GB2182962A - Enhanced recovery of hydrocarbons from subterranean formations - Google Patents
Enhanced recovery of hydrocarbons from subterranean formations Download PDFInfo
- Publication number
- GB2182962A GB2182962A GB08528412A GB8528412A GB2182962A GB 2182962 A GB2182962 A GB 2182962A GB 08528412 A GB08528412 A GB 08528412A GB 8528412 A GB8528412 A GB 8528412A GB 2182962 A GB2182962 A GB 2182962A
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- Prior art keywords
- alpha
- olefin sulfonate
- range
- dimer
- foam
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Links
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 37
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 32
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 30
- 238000011084 recovery Methods 0.000 title abstract description 17
- 238000005755 formation reaction Methods 0.000 title description 26
- 239000004711 α-olefin Substances 0.000 claims abstract description 65
- 238000000034 method Methods 0.000 claims abstract description 46
- 125000001273 sulfonato group Chemical class [O-]S(*)(=O)=O 0.000 claims abstract description 42
- 239000006260 foam Substances 0.000 claims abstract description 40
- 238000002347 injection Methods 0.000 claims abstract description 20
- 239000007924 injection Substances 0.000 claims abstract description 20
- 238000004519 manufacturing process Methods 0.000 claims abstract description 15
- 239000007789 gas Substances 0.000 claims description 71
- 239000004094 surface-active agent Substances 0.000 claims description 41
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 25
- 239000000203 mixture Substances 0.000 claims description 16
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 11
- -1 alkene hydrocarbon Chemical class 0.000 claims description 9
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 7
- 239000004215 Carbon black (E152) Substances 0.000 claims description 7
- 239000002585 base Substances 0.000 claims description 7
- 238000010438 heat treatment Methods 0.000 claims description 7
- 239000002253 acid Substances 0.000 claims description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 6
- 238000006243 chemical reaction Methods 0.000 claims description 6
- 239000007791 liquid phase Substances 0.000 claims description 6
- AKEJUJNQAAGONA-UHFFFAOYSA-N sulfur trioxide Chemical compound O=S(=O)=O AKEJUJNQAAGONA-UHFFFAOYSA-N 0.000 claims description 6
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 5
- QGZKDVFQNNGYKY-UHFFFAOYSA-N Ammonia Chemical compound N QGZKDVFQNNGYKY-UHFFFAOYSA-N 0.000 claims description 4
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 3
- 229910052799 carbon Inorganic materials 0.000 claims description 3
- 238000003763 carbonization Methods 0.000 claims description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 3
- 238000006384 oligomerization reaction Methods 0.000 claims description 3
- 238000006277 sulfonation reaction Methods 0.000 claims description 3
- LSNNMFCWUKXFEE-UHFFFAOYSA-M Bisulfite Chemical compound OS([O-])=O LSNNMFCWUKXFEE-UHFFFAOYSA-M 0.000 claims description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 claims description 2
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 claims description 2
- 229910052783 alkali metal Inorganic materials 0.000 claims description 2
- 150000001340 alkali metals Chemical class 0.000 claims description 2
- 229910021529 ammonia Inorganic materials 0.000 claims description 2
- 229910052791 calcium Inorganic materials 0.000 claims description 2
- 239000011575 calcium Substances 0.000 claims description 2
- 239000001569 carbon dioxide Substances 0.000 claims description 2
- 239000003546 flue gas Substances 0.000 claims description 2
- 229910052749 magnesium Inorganic materials 0.000 claims description 2
- 239000011777 magnesium Substances 0.000 claims description 2
- 150000003839 salts Chemical group 0.000 claims description 2
- 229910052757 nitrogen Inorganic materials 0.000 claims 2
- 125000000217 alkyl group Chemical group 0.000 claims 1
- 150000001721 carbon Chemical group 0.000 claims 1
- 229910002091 carbon monoxide Inorganic materials 0.000 claims 1
- 239000003921 oil Substances 0.000 description 23
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 13
- 239000012267 brine Substances 0.000 description 12
- 238000005187 foaming Methods 0.000 description 4
- 239000007788 liquid Substances 0.000 description 4
- 239000000178 monomer Substances 0.000 description 4
- 241000237858 Gastropoda Species 0.000 description 3
- 239000000539 dimer Substances 0.000 description 3
- 230000035699 permeability Effects 0.000 description 3
- 239000003208 petroleum Substances 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 238000006424 Flood reaction Methods 0.000 description 2
- 241000184339 Nemophila maculata Species 0.000 description 2
- 150000007513 acids Chemical class 0.000 description 2
- 150000003863 ammonium salts Chemical class 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 150000003138 primary alcohols Chemical class 0.000 description 2
- 238000010408 sweeping Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 150000001335 aliphatic alkanes Chemical class 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 239000004064 cosurfactant Substances 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 238000004821 distillation Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Inorganic materials O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 239000007858 starting material Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 210000002268 wool Anatomy 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B43/164—Injecting CO2 or carbonated water
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
A method of recovering hydrocarbons from a subterranean formation in the absence of steam includes the use of alpha-olefin sulfonates and/or alpha-olefin sulfonate dimers and oligomers along with a non- condensible gas to form a gas-foam drive medium which is injected into the formation through at least one injection well to enhance the recovery of hydrocarbons from at least one production well.
