Abstract: Nano- and micro-particles (NMP) can be formed from an oil/water emulsion. The emulsion is made by mixing a liquid solvent, at least one surfactant, a particle-forming compound, and at least curing agent. If desired, pH control agents and viscosity enhancers can be added to the liquid solvent. The particle-forming compound and the curing agents are mixed together and form the oil phase in the emulsion and after curing, the particles are formed. The nano- and micro-particles can be used as proppant to enhance the conductivity of nano- and microfractures and fluid-loss-control additive for hydraulic fracturing operations.

Abstract: A hydraulic fracture fluid is provided. The fluid can include a liquid solvent, one or more surfactants, a proppant-forming compound, and one or more curing agents. The liquid reacts to form proppant in-situ under downhole conditions.

Abstract: A drill bit for cutting formation comprises a bit body, a plurality of cutters, and a plurality of blades with pockets to accommodate the cutters, respectively. Each of the plurality of cutters has a substrate, an ultra-hard layer, an inclined surface on the top of the ultra-hard layer, wherein the inclined surface slants downward from a cutting edge to a trailing edge. The cutter can improve cutting efficiency and service life.

Abstract: A method to determine the velocity of static proppant settling in fracturing fluids. The proppant carrying capability of different friction reducer products can be compared, so the appropriate friction reducer product can be selected for hydraulic fracturing operations. The effect of friction reducer concentrations in the fracturing fluids, the salinity and hardness of the fracturing fluids, and the proppant size on the velocity of static proppant settling can be studied to optimize the chemical structures of the friction reducers in the process of synthesis and optimize the hydraulic fracturing operation, e.g. to determine the proper concentration of friction reducers according to the salinity and proppant size.

Abstract: A polyacrylamide friction reducer wherein the friction reducer contains surfactant functional groups, and wherein the polyacrylamide friction reducer is degradable, can be used for multi-functional, slickwater fracturing fluid projects. Under downhole conditions, the polymer degrades and releases the surfactant molecules to act as oil displacing agent to provide additional stimulation.

Abstract: A low-end rheology modifier for adjusting rheological characteristics of water-based drilling fluid systems, particularly for high salt, high density drilling fluids in high temperature and high-pressure applications. The low end rheology modifier comprises a copolymer and laponite clay, the copolymer comprising tert-Butylacrylamidosulfonic acid (TBAS) and n-vinylpyrrolidone (NVP) crosslinked with N,N?-Methylenebis(acrylamide).

Abstract: A polyacrylamide friction reducer wherein the friction reducer contains surfactant functional groups, and wherein the polyacrylamide friction reducer is degradable, can be used for multi-functional, slickwater fracturing fluid projects. Under downhole conditions, the polymer degrades and releases the surfactant molecules to act as oil displacing agent to provide additional stimulation.

Abstract: The retrievable packer system includes a packer mandrel, a lock ring, an upper cone, a lower cone, a slip device, a retrieval mandrel, and a slotted retrieval sleeve. The lock ring is attached to the packer mandrel, followed by the upper cone, the slip device, the lower cone, and the retrieval mandrel. The upper connection sleeve and the lower connection sleeve cover the packer mandrel so as to form a chamber in fluid connection with slip flow channels of the slip device. The packer system is run into the borehole with the slotted retrieval sleeve in the first position relative to the lower cone and the slip device in the run-in position. The packer system is set and can be locked at a location in the borehole. The slotted retrieval sleeve can push the upper cone to return the slip device to the run-in position for retrieval of the packer system.

Abstract: The force modulation system for a drill bit includes a cutter, a blade cap, a cap retention device, and a first force member. The cutter or cutters fit in the blade cap, and the blade cap fits to the drill bit. The cap retention device exerts a cap retention force in a first direction. The first force member exerts a first force in a second direction. The cutting profile of the force modulation system is now variable in more than one direction so as to avoid excessive forces from more than one direction for each cutter on the blade cap. There can also be a second force member to exert a second force in the first direction for more variability of the cutting profile in the first direction and a third force member to exert a third force in an opposite second direction.

Abstract: A method for significantly reducing and/or preventing loss circulation in a well during drilling operations. The method includes pumping water-based drilling fluid comprising shape memory polymer particles into bore hole while drilling and exposing the drilling fluid to an activation temperature. The polymer particles change shape at activation temperature filling all or portion of fractures in the bore hole thus significantly reducing and/or preventing loss circulation in the well.

