Abstract: Apparatus for use in sensing temperature in a wellbore, comprising: tubing comprising a plurality of temperature sensor modules provided at locations along the inside of the tubing, said temperature sensor modules comprising temperature sensors provided at least in part by at least one semiconductor element having electrical properties that vary with temperature; an electrical network configured to electrically connect to the semiconductor elements to in use allow measuring of the respective electrical properties of the semiconductor elements to infer a thermal characteristic of the semiconductor element; and at least one control module electrically connected to multiple temperature sensor modules, via the electrical network, and configured to receive and process an electrical signal associated with the temperature sensor modules to enable inference of the temperature of the semiconductor elements and the environment to which the tubing is exposed at the location of that semiconductor element.

Abstract: Memory gauge and method for processing recorded raw data acquired with a memory gauge in a well. The method includes selecting a first calibration table (C1), of the memory gauge, that has a highest calibration value for the measured parameter; performing a first analysis of the recorded raw data using the first calibration table (C1) to determine a highest measured value of the measured parameter; comparing the highest measured value of the measured parameter with highest calibration values of the plural calibration tables of the memory gauge; and when a highest calibration value of a second calibration table is closer to the highest measured value of the measured parameter than the highest calibration value of the first calibration table, selecting the second calibration table (C2); and performing a second analysis of the recorded raw data using the second calibration table (C2) to generate measured values of the measured parameter.

Abstract: A method and apparatus are provided for determining movement of a fluid into or out of a subsurface wellbore, to thereby enable accurate allocation of fluids being produced by or injected into each of several zones of the wellbore. A temperature change is effected in the fluid at a first location in the wellbore. A temperature of the fluid is measured at one or more sensing locations downstream of the location of the temperature change. A simulated heat flow profile is generated from a wellbore model. The simulated heat flow profile is compared to the measured temperature of the fluid at the one or more sensing locations. An inversion model is used to determine, for a plurality of points of interest, a fluid flow direction and/or a cumulative flow rate contribution.

Abstract: This inventive method provides a novel way of modeling basins in planning the drilling of crude oil and natural gas wells by accounting for thermodynamic considerations in tracking the pore pressure of a location of interest. By plotting the energy gradients, heat flux, and thermal conductivity of the location of interest, the user can more accurately identify the location of the Top of Geopressure and additional pertinent information during the well drilling planning process that can reduce costs and increase the safety of the process.

Abstract: A method for using the depth derivative of distributed temperature sensing data to identify fluid levels, gas production intervals, water production intervals, and other fluid flow activities inside or near the well-bore during the production process. The method may include providing a fiber optic based distributed temperature sensing measurement system through a production region. Temperatures through the production region are gathered as a function of the depth in the subsurface well and as a function of the elapsed time. The gathered data is utilized to calculate the depth derivative of the temperature changes as a function of depth in the subsurface well and of the elapsed time. The depth derivative data for analysis of the fluid levels are displayed by operators to identify fluid levels, gas production intervals, water production intervals, and other fluid flow activities inside or near the wellbore during the production process.

Abstract: A method for using a downhole probe. The method comprises providing a probe, at least one vertical cross section of the probe having an area of at least pi inches squared. The method further comprises inserting the probe into a bore of a drill collar and passing a drilling fluid through the bore of drill collar at a flow velocity of less than 41 feet per second.

Abstract: An apparatus for communicating with a downhole tool includes a sensor body including at least two electrodes electrically insulated from one another and an external control device configured to engage the two electrodes. Detection circuitry connected to the two electrodes is configured to monitor an electrical status across the two electrodes, through the external control device, and upon detecting a change in electrical status that matches a predefined pattern, communicate a command to power management circuitry to alter a power status of the downhole tool.