Description
SPECIFICATION
Enhanced recovery of hydrocarbons from subterranean formations
This invention relates to enhanced oil recovery. More specifically, this invention relates to a process of enhancing oil recovery with a gas foam injection.
Many petroleum producing formations require assistance to economically produce hydrocarbons therefrom. The hydrocarbons can be recovered through the use of gas drives which are miscible with the in-place oil or generate a miscible drive of the in-place oil. Optionally, the gas drives may lower the viscosity of the hydrocarbons and enhance the flow of the hydrocarbons toward a production well. However, after initial break-through of the injected gas at the production well, the injected gas preferentially follows the path of the break-through. Thus, the total amount of the formation that is swept by the injected gas is limited. Solutions of commercial surfactants, such as Orvus K Liquid, a product of the Procter & Gamble Co., and Alipal CD-128, a product of the GAF Corporation, have been injected along with gas to create a gas foam flood.These materials are modified ammonium alkyl sulfates and ammonium salts of sulfated linear primary alcohol ethoxylate, respectively. The surfactants and gas form a foam that inhibits the flow of the gas into that portion of the formation containing only residual oil saturation. Residual oil saturation is defined as the immobile oil remaining in that portion of the reservoir swept by gas or other enhanced recovery means. This forces the gas to drive the recoverable hydrocarbons from the less depleted portions of the reservoir toward the production well(s).
To maximize the extraction of hydrocarbons from a formation, it would be highly desirable to have foaming surfactants which inhibit the flow of gas in a gas zone containing only residual oil saturation. Furthermore, it would be desirable to have the surfactants in a gas foam recovery process which inhibit the flow of the gas in the zone which contains only the residual oil and enhance the flow of gas in the zone which contains the recoverable hydrocarbons. However, it is desirable not to have the flow of the recoverable hydrocarbons inhibited in the gas zone having an oil saturation greater than the residual oil saturation.
We have invented a surfactant gas foam process for recovering hydrocarbons from a subterranean formation in the absence of steam. The gas can be any non-condensible gas such as CO2,
N2, CH4, CO, flue gas, or air. The process comprises the injection of one or more alpha-olefin sulfonates, oligomers thereof, such as alphaolefin sulfonate dimers, or mixtures thereof, as foaming surfactants into the gas injection at at least one injection well to enhance the recovery of hydrocarbons from at least one production well. The foaming characteristics of the alphaolefin sulfonates and/or the alpha-olefin sulfonate dimers enhance the sweeping of the steam through the formation. This enhances the recovery of hydrocarbons at the production well.
Depending on the formation, alpha-olefin sulfonates alone, alpha-olefin sulfonate dimers alone or mixtures of these materials are preferred to enhance the oil recovery. The surfactant-gas foam combination also recovers additional hydrocarbons from the previously residual oil saturated portions of the formation swept by only gas. The foamable mixture of gas and surfactant solution is injected into the formation at an injection well and displaced toward the production well with either additional foamable mixture, gas alone, or a water drive to recover the hydrocarbons from the formation.
