WO2016183140A1 - Fluides de puits de forage assurant une stabilité accrue et un couple réduit aux puits de forage - Google Patents

Fluides de puits de forage assurant une stabilité accrue et un couple réduit aux puits de forage Download PDF

Info

Publication number
WO2016183140A1
WO2016183140A1 PCT/US2016/031757 US2016031757W WO2016183140A1 WO 2016183140 A1 WO2016183140 A1 WO 2016183140A1 US 2016031757 W US2016031757 W US 2016031757W WO 2016183140 A1 WO2016183140 A1 WO 2016183140A1
Authority
WO
WIPO (PCT)
Prior art keywords
wellbore fluid
wellbore
alkyl
fluid
group
Prior art date
Application number
PCT/US2016/031757
Other languages
English (en)
Inventor
James Friedheim
Gabriel MANESCU
Original Assignee
M-I L.L.C.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by M-I L.L.C. filed Critical M-I L.L.C.
Priority to CA2985746A priority Critical patent/CA2985746A1/fr
Publication of WO2016183140A1 publication Critical patent/WO2016183140A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions

Definitions

  • a drilling fluid may act to remove drill cuttings from the bottom of the hole to the surface, to suspend cuttings and weighting material when circulation is interrupted, to control subsurface pressures, to maintain the integrity of the wellbore until the well section is cased and cemented, to isolate the fluids from the formation by providing sufficient hydrostatic pressure to prevent the ingress of formation fluids into the wellbore, to cool and lubricate the drill string and bit, and/or to maximize penetration rate.
  • Water-based drilling fluids are often selected for use in a number of hydrocarbon plays, because of the lower associated cost and increased environmental compatibility as compared to oil-based drilling fluids often thought to be the first option in drilling operations.
  • other concerns beyond cost effectiveness may also be involved in the selection of wellbore fluids, such as the type of formation through which the well is being drilled.
  • subterranean formations may be at least partly composed of reactive clays, including shales, mudstones, siltstones, and claystones, that swell in the presence of water.
  • clays When dry, clays may lack sufficient water for the constituent particles to adhere to each other, creating a region of friable and brittle solids.
  • the clays may be liquid-like with very little inherent strength, and may become unstable and mobile when contacted with a circulating wellbore fluid. In the intermediate stages between these extremes, clays may have the form of a sticky plastic solid with increased agglomeration properties and inherent strength. While drilling in clay-containing formations, operators may encounter a number of problems encountered that may include bit balling, swelling or sloughing of the wellbore, stuck pipe, and dispersion of drill cuttings into the surrounding wellbore fluid.
  • embodiments disclosed herein relate to wellbore fluids containing an aqueous base fluid, a ROP enhancer, and a shale dispersion inhibitor, wherein the volume ratio of the ROP enhancer to the shale dispersion inhibitor is greater than 1 : 1.
  • methods may include circulating a wellbore fluid into a wellbore, wherein the wellbore fluid contains an aqueous base fluid, a ROP enhancer, and a shale dispersion inhibitor, and wherein the volume ratio of the ROP enhancer to the shale dispersion inhibitor is greater than 1 : 1.
  • embodiments disclosed herein relate to water-based wellbore fluid compositions for use in formations containing reactive clays and other materials that may swell in the presence of aqueous fluids.
  • Wellbore fluids in accordance with the present disclosure may be formulated to include rate of penetration (ROP) enhancers that improve drilling speed and reduce torque.
  • wellbore fluids may also combine ROP enhancers with a shale inhibitor at select ratios that promote retention of the wellbore fluid within the wellbore and prevent fluid loss due to absorption by clays and other hydrophilic minerals.
  • the combination of ROP enhancer and shale inhibitor may stabilize clay-containing formations and inhibit the dispersion of clay cuttings, reducing formation damage and undesirable changes in wellbore fluid rheology.
  • alkyl refers to a saturated straight chain, branched or cyclic hydrocarbon group in particular embodiments.
  • the hydrocarbon group may be selected from, for example, methyl, ethyl, n-propyl, isopropyl, n-butyl, isobutyl, sec-butyl, t-butyl, pentyl, cyclopentyl, isopentyl, neopentyl, hexyl, isohexyl, cyclohexyl, 3-methylpentyl, 2,2-dimethylbutyl, and 2,3-dimethylbutyl.
