A method of servicing a wellbore in a subterranean formation comprising placing in the wellbore and/or subterranean formation a pad fluid and forming a fracture in the subterranean formation. Next, a first slurry fluid may be placed into the fracture in the subterranean formation. The first slurry fluid may comprise a reducible material and a first particulate material. Next, a second slurry fluid and a spacer fluid may be placed into the fracture in the subterranean formation in an alternating sequence. The second slurry fluid may comprise a second particulate material. Then, the fracture is allowed to close and the fluids are allowed to break. Finally, the reducible materials degrade, to form a particulate-laden proppant pack (PLPP).

A method of designing a particle size distribution of particulate bridging lost circulation material for a fractured leakage includes the following steps: classifying the lost circulation materials according to a particle size; calculating an expected range of a characteristic particle size of the lost circulation materials according to a fracture width and particle size selection criteria; setting a relative percentage content of the each level of the lost circulation materials; using a particle size distribution function to fit a particle size distribution curve; calculating the characteristic particle size of the lost circulation materials according to the particle size distribution curve; determining whether the calculated characteristic particle size conforms to the expected range of the characteristic particle size; and generating the particle size distribution of the lost circulation materials conforming to the particle size selection criteria.

The present discloses a pressure-bearing plugging composition comprising 1-7 parts by weight bentonite, 0.1-1.5 parts by weight deformation material, 8-18 parts by weight filling material and 4-12 parts by weight modified bridging material, based on 100 parts by weight of water; the modified bridging material comprises a core, and a coating layer coated on an outer surface of the core, and a paraffin layer disposed between the core and the coating layer; the core is made of a water-absorbing material, and the coating layer is formed by bonding rigid particles and an adhesive.

A wellbore fluid may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous phase within the oleaginous phase; a low density material selected and in an amount to result in a specific gravity of the wellbore fluid that is less than 0.83; and at least one rheology modifier selected to suspend the low density material within the wellbore fluid.

Compositions and methods for using those compositions to at least partially stabilize subterranean formations are provided. In one embodiment, the methods include providing a treatment fluid including an aqueous base fluid and an additive including a low molecular mass organic gelator; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that includes shale; and allowing the additive to interact with the shale to at least partially stabilize the shale.

Methods and compositions for modifying the rheological properties of non-aqueous fluids for treating subterranean formation are provided. In one or mom embodiment, the compositions comprise a non-aqueous fluid; a weighting agent; and one or more associative polymers that are capable of associating to form one or more supramolecular assemblies. In one or more embodiments, the methods comprise introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation, wherein the treatment fluid comprises a non-aqueous fluid and one or more associative polymers.

An invert-emulsion drilling fluid may include a dispersed aqueous phase including an aqueous base fluid, a continuous non-aqueous phase including a non-aqueous base fluid, and a first bridging package. The first bridging package may include one or more particulate carbonate materials. All of the particulate carbonate materials of the invert-emulsion drilling fluid may be part of the first bridging package. The first bridging package may have a trimodal particle size distribution such that the particle size distribution of the first bridging package includes three peaks, wherein each peak may be in the range of less than or equal to 300 microns in the particle size distribution. The invert-emulsion drilling fluid may be included in methods for reducing lost circulation in subterranean formations during drilling operations.

Loss circulation material (LCM) and method for treating loss circulation in a wellbore in a subterranean formation, including placing the LCM having a solid body with permeable portions or pores into the wellbore to dispose the LCM at the loss circulation zone, and collecting solids onto the LCM at the loss circulation zone to form a barrier. The LCM may be applied at a loss circulation zone in a hydrocarbon reservoir section of the subterranean formation, and upon subsequent hydrocarbon production the collected solids may be dislodged by the produced hydrocarbon to allow for hydrocarbon production through the permeable portions or pores of the disposed LCM.

Loss circulation material (LCM) and method for treating loss circulation in a wellbore in a subterranean formation, including placing the LCM having a solid body with permeable portions or pores into the wellbore to dispose the LCM at the loss circulation zone, and collecting solids onto the LCM at the loss circulation zone to form a barrier. The LCM may be applied at a loss circulation zone in a hydrocarbon reservoir section of the subterranean formation, and upon subsequent hydrocarbon production the collected solids may be dislodged by the produced hydrocarbon to allow for hydrocarbon production through the permeable portions or pores of the disposed LCM.

The present invention discloses a composition for enhanced oil recovery comprising olefin sulfonate, sulfo-betaine, betaine and about 0.5 wt % to about 1.5 wt % magnesium chloride.