A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: providing a wellbore in need of stimulation; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and a spearhead or breakdown acid into the wellbore; positioning the tool at said predetermined location; perforating the wellbore with the tool thereby creating a perforated area; allowing the spearhead acid to come into contact with the perforated area for a predetermined period of time sufficient to prepare the formation for fracking or stimulation; removing the tool from the wellbore; and initiating the fracking of the perforated area using a fracking fluid. Also disclosed is a corrosion inhibiting composition for use with the acid composition.

A downhole well tool assembly can include a perforator and a selectively openable and closable perforation plug discharge port. A method of perforating and treating multiple formation zones of a well in a single trip of a downhole well tool assembly into the well can include positioning the downhole well tool assembly at a zone, closing a perforation plug discharge port of the downhole well tool assembly, perforating the zone, treating the zone, opening the perforation plug discharge port, deploying perforation plugs into the well via the perforation plug discharge port, plugging perforations in the zone with the perforation plugs, positioning the downhole well tool assembly at a subsequent zone, closing the perforation plug discharge port, perforating the subsequent zone, and treating the subsequent zone.

A perforating gun deployable in a wellbore as part of a tool string includes an outer sleeve including a generally tubular wall structure having a peripheral surface around the outside, opposite ends thereof and a central passage therethrough extending from one end to the other end and further including a connection at each end to connect to other tools in the tool string, and at least one pressure sealed perforating module slidably positioned within the central passage of the outer sleeve having a shaped charge sealed from the portion of the central passage of the outer sleeve external the pressure-sealed perforating module.

A perforating gun deployable in a wellbore as part of a tool string includes an outer sleeve including a generally tubular wall structure having a peripheral surface around the outside, opposite ends thereof and a central passage therethrough extending from one end to the other end and further including a connection at each end to connect to other tools in the tool string, and at least one pressure sealed perforating module slidably positioned within the central passage of the outer sleeve having a shaped charge sealed from the portion of the central passage of the outer sleeve external the pressure-sealed perforating module.

Methods for the fracking or stimulation of a hydrocarbon-bearing formation are provided in multiple embodiments. According to one method, it comprises the steps of: providing a wellbore having a casing; inserting a plug in the wellbore at a predetermined location; inserting a perforating tool and an acidic composition into the wellbore; wherein the acidic composition includes a corrosion inhibiting composition comprising at least two compounds selected from: Group A-I, and wherein at least two compounds are selected from different groups of the Groups A-I.

A method, system, and apparatus for determining the location of a tool traveling down a wellbore by measuring a first borehole magnetic anomaly with respect to time at two known locations on a tool, comparing the time difference between the two measurements, then calculating the velocity of the tool based on the comparison, then further calculating the distance traveled by the tool in the wellbore based on the velocity calculation, then executing a series of commands at a predetermined location in the wellbore.

A method, system, and apparatus for determining the location of a tool traveling down a wellbore by measuring a first borehole magnetic anomaly with respect to time at two known locations on a tool, comparing the time difference between the two measurements, then calculating the velocity of the tool based on the comparison, then further calculating the distance traveled by the tool in the wellbore based on the velocity calculation, then executing a series of commands at a predetermined location in the wellbore.

A method of perforating a wellbore is provided. The method includes generating a shockwave that propagates throughout said wellbore by firing a perforation device at a perforating direction, and measuring the shockwave at a fiber optic cable in the wellbore using the fiber optic cable. The method further includes determining an orientation of the fiber optic cable relative to the perforating direction based on the shockwave and the perforating direction, and changing the perforating direction based on the orientation of said the optic cable for a subsequent perforation of the wellbore to minimize damage to the fiber optic cable during the subsequent perforation. The fiber optic cable is an existing cable that has been deployed before the method starts.

A method of perforating a wellbore is provided. The method includes generating a shockwave that propagates throughout said wellbore by firing a perforation device at a perforating direction, and measuring the shockwave at a fiber optic cable in the wellbore using the fiber optic cable. The method further includes determining an orientation of the fiber optic cable relative to the perforating direction based on the shockwave and the perforating direction, and changing the perforating direction based on the orientation of said the optic cable for a subsequent perforation of the wellbore to minimize damage to the fiber optic cable during the subsequent perforation. The fiber optic cable is an existing cable that has been deployed before the method starts.

Construction and use of an instrument test fixture for capturing performance data for stimulation or fracturing treatments. The test fixture includes a target material, such as concrete, which includes embedded sensors surrounding a casing. An energetic stimulation treatment, such as a dynamic pulse fracturing technique, is applied through the casing to the target material to simulate a treatment that would be performed in a wellbore. During application of the treatment, the sensors capture measurements which are recorded for analysis by a data collection system. The sensors allow for the measurement of key performance indicators including static and dynamic pressure, generated temperature, and resulting strain energy. The captured data can be analyzed and used to design and optimize stimulation treatments for field applications.