Abstract: Milling systems, tools, and methods include using a mill with secondary attrition system to re-mill cuttings and other debris away from the face of the mill. The secondary attrition system may be located uphole of the mill may be used to stage conditioning and re-sizing of debris. After debris is generated by the mill, the secondary attrition system may re-mill the debris to a finer size before allowing the debris to pass out of the sleeve. The debris may be re-milled by secondary cutting elements while within an annular gap positioned radially between the sleeve and a drive shaft for the mill. The annular gap may have a variable width as a result of a tapered outer surface of the drive shaft and/or a tapered inner surface of the sleeve. The variable width may cause debris to be re-milled into increasingly finer sizes.

Abstract: Systems and methods are provided for estimating the tool center position of a downhole tool, the geometry of the borehole, and/or a mud parameter based on sensor measurements from the downhole tool, even when the downhole tool center is moving over time. At least one sensor may obtain a set of measurements that relates to distance-to-borehole in a borehole at a number of azimuths. A processor may estimate a set of values defining borehole boundary and a set of positions of a center of the downhole tool in the borehole, at least in part by estimating the borehole boundary based on the set of measurements assuming a previously estimated position of the center of the downhole tool is true and estimating the position of the center of the downhole tool based on the set of measurements assuming a previously estimated borehole boundary is true, and iterating at least until convergence.

Abstract: A method of producing fluids from a reservoir includes isolating a vertical section of a wellbore from a horizontal section; isolating a production tubing from the reservoir; pumping fluid from the reservoir adjacent a toe segment into a production tubing toe segment and towards the heel segment; and pumping fluid from the reservoir adjacent a heel segment into the production tubing heel segment and towards the vertical section, and pumping fluid up the vertical section to the surface.

Abstract: A drilling rig apparatus is disclosed for mitigating stick-slip using a saver sub that is compatible with different top drives. The saver sub includes a smart material adjustable whenever a stand is added to the drill string to have different spring characteristics to generally match the impedance of the top drive to the impedance of the drill string. The saver sub also includes a magneto rheological fluid that is adjusted whenever a stand is added to the drill string to compensate for the changed characteristics of the drill string. The damping constant implemented by the MR fluid enables the saver sub to absorb stick-slip vibrations at the top drive. Each time that a stand is connected to the drill string, the spring and damping constants may be updated to accommodate the changing characteristics of the drill string.

Abstract: A flow diverter is provided having a first sub member, a second sub member, a third sub member connected in series and a piston, a spring, and a sleeve member. The sleeve member is removeably disposed within the second sub member. The spring concentrically surrounds at least a portion of the piston and the spring are slidably disposed within the first sub member with the piston further slidably disposed within the second sub member and at least a portion of the third sub member. A drilling fluid having a first predetermined pressure passes through the flow diverter. The drilling fluid having a second predetermined pressure moves the piston until at least a portion of the drilling fluid passes through bypass ports formed in the piston, sleeve member, and second sub member and out of the flow diverter, thus controlling the pressure of the drilling fluid.

Abstract: Apparatus and methods for estimating an azimuth of at least part of a bottomhole assembly (BHA) in a borehole intersecting an earth formation, the BHA comprising magnetic material. Methods include conveying the BHA into the borehole; using a first sensor disposed on the BHA to produce a first measurement of a component of a magnetic field at a first borehole depth; estimating the axial component at the first borehole depth in dependence upon the first measurement; estimating an azimuth of at least a part of the BHA at the first borehole depth using the axial component; and controlling drilling operations with the BHA in dependence upon the azimuth. The magnetic field includes an axial component and a plurality of non-axial components unaligned with the axial component. The magnetic field is affected by the magnetic material and the first measurement is representative of at least one non-axial component of the plurality.

Abstract: A method of model-based acoustic measurements for a wellbore comprises creating an interpretation chart of acoustic measurements by a downhole tool in a wellbore using a numerical modeling and performing an evaluation with respect to the wellbore based on the interpretation chart.

Abstract: A carrier for at least one shaped charge, the carrier being disposable in use within an oil, gas, water or steam well bore. The carrier comprises a housing at least partially formed from a composite material which is non-frangible in normal use. The composite material component of the housing is arranged substantially to contain debris created within the carrier as a result of firing of the at least one shaped charge. The housing may be entirely of composite material or may comprise in inner metallic housing and an outer overwrap of composite material.

Abstract: Centralized control of a cement head using a pumping unit control device is provided. The control device, located at the pumping unit, is communicably coupled to the cement head and pumping unit via a wired or wireless link. Using the control device, the pumping unit operator sends control signals to the pumping unit and cement head to control the cementing operation from outside the red zone, thereby removing the need for a rig hand to operate the cement head.

Abstract: A method of controlling bottom hole pressure in a wellbore, including pumping drilling mud into the wellbore, estimating the annular friction pressure in the wellbore, and measuring the pressure of the drilling mud exiting the wellbore. The method includes measuring the flow rate of the drilling mud exiting the wellbore, and, based on the pressure of the drilling mud exiting the wellbore, the flow rate of the drilling mud exiting the wellbore, expected annular friction pressure in the wellbore, and rotational speed of drill string in the wellbore, controlling the flow rate of drilling mud exiting the wellbore to achieve a specified bottom hole pressure.

