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EP0246800A1 - Teilchen enthaltender Schaum - Google Patents

Teilchen enthaltender Schaum Download PDF

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Publication number
EP0246800A1
EP0246800A1 EP87304213A EP87304213A EP0246800A1 EP 0246800 A1 EP0246800 A1 EP 0246800A1 EP 87304213 A EP87304213 A EP 87304213A EP 87304213 A EP87304213 A EP 87304213A EP 0246800 A1 EP0246800 A1 EP 0246800A1
Authority
EP
European Patent Office
Prior art keywords
foam
sand
liquid
gas
stream
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Withdrawn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
EP87304213A
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English (en)
French (fr)
Inventor
Kevin Dale Edgley
James Lynn Stromberg
Phillip Carroll Harris
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
Priority claimed from US06/864,696 external-priority patent/US4780243A/en
Application filed by Halliburton Co filed Critical Halliburton Co
Publication of EP0246800A1 publication Critical patent/EP0246800A1/de
Withdrawn legal-status Critical Current

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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
    • 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
    • E21B21/062—Arrangements for treating drilling fluids outside the borehole by mixing components
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F23/00—Mixing according to the phases to be mixed, e.g. dispersing or emulsifying
    • B01F23/20—Mixing gases with liquids
    • B01F23/23—Mixing gases with liquids by introducing gases into liquid media, e.g. for producing aerated liquids
    • B01F23/235—Mixing gases with liquids by introducing gases into liquid media, e.g. for producing aerated liquids for making foam
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F25/00—Flow mixers; Mixers for falling materials, e.g. solid particles
    • B01F25/30—Injector mixers
    • B01F25/31—Injector mixers in conduits or tubes through which the main component flows
    • B01F25/311—Injector mixers in conduits or tubes through which the main component flows for mixing more than two components; Devices specially adapted for generating foam
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/2607—Surface equipment specially adapted for fracturing operations

