Halliburton Energy Services, Inc.

Landmark Graphics Corporation

Christopher Neil Marland

Robello Samuel

James Randolph Lovorn

Ian Bradford Mitchell

Jeremy Alexander Greenwood

John Wilkes

Aravind Prabhakar

Mark Anthony Sitka

Amit Kumar Singh

Ram Naresh Adari

Olivier Roger Germain

Systems and methods for predicting drilling tool failure based on an analysis of at least one of a plot of jerk and inverse jerk for the drilling tool and a plot of drilling tool failure pattern trends data.

Predicting drilling tool failure

Various systems and methods are disclosed for making and using an anonymized database for an industrial enterprise, such as oilfield operations. Providing statistical performance indicators for groupings of an activity in the oilfield allow for the information in confidential data sets to be shared without compromising the confidentiality of any one data entry. Comparisons may be made between or among oilfields with differing technologies, differing rig configurations, or even different crews when sufficient data are available.

Systems and methods for anonymizing and interpreting industrial activities as applied to drilling rigs

A system, drilling assembly, and method to control adjustable pads for use in downhole directional drilling. The drilling assembly comprises a bent housing comprising an upper section, a lower section, a bend between the upper and lower sections, and a bore extending from the upper to lower sections. The drilling assembly also comprises a drill bit coupled to a lower end of the bent housing and a fluid-driven motor coupled to the bent housing and comprising a drive shaft coupled to the drill bit. The drilling assembly also employs an adjustable pad extendable and retractable from an exterior of the bent housing to engage and disengage the wellbore wall to adjust a drilling direction of the drill bit, and a fluid control system operable to control extension of the pad.

System and method to control adjustable pads for use in downhole directional drilling assemblies

The present disclosure describes measuring bending moments within a drillstring or tool string to identify deflections (or 'dog-legs') within the string. In some systems, the bending moments a plurality of strain gauges. In some such systems the strain gauges will be arranged in a selected spacing around the circumference of the tool string, in many examples, at a common plane extending generally perpendicular to the longitudinal axis of the string proximate the strain gauges. The bending moments may be further evaluated to provide a measure of wellbore tortuosity. For example, the bending moments may be utilized to define a radius of curvature associated with the determined bending moments, which may be further correlated with a directional measurement to apply a direction to the bending moment, and therefore to the tortuosity an any given location. In many examples, the above measurements and determinations will be performed in essentially real time during a drilling operation; and will in some cases be used to perform remedial measures, where dictated.

Methods and apparatus for monitoring wellbore tortuosity

An apparatus and method for alleviating spiraling in boreholes is disclosed. The apparatus includes a sub, which adjusts the length of the bottom-hole assembly in response to tension/compression, flexural bending and/or torque measurements made above and below the reamer so that the drill bit and the reamer cut at the same depth rate. The sub is connected between the drill bit and the reamer. The apparatus further includes measurement devices disposed on the bottom-hole assembly above and below the reamer, which are capable of measuring the tension/compression, flexural bending and torque in the bottom-hole assembly. The method includes use of a data processor, which determines which operational output signals to supply to the sub in order to adjust its length and thereby accomplish the desired drilling rates.

Apparatus and method of alleviating spiraling in boreholes

A method of operating a drill string comprises independently modifying a rotary speed of a downhole portion of the drill string relative to other downhole portions of the drill string, each of the portions comprising a plurality of drill pipe sections. The modified-speed portion of the drill string can comprise a downhole end portion of the drill string extending between a downhole drill string end and a curved portion of the borehole in which the drill string is located. The downhole end portion can be rotated at an increased speed relative to a portion of the drill string coincident with the curved portion of the borehole. Independent speed modification can be effected by incorporating one or more transmission modifier devices in the drill string, the transmission modifier device being switchable between a disengaged mode in which it transfers unmodified drill string torque and rotation, and an engaged mode in which it transmits torque and rotation along the drill string at a modified speed and torque. Selective switching of the transmission modifier devices, while downhole, maybe controlled from the surface.

Independent modification of drill string portion rotational speed

A method of performing a drilling operation with a drill bit through a formation. The method including defining optimal settings of drilling parameters for cleaning of a wellbore formed by the drill bit, displaying a graphical indication of the optimal settings of the drilling parameters, determining a maximum rate of penetration of the drill bit based on the optimal settings, displaying, an optimal boundary depicting the maximum rate of penetration, wherein the optimal boundary graphically matches the graphical indication of the optimal settings, displaying, on the visualization tool, an actual boundary depicting an actual rate of penetration of the drill bit, sending a signal to adjust the actual rate of penetration to match the maximum rate of penetration, receiving the signal downhole at a bottom hole assembly, and adjusting the actual rate of penetration of the drill bit using the bottom hole assembly based on the signal.

Visualization of wellbore cleaning performance

A fluid monitoring system comprises a data acquisition and control interface and one or more fluid measurement devices communicatively coupled to the data acquisition and control interface. The one or more fluid measurement devices are configured to detect amounts of fluids pumped into or exiting the well bore during cementing. The data acquisition and control interface receives a first set of data comprising calculated volumes and/or pressures of a flow of one or more fluids exiting a model well bore over a predetermined period of time based in part on a heat of reaction produced by the curing of a cement composition, and a second set of data comprising volumes and/or pressures of a flow of one or more fluids pumped into or exiting the well bore from the one or more fluid measurement devices. The data acquisition and control interface uses the first and second sets of data received to determine one or more characteristics of the cement composition.

Systems and methods for monitoring and validating cementing operations using connection flow monitor (CFM) systems

A method for displaying performance of a wellbore drilling operation including wellbore cleaning includes defining drilling parameters for the drilling operation. The method includes defining a visualization tool including a boundary defined by the drilling parameters, where the boundary depicts an optimal rate of penetration (ROP). The method includes displaying the visualization tool with the optimal ROP, where the optimal ROP defines a maximum ROP for optimal wellbore cleaning based on the drilling parameters. The method includes displaying an actual rate of penetration (ROP) with respect to the optimal ROP on the visualization tool. The method further includes adjusting the actual ROP to match the optimal ROP.

Systems and methods for monitoring and characterizing fluids in a subterranean formation are provided. In one embodiment, a method for monitoring fluids in a well bore penetrating a subterranean formation is provided, the method comprising: determining an actual buoyed hookload of an apparatus at least partially disposed in the well bore wherein a first set of fluids are present therein; comparing the actual buoyed hookload to a calculated buoyed hookload of the apparatus, wherein the calculated buoyed hookload is based in part on the unbuoyed hookload of the apparatus, and the properties of a second set of fluids that are assumed to be present in the well bore; and determining at least one property of the first set of fluids based in part on the comparison of the actual buoyed hookload to the calculated buoyed hookload.

Growing community of inventors

Spring, TX, United States of America

Christopher Neil Marland