Halliburton Energy Services, Inc.

Jeff T Fleming

Philip D Nguyen

Bradley Leon Todd

Thomas Donovan Welton

Richard W Pauls

Stanley J Heath

Jimmie Dean Weaver, Jr

Feng Liang

David Eugene McMechan

Jason E Bryant

Christopher R Parton

L Todd Bradley

Generally, methods for propping complex fracture networks in tight subterranean formations may involve introducing a first treatment fluid comprising a first base fluid and a first propping agent having a mean particulate size distribution ranging from about 0.5 microns to about 20 microns into a fracture network in a subterranean formation; and then introducing a second treatment fluid comprising a second base fluid and a second propping agent having a mean particulate size distribution greater than about 35 microns into the fracture network.

Propping complex fracture networks in tight formations

Diverting compositions for treating a subterranean zone substantially distanced from a wellbore, comprising: a carrier fluid; and a particulate, partially dehydrated or anhydrous borate source material that does not substantially swell when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore, and wherein the borate source material is dissolvable through sufficient contact with an aqueous fluid. The carrier fluid is a water-miscible non-aqueous fluid selected from the group consisting of ethylene glycol, propylene glycol, N,N- dimethylformamide, tetrahydrofuran, dichloromethane, 1,4-dioxane, dimethylsulfoxide, tetramethylenesulfone, acetonitrile, hexamethylphosphoramide, 1,3-methyl-3,4,5,6-tetrahydro- 2(1H)-pyrimidinone, propylene carbonate, ethylene carbonate, and combinations thereof.

Far field diversion technique for treating subterranean formation

Methods of treating a subterranean formation comprising placing a treatment fluid comprising a base fluid, proppant particulates, a consolidating agent, a thermoplastic material, and a degradable polyester material into the subterranean formation; coating the proppant particulates and the consolidating agent with the thermoplastic material and the degradable polyester material together so as to form proppant pillars; and degrading the degradable polyester material.

Methods of forming and placing proppant pillars into a subterranean formation

Methods of fracturing a subterranean formation that include the steps of placing a stabilizing fluid comprising a formation stabilizing agent and a degradable fluid loss controlling agent into the subterranean formation at a pressure sufficient to create or enhance at least one fracture therein, wherein the degradable fluid loss controlling agent at least partially covers a face of the fracture; placing a treatment fluid comprising proppants into at least a portion of the fracture; bridging the fluid loss controlling agent, the proppants, or both at or near the tip of the fracture to induce a tip screenout; allowing the proppants to form a proppant pack in the portion of the fracture; and allowing the degradable fluid loss controlling agent to degrade.

Methods and compositions for enhancing well productivity in weakly consolidated or unconsolidated formations

An aqueous-swellable and degradable diverting system and the use of the system in treating a subterranean formation penetrated by a wellbore. The diverting system includes a carrier fluid and a partially dehydrated or anhydrous borate source material that does not swell or does not swell substantially when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore. Exposure of the diverting composition to a sufficient amount of aqueous fluid swells the borate source material, bridges a desired portion of the stimulation network, and then dissolves at least a portion of the diverting composition. The diverting techniques allow for treatment in a subterranean formation to be diverted to a previously untreated portion of the formation, in particular a portion of the formation that is significantly distanced from the wellbore.

Methods comprising first introducing a solids-free fracturing fluid into a subterranean formation at a rate sufficient to enhance or create at least one fracture therein. Once a fracture is created or enhanced, a treatment fluid comprising a carrier fluid and a shear-thickening fluid is placed into the fracture. The shear-thickening fluid comprises a propping material selected from the group consisting of: proppant, proppant aggregates, solids free gel bodies, and combinations thereof. The propping material forms a bed within the fracture. In some embodiments, solids-free gel bodies may also be included in the treatment fluid.

Methods for propping fractures using proppant-laden aggregates and shear-thickening fluids

Methods of reducing the viscosity of a viscosified treatment fluid; providing a clean-up composition comprising a carboxylic acid; a chlorite-based breaker system comprising an alkali metal compound and an activator wherein the activator comprises a metal and an amine. Placing a viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; first contacting the viscosified treatment fluid with the chlorite-based breaker; and then contacting the viscosified treatment fluid with the clean-up composition; and, allowing the viscosity of the viscosified treatment fluid to reduce.

Carboxylic acid and oxidizer clean-up compositions and associated methods of use in subterranean applications

Of the many methods provided herein, one method of reducing the viscosity of a viscosified treatment fluid includes: providing a clean-up composition comprising a carboxylic acid; providing a chlorite-based breaker system; providing a viscosified treatment fluid; placing the viscosified treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; contacting the viscosified treatment fluid with the clean-up composition; contacting the viscosified treatment fluid with the chlorite-based breaker; and allowing the viscosity of the viscosified treatment fluid to reduce. Also provided herein are methods that include a method of reducing polymeric residue from a subterranean formation that includes: placing a clean-up composition and a chlorite-based breaker system in a subterranean formation in contact with an amount of polymeric residue; and allowing the amount of polymeric residue present in the formation to be reduced.

Provided are methods that include a method comprising: placing a clean fluid comprising proppant particulates into a portion of a fracture in a subterranean formation, and depositing one or more of the proppant particulates into the fracture to form a partial monolayer. In another aspect, the invention provides methods that include placing a degradable fluid loss additive comprising collagen into a subterranean formation.

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Duncan, OK, United States of America

Jeff T Fleming