The present disclosure provides a low temperature resistant oil casing having high strength and high toughness, and the manufacturing method thereof, the chemical composition of the oil casing by mass of: C: 0.08-0.14%, Si: 0.1-0.4%, Mn: 0.6-1.3%, Cr: 0.5-1.5%, Mo: 0.2-0.5%, Ni: 0.2-0.5%, Nb: 0.02-0.05%, V: 0-0.1%, Al: 0.01-0.05%, Ca: 0.0005-0.005%, and the balance being Fe and unavoidable impurities. The method of manufacturing the oil casing includes: (1) smelting and continuous casting; (2) perforating and continuous rolling; (3) heat treatment, wherein an austenitizing temperature is controlled in the range of 900-930° C., and held for 30-60 min, followed by quenching, subsequently, tempering at temperature of 480-600° C., holding the temperature for 50-80 min; (4) hot sizing.

A logging system and method for operating a logging system are typically used in a wellbore. The logging system may include a logging instrument including a rechargeable energy storage and logging electronics, and a cable configured to trickle charge the rechargeable energy storage. The rechargeable energy storage may include an ultracapacitor. The rechargeable energy storage may be trickle charged through the cable from a remote power source.

A method for joining metallic well tubulars to be lowered into a wellbore (4) comprises the steps of: a) providing a first well tubular (6) having an upper end surface (6a), and a second well tubular (7) having a lower end surface (7a); b) lowering the first well tubular (6) into the wellbore (4), leaving the upper end thereof outside the wellbore (4); c) setting the second well tubular (7) in an axially aligned position on the first well tubular (6), with the lower end surface (7a) of the second well tubular (7) set against the upper end surface (6a) of the first well tubular (6); d) keeping the first and second well tubulars (6, 7) in said axially aligned position; e) welding the upper end of the first well tubular (6) to the lower end of the second well tubular (7), forming a circumferential weld bead (WL) in a position corresponding to said upper and lower end surfaces (6a, 7a); and f) lowering into the wellbore (4) the first well tubular (6) and the second well tubular (7) welded together. Step e) comprises the operations of: providing at least one laser welding head (13), configured for directing a laser beam (LB) towards a circumferential working zone (WA) that includes an upper end portion of the first well tubular (6) and a lower end portion of the second well tubular (7), the at least one laser welding head (13) being displaceable around the circumferential working zone (WA) according to a respective trajectory of revolution; providing at least one induction-heating device (141, 142), which is displaceable substantially according to the trajectory of revolution of the at least one laser welding head (13), the at least one induction-heating device (141, 142) being set upstream, respectively downstream, of the at least one laser welding head (13), with reference to the direction of revolution (R) of the at least one laser welding head (13); causing revolution of the at least one laser welding head (13) and revolution of the at least one induction-heating device (141, 142), in such a way that: the laser beam (LB) progressively forms the circumferential weld bead (WL); and the at least one induction-heating device (141, 142) supplies heat to a corresponding part (PH1, PH2) of the circumferential working zone (WA), which comprises respective parts of said upper and lower end portions of the respective first and second well tubulars (6, 7), before the laser

A method for joining metallic well tubulars to be lowered into a wellbore (4) comprises the steps of: a) providing a first well tubular (6) having an upper end surface (6a), and a second well tubular (7) having a lower end surface (7a); b) lowering the first well tubular (6) into the wellbore (4), leaving the upper end thereof outside the wellbore (4); c) setting the second well tubular (7) in an axially aligned position on the first well tubular (6), with the lower end surface (7a) of the second well tubular (7) set against the upper end surface (6a) of the first well tubular (6); d) keeping the first and second well tubulars (6, 7) in said axially aligned position; e) welding the upper end of the first well tubular (6) to the lower end of the second well tubular (7), forming a circumferential weld bead (WL) in a position corresponding to said upper and lower end surfaces (6a, 7a); and f) lowering into the wellbore (4) the first well tubular (6) and the second well tubular (7) welded together. Step e) comprises the operations of: providing at least one laser welding head (13), configured for directing a laser beam (LB) towards a circumferential working zone (WA) that includes an upper end portion of the first well tubular (6) and a lower end portion of the second well tubular (7), the at least one laser welding head (13) being displaceable around the circumferential working zone (WA) according to a respective trajectory of revolution; providing at least one induction-heating device (141, 142), which is displaceable substantially according to the trajectory of revolution of the at least one laser welding head (13), the at least one induction-heating device (141, 142) being set upstream, respectively downstream, of the at least one laser welding head (13), with reference to the direction of revolution (R) of the at least one laser welding head (13); causing revolution of the at least one laser welding head (13) and revolution of the at least one induction-heating device (141, 142), in such a way that: the laser beam (LB) progressively forms the circumferential weld bead (WL); and the at least one induction-heating device (141, 142) supplies heat to a corresponding part (PH1, PH2) of the circumferential working zone (WA), which comprises respective parts of said upper and lower end portions of the respective first and second well tubulars (6, 7), before the laser