Abstract: The present invention provides an actually-measured marine environment data assimilation method based on sequence recursive filtering three-dimensional variation. The method includes: preprocessing actually-measured marine environment data; calculating a target function value; calculating a gradient value of a target function; calculating a minimum value of the target function; extracting space multi-scale information from the actually-measured data; and updating background field data to form a final data assimilation analysis field. The present invention improves the traditional recursive filtering three-dimensional variation method, and sequentially assimilates information with different scales, thereby effectively overcoming the problem that multi-scale information cannot be effectively extracted by a traditional three-dimensional variation method.

Abstract: A method, apparatus, and program product cluster a plurality of cells of an input unstructured volumetric grid representative of a subsurface volume into a plurality of clusters, simplify a boundary of each cluster and generate an output unstructured volumetric grid representing at least a portion of the input unstructured volumetric grid by generating in the output unstructured volumetric grid a respective cell for each of the plurality of clusters. The resulting output grid may be used to facilitate the generation of visualizations and/or numerical simulations.

Abstract: Computer processing time and results are improved in fully-coupled fully-implicit well-reservoir simulation system using Jacobian matrix methodology. Approximate inverse preconditioners are provided which treat a well influence matrix at comparable accuracy and robustness to those for the grid-to-grid flow terms of system matrix. The methodology is highly parallelizable and the data processing can be performed faster, as fewer solver iterations are required to converge to the same acceptable tolerances.

Abstract: There is described a technique for determining a temperature at a region below the surface of the Earth. In an embodiment, a time of travel of a seismic wave following the emission from a source into the earth is provided, and the travel time is used to estimate the temperature. In one example, a model based on the travel time and a further component, which may for example be based on heat flow and a constant of proportionality between seismic velocity and thermal conductivity, may be used to estimate the temperature.

Abstract: A pop-up monitoring base station for seafloor heat flow includes a recovery unit, a discarding unit and a cable chopping mechanism. The recovery unit includes a recovery support, internally accommodating two acoustic release devices provided with closable hooks on bottoms thereof and loaded with floating balls. The discarding unit includes a discarding support, below which a heat flow probe is fixedly connected. The recovery unit and the discarding unit are fixed together through a steel wire rope with two ends connected with the closable hooks at the bottoms of the acoustic release devices. A cable extends from the discarding unit through the cable chopping mechanism fixed on the bottom of the recovery support and connects with the floating balls. The cable can be chopped off and/or pulled out automatically to realize successful separation between the recovery unit and the discarding unit.

Abstract: A system and method for monitoring oil flow rates along a producing oil or gas well using a Distributed Acoustic Sensing fiber is described. This system uses the low-frequency component of the acoustic signal as a measurement of temperature variations within the well. The relative flow contributions can then be inferred from these temperature fluctuations.

Abstract: Temperature sensing devices and methods for determining downhole fluid temperature at a drill string in a borehole while drilling are disclosed. The device includes a temperature sensor capable of detecting and measuring rapid temperature changes and may be used to sense the temperature of fluid inside or outside the drill string. In addition, the device includes a thermal conductor that receives and secures the temperature sensor; the thermal conductor is in turn received and secured in a thermal insulator that provides a thermal barrier. In an embodiment, the device is disposed in a channel within an outer diameter of the drill string such that the device is protected from the side wall of the borehole and drilling fluid and cuttings can pass through the channel without becoming packed around the temperature sensor.

Abstract: An apparatus including an electromagnetic radiation source that emits electromagnetic radiation, a sample chamber comprising a fluid sample inlet for introducing a solids-laden fluid sample therein, and a detector that receives a backscattering signal and generates an output signal corresponding to a concentration of solids in the solids-laden fluid sample. The electromagnetic radiation transmits through the sample chamber and optically interacts with the solids-laden fluid sample to generate a backscattering signal. The sample chamber may include one or more of a shear bob for applying a shear rate to the solids-laden fluid sample, the shear bob suspended in the sample chamber and rotatable about an axis, a sealable fluid pressurizing inlet for pressurizing the sample chamber and a pressure gauge for measuring the pressure in the sample chamber when pressurized, and/or a temperature source for heating the solids-laden fluid sample.

