EP0601724A2 - Verfahren und Vorrichtung zum Verringern der Grösse von Feststoffpartikeln in Flüssigkeiten - Google Patents

Verfahren und Vorrichtung zum Verringern der Grösse von Feststoffpartikeln in Flüssigkeiten Download PDF

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Publication number
EP0601724A2
EP0601724A2 EP93309257A EP93309257A EP0601724A2 EP 0601724 A2 EP0601724 A2 EP 0601724A2 EP 93309257 A EP93309257 A EP 93309257A EP 93309257 A EP93309257 A EP 93309257A EP 0601724 A2 EP0601724 A2 EP 0601724A2
Authority
EP
European Patent Office
Prior art keywords
solids
fluid
pump
choke
velocity
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Withdrawn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
EP93309257A
Other languages
English (en)
French (fr)
Other versions
EP0601724A3 (de
Inventor
James L. Doerksen
Robert J. Morris
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.)
Halliburton Co
Original Assignee
Halliburton Co
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 Halliburton Co filed Critical Halliburton Co
Publication of EP0601724A2 publication Critical patent/EP0601724A2/de
Publication of EP0601724A3 publication Critical patent/EP0601724A3/de
Withdrawn legal-status Critical Current

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    • 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
    • E21B21/06—Arrangements for treating drilling fluids outside the borehole
    • E21B21/063—Arrangements for treating drilling fluids outside the borehole by separating components
    • E21B21/065—Separating solids from drilling fluids
    • E21B21/066—Separating solids from drilling fluids with further treatment of the solids, e.g. for disposal
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B02—CRUSHING, PULVERISING, OR DISINTEGRATING; PREPARATORY TREATMENT OF GRAIN FOR MILLING
    • B02C—CRUSHING, PULVERISING, OR DISINTEGRATING IN GENERAL; MILLING GRAIN
    • B02C19/00—Other disintegrating devices or methods
    • B02C19/06—Jet mills
    • B02C19/066—Jet mills of the jet-anvil type