A unitary junction for deployment in a wellbore, wherein the unitary junction permits electrical power and communications signals to be established in both a lateral wellbore and a main wellbore utilizing. The unitary junction assembly generally includes a conduit having a first upper aperture, a first lower aperture and a second lower aperture where the first lower aperture is defined at the distal end of a primary leg extending from a conduit junction and the second lower aperture is defined at the distal end of a deformable lateral leg extending from the conduit junction. A lower wireless energy transfer mechanism is positioned along at least one of the legs between the distal end of the leg and the junction. The lower wireless energy transfer mechanism is in wired communication an upper energy transfer mechanism permitting electrical communication to be established across the intersection of wellbore branches utilizing the unitary junction.

An automated pipe tripping apparatus includes an outer frame and an inner frame. The inner frame includes a tripping slips and iron roughneck. The automated pipe tripping apparatus may, in concert with an elevator and drawworks, trip in a tubular string in a continuous motion. The tripping slips and iron roughneck, along with the inner frame, may travel vertically within the outer frame. The weight of the tubular string is transferred between the tripping slips and the elevator. The iron roughneck may make up or break out threaded connections between tubular segments, the upper tubular segment supported by the elevator and the lower by the tripping slips. An automated pipe handling apparatus may remove or supply sections of pipe from or to the elevator. A control system may control both the automated pipe tripping apparatus and the elevator and drawworks.

An automated pipe tripping apparatus includes an outer frame and an inner frame. The inner frame includes a tripping slips and iron roughneck. The automated pipe tripping apparatus may, in concert with an elevator and drawworks, trip in a tubular string in a continuous motion. The tripping slips and iron roughneck, along with the inner frame, may travel vertically within the outer frame. The weight of the tubular string is transferred between the tripping slips and the elevator. The iron roughneck may make up or break out threaded connections between tubular segments, the upper tubular segment supported by the elevator and the lower by the tripping slips. An automated pipe handling apparatus may remove or supply sections of pipe from or to the elevator. A control system may control both the automated pipe tripping apparatus and the elevator and drawworks.

A logging system for a tubular includes: a rail system comprising a plurality of rails and mounted to a surface of the tubular; a logging tool carrier connected to the rail system; and a logging tool disposed on the logging tool carrier. The logging tool is deployed on the logging tool carrier connected to the rail system along the tubular to a targeted position along the tubular and then retrieved from the wellbore. During deployment of the logging tool, the logging tool acquires a plurality of logging data.

An electric submersible pump (ESP) power cable. The ESP power cable has a first plurality of electric conductors encased in a first protective armor wherein a first void area is defined between the first plurality of electric conductors and the first protective armor, has a second plurality of electric conductors encased in a second protective armor wherein a second void area is defined between the second plurality of electric conductors and the second protective armor and wherein each one of the second plurality of electric conductors is spliced to a corresponding one of the first plurality of electric conductors, has a first filler positioned at least partially in the first void area, and comprises a second filler positioned at least partially in the second void area.

An improved cable guard and methods of use are provided for securing an MLE cable to an ESP system in a wellbore casing, the system having flange bolts and an annular channel. The cable guard may be unitary (i.e., one piece), comprising a body having a bridge portion and two side portions forming a cavity for securing the cable to the system, two connectors extending from the side portions, each connector forming at least one aperture for receiving a flange bolt, and skids extending from the side portions for guiding movement of the system within the casing. In some embodiments, methods of using the improved cable guard may comprise providing the cable guard, positioning the cable guard to receive the cable within the cavity and to receive at least one flange bolt within an aperture, and securing the cable guard to the system.