US3410344A - Fluid injection method - Google Patents
Fluid injection method Download PDFInfo
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- US3410344A US3410344A US567470A US56747066A US3410344A US 3410344 A US3410344 A US 3410344A US 567470 A US567470 A US 567470A US 56747066 A US56747066 A US 56747066A US 3410344 A US3410344 A US 3410344A
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- foam
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- column
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- 239000012530 fluid Substances 0.000 title description 20
- 238000000034 method Methods 0.000 title description 17
- 238000002347 injection Methods 0.000 title description 16
- 239000007924 injection Substances 0.000 title description 16
- 239000006260 foam Substances 0.000 description 65
- 230000015572 biosynthetic process Effects 0.000 description 45
- 238000005755 formation reaction Methods 0.000 description 45
- 239000007789 gas Substances 0.000 description 16
- 239000004088 foaming agent Substances 0.000 description 7
- 238000010793 Steam injection (oil industry) Methods 0.000 description 6
- 238000004519 manufacturing process Methods 0.000 description 4
- 239000004094 surface-active agent Substances 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- XQCFHQBGMWUEMY-ZPUQHVIOSA-N Nitrovin Chemical compound C=1C=C([N+]([O-])=O)OC=1\C=C\C(=NNC(=N)N)\C=C\C1=CC=C([N+]([O-])=O)O1 XQCFHQBGMWUEMY-ZPUQHVIOSA-N 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- NKJOXAZJBOMXID-UHFFFAOYSA-N 1,1'-Oxybisoctane Chemical compound CCCCCCCCOCCCCCCCC NKJOXAZJBOMXID-UHFFFAOYSA-N 0.000 description 1
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical class CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- REYJJPSVUYRZGE-UHFFFAOYSA-N Octadecylamine Chemical compound CCCCCCCCCCCCCCCCCCN REYJJPSVUYRZGE-UHFFFAOYSA-N 0.000 description 1
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 239000013504 Triton X-100 Substances 0.000 description 1
- 229920004890 Triton X-100 Polymers 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000003339 best practice Methods 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- MCWXGJITAZMZEV-UHFFFAOYSA-N dimethoate Chemical compound CNC(=O)CSP(=S)(OC)OC MCWXGJITAZMZEV-UHFFFAOYSA-N 0.000 description 1
- 230000008030 elimination Effects 0.000 description 1
- 238000003379 elimination reaction Methods 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 125000001183 hydrocarbyl group Chemical group 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 239000006193 liquid solution Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 230000005855 radiation Effects 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000000344 soap Substances 0.000 description 1
- GCLGEJMYGQKIIW-UHFFFAOYSA-H sodium hexametaphosphate Chemical compound [Na]OP1(=O)OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])O1 GCLGEJMYGQKIIW-UHFFFAOYSA-H 0.000 description 1
- 235000019982 sodium hexametaphosphate Nutrition 0.000 description 1
- 230000002277 temperature effect Effects 0.000 description 1
- 239000001577 tetrasodium phosphonato phosphate Substances 0.000 description 1
- 230000008646 thermal stress Effects 0.000 description 1
- GPRLSGONYQIRFK-MNYXATJNSA-N triton Chemical compound [3H+] GPRLSGONYQIRFK-MNYXATJNSA-N 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B21/14—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using liquids and gases, e.g. foams
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B36/00—Heating, cooling, insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
Definitions
- the invention contemplates the use of a column of foam pressure balanced against a flowing column of medium, eg., a hot liuid such as steam or gas, being injected into a formation, such as an oil-bearing stratum, to control the level at which the injected medium is forced into the formation, so that the level at which medium injection occurs can be changed by altering the pressure on the foam column relative to that of the medium being injected.
- a-lso reduces we-ll bore heat loss as the foam insulates the tubing through which steam can be'injected.
- One of the concepts of the invention involves supplying down a hole or passageway in a formation a column of foam and injecting the medium to 'be injected down another passageway to a point above or below the foam and maintaining the pressure at the foot of the foam column such that the injected medium must enter the formation ⁇ at substantially the level of the foam medium interface.
