DK2812409T3 - Forbedret fremgangsmåde til olieudvinding, der anvender vand med lav saltholdighed - Google Patents
Forbedret fremgangsmåde til olieudvinding, der anvender vand med lav saltholdighed Download PDFInfo
- Publication number
- DK2812409T3 DK2812409T3 DK13703111.8T DK13703111T DK2812409T3 DK 2812409 T3 DK2812409 T3 DK 2812409T3 DK 13703111 T DK13703111 T DK 13703111T DK 2812409 T3 DK2812409 T3 DK 2812409T3
- Authority
- DK
- Denmark
- Prior art keywords
- reservoir
- oil
- polymer
- water
- fluid
- Prior art date
Links
- 238000000034 method Methods 0.000 title claims description 88
- 238000000605 extraction Methods 0.000 title claims 3
- 229920000642 polymer Polymers 0.000 claims description 243
- 239000012530 fluid Substances 0.000 claims description 209
- 238000002347 injection Methods 0.000 claims description 205
- 239000007924 injection Substances 0.000 claims description 205
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 178
- 238000011084 recovery Methods 0.000 claims description 133
- 238000004519 manufacturing process Methods 0.000 claims description 46
- 150000001768 cations Chemical class 0.000 claims description 29
- 230000008569 process Effects 0.000 claims description 26
- 239000011148 porous material Substances 0.000 claims description 24
- 239000000243 solution Substances 0.000 claims description 16
- 229920002401 polyacrylamide Polymers 0.000 claims description 13
- 239000000839 emulsion Substances 0.000 claims description 11
- 239000007787 solid Substances 0.000 claims description 11
- 230000008719 thickening Effects 0.000 claims description 7
- 239000003380 propellant Substances 0.000 claims 3
- 239000002689 soil Substances 0.000 claims 1
- 239000003921 oil Substances 0.000 description 249
- 239000011435 rock Substances 0.000 description 53
- 230000015572 biosynthetic process Effects 0.000 description 45
- 238000005755 formation reaction Methods 0.000 description 45
- 230000035699 permeability Effects 0.000 description 32
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- 239000006185 dispersion Substances 0.000 description 21
- 239000012267 brine Substances 0.000 description 19
- 238000006073 displacement reaction Methods 0.000 description 19
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 19
- 238000004088 simulation Methods 0.000 description 14
- 230000001965 increasing effect Effects 0.000 description 12
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- 239000000203 mixture Substances 0.000 description 9
- 229910052791 calcium Inorganic materials 0.000 description 8
- 239000011575 calcium Substances 0.000 description 8
- 230000009467 reduction Effects 0.000 description 8
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 7
- 230000001419 dependent effect Effects 0.000 description 7
- 230000000694 effects Effects 0.000 description 7
- 239000010413 mother solution Substances 0.000 description 7
- 239000003208 petroleum Substances 0.000 description 7
- 239000000843 powder Substances 0.000 description 7
- 239000013535 sea water Substances 0.000 description 7
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 6
- 238000005553 drilling Methods 0.000 description 6
- 229910052500 inorganic mineral Inorganic materials 0.000 description 6
- 239000011707 mineral Substances 0.000 description 6
- 230000008961 swelling Effects 0.000 description 6
- NIXOWILDQLNWCW-UHFFFAOYSA-N 2-Propenoic acid Natural products OC(=O)C=C NIXOWILDQLNWCW-UHFFFAOYSA-N 0.000 description 5
- 238000002441 X-ray diffraction Methods 0.000 description 5
- 239000008346 aqueous phase Substances 0.000 description 5
- 239000004927 clay Substances 0.000 description 5
- 230000007062 hydrolysis Effects 0.000 description 5
- 238000006460 hydrolysis reaction Methods 0.000 description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 4
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 4
