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WO2006060388A2 - Additif de fluide de forage, et procede - Google Patents

Additif de fluide de forage, et procede Download PDF

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Publication number
WO2006060388A2
WO2006060388A2 PCT/US2005/043127 US2005043127W WO2006060388A2 WO 2006060388 A2 WO2006060388 A2 WO 2006060388A2 US 2005043127 W US2005043127 W US 2005043127W WO 2006060388 A2 WO2006060388 A2 WO 2006060388A2
Authority
WO
WIPO (PCT)
Prior art keywords
drilling fluid
wellbore
primary amine
drilling
filter cake
Prior art date
Application number
PCT/US2005/043127
Other languages
English (en)
Other versions
WO2006060388A3 (fr
Inventor
Leonard Michael Haberman
Original Assignee
Shell Internationale Research Maatschappij B.V.
Shell Canada Limited
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 Shell Internationale Research Maatschappij B.V., Shell Canada Limited filed Critical Shell Internationale Research Maatschappij B.V.
Priority to AU2005312035A priority Critical patent/AU2005312035A1/en
Priority to CA002587997A priority patent/CA2587997A1/fr
Priority to BRPI0516640-3A priority patent/BRPI0516640A/pt
Publication of WO2006060388A2 publication Critical patent/WO2006060388A2/fr
Publication of WO2006060388A3 publication Critical patent/WO2006060388A3/fr
Priority to GB0710206A priority patent/GB2435177A/en

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
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
    • 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
    • C09K8/06—Clay-free compositions
    • C09K8/08—Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
    • 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
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/20—Natural organic compounds or derivatives thereof, e.g. polysaccharides or lignin derivatives
    • C09K8/206—Derivatives of other natural products, e.g. cellulose, starch, sugars
    • 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
    • C09K8/38—Gaseous or foamed well-drilling compositions
    • 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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • 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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/514—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
    • 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
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • 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
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material

