CA2093186C

CA2093186C - Squeeze cementing

Info

Publication number: CA2093186C
Application number: CA 2093186
Authority: CA
Inventors: Jeffrey A. Dahl; E. Dwyann Dalrymple; James R. Stanford
Original assignee: Halliburton Co
Current assignee: Halliburton Co
Priority date: 1992-04-03
Filing date: 1993-04-01
Publication date: 1996-12-31
Anticipated expiration: 2013-04-01
Also published as: AU3561293A; CA2093186A1; EP0564294B1; AU654431B2; US5238064A; DE69320857D1; EP0564294A1; DE69320857T2; MY132027A

Abstract

This invention relates to a method of terminating the undesirable flow of water from a highly permeable portion of a portion of or a fracture in a subterranean formation into a wellbore, which method involves the use of a hydraulic cement consisting of discrete particles having a particle size not greater than about 30 microns. The cement, which is utilized in a slurry of a hydrocarbon liquid and a surfactant, has a low density, good thixotropic properties and, in one embodiment, expansive characteristics.

Description

2093 ~ 86 50U~h~ CEMENTING

R~c~J~ound of the Invention 1. Field of the Invention This invention relates to wells used in the introduction of fluids into and the recovery of fluids from subterranean formations. It further relates to the use of hydraulic cement compositions to construct and repair such wells. This invention particularly relates to methods of using a very finely divided hydraulic cement composition to construct and repair such wells.

2. Problems Solved In the operation of wells used in the recovery of fluids from or the introduction of fluids into subterranean formations problems relating to the unwanted passage of fluids and/or fine solids into or from undesirable locations in the formation or wellbore sometimes occur. This unwanted passage of fluids and/or fine solids can severely disrupt or in fact terminate the desired operation of a well.
To be more specific, the problems involving unwanted passage of fluids, referred to above, ordinarily involve the movement of fluids, such as oil, gas or water through very small undesirable openings. These problems are not unique and the n ~

solutions have traditionally involved apparatus, methods and compositions adapted to cover, seal or to otherwise plug 2 2093t ~6 the openings to thereby terminate the unwanted passage of fluid through the opening. The openings referred to above include: holes or cracks in well casing; spaces such as holes, cracks, voids or channels in the cement sheath deposited in the annular space between the formation face and well casing; very small spaces - called microannuli - between the cement sheath, referred to above, and the exterior surface of the well casing or formation; and permeable spaces in gravel packs and formations.
It is clear that holes or cracks in well casing and/or cement sheath can permit the unwanted and therefore uncontrolled passage of fluid therethrough. Sometimes, of course, holes are deliberately made in casing and sheath by a known process called perforating in order to permit the controlled recovery of fluid from a formation or to permit the controlled introduction or injection of fluid into a formation. The sealing or plugging of such holes or cracks, whether or not made deliberately, has been conducted by attempts to place or otherwise force a substance into the hole or crack and permitting it to remain therein to thereby plug the opening.- Naturally, the substance will not plug the opening if it will not enter the opening. If the substance does not fit then, at best, a bridge, patch, or skin may be formed over the opening to produce, perhaps, a temporary termination of the unwanted fluid flow.
Substances used in methods to terminate the unwanted passage of fluids through holes or cracks in casing and/or ~093 1 ~6 sheath have been compositions comprised of hydraulic cement, wherein the methods employ hydraulic pressure to force a water slurry of the cement into the cracks and holes wherein the cement is permitted to harden. These methods are variously referred to in the art as squeeze cementing, squeezing or as squeeze jobs. The success of squeezing hydraulic cement into such holes and cracks is among other factors a function of the size of the hole relative to the particle size of the cement as well as the properties of the slurry. As mentioned earlier, if the particle size of the cement is greater than the crack width, the cement will not enter and at best a patch instead of a plug is the result. A problem therefore is to substantially reduce cement particle size without reducing the hardening and strength characteristics of hydraulic cement.
During the construction of a well it is known to place a volume of a water slurry of a hydraulic cement into the annular space between the walls of the borehole and the exterior of the casing wherein the cement is permitted to solidify to thereby form an annular sheath of hardened cement.
The objective of the sheath, the construction of which is referred to as primary cementing, includes physical support and positioning of the casing in the borehole and prevention of unwanted fluid (liquid and gas) migration between various formations penetrated by the wellbore. If, for some reason, the hardened sheath contains spaces such as voids, cracks or channels due to problems involved in the placement of the slurry it is clear that the sheath may not be capable of providing the desired objectives. Accordingly, by employing known techniques to locate the voids, channels or cracks, a perforation penetrating the spaces can be made in the casing and sheath and cement then squeezed into the spaces via the perforation so as to place the sheath in a more desirable condition for protecting and supporting the casing and providing fluid flow control. As mentioned earlier, the success of the squeeze job is at least a function of the size of the space or spaces to be filled relative to the particle size of the cement.
Another problem incidental to the formation of the cement sheath, referred to above, revolves about the occasional failure of the sheath to tightly bond to the exterior wall~of the casing or the interior of the borehole. This failure can produce a very thin annular space called a microannulus between the exterior wall of the casing and the sheath or the sheath and the borehole. For the reasons already discussed, it is important to place a substance, such as a hydraulic cement, in the microannulus to enable the sheath to fully provide the intended benefits. Again, as stated above, the success of squeezing cement into a microannulus space is dependent upon the relative size of the space and the particle size of the cement.
The solid portions of some producing formations are not sufficiently stable and therefore tend to break down into small pieces under the influence of the pressure difference between the formation and the wellbore. When fluid, such as - 2093~ 8~

oil or water, flows under the influence of the pressure difference from the formation to the wellbore the small pieces referred to above can be carried with the fluid into the wellbore. Over a period of time, these pieces can build up and eventually damage the well and associated equipment and terminate production. The art has solved this problem by placing in the wellbore a production aid which is referred to in the art as a gravel pack. A gravel pack is usually comprised of a mass of sand within the interior of a well.
The sand bed completely surrounds a length of tubular goods containing very narrow slots or small holes; such goods are sometimes referred to as slotted liners or sand screens. The slots or holes permit the flow of fluid therethrough but are too narrow to permit the passage of the sand. The slotted liner or sand screen can be connected through a packer situated up-hole of the gravel pack to production tubing extended from the wellhead. The gravel pack ordinarily consists of siliceous material having sand grains in the range of from about 10 to about 100 mesh.
The gravel pack, which can be situated in the casing in the perforated interval, traps the small pieces of formation material, for convenience herein referred to as formation fines or sand, which flows from the formation with the fluid through the perforations and into the gravel pack.
Accordingly, neither formation sand nor gravel pack sand penetrates the slotted tubing and only fluid is permitted to pass into the tubular goods.

