Abstract: A wireline logging tool and method for fluid monitoring and flow characterization in individual zones of controlled salinity is disclosed. The tool and method advantageously facilitate zone-specific testing. Sets of packers are used to create hydraulically distinct zones proximate to the tool. Coiled tubing and isolation valves are used to selectively introduce and remove an electrically conductive fluid such as brine to and from a selected zone. Individual sensors are disposed near each zone to make zone-specific measurements while fluid properties are changed, e.g. while salinity is changed to cause salinity fronts in the formation.

Abstract: A fluids lifting tool and analysis system. The present invention comprises a fluid lifting system for a gas well. The system comprises a lifting tool positioned in the well and a docking station at the well surface. The tool includes a processor, pressure sensors, temperature sensors, an accelerometer, and a proximity sensor. A battery in the tool is adapted to be charged by inductive coupling using coils in the docking station and the tool. The tool is released from the docking station and descends the well. During descent the tool measures elapsed time, velocity of the tool, calculates distance traveled, measures pressure and temperature, determines volumes or oil and water in the well, and senses when the tool reaches the bottom of the well. The FLT chooses to ascend the well when appropriate and transfers measured and calculated data to the docking station.

Abstract: Methods for using a microemulsion system are disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: Determining a production gain index (PGI) for a petroleum reservoir provides a novel leading indicator and metric that is designed to quickly assess the potential for increases in production of petroleum from an operating petroleum reservoir when implementing a recovery plan. The PGI can be determined according to the following equation: P ? ? G ? ? I = ?? ? ? q A ? ? ? q Old where, ??qA=net actual production gain of the reservoir; and ?qOld=sum of current oil rates for existing producers. The PGI can also be determined according to the following equation: PGI=PR×(GPI?1) where, GPI=the global productivity index of the petroleum reservoir; and PR=the interference factor, which accounts for any losses in aggregate production gain due to well interference.

Abstract: Systems and methods for drainage of a heavy oil reservoir via a horizontal wellbore. A method of improving production of fluid from a subterranean formation includes the step of propagating a generally vertical inclusion into the formation from a generally horizontal wellbore intersecting the formation. The inclusion is propagated into a portion of the formation having a bulk modulus of less than approximately 750,000 psi. A well system includes a generally vertical inclusion propagated into a subterranean formation from a generally horizontal wellbore which intersects the formation. The formation comprises weakly cemented sediment.

Abstract: The system and method are utilized to control the flow of crude oil, natural gas, and field produced salt water to optimize production from an oil or gas well. The invention is suitable for use with a well that utilizes gas-lift as artificial lift. The equipment is designed to regulate the flow of injection gas into the production tubing to optimize production of the well.

Abstract: The present invention is directed to a method of hydrocarbon production from a hydrocarbon reservoir. The method includes providing a substantially horizontal wellbore having at least one productive interval within a hydrocarbon reservoir and forming at least one non-conductive transverse fracture in the reservoir along the substantially horizontal wellbore. An injection well is also provided. A fluid is injected into the reservoir through the injection well to displace hydrocarbons within the reservoir toward a production portion of the substantially horizontal wellbore. Hydrocarbons are drained from the reservoir into at least one production interval of the substantially horizontal wellbore. Fluid production from the at least one production interval into the substantially horizontal wellbore flows through an inflow control device that can restrict the fluid flow.

Abstract: A method for improving liquid injection into a rock formation. The method includes the steps of introducing a gas impulse device into a wellbore in the formation and pumping a pressurized liquid into the wellbore. The method also includes firing the gas impulse device periodically so that the device generates impulses of high pressure compressed gas. The gas expands through the pumped pressurized liquid substantially instantaneously increasing the liquid flow rate into the rock formation, and creates rapid cyclical injected liquid surges into the rock formation with liquid oscillation occurring inside the fractures and/or pores of the formation. The method may be used in regular oil production applications, waterflooding of wells that have ceased to be productive, in preventing lost circulation in oil wells, and in injecting hazardous wastes into rock formations.

Abstract: The present invention is directed to an in situ reservoir recovery process that uses a horizontal well located near the top of a reservoir and an inclined production well to extract bitumen or heavy oil from a reservoir. In a first stage, the top well is used for cold production of reservoir fluids to the surface, in which, reservoir fluids are pumped to the surface in the absence of stimulation by steam or other thermal and/or solvent injection. A lower production well is drilled into the formation below the top well. The top well is converted to an injection well or, if no cold production then a top well is drilled as an injector well. A portion of the bottom well is inclined so that one end of the incline is closer to the injector well than the other end of the incline. In the process, steam circulation creates a heated zone at the point of the two wells that are closest together in the reservoir.

