The patent badge is an abbreviated version of the USPTO patent document. The patent badge does contain a link to the full patent document.

The patent badge is an abbreviated version of the USPTO patent document. The patent badge covers the following: Patent number, Date patent was issued, Date patent was filed, Title of the patent, Applicant, Inventor, Assignee, Attorney firm, Primary examiner, Assistant examiner, CPCs, and Abstract. The patent badge does contain a link to the full patent document (in Adobe Acrobat format, aka pdf). To download or print any patent click here.

Date of Patent:
Feb. 14, 2017

Filed:

Nov. 12, 2013
Applicant:

Halliburton Energy Services, Inc., Houston, TX (US);

Inventors:

Dale E. Jamison, Humble, TX (US);

Robert L. Williams, Houston, TX (US);

Assignee:
Attorneys:
Primary Examiner:
Int. Cl.
CPC ...
E21B 41/00 (2006.01); E21B 44/06 (2006.01); E21B 21/08 (2006.01); E21B 44/00 (2006.01); E21B 44/02 (2006.01); E21B 44/04 (2006.01); E21B 45/00 (2006.01); E21B 47/024 (2006.01); E21B 47/04 (2012.01); E21B 47/06 (2012.01); E21B 47/10 (2012.01); E21B 49/00 (2006.01); G06F 17/10 (2006.01);
U.S. Cl.
CPC ...
E21B 41/0092 (2013.01); E21B 21/08 (2013.01); E21B 44/00 (2013.01); E21B 44/02 (2013.01); E21B 44/04 (2013.01); E21B 44/06 (2013.01); E21B 45/00 (2013.01); E21B 47/024 (2013.01); E21B 47/04 (2013.01); E21B 47/06 (2013.01); E21B 47/065 (2013.01); E21B 47/10 (2013.01); E21B 49/003 (2013.01); G06F 17/10 (2013.01);
Abstract

Systems and methods for optimizing drilling results may be based on, inter alia, (1) real-time data collected during drilling, (2) a transiently modeled cuttings distribution along the wellbore, and optionally (3) a theoretical change to one or more operational parameters. In some instances, methods may include drilling a wellbore penetrating a subterranean formation while circulating a drilling fluid; gathering real-time data about the drilling; calculating a cuttings distribution along the wellbore based on the real-time data using a transient model; calculating an equivalent circulating density profile along the wellbore based on (1) real-time data collected during drilling, (2) a transiently modeled cuttings distribution along the wellbore, and optionally (3) a theoretical change; and changing at least one operational parameter based on a comparison of the equivalent circulating density profile to a fracture gradient of the subterranean formation.


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