Abstract:
An improved method for completing wells formed in both consolidated and unconsolidated formations is disclosed. Further, methods are disclosed for completing deviated wells formed in consolidated formations which require stimulation by hydraulic fracturing. The present invention specifically relates to more efficient, less expensive techniques for well completion comprising novel techniques for the utilization of permeably consolidatably, resin coated particulates.

Description:
BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     The present invention generally relates to improved methods for completing wells formed in both consolidated and unconsolidated formations, and for completing deviated wells formed in consolidated formations which require stimulation by hydraulic fracturing. More particularly, the present invention relates to more efficient and less expensive methods for well completion in underground reservoir rock formations comprising novel techniques for the utilization of permeably consolidatable, resin coated packing materials. 
     2. Description of the Prior Art 
     Increased emphasis is being placed on proper initial well completion as the value of nonrenewable natural resources increases and the costs associated with their production escalate. While such emphasis is especially felt in the areas of hydrocarbon extraction, production of other valuable liquids, such as groundwater, also emphasizes the need for low cost, efficient production techniques. Maximum reliability and productivity of any production program is essential, particularly offshore and in remote locations. 
     The aforestated general objectives are difficult to obtain where the reservoir rock is unconsolidated or otherwise subject to failure, or where the reservoir requires stimulation to make production or injection economically attractive. Extraction from such formations usually require the utilization of techniques cumulatively referred to as &#34;sand control&#34;. Alternatively, such extraction may require hydraulic fracturing, or the combination of the two. The sand control mechanism, however, is exceedingly complex and is influenced by every well operation from first bit penetration throughout the lifetime of production or injection of the well. 
     Sand problems are most common in younger Tertiary sediments, particularly of the Miocene epoch. Notable examples are extensive, troublesome sand production areas in such sediments in the U.S. Gulf Coast, the Los Angeles basin of California, Canadian tar sands, Indonesia, Nigeria, Trinidad and Venezuela. However, sand inflow also occurs in other formations (i.e., older tertiary) if existing in situ stresses are altered by drilling, completion and production operations such that the rock matrix is weakened, thus allowing movement of sand into the wellbore, casing and tubing. 
     Factors contributing to the onset and continuance of uncontrolled sand production are numerous. One common basis is alteration of the stresses on the reservoir rock. If the balance of forces on the reservoir rock are sufficiently unbalanced, destruction of the rock matrix generally will follow. 
     Sand flow from unconsolidated or failure prone consolidated formations is often controlled through chemical or mechanical means to prevent or correct various problems including premature failure of artificial lift equipment; production loss caused by sand bridging in casing, tubing, and/or flow lines; failure of casing or lines and formations damage near the wellbore due to removal of surrounding formation, compaction, and erosion; abrasion of downhole and surface equipment; and handling and disposal of production formation materials. 
     A variety of techniques have been developed in the art to address the above noted problems of sand flow. One such method involves the process of injecting chemicals into the naturally unconsolidated formation to provide in situ grain-to-grain cementation Techniques for accomplishing this successfully are perhaps some of the most sophisticated undertaken in completion work. In closely related methods, sand or other appropriate matrix particulates are treated chemically and then injected into the wellbore (or through the perforations if casing is set), and into the formation where the resulting &#34;pack&#34; consolidates. Production is then commenced through a slotted or perforated liner or casing which is run along the length of the production zone. This technique is commonly referred to as resin coated sand gravel packing, or alternatively, resin coated sand consolidation. 
     In the consolidated gravel packing art, a particulate, usually a round silica sand of appropriate size and density, is coated with a suitable oil or water based epoxy or plastic resin and placed in a suitable carrier to form a viscous slurry. Such a resinous particulate slurry is described, for example, in Copeland, et al., U.S. Pat. No. 4,074,760. This slurry is then injected into the formation through the work string and perforations in the casing to form an area of high mechanical strength and high flow conductivity immediately adjacent the production inlets in the casing. Alternatively, a resin coated particulat may be placed between a wire wrapped screen or slotted liner and the casing. 
     Standard techniques for the application of such viscous particulate slurries may be described as follows. Once a well is established in the reservoir zone, the wellbore may generally be completed by one of two methods, either cased hole completion or open hole completion. 
     The general sequence of performing a cased hole completion includes drilling the hole, setting and cementing casing in place, perforating the casing for production; cleaning the perforation of damage and debris by flowing back, washing the perforations using a perforation wash tool, surging or perforating underbalanced; and stimulating the formation to decrease the skin factor as needed to make the well economically attractive. If the formation requires sand control, this is an additional step which must be performed in addition to the above. 
