USRE26260E - Process utilizing the combination of miscible and thickened floods ik petroleum recovery - Google Patents
Process utilizing the combination of miscible and thickened floods ik petroleum recovery Download PDFInfo
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- USRE26260E USRE26260E US26260DE USRE26260E US RE26260 E USRE26260 E US RE26260E US 26260D E US26260D E US 26260DE US RE26260 E USRE26260 E US RE26260E
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- thickened
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- 238000000034 method Methods 0.000 title description 27
- 238000004391 petroleum recovery Methods 0.000 title description 3
- 230000015572 biosynthetic process Effects 0.000 description 39
- 239000000839 emulsion Substances 0.000 description 38
- 238000005755 formation reaction Methods 0.000 description 31
- 239000000463 material Substances 0.000 description 26
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 23
- 241000237858 Gastropoda Species 0.000 description 11
- 150000002430 hydrocarbons Chemical class 0.000 description 11
- 238000004519 manufacturing process Methods 0.000 description 10
- 238000002347 injection Methods 0.000 description 7
- 239000007924 injection Substances 0.000 description 7
- 239000000203 mixture Substances 0.000 description 7
- 239000012530 fluid Substances 0.000 description 6
- 239000011148 porous material Substances 0.000 description 4
- 239000004094 surface-active agent Substances 0.000 description 4
- 238000011084 recovery Methods 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- TYQCGQRIZGCHNB-JLAZNSOCSA-N L-ascorbic acid Chemical compound OC[C@H](O)[C@H]1OC(O)=C(O)C1=O TYQCGQRIZGCHNB-JLAZNSOCSA-N 0.000 description 2
- UHOVQNZJYSORNB-UHFFFAOYSA-N benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 2
- 230000003292 diminished Effects 0.000 description 2
- 238000009472 formulation Methods 0.000 description 2
- 229920002134 Carboxymethyl cellulose Polymers 0.000 description 1
- 229920002307 Dextran Polymers 0.000 description 1
- 229920002367 Polyisobutene Polymers 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- 239000001768 carboxy methyl cellulose Substances 0.000 description 1
- 235000010948 carboxy methyl cellulose Nutrition 0.000 description 1
- 239000008112 carboxymethyl-cellulose Substances 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 230000003247 decreasing Effects 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- PEDCQBHIVMGVHV-UHFFFAOYSA-N glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 description 1
- 235000011187 glycerol Nutrition 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920001888 polyacrylic acid Polymers 0.000 description 1
- 239000004584 polyacrylic acid Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- VQOIVBPFDDLTSX-UHFFFAOYSA-M sodium;3-dodecylbenzenesulfonate Chemical compound [Na+].CCCCCCCCCCCCC1=CC=CC(S([O-])(=O)=O)=C1 VQOIVBPFDDLTSX-UHFFFAOYSA-M 0.000 description 1
- -1 sorbitan fatty ester Chemical class 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- 235000000346 sugar Nutrition 0.000 description 1
- 150000008163 sugars Chemical class 0.000 description 1
Images
Classifications
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
Definitions
- the present invention comprises a process [or recoven ing hydrocarbons from subterranean oil-bearing formations having drilled therein at least one each of a production well and injection well consisting essentially of.
- This invention relates to the use of thickened water in oil recovery and more particularly to a process wherein an emulsion is injected into a formation, followed by a thickened flood material, and driven through the formation with water or other drive material.
- Oil can be recovered from subterranean formations by injecting oil-external emulsions into subterranean formations where the emulsions act as watencumpatible slugs.
- the initial slug injected into a formation is followed by a water-external emulsion of decreasing viscosity. Finally water is used to drive these materials through the formation.
- the efficiency of an oil recovery process is determined by the amount of oil recovered in flooding operations compared to the amount of oil in the formation at the time flooding is initiated.
- the flooding media should have a viscosity, at least at its leading edge, greater than that of the crude being displaced; the flood material should preferentially displace the oil from the surface of the formations; and should be of a higher viscosity than that of the crude in the formation.
- the flood must utiline water as a major portion of the drive material. Water has a low viscosity; therefore, to obtain maximum efficiency and economy, the viscosity of the displacing material should be reduced gradually from its high at the oil interface to that of water, the primary drive material.
- FIGURES 2- 7 disclose various procedures coming within the scope of this invention. The letter designations are the same for all figures.
- FIG. 1 represents an injection well and P, a producing well.
- the sequence of FIG. 1 represents the normal emulsion flood described above.
- 0 and FW represent oil and formation water, respectively.
- IW is injected water; and slugs A, B, and C represent oil-external emulsions, water-external emulsions, and a water-external emulsion having an incremental viscosity reduction from that of slug B to that of WV, respectively.
