Abstract: To generate an absorption parameter model, estimated values of an effective absorption parameter are received, where the estimated effective absorption parameter values represent absorption encountered by a seismic wave in a subterranean structure. Based on the estimated effective absorption parameter values, an absorption parameter model is generated that varies absorption parameter values along at least one dimension of the subterranean structure.

Abstract: A method for correcting errors in LWD depths includes performing torque and drag model analysis using drillstring weight, downhole friction, weight on bit, thermal expansion, rig heave and tide to produce a corrected time-depth file, wherein the torque and drag model is automatically calibrated using effective block weight, drillpipe wear, and sliding friction; and correcting time-based LWD data using the corrected time-depth file to produce depth-corrected LWD data. A system for correcting errors in LWD depths includes a processor and a memory that stores a program having instructions for: performing torque and drag model analysis using drillstring weight, downhole friction, weight on bit, thermal expansion, rig heave and tide to produce a corrected time-depth file, wherein the torque and drag model is automatically calibrated using effective block weight, drillpipe wear, and sliding friction; and correcting time-based LWD data using the corrected time-depth file to produce depth-corrected LWD data.

Abstract: A method for allocating actual production loss of a wellsite. The method includes defining a data collection procedure and capturing production data according to the data collection procedure, the production data including actual production data and a maximum production potential of the wellsite. The method further includes selectively allocating a portion of the actual production data to the wellsite based on allocation rules to obtain derived production data, comparing the derived production data to the maximum production potential to determine the actual production loss for the wellsite, allocating the actual production loss to at least one of the production events, and determining a cause of the actual production loss based on an engineering analysis of the production events.

Abstract: A while-drilling Vertical Seismic Profiling (VSP) data acquisition system utilizing the same seismic shots for three purposes is disclosed. First, the seismic shots provide a means for synchronizing a downhole clock in the VSP receiver to a master clock at the surface, thereby enabling correct determination of seismic travel times. Second, the same seismic shots are also used to communicate commands and other information to the downhole VSP receiver, such commands controlling the actions of the VSP receiver or associated devices. Third, the same seismic shots are utilized for purposes of the VSP survey itself, i.e. determination of seismic travel times, forming of seismic images, and determination of geologic and formation fluid properties using the VSP methods.

Abstract: An apparatus and method for estimating a property of a species of the hydrocarbon in a downhole fluid are provided. In one aspect, the method may include: imparting a magnetic field on the fluid to align nuclei of the fluid with a direction of the primary magnetic field; imparting a perturbing radio frequency signal on the fluid to excite the nuclei of the fluid; detecting a radio frequency signal emitted by the excited nuclei of the fluid; estimating a frequency shift between the perturbing radio frequency and the detected radio frequency; and estimating using the frequency shift a property of one or more species of the hydrocarbons in the fluid.

Abstract: A method and apparatus are disclosed for synthesizing desired antenna responses from a combination of measured antenna responses, as well as antenna arrays particularly suited to provide the measurements. Those arrays may include cross dipole and double cross dipole antennas.

Abstract: A method of drilling a well. The method includes calculating an estimated formation dip angle, wherein said estimated formation dip angle being based on offset well data, seismic data, core data, pressure data. Next, the method includes drilling a well with a logging while drilling means so that real time logging data is generated along with drilling data and calculating an instantaneous formation dip angle. Next, real time logging data is obtained and a target formation window is projected ahead of the well path that includes a top of formation and a bottom formation. The method includes monitoring the real time logging and drilling data and drilling the well through the target formation window. The method further includes changing the estimated instantaneous formation dip based on the obtained data and adjusting the target formation top and bottom window.

Abstract: A method and apparatus for geobaric analysis. The method may include acquiring an in situ gas volume of a subterranean formation, acquiring a drilling fluid characteristic, determining a volume of gas excavated from the subterranean formation utilizing the drilling fluid characteristic, and estimating the formation pressure utilizing the in situ gas volume and the excavated gas volume.

Abstract: An instrument for measuring gravitational acceleration, the instrument including: a plurality of accelerometers disposed about a three-dimensional structure, the plurality of accelerometers providing output used for measuring the gravitational acceleration; wherein each accelerometer in the plurality is implemented by at least one of a micro-electromechanical system (MEMS) and a nano-electromechanical system (NEMS).