- the invention provides for varying the level at which the injected medium is forced into the formation by varying the pressure exerted yby the foam column at its bottom against the entering injected medium ina manner to move the meeting place or level of the foam column bottom and the injected medium .to another desired level.
- the injected medium is forced into the formation by way of a tubing within a casing while the annulus between the tubing and the casing is filled with a column of foam, as later more fully described,
- the invention is particularly adapted for use in oil production. Accordingly, it will be described in connection with such application. However, one skilled in the art of injecting various media into formations will understand that the invention can be applied to production of other materials from the earth or to treatment of such materials therein.
- the casing-tubing annulus can be pressured with a condensible or non-condensible foam and that, if this is done, the use of a packer can be eliminated.
- ⁇ steam can be injected down the tubing at a pressure slightly higher than the pressure at the foot of the foam column in the annulus, insuring movement of the steam into the bottom portion of the pay or formation.
- the annulus pressure can be reduced so that the steam will displace the foam column upward and can thus enter into a higher stratum.
- a method of injecting a fluid into a formation below the earths surface which comprises providing a column of foam in a passageway leading to a portion of said formation into which said fluid is to be injected, by way of another passageway injecting said fluid to said portion of said formation below said column of foam, maintaining on said column of foam a pressure suicient to retain it substantially in place against the pressure of said fliud being injected and injecting said fluid at a pressure sufficient to force the same into said formation below said column of foam.
- the foam column is provided in one of said piping and annulus and the medium is injected into the formation through the other of said piping and said annulus.
- 1 is a casing perforated at points 2 and containing therein tubing y3: to which steam can be admitted at 4.
- a condensible or a non-condensible gas is passed into casing 1 by way of pipe 6, foam generator 7, which, in this instance, is a porous plug, through check valve 8.
- foam generator 7 which, in this instance, is a porous plug
- check valve 8 There is admixed with the gas thus passed into casing 1 a foaming agent added to conduit 6 by Way of pipe 9.
- the gas and foaming agent, on pa-ssing through porous plug 7, generate a foam which passes through check valve 8 into casing 1 and down to a certain level, for example, to near the top of the producing formation, as shown in the drawing, or to the bottom of the well below the end of the tubing.
- the amount of foam to be injected will be controlled in the field by balancing the tubing and annulus pressures with appropriate allowance for hydrostatic and friction pressure drops.
- the volume of foam may be estimated by multiplying the steam injection rate by the ratio of the formation thickness where foam and steam, respectively, are entering, f/s in the drawing, and the ratio of the foams mobility to the steam mobility, i.e.
- Ms steam mobility
- Mf foam mobility
- the foaming agent may be selected from a large number of commercially availablesurfactants, such as Triton X-100 manufactured by Rohm and Haas, lgepal CO-990 manufactured by Antar Chemicals, Arquad C-50 manufactured by Armour Industrial Company or Ethomeen 18/60 stearyl amine. Other surfactants than these examples may be employed.
- the foam can be generated by combining 50 to 1500 volumes of condensible or non-condensible gas with one volume of liquid solution which contains 0.01 to 1.5 percent of a suitable foaming agent.
- a typical application would involve the injection of 10,000 lbs/hr. of saturated steam into a 100 ft. thick pay formation down a 1500 ft. long tubing string at 1000 p.s.i.a. bottom hole pressure.
- a 1000:l gas to liquid ratio and a one percent foaming agent concentration in the liquid only 5.56 (l0-5) gallons per hour of surfactant is required.
- the low foam requirements also requires a modest expenditure, such as for several compressed gas cylinders, to furnish the gas for the project. Allowing for thermal expansion of the gas, only 0.4 ft.3 of gas at 80 F. and 1000 p.s.i.a. is required to deliver 0.743 ft.3 at 545 F. injection temperature.
- the foam can be a mixture of any suitable foaming agent and a condensible or a non-condensible l gas.