  • cycloalkyl refers to cyclic alkyl groups such as cyclopropyl, cyclobutyl, cyclopentyl, cyclohexyl, cycloheptyl and cyclooctyl.
  • alkyl includes "modified alkyl", which references an alkyl group having from one to twenty-four carbon atoms, and further having additional groups, such as one or more linkages selected from ether-, thio-, amino-, phospho-, oxo-, ester-, and amido-, and/or being substituted with one or more additional groups including lower alkyl, phenyl, polycyclic alkyl, polycyclic aromatics, alkoxy, thioalkyl, hydroxyl, amino, sulfonyl, thio, mercapto, imino, halo, cyano, nitro, nitroso, azide, carboxy, sulfide, sulfone, sulfoxy, phosphoryl, silyl, silyloxy, and boronyl.
  • additional groups such as one or more linkages selected from ether-, thio-, amino-, phospho-, oxo-, ester-, and amido-,
  • alkoxy refers to a substituent -O-R wherein R is alkyl as defined above.
  • lower alkoxy refers to such a group wherein R is lower alkyl.
  • thioalkyl refers to a substituent -S-R wherein R is alkyl as defined above.
  • alkoxy ether refers to a substituent -O- wherein Ri and R 2 are independently alkyl groups as defined above, and where X may be any integer between 1 and 10.
  • alkylene refers to a bivalent saturated alkyl chain (such as ethylene) regarded as derived from an alkene by opening of the double bond or from an alkane by removal of two hydrogen atoms from different carbon atoms.
  • alkenyl refers to a branched, unbranched or cyclic (e.g. in the case of C5 and C6) hydrocarbon group of 2 to 30, or 2 to 12 in some embodiments, carbon atoms containing at least one double bond, such as ethenyl, vinyl, allyl, octenyl, decenyl, dodecenyl, and the like.
  • lower alkenyl intends an alkenyl group of two to eight carbon atoms, and specifically includes vinyl and allyl.
  • cycloalkenyl refers to cyclic alkenyl groups.
  • Wellbore operations in shale and other clay-containing formations may face adverse conditions when clays downhole swell in the presence of aqueous wellbore fluids.
  • bit balling occurs when cutting stick to the bit surface in water reactive formations, which may cause drilling equipment to skid on the bottom of the hole preventing it from penetrating uncut rock, therefore slowing the rate of penetration.
  • the overall increase in bulk volume accompanying clay swelling impacts the stability of the borehole, increases friction between the drill bit and the sides of the borehole, and inhibits wellbore fluid additive buildup, or filter cake, that seals the formation and decreases wellbore fluid penetration.
  • Clay minerals encountered in subterranean formations are often crystalline in nature, which can dictate the response observed when exposed to wellbore fluids.
  • Clays may have a flaky, mica-type structure made up of crystal platelets stacked face-to-face. Each platelet is defined as a unit layer, and the surfaces of the unit layer are basal surfaces.
  • Each unit layer is composed of multiple sheets, which may include octahedral sheets and tetrahedral sheets.
  • Octahedral sheets are composed of either aluminum or magnesium atoms octahedrally coordinated with the oxygen atoms of hydroxyls, whereas tetrahedral sheets contain silicon atoms tetrahedrally coordinated with oxygen atoms.
  • atoms having different valences may be positioned within the sheets of the structure to create a negative potential at the crystal surface, which causes cations to be adsorbed thereto. These adsorbed cations are called exchangeable cations because they may chemically trade places with other cations when the clay crystal is suspended in water.
  • ions may also be adsorbed on the clay crystal edges and exchange with other ions in the water.
  • Clay swelling is the phenomenon in which water molecules surround a clay crystal structure and position themselves to increase the structure's d-spacing, which results in a measureable increase in volume. Two types of swelling may occur: surface hydration and osmotic swelling.
  • Osmotic swelling is another type of swelling observed in clays. Where the concentration of cations between unit layers in a clay mineral is higher than the cation concentration in the surrounding water, water is osmotically drawn between the unit layers and the d-spacing is increased. Osmotic swelling results in larger overall volume increases than surface hydration, and only a limited number of clays, like sodium montmorillonite, swell in this manner.
