Abstract: Apparatuses and methods to power and communicate with downhole sensors are presented. Preferred embodiments of the present invention includes energizing a downhole sensor with a surface pressure wave generator and a downhole mechanical to electrical energy converter. Preferred embodiments of the present invention also include transmitting data measured from a downhole sensor to a surface unit through modulation of surface-generated pressure waves.

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: An acoustic telemetry apparatus and method for communicating encoded digital data from a down-hole location through a borehole to the surface is described including an acoustic channel terminated at a down-hole end by a reflecting terminal (133, 134), an acoustic wave generator (140) located at the surface and providing an acoustic wave carrier signal through said acoustic, channel, a modulator (162, 163) located down-hole to modulate amplitude and/or phase of said carrier wave in response to an encoded digital signal and one or more sensors (150) located at the surface adapted to detect amplitude and/or phase related information of acoustic waves traveling within said acoustic channel to determine the encoded digital data.

Abstract: Systems and methods are disclosed for measuring densities and flow rates of gas-liquid fluid mixtures. In the systems and methods, the fluid mixture is caused to exhibit swirling flow as it flows through a conduit that includes a constriction, a first pressure difference is measured between two vertically-spaced measurement positions in the conduit, a second pressure difference is measured between two horizontally-spaced measurement positions in the conduit, the first horizontally-spaced measurement position being at the constriction region and the second horizontally-spaced measurement position being upstream or downstream of the constriction region, and one or more of the pressure differences is used to determine a density or a flow rate of the gas-liquid fluid mixture.

Abstract: A subterranean location accessed via a wellbore is treated with an oilfield fluid containing a viscosifying agent which is a polymer and a cross-linking agent which can undergo the Diels-Alder reaction to form a gel. Conditions at the subterranean location alter fluid viscosity by bringing about the Diels-Alder reaction to increase viscosity or the retro Diels-Alder reaction to decrease the viscosity of the gel.

Abstract: An acoustic telemetry apparatus and methods for communicating digital data from a down-hole location through a borehole to the surface or between locations within the borehole are described including a receiver and a transmitter linked by an acoustic channel (210) wherein acoustic channel has a cross-sectional area of 58 cm2 or less and the transmitter comprises an electro-active transducer generating a modulated continuous waveform.

Abstract: The drill bit system may include a chassis, a head, and a first plurality of gauge pads. The chassis may be configured to be operably coupled with a first rotational motion source. The head may include a first plurality of cutters coupled with an end of the head, and the head may be rotatably coupled with chassis. The head may be configured to be operably coupled with a second rotational motion source. The first plurality of gauge pads may include a second plurality of cutters, and the first plurality of gauge pads may be fixedly coupled with the chassis.

Abstract: The invention relates in a one aspect to a method or apparatus for measuring flow properties of a multiphase fluid stream flowing in a pipeline comprising means for sampling, with a sampling probe, a portion of the fluid stream; for measuring a differential pressure between a first pressure of the fluid stream in the pipeline and a second pressure of the portion of the fluid stream in the sampling probe; for controlling flow rate of the sampled portion, wherein the flow rate of the sampled portion is controlled to provide for nullification of the differential pressure in order to obtain substantially isokinetic sampling of the fluid stream; for measuring properties of the portion of the fluid stream; and for processing the measured properties to determine the flow properties of the multiphase fluid stream flowing in the pipeline, wherein the above elements do not require- or are performed without the determination of the density of fluid in the fluid stream through nuclear radiation methods.

Abstract: A mobile system for providing start-up electrical power to a micro scale liquid hydrocarbon and/or oxygenate synthesis plant is provided including a portable gas or liquid fueled electrical generator, a steam turbine, a plant generator mechanically coupled to the steam turbine, a plant power load; and means for synchronizing electrical power generated by the portable electrical generator with electrical power generated by the plant generator is provided. Also provided is a process for synchronizing electrical power generated by the portable electrical generator with electrical power generated by the plant generator.

Abstract: A method that involves developing an electromagnetic property model of a near surface area and using this electromagnetic property model and electromagnetic data acquired using one or more electromagnetic transmitters located above the near surface area and one or more electromagnetic receivers located within a wellbore to determine one or more electromagnetic properties of a subsurface area. Also an electromagnetic data acquisition system that includes one or more electromagnetic transmitters capable of being operated on the earth's surface, one or more first electromagnetic receivers capable of being operated within a wellbore and capable of receiving signals from the one or more electromagnetic transmitters, and one or more second electromagnetic receivers capable of being located on the earth's surface near the one or more electromagnetic transmitters and capable of receiving signals from the one or more electromagnetic transmitters. Related embodiments are also described.