Definitions

  • the present invention relates to a drilling fluid composition and a method to provide a wellbore.
  • drilling fluids are typically circulated through a drill pipe, through the drill bit, and up an annulus around the drill pipe in order to circulate drilling cuttings out of the wellbore and to cool the drill bit.
  • This drilling fluid contains components that result in the density of the drilling fluid being a density that provides a bottom hole pressure that is about equal to or greater than the pore pressure of fluids in the formation through which the wellbore is being drilled, and also provide a pressure that is not greater than a pressure that causes the formation through which the wellbore is being drilled to fracture.
  • Drilling fluids also typically contain additives that serve other functions.
  • drilling fluids often contain solids that will form a filter cake along the wall of the wellbore in order to reduce fluid losses from the wellbore into the formation.
  • This filter cake desirably has a relatively low permeability in order to reduce the loss of fluids from the wellbore.
  • this very low permeability filter cake is undesirable when it is time to produce hydrocarbons from the formation.
  • the filter cakes Prior to production of hydrocarbons, the filter cakes are therefore preferably removed by, for example, circulation of an acid composition that will break down the solids within the filter cake. Complete removal of the filter cakes is desirable, but not readily achievable with current methods for removal of the filter cakes.
  • a filtration control additive is suggested by Clapper et al. in US patent no 4,735,732.
  • This filtration control additive is for use in inverted emulsion drilling fluids, and methods of using the fluids.
  • the additive includes a pyrolyzed product obtained by intermixing and heating finely divided humic acid-containing material and a primary amine having an alkyl radical of 10 to 20 carbon atoms or a primary amine having one alkyl- substituted phenyl radical, the alkyl radical having 10 to 20 carbon atoms.
  • Murphey et al. in US patent 6,143,698, suggests a method for removing filtercake from a subterranean borehole that includes drilling the borehole with a drilling fluid that includes additives to form a filtercake having an oxidation-degradable component.
  • the oxidation-degradable component is preferably a polysaccharide.
  • the brine contains bromide salts and an oxidant capable of delayed oxidation of the bromide to bromine at downhole conditions
  • a drilling fluid is used that includes an amine-substituted starch and an amine-substituted xanthan thickening agent.
  • the amine is preferably a diethylaminoisopropanol.
  • a polymer containing tertiary and quaternary functional groups such as a copolymer of polyethylenimine and ethylene oxide is suggested. The method relies on oxidation of the filter cake and not generation of gas to physically lift the filter cake from the wall of the wellbore.
  • Card et al. in US patent 5,979,557, suggests a method for limiting the inflow of formation water during a well turn around to maximize polymer recovery after a hydraulic fracturing treatment of a formation.
  • the method includes a step for selectively blocking the pore structure in a water-bearing zone and not blocking the pore structure of a hydrocarbon zone at the formation face; performing a hydraulic fracturing treatment using a fluid having a polymer; and turning the well around to recover the polymer.
  • the method includes a step for selectively blocking the pore structure in the water-bearing zone at the formation face to selectively retard migration of acid into the water-bearing zone; and injecting acid into the formation, wherein the acid is diverted from the water-bearing zone to the hydrocarbon zone as a result of the selective blocking step.
  • the method further includes injecting a mutual solvent prior to the step for selectively blocking.
  • the step for selectively blocking preferably forms a plug of a viscous fluid in the pore structure of the water-bearing zone at the formation face.
  • the viscous fluid preferably has at least a viscoelastic surfactant capable of forming a worm-like micelle in an aqueous environment, a water-soluble salt to effect formation stability, and an aqueous carrier fluid.
  • the present inventions include a method for drilling a wellbore comprising the steps of providing a drilling mud comprising a primary amine, circulating the drilling mud while the wellbore is being drilled wherein the primary amine is incorporated into a filter cake deposited on the wellbore wall as the wellbore is being drilled, and removing at least a portion of the filter cake after the wellbore is drilled by circulating fluid into the wellbore comprising nitrous acid.
  • the present inventions include a drilling fluid comprising between about 0.5 and about 3 percent by weight of nitrogen in the form of a primary amine.
  • the present inventions include a method of providing a wellbore in a hydrocarbon production zone comprising the steps of incorporating into a drilling fluid a solid component that forms a gas when exposed to an activating component, circulating the drilling fluid while drilling the wellbore in the hydrocarbon production zone whereby the solid component, and circulating a drilling fluid comprising the activating component after at least a portion of the wellbore within the production zone is drilled, and there by forming gas bubbles within the filter cake and causing the filter cake to at least partially release from a wall of the wellbore.
  • the drilling fluid of the present invention includes a component that generates a gas when an activating component is contacted with the solid component.
  • the component Upon circulation through a well during a drilling process, the component incorporates itself in a filtercak ⁇ against and slightly into the wall of the wellbore.
  • a slight overpressure within the wellbore forces some drilling fluid into the formation through which the wellbore is being drilled, and solids within the drilling fluid are thereby deposited on the surface of the wellbore and within pore spaces near the wellbore within the formation.
  • As drilling fluid passes into the formation more solids will deposit on the surface of the wellbore, and a filter cake will eventually form.
  • the filter cake then reduces loss of drilling fluids by creating a relatively impermeable skin on the surface and near the surface of the wall of the wellbore.
  • this skin is desirable for this skin to be removed after it has served its purpose of reducing loses of drilling fluid while drilling.
  • the drilling fluid of the present invention incorporates a component that generates a gas upon contact with an activating component.
  • the component that forms a gas is a primary amine-containing component, and the activating component includes nitrous acid.
  • the primary amine may be in the form of a solid so that it will be embedded within the filter cake.
  • a primary amine can, for example, be incorporated into a solid by grafting onto a starch or a xanthan gum, or another natural or synthetic polymer that is not soluble in the drilling fluid composition.
  • the primary amine could be a polymer such as a polyvinylformamide that has been hydrolyzed to the amine form.
  • Such a polyvinylformamide is available from BASF Corporation under the trade name Lupamin.
  • Lupamin 1595 a low molecular weight version of Lupamin designated as Lupamin 1595 or a high molecular weight version designated as Lupamin 9095, for example, may be useful.
