Rocco M Difoggio

6341498, Jan 29, 2002

Jan 8, 2001

09/756574

Rocco DiFoggio - Houston TX

Baker Hughes, Inc. - Houston TX

F25D 2312

622592, 62271, 166 66

A cooling system in which an electronic component is cooled by using one or more containers of liquid and sorbent that transfer heat from the component to the fluid in the well bore. According to the present invention, a sorption cooling system is provided for use in a well, Such as down hole tool which is in a drill string through which a drilling fluid flows, or in a down hole tool, which is on a wire line. This cooling system comprises a housing adapted to be disposed in a wellbore, the sorption cooler comprising a water supply adjacent to a sensor or electronics to be cooled; a Dewar flask lined with phase change material surrounding the electronics/sensor and liquid supply; a vapor passage for transferring vapor from the water supply; and a sorbent in thermal contact with the housing for receiving and adsorbing the water vapor from the vapor passage and transferring the heat from the sorbed water vapor through the housing to the drilling fluid or well bore. The electronics or sensors adjacent to the water supply are cooled by the evaporation of the liquid.

6420869, Jul 16, 2002

Oct 17, 2000

09/690642

Rocco DiFoggio - Houston TX

Baker Hughes Incorporated - Houston TX

G01V 300

324303, 324300

By developing correlations between near-infrared spectra (NIR) and the T and T Nuclear Magnetic Resonance (NMR) decay times of known crude oils, we can then use near-infrared measurements to predict T and T decay times of unknown crude oils. The purpose is to use NIR to predict NMR parameters of crude oils while they are being sampled downhole by a formation tester and to use these predictions to improve log interpretation of NMR logs.

6627873, Sep 30, 2003

Apr 16, 2001

09/836044

Borislav J. Tchakarov - Katy TX
Rocco DiFoggio - Houston TX
Stanislav W. Forgang - Houston TX
Otto N. Fanini - Houston TX
Marcelo F. Civarolo - The Woodlands TX
James C. Hunziker - New Caney TX

Baker Hughes Incorporated - Houston TX

G01V 800

250256, 250255, 2502691

A logging while drilling and wire line system for analyzing the concentration of carbon dioxide or another substance, in a sample down hole in a bore hole. A chamber is filled with a sample that may be fluid, or condensate and gas. The interior chamber volume is selectably expandable for decompression of the sample. The sample may alternately be decompressed by allowing a sample at formation pressure to enter the chamber at a lower pressure, thereby decompressing the sample. A sensor measures the absorbance, transmittance or attenuated total reflectance of the infrared light. Mid and near infrared light is utilized to identify carbon dioxide, water and a plurality of hydrocarbons. A wiper cleans the transmitter and sensor between readings to reduce measurement error caused by fluid sample contamination.

6672093, Jan 6, 2004

Dec 21, 2001

10/036972

Rocco DiFoggio - Houston TX

Baker Hughes Incorporated - Houston TX

F25B 1500

622592, 62476

A cooling system in which an electronic component is cooled by using one or more containers of liquid and sorbent that transfer heat from the component to the fluid in the well bore. According to the present invention, a sorption cooling and heating system is provided for use in a well, such as down hole tool which is in a drill string through which a drilling fluid flows, or in a down hole tool, which is on a wire line. This cooling system comprises a housing adapted to be disposed in a wellbore, the sorption cooler comprising a water supply adjacent to a sensor or electronics to be cooled; a Dewar flask lined with phase change material surrounding the electronics/sensor and liquid supply; a vapor passage for transferring vapor from the water supply; and a sorbent in thermal contact with the housing for receiving and adsorbing the water vapor from the vapor passage and transferring the heat from the sorbed water vapor through the housing to the drilling fluid or well bore. The electronics or sensors adjacent to the water supply are cooled by the evaporation of the liquid. A sample chamber to be heated or other element such as a clock crystal which is intended to be heated for stability can be placed adjacent to the dessicant to provide heat.

6683681, Jan 27, 2004

Apr 10, 2002

10/119492

Rocco DiFoggio - Houston TX
Arnold Walkow - Houston TX
Paul Bergren - Houston TX

Baker Hughes Incorporated - Houston TX

G01N 2141

356128, 356133, 250577

The invention relates to refractometry and attenuated reflectance spectrometry in a wellbore environment. Specifically, it pertains to a robust apparatus and method for measuring refractive index of fluids along a continuum (rather than in steps), and for measuring attenuated reflectance spectra, and for interpreting the measurements made with this apparatus to determine a variety of formation fluid parameters. The present invention provides a method and apparatus to distinguish between gas and liquid based on the much lower index of refraction of gas. It can also be used to monitor fluid sample clean up over time. The refractive index of a wellbore fluid is determined from the fraction, R, of light reflected off the interface between a transparent window that has a known refractive index and this fluid. Preferably, the refractive index is measured at some wavelength of light for which the fluid is not highly attenuating. However, the adjacent transmission spectrometer can be used to correct the refractive index measurement for attenuation at those wavelengths, which it monitors.

6714872, Mar 30, 2004

Aug 27, 2002

10/229228

Rocco DiFoggio - Houston TX
Jaedong Lee - Houston TX

Baker Hughes Incorporated - Houston TX

G01V 800

702 12

The present invention provides method of quantifying sample clean up in real time by providing curve-fitting measurements of optical or physical properties of fluid samples in boreholes. Sample fluid is extracted from the formation surrounding the borehole. As fluid continues to be extracted the composition of the extracted sample changes, altering the values of physical properties of the sample being measured. Measurements are made of optical or physical properties of the sampled fluid, and regression analysis is performed on the acquired measured data points. In one embodiment of the invention, iterative methods enable a user to determine an asymptotic value of a physical property, i. e. absorbance, as well as the percent of the progress that the current sample has obtained toward reaching the asymptotic property value and a projected time to reach the asymptotic property value. If the projected time required to reach that asymptotic value is too long, the operator may decide to abandon extracting fluid from the region. In another embodiment, a more general method enables the user to estimate, through the value of a variable, the speed at which cleanup can occur.

6798518, Sep 28, 2004

Jun 4, 2002

10/162030

Rocco DiFoggio - Houston TX
Arnold Walkow - Houston TX
Paul Bergren - Houston TX

Baker Hughes Incorporated - Houston TX

G01J 351

356416, 356419, 25033909

The invention comprises a method of adapting derivative spectrometry for use in a downhole environment and addresses problems that are inherent in this environment. Such problems include, but are not limited to, elevated temperatures and scattering from particles residing within dirty fluid samples. The invention improves the resolution by measuring the first derivative of the spectrum. The derivative spectrometer of this invention operates by vibrating a linear variable interference filter back and forth along the plane of the filter or by oscillating a circular variable filter about some angle.

6837105, Jan 4, 2005

Sep 18, 2003

10/664664

Rocco DiFoggio - Houston TX, US
Peter W. Reittinger - Katy TX, US

Baker Hughes Incorporated - Houston TX

G01V 122
G01V 140

7315246, 7315243, 7315247, 7315249, 175 1, 175 4, 367 86

A system and method for acquiring seismic data are disclosed. The system comprises a controller for causing the generation of a seismic signal, where the controller has a first clock used for time-stamping a record of the generated seismic signal. A seismic receiver is deployed in a wellbore so as to detect the generated seismic signal. An atomic clock is disposed in or with the seismic receiver for time-stamping a record of the detected seismic signal. The atomic clock is synchronized with the first clock prior to being placed downhole.