Definitions

  • the present invention relates generally to a method and apparatus for reducing the size of particulate solids in a fluid medium, particularly but not exclusively, solids such as drill cuttings from a well bore.
  • U.S. patent specification no. 5,109,933 discloses the use of a particular configuration of centrifugal pump having an open channel between the fluid inlet and the blade tips; with the pump assembly modified to operate at a speed approximately fifty percent faster than the recommended pump speed for conventional applications. The action of the pump subjects the cuttings to shear, resulting in reduced size. Once the action of the modified centrifugal pump has sufficiently reduced the cutting particle size, the slurry containing the centrifugally sheared cuttings is utilized to convey the cuttings to a subsurface location.
  • apparatus for reducing the particle size of drill cuttings contained in a fluid medium which apparatus comprises a primary pump for receiving and moving fluid medium containing said drill cuttings; a choke assembly arranged in the discharge path of said pump to receive fluid medium and said drill cuttings from said pump and to increase the velocity fluid and to impede the movement thereof; an impingement means cooperatively arranged with a choke for receiving the increased velocity mixture fluid and to impede the movement thereof.
  • the invention also provides a method of reducing the particle size of solids recovered from a wellbore, said solids being associated with sufficient liquid to be in a fluidizable state, which method comprises the steps of applying a pressure to said fluidizable solids to fluidize said solids and to impart a velocity thereto; and impinging said particles against a surface to stop the velocity thereof so as to induce breakage and particle size reduction of said solids.
  • An example of an apparatus in accordance with the present invention preferably includes a pressurizing assembly for receiving a volume of fluidizable solids.
  • the solids will be fluidizable, preferably by being mixed with, or otherwise contained within, a suitable volume of liquid to establish a flowable raw cutting slurry.
  • the pressurizing assembly for example a relatively high pressure pump, will be utilized to further impart a velocity to the raw cutting slurry.
  • a conventional choke assembly will be utilized to further increase the established velocity of the slurry.
  • the moving slurry will then be conveyed in such manner as to cause the slurry to strike a breaking or impingement assembly which will suddenly impede the movement of the solids within the slurry, thereby inducing breakage of the solids.
  • the fluids will be directed through a choke, as previously described, and will be allowed to strike a generally flat impingement surface several inches away.
  • the high pressure pump will preferably be utilized to apply pressure to the fluid sufficient in the system utilized to establish a velocity to the fluid sufficient to cover particle size reduction when travel of the particles thereby is impeded.
  • the pressure applied to the slurry by the high pressure pump will preferably be in excess of approximately 300-500 psi (2.07-3.45 MPa); will further preferably be in excess of approximately 1,000 psi (6.89 MPa), and most preferably will be within the range of approximately 1,400-1,700 psi (9.6-11.7 MPa).
  • These pump pressures may be adjusted in response to the size and composition of particles being treated.
  • Drill cutting size reduction apparatus 10 in accordance with the present invention; such apparatus adapted to reduce the size of drill cuttings and to inject the cuttings, such as through a wellhead, to a subterranean location.
  • Drill cutting size reduction apparatus 10 includes a mixing tank 12 which will retain cuttings and a liquid carrier or process fluid during the cutting size reduction operation.
  • drill cutting size reduction apparatus 10 includes a primer or booster pump 14 adapted to receive a slurry mixture from mixing tank 12 to pressurize the slurry for introduction into the suction end 16 of high pressure injection pump 18.
  • the assembly of a mixing tank and a booster pump to facilitate removal from the tank may be a conventional skid-mounted assembly as is commonly present at a drill site.
  • High pressure injection pump 18 will supply the force actually utilized to "break" or reduce the cutting particle size.
  • apparatus 10 includes a bypass conduit 19 past high pressure pump 18 to facilitate fluid returns to mixing tank 12.
  • the outlet side 20 of high pressure pump 18 is coupled to a manifold assembly, indicated generally at 22, which preferably includes first and second flow control valves 24 and 26.
  • Manifold assembly 22 also preferably includes a conventional pressure relief valve 28 suitably arranged to relieve an over-pressure condition in manifold assembly 22.
  • First flow control valve 24 controls the passage of fluid from outlet side 20 of high pressure pump 18 to a choke chamber 30; the output of which 32 serves as an inlet to mixing tank 12.
  • Second flow control valve 26 controls the passage of a slurry from the output of high pressure pump 18 to a collection location, such as a wellhead or other surface mechanism for communicating the slurry injection to a subterranean location.
  • mixing tank 12 will be a conventional tank having a capacity of approximately fifty barrels, and will preferably include a conventional agitation or mixing assembly, as indicated schematically at 34.
  • An appropriate conduit 36 will supply an effluent from mixing tank 12 to the inlet of booster pump 14.
  • Booster pump 14 may be of any convenient design capable of pressurizing the slurry effluent from tank 12 to pressurize suction end 16 of high pressure injection pump 18.
  • a 4 x 6 rubber-lined centrifugal pump manufactured by the Galligher Co. of Salt Lake City, Utah has been found to be satisfactory.
  • a rubber-lined pump is not necessary, but has been utilized for testing purposes, as it was least likely to induce breakage of the drill cuttings.
  • the pump utilized pumped at a rate of approximately 15 barrels per minute (BPM).
  • High pressure injection pump 18 may be of virtually any appropriate and desired configuration. Injection pump 18 can be, and will preferably be, the same high pressure pump to be utilized for pumping the reduced particle size slurry into the subsurface formation.
  • a model HT-400 pump, manufactured by Halliburton Services, Duncan, Oklahoma, pump has been utilized and found satisfactory. In test of the invention, the HT-400 pump was configured to pump a volume of approximately five barrels per minute (5 BPM) at a pressure of 1,500 psi.
  • the outlet of booster pump 14 may be coupled to high pressure injection pump 18 through use of a "logger" header which facilitates providing the pressurized output of booster pump 14 to multiple inlets of suction end 16 of pump 18, while allowing excess to return through bypass conduit 19 to mixing tank 12.
  • First and second flow control valves 24 and 26 are each preferably plug valves.
  • plug valves For example, the Low Torque Plug Valves made by Halliburton Services, of Duncan, Oklahoma have been found to be satisfactory.