Definitions

  • This invention relates generally to particle- containing foams and particularly, but not exclusively, to foamed fracturing fluids carrying high concentrations of proppant material.
  • one technique which is sometimes used to stimulate production is the fracturing of the subsurface producing formation. This is accomplished by pumping a fluid at a very high pressure and rate into the formation to hydraulically create a fracture extending from the well bore out into the formation.
  • a proppant material such as sand is included in the fracturing fluid, and subsequently deposited in the fracture to prop the fracture so that it remains open after fracturing pressure has been released from the formation.
  • foamed fracturing fluids which are at this point generally recognized. For example, one advantage is that they have low fluid loss characteristics resulting in more efficient fracture treatments and reduced damage to water sensitive formations. Another advantage is that foamed fracturing fluids have a relatively low hydrostatic head, thus minimizing fluid entry into the formation and its resultsing damage. Also, foamed fracturing fluids have a high effective viscosity permitting the creating of wider vertical fractures and horizontal fractures having greater area. Furthermore, foamed fracturing fluids typically have a high proppant carrying capacity, allowing more proppant to be delivered to the site of the fracture and more proppant to remain suspended until the fracture heals.
  • foamed fracturing fluids do have at least one major disadvantage, and this pertains to the proppant concentrations available with currently practiced foam generation techniques.
  • current techniques involve blending a mixture of proppant and liquid containing a suitable surfactant. The mixture is pumped to high pressure after which a gaseous phase, typically nitrogen or carbon dioxide, is added to produce the foamed proppant-laden fracturing fluid.
  • a gaseous phase typically nitrogen or carbon dioxide
  • This technique involves an inherent proppant concentration limitation due to the concentration limitation of the proppant/liquid mixture.
  • the theoretical maxmium concentration of a sand/liquid mixture is approximately 34 lb of sand per gallon (4.1g/cm 3 ) of liquid. This corresponds to a liquid volume just sufficient to fill the void spaces of bulk sand. In common practice, this maximum is further limited by the blending and pumping equipment capabilities and lies in a range of 15 to 25 lblgal (1.8 to 3.0g/cm 3 ).
  • foams are produced which have approximately three unit volumes of gaseous phase per unit volume of liquid phase corresponding to a foam quality, that is a gaseous volume fraction, of 75%.
  • a foam quality that is a gaseous volume fraction, of 75%.
  • the gas expands the carrier fluid to approximately four times its original volume.
  • a sand concentration of 25 pounds of sand per gallon (3.0g/cm l ) of liquid in a sand/liquid slurry is reduced to approximately 6 pounds of sand per gallon (0.7g/cm 3 ) of carrier fluid, that is foam, by the process of foaming.
  • Even the theoretical maximum sand concentration of 34 lb/gal (4.1g/cm 3 ) in the sand/liquid slurry would only produce an 8.5 Ib/gal (1.0g/cm 3 ) concentration in a 75% quality foam.
  • the concentration of proppant in the fracturing fluid is of considerable importance since this determines the final propped thickness of the fracture.
  • a fracturing fluid with a sand concentration of 34 pounds of sand per gallon (4.1g/cml) of carrier fluid could theoretically prop the fracture at its hydraulically created width.
  • Another problem encountered with many fracturing fluids including foam also involves proppant concentration and this pertains to the fracturing fluid's compatibility with the formation core and formation fluids particularly in gas wells.
  • many formations contain clays which swell when contacted by water base fluids resulting in reduced formation permeability.
  • Foamed fracturing fluids reduce this problem due to their low fluid loss and low hydrostatic head characteristics, both of which result in less fluid entering the formation.
  • the theoretical maximum sand concentration is 34 pounds of sand per gallon (4.1 g/cm 3 ) of liquid phase of the foam and, as previously mentioned, the current practical limit is-about 25 pounds per gallon (3.0g/cm 3 ).
  • a foamed fracturing fluid with a greater concentration of sand to liquid would be highly desirable for water sensitive formations since a given amount of sand could be delivered to the formation with less liquid in the carrier fluid.
  • the Bullen concentrator is stated to be capable of removing about 50% of the liquid from the slurry, thus doubling the proppant concentration in the subsequent foam to a maximum of about 5 pounds per gallon (0.6g/cm 3 ) of 75% quality foam, that is 20 pounds per gallon (2.4g/cm 3 ) of liquid in the resulting foam.
