US20100051274A1 - Methods, apparatus and products for drilling wells - Google Patents

Methods, apparatus and products for drilling wells Download PDF

Info

Publication number
US20100051274A1
US20100051274A1 US12/200,906 US20090608A US2010051274A1 US 20100051274 A1 US20100051274 A1 US 20100051274A1 US 20090608 A US20090608 A US 20090608A US 2010051274 A1 US2010051274 A1 US 2010051274A1
Authority
US
United States
Prior art keywords
bead
beads
specific gravity
well fluid
exceeds
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.)
Abandoned
Application number
US12/200,906
Inventor
Tommy Johnson
Dustin O'Neal
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.)
Individual
Original Assignee
Individual
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
Family has litigation
First worldwide family litigation filed litigation Critical https://patents.darts-ip.com/?family=41723616&utm_source=google_patent&utm_medium=platform_link&utm_campaign=public_patent_search&patent=US20100051274(A1) "Global patent litigation dataset” by Darts-ip is licensed under a Creative Commons Attribution 4.0 International License.
Application filed by Individual filed Critical Individual
Priority to US12/200,906 priority Critical patent/US20100051274A1/en
Publication of US20100051274A1 publication Critical patent/US20100051274A1/en
Priority to US13/473,838 priority patent/US9206646B2/en
Abandoned 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
    • E21B7/04—Directional drilling
    • E21B7/046—Directional drilling horizontal drilling
    • 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
    • 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
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/03—Freeing by flushing
    • 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
    • E21B31/00—Fishing for or freeing objects in boreholes or wells
    • E21B31/035—Fishing for or freeing objects in boreholes or wells controlling differential pipe sticking
    • 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