Foaming surfactants for the injection can be evaluated by comparing several properties of the foams. Some of these properties are resistance factors, (R), which are determined by the pressure drop across a foam generator or a sandpack with simultaneous flow of a noncondensible gas, and brine as illustrated and at the following conditions: (1) at residual oil saturation with and without surfactant, and (2) at mobile oil saturation with and without surfactant. The resistance factors are defined in Table I.
TABLE I
Resistance Relation to Desired
Factor Definition Reservoir Value #P (Surfactant + Brine +
NCD + Sor) #P in gas zone at Sor w/foam
R1 High #P(Brine + NCD + Sor) #P in gas zone at Sor wo/foam #P(Surfactant + Brine +
NCD + Sor) #P in gas zone at Sor w/foam
R2 High #P(Surfactant + Brine + #P in gas zone at So w/foam
NCD + So) #P(Surfactant + Brine +
NCD + So) #P in gas zone at So w/foam Low (pref
R3 erably < 1) #P(Brine + NCD + So) #P in gas zone at So wo/foam #P = Pressure drop across foam generator
Sor = Residual oil saturation
So = Oil saturation (So > Sor) w = with wo = without
NCD = Non-condensible Gas A high value of R, indicates that the surfactant has the capability to create a foam that strongly inhibits the flow of gas in a gas zone containing residual oil. This parameter has been used before to evaluate surfactants and gas floods.Higher R, values indicate more desirable surfactants. In addition, resistance factors R2 and R3 are also important for evaluating the surfactant effectiveness. A high value of R2 indicates the surfactant makes a much stronger flow inhibiting foam in a gas zone with residual oil than it makes in a gas zone with recoverable hydrocarbons. This has the effect of blocking off that portion of the formation which has been swept of recoverable hydrocarbons and forces the additional gas injection to drive the recoverable hydrocarbons toward the production well. R3 values should approach one and preferably be less than 1. An R3 value less than one indicates that the surfactant itself has the ability to actually improve the flow of recoverable hydrocarbons in the gas zone relative to the absence of surfactant.Thus, high values of R1 and R2 and a value of R3 less than 1.0 would indicate the most desirable surfactants to divert gas from the depleted zone of the reservoir and to accelerate the growth of the gas zone and thereby to accelerate and increase the production of crude oil for a given amount of steam injection.
The alpha-olefin sulfonate surfactants of the present invention exhibit superior R1-R3 values to standard sulfate surfactants, such as Alipal CD-128. Alipal CD-128 is an ammonium salt of a sulfated linear primary alcohol ethoxylate.
The surfactants of the invention are alpha-olefin sulfonates with a carbon chain length of from about C5 to about C24, preferably C11 to C18 and most preferably C11-C14. The C11 to C14 alphaolefin sulfonates exhibit superior mobility ratios to other alpha-olefin sulfonates and Alipal
CD-128 as tested in accordance with the procedures of John T. Patton in U.S. Department of
Energy Publication No. DOE/MC/03259-15, titled "Enhanced Oil Recovery By CO2 Foam Flood ing", published April 1982. These C11-C14 alpha-olefin sulfonates exhibit better foamability in the presence of oil than shorter chain C8-C10 alpha-olefin sulfonates. Mixtures of the alpha-olefin sulfonates monomers can be employed to optimize the recovery of hydrocarbons from a particular formation.The alpha-olefin sulfonates are prepared by any known process such as the procedure described in GB 2,095,309A. Suitable examples of alpha-olefin sulfonates are Thermophoam BW-DB, a product of the Far Best Company, and Stepanflo 30, a product of the
Stepan Company and the Chevron Alpha Olefin product series by Chevron Chemical Company which has been sulfonated.
Preferred alpha-olefin sulfonates are prepared according to the procedures outlined in U.S.
Patent 3,444,191, or U.S. Patent 3,463,231.
The alpha-olefin sulfonate dimer surfactants advantageously employed in the invention are the alpha-olefin sulfonate dimers wherein the monomers have a carbon chain length of from C5 to about C24. In other words, the alpha-olefin sulfonate dimer is in the range of CIO-C48. The alphaolefin sulfonate dimers derived from C11-C18 alpha-olefins are preferred. These are in the range of C22-C26. Mixtures of the alpha-olefin sulfonate dimers can be employed to optimize the recovery of hydrocarbons from a particular formation. Furthermore, the alpha-olefin sulfonates to further optimize the recovery from a particular formation.