Abstract: A method of operating an electrical submersible pumping system that includes realtime monitoring of the wellbore fluid and adjusting pump speed so the fluid entering the pump remains subcooled. The method can include adding sensors within the wellbore and digitally storing fluid data accessible by a pump controller. The pump speed can be increased or decreased by adjusting the frequency of the electrical power delivered to the pump motor.

Abstract: Method for increasing the recovery of crude oil from a reservoir containing at least one porous and permeable subterranean formation wherein the formation includes sandstone rock and at least one mineral that has a negative zeta potential under the reservoir conditions and wherein crude oil and connate water are present within the pores of the formation. The method is carried out by (A) injecting into the formation a slug of an aqueous displacement fluid that displaces crude oil from the surface of the pores of the formation wherein the pore volume (PV) of the slug of the aqueous displacement fluid is at least 0.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: Methods for accurately assessing the condition of a petroleum reservoir and designing and implementing a plan of action to increase production and recovery of petroleum from the reservoir. Information is gathered using a unique set of metrics and information gathering techniques and analyzed in a targeted fashion by properly weighting the data in the context of the particular reservoir and goals of the producer. A reservoir rating is generated using asymmetric analysis of metrics and then used to formulate a plan of action. Production architecture (e.g., number, location and manner of constructing oil and injector wells) is then constructed according to the plan of action. Reservoir performance can be continuously monitored and used to verify production and recovery goals and/or provide triggers or alarms to alter production equipment.

Abstract: A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heaters to a part of a formation. In some embodiments, heat from the one or more heat sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.

Abstract: A jet pump on pipe string and packer, pump body being provided with steplike pass channel embodied therein and communicates with pumped-out medium supplying channel and active medium supplying channel, connected to active nozzle at the output and to annular space. The pumped-out medium-supplying channel connects to the pipe string downstream of steplike channel via return valve. A hollow steplike cylindrical body sealing unit provided with a top part sealing element arranges in said steplike channel. An annular projection supported spring-loaded steplike piston is downstream. The piston lower position closes unit body holes. When the piston is in top position, the channel for supplying medium pumped-out from the well through the unit holes and pump bodies connects to the pipe string downstream of the pump body. The piston and sealing element include coaxial channels therein, used for passing a cable with logging instrument suspended below the pump body.

Abstract: A system for monitoring a location of a borehole for production of petroleum from an earth formation is provided. The system includes: an assembly including at least one of an injection conduit for injecting a thermal source into the formation and a production conduit for recovering material including the petroleum from the formation; a guide conduit attached to at least a portion of the at least one of the injection conduit and the production conduit, the guide conduit extending in a direction at least substantially parallel to the at least one of the injection conduit and the production conduit; and a detection source conduit insertable through the guide conduit and configured to dispose therein a detection source for detecting a location of the assembly in the formation. A method of monitoring a location of a borehole for production of petroleum from an earth formation is also provided.

Abstract: A system for production of petroleum from an earth formation is provided. The system includes: at least one injection borehole for injecting a thermal source into the formation; at least one production borehole for recovering material including the petroleum from the formation; and at least one drainage borehole intersecting a portion of the at least one production borehole. Methods of recovering petroleum from an earth formation and creating a petroleum production system are also provided.

Abstract: Systems and methods for producing a well using a gas are disclosed herein. A compressed lift gas can be provided to a well to obtain a production stream. The production stream can be separated to obtain the product and a recycle gas stream. The recycle gas stream can be immediately recompressed for use as lift gas, or separated to form a lift gas stream, and a power stream containing natural gasses from the well. The lift gas stream is recycled for use as lift gas, while the power stream can be transported and/or collected for sale, recycled for use as lift gas, or consumed as power for the compressor, based on measurements obtained throughout the system, coupled with practical and economic variables. By supplementing or replacing generated lift gas and/or an external power source with natural gas from the well, the present systems and methods can become self-contained after start-up.

Abstract: A method of testing the response of a subterranean formation to a formation treatment is described including the injection of a treatment fluid and the production of formation fluids from two separate boreholes or two boreholes from a single well such that the treatment fluid sweeps the formation between the two boreholes, and the use of downhole monitoring devices to determine a volume swept by the treatment fluid.