2093 t 86 The above expedient performs nicely until undesired fluid begins to penetrate the gravel pack from the formation. At that point the flow of undesired fluid, such as water, must be terminated preferably in a way which will not necessitate removal of the gravel pack. This invention permits such an objective.
The problems referred to above uniformly deal with the unwanted passage of materials into or from very small undesirable openings in a well, including the cement sheath constructed during a primary cementing procedure. Solution of these problems, according to this invention, all involve a remedial or repair operation featuring the use of a very finely divided hydraulic cement. Still another problem involved in the construction and repair of wells involves the primary cementing procedure itself.
Primary cementing, as was described above, is conducted during the construction of a well and involves the placement of a volume of a slurry of a hydraulic cement in water into the annular space between the walls of the borehole and the exterior of primary casings such as conductor pipe, surface casing, and intermediate and production strings. The slurry is permitted to solidify in the annulus to form a sheath of hardened cement the purpose of which is to provide physical support and positioning of the casing in the borehole and to isolate various formations penetrated by the borehole one from-another.
A problem encountered during primary cementing is centered upon the weight (that is the density) of the slurry itself. In certain circumstances the hydrostatic pressure developed by a column of slurry overcomes the resistance offered by a formation in which case the formation fractures or otherwise breaks down with the result that a portion of the slurry enters the formation and the desired sheath is not formed. The formation breakdown thus occurs prior in time to development of sufficient rigidity or hardening of the cement to enable it to be self-supporting.
One solution has been to reduce the density of the slurry so that the pressure developed by the required slurry height will not exceed the ability of the formation to resist breakdown. This expedient can result in sheaths having physical deficiencies such as reduced strength or increased permeability or both. Another solution has been to reduce the weight of the slurry while maintaining density by reducing the quantity of slurry pumped in a single lift or stage to thus reduce the height of slurry. This expedient requires several separate stages in order to produce the required sheath length. Time must pass between stages in order to permit previous stages to develop strength sufficient to support the weight of succeeding stages. The time expended waiting on cement to set is lost time in the process of constructing the well.
The use of the finely divided hydraulic cement of this invention solves the primary cementing problems referred to above.

8 20931 ~6 Still another problem involved in the operation of wells which are the subject of this invention, revolves about the unwanted movement of water via cracks and fractures in the subterranean formation - whether naturally occurring or deliberately produced - from the formation into the wellbore.
Terminating this water movement may require remedial efforts other than those referred to previously which feature plugging perforations, holes, cracks and the like in casing, cement sheath and gravel packs - all of which occur within the confines of the well borehole itself.
The unwanted movement of water from cracks and fractures in the formation outside of the well borehole itself may be prevented by use of the hydraulic cement composition of this invention .
Disclosure of the Invention The solutions to the problems discussed above broadly relate: to remedial cementing operations conducted inside a wellbore; to remedial cementing operations conducted outside a wellbore in a subterranean formation; and to primary cementing operations conducted during construction of a well.
The solutions to these problems, according to this invention, basically feature the practice of well cementing methods long accepted for confronting and solving these problems with one substantial change. The substantial change in the methods comprises the uniform use in the accepted methods of a hydraulic cement, as defined below, consisting of discrete particles of cementitious material having diameters no larger 2û93 1 ~6 than about 30 microns, preferably no larger than about 17 microns, and still more preferably no larger than about 11 microns. The distribution of various sized particles within the cementitious material, i.e., the particle size distribution, features 90 percent of them having a diameter not greater than about 25 microns, preferably about 10 microns and still more preferably about 7 microns, 50 percent having a diameter not greater than about 10 microns, preferably about 6 microns and still more preferably about 4 microns and 20 percent of the particles having a diameter not greater than about 5 microns, preferably about 3 microns and still more preferably about 2 microns.
The particle size of hydraulic cement can also be indirectly expressed in terms of the sùrface area per unit weight of a given sample of material. This value, sometimes referred to as Blaine Fineness or as specific surface area, can be expressed in the units square centimeters per gram (cm2/gram) and is an indication of the ability of a cementitious material to chemically interact with other materials. Reactivity is believed to increase with increase in Blaine Fineness. The Blaine Fineness of the hydraulic cement used in the cementing methods of this invention is no less than about 6000 cm2/gram. The value is preferably greater than about 7000, more preferably about 10,000, and still more preferably greater than about 13,000 cm2/gram.
Cementitious materials of particle size and fineness as set out above are disclosed in various prior U.S. Patents including U.S. 4,761,183 to Clark, which is drawn to slag, as defined herein, and mixtures thereof with Portland cement, and U.S. 4,160,674 to Sawyer, which is drawn to Portland cement. The cementitious materials preferred for use in this invention are Portland cement and combinations thereof with slag wherein the quantity of Portland cement included in any mixture of Portland cement and slag used in the methods of this invention can be as low as 10 percent but is preferably no less than about 40 percent, more preferably about 60 percent, still more preferably about 80 percent and most preferably no less than about 100% Portland cement by weight of mixture.
Broadly, the invention relates to a method for terminating the flow of water from a portion of a subterranean formation into a wellbore said method comprising the steps of:
placing within said wellbore adjacent said portion a volume of a slurry of hydraulic cement, said volume being in an amount at least sufficient to saturate said portion;
permitting said volume to penetrate into said portion; and maintaining said slurry in said portion for a time sufficient to enable said slurry to form a rigid mass of cement in said portion;

B

- lOa -2093 1 ~6 wherein said slurry consists essentially of a mixture of said hydraulic cement, a hydrocarbon liquid and a liquid surfactant soluble in said hydrocarbon liquid, and water, the particle size of said hydraulic cement is not greater than about 30 microns, the Blaine Fineness of said hydraulic cement is no less than about 6000 cm2/gram, and said hydraulic cement is Portland cement or slag or mixtures thereof.
Some of the problems solved by this invention require the use of a cementitious material of very small particle size to enable passage thereof through very narrow openings and penetration thereof into low permeability gravel packs and formations.
To solve other problems described above, the material when slurried in water must exhibit a sufficiently low slurry density to enable use in situations requiring a light-weight cement which nevertheless develops satisfactory high compressive strength. In this regard the large surface area of the cement of this invention, i e , the Blaine Fineness, renders it more reactive than cements of lower Blaine Fineness; accordingly, quantities of water greater than quantities usually employed in well cementing operations may be employed to thereby - lOb -enable the formulation of slurries of low density and low viscosity without unsatisfactory loss in strength.

Thus, slurries useful herein can be formulated utilizing ratios of the weight of water per unit weight of cementitious material in the range of from about 0.5 to about 5.0, preferably from about 1.0 to about 1.75 and still more preferably from about 1.00 to about 1.5 pounds water per pound of cementitious material. Water to cement ratios in excess of about 1.75 and up to about 5.0 can be formulated for highly specialized applications requiring slurries of very low density and very low viscosity. It is noted, however, that slurries having such high water ratios tend to exhibit free water separation and excessive solids settling. Additives can be utilized to control free water separation and solids settling.
The slurry densities of the fine, i.e., low particle size, cements of this invention are lower than cements having usual particle sizes because of the high water ratios required to wet all of the surface area of the fine cement. The compressive strengths, however, of the set lower density slurries are satisfactory for both primary cementing and penetration cementing purposes especially in view of the greater reactivity of the fine cements. Also, and particularly in the case of slurries formulated at high water ratios, where penetration into very small holes, cracks and openings is the goal, water may indeed be eventually forced out of the fine penetrating particles to thereby deposit in the target crack, opening or porosity a dense, high-strength and highly water impermeable mass of set cement.