  • the primary amine may be grafted to a starch, for example, but methods suggested by G. Mino and S. Kaizerman in Journal of Polymer Science, Vol. 31, pages 242-243.
  • eerie salts such as nitrate and sulfates
  • organic reducing agents such as, for example, alcohols, thiols, glycols, aldehydes, or amines.
  • the oxidation-reduction produces cerous ions and transient free radical species capable of initiating vinyl polymerization.
  • An exemplary graft polymer of polyacrylamide on polyvinyl alcohol may be prepared as follows: 2.5 ml.
  • This procedure may be used with starch or zanthan gum instead of the polyvinyl amide and the acrylamide could be replaced with, for example, a polyvinylformamide to produce a primary amine containing component useful in the practice of the present invention.
  • This method may be easily modified to provide grafting of primary amines onto other polymers that are not soluble in the drilling fluid composition of the present invention.
  • Such polymers may be, for example, synthetic or natural polymers.
  • the primary amine-containing component may be present in the drilling fluid composition in a concentration of, for example, about 0.1 to about 10 percent by weight nitrogen, and in another embodiment, from about 0.5 to about 3 percent by weight nitrogen in the drilling fluid composition.
  • the primary amine may be applied in a liquid form, but a solid may offer an advantage of concentrating in the filter cake and remaining in the filter cake until removal was initiated by contact with the nitrous acid composition.
  • An acid solution used to remove the filter cake may be formed by combining a solution of sodium nitrite with a mineral acid such as hydrochloric acid.
  • the sodium nitrite when combined with the acid, becomes nitrous acid, and will rapidly convert the primary amine functional groups to diazo functional groups, which further decompose to olefin and nitrogen gas.
  • the acid may further decompose the filter cake components by normal acid attack, but the action of generation of the nitrogen gas will have created permeability within the filter cake, breaking up the filter cake, and lifting the filter cake from the wellbore wall, and greatly enhance removal of the filter cake.
  • nitrous acid solution having a pH of, for example, 4 or less, or alternatively, 1 to 3, to remove the filter cake from the wellbore.
  • a shale hydration inhibition agent may be present in sufficient concentration to reduce either or both the surface hydration based swelling and/or the osmotic based swelling of the shale.
  • the exact amount of the shale hydration inhibition agent present in a particular drilling fluid formulation may be determined by a trial and error method of testing the combination of drilling fluid and shale formation encountered.
  • the shale hydration inhibition agent may be used in drilling fluids in a concentration from about 1 to about 18 pounds per barrel (lbs/bbl or ppb) (about 2.852 to about 51.34 gm/1) and more preferably in a concentration from about 2 to about 12 pounds per barrel (about 5.704 to about 34.22 gm/1) of drilling fluid.
  • the drilling fluids of the some embodiments of the present invention include a weight material in order to increase the density of the fluid.
  • the primary purpose for such weighting material is to increase the density of the drilling fluid so as to prevent kickbacks and blow-outs.
  • kickbacks and blow-outs are important to the safe day-to-day operations of a drilling rig.
  • the weight material is added to the drilling fluid in a functionally effective amount largely dependent on the nature of the formation being drilled.
  • Weight materials suitable for use in the formulation of the drilling fluids of the present invention may be generally selected from any type of weighting materials be it in solid, particulate form, suspended in solution, dissolved in the aqueous phase as part of the preparation process or added afterward during drilling. It is preferred that the weight material be selected from the group including barite, hematite, iron oxide, calcium carbonate, magnesium carbonate, organic and inorganic salts, and mixtures and combinations of these compounds and similar such weight materials that may be utilized in the formulation of drilling fluids.
  • materials generically referred to as gelling materials, thinners, and fluid loss control agents are optionally added to drilling fluid formulations.
  • Typical gelling materials used in aqueous based drilling fluids are bentonite, sepiolite, clay, attapulgite clay, anionic high-molecular weight polymer and biopolymers.
  • Thinners such as lignosulfonates are also often added to water-base drilling fluids. Typically lignosulfonates, modified lignosulfonates, polyphosphates and tannins are added. In other embodiments, low molecular weight polyacrylates can also be added as thinners. Thinners are added to a drilling fluid to reduce flow resistance and control gelation tendencies. Other functions performed by thinners include reducing filtration and filter cake thickness, counteracting the effects of salts, minimizing the effects of water on the formations drilled, emulsifying oil in water, and stabilizing mud properties at elevated temperatures.
  • a variety of fluid loss control agents may be added to the drilling fluids of come embodiments of the present invention that are generally selected from a group consisting of synthetic organic polymers, biopolymers, and mixtures thereof.
  • the fluid loss control agents such as modified lignite, polymers, modified starches and modified celluloses may also be added to the water base drilling fluid system of this invention, hi one embodiment the additives of the invention may be selected to have low toxicity and to be compatible with common anionic drilling fluid additives such as polyanionic carboxymethylcellulose (PAC or CMC), polyacrylates, partially-hydrolyzed polyacrylamides (PHPA), lignosulfonates, xanthan gum, mixtures of these and the like.
  • PAC or CMC polyanionic carboxymethylcellulose
  • PHPA partially-hydrolyzed polyacrylamides
  • lignosulfonates lignosulfonates
  • xanthan gum mixtures of these and the like.
  • the drilling fluid of some embodiments of the present invention may further contain an encapsulating agent generally selected from the group consisting 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 anioic, cationic, amphoteric, or non-ionic in nature.
  • additives that may be present in the drilling fluids of some embodiments of the present invention include products such as lubricants, penetration rate enhancers, defoamers, corrosion inhibitors and loss circulation products. Such compounds should be known to one of ordinary skill in the art of formulating aqueous based drilling fluids.
  • a filter cake was created in a lab environment from a 12 pound per gallon (1.438 kgm/1) PHPA drilling mud system and from a 12 pound per gallon (1.438 kgm/1) lignosulfonate drilling mud.
  • the mud was prepared according to the formulation of the table above. Samples of these muds were prepared with 10 pounds per gallon (1.198kgm/l) of Lupamin 1595 and another sample was prepared with 10 pounds per gallon (1.198 kgm/1) of Lupamin 9095.
  • a high temperature fluid loss experiment was then performed at 150 degrees F to generate sample filter cakes from each of the muds. The filter cakes were cut in half, and to a dish with one of the half samples, a solution of hydrochloric acid and sodium nitrite solutions with 5.0 percent by weight hydrochloric acid and 5.0 percent by weight sodium nitrite.

