WO1999051854A1 - Procede de recuperation du petrole par injection d'une solution aqueuse moussante - Google Patents
Procede de recuperation du petrole par injection d'une solution aqueuse moussante Download PDFInfo
- Publication number
- WO1999051854A1 WO1999051854A1 PCT/CN1998/000057 CN9800057W WO9951854A1 WO 1999051854 A1 WO1999051854 A1 WO 1999051854A1 CN 9800057 W CN9800057 W CN 9800057W WO 9951854 A1 WO9951854 A1 WO 9951854A1
- Authority
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- WIPO (PCT)
- Prior art keywords
- polymer
- foam
- flooding
- aqueous solution
- gas
- Prior art date
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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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/92—Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
- C09K8/94—Foams
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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 relates to a method for improving crude oil recovery, and in particular, to a foam composite flooding method.
- BACKGROUND OF THE INVENTION At present, many oilfields at home and abroad use oil injection to recover crude oil, but due to the heterogeneity of the reservoir and the unfavorable oil-water mobility ratio, a large amount of residual oil remains in the ground after water flooding. In order to recover these remaining oils, in addition to the use of infill wells and other measures, various new methods for improving oil recovery (EOR) have gradually transitioned from indoor research to mine practice, and have been widely used in many oil fields in the world. Among the new technologies of tertiary oil recovery, chemical flooding is still one of the promising methods.
- the flooding mechanism is mainly as follows: On the one hand, in the ternary composite system The presence of polymers can increase the viscosity of the displacement phase, thereby reducing the fluidity ratio between oil and water, Larger the volume; on the other hand, the synergistic effect of alkali and surfactant can form an ultra-low interfacial tension between oil and water, making it easier for crude oil to peel off the surface of rock and minerals, thereby improving oil displacement efficiency, and ultimately making oil recovery Yields have been greatly improved. References in this regard can be found in SPE24144, SPE21028, SPE17538.
- foam has better properties of entering and reducing the permeability of the high-permeability layer than polymers or gels, and the foam is generally separable.
- Ordinary foam is generally added with a surfactant in the injected gas to make it foam on the ground or underground.
- USP5363915 provides a technology that uses non-ionic surfactants, non-condensable gas, and water to improve crude oil recovery.
- the foam is stable in nature and can be formed underground or pre-formed on the ground. Oil carbonate formations are best used.
- other forms of stabilized foam are described in USP5074358.
- foam is reinforced foam, which means that in addition to surfactants, there is a chemical agent component that increases viscosity.
- USP5307878 uses polymer to reinforce foam to improve foam stability and reduce gas coning (referring to Into), the polymer reinforced foam is composed of a polymer, an aqueous solvent, a surfactant, and a gas.
- USP512947 is the use of polymer reinforced foam to treat fractured formations to improve the recovery of liquid hydrocarbons.
- the foam is also composed of a polymer, a surfactant, an aqueous solvent, and a gas. Foam will preferentially enter the fractures existing in the formation.
- the above-mentioned methods to increase the recovery of crude oil are aimed at increasing the sweep coefficient of the displacement agent.
- the chemical component in the foam cannot be as crude as the ternary system. Ultra-low interfacial tension is formed, so the final crude oil recovery is generally between 50 and 60%.
- the polymer profile control ability is much worse than foam, which limits the efficiency of the ripple effect.
- the displacement fluid is still easier to break through and channel in the high-permeability layer, and the final crude oil recovery is still generally around 60%.
- the purpose of the present invention is to address the shortcomings of low spread coefficient in the ternary compound flooding method and low wash efficiency in foam flooding, and to give full play to the high washing efficiency of the ternary compound flooding method and the high impact in the foam flooding method
- the advantage of efficiency is to use the gas and ternary composite system to simultaneously or alternately inject foam on the ground or underground to improve the crude oil recovery of underground oil-bearing formations.