The alpha-olefin sulfonate dimers can be prepared by any suitable process but the alpha-olefin sulfonate dimers are complex mixtures of compounds which can be prepared by heating alphaolefin monomers at a temperature above about 1 10"C as disclosed in U.S. Patent 3,721,707.
More specifically, the alpha-olefin sulfonate dimer is prepared by the oligomerization process of heating in the liquid phase the sulfonation product of the reaction of sulfur trioxide with a straight-chain alkene hydrocarbon having a carbon content in the range of from 5 to 24, wherein the heating is at a temperature above 1 10"C and below the carbonization temperature of the sulfonate, is effected in substantial absence of water, and is continued for a period at least sufficient for a significant conversion of the sulfonate feed to the corresponding oligomeric disulfonic acid. Optionally, the resulting oligomeric sulfonic acid is neutralized with a base such as ammonia, an alkali metal base, a calcium base, a magnesium base or a mixture thereof.For convenience, the oligomeric mixture has a molecular weight about twice the starting materials, i.e., primarily a dimer, and containing alkane disulfonic acids, cyclic disulfonic acids, alkane sultones, is referred to as alpha-olefin sulfonate dimers. Of course, a specific dimer can be prepared by starting with a specific monomer.
The injection and production wells can be arranged in any pattern. For example, a two-spot, a three-spot, a regular four-spot, a skewed four-spot, a five-spot, a seven-spot, an inverted sevenspot, and the like. Suitable patterns are described in The Reservoir Engineering Aspects of
Waterflooding by Forrest F. Craig, Jr., Society of Petroleum Engineers of AIME, 1971, page 49.
Preferably, the injection well is surrounded by production wells, i.e., inverted five-spot and seven-spot patterns.
Any standard method of creating a gas surfactant foam is suitable for use in the invention.
Preferably, the non-condensible gas is nitrogen or carbon dioxide. A preferred process of creating the foam and sweeping the formation is disclosed in U.S. Patent 4488598 entitled "Steam, Non-Condensible Gas and Foam for Steam and Distillation Drives in Subsurface Petro leum Formation". However, the surfactant water combination must not be heated to a temperature at which steam forms. Alternatively, the procedures outlined in U.S. Patent 4,086,964 can by employed. In addition, the procedures outlined in U.S. Patents 4,085,800 and 3,412,793 can be used with producing formations that contain zones of high permeability and/or are susceptible to channeling. In those formations, the high permeability zones are plugged to enhance the recovery of hydrocarbons fro the zones of lower permeability.Again, these processes must be carried out at a temperature below the steam formation temperature and pressure of the reservoir and primarily with the non-condensible gas as the drive fluid.
The foam is created by mixing water or other suitable liquid containing the surfactant and injecting the non-condensible gas therein at a rate of about 5,000,000 standard cubic feet per day, (5M SCF/D). The surfactant is from about 0.01% to about 10% of the liquid phase of the gas-foam combination. Preferably, the surfactant is employed in as small an amount as possible to enhance the oil recovery. This is of the order of 0. 1% to 1% surfactant present in the liquid phase. The non-condensible gas-foam combination is generally from 1 to 99% non-condensible gas and from 99 to 1% surfactant phase by volume. Preferably, the gas-foam is greater than about 75% non-condensible gas.The gasfoam is injected into an injection well at a rate determined by reservoir characteristics and well pattern area. Typically, gas and surfactant solution are injected into each injecton well at 5M SCF/D and 2,500 barrels per day (BPD), respectively. Optionally, the water or other suitable liquid for forming the foam can contain other additives which enhance its properties such as scale inhibitors, cosurfactants, and the like. The water can also contain salts.
The process is carried out in the following procedure to minimize the cost of the operation.
Initially, a first slug of gas is injected into the formation for a sufficient time to form a gas zone in the subterranean formation containing the hydrocarbons. The gas injection is contained until thereis gas -breakthrough at the production well. This recovers the mobile oil in the gas-swept portion of the formation. Thereafter, a second slug of gas and foam surfactant is injected. This slug diverts the gas from the area of breakthrough and forces it to sweep through undepleted portions of the formation to recover additional hydrocarbons. Slugs of gas and surfactant can be alternated with slugs of pure gas. Optionally, the slugs can be tapered compositionally from one slug into the next to form a smooth transition or surfactant-gas injection can be continuous.
