Abstract: A well site remote monitoring system comprises a monitoring station, a number of recording devices, a number of sensors, a processor, and a power source. The monitoring station supports the recording devices, processor, and power source thereon and is positioned at a strategic location at a well site so that the recording devices can create video, audio, or other recordings of points of interest of the well site. The processor controls the recording devices and uploads the recordings to a remote server computer for storage and so that an operator can manage and view the recordings on a remote monitoring computer.

Abstract: A well site remote monitoring system comprises a monitoring station, a number of recording devices, a number of sensors, a processor, and a power source. The monitoring station supports the recording devices, processor, and power source thereon and is positioned at a strategic location at a well site so that the recording devices can create video, audio, or other recordings of points of interest of the well site. Operation data relating to operational aspects of the points of interest may be overlaid on the recordings. The processor controls the recording devices and uploads the recordings to a remote server computer for storage and so that an operator can manage and view the recordings on a remote monitoring computer.

Abstract: Systems and methods which utilize functional objects in connectivity analysis are shown. Functional objects may be denoted by a geological feature, a user-defined location, a critical point in a connection network, a region within a 3D volume, etc. Each functional object preferably possesses and/or has associated therewith an ability to obtain information such as relevant connection pathways, linked regions of interest, statistical connection information, etc. Such functional objects may have dynamic regions associated therewith, such as to define an area of uncertainty, for facilitating exploring connectivity. Desired connectivity information can be revealed interactively from within a confusing web of connection pathways through use of the functional objects. Through interactive manipulation of functional objects analysis may be refined or revised. Additionally or alternatively, logical operations may be applied with respect to one or more functional objects to extend or reduce the connectivity of interest.

Abstract: Methods, systems, and devices for downhole evaluation using a sensor assembly that includes a sensor plate, wherein a surface of the sensor plate forms a portion of an exterior surface of a downhole tool. Methods may include submerging the surface of the sensor plate in a downhole fluid in a borehole; activating the sensor assembly to generate a guided wave that propagates along the sensor plate, wherein propagation of the guided wave along the sensor plate is dependent upon a parameter of interest of the downhole fluid; and using information from the sensor assembly relating to the propagation of the guided wave along the sensor plate to estimate the parameter of interest. Methods may include isolating an opposing surface of the sensor plate from the downhole fluid. The guided wave may be an interface guided wave or may propagate in the plate between the surface and an opposing surface.

Abstract: Seismic data processing methods and computing systems are presented. In one embodiment, a method is disclosed that includes simulating a set of simulated seismic data from a set of acquired seismic data; separating the simulated seismic data into a plurality of data sets, wherein one set of data is matched in the acquired seismic data and one set of data is unmatched in the acquired seismic data; conforming the simulated seismic data and the acquired seismic data to one another using separated, simulated seismic data unmatched by a counterpart in the acquired seismic data from the acquired seismic data; and performing an inversion between the acquired seismic data and the separated, simulated seismic data after they are conformed to one another.

Abstract: A method of processing borehole log data to create one or more image logs involve modeling the log data as components of an image in the form i(x, y)=l(x, y)×r(x, y) (1), in which i(x, y) is an image representative of the log data, l(x, y) denotes an illumination value of the image at two-dimensional spatial co-ordinates x, y, and r(x, y) denotes a surface reflectance value at the co-ordinates x, y. Equation (1) is transformed to a logarithmic domain, and a Fourier transform is obtained of the resulting logarithmic domain expression to obtain a Fourier domain expression. The Fourier domain expression is high-pass filtered, and an inverse Fourier transform is obtained of the resulting filtered Fourier domain expression. An exponential operation is performed on the result of inverse Fourier transform to obtain a filtered image model expression. Values of the filtered image model expression are mapped to respective color values across the range of the filtered image model expression values.

Abstract: A method for generating an EMF model includes establishing a time-domain finite data model associated with an electric device representing the electric device in the time-domain; utilizing the time domain finite data model, determining excitations representing an electrical characteristic of an electrical components of the electric device; and generating an EMF model by processing the excitations with a transformation routine determining an approximate representation of an EMF generated by the electric device. A system for generating the EMF model includes a modelling module establish a time-domain finite data model associated with the electric device and d representing the electric device in the time-domain. The modelling module utilizes the time domain finite data model to determine excitations representing an electrical characteristic of an electrical component of the electric device.