  • flow control valves may be of any desired type, such as ball valves; or a three-way valve could be utilized in place of both valves.
  • the outlet conduit 40 coupled to outlet side 20 of high pressure pump 18, will have approximately a two inch internal diameter.
  • each flow control valve 24, 26, and the related conduits will also preferably have an internal diameter of approximately two inches.
  • Choke chamber 30 operatively coupled downstream of first flow control valve 24.
  • Choke chamber 30 preferably includes a fixed diameter choke section, indicated generally at 42, coupled to a particle breaking chamber, indicated generally at 44.
  • a fixed choke having a ceramic-lined orifice with a diameter of 0.5 inches has been found satisfactory.
  • the velocity of the slurry through the choke was approximately 343 ft./sec.
  • Particle breaking chamber 44 is preferably a generally cylindrical chamber having an inlet 46 proximate one end and an impingement block 48 disposed longitudinally therefrom. A generally radial fluid exit 50 is preferably provided intermediate the length between inlet 46 and impingement block 48.
  • Impingement block 48 includes a generally flat impingement surface, although many configurations of impingement surfaces may be envisioned. For example, convex and concave surfaces, or multiple surfaces formed of rods or bars, or other structures, in chamber 44 are contemplated.
  • particle breaking chamber 44 is approximately 4.5 inches in internal diameter and extends approximately fourteen inches from choke 42 to forward surface 52 of impingement block 48. Fluid outlet 50 of choke chamber 30 will extend to a conduit 32 providing return flow to mixing tank 12. In the described exemplary apparatus, the return flow to mixing tank 12 is provided through a two-inch conduit.
  • Booster pump 14 will pull the mixed slurry of generally mixed drill cuttings and carrier fluid from tank 12 to provide a stable pressurized fluid source for high pressure injection pump 18.
  • High pressure injection pump 18 will further pressurize the slurry, forcing the mixture through outlet conduit 40 and first flow control valve 24, and thereby through fixed choke 42.
  • the velocity of the mixture is increased to "fire" the mixture into surface 52 of impingement block 48. This results in breaking of the drill cutting particles.
  • the partially reduced particle size slurry will be circulated through the system until such time as the drill cuttings are sufficiently reduced in size to facilitate introduction into the subterranean formation. At such time, first flow control valve 24 will be closed, and second flow control valve 26 will be opened, thereby facilitating the transfer of the reduced particle size slurry directly to a wellhead, or other appropriate assembly, for introduction into the subsurface formation.
  • the process was tested relative to reducing the size of drill cuttings of which almost 50 percent of the sample had a particle size greater than 2,000 microns (0.0779 inch; or retained by a 10 mesh screen), with the largest measured particle being 0.72 x 0.48 x 0.03 inch.
  • the particles of this latter approximate size made up approximately 2 percent of the total sample.
  • Approximately 23 percent of the cuttings ranged in size between 10 and 20 mesh (between 2000 microns and 850 microns); with another substantial portion of the cuttings ranging between 20 and 60 mesh (between 850 microns and 250 microns); with the remainder of the particles being of smaller sizes.
  • the process fluid may be any suitable and desired fluid, including, for example, fresh water, salt water and viscofied water.
  • fresh water was used as the process fluid in the mixing tank, and after circulation of the fluid began, the graded drill cuttings were metered into the reservoir. The addition rate of the drill cuttings was approximately 2 cubic feet per minute.
  • the process fluid was water viscofied with Halliburton WG-11 Gel, at a mixture of approximately 60 lb./1,000 gallons.
  • FIG. 3 therein is depicted an alternative embodiment of a drill cutting particle size reduction apparatus in accordance with the present invention, indicated generally at 60, and illustrated in schematic form.
  • Particle size reduction apparatus 60 is similar to previously described apparatus 10, with the exception that apparatus 60 schematically depicts the use of a mechanical particle size reduction apparatus, such as a grinder, "shredder” or similar device 62 coupled to the output of booster pump 14 to reduce the size of any exceptionally large cuttings to assure that all cuttings transmitted through the high pressure pump and other equipment will be of a size which may safely be handled.
  • a mechanical particle size reduction apparatus such as a grinder, "shredder” or similar device 62 coupled to the output of booster pump 14 to reduce the size of any exceptionally large cuttings to assure that all cuttings transmitted through the high pressure pump and other equipment will be of a size which may safely be handled.
  • Devices such as the Shredder or De-lumper devices manufactured by the Franklin Miller Company of New Jersey may be utilized.
  • Shredder 62 will also serve the purpose of eliminating large stones
  • Particle size reduction apparatus also includes a plurality of choke chambers 64, 66 and 68 coupled in series through conduits 65 and 67, with a return conduit 69 to mixing tank 12.
  • These multiple choke chambers 64, 66, and 68 are utilized in place of the single choke chamber 30 in the embodiment of Fig. 1.
  • Choke chambers 64, 66 and 68 may each have a uniform size choke or may have a graduation of size chokes. The sizes of the chokes should be selected to maintain an acceptable level of pressure drop across the combined choke chambers 64, 66, and 68.
  • Impingement assembly 70 includes a housing 72 defining an internal chamber 74 with a choke discharge 76 forming an inlet at one end of the chamber.
  • a chamber discharge 78 is placed generally longitudinally opposite inlet 76.
  • a number of reducing elements, such as metal balls 80 are placed in chamber 74.
  • Fig. 4 depicts balls 80 as they might appear during operation, where the discharge from choke 42 urges the balls 80 toward the opposite end of chamber 74.
  • Balls 80 may be of either a single size, or of varying sizes.
  • barrier members 82a and 82b such as crossbars, may be provided therein to retain balls 80 within chamber 74.
  • the balls should be caused to agitate as the fluid and drill cuttings are forced therethrough, thereby reducing the drill cutting size not only through impact, but also through the grinding action of the circulating and rotating balls.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Mechanical Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Food Science & Technology (AREA)
  • Excavating Of Shafts Or Tunnels (AREA)
  • Earth Drilling (AREA)
  • Disintegrating Or Milling (AREA)
EP93309257A 1992-12-09 1993-11-19 Verfahren und Vorrichtung zum Verringern der Grösse von Feststoffpartikeln in Flüssigkeiten. Withdrawn EP0601724A3 (de)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US98806392A 1992-12-09 1992-12-09
US988063 1992-12-09