Definitions

  • the present invention relates to drilling of wells, well fluids, and well fluid additives and to methods, apparatus and products related thereto.
  • a rotary oil rig The purpose of a rotary oil rig is to drill a hole to a predetermined depth. And, hopefully, in the drilling process, passing to or through one or more oil and gas bearing reservoir rock formations. Since rigs are expensive to manufacture, they need to be movable. In addition, since the rock chips created by the drilling bit must be removed, mud is pumped through the drill pipe to the bit and back up the annulus or space between the drill pipe and the outer casing that is added as drilling proceeds. The mud is mixed, usually with water but sometimes with chemicals, in a chemical tank, then sucked from the mud pit and pumped via a standpipe and rotary hose to a swivel that is attached to a Kelly, which is itself attached to the drill pipe. The returning mud and rock chips that reach the surface move by gravity down a return line to a shale shaker designed to separate the returning mud from the shale for reuse. The remaining rock chips travel down a shale slide to a reserve pit.
  • Horizontal drilling technology achieved commercial viability during the late 1980's. Its successful employment, particularly in the Bakken Shale of North Dakota and the Austin Chalk of Texas, has encouraged testing of it in many domestic geographic regions and geologic situations. Achievable horizontal bore hole length grew rapidly as familiarity with the technique increased; horizontal displacements have now been extended to over several miles. Some wells have featured multiple horizontal bores. Completion and production techniques have been modified for the horizontal environment, with more change required as the well radius decreases; the specific geologic environment and production history of the reservoir also determine the completion methods employed.
  • the technical objective of horizontal drilling is to expose significantly more reservoir rock to the well bore surface than can be achieved via drilling of a conventional vertical well.
  • the desire to achieve this objective stems from the intended achievement of other, more important technical objectives that relate to specific physical characteristics of the target reservoir, and that provide economic benefits. Examples of these technical objectives are the need to intersect multiple fracture systems within a reservoir and the need to avoid unnecessarily premature water or gas intrusion that would interfere with oil production.
  • Horizontal drilling is the process of drilling and completing, for production, a well that begins as a vertical or inclined linear bore which extends from the surface to a subsurface location, just above the target oil or gas reservoir called the “kickoff point,” then bears off on an arc to intersect the reservoir at the “entry point,” and, thereafter, continues at a near-horizontal attitude tangent to the arc, to substantially or entirely remain within the reservoir until the desired bottom hole location is reached.
  • That objective is to expose significantly more reservoir rock to the wellbore surface than would be the case with a conventional vertical well penetrating the reservoir perpendicular to its plane of more extensive dimension.
  • the desire to attain this immediate technical objective is almost always motivated by the intended achievement of more important objectives (such as avoidance of water production) related to specific physical characteristics of the target reservoir.
  • a producing zone is fifty feet in thickness and a vertical well is drilled through such a zone, then only fifty feet of the producing zone will be exposed for production.
  • a horizontally drilled well may penetrate the producing sand or zone by one thousand feet or more.
  • the amount or volume of oil or gas production is directly proportional to the horizontal penetration in feet into the producing sand or zone.
  • friction becomes a major problem.
  • the primary source of friction is directly related to the adhesion of the drilling assembly to the wall cake which lines the drilled well bore.
  • the capillary attractive forces generated by the adhesion of the drilling assembly to the wall cake are directly proportional to the amount or footage of the drilling assembly exposed to the surface of the wall cake.
  • Tortuosity includes the effect of rotation of the bit and its reactive torque against the formation thereby causing the bit, bottom hole assembly and drill string to buckle, turn and twist within the well bore. Tortuosity effects well path, penetration rate, pipe sticking, etc. In an effort to overcome these issues, many methods have been used in order to reduce friction between the drilling assembly and the wall cake.
  • liquid lubricant to the drilling fluid in order t o reduce the coefficient of friction of the drilling fluid.
  • liquid lubricants include oils, such as hydrocarbon based oils, vegetable oils, glycols, etc. These liquid lubricants will usually reduce the coefficient of friction of the drilling fluid resulting in a reduction of friction between the drilling assembly and the wall cake of the well bore.
  • Another method has been the use of spherical drilling beads in the drilling fluid to function as the friction reducer. These drilling beads act like ba 11 bearings and function as a lubricant in well drilling applications.
  • spherical beads are generally selected to have specific gravity greater than that of the well fluid, such that due to the horizontal inclination of the borehole, gravity will segregate the spherical beads to a position “below” the drill string.
  • U.S. Pat. No. 5,839,520 issued Nov. 24, 1998, to Maillet, discloses a method of increasing the penetration rate of a drill string within a deviated well bore.
  • the method includes providing a drill string with a drilling bottom hole assembly, and rotating the bit in order to create the deviated well bore as well as a filter cake on the walls of the well bore.
  • a pill comprising a spherical bead is prepared and pumped down into the well bore. The pill is allowed to migrated to the low side of the bore hole so that tortuosity is reduced.
  • a method of slide drilling, batch drilling, and running a liner in a well is also disclosed utilizing the spherical beads. In the novel methods disclosed, the spherical beads are allowed to migrate to the low side of the borehole and are allowed to penetrate through the borehole's filter cake.
  • IADC/SPE 72290 Drilling Fluids Design and Management for Extended Reach Drilling, C. Cameron, SPE, Halliburton Energy Services 2001, discloses use of solid glass beads for reduction in torque whilst running casing, which act as “ballbearings” between the casing or open hole and the drill pipe or casing.
  • the drilling fluid additive is provided wherein the additive is manufactured by a method comprised of admixing at least one carrier such as a polypropylene glycol to talc and subsequently admixing graphite to the talc and carrier mixture; and then admixing an uintaite (a natural black bitumen) to the talc, carrier and graphite mixture.
  • U.S. Patent Publication No. 20070111899 published May 17, 2007, to Wood, discloses pre-engineered pills for the improvement of drilling muds.
  • the pills can improve the lubricity of the mud as well as aiding in wellbore cleaning, prevention of bit balling and reduction of fluid loss to thief zones.
  • the pills can be prepared either on site or at a remote location and then transported to the drilling site for use.
  • the ground elastomer and non-aqueous fluid should be in contact with each other for a period sufficient to insure that the non-aqueous fluid has impregnated the elastomer particles. This will typically run from about 15 to 30 minutes.
  • a well fluid additive includes a heavier first bead and a lighter second bead.
  • the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • a well fluid additive for a well fluid having a well fluid specific gravity.
  • the additive includes a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity.
  • the first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • a method of modifying a well fluid includes contacting the well fluid with a well fluid additive.
  • the well fluid additive comprises a heavier first bead and a lighter second bead.
  • the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • a method of modifying a well fluid having a well fluid specific gravity includes contacting the well fluid with a well fluid additive.
  • the well fluid additive comprises a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity.