12 20931 ~6 Considering the range of water-to-cement ratios disclosed above, the slurries which can be formulated utilizing the fine cement of this invention have densities in the range of from about 9.4 to about 14.9, preferably from about 11.0 to about 12.5 and still more preferably in the range of from about 11.5 to about 12.5 pounds of slurry per gallon of slurry.
One particular advantage, in addition to the low slurry densities available herein, is that the high water ratios produce low heats of hydration. Thus, the fine particle size hydraulic cement of this invention is quite useful when conducting cementing operations, and particularly primary cementing operations, adjacent to structures which may undergo undesired physical breakdown in the presence of produced heat.
Examples of such structures include permafrost and gas hydrate zones.
Still another particular advantage accruing from using the fine particle size Portland cement of this invention is the observed unexpected expansion of the cement during setting. This expansion property can help prevent the formation of microannuli - when the cement is used in primary cementing operations - and can help the formation of very tightly fitting plugs - when the cement is used in squeeze cementing.
It is believed that this desirable expansive feature of the fine particle size Portland cement is due to the chemical content thereof and particularly to the high concentration of crystalline tricalcium aluminate (C3A) and sulfates present therein. See, for example, Table VII. It is thought that a Portland cement having a maximum particle size of about 11 microns, a Blaine Fineness of preferably greater than about 10,000 cm2/gram, a C3A crystalline content of preferably about 3.0 percent or more and a sulfate content of preferably about 1.0 percent or more will exhibit expansive characteristics desirable in an oil field cement.
Slurries of water and the fine particle size cement of this invention, as previously mentioned, are very useful to penetrate, fill and harden in fine holes, cracks and spaces such as might be expected to be found in well casing, cement sheaths, gravel packs and subterranean formations in the vicinity of a well bore. By way of example, it is believed that such slurries are useful to penetrate subterranean formations having effective permeabilities as low as about 3000 to about 5000 millidarcies. Accordingly, a condition known as water coning, in which water from a subterranean formation enters the wellbore in a rising or coning fashion, can be terminated by squeezing a slurry of fine particle size cement of this invention into formations producing such water, wherein the formations to be penetrated can have effective permeabilities as low as 3000 to 5000 millidarcies.
In addition, a water slurry of the fine particle size cement of this invention can be utilized to terminate the unwanted flow of water through a zone in a gravel pack. In this regard such a slurry can be formulated to permeate and set in a gravel pack consisting of a packed sand bed wherein 14 2~93 1 86 the sand in the pack has a particle size as low as 100 mesh (about 150 micron). Such a procedure can be utilized to plug channels in gravel packs created by flowing steam as well as by flowing water.
Still further, a water slurry of the fine particle size cement of this invention can be formulated to penetrate, plug and set in fine cracks in well pipe and in channels and microannulus spaces in and around the cement sheath wherein such fine cracks can be as narrow as about 0.05 millimeters (0.002 inches).
With regard to the above uses - but without being bound by the following slurry design aid - it is considered for commercial design purposes that a particle of given size in a suitable slurry as described herein can penetrate, fill and set in a crack, hole or void having a size of approximately 5 times greater than the size of the particle. Thus the 0.05 millimeter (50 micron) crack referred to above can be penetrated by a slurry of particles having a size of about 10 microns which is within the scope of the cement of this invention.
It was mentioned previously that the rate of hardening of the fine cement of this invention is related to the Blaine Fineness wherein the hardening rate increases as Blaine Fineness increases. In addition, the hardening rate is also related to the specific cementitious material being used and the temperature of the environment wherein the hardening reaction is proceeding. Thus fine particle size Portland -- 2093~ 86 cement, as hereinafter defined, hardens more rapidly in low temperature environments in the range of from about 30F to about 100F than does fine particle size slag cement, also as hereinafter defined. Also Portland cement hardens more rapidly at elevated temperatures than does slag cement.
Accordingly, to adjust to specific environments, specific slurries of fine cement can include mixtures of Portland cement and slag consistent with the concentrations previously disclosed. In general, longer set times can be achieved by increasing slag content with accompanying decrease in compressive strength and/or increasing slurry density or both.
In addition the usual well cementing additives can be combined with the cementitious materials of this invention to achieve the usual results. For example, to assist in the dispersion of individual cementitious particles in a slurry and thus to help prevent the formation of large particles by agglomeration or lumping a dispersing agent may be added to a water slurry of the cement of this invention in an amount effective to produce adequate dispersion. Such an effective amount is considered to include amounts up to about 1.5 parts by weight dispersant per 100 parts by weight of cementitious - 15a -material. One such dispersant is identified by the name CFR-3 and another by the name Halad-322 each of which is disclosed and claimed in U.S. Patent 4,557,763 to George, et al. In view of a principle object of this invention to provide a slurry of particles which will enter very small openings and still develop adequate compressive strength the use of a material to help assure particle dispersion is considered to be an important aspect of the invention.
Other additives commonly used in well cementing which may be utilized herein include defoaming agents, fluid loss additives, lost circulation additives, expansion additives, hardening accelerators (although, not normally required) and hardening retarders which may be particularly useful when high temperature environments are encountered. Portland cements having the small particle sizes required in this invention may require retardation of set time at elevated temperatures.
Accordingly, conventional lignosulfonates are considered to be useful to achieve sufficient retardation. Still other additives may be utilized to still further decrease the slurry density of the cement composition of this invention. Such lightweight additives include nitrogen, perlite, fly ash, silica fume, microspheres and the like. It is believed that a combination of fine particle size cement, water and additives can produce a competent slurry having a density of as low as about 9 pounds per gallon which will achieve compressive strength sufficient for oil field operations.
When well cementing environments exhibit high temperatures, e.g. about 230F or more, it may be necessary to combine with the slurry a material which wilL help prevent the loss of compressive strength of set cement over time - a condition referred to as compressive strength retrogression.
In one specific embodiment, a cement placed in a cased hole 17 2093 ~ ~6 adjacent a geothermal formation or a formation into which steam will be introduced can be subjected to temperatures of up to about 600F. Such extremely high temperatures can produce a loss in compressive strength of set cement; however, by using the fine particle size, preferably Portland, cement of this invention in combination with Silica Flour, a crystalline form of silicon dioxide (SiO2), compressive strength retrogression can be prevented or at least reduced in magnitude. This material is added to the slurry in an amount effective to react with the hydraulic cement to help prevent the development of compressive strength retrogression. It is believed that such an effective amount is in the range of from about 0.15 to about 1.0 and preferably about 0.35 pounds silica flour per pound of hydraulic cement.
Still another advantage of this invention in addition to light weight slurries, low viscosity, good compressive strength, and small particle size are the thixotropic properties displayed by the slurry. Accordingly, with a slurry preferably consisting solely of small particle size Portland cement used in primary cementing operations, the thixotropic properties help prevent unwanted fluid migration, especially unwanted gas migration, during the time when the cement is in an unset plastic condition.
Subterranean formations sometimes produce unwanted water from natural fractures as well as from fractures produced by forces applied deliberately or accidentally during production operations. It is known that such fractures provide a path of least resistance to the flow of fluid from a formation to a wellbore. When the fluid flowing in a fracture is primarily oil, the fracture is considered to be beneficial and thus desirable; however, when the fluid flowing in the fracture from the formation to the wellbore is primarily water the fracture is considered to be a problem and thus undesirable.
By the method of this invention the undesirable fracture can be filled with fine cement to plug it and thereby terminate the flow of fluid therein.
The fine particle size cement of this invention can be placed into a subterranean fracture as well as into a high permeability zone of the formation by the application of conventional procedures. The cement itself, although it is highly reactive due to its small particle size, can be rendered temporarily non-reactive by preventing contact between it and water prior in time to actual placement of the cement into the fracture. Accordingly the fine cement of this invention is dispersed in a relatively low viscosity, relatively non-volatile liquid hydrocarbon, such as diesel oil, to form a pumpable slurry of cement in oil. (See U.S.
Patent 4,126,003 to Tomic).
The dispersion of the cement in the non-volatile liquid hydrocarbon must be assisted by use of an appropriate surfactant, which is hereinafter more fully described. In this regard it has been discovered that a mixture of the fine-cement of this invention with the liquid hydrocarbon, in the absence of a surfactant, produces a blend having a viscosity 19 2093l~
so high that the blend cannot be pumped by conventional means into the desired location in the formation. Use of the surfactant, as described below, results in a blend of cement in hydrocarbon having a sufficiently low viscosity to permit convenient conventional introduction of the blend into the desired location in the formation.
Furthermore, it has also been discovered that the high beneficial hydraulic activity of the fine particle size cement of this invention can be unduly reduced upon contact with a hydrocarbon, but that the problem can be avoided by use of the hereinafter further described surfactant.
Thus, the use of a surfactant is necessary to enable the production of a cement in hydrocarbon slurry having a sufficiently low viscosity to permit convenient placement in the desired zone, and to prevent the liquid hydrocarbon carrier from oil wetting the surface of the small particle size cement because such oil wetting would cause the fine cement to suffer a loss of hydraulic activity.
The slurry is then introduced into the fracture.
After the slurry of cement and oil is in the fracture, water flowing in the fracture slowly contacts the cement to thereby render the cement reactive so as to initiate hydration, hardening and ultimate formation of a permanent plug in the fracture. By this technique the cement in the hydrocarbon/surfactant/cement slurry will only set when contacted by water in the fracture and thus will not set if the slurry enters a fracture containing oil. Accordingly, oil Z~931 ~6 producing portions of a reservoir will remain relatively damage free.
As mentioned above, successful formulation of a cement in hydrocarbon oil slurry to obtain the goals set out above depends upon sufficient dispersion of the cement in the oil.
In this regard, such a dispersion is obtained by combining a hydrocarbon liquid, such as diesel oil, a soluble hydrocarbon liquid surfactant, as hereinafter defined, and the fine particle size cement of this invention. The preferred order of blending of the ingredients involves adding the correct quantity of surfactant to the hydrocarbon liquid with thorough mixing and then slowly adding the cement to the oil/surfactant blend with continued mixing to obtain the desired slurry~of uniform consistency.
The surfactant useful herein which is a solution consisting of an aromatic sulfonic acid or a salt thereof dissolved in a low molecular weight alcohol, is mixed with a hydrocarbon liquid, such as diesel oil, in an amount in the range of from about 10 to about 25 and preferably about 20 gallons of surfactant solution per 1000 gallons of hydrocarbon liquid. The quantity of hydrocarbon liquid to be utilized is dependent upon the quantity of fine particle size cement employed and is in the range of from about 6 to about 10 gallons of hydrocarbon liquid per 100 pounds of fine cement.
The amount of hydrocarbon liquid and surfactant utilized, within the scope of the above proportions, will determine the density of the resulting cement/hydrocarbon slurry wherein the slurry density is inversely proportional to the quantity of liquid. Accordingly, 4400 pounds of fine cement, 5.5 gallons of a preferred surfactant and 275 gallons of diesel will produce a slurry having a density of about 14.1 pounds per gallon while 4400 pounds of fine cement, 8.0 gallons of surfactant and 400 gallons of diesel will produce a slurry having a density of about 12.5 pounds per gallon.
The low viscosity, non-volatile hydrocarbon liquid useful herein can be an aliphatic compound, such as hexane, heptane or octane, an aromatic compound such as benzene, toluene or xylene and mixtures thereof such as kerosene, diesel oil, mineral oil and lubricating oil.
As mentioned previously, the surfactant includes, as an essential component, an aromatic sulfonic acid or a salt thereof. This component is sometimes rèferred to herein as the organic acid or salt component. The organic acid component is a compound identified by the formulas:

