US3664422A - Well fracturing method employing a liquified gas and propping agents entrained in a fluid - Google Patents

Well fracturing method employing a liquified gas and propping agents entrained in a fluid Download PDF

Info

Publication number
US3664422A
US3664422A US3664422DA US3664422A US 3664422 A US3664422 A US 3664422A US 3664422D A US3664422D A US 3664422DA US 3664422 A US3664422 A US 3664422A
Authority
US
United States
Prior art keywords
propping agents
liquified gas
fluid
gelled
alcohol
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.)
Expired - Lifetime
Application number
Inventor
Ronald S Bullen
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.)
B J TITAN SERVICES COMPANY HOUSTON TEXAS A PARTNERSHIP OF TEXAS
Original Assignee
Dresser Industries Inc
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 Dresser Industries Inc filed Critical Dresser Industries Inc
Application granted granted Critical
Publication of US3664422A publication Critical patent/US3664422A/en
Assigned to WESTERN ATLAS INTERNATIONAL, INC., reassignment WESTERN ATLAS INTERNATIONAL, INC., ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: DRESSER INDUSTRIES, INC., A CORP. OF DE
Assigned to B. J. TITAN SERVICES COMPANY, HOUSTON, TEXAS, A PARTNERSHIP OF TEXAS reassignment B. J. TITAN SERVICES COMPANY, HOUSTON, TEXAS, A PARTNERSHIP OF TEXAS ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: WESTERN ATLAS INTERNATIONAL, INC., A CORP. OF DE
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Images

Classifications

    • EFIXED CONSTRUCTIONS
    • E21EARTH DRILLING; MINING
    • E21BEARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25Methods for stimulating production
    • E21B43/26Methods for stimulating production by forming crevices or fractures
    • E21B43/2605Methods for stimulating production by forming crevices or fractures using gas or liquefied gas
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17CVESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C9/00Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure
    • F17C9/02Methods or apparatus for discharging liquefied or solidified gases from vessels not under pressure with change of state, e.g. vaporisation
    • F17C9/04Recovery of thermal energy
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17CVESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00Handled fluid, in particular type of fluid
    • F17C2221/01Pure fluids
    • F17C2221/013Carbone dioxide
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17CVESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00Handled fluid, in particular type of fluid
    • F17C2221/01Pure fluids
    • F17C2221/014Nitrogen
    • FMECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17CVESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2223/00Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel
    • F17C2223/01Handled fluid before transfer, i.e. state of fluid when stored in the vessel or before transfer from the vessel characterised by the phase
    • F17C2223/0146Two-phase
    • F17C2223/0153Liquefied gas, e.g. LPG, GPL