  • the first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • an apparatus comprising a well and a well fluid circulating in the well.
  • the well fluid comprises a well fluid component and a well fluid additive.
  • the well fluid additive comprises a heavier first bead and a lighter second bead.
  • the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • an apparatus comprising a well and a well fluid having a well fluid specific gravity circulating in the well.
  • the well fluid comprises a well fluid component and a well fluid additive.
  • the well fluid additive comprises a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • a method of operating a well that includes circulating a well fluid in the well.
  • the well fluid comprises a well fluid component and a well fluid additive.
  • the well fluid additive comprises a heavier first bead and a lighter second bead.
  • the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • a method of operating a well including circulating a well fluid having a well fluid specific gravity circulating in the well.
  • the well fluid comprises a well fluid component and a well fluid additive.
  • the well fluid additive includes a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • the present invention includes well fluid additives comprising a heavier first bead and a lighter second bead, wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1, 2, 4, 5, 10, 15, 20, 25, 30, 40, 45, 50, 75, 100, 150, 200, or 300 percent.
  • first bead may comprise a first set of beads
  • second bead may comprise a second set of beads.
  • any suitable specific gravity may be utilized for the beads of the present invention.
  • the well fluids typically have specific gravities in the rang e of about 1 to about 4, with the specific gravity of the beads selected according to where the beads are to be positioned. While any suitable range of bead specific gravity may be utilized, non-limiting examples of commercially available beads include those from about 0.5 to about 5, and from about 1 to about 4. It should be understood that as difference between the specific gravity of the bead and the well fluid increases, the bead is more likely to settle at/near the bottom or float at/near the top of the well fluid. Beads with specific gravities close to that of the well fluid may tend to more slowly settle at the bottom or float at/near the top of the well fluid. By selecting specific gravities of the beads, it may be possible to urge the beads to be a different points of the well fluid, that is, there may be different layers or zones of beads.
  • the beads of different physical properties may be below the pipe, along the side of the pipe, and/or above the pipe. That is, the beads that are below the pipe will have the weight of the pipe as a factor, whereas, beads above the pipe will not, and those along the side of the pipe may or may not be effected by the weight of the pipe.
  • the first bead and the second bead will be urged by gravity to congregate in different levels of the wellbore.
  • the horizontal centerline of the wellbore divides the wellbore into a “low side” that is below the centerline, and a “high side” that is above the centerline.
  • the low side will include a portion that is below the drill string
  • the high side will include a portion that is above the drill string
  • both low and high sides include portions that are along the sides of the drill string.
  • the side of the drill string may be positioned in some combination of the low and high sides.
  • Various embodiments of the present invention provide for both beads to congregate on the low side or the high sid, or for the first on the low side and the second on the high side. Beads may also congregate along the side of the drill string. When both beads are on the same side of the wellbore, it is believed that the beads may be formed into layers that are predominately one bead or the other to optimize the frictional reduction.
  • the present invention also includes well fluid additives for a particular well fluid having a well fluid specific gravity, which comprises a heavier first bead and a lighter second bead, wherein the first bead has a specific gravity exceeding that of the well fluid specific gravity, and the second bead has a specific gravity less than that of the well fluid specific gravity.
  • a well fluid specific gravity which comprises a heavier first bead and a lighter second bead, wherein the first bead has a specific gravity exceeding that of the well fluid specific gravity, and the second bead has a specific gravity less than that of the well fluid specific gravity.
  • the heavier first bead will be urged by gravity toward the low side of the wellbore, and the lighter second bead will be urged by gravity toward the high side of the well bore.
  • the first bead specific gravity may exceed the well fluid specific gravity by at least 1, 2, 4, 5, 10, 15, 20, 25, 30, 40, 45, 50, 75, 100, 150, 200, or 300 percent.
  • the well fluid specific gravity may exceed the second
  • the heavier first bead and lighter second bead may comprise any sort of relatively spherical bead that is generally suitable for the drilling of wells.
  • Non-limiting examples of which include polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
  • first bead and lighter second bead may be utilized, depending upon the conditions of the well. As a non-limiting example, it may be desirable to utilize more of the heavier first bead which will generally wind up on the low side of the wellbore, and less of the lighter second bead which will generally wind upon on the high side of the wellbore. Suitable ratios of first bead to second bead include 99:1, 95:5, 90:10, 80:20, 70:30, 60:40 and 50:50 and inverses thereof.
  • first bead and second bead may be packaged together to form a well fluid additive.
  • first bead and second bead may be added simultaneously, or may be added sequentially.
  • the present invention also includes well fluids comprising a well fluid and the w ell fluid additive as described above.
  • the well fluid utilized in the present invention includes any suitable well fluid that may be utilized for drilling a well.
  • the well fluid additive may comprise at least 0.01, 0.1, 0.5, 1,2, 5, 10, 15,20, 25, 30, 50, or 75 weight percent of the well fluid.
  • the present invention also includes methods of modifying a well fluid comprising contacting the well fluid with a well fluid additive as described above.
  • the present invention contemplates that the well fluid additive may be added to a well fluid above ground, or while the well fluid is in the wellbore.
  • the present invention also includes methods of operating a well by circulating a well fluid through the well, wherein the well fluid comprises well fluid and the well fluid additive as described above.
  • Non-limiting embodiments of these methods of operating a well include embodiments in which at least most of the first bead and the second bead congregate on the low side of the wellbore; in which at least most of the first bead and the second bead congregate on the high side of the wellbore; in which at least most of the first bead congregates on the low side of the wellbore and at least most of the second bead congregates on the high side of the wellbore; in which all of the first bead and the second bead congregate on the high side of the wellbore; and in which all of the first bead congregates on the low side of the wellbore and all of the second bead congregates on the high side of the wellbore.
  • the present invention also includes apparatus comprising a well have circulating therein a well fluid comprising a well fluid component and the well fluid additive as described above.
  • Non-limiting embodiments of this apparatus include embodiments in which at least most of the first bead and the second bead congregate on the low side of the wellbore; in which at least most of the first bead and the second bead congregate on the high side of the wellbore; in which at least most of the first bead congregates on the low side of the wellbore and at least most of the second bead congregates on the high side of the wellbore; in which all of the first bead and the second bead congregate on the high side of the wellbore; and in which all of the first bead congregates on the low side of the wellbore and all of the second bead congregates on the high side of the wellbore.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Marine Sciences & Fisheries (AREA)
  • Mechanical Engineering (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Earth Drilling (AREA)
  • Lubricants (AREA)
  • Processing Of Stones Or Stones Resemblance Materials (AREA)

