Abstract: A process for treating a subterranean earth formation includes the step of introducing an acidizing treatment fluid comprising a monovalent salt of monochloroacetic acid into the subterranean earth formation in the presence of at least one bromide or iodide salt or salt precursor, wherein the at least one bromide or iodide salt or salt precursor is introduced into the subterranean earth formation in an amount of from about 0.3 to about 10 wt %, based on the total weight of the acidizing treatment fluid. The acidizing treatment fluid itself includes the monovalent salt of monochloroacetic acid, the at least one bromide or iodide salt or salt precursor, and optionally an element to suppress precipitation of calcium glycolate and/or at least one acid.

Abstract: The instant application relates to nanogels or compositions that hold multivalent metal ions until some level of nanogel degradation has occurred, then slowly release the multivalent metal ions for gelation with carboxylate containing polymers. Compositions comprising such nanogels, together with polymers that can be crosslinked with multivalent metal ions, allow the deployment of such mixtures in various applications, and greatly increased gelation times.

Abstract: Disclosed herein is a gas hydrate inhibitor that includes from 1 to 99% by weight of an alcohol, from 1 to 99% by weight of a polyol, from 0.01 to 2.0% by weight of an organic acid, and from 1 to 99% by weight of water. The gas hydrate inhibitor is useful in preventing and/or removing hydrates in a fluid to ensure a continuous flow of the fluid.

Abstract: Methods for drilling in higher temperature rock formations such as geothermal formations with phase change material augmented drilling fluid include observing flow rate of the augmented fluid. Heat exchange between the annulus returning fluid and tubular fluid can be minimized thereby facilitating a cooler fluid for contact with a rock face being drilled. The cooling assists in pre-fracturing the rock face prior to destruction by the drill bit.

Abstract: The present invention discloses an optimized design method for a temporary blocking agent to promote uniform expansion of fractures produced by fracturing in horizontal wells, which comprises the following steps: calculating a particle size and a volume range of a candidate temporary blocking agent in an applicable target area; establishing a hydraulic fracture expansion calculation model with complete fluid-solid coupling; calculating an optimal average particle size required for effective temporary blocking; determining the particle size distribution of the temporarily blocked particles according to the optimal average particle size; calculating the particle volume of the temporary blocking agent required for effective temporary blocking; and predicting and evaluating a fracturing effect after the preferred temporary blocking design is adopted in the target area.

Abstract: A stabilized water-dispersible latex additive useful in both freshwater-based and brine-based drilling fluids, may be formed by mixing an effective amount of a compound containing at least one pyrrolidone ring, such as, polyvinylpyrrolidone, a vinylpyrrolidone-vinyl acetate copolymer, poly(1-vinylpyrrolidone-co-2-dimethylaminoethyl methacrylate), a vinylpyrrolidone-acrylic acid copolymer, and combinations thereof, with the water-dispersible latex additive before or after the water-dispersible latex additive is introduced to the drilling fluid.

Abstract: A hydrate inhibitor comprising a boronic acid moiety and associated methods and compositions.

Abstract: A method of pulse power drilling in a subterranean formation may comprise providing a drilling fluid comprising an oil external phase, an internal phase, and a hydrolysis reactant compound for reaction with water. The method may also comprise passing an electric current through the subterranean formation to extend a wellbore in the subterranean formation while circulating the drilling fluid through the wellbore.

Abstract: A method of demulsifying an emulsion with an ionic liquid having a nitrogen or phosphorus cation.

Abstract: A magnetic depth of cut controller (DOCC) includes a housing having a body portion with a bore extending into the body portion and a depth of cut (DOC) element positioned at least partially within the bore and having a working face to engage a subterranean formation. The DOC element is moveable within the bore to extend or retract from a first end of the housing. Further, the DOCC includes a magnet secured within the bore of the housing between the DOC element and a second end of the housing. Moreover, the DOCC includes a magnetic fluid disposed within the bore of the housing between the DOC element and the second end of the housing. The magnetic fluid has a viscosity that changes responsive to proximity to the magnet to provide a variable resistance to movement of the DOC element.

