements are reduced to a nearly constant low rate. In addition, the pump off control function is accomplished by a microprocessor which is mounted adjacent to the downhole sensor array. This location allows simple direct control of the downhole electric motor and eliminates the requirement that a control element be placed on the surface far from the pump.

Abstract: Methods and apparatus are disclosed for controlling and monitoring injection zone and production zone parameters in order to control the injected fluid front to avoid breakthrough of the injected fluid to the production zone and thus optimize hydrocarbon recovery.

Abstract: Fluid property sensors and associated methods of calibrating sensors in a well provide enhanced well monitoring and control. In one described embodiment, an external venturi flowmeter is utilized to determine a flow rate of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In another described embodiment, a gamma ray fluid density sensor utilizes a unique combination of gamma ray sources and detectors to determine a density of fluid flowing through a tubing string. In yet another embodiment, external tubing string sensors are used to determine properties of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In still another embodiment, sensor systems for multiple independently produced zones are calibrated.

Abstract: In a production system for producing oil or gas from a well, the production system including a plunger in well tubing, and a motor valve in a sales line connected to a plunger lubricator which connects to the well tubing, a differential pressure controller system includes: a) a plunger arrival sensor; b) a plunger cycle controller receptive to signals from the plunger arrival sensor and receptive to signals from pressure transducers, for controlling the cycle of the plunger; c) a differential pressure controller; d) a first pressure transducer conductively coupled to the differential pressure controller, for measuring pressure in the well tubing, e) a second pressure transducer conductively coupled to the differential pressure controller for measuring pressure in the sales line; and f) a solenoid valve conductively coupled to the differential pressure controller and connected to the motor valve.

Abstract: A well control valve assembly having a downhole portion with a primary valve, and electromechanical actuator connected to the valve and a first wireless communicator connected to the actuator. The assembly further includes an uphole portion having a pump, a second wireless communicator complementary to the first wireless communicator and being supported in the uphole portion of the valve assembly. The downhole portion and uphole portion are physically non-connected and informationally connected.

Abstract: A programmable controller for operating an artificial lift well is provided to monitor and operate a variety of analog and digital devices. An on-cycle of the well is initiated based on a pressure differential measured between a casing pressure and a sales line pressure. When a predetermined ON pressure differential is observed, the controller initiates the on-cycle and open a motor valve to permit fluid and gas accumulated in the tubing to eurged out of the well. Thereafter, the controller initiates a mandatory flow period and maintains the motor valve open for a period of time. The valve remains open as the system transitions into the sales time period. During sales time, the controller monitors the gas flow through an orifice disposed in the sales line. A differential pressure transducer is used to measure a pressure differential across the orifice. When the measure pressure differential is less than or equal to a predetermined OFF pressure differential, the controller initiates the off cycle.

Abstract: A system and methods for proportionally controlling hydraulically actuated downhole flow control devices using derived feedback control. The system comprises a downhole flow control device with a moveable element in a stationary housing. The moveable element is actuated by a balanced hydraulic piston. Hydraulic lines are fed to either side of the piston to effect actuation in either direction. A processor controlled, surface mounted hydraulic system supplies fluid to the piston. A pressure sensor measures supply pressure to the piston and a cycle counter indicates pump cycles and both sensors generate outputs to the processor. The downhole moveable element is cycled between end stops until successive moveable element breakout pressures are within a predetermined value as measured by the surface pressure sensor. A relationship is then derived between moveable element movement and pumped fluid volume and the relationship is used to move the moveable element to a predetermined position to control flow.

Abstract: An electric submersible pumping system having a downhole gauge section. The electric submersible pumping system comprises a submersible motor powered by a submersible pump. The submersible pump may be located below the submersible motor when in operation, while the downhole gauge section is disposed above the submersible motor. A power cable is coupled to the submersible motor through the downhole gauge section.

Abstract: Complex algorithms and calculations such as multi-phase flow correlations, together with mathematical models which include the dynamic behavior of the wellbore or artificial lift equipment and the components therein (e.g., a variable speed drive, power cable, seal and pump) are employed to derive or compute information relevant to production based upon actual measurements made during operation. The derived or computed values, typically for parameters such as torque which are difficult to measure during operation, are provided with the measurements for control purposes. Improved optimization of production based on an expanded set of parameters is therefore enabled.