Definitions

  • This invention relates to the art of hydraulically fracturing subterranean earth formations surrounding oil wells, gas wells, and similar bore holes.
  • this invention relates to hydraulic fracturing utilizing a liquified gas and a fluid containing entrained propping agents.
  • Hydraulic fracturing has been widely used for stimulating the production of crude oil and natural gas from wells completed in reservoirs of low permeability.
  • Methods employed normally require the injection of a fracturing fluid containing suspended propping agents into a well at a rate sufficient to open a fracture in the exposed formation.
  • a fracturing fluid containing suspended propping agents into a well at a rate sufficient to open a fracture in the exposed formation.
  • Continued pumping of fluid into the well at a high rate extends the fracture and leads to the build-up of a bed of propping agent particles between the fracture walls. These particles prevent complete closure of the fracture as the fluid subsequently leaks off into the adjacent formations and results in a permeable channel extending from the well bore into the formations.
  • the conductivity of this channel depends upon the fracture dimensions, the size of the propping agent particles, the particle spacing, and the confining pressures.
  • the fluids used in hydraulic fracturing operations must have filter loss values sufficiently low to permit build-up and maintenance of the required pressures at reasonable injection rates. This normally requires that such fluids either have adequate viscosities or contain filter-loss control agents which will plug the pores in the formation.
  • the use of fracturing fluids having relatively low viscosities in conjunction with additives which provide the low filter-loss values needed avoids excessively high friction losses in the tubing and casing. The well head pressures and hydraulic horsepower required to overcome such friction losses may otherwise be prohibitive.
  • Fracturing of low permeability reservoirs has always presented the problem of fluid compatibility with the formation core and formation fluids, particularly in gas wells.
  • many formations contain clays which swell when contacted by aqueous fluids causing restricted permeability,
  • Another problem encountered in fracturing operations is the difficulty of total recovery of the fracturing fluid. Fluids left in the reservoir rock as immobile residual fluid impede the flow of reservoir gas or fluids, to an extent that the benefit of fracturing is decreased or eliminated. The removal of the fracturing fluid may require the expenditure of a large amount of energy and time, consequently the reduction or elimination of the problem is highly desirable.
  • gelled fluids prepared with water, diesel and similar low viscosity liquids have been useful. Such fluids have apparent viscosities high enough to support the propping agent particles without settling and yet low enough to give acceptable friction losses.
  • the gelling agents also promote laminar flow under conditions where turbulent flow would otherwise take place and hence in some cases, the losses may be lower than those obtained with low viscosity-base fluids containing no additives.
  • Certain water-soluble poly-acrylamides, oil soluble poly-isobutylene and other polymers which have little effect on viscosity when used in low concentration can be added to the ungelled fluid to achieve similar benefits.
  • Low density gases such as CO, or N; have been used in attempting to overcome the problem of removing the fracturing liquid.
  • the low density gasses are added at a calculated ratio which promotes fluid flow subsequent to the fracturing.
  • This .back flow of load fluids is usually due to reservoir pressure alone, without mechanical aid from surface, because of the reduction of hydrostatic head caused by gasifying the fluid.
  • the present invention provides a method of well stimulation with little or no reservoir contamination and a high percentage of load fluid recovery.
  • a liquified gas and a fluid containing entrained propping agents are injected into the formations. Since the two aforementioned fluid phases are completely miscible they may be either blended prior to well entry, or injected separately and blended in the well.
  • the fluids are injected until a fracture of suflicient width to produce a highly conductive .channel has been formed. Particles of the propping agent, suspended in the mixture, are carried into the fracture.
  • the injected fluid is then permitted to leak off into the formation until the fracture has closed sufficiently to hold the particles in place.
  • liquid carbon dioxide (CO and a high concentration of propping agents in a stream of gelled alcohol are simultaneously injected into the well bore.
  • the liquid carbon dioxide reaches the formations, it gasifies, leaving only a low fluid residual of alcohol to recover.
  • This alcohol in turn, is soluble in reservoir gas (methane) and is essentially returned as a vapor.
  • the propping agents are added to a separate side stream of alcohol at atmospheric pressure and subsequently blended with the liquid carbon dioxide for injection into the well.
  • a suitable alternate to alcohol is a light oil, condensate, or reformate (aromatic refinery by-product) gelled with additives such as aluminum stearate and time-dependant breakers.
  • FIG. 1 depicts a pressure enthalpy chart for CO in the re- I gion of interest of oil well servicing.
  • FIG. 2 shows the viscosity of CO
  • FIG. 3 shows the thermodynamic properties of saturated carbon dioxide.
  • FIG. 4 shows the rate of reaction of gel breaker on the gelled alcohol.
  • FIG. 5 is a schematic representation of a system used in this invention.
  • FIG. 6 shows a fracturing manifold that may be used to inject the fluids into the well bore.
  • liquid carbon dioxide is the primary fracturing fluid in a well fracturing method.
  • Simultaneous injection of gelled alcohol (methanol) is used to carry the propping agent.
  • FIG. 1 a pressure enthalpy chart for carbon dioxide in the region of interest in oil well servicing is shown. The probable path followed during a fracturing job is depicted by a dash line.
  • Liquid carbon dioxide is pumped from a delivery transport at approximately 300 psi and F. It is pumped to an elevated pressure where it is comingled with gelled alcohol and propping agents. The temperature of the combined fluids rises due to mixing with warm fluid and as the mixed stream goes down the well, it picks up additional heat from the borehole and additional pressure due to hydrostatic head. At the perforation, pressure is at its peak and it declines after formation fracturing as fluid enters the reservoir.
  • the viscosity of carbon dioxide determined by the method of Uyehara and Watson was calculated over the range of 0 to 300 F. for pressures from 100 to 30,000 psi. This information may be used in calculating the friction pressure drop which may be encountered when pumping pure liquid carbon dioxide into a well.
  • the density of carbon dioxide is calculated from the equation PV 0.243ZTM where P equals pressure in psia; V equals volume in cubic feet; Z equals compressibility factor; T equals temperature in degrees Rankin; M equals weight in pounds. This equation was solved for temperatures from 0 to 200 F. and pressures from 100 psi to 10,000 psi.
  • thermodynamic properties of saturated carbon dioxide are shown in the Table of FIG. 3.
  • the latent heat of vaporization is a function of temperature, ranging from 120.1 BTU/lb. at 0 F. (transport conditions) to 0.0 BTU/lb. at 87.8 F., when the CO is entirely gaseous.
  • the volume of gaseous carbon dioxide in the well reservoir at any temperature may also be calculated according to the formula:
  • V is the initial volume at standard conditions
  • f is the compressibility factor at final conditions
  • p is the final pressures in atmospheres.
  • the gelled alcohol used to carry the propping agent may be methanol or another alcohol with similar properties.
  • Methanol is used as a proppant carrying agent in view of its compatibility with most gas and oil reservoirs, its low freezing point, and potential chemical benefits to the stimulation.
  • the rate of reaction of gel breaker on the gelled alcohol is rapid, but allows adequate time for the displacement of the proppant into the formation at a high viscosity blend. From initial viscosity of 50 to 60 cp the gel breaks back to 2 cp as a final viscosity. By comparison, straight methanol has a viscosity of 0.6 cp. It is preferred that the alcohol be gelled to a viscosity of 20 cp or higher in order to be sufficient to carry the high concentration of propping agent through the pumping equipment and into the formation. In a low fluid residual treatment, the alcohol occupies as little as 16 percent of the total fluid volume. This alcohol is distributed over a total fracture area of many thousands of square feet, and in actual field use it is seldom recovered as a liquid.
  • Total recovery of the methanol without residual fluid saturation is realized by vaporization during subsequent production of the well.
  • the saturation of alcohol in methane varies with temperature and pressure, but is generally over 250 lbs. per million cubic feet of gas under reservoir conditions.
  • FIG. 5 one embodiment of a system of the present invention is shown in schematic form.
  • An alcohol storage tank 11 is connected to a blender 12.
  • the blender 12 may be of the type conventionally used in oil field fracturing operations and would normally include paddles, a ribbon mixer or jets for mixing and suspending propping agents in the gelled alcohol.
  • the alcohol is gelled in this blender just prior to the addition of the propping agents. It is generally preferred to operate the blender 12 at a high speed to prevent buildup and slugging of the propping agent particles.
  • a return line 13 from the blender to the alcohol storage tank 1] permits circulation to promote initial mixing of the fluid before the propping agent is added.
  • a suitable propping agent from container 14 is added to blender 12.
  • Discharge line 15 extends from blender 12 to high pressure fracturing pump or pumps 16. These pumps are normally positive displacement, Triplex pumps, truck mounted and specially equipped for pumping abrasive slurries at high rates and pressures.
  • Liquid carbon dioxide from tank or tanks 17 is injected into the well 18 by means of a pump or pumps 19.
  • Unit 19 may be a pumping unit similar to that described in connection with pumping unit 16.
  • the pumps 16 and 19, blender 12, tanks 11 and 17 and other equipment are normally located some distance from the well 18 to minimize the danger in case of fire or blowout. Valves are provided throughout the system to permit control of the fluids and the disconnection of individual units of equipment as necessary.
  • a fracturing manifold particularly suited for the present invention is indicated generally at 20.
  • Thegelled alcohol with proppant enters the manifold 20 at the inlet 21. It receives the gel breaking mixture which enters at 22 and the mixture then passes down the tubing 23.
  • the liquid carbon dioxide enters at 24 and passes down the annulus between tubing 23 and tubing 25. As the gelled alcohol including the additives exits from tubing 23 it is completely mixed with the carbon dioxide prior to entry into the formation 26.
  • alcohol with between 5 to 8 lbs. of proppant per gallon, depending on the well conditions, is pumped into a manifold at the rate of 7 barrels per minute.
  • the carbon dioxide is pumped at 14 barrels per minute into the manifold and a diluted sand/liquid ratio of approximately 2 lb./gal. is injected into the well.
  • Additional additives such as surfactants and fluid loss additives may be added to the alcohol at the blender during the treatment.
  • a controlled screen-out may be effected at the conclusion of the fracture treatment. Simultaneous with the flush, the annulus carbon dioxide rate is reduced to increase the bottom hole sand concentration. After the sand is displaced into the formation, the well is shut in for any length of time desired prior to the flowing back to evaluate treatment.
  • a method of treating a subsurface earth formation penetrated by a well bore comprising: injecting a liquified gas into the formation and injecting gelled alcohol containing entrained propping agents into said formation.
  • a method of treating subsurface earth formations penetrated b a borehole comprising: mixing ropping agents with gelled cohol, mixing said gelled alcoho containing the propping agents with a liquified gas and injecting the mixture into the formation surrounding said borehole.
  • the method of claim 10 including the step of adding a gel breaker to the gelled alcohol.
  • a system for treating subsurface earth formations comprising:

Abstract

The formations surrounding a well bore are subjected to hydraulic fracturing. A liquified gas and a fluid containing entrained propping agents are injected into the formations. The liquified gas returns to its gaseous state and is therefore easily removed from the formation.

