Abstract: An in situ extraction process for the recovery of hydrocarbons from a hydrocarbon bearing formation, including the steps of injecting a solvent consisting substantially of one of the group of H2S, Ammonia or COS into the formation to mobilize the hydrocarbons for extraction by forming a mobile in situ extraction fluid; and lifting the extraction fluid containing the mobilized hydrocarbons from the underground formation to the surface. In a further aspect an extraction method for a specific reservoir is provided including the steps of: establishing a minimum desired extraction rate, based on a value for the porosity, permeability and dead oil viscosity of the in situ bitumen in the specific reservoir, determining a desired minimum operating extraction temperature determining a desirable range of operating pressures identifying solvents predicted to deliver the operating extraction temperature within the range of operating pressures, and selecting a preferred solvent to use in the process.

Abstract: A method and apparatus is provided for off-line concentration determination of components liquid hydrocarbon mixtures such as crude or heavy oil. A sampling unit continuously delivers a sample volume to a fluid flow path while a temperature control module maintains the sample at a predetermined setpoint temperature. A homogenization module helps prevent sample stratification while a flow control module maintain a constant sample flow rate. A spectrometer is communicably coupled to an optical transmission cell to transmit and receive radiation. The transmission cell includes collection optics to capture and aggregate non-collimated radiation emerging from the cell, for transmission to the spectrometer. The spectrometer measures sample spectra at a predetermined rate of flow of the sample volume through the transmission cell. A processor is configured to capture and use the spectra in combination with a model of spectra for the hydrocarbon mixture.

Abstract: Methods of actuating a well tool can include releasing chemical energy from at least one portion of a reactive material, thermally expanding a substance in response to the released chemical energy, and applying pressure to a piston as a result of thermally expanding the substance, thereby actuating the well tool, with these steps being repeated for each of multiple actuations of the well tool. A well tool actuator can include a substance contained in a chamber, one or more portions of a reactive material from which chemical energy is released, and a piston to which pressure is applied due to thermal expansion of the substance in response to each release of chemical energy. A well tool actuator which can be actuated multiple times may include multiple portions of a gas generating reactive material, and a piston to which pressure is applied due to generation of the gas.

Abstract: A system for creating a log during gas detection and monitoring is disclosed herein. The system can include a gas detection and well logging device for sensing and transmitting data, which can include a processor in communication with a monitoring device. The monitoring device can monitor, acquire, and transmit data associated with a drilling operation. The processor can receive the data, calibrate the data, and log the data into files. The processor can capture sensed data based on a time event and a depth event. The processor can scale the data and form a geological-hydrocarbon log for transmission. A client device can be in communication with the gas detection and well logging device, and can have computer instructions for querying the geological hydrocarbon log, the data, and the files to obtain real time streaming data for instant display.

Abstract: An apparatus comprising a fluid communication device, a sample chamber, and a coupling assembly. The fluid communication device is operable to establish fluid communication between a downhole tool and a subterranean formation penetrated by a wellbore in which the downhole tool is positioned. The sample chamber is in selectable fluid communication with the formation via the fluid communication device. The coupling assembly mechanically couples the sample chamber within the downhole tool and comprises a cam rotatable between a first position and a second position, wherein the cam preloads the sample chamber when in the first position is disengaged from the sample chamber in the second position.

Abstract: This invention relates to oil production, more specifically, oil production using the formation hydrofracturing process, and can be used for monitoring the operation of a producing oil well.

Abstract: Described herein are variable-volume reservoir (e.g., syringe pump) based processes and systems usable to characterize samples of reservoir fluids, without having to first transport the fluids to the surface. Variable-volume reservoirs are used, for example, for one or more of storing reactants, controlling mixing ratios and storing used chemicals. The processes and systems can be used in various modes, such as continuous mixing mode, flow injection analysis, and titrations. A fluid interrogator, such as a spectrometer, can be used to detect a change in a physical property of the mixture, which is indicative of an analyte within the mixture. In at least some embodiments, a concentration of the analyte solution can be determined from the detected physical property.