- the process can take advantage of the high apparent viscosity of a foam and this eliminates the need to inject excessive amounts of foam into the upper pay zones during the operation.
- the condensible foam feature of the invention facilitates back flow production when the invention is applied to a huff and puff operation.
- the foam can be generated in situ or pumped into the well and can be made of any number of chemicals as indicated. The choice can be made dependent upon whether the foam is generated at the surface or in the well.
- the steam or. other fluid to be injected down to the tubing can be injected at a pressure slightly larger than that of the annulus which, however, is maintained sufliciently high to insure the movement of the steam into the bottom portion of the pay.
- the annulus pressure is reduced so that the steam can enter an upper stratum. In this step-Wise fashion, steam enters the entire face of the pay zone with a 4minimum amount of by-passing due to buoyancy and/or perme ability variation effects.
- the foam need not be injected into an annulus surrounding the steam or other fluid injection means. It is sufficient that the foam, in some cases, can be made to enter into the formation to form a blanket over the top thereof ⁇ so that the steam which is injected at a lower point is caused to spread throughout the formation. By releasing the pressure on the foam gradually, steam can be introduced to higher and higher levels or strata.
- Triton X- and Igepal (20-990 are materials of the alkyl phenoxy polyethoxy ethanol class.
- other surfactants can be employed, for example, Alconox which is sodium hexametaphosphate manufactured by Alconox, Incorporated, and the ordinary soaps, such as are available for use in the household.
- Detergents such as Trend manufactured by Purex Corporation, Ltd., can advantageously be used.
- a method for injecting a fluid into a formation below the earth surface which comprises injecting to a portion of a formation into which a fluid is to be injected a column of foam, maintaining said column of foam above said formation, separately injecting the fluid to he injected to said portion of said formation ⁇ below said column of foam, maintaining on said column of foam a pressure sufficient to retain it substantially in place against the pressure of said uid being injected and injecting said fluid at a pressure suicient to force the same into said formation below said column of foam.
- a method according to claim 2 wherein the fluid to be injected is steam. 4. A method according ⁇ to claim 3 wherein the uid employed to produce the foam is a condensible gas which is admixed with a foaming agent to produce said foam.
- the formation is an oil-bearing formation
- the uid to be injected is steam or a gas
- the steam is injected through a tubing string within a well bore and the foam is disposed in the bottom of the well below the end of the tubing.
Description
A GENT soLuT|oN coNDENslBLE 0R l NoN-CONDENSIBLE GAS G N M A O F A. J. CORNELIUS FLUID INJECTION METHOD Filed July 25. 1966 E I l @E 5%@ Nov. l2, 1968 /NVE N TOR A. J. CORNELIUS A T TORNEYS United States Patent-O FLUID INJECTION METHOD ArchieJ. Cornelius, Bartlesville, Okla., assignor to Phillips Petroleum Company, a corporation of Delaware Filed July 25, 1966, Ser. No. 567,470
8 Claims. (Cl. 166-40) ABSTRACT OF THE DISCLOSURE The invention contemplates the use of a column of foam pressure balanced against a flowing column of medium, eg., a hot liuid such as steam or gas, being injected into a formation, such as an oil-bearing stratum, to control the level at which the injected medium is forced into the formation, so that the level at which medium injection occurs can be changed by altering the pressure on the foam column relative to that of the medium being injected. The use of this inventiona-lso reduces we-ll bore heat loss as the foam insulates the tubing through which steam can be'injected.
Concepts One of the concepts of the invention involves supplying down a hole or passageway in a formation a column of foam and injecting the medium to 'be injected down another passageway to a point above or below the foam and maintaining the pressure at the foot of the foam column such that the injected medium must enter the formation `at substantially the level of the foam medium interface.
In another of its concepts, the invention provides for varying the level at which the injected medium is forced into the formation by varying the pressure exerted yby the foam column at its bottom against the entering injected medium ina manner to move the meeting place or level of the foam column bottom and the injected medium .to another desired level.
