US20050284641A1 - Controlled variable density fluid for wellbore operations - Google Patents

Controlled variable density fluid for wellbore operations Download PDF

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Publication number
US20050284641A1
US20050284641A1 US11/155,172 US15517205A US2005284641A1 US 20050284641 A1 US20050284641 A1 US 20050284641A1 US 15517205 A US15517205 A US 15517205A US 2005284641 A1 US2005284641 A1 US 2005284641A1
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Prior art keywords
fluid
elements
average
condition
wellbore
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Abandoned
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US11/155,172
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English (en)
Inventor
Larry Watkins
Roger Fincher
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Baker Hughes Holdings LLC
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Baker Hughes Inc
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Priority to US11/155,172 priority Critical patent/US20050284641A1/en
Assigned to BAKER HUGHES INCORPORATED reassignment BAKER HUGHES INCORPORATED ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: FINCHER, ROGER W., WATKINS, LARRY A.
Publication of US20050284641A1 publication Critical patent/US20050284641A1/en
Priority to US12/353,587 priority patent/US8343894B2/en
Priority to US13/688,366 priority patent/US8455402B2/en
Abandoned legal-status Critical Current

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    • 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
    • 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
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • 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
    • C09K8/03—Specific additives for general use in 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
    • 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
    • C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/138—Plastering the borehole wall; Injecting into the formation
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
    • Y10T428/00—Stock material or miscellaneous articles
    • Y10T428/29—Coated or structually defined flake, particle, cell, strand, strand portion, rod, filament, macroscopic fiber or mass thereof
    • Y10T428/2982—Particulate matter [e.g., sphere, flake, etc.]