     The typical cased hole completion sequence further contains some or all of the following elements. The borehole is drilled with mud as the well fluid leaves a region of impaired or damaged permeability adjacent to the borehole. Casing is next run and cemented in place using a Portland cement slurry. Use of such a cement slurry may cause further damage to the formation&#39;s native permeability adjacent to the wellbore. However, The Portland cement functions to mechanically support the casing and also to isolate individual permeable formation from each other. At this point, the drilling mud is exchanged with a clear, solids free, completion fluid to reduce the probability of severe damage to the formation permeability during the critical completion phases where the formation is not protected from incompatible fluid invasion by the protective filter cake of mud solids. The casing is next perforated, and a method of cleaning the crushed formation and perforating debris is used to clean and open the perforations. The perforation cleaning steps may consist of washing the perforations using a perforation wash tool, backsurging the perforations, or by underbalanced perforating. The latter method is now considered by most operators to be the most effective. Finally, the appropriate hardware can be positioned in the wellbore for either a RCS consolidation, a gravel pack, or a conventional completion without any sand control. 
     The general sequence of performing an open hole completion includes drilling a pilot hole through all formation down to the top of the deepest target formation; setting and cementing casing in place; drilling a pilot hole through the deepest target formation; opening the hole size of the formations to be completed using an underreamer to remove damage from prior operations; and stimulating the formation to decrease the skin factor, if needed, to make the well economical. Again, sand control measures are performed in addition to these steps. 
     The typical open hole completion further comprises the following elements. The final borehole through the interval to be completed is preferably drilled with a nondamaging drilling mud. Casing is then set above the productive interval. If the interval to be completed has not already been drilled though, a pilot hole is drilled through the interval or intervals to be completed. If the pilot hole is drilled with a damaging drill mud, then the hole must be underreamed through the completion internal to remove as much as possible of the damaged formation adjacent to the wellbore. This operation is normally performed with a underreamer rotated on a workstring of pipe, and using a non-damaging circulating fluid to carry cuttings to surface. Once the desired sections of formation are exposed, they may be isolated from each other using inflatable cement packers, or, alternatively, the isolated sections of hole may be cemented using formation packers and port collars. If sand control is required, normally a gravel slurry is placed between a slotted liner or wire wrapped screen and the exposed formation, again using ported collars and a combination tool. The combination tool functions to open and close the port collar and also isolates the port collar to direct the slurry placement. Once each exposed formation section is treated in this way, sand control is accomplished and the well is ready to produce. 
     The production rate possible from the above described completions techniques may be enhanced by stimulating the well. Well stimulation may consist of a chemical stimulation using some kind of acid or solvent solution to dissolve or remove material from the formation. Alternatively, the well may be stimulated by hydraulic fracturing. In hydraulic fracturing, a fracture is created in the reservoir rock by hydraulic forces and then propped open by a particulate material. This propped fracture provides a low resistance flow channel from deep within the formation to the wellbore. 
     The above described methods of well completion have a number of disadvantages. Present methods of completing unconsolidated or failure prone consolidated formations using the combination of a hydraulic fracturing method and some type of sand control have not yet addressed the problem of having both fracture entry control and the high perforation density needed for a high efficiency completion. If the fracture stimulation is performed with a limited number of perforations to achieve fracture propagation throughout the entire interval, then the well must be produced at low efficiency through the limited number of perforations. If the interval is re-perforated after the fracture stimulation, several problems arise. First, there is no guarantee that most or all of the second set of perforations will connect to the propped fracture. Therefore, the increased flow capacity of the fracture will be choked back at the wellbore since the fracture will connect to only some of the perforations. 
     Second, operations employed to clean the second set of perforations by flowthrough or surging may cause loss of proppant from the fracture, resulting in closure of the propped fracture at the critical wellbore juncture. Third, the high flow density at the interface between the fracture and the wellbore represents a potential problem area for both fines movement and plugging, as well as problems arising from deposition of organic deposits. The high flow velocity at the interface causes the fines to migrate and the large pressure drop at this point tends to precipitate out any paraffin or asphaltene deposits where they give the most restriction to production. A further problem with such high velocity fluid movement through the sands involve the possible erosion of the plastic bonds between the particulates. This problem of erosion is particularly acute for zones close to the wellbore and subject to multiphase flow. 