  • the present invention provides foamed compositions in which sand concentrations many times greater than even the theoretical maximum sand to liquid concentration of sand-containing slurries of 34 pounds sand per gallon (4.1g/cm 3 ) of liquid phase can be achieved. Tests have produced stable foams having sand to liquid ratios up to 100 pounds of sand per gallon (12g/cm 3 ) of liquid phase i.n the foam.
  • a foam composition containing a foam comprising liquid, gas and particulate matter, characterised by a foam quality and a particulate matter concentration as defined by the area enclosed by the trapezium A,B,C,D in Figure 3 of the accompanying drawings.
  • compositions of the present invention can be produced by introducing sand at high pressures with a gas stream into a mixing vessel, and introducing a high pressure liquid stream separately into the vessel, thus mixing the gas, liquid and sand at high pressure in the foam generator vessel. This process avoids the inherent sand carrying limitation present when the sand is introduced in a sand/liquid slurry.
  • a system generally designated by the numeral 10 for producing foamed fracturing fluids carrying high concentrations of proppant material in accordance with the principles of the present invention.
  • the system 10 is based upon the use of a dry sand foam generating apparatus generally designated by the numeral 12.
  • the invention is described in the context of the production of a proppant carrying foam for hydraulic fracturing of a well, the invention is also useful in other areas utilizing foamed fluids, such as foamed gravel packing wherein sand or the like is packed in an annulus surrounding a well casing.
  • foamed fluids such as foamed gravel packing wherein sand or the like is packed in an annulus surrounding a well casing.
  • any other particulate may be utilized such as, for example, sintered bauxite, glass beads, calcined bauxite and resin particles, as well as any other conventionally known particulates for use in the treatment of subterranean formations.
  • the foam generating apparatus 12 has a body 14 with a straight vertical main flow passage 16-disposed therethrough.
  • Main flow passage 16 has an inlet 18 at its upper end, and an outlet 20 at its lower end.
  • Foam generating apparatus 12 includes an upper first nozzle insert 22 thread ably engaged at 24 with an upper threaded counterbore 26 of body 14.
  • Nozzle insert 22 has an inner end 28 received in the body 14 and adjustably positioned relative to an annular conically tapered first seat 30 surrounding main flow passage 16.
  • Inner end 28 of nozzle insert 22 has a conically tapered annular surface 32 defined thereon.
  • the conical taper of surface 32 is complementary with that of annular seat 30, that is, the taper on both the surface 32 and seat 30 are substantially the same.
  • surface 32 and seat 30 are each tapered 60° from the horizontal.
  • An annular conical first flow path 34 is defined between tapered surface 32 and seat 30 and has width defined vertically in Fig. 1 which is adjustable by adjustment of the threaded engagement 24 between insert 22 and body 14.
  • insert 22 has a reduced diameter cylindrical outer portion 36 closely received within an upper cylindrical bore 38 of body 14 with a seal being provided therebetween by 0-ring 40.
  • An upper annular plenum 44 is defined between nozzle portion 42 of insert 22 and upper bore 38 of body 14, and surrounds the main flow passage 16.
  • a transverse liquid inlet passage 46 which may generally be referred to as a second flow passage 46, is disposed in the body 14.
  • Inlet passage 46 has an outer inlet end 48, and an inner second end 50 which is communicated with the annular plenum 44.
  • liquid inlet passage 46 is utilized to introduce a liquid stream, generally a water-based liquid including surfactant, into the foam generating apparatus 12.
  • the liquid stream also may contain other additives such as a viscosifying agent, crosslinking agent, gel breakers, corrosion inhibitors, clay stabilizers, various salts such as potassium chloride and the like which are well known conventional additives to fluids utilized in the treatment of subterranean formations.
  • the viscosifying agent can comprise, for example, hydratable polymers which contain in sufficient concentration and reactive position, one or more of the functional groups, such as, hydroxyl or hydroxyalkyl, cis-hydroxyl, carboxyl, sulfate, sulfonate, amino or amide.
  • Particularly suitable such polymers are polysaccharides and derivatives thereof, which include but are not limited to, guar gum and derivatives thereof, locust bean gum, tara, konjak, tamarind, starch, karaya, tragacanth, carrageenan, xanthan and cellulose derivatives.