R~ ~ - OH~ (1) and R3 ~ - OH (2) I
O

~2 22 ~93 1 ~6 wherein Rl is selected from linear alkyl groups having 12 carbon atoms or 16 to 24 carbon atoms and R2 and R3 are linear alkyl groups containing 12 carbon atoms.
Compounds within the scope of formulas (1) and (2) known to be useful herein are the acids themselves as well as the alkaline earth metal salts thereof. The preferred such salts are the calcium salts and the magnesium salts.
The preferred organic acid component of the surfactant of this invention is selected from the group consisting of calcium dodecylbenzene sulfonate, calcium didodecylbenzene sulfonate and calcium salts of benzenesulfonic acid having linear alkyl groups containing 16 to 24 carbon atoms. The most preferred is calcium dodecylbenzene sulfonate.
In a broader context the organic acid component is thought to include linear alkyl aromatic sulfonic acid, linear alkyl aromatic phosphonic acid, linear alkyl aromatic sulfonates and linear alkyl aromatic phosphonates having at least one linear alkyl group containing at least eight carbon atoms.
The low molecular weight alcohol solvent component of the surfactant solution is selected from aliphatic alcohols having in the range of from 1 to 5 carbon atoms wherein isopropanol is preferred.
The alcohol is present in the surfactant in the range of from about 20 to about 40 and preferably about 25 parts-alcohol per 100 parts by volume of the surfactant solution.
The organic acid or salt component of the surfactant 23 ~93 1 ~6 solution is present in the surfactant in the range of from about 60 to about 80 and preferably about 75 parts acid or salt per 100 parts by volume of the surfactant solution.
The surfactants known to be useful herein were identified by means of the following scree~ning tests. The test results are provided in Table A, below.
Evaluation procedure for screening surfactants:
Slurries were prepared by mixing 50 grams of small particle size cement that had been vacuum oven~dried with a solution of 25 ml of water-free kerosene and 0.5 ml of a compound as shown in Table A. Solubility of the compound in the kerosene was noted and the dispersibility of the cement in the solution was observed and recorded. To this slurry was added 2.5 ml of fresh water. The slurry was then shaken vigorously for 2 minutes. At this time, the slurry was checked for pourability and pumpability and the results recorded. If applicable, the samples were checked again at 1 hour to determine gel strength attainment.
Those compounds which were not soluble in the kerosene and were neither a free acid nor a calcium or magnesium salt were washed with both a 10% CaCl2 and a 50% CaCl2 solution through a separatory funnel in order to produce calcium salts.