Abstract

A well fluid additive having a heavier first bead and a lighter second bead, with the first bead having a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.

Description

    BACKGROUND OF THE INVENTION
  • 1. Field of the Invention
  • The present invention relates to drilling of wells, well fluids, and well fluid additives and to methods, apparatus and products related thereto.
  • 2. Description of the Related Art
  • The purpose of a rotary oil rig is to drill a hole to a predetermined depth. And, hopefully, in the drilling process, passing to or through one or more oil and gas bearing reservoir rock formations. Since rigs are expensive to manufacture, they need to be movable. In addition, since the rock chips created by the drilling bit must be removed, mud is pumped through the drill pipe to the bit and back up the annulus or space between the drill pipe and the outer casing that is added as drilling proceeds. The mud is mixed, usually with water but sometimes with chemicals, in a chemical tank, then sucked from the mud pit and pumped via a standpipe and rotary hose to a swivel that is attached to a Kelly, which is itself attached to the drill pipe. The returning mud and rock chips that reach the surface move by gravity down a return line to a shale shaker designed to separate the returning mud from the shale for reuse. The remaining rock chips travel down a shale slide to a reserve pit.
  • Technology in drilling for oil and gas has for a number of years included horizontal or directional drilling. The horizontal drilling concept exposes more surface area of the producing zone than the conventional vertical drilling operations.
  • Horizontal drilling technology achieved commercial viability during the late 1980's. Its successful employment, particularly in the Bakken Shale of North Dakota and the Austin Chalk of Texas, has encouraged testing of it in many domestic geographic regions and geologic situations. Achievable horizontal bore hole length grew rapidly as familiarity with the technique increased; horizontal displacements have now been extended to over several miles. Some wells have featured multiple horizontal bores. Completion and production techniques have been modified for the horizontal environment, with more change required as the well radius decreases; the specific geologic environment and production history of the reservoir also determine the completion methods employed.
  • The technical objective of horizontal drilling is to expose significantly more reservoir rock to the well bore surface than can be achieved via drilling of a conventional vertical well. The desire to achieve this objective stems from the intended achievement of other, more important technical objectives that relate to specific physical characteristics of the target reservoir, and that provide economic benefits. Examples of these technical objectives are the need to intersect multiple fracture systems within a reservoir and the need to avoid unnecessarily premature water or gas intrusion that would interfere with oil production.
  • In both examples, an economic benefit of horizontal drilling success is increased productivity of the reservoir. In the latter example, prolongation of the reservoir's commercial life is also an economic benefit. Applications of horizontal drilling technology have included the drilling of fractured conventional reservoirs, fractured source rocks, stratigraphic traps, heterogeneous reservoirs, coalbeds (to produce their methane content), older fields (to boost their recovery factors), and fluid and heat injection wells intended to boost both production rates and recovery factors.
  • Horizontal drilling is the process of drilling and completing, for production, a well that begins as a vertical or inclined linear bore which extends from the surface to a subsurface location, just above the target oil or gas reservoir called the “kickoff point,” then bears off on an arc to intersect the reservoir at the “entry point,” and, thereafter, continues at a near-horizontal attitude tangent to the arc, to substantially or entirely remain within the reservoir until the desired bottom hole location is reached.
  • Most oil and gas reservoirs are much more extensive in their horizontal (areal) dimensions than in their vertical (thickness) dimension. By drilling that portion of a well that intersects such a reservoir parallel to its plane of more extensive dimension, horizontal drilling's immediate technical objective is achieved.
  • That objective is to expose significantly more reservoir rock to the wellbore surface than would be the case with a conventional vertical well penetrating the reservoir perpendicular to its plane of more extensive dimension. The desire to attain this immediate technical objective is almost always motivated by the intended achievement of more important objectives (such as avoidance of water production) related to specific physical characteristics of the target reservoir.
  • For example, if a producing zone is fifty feet in thickness and a vertical well is drilled through such a zone, then only fifty feet of the producing zone will be exposed for production. In contrast, a horizontally drilled well may penetrate the producing sand or zone by one thousand feet or more. The amount or volume of oil or gas production is directly proportional to the horizontal penetration in feet into the producing sand or zone. In horizontal or directional drilling where the drill pipe must bend in order to achieve the desired penetration into the producing zone, friction becomes a major problem. The primary source of friction is directly related to the adhesion of the drilling assembly to the wall cake which lines the drilled well bore. The capillary attractive forces generated by the adhesion of the drilling assembly to the wall cake are directly proportional to the amount or footage of the drilling assembly exposed to the surface of the wall cake.
  • In the drilling of horizontal wells, gauge problems, sticking of the drill string, reactive torque, hole erosion, and tortuosity between the dynamic work string and bore hole, are generally all exacerbated. Tortuosity includes the effect of rotation of the bit and its reactive torque against the formation thereby causing the bit, bottom hole assembly and drill string to buckle, turn and twist within the well bore. Tortuosity effects well path, penetration rate, pipe sticking, etc. In an effort to overcome these issues, many methods have been used in order to reduce friction between the drilling assembly and the wall cake.
  • One such method would be to add a liquid lubricant to the drilling fluid in order t o reduce the coefficient of friction of the drilling fluid. These liquid lubricants include oils, such as hydrocarbon based oils, vegetable oils, glycols, etc. These liquid lubricants will usually reduce the coefficient of friction of the drilling fluid resulting in a reduction of friction between the drilling assembly and the wall cake of the well bore.
  • Another method has been the use of spherical drilling beads in the drilling fluid to function as the friction reducer. These drilling beads act like ba 11 bearings and function as a lubricant in well drilling applications.
  • These spherical beads are generally selected to have specific gravity greater than that of the well fluid, such that due to the horizontal inclination of the borehole, gravity will segregate the spherical beads to a position “below” the drill string.
