Halliburton Energy Services, Inc.

M-i Drilling Fluids Canada, Inc.

Ykk Corporation

Mukesh Kapila

Neale Browne

Perry Lomond

Paul Gover

Paul Newman

Rahul Dixit

Zoran Markanovic

Ivan Batinic

Jarrod Massam

Katerina V Newman

Rajesh C Kapila

Moray Lamond Laing

Glynda A Addicks

Casey Timothy Lesar

Bharat Arora

Glenn Antle

Robert Hood

Arthur Martin

Yanling Wu

Kathleen Mary Hall

A method includes receiving an image that includes a wellbore component used during a wellbore operation of a borehole at a wellsite captured by a camera at the wellsite and inputting the image into an image recognition model. The method includes outputting, from the image recognition model, a class representing the wellbore component and inputting the class into a context model. The method includes outputting, from the context model, contextual data related to the wellbore component based on, the class representing the wellbore component, contextual data relating to the wellbore operation, and a type of the wellbore operation. The method includes transmitting the contextual data to a wearable device worn by a user at the wellsite.

Contextual information displayable on wearable devices based on images captured during wellsite operations

A method may include: heating a drilling waste comprising water, oil, and solid particulate; vaporizing at least a portion of the water and oil from the drilling waste to form a vaporized fluid, wherein the step of vaporization is performed at a pressure less than about 101.325 kPa; and condensing the at least a portion of the water and oil to form a recovered fluid emulsion.

Recovered drilling fluid formulation

Methods and systems involving thermal desorption of an oily slurry are provided. In some embodiments, such systems include a desorption vessel including an inner chamber; a heating unit disposed adjacent to the desorption vessel configured to heat a slurry including solids and oil disposed in the inner chamber of the desorption vessel; and a plurality of vapor outlets in fluid communication with the inner chamber of the desorption vessel, wherein each vapor outlet is in fluid communication with a condenser or an eductor for condensing vapors generated by heating the slurry.

Thermal desorption of oily solids

A system for separating solids from fluid including a solid-laden fluid may include a base fluid, a first separator configured to receive the solid-laden fluid and separate the fluid into a solids portion and an effluent, and a membrane separator configured to receive the effluent and separate the effluent into a permeate and a concentrate. A method for separating solids from fluid may include obtaining a solid-laden fluid, wherein the solid-laden fluid comprises a base fluid, feeding the solid-laden fluid through a centrifuge, removing at least a portion of high gravity solids from the solid-laden fluids, flowing the solid-laden fluid through a membrane separator, removing at least a portion of low gravity solids from the solid-laden fluid, and collecting a permeate from the membrane separator.

System and method for separating solids from fluids

A method of mixing drilling fluids, the method including injecting a drilling fluid into a high shear mixing unit and processing the drilling fluid with the high shear mixing unit. The processing includes forcing the drilling fluid through a first row of teeth of a first stage.

Methods and apparatuses for mixing drilling fluids

The present invention relates to a system and a method for the extraction of hydrocarbons from drill cuttings in drilling mud. The system for extracting hydrocarbons from drill cuttings includes at least one extraction tank, a carbon dioxide tank fluidly connected to the at least one extraction tank, and at least one separation tank in fluid communication with the at least one extraction tank. The method for extracting hydrocarbons from drill cuttings consists of exposing the drill cuttings to liquid carbon dioxide, solubilizing hydrocarbons from the drill cuttings with the liquid carbon dioxide, heating the liquid carbon dioxide and the soluble hydrocarbons to convert liquid carbon dioxide to carbon dioxide vapor, separating the hydrocarbons from the carbon dioxide vapor, and collecting the separated hydrocarbons.

Method for hydrocarbon removal and recovery from drill cuttings

A system for treating recovered fluids in-line that includes a thermal reactor for separating contaminated drill cuttings into drill cuttings and contaminants by applying heat to the contaminated drill cuttings so as to vaporize contaminants from the contaminated drill cuttings; a first condenser in fluid connection with the thermal reactor for condensing the vaporized contaminants; a separator in fluid connection with the first condenser for separating the condensed vapors into an oleaginous liquid and an aqueous liquid, wherein at least a portion of one of the aqueous liquid and oleaginous liquid is fed back into the first condenser via a feedback line; and an ozone generator operatively coupled to the feedback line, wherein at least the portion of the fed back liquid is ozonated by the ozone generator and fed into the condenser is disclosed.

In-line treatment of hydrocarbon fluids with ozone

A system for separating solids from fluid including a solid-laden fluid including a base fluid, a first separator configured to receive the solid-laden fluid and separate the fluid into a solids portion and an effluent, and a membrane separator configured to receive the effluent and separate the effluent into a permeate and a concentrate is disclosed. A method for separating solids from fluid including obtaining a solid-laden fluid, wherein the solid-laden fluid comprises a base fluid, feeding the solid-laden fluid through a centrifuge, removing at least a portion of high gravity solids from the solid-laden fluids, flowing the solid-laden fluid through a membrane separator, removing at least a portion of low gravity solids from the solid-laden fluid, and collecting a permeate from the membrane separator is also disclosed.

