Abstract: A bottomhole tool and a method for optimizing oil production rate from an oil well with high gas-to-oil ratio and stabilizing thereof in case of occurrence of a gas cone or gas skin conditions are disclosed. The resistance of the adjustable multi-stage flow resistor is determined by a position of a telescoping needle, which in turn is defined by a driving means including a motor and a gearbox. The motor is driven via a cable from a surface by a control means adapted to receive information about the bottomhole parameters from local sensors via a sensor cable. Methodology explaining the principles of maintaining well stability is also disclosed. Automatic adjustment of the bottomhole pressure is maintained over a wide range of operating parameters throughout the life of the well to maximize its oil output.

Abstract: The invention provides a method of treating a subterranean formation penetrated by at least one injection well and at least one production well, the method comprising the steps of a) analyzing the injection well, the production well, and reservoir contained in the subterranean formation; b) selecting at least one fluid and at least one permeability reducer to be placed in flow ways contained within the formation; and c) performing a formation permeability modification using the selected fluids and at least one permeability reducer, whereby the flow of injected driving fluid between the injection well and production well is substantially reduced. In one embodiment, the method of analyzing the injection well, the production well, and reservoir contained in the subterranean formation includes the steps of evaluation of completion information, reservoir data, or both.

Abstract: A technique enables the reduction or prevention of galvanic action by electrically insulating components of a system. Fiber optic systems can be protected with the technique by preventing the formation of hydrogen ions through galvanic action that otherwise contribute to hydrogen darkening of optical fibers.

Abstract: A method and system for the production of a gas hydrate including the steps of drilling into a subterranean gas hydrate formation and at least partially depressurizing the gas hydrate formation to permit separation of gas and water from the hydrate form. The gas and water is then pumped from the formation and recovered from the well. At least a portion of water pumped from the well is water that is introduced into the well from the surface or reintroduced by a feed back loop from the production operation.

Abstract: A barrier system for a subsurface treatment area is described. The barrier system includes a first barrier formed around at least a portion of the subsurface treatment area. The first barrier is configured to inhibit fluid from exiting or entering the subsurface treatment area. A second barrier is formed around at least a portion of the first barrier. A separation space exists between the first barrier and the second barrier.

Abstract: A method for increasing production in a reservoir, comprising performing a swabbing test at a depth in a pipe, wherein the pipe is located in a wellbore and wherein a portion of the wellbore is located inside the reservoir, periodically measuring, during the swabbing test, pressure in the bottom portion of the pipe using the pressure gauge to obtain a plurality of pressure measurements, wherein the pressure gauge is affixed to an inner wall of a bottom portion of the pipe, and determining a plurality of flow rates of fluid flowing from the reservoir through perforations in the wellbore into the pipe using a flow rate equation and the plurality of pressure measurements

Abstract: A system and method is provided to measure a pressure or other characteristic at a source (e.g. a hydraulic power supply) and in or near a downhole tool. A comparison of the measurements is then made to verify that the system is operating according to desired parameters. In specific applications, the comparison can be made to ensure the supply of hydraulic fluid is reaching the downhole tool.

Abstract: A method for producing gas from a well with low pressure involves running a bottom hole pressure test to graph a P-Q curve. The operator computes a frictional pressure drop due to friction of the gas flowing through the production tubing to the surface. A packer is set above perforations in the well. A screw pump is selected that has a capacity equal to the sum of the frictional pressure drop plus a desired wellhead pressure. The screw pump has a flow rate capacity determined from the P-Q curve. The operator may vary the frequency of a downhole motor to achieve the desired wellhead pressure.

Abstract: A method for identifying annular gas sources in a wellbore is disclosed. In one embodiment, the method comprises providing a set of parameters, wherein the set of parameters corresponds to depths in the wellbore. In addition, the method comprises analyzing annular gas in the wellbore to provide isotopic data of the annular gas. The method further comprises correlating the isotopic data to the set of parameters to identify the annular gas source.

Abstract: Methods are provided in which reliance is placed on a first and second barrier respectively positioned in a well 10 to provide well control during well suspension, completion and/or workover operations. Each of the barriers is below the depth of the lowermost end of a completion string when that string is installed in the well. By not placing either barrier higher up in the well-bore, both of the barriers can remain in place during suspension and completion and workover operations, thus obviating the need to use a BOP stack to supplement well control. This results in a considerable saving in drill rig time and thus significantly reduces the cost of constructing a well.

