Peter Ross Kaufman

US Patent:

20080040086, Feb 14, 2008

Filed:

Aug 1, 2007

Appl. No.:

11/832290

Inventors:

Soraya Betancourt - Cambridge MA, US
Oliver Mullins - Ridgefield CT, US
Rimas Gaizutis - Kuala Lumpur, MY
ChengGang Xian - Tripoli, LY
Peter Kaufman - Highlands Ranch CO, US
Francois Dubost - Orgeval, FR
Lalitha Venkataramanan - Lexington MA, US

Assignee:

SCHLUMBERGER TECHNOLOGY CORPORATION - Cambridge MA

International Classification:

G01V 9/00
G06F 19/00
G06G 7/48

US Classification:

703010000, 702011000, 073152280

Abstract:

Formation fluid data based on measurements taken downhole under natural conditions is utilized to help identify reservoir compartments. A geological model of the reservoir including expected pressure and temperature conditions is integrated with a predicted fluid model fitted to measured composition and PVT data on reservoir fluid samples or representative analog. Synthetic downhole fluid analysis (DFA) logs created from the predictive fluid model can be displayed along the proposed borehole trajectory by geological modeling software prior to data acquisition. During a downhole fluid sampling operation, actual measurements can be displayed next to the predicted logs. If agreement exists between the predicted and measured fluid samples, the geologic and fluid models are validated. However, if there is a discrepancy between the predicted and measured fluid samples, the geological model and the fluid model need to be re-analyzed, e.g., to identify reservoir fluid compartments. A quantitative comparative analysis of the sampled fluids can be performed against other samples in the same borehole or in different boreholes in the field or region to calculate the statistical similarity of the fluids, and thus the possible connectivity between two or more reservoir regions.

US Patent:

20150363520, Dec 17, 2015

Filed:

Jan 13, 2014

Appl. No.:

14/762828

Inventors:

- Sugar Land TX, US
Benoit Couet - Belmont MA, US
Peter Kaufman - Highlands Ranch CO, US
Oliver C. Mullins - Houston TX, US

International Classification:

G06F 17/50
E21B 49/08

Abstract:

A method for deriving VOI for a hydrocarbon-bearing reservoir fluid model based on DFA data (“true fluid model”) versus an “incorrect fluid model” includes calculating first, second and third objective functions that are based on NPV(s) of simulated production by a reservoir simulator with different configurations. For the first objective function, the simulator is configured with the incorrect fluid model and control variables that are optimized to derive a first group of control variable values. For the second objective function, the simulator is configured with the true fluid model and the first group of control variable values. For the third objective function, the simulator is configured with the true fluid model and control variables that are optimized to identify a second group of control variable values. The objective functions can be deterministic, or can include statistics that account for uncertainty. A visualization of such results with uncertainty is also described.

US Patent:

20080062814, Mar 13, 2008

Filed:

Oct 27, 2006

Appl. No.:

11/553565

Inventors:

Romain C.A. Prioul - Cambridge MA, US
John Adam Donald - Highlands Ranch CO, US
Randolph Koepsell - Highlands Ranch CO, US
Tom R. Bratton - Littleton CO, US
Peter Kaufman - Mt. Lebanon PA, US
Claude Signer - Somerville MA, US

Assignee:

SCHLUMBERGER TECHNOLOGY CORPORATION - Ridgefield CT

International Classification:

G01V 1/40

US Classification:

367 31

Abstract:

Fracture- and stress-induced sonic anisotropy is distinguished using a combination of image and sonic logs. Borehole image and sonic logs are acquired via known techniques. Analysis of sonic data from monopole P- and S-waves, monopole Stoneley and cross-dipole shear sonic data in an anisotropic formation are used to estimate at least one compressional and two shear moduli, and the dipole fast shear direction. Fracture analysis of image logs enables determination of fracture types and geometrical properties. Geological and geomechanical analysis from image logs provide a priori discrimination of natural fractures and stress-induced fractures. A forward quantitative model of natural fracture- and stress-induced sonic anisotropy based on the knowledge of fracture properties interpreted from image logs allows the computation of the fast-shear azimuth and the difference in slowness between the fast- and slow-shear. The misfit between predicted and observed sonic measurements (i.e. fast-shear azimuth and slownesses) is then optimized in order to discriminate depth zones with an elastic medium as being influenced by the presence of open natural fractures, closed natural fractures and fractures induced by non-equal principal stress effects.