Abstract: A temperature sensor for measuring a temperature within a subsea installation includes a fixture portion coupled to the subsea installation and a retrievable portion that is selectively operable to couple to the fixture portion. The fixture portion includes a constant volume of a fluid disposed at a measurement point within the subsea installation. The retrievable portion includes a pressure sensing element operable to measure a pressure associated with the constant volume of fluid such that a temperature at the measurement point is determinable.

Abstract: Wellbore wireless thermal conductivity quartz transducer comprising a thermal conductivity quartz transducer and a wireless communication system comprising an external device and an internal device, a cable, and a surface device. The thermal conductivity quartz transducer comprises a first quartz resonator, a heat dissipation element, a second quartz resonator, an electronics circuit and heat guiding means arranged for transferring a heat generated by said electronics circuit to said heat dissipation element, so that said dissipation temperature is higher than said ambient temperature. The invention is also a method for wirelessly performing transient response analysis of a formation in a wellbore with such transducer.

Abstract: A method for forming an ink jet printhead comprises processing an epoxy adhesive such that negative effects from physical contact with particular inks are reduced or eliminated. Conventional adhesives processed using conventional techniques are known to gain weight and squeeze out when exposed to certain inks such as ultraviolet inks and pigmented inks. An embodiment of the present teachings can include processing of a particular adhesive such that the resulting epoxy adhesive is suitable for printhead applications.

Abstract: The present invention concerns a method for measuring the thickness of any deposit of material on the inner wall of a structure conducting a fluid stream of hydrocarbons, the method comprising the steps of: applying a first heat pulse or continuous heating to at least one first section of the structure removing deposits on the inner wall of the first section of the structure; applying a second heat pulse to both the first section of the structure and at least one second section of the structure, the first and second sections being spaced apart, which heat pulse does not loosen any deposit of material in the second section; measuring the temperature of the wall of the structure or the fluid during the second heat pulse at both the first and second sections; and determining the thickness of any deposit of material on the inner wall of the structure at the second section based on the measured temperatures. The present invention also relates to a corresponding device and arrangement.

Abstract: Fiber optic sensing systems and methods. In a described embodiment, a fiber optic sensing system includes an optical fiber transmitting energy to a chemical vapor deposited diamond material proximate a substance in a well. The diamond material is deposited as a coating on a substrate. The substrate and coating are heated when the energy is transmitted by the optical fiber. This heats the substance in the well, which is detected to determine a property of the substance. In another embodiment, light energy is transmitted through the diamond material.

Abstract: Quartz resonator pressure transducers for use in subterranean boreholes include a quartz pressure sensor and an electronic temperature sensor. Temperature sensors include a constant current generator, a proportional to absolute temperature (PTAT) current generator, and a relaxation oscillator. Pressure transducers may include such a temperature sensor. Methods of monitoring pressure in a subterranean borehole may include monitoring a frequency output of a quartz pressure sensor and monitoring a frequency output of an electronic temperature sensor.

Abstract: A system and method of monitoring a pressure, temperature, and/or vibration of a hostile environment without requiring the use of active electronics or an oscillator circuit in that environment. The system and method interrogate a resonant pressure sensor and a resonant or passive temperature sensor connected to a transmission line and located at least 100 feet (30.48 m) away from a network analyzer. The system and method use the reflected frequencies from the sensors to determine the pressure, temperature, and/or vibration. If the sensors are networked by the transmission line or a network filter, the reflected portion can include the reflected transmission energy. The applied signal and reflected portion travel along the transmission line, which is preferably impedance matched to that of the system. If a multi-conductor cable is used, the effects of the cable's length and temperature are compensated for via a system calibration when in field use.

Abstract: A system for assessing one or more temperatures in an opening in a subsurface formation includes an electrical conductor and electrical insulation at least partially surrounding the electrical conductor. The electrical insulation includes magnesium oxide and a ferroelectric material. An electrically conductive sheath at least partially surrounds the electrical insulation. A profile of one or more dielectric properties of the electrical insulation along a length of the electrical insulation is assessed during use to assess a temperature profile with spatial resolution along the length of the electrical insulation.

