Baker Hughes Corporation

Baker Hughes Oilfield Operations LLC

Baker Hughes, a Ge Compnay, LLC

Ansgar Cartellieri

Tobias Kischkat

Bastian Baecker

Salar Azizi

Detlev Benedict

Nicklas Jeremias Ritzmann

Eick Niemeyer

Sandip Maity

Mouin Hamdan

Stefan Sroka

Christopher Jakubeit

Gunnar Bothmann

Svenja Erdmann

A method of analyzing a fluid includes acquiring a sample of the fluid extracted from a subterranean region proximate to a borehole, the borehole including an injected fluid, applying light having a first excitation wavelength to the fluid sample, and measuring a first fluorescence spectrum. The method also includes comparing the first fluorescence spectrum to a reference fluorescence spectrum corresponding to a fluid having injected fluid contamination and/or to a second fluorescence spectrum based on applying light having a second excitation wavelength to the fluid sample. The method further includes estimating a level of contamination of the fluid sample with the injected fluid based on the comparing.

Fluorescence spectroscopy for estimation of fluid contamination

A system for separation of components of a natural gas product uses a first separation column to receive the natural gas product and to provide first stage components including a first component gas, uses a gas converter to provide second stage components that includes third component gas from at least a second component gas of such first stage components, and uses a second separation column to provide third stage components that includes the first component gas, the third component gas, and one or more additional carbon-based components provided in or over a period of time associated with the separation of the components of the natural gas product.

Fast in-field chromatography system and method using isotope measurements

A method for evaluating a formation fluid includes the steps of drilling a borehole intersecting a formation with a drill string, circulating a drilling fluid in the wellbore, selectively liberating a formation fluid from the formation, injecting the liberated fluid into the drilling fluid returning to the surface, drawing a sample of the returning drilling fluid at the surface, and estimating at least one parameter of the drawn sample at the surface.

Method and systems for integrating downhole fluid data with surface mud-gas data

A method for measuring viscosity in a borehole includes: pumping downhole fluid through at least one tube disposed in a carrier configured to be disposed in a borehole in an earth formation; taking at least one differential pressure measurement of the fluid in the at least one tube via a pressure transducer; and estimating a viscosity of the fluid based on the differential pressure measurement.

Viscometer for downhole use

An apparatus and method conducting downhole measurement operations in a borehole penetrating an earth formation. The apparatus may include a module configured to be conveyed in a borehole and to receive at least one device. The module may receive the device internally or in one or more recessed areas. A housing with at least one opening may encompass the exterior of the module. The apparatus may have a first position that allows access to the module through the at least one opening, and a second position that isolates the module from the exterior of the housing. The method may include conducting downhole measurement related operations using the apparatus. The method may include moving the housing and module between the first position and the second position.

Apparatus and method for protecting devices downhole

A downhole fluid property estimating apparatus includes an interface in communication with a fluid in a first pressure zone, a collector in communication with the interface, the collector having a second pressure zone, wherein a second pressure zone pressure is less than a first pressure zone pressure, and a gas chromatograph coupled to the collector. A method includes establishing a first pressure zone having a fluid in communication with an interface, establishing a second pressure zone in a collector in communication with the interface, wherein a second pressure zone pressure is less than a first pressure zone pressure, collecting a fluid sample of the fluid in the first pressure zone using the collector, and estimating the downhole fluid property in-situ using a gas chromatograph coupled to the collector.

Downhole gas chromatograph

Apparatus and methods for estimating a downhole property are provided. The apparatus may include a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature and a temperature controller in communication with the downhole tool that maintains a downhole tool temperature substantially within the predetermined temperature calibration. A method may include conveying a downhole tool having a predetermined temperature calibration based at least in part on an expected downhole temperature in a well borehole and adjusting the temperature of the downhole tool during downhole operation to maintain a downhole tool temperature substantially within the predetermined temperature calibration.

Apparatus and methods for estimating a downhole property

Measurements of fluorescence spectra of fluid samples recovered downhole are processed to give the fluid composition. The processing may include a principal component analysis followed by a clustering method or a neutral network. Alternatively the processing may include a partial least squares regression. The latter can give the analysis of a mixture of three or more fluids.

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Lower Saxony, Germany

Ansgar Cartellieri