  • clay swelling may be inhibited through the use of a combination of ROP enhancers and shale inhibitors that may reduce swelling and reactivity of clays when conducting wellbore operations in clay-containing formations. While not limited by any particular theory, it is believed that increasing the concentration of ROP enhancer with respect to a shale inhibitor component within wellbore fluid results in a favorable modification of the ability of the wellbore fluid to reduce water penetration and clay swelling.
  • wellbore fluids may include an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid, an aqueous base fluid
  • ROP enhancer a shale inhibitor, and other wellbore fluid additives such as an encapsulating agent that may be present depending on the particular application.
  • Wellbore fluids in accordance with the present disclosure may be used in shale formations or formations containing regions of intercalated clay during drilling operations, specialty applications as displacement fluids, used in pill formulations, and during completions.
  • wellbore fluids of the present disclosure may be used in drilling a horizontal section of a well containing intercalated clay and may do so in manner that increases the ROP to near or even better than what would be achieved with an oil-based fluid.
  • Wellbore fluids in accordance with embodiments of the present disclosure may include rate of penetration (ROP) enhancers that reduce accretion of cuttings onto a drill bit, and enhance penetration rates the when drilling through reactive clay-containing formations.
  • ROP rate of penetration
  • structure for ROP enhancers may vary, the chemical structure may be categorized as having a hydrophobic portion that associates with clays and other surfaces and a hydrophilic portion that increases the solubility of the molecule in aqueous solutions.
  • the ROP enhancer may be a fatty acid including fatty acids derived from natural fats and oils.
  • fatty acids derived from natural fats and oils For example, tall-oil fatty acids are distilled from conifer trees. Animal and vegetable fats and oils may be hydrolyzed to give fatty acids. Fatty acids from animals are mostly saturated acids, having single bonds between carbon atoms. Tall oils and vegetable oils yield both saturated and unsaturated (double- and triple-bond) fatty acids.
  • suitable fatty acids may also include cyclic and aromatic fatty acids such as abietic acid, palmiric acid, and other acids derived from natural sources.
  • the ROP enhancer may include fatty acids having the general formula XR ⁇ R 2 , where X may be a counter ion such as an alkaline or alkali metal, ammonium, or be a covalent hydrogen; R 1 is an acidic functional group capable of forming an anion such as a carboxylic acid or a sulfate group, and R 2 is an alkyl, phenyl alkyl, cycloalkyl, polycyclic alkyl, or polycyclic aromatic alkyl group having 3-22 carbon atoms.
  • ROP enhancers in accordance with the present disclosure may also be a fatty acid selected from butyric acid, valeric acid, caproic acid, enanthic acid, caprylic acid, pelargonic acid, capric acid, lauric acid, mysristic acid, palmitic acid, stearic acid, in addition to unsaturated fatty acids such as myristoleic acid, palmitoleic acid, oleic acid, linoleic acid, alpha-linoleic acid, erucic acid, and the like.
  • the compounds may also have a small degree of substitution and/or branching, or may be sulfonic or phosphonic derivatives thereof.
  • ROP enhancers may be selected from commercial reagents such as HYDRASPEEDTM, available from M-I L L C. (Houston, TX).
  • the field concentration of ROP enhancer may be from 0.5% to 5% by volume of the wellbore fluid.
  • the concentration of ROP enhancer may be from 1.5% to 4.5% by volume of the wellbore fluid in some embodiments, and from 2% to 4% by volume of the wellbore fluid in yet other embodiments.
  • Wellbore fluids in accordance with the present disclosure may also contain shale inhibitors that reduce clay dispersion, stabilizing the clay particles and preventing formation damage and dissolution that would otherwise alter the wellbore fluid composition and rheology. Further, shale inhibitors may decrease or eliminate water uptake by reactive shales, thereby preventing fluid loss to clay-rich formations.
  • shale inhibitors may include alkyl amines containing one or more amino groups, and oligomers and polymers of amino-substituted compounds.