Abstract: Watercraft automation and aquatic data are utilized for aquatic efforts. In one aspect, an anchor point is obtained and a watercraft position maintenance routine is actuated to control the watercraft to maintain association with the anchor point. In another aspect, prior aquatic effort data is obtained in association with an anchor point. In yet another aspect, current aquatic effort data is generated in association with an anchor point. In still another aspect, current aquatic effort data and prior aquatic effort data are utilized for prediction generation. In yet another aspect, current aquatic effort data and prior aquatic effort data are utilized to obtain another anchor point for a watercraft.

Abstract: The disclosure provides a system, tools and methods for estimating a property or characteristic of a fluid downhole. In one aspect, the method may include: heating the fluid at a selected or first location during a first time phase, taking temperature measurements of the fluid substantially at the selected location during a second time phase, and estimating the property of the downhole fluid using temperature measurements. Temperature measurements may also be taken at a location spaced apart from the first location and used to estimate the property of the fluid. The tool may include a device that heats the fluid during a first time phase and takes temperature measurements of the fluid during a second time phase. A processor uses the temperature measurements and a model to estimate a property of interest of the fluid.

Abstract: An apparatus for measuring environmental parameters includes: an optical fiber sensor configured to be disposed along a path in an environment to be measured, the path of the optical fiber sensor defining a longitudinal axis; and at least one section of the optical fiber sensor configured so that an entire length of the at least one section is exposed to an at least substantially homogeneous environmental parameter, at least part of the at least one section extending in a direction having a radial component relative to the longitudinal axis.

Abstract: A geohydrology monitoring system is disclosed. In one example, the system includes a heating mechanism assembly including an array of heating elements disposed longitudinally within a fluid-containing environment so that portions of the heating mechanism assembly are at different positions lengthwise within the fluid-containing environment. The heating mechanism assembly is configured to impart energy to the fluid-containing environment such that heating provided at some locations varies from heating provided at other locations. The system includes a fiber optic distributed temperature sensor (DTS) disposed in proximity to the heating mechanism assembly and configured to sense temperature at a plurality of positions and at multiple times along the length of the fluid-containing environment. Based on output from the DTS, processing logic generates an output that indicates properties of, and movement of fluid within, the fluid-containing environment.

Abstract: A method and apparatus for monitoring waterbed environment are described. The method may comprise determining a first temperature at a location within the water column of a surface body of water that is representative of the upper thermal boundary condition between surface water and pore water environments, and determining at least a second temperature at the location at a first depth below a waterbed surface. The first and second temperatures are then used to monitor a waterbed environment. Certain embodiments are particularly useful for monitoring spatiotemporal variations of riverbed surface elevations, such as scour and deposition, over a time period. Probe/sensor assemblies are disclosed for practicing the method.

Abstract: A line is deployed along a landing string or along a marine riser of a subsea well. The line has sensors, such as temperature sensors, distributed along its length. In one embodiment, the line comprises a fiber optic line that includes fiber optic temperature sensors distributed along its length. In another embodiment, the line comprises a fiber optic line used to transmit light, wherein the returned back-scatter light is analyzed to provide a temperature profile along the length of the fiber line. The fiber optic line can be deployed by connecting it to the landing string, pumping it down a pre-existing conduit (such as a hydraulic or chemical injection conduit), or pumping it down a dedicated fiber optic specific conduit.

Abstract: A system for monitoring a borehole in an earth formation includes: a borehole string configured to direct a fluid into the earth formation; at least one optical fiber sensor disposed on the borehole string at a fixed location relative to the borehole string, the optical fiber sensor including a plurality of measurement units configured to generate measurements of at least one of strain and deformation of the borehole string; at least one temperature sensor configured to measure a temperature at a plurality of locations along the length of the optical fiber sensor; and a processor configured to receive the measurements from the at least one optical fiber sensor, receive temperature measurements from the at least one temperature sensor, and identify a fluid leak in at least one of the borehole string and the formation based on a correlation of the optical fiber sensor measurements and the temperature measurements.

