US20150000916A1 - Enhanced oil recovery using seawater and edta - Google Patents
Enhanced oil recovery using seawater and edta Download PDFInfo
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- US20150000916A1 US20150000916A1 US13/932,986 US201313932986A US2015000916A1 US 20150000916 A1 US20150000916 A1 US 20150000916A1 US 201313932986 A US201313932986 A US 201313932986A US 2015000916 A1 US2015000916 A1 US 2015000916A1
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- 239000013535 sea water Substances 0.000 title claims abstract description 68
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 title claims abstract description 63
- 238000011084 recovery Methods 0.000 title claims abstract description 56
- 239000000243 solution Substances 0.000 claims abstract description 52
- 238000000034 method Methods 0.000 claims abstract description 18
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- 239000012267 brine Substances 0.000 claims description 7
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 7
- 150000001768 cations Chemical class 0.000 claims description 4
- 238000002347 injection Methods 0.000 abstract description 14
- 239000007924 injection Substances 0.000 abstract description 14
- 238000000605 extraction Methods 0.000 abstract description 7
- 238000002474 experimental method Methods 0.000 description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 12
- 230000001965 increasing effect Effects 0.000 description 8
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 6
- 238000005755 formation reaction Methods 0.000 description 6
- 239000012530 fluid Substances 0.000 description 5
- 239000011435 rock Substances 0.000 description 5
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 3
- 239000011575 calcium Substances 0.000 description 3
- 229910052791 calcium Inorganic materials 0.000 description 3
- 230000007423 decrease Effects 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 3
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000002708 enhancing effect Effects 0.000 description 2
- 239000013505 freshwater Substances 0.000 description 2
- 229910052500 inorganic mineral Inorganic materials 0.000 description 2
- 239000011707 mineral Substances 0.000 description 2
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 1
- VEXZGXHMUGYJMC-UHFFFAOYSA-M Chloride anion Chemical compound [Cl-] VEXZGXHMUGYJMC-UHFFFAOYSA-M 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- 238000005341 cation exchange Methods 0.000 description 1
- 230000009920 chelation Effects 0.000 description 1
- 239000008367 deionised water Substances 0.000 description 1
- 238000007865 diluting Methods 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 239000011777 magnesium Substances 0.000 description 1
- 229910052749 magnesium Inorganic materials 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000011734 sodium Substances 0.000 description 1
- 229910052708 sodium Inorganic materials 0.000 description 1
- 159000000000 sodium salts Chemical class 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- UEUXEKPTXMALOB-UHFFFAOYSA-J tetrasodium;2-[2-[bis(carboxylatomethyl)amino]ethyl-(carboxylatomethyl)amino]acetate Chemical compound [Na+].[Na+].[Na+].[Na+].[O-]C(=O)CN(CC([O-])=O)CCN(CC([O-])=O)CC([O-])=O UEUXEKPTXMALOB-UHFFFAOYSA-J 0.000 description 1
Images
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
Definitions
- the present invention relates to the enhancement of oil recovery in oil reservoirs, and particularly to enhanced oil recovery using seawater and EDTA (ethylenediaminetetraacetic acid) that enhances oil recovery in seawater injection systems by adding EDTA to the seawater.
- EDTA ethylenediaminetetraacetic acid
- seawater provides the most economical and abundant source of water.
- seawater contains sulfates, which can precipitate calcium sulfate and other insoluble or slightly soluble sulfates from minerals in the formation brine of sandstone reservoirs. These sulfates develop into formations of scale, which constrict the injection and pumping equipment, reducing the recovery of oil and requiring shutdown to clean or replace machinery.
- Various attempts are being used to improve oil recovery in reservoirs that use seawater injection, e.g., by diluting the seawater with fresh water to form “smart water” or low salinity water. Nevertheless, there is still a need for cost effective methods of enhancing oil recovery from oil reservoirs using seawater injection systems, particularly in regions where fresh water is a scarce and valuable commodity.
- the enhanced oil recovery using seawater and EDTA is a method that uses injection of EDTA in seawater to enhance the recovery of oil from sandstone reservoirs.
- the EDTA may be introduced into seawater during the initial extraction of oil from the reservoir by seawater injection, or a solution of EDTA in seawater may be used to flush residual oil from the reservoir after the initial extraction by seawater injection.
- the EDTA is present in about 1.0 wt % to about 5.0 wt % of the seawater solution, and the solution has a pH of between 10.5 and 11.0.
- FIG. 1 is a graph showing a comparison of the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores between a control seawater sample, a solution of seawater with 1.0 wt % ethylenediaminetetraacetic acid (EDTA), and a solution of seawater with 5.0 wt % EDTA, each of the examples showing initial extraction of oil from the sandstone cores.