Abstract: A process may include providing heat from one or more heaters to at least a portion of a subsurface formation. Heat may transfer from one or more heaters to a part of a formation. In some embodiments, heat from the one or more heat sources may pyrolyze at least some hydrocarbons in a part of a subsurface formation. Hydrocarbons and/or other products may be produced from a subsurface formation. Certain embodiments describe apparatus, methods, and/or processes used in treating a subsurface or hydrocarbon containing formation.

Abstract: Systems and methods for producing a well using a gas are disclosed herein. A compressed lift gas can be provided to a well to obtain a production stream. The production stream can be separated to obtain the product and a recycle gas stream. The recycle gas stream can be immediately recompressed for use as lift gas, or separated to form a lift gas stream, and a power stream containing natural gasses from the well. The lift gas stream is recycled for use as lift gas, while the power stream can be transported and/or collected for sale, recycled for use as lift gas, or consumed as power for the compressor, based on measurements obtained throughout the system, coupled with practical and economic variables. By supplementing or replacing generated lift gas and/or an external power source with natural gas from the well, the present systems and methods can become self-contained after start-up.

Abstract: Methods for treating a tar sands formation are described herein. The tar sands formation may have one or more karsted zones. Methods may include providing heat from one or more heaters to one or more karsted zones of the tar sands formation to mobilize fluids in the formation. At least some of the mobilized fluids may be produced from the formation.

Abstract: Systems and methods for testing a subterranean formation are herein disclosed. According to one embodiment, a method includes stimulating a substantially non-permeable medium within a subterranean formation to create a fractured reservoir. At least one stimulation parameter is measured during stimulation. A well drilled in the subterranean formation is shut-in. A fluid is produced from the subterranean well and at least one production parameter is measured during production. The stimulation and production parameters are used in a numerical reservoir fluid flow model to identify parameters of the fractured reservoir.

Abstract: Systems and methods for drainage of a heavy oil reservoir via a horizontal wellbore. A method of improving production of fluid from a subterranean formation includes the step of propagating a generally vertical inclusion into the formation from a generally horizontal wellbore intersecting the formation. The inclusion is propagated into a portion of the formation having a bulk modulus of less than approximately 750,000 psi. A well system includes a generally vertical inclusion propagated into a subterranean formation from a generally horizontal wellbore which intersects the formation. The formation comprises weakly cemented sediment.

Abstract: A system for production of petroleum from an earth formation is provided. The system includes: at least one injection borehole for injecting a thermal source into the formation; at least one production borehole for recovering material including the petroleum from the formation; and at least one drainage borehole intersecting a portion of the at least one production borehole. Methods of recovering petroleum from an earth formation and creating a petroleum production system are also provided.

Abstract: A system for monitoring a location of a borehole for production of petroleum from an earth formation is provided. The system includes: an assembly including at least one of an injection conduit for injecting a thermal source into the formation and a production conduit for recovering material including the petroleum from the formation; a guide conduit attached to at least a portion of the at least one of the injection conduit and the production conduit, the guide conduit extending in a direction at least substantially parallel to the at least one of the injection conduit and the production conduit; and a detection source conduit insertable through the guide conduit and configured to dispose therein a detection source for detecting a location of the assembly in the formation. A method of monitoring a location of a borehole for production of petroleum from an earth formation is also provided.

Abstract: A remediation process that a employs improved quantitative method(s) of estimating of the volume and/or mass of contaminant in the subsurface, removal and or in situ degradation of the contamination using subsurface pulsing treatment (“SPT”) technology, and evaluation of the degree of remediation by re-applying the quantitative contaminant evaluation methods. The process uses SPT technology with the addition of a vacuum or sub-atmospheric pressure to an extraction well in order to create a push-pull effect to remove free contaminant or residual in conjunction with the pressure wave driving force created in the excitation or excitation well. The process can quantitatively measure the amount of residual contaminant, which up until now has not been possible or tractable using in situ methods, as well as measure the amount of residual that can be removed by SPT.

Abstract: A method of testing the response of a subterranean formation to a formation treatment is described including the injection of a treatment fluid and the production of formation fluids from two separate boreholes or two boreholes from a single well such that the treatment fluid sweeps the formation between the two boreholes, and the use of downhole monitoring devices to determine a volume swept by the treatment fluid.

Abstract: An object is to provide a monitoring method for monitoring underground diffusion of carbon dioxide, which is used when injecting carbon dioxide into an underground coal seam to cause it to be adsorbed to the coal seam, and collecting hydrocarbon gases that have been displaced by the carbon dioxide and released from the coal seam, and with which the behavior of carbon dioxide injected into the ground can be continuously measured over a long period of time at a low cost, using a relatively simple device. A plurality of wells including an injection well 3 and a production well 4 extending to underground coal seams (main layer 1 and lower layer 2) are formed.

