Baker Hughes Corporation

Ingrain, Inc.

Theodore Edward Zaleski, Jr

Daniel E Ruff

Scott Ray Schmidt

Eric Charles Sullivan

Don Quy Nguyen

Michael L Doster

Jack Thomas Oldham

Mark William Dykstra

Christopher C Beuershausen

William Heuser

Terry D Watts

Glenn R Zadrapa

Rodney B Walzel

Chih C Lin

Timothy King Marvel

Avrami Grader

Carl Sisk

Henrique Tono

A method for determining effects of perforation on a rock formation includes obtaining a sample of the rock formation. A perforation tunnel is created in the sample of the rock formation. The core sample is either subdivided into subsamples and a three dimensional tomographic image is made of each subsample and/or a three dimensional tomographic image is made of the sample of rock formation and the image thereof is segmented into sub images of selected subvolumes of the rock formation sample. At least one physical property of the rock formation is estimated from each tomographic image.

Method for evaluating shaped charge perforation test cores using computer tomographic images thereof

A method and system for obtaining a consistent and integrated set of physical properties of a sample specimen of porous media, e.g., rock, in which a specimen is prepared for imaging. The specimen is imaged multiple times to yield a set of images that undergo a segmentation process to provide a digital representation of the sample specimen. The digital representation provides a view of the solid phase and pore space of the sample specimen. The digital representation may be used to determine a plurality of physical properties of the sample porous specimen, such that the sample porous specimen may remain intact throughout the method.

Method for obtaining consistent and integrated physical properties of porous media

A rotary drilling apparatus and method for drilling subterranean formations, including a body being provided with at least one cutter thereon exhibiting reduced, or limited, exposure to the formation, so as to control the depth-of-cut of the at least one cutter, so as to control the volume of formation material cut per rotation of the drilling apparatus, as well as to control the amount of torque experienced by the drilling apparatus and an optionally associated bottomhole assembly regardless of the effective weight-on-bit are all disclosed. The exterior of the drilling apparatus may include a plurality of blade structures carrying at least one such cutter thereon and including a sufficient amount of bearing surface area to contact the formation so as to generally distribute an additional weight applied to the drilling apparatus against the bottom of the borehole without exceeding the compressive strength of the formation rock.

Drilling apparatus with reduced exposure of cutters and methods of drilling

A rotary drag bit and method for drilling subterranean formations, including a bit body being provided with at least one cutter thereon exhibiting reduced, or limited, exposure to the formation, so as to control the depth-of-cut of the at least one cutter, so as to control the volume of formation material cut per bit rotation, as well as to control the amount of torque experienced by the bit and an optionally associated bottomhole assembly regardless of the effective weight-on-bit are all disclosed. The exterior of the bit preferably includes a plurality of blade structures carrying at least one such cutter thereon and including a sufficient amount of bearing surface area to contact the formation so as to generally distribute an additional weight applied to the bit against the bottom of the borehole without exceeding the compressive strength of the formation rock.

Drill bits with reduced exposure of cutters

An improved drill bit for use in drilling operations in a wellbore comprising a bit body including a plurality of bit legs, each supporting a rolling cone cutter, a lubrication system for a rolling cone cutter, at least one lubrication sensor for monitoring at least one condition of said lubricant during drilling operations, and an electronics member in the bit body for recording data obtained form said lubrication sensor.

Method and apparatus for monitoring and recording of the operating condition of a downhole drill bit during drilling operations

A rotary drag bit and method for drilling subterranean formations including a bit body being provided with at least one cutter thereon exhibiting reduced, or limited, exposure to the formation so as to control the depth-of-cut of the at least one cutter, so as to control the volume of formation material cut per bit rotation, as well as to control the amount of torque experienced by the bit and an optionally associated bottomhole assembly regardless of the effective weight-on-bit. The exterior of the bit preferably includes a plurality of blade structures carrying at least one such cutter thereon and including a sufficient amount of bearing surface area to contact the formation so as to generally distribute an additional weight applied to the bit against the bottom of the borehole without exceeding the compressive strength of the formation rock.

Drill bits with controlled exposure of cutters

An improved drill bit is provided with a sensor for monitoring an operating condition during drilling. A fastener system is provided for securing an erodible ball in a fixed position relative to a flow pathway until a predetermined operating condition is detected by the sensor, and for releasing the erodible ball into the flow pathway to obstruct the flow through at least one bit nozzle.

An improved drill bit includes a bit body, a coupling member formed at an upper shank portion. It further includes at least one sensor for monitoring at least one condition of the bit during drilling operations. In one embodiment the at least one sensor is a capacitor disposed in a lubrication pathway. An electronics bay is defined in-part by the upper shank portion. It houses at least one monitoring circuit. A battery cavity is disposed in at least one of the bit legs. A battery cavity cap is provided. A seal is provided to seal the battery cavity cap at the bit leg to define a fluid tight battery cavity.

A drill bit for use in drilling operations in a wellbore, the drill bit having a bit body including a plurality of bit legs, each supporting a rolling cone cutter; a coupling member formed at an upper portion of the bit body; at least one temperature sensor for monitoring at least one temperature condition of the improved drill bit during drilling operations; and at least one temperature sensor cavity formed in the bit body and adapted for receiving, carrying, and locating the at least one temperature sensor in a particular position relative to the bit body which is empirically determined to optimize temperature sensor discrimination.

A rotary drag bit and method for drilling subterranean formations including a bit body being provided with at least one cutter thereon exhibiting reduced, or limited, exposure to the formation so as to control the depth-of-cut of the at least one cutter, so as to control the volume of formation material cut per bit rotation, as well as to control the amount of torque experienced by the bit and an optionally associated bottomhole assembly regardless of the effective weight-on-bit. The exterior of the bit preferably includes a plurality of blade structures carrying at least one such cutter thereon and including a sufficient amount of bearing surface area to contact the formation so as to generally distribute the weight of the bit against the bottom of the borehole without exceeding the compressive strength of the formation rock.

An improved drill bit includes a condition sensor and a semiconductor memory. The condition sensor includes an electrical sensor which has an attribute which changes in response to changes in the bit condition. Monitoring and sampling circuits are utilized to record this data into the semiconductor memory. A communication system may be provided which includes a signal flow path and a selectively-actuable flow control device for controlling the signal flow path until a predetermined operating condition is detected; upon actuation, a detectable pressure change is developed in the wellbore.

Growing community of inventors

Spring, TX, United States of America

Theodore Edward Zaleski, Jr