Description

05*Z372 XR 366646422 U llllefl mates ratent [1 1 3,664,422
Bullen 1 51 May 23, 1972 4 WELL FRACTURING METliOl) 3,396,107 8/1968 11111 ..l66/308 x A G s AND 2,896,717 7/ 1959 Howard ..166/28l 3,368,627 2/1968 11 1 1 a1. ..166/3o8 x PROPPING AGENTS ENTRAINED IN A 3,108,636 10/1963 P328311 166/308 FLUID 3,170,517 2/1965 Graham et a]. 166/308 x [721 lnvenm" Bulk", Calgary Albem' 2,596,844 5/1952 Clark 166/308 ux Canada v [73] Assignee: Dresser Industries, Inc., Dallas, Tex. Primary Examiner'"stephen Novosad Attorney-Robert W. Mayer, Thomas P. Hubbard, Jr., Danlel [22] Filed: Aug. 17, 1970 Rubin, Raymond T. Majesko, Roy L. Van Winkle, William E.
[ 1 pp 64,271 Johnson, Jr. and Eddie E. Scott ABS (ACT [52] US. Cl. 166/283, [66/308, 166/75 The formations Surrounding a we bore are subjected to [51 1 Int. 6 hydraulic fracturing A gas and a containing en- Field of Search 281, trained propping agents are injected into the formations, The 166/283 liquified gas returns to its gaseous state and is therefore easily removed from the formation.
[56] References Cited 14 Claims, 6 Drawing figures UNITED STATES PATENTS 3,136,361 6/1964 Marx ..l66/308 ALCOHOL l3 PROPPING BLENDER 2 AGENT l6 PUMP PUMP WELL PATENTEUMM 23 m2 8,664, 12 2 SHEET 3 [IF 3 METHANOL GEL BREAK 5o 1 I I GEL VISCOSITY 480p C zo 2 METHANOL VISCOSITY 0.6cp L l l -l JLL .L 4 .E-. L E- E 0 IO so so e0 :oo no I20 I30 I40 :50 TIME IN MINUTES & J
FIG. 4
ALCOHOL l3 l4 2 8 ZQ w BLENDER 00 PUMP f PUMP L IS f 25 PIC 15 T wELL 6 INVENTOR 26 RONALD S. BULLEN ATTORNEY WELL FRACTURING METHOD EMPLOYING A LIQUIFIED GAS AND PROPPING AGENTS ENTRAINED IN A FLUID BACKGROUND OF THE INVENTION This invention relates to the art of hydraulically fracturing subterranean earth formations surrounding oil wells, gas wells, and similar bore holes. In particular, this invention relates to hydraulic fracturing utilizing a liquified gas and a fluid containing entrained propping agents.
Hydraulic fracturing has been widely used for stimulating the production of crude oil and natural gas from wells completed in reservoirs of low permeability. Methods employed normally require the injection of a fracturing fluid containing suspended propping agents into a well at a rate sufficient to open a fracture in the exposed formation. Continued pumping of fluid into the well at a high rate extends the fracture and leads to the build-up of a bed of propping agent particles between the fracture walls. These particles prevent complete closure of the fracture as the fluid subsequently leaks off into the adjacent formations and results in a permeable channel extending from the well bore into the formations. The conductivity of this channel depends upon the fracture dimensions, the size of the propping agent particles, the particle spacing, and the confining pressures.
The fluids used in hydraulic fracturing operations must have filter loss values sufficiently low to permit build-up and maintenance of the required pressures at reasonable injection rates. This normally requires that such fluids either have adequate viscosities or contain filter-loss control agents which will plug the pores in the formation. The use of fracturing fluids having relatively low viscosities in conjunction with additives which provide the low filter-loss values needed avoids excessively high friction losses in the tubing and casing. The well head pressures and hydraulic horsepower required to overcome such friction losses may otherwise be prohibitive.
Fracturing of low permeability reservoirs has always presented the problem of fluid compatibility with the formation core and formation fluids, particularly in gas wells. For example, many formations contain clays which swell when contacted by aqueous fluids causing restricted permeability,
and it is not uncommon to see reduced flow through gas well cores tested with various oils. 1
Another problem encountered in fracturing operations is the difficulty of total recovery of the fracturing fluid. Fluids left in the reservoir rock as immobile residual fluid impede the flow of reservoir gas or fluids, to an extent that the benefit of fracturing is decreased or eliminated. The removal of the fracturing fluid may require the expenditure of a large amount of energy and time, consequently the reduction or elimination of the problem is highly desirable.
DESCRIPTION OF THE PRIOR ART In attempting to overcome the filter-loss problem, gelled fluids prepared with water, diesel and similar low viscosity liquids have been useful. Such fluids have apparent viscosities high enough to support the propping agent particles without settling and yet low enough to give acceptable friction losses. The gelling agents also promote laminar flow under conditions where turbulent flow would otherwise take place and hence in some cases, the losses may be lower than those obtained with low viscosity-base fluids containing no additives. Certain water-soluble poly-acrylamides, oil soluble poly-isobutylene and other polymers which have little effect on viscosity when used in low concentration can be added to the ungelled fluid to achieve similar benefits.
In attempting to overcome the problem of fluid compatibility when aqueous fracturing fluids are used, chemical additives have been used such as salt or chemicals for pH control. Salts such as NaCl, KCl, or CaCl, have been widely used for fracturing water sensitive formations. Where hydrocarbons are used, light products such as gelled condensate have seen a wide degree of success, but are restricted in use due to the inherent hazards of pumping volative fluids.
Low density gases such as CO, or N; have been used in attempting to overcome the problem of removing the fracturing liquid. The low density gasses are added at a calculated ratio which promotes fluid flow subsequent to the fracturing. This .back flow of load fluids is usually due to reservoir pressure alone, without mechanical aid from surface, because of the reduction of hydrostatic head caused by gasifying the fluid.
SUMMARY OF THE INVENTION The present invention provides a method of well stimulation with little or no reservoir contamination and a high percentage of load fluid recovery. A liquified gas and a fluid containing entrained propping agents are injected into the formations. Since the two aforementioned fluid phases are completely miscible they may be either blended prior to well entry, or injected separately and blended in the well. The fluids are injected until a fracture of suflicient width to produce a highly conductive .channel has been formed. Particles of the propping agent, suspended in the mixture, are carried into the fracture. The injected fluid is then permitted to leak off into the formation until the fracture has closed sufficiently to hold the particles in place.
Inone embodiment of the invention, liquid carbon dioxide (CO and a high concentration of propping agents in a stream of gelled alcohol are simultaneously injected into the well bore. When the liquid carbon dioxide reaches the formations, it gasifies, leaving only a low fluid residual of alcohol to recover. This alcohol, in turn, is soluble in reservoir gas (methane) and is essentially returned as a vapor. The propping agents are added to a separate side stream of alcohol at atmospheric pressure and subsequently blended with the liquid carbon dioxide for injection into the well. A suitable alternate to alcohol is a light oil, condensate, or reformate (aromatic refinery by-product) gelled with additives such as aluminum stearate and time-dependant breakers.
It is therefore an object of the present invention to provide a method of fracturing the formations surrounding a well bore wherein propping agents contained in a suitable fluid are added to a liquified gas and injected into the formations.
It is a still further object of the present invention to provide a fracturing method wherein propping agents are added to a suitable fluid at atmospheric pressure and the fluid containing the propping agents is subsequently mixed with a liquified gas and injected into the formations surrounding a well bore.
It is a still further object of the present invention to provide a well fracturing method that prevents any fluid of questionable compatibility from contacting either the formation or reservoir fluids.
It is a still further object of the present invention to provide a well fracturing method that allows extension of the shut-in period of the well to an indefinite period of time for fracture healing, also allowing flow-back and evaluation at the operators convenience.
It is astill further object of the present invention to provide a well fracturing method that includes a combination of alcohol, surface active agents and liquified carbon dioxide to be injected into the formation surrounding a well bore.
The above and other objects and advantages will become apparent from a consideration of the following detailed description when taken in conjunction with the accompanying drawings.
BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 depicts a pressure enthalpy chart for CO in the re- I gion of interest of oil well servicing.
FIG. 2 shows the viscosity of CO FIG. 3 shows the thermodynamic properties of saturated carbon dioxide.
FIG. 4 shows the rate of reaction of gel breaker on the gelled alcohol.
FIG. 5 is a schematic representation of a system used in this invention.
FIG. 6 shows a fracturing manifold that may be used to inject the fluids into the well bore.
In the preferred embodiment of the present invention liquid carbon dioxide (CO is the primary fracturing fluid in a well fracturing method. Simultaneous injection of gelled alcohol (methanol) is used to carry the propping agent.
Referring now to FIG. 1, a pressure enthalpy chart for carbon dioxide in the region of interest in oil well servicing is shown. The probable path followed during a fracturing job is depicted by a dash line. Liquid carbon dioxide is pumped from a delivery transport at approximately 300 psi and F. It is pumped to an elevated pressure where it is comingled with gelled alcohol and propping agents. The temperature of the combined fluids rises due to mixing with warm fluid and as the mixed stream goes down the well, it picks up additional heat from the borehole and additional pressure due to hydrostatic head. At the perforation, pressure is at its peak and it declines after formation fracturing as fluid enters the reservoir. As the critical temperature of the carbon dioxide (87.8 F.) is exceeded, it changes to the vapor stage. When pressure is relieved at the well head after completion of the treatment, the gaseous carbon dioxide expands along a path similar to that shown, until it emerges as a gas at the well head at atmospheric pressure.
