EP2007970A2 - Fluide dispersif de forage sans tube prolongateur - Google Patents

Fluide dispersif de forage sans tube prolongateur

Info

Publication number
EP2007970A2
EP2007970A2 EP07760926A EP07760926A EP2007970A2 EP 2007970 A2 EP2007970 A2 EP 2007970A2 EP 07760926 A EP07760926 A EP 07760926A EP 07760926 A EP07760926 A EP 07760926A EP 2007970 A2 EP2007970 A2 EP 2007970A2
Authority
EP
European Patent Office
Prior art keywords
drilling
fluid
drilling fluid
borehole
casing
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP07760926A
Other languages
German (de)
English (en)
Other versions
EP2007970A4 (fr
Inventor
Doug Jones
Randy Ray
Jay Forrester
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
MI LLC
Original Assignee
MI LLC
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 MI LLC filed Critical MI LLC
Publication of EP2007970A2 publication Critical patent/EP2007970A2/fr
Publication of EP2007970A4 publication Critical patent/EP2007970A4/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • 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
    • E21B7/12—Underwater drilling
    • E21B7/128—Underwater drilling from floating support with independent underwater anchored guide base
    • 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
    • C09K8/145—Clay-containing compositions characterised by the composition of the clay
    • 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
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/001—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor specially adapted for underwater drilling