- EDTA ethylenediaminetetraacetic acid
- FIG. 2 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in 3-inch Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA, showing the recovery of residual oil after initial seawater flooding.
- FIG. 3 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in 5-inch Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA, showing the recovery of residual oil after initial seawater flooding.
- FIG. 4 is a graph showing the oil/rock contact angle as a function of pH of a core flooding solution.
- FIG. 5 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA and with a pH of 12.2, showing the recovery of residual oil after initial seawater flooding.
- the enhanced oil recovery using seawater and EDTA is a method that uses injection of EDTA in seawater to enhance the recovery of oil from sandstone reservoirs.
- the EDTA may be introduced into seawater during the initial extraction of oil from the reservoir by seawater injection, or a solution of EDTA in seawater may be used to flush residual oil from the reservoir after the initial extraction by seawater injection.
- the EDTA is present in about 1.0 wt % to about 5.0 wt % of the seawater solution, and the solution has a pH of between 10.5 and 11.0.
- the method is demonstrated by the following experiments.
- Core flooding experiments were performed using Berea sandstone cores, each core having a diameter of 1.5 inches and a length of either 3 or 6 inches.
- the permeability of the cores was each approximately 100 mD, and porosity was approximately 18%. All the experiments were performed at 100° C.
- Formation brine i.e., connate water
- oil was injected to stabilize the initial water saturation S wi under a back pressure of 2,000 psi.
- the difference between the overburden pressure and the injection pressure i.e., the effective stress
- the flow rate was 0.25 mL/min through the different flooding stages. Seawater was injected to recover the oil from the three and six inches core samples.
- a chelating fluid formed from a solution of seawater having the composition shown in Table 1 and 1.0 wt % ethylenediaminetetraacetic acid (EDTA, in the form of the sodium salt, Na 4 EDTA) added to the seawater, and then a solution of 5 wt % EDTA in seawater to test the effect of the concentration of EDTA.
- EDTA ethylenediaminetetraacetic acid
- the EDTA was used both to recover residual oil after seawater flooding, and to enhance the recovery of oil during the initial seawater flooding.
- the pH values of the different flooding fluids are shown in Table 2.
- FIG. 1 shows the recovery of oil from the core flooding experiments using three different fluids at 100° C. and 0.25 mL/min for the recovery of oil during the initial flooding of the cores.
- the recovery factor from the control seawater was 40%, and the recovery factor from the 1.0 wt % EDTA solution was 46%.
- the increase in the recovery from 40 to 46% that was achieved by the addition of EDTA was due to the cation exchange between the rock surface and the solution, and also the pH increase by 2.35 units, from the seawater value of 7.5 to 9.85 (for the EDTA solution).
- Increasing the pH reduces the interfacial tension (IFT) of the solution. Adding EDTA at a concentration of 5.0 wt % gave a 47% recovery.
- IFT interfacial tension
- FIG. 2 shows the recovery of oil from the core flooding experiments using first, initial recovery of oil by seawater flooding, followed by second, recovery of residual oil from the core by the 5.0 wt % EDTA solution in seawater at 100° C. and 0.25 mL/min in the three-inch long cores. Seawater alone was able to recover 54% of the initial oil, and the EDTA solution recovered an additional 7% of the residual oil. The same experiment was repeated using the six-inch long cores, and the recovery increased almost by the same percentage, as shown in FIG. 3 .
- Table 4 below shows the interfacial tension (IFT) of Arabian light oil measured as a function of pH.
- IFT interfacial tension
- EDTA EDTA acted in a manner similar to low salinity water flooding, forcing the rock to release cations to replace the cation shortage in the flooding solution, thus changing the wettability to a greater water-wet state.
- the EDTA acted as a surfactant, since it contains four carboxylic groups, thus reducing the interfacial tension of the seawater.
- the viscosity of the EDTA rises when it chelates cations from the solution, and this increases the viscosity of seawater and aids in controlling the mobility of injected water.
- the EDTA leaches all calcium in the solution, thus eliminating the possibility of calcium sulfate precipitation and maintaining the injectivity in the reservoir at a constant level.
- FIG. 5 shows the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA and with an increased pH of 12.2, showing the recovery of residual oil after initial seawater flooding. Recovery of 29% of the original oil in place and almost 75% of the residual oil after sea water flooding was attained by injecting 5 PV of EDTA (pH 12.2). The increase in oil recovery compared to the previous cases can be attributed to the high pH value of the EDTA in this case.