- SUMMARY OF THE INVENTION The present invention relates to a method for improving crude oil recovery in an underground oil-bearing layer, and in particular, to a foam composite flooding method, which method includes:
- the present invention relates to a method for improving the crude oil recovery rate of an underground oil-bearing layer, in particular to a foam composite flooding method, which method comprises:
- the aqueous solution of the foaming composition includes a base, a surfactant, and a polymer;
- the polymer aqueous solution was It preferentially enters the high-permeability layer and / or thief layer in the formation to reduce its permeability, so as to prevent the gas in the subsequent foam from channeling along the high-permeability channel; on the other hand, polymer molecules are adsorbed on the rock surface Retention can effectively reduce the loss caused by the adsorption of various effective substances in the subsequent foam on the rock surface.
- the polymer used as the front slug is a water-soluble biopolymer and / or a synthetic polymer having a molecular weight of 300 to 30,000 Daltons.
- biopolymers xanthan gum and guar are included; as synthetic polymers, polymers including polyacrylamide and partially hydrolyzed polyacrylamide are included.
- a non-condensable gas and a polymer including alkali, surfactant and polymer are periodically or simultaneously injected.
- An aqueous solution of the composition is foamed to form a composite foam in the ground; or the gas and the aqueous solution are periodically injected into a composite foam formed in advance on the ground.
- the foam formed in the ground at the same time or alternately with the non-condensable gas and the foaming solution or directly injected with the non-condensable gas and the foaming solution forms on the ground
- the penetration of the foam in the formation is relatively uniform, and no tapering (finger-in) phenomenon will occur.
- the non-condensable gas used in the method of the present invention includes nitrogen, natural gas, methane gas, air or a mixture thereof.
- the aqueous foaming composition solution used therein includes a base, a surfactant, and a polymer.
- the most significant feature of the foaming composition aqueous solution is that it can form ultra-low interfacial tension with crude oil and has a high viscosity.
- the addition of polymer can increase the viscosity of the displacing phase, reduce the fluidity ratio, and expand the spread. coefficient.
- the synergistic effect of alkali and surfactant can make the system form ultra-low interfacial tension with crude oil, and its oil-water interfacial tension value can reach the order of l (T 3 mN / m, which is an ultra-low interfacial tension system. Therefore, the washing efficiency can be improved and the The final crude oil recovery rate is greatly improved.
- the final crude oil recovery rate can generally be increased by 25 to 30%.
- the foaming composition aqueous solution based on the total weight of the composition aqueous solution, includes 0.5 to 5% (weight) of the base, 0.05 to 0.5% (weight ) Surfactant and 0.05-0.5% by weight of polymer.
- the base includes sodium hydroxide, potassium hydroxide, potassium carbonate, potassium bicarbonate, sodium carbonate and / or sodium bicarbonate, preferably sodium hydroxide and sodium carbonate;
- the surfactant includes an ionic surface or nonionic surfactants, said ionic surfactants include ⁇ - olefin sulfonates, C 12 - 16 alkyl sulfate, (: 14--18 embankment benzene sulfonate, the Non-ionic surfactants include triethanolamine; wherein the polymer is a water-soluble biopolymer and / or a synthetic polymer having a molecular weight of 300 to 30,000 Daltons, and the biopolymer includes xanthan Gum, guar gum, and the synthetic polymer includes polyacrylamide and partially hydrolyzed polyacrylamide.
- the third step of the method of the invention is to inject a polymer protective slug, followed by water flooding.
- the purpose of injecting the protective plug is to effectively protect the formed foam and reduce the dilution and damage effect of subsequent water flooding on the foam.
- injecting the polymer protective plug according to the method of the present invention can fully play the role of foam.
- the polymer used as the protective plug is a water-soluble biopolymer and / or a synthetic polymer having a molecular weight of 300 to 30,000 Daltons, wherein the biopolymer includes xanthan gum and guar.
- the synthetic polymer includes polyacrylamide and partially hydrolyzed polyacrylamide.
- the method further comprises the step of performing subsequent water flooding after injecting the polymer aqueous solution as the protective slug.
