Halliburton Energy Services, Inc.

Landmark Graphics Corporation

Martin Dale Paulk

Michael S Bittar

Clive D Menezes

E Alan Coats

Carey John Naquin

David Johnson

Paul F Rodney

Rickey Lynn Morgan

Teruhiko Hagiwara

James B Terry

Haoshi Song

James W Estep

Michael John Strachan

Samuel Mark Haugland

Gary Dean Althoff

Patrick Emmett Laursen

Ron James Crook

Richard B Logan

Hamayun Zafar Raja

Frode Hveding

Stephen R Ingram

Systems and methods for real time data management in a collaborative environment. In one embodiment, the systems and methods dynamically link stakeholders, through a collaborative environment, to current and updated data. The systems and methods also cross-reference data objects between stakeholders for calling data objects by a common name, and determine a preferred method for each operation related to processing data for a data object.

Systems and methods for real time data management in a collaborative environment

A retrievable tool for steering through an earth formation includes a first tool assembly and a tilted antenna attached to the first tool assembly. The tool also includes a second tool assembly attached to the first tool assembly and a tilted antenna attached to the second tool assembly. The first tool assembly attaches to the second tool assembly so that the antennas are tilted in predetermined directions. The tilted antennas are transmitter antennas or receiver antennas. Each tool assembly is a tubular cylinder with a longitudinal axis running the length of the cylinder, wherein the tubular cylinder has two ends, each end including a rotational attachment mechanism. The tool assemblies attach to each other through their rotational attachment mechanisms. The rotational attachment mechanism may be a screw-on mechanism, press-fit mechanism, or welded mechanism.

Modular geosteering tool assembly

Borehole data presentation systems and methods that facilitate communication of volumetric logging data to a surface processing system for presentation to a driller or other user interested in visualizing the formations surrounding a borehole. The disclosed systems optionally tailor the telemetry stream to match the chosen display technique, thereby maximizing the logging system utility for the driller. Variable opacity of certain data regions or certain data discontinuities greatly facilitates data comprehension, particularly when true three-dimensional display technologies are employed. Holographic or stereoscopic display technologies may be employed to show the three-dimensional dependence of measured formation properties such as resistivity, density, and porosity. Alternatively, the radial axis can be used to represent a formation parameter value, thereby enabling cylindrical cross-plots of multiple measurements. The user can control viewing position and orientation to more fully explore the three dimensional representation.

Systems and methods for displaying logging data

Drilling laterals in shale formations. At least some of the illustrative embodiments are methods including: drilling a deviated borehole through a shale formation with a drill string comprising a drill bit; logging the shale formation with a logging tool disposed within the drill string; estimating, in real time with the drilling, fracture potential of a portion of the shale formation near the drill bit, the estimation of fracture potential based on information acquired by the logging tool; and controlling drilling direction based on the fracture potential.

Method and system of drilling laterals in shale formations

Estimating formation parameters. At least some of the illustrative embodiments are methods including: combining a first plurality of actual logs from a first plurality of actual boreholes, at least one actual log associated with each actual borehole, and thereby creating a first equivalent log along a first equivalent path; combining a second plurality of actual logs from a second plurality of actual boreholes, at least one actual log of the second plurality of actual logs associated with each actual borehole of the second plurality of actual boreholes, and thereby creating a second equivalent log along a second equivalent path; and estimating a plurality of values of a parameter of one or more formations along a proposed borehole path, each value associated with a distinct depth along the proposed borehole path, the estimating using the equivalent logs.