Abstract: The invention relates to powdered lubricants for water based drilling fluids. Conventional liquid lubricants containing particularly divalent ions have the tendency to grease out. The powdered lubricants have excellent dispersion properties and hence do not grease out, when added to the drilling mud in the concentrations, preferably of the order of about 3% or less. The powdered lubricant is a combination of inert fillers with fatty acids that are essentially free from fatty acid esters and metal soaps and have organic acids containing C10-C24 alkyl groups fatty acids. The improved lubricating properties of the drilling muds result in greatly increased life of the rotary drilling bits and marked reduction in torque required to rotate the bit. Solid powdered additives compositions greatly reduce transportation costs and simplify the logistics and environmental concerns associated with shipping large volumes of liquids and overcome the pour point issues associated with liquid additives.

Abstract: Dissolving iron sulfide on the carbon steel tubing to yield chelated iron is achieved by treating the carbon steel tubing with a composition including an iron chelant and an additive. The additive includes at least one of an oxidizing agent and a base. A weight ratio of the iron chelant to the additive is in a weight range of 50:1 to 5:1.

Abstract: The present invention relates to the technical field of oil and gas drilling, and discloses a biodiesel-based constant rheological property drilling fluid containing intelligent temperature responsive polymer, which contains two or more of the following components which are stored in admixture or separately: base oil biodiesel, aqueous phase, emulsifier, organic soil, constant rheological property flow pattern modifier, hydrolysis inhibitor, filtrate reducer and weighting material; the constant rheological property flow pattern modifier is an intelligent temperature responsive polymer, and the polymer contains structural units provided by bis-hydroxyethyl bis-hydroxypropyl stearyl ammonium chloride, ethylene bis-stearamide and dimerized fatty acid.

Abstract: A wellbore treatment fluid comprising: a base fluid; and a water-soluble salt, the salt comprising: a cation; and an anion, wherein the anion is selected from phosphotungstate, silicotungstate, phosphomolybdate, and silicomolybdate. The treatment fluid can have a density greater than or equal to 13 pounds per gallon. A method of treating a portion of a subterranean formation penetrated by a well comprising: introducing the treatment fluid into the well.

Abstract: A method of treating in a subterranean formation including combining a dimer acid; proppant; an emulsifier; an oil base fluid; and aqueous base fluid to form an oil-external emulsified fluid; and introducing the oil-external emulsified fluid into the subterranean formation. A method of forming a wellbore fluid including combining proppant; a dimer acid; an aqueous base fluid, an oil base fluid, and an emulsifier to form a pre-emulsified fluid; and mixing the pre-emulsified fluid to form an oil-external emulsified fluid.

Abstract: A date tree fiber mix lost circulation material (LCM) is provided that includes a trinary mix of fibers produced from date trees. The date tree fiber mix LCM may include date tree trunk fibers produced from date tree trunks, date tree leaf and leaf stem fibers produced from date tree leaves and leaf stems, and date tree panicle fibers produced from date tree panicles. The LCM include a mix of 30% by weight date tree trunk fibers, 30% date tree leaf and leaf stem fibers, and 40% by weight date tree panicle fibers. Methods of lost circulation control using and manufacture of a date tree fiber mix LCM are also provided.

Abstract: A method of limiting or reducing permeability of a matrix to liquid and/or gas inflow is described. The method includes limiting inflow of water, liquid and/or gas into passages such as cavities, fissures, voids and the like, encountered in formations such as geological formations though can be used to form barriers to water, liquid or gas flow through a matrix. The method includes steps of measuring one or more parameters relating to the matrix and selecting one or more components of a multi-component sealing composition with reference to the measured parameters. The selected components are introduced into the matrix where it is set or coagulated in a non-exothermic or low exothermic process to form a seal barrier.

Abstract: The embodiments of the present disclosure relate to increasing fracture network complexity within a subterranean formation using a plurality of fluid stages where one or more of such fluid stages utilizes a liquid gas treatment fluid. The embodiments described herein allow creation or extension of a dominant fracture and branch fractures extending therefrom at one or both of the near-wellbore region and/or the far-field region of a fracture network, thereby enhancing fracture network complexity.

Abstract: An emulsified drilling fluid additive includes an emulsion of asphalt, at least one emulsifier, cellulose ether, and water. The asphalt has a softening point of 160 to 212° F., a penetration depth of 0 to 45 mm, and a viscosity of 200 to 800 cP at 350° F. The drilling fluid additive has an average particle size of 0.1-10 microns. The drilling fluid has an API fluid loss at 7.5 minutes of 0 to 0.5 mL and an API fluid loss at 30 minutes of 0 to 3.5 mL. A method of making the drilling fluid additive includes mixing at least one emulsifier, cellulose ether, and water to form a solution, heating a water-dispersible asphalt to above 300° F. and adding the asphalt to the water-based solution in a colloid mill to form an emulsion.