Abstract: A method to determine movement of a wellhead component includes sensing a relative position of the wellhead component with a magnetostrictive sensor over a selected interval of time. The method includes sending a signal from the magnetostrictive sensor to a data acquisition device and recording the relative position of the wellhead component with the data acquisition device with respect to the selected interval of time. Further, the method includes comparing the recorded position of the wellhead component with operations data to determine if the relative position is desirable.

Abstract: A method and apparatus for testing a blowout preventer (BOP) wherein a pressurization unit applies fluid to an isolated portion of the throughbore of the BOP. A signal that is representative of the actual pressure in the isolated portion of the throughbore over successive time points and a pre-determined non-deterministic finite state automaton are used to predict the pressure in the isolated portion of the throughbore as a function of time relative to a pre-determined acceptable leak rate and the time at which stability is achieved. In one embodiment stability is achieved when successive predicted pressures are within a predetermined difference over a predetermined interval of time. Visual indications are provided to depict the progress of testing.

Abstract: A method for producing gas from a well with low pressure involves running a bottom hole pressure test to graph a P-Q curve. The operator computes a frictional pressure drop due to friction of the gas flowing through the production tubing to the surface. A packer is set above perforations in the well. A screw pump is selected that has a capacity equal to the sum of the frictional pressure drop plus a desired wellhead pressure. The screw pump has a flow rate capacity determined from the P-Q curve. The operator may vary the frequency of a downhole motor to achieve the desired wellhead pressure.

Abstract: A technique enables sensing one or more wellbore parameters along a specific well zone. A section of instrumented coiled tubing is provided with a sensor array extending along its exterior. The sensor array is designed to sense well fluid related parameters and may comprise an optical fiber sensor. A cross-over allows the sensor array to communicate with a surface location via a control line routed along a coiled tubing interior.

Abstract: A method and system used for testing a subterranean well. A sensor (34), such as a distributed temperature sensor, comprising a sensing optical fiber (48) connected to an interrogation unit (50), is deployed together with a drill stem test string (20) so that the sensor extends below the packer of the drill stem test string and across at least one formation (22) of the wellbore.

Abstract: The present invention provides methods and apparatus for obtaining downhole well pressure during wellbore operations. One method comprises providing a well intervention tool comprising a straddle sealing assembly having upper and lower annulus sealing elements and a fluid injection port positioned therebetween, the well intervention tool comprising a fluid injection bore having positioned therein a pressure measurement tool; placing the tool in straddle position about a wellbore region to be intervened, with the pressure measurement tool fluidly connected to a wellbore region below the lower annulus sealing element; and performing the wellbore intervention operation while communicating fluid from below the lower annulus sealing element to the pressure measurement tool, thus obtaining a pressure measurement below the lower annulus sealing element during the wellbore intervention operation. This abstract will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b).

Abstract: A method of installing a sensor located in a chamber on the out-side of a casing, comprising the steps of positioning the casing in a well, cementing the casing in position, positioning a drilling tool inside the casing level with the chamber, drilling through the casing, chamber and cement into the formation surrounding the well so as to create a fluid communication path, and sealing the hole drilled in the casing.

Abstract: The present invention provides a method and apparatus for maintaining or restoring decreasing production from a hydrocarbon or gas well using the exhaust of an internal combustion engine. The exhaust is utilized to displace or lighten the fluids in a well bore and increase the bottom hole pressure allowing the well to flow more easily with minimal or no damage to the formation that produces the hydrocarbon or gas. In another aspect, the present invention provides a means of purging and/or pressure testing production wells, pipelines, containers or vessels using exhaust gas. The present invention is a simple, effective, inexpensive and mobile means for maintaining or restoring a production well and/or purging and/or pressure testing of pipelines, containers or vessels.

Abstract: A system and method is provided for sensing a variety of parameters in well-related environments. A skin sensor is deployed in downhole applications to obtain data used in analyzing well characteristics.

Abstract: A system and method is provided for producing fluid from a subterranean formation. A sensor system is used to monitor bottom hole flowing pressure and formation pressure. The relationship of these pressures is utilized in conjunction with a stability envelope of the formation in optimizing fluid production.