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- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The enhanced oil recovery using seawater and EDTA (ethylenediaminetetraacetic acid) is a method that uses injection of EDTA in seawater to enhance the recovery of oil from sandstone reservoirs. The EDTA may be introduced into seawater during the initial extraction of oil from the reservoir by seawater injection, or a solution of EDTA in seawater may be used to flush residual oil from the reservoir after the initial extraction by seawater injection. In either case, the EDTA is present in about 1.0 wt % to about 5.0 wt % of the seawater solution, and the solution has a pH of between 10.5 and 11.0.
Description
- 1. Field of the Invention
- The present invention relates to the enhancement of oil recovery in oil reservoirs, and particularly to enhanced oil recovery using seawater and EDTA (ethylenediaminetetraacetic acid) that enhances oil recovery in seawater injection systems by adding EDTA to the seawater.
- 2. Description of the Related Art
- One method of enhancing oil recovery from oil reservoirs involves injecting water into the reservoir. In many areas, seawater provides the most economical and abundant source of water. However, seawater contains sulfates, which can precipitate calcium sulfate and other insoluble or slightly soluble sulfates from minerals in the formation brine of sandstone reservoirs. These sulfates develop into formations of scale, which constrict the injection and pumping equipment, reducing the recovery of oil and requiring shutdown to clean or replace machinery. Various attempts are being used to improve oil recovery in reservoirs that use seawater injection, e.g., by diluting the seawater with fresh water to form “smart water” or low salinity water. Nevertheless, there is still a need for cost effective methods of enhancing oil recovery from oil reservoirs using seawater injection systems, particularly in regions where fresh water is a scarce and valuable commodity.
- Thus, enhanced oil recovery using seawater and EDTA solving the aforementioned problems is desired.
- The enhanced oil recovery using seawater and EDTA (ethylenediaminetetraacetic acid) is a method that uses injection of EDTA in seawater to enhance the recovery of oil from sandstone reservoirs. The EDTA may be introduced into seawater during the initial extraction of oil from the reservoir by seawater injection, or a solution of EDTA in seawater may be used to flush residual oil from the reservoir after the initial extraction by seawater injection. In either case, the EDTA is present in about 1.0 wt % to about 5.0 wt % of the seawater solution, and the solution has a pH of between 10.5 and 11.0.
- These and other features of the present invention will become readily apparent upon further review of the following specification.
-
FIG. 1 is a graph showing a comparison of the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores between a control seawater sample, a solution of seawater with 1.0 wt % ethylenediaminetetraacetic acid (EDTA), and a solution of seawater with 5.0 wt % EDTA, each of the examples showing initial extraction of oil from the sandstone cores. -
FIG. 2 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in 3-inch Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA, showing the recovery of residual oil after initial seawater flooding. -
FIG. 3 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in 5-inch Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA, showing the recovery of residual oil after initial seawater flooding. -
FIG. 4 is a graph showing the oil/rock contact angle as a function of pH of a core flooding solution. -
FIG. 5 is a graph showing the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA and with a pH of 12.2, showing the recovery of residual oil after initial seawater flooding. - Similar reference characters denote corresponding features consistently throughout the attached drawings.
- The enhanced oil recovery using seawater and EDTA (ethylenediaminetetraacetic acid) is a method that uses injection of EDTA in seawater to enhance the recovery of oil from sandstone reservoirs. The EDTA may be introduced into seawater during the initial extraction of oil from the reservoir by seawater injection, or a solution of EDTA in seawater may be used to flush residual oil from the reservoir after the initial extraction by seawater injection. In either case, the EDTA is present in about 1.0 wt % to about 5.0 wt % of the seawater solution, and the solution has a pH of between 10.5 and 11.0. The method is demonstrated by the following experiments.
- As a control, untreated seawater with a high sulfate content was injected into a Berea sandstone core, which was initially saturated with a composition that simulates a typical formation brine. The contents of the seawater and the connate water (water that is trapped in the pores of sedimentary rocks, i.e., formation brine) are shown below in Table 1. Calcium sulfate in mineral form was found to have precipitated in the sandstone core, as expected.
-
TABLE 1 Composition of Seawater and Formation Brine (Connate Water) Connate Water Ions (ppm) Seawater (ppm) Sodium 59,491 18,300 Calcium 19,040 650 Magnesium 2,439 2,110 Sulfate 350 4,290 Chloride 132,060 32,200 Bicarbonate 354 120 TDS 213,734 57,670 - Core flooding experiments were performed using Berea sandstone cores, each core having a diameter of 1.5 inches and a length of either 3 or 6 inches. The permeability of the cores was each approximately 100 mD, and porosity was approximately 18%. All the experiments were performed at 100° C. Formation brine (i.e., connate water) having the properties shown above in Table 1 was injected through the cores, and then oil was injected to stabilize the initial water saturation Swi under a back pressure of 2,000 psi. The difference between the overburden pressure and the injection pressure (i.e., the effective stress) was kept constant at 500 psi. The flow rate was 0.25 mL/min through the different flooding stages. Seawater was injected to recover the oil from the three and six inches core samples.