Definitions

  • the present invention relates to wellbore operations fluids, and more particularly relates, in one embodiment, to wellbore operations fluids having variable density.
  • Prior variable density drilling fluids primarily concerned the use of a highly compressible gas (e.g. air or nitrogen) as a free phase in the fluid. Limited, if any, efforts are made during conventional air, mist or foam drilling to control the expandability of the bulk fluid or to adjust or engineer the compressibility of the fluid other than managing the ratio of air or other gas to the fluid.
  • Other proposals to employ a virtual multiple gradient fluid include so-called dual gradient drilling. This method would use two columns of different density fluids. One column would be essentially static, while the second fluid density is circulated below the seafloor. During drilling the vertical height of the in well bore column would change as the well is deepened and the resulting bulk average fluid density along the wellbore would thus vary with depth.
  • Typical “single gradient” fluids used today include multiple components (base fluid, various solids and additives).
  • the density of the base fluids is known to vary with temperature and to some degree with pressure. While these density changes are often accounted for during the mathematical modeling of the fluid pressures in the wellbore, the density changes resulting from this behavior is not sufficient to change the design of the wellbore with respect to pore and fracture pressure profiles, as well as position and number of casing strings. No effort is known to be made to intentionally modify the compressibility (density) of classic drilling fluids.
  • variable density fluid for wellbore operations.
  • Still another object of the invention is to provide a method of drilling a wellbore with a reusable, variable density fluid that permits construction and operation of a wellbore with longer hole sections than when using conventional single gradient fluids.
  • variable density fluids of the invention have unit densities that can be deliberately changed as contrasted with existing fluids where the bulk fluid density changes only slightly in response to temperature and/or pressure.
  • a method of constructing a wellbore that includes drilling a wellbore using a wellbore operation fluid within the wellbore.
  • the wellbore operation fluid is subjected to a condition, where the density of the fluid changes in response to a condition such as pressure, temperature, and/or chemical composition of the base fluid.
  • the fluid includes a base fluid, and a plurality of elements that change their volume/weight ratio in response to the condition.
  • a method of improving the lift of a produced fluid that involves injecting into the produced fluid at a subsurface point an effective amount of a plurality of elements that change their volume/weight ratio in response to a condition that may be pressure, temperature, and/or chemical composition of the produced fluid to increase the lift thereof.
  • an element that changes its volume/weight ratio in response to a condition that includes a non-deformable core, a compliant skin surrounding the core, and at least one gas-filled space between the non-deformable core and the compliant skin, where the condition includes pressure, temperature, and/or chemical composition of the base fluid.
  • a non-limiting embodiment that involves a hollow rigid external shell having at least one cavity therein and at least one opening into the cavity and an inner material within the cavity that changes its volume/weight ratio in response to a condition, where the condition includes pressure, temperature, and/or chemical composition of the base fluid.
  • FIGS. 1A-1C are schematic, cross-sectional illustrations of various states of an element of one embodiment of the invention, where FIG. 1A is an element of the variable density wellbore operation fluid in its fully expanded state of the largest volume/weight ratio, FIG. 1B is the element of FIG. 1A in an intermediate state, and FIG. 1C is the element of FIGS. 1A and 1B in its fully contracted state of the smallest volume/weight ratio;
  • FIGS. 2A-2C are schematic, cross-sectional illustrations of various states of another non-limiting embodiment of an element of the invention, where FIG. 2A is an element of the variable density wellbore operation fluid in its fully expanded state of the largest volume/weight ratio, FIG. 2B is the element of FIG. 2A in an intermediate state, and FIG. 2C is the element of FIGS. 2A and 2B in its fully contracted state of the smallest volume/weight ratio;
  • FIG. 3A is a schematic, cross-sectional illustration of an alternate embodiment of the invention showing a different element in an intermediate state between full expansion and full contraction;
  • FIG. 3B is a schematic, cross-sectional illustration of the alternate embodiment of the invention of FIG. 3A illustrating the element in a state of full or complete contraction;
  • FIG. 4A is a schematic, cross-sectional illustration of yet another non-limiting embodiment of the invention showing a pseudoporous particle (e.g. carbide) with volumes of a cellular elastomer in a relatively contracted state;
  • a pseudoporous particle e.g. carbide
  • FIG. 4B is a schematic, cross-sectional illustration showing the pseudo-porous carbide particle of FIG. 4A where the cellular elastomer is in a relatively expanded state where the cells are enlarged as compared with FIG. 4B .
  • FIG. 5C is a schematic, cross-sectional illustration of the FIG. 5B embodiment where the inner, volume-changing material is in a relatively expanded state;
  • An alternative to efforts to modify or change the wellbore strength and/or fluid pressure communication is to change the profile of the hydrostatic pressure developed by the fluid column so as to stay with the pore-frac window and allow longer hole sections.
  • two methods are currently proposed in which the goal is to develop a substantially variable fluid gradient along the length of the open hole section.
  • the two methods involve the use of air or nitrogen in the fluid and so-called “dual gradient” drilling. These methods are further described in the Background of the Invention.
  • FIGS. 2A-2C show an alternate embodiment of the invention having no non-deformable core 16 , such as the embodiment shown in FIGS. 2A-2C , where FIG. 2A shows a gas filled sphere or element 20 with a compliant or elastomeric skin 22 surrounding at least one gas-filled void 24 in its maximum expansion state.