Abstract: Safety valve apparatus for a pressure telemetry system utilizing a small diameter tubing conveying pressure from a downhole pressure chamber to the surface, the system pressurized with a monitoring gas, is presented. A check valve assembly is placed along the fluid flow path having a check valve with an operating member. The operating member moves to a sealed position by floating on an activating fluid. The operating member must be of low effective specific gravity to float on wellbore hydrocarbon fluids, either liquid or gas. Consequently, in one preferred embodiment, the check valve operating member is a hollow dart which retains the monitoring gas inside the hollow portion, thereby effectively reducing its specific gravity such that it will float on the activating fluid.

Abstract: A downhole tool positionable in a wellbore for penetrating a subterranean formation includes a housing having at least one protuberance extending therefrom. The protuberance has at least one centralizing section and a protective section. A probe is positioned in the protective section such that the horizontal cross-sectional area of the housing along the protective section is less than the horizontal cross-sectional area of the housing along the at least one centralizing section.

Abstract: A product consisting of a plurality of thermocouple cables braided or wound and covered with protective armour, thereby forming a braided bundle. The product is used in accordance with a method involving a further step of inserting the braided bundle into a well.

Abstract: An improved method of controlled energy delivery utilizing solid, liquid, and gaseous carbon dioxide (CO2) into a water well and the surrounding aquifer to remove deposited material which may cause loss of capacity in wells and a variety of water quality problems. After proper study and evaluation of problems associated with a well to be treated, adequate injection of the required amount of CO2 and energy is achieved by real-time monitoring during the injection and manipulating the phase changes in the CO2 that take place in the well and the aquifer.

Abstract: This application relates to various methods and apparatus for rapidly obtaining accurate formation property data from a drilled earthen borehole. Once obtained, the formation property data, including formation fluid pressure, may be corrected, calibrated and supplemented using various other data and techniques disclosed herein. Furthermore, the formation property data may be used for numerous other purposes. For example, the data may be used to correct or supplement other information gathered from the borehole; it may be used to supplement formation images or models; or, it may be used to adjust a drilling or producing parameter. Various other uses of accurately and quickly obtained formation property data are also disclosed.

Abstract: A system and method measures a pressure or other measurement at a source (e.g. a hydraulic power supply) and in or near a downhole tool and compares the measurements to verify that, for example, the supply is reaching the tool. The system and method also may utilize a gauge positioned within a packer or positioned for communication with the setting chamber of a packer.

Abstract: A process to determine optimal completion type and design prior to drilling of a hydrocarbon producing well utilizing information from hydrocarbon recovery modeling such as reservoir, geo-mechanical, and material modeling over the production life of the well. An embodiment of the process includes obtaining information regarding pore pressure depletion, stress magnitudes and orientations, and strength of rock formation from hydrocarbon recovery modeling to determine optimum well completion design including the selection of a completion type, trajectory, and location. Additionally, the process may also consider probable failure mechanisms and identified completion requirements, and their corresponding effect on completion options.

Abstract: A method for optimizing oil production rate from an oil well with high gas-to-oil ratio is disclosed to include modeling an Inflow Performance Relationship curve and calculating an optimal level of bottomhole pressure to be higher than zero. Maintaining the bottomhole pressure at that calculated optimum level by using a bottomhole tool of the invention or other known means such as gas injection provides for maximum oil recovery from a given well. The bottomhole tool includes a multi-stage flow resistor and a needle moved in and out of the resistor by a spring-biased piston responsive to a difference in pressure between a bottomhole pressure and a pipe pressure. Automatic adjustment of the bottomhole pressure is maintained over a wide range of operating parameters throughout the life of the well.

Abstract: Methods, apparatus, and systems for obtaining information regarding a formation, a casing, or fluid within the casing are provided which utilize an interrogator and one or more sensing devices attached to a casing in a wellbore. The interrogator is located within and may be movable inside the wellbore. The sensing device is positioned and fixed in an opening in the casing. The sensing device includes a housing and a sensor with associated electronic circuitry. The interrogator and sensing device include a magnetic coupling therebetween that is operable when the interrogator and sensing device are positioned in close proximity to one another. Preferably, the magnetic coupling is realized by at least one solenoid winding for the interrogator and at least one solenoid winding for the sensing device, which provide a loosely-coupled transformer interface therebetween. The interrogator and sensing device communicate in a wireless manner over the magnetic coupling therebetween.