24 20~1 86 Table A
Compound Soluble Dispersibility Remains Set (Calcium In Pourable After salts) Kerosene After 2 1 Hour Minutes Dinonyl- passed passed failed N/A
naphthalene sulfonic acid Dodecyl passed passed passed passed benzene sulfonate Dodecyl failed N/A N/A N/A
ether ethoxylate sulfonate Aliphatic passed failed N/A N/A
Phosphate Ester Amine salt of failed N/A N/A N/A
naphthalene sulfonate diethyl failed N/A N/A N/A
naphthalene sulfonate Ammonium failed N/A N/A N/A
xylene sulfonate oleic acid passed passed passed never set and linoleic acid 20931 ~6 Table A (Continued) Compound Soluble Dispersibility Remains Set (Calcium In Pourable After salts) Kerosene After 2 1 Hour Minutes Octyl and failed N/A N/A N/A
dioctyl phosphonate Sodium failed N/A N/A N/A
lauryl sulfonate Sodium failed N/A N/A N/A
alkylsulfate Magnesium passed passed failed N/A
sulfonate Calcium passed failed N/A N/A
sulfonate benzene passed passed failed N/A
sulfonic acid salt of passed passed failed N/A
sulfonic acid Overbased passed passed failed N/A
magnesium sulfonate Benzene passed passed passed passed sulfonic acid, Cl6 -C~ alkyl-derivatives Amine salt of passed passed failed N/A
dinonyl naphthalene sulfonate Didodecyl passed passed passed passed benzene sulfonate 2093 1 ~6 Table A (Continued) Compound Soluble Dispersibility Remains Set (Calcium In Pourable After salts) Kerosene After 2 1 Hour Minutes phosphoric failed N/A N/A N/A
acid Sulfate failed N/A N/A N/A
lauryl sulfate No compound N/A passed passed did not set in 72 hours The tables which follow provide information and data concerning the chemical, physical and performance properties of four hydraulic cements. Three of the cements are Portland cements and the fourth is a slag cement. One of the cements, identified as API Class A, due to particle size only, is not within the scope of this invention. The remaining three cements are within the scope of this invention.
Tables I and II provide physical data including specific surface, specific gravity, blending, and particle size analysis.
Tables III and IV provide performance data including compressive strength developed by stated slurries and penetration by stated slurries.
Tables V, VI, VII and VIII provide chemical content as determined by various different analysis techniques.
Table IX provides a chemical analysis of Portland type III cement as disclosed in U.S. Patent 4,160,674 to Sawyer.

20931 ~6 TABLE I
Comparison of Cements Specific Specific Slag Hydraulic Surface Gravity aOntent Cement Blaine, cm2/, g/cc Weight Name Type %
Ultra Fine Portland 13080 3.03 0 API
Class A Portland 3900 3.15 0 White Portland 6460 3.03 0 MC-500 SLAG/Portland 8960 2.95 80 to 90 -28- 2093 t ~6 N t`
-- 'D O ~Ul N l l I

I I I I N
N
O ~1 N ~ N
.~ rl N

U) I I

N

U~
O U~
~.~ C~ N1`~0 U~
~r o O I I I
~D
O
N
N ~ O
r ~,, ; 8 O~ I , I ,0 .~,I t ~`
O ~o O N
_ N o "~ O
_l O O
., I I I ~ ~

l~ ~ O

O O
N

~ O
O I ~ I
O

I ~ I I

~ N ~I
r C ~

U Z D ~ ~ 3 U

TABLE III
Comparison of Properties of Water Slurriee of Hydraulic Cement~3 Hydraulic 1500 p8i Compressive Strength 2505 p8i Compre~sive Strength CementAfter 24 hours Set @ 80F After 24 hour~3 Set @ 80F
Name Type lb Cement lb Water Den~ity, lb/gal lb Cement lb Water Density, lb/gal Ultra Fine Portland 1.00 1.00 12.5 1.00 1.41 11.5 API
Class A Portland1.00~ 0.576 14.7 1. oo4 O. 99 12.3 White Portland1 002 0.80 13.2 1.00 1.17 12.0 MC-S00 SLAG/Portland 3 3 _ 3 1.00 1.00 12.5 Notes:
~ 0.02 lb Bentonite, 0.01 lb Calcium Chloride O
2 0 . 01 lb CFR-3 Di~persant 3 For practical commercial usage~ a slurry of ~ufficiently high den~ity cannot be made to p~roduce the indicated compre~3ive strength 4 0.39 lb Amorphoun Silica, 0.39 lb Pozmix, 0.01 lb Calcium Chloride 5 The Texas Railroad Commission requirement for primary cementing of surface casing -30- 2093 l ~6 o o.~", o o o ~:N o~ I~ N
~" N
.. ~
O--I r' N N c-- O --3 ~ a~
~U--~~O O o ~U ' ~d 3 3 ~ o ~ 3 ~ -~1 o - c 3 o~ n J ~
O O O O , u ~, . ~, ~ a~ ~ '' .a o o o o O ~ U ~
I I I ~r `~

O ~ o o C ~ U C U
~ ~ r o ~ u~ N ~ O C

O ~ O P' O ._ " ~ a~ ~, ~ O ~U
~U
- O ~ ~UN N N N ~U ~U

~ ~ 3 GN ~ c ' - I r. rO ~ U ~ r .-~
~ ~ ~ O r .~ u r~
~c ~ ,a ~ ~ ~ ù
--I ~ --~ ~ _ ,..... . I ~u ~ u :~ O o o ~ o E~ w . .,~

o U o ~n ~u ~U ~ ~ ~ U1 ~ ~
e ~ o ~ ~ l~, I c~ o z r ~ z ~ ~ 3 z TABLE V
X-ray Fluorescence Analysis of Hydraulic Cement Material Oxide Hydraulic Cement Name Cc ,-r^nts Percent API
MC-500Ultra FineClass A White Na2O 0.30 0.17 0.37 0.37 MgO 3.40 1.10 1.30 2.40 Al2O3 11.29 4.26 4.32 4.01 SiO2 29.54 17.80 20.86 21.08 S03 2.15 7.85 2.98 3.40 K2O 0.41 0.95 0.93 0.27 CaO 50.79 62.12 65.29 ~ 65.64 TiO2 0.49 0.18 0.23 0.12 Cr203 0.0 0.0 0.0 0.0 MnO 0.38 0.03 0.03 0.02 Fe~3 1.16 2.30 2.35 0.29 ZnO 0.01 0.01 0.02 0.01 SrO 0.08 0.11 0.07 0.04 Loss On 0.0 3.12 1.25 2.35 Ignition TABLE VI
Cement Compound Concentration, Percent C _und By Bogue Calculation From Oxide Components in Table V

API
MC-500Ultra Fine Class A White Free Lime 0.4 0.7 0.58 3.67 C3S * 62.56 64.89 55.58 C2S * 5.47 11.6 19.96 C3A * 7.63 7.57 10.39 C4AF * 7.22 7.23 0.89 CaSO4 (CS) * 13.78 5.12 5.92 *Cannot Calculate due to excess of Al and Si TABLE VII
Quantitative X-Ray Diffraction Analysis Hydraulic Cement Materials Extract Crystalline HYdraulic Cement Name Component Compound MC-500 API White % Ultra Fine Class A %
% %
Silicates * 74.0 79.9 81.7 C3S * 41.5 52.0 55.6 C.S * 32.5 27.9 26.1 Sulfates * 10.6 4.6 4.8 CaSO~2H~O * 4.7 0.4 1.9 CaSOJ1/2H.O * 2.5 1.6 3.4 Syngenite * 3.4 2.6 Alumino Ferrites *15.4 15.5 13.5 ClAI * 7.7 4.6 8.5 w C~A~ * 1.1 2.8 4.0 C~AF * 6.4 7.8 Periclase * 0.1 0.2 0.8 Dolomite * 0.1 0.1 Quartz * - - O.2 o ~) *Compounds`ar~e`primarily non-Crystalline and therefore cannot be ,.y, ; necl quantitativelY CO
~ Cubic Crystalline form C~
2 Orthorhombic Crystalline form TABLE VI ~ I

MiscelLaneous Infor~ation Hydraul ic Cement Name, Percent Measurement MC-500 Ultra-Flne ~PI Class A WE~ite Insolu~le Resid~e 0 . 24 0~ Og 0.16 0. 41 Total Alkali 0. 57 ~.80 û. 98 o. 55 ~otal HzO Sol . Alkali 0. 5F, 0. 05 0. 43 0. 17 I}if ferential Therm~l AnalYsis ~;ypsum 0.~ 5.44 0.30 0.85 Hemihydra~e 1. 04 0 . 4 4 0 .17 o . BB p, 2093 ~ ~