Definitions

  • Embodiments relate generally to drilling fluids. More specifically, embodiments relate to drilling fluids used in a riserless section.
  • drill bit cutting surfaces When drilling or completing wells in earth formations, various fluids typically are used in the well for a variety of reasons.
  • Common uses for well fluids include: lubrication and cooling of drill bit cutting surfaces while drilling generally or drilling- in (i.e., drilling in a targeted petroliferous formation), transportation of "cuttings" (pieces of formation dislodged by the cutting action of the teeth on a drill bit) to the surface, controlling formation fluid pressure to prevent blowouts, maintaining well stability, suspending solids in the well, minimizing fluid loss into and stabilizing the formation through which the well is being drilled, fracturing the formation in the vicinity of the well, displacing the fluid within the well with another fluid, cleaning the well, testing the well, transmitting hydraulic horsepower to the drill bit, fluid used for emplacing a packer, abandoning the well or preparing the well for abandonment, and otherwise treating the well or the formation.
  • mud is pumped down the drill string, through the bit and up the casing-drill string annulus to the surface.
  • the mud's viscosity is designed to carry drill cuttings back to surface for disposal and its density to contain the well's natural pressure.
  • Drilling for oil and gas in very deep water presents problems not found in terrestrial or shallow water oil and gas exploration.
  • One problem encountered in deep water is drilling fluid management.
  • a drilling fluid is a fluid specially designed to be circulated through a wellbore as the wellbore is being drilled to facilitate the drilling operation.
  • the circulation path of the drilling fluid typically extends from the drilling rig down through the drill pipe string to the bit face and back up through the annular space between the drill pipe string and wellbore face to the wellhead and/or riser, returning to the rig.
  • the drilling fluid also desirably prevents sloughing and wellbore cave-ins when drilling through water sensitive formations.
  • Offshore drillers have to get mud down to the bottom of the sea, where the borehole starts. To do that, they run a steel tube, called a riser, to extend the borehole from the bottom of the sea to the rig.
  • a riser which provides a connection between the drilling vessel and the wellhead.
  • the riser serves as a guide for the drill pipe into the hole and as a mud return path to the vessel and also supports control cables and choke and kill lines.
  • Floating drilling operations in deep water presently involve the use of a 21 inch outer diameter (OD) marine riser.
  • a riser system which is a separate casing rising from the sea floor to the base of a drilling ship or drilling rig, can be used to return drilling mud to a drilling ship or platform for reuse.
  • the use of a riser is not without problems, and these problems can be exaggerated in deep water drilling projects.
  • One such problem is weight.
  • a 6,000-foot riser, 21 inches in diameter, holding drilling mud has been estimated to weigh from about 1,000 to 1,500 tons. It is for this reason that riserless drilling methods have been disclosed, particularly for deep water drilling, in patents such as U.S. Pat. No. 6,102,673 to Mott, et al., and U.S. Pat. No. 4,149,603 to Arnold.
  • Drilling muds comprise high-density dispersions of fine solids in an aqueous liquid. Because muds used in riserless drilling are not typically circulated to the rig, the cost of "pumping and dumping" must be balanced with the benefits provided by the mud, when muds are pumped at a minimum of 1,200 gallons per minute into a well. For example, when drilling riserless, seawater alone, or blends of sea water with muds containing polymers, hydrating clays, and salts to improve inhibition, density, viscosity, and other rheological properties have been typically used.
  • embodiments relate to a method for drilling riserless that includes providing a drilling fluid to a drilling assembly for drilling a borehole on a seafloor, the drilling assembly comprising a drill string and a bottomhole assembly, and wherein the drilling fluid includes a brine, and a non-hydratable clay, wherein the drilling fluid is substantially free of hydrating clays, and flowing the drilling fluid and cuttings through an annulus formed by the drill string and the borehole into sea water.
  • embodiments relate to a a method for drilling riserless that includes providing a drilling fluid to a drilling assembly for drilling a borehole on a seafloor, the drilling assembly comprising a drill string and a bottomhole assembly, and wherein the drilling fluid includes a brine, attapulgite clay, and a salt of an alkali metal or alkaline earth metal wherein the drilling fluid is substantially free of hydrating clays, and flowing the drilling fluid and cuttings through an annulus formed by the drill string and the borehole into sea water.
  • embodiments relate to a wellbore fluid that includes an aqueous fluid, attapulgite clay, and a salt of an alkali metal or alkaline earth metal, wherein the wellbore fluid is substantially free of hydrating clays.
  • FIG. 1 is a schematic view of open hole drilling according to one embodiment disclosed herein.
  • embodiments disclosed herein relate to dispersive drilling fluids and methods of drilling with these fluids.
  • embodiments disclosed herein relate to drilling fluids useful in drilling a section of a borehole without a riser.