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: An apparatus and method useful for acquiring information from a subsurface formation penetrated by a wellbore contemplate the use of a tubular body adapted for connection within a drill string disposed in the wellbore. The tubular body is equipped with one or more protuberances (e.g., ribs) defining an expanded axial portion. A probe is carried by the tubular body at or near a first location within the expanded axial portion of the body where the cross-sectional area of the expanded axial portion is a minimum. The probe is movable between retracted and extended positions. In another aspect, the inventive apparatus may further include a cover releasably-secured about the probe for protecting the probe while drilling. In a further aspect, the inventive apparatus may include a shearable backup support carried by the tubular body azimuthally opposite the probe permitting release of the apparatus from the wellbore in the event of a failure.

Abstract: A system for controlling drilling mud density at a location either at the seabed (or just above the seabed) or alternatively below the seabed of wells in offshore and land-based drilling applications is disclosed. The present invention combines a base fluid of lesser/greater density than the drilling fluid required at the drill bit to drill the well to produce a combination return mud in the riser. By combining the appropriate quantities of drilling mud with a light fluid, a riser mud density at or near the density of seawater may be achieved to facilitate transporting the return mud to the surface. Alternatively, by injecting the appropriate quantities of heavy fluid into a light return mud, the column of return mud may be sufficiently weighted to protect the wellhead. At the surface, the combination return mud is passed through a treatment system to cleanse the mud of drill cuttings and to separate the drilling fluid from the base fluid.

Abstract: Embodiments of the present invention generally provide a method, apparatus, and system for monitoring conditions in wellbore in real time prior to setting an inflatable element in the wellbore. The inflatable element is inflated with an inflation tool run on a cable with one or more electrically conductive wires (the cable is commonly referred to as a “wireline”). One or more sensors, internal or external to the inflation tool, are monitored before setting the inflatable element to verify well conditions are compatible with the inflatable element. The sensors may be internal or external to the inflation tool.

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: The present invention relates to systems and methods useful in subterranean treatment operations. Examples of methods of the present invention include methods for fracturing a portion of a subterranean formation penetrated by a well bore; methods of enhancing production from multiple subterranean formations penetrated by a well bore during a single trip through the well bore; and methods of enhancing production, in real time, from multiple subterranean formations penetrated by a well bore during a single trip through the well bore.

Abstract: A method for determining formation pressure at a depth region of formations surrounding a borehole, including: keeping track of the time since cessation of drilling at the depth region; deriving formation permeability at the depth region; causing wellbore pressure to vary periodically in time and determining, at the depth region, the periodic and non-periodic component of pressure measured in the formations; determining, using the time, the periodic component and the permeability, the formation pressure diffusivity and transmissibility and an estimate of the size of the pressure build-up zone around the wellbore at the depth region; determining, using the time, the formation pressure diffusivity and transmissibility, and the non-periodic component, the leak-off rate of the mudcake at the depth region; determining, using the leak-off rate, the pressure gradient at the depth region; and extrapolating, using the pressure gradient and the size of the build-up zone, to determine the formation pressure.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. An average temperature and/or pressure within the formation may be controlled to inhibit production of hydrocarbons that have carbon numbers greater than a selected carbon number. In some embodiments, the selected carbon number is 25. A small number of hydrocarbons having carbon numbers greater than the selected carbon number may be entrained in vapor produced from the formation.

Abstract: A control system for a hydrocarbon well is also disclosed. A control valve system is used to control the flow of fluid being produced by the well. A real time sensor is provided downhole and is used to make real time measurements of phase characteristics of the fluid. A controller is used to control the valve system so as to reduce the risk of undesirable phase transitions in the fluid based on the real time measurements made by the sensor. The sensor includes an acoustic transducer configured to emit acoustic energy into the fluid at a level which causes a phase transition in the fluid. The controller determines the level of acoustic energy emitted into the fluid, and also determines the pressure associated with a phase transition using the level of emitted acoustic energy.

Abstract: A method for evaluating the permeability and formation damage in the porous rock around a well bore. This method relates to the use of a single string coiled tubing and a down hole assembly which includes a microcontroller, an electrically operable fluid control valve and electrically operable pressure sensing devices which allow for real time pressure transient analysis techniques before, during and after formation stimulation treatments.

