Abstract: A system and a method for time lapse monitoring of a target feature within a rock formation are provided. The system includes a data weighted electromagnetic source configured to generate an electromagnetic field in vicinity or at a surface of the rock formation; and an electromagnetic receiver configured to measure a component of the electromagnetic field generated by the source. The data weighted electromagnetic source includes a plurality of electromagnetic sources and an electromagnetic field contribution from each electromagnetic source is weighted so as to enhance the component of the electromagnetic field measured by the electromagnetic receiver.

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: 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: Mechanical properties of formation rock from a subsurface reservoir are measured with a computerized system while a core sample from the formation is being cut, during a process known as slabbing, for other analytical purposes. Forces exerted during cutting of the slab from the original core sample are sensed and stored in the computer system. The recorded force data, cutting time and dimensions of the core sample and the cut slab are processed in the computer system. Measures of characteristics and mechanical properties of the rock, such as rock strength and angle of internal friction, are obtained with the computer system. Separate and specialized testing procedures performed on test core plugs using samples specially extracted from the original core sample are not required.

Abstract: An apparatus for estimating a property of an earth formation includes: a plurality of sensors configured to estimate at least one property, each of the plurality of sensors located at a known position relative to one another; and a processor in operable communication with the plurality of sensors and configured to estimate uncertainties of the location of the plurality of sensors over a period of time. A method and computer program product for estimating a property of an earth formation is also disclosed.

Abstract: A clock oscillator includes a first crystal controlled oscillator, a second crystal controlled oscillator and a logic controller functionally coupled to the first and second crystal controlled oscillators. The logic controller is programmed to calculate a frequency of the first crystal controlled oscillator as a function of the frequency of the first crystal controlled oscillator with respect to a frequency of the second crystal controlled oscillator characterized with respect to an environmental parameter.

Abstract: A method of event location to avoid first break picking when signals are small or the ambient noise level is high is described. In this method traveltime associated with the maximum amplitude phases (for any mode of wave) are identified and picked from one or more sensors in an array. Difference between the arrival times are then calculated. A grid search (or optimization) techniques are then employed to search for the event location to match the observed time differences.

Abstract: In an electronic device and its display method, which dissolves a feeling of wrongness given to users in the case where information displayed in the foreground image and its related information is displayed in the background image, thereby making it possible to reduce a burden imposed on users; when a wallpaper display processing is carried out and a background image displayed by a background image display unit (183) is included in information and its related information displayed by an information display unit (182), such as a clock, a date, a radio condition, a remaining battery charge, and the like; an information display suppression unit (184) suppresses display of either the information display by the information display unit (182) or the information display by the background image display unit (183).

Abstract: A system and a method for associating measurements from a wellbore with times and depths is provided. Tools located in a wellbore obtain the measurements and provide time data used to determine the times. The tools and a surface clock may be synchronized. The times may be used to associate the measurements with corresponding depths of the wellbore.

Abstract: A distributed drilling simulation system includes a choke manifold, a high pressure manifold, a blowout preventer console, a choke console, a remote console, a driller console, a teacher console and a graphic projecting unit, wherein the driller console, the remote console, the blowout preventer console, the choke console, the choke manifold, and the high pressure manifold are interconnected through a PPI (processor/peripheral interface) protocol. The teacher console is connected with the PPI protocol through a PPI interface. A communication program and a main control program run on a main control computer and a graphic processing program runs on a graphic computer. The invention has the advantages of realizing high-degree top driving drilling simulation, enhancing the field sense for teaching and training, shortening the training period and reducing the training cost.

Abstract: A system, method and computer readable medium capable of improving the efficiency and accuracy of oilfield production forecasting operations is described herein. Measured oilfield production data may be utilized to generate estimates for the mean, covariance and noise. Refined estimates for the mean and the covariance may be generated using a Bayesian probabilistic updating algorithm. The refined estimates may be utilized to generate an oilfield production forecast having a refined exponential decline curve associated with the measured production data and one or more uncertainty designations.

Abstract: Multiphase flow behavior in gas condensate reservoirs is analyzed, and in particular estimating gas condensate well deliverability. Inflow performance relationship (IPR) measures for gas condensate wells are analytically generated and made available. The inflow performance relationship measures of gas condensate wells incorporate the effect of condensate banking as pressure near the well bore drops below the dew point. The inflow performance relationship measures are based on formation rock relative permeability data and Constant Composition Expansion (CCE) experiment data.