Referring now to FIG. 2, the viscosity of carbon dioxide determined by the method of Uyehara and Watson" was calculated over the range of 0 to 300 F. for pressures from 100 to 30,000 psi. This information may be used in calculating the friction pressure drop which may be encountered when pumping pure liquid carbon dioxide into a well. The density of carbon dioxide is calculated from the equation PV 0.243ZTM where P equals pressure in psia; V equals volume in cubic feet; Z equals compressibility factor; T equals temperature in degrees Rankin; M equals weight in pounds. This equation was solved for temperatures from 0 to 200 F. and pressures from 100 psi to 10,000 psi.
Knowing viscosity and density, friction pressures of liquid carbon dioxide may then be calculated using Crittendon's correlation for pressure drop in oilfield production pipe:
where P/L pressure drop per l ,000 feet p density, gm/cc u viscosity, cp
Q injection rate, BPM
D pipe diameter, inches An example of friction drop for carbon dioxide at high pressures was calculated at BPM for 3.548 in. I.D. tubing at 6,000 psi indicating that the pressure drop for carbon dioxide under these conditions is only 43 percent less than that of water with 1 cp viscosity. The addition of the gelled alcohol and sand slurry to the carbon dioxide injected into a well does not appear to change the pipe friction appreciably from that calculated, although variations in perforation friction are proportionate to the increased density of the slurry according to the equation:
P perforation friction, psi
Q injection rate, BPM
p density, gm/cc n diameter of perforation, inches D diameter of perforations in inches Orifice coefficient assumed 0.8
The thermodynamic properties of saturated carbon dioxide are shown in the Table of FIG. 3. As may be seen from this Table, the latent heat of vaporization is a function of temperature, ranging from 120.1 BTU/lb. at 0 F. (transport conditions) to 0.0 BTU/lb. at 87.8 F., when the CO is entirely gaseous.
In a fracture treatment using carbon dioxide as a base fluid, the total heat absorption from the tubing, casing and formation for a stimulation incorporating 10,000 gallons of liquid carbon dioxide would therefore be 1.0 X 10 BTU. This is usually well within the tolerable range for cooling effect corresponding to an average temperature drop throughout the system of only 20 F. to 30 F. which is quickly replaced by downhole heat transfer to equilibrium.
Under reservoir temperature and pressure conditions, the specific volume of carbon dioxide increases from that at the surface. This volume expansion increases the velocity of the fracturing fluid in the formation for improved fracture width and penetration. The volume occupied by 1,000 SCF of carbon dioxide prior to injection is 1.78 ft. (0 F 300 psi). This volume expands under reservoir conditions, with the greatest effect at lower pressures.
The volume of gaseous carbon dioxide in the well reservoir at any temperature may also be calculated according to the formula:
m X tn/p where V is the final volume,
V is the initial volume at standard conditions,
f is the compressibility factor at final conditions,
p is the final pressures in atmospheres.
The gelled alcohol used to carry the propping agent may be methanol or another alcohol with similar properties. Methanol is used as a proppant carrying agent in view of its compatibility with most gas and oil reservoirs, its low freezing point, and potential chemical benefits to the stimulation.
As shown in FIG. 4 the rate of reaction of gel breaker on the gelled alcohol is rapid, but allows adequate time for the displacement of the proppant into the formation at a high viscosity blend. From initial viscosity of 50 to 60 cp the gel breaks back to 2 cp as a final viscosity. By comparison, straight methanol has a viscosity of 0.6 cp. It is preferred that the alcohol be gelled to a viscosity of 20 cp or higher in order to be sufficient to carry the high concentration of propping agent through the pumping equipment and into the formation. In a low fluid residual treatment, the alcohol occupies as little as 16 percent of the total fluid volume. This alcohol is distributed over a total fracture area of many thousands of square feet, and in actual field use it is seldom recovered as a liquid.
Total recovery of the methanol without residual fluid saturation is realized by vaporization during subsequent production of the well. The saturation of alcohol in methane varies with temperature and pressure, but is generally over 250 lbs. per million cubic feet of gas under reservoir conditions.
Referring now to FIG. 5 one embodiment of a system of the present invention is shown in schematic form. An alcohol storage tank 11 is connected to a blender 12. The blender 12 may be of the type conventionally used in oil field fracturing operations and would normally include paddles, a ribbon mixer or jets for mixing and suspending propping agents in the gelled alcohol. The alcohol is gelled in this blender just prior to the addition of the propping agents. It is generally preferred to operate the blender 12 at a high speed to prevent buildup and slugging of the propping agent particles. A return line 13 from the blender to the alcohol storage tank 1] permits circulation to promote initial mixing of the fluid before the propping agent is added. A suitable propping agent from container 14 is added to blender 12. Discharge line 15 extends from blender 12 to high pressure fracturing pump or pumps 16. These pumps are normally positive displacement, Triplex pumps, truck mounted and specially equipped for pumping abrasive slurries at high rates and pressures.
Liquid carbon dioxide from tank or tanks 17 is injected into the well 18 by means of a pump or pumps 19. Unit 19 may be a pumping unit similar to that described in connection with pumping unit 16.
The pumps 16 and 19, blender 12, tanks 11 and 17 and other equipment are normally located some distance from the well 18 to minimize the danger in case of fire or blowout. Valves are provided throughout the system to permit control of the fluids and the disconnection of individual units of equipment as necessary.
Referring now to FIG. 6 another embodiment of the present invention is shown. A fracturing manifold particularly suited for the present invention is indicated generally at 20. Thegelled alcohol with proppant enters the manifold 20 at the inlet 21. It receives the gel breaking mixture which enters at 22 and the mixture then passes down the tubing 23. The liquid carbon dioxide enters at 24 and passes down the annulus between tubing 23 and tubing 25. As the gelled alcohol including the additives exits from tubing 23 it is completely mixed with the carbon dioxide prior to entry into the formation 26.
in a typical treatment, alcohol with between 5 to 8 lbs. of proppant per gallon, depending on the well conditions, is pumped into a manifold at the rate of 7 barrels per minute. The carbon dioxide is pumped at 14 barrels per minute into the manifold and a diluted sand/liquid ratio of approximately 2 lb./gal. is injected into the well. Additional additives such as surfactants and fluid loss additives may be added to the alcohol at the blender during the treatment.
When injecting the alcohol and carbon dioxide separately into the tubing and casing, a controlled screen-out may be effected at the conclusion of the fracture treatment. Simultaneous with the flush, the annulus carbon dioxide rate is reduced to increase the bottom hole sand concentration. After the sand is displaced into the formation, the well is shut in for any length of time desired prior to the flowing back to evaluate treatment.
It is generally recognized that the stimulation benefits resulting from the present invention are two-fold:
1. highly permeable channels are developed which have the effect of allowing increased flow into the well bore; and
2. the well bore area itself is cleaned out of water blocks,
mud contamination and emulsions by the scouring and flushing action of the fluids.
In the second (2) area of stimulation, the action of alcohol, carbon dioxide and surfactants would have significant benefit. It has been shown that the injection of alcohol, surfactants and carbon dioxide restores the permeability of the productive formation to gas by removing water from the capillary pores of the formation. The surfactant decreases the surface tension of the water causing a decrease in capillary pressure which allows the water to be more easily displaced by injected gas. The alcohol acts as a drying agent; thus, the combination of surfactant and dessicant forced into the formation by a gas at high pressure is very effective for removing a water block in the immediate vicinity of the well bore.
The embodiments of the invention in which an exclusive property or privilege is claimed are defined as follows:
1. A method of treating a subsurface earth formation penetrated by a well bore, comprising: injecting a liquified gas into the formation and injecting gelled alcohol containing entrained propping agents into said formation.
2. The method of claim 1 including the step of injecting a gel breaker into said formation.
3. The method of claim 1 wherein said gelled alcohol is gelled methanol.
4. The method of claim 1 wherein said liquified gas is carbon dioxide.
5. The method of claim 1 wherein said steps of injecting a liquified gas and said step of injecting gelled alcohol containing entrained propping agents are performed simultaneously.
6. The method of claim 1 wherein said liquified gas and gelled alcohol containing the entrained propping agents are blended prior to injection into the formations.
7. The method of claim 1 wherein said liquified gas and gelled alcohol containing the entrained propping agents are mixed after each has been injected into the well bore.
8. The method of claim 1 wherein said gelled alcohol containing the entrained propping agents is at atmospheric pres sure prior to injection into the well bore.
9. The method of claim 1 wherein the entrained propping agents are sand.
10. A method of treating subsurface earth formations penetrated b a borehole, comprising: mixing ropping agents with gelled cohol, mixing said gelled alcoho containing the propping agents with a liquified gas and injecting the mixture into the formation surrounding said borehole.
11. The method of claim 10 including the step of adding a gel breaker to the gelled alcohol.
12. The method of claim 10 wherein said liquified gas is liquified N 13. The method of claim 10 wherein said liquified gas is liquified CO 14. A system for treating subsurface earth formations comprising:
means for mixing propping agents with gelled alcohol;
means for blending the propping agents and gelled alcohol mixture with a liquified gas; and means for injecting the blend into said subsurface earth formations.

