An apparatus for evaluating an obstruction in a conduit of a tubular includes a first cylindrical rod connected to a deployment device configured to deploy the first cylindrical rod into the conduit of the tubular; a second cylindrical rod connected to the first cylindrical rod; an outer sleeve movable between a first position and a second position; and an impression block connected to the second cylindrical rod. The impression block is configured to obtain an impression of the obstruction. The second cylindrical rod has a diameter larger than a diameter of the first cylindrical rod, when the outer sleeve is concentrically disposed around the second cylindrical rod in the first position and concentrically disposed around the first cylindrical rod after an interaction between the outer sleeve and the obstruction. The outer sleeve includes a plurality of panels connected to one another by a plurality of stretchable elements.

An apparatus for evaluating an obstruction in a conduit of a tubular includes a first cylindrical rod connected to a deployment device configured to deploy the first cylindrical rod into the conduit of the tubular; a second cylindrical rod connected to the first cylindrical rod; an outer sleeve movable between a first position and a second position; and an impression block connected to the second cylindrical rod. The impression block is configured to obtain an impression of the obstruction. The second cylindrical rod has a diameter larger than a diameter of the first cylindrical rod, when the outer sleeve is concentrically disposed around the second cylindrical rod in the first position and concentrically disposed around the first cylindrical rod after an interaction between the outer sleeve and the obstruction. The outer sleeve includes a plurality of panels connected to one another by a plurality of stretchable elements.

Technologies for facilitating the placement of lateral liners from a main casing. A first technology is directed to a system for orienting placement of a lateral wellbore from a main wellbore comprising: a whipstock and a tubular structure installable in a wellbore casing, the tubular structure including a pocket on its inner diameter configured to receive a key of the whipstock and a first orientation indicator with a characteristic capable of being logged by a logging tool to determine a circumferential location of the orientation indicator within the tubular structure. Another technology is directed to a device for positioning a lateral liner in a lateral wellbore. The device includes: a lateral liner biasing member configured to be positioned between the lateral liner and the lateral wellbore and configured to urge the lateral liner away from one side of the lateral wellbore.

Technologies for facilitating the placement of lateral liners from a main casing. A first technology is directed to a system for orienting placement of a lateral wellbore from a main wellbore comprising: a whipstock and a tubular structure installable in a wellbore casing, the tubular structure including a pocket on its inner diameter configured to receive a key of the whipstock and a first orientation indicator with a characteristic capable of being logged by a logging tool to determine a circumferential location of the orientation indicator within the tubular structure. Another technology is directed to a device for positioning a lateral liner in a lateral wellbore. The device includes: a lateral liner biasing member configured to be positioned between the lateral liner and the lateral wellbore and configured to urge the lateral liner away from one side of the lateral wellbore.

A polystyrene copolymer blend product achieving an optimal combination of haze/clarity, strength, toughness/snap, and organoleptic properties is provided. The polystyrene copolymer blend product includes a first layer forming about 2 to about 6 weight percent of the total weight percent of the product. The first layer includes from about 95 to about 100 weight percent of GPPS or HIPS, based on the weight of the layer. The polystyrene copolymer blend product includes a second (and optional third and fourth) layer(s) that firm about 98 to about 94 weight percent of the product. The second (and optional third and fourth) layer(s) include about 23 to about 43 weight percent of GPPS, from either about 35 to about 70 weight percent, such as from about 50 to about 65 weight percent of SBC, and from about 0 to about 17 weight percent of HIPS, based on the weight of the respective layer.

A wellhead impression tool includes an elongate central body having opposing upper and lower ends, and defining an inner chamber, an impression sleeve arranged concentric with the central body and made of a malleable material, and a hydraulic assembly extending between the impression sleeve and the central body and in fluid communication with the inner chamber to receive a hydraulic fluid from the inner chamber. The hydraulic assembly is operable to force the impression sleeve radially outward and into engagement with a bowl of a wellhead spool of a wellhead assembly, and forcing the impression sleeve against the bowl results in a physical impression of the bowl on an outer surface of the impression sleeve.

A wellhead impression tool includes an elongate central body having opposing upper and lower ends, and defining an inner chamber, an impression sleeve arranged concentric with the central body and made of a malleable material, and a hydraulic assembly extending between the impression sleeve and the central body and in fluid communication with the inner chamber to receive a hydraulic fluid from the inner chamber. The hydraulic assembly is operable to force the impression sleeve radially outward and into engagement with a bowl of a wellhead spool of a wellhead assembly, and forcing the impression sleeve against the bowl results in a physical impression of the bowl on an outer surface of the impression sleeve.

A method is for testing the pressure integrity of a barrier in an annulus outside a pipe string in a wellbore, the method including the steps of: establishing a fluid connection between an inside of the pipe string and an annulus out-side the pipe string at a first position and second positions in the wellbore, the second position being offset from the first position along the axial direction of the wellbore; establishing a temporary barrier between the fluid connections at the first and second positions in the wellbore; establishing a pressure differential across the temporary barrier; releasing a tracer from below the temporary barrier; and sniffing for tracer above the temporary barrier to verify a leakage through the temporary barrier and/or the barrier in the annulus. There is also disclosed a tool for executing such a method.

A method is for testing the pressure integrity of a barrier in an annulus outside a pipe string in a wellbore, the method including the steps of: establishing a fluid connection between an inside of the pipe string and an annulus out-side the pipe string at a first position and second positions in the wellbore, the second position being offset from the first position along the axial direction of the wellbore; establishing a temporary barrier between the fluid connections at the first and second positions in the wellbore; establishing a pressure differential across the temporary barrier; releasing a tracer from below the temporary barrier; and sniffing for tracer above the temporary barrier to verify a leakage through the temporary barrier and/or the barrier in the annulus. There is also disclosed a tool for executing such a method.

An intervention tool is provided having one or more packing elements; said device being moveable between a first position in which the device is positively locatable within a profile, and a second position wherein the device is settable in a blank casing that lacks a profile, wherein movement between the first position and the second position is controlled by axial movement of the intervention tool. A device is further provided for positively locating within a profile, wherein said device comprises one or more locator mechanisms; one or more slips; one or more packing elements; and a stopping mechanism; wherein said one or more locator mechanisms are locatable within said profile and wherein said stopping mechanism prevents engagement of said one or more slips and said one or more packing elements unit said one or more locator mechanisms are located in the profile. A method is provided for applying downhole isolation, said method comprising the steps of running an intervention tool downhole, said intervention tool comprising one or more packing elements; locating one or more locating mechanisms on the device into one or more profiles by shifting said device axially; engaging the one or more packing elements by shifting said device axially after the locating mechanisms are located within the profiles; disengaging said one or more packing elements by shifting said device axially; and moving said device to another downhole location.