Abstract: The present invention relates to an oil-pressure type fixed piston sampler for sampling a soil sample for site investigation. The oil-pressure type fixed piston sampler comprises a sampling unit (12) and an oil-pressure controller (14). Here, when the sampling unit (12) inserted into a drilled hole and a movable piston (80) moves downward, a sampling tube (1) moves downward to take a sample. The oil-pressure controller (14) connected with the sampling unit (12) controls oil pressure to cause the movable piston (80) to shift vertically. The sampling unit (12) comprises an upper head (20), a lower head (40), a piston housing (70), a rod block (100), a movable rod (90), a fixed piston (110), a fixed rod (92) and a separation rod (94). Since the sampling tube (1) takes a sample by a piston indentation method, high-quality, undisturbed samples can be obtained.

Abstract: Methods and systems to characterize a fluid in a reservoir to determine if the fluid is in one of equilibrium or non-equilibrium in terms of one of gravity, solvency power, entropy effect or some combination thereof. The method includes acquiring tool data at each depth for each fluid sample of at least two fluid samples wherein each fluid sample is at a different depth and communicating the tool data to a processor. Determining formation properties of each fluid sample to obtain formation property data and determining fluid properties for each fluid sample to obtain fluid property data. Selecting a mathematical model based on one of gravity, solvency power or entropy, in view of a fluid property, using one of tool data, formation property data, fluid property data, known fluid reservoir data or some combination thereof, to predict if the fluid is in an equilibrium distribution or a non-equilibrium distribution.

Abstract: Methods and apparatus for acquiring mud gas logging data, comparing the mud gas logging data to second data associated with a sidewall fluid sample measurement, and adjusting calibration data associated with a mud gas logging tool based on the comparison of the mud gas logging data and the second data associated with the sidewall fluid sample measurement.

Abstract: A method of mixing a formation fluid sample obtained in a downhole sampling chamber. The method includes positioning the downhole sampling chamber having a longitudinal axis in a rotary stand and rotating the downhole sampling chamber generally about the longitudinal axis. The method also includes imparting angular momentum to the formation fluid sample in the downhole sampling chamber, thereby mixing the formation fluid sample.

Abstract: Subsurface formation evaluation comprising, for example, sealing a portion of a wall of a wellbore penetrating the formation, forming a hole through the sealed portion of the wellbore wall, injecting an injection fluid into the formation through the hole, and determining a saturation of the injection fluid in the formation by measuring a property of the formation proximate the hole while maintaining the sealed portion of the wellbore wall.

Abstract: A packer is disclosed comprising a body with a first end and a second end, wherein the first end and the second end are configured to establish a connection with downhole equipment and wherein at least one of the first end and the second end is configured to establish a fluid flow between the downhole equipment, at least one guard drain, at least one sample drain, at least one guard drain flow line, at least one sample drain flow line configured to transport fluid flow from and to the at least one sample drain and one of the first end and the second end of the body, two swivel connections and a sealing element.

Abstract: An apparatus for testing a subterranean formation penetrated by a wellbore, comprising a tool having a sample flow line an inlet disposed with the tool and configured to establish fluid communication between the formation and the sample flow line to draw a fluid sample into the sample flow line, and an active filter positioned in the sample flow line and providing a filter flow route and a bypass flow route in the sample flow line.

Abstract: The system includes a gas processor with gas processor data storage and computer instructions to receive in various device protocols simultaneously information from rig based sensors and gas analysis devices drilling data, calibrate the devices and graphically present the data using both time events and depth events. Computer instructions scale the data and form the geological-hydrocarbon executive dashboard for transmission to various client devices to present real time streaming data, real time calibration information, real time alarms while enabling users to add and remove detection devices and sensors, including rig servers and remote servers, online without shutting down the entire monitoring and analysis system.