Claims (13)

  1. 2. The method of claim 1 including the step of injecting a gel breaker into said formation.
  2. 3. The method of claim 1 wherein said gelled alcohol is gelled methanol.
  3. 4. The method of claim 1 wherein said liquified gas is carbon dioxide.
  4. 5. The method of claim 1 wherein said steps of injecting a liquified gas and said step of injecting gelled alcohol containing entrained propping agents are performed simultaneously.
  5. 6. The method of claim 1 wherein said liquified gas and gelled alcohol containing the entrained propping agents are blended prior to injection into the formations.
  6. 7. The method of claim 1 wherein said liquified gas and gelled alcohol containing the entrained propping agents are mixed after each has been injected into the well bore.
  7. 8. The method of claim 1 wherein said gelled alcohol containing the entrained propping agents is at atmospheric pressure prior to injection into the well bore.
  8. 9. The method of claim 1 wherein the entrained propping agents are sand.
  9. 10. A method of treating subsurface earth formations penetrated by a borehole, comprising: mixing propping agents with gelled alcohol, mixing said gelled alcohol containing the propping agents with a liquified gas and injecting the mixture into the formation surrounding said borehole.
  10. 11. The method of claim 10 including the step of adding a gel breaker to the gelled alcohol.
  11. 12. The method of claim 10 wherein said liquified gas is liquified N2.
  12. 13. The method of claim 10 wherein said liquified gas is liquified CO2.
  13. 14. A system for treating subsurface earth formations comprising: means for mixing propping agents with gelled alcohol; means for blending the propping agents and gelled alcohol mixture with a liquified gas; and means for injecting the blend into said subsurface earth formations.
US3664422D 1970-08-17 1970-08-17 Well fracturing method employing a liquified gas and propping agents entrained in a fluid Expired - Lifetime US3664422A (en)

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US6427170A 1970-08-17 1970-08-17

Publications (1)

Publication Number Publication Date
US3664422A true US3664422A (en) 1972-05-23

Family

ID=22054756

Family Applications (1)

Application Number Title Priority Date Filing Date
US3664422D Expired - Lifetime US3664422A (en) 1970-08-17 1970-08-17 Well fracturing method employing a liquified gas and propping agents entrained in a fluid

Country Status (2)

Country Link
US (1) US3664422A (en)
CA (1) CA932655A (en)