  • suitable alkyl amines may be molecules containing one or more amino groups that may be primary, secondary, tertiary, or quaternary.
  • alkyl amines may have of varying levels of alkyl substitution including, for example, tertiary amines such as trimethylamine and triethylamine, and tetra- substituted alkyl amines such as alkyl quaternary ammonium compounds typified by tetraethylammonium, tetrabutylammonium, choline, and the like; and alkylbenzyl quaternary ammonium compounds including one or more alkyl chains and one or more aromatic groups such as benzyltrimethylammonium, benzyltriethylammonium, and the like.
  • alkyl substitution including, for example, tertiary amines such as trimethylamine and triethylamine, and tetra- substituted alkyl amines such as alkyl quaternary ammonium compounds typified by tetraethylammonium, tetrabutylammonium, choline, and
  • the shale inhibitor may be a difunctional primary amine [H 2 N— R— H 2 ] such as butylene diamine, pentamethylene diamine, hexamethylene diamine, difunctional secondary and tertiary diamines, and the like.
  • Shale inhibitors may also include alkyl quaternary ammonium compounds having alkyl substituents independently selected from alkyl chain lengths ranging from 1 to 6 carbons in length, aromatic groups such as benzyl or phenyl groups, hydroxyl-substituted alkyl, and cycloalkyl groups such as cyclopentyl or cyclohexyl.
  • shale inhibitors may include mixed alkyl quaternary amines prepared from the reaction of trihydroxyalkyl amines with various alkyl halides.
  • Suitable shale inhibitors also include polyamines having two or more amino groups, at least one of which is present in an alkyl chain, such as a polyalkylene amine, and polyamines containing two or more amino groups as pendant groups from an alkyl chain, such as a polyallylamine.
  • Amino groups in the polyamines may be primary, secondary, tertiary, or quaternary.
  • Polyamines in accordance with the present disclosure may include spermine, spermidine, amidine, protamine, 1,6-diaminocyclohexane, cyclic amines including piperazine, cyclen, and the like.
  • Shale inhibitors in accordance with the present disclosure may also include polyether amines and polyalkylene amines.
  • polyamines may be a polyetheramine such as those commercially available under the trade name JEFF AMINE® from Huntsman Performance Products (Woodlands, TX).
  • JEFF AMINE® products may include triamines JEFF AMINE® T-5000 and JEFF AMINE ® T-3000, and diamines such as JEFF AMINE® D-400, D-230, and D-2000.
  • polyamine additives may be selected from commercial shale inhibitors such as ULTRAHIB , KLASTOP , KLAGARD , KLACURE , HYDRAHIB , HIB 933TM, and KLAHIBTM, available from M-I L.L.C. (Houston, TX).
  • commercial shale inhibitors such as ULTRAHIB , KLASTOP , KLAGARD , KLACURE , HYDRAHIB , HIB 933TM, and KLAHIBTM, available from M-I L.L.C. (Houston, TX).
  • Shale inhibitors of the present disclosure may be combined with a wellbore fluid in concentrations sufficient to inhibit clay swelling for a particular formation in a given geographic region.
  • the field concentration of shale inhibitor may be from 0.5% to 5% by volume of the wellbore fluid. In other embodiments, the concentration of shale inhibitor may be from 1% to 3% by volume of the wellbore fluid.
  • Shale hydration rates may depend in part on the pH of the wellbore fluid. At elevated pH, shale hydration may occur more rapidly than at lower pH, and shale inhibitors may be selected to minimize this effect.
  • shale inhibitors may be amino-containing compounds having reduced basicity such that addition of these compounds to a wellbore fluid maintains the pH within a weakly basic range.
  • the shale inhibitor may maintain the pH of the wellbore fluid in the pH range of pH 8 to pH 12.
  • the shale inhibitor may maintain the pH of the wellbore fluid in the pH range of pH 8.5 to pH 11.
  • a wellbore fluid may be formulated such that the volume ratio of the ROP enhancer to the shale dispersion inhibitor is greater than 1 : 1.
  • volume ratio of the ROP enhancer to the shale dispersion inhibitor is greater than 1 : 1
  • the ratio of the ROP enhancer to the shale inhibitor may be 1.01 : 1, 2: 1, 3 : 1, etc.
  • wellbore fluids may contain an encapsulating agent selected from the group of synthetic organic, inorganic and bio-polymers and mixtures thereof.
