US4617994A
Expired / Lapsed
US
⏱️ 0.0 years remaining
Determining residual oil saturation by injecting CO2 and base generating reactant
Assignee: Shell USA Inc
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Filing: 1985-11-22
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Granted: 1986-10-21
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Expires: 2005-11-22
Abstract
Abstract Residual oil saturation is determined by injecting water containing dissolved CO 2 and subsequently active base generating reactant into an oil and water containing reservoir and chromatographically analyzing the patterns of the concentrations of in situ reaction-depleted CO 2 and reaction-increased bicarbonate salt in fluid produced from the reservoir.
Inventors
- 👤 Edwin A. Richardson
Bibliographic Details
Application Number
—
Jurisdiction
US
Data Source
google_patents
Last Synchronized
2026-11-08 22:20
CPC Classifications
E; E21; E21B; E21B47/00; E21B47/10; E21B47/11; E21B49/00; E21B49/08; G; G01; G01V; G01V9/00
Claims Analysis
Total Claims: 6
Claim 1
Independent Claim
177 words
A process for determining the relative concentrations of substantially immobile oil phase fluid and relatively mobile water phase fluid within a subterranean reservoir formation comprising: injecting fluid consisting essentially of an aqueous solution which at least soon after entering the reservoir formation contains at least a detectible concentration of dissolved CO 2 and a concentration of subsequently active pH increasing reactant material which at the temperature of the reservoir formation is sufficient to convert a significant proportion of the dissolved CO 2 to dissolved bicarbonate ion; then injecting an aqueous solution which contains at least said concentration of dissolved CO 2 but is free of said reactant; allowing the occurrence of said pH increasing reaction; producing the injected fluid and measuring the variation with amount of fluid produced in the concentration of both dissolved CO 2 and dissolved bicarbonate ion; and determining relative concentrations of said oil phase and water phase fluids indicated by the extent of chromatographic separation between the reduction in concentration of dissolved CO 2 and the increase in concentration of dissolved bicarbonate ion.
Claim 2
Dependent Claim
177 words
A process for determining the relative concentrations of substantially immobile oil phase fluid and relatively mobile water phase fluid within a subterranean reservoir formation comprising: injecting fluid consisting essentially of an aqueous solution which at least soon after entering the reservoir formation contains at least a detectible concentration of dissolved CO 2 and a concentration of subsequently active pH increasing reactant material which at the temperature of the reservoir formation is sufficient to convert a significant proportion of the dissolved CO 2 to dissolved bicarbonate ion; then injecting an aqueous solution which contains at least said concentration of dissolved CO 2 but is free of said reactant; allowing the occurrence of said pH increasing reaction; producing the injected fluid and measuring the variation with amount of fluid produced in the concentration of both dissolved CO 2 and dissolved bicarbonate ion; and determining relative concentrations of said oil phase and water phase fluids indicated by the extent of chromatographic separation between the reduction in concentration of dissolved CO 2 and the increase in concentration of dissolved bicarbonate ion.
Claim 3
Dependent Claim
21 words
The process of claim 1 in which the injected CO 2 -containing fluid is water produced from the reservoir being tested.
Claim 4
Dependent Claim
95 words
The process of claim 1 in which a stream of CO 2 -containing water is pumped into the reservoir and a suitable flow rate and a portion of the inflowing stream is converted to fluid containing the subsequently active pH increasing reactant material by mixing enough of that base generating material with the inflowing stream to provide a suitably sized slug of solution containing the base generating material and then continuing to pump in the CO 2 -containing material free of that reactant to displace the reacting-containing solution to the selected distance within the reservoir.
Claim 5
Dependent Claim
28 words
The process of claim 1 in which the pH increasing reactant material is at least one compound of the group urea potassium cyanate sodium nitrite and propylene oxide.
Claim 6
Dependent Claim
60 words
The process of claim 1 in which the injected CO 2 and base generating reactant solution contains about 0.001 to 0.1 M/L dissolved CO 2 about 0.0005 to 0.05 M/L of the base generating reactant and has a volume occupying the desired pore volume of the reservoir when displaced about 5-25 feet from the well through which it is injected.
References Cited (Backward Citations)
USPTO Annuity & Maintenance Windows
| Annuity Stage | Window Opens | Payment Deadline | Surcharge Period Until | Estimated Fee | Status |
|---|---|---|---|---|---|
| 3.5 Years (Year 4) | 1989-10-20 | 1990-04-21 | 1990-10-21 | $2000.00 | Window Closed / Lapsed |
| 7.5 Years (Year 8) | 1993-10-20 | 1994-04-21 | 1994-10-21 | $3760.00 | Window Closed / Lapsed |
| 11.5 Years (Year 12) | 1997-10-20 | 1998-04-21 | 1998-10-21 | $7700.00 | Window Closed / Lapsed |