Finaily, pure gas is injected to sweep the last portion of the formation.
Having described the invention, the following examples are illustrative of the superior surfactants and process of recovery. However, it should be understood that the examples are not intended to limit the scope of the invention. Modifications to the above alpha-olefin sulfonates, alpha-olefin suifonate dimers and process of recover which would be obvious to the ordinary skilled artisan are contemplated to be within the scope of the invention.
EXAMPLE
An alpha-olefin sulfonate surfactant was compared with a surfactant recommended for CO2 floods by the stainless-steel wool pack procedure to evaluate their performance. Gas-foam flow tests were run in a 1/4 inch (6.35 mm) diameter by 2-1/2-inch (63.4 mm) long stainless-steelwool pack containing brine (1% Nail+500 ppm CaCI2) and Kern River crude oil. The comparison tests were run at 100"F (38"C) and 1000 psig (6895 kP). Foam flow rate was 43.3 cc/min. and liquid volume fraction was 0.075. Pressure drops and resistance factors (R1) across the foam generator are given in Tabie II.
AP, psig (R1) brine (R1) D.l. water
Alipal CD-128 136 5.0 19.4
Chevron C1s-C18 145 5.4 20.7
alpha-olefin
sulfonate
M.W. Well 269 brine 27 1.0 3.9
D.l. Water 7 0.26 1.0
The R1 resistance factors of the C15-C18 alpha-olefin sulfonate surfactant foams of the invention are higher than Murphy-Whittier brine and Alipal CD-128 and dionized water of Alipal
CD-128 and brine. The R2 and R3 values were not calculated.
Claims (24)
1. A method of recovering hydrocarbons from a subterranean formation in the absence of steam, wherein said formation is penetrated by at least one injection well and at least one production weil, said method comprising:
(a) injecting a non-condensible gas and a sufficient amount of an alpha-olefin sulfonate and/or an alpha-olefin sulfonate dimer to form a non-condensible gas and alpha-olefin sulfonate and/or alpha-olefin sulfonate dimer foam at the injection well;
(b) continuing to inject said non-condensible gas and alpha-olefin sulfonate and/or alpha-olefin sulfonate dimer foam to assist the movement of hydrocarbons toward the production well; and
(c) recovering hydrocarbons from the production well.
2. A method according to Claim 1, wherein the alpha-olefin sulfonate and/or alpha-olefin sulfonate dimer comprises from 0.01% to 10% of the liquid phase of the foam.
3. A method according to Claim 2, wherein the non-condensible gas is from 1 % to 99% of the foam.
4. A method according to Claims 1, 2 or 3, wherein the non-condensible gas is nitrogen, carbon dioxide, methane, air, carbon monoxide or flue gas.
5. A method according to any preceding claim, wherein an alpha-olefin sulfonate dimer is injected, the alpha-olefin sulfonate dimer having been prepared by the oligomerization process of heating in the liquid phase the sulfonation product of the reaction of sulfur trioxide with a straight-chain alkene hydrocarbon having a carbon content in the range from 5 to 24, wherein the heating is at a temperature above llO"C and below the carbonization temperature of the sulfonate, is effected in substantial absence of water, and is continued for a period at least sufficient for a significant conversion of the sulfonate feed to the corresponding oligomeric disulfonic acid.
6. A method according to any preceding claim, wherein the alpha-olefin sulfonate dimer includes alpha-olefin sulfonate dimer in the range of C10-C48.
7. A method according to Claim 5, wherein said straight-chain alkene hydrocarbon is a mixture in the range of C5-C24.
8. A method according to Claim 7, wherein said straight chain alkene hydrocarbon mixture is in the range of C11-C18.
9. A method according to Claim 7 or 8, wherein the alpha-olefin sulfonate dimer includes a mixture of alpha-olefin sulfonate dimer in the range of C10-C48.
10. A method accordng to Claim 9, wherein alpha-olefin sulfonate is included therewith and the alpha-olefin sulfonate has an alkyl carbon chain length in the range of from C5 to C24.