Abstract: A computer implemented system and method for parallel adaptive data partitioning on a reservoir simulation using an unstructured grid includes a method of simulating a reservoir model which includes generating the reservoir model. The generated reservoir model is partitioned into multiple sets of different domains, each one corresponding to an efficient partition for a specific portion of the model.

Abstract: The gas trap collects formation gases from oil well fluid flow in real time. Gases are released by the fluid when agitated by an agitating pipe which stirs the fluid flow; the gases are then collected and separated from the fluid to be analyzed. The gas trap does hinder the flow of formation cuttings in the drilling fluid flow line, but allows the formation cuttings to flow around the agitator pipe and out to the sample box.

Abstract: A prog analysis and execution system and method. The system includes a computer control system, an interface engine in communication with the computer control system, the interface engine being configured to receive prog information, and an action item development engine in communication with the control system, the action item development engine being configured to analyze received prog information and to determine corresponding action items. The system further includes a sensor engine in communication with the computer control system, the sensor engine being configured to receive input from at least one sensor for use in controlling a well drilling operation, and an operational equipment engine in communication with the computer control system, the operational equipment engine being configured to receive input from the computer control system and to control the well drilling operation in accordance with the determined action items in the prog.

Abstract: A method of processing data generated from an energy industry or oilfield operation includes: receiving a data set representing parameter values generated during at least a portion of the operation, the parameter values including values of a plurality of parameters relating to the operation; dividing the data set into a plurality of data subsets, each data subset including values for multiple parameters; determining a measure of similarity between data in each subset relative to data in one or more other subsets; displaying a map of the data set in at least two dimensions, the map including a visual representation of each subset positioned relative to a visual representation of the one or more other subsets based on the measure of similarity; and analyzing the map to estimate a condition associated with the operation.

Abstract: A method includes analyzing historical surface check data to train classifiers indicative of data separation between healthy and unhealthy downhole tools. The method also includes developing, based on the classifiers, prognostics health and management algorithms to predict failures in the downhole tools.

Abstract: According to one embodiment, a method for selecting drilling components is disclosed. The method may include determining properties of drilling components. The drilling components may include a bottom hole assembly (BHA) and drilling fluid. The properties of drilling components may include BHA properties and drilling fluid properties. The method may also include determining a total organic carbon content in a rock formation unit using a computer. The method may further include determining a pyrite content in the rock formation unit using the computer. The method may still further include determining whether the and the drilling fluid are incompatible for use in the rock formation, based upon the BHA properties, drilling fluid properties, the total organic carbon content, and the pyrite content.

Abstract: A method of drilling a well is disclosed. A first estimate is obtained of a location of the well with respect to a reference well at a selected depth. A magnetic measurement is obtained at the selected depth using a sensor. The obtained magnetic measurement is related to a residual magnetic charge distribution in the reference well. An expected value of the magnetic measurement at the selected depth is determined from the residual magnetic charge distribution. A second estimate is obtained of the location of the well using the first estimate of the location, the obtained magnetic measurement and the expected value of the magnetic measurement. A drilling parameter of the well is altered using the second estimate of the location.

Abstract: A sensor assembly includes an optical computing device having an integrated computational element (ICE) configured to optically interact with a fluid stream and detect a first characteristic of a substance within the fluid stream. The optical computing device is configured to generate a first signal corresponding to the first characteristic. The sensor assembly also includes a parameter sensor configured to measure a second characteristic of the fluid stream and generate a second signal corresponding to the second characteristic and a processor communicatively coupled to the optical computing device and the parameter sensor. The processor is configured to receive the first and second signals and determine a mass flow rate of the substance.

Abstract: A system and method may be configured to support the evaluation of the economic impact of uncertainties associated with the planning of a petroleum production project, e.g., uncertainties associated with decisions having multiple possible outcomes and uncertainties associated with uncontrollable parameters such as rock properties, oil prices, etc. The system and method involve receiving user input characterizing the uncertainty of planning variables and performing an iterative simulation that computes the economic return for various possible instantiations of the set of planning variables based on the uncertainty characterization. The system and method may (a) utilize and integrate highly rigorous physical reservoir, well, production flow, and economic models, and (b) provide a mechanism for specifying constraints on the planning variables. Furthermore, the system and method may provide a case manager process for managing multiple cases and associated “experimental runs” on the cases.

Abstract: Systems, computer readable medium, program code, and methods for monitoring and managing a plurality of marine riser assets are provided. An example of a system includes a computer and a computer readable medium containing a program code of instructions that when executed by the computer, cause the computer to perform operations for tracking the subsea deployment and retrieval of each of a plurality of riser joints. The operations can include receiving riser joint identification data from a riser joint identification indicator connected to the respective riser joint during the operational deployment thereof, and identifying the respective riser joint being operationally deployed to thereby track the deployment thereof. The operations can also include receiving riser joint identification data from the riser identification indicator of the respective riser joint during retrieval thereof, and identifying the respective one or more riser joints being retrieved to thereby track the retrieval thereof.