Abstract: Methods for managing an intelligent field, are provided. An exemplary method can include receiving real-time dynamic field data, analyzing validity of the dynamic field data, validating values of the field data, validating a state/condition of a well, and flagging well components, well conditions, and/or well state validation issues.

Abstract: Implementations of computer-implemented methods, computer-readable media, and computer systems for interactive wellbore design management include displaying a well design including a wellbore profile representing a wellbore in a user interface. A first well component object is positioned at a first user interface position in the user interface. The first user interface position corresponds to a first well position of a first well component represented by the first well component object in the wellbore. A positioning of a second well component object at a second user interface position in the user interface is detected. The second user interface position corresponds to a second well position of a second well component represented by the second well component object in the wellbore. Using the well design, a compatibility of the second well component positioned at the second well position with the first well position of the first well component is determined.

Abstract: A system to create a surface log by using a processor connected to data storage on a network that creates and executive dashboard of surface log information using computer instructions to (a) form an editable surface log template, (b) import user information, well sensor information, well event based observation data; well fluid testing data, (c) scale the imported data, forming scaled values, (d) computing a microview and a macroview log plot using the scaled values; (e) creating an executive dashboard, (f) inserting the log plots onto the executive dashboard and other real time well logging information allowing viewing of the log plots simultaneously with the other information on a real time basis, enabling safety interpretations for drilling, geological interpretations for drilling, operational interpretations for drilling, and combinations of these interpretations, in real time.

Abstract: Techniques for an image-based analysis of a geological thin section include (i) acquiring a plurality of images from a geological thin section of a rock sample from a subterranean zone; (ii) manipulating the plurality of images to derive a composite image; (iii) optimizing the composite image to derive a seed image; (iv) identifying, in the seed image, a particular seed pixel of a plurality of contiguous pixels that comprise an image of a grain of a plurality of grains of the rock sample in the seed image; (v) determining, with a specified algorithm, a shape of the grain based on the seed pixel; (vi) determining, based on the shape of the grain, a size of the grain; and (vii) preparing the determination of the size of the grain for presentation to a user.

Abstract: A method for determining existence of a fracture in a formation surrounding a wellbore drilled through subsurface rock formations includes calculating vertical resistivity, horizontal resistivity, apparent formation dip, apparent formation azimuth and axial resistivity for a plurality of longitudinal instrument spacings using measurements from a triaxial induction well logging instrument disposed in the formation. A spread in the axial resistivity values is determined and the axial resistivity spread threshold therefrom. Fracture indicator values and fracture orientation values are calculated from transverse components of the triaxial induction measurements. Presence of a fracture is indicated when at least one of the fracture indicator value exceeds a selected threshold, the axial resistivity spread exceeds the spread threshold and when the apparent formation dip exceeds a selected threshold.

Abstract: A three-coil bucking system is used for determination of a formation resistivity property ahead of the drill bit. The conductive drill pipe is provided with non-conductive inserts in the proximity of at least one transmitter and at least two receivers. Transient electromagnetic signals are processed to give the estimate of the resistivity property and for geosteering.

Abstract: Methods of and apparatus to perform a drawdown of a formation fluid in a downhole environment are disclosed. An example method includes contacting a borehole wall with a fluid communication device of a formation testing tool and performing a first type of drawdown to draw fluid into the fluid communication device. The method also includes detecting a breach of a mudcake on the borehole wall during performance of the first type of drawdown and performing a second type of drawdown to draw fluid into the sample probe in response to detecting the breach of the mudcake. The second type of drawdown is different than the first type of drawdown. Furthermore, the example method includes confirming the breach of the mudcake on the borehole wall during performance of the second type of drawdown.

Abstract: A system for monitoring rotational time of a rotational equipment. At least some of the illustrative embodiments are systems comprising a rotatable equipment, a sensor, and an electronic system. The sensor is coupled to the rotatable equipment, and is configured to sense rotation of the rotatable equipment. The electronic system is electrically couple to the sensor. The electronic system is self-contained, and is configured to power the sensor to determine rotational time of the rotatable equipment.