Publications (2)

Publication Number Publication Date
EP0601724A2 true EP0601724A2 (de) 1994-06-15
EP0601724A3 EP0601724A3 (de) 1995-01-18

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EP93309257A Withdrawn EP0601724A3 (de) 1992-12-09 1993-11-19 Verfahren und Vorrichtung zum Verringern der Grösse von Feststoffpartikeln in Flüssigkeiten.

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EP (1) EP0601724A3 (de)
AU (1) AU5224093A (de)
CA (1) CA2110956A1 (de)
MX (1) MX9307759A (de)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7600703B2 (en) 2003-08-19 2009-10-13 Resolution Chemicals Limited Particle-size reduction apparatus and use thereof
US7644880B2 (en) 2004-12-16 2010-01-12 Resolution Chemicals Limited Particle-size reduction apparatus, and use thereof
US9133705B2 (en) 2010-12-16 2015-09-15 Exxonmobil Upstream Research Company Communications module for alternate path gravel packing, and method for completing a wellbore
US9291019B2 (en) 2011-12-20 2016-03-22 Exxonmobil Upstream Research Company Systems and methods to inhibit packoff formation during drilling assembly removal from a wellbore
CN108686526A (zh) * 2018-07-05 2018-10-23 马鞍山市思迪包装材料科技有限公司 一种流动式复合纸板加工用固液混合设备

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN113058715B (zh) * 2021-03-19 2022-11-18 贵州宇昆湿拌砂浆环保建材有限公司 一种磷石膏湿拌砂浆制备应用过程中的冲喷装置

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
BE787325A (fr) * 1971-08-09 1973-02-08 Lone Star Ind Inc Procede de fragmentation de substances solides anisotropes et appareil pour sa mise en oeuvre
CA1001090A (en) * 1972-03-20 1976-12-07 Canuck Oilfield Services Ltd. Drilling fluid degassing
US3881660A (en) * 1973-09-13 1975-05-06 United States Steel Corp Mineral beneficiation by decompression scalping
DE69016000T3 (de) * 1990-03-09 2000-01-05 Mitsubishi Kasei Corp., Tokio/Tokyo Prallzerkleinerer.
FR2661450A1 (fr) * 1990-04-30 1991-10-31 Total Petroles Procede et dispositif pour le cassage de mousses chargees de deblais provenant du forage de puits et pour la recuperation de la phase liquide de ces mousses.

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US7600703B2 (en) 2003-08-19 2009-10-13 Resolution Chemicals Limited Particle-size reduction apparatus and use thereof
US7861957B2 (en) 2003-08-19 2011-01-04 Resolution Chemicals Limited Particle-size reduction apparatus, and use thereof
US7644880B2 (en) 2004-12-16 2010-01-12 Resolution Chemicals Limited Particle-size reduction apparatus, and use thereof
US8052076B2 (en) 2004-12-16 2011-11-08 Resolution Chemicals Limited Particle-size reduction apparatus, and use thereof
US9327039B2 (en) 2004-12-16 2016-05-03 Resolution Chemicals Limited Particle size reduction apparatus, and use thereof
US9133705B2 (en) 2010-12-16 2015-09-15 Exxonmobil Upstream Research Company Communications module for alternate path gravel packing, and method for completing a wellbore
US9291019B2 (en) 2011-12-20 2016-03-22 Exxonmobil Upstream Research Company Systems and methods to inhibit packoff formation during drilling assembly removal from a wellbore
CN108686526A (zh) * 2018-07-05 2018-10-23 马鞍山市思迪包装材料科技有限公司 一种流动式复合纸板加工用固液混合设备

Also Published As

Publication number Publication date
MX9307759A (es) 1994-06-30
EP0601724A3 (de) 1995-01-18
AU5224093A (en) 1994-06-23
CA2110956A1 (en) 1994-06-10

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