Abstract: The method uses a gas processor, various data collection devices each having a unique device protocol to receive drilling data, calibrate the devices and graphically present the data using both time events and depth events. The method includes computer implemented steps to scale the data and form the geological-hydrocarbon executive dashboard for transmission to various client devices to obtain real time streaming data, real time calibration information, while adding and removing detection devices and sensors online without shutting down the entire monitoring and analysis system for instant display.

Abstract: Formation testing which may involve circulating mud in a pipe string from a mud pit through a port in the pipe string to a downhole diverter sub, wherein the pipe string is suspended in a wellbore extending into a subterranean formation, operating a downhole pump to pump formation fluid from the formation, wherein the formation fluid comprises gas, and mixing the pumped formation fluid with circulated mud such that a proportion of the pumped formation gas in the circulated mud is maintained below a threshold value.

Abstract: A wireline configurable toolstring is conveyed within a wellbore extending into a subterranean formation via a tubular string to which the wireline configurable tool string is coupled in a manner permitting relative motion of the wireline configurable toolstring and the tubular string. The wireline configurable toolstring converts rotary motion imparted by rotation of the tubular string, or by fluid flow resulting from reciprocation of the tubular string, into electrical energy. The wireline configurable toolstring also comprises at least one wireline configurable instrument powered by the electrical energy.

Abstract: A method for controlling drilling fluid rate in a wellbore is disclosed. A drill string is disposed into the well and connected to a formation testing or sampling tool. Drilling fluid is circulated at a first rate through the drill string. Data related to the wellbore, a formation about the wellbore or the formation sampling tool is transmitted to a processor. Upon analysis of the data, the drilling fluid circulation rate is changed to a second rate that is different from the first rate.

Abstract: An assembly capable of being disposed in a subterranean bore for obtaining a fluid sample is described. The assembly can include an apparatus having a sample chamber and a housing encasing the sample chamber and providing a pressure source. The pressure source can be disposed of in an annulus defined by the sample chamber and the housing. The assembly can be attached to a slick line or wire line and conveyed into a wellbore.

Abstract: In one aspect, an apparatus for obtaining a fluid from a formation is disclosed that in embodiment may include a fluid extraction device that extracts the fluid from the formation into a first fluid line, a sample chamber coupled to the first fluid line via a second fluid line that receives the fluid from the first fluid line, wherein the first fluid line and the second fluid line receive contaminated formation fluid when the fluid extraction device initially extracts the fluid from the formation, and a fluid removal device associated with the second fluid line for receiving at least a portion of the contaminated formation fluid from the second fluid line.

Abstract: An arrangement having a body with at least one drain provided in the body is disclosed. The drain is configured to receive fluid when the body is expanded from a first unexpanded condition to a second expanded condition. At least one flowline is connectable to the drain. A screen is positioned over the drain and is configurable to expand from the first unexpanded condition to the second expanded condition.

Abstract: A method for detecting the presence of an acid gas in a formation fluid from a subterranean formation comprises (a) lowering a coring assembly into a wellbore. The coring assembly including an outer core barrel and an inner core barrel disposed within the outer core barrel. The inner core barrel has an upper end, a lower end opposite the upper end, and a core sample chamber extending axially from the lower end. In addition, the method comprises (b) capturing a core sample from the subterranean formation within the sample chamber. Further, the method comprises (c) raising the coring assembly to the surface after (b). Still further the method comprises (d) contacting a formation fluid in the sample chamber with at least one detector during (c). Moreover, the method comprises (e) detecting the presence of a formation acid gas in the formation fluid with the at least one detector during (c).

Abstract: Cleanup monitoring and prediction in real time targeting estimation of pumpout volume versus final contamination, including detecting breakthrough of formation fluid to a sampling tool and detecting transition of cleanup regime from a predominantly circumferential cleanup regime to a predominantly vertical cleanup regime. Similar workflow can be employed for estimating contamination at the end of cleanup production for a given pumpout volume.