Referring now to Tables I, II, III, IV, V, VI,VII, and VIII set out above, there is presented, in convenient tabular form, a comparison of various properties of four different cementitious materials each of which exhibit hydraulic activity. "Hydraulic activity" and "reactivity" as used herein mean the chemical nature of a material to set and harden, upon being mixed with water, without contact with the atmosphere (e.g. the ability to harden under water) due to the interaction of the constituents of the material rather than by evaporation of the water. The term "hydraulic cement" as used herein means all inorganic cementitious materials of known type which comprise compounds of calcium, aluminum, silicon, oxygen and/or sulfur which exhibit "hydraulic activity", that is, which set solid and harden in the presence of water.
Cements of this type include common Portland cements, fast setting or extra fast setting, sulfate resistant cements, modified cements, alumina cements, high alumina cements, calcium aluminate cements, and cements which contain secondary components such as fly ash, pozzalona and the like. See for example Roca, et al., U.S. 4,681,634. There are in existence inorganic cementitious materials other than those exemplified in Tables I - VIII which exhibit hydraulic activity, but this invention is preferably limited to the types included in Tables I - VIII.
Accordingly, Portland cement, one of the materials listed in the Tables is made by sintering (thermally treating) a ground mixture of raw materials one of which is usually 2 0 9 3 1 ~ 6 composed mainly of calcium carbonate (as limestone) and another of which is usually composed mainly of aluminum silicates (as clay or shale) to obtain a mixture of lime, aluminum oxide, silicon dioxide and ferric oxide. During the sintering process chemical reactions occur which produce nodules, called clinkers, which are primarily composed of mixed calcium silicates (C2S and C3S), calcium aluminates (C3A) and calcium aluminoferrites (C4AF) all of which compounds contribute to the hydraulic activity of Portland cement. See for example Braunauer, U.S. 3,689,294; Buchet, et al., U.S.
4,054,460; and Gartner, U.S. 4,619,702. An example of a chemical analysis of Portland cement clinker is provided by Skvàra, U.S. 4,551,176 as follows:
Component Weight Percent SiO2 20 - 21.9 CaO 62.2 - 67.3 Al2O3 4-7 6.3 Fe2O3 2.4 - 4.5 MgO 1.3 - 3.3 S03 0.16 - 1.05 Na2O + K2O 0.81 - 0.95 After sintering, the clinkers are ground together with additives, including for example a quantity of calcium sulfate dihydrate (gypsum) to control set time, to a specific surface area, sometimes called Blaine Fineness, of as high as 10,000 cm2/gram or more, but ordinarily the grinding is sufficient to produce a specific surface area in the range of from about -36- 20931 ~6 2500 to 5000 cm2/gram with 3000 to 4500 cm2/gram being the usual Blaine Fineness range for Portland cement. See for example Gartner, U.S. 4,619,702; Miyoshi, et al., U.S.
4,443,260; Buchet, et al., U.S. 4,054,460; and Braunauer, U.S.
3,689,294.
Portland cements are classified by the American Society of Testing Materials (ASTM) into five major types identified by Roman Numerals I, II, III, IV and V and by the American Petroleum Institute into at least 9 categories identified by the letters A, B, C, D, E, F, G, H and J. The classifications are based on chemical composition and physical properties.
Sawyer in U.S. 4,160,674 specifically discloses a Type III Portland cement exhibiting high early compressive strength wherein: substantially all particles in the cement are of a size of about 20 microns and smaller; the Blaine Fineness is about 8990 cm2/gram; and the specific gravity is 3.00. Sawyer provides an analysis of the Type III material, which is preferred to as the "fine product". The analysis is set out in Table IX below.

_37_ 20 93 ~ ~6 Table IX
Chemical Analysis-Fine Product Compound Composition SiO2 19.61 C3S 46.58 Al2O3 4 93 C2S 21.10 Fe2O3 2.50 C3A 8.83 CaO 61.26 C4AF 7.61 MgO 1.42 CaSO4 10.18 SO3 5.99 Loss 3.12 Total 98.83 Lime Factor 2.45 Silica Ratio 2.64 .
A/F 1.97 .
Insol Residue 0.53 Free CaO 1.26 Na2O 0.11 K2O 1.06 Total alk. 0.81 Galer, et al., in U.S. 4,350,533 provides abbreviations for chemical formulas of cement compounds in accordance with general practice in the cement industry as follows:
C represents calcium oxide (CaO) A represents aluminum oxide (Al2O
F represents ferric oxide (Fe2O3) M represents magnesium oxide (MgO) S represents silicon dioxide tsio2) _3~_ 2093 1 86 K represents potassium oxide (K20) N represents sodium oxide (Na20) H represents water (H20) S represents sulfur trioxide (S03) C represents carbon dioxide (CO2) Accordingly, based upon the above abbreviations the chemical composition of the Type III Portland cement disclosed by Sawyer (Table IX above) is:
C3S : 3CaO SiO2 46.58 C2S : 2CaO SiO2 21.10 C3A : 3CaO Al203 8.83 C4AF : 4CaO Al203Fe203 7.61 CS : CaS04 10.18 Tables I - VIII also include a hydraulic cement material identified as "Slag/Portland" which is a combination of Portland cement and slag.
"Slag", as used herein, means a granulated, blast-furnace, by-product formed in the production of cast iron and is broadly comprised of the oxidized impurities found in iron ore.
During the operation of a blast furnace to remove iron from iron ore a molten waste product is formed. By preventing this molten product from crystallizing, and thereby losing its energy of crystallization, a super-cooled liquid or non-crystalline glassy material can be formed thus retaining the energy of crystallization. This non-crystalline, glassy material, which has also been described as a vitreous - 2093 1 ~6 substance free from crystalline substances as determined by X-ray diffraction analysis, is said to be capable of exhibiting hydraulic activity upon being reduced in size by grinding from a particle size of 1 to 5 millimeters to a fine particle size in the range of from about l to about 100 microns. Many commentators, including Clarke in U.S. 4,761,183 and Forss in U.S. 4,306,912, state that the glass content of the material, in order to exhibit latent hydraulic activity, must be high and preferably above about 95 percent.
Crystallization of the molten blast-furnace waste product can be prevented and the super cooled liquid or glass can be formed by rapidly chilling the molten waste. This rapid chilling can be effected by spraying the molten waste with streams of water which operation causes rapid solidification and formation of a water slurry of small, glassy, sand-like particles. The slurry is then thermally dried to remove substantially all moisture to thereby produce a dry blend of coarse particles. This dry blend of particles, having a particle size in the range of 1 to 5 millimeters, is then ground to reduce particle size to values in the range of from 1 to about 100 microns and preferably less than about 325 mesh ( 45 microns) to produce the granulated, blast-furnace by-product herein defined as "Slag". See, for example, Miyoshi, et al., U.S. 4,443,260; Allemand, et al., U.S. 3,809,665;
Buchet, et al., U.S. 4,054,460; Gee, et al., U.S.
4,242,142; Clarke, U.S. 4,761,183; and Forss, U.S. 4,306,912.
Clarke '183 and Miyoshi, et al., in U.S. 4,306,910 2093 1 ~6 disclose the following analysis, said by them to be representative of the usual ranges of chemical content of slag.
Weiqht Per Cent Component Clarke Miyoshi SiO2 30 - 40 30 - 35 Al203 8 - 18 13 - 18 Fe203 ~ 0.5 - 1.0 CaO 35 - 50 38 - 45 MgO 0 - 15 3 - 6 FeO 0 - 1 S 0 - 2 0.5 - 1.0 Mn203 0 - 2 MnO - 0.5 - 1.5 Tio2 0 0.5 - 1.0 Clarke further states that the density of slag is considered to be 2.92 grams per cubic centimeter.
Another analysis of slag is provided by Yamaguchi, et al., in U.S. 3,904,568 as follows:
Component Weight Per Cent Sio2 34.9 Al203 + Fe203 16.8 CaO - 41.}
MgO 5.5 Miyoshi, et al., '910 state that the hydraulic activity of slag is low if the particle size of the slag is in the 2~93 t ~6 range of 1 to 5 millimeters and accordingly, suggest that the particle size of slag should be reduced by grinding to a value of at least about 5 microns or less; and still further state that the slag, by itself, even after grinding has no or very low hydraulic activity and thus requires activation or stimulation such as by the addition thereto of slaked lime (CaO H2O). Other additives to stimulate or activate the hydraulic activity of Slag include sodium hydroxide, sodium sulfate, sodium carbonate, sodium silicate, potassium sulfate and Portland cement. See for example Clarke, U.S. 4,761,183 and Clarke, U.S. 4,897,119.
According to Forss in U.S. 4,306,912 grinding slag to a high specific surface, e.g. in the range of from about 4000 to about 8000 cm2/gram, can increase the hydraulic activity and hardening rate of the material. Forss also states that it is known that grinding cement clinker beyond a certain limit is not beneficial because additional fineness hardly improves the properties of hardening and strength. On the other hand Birchall, et al., in U.S. 4,353,747 state that the strength of Portland cement can be improved by reducing the weight average mean particle size of Portland cement to a value of less than 20 microns.
The various methods for conducting cementing operations normally associated with wells in subterranean hydrocarbon producing formations are generally known. These basic techniques with changes, as required, can be employed to place the fine particle size cement of this invention in position to -~2- 20931 86 solve the various problems addressed herein.
The techniques which can be used herein are set out below in outline format.
Procedure I, "Method for Placing Cement in a Microannulus,"
Procedure II, "Method for Placing Cement in Voids, Cracks and Channels in the Cement Sheath,"
Procedure III, "Method for Plugging Cracks and Perforations in Casing,"
Procedure IV, "Alternate Method for Repair of Cracks in Casing," and Procedure V, "Method for Terminating Water Flow Through a Gravel Pack and the Matrix of a Subterranean Formation" can be employed to perform remedial cementing operations within a wellbore.
Procedure VI, "Method for Terminating the Flow of Water from a Zone in a Subterranean Formation" can be employed to perform remedial cementing operations outside of a wellbore in the formation.
Procedure VII, "Method for Using Ultra Fine Cement in Primary Cementing Operations," can be employed to perform primary cementing.
Procedure I
Method For Placing cement in a Microannulus 1. Determine the location, size and upper and lowermost linear limits of the microannulus relative to the axis of the wellbore. This determination may be accomplished by use of a ~~ _43_ 2 0 ~ 3 1 ~ 6 conventional cement bond log procedure.
2. BLOCK SQUEEZE TECHNIQUE
a. Perforate the well casing so as to intersect the microannulus at its lowest point relative to the wellhead.
b. Isolate the perforation by placing a bridge plug in the casing below the perforation and a packer in the casing above the perforation to thereby define a space within the casing between the bridge plug and packer which is in communication with the microannulus via the perforation; establish communication with the wellhead via tubing from the wellhead to the packer.
c. Introduce an acid solution into the microannulus via tubing from the wellhead to the packer, the defined space and the perforation. The purpose of the acid, which can be a 15%
hydrochloric acid solution, is to prepare the perforation and microannulus for cementing.
d. Introduce water into the microannulus via the tubing and perforation to establish an injection rate.
e. Introduce a water slurry of the cement composition of the invention into the microannulus.
The slurry must be of sufficient volume to form a plug in the entire lower portion of the 20~3 1 ~6 microannulus to prevent passage of fluid therethrough. Introduction of the slurry must be effected at a pressure less than the pressure required to fracture the formation.
f. Remove excess slurry from tubular goods and casing.
g. Shut well in, preferably under pressure, to permit the cement to harden.
h. Remove the tubing, the packer and the bridge plug from the well and perforate the well casing so as to intersect the microannulus at its uppermost point relative to the wellhead.
i. Repeat steps "b" through "g" with respect to the perforation made in step "h".
The block squeeze method described in steps 2a - 2i thus produces water blocks at the extreme linear limits of a microannulus but does not completely fill the microannulus with cement.
The use of acid, as described in Step 2c, may be eliminated in the performance of the procedure when the cement of this invention is employed.
3. ROLLOVER TECHNIQUE
a. Perforate the well casing in two locations, so as to intersect the microannulus at its uppermost point and its lowermost point relative to the wellhead.
b. Isolate the zones below the perforated 2093 ~ 86 interval by placing a bridge plug in the casing below the perforation in the lowermost point of the microannulus.
c. Place a drillable packer in the casing between the uppermost perforation and the lowermost perforation to thus establish a space within the casing between the bridge plug and drillable packer.
d. Establish communication between the wellhead and the defined space via tubular goods from the wellhead to the packer.
e. Establish communication between the perforations by introducing an acid solution into the microannulus via the tubing, the defined space and the lowermost perforation and permitting the solution to exit the microannulus via the uppermost perforation.
f. Fill the microannulus with a water slurry of the cement composition of this invention by introducing the slurry into the microannulus via the tubing, the defined space, and the lowermost perforation and maintaining such introduction until the slurry exits the microannulus via the uppermost perforation.
g. Remove excess slurry from the defined space by backwashing.
h. Shut well in, preferably under pressure, 2093 1 ~6 to permit the cement to harden.
i. Drill set cement above drillable packer and drill through packer and remove bridge plug.
The rollover squeeze method described in steps 3a - 3i results in a microannulus completely filled with the cement composition of this invention.
The use of acid, as described in Step 3e, may be eliminated in the performance of the procedure when the cement of this invention is employed.
Procedure II

Method For Placing Cement in Voids, Cracks and Channels in the Cement Sheath Utilize the procedure described in Procedure I for placing the cement composition of this invention in microannuli, however, as an additional step, a chemical flush preceding introduction of the cement slurry maybe employed.
The purpose of the flush, which is not essential to the procedure, is to condition the hardened cement in the sheath for bonding. An example of a suitable such reactive chemical pre-flush is sodium silicate.
Procedure III
Method For Plugging Cracks and Perforations in Casing 1. Locate the casing hole by conventional means.
2. Isolate the hole by placing a bridge plug in the casing below the hole and a packer in the casing above the hole to thereby define a space within the casing between the bridge plug and packer; establish communication with the wellhead via tubing from the wellhead to the packer.

2093 1 ~6 3. Introduce an acid solution into the hole via tubing from the wellhead to the packer and the defined space. The acid, which can be a 15~ hydrochloric acid solution, will prepare the hole for cementing.
4. Introduce water into the hole via the tubing to establish an injection rate.
5. Introduce a water slurry of the cement composition of the invention into the hole via tubing from the wellhead to the packer and the defined space. The slurry must be of sufficient volume to form a plug in the hole to prevent passage of fluid therethrough. Introduction of the slurry must be effected at a pressure less than the pressure required to fracture the formation.