Cited By (52)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3759329A (en) * 1969-05-09 1973-09-18 Shuffman O Cryo-thermal process for fracturing rock formations
US3765488A (en) * 1972-04-06 1973-10-16 Dow Chemical Co Well treating method
US3766986A (en) * 1972-08-18 1973-10-23 Exxon Production Research Co Method of treating a well using a volatile hydrocarbon liquid
US3858658A (en) * 1973-11-19 1975-01-07 Mobil Oil Corp Hydraulic fracturing method for low permeability formations
US3954626A (en) * 1973-09-24 1976-05-04 The Dow Chemical Company Well treating composition and method
US3954636A (en) * 1973-08-30 1976-05-04 The Dow Chemical Company Acidizing fluid for stimulation of subterranean formations
US3980136A (en) * 1974-04-05 1976-09-14 Big Three Industries, Inc. Fracturing well formations using foam
US4010803A (en) * 1974-11-14 1977-03-08 Rose Shuffman, executrix Method for cryothermal fracturing of rock formations
US4126181A (en) * 1977-06-20 1978-11-21 Palmer Engineering Company Ltd. Method and apparatus for formation fracturing with foam having greater proppant concentration
US4186802A (en) * 1978-03-13 1980-02-05 William Perlman Fracing process
US4212354A (en) * 1979-03-19 1980-07-15 Service Fracturing Company and Airry, Inc. Method for injecting carbon dioxide into a well
US4226475A (en) * 1978-04-19 1980-10-07 Frosch Robert A Underground mineral extraction
US4374545A (en) * 1981-09-28 1983-02-22 L.H.B. Investment, Inc. Carbon dioxide fracturing process and apparatus
US4480696A (en) * 1982-10-25 1984-11-06 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4487025A (en) * 1983-04-18 1984-12-11 Halliburton Company Passive booster for pumping liquified gases
US4488975A (en) * 1982-12-13 1984-12-18 Halliburton Company High temperature stable crosslinked gel fracturing fluid
US4519455A (en) * 1984-01-20 1985-05-28 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4554082A (en) * 1984-01-20 1985-11-19 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4607699A (en) * 1985-06-03 1986-08-26 Exxon Production Research Co. Method for treating a tar sand reservoir to enhance petroleum production by cyclic steam stimulation
US4627495A (en) * 1985-04-04 1986-12-09 Halliburton Company Method for stimulation of wells with carbon dioxide or nitrogen based fluids containing high proppant concentrations
USRE32302E (en) * 1982-10-25 1986-12-09 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4701270A (en) * 1985-02-28 1987-10-20 Canadian Fracmaster Limited Novel compositions suitable for treating deep wells
US4825952A (en) * 1987-11-13 1989-05-02 Dwight N. Loree Fracturing process for low permeability reservoirs employing a compatible hydrocarbon-liquid carbon dioxide mixture
US4850750A (en) * 1985-07-19 1989-07-25 Halliburton Company Integrated blending control system
US4887671A (en) * 1988-12-23 1989-12-19 Texaco, Inc. Fracturing with a mixture of carbon dioxide and alcohol
US5515923A (en) * 1994-08-26 1996-05-14 Loree; Dwight N. Oil and gas well productivity
US5566760A (en) * 1994-09-02 1996-10-22 Halliburton Company Method of using a foamed fracturing fluid
US5575335A (en) * 1995-06-23 1996-11-19 Halliburton Company Method for stimulation of subterranean formations
EP0764235A1 (en) * 1994-06-06 1997-03-26 Mobil Oil Corporation Method for fracturing and propping a subterranean formation
US5674816A (en) * 1995-01-25 1997-10-07 Loree; Dwight N. Olefin based frac fluid
US6509300B1 (en) * 1998-12-24 2003-01-21 B.J Services Company Liquid CO2/hydrocarbon oil emulsion fracturing system
US20050211439A1 (en) * 2004-03-24 2005-09-29 Willett Ronald M Methods of isolating hydrajet stimulated zones
US20060260815A1 (en) * 2005-04-06 2006-11-23 Dahanayake Manilal S Method of recycling fracturing fluids using a self-degrading foaming composition
US20070204991A1 (en) * 2006-03-03 2007-09-06 Loree Dwight N Liquified petroleum gas fracturing system
US20070261844A1 (en) * 2006-05-10 2007-11-15 Raytheon Company Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and critical fluids
WO2008037981A1 (en) * 2006-09-29 2008-04-03 Halliburton Energy Services, Inc. Methods of fracturing a subterranean formation using a jetting tool and a viscoelastic surfactant fluid to minimize formation damage
US20090200011A1 (en) * 2006-02-13 2009-08-13 Decker Randal L Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
US20110209882A1 (en) * 2009-12-28 2011-09-01 Enis Ben M Method and apparatus for sequestering CO2 gas and releasing natural gas from coal and gas shale formations
EP2527586A1 (en) 2011-05-27 2012-11-28 Shell Internationale Research Maatschappij B.V. Method for induced fracturing in a subsurface formation
US8833474B2 (en) 2009-12-28 2014-09-16 Ben M. Enis Method and apparatus for using pressure cycling and cold liquid CO2 for releasing natural gas from coal and shale formations
US20140262292A1 (en) * 2013-03-15 2014-09-18 Schlumberger Technology Corporation Stimulation with Natural Gas
US20140378354A1 (en) * 2013-06-21 2014-12-25 Richard M. Kelly Fracturing fluid composition and method of using same in geological formations
WO2013173725A3 (en) * 2012-05-17 2015-03-19 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Fracturing rock formations using liquefied industrial gas
US8991499B2 (en) 2011-01-17 2015-03-31 Millennium Stimulation Services Ltd. Fracturing system and method for an underground formation
US9187996B1 (en) 2012-08-23 2015-11-17 Millennium Stimulation Services, Ltd. Reduced emissions method for recovering product from a hydraulic fracturing operation
WO2015181028A1 (en) * 2014-05-27 2015-12-03 Statoil Gulf Services LLC Applications of ultra-low viscosity fluids to stimulate ultra-tight hydrocarbon-bearing formations
US9243182B2 (en) 2012-08-21 2016-01-26 American Air Liquide Inc. Hydraulic fracturing with improved viscosity liquefied industrial gas based solution
US9683432B2 (en) 2012-05-14 2017-06-20 Step Energy Services Llc Hybrid LPG frac
US10125592B2 (en) * 2013-08-08 2018-11-13 Halliburton Energy Services, Inc. Methods and systems for treatment of subterranean formations
WO2019125622A1 (en) 2017-12-20 2019-06-27 Weatherford Technology Holdings, Llc Alternating liquid gas fracturing for enhanced oil recovery of well
US11008842B2 (en) * 2015-10-14 2021-05-18 Cnooc Petroleum North America Ulc Methods for hydraulic fracturing
US20210388695A1 (en) * 2017-09-01 2021-12-16 Spm Oil & Gas Inc. Fluid delivery device for a hydraulic fracturing system

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2129613C (en) 1994-08-05 1997-09-23 Samuel Luk High proppant concentration/high co2 ratio fracturing system
CA2135719C (en) 1994-11-14 1998-01-20 Robin Tudor Nitrogen/carbon dioxide combination fracture treatment

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2596844A (en) * 1949-12-31 1952-05-13 Stanolind Oil & Gas Co Treatment of wells
US2896717A (en) * 1956-12-28 1959-07-28 Pan American Petroleum Corp Avoiding increased water production in fracturing operations
US3108636A (en) * 1961-05-01 1963-10-29 Pacific Natural Gas Exploratio Method and apparatus for fracturing underground earth formations
US3136361A (en) * 1959-05-11 1964-06-09 Phillips Petroleum Co Fracturing formations in wells
US3170517A (en) * 1962-11-13 1965-02-23 Jersey Prod Res Co Fracturing formation and stimulation of wells
US3368627A (en) * 1966-03-21 1968-02-13 Dow Chemical Co Method of well treatment employing volatile fluid composition
US3393741A (en) * 1966-05-27 1968-07-23 Gulf Research Development Co Method of fracturing subsurface formations
US3396107A (en) * 1962-08-09 1968-08-06 Producers Chemical Company Composition for fracturing process