     Yet another disadvantage of conventional methods of completion utilizing contemporary techniques for sand control involve the time necessitated in securing the casing along the production zone and in isolating separate reservoirs, and further, in the numerous subsequent completion steps required to complete a number of narrow production intervals in such zone. In such cases, cement seals or formation packers must be introduced between each production interval. Then formation damage or debris must be removed from the interface between the virgin, undamaged formation and the wellbore to effect an efficient completion. Ordinarily, this removal must be accomplished prior to placement of sand control measures for each formation interval to be completed. This debris removal is generally accomplished via chemical means, mechanical means, or a combination of the two. 
     Underreaming is generally the preferred mechanical method for damage removal prior to placement of sand control measures in open hole completions Underreaming, however, is highly time consumptive since it entails the introduction of the underreaming tool via a work string, hence necessitating at least one &#34;round trip&#34; for each production interval. Furthermore, additional trips may be required if hole stability problems are encountered. Even when the production intervals are grouped in a single zone, such damage removal processes can involve extensive time expenditures. Such time expenditures are especially noteworthy in deeper wells or in deviated wells having a large net length. Additionally, underreaming procedures conducted in some unconsolidated formations might result in a complete collapse of the borehole, and hence abandonment of the well. 
     Further disadvantages of contemporary completion art involve the inconsistency in the character of the high conductivity region created by the resin coated particulate slurry. Contemporary completion techniques incorporating provisions for sand control describe the introduction of the resin particulate slurry into the wellbore in such a fashion as to cause laminar flow of the slurry in the annulus between the wellbore and the production casing. If the casing is situated off center in the wellbore, the laminar flow of the resin slurry often leaves unfilled voids immediately adjacent the casing which may often decrease production efficiency. Such problems are again particularly acute in deviated wells where undesirable &#34;duning&#34; occurs. Laminar flow of such sands into the annulus also allows time for the formation to dehydrate the resin slurry, also resulting in premature and often unsatisfactory set up of the consolidated formation adjacent the production casing. 
     SUMMARY OF THE INVENTION 
     The present invention addresses the aforementioned and other disadvantages by providing improved methods for completing wells in unconsolidated sand and limestone formations. The present invention also provides for the completion of deviated wells in consolidated formations which require stimulation by hydraulic fracturing. 
     In a preferred embodiment of the present invention, an open hole resin coated particulate pack is placed around the uncemented production casing across the projected production interval(s). The well is next hydraulically fractured with a resin coated sand proppant utilizing the limited entry perforating technique through the open hole resin coated sand consolidation. At this point a conductive channel or series of channels into the reservoir is realized with minimized restriction close to the wellbore region. In the next phase of the method, the casing is then perforated using a large hole diameter, shallow penetration depth, high shot density perforating gun. Finally, a gravel pack is performed inside the casing using a wire wrapped screen and a gravel packer. 
     Before production casing may be set in the wellbore, the wellbore must first be mechanically underreamed in order to remove the mudcake and also to enhance the diameter of the void around the casing. In such a fashion, the resin coated sand or particulate slurry is able to contact uncontaminated areas of the formation while establishing a larger cross sectional area of permeable consolidation. In another preferred embodiment of the invention, the wellbore is underreamed or scoured via an abrasive sand slurry which is injected down the casing or inner string and into turbulent contact with the formation. The turbulent action of the abrasive slurry simultaneously removes the mudcake from the walls of the wellbore while contouring the wellbore to a desired production diameter. This abrasive slurry may then be displaced in the wellbore by the introduction of a resin coated particulate slurry as above described which is introduced at a pressure so as to result in optimal flow characteristics, e.g. either transition flow or turbulent flow rates which do not impart sufficient stress on the walls of the borehole to cause formation sloughing or undesirable mixing of formation material with the RCP slurry. This second slurry then is allowed to set around the production casing or cement packer to form a consolidated zone of high conductivity. 
     The present invention has a number of advantages over the prior art. The proposed method of completion results in a high conductivity region surrounding the wellbore which acts like a channel between the fracture flow and the high density perforations while giving fracture propagation control during the hydraulic fracturing operation. As such, production efficiency is dramatically increased. 
     A second advantage of the present method is the ability to secure production casing along a potential pay zone without cementing, therefore avoiding undue contamination and formation damage along the production zone so as to necessitate time consuming opening, underreaming operations, or other rigorous methods of debris removal which risk formation damage. 
