Abstract: A sensor assembly includes a position measurement sensor, a slickline, and a processor. The position measurement system measures angular velocity of the sensor assembly inside a wellbore that extends in an axial direction. The slickline raises and lowers the position measurement sensor in the wellbore. The processor executes a series of measurement units including: an inclination measurement unit, a coordinate measurement unit, a depth measurement unit, and a data storage unit. The inclination measurement unit determines an inclination of the position measurement sensor. The coordinate measurement unit determines radial coordinates of the position measurement sensor. The depth measurement unit determines a real-time depth level of the position measurement sensor. Each of the inclination, the radial coordinates, and the real-time depth level are determined from the angular velocity.

Abstract: A sag detection apparatus comprises an oven containing a sample cell supported by a cell support structure, a thermal conductivity sensor including a sensor housing, and a roller with a first end supported by a first bearing and fixedly coupled to a first end of the cell support structure and a second end supported by a second bearing and fixedly coupled to a second end of the cell support structure. Temperature sensor wires electrically connect a temperature sensor and first fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller. Heat source wires electrically connect a heat source and a second fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller.

Abstract: A method that includes deploying a casing with a multi-electrode configuration over a dielectric layer in a downhole environment. The method also includes collecting electromagnetic (EM) measurements using the multi-electrode configuration, and processing the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall. A related system includes a casing deployed downhole, the casing having a multi-electrode configuration and a dielectric layer between the casing and the multi-electrode configuration. The system also includes a controller for directing collection of EM measurements using the multi-electrode configuration, and a processor that processes the EM measurements to obtain a characterization of fluids in an annulus between the casing and a borehole wall.

Abstract: A method includes acquiring trajectory information; based at least in part on a portion of the trajectory information, generating a set of candidate trajectories with associated performance indicator values; rendering a graphical user interface to a display; via the graphical user interface, receiving input that adjusts one of the performance indicator values; and, responsive to the adjustment of the one of the performance indicator values, selecting one of the set of candidate trajectories.

Abstract: Tools, processes, and systems for in-situ fluid characterization based on a thermal response of a fluid are provided. The thermal response of a downhole fluid may be measured using a downhole thermal response tool and compared with thermal responses associated with known fluids. The properties of the downhole fluid, such as heat capacity, diffusivity, and thermal conductivity, may be determined by matching the thermal response of the downhole fluid with a thermal response of a known fluid and using the properties associated with the known fluid. The composition of the downhole fluid may be determined by matching the viscosity of the downhole fluid to the viscosity of known fluid. A downhole thermal response tool for cased wellbores or wellbore sections and a downhole thermal response tool for openhole wellbores or wellbore sections are provided.

Abstract: Systems and methods of determining fluid properties are disclosed. An example apparatus to determine a saturation pressure of a fluid includes a housing having a detection chamber and a heater assembly partially positioned within the detection chamber to heat a fluid. The example apparatus also includes a sensor assembly to detect a property of the fluid and a processor to identify a saturation pressure of the fluid using the property of the fluid.

Abstract: Apparatus and methods for determining downhole fluid parameters are disclosed herein. An example method includes deploying a downhole apparatus into a wellbore. The downhole apparatus includes a sensor having a heater and a temperature sensor. The method also includes traversing the downhole apparatus through the wellbore and obtaining a first response with the sensor in a first position of the wellbore. The method also includes obtaining a second response with the sensor in a second position of wellbore and determining a presence of a boundary between the first and second positions based on the first and second responses.

Abstract: A thermal disturbance of a rock mass is performed by circulating a fluid through a borehole, a temperature of the circulation fluid differs from a temperature of the rock mass. Before, during and after the thermal disturbance, differential electrical signals proportional to a temperature difference between two points along the borehole are registered by at least one pair of differential temperature transducers disposed along an axis of the borehole Differential electrical signals measured before the thermal disturbance are compared with differential electrical signals measured during the thermal disturbance and differential electrical signals of different temperature transducers positioned along the wellbore borehole are compared with one another. Based on the comparison results of different rock mass areas with different properties are identified.

Abstract: A method for determining properties of a formation is described herein. The method includes disposing a well-logging tool in a borehole. The well-logging tool includes a device for varying temperature of the formation and two acoustic logging probes located symmetrically along the well-logging tool length relative to the device for varying temperature of the formation. During the logging tool movement in the borehole, continuous varying of the formation temperature, continuous acoustic logging, and continuous measurement of formation temperature are performed. Dependencies of the measured velocity and attenuation of the Stoneley waves as functions of the measured temperature of the formation are obtained. Based on the obtained dependencies, properties of the formation are determined.