- the mechanism of the foam composite flooding method of the present invention is as follows: On the one hand, the formed foam preferentially enters and blocks high-permeability pores in the formation, so that the displacement fluid (including foam) is diverted and enters the low-permeability zone, and the spread coefficient is enlarged ; On the other hand, the injected ternary composite system can form ultra-low interfacial tension with crude oil, which makes it easier for crude oil to peel off the rock surface, improves oil washing efficiency and has a certain bubble stabilizing effect. Increasing the utilization of crude oil in the upper low-permeability layer can greatly improve the recovery of hydrocarbons, that is, crude oil.
- the polymer in the ternary composite system used in the method of the invention has a stabilizing effect on the foam formed by the ternary composite system.
- a ternary composite system was prepared using ORS-41 as a surfactant, NaOH as a base, and different amounts of partially hydrolyzed polyacrylamide (HPAM) as polymers. The half-life of the foam produced by the system. The results are shown in Table 1 below: Effect of polymer on foam stability
- the addition of the polymer causes the half-life of the foam produced by the composition to be extended.
- the greater the amount of polymer added the longer the half-life of the foam, that is, the stability of the foam. The better.
- the added amounts of various components will be determined according to reservoir conditions in the oil production area, such as heterogeneity, loss of chemical agents, and economic costs .
- the volume of the pores of the entire system is generally not less than 50%
- the amount of liquid is 10-50% of the volume of the pores of the entire system
- the polymer pre-segment and the protective slug The amount is 2% ⁇ 8% and 10% ⁇ 45% respectively, which accounts for the pore volume of the whole system.
- the amount of polymer leading slugs and protective slugs can be reduced, and even these two slugs or one of them can be eliminated.
- the invention can effectively improve the crude oil recovery rate of the underground oil-bearing layer, and generally can improve the recovery rate by 25 to 30% 00 I P (primary geological reserve) on the basis of water flooding.
- Example 1A foaming composition was prepared having the following composition: Amount of component (% (weight)) fluorenyl arene sulfonate 1 0.3
- the salinity of 3 water is 918. 31 ⁇ 2g / L.
- the artificial core (I) as described above was used for the oil displacement experiment.
- the core is saturated with water for oil flooding, so that the original oil content of the core is saturated, and then the water is flooded to the core outlet with 98% water content.
- At the beginning of the core outlet pressure is 8. OMPa, the above foaming composition aqueous solution is injected.
- methane gas wherein the injection amount of the foaming composition aqueous solution is 0.3 PV, the gas phase is Q. 36PV, and then the concentration of Q. 283PV is 60Gmg / L fishing polymer (1275A) aqueous solution plug
- water flooding was performed until the core outlet had 98% water content.
- Example 2 and Example 1 experimental process is basically the same, there are two conditions are different, one is the core outlet pressure is normal pressure; the second is the gas and composite system is injected into 11 slugs, the gas-liquid ratio is maintained at 1.0.
- Table 3 Experimental results of gas-liquid injection
- the liquid-gas alternating injection method can still improve the recovery factor by 33.5% on the basis of water flooding, and the total recovery factor reaches 73.6%, indicating that the formazan and the foaming composition aqueous solution are alternately injected.
- the composite foam it can form a composite foam with good structure and properties in the core, which has a similar effect to foaming in front of the core.
- the model used in the following examples is a two-dimensional longitudinal heterogeneous composite prosody physical model (II).
- the geometric size of the model ( ⁇ ) is 4.5 cm x 4.5 cm x 30 cm.
- the model is made of quartz sand cemented with epoxy resin, with an average permeability of about 1 ⁇ m 2 and divided into five layers. There is no impervious barrier in the middle. permeability variation coefficient 0.61, respectively, from top to bottom permeability layers 190 X 10 m 2, 650 X 10- 3 ⁇ 2, 390 X 10- 3 ⁇ 2, 2700 X 10 - 3 ⁇ 1100 X 1 ( ⁇ 3 ⁇ 2.
- the saturation model uses artificially synthesized simulated salt water with a salinity of 6778mg / L.
- the experimental oil is prepared by degassing and dehydrating crude oil in the mine.