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  • 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)
  • Dispersion Chemistry (AREA)
  • Treatment Of Sludge (AREA)
  • Solid-Sorbent Or Filter-Aiding Compositions (AREA)
  • Excavating Of Shafts Or Tunnels (AREA)
  • Filtering Materials (AREA)

Abstract

L'invention concerne un procédé de forage de puits comprenant les étapes qui consistent : à fournir une boue de forage contenant une amine primaire ; à faire circuler cette boue de forage pendant le forage du puits, l'amine primaire étant incorporée dans un gâteau de filtration déposé sur la paroi du puits pendant le forage du puits, et ; à supprimer au moins une partie du gâteau de filtration après le forage du puits, ce qui consiste à faire circuler une composition fluide contenant de l'acide nitreux dans le puits. Cette invention se rapporte en outre à un fluide de forage contenant un composant solide qui génère un gaz dans le gâteau de filtration, au contact d'un composant qui induit cette génération de gaz du composant solide. Dans certains modes de réalisation, le composant solide se présente sous la forme d'une amine primaire greffée sur un polymère qui n'est pas soluble dans la composition de fluide de forage, par exemple un amidon.
PCT/US2005/043127 2004-12-02 2005-11-30 Additif de fluide de forage, et procede WO2006060388A2 (fr)