  • Hydratable synthetic polymers include, but are not limited to, polyacrylate, polymethacrylate, polyacrylamide, maleic anhydride-methylvinyl ether copolymers, polyvinyl alcohol and the like.
  • crosslinking agents for the above- viscosifying agents include, but are not limited to, compounds containing titanium (IV) such as various organotitanium chelates, compounds containing zirconium IV such as various organozirconium chelates, various borate-containing compounds, pyroantimonates and the.like.
  • a lower second nozzle insert 52 is threadably engaged at 54 with an internally threaded lower counterbore 56 of body 14.
  • Second nozzle insert 52 is constructed similar to first nozzle insert 22, except that its upper inner end has a radially inner conical tapered surface 58 which is complimentary with a downward facing conically tapered second annular seat 60 defined on body 14 and surrounding main flow passage 16.
  • surface 58 and seat 60 are each tapered 15° from the horizontal.
  • the apparatus 12 can be inverted with the seats 30 and 60 then being tapered upwardly so that the conical fluid jets ejected therefrom are directed against the downward flow of gas and sand through flow passage 16.
  • a lower second annular plenum 62 is defined between second nozzle insert 52 and lower counterbore 64 of body 14.
  • a transverse supplemental gas inlet passage 66 is disposed in body 14 and communicates a supplemental gas inlet 68 thereof with the second plenum 62.
  • transverse gas inlet passage 66 and the adjustable lower nozzle insert 52 are utilized to provide supplemental gas, if necessary, to the proppant carrying foam. In some instances, however, such supplemental gas may not be necessary, and the transverse gas inlet passage 66 will not be used. In fact, the methods of the present invention can in many instances be satisfactorily performed with a foam generator in which the lower second nozzle insert 52 and the associated transverse gas inlet passage 66 are eliminated.
  • the main flow passage 16 can generally be described as including an upper portion 70 disposed through first nozzle insert 22, a middle portion 72 defined within the body 14 itself, and a lower portion 74 defined in second nozzle insert 52.
  • FIG. 1 Also schematically illustrated in Fig. 1 are a plurality of associated apparatus which are utilized with the foam generating apparatus 12 to produce a proppant laden foamed fracturing fluid.
  • a high pressure sand tank 76 is located vertically directly above the foam generating apparatus 12.
  • Sand tank 76 is substantially filled with a particulate material such as sand 78 through a sand fill inlet valve 80.
  • the sand tank 76 is then filled with high pressure nitrogen gas from a nitrogen gas supply 82 through primary nitrogen supply line 84.
  • a pressure regulator 86 and other conventional equipment (not shown) for controlling the pressure of the gas supplied to sand tank 76 are included in supply line 84.
  • gas supply 82 is disclosed herein as comprising nitrogen, many other gases are suitable for use in generating a foam according to the method and using the apparatus of the present invention. Such other gases include without limitation air and carbon dioxide, as well as any inert gas, such as any of the noble gases.
  • the sand tank 76 As the sand tank 76 is filled with sand 78, it is pressurized with nitrogen gas to a relatively high pressure, preferably above 500 psi (3.45 MPa) for reasons that are further explained below.
  • This dry sand 78 is introduced into the foam generating apparatus 12 by opening a valve 88 in sand supply line 90 which extend from a bottom 92 of sapd tank 76 to inlet 18 of main flow passage 16 of foam generating apparatus 12.
  • the sand supply line 90 preferably is a straight vertical conduit, and the valve 88 is preferably a full opening type valve such as a fully opening ball valve.
  • valve 88 When the valve 88 is opened, a stream of gas and sand is introduced into the main flow passage 16 of apparatus 12 through insert-22.
  • the dry sand 78 flows by the action of gravity and differential gas pressure downward through sand supply line 90 into the vertical bore 16 of foam generating apparatus 12.
  • a water based liquid 94 is contained in-a liquid supply tank 96.
  • a high pressure pump 98 takes the liquid 94 from supply tank 96 through a suction line 100 and discharges it under high pressure through a high pressure liquid discharge line 102 to the inlet 48 of transverse liquid inlet passage 46.
  • the liquid 94 in supply tank 96 will have a sufficient concentration of a suitable surfactant mixed therewith in tank 96, so that upon mixing the liquid 94 with gas and sand in flow passage 16, a stable foam will be formed.