Abstract: A method of sampling fluid from a subterranean formation includes positioning a first tool having a heater in a borehole so that the heater is adjacent a portion of the subterranean formation; heating with the heater the portion of the subterranean formation; removing the first tool from the borehole; orienting a second tool having a sampling probe in the borehole so that the sampling probe is to contact a portion of the subterranean formation heated by the heater; and obtaining via the sampling probe a fluid sample from the portion of the subterranean formation heated by the heater.

Abstract: The invention includes a method for determining a steam injection schedule for a set of subsurface formation subsurface regions of an oil field, the method including the steps of determining a thermal maturity for each subsurface region of the set; calculating a latent heat target for each subsurface region according to the determined thermal maturity therefore; calculating a steam injection target for each subsurface region according to the calculated latent heat target therefore; determining the availability of steam for injection to the subsurface regions; and calculating a steam injection schedule for each subsurface region according to the determined steam availability and calculated steam injection targets for all subsurface regions of the set.

Abstract: An apparatus comprising a downhole measurement tool, a transducer coupled to the measurement tool, the transducer having a body with an outer surface, and a heater disposed adjacent the outer surface to conduct heat from the heater to the outer surface.

Abstract: Tracking fluid displacement along a wellbore using real time temperature measurements. A method of tracking fluid displacement along a wellbore includes the steps of: monitoring temperature in real time in the wellbore; and observing in real time a variation in temperature gradient between fluid compositions in the wellbore. Another method of tracking fluid displacement along a wellbore includes the steps of: monitoring temperature along the wellbore; and observing a variation in temperature gradient due to a chemical reaction in the wellbore. Another method includes the step of causing a variation in temperature gradient in the fluid while the fluid flows in the wellbore.

Abstract: Tracking fluid displacement along a wellbore using real time temperature measurements. A method of tracking fluid displacement along a wellbore includes the steps of: monitoring temperature in real time in the wellbore; and observing in real time a variation in temperature gradient between fluid compositions in the wellbore. Another method of tracking fluid displacement along a wellbore includes the steps of: monitoring temperature along the wellbore; and observing a variation in temperature gradient due to a chemical reaction in the wellbore. Another method includes the step of causing a variation in temperature gradient in the fluid while the fluid flows in the wellbore.

Abstract: A method of sampling fluid from a subterranean formation includes positioning a first tool having a heater in a borehole so that the heater is adjacent a portion of the subterranean formation; heating with the heater the portion of the subterranean formation; removing the first tool from the borehole; orienting a second tool having a sampling probe in the borehole so that the sampling probe is to contact a portion of the subterranean formation heated by the heater; and obtaining via the sampling probe a fluid sample from the portion of the subterranean formation heated by the heater.

Abstract: Disclosed is a method and apparatus for measuring in-situ stress in rock using a thermal crack. The method involves forming a borehole, cooling a wall of the borehole, applying tensile thermal stress, forming a crack in the borehole wall, and measuring temperature and cracking point. Afterwards, the borehole wall is heated to close the formed crack, the borehole wall is cooled again to re-open the crack, and temperature is measured when the crack is re-opened. The in-situ stress of the rock is calculated using a first cracking temperature at which the crack is formed and a second cracking temperature at which the crack is re-opened. Further, the apparatus cools, heats and re-cools the borehole wall, thereby measuring the first cracking temperature, the second cracking temperature, and the cracking point.

Abstract: A technique that is usable with a well includes disposing a distributed temperature sensor in a conduit that traverses a region of the well. The region contains at least two different well fluid layers. The technique includes circulating a fluid through the conduit and using the distributed temperature sensor to observe at least one temperature versus depth profile of the fluid. Based on the observation, the depth of a boundary of at least one of the well fluid layers is determined.