Priority Applications (4)

Application Number Priority Date Filing Date Title
AU2005312035A AU2005312035A1 (en) 2004-12-02 2005-11-30 Drilling fluid additive and method
CA002587997A CA2587997A1 (fr) 2004-12-02 2005-11-30 Additif de fluide de forage, et procede
BRPI0516640-3A BRPI0516640A (pt) 2004-12-02 2005-11-30 fluido de perfuração, e, método para proporcionar um furo de poço em uma zona de produção de hidrocarnonetos
GB0710206A GB2435177A (en) 2004-12-02 2007-05-29 Drilling fluid additive and method

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US63250804P 2004-12-02 2004-12-02
US60/632,508 2004-12-02

Publications (2)

Publication Number Publication Date
WO2006060388A2 true WO2006060388A2 (fr) 2006-06-08
WO2006060388A3 WO2006060388A3 (fr) 2006-09-14

Family

ID=36087605

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2005/043127 WO2006060388A2 (fr) 2004-12-02 2005-11-30 Additif de fluide de forage, et procede

Country Status (7)

Country Link
US (1) US20060137878A1 (fr)
CN (1) CN101068904A (fr)
AU (1) AU2005312035A1 (fr)
BR (1) BRPI0516640A (fr)
CA (1) CA2587997A1 (fr)
GB (1) GB2435177A (fr)
WO (1) WO2006060388A2 (fr)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN101868513A (zh) * 2007-09-25 2010-10-20 哈利伯顿能源服务公司 涉及将长层段上的微粒迁移最小化的方法和组合物

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20070246221A1 (en) * 2006-04-19 2007-10-25 M-I Llc Dispersive riserless drilling fluid
CA2723811C (fr) * 2008-05-09 2013-09-10 M-I Llc Fluides de forage contenant une argile calibree et leurs procedes d'utilisation
CN104178093B (zh) * 2013-05-21 2016-12-28 金川集团股份有限公司 抗高硬水的润滑钻井液的制备方法
GB2553687B (en) * 2015-04-20 2020-11-18 Halliburton Energy Services Inc Methods for quantifying nitrogen-containing compounds in subterranean treatment fluids
WO2018160259A1 (fr) * 2017-03-03 2018-09-07 Halliburton Energy Services, Inc. Additifs de fluide de forage marqués chimiquement
CN119039949B (zh) * 2024-10-29 2025-01-24 中石化胜利石油工程有限公司难动用项目管理中心 一种卤水基储层专打钻井液及其制备方法

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Publication number Priority date Publication date Assignee Title
US3273643A (en) * 1966-09-20 Method of initiating foam in drowned wells
US6609578B2 (en) * 2000-02-11 2003-08-26 Mo M-I Llc Shale hydration inhibition agent and method of use
US20030078169A1 (en) * 2001-06-01 2003-04-24 Kippie David P. Thermal extenders for well fluid applications
US6715553B2 (en) * 2002-05-31 2004-04-06 Halliburton Energy Services, Inc. Methods of generating gas in well fluids
AU2003270869A1 (en) * 2002-09-17 2004-04-08 M-Il.L.C. Membrane forming in-situ polymerization for water based drilling fluids
KR20040049488A (ko) * 2002-12-06 2004-06-12 삼성전자주식회사 애플릿 실행 장치 및 방법

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN101868513A (zh) * 2007-09-25 2010-10-20 哈利伯顿能源服务公司 涉及将长层段上的微粒迁移最小化的方法和组合物

Also Published As

Publication number Publication date
GB2435177A (en) 2007-08-15
CA2587997A1 (fr) 2006-06-08
GB0710206D0 (en) 2007-07-04
BRPI0516640A (pt) 2008-09-16
US20060137878A1 (en) 2006-06-29
WO2006060388A3 (fr) 2006-09-14
CN101068904A (zh) 2007-11-07
AU2005312035A1 (en) 2006-06-08

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