Abstract: Methods including introducing a solids-free high-viscosity fracturing fluid into a subterranean formation above the fracture gradient to create or enhance at least one dominate fracture. Introducing a first low-viscosity pad fluid (LVPadF) above the fracture gradient to create or enhance at least one first microfracture extending from the dominate fracture. The first LVPadF comprises an aqueous base fluid, high-density micro-proppants (HDMPs), and low-density micro-beads (LDMBs), the HDMPs having a specific gravity that is at least about 100% greater than the specific gravity of the LDMBs. Placing at least a portion of the HDMPs and LDMBs into the microfracture to form at least a partial monolayer. Introducing a low-viscosity proppant fluid (LVPropF) into the subterranean formation above the fracture gradient. The LVPropF comprises an aqueous base fluid and medium-sized proppants (MSPs). Placing at least a portion of the MSPs into the dominate fracture.

Abstract: The present disclosure relates to oil and gas well proppant compositions and methods for enhancing the conductivity of a propped fracture formed during a hydraulic fracturing operation. The method introduces a micro-proppant slurry prepared with slickwater containing both a low-density and a conventional micro-proppant during injection of the pad fluid stages to prop the natural and induced microfractures open and then injecting a proppant slurry prepared with slickwater containing low-density proppant and conventional frac sand during proppant slurry stage to prop the dominant fractures or large branches, provide open flow paths to keep them connective with the wellbore.

Abstract: Methods including introducing a high-viscosity treatment fluid into a subterranean formation through an opening and applying incrementally increased fracturing rate steps (IIFRSs) to create or enhance a dominate fracture, wherein between each IIFRS a downhole pressure slope over time will increase, decline, or stabilize at a HVTF measured pressure slope. Further evaluating the HVTF measured pressure slope prior to applying a subsequent IIFRS. Performing a particulate sequence transport operation with a first, second, and third low-viscosity treatment fluid (LVTF), wherein the LVTFs collectively create or enhance at least one near-wellbore secondary azimuth fracture and at least one far-field secondary azimuth fracture extending from the dominate fracture, and further propping the dominate fracture, near-wellbore, and far-field secondary azimuth fractures with the particulates.

Abstract: Provided here are various invert emulsion drilling fluid compositions. The invert emulsion fluid is a water in oil emulsion, which can include an invert emulsifier to stabilize the water in oil emulsion, a 16 to 18 carbon carboxylic acid, a 36 carbon fatty dimer diol, a polymeric filter control agent, and an inorganic mineral including one or more of lime, calcium chloride, and barite. The invert emulsion drilling fluids can be formulated to be substantially free of clay.

Abstract: A date tree fiber mix lost circulation material (LCM) is provided that includes a trinary mix of fibers produced from date trees. The date tree fiber mix LCM may include date tree trunk fibers produced from date tree trunks, date tree leaf and leaf stem fibers produced from date tree leaves and leaf stems, and date tree panicle fibers produced from date tree panicles. The LCM include a mix of 30% by weight date tree trunk fibers, 30% date tree leaf and leaf stem fibers, and 40% by weight date tree panicle fibers. Methods of lost circulation control using and manufacture of a date tree fiber mix LCM are also provided.

Abstract: In some instances, a fluid loss control enhancement additive may synergistically work with lost circulation materials (“LCM”) to arrest lost circulation in wellbores where LCMs alone have been ineffective. For example, a method may involve treating a wellbore penetrating a subterranean formation with a pill comprising an aqueous base fluid and a lost circulation material; observing fluid loss from the wellbore to the subterranean formation while treating the wellbore with the pill; and adding salt, a swellable polymer, and fibers to the pill.

Abstract: Disclosed herein is a nanoparticle modified fluid that includes nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 50 nanometers; nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 70 nanometers; and a liquid carrier; wherein the nanoparticle modified fluid exhibits a viscosity above that of a comparative nanoparticle modified fluid that contains the same nanoparticles but whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature.