     Another advantage of the present invention is the ability to form an annulus of desired diameter without the need to resort to mechanical underreamers or openers. Such ability greatly reduces or eliminates the need to trip mechanical underreamers or the like in the hole. This advantage is particularly significant in deep wells, wells formed in highly unconsolidated formation, or in deviated wells which involve an abnormally long net production lengths. 
    
    
     BRIEF DESCRIPTION OF THE DRAWINGS 
     FIG. 1A generally illustrates a side cutaway view of a well formed in an unconsolidated sand formation, in accordance with prior art methods of sand control. 
     FIG. 1B illustrates a side cutaway view of a mechanical underreaming tool as it may be used to enlarge the diameter of the wellbore through the production zone. 
     FIGS. 2A-J illustrate side cutaway views illustrating the process comprising the general embodiment of the present invention. 
     FIGS. 3A-C illustrate a side cutaway view illustrating the method by which the wellbore may be contoured by use of turbulent particulate injection. 
     FIG. 4 illustrates a top cross sectional view of the high productivity region surrounding the wellbore produced as a result of the claimed method. 
     FIGS. 5A-D illustrate a top cross sectional view of casing unsymetrically situated in the wellbore. 
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENT 
     FIG. 1 generally illustrates a side, cross sectional view of a well completed in an unconsolidated formation in accordance with prior art techniques of well completion utilizing either a consolidatable resin coated packing material or a gravel pack. As seen in FIG. 1C of 1F, an open hole has been formed in a production zone 10, such as a younger tertiary sand lens, extending between two nonproducing intervals 14. Prepatory to setting casing through this zone 10, the wellbore has been &#34;opened&#34; or &#34;underreamed&#34; with a tool 20 similar to that illustrated in FIG. 1B. 
     Hole opening devices 20 such as that illustrated in FIG. 1B, feature cutting arms which may be expanded by hydraulic pressure after the tool 20 is first run through casing in order to enlarge the open hole beneath the shoe 19. Hole openers or underreamers 20 are used to enlarge the hole to allow for increased gravel thickness around slotted or screen type liners. Such underreaming operations are also necessary to remove the mudcake from the wall of the wellbore and form the adjacent damaged region. 
     Referring to FIG[S.] 1B[-C], . . . when the wellbore has thus been contoured or underreamed to a desired diameter as above described, a gravel pack, normally consisting of a particulate slurry (RCP) or a resin coated particulate slurry, is injected in the widened annular space 15 formed by the underreamer 20 between the walls of the wellbore 17 and the casing 2. Generally, this viscous slurry is injected into the annular space by pumping from the workstring through a crossover tool into the annular space between the slotted or screen liner, until the annulus is filled with the particulate, whereupon the well is essentially complete except for installation of tubing and wellhead. 
     Another open hole type completion utilizing a resin coated particulate slurry is the patented process known as the Puddle Pack This type of completion is performed on a well having an open hole interval such as that created by shooting the well with nitroglycerine. The Puddle Pack process entails filling the open hole space with a RCP slurry. When the resin has set a borehole is drilled through the consolidated pack, casing is run and cemented in place across the zone 4. A perforating tool (not shown) is then introduced in the well, forming perforations 16 through the casing 2 and cement 4 into the high conductivity region 12 formed by the resin coated Puddle Pack, whereupon the well may then be produced. 
     The method of the present invention generally facilitates the above-mentioned prior art technique while enhancing the productivity of a given formation. The method of the present invention further results in the realization of substantial economic benefits in deeper wells, as well as in deviated wells. 
     The general method of the present invention can generally be seen by reference to FIGS. 2 and 3 consisting of FIGS. 2A-J and 3A-3, respectively. FIG. 2 illustrates a bore 46 formed in a producing formation 40 situated vertically adjacent a nonproducing horizon 44 such as a shale or nonpermeable sand. In FIG. 2A, intermediate casing 42 has been set above the zone of interest 40 to the extent of this nonproducing zone 44. In accordance with prior art techniques, the bore 46 is then recontoured or underreamed (FIG. 2B) to remove the mudcake formed along the walls of the wellbore and to establish an annulus 48 of sufficient size to sustain the gravel pack. This recontouring or opening may be accomplished via an underreaming tool as illustrated in FIG. 1B. Alternatively, this underreaming may be accomplished via the introduction of an abrasive sand slurry as will be further discussed herein. 
