Methods and compositions for stimulating the production of hydrocarbons from subterranean formations
First Claim
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1. A method of treating a formation crude oil well having a wellbore comprising:
- injecting an emulsion or a microemulsion into the wellbore of the formation crude oil well to stimulate displacement of residual aqueous treatment fluid by formation crude oil and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
wherein the ratio of water to terpene is between about 3;
1 and about 1;
2; and
wherein the terpene has a phase inversion temperature greater than or equal to 43°
C.
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Abstract
Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.
16 Citations
18 Claims
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1. A method of treating a formation crude oil well having a wellbore comprising:
- injecting an emulsion or a microemulsion into the wellbore of the formation crude oil well to stimulate displacement of residual aqueous treatment fluid by formation crude oil and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
wherein the ratio of water to terpene is between about 3;
1 and about 1;
2; and
wherein the terpene has a phase inversion temperature greater than or equal to 43°
C. - View Dependent Claims (2, 3, 4, 5, 6, 7)
- injecting an emulsion or a microemulsion into the wellbore of the formation crude oil well to stimulate displacement of residual aqueous treatment fluid by formation crude oil and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
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8. A method of treating a formation gas well having a wellbore comprising:
- injecting an emulsion or a microemulsion into the wellbore of the formation gas well to stimulate displacement of residual aqueous treatment fluid by formation gas and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
wherein the ratio of water to terpene is between about 3;
1 and about 1;
2; and
wherein the terpene has a phase inversion temperature less than 43°
C. - View Dependent Claims (9)
- injecting an emulsion or a microemulsion into the wellbore of the formation gas well to stimulate displacement of residual aqueous treatment fluid by formation gas and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
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10. A method of treating a formation crude oil well having a wellbore comprising:
- using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by formation crude oil by injecting the emulsion or the microemulsion into the wellbore of the formation crude oil well, and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
wherein the ratio of water to terpene is between about 10;
1 and about 3;
1; and
wherein the terpene has a phase inversion temperature of greater than or equal to 43°
C. - View Dependent Claims (11, 12, 13, 14, 15, 16)
- using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by formation crude oil by injecting the emulsion or the microemulsion into the wellbore of the formation crude oil well, and increase production of formation crude oil by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
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17. A method of treating a formation gas well having a wellbore comprising:
- using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by gas by injecting the emulsion or the microemulsion into the wellbore of the formation gas well, and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
wherein the ratio of water to terpene is between about 10;
1 and about 3;
1; and
wherein the terpene has a phase inversion temperature of less than 43°
C. - View Dependent Claims (18)
- using an emulsion or a microemulsion to stimulate displacement of residual aqueous treatment fluid by gas by injecting the emulsion or the microemulsion into the wellbore of the formation gas well, and increase production of formation gas by the well, wherein the emulsion or the microemulsion comprises water, a terpene, and a surfactant;
Specification