Abstract: Embodiments described herein relate to injecting steam into a wellbore using a device. The device includes a body having a bore configured to communicate steam through the body. The device also includes a sleeve movable in the bore of the body between a first position and a second position, wherein the sleeve in the first position blocks steam from exiting an opening of the body and the sleeve in the second position allows steam to exit the opening of the body. The device can be activated by an activation device conveyed down a tubing string and can include a seat on which the activation device. The seat is expandable to allow the activation device to pass.

Abstract: A technique facilitates monitoring of a multiphase fluid flow. The fluid flow is directed through a choke valve comprising a choke actuation system which controls a flow rate of the fluid passing through the choke valve. The choke valve also comprises a velocity reduction area which is created by a choke gallery. The choke gallery reduces the velocity of the fluid flow to encourage separation of phases of the multiphase fluid. A sensor is positioned along the gallery at a desired region to monitor a property of at least one separated phase of the multiphase fluid. For example, the sensor may be positioned proximate a bottom of the choke gallery to monitor a property related to a water phase which separates and transitions to the bottom due to its greater density.

Abstract: A flow system for use at a hydraulic fracturing well site, including a tree attached to a wellhead, an inlet head in fluid communication with at least one hydraulic fracturing pump at the well site, and an adjustable fluid conduit providing fluid communication between the inlet head and the tree. The flow system further includes a valve in the fluid conduit and having an open position and a closed position, the valve permitting fluid flow through the fluid conduit when in the open position, and preventing fluid flow through the fluid conduit when in the closed position, at least a portion of the fluid conduit positioned between the valve and the tree.

Abstract: A method and system are provided for exploration, production and development of hydrocarbons. The method involves analyzing a sample for a geochemical signature, which includes a multiply substituted isotopologue signature and/or a position specific isotope signature. Then, historical temperatures are determined based on the signature. The historical temperature is used to define seal timing, trap timing, migration efficiency and/or charge efficiency, which is used to develop or refine an exploration, development, or production strategy.

Abstract: Methods and control systems for optimizing production of a hydrocarbon well with a local controller in communication with a supervisory control and data acquisition (SCADA) system are disclosed. The presently disclosed methods may include calculating, at the local controller, optimal targets for one or more well parameters using measured values associated with operation of the hydrocarbon well; obtaining, at the local controller, a model that comprises a relationship between an operation of a gas injection choke and an operation of a production choke with the one or more well parameters based on the measurement values and received model parameters from the SCADA system; determining, at the local controller, operating set points based on the model for control of at least one of the production choke and the gas injection choke; and operating at least one of the production choke and the gas injection choke for optimized production.

Abstract: A pumping system is provided. The pumping system includes an output conduit, a first sensor, a second second sensor, a feedforward active controller, and a fluid flow normalizer (FFN). The output conduit is associated with an output of a positive displacement pump. The first sensor is configured to measure a fluid flow characteristic (FFC) within the output conduit. The second sensor is configured to measure a phase of the positive displacement pump. The feedforward active controller is configured to receive information related to the FFC, receive information related to the phase of the positive displacement pump, and determine an FFC variability value. The first fluid flow normalizer (FFN) is configured to at least one of add fluid to the output of the positive displacement pump and remove fluid from the output of the positive displacement pump in response to a signal from the feedforward active controller.

Abstract: A casing wear estimation method includes obtaining a set of input parameters associated with extending a partially-cased borehole and applying the set of input parameters to a physics-driven model to obtain an estimated casing wear log. The method also includes employing a data-driven model to produce a predicted casing wear log based at least in part on the estimated casing wear log. The method also includes storing or displaying information based on the predicted casing wear log.

Abstract: A system includes a drillstring with an electromagnetic (EM) transmitter in a first borehole. The system also includes at least one fiber optic sensor deployed in a second borehole. The system also includes a processor configured to demodulate a data stream emitted by the EM transmitter based on EM field measurements collected by the at least one fiber optic sensor.

Abstract: A tong and method, in which the tong includes a first plate, and a gear that is rotatable relative to the first plate. The gear defines a slot laterally therethrough. An inner surface of the gear includes at least three cam surface. The tong also includes at least three jaws coupled to the first plate such that the at least three jaws are radially movable with respect to the first plate and are prevented from circumferential movement with respect thereto. The at least three jaws are engageable with the at least three cam surfaces such that rotation of the gear relative to the first plate causes the at least three jaws to move in a radial direction between an extended position and a retracted position.

Abstract: A packing element and a sealing element is disclosed. The packing element includes a sealing element positioned on an outer surface of a mandrel deployed in the wellbore, where the sealing element is disposed in an annulus between the mandrel and a portion of the wellbore. The sealing element includes a first cavity on an inner surface of the sealing element, where the first cavity has a first size and is positioned proximate a first end of the sealing element. The sealing element also includes a second cavity on the inner surface of the sealing element, where the second cavity has a second size that is different from the first size, and is positioned proximate a second end of the sealing element. The packing element also includes a first and second gauge rings positioned at first and second ends of the sealing element, respectively.