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N Iron oxide Chemical compound [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 description 4
- 239000007864 aqueous solution Substances 0.000 description 4
- 238000009826 distribution Methods 0.000 description 4
- 238000011156 evaluation Methods 0.000 description 4
- 239000013505 freshwater Substances 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 238000002156 mixing Methods 0.000 description 4
- 239000012071 phase Substances 0.000 description 4
- 230000004044 response Effects 0.000 description 4
- 125000006850 spacer group Chemical group 0.000 description 4
- SMZOUWXMTYCWNB-UHFFFAOYSA-N 2-(2-methoxy-5-methylphenyl)ethanamine Chemical compound COC1=CC=C(C)C=C1CCN SMZOUWXMTYCWNB-UHFFFAOYSA-N 0.000 description 3
- 238000006424 Flood reaction Methods 0.000 description 3
- 241000237858 Gastropoda Species 0.000 description 3
- 230000015556 catabolic process Effects 0.000 description 3
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- 238000001179 sorption measurement Methods 0.000 description 3
- RZVAJINKPMORJF-UHFFFAOYSA-N Acetaminophen Chemical compound CC(=O)NC1=CC=C(O)C=C1 RZVAJINKPMORJF-UHFFFAOYSA-N 0.000 description 2
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 2
- 238000012935 Averaging Methods 0.000 description 2
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 2
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 229910052788 barium Inorganic materials 0.000 description 2
- DSAJWYNOEDNPEQ-UHFFFAOYSA-N barium atom Chemical compound [Ba] DSAJWYNOEDNPEQ-UHFFFAOYSA-N 0.000 description 2
- 238000009835 boiling Methods 0.000 description 2
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 2
- 238000005341 cation exchange Methods 0.000 description 2
- 229920001577 copolymer Polymers 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 230000003247 decreasing effect Effects 0.000 description 2
- 238000010612 desalination reaction Methods 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 description 2
- 229910052631 glauconite Inorganic materials 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 229910052900 illite Inorganic materials 0.000 description 2
- 238000011065 in-situ storage Methods 0.000 description 2
- 229910052742 iron Inorganic materials 0.000 description 2
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 description 2
- 229910052622 kaolinite Inorganic materials 0.000 description 2
- 229940096405 magnesium cation Drugs 0.000 description 2
- 229910052901 montmorillonite Inorganic materials 0.000 description 2
- 229910052757 nitrogen Inorganic materials 0.000 description 2
- VGIBGUSAECPPNB-UHFFFAOYSA-L nonaaluminum;magnesium;tripotassium;1,3-dioxido-2,4,5-trioxa-1,3-disilabicyclo[1.1.1]pentane;iron(2+);oxygen(2-);fluoride;hydroxide Chemical compound [OH-].[O-2].[O-2].[O-2].[O-2].[O-2].[F-].[Mg+2].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[K+].[K+].[K+].[Fe+2].O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2 VGIBGUSAECPPNB-UHFFFAOYSA-L 0.000 description 2
- 230000000704 physical effect Effects 0.000 description 2
- 229910052655 plagioclase feldspar Inorganic materials 0.000 description 2
- 229910052903 pyrophyllite Inorganic materials 0.000 description 2
- 239000011347 resin Substances 0.000 description 2
- 229920005989 resin Polymers 0.000 description 2
- 150000003839 salts Chemical class 0.000 description 2
- 238000004626 scanning electron microscopy Methods 0.000 description 2
- 229910021646 siderite Inorganic materials 0.000 description 2
- 239000011780 sodium chloride Substances 0.000 description 2
- 238000010408 sweeping Methods 0.000 description 2
- 229920001897 terpolymer Polymers 0.000 description 2
- 150000003623 transition metal compounds Chemical class 0.000 description 2
- 239000003643 water by type Substances 0.000 description 2
- 239000004215 Carbon black (E152) Substances 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000012062 aqueous buffer Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 229910001919 chlorite Inorganic materials 0.000 description 1