  • the role of the encapsulating agent is to absorb at multiple points along the chain onto the clay particles, thus binding the particles together and encapsulating the cuttings.
  • These encapsulating agents help improve the removal of cuttings with less dispersion of the cuttings into the drilling fluids.
  • the encapsulating agents may be anionic, cationic, amphoteric, or non-ionic in nature and may also include larger molecular weight polymers that remedy fluid loss and decrease formation permeability
  • Encapsulating agents in accordance with the present disclosure may include polymers, copolymers, block copolymers, and higher order copolymers (i.e., a terpolymer or quaternary polymer, etc.) composed of monomers that may include 2- acrylamido-2-methylpropanesulfonate, aciylamide, acrylic acid, methacrylic acid, diallyldimethyl ammonium chloride, methacrylamide, N,N dimethyl aciylamide, N,N dimethyl methacrylamide, tetrafluoroethylene, dimethylaminopropyl methacrylamide, N- vinyl -2-pyrrolidone, N-vinyl-3-methyl-2-pyrrolidone, N-vinyl-4,4-diethyl-2- pyrrolidone, 5-isobutyl-2-pyrrolidone, N-vinyl-3-methyl-2-pyrrolidone, alkyl oxazoline, poly(2-ethyl-
  • polyamine shale inhibitors may include copolymers of acrylamide-type comonomers and at least one cationic amino-containing comonomer (e.g., diallyldimethyl ammonium chloride, DADMAC).
  • encapsulating agents may also include polylysine, cationic polymers such as polyallylamine, polyethyleneimine (PEI), polydiallyldimethylammonium halide, chitosan, or mixtures of polyamines.
  • the encapsulating agent may include polyacrylates having varying levels of alkoxy substitution, such as 5% to 50% of the available carboxylate moieties of the polyacrylate, including hydroxyethyl aciylate, hydroxypropyl aciylate (HP A), and the like.
  • Encapsulating agents may also include anionic wellbore fluid additives such as polyanionic carboxymethylcellulose (PAC), partially-hydrolyzed polyacrylamides (PHP A), and the like.
  • encapsulating agents may be selected from commercial reagents such as POLYPLUSTM LV, ULTRACAPTM, IDCAPTM D, HYDRACAPTM and KLACAPTM, all of which are available from M-I L L C. (Houston, TX).
  • Wellbore fluids in accordance with embodiments disclosed herein may contain encapsulating agents in an amount ranging from 0.5 to 5 pounds per barrel; however, more or less may be used depending on the characteristics of the particular formation and the composition of the selected fluid.
  • Wellbore fluids may contain a base fluid that is entirely aqueous base or contains a full or partial oil-in-water emulsion.
  • the wellbore fluid may be any water-based fluid that is compatible with the shale hydration inhibition agents disclosed herein.
  • the fluid may include at least one of fresh water, mixtures of water and water soluble organic compounds and mixtures thereof.
  • the wellbore fluid may contain a brine such as seawater, aqueous solutions wherein the salt concentration is less than that of sea water, or aqueous solutions wherein the salt concentration is greater than that of sea water.
  • Salts that may be found in seawater include, but are not limited to, sodium, calcium, aluminum, magnesium, potassium, strontium, lithium, and salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, sulfates, phosphates, silicates and fluorides.
  • Salts that may be incorporated in a given brine include any one or more of those present in natural seawater or any other organic or inorganic dissolved salts.
  • brines that may be used in the drilling fluids disclosed herein may be natural or synthetic, with synthetic brines tending to be much simpler in constitution.
  • the above salts may be present in the base fluid or may be added according to the method disclosed herein.
  • the amount of the aqueous based continuous phase should be sufficient to form a water based drilling fluid. This amount may range from nearly 100% of the wellbore fluid to less than 30% of the wellbore fluid by volume. In some embodiments, the aqueous based continuous phase may constitute from about 95 to about 30% by volume or from about 90 to about 40%) by volume of the wellbore fluid.
  • the wellbore fluids may also include viscosif ing agents in order to alter or maintain the viscosity and potential changes in viscosity of the drilling fluid. Viscosity control may be needed in some scenarios in which a subterranean formation contains varying temperature zones. For example, a wellbore fluid may undergo temperature extremes of nearly freezing temperatures to nearly the boiling temperature of water or higher during the course of its transit from the surface to the drill bit and back.
