A method for evaluating and optimizing complex fractures, in one non-limiting example far-field complex fractures, in subterranean shale reservoirs significantly simplifies how to generate far-field fractures and their treatment designs to increase or optimize complexity. The process gives information on how much complexity is generated for a given reservoir versus distance from the wellbore under known fracturing parameters, such as rate, volume and viscosity. The method allows the evaluation of the performance of diversion materials and processes by determining the amount of fracture volume generated off of primary fractures, including far-field secondary fracture volumes. The methodology utilizes fracture hit times, volumes, pressures and similar parameters from injecting fracturing fluid from a first primary lateral wellbore to create fractures and record fracture hit times, pressures and volumes from a diagnostic lateral wellbore in the same interval.

A system for extracting oil and gas includes at least one drilling rod having an elongated body and a working head positioned at the distal end of the elongated body, wherein the working head has a proximal end and a distal end, a first mechanical drilling device positioned at the distal end of the working head, a second mechanical drilling device position at the proximal end of the working head, a central laser emitter positioned at the distal end of the working head, at least one lateral emitter positioned on a side wall of the working head between the distal end and the proximal end, a fiber optic cable positioned within a lumen of the elongated body and coupled to the central laser emitter and the at least one lateral emitter, and a laser source coupled to and supplying a laser beam to the fiber optic cable.

A method for enhancing recovery of hydrocarbons from a hydrocarbon-bearing subterranean formation includes withdrawing hydrocarbons from a production well and injecting a treatment fluid that includes carbon nanodots dispersed in a brine solution from an injection well that is spaced apart from the production well. The carbon nanodots include carbon, oxygen, nitrogen, and hydrogen and are surface functionalized. A concentration of carbon nanodots in the treatment fluid is less than or equal to 500 parts per million by weight. Injection of the treatment fluid having the carbon nanodots is characterized by an injection duration, an injection pressure, an injection volume, or a combination thereof, that is sufficient to increase cumulative oil recovery of hydrocarbons from the first subterranean formation, the second subterranean formation, or both by at least 10% compared to injecting the brine solution without the carbon nanodots.

A method for enhancing recovery of hydrocarbons from a hydrocarbon-bearing subterranean formation includes withdrawing hydrocarbons from a production well and injecting a treatment fluid that includes carbon nanodots dispersed in a brine solution from an injection well that is spaced apart from the production well. The carbon nanodots include carbon, oxygen, nitrogen, and hydrogen and are surface functionalized. A concentration of carbon nanodots in the treatment fluid is less than or equal to 500 parts per million by weight. Injection of the treatment fluid having the carbon nanodots is characterized by an injection duration, an injection pressure, an injection volume, or a combination thereof, that is sufficient to increase cumulative oil recovery of hydrocarbons from the first subterranean formation, the second subterranean formation, or both by at least 10% compared to injecting the brine solution without the carbon nanodots.

A method includes mounting a first jacket connector block (400) to an apparatus. The first jacket connector block includes a first frame (415), a plurality of first conductor tubes (405) connected to the first frame, a first plurality of releasable connectors (420) coupled to first ends of the first conductor tubes, and a second plurality of releasable connectors (420) coupled to second ends of the first conductor tubes and engaging the apparatus.

A method includes mounting a first jacket connector block (400) to an apparatus. The first jacket connector block includes a first frame (415), a plurality of first conductor tubes (405) connected to the first frame, a first plurality of releasable connectors (420) coupled to first ends of the first conductor tubes, and a second plurality of releasable connectors (420) coupled to second ends of the first conductor tubes and engaging the apparatus.

A method for enhancing recovery of hydrocarbons from a hydrocarbon-bearing subterranean formation includes withdrawing hydrocarbons from a production well and injecting a treatment fluid that includes carbon nanodots dispersed in a brine solution from an injection well that is spaced apart from the production well. The carbon nanodots include carbon, oxygen, nitrogen, and hydrogen and are surface functionalized. A concentration of carbon nanodots in the treatment fluid is less than or equal to 500 parts per million by weight. Injection of the treatment fluid having the carbon nanodots is characterized by an injection duration, an injection pressure, an injection volume, or a combination thereof, that is sufficient to increase cumulative oil recovery of hydrocarbons from the first subterranean formation, the second subterranean formation, or both by at least 10% compared to injecting the brine solution without the carbon nanodots.

A method for enhancing recovery of hydrocarbons from a hydrocarbon-bearing subterranean formation includes withdrawing hydrocarbons from a production well and injecting a treatment fluid that includes carbon nanodots dispersed in a brine solution from an injection well that is spaced apart from the production well. The carbon nanodots include carbon, oxygen, nitrogen, and hydrogen and are surface functionalized. A concentration of carbon nanodots in the treatment fluid is less than or equal to 500 parts per million by weight. Injection of the treatment fluid having the carbon nanodots is characterized by an injection duration, an injection pressure, an injection volume, or a combination thereof, that is sufficient to increase cumulative oil recovery of hydrocarbons from the first subterranean formation, the second subterranean formation, or both by at least 10% compared to injecting the brine solution without the carbon nanodots.

System, methods, and devices for simultaneously fracturing a target formation and an adjacent secondary formation are disclosed. The simultaneous fracturing operations interfere with each other to form in-situ dynamic barriers. The in-situ barriers prevent acid from the fracturing treatment in the target formation from invading the secondary formation and, in some instances, sealing formation rock at the location of the in-situ barrier to prevent or reduce water movement from the secondary formation into the primary formation.

A wellbore completion comprises a borehole extending into a subterranean formation, a first portion of the borehole disposed within at least one production zone of the subterranean formation, and one or more completion zones within the first portion of the wellbore. The first portion maintains a high dog-leg severity throughout the first portion, and the one or more completions are configured to allow for fluid communication between an interior of the borehole and the subterranean formation.