Abstract: A technique facilitates a water flood, e.g. dump flood, operation. A standard electric submersible pumping system is deployed in a wellbore to draw water from an aquifer or water source zone along the wellbore. A shroud and a crossover port are used in combination with the submersible pumping system to redirect pumped water downwardly along an isolated flow path. The downward flow of pumped water is directed along the wellbore and injected into a desired, injection zone to facilitate recovery of oil or to perform other types of water flood operations.

Abstract: A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation.

Abstract: A method and apparatus for controlling the production of well treatment fluid is disclosed. The apparatus includes: a sand system, a water system, a pumping system, a blender tub, and a virtual rate control system. The method includes determining an output rate from a sand system; sensing an output rate from a water system; sensing an output rate from a pumping system; sensing the height within a blender tub of a mixture of sand from the sand system and water from the water system; providing a virtual rate control system; and producing a drive signal to the pumping system using the virtual rate control system using a desired rate of well treatment fluid to be delivered to a well, the output rate of the sand system, the output rate of the water system, and the output rate of the pumping system.

Abstract: A new well system and a corresponding method for the production of fluids from the well is presented. The well system and production process taught herein presents the means to use larger cross sectional flow areas for well fluid production by injecting energized gas and chemicals into the well.

Abstract: A method to clean a wellbore and the near wellbore area adjacent to the wellbore of a hydrocarbon bearing and/or coal bed methane formation adjacent to the production zone of the wellbore is provided. Specifically, a method for removing liquids such as water and/or oil from the near wellbore formation is provided. Furthermore, A method to clean a casing inserted into a wellbore is also disclosed. A method for cleaning a wellbore of fracturing fluid, with or without proppant is also disclosed. Each of the methods includes the steps of injecting either liquid carbon dioxide or a treatment medium comprising liquid carbon dioxide into a wellbore through tubing such that the location at which the treatment medium is administered may be controlled. In some embodiments, pressure within the wellbore is regulated in order to either maintain the treatment medium in the liquid state, or allow at least a portion of the treatment medium to vaporize upon introduction into the wellbore.

Abstract: A method of obtaining a treatment composition for treating a hydrocarbon-bearing clastic formation having brine therein to enhance recovery of hydrocarbon from the formation.

Abstract: Treating fluid production and subterranean formation treating methods as well as treating fluid compositions that reuse at least part of a prior treating fluid, particularly a fluid having one or more constituents that can be relinked. This includes conditioning a selected at least partially delinked flow-back fluid recovered from a first treating fluid pumped into a well, such that the conditioned selected at least partially delinked flow-back fluid provides a constituent for a second treating fluid. Also included are pricing considerations. A composition for a treating fluid includes a treating fluid residual recovered from a well, preferably a conditioned treating fluid residual. Examples of such compositions include fracturing fluids and gravel pack fluids.

Abstract: In a WAG flood oil is displaced from a subterranean formation by injecting water alternately with gas into a single injection completion per pattern. The ratio of water to gas injected is the WAG ratio. In this invention, two separate injection completions are used in each pattern, with one placed directly above the other. A very low WAG ratio is used for injection into the bottom extremity of the formation. A very high WAG ratio is injected into the upper interval, at as high a rate as can safely be used without fracturing the formation. In the preferred embodiment, two horizontal well bores serve as the two completion intervals. Proper design of this method gives a vertical sweep efficiency of the gas that is several-fold greater than the best of previous WAG flood designs, especially in thin formations.

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 control system and method for determining optimal fluid injection pressure is based upon a model of a growing hydrofracture due to waterflood injection pressure. This model is used to develop a control system optimizing the injection pressure by using a prescribed injection goal coupled with the historical times, pressures, and volume of injected fluid at a single well. In this control method, the historical data is used to derive two major flow components: the transitional component, where cumulative injection volume is scaled as the square root of time, and a steady-state breakthrough component, which scales linearly with respect to time. These components provide diagnostic information and allow for the prevention of rapid fracture growth and associated massive water break through that is an important part of a successful waterflood, thereby extending the life of both injection and associated production wells in waterflood secondary oil recovery operations.