     Referring to FIGS. 2C-2D, once the wellbore has been contoured to a desired dimension and the mudcake removed, production casing 50 is then set in the enlarged bore 46. Once the casing is in place, an inner workstring 56 is preferably set in place. (See FIG. 2C &amp; 2D). The well is now prepared to receive the resin coated particulate slurry (RCP). In wells where undesired migration of formation sands is expected, a slotted liner or wire wrapper screen (not shown) may be used and a gravel pack performed between the screen and the casing later in the completion sequence. 
     Referring to FIGS. 2E-F, the placement of the resin coated packing material is accomplished by pumping the resin coated slurry 60 down through the workstring 56. The workstring 56 is preferably sealed into a casing shoe 54 or a float shoe if the zone to receive the packing material exists at the point of the casing seat. Otherwise, the workstring 56 is sealed to or isolated with a port or multistage cementing tool (not shown) placed at an appropriate depth in the casing string. The resin coated slurry is then pumped down the workstring 56 through the casing shoe 54 or port in the casing string (not shown) and up across the zone of interest 10. Preferably, the resultant high conductivity region 60 is equally consolidated around the production casing 50 so as to ensure even production flow. 
     Once the resin coated slurry injected in the annulus has consolidated around the production casing to form a high conducting region 60, the casing is then perforated (FIG. 2G). Such perforation may be accomplished via a deep penetrating bullet perforation or jet charge type technique. Once perforated at the desired interval spacing, the formation is then fractured. In a preferred embodiment, formation fracturing is induced by injecting a suitable proppant, such as additional amounts of the resin coated slurry, into the perforations 62 (See 2H). 
     Once fractured, the formation is then re-perforated (FIG. 2I). In preferred embodiments, a large bore, high shot density, shallow penetration, tubing conveyed perforation device is utilized to achieve this reperforation. Since a highly permeable sheath of resin coated particulates surrounds the casing, the optimal charge design is a maximum bore charge which will penetrate only the casing. Where extensive migration of formation sands through the gravel pack is expected, a slotted or perforated screen 80 may then be introduced inside the production casing. 
     The consolidatable, resin coated packing material, e.g. Hydrocon-E, is important to provide a high permeability interface region or &#34;gravel pack&#34; to connect the wellbore to the fracture. Utilized in accordance with the present invention, such &#34;gravel pack&#34; generally provides the following advantages: 
     1. Structural support for the casing; 
     2. Consolidated media to support the deep penetrating limited entry charges used for fracturing; 
     3. Creates a high permeability channel between the proposed fracture and the high density, large hole, shallow penetration (OHDLHSP) perforations in the casing which are necessary to minimize drawdown and restriction to flow through a gravel pack. The resin coated packing material provides the connection to allow flow from the fracture to access all the casing perforations; 
     4. Expands the effective wellbore radius to enhance and reduce the velocity of fluid flow through the formation pores near the wellbore. The reduced flow velocity will reduce the tendency of fine particles of formation material to migrate in the formation pores and cause plugging of the pores. This facilitates the completion to maintain high productivity with less chance of premature flow impairment due to fines migration; 
     5. Eliminates needs for cement across the production zone, thus eliminating cement filtrate damage. 
     In one preferred embodiment of the invention, a ported section of casing covered by a wire wrapped screen is introduced above the zone of interest so as to facilitate circulation of slurry across a given production interval, and to give more complete coverage and packing of the resin coated sand. An upper ported section or multistage cementing tool may be added in combination with formation packers so as to allow the completion of multiple zones utilizing the proposed method. In such an embodiment, the use of multistage cementing tools and formation packers, such as a Lynes ECP open hole gravel pack system, allows isolation of multiple high consolidation zones by placement of cemented sections between the production zones. 
     The resin coated sand or particulate slurry (RCP) is preferably introduced through the workstring or casing at a rate and pressure so as to result in sub-erosive flow of the slurry into the annulus around the casing. Sub-erosive flow, or a flow rate greater than laminar flow but less than the flow rate sufficient to cause shear and erosion of the borehole well to precipitate formation sloughing or mixing of formation material with the consolidatible slurry, enhances the consolidation of the resin coated packing material by filling in voids created during premature &#34;setting&#34;of the sand pack, or as created by off center placement of the casing in the wellbore. 