- 0 and some FW are displaced from the formation through well P by initial injection of slug A; followed, in order, by the injection of slugs B and C; and finally 1W through well I.
- slug A has been reduced in volume and slugs B and C of FIG. 1 have been replaced by slug D (a water-miscible thickened flood material) and slug E (a water-miscible thickened flood material having incremental viscosity reduction from a viscosity about that of slug A to that of 1W).
- slug D a water-miscible thickened flood material
- slug E a water-miscible thickened flood material having incremental viscosity reduction from a viscosity about that of slug A to that of 1W.
- slugs A and B are driven by a smaller slug E for incremental viscosity reduction.
- This process provides three slugs-A, B and D-of approximately equal viscosity and also a very stable front having little fingering or channeling.
- FIG. 6 The process represented by FIG. 6 is essentially that of FIG. 4, although slug D has been increased appreciably to provide a highly stable frontal movement.
- slug F an oil-miscible thickened flood material
- the first slug injected into the subterranean formation is an oil-compatible emulsion.
- These emulsions are opaque and are preferably relatively stable.
- An effective emulsion is made up of 50% Tip Top crude, 40% water, 4% of a sorbitan fatty ester sold under the mark Atpet 200, and 6% of an alkyl aryl sulfonate detergent.
- the emulsion is prepared by dissolving the surfactants in cetane and incrementally stirring water into the octane-surfactant mixture. This particular emulsion has a viscosity of 23-27 cps.
- oil-compatible slug is a preferred formulation
- other surfactants or petroleum fractions can be utilized in making up emulsions according to well-known formulation techniques.
- Thickened flood materials which can be utilized in the process of this invention are legion.
- sugars. dextrans, carboxymethyl cellulose, amines, polymers, glycerin, alcohols, and mixtures of these agents have been suggested for use in thickened water floods.
- Thickened hydrocarbon slugs known to the art include polyisobutylene or rubber in benzene.
- a thickened water flood of particular utility utilizes up to 1% of polyacrylic acid having molecular weight and the range of about l-l0 million. Viscosities in excess of 50 cps. are achieved at the 1.0% level.
- the combined slug volume can be divided as desired, though the emulsion slug(s) should comprise about 5- 50%, and preferably l0-30%, of the total combined slugs.
- Example 1 In a set of experiments using Tip Top crude in an emulsion made of 25 ml. crude, 20 ml. water, 2 grams Atpet 200, and 3 grams of (3-3300, the results of the following table were obtained when cetane was displaced from a core having a pore volume of 10.3 ml.
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
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Description
INVENTOR. CLAUDE P COPPEL BY c ATTORNEY P. COPPEL C. PROCESS UTILIZING THE COMBINATION OF MISClBLE AND THICKENED FLOODS IN PETROLEUM RECOVERY Original Filed June 19.
Sept. 5, 1967 W W. W m H W m m m o m r h 5531? 4 543 -5 33- F 1- q 1 A n o a B F l I I 4 l C I 1 4 E E D D E E M k: I 2 3 m 4 w 5 6 O O M I I I. I l O 01 O m I w I l m I .w T I w I 0 w I F F F F F United States Patent 26,260 PROCESS UTILIZING THE COMBINATION OF MISCIBLE AND THICKENED FLOODS IN PETROLEUM RECOVERY Claude P. Coppel, La I-Iabra. Calif., assignor to Marathon Oil Company, Findlay, Ohio, a corporation of Ohio Original No. 3,261,399, dated July 19, 1966, Ser. No. 289,090, June 19, 1963. Application for reissue Nov. 15, 1966, Ser. No. 597,501
6 Claims. (Cl. 166-9) Matter enclosed in heavy brackets appears in the original patent but forms no part of this reissue specificanon; matter printed in italics indicates the additions made by reissue.
ABSTRACT OF THE DISCLOSURE The present invention comprises a process [or recoven ing hydrocarbons from subterranean oil-bearing formations having drilled therein at least one each of a production well and injection well consisting essentially of.
(a) injecting into the oil-bearing formation a slug of emulsion,
(b) subsequently injecting into the formation a thickenea' water flood material difiering from said emulsion in character, thereafter,
(0) injecting a drive fluid into the formation to displat-e hydrocarbons toward said production well, and
(d) recovering oil from said formation.
This application is a continuation-in-part of my copending United States application Serial No. 235,139, filed Nov. 2, i962, and now abandoned.
This invention relates to the use of thickened water in oil recovery and more particularly to a process wherein an emulsion is injected into a formation, followed by a thickened flood material, and driven through the formation with water or other drive material.
Oil can be recovered from subterranean formations by injecting oil-external emulsions into subterranean formations where the emulsions act as watencumpatible slugs. The initial slug injected into a formation is followed by a water-external emulsion of decreasing viscosity. Finally water is used to drive these materials through the formation.