  • a drilling fluid may include a brine and a non-hydratable clay.
  • brine is defined as including any aqueous saline solution
  • non-hydratable clay is defined as those clays which do not swell appreciably in either fresh water or salt water.
  • the brine may include 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.
  • the salinity of seawater may range from about 1 percent to about 4.2 percent salt by weight based on total volume of seawater.
  • Salts that may be found in seawater include, but are not limited to, sodium, calcium, sulfur, aluminum, magnesium, potassium, strontium, silicon, lithium, and phosphorus salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, 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. Additionally, 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. In one embodiment, the density of the drilling fluid may be controlled by increasing the salt concentration in the brine (up to saturation). In a particular embodiment, a brine may include halide or carboxylate salts of mono- or divalent cations of metals, such as cesium, potassium, calcium, zinc, and/or sodium. [0019] Clays
  • the drilling fluids disclosed herein may also contain a non-hydratable clay.
  • the non-hydratable clay may be a clay having a needle-like or chain-like structure.
  • the non-hydratable clay may be selected from at least one of attapulgite and sepiolite clays.
  • the non-hydratable clay includes attapulgite clay. While the non- hydratable clays do not substantially swell in either fresh or salt water, they may still operate to thicken salt solutions. This thickening may be attributed to what is believed to be a unique orientation of charged colloidal clay particles in the dispersion medium, and not actual "hydration.”
  • non-hydratable refers to the clay's characteristic lack of swelling, i.e., measurable volume increase, in the presence of salt water
  • a given clay's swellability in sea water may be tested by a procedure described in an article by K. Norrish, published as "The swelling of Montmorillonite," Disc. Faraday Soc. vol. 18, 1954 pp. 120-134. This test involves submersion of the clay for about 2 hours in a solution of deionized water and about 4 percent sodium chloride by weight per volume of the salt solution.
  • a given clay ' s swellability in fresh water may be tested by an analogous procedure in which the sodium chloride is excluded.
  • non-hydratable clay is defined in one embodiment as one that, under this test, swells less than 8 times by volume compared with its dry volume. In another embodiment, a non-hydratable clay exhibits swelling on the order of less than 2 times; less than 0.3 times in another embodiment; and less than 0.2 times in yet another embodiment.
  • the drilling fluids disclosed herein may be substantially free of hydrating clays.
  • hydrating clays is defined as those clays which swell appreciably (i.e., increase their volume by an amount of at least about 8 times) in either fresh water or salt water, and “substantially free” is defined as an amount that does not significantly affect dispersibility.
  • Hydrating clays may include those clays which swell appreciably in contact with fresh water, but not when in contact with salt water, include, for example, clays containing sodium montmorillonite, such as bentonite. Many hydrating clays have a sheet- or plate-like structure.
  • the drilling fluid disclosed herein may also contain at least one additional salt, including any salt that may be incorporated in brines, as disclosed herein.
  • at least one of sodium chloride, calcium chloride, potassium chloride, and sodium carbonate may be incorporated in the drilling fluids disclosed here.
  • the at least one additional salt may incorporated into the drilling fluid disclosed herein in an amount ranging from about 0.5 weight percent to salt saturation.
  • the wellbore fluids disclosed herein may optionally contain various additives, depending on the end use of the fluid.
  • weighting agents, deflocculants, and combinations thereof may be added to the fluid compositions disclosed herein for additional functional properties.
  • the addition of such agents should be well known to one of skill in the art of formulating drilling fluids and muds. However, it should be noted that the addition of such agents should not adversely interfere with the properties associated with the mud's ability to disperse cuttings as disclosed herein.
  • Weighting agents or density materials suitable for use in the fluids disclosed herein include, for example, galena, hematite, magnetite, iron oxides, illmenite, barite, siderite, celestite, dolomite, calcite, and the like.
  • the quantity of such material added, if any, depends upon the desired density of the final composition.
  • weight material is added to result in a drilling fluid density of up to about 19 pounds per gallon in one embodiment; and ranging from 9.5 to 14 pounds per gallon in another embodiment,
  • Deflocculants or thinners that may be used in the drilling fluids disclosed herein include, for example, lignosulfonates, modified lignosulfonates, polyphosphates, tannins, and low molecular weight water soluble polymers, such as polyacrylates. Deflocculants are typically added to a drilling fluid to reduce flow resistance and control gelation tendencies. In a particular embodiment, a deflocculant may be desirable when a drilling fluid is formed from a heavier mud diluted withsea water. TANNATHIN ® , an oxidized lignite, is an example of a deflocculant which is available from M-I L.L.C. (Houston, Texas). [0029] Formulations