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: An apparatus, method and computer-readable medium for estimating a bulk shale volume of an earth formation. In one aspect, measurements are obtained at a plurality of depths in a wellbore penetrating the earth formation and a first distribution is produced of the obtained measurements. A measurement is obtained at a selected depth in the wellbore and a second distribution is produced using the measurement at the selected depth and the measurements obtained at the plurality of depths. A cumulative distribution is produced cumulative of the first distribution and the second distribution. The bulk shale volume is estimated at the selected depth by comparing the cumulative distribution and the second distribution.

Abstract: Graphical User Interface (GUI) facilitated centralization methods and system, including a method that includes displaying a graphical representation of a tubular string within a borehole, accepting an interactive graphical selection of a starting location for a range along the borehole, and accepting an interactive graphical selection of an ending location for the range along the borehole. The method further includes determining string stand-off device positions that provide centralization within the range, and providing said positions to field personnel assembling and placing the tubular string in the borehole.

Abstract: A system for detecting when a plunger reaches a bottom of a well includes a pressure sensor configured to measure a pressure of the well and provide a measured pressure output. Derivative calculation circuitry calculates a derivative of the measured pressure output. Detection circuitry detects when the plunger reaches the bottom of the well based upon the calculated derivative.

Abstract: A well log is obtained that includes log data gathered along a trajectory of a wellbore. An orientation parameter defining a perspective for displaying the log data along the trajectory is also obtained. Following a path of the trajectory, an image strip is rendered from the log data based on the orientation parameter, where the image strip is a pictorial representation of the log data. The image strip is displayed along the trajectory.

Abstract: The present invention relates to a method and system for integrating logging tool data and digital rock physics to estimate rock formation properties. A rock sample from a logging tool such as a sidewall plug or large enough cutting can be extracted by the logging tool at approximately the same well bore location that the logging tool measures fluid properties. The rock samples thus obtained is scanned using a CT scanner, scanning electron microscope or other suitable scanning device. The resulting scanned rock image can be segmented and rock properties comprising porosity, absolute permeability, relative permeability, capillary pressure and other relevant rock properties are calculated. The resulting digital calculations are integrated with logging tool data and rock property estimates to improve the accuracy and timeliness of the logging tool data.

Abstract: An arrangement and an associated method are described in which a boring tool is moved through the ground within a given region along a path in which region a cable is buried. The boring tool and the cable transmit a boring tool locating signal and a cable locating signal, respectively. Intensities of the boring tool locating signal and the cable locating signal are measured along with a pitch orientation of the boring tool. Using the measured intensities and established pitch orientation, a positional relationship is determined to relative scale including at least the boring tool and the cable in the region. The positional relationship is displayed to scale in one view. The positional relationship may be determined and displayed including the forward locate point in scaled relation to the boring tool and the cable. Cable depth determination techniques are described including a two-point ground depth determination method.

Abstract: A method performed with a computing system for determining well integrity includes receiving a selection of a well configuration of a well, and receiving a selection of a wellbore operation performed with the well configuration. The selected well configuration includes one or more casing strings and a production tubing extending from adjacent a wellhead of the well to adjacent a bottom of the well. In some examples, the method further includes determining, based on the well configuration and the wellbore operation, a characteristic of the well at or adjacent the one or more casing strings and the production tubing during the wellbore operation, and modifying the well configuration to remove the production tubing. In some examples, the method still further includes determining, based on the modified well configuration and the wellbore operation, the characteristic of the well at or adjacent the one or more casing strings during the wellbore operation.

Abstract: A system for calculating the radius of investigation of a radial, composite reservoir has a processor with a clock, a display, and an electronic input coupled to the processor. The system divides the reservoir into a predetermined number (n) of concentric regions, and the processor is programmed to calculate periodically the radius of investigation based a starting time or elapsed time, and data relating to the reservoir rock, fluids, and geometries of each of the n regions. The processor computes the radius of investigation using at least one of Equations (1), (2), and (6) through (12) set forth in the specification, if using the System of U.S. Oilfield Units, or using an equivalent equation if using other units. These equations account for the effects of variations of both permeability and storativity in composite reservoirs on the radius of investigation with elapsed time.