Abstract: A system and method for monitoring the permeability of a well structure defining a bore hole. The system comprises a wave generator, a sensor adapted to receive current wave data, and a processor programmed to compare the current wave data to prior wave data in order to determine the permeability of the well structure. The processor can calculate a correlation value and/or a decay value that reflects changes between the current wave data and the prior wave data, and these values can be displayed for the user. The method comprises creating a pressure wave in the bore hole, sensing current wave data, and comparing the current wave data to prior wave data in order to determine the permeability of the well structure. The step of comparing can include calculating a correlation value and/or a decay value that corresponds with the change in the data, and the values can be displayed.

Abstract: A system and method for determining uncertainty of a wellbore orientation is disclosed. The system and method obtains a measurement related to a first orientation of a drill string at a measurement device. Based on the first orientation and drilling settings, the system and method predict a second orientation. A probability of the second orientation being within a predetermined area is also obtained. As a result of this information, an action may be taken, such as, skipping a planned static survey, obtaining a static survey prior to the plan, or changing a drilling setting.

Abstract: Disclosed is a method for estimating downhole lateral vibrations a drill tubular disposed in a borehole penetrating the earth or a component coupled to the drill tubular. The method includes rotating the drill tubular to drill the first borehole and performing a plurality of measurements in a time window of one or more parameters of the drill tubular at or above a surface of the earth during the rotating using a sensor. The method further includes estimating the downhole lateral vibrations using a processor that receives the plurality of measurements.

Abstract: A cloud computing system for low maintenance sampling of gas from a well using a computing cloud, at least one gas analyzer for analyzing gas samples from a well being drilled connected to the computing cloud, a sample conditioning and filtering device in fluid and electronic communication with each gas analyzer for removing moisture from the gas samples; and a gas trap in communication with the gas analyzer and the computing cloud.

Abstract: The fill of a downhole pump of a pumpjack or other system may be estimated based on a dynamically changing a reference torque or force curve and actual torque or force measurements during at least a portion of a pump stroke. Using various techniques, the reference curve may dynamically change over time to take into account slowly changing operating conditions. Moreover, the reference curve and/or the measurements may be adjusted to ensure that the estimated and/or reported pump fill does not exceed 100 percent of pump capacity.

Abstract: One or more computer-readable media include computer-executable instructions to instruct a computing system to iteratively solve a system of equations that model a wellbore and fracture network in a reservoir where the system of equations includes equations for multiphase flow in a porous medium, equations for multiphase flow between a fracture and a wellbore, and equations for multiphase flow between a formation of a reservoir and a fracture. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A method and apparatus for determining the fluid permeability of an earth formation is described. An instrument comprising an acoustic source and acoustic and electrokinetic sensors is located in a borehole at a site of interest. The acoustic source is fired and the resulting variations in pressure and electric field generated are measured and recorded. The Biot equation, and an equation for the streaming potential coupled to fluid displacement terms, is solved using finite element analysis to give an expected pressure waveform and electrokinetic waveform based on estimated earth formation properties. By comparison of the measured waveforms and those calculated from the equations, the actual permeability of the earth formation can be deduced.

Abstract: A method to determine the earth's magnetic field vector along a sub-surface wellpath having unknown and possibly changing azimuth, in the presence of a magnetic disturbance caused by a magnetic source external to the wellpath includes estimating the three components of the earth field along the three axes of a magnetic sensor package by a polynomial function of measured depth along the wellpath. Upon removal of the earth's magnetic field from the measurements, the resultant magnetic field of the disturbance is determined and can be used to determine the position and orientation of the source of the disturbance.

Abstract: A multiple sensor fiber optic sensing system. A method of sensing distributed temperature and at least another property in a well includes the steps of: interconnecting an optical switch to an optical fiber which extends along a wellbore in the well; operating the optical switch to optically connect the optical fiber to an interferometric measurement system; and operating the optical switch to optically connect the optical fiber to a distributed temperature measurement system. Another method includes the steps of: installing an optical fiber along a wellbore in the well, the optical fiber being a first distributed temperature sensor, the installing step including providing a substantial length of the optical fiber proximate a second sensor which senses the well property; and calibrating the second sensor using a temperature sensed by the first sensor in the substantial length of the optical fiber.