  • Viscosifying agents suitable for use in the formulation of the fluids of the present disclosure may be generally selected from any type of natural biopolymer suitable for use in aqueous based drilling fluids.
  • Biopolymers may include starches, celluloses, and various gums, such as xanthan gum, gellan gum, welan gum, and schleroglucan gum.
  • Such starches may include potato starch, corn starch, tapioca starch, wheat starch and rice starch, etc.
  • the biopolymer viscosifying agents may be unmodified (i.e., without derivitization).
  • Polymeric viscosifiers may include, for example, POLYP AC ® UL polyanionic cellulose (PAC), DUOVIS ® , and BIOVIS ® , each available from M-I L.L.C. (Houston, TX).
  • PAC POLYP AC ® UL polyanionic cellulose
  • BIOVIS ® BIOVIS ®
  • the wellbore fluids of the present disclosure may include a weight material or weighting agent in order to increase the density of the fluid.
  • the primary purpose for such weighting materials is to increase the density of the fluid so as to prevent kick-backs and blow-outs.
  • the weighting agent may be added to the drilling fluid in a functionally effective amount largely dependent on the nature of the formation being drilled.
  • Weighting agents or density materials suitable for use the fluids disclosed herein include the salts used to form the brine used as the base fluid, as well as solid weighting agents such as galena, hematite, magnetite, iron oxides, illmenite, barite, siderite, celestite, dolomite, calcite, and the like, mixtures and combinations of these compounds and similar such weight materials that may be used in the formulation of wellbore fluids.
  • the quantity of such material added, if any, may depend upon the desired density of the final composition.
  • the methods of the present disclosure may include providing a wellbore fluid (e.g., a drilling fluid, reservoir drill-in fluid, fracturing fluid, etc.) that contains an aqueous base fluid, a ROP enhancer, and a shale inhibitor, and placing the wellbore fluid in a subterranean formation.
  • a wellbore fluid e.g., a drilling fluid, reservoir drill-in fluid, fracturing fluid, etc.
  • the selected additives may be mixed into the wellbore fluid individually or as a multi-component additive that contains ROP enhancer and shale inhibitor, and/or other components.
  • the additives may be added to the wellbore fluid prior to, during, or subsequent to placing the wellbore fluid in the subterranean formation.
  • a wellbore fluid according to the disclosure may be used in a method for drilling a well into a subterranean formation in a manner similar to those wherein conventional wellbore fluids are used.
  • a wellbore fluid is circulated through the drill pipe, through the bit, and up the annular space between the pipe and the formation or steel casing to the surface.
  • the wellbore fluid performs several different functions, such as cooling the bit, removing drilled cuttings from the bottom of the hole, suspending the cuttings and weighting the material when the circulation is interrupted.
  • the ROP enhancer and shale inhibitor may be added to a base fluid on location at a well-site where it is to be used, or it can be carried out at another location than the well-site. If the well-site location is selected for carrying out this step, the ROP enhancer and shale inhibitor may be dispersed in an aqueous fluid, and the resulting wellbore fluid may be emplaced in the well using techniques known in the art.
  • Another embodiment of the present method includes a method of reducing the swelling of shale in a well whereby a water-base fluid formulated in accordance with the teachings of this disclosure is circulated in a well.
  • the methods and fluids of the present disclosure may be utilized in a variety of subterranean operations that involve drilling, drilling-in (without displacement of the fluid for completion operations), and fracturing.
  • suitable subterranean drilling operations include, but are not limited to, water well drilling, oil/gas well drilling, utilities drilling, tunneling, construction/installation of subterranean pipelines and service lines, and the like.
  • wellbore fluids in accordance with the present disclosure may be used to stimulate the fluid production.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Medicinal Preparation (AREA)