- Core flooding experiments were then performed with a chelating fluid formed from a solution of seawater having the composition shown in Table 1 and 1.0 wt % ethylenediaminetetraacetic acid (EDTA, in the form of the sodium salt, Na4EDTA) added to the seawater, and then a solution of 5 wt % EDTA in seawater to test the effect of the concentration of EDTA. The EDTA was used both to recover residual oil after seawater flooding, and to enhance the recovery of oil during the initial seawater flooding. The pH values of the different flooding fluids are shown in Table 2.
-
TABLE 2 pH Values of Different Flooding Solutions Solution pH Seawater 7.50 1.0 wt % EDTA + Seawater 10.5 5.0 wt % EDTA + Seawater 11 -
FIG. 1 shows the recovery of oil from the core flooding experiments using three different fluids at 100° C. and 0.25 mL/min for the recovery of oil during the initial flooding of the cores. The recovery factor from the control seawater was 40%, and the recovery factor from the 1.0 wt % EDTA solution was 46%. The increase in the recovery from 40 to 46% that was achieved by the addition of EDTA was due to the cation exchange between the rock surface and the solution, and also the pH increase by 2.35 units, from the seawater value of 7.5 to 9.85 (for the EDTA solution). Increasing the pH reduces the interfacial tension (IFT) of the solution. Adding EDTA at a concentration of 5.0 wt % gave a 47% recovery. This 1% increase in recovery over the 1.0 wt % solution is due to the increase in chelation, which increased the viscosity of the solution. This effect is detailed below in Table 3. Increasing the solution viscosity will control the mobility of the injected fluid, and this mobility control increased the recovery by 1%. -
TABLE 3 Viscosity and Density of 5.0 wt % EDTA Solution Prepared in De-ionized Water at 70° F. Calcium Concentration (ppm) Viscosity (cP) Density (g/mL) 0 1.45 1.101 5000 1.64 1.115 10000 1.98 1.134 20000 2.14 1.187 30000 2.67 1.221 -
FIG. 2 shows the recovery of oil from the core flooding experiments using first, initial recovery of oil by seawater flooding, followed by second, recovery of residual oil from the core by the 5.0 wt % EDTA solution in seawater at 100° C. and 0.25 mL/min in the three-inch long cores. Seawater alone was able to recover 54% of the initial oil, and the EDTA solution recovered an additional 7% of the residual oil. The same experiment was repeated using the six-inch long cores, and the recovery increased almost by the same percentage, as shown inFIG. 3 . - Table 4 below shows the interfacial tension (IFT) of Arabian light oil measured as a function of pH. Increasing the solution pH decreases the IFT between oil and rock. In the present method, the pH of the solution is 11. By utilizing a high pH solution, oil recovery is enhanced by a decrease in the IFT. Additionally, it was found that the contact angle was greatly affected by the pH of the flooding fluid, as illustrated in
FIG. 4 . Increasing the pH of the solution to 11 can decrease the contact angle to 70°, which, in terms of wettability, is a water-wet state. The high pH (of about 11) of the present EDTA solutions aids in changing the wettability to more water-wet and reduces the IFT, thus allowing for greater oil recovery. -
TABLE 4 IFT of Arabian Light Oil at Varying pH Values pH IFT (N/m) 2 15.8 3 17 4 20.2 4.5 17.8 5.1 20 7 13.9 9.21 5.4 10 5.2 13 0.1 - It is thought that the addition of EDTA acted in a manner similar to low salinity water flooding, forcing the rock to release cations to replace the cation shortage in the flooding solution, thus changing the wettability to a greater water-wet state. Further, the EDTA acted as a surfactant, since it contains four carboxylic groups, thus reducing the interfacial tension of the seawater. Additionally, the viscosity of the EDTA rises when it chelates cations from the solution, and this increases the viscosity of seawater and aids in controlling the mobility of injected water. Importantly, the EDTA leaches all calcium in the solution, thus eliminating the possibility of calcium sulfate precipitation and maintaining the injectivity in the reservoir at a constant level.