Abstract: An apparatus and method for measuring depth, velocity, or both depth and velocity of instrumentation along a wellbore is provided. The apparatus includes a downhole portion movable within the wellbore in a direction generally parallel to the wellbore. The apparatus further includes a first acceleration sensor that generates a first signal indicative of a first acceleration. The apparatus further includes a second acceleration sensor that generates a second signal indicative of a second acceleration. The apparatus further includes a bend sensor generating a third signal indicative of an amount of bend of at least a portion of the downhole portion.

Abstract: A method and system for autonomously enhancing the performance of rig operations at a rig-site, including subterranean operations at a rig-site. The system may include an integrated control system, wherein the integrated control system monitors one or more parameters of sensor units of the rig operations, and a central computer that can communicate with sensor units reporting the health and operational status of the rig operations. The system may further be upgraded by a package of sensors attached to the various tools that allow the central computer an overall synchronized view of the rig operations.

Abstract: Systems and methods for monitoring, diagnosing and optimizing operation of a gas lift (GL) system, at least some of which include a method that includes collecting measured data representative of the GL system's state, storing the measured data, comparing the measured data to a well model's calculated data for the well and identifying likely conditions of the GL system based on mismatches between the measured data and the calculated data. The method further includes updating the model to reflect the likely conditions and selected corrections of the likely conditions, generating GL system performance curves using the updated model and presenting to a user actions recommended to achieve a GL system performance consistent with a GL system operating point on at least one of the GL system performance curves.

Abstract: A simple, applicable in the field, and extra-equipment free method is provided for determining steam dryness directly in a thermal recovery of high-viscosity oil. A non-condensable gas is added into a saturated steam being injected into a well. The presence of non-condensable gas changes partial steam pressure. Correspondingly the steam condensation temperature also changes. The borehole temperature or pressure measurements can be used to evaluate the steam dryness.

Abstract: Disclosed herein are multicomponent borehole radar tools and methods. At least some tool embodiments employ at least two antennas that receive reflections of electromagnetic pulses transmitted from the tool. A processor processes the receive signals to identify reflection signals and to determine a direction and/or distance to the sources of the reflection signals. Possible sources include formation boundaries, fluid boundaries, cased wells, and other features that cause contrasts in electromagnetic properties. In addition to reflection signals, the measured responses may include direct signal measurements that are useful for determining formation resistivity and permittivity. Each of the antennas may transmit and receive, and they may be collocated to reduce tool size and reduce processing complexity. Disclosed logging tool examples employ both electric and magnetic dipole antennas.

Abstract: A method and apparatus for removing drift from a curve of raw data acquired from a wellbore that intersects a subterranean formation. The raw data curve is filtered to remove DC components, integrating the filtered curve generates a new baseline curve. Adding the new base line curve to the filtered curve yields a corrected curve that is used to extract drift from the raw data curve. The corrected curve is filtered and then subtracted from the raw data curve to produce a drift curve. A data curve, absent any drift, is generated by filtering the drift curve, and subtracting the filtered data curve from the raw data curve.

Abstract: Systems and methods for determining the bending moment and shear force of tubing and casing when the tubing buckles and contacts the casing.

Abstract: A method for monitoring fluid flow through a downhole device, comprises a) providing an acoustic tube wave in fluid in the device; b) measuring the acoustic tube wave after it has passed through the fluid in the device; and c) assessing the permeability of the device by measuring the attenuation of the acoustic signal. Changes in velocity of the acoustic signal may also be measured. The device may be a permeable downhole device such as a sand screen the measurements in step b) are made using a plurality of sensors deployed in the hole. The method may further including the step of cross-correlating a signal received at a first receiver with signals received at additional sensors so as to obtain an effective response as if the signal had been emitted from a source at the position of said first receiver.

Abstract: A microseismic monitoring system includes a seismic sensor positioned proximate to a wellbore traversing a formation; an orientation source producing an orientation shot; a hydraulic apparatus operationally connected with the formation to produce a fracture in the formation; a computer control system operationally connected with a database of known spectral attributes for event categories; and a computer readable medium that carries instructions executable by the computer control system that, when executed: receive data from the seismic sensor; select an event of interest from the data received; determine a spectral estimate of the selected event of interest; compare the determined spectral estimate of the selected event of interest to the known spectral estimates; and select from the data received by the seismic source the orientation shot for orientation of the seismic sensor.