Abstract

La présente invention concerne des fluides de puits de forage et des procédés d'utilisation de ceux-ci. Des fluides de puits de forage peuvent comprendre un fluide de base aqueux, un activateur de vitesse de pénétration, et un inhibiteur de dispersion de schiste, le rapport en volume de l'activateur de vitesse de pénétration et de l'inhibiteur de dispersion des schistes étant supérieur à 1:1. Des procédés peuvent comprendre la circulation du fluide de puits de forage.
PCT/US2016/031757 2015-05-11 2016-05-11 Fluides de puits de forage assurant une stabilité accrue et un couple réduit aux puits de forage WO2016183140A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CA2985746A CA2985746A1 (fr) 2015-05-11 2016-05-11 Fluides de puits de forage assurant une stabilite accrue et un couple reduit aux puits de forage

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201562159449P 2015-05-11 2015-05-11
US62/159,449 2015-05-11

Publications (1)

Publication Number Publication Date
WO2016183140A1 true WO2016183140A1 (fr) 2016-11-17

Family

ID=57248546

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2016/031757 WO2016183140A1 (fr) 2015-05-11 2016-05-11 Fluides de puits de forage assurant une stabilité accrue et un couple réduit aux puits de forage

Country Status (2)

Country Link
CA (1) CA2985746A1 (fr)
WO (1) WO2016183140A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2020018129A1 (fr) * 2018-07-17 2020-01-23 Saudi Arabian Oil Company Lubrifiant écologique pour applications de fluide de forage de champ pétrolifère
US11124687B2 (en) 2018-07-17 2021-09-21 Saudi Arabian Oil Company Synthesized lubricants for water-based drilling fluid systems

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050197255A1 (en) * 2004-03-03 2005-09-08 Baker Hughes Incorporated Lubricant composition
WO2010065634A2 (fr) * 2008-12-04 2010-06-10 M-I L.L.C. Lubrifiant pour boues à base d'eau et leurs procédés d'utilisation
CN103773325A (zh) * 2014-02-27 2014-05-07 西安石油大学 一种具有润滑作用黏土防膨剂的制备与应用
WO2014191389A1 (fr) * 2013-05-29 2014-12-04 Lamberti Spa Inhibiteurs du gonflement des schistes
WO2014200671A2 (fr) * 2013-06-12 2014-12-18 Meadwestvaco Corporation Inhibiteurs d'argile pour opérations de forage, de fracturation, et autres

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20050197255A1 (en) * 2004-03-03 2005-09-08 Baker Hughes Incorporated Lubricant composition
WO2010065634A2 (fr) * 2008-12-04 2010-06-10 M-I L.L.C. Lubrifiant pour boues à base d'eau et leurs procédés d'utilisation
WO2014191389A1 (fr) * 2013-05-29 2014-12-04 Lamberti Spa Inhibiteurs du gonflement des schistes
WO2014200671A2 (fr) * 2013-06-12 2014-12-18 Meadwestvaco Corporation Inhibiteurs d'argile pour opérations de forage, de fracturation, et autres
CN103773325A (zh) * 2014-02-27 2014-05-07 西安石油大学 一种具有润滑作用黏土防膨剂的制备与应用

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2020018129A1 (fr) * 2018-07-17 2020-01-23 Saudi Arabian Oil Company Lubrifiant écologique pour applications de fluide de forage de champ pétrolifère
US11124687B2 (en) 2018-07-17 2021-09-21 Saudi Arabian Oil Company Synthesized lubricants for water-based drilling fluid systems
US11472995B2 (en) 2018-07-17 2022-10-18 Saudi Arabian Oil Company Environmentally-friendly lubricant for oil field drilling fluid applications

Also Published As

Publication number Publication date
CA2985746A1 (fr) 2016-11-17

Similar Documents

Publication Publication Date Title
CA2581888C (fr) Agent d'inhibition d'hydratation du schiste argileux et son procede d'utilisation
US7012043B2 (en) Drilling fluids
US7497262B2 (en) High performance water-based drilling mud and method of use
US7084092B2 (en) Shale hydration inhibition agent and method of use
WO2016160097A1 (fr) Compositions et procédés de stabilisation de sols contenant de l'argile
NO20170565A1 (en) Shale hydration inhibitor and method of use
US20070111895A1 (en) Subterranean treatment fluids comprising polyoxazoline compositions and methods of use in subterranean formations
WO2010065634A2 (fr) Lubrifiant pour boues à base d'eau et leurs procédés d'utilisation
WO2019175792A1 (fr) Système de fluide de forage pour réguler la perte de circulation
US20100144561A1 (en) Shale hydration inhibition agent and method of use
WO2016183140A1 (fr) Fluides de puits de forage assurant une stabilité accrue et un couple réduit aux puits de forage
US20170327723A1 (en) Wellbore fluids for increased wellbore stability and reduced torque
CA3046407A1 (fr) Agent d'inhibition de l'hydratation de schiste
CA2581891C (fr) Agent d'inhibition d'hydratation de schiste et procede d'utilisation
US8598095B2 (en) Low conductivity water based wellbore fluid
WO2023055905A1 (fr) Additifs inhibiteurs de schistes, fluides de puits de forage comprenant lesdits additifs et procédé d'utilisation desdits fluides
US20080227671A1 (en) Low toxicity shale hydration inhibition agent and method of use
WO2023192475A1 (fr) Dérivatisation d'amines pour l'utilisation comme inhibiteurs de schiste dans une formation souterraine
WO2016019281A1 (fr) Fluide à base d'eau à haute efficacité

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 16793404

Country of ref document: EP

Kind code of ref document: A1

ENP Entry into the national phase

Ref document number: 2985746

Country of ref document: CA

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 16793404

Country of ref document: EP

Kind code of ref document: A1