Abstract: A method to determine a parameter of a subsurface formation such as anisotropy and dip comprises making at least two cross dipole measurements and forming an anti-symmetrized combination from the at least two cross dipole measurements.

Abstract: A method for tracking a sinusoidal electromagnetic signal in noisy data using a Kalman filter or other tracking algorithm. The method is useful for controlled source electromagnetic surveying where longer source-receiver offsets can cause the source signal to decay significantly and be difficult to retrieve from magnetotelluric or other electromagnetic background.

Abstract: Two embodiments of marine geo-electric probe methods for hydrocarbon deposits survey comprise—excitation of electromagnetic field in a surveyed medium by transmitting two rectangular current pulses therethrough, the first—during forward traveling of a probe device along a profile and the second—during backward traveling thereof, —measuring instant values of the first and second electric potential differences during the time between the pulses, wherein, the equal-zero condition of the electric potential differences along the profile is ensured, —calculating three sets of normalized electrical parameters based on difference values, —solving an inverse problem via a differential equation for the dipole source voltage in an electrochemically polarizable medium using the parameters, —producing data according to said electrical parameters, and—determining conductivity of the medium, induced-polarization factor and decay time constant of the polarization potential difference.

Abstract: A borehole conveyance system that integrates wireline type downhole instrumentation into the drill string tripping operations that are typically performed in a borehole drilling operation to increase the types of measurements that can be obtained during the drilling operation and reduce equipment costs and maintenance costs. Certain wireline type tools can be used during drilling operations to yield measurements superior to their LWD/MWD counterparts, but not during any drilling operation in which the drill string is rotating while other types of wireline tools can be used to obtain measurements not possible with LWD/MWD systems.

Abstract: A sensor for measuring at least one of temperature and pressure in a borehole, the sensor including a mixing medium disposed in a housing adapted for insertion into the borehole, the mixing medium exposed to at least one of the temperature and the pressure; wherein the mixing medium is used for four wave mixing of light to provide a signal that indicates at least one of the temperature and the pressure.

Abstract: A method which can correctly calculate a twist angle in a wire harness, an apparatus for the method, and a program for the method are provided. In the invention, a shape obtained by deforming a reference shape model and superimposing the deformed reference shape model on a deformed shape model is calculated with using a finite element method, while referring physical properties of a wire-like structure. In accordance with the superimposition, also a reference axis of the reference shape model is rotated. An angle formed by the reference axis at the timing when the superimposition is ended, and a clamp axis of the deformed shape model and/or a virtual clamp axis is calculated as a twist angle.

Abstract: A method and system for characterization of fault conditions within a subterranean volume. In one embodiment, the system comprises means for mathematically modeling stress conditions, to predict breakout conditions along a borehole trajectory. The system further comprises means for sensing actual breakout conditions along the borehole . Predictive breakout data is compared with sensed breakout conditions to assess correlation between predictive data and actual data, verifying the accuracy of the stress model. The mathematical model may be revised to reflect the presence of an active fault plane in the volume, the presumed fault plane not being intersected by the borehole. The revised model is used to generate new predictive data. Revising the stress model and assessing correlation between predictive and actual breakout conditions is repeatable to achieve an optimally accurate stress model reflecting fault conditions proximal to but not necessarily penetrated by the borehole.

Abstract: Methods and apparatus for distributed temperature sensing (DTS) along a single mode or multimode optical waveguide or fiber include a calibration of initial Brillouin-based DTS measurements using Raman-based DTS measurements to enable accurate subsequent Brillouin-based DTS measurements. Such calibration may occur while the fiber is deployed in the environment in which temperature is to be sensed and thereby corrects influences on Brillouin scattered light from stress or strain along the fiber. Further, calibration may utilize one or more discrete temperature sensors to correct errors in one or both of the Brillouin-based DTS measurements and the Raman-based DTS measurements.

Abstract: A method of determining a particular value on a display, comprises the steps of: moving a time log relative to a time line until the time line identifies a selected time on the time log; moving a plurality of values on the display in synchronism with the moving of the time log relative to the time line; and identifying one of the plurality of values on the display when the time line identifies the selected time on the time log, the one of the plurality of values on the display representing the particular value. The particular value on the display comprises a depth on a depth log representing a depth of a drill bit in a borehole. The depth log moves in synchronism with a movement of the time log when the time log moves relative to the time line.