Abstract: A technique involves collecting formation fluids through a single packer. The single packer comprises an outer bladder with drains positioned in the outer bladder to obtain formation fluid samples. Features also may be incorporated into the single packer to limit sealing in the circumferential spaces between the drains and to provide a larger sampling surface than provided simply via the drain surface area.

Abstract: The present disclosure relates methods and apparatuses for testing and sampling of underground formations or reservoirs. The apparatus may include at least one extendable element configured to penetrate a formation. The at least one extendable element may include at least one drill bit with a nozzle configured to receive formation fluids. The at least one extendable element may include at least one sensor disposed on the at least one extendable element. The at least one extendable element may also include a source of stimulus for stimulating the formation. The at least one extendable element may be configured to detach and/or attach from/to a bottom hole assembly (BHA). One method may include steps for performing testing on the formation for estimating a parameter of interest of the formation. Another method may include steps for performing testing to estimate a parameter of interest of the formation fluid.

Abstract: An apparatus for obtaining a fluid at a position within a wellbore that penetrates a subterranean formation includes a body adapted to be disposed in the wellbore on a conveyance equipped with one or more expandable packers providing a sample region disposed between an upper cleanup zone and a lower cleanup zone when expanded into abutting contact with the wellbore wall; an upper cleanup port provided at the upper cleanup zone; a lower cleanup port provided at the lower cleanup zone; at least one fluid cleanup flowline in fluid connection with the upper and lower cleanup ports; a sampling inlet provided at the sampling region; and a sampling flowline in fluid connection with the sampling inlet for drawing fluid from the sampling region.

Abstract: A downhole tool includes a pump to facilitate a flow of sampling fluid through the downhole tool. The sampling fluid flows from an inlet of the downhole tool toward an outlet of the downhole tool or to a sampling chamber. The downhole tool also includes a sensor located in the pump. The sensor facilitates a calculation of a pumping efficiency of the downhole tool.

Abstract: Methods and apparatus for acquiring mud gas logging data, comparing the mud gas logging data to second data associated with a sidewall fluid sample measurement, and adjusting calibration data associated with a mud gas logging tool based on the comparison of the mud gas logging data and the second data associated with the sidewall fluid sample measurement.

Abstract: An apparatus for controlling fluid flow that includes a chamber having a first valve and a second valve; a sensor that senses a pressure parameter associated with the chamber; and a controller programmed to operate the first valve and the second valve in response to the sensed pressure parameter may be used to control for flow and to obtain data relating to a formation and/or formation fluid.

Abstract: A system and method for capturing fluid samples from a borehole is described. The system includes an outer pipe (703) and an inner pipe (702) disposed within the outer pipe. A removable capture assembly may be disposed within the inner pipe proximate to a top of the inner pipe. A flow port (706) may provide fluid communication with the inner pipe. The system may also include a flow mandrel (756) disposed around the outer pipe. The flow mandrel may include a flow path in fluid communication with an annular space within the outer pipe, and the removable capture assembly may be at least partially disposed within the flow mandrel.

Abstract: A pumping system comprising: a probe to suction a fluid from a fluid reservoir; a pump in fluid communication with said probe; a sensor for detecting phase changes in said pumping system, said sensor in fluid communication with said probe or pump, said sensor generating a sensor signal; a fluid exit from said pumping system, said fluid exit being in fluid communication with said pump; and a variable force check valve located between said probe and said fluid exit.

Abstract: A formation testing apparatus and method for obtaining samples with lower levels of contaminants is provided. Such a method can remove contaminants from at fluid sample, and can include the steps of obtaining fluid, from a formation and passing a first quantity of the fluid through a sample flow line. A connection between the sample flow line and a sample chamber can he opened, and a first portion of the first quantity of the fluid can be drawn into the sample chamber via a floating piston. The first portion can be forced out of the sample chamber, and this process can be repeated until sufficient contaminants have been removed. Finally, a second portion of the first quantity of the fluid can be drawn into the sample chamber as the fluid sample.