I have now discovered that the water-compatible material required in the above processes can be reduced in size or eliminated by driving the emulsion with thickened flood material. This technique retains the excellent properties of the emulsion flood. Furthermore, the amount of surfactant required to make up the oil and water compatible emulsions is reduced considerably when a thickened water flood is used.
Prior to describing my invention in detail, a brief review of the requirements for an efficient flood might be helpful. The efficiency of an oil recovery process is determined by the amount of oil recovered in flooding operations compared to the amount of oil in the formation at the time flooding is initiated. To have a good efficiency, the flooding media should have a viscosity, at least at its leading edge, greater than that of the crude being displaced; the flood material should preferentially displace the oil from the surface of the formations; and should be of a higher viscosity than that of the crude in the formation. To be the most economical, the flood must utiline water as a major portion of the drive material. Water has a low viscosity; therefore, to obtain maximum efficiency and economy, the viscosity of the displacing material should be reduced gradually from its high at the oil interface to that of water, the primary drive material.
The figures of the attached drawing illustrate various Re. 26,260 Reissues! Sept. 5, 1967 ice recovering techniques utilizing emulsions. FIGURES 2- 7 disclose various procedures coming within the scope of this invention. The letter designations are the same for all figures.
1 represents an injection well and P, a producing well. The sequence of FIG. 1 represents the normal emulsion flood described above. In FIG. 1, 0 and FW represent oil and formation water, respectively. IW is injected water; and slugs A, B, and C represent oil-external emulsions, water-external emulsions, and a water-external emulsion having an incremental viscosity reduction from that of slug B to that of WV, respectively. In use, 0 and some FW are displaced from the formation through well P by initial injection of slug A; followed, in order, by the injection of slugs B and C; and finally 1W through well I.
In the process of FIG. 2, slug A has been reduced in volume and slugs B and C of FIG. 1 have been replaced by slug D (a water-miscible thickened flood material) and slug E (a water-miscible thickened flood material having incremental viscosity reduction from a viscosity about that of slug A to that of 1W).
In the process of FIG. 3, slug A has been further reduced and the incremental reduction in viscosity accomplished with a much larger slug E.
In the process of FIG. 4, slugs A and B are driven by a smaller slug E for incremental viscosity reduction. This process provides three slugs-A, B and D-of approximately equal viscosity and also a very stable front having little fingering or channeling.
In the process of FIG. 5, slug D of FIG. 4 has been omitted and slug E enlarged to provide a more gradual viscosity gradient.
The process represented by FIG. 6 is essentially that of FIG. 4, although slug D has been increased appreciably to provide a highly stable frontal movement.
In the process of FIG. 7, slug F (an oil-miscible thickened flood material) has been substituted for slug B of FIG. 6.
Other variations of my process are obvious, and it is intended that they be included within the scope of my invention as claimed. For example, in the process of FIG. 3, an oiLmiscible thickened slug, having an incrementally reduced viscosity from its leading to its trailing edge, can be substituted for E and a hydrocarbon gas drive substituted for IW.
As mentioned previously, the first slug injected into the subterranean formation is an oil-compatible emulsion. These emulsions are opaque and are preferably relatively stable.
An effective emulsion is made up of 50% Tip Top crude, 40% water, 4% of a sorbitan fatty ester sold under the mark Atpet 200, and 6% of an alkyl aryl sulfonate detergent. The emulsion is prepared by dissolving the surfactants in cetane and incrementally stirring water into the octane-surfactant mixture. This particular emulsion has a viscosity of 23-27 cps.
While the above oil-compatible slug is a preferred formulation, other surfactants or petroleum fractions can be utilized in making up emulsions according to well-known formulation techniques.
Thickened flood materials which can be utilized in the process of this invention are legion. For example, sugars. dextrans, carboxymethyl cellulose, amines, polymers, glycerin, alcohols, and mixtures of these agents have been suggested for use in thickened water floods. Thickened hydrocarbon slugs known to the art include polyisobutylene or rubber in benzene.
A thickened water flood of particular utility utilizes up to 1% of polyacrylic acid having molecular weight and the range of about l-l0 million. Viscosities in excess of 50 cps. are achieved at the 1.0% level.
As is evident from a perusal of FIGS. 1-7, quite a variety of combinations of emulsion and thickened flood slugs can be utilized in my process. Normally, from about 1 to about 20% of the formation pore volume of combined slugs is necessary to effect good oil recoveries. Preferably, from about 2 to about 10% combined slugs are used. The total amount of emulsion and thickened slug required varies with the acreage to be flooded. Total slug volumes of 2.55.0% are adequate to flood a 40-50 acre area, while 540% of the pore volume of total slugs are necessary in a 3-5 acre area.