- the water for the foaming composition and the flooding water were artificial saline, and the mineralization was 37QQmg / L. 31 ⁇ 2g / L ⁇
- Preparation of polymer polymer brine is artificially synthesized brine with a salinity of 918. 31 ⁇ 2g / L.
- the experimental temperature was 45 ° C.
- Example 3 Using a foaming composition having the same composition as that described in Example 1, an oil displacement experiment was performed on the artificial core model ( ⁇ ) as described above.
- Example 4 Using a foaming composition having the same composition as described in Example 1, an oil displacement experiment was performed in the artificial core model ( ⁇ ) as described above. After the core is saturated with water, oil flooding is performed to saturate the original oil content of the core, and then the oil is flooded at a rate of lm / d to 98% water content at the model outlet to calculate the water flooding recovery factor. Then in the case where the core outlet pressure is 8. OMPa, the foaming composition and the natural gas are alternately injected: (1) the foaming composition of Q.
- the method of the present invention can improve the recovery of crude oil by 25-30%, which is a very effective method suitable for improving the recovery of crude oil under the heterogeneous reservoir geological conditions.
Description
Claims
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US09/647,854 US6439308B1 (en) | 1998-04-06 | 1998-04-06 | Foam drive method |
PCT/CN1998/000057 WO1999051854A1 (fr) | 1998-04-06 | 1998-04-06 | Procede de recuperation du petrole par injection d'une solution aqueuse moussante |
CN98813947A CN1093589C (zh) | 1998-04-06 | 1998-04-06 | 泡沫复合驱油方法 |
GB0024418A GB2352260B (en) | 1998-04-06 | 1998-04-06 | A foam drive method |
CA002327744A CA2327744C (en) | 1998-04-06 | 1998-04-06 | A foam drive method |
AU68193/98A AU6819398A (en) | 1998-04-06 | 1998-04-06 | A foam drive method |
NO20004970A NO322769B1 (no) | 1998-04-06 | 2000-10-02 | Fremgangsmate for skumdriv. |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/CN1998/000057 WO1999051854A1 (fr) | 1998-04-06 | 1998-04-06 | Procede de recuperation du petrole par injection d'une solution aqueuse moussante |
Publications (1)
Publication Number | Publication Date |
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WO1999051854A1 true WO1999051854A1 (fr) | 1999-10-14 |
Family
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Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/CN1998/000057 WO1999051854A1 (fr) | 1998-04-06 | 1998-04-06 | Procede de recuperation du petrole par injection d'une solution aqueuse moussante |
Country Status (7)
Country | Link |
---|---|
US (1) | US6439308B1 (zh) |
CN (1) | CN1093589C (zh) |
AU (1) | AU6819398A (zh) |
CA (1) | CA2327744C (zh) |
GB (1) | GB2352260B (zh) |
NO (1) | NO322769B1 (zh) |
WO (1) | WO1999051854A1 (zh) |
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- 1998-04-06 GB GB0024418A patent/GB2352260B/en not_active Expired - Lifetime
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CN102828733A (zh) * | 2012-09-04 | 2012-12-19 | 北京科技大学 | 一种使用泡沫复合体系开采油田剩余原油的方法 |
CN114517657A (zh) * | 2020-11-20 | 2022-05-20 | 中国石油化工股份有限公司 | 一种用于高温高盐底水油藏的二元复合控水工艺 |
Also Published As
Publication number | Publication date |
---|---|
CA2327744A1 (en) | 1999-10-14 |
GB2352260A (en) | 2001-01-24 |
CN1093589C (zh) | 2002-10-30 |
NO20004970L (no) | 2000-10-24 |
NO20004970D0 (no) | 2000-10-02 |
US6439308B1 (en) | 2002-08-27 |
GB0024418D0 (en) | 2000-11-22 |
GB2352260B (en) | 2002-10-23 |
AU6819398A (en) | 1999-10-25 |
CN1291253A (zh) | 2001-04-11 |
NO322769B1 (no) | 2006-12-11 |
CA2327744C (en) | 2004-07-13 |
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