Abstract: A borehole includes a tubular member, a sealing member for sealing an annulus between the tubular member and the borehole, a pump for pumping fluidic materials into the tubular member, and an automatic choke for controllably releasing pressurized fluidic materials out of the annulus. A system and method monitor the operating pressure within the tubular member and compare the actual operating pressure with a desired operating pressure. The difference between the actual and desired operating pressure is then processed to control the operation of the automatic choke to thereby controllably bleed pressurized fluidic materials out of the annulus thereby creating back pressure within the borehole.

Abstract: The present invention relates to a gas lift valve for use in an oil well producing by means of gas lift, said gas lift valve making use of a central body venturi for both controlling the flow of the injection gas from the annulus between the tubing and the casing of the oil well, and precluding a reverse flow of fluids from said oil well towards said annulus to occur.

Abstract: An apparatus and method for collecting a sample from a low-yield well or perched aquifer includes a pump and a controller responsive to water level sensors for filling a sample reservoir. The controller activates the pump to fill the reservoir when the water level in the well reaches a high level as indicated by the sensor. The controller deactivates the pump when the water level reaches a lower level as indicated by the sensors. The pump continuously activates and deactivates the pump until the sample reservoir is filled with a desired volume, as indicated by a reservoir sensor. At the beginning of each activation cycle, the controller optionally can select to purge an initial quantity of water prior to filling the sample reservoir. The reservoir can be substantially devoid of air and the pump is a low volumetric flow rate pump. Both the pump and the reservoir can be located either inside or outside the well.

Abstract: A subterranean well production system utilizes a single well to perform both hydrocarbon fluid production and water dumpflooding processes. The well has a primary wellbore that is communicated with first and second subterranean zones respectively containing hydrocarbon fluid and higher pressure water. A second, lateral wellbore extends from the primary wellbore and communicates with the first zone. A remotely controllable routing system, including a valved production tubing structure extending through the primary wellbore, is operable to (1) flow hydrocarbon fluid from the first zone to the surface via the production tubing and (2) simultaneously dumpflood water from the second zone into the first zone, via the production tubing, to increase the pressure within the first zone and thereby increase the hydrocarbon fluid production rate.

Abstract: The present invention provides an artificial lift apparatus that monitors the conditions in and around a well and makes automated adjustments based upon those conditions. In one aspect, the invention includes a pump for disposal at a lower end of a tubing string in a cased wellbore. A pressure sensor in the wellbore adjacent the pump measures fluid pressure of fluid collecting in the wellbore. Another pressure sensor disposed in the upper end of the wellbore measures pressure created by compressed gas above the fluid column and a controller receives the information and calculates the true height of fluid in the wellbore. Another sensor disposed in the lower end the tubing string measures fluid pressure in the tubing string and transmits that information to the controller. The controller compares the signals for the sensors and makes adjustments based upon a relationship between the measurements and preprogrammed information about the wellbore and the formation pressure therearound.

Abstract: 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.

Abstract: A method monitors pumping operations of a vehicle that pumps various fluid treatments down into a well being serviced at a well site. The method records the vehicle's engine speed and the values of one or more fluid-related variables, such as pressure, temperature, flow rate, and pump strokes per minute. The values are recorded as a function of the time of day that the variables and engine speed were sensed. In some embodiments, the recorded values are communicated over a wireless communication link from a remote well site to a central office.

Abstract: Complex algorithms and calculations such as multi-phase flow correlations, together with mathematical models which include the dynamic behavior of the wellbore or artificial lift equipment and the components therein (e.g., a variable speed drive, power cable, seal and pump) are employed to derive or compute information relevant to production based upon actual measurements made during operation. The derived or computed values, typically for parameters such as torque which are difficult to measure during operation, are provided with the measurements for control purposes. Improved optimization of production based on an expanded set of parameters is therefore enabled.