  • Drilling Sideways—A Review of Horizontal Well Technology and Its Domestic Application, April 1993, published by the Energy Information Administration, Office of Oil and Gas, of the U.S. Department of Energy, is an overview of horizontal drilling technology.
  • U.S. Pat. No. 5,839,520, issued Nov. 24, 1998, to Maillet, discloses a method of increasing the penetration rate of a drill string within a deviated well bore. The method includes providing a drill string with a drilling bottom hole assembly, and rotating the bit in order to create the deviated well bore as well as a filter cake on the walls of the well bore. A pill comprising a spherical bead is prepared and pumped down into the well bore. The pill is allowed to migrated to the low side of the bore hole so that tortuosity is reduced. A method of slide drilling, batch drilling, and running a liner in a well is also disclosed utilizing the spherical beads. In the novel methods disclosed, the spherical beads are allowed to migrate to the low side of the borehole and are allowed to penetrate through the borehole's filter cake.
  • IADC/SPE 72290, Drilling Fluids Design and Management for Extended Reach Drilling, C. Cameron, SPE, Halliburton Energy Services 2001, discloses use of solid glass beads for reduction in torque whilst running casing, which act as “ballbearings” between the casing or open hole and the drill pipe or casing.
  • U.S. Pat. No. 7,001,871, issued Feb. 21, 2006, to Rayborn, discloses water-based drilling fluid additive containing talc and graphite. The drilling fluid additive is provided wherein the additive is manufactured by a method comprised of admixing at least one carrier such as a polypropylene glycol to talc and subsequently admixing graphite to the talc and carrier mixture; and then admixing an uintaite (a natural black bitumen) to the talc, carrier and graphite mixture.
  • U.S. Patent Publication No. 20070111899, published May 17, 2007, to Wood, discloses pre-engineered pills for the improvement of drilling muds. By introducing pills of ground elastomer into the well, the pills can improve the lubricity of the mud as well as aiding in wellbore cleaning, prevention of bit balling and reduction of fluid loss to thief zones. The pills can be prepared either on site or at a remote location and then transported to the drilling site for use. When the pill is prepared on site, the ground elastomer and non-aqueous fluid should be in contact with each other for a period sufficient to insure that the non-aqueous fluid has impregnated the elastomer particles. This will typically run from about 15 to 30 minutes.
    • SUMMARY OF THE INVENTION
  • The following presents a general summary of some of the many possible embodiments of this disclosure in order to provide a basic understanding of this disclosure. This summary is not an extensive overview of all embodiments of the disclosure. This summary is not intended to identify key or critical elements of the disclosure or to delineate or otherwise limit the scope of the claims. The following summary merely presents some concepts of the disclosure in a general form as a prelude to the more detailed description that follows.
  • According to one embodiment of the present invention, there is provided a well fluid additive. The additive includes a heavier first bead and a lighter second bead. The first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • According to another embodiment of the present invention, there is provided a well fluid additive for a well fluid having a well fluid specific gravity. The additive includes a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • According to even another embodiment of the present invention, there is provided a method of modifying a well fluid. The method includes contacting the well fluid with a well fluid additive. The well fluid additive comprises a heavier first bead and a lighter second bead. The first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • According to still another embodiment of the present invention, there is provided a method of modifying a well fluid having a well fluid specific gravity. The method includes contacting the well fluid with a well fluid additive. The well fluid additive comprises a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • According to yet another embodiment of the present invention, there is provided an apparatus comprising a well and a well fluid circulating in the well. The well fluid comprises a well fluid component and a well fluid additive. The well fluid additive comprises a heavier first bead and a lighter second bead. The first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • According to even still another embodiment of the present invention, there is provided an apparatus comprising a well and a well fluid having a well fluid specific gravity circulating in the well. The well fluid comprises a well fluid component and a well fluid additive. The well fluid additive comprises a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
  • According to even yet another embodiment of the present invention, there is provided a method of operating a well that includes circulating a well fluid in the well. The well fluid comprises a well fluid component and a well fluid additive. The well fluid additive comprises a heavier first bead and a lighter second bead. The first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
  • According to even still another embodiment of the present invention, there is provided a method of operating a well including circulating a well fluid having a well fluid specific gravity circulating in the well. The well fluid comprises a well fluid component and a well fluid additive. The well fluid additive includes a heavier first bead having a first specific gravity and a lighter second bead having a second specific gravity. The first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
    • DETAILED DESCRIPTION OF THE INVENTION
  • The present invention includes well fluid additives comprising a heavier first bead and a lighter second bead, wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1, 2, 4, 5, 10, 15, 20, 25, 30, 40, 45, 50, 75, 100, 150, 200, or 300 percent. It should be understood that as used herein, the first bead may comprise a first set of beads, and the second bead may comprise a second set of beads.
  • It should be understood that any suitable specific gravity may be utilized for the beads of the present invention. The well fluids typically have specific gravities in the rang e of about 1 to about 4, with the specific gravity of the beads selected according to where the beads are to be positioned. While any suitable range of bead specific gravity may be utilized, non-limiting examples of commercially available beads include those from about 0.5 to about 5, and from about 1 to about 4. It should be understood that as difference between the specific gravity of the bead and the well fluid increases, the bead is more likely to settle at/near the bottom or float at/near the top of the well fluid. Beads with specific gravities close to that of the well fluid may tend to more slowly settle at the bottom or float at/near the top of the well fluid. By selecting specific gravities of the beads, it may be possible to urge the beads to be a different points of the well fluid, that is, there may be different layers or zones of beads.