Abstract: The present disclosure relates to determining a property, such as resistivity, of an earth formation. A transmitter is disposed in a wellbore penetrating the formation, and a plurality of receivers are distributed on or near the earth's surface. The transmitter sends electromagnetic energy into the formation and the resulting signal, after passing through the formation, is detected by the array of receivers. The received signal is used to determine the property of the formation. This is often achieved using an inversion or numerical model of the formation being measured. The inversion takes into account changes in the background formation model due to transmitting from various locations. The measurements made on the formation can be performed while drilling the wellbore or subsequent to the drilling.

Abstract: Embodiments of the present invention provide techniques for using data from a select set of wells to develop correlations between surface-measured properties and properties typically determined from subsurface measurements (e.g., from logging tool responses, core analysis, or other subsurface measurements). When new wells are drilled, the surface data acquired while drilling may be used as an input to these correlations in order to predict properties associated with subsurface measurements.

Abstract: A method of transmitting borehole image data from a borehole location to a remote location includes obtaining a set of image data describing formation surrounding a borehole using a logging tool at a selected depth or range of depths in the borehole, extracting one or more image features from the set of image data downhole, and transmitting a representation of the extracted image features to the surface.

Abstract: An apparatus for making a resistivity measurement of an underground formation surrounding a borehole is provided. The apparatus includes a conductive tool body, at least one current injector electrode positioned between the tool body and a wall of the bore hole, at least one current return electrode positioned between the tool body and the wall of the bore hole, an electrical measurement device configured to monitor a voltage or a current signal indicative of an impedance imbalance, a regulator connected to the electrical measurement device, whereby the regulator is configured to receive the voltage or the current signal indicative of the impedance imbalance and is configured to generate an adjustment signal based on the voltage or the current signal indicative of the impedance imbalance.

Abstract: Mechanical properties of formation rock from a subsurface reservoir are measured with a computerized system while a core sample from the formation is being cut, during a process known as slabbing, for other analytical purposes. Forces exerted during cutting of the slab from the original core sample are sensed and stored in the computer system. The recorded force data, cutting time and dimensions of the core sample and the cut slab are processed in the computer system. Measures of characteristics and mechanical properties of the rock, such as rock strength and angle of internal friction, are obtained with the computer system. Separate and specialized testing procedures performed on test core plugs using samples specially extracted from the original core sample are not required.

Abstract: A method of calibrating a measurement device includes: compiling historical calibration data for the measurement device, the historical calibration data including values corresponding to outputs of the measurement device over a first operating duration in environmental conditions associated with an operating environment; projecting the historical calibration data over a subsequent operating duration to generate predictive calibration data; disposing the measurement device in the operating environment and generating measurement signals during the first operating duration and the subsequent operating duration; and generating measurement values from measurement signals generated during the subsequent operating duration based on the predictive calibration data.

Abstract: A method for collecting and analyzing downhole pressure data includes disposing a plurality of pressure sensors at axially spaced locations along a drill string disposed in a well. A first data set that includes a data point for each of the pressure sensors is collected. Each data point includes a pressure value and a depth value. A value of modified equivalent circulating density (ECDm) is calculated for at least one data point. ECDm includes a static pressure component and a dynamic pressure component. Calculating the ECDm includes computing the static pressure component based on the true vertical depth of the pressure sensor, and computing the dynamic pressure component based on a second depth value that differs from the true vertical depth and is common to all the pressure sensors for which ECDm is calculated.

Abstract: A computer system and computer implemented method for automatically identifying a hydrocarbon (such as kerogen, gas, oil) rich zone in a well bore includes obtaining well log data comprising neutron data, density data, radioactivity data, and resistivity data representative of physical characteristics of a formation surrounding the well bore and computing an apparent neutron porosity and an apparent density porosity based on the neutron data and density data. A normalized neutron-density separation is computed based on the computed apparent neutron porosity and the computed apparent density porosity and a baseline of the formation is determined for each data type. Using the computed normalized neutron-density separation, the radioactivity data, the resistivity data, and the determined baselines, the presence or absence of a hydrocarbon rich zone is determined. A quality index may further be derived from the data.

Abstract: Based on measurements that are obtained from a well test, a pressure in the well is modeled as a function of at least a skin effect factor that varies with time. The results of the modeling may be used to estimate at least one well parameter, such as a formation parameter and/or a well pressure, as examples.

Abstract: A method can include proposing a new well; accessing data associated with at least one other well where at least a portion of the data includes indicia of uncertainty; performing a geostatistical analysis of the accessed data for an issue for drilling of the new well to provide a probability of occurrence for the issue and an uncertainty for the accessed data; and rendering to a display a graphical representation of the well, the probability of occurrence for the issue and the uncertainty for the accessed data as a function of depth. Various other apparatuses, systems, methods, etc., are also disclosed.