Abstract: A method includes lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe and establishing a fluid communication between the downhole tool and the formation at a location in the wellbore. The method also includes extracting from the formation a first fluid stream through the fluid communication and passing the first fluid stream through the downhole tool for a first duration. The method further includes breaking the fluid communication between the downhole tool and the formation, moving the pipe in the wellbore, and reestablishing the fluid communication between the downhole tool and the formation essentially at the location in the wellbore subsequent to moving the pipe in the wellbore.

Abstract: Well fluids in coalbed natural gas reservoirs and other carbonaceous reservoirs are analyzed to determine production factors such as gas content, critical desorption pressure, and/or other reservoir and operational variables. In particular, the partial pressure of methane or a predictor substance, or a methane concentration, are measured and/or determined for the wells and production factors are determined therefrom.

Abstract: In one embodiment, a sampling while drilling tool includes a drill collar having a first end, a second end, an outer wall extending between the first and second ends, and at least one opening extending through the outer wall to a cavity within the drill collar. The sampling while drilling tool also includes a sample chamber positionable in the cavity through the opening in the outer wall and a passage for conducting a drilling fluid through the drill collar.

Abstract: The current invention relates to families of scale-inhibitors having different UV/VIS absorption profiles and their application in a method for stimulating an oilfield comprising those families.

Abstract: A packer assembly has an inner expandable packer. An outer layer having sealing bodies may be disposed about and/or positioned on the outer surface of the inner expandable packer member. Each of the sealing bodies may have an elastomeric body, and one or more flowlines may be embedded in the elastomeric body of each of the sealing bodies. The sealing bodies may be located in grooves in the inner expendable packer member. The sealing bodies may contact a surrounding casing or a surrounding formation to form an annular seal; in an embodiment, the sealing bodies and the inner expandable packer member may contact a surrounding casing or a surrounding formation to form an annular seal. The sealing bodies may be non-integral with each other and/or separable from each other.

Abstract: Methods and related systems are described relating to monitoring particulates downhole at in-situ conditions. Solid particles being carried in the fluid as the fluid is produced from the reservoir formation are monitored. The downhole solid particle monitoring can include measuring the quantity (e.g., volume fraction, weight fraction, or the like) of solid particles, measuring the distribution of sizes of the solid particles, and/or measuring the shape of the particles. The solid particles can be monitored using one or more of sensors such as optical spectrometers, acoustic sensors, video cameras, and erosion probes. A sanding prediction is generated based at least in part on the monitoring of the solid particles, and the sanding prediction is then used to design a completion, lift system, and surface facilities for the wellbore and/or select operating conditions so as to control sanding during production.

Abstract: Methods for improving the quality of hydrocarbon fluids produced by in situ pyrolysis or mobilization of organic-rich rock, such as oil shale, coal, or heavy oil. The methods involve reducing the content of olefins, which can lead to precipitation and sludge formation in pipelines and during storage of produced oils. The olefin content is reduced by arranging wells and controlling well pressures such that hydrocarbon fluids generated in situ are caused to pass through and contact pyrolyzed zones in which coke has been left. This contacting chemically hydrogenates a portion of the olefins in the pyrolysis oil by reducing the hydrogen content of the coke.

Abstract: A system for measuring a formation parameter, the system including: a formation parameter test device having: a structure capable of segregating a discrete volume including a formation interface surface within a well, and a parameter sensor in operable communication with the volume; a high bandwidth communications system in operable communication with the parameter sensor; and a processing unit in operable communication with the high bandwidth communications system and disposed remotely from the parameter sensor, the processing unit configured to receive parameter data.