  • suitable surfactants are well known in the art, and include, by way of example and not limitation, betaines, sulfated or sulfonated alkoxylates, alkyl quaternary amines, alkoxylated linear alcohols, alkyl sulfonates, alkyl aryl sulfonates-, C 10 - C 20 alkyldiphenyl ether sulfonates and the like.
  • the liquid and surfactant flow through the transverse liquid inlet passage 46 into the annular plenum 44.
  • the liquid and surfactant then flow from the annular plenum 44 in the form of a self-impinging conical jet flowing substantially symmetrically through the first annular flow passage 34 and impinging upon the vertically downward flowing stream of gas and sand flowing through main flow passage 16.
  • This high pressure, high speed, self-impinging conical jet of water based liquid and surfactant mixes with the downward flowing stream of gas and dry sand in a highly turbulent manner so as to produce a foam comprised of a liquid matrix of bubbles filled with nitrogen gas.
  • This foam carries the sand in suspension therein.
  • Supplemental gas supply line 110 connects to supplemental gas inlet 68 of transverse gas inlet passage 66 so that gas is introduced into the second annular plenum 62 and then through the conical flow passage defined between conically tapered surface 58 on the inner end of lower nozzle insert 52 and the tapered annular lower set 60 of body 14.
  • the proppant laden foam generated in the foam generating apparatus 12 exits the outlet 20 and is conducted through conduit 114 to a well 116.
  • the foam fracturing fluid is airected downwardly through tubing (not shown) in the well l 16 to a subsurface formation (not shown) which is to be fractured.
  • the pressure of the fracturing fluids contained in conduit 1 14 when introduced into the well head 116 are substantially in excess of atmospheric pressure.
  • Well.head pressures in a range from 1000 psi to 10,000 psi (6.89 to 68.9 MPa) are common for hydraulic fracturing operations.
  • the delivery rate of dry sand 78 into the foam generator 12 is controlled by the differential gas pressure between the sand tank 76 and the bore 16 of the foam generator apparatus 12.
  • flow rate of the liquid jet entering transverse liquid inlet passage 46 determines the liquid sand concentration, that is, the pounds of sand per gallon of liquid phase in the carrier fluid, of the generated foam.
  • the volume rate of gas through sand supply line 90 required to deliver the dry sand together with the volume rate of supplemental gas, if any, supplied through transverse gas inlet passage 66 determine the quality, that is, the gaseous volume fraction of fluid phases of the generated foam.
  • the setting of the threaded engagement of upper nozzle insert 22 with body 14, permits adjustment of the width of annular flow passage 34. This adjustment generally is utilized for the purpose of achieving an appropriate mixing energy and, thus, a satisfactory foaming of the materials which are mixing within the main flow passage 16.
  • suitable flowmeters may be placed in lines 84, 102 and 110, if desired. Flow of sand out of tank 76 can be measured by measuring a change in weight of the tank 76 and its contents.
  • Fig. 2 a graphical representation is presented of the theoretical maximum sand concentration of a foam as a function of foam quality, both for wet sand foam generation such as has been practiced in the prior art where the sand is introduced in a sand/liquid slurry, and for dry sand foam generation as disclosed in the present application wherein the sand is introduced with a stream of gas.
  • Foam sand concentration e.g., the pounds of sand per gallon of foam
  • the values displayed on the right-hand vertical axis of Fig. 2 are for liquid sand concentrations, e.g., pounds of sand per gallon of liquid phase of the foam.
  • the theoretical maximum foam sand concentration for a wet sand foam generation process like that utilized in the prior art is shown by the dashed line 118 and is seen to be a decreasing linear function of foam quality.
  • the plotted maximum concentrations for the wet sand foam generation process as represented by line 118 are obtained by adding sufficient gas volume to the liquid occupying the void volume of bulk sand to obtain a given foam quality.
  • the theoretical maximum foam sand concentration for the dry sand foam generation process of the present invention is represented by the solid line 120 and is seen to be an increasing linear function of foam quality.
  • the plotted maximum concentrations for the dry sand foam generation process as represented by straight line 120 are obtained by adding sufficient liquid to the gas volume occupying the void volume of bulk sand to obtain a given foam quality.