Inv a more specific concept of the invention, the injected medium is forced into the formation by way of a tubing within a casing while the annulus between the tubing and the casing is filled with a column of foam, as later more fully described,
The invention is particularly adapted for use in oil production. Accordingly, it will be described in connection with such application. However, one skilled in the art of injecting various media into formations will understand that the invention can be applied to production of other materials from the earth or to treatment of such materials therein.
The beneficial use of steam in the production of certain oil-bearing formations or reservoirs poses certain problems. It is difficult to control sufficiently injection of steam as uniformly as possibly over the producing level as is desired. Further, the minimization of thermal effects on the well casing is highly desirable, since expansion due to heating of the well casing is undesirable, as unde-rstood by those in this art. Thus, when the tubing and pump are set above the producing interval, analyses of results of steam injection show the majority of steam entering the top of an approximately 100 ft. thick formation while hot water or steam condensate enters the bottom of the formation. Further, with wells approximately 5000 ft. deep, the casing expansion is in excess of l ft.
To minimize thermal effects of the steam on the Well casing, best practice has been to use a steam packer to `prevent steam from entering the annulus of the well and to inject steam through the tubing string to the bottom of the well, thus assuring better steam distribution over and into the for-mation.
l have now conceived that the casing-tubing annulus can be pressured with a condensible or non-condensible foam and that, if this is done, the use of a packer can be eliminated. Thus,` steam can be injected down the tubing at a pressure slightly higher than the pressure at the foot of the foam column in the annulus, insuring movement of the steam into the bottom portion of the pay or formation. When steam injection has progressed `for a sufficiently long period of time so that the major portion of the steam has entered the bottom strata of the pay, the annulus pressure can be reduced so that the steam will displace the foam column upward and can thus enter into a higher stratum. By operating step-wise in the fashion described, steam enters the entire face of the pay zone with minimum amount of by-passing due to buoyancy and/or permeability variation eifects.
It is an object of this invention to provide a method for injecting Huid into a formation. It is another object of this invention to provide a method for injecting a fluid, e.g., steam, into a hydrocarbon-bearing formation. It is a further object of this invention to provide a method for injecting a hot medium, such as steam, into a well extending into a hydrocarbonor petroleum-bearing formation. It is a still `further object of this invention to provide a method for injecting 4a hot medium into an oil well without use of a packer. It is a still further object of this invention to provide a method for injecting a hot fluid into an oil well at various levels which can be controlled by a control of pressure and without the use of a packer.
Other concepts, objects and advantages of the invention are apparent from a study of this disclosure, the drawing and the appended claims.
According to the invention, there is provided a method of injecting a fluid into a formation below the earths surface which comprises providing a column of foam in a passageway leading to a portion of said formation into which said fluid is to be injected, by way of another passageway injecting said fluid to said portion of said formation below said column of foam, maintaining on said column of foam a pressure suicient to retain it substantially in place against the pressure of said fliud being injected and injecting said fluid at a pressure sufficient to force the same into said formation below said column of foam.
Further, according to the invention, as it is applied to a well having a piping therein and a casing or an annulus portion, the foam column is provided in one of said piping and annulus and the medium is injected into the formation through the other of said piping and said annulus.
Referring to the drawing, 1 is a casing perforated at points 2 and containing therein tubing y3: to which steam can be admitted at 4. A condensible or a non-condensible gas is passed into casing 1 by way of pipe 6, foam generator 7, which, in this instance, is a porous plug, through check valve 8. There is admixed with the gas thus passed into casing 1 a foaming agent added to conduit 6 by Way of pipe 9. The gas and foaming agent, on pa-ssing through porous plug 7, generate a foam which passes through check valve 8 into casing 1 and down to a certain level, for example, to near the top of the producing formation, as shown in the drawing, or to the bottom of the well below the end of the tubing. The pressures of the foam and steam are adjusted so that the foam column remains in the casing downto a certain level. Check valve S'cooperates to accomplish this end. As shown in the drawing, some foam is allowed, in this example, to escape into the upper portion of the producing formation, as indicated at f. Steam, which is prevented from rising up through the annulus by the weight of the column of foam and the pressure thereon, passes through perforations 2 into the producing formation throughout a stratum indicated by s. One -skilled in the art in possession of this disclosure, having studied the same, will see at once that, by suitably balancing the length of the column of foam and its pressure and the injection pressure of the steam, it is possible to gradually or step-wise inject the steam into various portions of the formation. As shown in the drawing, steam has been injected initially into the lower portions of the formation and the column of foam has gradually been shortened or allowed to shorten so that steam now is being injected over substantially the full height of the producing formation, except for the small portion indicated by The amount of foam to be injected will be controlled in the field by balancing the tubing and annulus pressures with appropriate allowance for hydrostatic and friction pressure drops. The volume of foam may be estimated by multiplying the steam injection rate by the ratio of the formation thickness where foam and steam, respectively, are entering, f/s in the drawing, and the ratio of the foams mobility to the steam mobility, i.e.