Abstract: Described herein are various methods, systems, and apparatus for reducing and eliminating biofilms from hydrocarbons. A combination of oxidizing agents and radiation of certain wavelengths forms a synergistic reaction. The synergistic reaction generates EMODs, which are effective in reducing microbial count and eliminating or blocking biofilm formation, particularly in anaerobic environments. This synergistic reaction has a relationship to EMOD creation and has a detrimental effect on Microbial Contamination (MC), Microbial Influenced Corrosion (MIC) and biofilm creation. MC, MIC and biofilm can be eliminated or greatly reduced with the treatment methods in or on equipment including pipelines, storage tanks, and refinery processing equipment.

Abstract: Methods of inhibiting corrosion of metal surfaces by aqueous acids are described. The methods include combining an effective amount of a corrosion inhibitor composition with an aqueous acid solution to form an inhibited acid solution and contacting a metal surface with the inhibited acid solution. The corrosion inhibitor composition includes an aromatic ketone or a salt thereof.

Abstract: Various embodiments disclosed related to methods, compositions, and systems for treatment of a subterranean formation. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a crosslinkable viscosifier polymer. The crosslinkable viscosifier polymer can include an ethylene repeating unit including a —C(O)NH2 group and an ethylene repeating unit including an —S(O)2OR1 group, wherein the repeating units are in block, alternate, or random configuration. At each occurrence R1 can be independently selected from the group consisting of —H and a counterion. The composition can also include at least one crosslinker. The method also includes placing the composition in a subterranean formation downhole.

Abstract: Highly resilient carbon-based materials having a resiliency greater than about 120% at 10,000 psi may be useful as lost circulation materials (LCMs) for wellbore strengthening and lost circulation mitigation in downhole operations in subterranean formations with depleted zones. For example, a downhole method may include drilling at least a portion of a wellbore penetrating a subterranean formation with at least one depleted zone having a plurality of fractures extending from the wellbore into the at least one depleted zone; circulating a treatment fluid through the wellbore, the treatment fluid comprising a base fluid and a resilient carbon-based material having a resiliency greater than about 120% at 10,000 psi; contacting the at least one depleted zone with the resilient carbon-based material; and plugging at least some of the plurality of fractures in the at least one depleted zone with the resilient carbon-based material.

Abstract: An actively controlled self-adjusting earth-boring tool includes a body carrying cutting elements and an actuation device disposed at least partially within the body. The actuation device may include a first fluid chamber, a second fluid chamber, and a reciprocating member dividing the first fluid chamber from the second fluid chamber. A connection member may be attached to the reciprocating member and may have a drilling or bearing element connected thereto. A first fluid flow path may extend from the second fluid chamber to the first fluid chamber. A second fluid flow path may extend from the first fluid chamber to the second fluid chamber. A rate controller may control a flowrate of a hydraulic fluid through the first and second fluid flow paths. The rate controller may include an electromagnet, and the flowrates of the hydraulic fluid may be adjusted by adjusting fluid properties of the hydraulic fluid.

Abstract: A method and wellbore fluid using Curaua fiber to prevent or cure loss circulation during well operations. The wellbore fluid includes a base fluid and a plurality of Curaua fibers. The wellbore fluid may include concentration up to 120 lb/bbl Curaua fibers. The base fluid may include at least one of water-based fluid, brine-based fluid, oil-based fluid, synthetic-based fluid, or Pneumatic-drilling fluid system. The water-based fluids may further include at least one of seawater, brine, saturated brine, or formate brine. The water-based fluid may include a dispersed system. The water-based fluid may further include a non-dispersed system. The oil-based fluid may include at least one of diesel, mineral oil, and low-toxicity linear olefins and paraffins. The synthetic-based fluid may include at least one of one of esters, internal olefins and linear paraffins. The oil-based and the synthetic-based fluids may further include lime.

Abstract: The present disclosure relates to compositions, systems and methods for removing iron sulfide scale from a solid object, such as an oilfield component. The compositions include a carbon-carbon (C—C) double bond with an electron withdrawing group bonded to at least one of the double-bonded carbons.

Abstract: Disclosed herein is a nanoparticle modified fluid that includes nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 50 nanometers; nanoparticles that are surface modified to increase a viscosity of the nanoparticle modified fluid and that have at least one dimension that is less than or equal to about 70 nanometers; and a liquid carrier; wherein the nanoparticle modified fluid exhibits a viscosity above that of a comparative nanoparticle modified fluid that contains the same nanoparticles but whose surfaces are not modified, when both nanoparticle modified fluids are tested at the same shear rate and temperature.