  • FIGS. 2B and 2C shown sphere 20 in intermediate, and minimum contraction states, respectively.
  • the elements have an average fully expanded state or size and an average fully or completely contracted state or size, where the volume ratio of the average expanded state to average contracted state is at least 2.5, alternatively the volume ratio is at least 5, in another non-limiting embodiment the volume ratio is at least 10, in a different, non-restrictive version the volume ratio is at least 5, or alternatively the volume ratio is at least 50.
  • the relative amounts of the spheres 10 or 20 within a drilling fluid it is possible to have a drilling fluid that significantly changes density in response to local pressure.
  • Other parameters that may influence the amount of density variation include the base material density of the structural elements ( 12 , 14 and 16 ; or 22 and 24 ) and the nature of the expanding or elastic material ( 12 or 22 ) of the sphere ( 10 or 20 , respectively).
  • Additional important parameters in the design of the controlled compressibility fluid include the pumpability of the resulting fluid and interaction with other solid elements in the fluid such as drill cuttings, or special mud solids for filtration and/or viscosity control, e.g. gels.
  • the unit densities of the drilling muds herein are likely to be within a wider range than in typical muds, and apparent densities will change as a function of pressure, in one non-limiting embodiment.
  • the spheres or elements may tend to drift or sink at downhole pressures, and/or may try to float or rise in the mud tanks at the surface. These effects may affect the way that mud systems are managed, but they are not expected to be limitations on the practicality of the concept herein.
  • the element is given as a gas-filled sphere, 10 or 20 , respectively.
  • the element shape is not required to be spherical nor gas filled.
  • the driver for the element expansion is a gas pressure.
  • the gas does not need to be conventional air or nitrogen and may be composed of material with much higher liquification pressures due to the relatively high pressure encountered in sub-surface wellbore operations.
  • Non-limiting examples of such a gas or fluid include, but are not limited to natural gases (e.g. oilfield gas) which may be selected to have a wide range of compressibility behaviors, e.g. a wide range of Z factors.
  • FIG. 3A illustrates element 30 in an intermediate position, where the spring component 32 is partially expanded and piston 36 is approximately half-way between the upper rail condition 37 and lower rail condition 39 .
  • FIG. 3B illustrates the spring component 32 is fully contracted and piston 36 is against upper rail condition 37 .
  • the volume of the element 30 is decreased by ⁇ V as fluid 38 flows into the body 34 of element 30 in the direction of the arrow and the total decrease in volume in the system from the sum of the ⁇ Vs of each element 30 is Total ⁇ V.
  • Elements such as schematically illustrated in FIGS. 3A and 3B may be micro- or nanomanufactured using current and future techniques.
  • a variable density fluid containing elements such as elements 30 of this invention would behave on the surface as a 10 lb (10 lbs/gal or ppg) density fluid, that is at 0 feet of depth and 0 psi pressure (atmospheric pressure) under lower rail conditions, whereas the same fluid containing elements 30 may behave as a 24 ppg fluid at a depth of 14,000 feet and a pressure of 12,400 psi under upper rail conditions, where the composite average between the two rail conditions is about 17 ppg.
  • FIG. 6A A schematic graph of how the density of such a fluid would change is shown in FIG. 6A . That is, FIG. 6A is a representation of densification with depth, pressure, and/or other factors.
  • the invention could be practiced in such a way, and the inventive elements may be designed in such a way that the fluid bulk density decreases with depth, pressure, and/or other factors. That is, such a fluid would become lighter or there would be “undensification” or reverse densification in response to particular conditions, as schematically illustrated in FIG. 6B .
  • Yet another configuration is to intentionally use base fluids (or blends of fluids) with high compressibilities to accomplish a portion or all of the needed fluid density variation.
  • variable density The initial application for this controlled variable density is in the construction of wellbores. This includes the initial open hole drilling with drilling-muds.
  • the process of placing cement around casing and liner strings is also limited to some degree by the density of the pumped cement.
  • the variable density spheres or elements may also be added to cement to provide improved cement placement characteristics and opportunities.
  • the variable density elements are also expected to find utility in other sealants or sealing materials besides cements, including, but not necessarily limited to, epoxies, expansive liquids, gels, dehydrated slurries, and materials that form temporary or permanent partial or complete barriers, and the like. Other applications for fluids with variable densities may also be imagined.
  • an important feature of the invention is that the element changes in response to a local environmental physical parameter or condition that may vary along the length or depth or distance of the wellbore.
  • the element is dependent upon something else that naturally changes or that the operator changes.
  • the changes may be in the environment, in the base fluid or both.
  • the rate at which volume will change in response to a condition such as pressure, temperature, chemical composition, or other factor can also be designed and determined in advance, based on the parameters discussed above, that is, including, but not necessarily limited to the material compositions of the elements, the physical dimensions of the elements, the properties and physical composition of the base fluid which carry the inventive elements. In some cases, the volume may drop sharply with pressure and in other cases more gradually.
  • Instances or circumstances where the elements may change their volume/weight ratio relative to chemical composition of the environment include, but are not necessarily limited to, changes in the brine salt concentration, changes in pH, electrical properties of the fluid, and the like and combinations thereof.