if=foam injection rate, b.p.d.
iszsteam injection rate, b.p.d.
f=formation thickness foam enters, ft.
s=formation thickness steam enters, ft.
Ms=steam mobility Mf=foam mobility.
Assuming f/s=.1 and Mf/Ms: A500, only 1/6000 as much foam as steam must be injected.
The foaming agent may be selected from a large number of commercially availablesurfactants, such as Triton X-100 manufactured by Rohm and Haas, lgepal CO-990 manufactured by Antar Chemicals, Arquad C-50 manufactured by Armour Industrial Company or Ethomeen 18/60 stearyl amine. Other surfactants than these examples may be employed.
In general, the foam can be generated by combining 50 to 1500 volumes of condensible or non-condensible gas with one volume of liquid solution which contains 0.01 to 1.5 percent of a suitable foaming agent.
A typical application would involve the injection of 10,000 lbs/hr. of saturated steam into a 100 ft. thick pay formation down a 1500 ft. long tubing string at 1000 p.s.i.a. bottom hole pressure. With Mf/MS=% only about 0.743 ft.3 of foam per hour must be injected at the sand face to maintain the foam/ steam interface ft. below the top of the pay. At a 1000:l gas to liquid ratio and a one percent foaming agent concentration in the liquid only 5.56 (l0-5) gallons per hour of surfactant is required. The low foam requirements also requires a modest expenditure, such as for several compressed gas cylinders, to furnish the gas for the project. Allowing for thermal expansion of the gas, only 0.4 ft.3 of gas at 80 F. and 1000 p.s.i.a. is required to deliver 0.743 ft.3 at 545 F. injection temperature.
It will be evident from the foregoing discussion, description of the drawing and the specific example given that the invention is entirely operative without use of packers with which it is not ordinarily feasible to differentiate between producing zones in a real way. Further, minimization of thermal stress in the well casing and tubing are possible and there is also possible control of the injection level of the generated foam enabling differential control of injection of steam, for example starting with the deepest formation, as described. Elimination of the steam packer minimizes expense and also eliminates the problems which occur when the packers are stuck in a well.
As noted, the foam can be a mixture of any suitable foaming agent and a condensible or a non-condensible l gas. The process can take advantage of the high apparent viscosity of a foam and this eliminates the need to inject excessive amounts of foam into the upper pay zones during the operation.
When a condensible gas is used to produce the foam, when the foam is displaced into the colder parts of the reservoir, the effective mobility block collapses and this facilitates steam injection into upper zones during lthe latter phases of the injection operation. The condensible foam feature of the invention facilitates back flow production when the invention is applied to a huff and puff operation.
The foam can be generated in situ or pumped into the well and can be made of any number of chemicals as indicated. The choice can be made dependent upon whether the foam is generated at the surface or in the well. v
It is evident from the foregoing discussion that the foam will fill the annulus and, accordingly, will decrease convection and radiation well bore heat losses.