  • It may be desirable to utilize beads of different physical properties at various points or zones of the well fluid. As a non-limiting example, in a horizontal section, the beads of different properties may be below the pipe, along the side of the pipe, and/or above the pipe. That is, the beads that are below the pipe will have the weight of the pipe as a factor, whereas, beads above the pipe will not, and those along the side of the pipe may or may not be effected by the weight of the pipe.
  • Because of the differences in specific gravity, the first bead and the second bead will be urged by gravity to congregate in different levels of the wellbore. In a horizontal portion of a wellbore, the horizontal centerline of the wellbore divides the wellbore into a “low side” that is below the centerline, and a “high side” that is above the centerline. The low side will include a portion that is below the drill string, the high side will include a portion that is above the drill string, and both low and high sides include portions that are along the sides of the drill string. The side of the drill string may be positioned in some combination of the low and high sides. Various embodiments of the present invention provide for both beads to congregate on the low side or the high sid, or for the first on the low side and the second on the high side. Beads may also congregate along the side of the drill string. When both beads are on the same side of the wellbore, it is believed that the beads may be formed into layers that are predominately one bead or the other to optimize the frictional reduction.
  • The present invention also includes well fluid additives for a particular well fluid having a well fluid specific gravity, which comprises a heavier first bead and a lighter second bead, wherein the first bead has a specific gravity exceeding that of the well fluid specific gravity, and the second bead has a specific gravity less than that of the well fluid specific gravity. This generally means that the heavier first bead will be urged by gravity toward the low side of the wellbore, and the lighter second bead will be urged by gravity toward the high side of the well bore. As non-limiting examples, the first bead specific gravity may exceed the well fluid specific gravity by at least 1, 2, 4, 5, 10, 15, 20, 25, 30, 40, 45, 50, 75, 100, 150, 200, or 300 percent. As non-limiting examples, the well fluid specific gravity may exceed the second bead specific gravity by at least 1, 2, 4, 5, 10, 15, 20, 25, 30, 40, 45, 50, 75, 100, 150, 200, or 300 percent.
  • In the practice of the present invention, the heavier first bead and lighter second bead may comprise any sort of relatively spherical bead that is generally suitable for the drilling of wells. Non-limiting examples of which include polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
  • Any suitable ratio of heavier first bead and lighter second bead may be utilized, depending upon the conditions of the well. As a non-limiting example, it may be desirable to utilize more of the heavier first bead which will generally wind up on the low side of the wellbore, and less of the lighter second bead which will generally wind upon on the high side of the wellbore. Suitable ratios of first bead to second bead include 99:1, 95:5, 90:10, 80:20, 70:30, 60:40 and 50:50 and inverses thereof.
  • In the practice of the present invention, the first bead and second bead may be packaged together to form a well fluid additive. In the practice of the various methods of the present invention, the first bead and second bead may be added simultaneously, or may be added sequentially.
  • The present invention also includes well fluids comprising a well fluid and the w ell fluid additive as described above.
  • The well fluid utilized in the present invention includes any suitable well fluid that may be utilized for drilling a well.
  • In the practice of the present invention, the well fluid additive may comprise at least 0.01, 0.1, 0.5, 1,2, 5, 10, 15,20, 25, 30, 50, or 75 weight percent of the well fluid.
  • The present invention also includes methods of modifying a well fluid comprising contacting the well fluid with a well fluid additive as described above. The present invention contemplates that the well fluid additive may be added to a well fluid above ground, or while the well fluid is in the wellbore.
  • The present invention also includes methods of operating a well by circulating a well fluid through the well, wherein the well fluid comprises well fluid and the well fluid additive as described above. Non-limiting embodiments of these methods of operating a well include embodiments in which at least most of the first bead and the second bead congregate on the low side of the wellbore; in which at least most of the first bead and the second bead congregate on the high side of the wellbore; in which at least most of the first bead congregates on the low side of the wellbore and at least most of the second bead congregates on the high side of the wellbore; in which all of the first bead and the second bead congregate on the high side of the wellbore; and in which all of the first bead congregates on the low side of the wellbore and all of the second bead congregates on the high side of the wellbore.
  • The present invention also includes apparatus comprising a well have circulating therein a well fluid comprising a well fluid component and the well fluid additive as described above. Non-limiting embodiments of this apparatus include embodiments in which at least most of the first bead and the second bead congregate on the low side of the wellbore; in which at least most of the first bead and the second bead congregate on the high side of the wellbore; in which at least most of the first bead congregates on the low side of the wellbore and at least most of the second bead congregates on the high side of the wellbore; in which all of the first bead and the second bead congregate on the high side of the wellbore; and in which all of the first bead congregates on the low side of the wellbore and all of the second bead congregates on the high side of the wellbore.
  • The apparatus, methods and products of the present invention have described and illustrated by examples. While these apparatus, methods and products have been described in terms of particular embodiments and illustrative figures, one of ordinary skill in the art will recognize that the invention and the appended claims are not limited to the embodiments or figures described. In addition, where methods and steps described above indicate certain events occurring in certain order, those of skill in the art will recognize that the ordering of certain steps may be modified and that such modifications are in accordance with the invention, and embodiments of the invention. Additionally, certain of the steps may be performed concurrently or in parallel processes when possible, as well as performed sequentially, as described above. Thus, to the extent that there are embodiments of the invention, which are within the spirit of the disclosure or equivalent to the inventions found in the claims, it is intended that the patent will cover those embodiments as well. Finally, all publications, patents and patent applications cited in this specification are herein incorporated by reference in their entirety as if each individual reference was specifically and individually set forth herein.