Abstract: The disclosure includes a new test method of evaluating lost circulation prevention with expandable geopolymers. The expandable geopolymer is tested using a permeability plugging tester, slot disk, drilling fluid, and a piston to determine how much fluid is released from the test cell.

Abstract: A novel surfactant composition that comprises of two surfactant components, a solvent, and water. The surfactant composition is added to a fracturing fluid, which is then pumped downhole into a subterranean formation where the novel characteristics of the fracturing fluid lend to improved oil production over the fracturing fluid without the surfactant composition.

Abstract: The patent application discloses a degradable polymers compounds. The polymer compounds comprises product of blends of polyglycolic acid and polylactic acid in a weight ratio of from about 99/1 to about 50/50 in mixture with a compatibilizer poly(lactic-co-glycolic acid), wherein the compounded product has a tensile strength of at least about 12,000 psi.

Abstract: The force modulation system for a drill bit includes a cutter, a holder, a holder retention device, and a first force member. The cutter fits in the holder, and the holder fits in the drill bit. The holder retention device exerts a holder retention force in a first direction. The first force member exerts a first force in a second direction. The second direction is angled offset to the first direction so as that the cutting profile of the force modulation system is now variable in the second direction, according to the first force. There can also be a second force member to exert a second force in the first direction for more variability of the cutting profile in the first direction. The second force member can be made integral with the first force member.

Abstract: The method for forming cutters includes applying a protective layer on an O-ring so as to form a protected O-ring. The protected O-ring is placed around a cutter body having a substrate section and diamond section with a metallic binder. The method includes inserting the cutter body into the pod cavity and leaching the metallic binder through an end portion of the diamond section for at least one day at 60 degrees Celsius or higher so as to form a polycrystalline diamond compact cutter from the cutter body. The protected O-ring seals the substrate section during the step of leaching. The step of leaching forms an exposed O-ring from the protected O-ring with a hardness reduction and a modulus reduction that identifies a time window for maintaining a sealing force to protect the substrate, while achieving the target profile of the diamond table for a high quality and reliable cutter.

Abstract: Some reservoirs have tight oil formations, such as the Changqing reservoir. The surfactant polymer flooding and low-tension gas flooding are two potential chemical flooding methods for use in tight oil formations. In these methods, an oil displacement agent, or surfactant, is added. Derivatives of nonionic surfactants with extended chains (by propylene oxide and ethylene oxide) from di-alkyl alcohols were developed and tested. A synergistic blend of surfactants was developed between the di-alkyl chain surfactants and a commercially available anionic surfactants that lowers interfacial tension and improves surfactant solubility in high salinity water and oil.

Abstract: This disclosure describes the composition and methods of use for a novel delayed polymer gelation system. This polymer gelation system includes a polymer of acrylamide, AMPS and 100-2,000 ppm polyethylene glycol diacrylate in inverse emulsion form, and a polyethyleneimine (PEI) with Mw of 5,000-100,000 Dalton as the crosslinking agent.

Abstract: This disclosure describes the composition and methods of use for a novel delayed polymer gelation system for high temperature and high salinity applications. This polymer gelation system includes a polymer of acrylamide, AMPS and 500-5000 ppm polyethylene glycol diacrylate in inverse emulsion form, and a polyethyleneimine (PEI) with a MW of 2,000-30,000 daltons as the crosslinking agent.

Abstract: The force modulation system for a drill bit includes a cutter, a holder, a holder retention device, and a first force member made of a first woven material. The cutter fits in the holder, and the holder fits in the drill bit. The holder retention device exerts a holder retention force in a first direction. The first force member exerts a first force in a second direction. The second direction is angled offset to the first direction so as that a cutting profile of the force modulation system is variable. There can also be a second force member of a second woven material to exert a second force in the first direction for more variability of the cutting profile in the first direction. The second force member can be made integral with the first force member, including the first woven material and the second woven material being the same material.

Abstract: A hydraulic fracture fluid is provided. The fluid can include a liquid solvent, one or more surfactants, a proppant-forming compound, and one or more curing agents. The liquid reacts to form proppant in-situ under downhole conditions.