The combined slug volume can be divided as desired, though the emulsion slug(s) should comprise about 5- 50%, and preferably l0-30%, of the total combined slugs.
The following example more fully illustrates my invention, but it is not intended that my invention be limited to the particular emulsion, thickened water material, etc. Rather, it is intended that all equivalents obvious to those skilled in the art be included within the scope of my invention as claimed.
Example 1 In a set of experiments using Tip Top crude in an emulsion made of 25 ml. crude, 20 ml. water, 2 grams Atpet 200, and 3 grams of (3-3300, the results of the following table were obtained when cetane was displaced from a core having a pore volume of 10.3 ml.
These tests indicate that the emulsion had the displacement efficiency of a miscible fluid at high slug volume (30% or greater) and performed almost as well as slug volume.
Now having described my invention, what I claim is:
1. The process for recovering fluid hydrocarbons from subterranean formations having drilled therein at least one each of a. production well and an injection well consisting essentially of (a) injecting into the subterranean formation at least one slug of an emulsion,
(b) injecting into said formation at least one slug of a thickened flood material differing from said emulsion in character,
at least a portion of said material being incrementally diminished in viscosity from about that of the emulsion at the leading edge of the material to about that of a drive material at the interface between the thickened flood material and a drive fluid,
(c) injecting a drive fluid into the formation to displace hydrocarbons toward said production well, and
(d) recovering oil from said formation.
2. The process of claim 1 wherein the total volume of emulsion slug and thickened flood material injected into the formation comprises from about 1 to about 20% of the pore volume of the formation from which oil is recovered.
3. The process of claim 2 wherein the emulsion comprises about 550% of the total volume of the emulsion and thickened flood material volume.
4. The process for recovering hydrocarbons from subterranean formations having drilled therein at least one each of a production well and an injection well comprising (a) injecting into the subterranean formation a first slug of an oil-external emulsion,
(b) injecting into the formation at least one slug of a nonemulsiod thickened water flood material,
at least a portion of said thickened water flood material being incrementally diminished in viscosity from about that of the emulsion to about that of water,
(c) injecting water into the formation to displace hydrocarbons toward said production well, and
(d) recovering oil from said formation.
5. The process for the recovery of hydrocarbons from subterranean oil-bearing formations having drilled therein at least one each of a production well and an injection well consisting essentially of (a) injecting into the oil-bearing formation a slug of an oil-external emulsion, subsequently (b) injecting into the formation a thickened water flood material differing from said emulsion in character, thereafter (c) injecting water into the formation to displace hydrocarbons toward said production well, and
(d) recovering oil from said formation.
6. The process for recovering hydroclarbons from subterranean oil-bearing formations having drilled therein at least one each of a production well and an ejection well consisting essentially of (a) injecting into the oilbetm'ng formation a slug of emulsion, (b) subsequently injecting into the formation a thickened water flood material diflering from said emulsion in character, thereafter (0) injecting a drive fluid into the formation to displace hydrocarbons toward said production well and (d) recovering oil from said formation.
References Cited The following references, cited by the Examiner, are of record in the patented file of this patent or the original CHARLES E. OCONNELL, Primary Examiner. STEPHEN J. NOVOSAD, Examiner.
Publications (1)
| Publication Number | Publication Date |
|---|---|
| USRE26260E true USRE26260E (en) | 1967-09-05 |
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Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| US26260D Expired USRE26260E (en) | Process utilizing the combination of miscible and thickened floods ik petroleum recovery |
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| Country | Link |
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| US (1) | USRE26260E (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4433727A (en) | 1981-06-19 | 1984-02-28 | Marathon Oil Company | Oil recovery process |
| USRE32114E (en) | 1981-06-19 | 1986-04-15 | Marathon Oil Company | Oil recovery process |
-
0
- US US26260D patent/USRE26260E/en not_active Expired
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4433727A (en) | 1981-06-19 | 1984-02-28 | Marathon Oil Company | Oil recovery process |
| USRE32114E (en) | 1981-06-19 | 1986-04-15 | Marathon Oil Company | Oil recovery process |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| AS | Assignment |
Owner name: MARATHON OIL COMPANY, AN OH CORP Free format text: ASSIGNS THE ENTIRE INTEREST IN ALL PATENTS AS OF JULY 10,1982 EXCEPT PATENT NOS. 3,783,944 AND 4,260,291. ASSIGNOR ASSIGNS A FIFTY PERCENT INTEREST IN SAID TWO PATENTS AS OF JULY 10,1982;ASSIGNOR:MARATHON PETROLEUM COMPANY;REEL/FRAME:004172/0421 Effective date: 19830420 |