Claims (40)

1. A well fluid additive comprising:
a heavier first bead; and
a lighter second bead;
wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
2. The well fluid additive of claim 1, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
3. The well fluid additive of claim 1, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
4. The well fluid additive of claim 1, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
5. The well fluid additive of claim 1, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent.
6. A well fluid additive for a well fluid having a well fluid specific gravity, the additive comprising:
a heavier first bead having a first specific gravity; and
a lighter second bead having a second specific gravity;
wherein first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
7. The well fluid additive of claim 6, wherein the first bead and the second be ad are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
8. The well fluid additive of claim 6, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
9. The well fluid additive of claim 6, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
10. The well fluid additive of claim 6, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent.
11. A method of modifying a well fluid, comprising:
contacting the well fluid with a well fluid additive, wherein, the well fluid additive comprises:
a heavier first bead; and
a lighter second bead;
wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
12. The well fluid additive of claim 11, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
13. The well fluid additive of claim 11, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
14. The well fluid additive of claim 11, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
15. The well fluid additive of claim 11, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent
16. A method of modifying a well fluid having a well fluid specific gravity, comprising:
contacting the well fluid with a well fluid additive, wherein, the well fluid additive comprises:
a heavier first bead having a first specific gravity; and
a lighter second bead having a second specific gravity;
wherein first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
17. The well fluid additive of claim 16, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
18. The well fluid additive of claim 16, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
19. The well fluid additive of claim 16, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
20. The well fluid additive of claim 16, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent
21. An apparatus comprising:
a well; and,
a well fluid circulating in the well;
wherein the well fluid comprises a well fluid component and a well fluid additive,
wherein, the well fluid additive comprises:
a heavier first bead; and
a lighter second bead;
wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
22. The well fluid additive of claim 21, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
23. The well fluid additive of claim 21, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
24. The well fluid additive of claim 21, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
25. The well fluid additive of claim 21, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent
26. An apparatus comprising:
a well; and,
a well fluid having a well fluid specific gravity circulating in the well;
wherein the well fluid comprises a well fluid component and a well fluid additive, wherein, the well fluid additive comprises:
a heavier first bead having a first specific gravity; and
a lighter second bead having a second specific gravity;
wherein first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
27. The well fluid additive of claim 26, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
28. The well fluid additive of claim 26, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
29. The well fluid additive of claim 26, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
30. The well fluid additive of claim 26, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent
31. A method of operating a well comprising:
circulating a well fluid in the well;
wherein the well fluid comprises a well fluid component and a well fluid additive,
wherein, the well fluid additive comprises:
a heavier first bead; and
a lighter second bead;
wherein first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 1 percent.
32. The well fluid additive of claim 31, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
33. The well fluid additive of claim 31, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
34. The well fluid additive of claim 31, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
35. The well fluid additive of claim 32, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent.
36. A method of operating a well comprising:
circulating a well fluid having a well fluid specific gravity circulating in the well;
wherein the well fluid comprises a well fluid component and a well fluid additive,
wherein, the well fluid additive comprises:
a heavier first bead having a first specific gravity; and
a lighter second bead having a second specific gravity;
wherein first bead first specific gravity exceeds the well fluid specific gravity, and the second bead second specific gravity is less than the well fluid specific gravity.
37. The well fluid additive of claim 36, wherein the first bead and the second bead are independently selected from the group of beads consisting of polymeric drilling beads, silicone beads, graphite beads, metal beads, ceramic beads, diamond beads, fullerene beads, metallofullerene beads, composite material beads, glass drilling beads, and any bead combination thereof, and beads made from a combination of any of the foregoing materials.
38. The well fluid additive of claim 36, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 10 percent.
39. The well fluid additive of claim 36, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 30 percent.
40. The well fluid additive of claim 36, wherein the first bead has a specific gravity that exceeds the specific gravity of the second bead by at least 100 percent.
US12/200,906 2008-08-28 2008-08-28 Methods, apparatus and products for drilling wells Abandoned US20100051274A1 (en)

Priority Applications (2)

Application Number Priority Date Filing Date Title
US12/200,906 US20100051274A1 (en) 2008-08-28 2008-08-28 Methods, apparatus and products for drilling wells
US13/473,838 US9206646B2 (en) 2008-08-28 2012-05-17 Methods and apparatus for drilling wells

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US12/200,906 US20100051274A1 (en) 2008-08-28 2008-08-28 Methods, apparatus and products for drilling wells

Related Child Applications (1)

Application Number Title Priority Date Filing Date
US13/473,838 Division US9206646B2 (en) 2008-08-28 2012-05-17 Methods and apparatus for drilling wells

Publications (1)

Publication Number Publication Date
US20100051274A1 true US20100051274A1 (en) 2010-03-04

Family

ID=41723616

Family Applications (2)

Application Number Title Priority Date Filing Date
US12/200,906 Abandoned US20100051274A1 (en) 2008-08-28 2008-08-28 Methods, apparatus and products for drilling wells
US13/473,838 Expired - Fee Related US9206646B2 (en) 2008-08-28 2012-05-17 Methods and apparatus for drilling wells

Family Applications After (1)