  • the foam composition produced by the present invention have a "Mitchell quality", that is, a volume ratio of the gaseous phase to the total gaseous and liquid phases and disregarding the volume of the particulate solids, in the range from about 0.53 to 0.99 during at least some portion of the treatment of a subterranean formation with such f,oam composition.
  • This can also be expressed as a quality in the range from about 53% to about 99%.
  • a general discussion of the Mitchell quality concept can be found in U.S. Patent Nos. 4,480,696 to Almond et al; 4,448,709 to Bullen and 3,937,283 to Blauer et al.
  • an upper limit of foam quality be about 96% because the properties of the foam become somewhat unpredictable at higher quality levels where the foam may convert to a mist.
  • the generally preferred range of quality for foams generated by the dry sand foam generation process of the present invention is in a range from about 53% to about 96%.
  • line 124 shows a constant 34 lb/gal (4.1g/cm3) theoretical maximum liquid sand concentration. As previously explained, this is determined by the volume of liquid required to fill the void spaces in tightly packed sand.
  • proppant carrying foamed fracturing fluid compositions can be produced which contain a ratio of sand to the liquid phase of the foam, that is, a liquid sand concentration such as that represented on the right-hand vertical axis of Fig. 2, substantially in excess of both the theoretical maximum ratio of particulate material to liquid which could have been contained in the liquid, such as 34 lbs/gal (4.1g/cm 3 ), and the somewhat lower practical maximum ratio, such as 15 to 25 lbs/gal (1.8 to 3.0g/cm 3 ), which could have been contained in the liquid as a result of limitations on pumping equipment and the like.
  • the compositions of the present invention are those denoted by the trapezoidal region defined by the points A,B,C and D.
  • the sand tank 76 was pressurized to approximately 75 psi (520 kPa) with compressed air.
  • the differential pressure between sand tank 76 and main flow passage 16 of the foam generator was about 50 pst (345 kPa).
  • the test was run until a five-gallon bucket (1.9 x 10 2 M 3 ) was filled with foam exiting outlet 20.
  • the weight of sand delivered from sand tank 76, and water delivered from supply tank 96 were determined, and converted on a volume basis.
  • the five gallons (1.9 x 10 -2 m ) of foam collected included 1.32 gallons (5.0 x 10- 3 m 3 ) of sand and 0.37 gallons (1.4 x 10 -3 m 3 ) of water.
  • the remaining volume of the five gallons (1.9 x 10 -2 m 3 ) of foam, such as, 3.31 gallons (1.3 x 10 -2 m 3 ) was comprised of air. From this data, a foam quality of 89.9% was calculated.
  • the liquid sand concentration was calculated to be 74.9 pounds of sand per gallon (9.0 g/cm 3 ) of water in the foam, which corresponds to 7.53 pounds of sand per gallon (0.9 g/cm B ) of foam.
  • the liquid was actually introduced through passage 66 rather than passage 46, so that the liquid entered flow passage 16 as a concentric conical jet tapered downwardly at an angle of 15° to the horizontal.
  • the foam generating apparatus 12 utilized in this test had a bore 16 with a diameter of 3/8 inch (9.5mm).
  • This test was run using a foam generator with a 5/8 inch (15.9mm) bore.
  • the liquid stream was injected into passage 46 so that it entered the main flow passage 16 at a downward angle of 60° to the horizontal.
  • the test apparatus was modified to allow the generated foam to be collected in a receiver vessel (not shown) at approximately the same pressure at which it was generated.
  • the volume of generated foam was determined by measuring a volume of water displaced from the receiver vessel.
  • An average nitrogen pressure in sand tank 76 was 756 psig (5.2 MPa gauge).
  • Average pressure in the bore 16 of foam generating apparatus 12 was 750 psig (5.2 MPa gauge).
  • Average pressure in the foam receiver vessel was 730 psi.g (5.0 MPa gauge).
  • the test was run for 5.0 minutes.
  • Total sand weight delivered was 292 lb. (133 kg) for a sand rate of 58.4 lb/min (26.5 kg/min).
  • Total liquid supplied was 3.0 gal (1.1 x 10 -2 m 3 ) for a liquid rate of 0.60 gallons per minute (2.3 x 10-2 m 3 per minute).
  • the gas flow rate of the apparatus 12 was calculated to be 55.7 standard cubic feet (1.56 m 3 ) per minute.
  • Total foam generated was 57.37 gal (0.22 m 3 ). From this data, a foam quality at the foam generator 12 of 93% was calculated.
  • a liquid sand concentration of 97.3 pounds of sand per gallon (11.7g/cm 3 ) of liquid phase of the foam was calculated. This corresponds to a foam sand concentration of 6.8 pounds of sand per gallon (0.8g/cm3) of foam.
  • a volumetric rate of foam production at the generator was 11.26 gallons (4.3 x 10 2 m 3 ) per minute

