A technique facilitates servicing of a subterranean formation by treating a specific section of a well. The technique utilizes a straddle packer conveyed downhole and then activated via coiled tubing. The straddle packer comprises a first, e.g. upper, packer and a second, e.g. lower, packer which are deployed downhole into the wellbore to the specific section of the wellbore proximate a target formation zone. Once properly located, the straddle packer is uniquely activated by compression and tension inputs applied via the coiled tubing.

An oil or gas well fishing tool is provided. The downhole fishing tool has a receptacle that is open at one end. The tool also has deployment tool engaging means, located on the opposite end of the receptacle to the one end. The tool further has a layer of an alloy provided on the interior surface of the receptacle. The alloy is a eutectic alloy and/or a bismuth alloy. The tool further comprises heating means to heat the alloy so that it melts and can flow over any object received within the receptacle.

An oil or gas well fishing tool is provided. The downhole fishing tool has a receptacle that is open at one end. The tool also has deployment tool engaging means, located on the opposite end of the receptacle to the one end. The tool further has a layer of an alloy provided on the interior surface of the receptacle. The alloy is a eutectic alloy and/or a bismuth alloy. The tool further comprises heating means to heat the alloy so that it melts and can flow over any object received within the receptacle.

A method includes designing a lower completion string for a multi-stage hydraulic fracturing job for a wellbore drilled into a subterranean zone. The lower completion string includes a plurality of stages and a plurality of packers configured to isolate each of the stages. Each stage of the plurality of stages includes a respective tubular stage assembly, and each stage is configured to be placed within a respective one of a plurality of frac intervals of the wellbore defined by the plurality of packers. Designing the lower completion string includes, for each stage of the plurality of stages, receiving a measured hole diameter of the respective one of the plurality of frac intervals and performing an axial safety factor analysis of the stage. The axial safety factor analysis includes a comparison of a yield strength in tension or compression of the respective tubular stage assembly of the stage with calculated effective axial tensile or compressive forces to which the respective tubular stage assembly of the stage would be subject when positioned in the frac interval in the wellbore. The axial safety factor analysis uses a predicted anchored status of the lower completion string, which includes an extent to which the respective tubular stage assembly would be predicted to elongate or contract when the lower completion string is positioned in the wellbore and the plurality of packers are set. The axial safety factor analysis also uses a distance between a first packer of the plurality of packers isolating the stage and a second packer of the plurality of packers isolating the stage, and the measured hole diameter of the respective frac interval. The method also includes determining that the axial safety factor analysis for each stage of the plurality of stages satisfies a threshold and, in response to the determining that the threshold is satisfied for each stage of the plurality of stages, inserting the lower completion string into the wellbore and performing the multi-stage hydraulic fracturing job.

A method includes designing a lower completion string for a multi-stage hydraulic fracturing job for a wellbore drilled into a subterranean zone. The lower completion string includes a plurality of stages and a plurality of packers configured to isolate each of the stages. Each stage of the plurality of stages includes a respective tubular stage assembly, and each stage is configured to be placed within a respective one of a plurality of frac intervals of the wellbore defined by the plurality of packers. Designing the lower completion string includes, for each stage of the plurality of stages, receiving a measured hole diameter of the respective one of the plurality of frac intervals and performing an axial safety factor analysis of the stage. The axial safety factor analysis includes a comparison of a yield strength in tension or compression of the respective tubular stage assembly of the stage with calculated effective axial tensile or compressive forces to which the respective tubular stage assembly of the stage would be subject when positioned in the frac interval in the wellbore. The axial safety factor analysis uses a predicted anchored status of the lower completion string, which includes an extent to which the respective tubular stage assembly would be predicted to elongate or contract when the lower completion string is positioned in the wellbore and the plurality of packers are set. The axial safety factor analysis also uses a distance between a first packer of the plurality of packers isolating the stage and a second packer of the plurality of packers isolating the stage, and the measured hole diameter of the respective frac interval. The method also includes determining that the axial safety factor analysis for each stage of the plurality of stages satisfies a threshold and, in response to the determining that the threshold is satisfied for each stage of the plurality of stages, inserting the lower completion string into the wellbore and performing the multi-stage hydraulic fracturing job.

Methods, systems, and computer program products for generating a schedule for fluid placement. A computer-implemented method may include determining, for each zone of a plurality of zones of a treatment interval to be treated by the fluids placement system, a criterion value based on a heterogeneity parameter of the zone, sorting the zones into an ordered sequence based on the criterion value associated with each zone, and generating a schedule that designates an order of treating the zones in accordance with the order of the sequence.

Methods, systems, and computer program products for generating a schedule for fluid placement. A computer-implemented method may include determining, for each zone of a plurality of zones of a treatment interval to be treated by the fluids placement system, a criterion value based on a heterogeneity parameter of the zone, sorting the zones into an ordered sequence based on the criterion value associated with each zone, and generating a schedule that designates an order of treating the zones in accordance with the order of the sequence.

A downhole tool for use in a gas or oil well is provided. The tool comprising a length of tubing having at least one annular sealing means mounted on the outer surface thereof. The annular sealing means, which are formed from a eutectic/bismuth based alloy, serve to secure the downhole tool in position within an oil or gas well during so that the tool can carry out its function.

A downhole tool for use in a gas or oil well is provided. The tool comprising a length of tubing having at least one annular sealing means mounted on the outer surface thereof. The annular sealing means, which are formed from a eutectic/bismuth based alloy, serve to secure the downhole tool in position within an oil or gas well during so that the tool can carry out its function.

An oil or gas well downhole fishing tool has a receptacle that is open at one end. The tool also has deployment tool engaging means, located on the opposite end of the receptacle to the one end. The tool further has a layer of an alloy provided on the interior surface of the receptacle. The alloy is a eutectic alloy and/or bismuth alloy. The tool further comprises heating means to heat the alloy so that it melts and can flow over any object received within the receptacle.