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2596844A (en) * 1949-12-31 1952-05-13 Stanolind Oil & Gas Co Treatment of wells
US2896717A (en) * 1956-12-28 1959-07-28 Pan American Petroleum Corp Avoiding increased water production in fracturing operations
US3136361A (en) * 1959-05-11 1964-06-09 Phillips Petroleum Co Fracturing formations in wells
US3108636A (en) * 1961-05-01 1963-10-29 Pacific Natural Gas Exploratio Method and apparatus for fracturing underground earth formations
US3396107A (en) * 1962-08-09 1968-08-06 Producers Chemical Company Composition for fracturing process
US3170517A (en) * 1962-11-13 1965-02-23 Jersey Prod Res Co Fracturing formation and stimulation of wells
US3368627A (en) * 1966-03-21 1968-02-13 Dow Chemical Co Method of well treatment employing volatile fluid composition
US3393741A (en) * 1966-05-27 1968-07-23 Gulf Research Development Co Method of fracturing subsurface formations

Cited By (79)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3759329A (en) * 1969-05-09 1973-09-18 Shuffman O Cryo-thermal process for fracturing rock formations
US3765488A (en) * 1972-04-06 1973-10-16 Dow Chemical Co Well treating method
FR2179198A1 (en) * 1972-04-06 1973-11-16 Dow Chemical Co
US3766986A (en) * 1972-08-18 1973-10-23 Exxon Production Research Co Method of treating a well using a volatile hydrocarbon liquid
US3954636A (en) * 1973-08-30 1976-05-04 The Dow Chemical Company Acidizing fluid for stimulation of subterranean formations
US3954626A (en) * 1973-09-24 1976-05-04 The Dow Chemical Company Well treating composition and method
US3858658A (en) * 1973-11-19 1975-01-07 Mobil Oil Corp Hydraulic fracturing method for low permeability formations
US3980136A (en) * 1974-04-05 1976-09-14 Big Three Industries, Inc. Fracturing well formations using foam
US4010803A (en) * 1974-11-14 1977-03-08 Rose Shuffman, executrix Method for cryothermal fracturing of rock formations
US4126181A (en) * 1977-06-20 1978-11-21 Palmer Engineering Company Ltd. Method and apparatus for formation fracturing with foam having greater proppant concentration
US4186802A (en) * 1978-03-13 1980-02-05 William Perlman Fracing process
US4226475A (en) * 1978-04-19 1980-10-07 Frosch Robert A Underground mineral extraction
US4212354A (en) * 1979-03-19 1980-07-15 Service Fracturing Company and Airry, Inc. Method for injecting carbon dioxide into a well
US4374545A (en) * 1981-09-28 1983-02-22 L.H.B. Investment, Inc. Carbon dioxide fracturing process and apparatus
DE3235845A1 (en) * 1981-09-28 1983-04-14 Canadian Fracmaster Ltd., Calgary, Alberta METHOD AND DEVICE FOR SPLITTING UNDERGROUND STRATIGRAPHIC LAYERING
NL8203477A (en) * 1981-09-28 1983-04-18 Canadian Fracmaster Ltd METHOD AND APPARATUS FOR BREAKING AN UNDERGROUND STRATIGRAPHIC LAYER
US4480696A (en) * 1982-10-25 1984-11-06 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
USRE32302E (en) * 1982-10-25 1986-12-09 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4488975A (en) * 1982-12-13 1984-12-18 Halliburton Company High temperature stable crosslinked gel fracturing fluid
US4487025A (en) * 1983-04-18 1984-12-11 Halliburton Company Passive booster for pumping liquified gases
EP0150112A2 (en) * 1984-01-20 1985-07-31 Halliburton Company Fracturing method for stmulation of wells
US4554082A (en) * 1984-01-20 1985-11-19 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
EP0150112A3 (en) * 1984-01-20 1986-02-12 Halliburton Company Fracturing method for stmulation of wells
US4519455A (en) * 1984-01-20 1985-05-28 Halliburton Company Fracturing method for stimulation of wells utilizing carbon dioxide based fluids
US4701270A (en) * 1985-02-28 1987-10-20 Canadian Fracmaster Limited Novel compositions suitable for treating deep wells
US4627495A (en) * 1985-04-04 1986-12-09 Halliburton Company Method for stimulation of wells with carbon dioxide or nitrogen based fluids containing high proppant concentrations
US4607699A (en) * 1985-06-03 1986-08-26 Exxon Production Research Co. Method for treating a tar sand reservoir to enhance petroleum production by cyclic steam stimulation
US4850750A (en) * 1985-07-19 1989-07-25 Halliburton Company Integrated blending control system
US4825952A (en) * 1987-11-13 1989-05-02 Dwight N. Loree Fracturing process for low permeability reservoirs employing a compatible hydrocarbon-liquid carbon dioxide mixture
US4887671A (en) * 1988-12-23 1989-12-19 Texaco, Inc. Fracturing with a mixture of carbon dioxide and alcohol
EP0764235A1 (en) * 1994-06-06 1997-03-26 Mobil Oil Corporation Method for fracturing and propping a subterranean formation
EP0764235A4 (en) * 1994-06-06 2000-07-05 Mobil Oil Corp Method for fracturing and propping a subterranean formation
US5515923A (en) * 1994-08-26 1996-05-14 Loree; Dwight N. Oil and gas well productivity
US5566760A (en) * 1994-09-02 1996-10-22 Halliburton Company Method of using a foamed fracturing fluid
US5990052A (en) * 1994-09-02 1999-11-23 Halliburton Energy Services, Inc. Foamed fracturing fluid
US5674816A (en) * 1995-01-25 1997-10-07 Loree; Dwight N. Olefin based frac fluid
US5575335A (en) * 1995-06-23 1996-11-19 Halliburton Company Method for stimulation of subterranean formations
US6509300B1 (en) * 1998-12-24 2003-01-21 B.J Services Company Liquid CO2/hydrocarbon oil emulsion fracturing system
US20050211439A1 (en) * 2004-03-24 2005-09-29 Willett Ronald M Methods of isolating hydrajet stimulated zones
US7766083B2 (en) 2004-03-24 2010-08-03 Halliburton Energy Services, Inc. Methods of isolating hydrajet stimulated zones
US7225869B2 (en) * 2004-03-24 2007-06-05 Halliburton Energy Services, Inc. Methods of isolating hydrajet stimulated zones
US20060000610A1 (en) * 2004-03-24 2006-01-05 Halliburton Energy Services, Inc. Methods of fracturing sensitive formations
US7681635B2 (en) 2004-03-24 2010-03-23 Halliburton Energy Services, Inc. Methods of fracturing sensitive formations
US20060260815A1 (en) * 2005-04-06 2006-11-23 Dahanayake Manilal S Method of recycling fracturing fluids using a self-degrading foaming composition
US7404442B2 (en) 2005-04-06 2008-07-29 Rhodia Inc. Method of recycling fracturing fluids using a self-degrading foaming composition
US8020615B2 (en) * 2006-02-13 2011-09-20 Decker Randal L Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
US20090200011A1 (en) * 2006-02-13 2009-08-13 Decker Randal L Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
US7694731B2 (en) * 2006-02-13 2010-04-13 Team Co2, Inc. Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
US20100147506A1 (en) * 2006-02-13 2010-06-17 Team Co2, Inc. Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
US20070204991A1 (en) * 2006-03-03 2007-09-06 Loree Dwight N Liquified petroleum gas fracturing system
US8408289B2 (en) 2006-03-03 2013-04-02 Gasfrac Energy Services Inc. Liquified petroleum gas fracturing system
US20070261844A1 (en) * 2006-05-10 2007-11-15 Raytheon Company Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and critical fluids
AU2007250001B2 (en) * 2006-05-10 2010-06-24 Raytheon Company Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and critical fluids
US7562708B2 (en) * 2006-05-10 2009-07-21 Raytheon Company Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and critical fluids
CN101438027B (en) * 2006-05-10 2013-09-18 雷斯昂公司 Method and apparatus for capture and sequester of carbon dioxide and extraction of energy from large land masses during and after extraction of hydrocarbon fuels or contaminants using energy and criti
WO2008037981A1 (en) * 2006-09-29 2008-04-03 Halliburton Energy Services, Inc. Methods of fracturing a subterranean formation using a jetting tool and a viscoelastic surfactant fluid to minimize formation damage
US20110209882A1 (en) * 2009-12-28 2011-09-01 Enis Ben M Method and apparatus for sequestering CO2 gas and releasing natural gas from coal and gas shale formations
US8833474B2 (en) 2009-12-28 2014-09-16 Ben M. Enis Method and apparatus for using pressure cycling and cold liquid CO2 for releasing natural gas from coal and shale formations
US8839875B2 (en) 2009-12-28 2014-09-23 Ben M. Enis Method and apparatus for sequestering CO2 gas and releasing natural gas from coal and gas shale formations
US9453399B2 (en) 2009-12-28 2016-09-27 Ben M. Enis Method and apparatus for using pressure cycling and cold liquid CO2 for releasing natural gas from coal and shale formations
US9796910B2 (en) 2011-01-17 2017-10-24 Halliburton Energy Services, Inc. Fracturing system and method for an underground formation using natural gas and an inert purging fluid
US8991499B2 (en) 2011-01-17 2015-03-31 Millennium Stimulation Services Ltd. Fracturing system and method for an underground formation
US9033035B2 (en) 2011-01-17 2015-05-19 Millennium Stimulation Services, Ltd. Method for fracturing a formation using a fracturing fluid mixture
US9181789B2 (en) 2011-01-17 2015-11-10 Millennium Stimulation Servicesltd. Fracturing system and method for an underground formation using natural gas and an inert purging fluid
EP2527586A1 (en) 2011-05-27 2012-11-28 Shell Internationale Research Maatschappij B.V. Method for induced fracturing in a subsurface formation
US9683432B2 (en) 2012-05-14 2017-06-20 Step Energy Services Llc Hybrid LPG frac
WO2013173725A3 (en) * 2012-05-17 2015-03-19 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Fracturing rock formations using liquefied industrial gas
US9243182B2 (en) 2012-08-21 2016-01-26 American Air Liquide Inc. Hydraulic fracturing with improved viscosity liquefied industrial gas based solution
US9187996B1 (en) 2012-08-23 2015-11-17 Millennium Stimulation Services, Ltd. Reduced emissions method for recovering product from a hydraulic fracturing operation
US9790775B2 (en) * 2013-03-15 2017-10-17 Schlumberger Technology Corporation Stimulation with natural gas
US20140262292A1 (en) * 2013-03-15 2014-09-18 Schlumberger Technology Corporation Stimulation with Natural Gas
US20140378354A1 (en) * 2013-06-21 2014-12-25 Richard M. Kelly Fracturing fluid composition and method of using same in geological formations
US10233384B2 (en) * 2013-06-21 2019-03-19 Praxair Technology, Inc. Fracturing fluid composition and method of using same in geological formations
US10125592B2 (en) * 2013-08-08 2018-11-13 Halliburton Energy Services, Inc. Methods and systems for treatment of subterranean formations
US20150345268A1 (en) * 2014-05-27 2015-12-03 Statoil Gulf Services LLC Applications of ultra-low viscosity fluids to stimulate ultra-tight hydrocarbon-bearing formations
WO2015181028A1 (en) * 2014-05-27 2015-12-03 Statoil Gulf Services LLC Applications of ultra-low viscosity fluids to stimulate ultra-tight hydrocarbon-bearing formations
US11008842B2 (en) * 2015-10-14 2021-05-18 Cnooc Petroleum North America Ulc Methods for hydraulic fracturing
US20210388695A1 (en) * 2017-09-01 2021-12-16 Spm Oil & Gas Inc. Fluid delivery device for a hydraulic fracturing system
WO2019125622A1 (en) 2017-12-20 2019-06-27 Weatherford Technology Holdings, Llc Alternating liquid gas fracturing for enhanced oil recovery of well