Abstract: A method for estimating a temperature within sub-surface materials traversed by a wellbore includes: obtaining temperature data from a plurality of measurements of temperature taken within the wellbore; calculating an overall heat transfer coefficient from the measurement data; calculating a geothermal gradient from the overall heat transfer coefficient; and using the geothermal gradient to estimate the temperature within the sub-surface materials. A system and a computer program product are provided.

Abstract: Apparatus and method for monitoring at least one parameter associated with an elongate structure are disclosed. The apparatus may include at least one elongate support body element arranged along a longitudinal structure axis associated with an elongate target structure; and at least one optic fibre element arranged substantially helically along a longitudinal body element axis associated with the at least one support body element. A method of manufacturing flexible pipe body is also disclosed.

Abstract: A system for assessing one or more temperatures along an insulated conductor in an opening in a subsurface formation includes an insulated conductor with a length comprising at least two sections of insulation with different capacitances. The sections with the different capacitances include different takeoff temperatures for at least one dielectric property of the insulation.

Abstract: A monitoring tool is provided for monitoring wells for flow anomalies. The temperatures of flowing well fluid and ambient temperature are monitored and various methods applied to indicate if a well is normal flowing, at risk of flow stoppage or cessation of flow. Approaches are described for determining trending indicators from actual flow temperatures compared to a normal flow relationship for establishing the presence of flow anomalies. Temperature sensors, onsite processors and communications upload data for display of well status flags on a mapping module enabling pro-active detection and preventative action by operators.

Abstract: Methods for assessing a temperature in an opening in a subsurface formation are described herein. A method may include assessing one or more dielectric properties along a length of an insulated conductor located in the opening and assessing one or more temperatures along the length of the insulated conductor based on the one or more assessed dielectric properties.

Abstract: Methods and systems for compensating temperature measurements by a temperature gauge comprising a first temperature sensor and a second reference temperature sensor, having different thermal properties, located in the same temperature environment to be measured. The methods and systems compensate for errors in the measured temperatures due to variations in the reference sensor caused by temperature effects.

Abstract: An apparatus includes a tool configured to operate within a borehole during a period wherein matter is being output from a surrounding earth formation into a flow of matter in the borehole. The tool includes a main tool body having a longitudinal axis. A temperature probe array is coupled to the main tool body, including a first temperature probe and a second temperature probe. The first temperature probe is radially spaced from and is at a different circumferential position relative to the second temperature probe during operation. The first temperature probe and the second temperature probe are configured to measure a first temperature and a second temperature, respectively, during operation, wherein at least one of a type of matter in the flow and an entry point of the matter from the surrounding earth formation is derived using the first temperature and the second temperature.

Abstract: An electronic apparatus (12) of a downhole tool (9, 11) comprises a first electronic device (13) operating up to a first maximum operating temperature, a second electronic device (14) operating up to a second maximum operating temperature, a switch (15) coupling the first electronic device (13) to the second electronic device (14), the second electronic device (14) providing electrical power to the first electronic device (13). The second maximum operating temperature is higher than the first maximum operating temperature. The switch (15) is a thermally controlled switch such that the switch is only closed when a measured temperature of the first electronic device is lower than the first maximum operating temperature.

Abstract: A method of determining a subsurface temperature in a body of water is disclosed. The method includes obtaining surface temperature anomaly data and surface height anomaly data of the body of water for a region of interest, and also obtaining subsurface temperature anomaly data for the region of interest at a plurality of depths. The method further includes regressing the obtained surface temperature anomaly data and surface height anomaly data for the region of interest with the obtained subsurface temperature anomaly data for the plurality of depths to generate regression coefficients, estimating a subsurface temperature at one or more other depths for the region of interest based on the generated regression coefficients and outputting the estimated subsurface temperature at the one or more other depths. Using the estimated subsurface temperature, signal propagation times and trajectories of marine life in the body of water are determined.