Application Number Title Priority Date Filing Date
US13/473,838 Expired - Fee Related US9206646B2 (en) 2008-08-28 2012-05-17 Methods and apparatus for drilling wells

Country Status (1)

Country Link
US (2) US20100051274A1 (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11447538B2 (en) 2013-02-01 2022-09-20 Bristol-Myers Squibb Company Fibronectin based scaffold proteins

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20170335643A1 (en) * 2016-04-27 2017-11-23 Barrett Allen Drilling system using drill beads and method of using and recovering the same

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3625892A (en) * 1966-03-25 1971-12-07 Union Oil Co Hydraulic fracturing of tilted subterranean formations
US3979304A (en) * 1972-09-29 1976-09-07 Union Oil Company Of California Method for drilling and treating subterranean formations using a low fluid loss agent
US6742592B1 (en) * 1999-10-07 2004-06-01 Schlumberger Technology Corporation Cementing compositions and applications of such compositions for cementing oil wells or the like
US20050230107A1 (en) * 2004-04-14 2005-10-20 Mcdaniel Billy W Methods of well stimulation during drilling operations
US20060175059A1 (en) * 2005-01-21 2006-08-10 Sinclair A R Soluble deverting agents

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3625892A (en) * 1966-03-25 1971-12-07 Union Oil Co Hydraulic fracturing of tilted subterranean formations
US3979304A (en) * 1972-09-29 1976-09-07 Union Oil Company Of California Method for drilling and treating subterranean formations using a low fluid loss agent
US6742592B1 (en) * 1999-10-07 2004-06-01 Schlumberger Technology Corporation Cementing compositions and applications of such compositions for cementing oil wells or the like
US20050230107A1 (en) * 2004-04-14 2005-10-20 Mcdaniel Billy W Methods of well stimulation during drilling operations
US20060175059A1 (en) * 2005-01-21 2006-08-10 Sinclair A R Soluble deverting agents

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
Schlumberger Online Oilfield dictionary definition of drill pipe, no date *

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11447538B2 (en) 2013-02-01 2022-09-20 Bristol-Myers Squibb Company Fibronectin based scaffold proteins

Also Published As

Publication number Publication date
US20130126242A1 (en) 2013-05-23
US9206646B2 (en) 2015-12-08

Similar Documents

Publication Publication Date Title
US20110005762A1 (en) Forming Multiple Deviated Wellbores
Baltoiu et al. State-of-the-art in coalbed methane drilling fluids
Alexander et al. Evolution of open-hole gravel pack methodology in a low Frac-window environment: case histories and lessons learned from the kraken field development
Browning* et al. Effects of Toe-Up Vs Toe-Down wellbore trajectories on production performance in the Cana Woodford
US9206646B2 (en) Methods and apparatus for drilling wells
Seymour et al. Drilling close to salt diapirs in the North Sea
Nguyen Drilling
Peterson et al. Beaver Creek Madison CO2 Enhanced Oil Recovery Project Case History; Riverton, Wyoming
Ezzat Horizontal drilling and completion fluids design criteria
Bou-Hamdan Implementation challenges of extended reach drilling and hydraulic fracturing operations in unconventional reservoirs
Tolan et al. Gravel Packing Long Openhole Intervals with Viscous Fluids Utilizing High Gravel Concentrations: Toe-to-Heel Packing without the Need for Alternate Flow Paths
Jin et al. Research on Drilling Technologies of Ultra-Thick Salt Domes in Middle Asia and Pre-Salt Strata in Middle East: Lessons Learnt from a Pilot Well in Kenkyak Oilfield and an HPHT Well in Halfaya Oilfield
Hertel Ventura Avenue Oil Field, Ventura County California
Carter et al. An integrated approach to horizontal well design and planning in Widuri field, offshore southeast Sumatra, Indonesia
Ruifeng et al. Successful cold heavy oil production with sand (CHOPS) application in massive heavy oil reservoir in Sudan: A case study
Van Kranenburg et al. Sand Control Completions for Ormen Lange Big-Bore, High-Rate Gas Development, Evaluation of Concept Selection, Qualification, Execution and Well Performance
Chellappan et al. Successful Integrated Reservoir Management Leads to Doubling of Production: A Case Study of Upper Burgan Reservoir, Raudhatain Field, Kuwait
Thomas et al. Overcoming Weight Transfer Challenges in Complex, Shallow, Extended Reach Wells on Alaska's North Slope.
Granger et al. Horizontal Well Applications in the Guymon-Hugoton Field: A Case Study
Grishankov et al. Integrated engineering approach for drilling of the first well in the Laptev Sea
Sawyer et al. The Contribution Of Synthetic Based, Non-Aqueous, Drilling Fluids To The Successful Development Of Mangala Field, India’s Largest Onshore Oilfield
Delattre et al. Performance of Cased-Hole Sand-Control Completions in High-Rate Wells—A Case Study from the Girassol Field, Angola
Firmanto et al. Alternate Path Horizontal Openhole Gravel-Pack Completion in Soft-Weak Carbonate Gas Reservoir: Offshore East Java
Cook et al. Productivity preservation via hydraulic propped fractures in the Eldfisk North Sea chalk field
Roy et al. Water Injection Completion Philosophy in A Deepwater Subsea Environment Requiring Sand Control: A Case Study of 29 Injection Wells West Of Shetland.

Legal Events

Date Code Title Description
STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION