Methods of inhibiting the flow of water in subterranean formations

Abstract

Methods of inhibiting the flow of water into and from subterranean well formations wherein one or more gelling agents having the property of forming highly viscous gels in the presence of water are injected into the formation.

Description

BACKGROUND OF THE INVENTION

1. Field of the Invention

This invention relates to treating subterranean formations penetrated by well bores for the purpose of reducing the production of undesirable water from the formations or reducing the loss of aqueous treating fluids to the formations.

2. Description of the Prior Art

In drilling, completing and producing subterranean formations penetrated by well bores, the in-flow or out-flow of water to and from water-bearing or water permeable formations penetrated by the well bores is often undesirable. For example, in producing oil and/or gas from subterranean formations which also contain water, the production of water along with the oil and/or gas is undesirable in that the produced water forms an undesirable emulsion with oil which can plug or otherwise interfere with efficient operation of surface separation and storage equipment and which requires special treating equipment to break the emulsion and recover oil therefrom. In addition, the produced water must be disposed of which adds to the expense of producing the wells. In instances where the well bore penetrates water-bearing formations as well as formations containing desired fluids such as oil and/or gas, the same problem exists.

In drilling, treating and completing oil and/or gas wells, highly permeable formations penetrated by the well bore often cause problems in that water from drilling muds, treating fluids such as formation fracturing fluids, acidizing fluids, packer fluids, etc., and cement slurries enter the permeable formations reducing the water content of the fluids or preventing all or part of the fluids from reaching the desired zone or formation whereby the effectiveness of the fluids is lost or reduced.

A variety of methods, compositions and means have been heretofore developed and used for plugging or sealing water-bearing or water permeable formations. For example, bulky solid materials, resinous materials and various gelatinous compounds, cement compositions and the like have been utilized heretofore for plugging subterranean formations to prevent the in-flow and out-flow of water and other fluids into and from the formations. However, such methods and compositions are generally expensive to carry out and/or are only temporarily effective. Further, such methods and compositions are generally ineffective in preventing the production of water from subterranean formations containing both water and desired fluids such as oil and/or gas.

Methods employing chemical compositions for inhibiting the flow of water in subterranean formations have been developed and used heretofore. For example, U.S. Pat. No. 3,604,508 to Marion O. Son, Jr. teaches the selective water shut-off of highly permeable subterranean formations wherein a micellar dispersion comprised of hydrocarbons, surface active agents and an aqueous medium is injected into the formation. The micellar dispersion takes up water to form a highly viscous dispersion which blocks the formation from intrusion of fluids.

U.S. Pat. No. 3,330,351 to George G. Bernard teaches a method of selectively reducing the flow of a particular fluid-producing formation into a well bore by injecting a solution containing a surface active agent into the formation followed by injecting a gas therein whereby a foam is formed in the formation adjacent the well bore which shuts off or blocks the influx of water therefrom into the well bore.

U.S. Pat. No. 3,495,664 to John Kelly, Jr. teaches shutting off water from water-producing formations in a pneumatically drilled well bore by introducing an oil wetting surface active agent and a non-volatile hydrophobic liquid into contact with the water-producing formation.

By the present invention improved methods of inhibiting the flow of water from a subterranean formation containing desired fluids such as oil and/or gas in addition to containing water are provided which are economical to carry out and which inhibit the production of water whle allowing the production of oil and/or gas from the formation. The methods of the present invention can also be effectively utilized to inhibit the flow of fluids into permeable formations penetrated by a well bore as well as inhibiting the flow of water from water-bearing formations penetrated by a well bore.

SUMMARY OF THE INVENTION

Methods of inhibiting the flow of water in subterranean formations are provided comprising introducing a gelling agent into the formations having the property of forming a highly viscous gel in the presence of water.

It is, therefore, a general object of this invention to provide methods of inhibiting the flow of water in subterranean formations.

Another object of the present invention is the provision of methods of plugging or shutting off the production of water from subterranean water zones or water-bearing formations by in situ chemical means.

A further object of the present invention is the provision of methods of inhibiting the flow of water to and from subterranean formations which are effective and economical to carry out.

Other objects, features and advantages of this invention will be readily apparent to those skilled in the art upon a reading of the description of preferred embodiments which follows.

DESCRIPTION OF PREFERRED EMBODIMENTS

The production of water with oil and/or gas from subterranean formations penetrated by a well bore is a common problem encountered in the oil industry. The water may be produced from a water-bearing formation or zone adjacent the oil and/or gas-bearing formation or zone, or the producing formation may contain both hydrocarbons and water. In the drilling and completing of well bores penetrating subterranean formations, water-bearing or water permeable formations also often cause problems. For example, when a water-bearing formation is encountered in the drilling of a well bore whereby large quantities of water are produced into the well bore, the driling operations are interrupted and it is necessary to plug the water-bearing formation before drilling operations can be recommenced. When formations are encountered which are highly permeable, drilling mud and other treating fluids are lost into the highly permeable formations again interrupting operations or at least adversely affecting such operations.

In accordance with the present invention, one or more gelling agents having the property of forming a highly viscous gel in the presence of water are introduced or injected into a formation whereby water existing in the formation or water subsequently entering the formation reacts with the gelling agent to form a gel and inhibit the flow of water to or from the formation. In the case where a formation produces both water and oil, one or more gelling agents are introduced therein which react with water to plug or inhibit the flow of water from the portions or strata producing water but do not appreciably interfere with the oil producing strata.

The term "gelling agent" is used herein to mean surface active agents of mixtures of surface active agents which form highly viscous gels in the presence of water. Examples of surface active agents falling within the foregoing definition which are suitable for use in accordance with this invention are as follows:

__________________________________________________________________________General Type of CTFA.sup.1 OtherSurfactant Designation Designation.sup.2 Structural Formula__________________________________________________________________________EthoxylatedAliphatic PEG-10Stearamine ##STR1##EthoxylatedAliphatic PEG-5Cocamine ##STR2##EthoxylatedAliphatic PEG-10Oleate ##STR3##Ethoxylated ALFONIC .RTM. CH.sub.3 (CH.sub.2).sub.x CH.sub.2 (OCH.sub.2 CH.sub.2).sub.n OHAlcohols 1412-40 where x has a value in the range of from 10 to 12 and n has an average value of 3Ethoxylated ALFONIC .RTM. CH.sub.3 (CH.sub.2).sub.x CH.sub.2 (OCH.sub.2 CH.sub.2).sub.n OHAlcohols 610-50 where x has a value in the range of from 4 to 8 and n has an average value of 3Ethoxylated ALFONIC .RTM. CH.sub.3 (CH.sub.2).sub.x CH.sub.2 (OCH.sub.2 CH.sub.2).sub.n OHAlcohols 1012-60 where x has a value in the range of from 8 to 10 and n has an average value of 5.7Ammonium Lauryl Ammonium Lauryl CH.sub.3 (CH.sub.2).sub.10 CH.sub.2 OSO.sub.3 NH.sub.4Sulfate SulfateSodium Lauryl Sodium Lauryl CH.sub.3 (CH.sub.2).sub.10 CH.sub.2 OSO.sub.3 NaSulfate SulfateAmido Betaine Coca-Betaine ##STR4##Amido Betaine Lauryl Betaine ##STR5##Amino AmineOxide Cocamidopro-pylamine oxide ##STR6##Polyoxyethylene Oleth-10 CH.sub.3 (CH.sub.2).sub.7 CHCH(CH.sub.2).sub.7 CH.sub.2 (OCH.sub.2 CH.sub.2).sub.n OHOleyl Ether where n has an average value of 10Polyoxyethylene PEG-25 A polyethylene glycol derivative of hydrogenatedFatty Glyceride Hydrogenated castor oil with an average of 25 moles of Castor Oil ethylene oxidePolyoxyethylene20 SorbitanMonolaurate Polysorbate 20 ##STR7##Polyoxyethylene20 SorbitanMonooleate Polysorbate 80 ##STR8##Sulfated ALFONIC .RTM. [CH.sub.3 (CH.sub.2).sub.x CH.sub.2 (OCH.sub.2 CH.sub.2).sub.n OSO.sub.3 ]MEthoxylated 1412-S where x has a value in the range of from 10 to 12,Alcohol 1412-A n has a value of 3 and M is ammonium or__________________________________________________________________________ sodium .sup.1 Cosmetic, Toiletry and Fragrance Association (CFTA) Cosmetic Ingredient Dictionary .sup.2 Conoco Chemicals Co., a Division of Continental Oil Company.

Generally, ethoxylated surface active agents give the best results and are preferred for use in accordance with this invention. The most preferred gelling agents for use in accordance with this invention are polyoxyethylene oleyl ether, polyoxyethylene 20 sorbitan monooleate, and polyoxyethylene fatty glyceride which increase in viscosity in the presence of water but reduce in viscosity in the presence of oil. Of these, polyoxyethylene oleyl ether is the most preferred.

In carrying out the methods of this invention, the surface active agent or agents utilized are injected into the formation or formations in which the flow of water is to be inhibited in a sufficient quantity. If the formation contains water, the surface active agent or agents react with the water to form a highly viscous gel which functions to plug the formation and inhibit the flow of water thereinto or therefrom. If the formation does not contain water, the injection of the surface active agent or agents can be followed by a quantity of water sufficient to react with the surface active agent or agents whereby a gel is formed. Generally, a water-surface active agent or agents mixture in the formation whereby water is present in an amount in the range of from about 50% by volume of the mixture to about 75% by volume of the mixture is required to form the highly viscous gel. Once formed, the gel will remain indefinitely in the formation so long as water is present therein. If it is desired to remove the gel from the formation, the formation can be treated with a strong acid or base, depending upon the particular gelling agent used to break the gel.

A variety of techniques can be utilized for injecting the gelling agent or agents used into a formation. A particularly convenient technique is to dilute the gelling agent or agents used with a quantity of water whereby the viscosity of the mixture is increased, but the mixture is still pumpable. The mixture is then displaced through the well bore and into the formation to be treated using conventional techniques with a pumpable fluid which is immiscible with water and in which the gelling agent or agents used are insoluble. Examples of such fluids are liquid hydrocarbons such as crude oil, diesel oil, kerosene, etc., liquid glycols and natural oils such as cottonseed oil.

In order to facilitate a clear understanding of the methods of the present invention the following examples are given.

EXAMPLE 1

In the laboratory, the viscosities of 100% ALFONIC.RTM. 1412-S surface active agent, a mixture of such surface active agent and synthetic sea water containing 25% by volume water, a mixture of such surface active agent and synthetic sea water containing 50% by volume water and a mixture of such surface active agent and synthetic sea water containing 75% by volume water are measured on a Brookfield Model LVT viscometer using the spindle and rpms given in Table I below at room temperature. The synthetic sea water used is as follows:

______________________________________Synthetic* Sea SaltComponent % By Weight______________________________________NaCl 58.490MgCl.6 H.sub.2 O 26.460NaSO.sub.4 9.750CaCl.sub.2 2.765KCl 1.645NaHCO.sub.3 .477KBr .238H.sub.3 BO.sub.4 .071SrCl.sub.2.6 H.sub.2 O .095NaF .007______________________________________ *Mixture composition based on ASTM D 114175, "Substitute Ocean Water." Five and onehalf ounces of "SEA SALT" is added to one gallon of deionized water. The results of these tests are given in Table I below.

The viscosity measurements given in Table I are apparent viscosities in units of consistency approximately equal to centipoises.

TABLE I__________________________________________________________________________VISCOSITIES OF VARIOUS ALFONIC .RTM. 1412-S - SYNTHETIC SEA WATERMIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentsSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 6 -- 4 60 300 3 60 40 3 6 1004 13 32,000 4 30 340 3 30 56 3 12 1004 1.5 49,600 4 12 550 3 12 90 3 20 1004 0.6 78,000 4 6 400 3 6 100 3 60 1004 0.3 116,000 3 6 440 3 12 360 3 30 280 3 60 310__________________________________________________________________________

From Table I it can be seen that ALFONIC.RTM. 1412-S surface active agent increases in viscosity with small amounts of water, but decreases in viscosity with higher amounts of water.

EXAMPLE 2

The procedure of Example 1 is repeated using ALFONIC.RTM. 1412-S surface active agent and various quantities of No. 1 Supre diesel oil instead of synthetic sea water. The results of these tests are given in Table II below.

TABLE II__________________________________________________________________________VISCOSITIES OF VARIOUS ALFONIC .RTM. 1412-S - DIESEL OIL MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume 50% by Volume 75% by VolumeDiesel Oil Diesel Oil Diesel Oil 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 1,038 3 60 60 3 60 30 3 60 1003 30 1,560 3 30 60 3 30 32 3 30 1003 12 2,750 3 12 60 3 12 50 3 12 1003 6 4,300 3 6 60 3 6 60 3 6 1003 3 6,8003 1.5 11,2003 0.6 20,0003 0.3 30,000__________________________________________________________________________

From Table II it can be seen that the surface active agent increases in viscosity when mixed with small amounts of diesel oil.

EXAMPLE 3

The procedure of Example 1 is repeated using Oleth-10 surface active agent and synthetic sea water. The results of these test are given in Table III below.

TABLE III__________________________________________________________________________VISCOSITIES OF VARIOUS OLETH-10 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 60 4,950 4 3 -- 4 60 520 3 60 1904 30 6,900 4 1.5 -- 4 30 600 3 30 1964 12 12,000 4 0.6 820,000 4 12 600 3 12 2004 6 19,000 4 0.3 1,200,000 4 6 600 3 6 180__________________________________________________________________________

From Table III it can be seen that Oleth-10 surfactant increases in viscosity greatly in the presence of synthetic sea water up to over 50% by volume water.

EXAMPLE 4

The procedure of Example 2 is repeated except that No. 1 Super diesel oil is substituted for the synthetic sea water. The results of these tests are given in Table IV below.

TABLE IV__________________________________________________________________________VISCOSITIES OF VARIOUS OLETH-10 - DIESEL OIL MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume 50% by Volume Diesel Oil andDiesel Oil Diesel Oil Synthetic Sea Water.sup.1 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 90 3 60 40 4 1.5 -- 3 60 2003 30 100 3 30 36 4 0.6 150,000 3 30 2003 12 100 3 12 40 4 0.3 200,000 3 12 2003 6 100 3 6 240 3 3 240 3 1.5 240__________________________________________________________________________ .sup.1 Surfactant combined with 1/3 by volume No. 1 Super diesel oil and 1/3 by volume synthetic sea water.

From Table IV it can be seen that Oleth-10 surfactant reduces in viscosity in the presence of oil. In the presence of a 50% mixture of diesel oil and synthetic sea water the viscosity increases, but such viscosity is appreciably lower than the viscosities shown in Table III for mixtures of Oleth-10 and sea water.

EXAMPLE 5

The procedure of Example 1 is repeated using Polysorbate 80 surface active agent and synthetic sea water. The results of these tests are shown in Table V below.

TABLE V__________________________________________________________________________VISCOSITIES OF VARIOUS POLYSORBATE 80 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 2,140 3 0.6 -- 4 6 120 3 60 5503 30 2,200 3 0.3 392,000 4 30 160 3 30 5603 12 2,200 4 0.3 490,000 3 60 60 3 12 5503 6 2,200 4 0.6 330,000 3 30 68 3 6 5003 3 2,400 4 1.5 196,000 3 12 603 1.5 2,200 4 3 135,000 3 6 603 0.6 4 6 --__________________________________________________________________________

From Table V it can be seen that Polysorbate 80 surfactant in the presence of sea water achieves high viscosity up to about 50% by volume of water.

EXAMPLE 6

The procedure of Example 5 is repeated except that No. 1 Super diesel oil is substituted for the synthetic sea water. The results of these tests are shown in Table VI below.

TABLE VI__________________________________________________________________________VISCOSITIES OF VARIOUS POLYSORBATE 80 - DIESEL OIL MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume 50% by Volume Diesel Oil andDiesel Oil Diesel Oil Synthetic Sea Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 136 3 60 22 3 60 400 3 60 5603 30 192 3 30 28 3 30 400 3 30 5603 12 300 3 12 20 3 12 430 3 12 5603 6 320 3 6 420 3 6 5203 3 400 3 3 440 3 3 520 3 1.5 400__________________________________________________________________________

From Table VI it can be seen that the viscosity of Polysorbate 80 reduces appreciably in the presence of oil as compared to the high viscosities attained in the presence of water.

EXAMPLE 7

The procedure of Example 1 is repeated using Polysorbate 20 surface active agent. The results of these tests are shown in Table VII below.

TABLE VII__________________________________________________________________________VISCOSITIES OF POLYSORBATE 20 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 390 3 60 120 3 60 22 3 60 4303 30 400 3 30 144 3 30 24 3 30 4403 12 400 3 12 150 3 12 20 3 12 4203 6 400 3 6 220 3 6 0 3 6 420__________________________________________________________________________

From Table VII it can be seen that Polysorbate 20 surface active agent does not increase in viscosity in the presence of synthetic sea water.

EXAMPLE 8

The procedure of Example 1 is repeated using PEG-25 hydrogenated castor oil surface active agent. The results of these tests are given in Table VIII below.

TABLE VIII__________________________________________________________________________VISCOSITIES OF PEG-25 HYDROGENATED CASTOR OIL - SYNTHETIC SEA WATERMIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 6 -- 4 60 8,500 3 60 24 3 60 --4 3 134,000 4 30 10,400 3 30 24 3 30 2,5404 1.5 208,000 4 12 12,500 3 12 20 3 12 2,8504 0.6 380,000 4 6 14,500 3 6 0 3 6 2,9004 0.3 550,000 4 3 14,000 4 1.5 26,000 4 0.6 41,000 4 0.3 60,000__________________________________________________________________________

From Table VII it can be seen that PEG-15 hydrogenated castor oil surface active agent increases in viscosity in the presence of synthetic sea water up to about 50% by volume sea water.

EXAMPLE 9

The procedure of Example 8 is repeated except that No. 1 Super diesel oil is substituted for the synthetic sea water. The results of these tests are given in Table IX below.

TABLE IX__________________________________________________________________________VISCOSITIES OF VARIOUS PEG-25 HYDROGENATED CASTOR OIL - DIESEL OILMIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume 50% by Volume Diesel Oil andDiesel Oil Diesel Oil Synthetic Sea Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 60 734 3 60 140 3 60 12 3 60 --3 30 740 3 30 160 3 30 12 3 30 2,6003 12 720 3 12 200 3 12 0 3 12 2,7003 6 700 3 6 340 3 6 2,8003 3 800 3 3 4003 1.5 560 3 1.5 400 3 1.5 2,5003 0.6 800 3 0.6 3,000 3 0.3 2,800__________________________________________________________________________

From Table IX it can be seen that PEG-25 hydrogenated castor oil surface active agent has reduced viscosity in the presence of oil as compared to the viscosities of the surfactant in the presence of synthetic sea water (Table VIII).

EXAMPLE 10

The procedure of Example 1 is repeated using ALFONIC.RTM. 1412-40 surface active agent. The results of these tests are given in Table X below.

TABLE X__________________________________________________________________________VISCOSITIES OF ALFONIC .RTM. 1412-40 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________5 0.3 64,000 5 0.3 168,000 3 3 Extremely High 3 3 --5 0.6 52,000 5 0.6 104,000 3 6 Extremely High 3 6 205 1.5 38,500 5 1.5 76,800 3 12 Extremely High 3 12 305 3 27,600 5 3 83,200 3 30 Extremely High 3 30 365 6 15,000 5 6 59,200 3 60 Extremely High 3 60 425 12 10,000 5 12 45,7005 30 5,400 5 30 29,0405 60 3,460__________________________________________________________________________

From Table X it can be seen that ALFONIC.RTM. 1412-40 surface active agent increases in viscosity in the presence of synthetic sea water.

EXAMPLE 11

The procedure of Example 1 is repeated using ALFONIC.RTM. 610-50 surface active agent. The results of these tests are given in Table XI below.

TABLE XI__________________________________________________________________________VISCOSITIES OF ALFONIC .RTM. 610-50 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 560 3 3 8,480 3 3 -- 3 3 --3 6 320 3 6 5,880 3 6 40 3 6 403 12 180 3 12 3,640 3 12 40 3 12 403 30 104 3 30 1,828 3 30 36 3 30 323 60 72 3 60 1,172 3 60 38 3 60 28__________________________________________________________________________

From Table XI it can be seen that ALFONIC.RTM. 610-50 surface active agent increases in viscosity in the presence of synthetic sea water up to about 50% by volume water.

EXAMPLE 12

The procedure of Example 1 is repeated using ALFONIC.RTM. 1012-60 surface active agent. The results of these tests are given in Table XII below.

TABLE XII__________________________________________________________________________VISCOSITIES OF ALFONIC .RTM. 1012-60 - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 120 3 3 840 3 3 2,600 3 3 403 6 100 3 6 380 3 6 2,000 3 6 803 12 70 3 12 310 3 12 1,600 3 12 603 30 68 3 30 160 3 30 1,628 3 30 563 60 78 3 60 148 3 60 1,714 3 60 54__________________________________________________________________________

From Table XII it can be seen that ALFONIC.RTM. 1012-60 surface active agent increases in viscosity in the presence of synthetic sea water.

EXAMPLE 13

The procedure of Example 1 is repeated using PEG-10 stearamine surface active agent. The results of these tests are given in Table XII below.

TABLE XIII__________________________________________________________________________VISCOSITIES OF PEG-10 STEARAMINE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 Extremely high 3 3 Extremely High 4 0.3 1,460,000 3 0.7 2803 6 Extremely High 3 6 Extremely High 4 0.6 922,000 3 1.4 2803 12 Extremely High 3 12 Extremely High 4 1.5 Extremely High 3 2.8 2803 30 Extremely High 3 30 Extremely High 3 6.4 2563 60 Extremely High 3 60 Extremely High 3 12.6 252__________________________________________________________________________

From Table XIII it can be seen that PEG-10 stearamine surface active agent increases greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 14

The procedure of Example 1 is repeated using PEG-10 oleate surface active agent. The results of these tests are given in Table XIV below.

TABLE XIV__________________________________________________________________________VISCOSITIES OF PEG-10 OLEATE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 4,080 4 3 43,600 3 3 4,440 3 3 2403 6 2,500 4 6 25,100 3 6 3,460 3 6 1803 12 1,590 4 12 14,000 3 12 3,090 3 12 1703 30 876 4 30 6,920 3 30 2,360 3 30 1523 60 584 4 60 4,340 3 60 1,592 3 60 154__________________________________________________________________________

From Table XIV it can be seen that PEG-10 oleate surface active agent increases greatly in viscosity in the presence of synthetic sea water up to about 50% by volume.

EXAMPLE 15

The procedure of Example 1 is repeated using PEG-5 cocamine surface active agent. The results of these tests are given in Table XV below.

TABLE XV__________________________________________________________________________VISCOSITIES OF PEG-5 COCAMINE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 -- 3 3 400 3 3 280 3 3 1603 6 40 3 6 380 3 6 300 3 6 1603 12 50 3 12 320 3 12 300 3 12 1603 30 52 3 30 304 3 30 264 3 30 1523 60 50 3 60 294 3 60 260 3 60 160__________________________________________________________________________

From Table XV it can be seen that PEG-5 cocamine surface active agent does not increase greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 16

The procedure of Example 1 is repeated using ammonium lauryl sulfate surface active agent. The results of these tests are given in Table XVI below.

TABLE XVI__________________________________________________________________________VISCOSITIES OF AMMONIUM LAURYL SULFATE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 80 3 3 300 3 3 680 3 3 8003 6 100 3 6 240 3 6 600 3 6 8003 12 80 3 12 230 3 12 540 3 12 7803 30 76 3 30 212 3 30 532 3 30 7763 60 80 3 60 210 3 60 526 3 60 786__________________________________________________________________________

From Table XVI it can be seen that ammonium lauryl sulfate surface active agent does not increase greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 17

The procedure of Example 1 is repeated using sodium lauryl sulfate surface active agent. The results of these tests are given in Table XVII below.

TABLE XVII__________________________________________________________________________VISCOSITIES OF SODIUM LAURYL SULFATE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________3 3 80 3 3 160 3 3 360 3 3 4003 6 80 3 6 120 3 6 320 3 6 3803 12 60 3 12 80 3 12 240 3 12 3403 30 48 3 30 60 3 30 236 3 30 3283 60 56 3 60 66 3 60 216 3 60 318__________________________________________________________________________

From Table XVII it can be seen that sodium lauryl sulfate surface active agent does not increase in viscosity in the presence of synthetic sea water.

EXAMPLE 18

The procedure of Example 1 is repeated using coca-betaine surface active agent. The results of these tests are given in Table XVIII below.

TABLE XVIII__________________________________________________________________________VISCOSITIES OF COCA-BETAINE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 3 -- 4 3 0 4 3 Extremely High 4 3 04 6 -- 4 6 100 4 6 Extremely High 4 6 1004 12 50 4 12 50 4 12 Extremely High 4 12 1004 30 40 4 30 60 4 30 Extremely High 4 30 804 60 30 4 60 50 4 60 Extremely High 4 60 60__________________________________________________________________________

From Table XVIII it can be seen that coca-betaine surface active agent increases greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 19

The procedure of Example 1 is repeated using a 50% by volume mixture of Oleth-10 and PEG-25 hydrogenated castor oil surface active agent. The results of these tests are given in Table XIX below.

TABLE XIX__________________________________________________________________________VISCOSITIES OF 50% BY VOLUME MIXTURE OF OLETH-10 AND PEG-25HYDROGENATED CASTOR OIL - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 3 440 4 3 22,000 4 3 290 4 12 04 6 350 4 6 Extremely High 4 6 190 4 30 604 12 120 4 12 Extremely High 4 12 120 4 60 70 4 30 Extremely High 4 30 70 4 60 50__________________________________________________________________________

From Table XIX it can be seen that a 50% by volume mixture of Oleth-10 and PEG-25 hydrogenated castor oil surface active agent increases greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 20

The procedure of Example 1 is repeated using a 50% by volume mixture of sodium lauryl sulfate and cocamidopropylamine oxide surface active agent. The results of these tests are given in Table XX below.

TABLE XX__________________________________________________________________________ VISCOSITIES OF A 50% BY VOLUME MIXTURE OF SODIUM LAURYL SULFATEAND COCAMIDOPROPYLAMINE OXIDE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 3 54,000 4 3 Extremely High 4 3 Extremely High 4 3 Extremely High4 6 35,000 4 6 Extremely High 4 6 Extremely High 4 6 Extremely High4 12 19,000 4 12 Extremely High 4 12 Extremely High 4 12 Extremely High4 30 8,000 4 30 Extremely High 4 30 Extremely High 4 30 Extremely High4 60 4,000 4 60 Extremely High 4 60 Extremely High 4 60 Extremely__________________________________________________________________________ High

From Table XX it can be seen that a 50% by volume mixture of sodium lauryl sulfate and cocamidopropylamine oxide surface active agent increases greatly in viscosity in the presence of synthetic sea water.

EXAMPLE 21

The procedure of Example 1 is repeated using a 50% by volume mixture of lauryl betaine and ammonium lauryl sulfate surface active agent. The results of these tests are given in Table XXI below.

TABLE XXI__________________________________________________________________________VIXCOSITIES OF A 50% BY VOLUME MIXTURE OF LAURYL BETAINE ANDAMMONIUM LAURYL SULFATE - SYNTHETIC SEA WATER MIXTURESMixture Containing Mixture Containing Mixture Containing25% by Volume Water 50% by Volume Water 75% by Volume Water 100% Surface Active AgentSpindle Viscosity, Spindle Viscosity, Spindle Viscosity, Spindle ViscosityNo. RPM cp No. RPM cp No. RPM cp No. RPM cp__________________________________________________________________________4 3 400 4 3 200 4 3 7,400 4 3 4,0004 6 400 4 6 200 4 6 4,700 4 6 3,2004 12 200 4 12 150 4 12 2,850 4 12 2,1004 30 100 4 30 120 4 30 1,540 4 30 2,6404 60 120 4 60 90 4 60 910 4 60 2,050__________________________________________________________________________

From Table XXI is can be seen that a 50% by volume mixture of lauryl betaine and ammonium lauryl sulfate surface active agent increases greatly in viscosity in the presence of synthetic sea water.

Claims

1. A method of reducing the water loss from an aqueous subterranean well formation treating fluid into a water permeable subterranean formation penetrated by a well bore comprising the steps of:

injecting a gelling agent into said formation having the property of forming a highly viscous gel in the presence of water;

and then introducing said aqueous treating fluid into said well bore whereby water therefrom and water contained in said water permeable subterranean formation forms a highly viscous gel with said gelling agent in said formation which reduces the flow of water thereinto;

wherein said gelling agent is selected from the group consisting of ethoxylated surface active agents and mixtures of such agents.

2. A method of reducing the water loss from an aqueous subterranean well formation treating fluid into a water permeable subterranean formation penetrated by a wellbore comprising the steps of:

injecting a gelling agent into said formation having the property of forming a highly viscous gel in the presence of water;

and then introducing said aqueous treating fluid into said wellbore whereby water therefrom and water contained in said water permeable subterranean formation forms a highly viscous gel with said gelling agent in said formation which reduces the flow of water thereinto;

wherein said gelling agent is a surface active agent selected from the group consisting of ethoxylated alcohols, ethoxylated aliphatics, amido betaines, polyoxyethylene oleyl ether, polyoxyethylene 20 sorbitan mono-oleate, and polyoxyethylene fatty glyceride, and mixtures of such agents.

3. The method of claim 1 wherein said gelling agent is polyoxyethylene oleyl ether.

4. The method of claim 1 wherein said gelling agent is a 50% by volume mixture of polyoxyethylene oleyl ether and polyoxyethylene fatty glyceride.