Abstract: A new method for measuring the temperature gradient of a well is claimed. This method uses multiple and parallel temperature sensors to calculate the well's temperature at each point in the well. This reduces noise found in electronic measurements in order to improve the well's temperature measurement and improve the calculation of the well's temperature gradient. The use of natural background gamma enhances the calculation of the well's temperature gradient and improves the detection of changing rock formations intersecting the well.

Abstract: A technique that is usable with a well includes changing the temperature of a local environment of a distributed temperature sensor, which is deployed in a region of the well and using the sensor to acquire measurements of a temperature versus depth profile. The region contains at least two different well fluid layers, and the technique includes determining the depth of a boundary of at least one of the well fluid layers based at least in part on a response of the temperature versus depth profile to the changing of the temperature.

Abstract: A method and system for detecting the location of an air/sea interface on an Instrumented Tow Cable (ITC) when distributed temperature measurements are provided. The air/sea interface is determined by estimating the variance of observed temperature in the proximity of each measurement cell. The method and system described herein uses a sliding variance across the entire cable length. The variance of the cell or cells in the area of the interface has been found to be large compared to other cells. Accordingly, the location of the air/sea interface is determined based on the location of the peak variance. The location of the air/sea interface is used in determining the catenary of the ITC.

Abstract: Geothermal energy probes, in particular at least a first group of two to five geothermal energy probes, are installed in the ground from a starting point in the radial direction such that the corresponding spreading angle between adjacent geothermal energy probes is at least 72° and the corresponding differential inclination angle is at least 10°, wherein the differential inclination angle continuously increases or decreases from one geothermal probe of the first group to the next.

Abstract: Methods for assessing a temperature in an opening in a subsurface formation are described herein. A method may include assessing one or more dielectric properties along a length of an insulated conductor located in the opening and assessing one or more temperatures along the length of the insulated conductor based on the one or more assessed dielectric properties.

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: The invention provides an apparatus for use in high temperature conditions, constituted of a downhole element and a master element connected together via a sealed connection; wherein the downhole element comprises a temperature sensor and a pressure sensor without any electronics and is embedded in a sealed housing resistant to high temperature; wherein the master element comprises electronics needed for function of the temperature sensor and the pressure sensor; and wherein the sealed connection is resistant to high temperature.

Abstract: Methods and systems of the invention are directed to a temperature sensor that includes a substrate, a first conductive plate, and a second conductive plate. The substrate is formed of a material having a low coefficient of thermal expansion (CTE). The first conductive plate is formed of a material having a CTE that is higher than the CTE of the substrate, and is attached to a first surface of the substrate. The second conductive plate is rotatably connected to the substrate through a hinge, and includes a portion that is adjacent to the first conductive plate.

Abstract: A technique that is usable with a well includes changing the temperature of a local environment of a distributed temperature sensor, which is deployed in a region of the well and using the sensor to acquire measurements of a temperature versus depth profile. The region contains at least two different well fluid layers, and the technique includes determining the depth of a boundary of at least one of the well fluid layers based at least in part on a response of the temperature versus depth profile to the changing of the temperature.

Abstract: A technique that is usable with a well includes changing the temperature of a local environment of a distributed temperature sensor, which is deployed in a region of the well and using the sensor to acquire measurements of a temperature versus depth profile. The region contains at least two different well fluid layers, and the technique includes determining the depth of a boundary of at least one of the well fluid layers based at least in part on a response of the temperature versus depth profile to the changing of the temperature.

Abstract: One aspect of the invention relates to a method (10) for characterizing a well (700) using distributed temperature sensor (DTS) data to optimise a well model (12). The method comprises providing a well model of flow and thermal properties (12a, 12b) of the well (700), where the well model (12) has a plurality of adjustable physical parameters, providing a data set made up of a plurality of DTS temperature profiles of the well (700) taken at different times during operation of the well (700), and running the well model (12) with different combinations of the plurality of adjustable physical parameters to match to the plurality of DTS temperature profiles. The DTS temperature profiles may also be pre-processed to make them consistent with one another.