     Such off centered conditions are particularly severe in deviated holes. FIGS. 5A-D generally exemplify how a casing symmetrically aligned and seated in the wellbore 210 may begin to experience lateral displacement along its length to a point where it contacts or is near contact with the wall 212 of the wellbore. Referring to FIGS. 5A-B, a casing 200 is initially centered in the wellbore at the shoe (not shown), but at only 48&#34; above the shoe the casing already demonstrates substantial off-center deflection from the wellbore axis. This deflection increases at 72&#34; (5C) and at 120&#34; (5D) above the shoe. Hence, at only ten feet above the casing shoe the centered casing 200 already contacts or nearly contacts the wellbore wall 212. When such deflection exists, resin coated sand slurry introduced into the annulus 208 under laminar flow leaves voids 204 at these areas where the casing 200 is off-center with respect to the wellbore. When the casing is perforated and production commences through the high permeability region 208, these voids 204 dramatically inhibit favorable production by allowing low conductivity formation sand 212 to fill casing perforations. 
     These problems may be addressed by injecting the slurry at a transition or sub-erosive fluid flow, i.e., greater than laminar flow, since the agitated slurry will be forced into voids 204 created in the annulus 208. In comparison, injection of the slurry as to result in greater than transition flow or turbulent flow is not desired since such turbulent flow might cause undesired sloughing or deterioration of the wellbore wall. Such deterioration in turn would introduce low permeability formation sands into the resulting matrix adjacent the production casing, hence detrimentally affecting production. 
     Prior to setting production casing through the production zone, the wellbore must often be &#34;underreamed&#34; or &#34;opened&#34; to remove mudcake from the walls of the wellbore. When sand control is implemented, the wellbore will also often have to be underreamed to an additional diameter so as to support the packing material. Such underreaming or opening procedures, while vital to efficient production from the zone, involves the use of mechanical tools which must be run or &#34;tripped&#34; into the hole. Such tripping necessitates the utilization of a derrick rig and involves a time consumptive and hence expensive process. Such is particularly true if a plurality of individual producing horizons must be addressed, each involving an individual underreaming operation. One embodiment of the present invention substantially eliminates the need for this time-consuming procedure. In accordance with the method of the present invention, casing is run across the target zone in the original borehole and hole opening, and damage removal is accomplished immediately prior to setting the casing via placement of the RCP. 
     FIGS. 3A-C illustrate yet another preferred embodiment of the invention which addresses the above noted disadvantages of well completion. FIGS. 3A-C generally illustrate a bore 82 formed through a nonproducing zone 44 into an adjacent producing horizon 40. In these figures, intermediate casing 42 has been set in the nonproductive zone 44 and cemented in place. From this intermediate casing 42 has been hung production casing or liner 80. This casing 80 is run into the bore 82 which has not been underreamed or opened. Once the casing 80 is fully run on the bore 82, an abrasive slurry 90 is pumped down into the casing at a pressure so as to induce turbulent flow of the abrasive slurry 90 down the bottom of the casing 80 and up between said casing 80 and the wellbore 82. This abrasive slurry 90 strips the mudcake from the wellbore wall while simultaneously recontouring the wellbore 82 to a diameter sufficient to accept the resin coated packing material as will be later described. 
     Once a sufficient area has been formed in the production zone 40 adjacent the casing 80 such that damage from drilling is substantially eliminated and the bore diameter is sufficiently large to allow laminate flow at the projected producing rate, a resin coated packing (RCP) material 100 is then injected down into the casing 80 into the resulting annulus 94. This packing material 100 displaces the abrasive slurry 90 which is then retrieved along with formation debris at the surface. Preferably, the resin coated packing material is injected at a pressure so as to induce sub-erosive flow in the slurry 100. As such, a maximum flow rate is achieved in this material so as to give sufficient displacement of debris by the RCP slurry 100 while not inducing additional abrasion of the wellbore wall 83. 
     While it is envisioned that a separate abrasive slurry e.g. walnut hulls or blasting sand, and a packing material may be used in accordance with the above-described embodiment, some occasions may suggest the use of a single slurry compound, e.g., a resin coated sand, which accomplishes the above described result by use of varying injection pressures. Hence, it is envisioned that it may be possible to first inject the resin coated packing compound at a pressure so as to induce turbulent flow. Once the wellbore is appropriately contoured, the pump pressure would then be reduced to allow for the injection of the resin coated packing material under non-turbulent conditions, preferably sub-erosive flow. 
     The foregoing descriptions of selected embodiments of the invention shall be construed as illustrative only, and not as a limitation upon the scope of the invention as defined in the claims.