Abstract: This invention relates to a non-invasive method for easily locating an underground septic tank, distribution box, field line, conduit, or the like. In the preferred embodiment, prescribed acoustic signals are injected into an underground cavity via an accessable port and remotely detected by a time synchronized detector in contact with the ground which cross correlates the detected signal with a duplicate of the prescribed acoustic signal in order to reject background noise, and thus locate the underground cavity. A frequency sweep is conducted to exploit cavity resonance modes and thus further enhance the signal to noise ratio.

Abstract: A weather forecast providing easy access to Internet, a subscriber's network, and a computer connected to Internet or the subscriber's network for retrieving correct weather forecast information in time without being vulnerable to interference includes a casing; and a sensor unit to detect ambient weather information, a sensor signal process and data output unit to process those signals, a display unit to display weather data, and a key-in unit disposed to the casing; and further includes an interface unit to capture data from a network, and a unit to process data captured by the interface unit and convert them into that is identified by and inputted into the display unit.

Abstract: A method of evaluating changes for a wellbore interval involves acquiring a first log data from a logging sensor during a first pass over the wellbore interval, acquiring a second log data from the logging sensor during a second pass over the wellbore interval, calculating a plurality of delta values between the first log data and the second log data, deriving an observed effect using the plurality of the delta values, identifying a correlation between the observed effect and a casual event, and displaying the correlation on a display device.

Abstract: Methods and apparatus for emergency rig monitoring are disclosed herein. The invention generally relates to methods and apparatus for monitoring an offshore rig. The rig monitoring systems and methods of use can relay information regarding the rig such as location, attitude (e.g. tilt, oscillation), and local water and weather conditions. The rig monitoring systems and methods can also facilitate emergency communication for rig personnel. Access to the information can be remotely initiated and the systems can be configured to automatically respond to such initiation. The rig monitoring systems are equipped with a self-sustainable power supply for operation under conditions where external power sources are unavailable. Such rig monitoring systems and methods are particularly useful on rigs that are located in waters subject to rapid and severe changes in local weather such as storms.

Abstract: On the basis of rainfall amount data (24) representing a timeseries change in the amount of rainfall in a district as an estimation target and unascertained water amount data (23) representing a time-series change in the amount of unascertained water at a base point located downstream of each district, an unascertained water occurrence distribution estimating unit (12) of a control unit (10) calculates a correlation value between the rainfall amount data (24) in each district and the unascertained water amount data (23), and outputs each correlation value as an unascertained water occurrence distribution in each district.

Abstract: A method for analyzing a tubing section with multiple sensors at a consistent speed to improve the analysis and grading of tubing retrieved from an oil well. An analysis speed can be pre-set or input based on the tubing being analyzed and the sensors employed. The analysis data can be retrieved and charted based on whether the data was obtained within the required analysis speed. The data can then be displayed for grading and color-coded based on the data obtained within the required ranged and that obtained outside the range. Further, the display can remove the data obtained outside the required range and link together the remaining data to improve the grading process of the tubing sections.

Abstract: Aspects of this invention include a downhole tool and method for making a physical caliper measurement of a subterranean borehole. The tool is configured to make the physical borehole caliper measurement only when the measured pressure in each of three or more outwardly extendable blades is greater than a predetermined threshold pressure. Blade positions are measured and the borehole caliper calculated only when the pressure in each of the blades exceeds the threshold. Exemplary embodiments of the invention enable physical caliper measurements to be made with increased accuracy with each of the blades making firm contact with the borehole wall. Methods in accordance with the invention are especially well suited for use in directional drilling applications in that they tend to enable accurate caliper measurements to be made without repositioning the steering tool in the borehole.

Abstract: A method for monitoring a formation property includes determining at least two slowness values from at least two datasets each characterizing an acoustic wave having a different frequency traversing a formation; and deriving an indicator based on the at least two slowness values. A system for monitoring a formation property includes a process and a memory, wherein the memory stores a program having instructions for: determining at least two slowness values from at least two datasets each characterizing an acoustic wave having a different frequency traversing a formation; and deriving an indicator based on the at least two slowness values.