  • the drilling fluid may be formulated to have a density range from about 9 to 14 pounds per gallon.
  • the drilling fluid may be initially formulated to have the desired formulation.
  • the drilling fluid may be formed from a concentrated mud, such as a 16 pound per gallon mud, or heavier which is be blended with a brine prior to use to the desired formulation. Those having ordinary skill in the art will appreciate that other densities may be used as desired.
  • the mud When blended from a mud and a brine, the mud may optionally contain a salt, such as a salt of an alkali metal or alkaline earth metal.
  • the drilling fluid may have a pH greater than about 6.
  • the drilling fluid may have a pH ranging from about 7.5 to 12.
  • the pH of the drilling fluid may be tailored with the addition of acidic or basic additives, as recognized by one skilled in the art. For example, caustic soda and citric acid may be used to increase or decrease the pH of a fluid, respectively.
  • a drill string 14 typically extends unsupported from a vessel or platform 12 through the water to the seafloor 16 without a riser.
  • a drilling assembly that includes the drill string 14 and a bottom hole assembly (BHA) (not shown separately), and casing 20 is lowered to the seafloor via the drill string 14.
  • the BHA includes a drill bit 16, and may also include other components such as, drill collars and a downhole motor (not shown separately).
  • the bit 16 is positioned just below the bottom end of the structural casing 20 and is sized to drill a borehole 22 with a slightly smaller diameter than the diameter of the casing 20.
  • the structural casing 20 moves downwardly with the BHA. The weight of the structural casing 20 and BHA drives the casing 20 into the sediments.
  • the structural casing 20, in its final position, may extend downwardly to a depth of 150 to 400 feet, depending upon the formation conditions and the final well design. After the structural casing 20 is in place, it may be released from the drill string 14 and BHA. The drill string 14 and BHA may be tripped back to the platform, or alternatively, may be lowered to drill below the structural casing.
  • the structural casing 20 may be installed in a two-step process.
  • the structural casing 20 is run into the borehole 22 and cemented into place.
  • the low-pressure wellhead housing (not shown separately) is connected to the upper end of the structural casing 20 and installed at the same time, such that the structural casing 20 extends below the seafloor with the low-pressure wellhead housing above the seafioor.
  • the bit 16 on the drill string 14 drills downwardly below the structural casing 20 to drill a new borehole section using open hole drilling for an intermediate casing 24, known as "conductor casing," which may be, for example, 20-inches in diameter.
  • the structural casing 20 guides the BHA as it begins to drill the conductor casing 24 interval.
  • the BHA is tripped to the surface.
  • the conductor casing 24 is cemented into place in a well known manner, with the float valve preventing cement from flowing upwardly into the conductor casing after cement placement.
  • the conductor casing 24 generally may extend downwardly to a depth of 1 ,000 to 3,000 feet below the seafloor, depending on the formation conditions and the final well design.
  • the high- pressure wellhead housing (not shown separately) may engage the low-pressure wellhead housing (not shown separately) to form the subsea wellhead, thereby completing the riserless portion of the drilling operations.
  • Installation of a subsea blowout preventer (BOP) stack may be conveyed down to the seafloor by a riser and latched onto the subsea wellhead housing for subsequent riser drilling.
  • BOP subsea blowout preventer
  • drilling fluid flows through the drill string 14 and out of the drill bit 16 as shown by downward arrows 26.
  • the flow of the drilling fluid continues through the annulus between the borehole 22 and the drilling assembly 14, 16.
  • the drilling fluid may carry drilled cuttings through the borehole, indicated by upward arrows 28 and may exit the well to be dispersed into the sea, as indicated by arrows 30. Therefore, in open hole drilling the returns, i.e. the drilling fluid, cuttings, and well fluids, are discharged onto the seafloor and are not conveyed to the surface.
  • Drilling muds were formulated having the following components, all of which are commercially available, as shown below in Table 1.
  • M-I GEL ® is an example of a bentonite clay
  • SALT GEL ⁇ is an example of an attapulgite clay
  • TANNATHIN ® is a lignite
  • DUOVIS* is a xanthan gum, all of which are commercially available from M-I L.L.C. (Houston, Texas).
  • embodiments disclosed herein may provide for a drilling fluid that may be used in open hole drilling.
  • the fluids disclosed herein may provide the rheological properties needed for drilling without a riser. Additionally, by increasing the amount of dispersion of cuttings into the fluids and subsequently into the sea water, the fluids may at least reduce cuttings accretion and agglomeration, build up of cuttings that cover the wellhead, bit balling, and hole cleaning issues, such as swabbing, surging, and packing off, which may lead to pressure issues.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Chemical & Material Sciences (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Dispersion Chemistry (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Mechanical Engineering (AREA)
  • Earth Drilling (AREA)
  • Drilling And Exploitation, And Mining Machines And Methods (AREA)

