Abstract: A hybrid evolutionary algorithm (“HEA”) technique is described for automatically calculating well and drainage locations in a field. The technique includes planning a set of wells on a static reservoir model using an automated well planner tool that designs realistic wells that satisfy drilling and construction constraints. A subset of these locations is then selected based on dynamic flow simulation using a cost function that maximizes recovery or economic benefit. In particular, a large population of candidate targets, drain holes and trajectories is initially created using fast calculation analysis tools of cost and value, and as the workflow proceeds, the population size is reduced in each successive operation, thereby facilitating use of increasingly sophisticated calculation analysis tools for economic valuation of the reservoir while reducing overall time required to obtain the result. In the final operation, only a small number of full reservoir simulations are required for the most promising FDPs.

Abstract: A system for automatically optimizing a Field Development Plan (FDP) for an oil or gas field uses a fast analytic reservoir simulator to dynamically model oil or gas production from the entire reservoir over time in an accurate and rapid manner. An objective function defining a Figure of Merit (FoM) for candidate FDPs is maximized, using an optimization algorithm, to determine an optimized FDP in light of physical, engineering, operational, legal and engineering constraints. The objective function for the Figure of Merit, e.g., net present value (NPV) or total production for a given period of time, relies on a production forecast from the fast analytic reservoir simulator for the entire FDP. The position, orientation and dimensions of analytical model elements for the subsurface oil or gas field, as well as the physical properties associated with these elements, correlate to connected flow volume data from a Shared Earth Model (SEM). Uncertainty in the SEM is considered via stochastic sampling.

Abstract: A system and method for performing an adaptive drilling operation is provided. The method involves obtaining data prior to drilling, constructing a base model with a base model unit from data obtained prior to drilling, constructing an overburden posterior model with an overburden model unit using the base model and data obtained from overburden drilling, constructing a reservoir posterior model with a reservoir model unit using the overburden posterior model and the data obtained from reservoir drilling and updating drilling operation based on the models.

Abstract: A novel method is presented to automatically design a multi-well development plan given a set of previously interpreted subsurface targets. This method identifies the optimal plan by minimizing the total cost as a function of existing and required new platforms, the number of wells, and the drilling cost of each of the wells. The cost of each well is a function of the well path and the overall complexity of the well.

Abstract: A method of measuring oxygen-containing nitrogen components including nitrogen dioxide in exhaust gases of internal combustion engines, wherein an exhaust gas sample is taken from a removal point 10 at the exhaust gas pipe 1 and is guided to at least one measuring instrument by means of a removal line, wherein, for the purpose of measuring the oxygen-containing nitrogen components, there are provided a separate removal point 10 and a removal line 11 and that the exhaust gas sample for measuring the oxygen-containing nitrogen components is set to a temperature at which a reaction between the nitrogen dioxide and soot is low.

Abstract: A novel method is presented to automatically design a multi-well development plan given a set of previously interpreted subsurface targets. This method identifies the optimal plan by minimizing the total cost as a function of existing and required new platforms, the number of wells, and the drilling cost of each of the wells. The cost of each well is a function of the well path and the overall complexity of the well.

Abstract: A hybrid evolutionary algorithm (“HEA”) technique is described for automatically calculating well and drainage locations in a field. The technique includes planning a set of wells on a static reservoir model using an automated well planner tool that designs realistic wells that satisfy drilling and construction constraints. A subset of these locations is then selected based on dynamic flow simulation using a cost function that maximizes recovery or economic benefit. In particular, a large population of candidate targets, drain holes and trajectories is initially created using fast calculation analysis tools of cost and value, and as the workflow proceeds, the population size is reduced in each successive operation, thereby facilitating use of increasingly sophisticated calculation analysis tools for economic valuation of the reservoir while reducing overall time required to obtain the result. In the final operation, only a small number of full reservoir simulations are required for the most promising FDPs.

Abstract: A novel method is presented to automatically design a multi-well development plan given a set of previously interpreted subsurface targets. This method identifies the optimal plan by minimizing the total cost as a function of existing and required new platforms, the number of wells, and the drilling cost of each of the wells. The cost of each well is a function of the well path and the overall complexity of the well.

Abstract: A method of characterizing a borehole traversing an earth formation including (a) obtaining an array of data from a formation characterization tool, wherein the data describes a section of the borehole; (b) computing at least one spatial characteristic describing the relative position of pairs of data; (c) assigning said pairs of data to bins based on the spatial characteristic, wherein the size of the bins are selected based on the tool; (d) transforming the data to petrophysical properties of the borehole; (e) calculating the variance of each bin; (f) developing a model of the variances; (g) determining at least one geostatistical parameter using the model; and (h) upscaling the geostatistical parameters to characterize a region of said earth formation. The method may further include generating a heterogeneity index log using the geostatistical model parameters. The method may be implemented using a computer program product for processing and interpreting borehole data.

Abstract: A method of managing oil fields include installing oil field sensors, coupling them to a local CPU having memory, programming the CPU for data collection and data analysis, and coupling local oil field CPUs to a web server. Human experts are granted access to oil field data in real time via the Internet. The local CPUs provide different levels of data to the web server. The web server provides the option to view raw data, partially analyzed data, or fully analyzed data. The local CPUs are programmed with parameters for analyzing the data and automatically determining the presence of anomalies. Upon detecting the occurrence of an anomaly, the local CPUs are programmed to notify one or more human experts by email, pager, telephone, etc. If no human expert responds to the notification within a programmed period of time, the local CPU automatically takes a programmed corrective action.

Abstract: A method of characterizing a borehole traversing an earth formation including (a) obtaining an array of data from a formation characterization tool, wherein the data describes a section of the borehole; (b) computing at least one spatial characteristic describing the relative position of pairs of data; (c) assigning said pairs of data to bins based on the spatial characteristic, wherein the size of the bins are selected based on the tool; (d) transforming the data to petrophysical properties of the borehole; (e) calculating the variance of each bin; (f) developing a model of the variances; (g) determining at least one geostatistical parameter using the model; and (h) upscaling the geostatistical parameters to characterize a region of said earth formation. The method may further include generating a heterogeneity index log using the geostatistical model parameters. The method may be implemented using a computer program product for processing and interpreting borehole data.

Abstract: Control means are provided for an apparatus for cross-winding packages of textile yarn or the like. The control means includes means operable during at least a portion of the rotation of the package at the selected rotational speed for increasing the relative frequency of traverse of the yarn guide means with respect to the selected rotational speed to a ratio less than the ratio of the rotational speed to the relative frequency of traverse prior to rotation at the selected rotational speed. The control means can gradually increase the relative frequency during operation at the selected rotational speed so that the ratio of the rotational speed to the relative frequency of traverse of the yarn guide means gradually decreases from the ratio of the rotational speed to the relative frequency of traverse at the beginning of rotation at the selected rotational speed.

Abstract: Control means in an apparatus for cross-winding packages of textile yarn or the like is provided and includes means operable during at least a portion of the high speed or accelerating rotation for increasing the relative frequency of traverse of the traversing yarn guide means with respect to the rotational winding speed of the package from a frequency at which the ratio of the rotational winding speed to the relative frequency of traverse is greater than the ratio of the selected rotational winding speed and the related selected frequency of traverse. The control means can gradually increase the relative frequency during the high speed or accelerating rotation so that at least before the end of the high speed or accelerating rotation, the ratio of the rotational winding speed to the relative frequency of traverse of the yarn guide means is approximately the same as the ratio of the selected rotational winding speed and the related selected frequency.