  • the elements of the inventive fluids herein may also change their volume/weight ratio in response to other properties of the fluid, including, but not necessarily limited to, electrical properties of the fluid, magnetic field, radiation (natural or induced), and the like and combinations thereof.
  • the response to the local environment could be any of the many mechanisms mentioned herein or suggested by others, downhole or otherwise, for control of water influx via swelling or plugging of pore spaces.
  • FIG. 4A illustrates an element 40 having a pseudo-porous body 42 that is essentially non-deformable, for instance silicon carbide dust or metals or metal oxides.
  • An important goal to the selection of the pseudo-porous body is to achieve a specific gravity core so the collapsed element behaves or acts on the system like a weighting material.
  • These bodies 42 would have at least one cellular compliant or elastomeric component or material 44 thereon, where the individual cells 46 would not communicate with one another.
  • material 44 is a foam
  • the foam would be a closed-cell elastic foam, rather than an open cell foam.
  • the cells may be filled with a gas, such as nitrogen, air, a noble gas, etc.
  • a gas such as nitrogen, air, a noble gas, etc.
  • cells 46 are illustrated as spheres, it will be understood that they need not necessarily be spherical, but may be any volumetric shape.
  • FIG. 4A the cellular compliant component 44 is collapsed or contracted and cells 46 are relatively small, whereas in FIG. 4B , the cellular compliant component 44 is expanded or enlarged and the cells 46 are relatively large.
  • the mean average maximum size of the element 40 essentially does not change.
  • FIG. 5A shows element 50 having a hollow or porous rigid external shell 52 , which in very rough analogy may or may not resemble a “whiffle” ball, with at least one cavity 58 and one or more orifices or openings 54 therein between the exterior and the cavity 58 .
  • Outer structural shell 52 limits the expansion of an inner material 56 within the cavity 58 of shell 52 .
  • the inner material or “kernel” 56 provides the minimum expansion limit ( FIG. 5B ), while the external shell 52 defines the maximum expansion limit ( FIG. 5C ).
  • the average particle size (largest dimension) of the elements is about 100 microns or less, alternatively about 75 microns or less, and in still another non-restrictive embodiment about 50 microns or less.
  • the initial average element diameter may be about 100 microns or less and contract or shrink to within the range of about 30-50 microns or less.
  • the initial average element diameter may be about 70 microns or less and contract or shrink to within the range of about 25-35 microns or less.
  • the sizes are designed to generally pass through a shaker screen and still be the approximate size of current or conventional barite grind (>325 mesh; >44 microns) when collapsed downhole.
  • these average particle sizes may be for the average contracted state size, in the case where the elements have an average contracted state size (or contracted characteristic dimension) and an average expanded state size (or expanded characteristic dimension).
  • Manufacture of the elements for the fluids of the invention can be performed using micromanufacturing or nanomanufacturing techniques, as noted.
  • Elements 10 and 20 as seen in FIGS. 1 and 2 respectively may be produced by known and future microencapsulation methods.
  • Elements 50 shown in FIGS. 5A-5C could be made by microencapsulation, micromanufacturing and/or nanomanufacturing processes.
  • Elements 40 such as shown schematically in FIGS.
  • 4A and 4B could be produced by grinding or pulverizing tungsten carbide, silicon carbide, other dense, carbide-like element or other pseudo-porous materials, infusing the particles with a dense, but microcellular polymeric elastomer, and then cryogenically grinding the elastomer down to essentially the initial size of the particles.
  • Other possible materials for the non-deformable pseudo-porous materials besides carbide include, but are not necessarily limited to, silicon oxide (glass or sand), nanocarbon structures such as nanotubes or Buckminster fullerenes (buckyballs), and the like.
  • the wellbore operation fluids of this invention may contain more than one kind of element, that is, more than one element embodiment of the invention can be employed at once. Indeed, the use of different types of elements that change their volume/weight ratio differently in response to the same conditions, or in response to different conditions would permit the fluid designer greater flexibility.
  • variable density fluids of this invention may be used in operations other than wellbore operations, as in the recovery of hydrocarbons from subterranean formations.
  • these variable density fluids would find utility in cementing or sealing, as drilling fluids or muds, as packer fluids, as workover fluids, as completion fluids, as drill-in fluids, or in applications where the variable density may affect the buoyancy of a body.
  • the elements of this invention could be used to advantage in a pseudo-gas lift operation.
  • gas lifts are artificial-lift methods in which gas is injected into the production tubing to reduce the hydrostatic pressure of the fluid column. The resulting reduction in bottomhole pressure allows the reservoir liquids to enter the wellbore at a higher flow rate.
  • the inventive elements would replace the gas, or optionally be used together with the gas, to permit reservoir fluids to flow more readily.
  • the lift of a produced fluid is improved by injecting into the produced fluid at a subsurface point an effective amount of a plurality of the inventive elements that change their volume/weight ratio in response to one or more of the conditions previously discussed.
  • the volume/weight ratio of the elements would change in response to the condition giving added lift to the produced fluid by reducing its local average density.
  • the upper limits for the various average particle sizes may be about 1000 microns, on the other hand about 500 microns, alternatively about 250 microns, and in another case about 150 microns, whereas the lower limits for these average particles sizes may be about 50 microns, about 75 microns and about 100 microns.