Abstract: The invention relates to pumping units for extraction oil from oil wells comprising, all of them being installed on the piping string, a packer, a back pressure valve, a jet pump having the active nozzle, the mixing chamber, the diffuser and the central channel for supplying a passive medium, and a seal assembly. The back pressure valve is installed below the seal assembly, and a geophysical instrument is installed on the well-logging cable going through the seal assembly. The unit further comprises a filter and a perforator. The geophysical instrument is installed above the back pressure valve and below the jet pump, and the filter and the perforator are installed below the back pressure valve.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. The mixture produced from the formation may have a relatively high hydrogen partial pressure, and a large portion of the pressure within the formation may be attributable to hydrogen partial pressure.

Abstract: An oil shale formation may be treated using an in situ thermal process. A mixture of hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. A reducing environment may be maintained within a portion of the formation.

Abstract: The present invention provides methods and systems for making measurements associated with a rock formation including a main borehole, a microborehole extending from the main borehole into the rock formation, and one or more sensing devices positioned and arranged to make a measurement at measurement zones being located in the microborehole. A packer can also be installed in the microborehole dimensioned and arranged to hydraulically isolate the measurement zones from conditions present in other parts of the microborehole and/or main borehole. Methods and systems are also provided for taking fluid samples and injecting fluid tracers in a microborehole.

Abstract: Embodiments of the present invention generally provide a method, apparatus, and system for monitoring conditions in wellbore in real time prior to setting an inflatable element in the wellbore. The inflatable element is inflated with an inflation tool run on a cable with one or more electrically conductive wires (the cable is commonly referred to as a “wireline”). One or more sensors, internal or external to the inflation tool, are monitored before setting the inflatable element to verify well conditions are compatible with the inflatable element. The sensors may be internal or external to the inflation tool.

Abstract: The present invention relates to a method of determining the proppant friction generated in a fracture of a subterranean formation during a hydraulic fracturing treatment involving injection stages of pad and of proppant-laden fluids. This method is based on close monitoring of surface pressure to define a “net pressure rate” which defines an increase or decrease of net pressure while the job is being pumped, and then relates it with the pressure changes observed with the onset of proppant stages of varying concentrations.

Abstract: This invention comprises the use of a variable orifice valve as a flow controller and flow meter. Pressure measurements are taken upstream and downstream of the variable orifice valve by way of a differential pressure measurement mechanism. The differential pressure measurement mechanism may comprise two separate absolute pressure measurement devices or a single differential pressure measurement device. Flow rate through the valve is determined from the pressure drop across the valve. In wellbores having multiple zones, a variable orifice valve together with a differential pressure measurement mechanism may be deployed for each zone. The flow rate through each of the zones and at the surface can then be monitored and controlled.

Abstract: The effects of storage on the interpretation of data obtained at observation probes of a borehole tool are eliminated by controlling the storage volumes relative to the observation probes. For a homogeneous medium, the effect of storage on the interpretation of data is eliminated by causing the flow line volumes connected to each observation probe to be equal to each other. For a heterogeneous medium, the effect of storage on the interpretation of data is eliminated by causing the flow line volumes to vary in proportion to the relative permeabilities of the strata of the heterogeneous medium adjacent the probes. The borehole tool is provided with mechanisms for conducting flow line volume adjustment.

Abstract: Methods and apparatus for monitoring and controlling the pressure in a wellbore characterized by a drilling system utilizing real-time bottom hole pressure measurements and a control system adapted to control parameters such as well shut-in, drilling fluid weight, pumping rate, and choke actuation. In the preferred embodiments, the control system receives input from the bottom hole pressure sensor as well as pressure sensors, mud volume sensors, and flowmeters located at the surface. The control system then adjusts one or more of drilling fluid density, pumping rate, or choke actuation to detect, shut-in, and circulate out wellbore influxes. The preferred system operates automatically without any manual intervention in well control processes.

Abstract: A method is provided for gathering information on the pore pressure in an earth formation surrounding a wellbore. The method includes the initial steps of selecting at least one suitable property (e.g., porosity, drilling fluid composition, etc.) of the drilling environment (which is defined by the wellbore and the surrounding formation) and at least one NMR parameter (e.g., T2 distribution) in an NMR measurement response. The method selects a suitable property for which values over a plurality of wellbore depths can be correlated with the characteristics or behavior of the pore pressure in the earth formation. The method further includes conducting an NMR measurement at a plurality of wellbore depths, thereby generating an NMR response from the drilling environment. The measured values of the NMR parameter in the NMR response are then correlated with values of the suitable property.

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.