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 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: 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: 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: 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: 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: 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: 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: 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 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: 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: 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: 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: 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 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: 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: 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: 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.

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: Embodiments relate to a method for recovering hydrocarbons from a formation including collecting a formation sample, forming the sample into particles, exposing the sample to a cleaning fluid, and analyzing the sample. Embodiments also relate to a method for recovering hydrocarbons from a formation including the steps of collecting a formation sample, first exposing the sample to a cleaning fluid, forming the sample into particles, exposing the sample to a second cleaning fluid and analyzing the sample.

Abstract: A method for gas analysis can include continuously diverting a portion of drilling fluid into a sample chamber from a drilling fluid stream, creating a bidirectional drilling fluid circulation to liberate gas from the drilling fluid, applying a suction to a gas capturing chamber, and allowing a sample of the liberated fluid to continuously flow through the gas capturing chamber, continuously be filtered, and continuously flow into a gas analyzer. The method can include maintaining the sample chamber in an open configuration or decompressing the gas capturing chamber by closing off one or more sample inlets and sample outlets and exhausting portions of the liberated fluid that do not flow to the gas analyzer. The method can include simultaneously providing analysis data to client devices.

Abstract: A formation testing apparatus and method are disclosed. In one aspect, a fluid is drawn from a formation, one or more sensors measure pressure of the fluid during the during drawing of the fluid, and a processor estimates an inflection point from the pressure measurements and controls the drawing of the fluid from the inflection point until the pressure of the fluid drops to a selected level.

Abstract: Methods and apparatuses for evaluating a fluid from a subterranean formation of a wellsite via a downhole tool positionable in a wellbore penetrating a subterranean formation are provided. The apparatus relates to a downhole tool having a probe with at least two intakes for receiving fluid from the subterranean formation. The downhole tool is configured according to a wellsite set up. The method involves positioning the downhole tool in the wellbore of the wellsite, drawing fluid into the downhole tool via the at least two intakes, monitoring at least one wellsite parameter via at least one sensor of the wellsite and automatically adjusting the wellsite setup based on the wellsite parameters.

Abstract: Methods and apparatus that change the mobility of formation fluids using thermal and non-thermal stimulation including, an example apparatus to simultaneously provide thermal and non-thermal stimulation to change a mobility of a fluid in a subsurface formation includes one or more containers to hold one or more reactants. Additionally, the example apparatus includes a reactor to initiate a chemical reaction with at least one of the reactants. Further, the example apparatus includes an injector to inject a product of the chemical reaction into a formation. The product of the chemical reaction includes heat and a gaseous diluent to change a mobility of a fluid in a subsurface formation.

Abstract: An apparatus for obtaining fluid samples in a subterranean wellbore comprises a carrier assembly configured to be disposed in a subterranean wellbore; a sampling chamber operably associated with the carrier assembly; a pressure assembly coupled to the sampling chamber and configured to pressurize a fluid sample obtained in the sampling chamber, wherein the pressure assembly is configured to contain a pressure generating agent; an activation mechanism configured to activate the pressure generating agent; and a power device operably associated with the carrier assembly and configured to provide an impulse for activating the activation mechanism, wherein the power device is not disposed on the pressure assembly.

Abstract: Apparatus and methods for measuring properties of formation material and fluid in a borehole wall. In some embodiments, the apparatus includes a cylinder with a drawdown piston slideably disposed therein, a probe assembly and a passageway configured to provide fluid communication between the probe assembly and the cylinder. The probe assembly has a housing, a piston slideably disposed within the housing, the piston having a throughbore and a pad coupled thereto, and a tubular slideably disposed within the throughbore. The drawdown piston is translatable from a first position toward a second position to draw fluid into the probe assembly, the passageway and the cylinder, and translatable from the second position toward the first position to increase pressure of fluid in the passageway.

Abstract: A retrievable flow module (RFM) apparatus is provided. In one embodiment, the RFM apparatus is a standalone assembly configured to mate with a subsea device, such as a production tree. The RFM apparatus may include a frame within which various flow control and monitoring elements are disposed. The frame may have an alignment system that enables the RFM apparatus to horizontally mate with the tree. Because the RFM apparatus provides for the collocation of flow control and monitoring elements within a standalone assembly, deployment or retrieval of the flow control and monitoring elements may be accomplished in single operation. Additional systems, devices, and methods are also disclosed.