An apparatus for blending two or more fluid streams, wherein a first fluid has a higher density than the other fluids, includes a first fluid director and at least a second fluid director providing fluid communication of a first and second fluid stream, respectively, to a primary mixing chamber. The first fluid director includes one or more baffles to disturb the first fluid stream and to direct it toward a rearward portion of the first inlet to the primary mixing chamber. A secondary blending chamber is in fluid communication with the primary chamber outlet and includes at least one, and preferably two static mixers. When two static mixers are serially retained in the secondary blending chamber, they may be skewed rotationally relative to each other such that the orifice profiles of each static mixer are not in alignment.

Apparatus and method for homogenizing two or more fluids of different densities

Disclosed herein is a mixing apparatus for mixing solids and liquids comprising a mixing chamber defined within a plurality of sides radially arranged about a central axis, the mixing chamber comprising an eductor, the eductor comprising a first chamber inlet separated along the central axis from a chamber outlet by a frusta conical venturi throat arranged coaxial with a central axis; the eductor further comprising a second chamber inlet disposed through one or more of the plurality of sides and located between the first chamber inlet and the chamber outlet, the second chamber inlet having a plurality of second inlet opening diameters, each determined perpendicular to the central axis at the point at which the second chamber inlet intersects with an outer wall of the venturi throat, wherein the second inlet diameters are each less than the diameter of the venturi throat at each of the points at which the second chamber inlet intersects with the outer wall of the venturi throat. A method of mixing solids with a liquid is also disclosed.

Methodology for improved mixing of a solid-liquid slurry

A blending apparatus for blending a first fluid stream having a first density and a second fluid stream having a second fluid density, the first density being greater than said second density, is discussed. The apparatus includes a first fluid director including a plurality of baffles affixed therein to create turbulence and shear in the first fluid, a cylindrical second fluid director, a primary mixing chamber receiving the first sheared fluid from the first fluid director and receiving the second fluid from the second fluid director, wherein the first fluid and second fluid are mixed in the primary mixing chamber to form a mixed primary fluid stream, and a secondary blending chamber comprising at least one static mixer and coaxially aligned with and receiving the mixed primary fluid stream from the primary mixing chamber.

Apparatus for homogenizing two or more fluids of different densities

A test kit for testing production waste includes a plurality of components including reagents, test equipment, or a combination thereof, sufficient to perform analysis on production waste and at least one protective case for shipping and for using the plurality of components, the protective case including a top portion releasably engaged with a bottom portion. The top portion includes a top side attached at an inner face of the top side to a top edge of a continuous sidewall formed by a plurality of sides such that the top portion of the protective case includes a hollow interior cavity bound by the inner face of the top side and an inner face of the continuous sidewall, wherein the hollow interior cavity is open on a bottom side, and wherein the hollow interior cavity defines a water-tight enclosure opened on the bottom side, such that the top portion, resting on a support surface inverted on an outer face of the top side, is capable of forming a liquid reservoir.

Production waste test kit

An improved thermal phase separation unit separates contaminants from a contaminated substrate. The improved thermal phase separation unit includes an enclosure arranged to withstand temperatures created by a combustion system, an essentially air-tight processing chamber supported within the enclosure by support columns connected between the processing chamber and a bottom of the enclosure, a heat shield disposed between the processing chamber and the bottom of the enclosure, and a vapor handling system arranged to remove vapor from the processing chamber. The combustion system heats the processing chamber, and, in turn, indirectly heats contaminated substrate being processed in the processing chamber so as to volatize contaminants in the contaminated substrate to vapor that is subsequently removed by the vapor handling system.

Method and apparatus for thermal phase separation

An additive that increases the density of fluids used in a wellbore during the construction or repair of oil, gas, injection, water, or geothermal wells comprises In one illustrative embodiment the additive comprises a weighting agent, and more preferably an ultra-fine weighting agent. Another embodiment includes a wellbore fluid containing an ultra-fine weighting agent that has an increased density with improved suspension stability without a significant viscosity increase. The wellbore fluid as described herein has rheological properties comparable to a conventional wellbore fluid. An illustrative embodiment of the claimed subject matter is further directed to a method for making the ultra-fine weighting agent and a method for using such ultra-fine weighting agent in a wellbore fluid. In one preferred embodiment the additive has a particle diameter between 4 &#x3bc;m to 15 &#x3bc;m. In another preferred embodiment, the additive has a Dof approximately 3 &#x3bc;m (1 &#x3bc;m to 6 &#x3bc;m). In another preferred embodiment the additive has a Dof approximately 6 &#x3bc;m (4 &#x3bc;m to 8 &#x3bc;m). The additive may be used in any wellbore fluid such as drilling, cementing, completion, packing, work-over (repairing), stimulation, well killing, and spacer fluid, as well as in a dense media separating fluid or in a ship's or other vehicle's ballast fluid.

Growing community of inventors

The Woodlands, TX, United States of America

Mukesh Kapila