Abstract: The present disclosure relates to a method to determine a formation property of a subsurface formation. A downhole logging tool having two or more tri-axial antennas is provided and used to obtain azimuthally sensitive data. Borehole correction is performed on the obtained data and a ZD-inversion is performed on the borehole corrected data for all antenna spacing groups. A formation indicator flag is determined and, depending on the determined formation indicator flag, a 1D-axial inversion and/or a 1D-radial inversion is performed over selected zones, or neither is performed. The best ZD-inversion results are selected and the 1D-axial inversion results and/or the 1D-radial inversion results, if any, are combined with the selected best ZD-inversion results to form a composite inversion result. The formation property of the subsurface formation is determined using the composite inversion result.

Abstract: A well site remote monitoring system comprises a monitoring station, a number of recording devices, a number of sensors, a processor, and a power source. The monitoring station supports the recording devices, processor, and power source thereon and is positioned at a strategic location at a well site so that the recording devices can create video, audio, or other recordings of points of interest of the well site. The processor controls the recording devices and uploads the recordings to a remote server computer for storage and so that an operator can manage and view the recordings on a remote monitoring computer.

Abstract: A directional antenna, system and method are provided. The methods include acquiring a plurality of data pairs, each data pair comprising an induced signal at a receiver and a corresponding toolface angle using a tool including at least one antenna assembly, as described herein. It further discloses a method to generate a measurement containing information about the directionality of the formation by calculating areas of an induced signal function approximated by the plurality of data pairs.

Abstract: Methods for determining a value indicative of liquid density of a formation include obtaining an inelastic count rate and a capture count rate of a gamma detector for a particular borehole depth, calculating a ratio of an inelastic count rate to a capture count rate for the particular borehole depth, determining a value indicative of liquid density based on the ratio of the inelastic count rate to the capture count rate for the particular borehole depth, repeating the obtaining, calculating and determining for a plurality of borehole depths, and producing a plot of the value indicative of liquid density of the formation as a function of borehole depth.

Abstract: Various embodiments of the invention provide for fully-integrated, low-latency power reduction in multi-sensor systems. In certain embodiments, power consumption is minimized by modulating power and mode of operation of gyroscopes, magnetometers, and accelerometers under certain conditions. Certain embodiments provide for reduction of power consumption by the use of emulated gyroscope data.

Abstract: A recoverable data acquisition system includes at least a portion of at least one sensor be positionable within a tubular of a completion system, the at least a portion being recoverable therefrom and a retainer movably disposed at the tubular between at least a first position and a second position, a cavity being defined between the tubular and the retainer when the retainer is in the first position, the at least a portion of the at least one sensor being removable from the cavity in response to movement of the retainer from the first position to the second position.

Abstract: The invention relates to techniques, such as a system for generating a density of a cased wellbore. The system includes at least one downhole tool deployable into the cased wellbore, a radiation source supportable by the downhole tool for passing radiation through the subterranean formation, at least one detector supportable by the downhole tool for measuring the radiation, and a measurement tool for generating at least one apparent density log from the measured radiation. The measurement tool has at least one quality indicator tool for generating at least one quality indicator and for generating at least one compensated density log based on the apparent density log and the quality indicator whereby error is removed therefrom.

Abstract: A subsea intervention system including at least one control station, at least one programmable logic controller system in each control station, at least one supervisory control and data acquisition system, at least one safety system capable of interacting with each control station, wherein the safety system is capable of controlling a process shutdown process, an emergency shutdown process, and an emergency quick-disconnect process. The system may also include subsea distribution units, safety manifold subsea control modules, system hydraulic power units, client hydraulic power units, grease skids, flushing and chemical injection units, or umbilical reelers.

Abstract: An electrical capacitance tomography sensor comprised of a sensor having a plurality of electrodes, where each electrode is further comprised of a plurality of capacitance segments. Each of the capacitance segments of each electrode can be individually addressed to focus the electric field intensity or sensitivity to desired regions of the electrodes and the sensor.