With use of the check valve noted, the steam or. other fluid to be injected down to the tubing can be injected at a pressure slightly larger than that of the annulus which, however, is maintained sufliciently high to insure the movement of the steam into the bottom portion of the pay. When steam injection has progressed a sufliciently long period of time and it is determined that the majority of the steam has entered the bottom stratum of the pay, the annulus pressure is reduced so that the steam can enter an upper stratum. In this step-Wise fashion, steam enters the entire face of the pay zone with a 4minimum amount of by-passing due to buoyancy and/or perme ability variation effects.
In lieu of the steam, there can be used natural gas or vaporized hydrocarbons or other gases which, when heat is desired in the formation, are preheated before injection or are otherwise heated as may be desired.
It will be evident from a consideration of this disclosure and the several concepts of the invention as therein set forth, that the foam need not be injected into an annulus surrounding the steam or other fluid injection means. It is sufficient that the foam, in some cases, can be made to enter into the formation to form a blanket over the top thereof `so that the steam which is injected at a lower point is caused to spread throughout the formation. By releasing the pressure on the foam gradually, steam can be introduced to higher and higher levels or strata.
The commercially available surfactants to which reference has been made herein are well known. Thus, the Triton X- and Igepal (20-990 are materials of the alkyl phenoxy polyethoxy ethanol class. As noted, other surfactants can be employed, for example, Alconox which is sodium hexametaphosphate manufactured by Alconox, Incorporated, and the ordinary soaps, such as are available for use in the household. Detergents, such as Trend manufactured by Purex Corporation, Ltd., can advantageously be used.
Reasonable variation and modification are possible within the scope of the foregoing disclosure, the drawing and the appended claims to the invention the essence of which is that the injection of steam without a packer has been accomplished by employing a column of foam at a relative pressure such and against the pressure of a fluid being injected that the fluid being injected can be injected into a formation in the earth in a controlled manner at a desired or at various levels, the level being determined by the depth to which and at which the foot of the column o foam is maintained at any given time.
I claim:
1. A method for injecting a fluid into a formation below the earth surface which comprises injecting to a portion of a formation into which a fluid is to be injected a column of foam, maintaining said column of foam above said formation, separately injecting the fluid to he injected to said portion of said formation `below said column of foam, maintaining on said column of foam a pressure sufficient to retain it substantially in place against the pressure of said uid being injected and injecting said fluid at a pressure suicient to force the same into said formation below said column of foam.
v2. A method according to claim 1 wherein there are provided a well bore having a tubing therein forming an annulus, the foam is pumped into one of said tubing and annulus and the fluid injected is injected through the other of said tubing and said annulus.
3. A method according to claim 2 wherein the fluid to be injected is steam. 4. A method according `to claim 3 wherein the uid employed to produce the foam is a condensible gas which is admixed with a foaming agent to produce said foam.
5. A methodaccording to claim 4 wherein there is provided fa well bore having therein a casing and said casing has therein a strintg olf tubing, the steam is injected through the tubing and the foam is disposed in the annulus'and thus protects the casing against adverse temperature effects due to the heat of the steam.
`6. A method according to claim 1 wherein the formation is an oil-bearing formation, the fluid to be injected is steam, the steam is injected through a tubing string within a well bore and the foam is disposed in the annulus between said tubing string and the well wall.
7. A method according to claim `6 wherein, as steam injection progresses, the column of foam is gradually raised so that the steam penetrates the formation at successively higher levels.
8. A method according to claim 1 wherein the formation is an oil-bearing formation, the uid to be injected is steam or a gas, the steam is injected through a tubing string within a well bore and the foam is disposed in the bottom of the well below the end of the tubing.
References Cited UNITED STATES PATENTS 2,897,894 8/1959 Draper et al 166-9 2,973,813 3/1961 Parker 166--11 3,299,953 1/ 1967 Bernard 166-29 3,306,354 2/1967 OBrien 166-42 X 3,330,346 7/1967 Jacobs et al 166-9 3,342,261 9/1967 Bond 166--9 STEPHEN I. NOVOSA-D, Primary Examiner.