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US11/155,172 2004-06-24 2005-06-17 Controlled variable density fluid for wellbore operations Abandoned US20050284641A1 (en)

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US11/155,172 US20050284641A1 (en) 2004-06-24 2005-06-17 Controlled variable density fluid for wellbore operations
US12/353,587 US8343894B2 (en) 2004-06-24 2009-01-14 Controlled variable density fluid for wellbore operations
US13/688,366 US8455402B2 (en) 2004-06-24 2012-11-29 Wellbore operations using controlled variable density fluid

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Cited By (20)

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US20050113262A1 (en) * 2003-11-24 2005-05-26 Halliburton Energy Services, Inc. Variable density fluids and methods of use in subterranean formations
US20050161262A1 (en) * 2004-01-27 2005-07-28 Jamison Dale E. Variable density treatment fluids and methods of using such fluids in subterranean formations
US20060254775A1 (en) * 2004-01-26 2006-11-16 Jamison Dale E Variable density treatment fluids
WO2007102971A2 (fr) * 2006-03-06 2007-09-13 Exxonmobil Upstream Research Company Procede et appareil pour gerer une boue de forage de densite variable
WO2007145734A2 (fr) * 2006-06-07 2007-12-21 Exxonmobil Upstream Research Company Objets compressibles à garniture partielle en mousse combinés à un fluide de forage pour former une boue de forage à densité variable
WO2007145733A1 (fr) * 2006-06-07 2007-12-21 Exxonmobil Upstream Research Company Objets compressibles à pression interne prédéterminée destinés à être combinés à un fluide de forage pour former une boue de forage à densité variable
WO2008009957A1 (fr) * 2006-07-20 2008-01-24 Hallibruton Energy Services, Inc. Procédés et matériaux améliorés pour former des barrières au fluide souterrains dans des matériaux entourant des puits
GB2445086A (en) * 2006-12-21 2008-06-25 Schlumberger Holdings Activating oilfield chemical by use of a magnetic filed and a susceptor
US7866399B2 (en) 2005-10-20 2011-01-11 Transocean Sedco Forex Ventures Limited Apparatus and method for managed pressure drilling
US7938203B1 (en) 2010-10-25 2011-05-10 Hall David R Downhole centrifugal drilling fluid separator
US7972555B2 (en) 2004-06-17 2011-07-05 Exxonmobil Upstream Research Company Method for fabricating compressible objects for a variable density drilling mud
US8076269B2 (en) 2004-06-17 2011-12-13 Exxonmobil Upstream Research Company Compressible objects combined with a drilling fluid to form a variable density drilling mud
US8088716B2 (en) 2004-06-17 2012-01-03 Exxonmobil Upstream Research Company Compressible objects having a predetermined internal pressure combined with a drilling fluid to form a variable density drilling mud
US20120018155A1 (en) * 2010-07-21 2012-01-26 Rahul Chandrakant Patil Cement compositions with a high-density additive of silicon carbide or sintered bauxite
WO2012091982A2 (fr) * 2010-12-29 2012-07-05 Baker Hughes Incorporated Substance produisant un bouchon et méthode de bouchage d'un puits de forage
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US20090114450A1 (en) 2009-05-07
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GB2430459A (en) 2007-03-28
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