Abstract

L'invention concerne une méthode de forage sans tube prolongateur qui consiste à fournir un fluide de forage à un assemblage de forage permettant de réaliser un forage sur un fond océanique, l'assemblage de forage comprenant un train de tiges de forage et un assemblage de fond de puits, le fluide de forage étant constitué d'une saumure et d'une argile non-sensible à l'hydratation et en majorité sans argile sensible à l'hydratation, ainsi qu'évacuer le fluide de forage et les déblais de forage dans l'espace annulaire formé par le train de tiges de forage et le forage vers l'eau de mer.
EP07760926.1A 2006-04-19 2007-04-19 Fluide dispersif de forage sans tube prolongateur Withdrawn EP2007970A4 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US79303106P 2006-04-19 2006-04-19
US11/737,058 US20070246221A1 (en) 2006-04-19 2007-04-18 Dispersive riserless drilling fluid
PCT/US2007/066983 WO2007124368A2 (fr) 2006-04-19 2007-04-19 Fluide dispersif de forage sans tube prolongateur

Publications (2)

Publication Number Publication Date
EP2007970A2 true EP2007970A2 (fr) 2008-12-31
EP2007970A4 EP2007970A4 (fr) 2014-11-12

Family

ID=38618382

Family Applications (1)

Application Number Title Priority Date Filing Date
EP07760926.1A Withdrawn EP2007970A4 (fr) 2006-04-19 2007-04-19 Fluide dispersif de forage sans tube prolongateur

Country Status (10)

Country Link
US (1) US20070246221A1 (fr)
EP (1) EP2007970A4 (fr)
AU (1) AU2007240399B2 (fr)
BR (1) BRPI0710460A2 (fr)
CA (1) CA2649574C (fr)
EA (1) EA200870450A1 (fr)
MX (1) MX2008013311A (fr)
MY (1) MY146020A (fr)
NO (1) NO20084782L (fr)
WO (1) WO2007124368A2 (fr)

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
BRPI0822664A2 (pt) * 2008-05-09 2015-06-30 Mi Llc Fluidos de furo de poço contendo material de argila e métodos de uso dos mesmos
US8767063B1 (en) * 2013-07-26 2014-07-01 Berger Geosciences, LLC System for monitoring a marine well for shallow-water flow
WO2015145293A1 (fr) * 2014-03-26 2015-10-01 Drillmec Spa Procédé d'assemblage d'une rame d'éléments pour forage en eau profonde et ultra profonde, élément d'obstruction et utilisation correspondante de celui-ci dans ladite rame de forage
WO2015160417A1 (fr) * 2014-04-15 2015-10-22 Halliburton Energy Services, Inc. Formation de puits de forage sous-marin
US20200181473A1 (en) * 2018-12-06 2020-06-11 Halliburton Energy Services, Inc. Treatment fluids and methods of use
CN118933713B (zh) * 2024-07-29 2025-02-28 中国石油大学(华东) 一种深水浅层开路钻井溢流后井底压力快速调控装置及方法

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DE2349405A1 (de) * 1972-11-24 1974-06-06 Texaco Development Corp Waessrige bohrspuelung und ihre verwendung
US3989630A (en) * 1972-11-24 1976-11-02 Texaco Inc. Low solids shale controlling drilling fluid
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US5229018A (en) * 1986-02-24 1993-07-20 Forrest Gabriel T Completion and workover fluid for oil and gas wells comprising ground peanut hulls
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US6739408B2 (en) * 2000-10-30 2004-05-25 Baker Hughes Incorporated Apparatus and method for preparing variable density drilling muds
US6843331B2 (en) * 2001-02-15 2005-01-18 De Boer Luc Method and apparatus for varying the density of drilling fluids in deep water oil drilling applications
US6745853B2 (en) * 2002-10-04 2004-06-08 Halliburton Energy Services, Inc. Methods and apparatus for open hole drilling
MXPA04004343A (es) * 2003-05-06 2007-06-29 Masi Technologies Llc Sistemas acuosos basados en fluidos de arcilla y coloidales similares.
US20050080145A1 (en) * 2003-10-09 2005-04-14 Hoy Edgar Franklin Method and compositions for rheology modification of aqueous soluble salt solutions
GB0405273D0 (en) * 2004-03-09 2004-04-21 Ici Plc Improved drilling fluids
AU2005312035A1 (en) * 2004-12-02 2006-06-08 Shell Internationale Research Maatschappij B.V. Drilling fluid additive and method
GB2424432B (en) * 2005-02-28 2010-03-17 Weatherford Lamb Deep water drilling with casing

Also Published As

Publication number Publication date
MX2008013311A (es) 2008-10-27
EA200870450A1 (ru) 2009-04-28
MY146020A (en) 2012-06-15
CA2649574A1 (fr) 2007-11-01
WO2007124368A2 (fr) 2007-11-01
CA2649574C (fr) 2011-09-20
US20070246221A1 (en) 2007-10-25
WO2007124368A3 (fr) 2007-12-06
EP2007970A4 (fr) 2014-11-12
BRPI0710460A2 (pt) 2011-08-16
NO20084782L (no) 2009-01-15
AU2007240399A1 (en) 2007-11-01
AU2007240399B2 (en) 2011-06-09

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