11. A method according to Claim 5, wherein alpha-olefin sulfonate is included therewith and the alpha-olefin sulfonate includes alpha-olefin sulfonate having carbon chain lengths in the range from C5 to C24.
12. A method according to any preceding claim and further comprising injecting non-condensible gas into the formation prior to the injection of the foam.
13. A method according to Claim 12 and further comprising injecting non-condensible gas into the formation after the injection of the foam.
14. A method according to Claim 13, wherein the non-condensible gas injection is tapered into a non-condensible gas and foam injection which in turn is tapered into a non-condensible gas injection.
15. A method according to Claim 14, wherein the alpha-olefin sulfonate and/or alpha-olefin sulfonate dimer surfactants are injected in their salt form or the acid form.
16. A method according to any one of Claims 1 to 4, wherein an alpha-olefin sulfonate is injected and the alpha-olefin sulfonate comprises an alpha-olefin sulfonate having alkyl chain lengths of from C5 to C24.
17. A method according to Claim 16, wherein the alpha-olefin sulfonate includes carbon chain lengths in the range from C,1 to C,8.
18. A method according to Claim 17, wherein the alpha-olefin sulfonate has carbon chain lengths in the range from C11 to C14.
19. A method according to Claim 17 or 18, wherein the non-condensible gas is CO2 or nitrogen.
20. A method according to Claim 16, wherein the foam further includes alpha-olefin sulfonate dimer synthesized according to the oligomerization process which comprises heating in the liquid phase the sulfonation product of the reaction of sulfur trioxide with a straight-chain alkene hydrocarbon having a carbon atom content in the range from 5 to 24, wherein the heating is at a temperature above 100"C and below the carbonization temperature of the sulfonate, is effected in the substantial absence of water, and is continued for a period at least sufficient for a significant conversion of the sulfonate feed to the corresponding oiigomeric disulfonic acid and wherein the resulting oligomeric sulfonic acid is neutralized with ammonia, an alkali metal base, a calcium base, a magnesium base, or a mixture thereof.
21. A method according to Claim 20, wherein said straight chain alkene hydrocarbon is a mixture in the range of C5-C24.
22. A method according to Claim 21, wherein said alpha-olefin sulfonate dimer includes a mixture of alpha-olefin sulfonate dimer in the range of C22-C26.
23. A method according to Claim 21, wherein said straight chain alkene hydrocarbon mixture is in the range of C11-C18.
24. A method of recovering hydrocarbons substantially as described in the foregoing
Example.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB08528412A GB2182962B (en) | 1985-11-19 | 1985-11-19 | Enhanced recovery of hydrocarbons from subterranean formations |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB08528412A GB2182962B (en) | 1985-11-19 | 1985-11-19 | Enhanced recovery of hydrocarbons from subterranean formations |
Publications (3)
| Publication Number | Publication Date |
|---|---|
| GB8528412D0 GB8528412D0 (en) | 1985-12-24 |
| GB2182962A true GB2182962A (en) | 1987-05-28 |
| GB2182962B GB2182962B (en) | 1988-11-09 |
Family
ID=10588408
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB08528412A Expired GB2182962B (en) | 1985-11-19 | 1985-11-19 | Enhanced recovery of hydrocarbons from subterranean formations |
Country Status (1)
| Country | Link |
|---|---|
| GB (1) | GB2182962B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103114835A (en) * | 2013-03-18 | 2013-05-22 | 西南石油大学 | Nitrogen-aided thickened oil formation emulsification and viscosity reduction exploitation method |
-
1985
- 1985-11-19 GB GB08528412A patent/GB2182962B/en not_active Expired
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103114835A (en) * | 2013-03-18 | 2013-05-22 | 西南石油大学 | Nitrogen-aided thickened oil formation emulsification and viscosity reduction exploitation method |
| CN103114835B (en) * | 2013-03-18 | 2016-04-13 | 西南石油大学 | A kind of nitrogen assists viscous crude stratum reducing viscosity by emulsifying exploitation method |
Also Published As
| Publication number | Publication date |
|---|---|
| GB2182962B (en) | 1988-11-09 |
| GB8528412D0 (en) | 1985-12-24 |
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| Date | Code | Title | Description |
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| PCNP | Patent ceased through non-payment of renewal fee |
Effective date: 19951119 |