Abstract: A method, practiced by a Hydraulic Fracturing Simulator software, is adapted for simulating a hydraulic fracture in an Earth formation, the formation including a multilayered reservoir, a mesh adapted to overlay the fracture in the formation thereby defining a plurality of elements, the mesh and the fracture defining one or more partially active elements, the method comprising the step of: setting up an Influence Coefficient Matrix, the matrix having a plurality of numbers, the plurality of numbers of the Influence Coefficient Matrix being calculated and determined such that the method, practiced by the Hydraulic Fracturing Simulator software for simulating the hydraulic fracture, models, or take into account an existence of, the multilayered reservoir and the partially active elements.

Abstract: A technique usable with a well includes disposing a retractable line in a conduit having an open end located above a region of interest in the well. The retractable line comprises a sensing portion that, when the line is deployed, extends from the open end of the conduit and into the region of interest. Information observed by the sensing portion in the region of interest is communicated to the surface. When further well operations are to be performed in the region of interest, the retractable line is retracted until the sensing portion is located above the region of interest and below the surface. After the well operation is completed, the retractable line may be re-deployed such that the sensing portion again extends through the open end of the conduit and into the region of interest to continue observing characteristics associated with the well.

Abstract: The present invention is directed to methods for controlling the operations of a well service rig at a well site by evaluating load sensor data obtained from sensors on or associated with the well service rig. A rig load data chart can be reviewed and an average rig load can be determined for each pull of tubing or rods from a well. The average rig load can be used to calculate and set a rig overload level. If the rig load sensor reads a rig load at or above the rig overload level, the clutch for the hoist can be disengaged and the brake applied to prevent the load from either damaging the rig or breaking off the tubing or rods in the well. In addition, the rig load can be evaluated to determine when the limit the block speed when pulling rods or tubing.

Abstract: A method of analyzing characteristics of a subterranean formation includes transmitting a signal at least partially into a material of the subterranean formation such that the signal is transformed in a manner indicative of a characteristic of the material, receiving the transformed signal from the material, converting the transformed signal into image data indicative of the characteristic of the material, applying a first set of machine executable rules to the image data to produce segmented image data, wherein portions of the image that are sufficiently related according to the applied rules are grouped into segments, and analyzing, according to a second set of machine executable rules, the segmented image data to produce a geological profile of the subterranean formation.

Abstract: The invention relates to an image-reconstruction technique which is used to view multiphase flows using electrical capacitance tomography (ECT), which is based on non-linear heuristic global optimization methods involving simulated annealing and genetic algorithms. The inventive method consists in obtaining electrical capacitance data which are measured between electrodes positioned on the outer surface of pipeline, well or tank (electrically-insulating) containing fluids. The aforementioned data are dependent on the distribution of the fluids inside the pipeline, well or tank. Moreover, the data are processed in order to reconstruct an image of the spatial distribution of the relative electrical permittivity (also known as the dielectric constant) inside the tube, well or tank, which reflects the distribution of the different phases present in the flow.

Abstract: A communication module for use in wellbore logging operations. The module is attachable around a wireline, slickline, tubing or coiled tubing having a logging tool on its end. The module includes a drive means for transporting it down the line, a controller for controlling its operation, and communications for communicating with the logging tool. Communication between the module and the logging tool includes the transfer of data and operational instructions.

Abstract: A method of electromagnetic surveying of an area of seafloor that is thought or known to contain a subterranean hydrocarbon reservoir is described. The method includes broadcasting an EM signal from a horizontal electric dipole (HED) transmitter and obtaining vertical electric dipole (VED) response data at a remote receiver in response thereto. Survey data are analysed by comparing the VED response data with background data which are not sensitive to the postulated hydrocarbon reservoir. Accordingly, differences between the VED response data and the background data allow for the identification of buried hydrocarbon reservoirs. The background data may be provided by magneto-telluric surveying, controlled source electromagnetic surveying or from direct geophysical measurement.

Abstract: Techniques and a system for performing geological interpretation operations in support of energy resources exploration and production perform well log correlation operations for generating a set of graphical data describing the predetermined geological region. The process and system interpret the geological environment of the predetermined geological region from measured surface and fault data associated with the predetermined geological region. Allowing the user to query and filter graphical data representing the predetermined geological region, the method and system present manipulable three-dimensional geological interpretations of two-dimensional geological data relating to the predetermined geological region and provide displays of base map features associated with the predetermined geological region.

