Abstract: A clamp system for hot-tapping tubulars includes a saddle having a saddle body with an inner surface, an outer surface, and an opening extending from the inner surface to the outer surface, a metal protrusion extending from the inner surface of the saddle body to provide a metal seal, an elastomer seal coupled to the inner surface of the saddle body adjacent to the metal protrusion, and a nipple integrally formed with the saddle body and extending outwardly from the outer surface of the saddle body, the nipple positioned over the opening of the saddle body, and a clamp having a nipple opening configured to receive the nipple, the clamp formed separately from the saddle. A method includes positioning the saddle on a tubular and assembling the clamp around the saddle and the tubular including inserting the nipple through the nipple opening formed in the clamp.

Abstract: A tieback assembly for insertion into a wellbore may include a tieback stem seal, a check valve, and a circulating sub. The tieback stem seal may be engaged into a tieback receptacle of a liner in the wellbore and may isolate an annular space of the wellbore. The circulating sub may pass kill fluid from the tieback assembly into the annular space of the wellbore. The check valve may control a flow of fluid. A method of isolating an annular space of a wellbore may include inserting a tieback assembly into the wellbore, engaging the tieback stem seal of the tieback assembly at a tieback receptacle of a liner in the wellbore, passing a kill fluid into the annular space of the wellbore, and displacing an annulus fluid in the annular space of the wellbore with the kill fluid to isolate the annular space of the wellbore.

Abstract: A clamp system for hot-tapping tubulars includes a saddle having a saddle body with an inner surface, an outer surface, and an opening extending from the inner surface to the outer surface, a metal protrusion extending from the inner surface of the saddle body to provide a metal seal, an elastomer seal coupled to the inner surface of the saddle body adjacent to the metal protrusion, and a nipple integrally formed with the saddle body and extending outwardly from the outer surface of the saddle body, the nipple positioned over the opening of the saddle body, and a clamp having a nipple opening configured to receive the nipple, the clamp formed separately from the saddle. A method includes positioning the saddle on a tubular and assembling the clamp around the saddle and the tubular including inserting the nipple through the nipple opening formed in the clamp.

Abstract: A tieback assembly for insertion into a wellbore may include a tieback stem seal, a check valve, and a circulating sub. The tieback stem seal may be engaged into a tieback receptacle of a liner in the wellbore and may isolate an annular space of the wellbore. The circulating sub may pass kill fluid from the tieback assembly into the annular space of the wellbore. The check valve may control a flow of fluid. A method of isolating an annular space of a wellbore may include inserting a tieback assembly into the wellbore, engaging the tieback stem seal of the tieback assembly at a tieback receptacle of a liner in the wellbore, passing a kill fluid into the annular space of the wellbore, and displacing an annulus fluid in the annular space of the wellbore with the kill fluid to isolate the annular space of the wellbore.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A method for treating a well includes flowing a sealant heated to a gaseous phase to cement disposed in an annulus of a wellbore, where the annulus is formed between a casing installed in the wellbore and a cylindrical wall radially outward of the casing. The cement includes a fluid loss opening formed over time. The method includes flowing the sealant in gaseous phase through the fluid loss opening in the cement of the annulus, and cooling the sealant in the gaseous phase into a phase transition of the sealant. The phase transition includes a deposition of the sealant from the gaseous phase to a solid phase or a condensation of the sealant from the gaseous phase to a liquid phase. Further, the sealant seals the fluid loss opening in response to cooling the sealant.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: One example of a wellbore control tool and a method of use is described. A leak is detected in a cased wellbore comprising a multiple telescoping casing sections. A fluid flows in an uphole direction through the cased wellbore. A flow of the fluid in the uphole direction results in a first force in the uphole direction. The leak is in a first telescoping casing section. An open downhole end of a wellbore tool having a weight at least equal to a second force greater than the first force on an uphole end of a second telescoping casing section that is downhole from a location of the leak in the first telescoping casing section is seated. The open downhole end of the wellbore tool provides metal to metal contact against the uphole end of the second telescoping casing section and restricts fluid flow into the leak.

Abstract: A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Abstract: One example of a wellbore control tool and a method of use is described. A leak is detected in a cased wellbore comprising a multiple telescoping casing sections. A fluid flows in an uphole direction through the cased wellbore. A flow of the fluid in the uphole direction results in a first force in the uphole direction. The leak is in a first telescoping casing section. An open downhole end of a wellbore tool having a weight at least equal to a second force greater than the first force on an uphole end of a second telescoping casing section that is downhole from a location of the leak in the first telescoping casing section is seated. The open downhole end of the wellbore tool provides metal to metal contact against the uphole end of the second telescoping casing section and restricts fluid flow into the leak.