- 229910052619 chlorite group Inorganic materials 0.000 description 1
- CRQQGFGUEAVUIL-UHFFFAOYSA-N chlorothalonil Chemical compound ClC1=C(Cl)C(C#N)=C(Cl)C(C#N)=C1Cl CRQQGFGUEAVUIL-UHFFFAOYSA-N 0.000 description 1
- QBWCMBCROVPCKQ-UHFFFAOYSA-N chlorous acid Chemical compound OCl=O QBWCMBCROVPCKQ-UHFFFAOYSA-N 0.000 description 1
- 239000002734 clay mineral Substances 0.000 description 1
- 238000001246 colloidal dispersion Methods 0.000 description 1
- 238000005094 computer simulation Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 239000003657 drainage water Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 239000008233 hard water Substances 0.000 description 1
- 229920000140 heteropolymer Polymers 0.000 description 1
- 229920001519 homopolymer Polymers 0.000 description 1
- 238000005213 imbibition Methods 0.000 description 1
- 230000002427 irreversible effect Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 238000009533 lab test Methods 0.000 description 1
- 239000002480 mineral oil Substances 0.000 description 1
- 235000010446 mineral oil Nutrition 0.000 description 1
- 230000000116 mitigating effect Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
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- 229920003169 water-soluble polymer Polymers 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
- E21B43/20—Displacing by water
-
- 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
-
- 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
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- 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
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Water Treatment By Sorption (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Extraction Or Liquid Replacement (AREA)
- Liquid Carbonaceous Fuels (AREA)
- Removal Of Floating Material (AREA)
Claims (20)
1. Fremgangsmåde til udvinding af olie fra et underjordisk oliebærende reservoir ved anvendelse af en injektionsfluid omfattende en fortykkende polymer i vand med lav saltholdighed, hvor vandet med lav saltholdighed har et samlet opløst faststofs-(TDS)-indhold på 15.000 ppmv eller derunder, hvor forholdet mellem det multivalente kationindhold i vandet med lav saltholdighed og det multivalente kationindhold i reservoirets indelukkede vand er mindre end 1, og hvor injektionsfluidens viskositet er i området fra 3 til 200 cP, hvor reservoiret gennemtrænges af en eller flere injektionsbrønde og en eller flere produktionsbrønde, hvilken fremgangsmåde omfatter at injicere injektionsfluiden i en slug-størrelse i området fra 0,4 til 1,5 porevolumener (PV) ind i mindst én af injektionsbrøndene; og hvor injektionsfluiden injiceres: i) ved påbegyndelse af olieproduktion fra reservoiret således at primær udvinding undlades; eller ii) i et sekundær udvindingsstadie, efter primær udvinding af olie under reservoirets naturlige tryk eller iii) i et tertiært udvindingsstadie efter vandfyldning med: a) vand med lav saltholdighed, der har et totalt opløst fast-stofs-(TDS)-indhold på 15.000 ppmv eller mindre, og som ikke omfatter nogen fortykkende polymer, eller b) vand med høj saltholdighed med et totalt opløst faststofs-(TDS)-indhold på mere end 20.000 ppmv.
2. Fremgangsmåde ifølge krav 1, hvor injektionsfluiden injiceres i en slug-størrelse på fra 0,5 til 1,0 PV, fortrinsvist 0,6 til 0,9 PV.
3. Fremgangsmåde ifølge krav 1 eller 2, hvor injektionsfluiden injiceres i et sekundært udvindingsstadie efter primær udvinding af olie under reservoirets naturlige tryk.
4. Fremgangsmåde ifølge krav 3, hvor olien har en viskositet på fra 40 til 200 cP under reservoirforhold.
5. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor injektionsfluidens vand med lav saltholdighed har et TDS-indhold på mindre end 12.000 ppmv, fortrinsvist mindre end 10.000 ppmv, mere fortrinsvist mindre end 8.000 ppmv og især mindre end 5.000 ppmv.
6. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor injektionsfluidens vand med lav saltholdighed har et samlet opløst faststofs-(TDS)-indhold på mindst 100 ppmv, fortrinsvist mindst 200 ppmv, mere fortrinsvist mindst 500 ppmv, mest fortrinsvist mindst 1000 ppmv.
7. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor forholdet mellem det multivalente kationindhold af injektionsfluidets vand med lav saltholdighed til det multivalente kationindhold i reservoirets indelukkede vand er mindre end 0,9, for eksempel mindre end 0,8.
8. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor vandet med lav saltholdighed, der anvendes som basisfluiden i injektionsfluiden, har et multivalent kationindhold på mindre end 200 ppmv, mere fortrinsvist mindre end 100 ppm, især 40 ppmv eller mindre, for eksempel mindre end 25 ppmv.
9. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor den for-tykkende polymer er en akrylamidpolymer.
10. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor injektionsfluiden er en opløsning af den fortykkende polymer i vand med lav saltholdighed.
11. Fremgangsmåde ifølge et hvilket som helst af kravene 1 til 9, hvor injektionsfluiden er en emulsion af den fortykkende polymer i vand med lav saltholdighed.
12. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor injektionsfluiden omfatter mindst 500 ppm af polymeren efter vægt.
13. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor olien har en viskositet på fra 40 til 200 cP under reservoirforhold, og injektionsfluiden slug-størrelse er i området fra 0,5 til 0,9 PV.
14. Fremgangsmåde ifølge krav 1, hvor olien har en viskositet på 3 til 40 cP under reservoirforhold, og injektionsfluidens slug-størrelse er i området fra 0,7 til 1,5 PV.
15. Fremgangsmåde ifølge et hvilket som helst af kravene 1 til 14, hvor en drivfluid kan injiceres i reservoiret efter injektion af injektionsfluiden, hvilken drivfluid driver injektionsfluiden gennem reservoiret til produktionsbrønden.
16. Fremgangsmåde ifølge krav 15, hvor drivfluiden injiceres i reservoiret i et større porevolumen end injektionsfluiden.
17. Fremgangsmåde ifølge krav 16, hvor drivfluiden injiceres i reservoiret i et porevolumen på mindst 1, fortrinsvist mindst 2, for eksempel i området fra 2 til 10.
18. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor en udfyldningsfluid injiceres i reservoiret før og/eller efter injektion af injektionsfluiden, og hvor udfyldningsfluiden er vandet med lav saltholdighed, der anvendes som basisfluiden i injektionsfluiden, eller blødgjort vand med høj saltholdighed.
19. Fremgangsmåde ifølge et hvilket som helst af de foregående krav, hvor injektionsfluiden injiceres under tryk i mindst én injektionsbrønd, der er anbragt med afstand fra en produktionsbrønd, og hvor injektionsfluiden går direkte fra injektionsbrønden ind i reservoirets oliebærende jordlag.
20. Fremgangsmåde ifølge krav 19, hvor injektionsfluiden injiceres ved et tryk på 10.000 til 100.000 kPa (100 til 1000 bar).