Abstract: A computer program product includes machine readable instructions stored on machine readable media, the instructions for correlating nuclear magnetic resonance (NMR) well logging data with other well logging data, the product including instructions for: receiving the NMR well logging data; receiving the other well logging data; determining a tendency of the NMR logging data to correlate with the other logging data and providing output including correlation information. A system is also provided.

Abstract: A method for data processing includes transforming measurement data acquired in the time domain during an oilfield operation into a second domain to produce transformed data; identifying distortions in the transformed data; removing the distortions from the transformed data; and transforming back from the second domain to the time domain to produce cleaned-up data. The transforming measurement data may use a Fourier transform or a wavelet transform. The method may further include compressing the cleaned-up data or reconstructing signals from the cleaned-up data. A method for data processing includes decomposing measurement data, which are acquired in an oilfield operation, using a low pass filter to produce a first dataset; decomposing the measurement data using a high pass filter to produce a second dataset; removing distortions from the second dataset to yield a corrected second dataset; and reconstructing a corrected dataset from the first dataset and the corrected second dataset.

Abstract: A method of measuring depth and/or azimuth of logging data, the logging data being related to at least one property of a zone GF, CS, CA surrounding a wellbore and being measured by at least a sensor array SA1D, SA2D, the method comprising the steps of: acquiring and storing a first logging data frame F11, F21 corresponding to a first position of the sensor array, acquiring and storing a second logging data frame F12, F22 corresponding to a second position of the sensor array, the first and second position are such that the second logging data frame F12, F22 overlaps at least partially the first logging data frame F11, F21, comparing the first F11, F21 and second F12, F22 logging data frame, and calculating a relative change in the depth ?DP and/or azimuth ?AZ of logging data measured by the sensor array SA1D, SA2D between the first F11, F21 and second F12, F22 logging data frame.

Abstract: A method for initializing the input of each of m receiver channels of a receiving transducer in a well logging tool comprising the steps of selecting a logging tool having a multi-element receiving transducer wherein each element of the multi-element receiving transducer operates in an anti-resonant mode below its resonant frequency, and executing a routine in an initialization mode wherein a predetermined number of run cycles are operated and receiver input responses are measured and averaged for each of the m channels while transmitter fixing signals are disabled.

Abstract: In general, the invention relates to a method for managing a drilling operation in a multicomponent particulate system.

Abstract: In a particular embodiment, a method and system are disclosed for measuring ion concentrations for a fluid and determining a degree of sample cleanup during sampling of a fluid downhole. The method includes but is not limited to deploying an ion selective sensor downhole, exposing the fluid to the ion selective sensor downhole, measuring ion concentrations of the fluid over time during sampling and estimating a degree of sample clean up from the ion concentration measurements. The system includes but is not limited to a tool deployed in a wellbore, an ion selective sensor in the tool, a processor in communication with the ion selective sensor and a memory for storing an output from the ion selective sensor.

Abstract: An appropriate rock physics model is chosen from well-log data and/or experience. The rock physics model is then used to generate a plurality of attribute values, including compression and shear velocities, at different porosities and gas hydrate saturations. Gas hydrates are classified into different ranges of porosity and hydrate saturation based on the population of multiple attributes, and probability density functions for each individual gas hydrate class are created. Probability density distribution functions for individual attributes and a joint conditional probability density functions are created using a Bayesian function. The conditional probability of the occurrences of gas hydrate classes given a set of values of the chosen attributes derived from seismic inversion and or well measurements is inverted. Finally, a maximum a-posteriori (MAP) rule is employed to obtain the optimal porosity and hydrate saturation estimation.

Abstract: A method and system for integrating multiple analytical processes for evaluating risk and uncertainty elements of a petroleum system. The integrated environment provides a consistent means of analysis for evaluating multiple petroleum systems including exploration prospects and reservoirs, wherein multiple evaluation tools can be used and each of the tools has a similar “look” and “feel” so that a user can efficiently utilize all of the tools in the integrated environment. The evaluation tools analyze common data sets within the integrated environment so that a consistent evaluation of a petroleum system can be performed.