Abstract: A method of stimulating coalbed methane production by injecting gas into a producer and subsequently placing the producer back on production is described. A decrease in water production may also result. The increase in gas production and decrease in water production may result from: (1) the displacement of water from the producer by gas; (2) the establishment of a mobile gas saturation at an extended distance into the coalbed, extending outward from the producer; and (3) the reduction in coalbed methane partial pressure between the coal matrix and the coal's cleat system.

Abstract: A hydrocarbon containing formation may be treated using an in situ thermal process. Hydrocarbons, H2, and/or other formation fluids may be produced from the formation. Heat may be applied to a first portion of the formation to mobilize hydrocarbons within the formation. Heat may be applied to a second portion of the formation to raise a temperature of the second portion to a pyrolysis temperature. Vaporized hydrocarbons and pyrolysis fluids may be produced from the formation.

Abstract: A method and a system for testing a borehole in an underground formation by the use of so-called closed chamber testing. When carrying out the method, a test or production pipe (5) is carried down the borehole, where the test pipe can be closed at its upper end and at its lower end is provided with a downhole assembly (6) comprising equipment for testing of fluid flow from the formation (3), the annulus (23) between the test pipe (5) and a casing (20) in the borehole being shut off during the test by a gasket (22) at a desired depth, and fluid from the formation being allowed to flow through the test pipe (5) to a collecting tank (9) coupled to the test pipe via a flow head (4) at the upper end of the test pipe (5).

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: An apparatus is provided comprising a first tubular having an inside surface and outside surface defining an outside diameter; a second tubular concentric with the first tubular, the second tubular having an inside surface defining an inside diameter greater than the outside diameter of the first tubular, an outside surface, and a longitudinal axis; a plurality of spacers between the first and second tubulars, each spacer having a longitudinal axis parallel to the longitudinal axis of the second tubular, wherein at least one spacer is hollow; and at least one data sensing device and/or at least one data collecting device and/or at least one data transmitting device is carried within the at least one hollow spacer.

Abstract: A control system and method for determining optimal fluid injection pressure is based upon a model of a growing hydrofracture due to waterflood injection pressure. This model is used to develop a control system optimizing the injection pressure by using a prescribed injection goal coupled with the historical times, pressures, and volume of injected fluid at a single well. In this control method, the historical data is used to derive two major flow components: the transitional component, where cumulative injection volume is scaled as the square root of time, and a steady-state breakthrough component, which scales linearly with respect to time. These components provide diagnostic information and allow for the prevention of rapid fracture growth and associated massive water break through that is an important part of a successful waterflood, thereby extending the life of both injection and associated production wells in waterflood secondary oil recovery operations.

Abstract: 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.

Abstract: The invention includes a method of scheduling cyclic steaming of a group of petroleum-containing wells including: inputting to a production-predicting means a group of data describing at least in part the past cyclic steaming and resulting production of a group of petroleum-containing wells; processing the data in the production-predicting means and outputting a group of production predictions for the group of wells during a future steaming cycle; inputting the group of production predictions into an optimization means; inputting an initial steaming cycle schedule for the group of wells into the optimization means; processing the group of production predictions and the initial steaming cycle schedule in the optimization means by the steps including: determining a ranking for the initial steaming cycle schedule for the group of production predictions against a pre-determined ranking criteria; producing a group of new steaming cycle schedules based on the ranking of the initial steaming cycle a schedule optimiz

Abstract: One embodiment of my invention comprises a tool string for testing a wellbore formation that includes a production inlet, an injection outlet, and a sampler apparatus. Fluid is taken from a production zone, into the tool string through the production inlet, out of the tool string through the injection outlet, and into the injection zone. Within the interior of the tool string, the sampler apparatus takes samples of the fluid flowing therethrough. In another embodiment, a large volume of sample fluid is trapped within the interior of the tool string, such as between two valves, and is removed from the wellbore along with the tool string subsequent to the test. In another embodiment, the tool string includes at least one perforating gun to perforate one of the production and injection zones. The tool string may also include two perforating guns to perforate both the production and injection zones.

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: One embodiment of my invention comprises a tool string for testing a wellbore formation that includes a production inlet, an injection outlet, and a sampler apparatus. Fluid is taken from a production zone, into the tool string through the production inlet, out of the tool string through the injection outlet, and into the injection zone. Within the interior of the tool string, the sampler apparatus takes samples of the fluid flowing therethrough. In another embodiment, a large volume of sample fluid is trapped within the interior of the tool string, such as between two valves, and is removed from the wellbore along with the tool string subsequent to the test. In another embodiment, the tool string includes at least one perforating gun to perforate one of the production and injection zones. The tool string may also include two perforating guns to perforate both the production and injection zones.