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US567470A US3410344A (en) | 1966-07-25 | 1966-07-25 | Fluid injection method |
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US567470A US3410344A (en) | 1966-07-25 | 1966-07-25 | Fluid injection method |
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Cited By (25)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3486560A (en) * | 1968-04-12 | 1969-12-30 | Chevron Res | Ammoniated foamed well circulation fluids and uses thereof |
US3504745A (en) * | 1968-05-08 | 1970-04-07 | Pan American Petroleum Corp | Use of foams to prevent vertical flow in tar sands during in-situ combustion |
US3525399A (en) * | 1968-08-23 | 1970-08-25 | Exxon Production Research Co | Technique for insulating a wellbore with silicate foam |
US3561533A (en) * | 1969-07-17 | 1971-02-09 | Chevron Res | Controlled chemical heating of a well using aqueous gas-in-liquid foams |
US3664424A (en) * | 1970-12-21 | 1972-05-23 | Exxon Production Research Co | Method for insulating a well |
US3664425A (en) * | 1970-12-21 | 1972-05-23 | Exxon Production Research Co | Well insulation method |
US3707193A (en) * | 1971-10-01 | 1972-12-26 | Shell Oil Co | Gas-strengthened steam foam well cleaning |
US3750753A (en) * | 1972-05-03 | 1973-08-07 | Union Oil Co | Method of placing a well on production |
FR2214037A1 (en) * | 1973-01-16 | 1974-08-09 | Schlumberger Ltd | |
US3964547A (en) * | 1973-01-15 | 1976-06-22 | Amoco Production Company | Recovery of heavy hydrocarbons from underground formations |
US4088188A (en) * | 1975-12-24 | 1978-05-09 | Texaco Inc. | High vertical conformance steam injection petroleum recovery method |
US4413859A (en) * | 1981-08-03 | 1983-11-08 | Stewart Folk & Company, Incorporated | Mining of sulphur with foam barrier |
US4445573A (en) * | 1982-11-04 | 1984-05-01 | Thermal Specialties Inc. | Insulating foam steam stimulation method |
US4540049A (en) * | 1984-02-03 | 1985-09-10 | Texaco Inc. | Method of improving steam flood conformance with steam flooding agents without a non-condensable gas |
US4540050A (en) * | 1984-02-03 | 1985-09-10 | Texaco Inc. | Method of improving conformance in steam floods with steam foaming agents |
US4577688A (en) * | 1984-02-03 | 1986-03-25 | Texaco Inc. | Injection of steam foaming agents into producing wells |
US4694906A (en) * | 1985-08-30 | 1987-09-22 | Union Oil Company Of California | Method for emplacement of a gelatinous foam in gas flooding enhanced recovery |
US4797003A (en) * | 1987-04-22 | 1989-01-10 | Dowell Schlumberger Incorporated | Foamed slurry generator |
US5529122A (en) * | 1994-12-15 | 1996-06-25 | Atlantic Richfield Company | Method for altering flow profile of a subterranean formation during acid stimulation |
US20030096048A1 (en) * | 2001-11-22 | 2003-05-22 | Ajinomoto Co. Inc | Processes for preparing an aspartame slurry |
US20040110643A1 (en) * | 2002-12-06 | 2004-06-10 | Zevallos Manuel Legendre | Self-generating foamed drilling fluids |
US20160032692A1 (en) * | 2014-07-30 | 2016-02-04 | Shell Oil Company | Induced control excitation for enhanced reservoir flow characterization |
US9739124B2 (en) | 2013-03-28 | 2017-08-22 | Dow Global Technologies Llc | Enhanced steam extraction of in situ bitumen |
US10941347B2 (en) | 2016-06-21 | 2021-03-09 | Dow Global Technologies Llc | Composition for steam extraction of bitumen |
US11001747B2 (en) | 2017-10-06 | 2021-05-11 | Dow Global Technologies Llc | Alkanolamine and glycol ether composition for enhanced extraction of bitumen |