Abstract: Various systems and methods determine a distance, magnitude, and azimuthal angle describing the location of an anomaly within a geologic formation. For example, a method involves identifying an electrical characteristic (e.g., resistivity or conductivity) at each of several sensors in a measurement-while-drilling (MWD) tool. Based on the electrical characteristic, information identifying a formation property of the anomaly is generated. The information includes at least one magnitude and at least one distance. Information information identifying an azimuthal angle is also generated based upon the electrical characteristic. The azimuthal angle relates a position of the anomalous formation to a position of a first sensor in the MWD tool.

Abstract: Aspects of this invention include a downhole tool having an angular position sensor disposed to measure the relative angular position between first and second members disposed to rotate about a common axis. A plurality of magnetic field sensors are deployed about the second member and disposed to measure magnetic flux emanating from first and second magnets deployed on the first member. A controller is programmed to determine the relative angular position based on magnetic measurements made by the magnetic field sensors. In a one exemplary embodiment, a downhole steering tool includes first and second magnets circumferentially spaced on the shaft and a plurality of magnetic field sensors deployed about the housing.

Abstract: Aspects of this invention include methods for surveying a subterranean borehole. In one exemplary aspect, a change in borehole azimuth between first and second longitudinally spaced gravity measurement sensors may be determined directly from gravity measurements made by the sensors and a measured angular position between the sensors. The gravity measurement sensors are typically disposed to rotate freely with respect to one another about a longitudinal axis of the borehole. Gravity MWD measurements in accordance with the present invention may be advantageously made without imposing any relative rotational constraints on first and second gravity sensor sets. The present invention also advantageously provides for downhole processing of the change in azimuth between the first and second gravity sensor sets. As such, Gravity MWD measurements in accordance with this invention may be advantageously utilized in closed-loop steering control methods.

Abstract: Methods and systems for investigating downhole conditions are described. One method comprises inserting a tubular into a wellbore, the tubular comprising a tubular section having upper and lower fluid injection ports, and having a thermally insulated fiber optic cable section positioned inside the tubular extending to the upper fluid injection port, and a non-insulated fiber optic cable section positioned outside of the tubular section and extending at least between the upper and lower fluid injection ports; positioning the tubular section having upper and lower fluid injection ports near a suspected thief or pay zone; injecting a fluid through the upper fluid injection port; determining a first differential temperature profile between the upper and lower fluid injection ports; injecting a fluid through the lower fluid injection port; and determining a second differential temperature profile at least between the upper and lower fluid injection ports.

Abstract: The downhole tool disclosed herein comprises a body, a flexible member attached to the body, and a transducer housed in the body. The flexible member compresses against one side of the wellbore and urges the body against the other side. The transducer emits a signal to the flexible member reflectable from the flexible member back to the transducer. The signal travel time from the transducer to the flexible member and back is analyzed for estimating the distance between the body and the flexible member. The standoff distance can be estimated from the distance between the body and the flexible member. From the standoff distance, the wellbore diameter is estimated. The tool may also obtain wellbore dimensions by obtaining near side wellbore standoff and using a magnetic ruler to determine bowspring flexing. The magnetic ruler results may be used in conjunction with or without the far side standoff data.

Abstract: A method of deriving a calibration filter for electromagnetic data is provided. The method comprises providing a source (21, 22) of electromagnetic radiation and subsequently measuring components of the source electromagnetic field (23, 24, 25) at a receiver when the source is sufficiently close to the receiver that the down-going signal dominates over the up-going signal reflected from features below the receiver. Such a measurement can be used in frequency domain analysis (26, 28, 29) to extract the down-going signal component and derive a calibration filter for the receiver. The method is repeated (27, 30) for each receiver used in an electromagnetic sounding survey.

Abstract: Measurements made with an induction logging tool are processed to provide a resistivity model of fluid invasion of the formation. Up to five zones can be determined over a radial distance of about 0.6 m. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

Abstract: The invention relates to a method of performing production operations. The method includes identifying a plurality of simulators from a group consisting of a wellsite simulator for modeling at least a portion of the wellsite of the oilfield and a non-wellsite simulator for modeling at least a portion of a non-wellsite portion of the oilfield, defining a first strategy template comprising a first condition defined based on a first variable of the plurality of simulators and a first action defined based on a control parameter of the plurality of simulators, wherein execution of the first action during simulation is determined based on the first condition in view of a logical relationship, developing a first strategy for managing the plurality of simulators during simulation, wherein the first strategy is developed using the first strategy template, and selectively simulating the operations of the oilfield using the plurality of simulators based on the first strategy.