Abstract: A method and apparatus for determining the concentration of organic acids in formation fluids is provided including pumps for pumping fluids from a subterranean formation into the body of a downhole tool and sources for illuminating the flow with infrared radiation to obtain the infrared absorption or a related parameter at one or more wavelengths, and processors for converting the measured absorption into the concentration of the organic acids, using for example a multi-value calibration matrix which relates IR absorption spectral values to concentration measurement under downhole conditions.

Abstract: A method of measuring a parameter characteristic of a rock formation is provided, the method including the steps of deploying in a section of a well penetrating the rock formation a toolstring combining a tool for generating and measuring responses to a sensing field at different radial depth shells in the rock formation relative to the well and a tool to cause a flow of fluid through the different radial depth shells such that responses to the sensing field are obtained for at least two different radial depth shells and for at least two different flow conditions in said at least two different radial depth shells to determine a radial depth dependent profile of said parameter.

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: Methods and devices are provided for investigating an earth formation use electro-kinetics and/or electro-osmosis measurements. In one example, the method includes creating a pressure difference in the earth formation proximate to a wellbore; measuring a generated electro-kinetic property of the earth formation proximate to the wellbore, the generated electro-kinetic property generated by the pressure difference; applying an electric field to the earth formation proximate to the wellbore; measuring a generated pressure change in the earth formation proximate to the wellbore, the generated pressure change generated by the electric field; and determining wettability of the earth formation proximate to the wellbore by the use of the measurement of the generated electro-kinetic property and the measurement of the generated pressure change.

Abstract: A preferred method for determining the flow fraction of a mixture of water, gas and oil in a hydrocarbon reservoir includes measuring pressure and density of the mixture over time, determining a function which approximates a relationship between the density and pressure measurements, calculating a derivative of the function over time, and determining flow fraction based, in part, on the derivative. Preferably, transient data points are eliminated and the remaining set of data points are weight averaged to improve signal to noise ratio. Bubble point pressure, bubble point density and molecular weight and density of the liquid portion of the mixture are also used in the determination.

Abstract: A cased hole pressure test tool is used to determine the integrity of cement between two points in a borehole in terms of permeability or transmissibility. The test tool drills at least one probe hole through the casing up to the cement. In one embodiment, two probes are set and the dissipation of a pressure pulse through the cement initiated by the first probe is observed by the second probe. In another embodiment, one probe hole is in hydraulic communication with the borehole fluid and a single offset probe is set in another probe hole. Fluid (water) is then added to the borehole to cause a pressure increase in the borehole fluid. Detection of the pressure increase through the cement by the offset probe is indicative of a loss of hydraulic isolation. Packers may be used to isolate the portion of the borehole under test. A mechanism for generating a pressure pulse of known magnitude is also described.

Abstract: This invention pertains to the extraction of the slowness dispersion characteristics of acoustic waves received by an array of two or more sensors by the application of a continuous wavelet transform on the received array waveforms (data). This produces a time-frequency map of the data for each sensor that facilitates the separation of the propagating components thereon. Two different methods are described to achieve the dispersion extraction by exploiting the time frequency localization of the propagating mode and the continuity of the dispersion curve as a function of frequency. The first method uses some features on the modulus map such as the peak to determine the time locus of the energy of each mode as a function of frequency. The second method uses a new modified Radon transform applied to the coefficients of the time frequency representation of the waveform traces received by the aforementioned sensors.

Abstract: Determination of in-situ rock yield stress state of a geological formation surrounding a borehole includes determining a profile for each of an axial effective, a radial effective, and a hoop effective stress within at least one axial plane containing a borehole axis. A predicted radial shear response radial profile is calculated from the effective stresses within the at least one axial plane. A measurement-based estimate of a shear response radial profile within the at least one axial plane is determined from measured data. A maximum radial distance at which a difference between the predicted and measurement-based shear response radial profiles is identified within the at least one axial plane as being greater than a difference threshold. The respective axial, radial, and hoop stresses, are determined at the identified maximum radial distance. The identified stresses are indicative of an in-situ yield stress state of the rock.

Abstract: An apparatus for use in a system that includes a network analyzer for determining a property, such as dielectric permittivity of a sample material as a function of frequency, the apparatus including: a cylindrical chamber for receiving the sample; a coaxial connector having a first relatively small diameter end coupleable with the analyzer and a second relatively large diameter end communicating with a side of the cylindrical chamber, the connector having inner and outer coaxial conductors; the inner conductor of the connector having a diameter that tapers outwardly from the first end to the second end, and the outer conductor of the connector having an inner surface whose diameter tapers outwardly from the first end to the second end. The chamber can accommodate relatively large samples, such as standard earth formation coring samples.

Abstract: A method of determining the nature of a submarine or subterranean reservoir having an electromagnetic characteristic is described. The method comprises analyzing data associated with the application of a time varying electromagnetic field from above the reservoir using a data analysis methodology that does not utilize an estimate of the reservoir's geometry in determining one or more characteristics of the reservoir.