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US201261596789P | 2012-02-09 | 2012-02-09 | |
| PCT/EP2013/052614 WO2013117741A1 (en) | 2012-02-09 | 2013-02-08 | Enhanced oil recovery process using low salinity water |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| DK2812409T3 true DK2812409T3 (da) | 2019-03-25 |
Family
ID=47678876
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| DK13703111.8T DK2812409T3 (da) | 2012-02-09 | 2013-02-08 | Forbedret fremgangsmåde til olieudvinding, der anvender vand med lav saltholdighed |
Country Status (13)
| Country | Link |
|---|---|
| US (1) | US10041339B2 (da) |
| EP (1) | EP2812409B1 (da) |
| CN (1) | CN104334678A (da) |
| AR (1) | AR089956A1 (da) |
| AU (1) | AU2013217930B2 (da) |
| BR (1) | BR112014019875B1 (da) |
| CA (1) | CA2863352C (da) |
| CO (1) | CO7111311A2 (da) |
| DK (1) | DK2812409T3 (da) |
| EA (1) | EA026799B1 (da) |
| MA (1) | MA35919B1 (da) |
| MX (1) | MX360817B (da) |
| WO (1) | WO2013117741A1 (da) |
Families Citing this family (32)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP2261459A1 (en) * | 2009-06-03 | 2010-12-15 | BP Exploration Operating Company Limited | Method and system for configuring crude oil displacement system |
| US9458713B2 (en) * | 2012-11-14 | 2016-10-04 | Repsol, S. A. | Generating hydrocarbon reservoir scenarios from limited target hydrocarbon reservoir information |
| CA2935133A1 (en) * | 2014-01-03 | 2015-07-09 | Shell Internationale Research Maatschappij B.V. | Method and system for inhibiting freezing of low salinity water in a subsea low salinity water injection flowline |
| US20160009981A1 (en) * | 2014-02-19 | 2016-01-14 | Tadesse Weldu Teklu | Enhanced oil recovery process to inject low-salinity water alternating surfactant-gas in oil-wet carbonate reservoirs |
| WO2017011658A2 (en) * | 2015-07-14 | 2017-01-19 | Conocophillips Company | Enhanced oil recovery response prediction |
| CN105089573A (zh) * | 2015-07-21 | 2015-11-25 | 中国石油天然气股份有限公司 | 双重介质储层注气提高基质、微裂缝驱油效率的开采方法 |
| EP3135742A1 (en) * | 2015-08-27 | 2017-03-01 | Shell Internationale Research Maatschappij B.V. | Process for oil recovery |
| US10685086B2 (en) | 2015-09-15 | 2020-06-16 | Conocophillips Company | Avoiding water breakthrough in unconsolidated sands |
| US10723937B2 (en) | 2016-01-19 | 2020-07-28 | Saudi Arabian Oil Company | Oil recovery process using an oil recovery composition of aqueous salt solution and dilute polymer for carbonate reservoirs |
| US10287486B2 (en) | 2016-01-19 | 2019-05-14 | Saudi Arabian Oil Company | Oil recovery process using an oil recovery composition of aqueous salt solution and dilute polymer for carbonate reservoirs |
| US10457851B2 (en) * | 2016-01-19 | 2019-10-29 | Saudi Arabian Oil Company | Polymer flooding processes for viscous oil recovery in carbonate reservoirs |
| US10781362B2 (en) | 2016-01-19 | 2020-09-22 | Saudi Arabian Oil Company | Oil recovery process using an oil recovery composition of aqueous salt solution and dilute polymer for carbonate reservoirs |
| US10961831B2 (en) | 2016-01-19 | 2021-03-30 | Saudi Arabian Oil Company | Polymer flooding processes for viscous oil recovery in carbonate reservoirs |
| US10550312B2 (en) | 2016-01-19 | 2020-02-04 | Saudi Arabian Oil Company | Oil recovery process using an oil recovery composition of aqueous salt solution and dilute polymer for carbonate reservoirs |
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| CA2863352C (en) | 2019-09-17 |
| EA201400880A1 (ru) | 2015-01-30 |
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| AU2013217930B2 (en) | 2016-02-11 |
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| AU2013217930A1 (en) | 2014-09-04 |
| CN104334678A (zh) | 2015-02-04 |
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| AR089956A1 (es) | 2014-10-01 |
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| EA026799B1 (ru) | 2017-05-31 |
| EP2812409A1 (en) | 2014-12-17 |
| BR112014019875A8 (pt) | 2017-07-11 |
| US10041339B2 (en) | 2018-08-07 |
| BR112014019875B1 (pt) | 2021-06-22 |
| AU2013217930A2 (en) | 2014-09-25 |
| CO7111311A2 (es) | 2014-11-10 |
| EP2812409B1 (en) | 2018-11-28 |
| BR112014019875A2 (da) | 2017-06-20 |
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