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Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Dietmar J Neidhardt

Cesar Pena

Kevin J Nikiforuk

Sidney Johnson Morrison, Jr

Georg Hiller, Jr

A system including a display for displaying a comparison between a calculated energy value and a desired energy value of a drilling system, the display including a first portion defining a first potential operational issue, a second portion defining a second potential operational issue, a third portion defining a third potential operational issue, and a fourth portion indicating the comparison between the calculated energy value compared and the desired energy value of the drilling system.

Interface for controlling and improving drilling operations

A drilling rig having a top drive has a pipe gripper with a mandrel having an upper end for connection to and rotation with a drive string extending downward from the top drive. The pipe gripper has gripping elements that move radially into engagement with a string of pipe. A pull-down mechanism is mounted to the rig and secured to a non-rotating portion of the pipe gripper for exerting a downward force on the mandrel. A sensor is operatively coupled to the top drive to sense weight being supported by the top drive. A controller is linked to the sensor and the pull-down mechanism for controlling the downward force exerted on the mandrel by the pull-down mechanism in response to the weight sensed by the sensor.

Pull-down method and equipment for installing well casing

Embodiments include drilling through a formation using a drill bit conveyed by a tubular string having an outer diameter at least 70 percent of the wellbore being drilled. The formation is drilled at a first rate of penetration (ROP) while pumping drilling fluid at a first flow rate. After drilling through the formation, the ROP is reduced to a second ROP, the flow rate is reduced to a second flow rate, and pressure is increased in the wellbore until drilling fluid begins to leak into the formation. While maintaining the increased pressure in the wellbore, the volume of drilling fluid lost to the formation is monitored until the rate at which the drilling fluid loss occurs is reduced. Components of this procedure are repeated until a selected wellbore strength is achieved.

Method and apparatus for strengthening a wellbore

The centrifuge continuously separates free flowing substances that have different densities. The centrifuge includes a rotor,having a cylindrical drum,and a conical drum,. The rotor wall includes discharge ports,&Prime; for a heavy phase and weirs,for a light phase arranged on a front end wall,of the cylindrical drum. The rotatable scroll conveyor,includes a hollow shaft,and a helix,for transporting the heavy phase toward the discharge ports. A feed pipe,is coaxially within the hollow shaft and opens into a chamber,within the hollow shaft. A plurality of nozzles each within a respective discharge port in the conical drum and a non-restrictive discharge port,in the end section of the conical drum discharge the heavy phase from the centrifuge. The nozzles are preferably arranged in a plurality of circumferential rings.

Helix centrifuge with removable heavy phase discharge nozzles

Methods and apparatus are provided for the uninterrupted transfer of oil and gas well drill cuttings from a collection point, such as a shale shaker trough, to several types of variously configured on rig and off rig receptacles. Two or more hoppers are arranged for alternating receipt and discharge of cuttings, the cuttings being continuously drawn to the hoppers by a suction force from an upstream blower. The receptacles utilized in the various embodiments are varied, such as barges, box containers, and slurry units. The hoppers are, in some embodiments, moved to remote locations, such as off rig barges, prior to beginning the cuttings transfer.

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The Woodlands, TX, United States of America

Dietmar J Neidhardt