Abstract: A method for estimating velocity dispersion in seismic surface waves in massive 3-D data sets (401) that improves upon auto-picking of a curve along the peak or ridge of the magnitude of the beam-formed field (402). The seismic data are transformed to the frequency-slowness domain, where nonlinear constrained optimization is performed on the transformed data. The optimization matches a nonlinear mathematical parametric model (403) of a beam-formed field to that in the transformed data, adjusting the parameters each iteration to reduce mismatch (404). Dispersion curves are determined by the center of the beam in the optimized models (405). A preferred nonlinear parametric mathematical model is a Gaussian-shaped beam or a cosine-tapered boxcar beam.

Abstract: A method for calculating connected productive regions (“geobodies”) in a hydrocarbon reservoir uses an algorithm which visits a cell in a geological model of the reservoir, assigning a geobody identifier if the cell possesses certain threshold characteristics and adding the connected neighbors of each visited cell to a data queue or stack. The data queue is emptied cell by cell, each cell popped out of the queue being assigned the same geobody identifier value and having its own connected neighbors added to the queue. Cells are popped out until the queue is empty and then another cell in the model which has not yet been visited is selected. The process continues until all cells have been visited. Cells may also be pre-identified as being part of a well; in this case the algorithm will also establish well connectivity.

Abstract: A machine, computer program product, and method to enable scalable parallel reservoir simulations for a variety of simulation model sizes are described herein. Some embodiments of the disclosed invention include a machine, methods, and implemented software for performing parallel processing of a grid defining a reservoir or oil/gas field using a plurality of sub-domains for the reservoir simulation, a parallel process of re-ordering a local cell index for each of the plurality of cells using characteristics of the cell and location within the at least one sub-domain and a parallel process of simulating at least one production characteristic of the reservoir.

Abstract: A method for modeling deformation in subsurface strata, including defining physical boundaries for a geomechanical system. The method also includes acquiring one or more mechanical properties of the subsurface strata within the physical boundaries, and acquiring one or more thermal properties of the subsurface strata within the physical boundaries. The method also includes creating a computer-implemented finite element analysis program representing the geomechanical system and defining a plurality of nodes representing points in space, with each node being populated with at least one of each of the mechanical properties and the thermal properties. The program solves for in situ stress at selected nodes within the mesh.

Abstract: A system for determining the position of an underground sonde transmitter is disclosed. In some embodiments, the system measures a set of complex electromagnetic field magnitude and phase strengths at one or more positions while traversing a target sonde path at any angle using one or more electromagnetic coil sensors, models a set of expected complex electromagnetic strengths of a hypothetical sonde at the positions for one or more of the electromagnetic coil sensors, the set of expected electromagnetic field values corresponding to a model for the target sonde, and estimates parameters related to the target sonde based on the residual error between the measured set of complex electromagnetic field values and the modeled set of expected complex electromagnetic field strengths. A final estimated parameter set is determined after the residual error has converged to a minimum tolerance to indicate the sonde transmitter position.

Abstract: A method for computing or estimating relative permeability for fractional multi-phase, multi-component fluid flow through a porous medium, which employs a 3D digital representation of a porous medium and a computational fluid dynamics method to calculate flow rates, pressures, saturations, velocities and other flow parameters, is described. The method employs a unique method which integrates a precursor simulation used to generate a set of variables like pressure, saturation and velocity distribution associated with a selected storage plane in the 3D digital representation of a porous medium, which variables are used as inlet condition in the workflow of a second simulation that can generate values of fractional flow rates, pressures, saturations, velocities, or other parameters of wetting and non-wetting phases, which can be used to compute or estimate relative permeability values or other fluid transport properties of the porous medium.

Abstract: An apparatus and method for determining a formation/fluid interaction of a target formation and a target drilling fluid is described herein. The method may include training an artificial neural network using a training data set. The training data set may include a formation characteristic of a source formation and a fluid characteristic of a source drilling fluid and experimental data on source formation/fluid interaction. Once the artificial neural network is trained, a formation characteristic of the target formation and fluid characteristic of target drilling fluid may be input. The formation characteristic of the target formation may correspond to the formation characteristic of the source formation. The fluid characteristic of the target drilling fluid may correspond to the fluid characteristic of the source drilling fluid. A formation/fluid interaction of the target formation and the target drilling fluid may be determined using a value output by the artificial neural network.