Methods and systems of estimating formation parameters

A drilling system has multiple cutting structures, including a bit and one or more secondary cutting structures. A method balances the rate of penetration of the drilling system and the wear on the cutting structures by controlling weight on bit and RPM. The method includes calculating a predicted rate of penetration for the bit, using in the calculation the current predicted wear on the bit and the properties of the rock to be penetrated by the bit. The method includes calculating a predicted rate of penetration for at least one of the one or more secondary cutting structures, using in the calculation the current predicted wear on the secondary cutting structure and the properties of the rock to be penetrated by the secondary cutting structure. The method includes determining the slowest rate of penetration among those calculated for the bit and at least one the one or more secondary cutting structures. The method includes calculating the weight on bit and RPM for each of the bit and at least one of the one or more secondary cutting structures to substantially match the determined slowest rate of penetration. The method includes summing the calculated weights on bit to calculate a goal weight on bit for the drilling system and setting a goal RPM for a rotary portion of the drilling system to the slowest RPM calculated for the cutting structures that rotate at substantially the speed of the rotary portion of the drilling system.

Method and system for predicting performance of a drilling system having multiple cutting structures

An apparatus and method for removing cuttings in a deviated borehole using drilling fluids. The apparatus includes a pipe string and a bottom hole assembly having a down hole motor and bit for drilling the borehole. The pipe string has one end attached to the bottom hole assembly and does not rotate during drilling. The apparatus and methods raise at least a portion of the pipe string in the deviated borehole to remove cuttings from underneath the pipe string portion.

Method and apparatus for removing cuttings

Methods and apparatus for monitoring and controlling the pressure in a wellbore characterized by a drilling system utilizing real-time bottom hole pressure measurements and a control system adapted to control parameters such as well shut-in, drilling fluid weight, pumping rate, and choke actuation. In the preferred embodiments, the control system receives input from the bottom hole pressure sensor as well as pressure sensors, mud volume sensors, and flowmeters located at the surface. The control system then adjusts one or more of drilling fluid density, pumping rate, or choke actuation to detect, shut-in, and circulate out wellbore influxes. The preferred system operates automatically without any manual intervention in well control processes.

Well control using pressure while drilling measurements

A method of compensating for tool motion is disclosed. In one embodiment, the method includes passing a logging tool through a borehole, obtaining a series of tool response measurements, and obtaining a series of tool position measurements associated with the tool response measurements. The tool position measurements preferably indicate the distance between the tool axis and the borehole axis. The tool position measurements are preferably examined to determine if the tool was moving while the tool was making measurements. For measurements made while the tool was moving, the measurement time interval is preferably divided into subintervals each having a corresponding tool position. A formation property (such as resistivity) is estimated, and the expected tool response for each tool position is calculated. The expected tool responses are combined to form a model tool response, that is, the tool response that might be expected for a tool in motion. The model tool response is then compared to the measured tool response. The estimate of the formation property is adjusted and the process is repeated until the model tool response is substantially equal to the measured tool response.

Formation resistivity measurement method that eliminates effects of lateral tool motion

A reel assembly having three reels disposed side-by-side on a shaft pays out coiled tubing to an injector. A conveyor is used to support and guide the coiled tubing during travel from the reels to the injector. The conveyor is selectively rotatable such that the conveyor may be directed to the reel which actively pays out the coiled tubing. In another embodiment, two reels are slidably disposed side-by-side on a shaft. A conveyor is used to support and guide the coiled tubing during travel from the reels to the injector. In this embodiment, the conveyor is directed to a specific location on the shaft and the reels are slid into the specific location for coiled tubing payout.

Method and apparatus for a multi-string composite coiled tubing system

A wireline, coiled tubing, and measurement while drilling resistivity tool having three or more receivers is disclosed. This results in a tool capable of gathering substantial resistivity data about a subterranean formation while being drawn quickly past a borehole wall. One embodiment of this resistivity tool includes four receivers and a pair of transmitters, resulting in six resistivity measurements from each firing of a transmitter. The transmitters are arranged to obtain a regularly spaced series of resistivity measurements. The transmitters may be fired at two or more frequencies to result in further information about the formation. Another embodiment of this resistivity tool places its transmitters and receivers to obtain a number of redundant resistivity readings, resulting in error checking and increased reliability. For enhanced performance, transceivers may also be used. An analogous method is also disclosed.

Growing community of inventors

Houston, TX, United States of America

Martin Dale Paulk