Abstract: An apparatus, system, and method are provided for determining injected fluid vertical placement in a formation. The apparatus includes a borehole drilled through a formation, and an injection conduit within the borehole. In one embodiment, the apparatus includes a fiber optic cable within the borehole wrapped helically around the injection conduit such that the fiber optic cable reads temperatures at specific depths and radial angles throughout the borehole. The apparatus includes a thermal insulation layer interposed between the injection conduit and the fiber optic cable such that the fiber optic cable detects the formation temperature rather than the injection conduit temperature. The apparatus includes a computer programmed to determine the vertical placement of the injected fluid within the formation based on the temperature readings. The apparatus detects an induced hydraulic fracture height, and detects whether an induced hydraulic fracture has deviated from the plane of the borehole.

Abstract: Samples of hydrocarbon are obtained with a coring tool. An analysis of some thermal or electrical properties of the core samples may be performed downhole. The core samples may also be preserved in containers sealed and/or refrigerated prior to being brought uphole for analysis. The hydrocarbon trapped in the pore space of the core samples may be extracted from the core samples downhole. The extracted hydrocarbon may be preserved in chambers and/or analyzed downhole.

Abstract: The present invention relates to methods and apparatus for making in situ thermal property determinations utilizing a heat source employed in wellbore stabilization procedures, well drilling, or well perforating, for example. In particular, using a heat source, such as a laser driller, to enable formation temperature measurements. Based on these measurements, thermal properties of the formation may be inferred.

Abstract: Wellbore heat loop systems, fillers for bores in the systems, and methods of the use of such systems; the systems in certain aspects having a heat loop wellbore in the earth having heat loop pipe extending down to one side of a bottom member and up therefrom on another side thereof, the bottom member in certain aspects having a body with first and second bores therethrough, the second bore sized and configured for securement thereat of an end of coil tubing; and, in certain aspects, filler material around the heat loop in the wellbore with a gel material mixed with the water.

Abstract: An environmentally mitigated navigation system includes a thermal isolating chamber, an inertial measurement unit that can include individual gyroscopes and accelerometers for making inertial measurements, and a temperature control system; the temperature control system includes a thermoelectric cooling system, which in a powered mode maintains the inertial measurement unit at a substantially predetermined temperature, and a phase change device for maintaining the inertial measurement unit or inertial sensors at substantially a predetermined temperature in an unpowered mode; the phase change device substantially maintains the predetermined temperature by changing phase to define a stable temperature window for the inertial measurement unit or individual sensors to make inertial measurements during the unpowered mode as well as during the powered mode.

Abstract: An earth energy transfer system with a moving energy transfer fluid, the system for transferring energy for an entity, the system, in certain aspects, having apparatus and related items for measuring an amount of energy transferred for the entity to or from the moving energy transfer fluid, and apparatus and related items for invoicing the entity for the amount of energy transferred. The system, in certain aspects, including apparatus and related items for calculating a price for the amount of energy transferred, said invoicing based on said price. The system, in certain aspects, including apparatus and related items for transmitting a signal indicative of a measured amount of energy transferred from the apparatus and related items for measuring to the apparatus and related items for invoicing. Methods are disclosed for using such systems to measure and calculate an amount of energy transferred and/or to invoice an entity for the transferred energy.

Abstract: The present invention provides a heater cable (10) that may be deployed in a wellbore to elevate the temperature of the wellbore above the temperature of the surrounding fluid and the formation. One or more fiber optic strings are included in or are carried by the heater cable. The heater cable carrying the fiber optics is placed along the desired length of the wellbore. At least one fiber optic string measures temperature of the heater cable at a plurality of spaced apart locations. Another string may be utilized to determine the temperature of the wellbore. In one aspect of this invention, the heater cable is heated above the temperature of the wellbore. The fluid flowing from the formation to the wellbore lowers the temperature of the cable at the inflow locations. The fiber optic string provides measurements of the temperature along the heater cable. The fluid flow is determined from the temperature profile of the heater cable provided by the fiber optic sensors.

Abstract: An earth energy transfer system with a moving energy transfer fluid, the system for transferring energy for an entity, the system, in certain aspects, having apparatus and related items for measuring an amount of energy transferred for the entity to or from the moving energy transfer fluid, and apparatus and related items for invoicing the entity for the amount of energy transferred. The system, in certain aspects, including apparatus and related items for calculating a price for the amount of energy transferred, said invoicing based on said price. The system, in certain aspects, including apparatus and related items for transmitting a signal indicative of a measured amount of energy transferred from the apparatus and related items for measuring to the apparatus and related items for invoicing. Methods are disclosed for using such systems to measure and calculate an amount of energy transferred and/or to invoice an entity for the transferred energy.