Abstract: The lubricating base oil of the present invention comprises an ester synthesized from: a first component that is at least one selected from polyhydric alcohols having 2 to 4 hydroxyl groups; a second component that is at least one selected from polybasic acids having 6 to 12 carbon atoms; and a third component that is at least one selected from monohydric alcohols having 4 to 18 carbon atoms and monocarboxylic acids having 2 to 12 carbon atoms. In addition, the refrigerating machine oil and the working fluid composition for a refrigerating machine of the present invention each comprise the above lubricating base oil.

Abstract: Phospho-friction reducing agents may include phosphonates, thiophosphonates, and derivatives thereof. The phospho-friction reducing agents may be included in drilling fluids with oleaginous base fluids and used in methods that involve drilling a wellbore penetrating a subterranean formation. Further, the phospho-friction reducing agents may be useful at relatively low concentrations in the drilling fluids (e.g., about 0.001 v/v % to about 0.5 v/v % of the drilling fluid).

Abstract: Apparatus, computer readable media, method and program code for determining well characteristics and pore architecture for a hydrocarbon well utilizing data available from conventional/standard electronic well logs, are provided. An example apparatus is configured to perform operations which include determining the value of well constants from well log data to include calculating water saturation, free water level location, wettability, and pore throat heterogeneity, and calculating pore architecture at log resolution responsive thereto. This can be accomplished, for example, by accessing well log data from a conventional well log, determining a linear regression line responsive to parameters calculated from the well log data, the linear regression line having a slope and an intercept, and determining a value of each of a plurality of well constants responsive to a value of the slope and of the intercept of the linear regression line.

Abstract: A system for cementing a wellbore penetrating an earth formation into which a pipe extends. A cement material is positioned in the space between the wellbore and the pipe by circulated capsules containing the cement material through the pipe into the space between the wellbore and the pipe. The capsules contain the cementing material encapsulated in a shell. The capsules are added to a fluid and the fluid with capsules is circulated through the pipe into the space between the wellbore and the pipe. The shell is breached once the capsules contain the cementing material are in position in the space between the wellbore and the pipe.

Abstract: The present invention relates to a composition and method for inhibiting the formation of naphthenate solids in a liquid hydrocarbon. The method includes contacting a composition including a rosin amine having a formula (I): or (II): where formula (AA): represents a single or double bond; R1, R2 and R5 each independently represent H, alkyl, alkenyl or an alkynyl group each having between one and ten carbon atoms, —(R3O)nR4 wherein R3 is an alkyl group having 1 to 3 carbon atoms and R4 is H, alkyl, alkenyl or an alkynyl group each having between one and ten carbon atoms; n is an integer between 5 and 50; X is a halide, sulphate, phosphate or acetate ion; and a demulsifier intermediate with the liquid hydrocarbon.

Abstract: A process of making observations of a subterranean reservoir penetrated by a wellbore uses distinguishable sets of tracer particles and comprises steps of: (i) delivering a plurality of sets of tracer particles to respective subterranean locations via the wellbore, the particles in each set comprising a tracer substance which distinguishes that set form the other sets; (ii) causing or allowing the tracer substances to flow out from the tracer particles whilst the particles are at the respective subterranean locations; (iii) causing or allowing production of fluid out of said reservoir via the wellbore; and (iv) detecting the presence or absence of the tracer substances in the produced fluid. The tracer substances are sufficiently distinguishable from each other to enable a tracer substance detected in the produced fluid to identify the set of tracer particles from which it has come and hence identify the location from which it has come.

Abstract: The invention relates to a method for producing expanded glass granules. To this end, starting materials are provided, comprising 80% to 95% glass and 5% to 20% sodium silicate hydrate having a water of crystallization content between 1 and 2 wt %, in relation to the solids content. After the glass is ground, the starting materials are mixed, the ground starting materials are granulated into raw granules, and the raw granules are mixed with a release agent, the mixture comprising the raw granules and the release agent is heated to a processing temperature. In a first partial step, the pores on the surfaces of the particles of the raw granules are closed, and in a second partial step, the water of crystallization is dissolved from the sodium silicate hydrate and caused to thermally expand, whereby the particles of the raw granules expand and form the expanded glass granules.