-
FIG. 5 shows the oil recovery factor for core flooding experiments performed at a temperature of 100° C. at a rate of 0.25 mL/min in Berea sandstone cores by a solution of seawater with 5.0 wt % EDTA and with an increased pH of 12.2, showing the recovery of residual oil after initial seawater flooding. Recovery of 29% of the original oil in place and almost 75% of the residual oil after sea water flooding was attained by injecting 5 PV of EDTA (pH 12.2). The increase in oil recovery compared to the previous cases can be attributed to the high pH value of the EDTA in this case. - It is to be understood that the present invention is not limited to the embodiments described above, but encompasses any and all embodiments within the scope of the following claims.
Claims (11)
1. A method for enhanced oil recovery from a sandstone oil reservoir, comprising the step of injecting a solution consisting of an effective amount of ethylenediaminetetraacetic acid (EDTA) in seawater into the reservoir for chelating cations in the formation brine to prevent scaling caused by mixing the seawater with the formation brine.
2. The method for enhanced oil recovery according to claim 1 , wherein the effective amount of EDTA comprises about 1 wt % EDTA.
3. The method for enhanced oil recovery according to claim 1 , wherein the effective amount of EDTA comprises about 5 wt % EDTA.
4. The method for enhanced oil recovery according to claim 1 , wherein the solution has a pH of about 11.
5. The method for enhanced oil recovery according to claim 1 , wherein the step of injecting the solution comprises injecting the solution for the initial recovery of oil from the reservoir.
6. The method for enhanced oil recovery according to claim 1 , wherein the step of injecting the solution comprises injecting the solution containing the EDTA after the initial recovery of oil from the reservoir by seawater flooding in order to recover residual oil from the reservoir.
7. A method for enhanced oil recovery from a sandstone oil reservoir, comprising the step of injecting a solution consisting of between 1 wt % and 5 wt % ethylenediaminetetraacetic acid (EDTA) in seawater into the reservoir, the solution having a pH of about 11.
8. The method for enhanced oil recovery according to claim 7 , wherein the solution comprises 1 wt % EDTA.
9. The method for enhanced oil recovery according to claim 7 , wherein the solution comprises 5 wt % EDTA.
10. The method for enhanced oil recovery according to claim 7 , wherein the step of injecting the solution comprises injecting the solution for the initial recovery of oil from the reservoir.
11. The method for enhanced oil recovery according to claim 7 , wherein the step of injecting the solution comprises injecting the solution containing the EDTA after the initial recovery of oil from the reservoir by seawater flooding in order to recover residual oil from the reservoir.
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Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140345868A1 (en) * | 2013-05-21 | 2014-11-27 | King Fahd University Of Petroleum And Minerals | Method of maintaining oil reservoir pressure |
CN108825177A (en) * | 2018-07-09 | 2018-11-16 | 中国海洋石油集团有限公司 | A kind of horizontal well transfer drive technique |
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Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4979564A (en) * | 1989-01-31 | 1990-12-25 | The Standard Oil Company | Method of enhanced oil recovery using low tension viscous waterflood |
US20080035339A1 (en) * | 2006-08-04 | 2008-02-14 | Halliburton Energy Services, Inc. | Composition and method relating to the prevention and remediation of surfactant gel damage |
US20110290482A1 (en) * | 2010-05-25 | 2011-12-01 | Board Of Regents, The University Of Texas System | Surfactant-Less Alkaline-Polymer Formulations for Recovering Reactive Crude Oil |
US20140345868A1 (en) * | 2013-05-21 | 2014-11-27 | King Fahd University Of Petroleum And Minerals | Method of maintaining oil reservoir pressure |
-
2013
- 2013-07-01 US US13/932,986 patent/US20150000916A1/en not_active Abandoned
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4979564A (en) * | 1989-01-31 | 1990-12-25 | The Standard Oil Company | Method of enhanced oil recovery using low tension viscous waterflood |
US20080035339A1 (en) * | 2006-08-04 | 2008-02-14 | Halliburton Energy Services, Inc. | Composition and method relating to the prevention and remediation of surfactant gel damage |
US20110290482A1 (en) * | 2010-05-25 | 2011-12-01 | Board Of Regents, The University Of Texas System | Surfactant-Less Alkaline-Polymer Formulations for Recovering Reactive Crude Oil |
US20140345868A1 (en) * | 2013-05-21 | 2014-11-27 | King Fahd University Of Petroleum And Minerals | Method of maintaining oil reservoir pressure |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20140345868A1 (en) * | 2013-05-21 | 2014-11-27 | King Fahd University Of Petroleum And Minerals | Method of maintaining oil reservoir pressure |
CN108825177A (en) * | 2018-07-09 | 2018-11-16 | 中国海洋石油集团有限公司 | A kind of horizontal well transfer drive technique |
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