Also Published As

Publication number Publication date
CA932655A (en) 1973-08-28

Similar Documents

Publication Publication Date Title
US3664422A (en) Well fracturing method employing a liquified gas and propping agents entrained in a fluid
US10883042B2 (en) Enhancing acid fracture conductivity
CA1056590A (en) Formation fracturing with stable foam
CA2129613C (en) High proppant concentration/high co2 ratio fracturing system
US3100528A (en) Methods for using inert gas
US4374545A (en) Carbon dioxide fracturing process and apparatus
US3136361A (en) Fracturing formations in wells
US3195634A (en) Fracturing process
US5883053A (en) Nitrogen/carbon dioxide combination fracture treatment
CA2405391C (en) Method for acid stimulating a subterranean well formation for improving hydrocarbon production
US4410041A (en) Process for gas-lifting liquid from a well by injecting liquid into the well
Crawford et al. Carbon dioxide-a multipurpose additive for effective well stimulation
US6838418B2 (en) Fracturing fluid
US20150218439A1 (en) Cryogenic acid frack
US4424866A (en) Method for production of hydrocarbons from hydrates
US20160289550A1 (en) In-situ generation of acid for use in subterranean formation operations
CA1305659C (en) Remedial treatment for coal degas wells
US3193014A (en) Apparatus for fracturing subsurface formations
Gruber et al. Carbonated hydrocarbons for improved gas well fracturing results
Shouldice Liquid nitrogen developments and applications in drilling and completion operations
US20070131423A1 (en) Method of extracting hydrocarbons
US11333012B2 (en) Hybrid fracturing treatment with natural gas
Scott et al. Air foam improves efficiency of completion and workover operations in low-pressure gas wells
CA2357973C (en) Fracturing fluid
Bharadwaj et al. Technological Advances in Water-less Fracking: A Case Study

Legal Events

Date Code Title Description
AS Assignment

Owner name: WESTERN ATLAS INTERNATIONAL, INC.,

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:DRESSER INDUSTRIES, INC., A CORP. OF DE;REEL/FRAME:004725/0094

Effective date: 19870430

AS Assignment

Owner name: B. J. TITAN SERVICES COMPANY, HOUSTON, TEXAS, A PA

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST.;ASSIGNOR:WESTERN ATLAS INTERNATIONAL, INC., A CORP. OF DE;REEL/FRAME:004822/0834

Effective date: 19880119