6. Remove excess slurry from the defined space by backwashing.

7. Shut well in preferably under pressure to permit the cement to harden.
The use of acid as described in Step 3 may be eliminated in the performance of the procedure when the cement of this invention is employed.
Procedure IV
Alternate Method For Repair of Cracks in Casing 1. Locate crack in casing by conventional means.
2. Place a bridge plug in the casing below the crack to thereby isolate the crack from portions of the casing below the crack.
3. Introduce tubing into the casing from the wellhead to a location in the approximate vicinity of the crack.
4. Remove any debris from the portion of the casing above the bridge plug by introducing therein water via the tubing and circulating the same out the casing.
5. Introduce a water slurry of the cement composition of this invention via the tubing into the casing above the bridge plug in amount sufficient to cover the crack.
6. Increase the pressure in the casing above the slurry to force the slurry to slowly penetrate into the crack and continue to increase casing pressure to assure such penetration.
7. Shut well in under pressure and do not release the pressure for a period of time, preferably about 24 hours,~to permit the cement to harden in the crack.

8. Remove set cement from casing by drilling.

9. Pressure casing with water to determine whether repaired crack prevents loss of water.
Procedure V

Method For Terminating Water Flow Through A Gravel Pack and the Matrix of a Subterranean Formation 1. Place a volume of a slurry of hydraulic cement in water within the slotted liner. The volume of slurry placed should be in an amount at least sufficient to saturate the portion of the gravel pack through which the unwanted water is flowing. The slurry may be spotted by permitting it to flow from the wellhead via tubing extended therefrom to the liner or by lowering it to the liner in a section of pipe having a valve in the bottom portion thereof and thereafter opening the 2093 1 ~

valve and literally dumping the slurry in the liner. The section of pipe and valve is referred to as a dump bailer.
2. Apply pressure against the slurry in an amount sufficient to force the slurry from the liner and into and through the gravel pack and at least partially into the portion of the formation from which undesirable water is being produced. The pressure applied to the slurry should not be of sufficient intensity to make a fracture in the formation.
3. Maintain applied pressure for a time sufficient to permit the cement to harden before the well is returned to production.
Procedure VI -Method for Terminating the Flow of Water From a Zone in a Subterranean~Formation 1. Locate the zone within the subterranean formation from which water is being produced. This task may be performed by using known methods of identifying casing perforations through which water is flowing. The water may be flowing from a fracture or from a high permeability portion in the zone.
2. Isolate the identified perforations by placing a bridge plug in the casing, a bridge plug below the perforations and a packer in the casing above the perforations to thereby define a space within the casing between the bridge plug and packer which is in communication with the zone via the perforations; establish communication with the wellhead via tubing from the wellhead to the packer.
3. Introduce a spacer fluid such as diesel oil into the 20931 ~6 zone via the tubing and perforations.
4. Introduce a slurry of the cement composition of the invention in a hydrocarbon liquid into the zone. The cement must be of sufficient volume to form a plug in the zone to prevent passage of fluid therethrough. Introduction of the cement is preferably effected at a pressure less than the pressure required to fracture the zone.
5. Introduce an overflush fluid such as diesel oil into the zone via the tubing and perforations to help in the introduction of the hydrocarbon-cement slurry into the zone.
6. Shut well in for 24 hours, preferably under pressure, to permit the cement to hydrate with formation water in zone and harden. Remove the tubing, the packer and the bridge plug from the well.
Procedure VII

Nethod for Using Ultra Fine Cement in Primary Cementing operations The method of cementing primary oil field casings using ultra fine cement slurries include conductor pipe, surface casing, intermediate casing, production casing, drilling liner, production liner, scab liner, and tieback casing.
1. Pump the slurry or any preceding or following fluid down the casing (tubing or drill pipe) and back up the annular space between the casing and the drilled hole.
2. (optional) Precede all fluids with a "bottom" wiper plug to clean drilling fluid from the casing.
3. (optional) Pump a preflush chemical wash or "spacer"
to serve as a drilling fluid removal agent and as a compatible 2093 1 ~6 spacer between the drilling fluid and the cement slurry.
4. Pump the cement slurry.
5. (optional) Follow the cement slurry with a conventional cement slurry.
6. Follow the cement slurry with a "top" wiper plug.
7. Pump a commonly used displacement fluid (water, drilling fluid, e.g.) to force the cement slurry down the casing and up into the annulus. Pump enough fluid to displace the required amount of casing volume. The "top" plug should land on a baffle or "float collar", closing off the flow of fluid to the annulus.
8. Pressure up to ensure that the top plug has landed.
9. Release pressure on casing to test if the "float" is holding to keep the cement in the annulus.

10. Terminate any operation in the wellbore for a time sufficient to permit the cement to set (WOC).

Claims

1. A method for terminating the flow of water from a portion of a subterranean formation into a wellbore said method comprising the steps of:
placing within said wellbore adjacent said portion a volume of a slurry of hydraulic cement, said volume being in an amount at least sufficient to saturate said portion;
permitting said volume to penetrate into said portion; and maintaining said slurry in said portion for a time sufficient to enable said slurry to form a rigid mass of cement in said portion;
wherein said slurry consists essentially of a mixture of said hydraulic cement, a hydrocarbon liquid and a liquid surfactant soluble in said hydrocarbon liquid, and water, the particle size of said hydraulic cement is not greater than about 30 microns, the Blaine Fineness of said hydraulic cement is no less than about 6000 cm/gram, and said hydraulic cement is Portland cement or slag or mixtures thereof.

2. The method of Claim 1 wherein said portion has an effective permeability as low as about 3000 to 5000 millidarcies.

3. The method of Claim 1 wherein said hydrocarbon liquid is present in said slurry in an amount in the range of from about 6 to about 10 gallons per 100 pounds of said cement.

4. The method of Claim 3 wherein said liquid surfactant soluble in said hydrocarbon liquid is present in said slurry in an amount in the range of from about 10 to about 25 gallons surfactant per 1000 gallons of hydrocarbon liquid.

5. The method of Claim 4 wherein said surfactant consists of a solution of an alkyl aromatic sulfonic acid and the alkaline earth metal salts thereof dissolved in a low molecular weight alcohol wherein said alkyl aromatic sulfonic acid and the alkaline earth metal salts thereof is present in said solution in the range of from about 60 to about 80 parts per 100 parts by volume of said surfactant.

6. The method of Claim 5 wherein said cement is Portland cement.

7. The method of Claim 6 wherein said hydrocarbon liquid is diesel oil and said surfactant consists of calcium dodecylbenzene sulfonate and isopropanol.

8. The method of Claim 7 wherein said volume of said slurry is permitted to penetrate into said portion by applying pressure against said slurry in said wellbore.

9. The method of Claim 5 wherein 90 percent of said particles have a diameter not greater than about 25 microns, 50 percent of said particles have a diameter not greater than about 10 microns and 20 percent of said particles have a particle size not greater than about 5 microns.

10. The method of Claim 9 wherein said volume of said slurry is permitted to penetrate into said portion by applying pressure against said slurry in said wellbore.

11. The method of Claim 10 wherein said hydraulic cement is Portland cement.

12. The method of Claim 11 wherein said particle size of said cement is not greater than about 17 microns and said Blaine Fineness is no less than about 7000 cm2/gram.