Abstract: A method for using a controller to control a fluid pump by controlling the rate at which the pump fills with fluid and subsequently discharges fluid. The pump includes a chamber for collecting fluid from within a well bore in which the pump is disposed. A user inputs a pump cycle time and a pump cycle volume to the controller. The pump cycle time input is used to determine a cycling period for the pump. The pump cycle volume is used to allot a portion of the cycling period to the refilling of the pump with fluid and the remaining portion of the cycling period to the discharging of fluid from the pump. The controller controls the pump such that the pump is vented to atmosphere during the refill portion, allowing the pump to fill with fluid, and such that pressurized fluid, such as compressed gas, is injected into the pump during the discharge cycle, causing fluid collected within the pump to be discharged. In another mode of operation, a sensor is coupled to the controller.

Abstract: A tubing is used in a well bore capable of furnishing a well fluid. The tubing has an annular member having a passageway. The tubing has at least one port that is connected to detect a composition of the well fluid and control flow of the well fluid into the passageway based on the composition.

Abstract: The present invention relates to a well-bore sensor apparatus and method. The apparatus includes a downhole tool carrying at least one sensor plug for deployment into the sidewall of a well-bore. The apparatus may also be used in conjunction with a surface control unit and a communication link for operatively coupling the sensor plug to the surface control unit. The sensor plug is capable of collecting well-bore data, such as pressure or temperature, and communicating the data uphole via a communication link, such as the downhole tool or an antenna. The downhole data may then be analyzed and control commands sent in response thereto. The sensor plug and/or the downhole tool may be made to respond to such control commands. In some embodiments, multiple surface control units for corresponding wells may be networked for decision making and control across multiple well-bores.

Abstract: Improvements in method and apparatus for producing hydrocarbons from marginal oil wells, especially wells that previously used standard pump jacks. Substitution of the present invention for prior art production equipment solves many common problems found in the prior art, such as a well pump that experiences gas lock and pounding, which is a hindrance to efficient production in other known pump systems but is advantageous when using the Smart Pump of this disclosure. Disclosed herein is a pump assembly which senses when fluid is pumped uphole at a rate different than the rate that fluid is produced from the formation, by continually adjusting the time interval of one cycle of operation to coincide with the production history of the well.

Abstract: A technique for controlling fluid production in a deviated wellbore is disclosed. The technique utilizes a flow pipe the interior of which is in hydraulic communication with the earth's surface. A plurality of flow control valves are disposed at spaced apart positions along the length of the flow pipe. The flow control valves are used to regulate flow along intervals of the flow pipe.

Abstract: An improved, unattended, liquid pumping device for oil and gas wells featuring a bellows controlled flow valve that opens and closes at preset pressures. Additionally a well head receiver design that releases shut in production gas below the pumping device and provides a positive pressure differential across the pumping device prior to valve opening.

Abstract: Apparatus and system control for the removal of fluids and gas from a well comprising winch means for removing the oil, a temporary storage tank, a bailer tube, first, second and third bailer tube guide pipes axially aligned to each other, means for exhausting and recovering a natural gas, the bailer tube being capable of being lowered into and elevated from the well casing through the temporary storage tank such that captured oil can be discharged into the temporary storage tank, sensors for monitoring operational parameters including the depth of oil and depth of a top level of water in the well casing, and a programmable logic controller means for providing system control so that only oil is removed from the well casing by using a logging sequence and a balanced oil production operational sequence.

Abstract: An apparatus and method are provided to improve production from a gas-lift well comprising injecting gas into a well to lift multi-phase formation fluid from the well; measuring at least one characteristic of the multi-phase formation fluid with a multi-phase flow meter while the fluid is in multi-phase form determining a value of the at least one characteristic from the measurement and adjusting at least one injection gas characteristic based on the determined value, the adjustment tending to improve well system production.

Abstract: An intelligent well system and method has a sand face completion and a monitoring system to monitor application of a well operation. Various equipment and services may be used. In another aspect, the invention provides a monitoring system for determining placement of a well treatment. Yet another aspect of the invention is an instrumented sand screen. Another aspect is a connector for routing control lines. 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. 37 CFR 1.72(b).

Abstract: One or more subterranean zones are isolated from one or more other subterranean zones using a combination of solid tubulars and perforated tubulars.