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US3486560A (en) * | 1968-04-12 | 1969-12-30 | Chevron Res | Ammoniated foamed well circulation fluids and uses thereof |
US3504745A (en) * | 1968-05-08 | 1970-04-07 | Pan American Petroleum Corp | Use of foams to prevent vertical flow in tar sands during in-situ combustion |
US3525399A (en) * | 1968-08-23 | 1970-08-25 | Exxon Production Research Co | Technique for insulating a wellbore with silicate foam |
US3561533A (en) * | 1969-07-17 | 1971-02-09 | Chevron Res | Controlled chemical heating of a well using aqueous gas-in-liquid foams |
US3664424A (en) * | 1970-12-21 | 1972-05-23 | Exxon Production Research Co | Method for insulating a well |
US3664425A (en) * | 1970-12-21 | 1972-05-23 | Exxon Production Research Co | Well insulation method |
US3707193A (en) * | 1971-10-01 | 1972-12-26 | Shell Oil Co | Gas-strengthened steam foam well cleaning |
US3750753A (en) * | 1972-05-03 | 1973-08-07 | Union Oil Co | Method of placing a well on production |
US3964547A (en) * | 1973-01-15 | 1976-06-22 | Amoco Production Company | Recovery of heavy hydrocarbons from underground formations |
FR2214037A1 (en) * | 1973-01-16 | 1974-08-09 | Schlumberger Ltd | |
US3863717A (en) * | 1973-01-16 | 1975-02-04 | Schlumberger Cie Dowell | Methods for forcing a liquid into a low pressure formation |
US4088188A (en) * | 1975-12-24 | 1978-05-09 | Texaco Inc. | High vertical conformance steam injection petroleum recovery method |
US4413859A (en) * | 1981-08-03 | 1983-11-08 | Stewart Folk & Company, Incorporated | Mining of sulphur with foam barrier |
US4445573A (en) * | 1982-11-04 | 1984-05-01 | Thermal Specialties Inc. | Insulating foam steam stimulation method |
US4540049A (en) * | 1984-02-03 | 1985-09-10 | Texaco Inc. | Method of improving steam flood conformance with steam flooding agents without a non-condensable gas |
US4540050A (en) * | 1984-02-03 | 1985-09-10 | Texaco Inc. | Method of improving conformance in steam floods with steam foaming agents |
US4577688A (en) * | 1984-02-03 | 1986-03-25 | Texaco Inc. | Injection of steam foaming agents into producing wells |
US4694906A (en) * | 1985-08-30 | 1987-09-22 | Union Oil Company Of California | Method for emplacement of a gelatinous foam in gas flooding enhanced recovery |
US4797003A (en) * | 1987-04-22 | 1989-01-10 | Dowell Schlumberger Incorporated | Foamed slurry generator |
US5529122A (en) * | 1994-12-15 | 1996-06-25 | Atlantic Richfield Company | Method for altering flow profile of a subterranean formation during acid stimulation |
US20030096048A1 (en) * | 2001-11-22 | 2003-05-22 | Ajinomoto Co. Inc | Processes for preparing an aspartame slurry |
US20040110643A1 (en) * | 2002-12-06 | 2004-06-10 | Zevallos Manuel Legendre | Self-generating foamed drilling fluids |
US7199083B2 (en) | 2002-12-06 | 2007-04-03 | Self Generating Foam Incoporated | Self-generating foamed drilling fluids |
US9739124B2 (en) | 2013-03-28 | 2017-08-22 | Dow Global Technologies Llc | Enhanced steam extraction of in situ bitumen |
US20160032692A1 (en) * | 2014-07-30 | 2016-02-04 | Shell Oil Company | Induced control excitation for enhanced reservoir flow characterization |
US10233727B2 (en) * | 2014-07-30 | 2019-03-19 | International Business Machines Corporation | Induced control excitation for enhanced reservoir flow characterization |
US10941347B2 (en) | 2016-06-21 | 2021-03-09 | Dow Global Technologies Llc | Composition for steam extraction of bitumen |
US11001747B2 (en) | 2017-10-06 | 2021-05-11 | Dow Global Technologies Llc | Alkanolamine and glycol ether composition for enhanced extraction of bitumen |
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