Abstract: A sampling assembly has an inner expandable packer, and an outer layer formed by rings may be disposed about and/or may be positioned on the outer surface of the inner expandable packer member. Drains may be positioned between the rings and may be located under ports positioned between the rings. Flowlines may be connected to the drains, may be positioned in the rings and may extend through the rings. For each of the ports, a plate may be positioned between the port and the laterally adjacent port. The flowlines may be connected to a downstream component, such as a fluid analysis module, a fluid containment module and/or the like.

Abstract: A method, according to one or more aspects of the present disclosure, for operating a positive displacement pump of a downhole tool comprises supplying a hydraulic pressure to the pump to actuate a two-stroke piston to displace fluid at least partially through the downhole tool; moving the piston in a first stroke direction; and reversing the direction of the piston upon completion of the first stroke of the piston. Completion of a stroke may comprise a head of the piston substantially abutting an end wall of a chamber of the pump.

Abstract: Methods comprising lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe, establishing fluid communication between the downhole tool and the formation at a location in the wellbore, extracting from the formation a first fluid stream and passing the first fluid stream through the downhole tool for a first duration, breaking fluid communication between the downhole tool and the formation, reestablishing fluid communication between the downhole tool and the formation essentially at the location in the wellbore, extracting from the formation a second fluid stream and passing the second fluid stream through the downhole tool for a second duration, and capturing in the downhole tool a fluid sample of the second fluid stream.mud.

Abstract: A technique involves collecting formation fluids through a single packer having at least one drain located within the single packer. The single packer is designed with an outer structural layer that expands across an expansion zone to facilitate creation of a seal with a surrounding wellbore wall. An inflatable bladder can be used within the outer structural layer to cause expansion, and a seal can be disposed for cooperation with the outer structural layer to facilitate sealing engagement with the surrounding wellbore wall. One or more drain features are used to improve the sampling process and/or to facilitate flow through the drain over the life of the single packer.

Abstract: An apparatus comprising a tool body configured to be conveyed within a wellbore extending into a subterranean formation, an inflatable packer coupled to the tool body, and a probe assembly coupled to the tool body and comprising an inner sealing element and an outer sealing element, wherein at least one of the inner sealing element and the outer sealing element comprises an elongated shape, and wherein at least a portion of the probe assembly is disposed on the inflatable packer.

Abstract: A flow rate control valve, wherein the flow rate control valve is provided with a first circular tube section having first and second ports formed on a body forming the flow rate control valve, and also with a plate section mounted to the upper part of the first circular tube section through a mounting section. The plate section is provided to only one end side of the first circular tube section, is supported on the mounting section in a cantilever manner, and is formed flat.

Abstract: An apparatus and method is disclosed for conducting a fluid and solids production test in a subterranean well. A testing apparatus may be inserted into a wellbore. The apparatus may employ a tubular housing with entry port(s) through the housing. An inner assembly may be positioned within the tubular housing, the inner assembly being configured for connection to the tubular housing. The inner assembly may include a fluid permeable screen and a distal end forming a reservoir that is scaled, or may be adapted to be scaled, for the collection of solids during a well production testing event. Following a testing event, the apparatus may be removed from the wellbore to enable the collected solids to be measured to determine the amount of solids generated by a subterranean formation at actual field flow conditions.

Abstract: Downhole tools and methods are provided for injecting fluid into a formation. A downhole tool may include a first chamber of injection fluid separated from a second chamber of working fluid by a piston. The working fluid may be employed to apply pressure to the piston to direct injection fluid from the first chamber to the formation. A flow regulator may regulate flow of the injection fluid from the first chamber to the formation.

Abstract: A probe for establishing fluid communication between a downhole tool and a subterranean formation is provided. The downhole tool is positioned in a wellbore penetrating the subterranean formation. The probe includes a platform operatively connected to the downhole tool, at least one packer operatively connected to the platform, the packer having at least one hole extending therethrough and at least one embedded member disposed in the packer for enhancing the operation of the packer as it is pressed against the wellbore wall.