Abstract: Fluid property sensors and associated methods of calibrating sensors in a well provide enhanced well monitoring and control. In one described embodiment, an external venturi flowmeter is utilized to determine a flow rate of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In another described embodiment, a gamma ray fluid density sensor utilizes a unique combination of gamma ray sources and detectors to determine a density of fluid flowing through a tubing string. In yet another embodiment, external tubing string sensors are used to determine properties of fluid from a zone into a tubing string, independent of flow into the tubing string of fluid produced from any upstream zone. In still another embodiment, sensor systems for multiple independently produced zones are calibrated.

Abstract: System and methods are disclosed for transmitting and receiving electromagnetic pulses through a geological formation. A preferably programmable transmitter having an all-digital portion in a preferred embodiment may be operated at frequencies below 1 MHz without loss of target resolution by transmitting and over sampling received long PN codes. A gated and stored portion of the received signal may be correlated with the PN code to determine distances of interfaces within the geological formation, such as the distance of a water interfaces from a wellbore. The received signal is oversampled preferably at rates such as five to fifty times as high as a carrier frequency. In one method of the invention, an oil well with multiple production zones may be kept in production by detecting an approaching water front in one of the production zones and shutting down that particular production zone thereby permitting the remaining production zones to continue operating.

Abstract: The systems and the methods relating to process control optimizations systems useful to manage oilfield hydrocarbon production. The systems and the methods utilize intelligent software objects which exhibit automatic adaptive optimization behavior. The systems and the methods can be used to automatically manage hydrocarbon production in accordance with one or more production management goals using one or more adaptable software models of the production processes.

Abstract: Methods for optimization of oil well production with deference to reservoir and financial uncertainty include the application of portfolio management theory to associate levels of risk with Net Present Values (NPV) of the amount of oil expected to be extracted from the reservoir. Using the methods of the invention, production parameters such as pumping rates can be chosen to maximize NPV without exceeding a given level of risk, or, for a given level of risk, the minimum guaranteed NPV can be predicted to a 90% probability. An iterative process of generating efficient frontiers for objective functions such as NPV is provided.

Abstract: An overall petroleum reservoir production optimization methodology permits the identification and remediation of unstimulated, under-stimulated, or simply poorly performing reservoir completed intervals in a multilayer commingled reservoir that can be recompleted using any of various recompletion methods (including but not limited to hydraulic fracturing, acidization, re-perforation, or drilling of one or more lateral drain holes) to improve the productivity of the well. This provides an excellent reservoir management tool and includes the overall analysis and remediation methodology that has been developed for commingled reservoirs. The specialized recompletion techniques can be used to improve the productivity of previously completed individual reservoir intervals in a commingled reservoir.

Abstract: In a multiple well completion, spaced apart production packers isolate independent production zones from one another. In each isolated production zone, a side pocket mandrel with a full opening bore has lengthwise extending side by side elongated pockets (1) for receiving a static pressure measuring instrument or tool (static pressure pocket); (2) for providing a venturi flow passageway (flow passageway pocket); and (3) for receiving a differential pressure measuring tool (differential pressure pocket). The static pressure measuring tool and the differential pressure measuring tool or instrument are commonly connected by a data coupling means to a single electrical conductor line which is strapped to the string of tubing and extends to the earth's surface for transmission of control signals and data signals between the earth's surface and the various side pocket tools.

Abstract: A hydrocarbon production system comprises a topside installation connected to a underwater distribution unit 4 by an umbilical 3. The unit 4 is connected to Christmas Trees 8, 9 and 10 by respective ones of jumper interconnects 11, 12 and 13. Each Christmas Tree may comprise one or more of an electrical actuator 14, flow rate control choke 16, pressure and/or temperature transducers 18, down hole measurement transducers 18a and/or a down hole safety valve 21. Electrical power is transmitted to the unit 4 by a high voltage transmission cable forming part of the umbilical 3. A transformer forming part of the unit 4 steps down the voltage transmitted over the umbilical 3 to a level suitable for use by the electrical devices 14, 16 and 21. Power and control of the devices 14, 16, 18, 18a, 21 is effected by an underwater controller 5, 6, 7 associated with its respective Christmas Tree 8, 9, 10.

Abstract: A system for reservoir control. The system allows segregated production of fluids, e.g. water and oil, to control the fluid-fluid interface. Downhole sensors are utilized in providing data about the location of the interface. This permits the proactive monitoring and control of the interface prior to unwanted intermingling of fluids, e.g. oil and water, during production.