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Mechanical Engineering (AREA)
EP87304213A 1986-05-16 1987-05-12 Teilchen enthaltender Schaum Withdrawn EP0246800A1 (de)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US86462186A 1986-05-16 1986-05-16
US864621 1986-05-16
US864696 1986-05-19
US06/864,696 US4780243A (en) 1986-05-19 1986-05-19 Dry sand foam generator

Publications (1)

Publication Number Publication Date
EP0246800A1 true EP0246800A1 (de) 1987-11-25

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EP87304214A Expired EP0247754B1 (de) 1986-05-16 1987-05-12 Apparat und Verfahren zum Herstellen von Teilchen enthaltendem Schaum
EP87304213A Withdrawn EP0246800A1 (de) 1986-05-16 1987-05-12 Teilchen enthaltender Schaum

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Application Number Title Priority Date Filing Date
EP87304214A Expired EP0247754B1 (de) 1986-05-16 1987-05-12 Apparat und Verfahren zum Herstellen von Teilchen enthaltendem Schaum

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EP (2) EP0247754B1 (de)
DE (1) DE3765698D1 (de)
ES (1) ES2018546B3 (de)
SG (1) SG5791G (de)

Cited By (4)

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US7213651B2 (en) 2004-06-10 2007-05-08 Bj Services Company Methods and compositions for introducing conductive channels into a hydraulic fracturing treatment
CN107130953A (zh) * 2017-05-17 2017-09-05 成都百联油田技术服务有限公司 一种化学强化采气工艺
CN108035700A (zh) * 2017-11-30 2018-05-15 青岛海洋地质研究所 海洋天然气水合物生产井井筒携砂规律仿真系统及方法
CN114262607A (zh) * 2021-12-31 2022-04-01 昆山京昆油田化学科技有限公司 一种铝钛复合交联剂及其制备方法和应用、瓜尔胶酸性压裂液体系

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GB201112754D0 (en) * 2011-07-25 2011-09-07 Clyde Union Ltd Particulate material delivery method and system
NO20141019A1 (no) * 2013-08-23 2015-02-24 Chevron Usa Inc System, anordning og fremgangsmåte for deliquification av en brønn
US10408026B2 (en) 2013-08-23 2019-09-10 Chevron U.S.A. Inc. System, apparatus, and method for well deliquification
EP3658264A4 (de) * 2017-07-07 2021-04-07 Linde GmbH Kryogenes und lco2-mehlkühlsystem
CN115945115B (zh) * 2022-12-16 2024-05-17 重庆科技学院 一种三级搅拌一级增速油套环空起泡装置

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US4126181A (en) * 1977-06-20 1978-11-21 Palmer Engineering Company Ltd. Method and apparatus for formation fracturing with foam having greater proppant concentration
FR2521869A1 (fr) * 1982-02-25 1983-08-26 Debreceni Mezoegazdasagi Dispositif de formation de mousse comportant un appareil de commande, notamment pour le marquage a la mousse dans le domaine agricole
US4448709A (en) * 1980-11-06 1984-05-15 Bullen Ronald S Proppant concentrator
EP0145227A1 (de) * 1983-12-13 1985-06-19 Halliburton Company Verfahren und Vorrichtung zur Schaumerzeugung

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US4354552A (en) * 1980-09-08 1982-10-19 The Dow Chemical Company Slurry concentrator
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Publication number Priority date Publication date Assignee Title
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US7213651B2 (en) 2004-06-10 2007-05-08 Bj Services Company Methods and compositions for introducing conductive channels into a hydraulic fracturing treatment
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CN108035700A (zh) * 2017-11-30 2018-05-15 青岛海洋地质研究所 海洋天然气水合物生产井井筒携砂规律仿真系统及方法
CN108035700B (zh) * 2017-11-30 2023-04-18 青岛海洋地质研究所 海洋天然气水合物生产井井筒携砂规律仿真系统及方法
CN114262607A (zh) * 2021-12-31 2022-04-01 昆山京昆油田化学科技有限公司 一种铝钛复合交联剂及其制备方法和应用、瓜尔胶酸性压裂液体系

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SG5791G (en) 1991-04-05
DE3765698D1 (de) 1990-11-29
EP0247754A1 (de) 1987-12-02
ES2018546B3 (es) 1991-04-16
EP0247754B1 (de) 1990-10-24

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