Abstract: A passive method for exploring a region below the surface of the earth. The method comprises using a single sensor located in turn at a plurality of locations to obtain seismic data obtained by recording ambient seismic interface waves in a frequency range whose lower limit is greater than 0 Hz, and whose upper limit is less than or equal to substantially 1 Hz. The data are processed so as to obtain a measure of the energy in a frequency band within the frequency range. For example, the seismic data may be filtered and may be subjected to amplitude normalization before being transformed into the frequency domain. The energy measure may then be calculated by integrating the spectrum in the frequency domain over a desired frequency range. The resulting calculated energy provides information about the region of the earth being explored.

Abstract: In one embodiment, a system includes a motion detector to determine a motion event or a no motion event for an inertial system. The determination of the events is based upon comparing at least one motion parameter in the inertial system to at least one predetermined threshold. An azimuth update controller (AUC) periodically requests motion detection events from the motion detector and corrects heading information to a previous positional state in the inertial system in response to receipt of the no motion event.

Abstract: Models of underground formations. At least some of the illustrative embodiments are methods including creating a model of an underground formation. The creating may include: calculating a set of probabilities associated with a first horizontal location, each probability indicative of a likelihood of finding abutting geological layers; estimating a plurality of successions of geological layers to create a plurality of estimated successions, and the estimating using the set of probabilities; determining, for each of the estimated succession, a value indicative of how closely each estimated succession matches a measured succession, the measured succession determined by a seismic survey; and selecting from the plurality of estimated successions based on the values, the selecting creates a selected succession of geological layers, and the plurality of modeled values associated with the first horizontal location determined based on the selected succession of geological layers.

Abstract: A method is presented for modeling reservoir properties. The method includes constructing a coarse computational mesh for the reservoir. The coarse computational mesh comprises a plurality of cells. The method further includes determining a plurality of flows for each of the plurality of cells based on Dirichlet boundary conditions. Additionally, the method includes determining a solution to a coarse pressure equation for the reservoir based on the plurality of flows.

Abstract: A system and method are provided for determining borehole azimuth. The method comprises receiving a first set of data from a first sensor module, the first sensor module comprising a first plurality of accelerometers; receiving a second set of data from a second sensor module, the second sensor module comprising a second plurality of accelerometers, the second sensor module being positioned further downhole than the first sensor module; determining a first set of gravity components using the first set of data and a second set of gravity components using the second set of data; determining a bend angle and a tilt angle using the first and second sets of gravity components; determining a change in azimuth using the bend and tilt angles; and providing an output indicative of the change in azimuth. The system and method may also use a crustal gravity vector to correct the computed azimuth.

Abstract: A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth.

Abstract: A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Abstract: The present disclosure relates to a method to determine a volume of clearance surrounding a wellbore. A logging tool is provided. The logging tool may be disposed on a wireline, a drill string, or a wired drill pipe. A formation property is obtained using the logging tool. The formation property may include a voltage, a bulk resistivity, a horizontal resistivity, a vertical resistivity, a porosity, a permeability, a fluid saturation, an NMR relaxation time, a borehole size, a borehole shape, a borehole fluid composition, an MWD parameter, or an LWD parameter. The maximum depth of investigation into the subsurface formation is determined using a model response and a noise level, and the volume of clearance is determined using the determined maximum depth of investigation. The maximum depth of investigation and volume of clearance may be determined even though no boundary layers are detected.

Abstract: A method for performing contamination monitoring through estimation wherein measured data for optical density, gas to oil ratio, mass density and composition of fluid components are used to obtain plotting data and the plotting data is extrapolated to obtain contamination levels.

Abstract: In accordance with one aspect of the present technique, a method is disclosed. The method includes receiving sensor data from a first set of sensors mechanically coupled to a first riser joint of a marine riser. The method also includes analyzing the sensor data to determine a condition of the first riser joint and determining whether the condition satisfies a transmission criterion. The method further includes sending a notification including the condition to an on-vessel monitor communicatively coupled to the marine riser in response to determining that the condition satisfies the transmission criterion.