Abstract: A method for controlling the loss of drilling fluid from an oil well borehole into formations penetrated by a drill bit is disclosed by which resilient graphitic carbon particles having a resiliency greater than about 130% rebound after compression to 10,000 psi; a degree of graphitization greater than 85%, as measured by d002 using XRD; an average pore size larger than 0.035 micron; and an aspect ratio smaller than 0.63 are added to the drilling fluid.

Abstract: Embodiments disclosed herein relate to methods for stabilizing shales while drilling a wellbore into an earthen formation comprising circulating an aqueous based wellbore fluid in the wellbore while drilling through shales; wherein the aqueous-based wellbore fluid comprises a copolymer of acrylamide-type comonomers and at least one cationic comonomer.

Abstract: Of the many compositions and methods provided herein, one example composition includes a treatment fluid comprising: an aqueous fluid; and a tar stabilizing polymer comprising at least one polymer selected from the group consisting of a styrene polymer, an acrylate polymer, a styrene-acrylate polymer, and any combination thereof.

Abstract: The present invention relates to a method of treating a subterranean formation. The present invention also relates to a method of delivering an acid to a subterranean formation. The methods include obtaining or providing a composition that includes filter cake breaker, viscosifier, corrosion inhibitor, and pH buffering agent. The methods also include contacting the composition with a subterranean material downhole. The present invention also relates to a composition for the treatment of a subterranean formation. The composition includes: filter cake breaker, viscosifier, corrosion inhibitor, pH buffering agent, and at least one of drilling fluid, stimulation fluid, fracturing fluid, spotting fluid, clean-up fluid, production fluid, completion fluid, remedial treatment fluid, abandonment fluid, pill, acidizing fluid, cementing fluid, and packer fluid.

Abstract: Mineral particles may provide for wellbore fluids with tailorable properties and capabilities. In some instances, a dry wellbore additive may comprise a plurality of first mineral particles having a specific gravity of about 2.6 to about 20; a plurality of second mineral particles having a specific gravity of about 5.5 to about 20; a plurality of lubricant particles having a specific gravity of about 2.6 to about 20; wherein the first mineral particles, the second mineral particles, and the lubricant particles are different; and wherein the first mineral particles, the second mineral particles, and the lubricant particles have a multiparticle specific gravity of about 3 to about 20.

Abstract: Among the methods provided is a method of drilling a subterranean well with an invert emulsion fluid comprising: providing an invert emulsion fluid formed by combining components that comprise: an oil-based continuous phase; an aqueous discontinuous phase; and a polar hydrophobic additive that comprises a polar hydrophobe, wherein the polar hydrophobic additive may substantially increases the yield point, the low-shear yield point, or both of the invert emulsion fluid relative to a fluid without a polar hydrophobic additive while limiting the change in the plastic viscosity to no more than about 35% of the change in the property with the largest increase; and placing the invert emulsion fluid in a subterranean formation.

Abstract: An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mud cake. The mixture of particles and blend of fibers may be added to water based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application.

Abstract: A method of servicing a wellbore in contact with a subterranean formation, comprising placing a wellbore servicing fluid comprising a drilling fluid and lost circulation material into a lost circulation zone within the wellbore, wherein the lost circulation material comprises a polyelectrolyte multilayer material and a first counterion. A wellbore servicing fluid comprising a drilling fluid and a lost circulation material comprising a polyelectrolyte multilayer material and a counterion comprising a halide, wherein the LCM has a first state that is hydrophilic. A tunable lost circulation material comprising a base material, a polyelectrolyte multilayer on said base material, wherein the polyelectrolyte multilayer comprises a first electrolyte layer, a second electrolyte layer, and a charged surface, and a counterion, wherein wettability of the lost circulation material is a function of the counterion.

Abstract: Complementary surfactant systems and downhole fluids made using the systems are disclosed along with methods for making and using same, where the surfactant systems include from 0 wt. % to 100 wt. % of a first surfactant subsystem, from 100 wt. % to 0 wt. % of a second surfactant subsystem, and from 0 wt. % to 100 wt. % of a solvent subsystem based on the wt. % of the surfactant subsystems, where the system is tailored to foam the fluid including the analyzed crude and/or condensate.