Abstract:
A method for treating an open-hole horizontal water injection well in a tight reservoir rock formation to remove undesirable materials such as formation-damaging polymers and chemical residues from pipe dope from the formation surface and adjacent formation pores prior to an acidizing treatment includes maintaining the drilling fluid pressure on the injection zone to induce flowback of formation fluid which is produced at the wellhead located at the earth&#39;s surface, where it is monitored for a reduction in the undesirable materials. In the event that the formation pressure is insufficient to produce formation fluid flowback, a nitrogen-lift is introduced at a predetermined location in the adjacent vertical well that will reduce the drilling fluid pressure to induce production of formation fluid at the wellhead.

Description:
FIELD OF THE INVENTION 
     This invention relates to a method of conditioning a long horizontal open-hole water injection well in a tight formation prior to acid stimulation to improve the contact of the acid with the rock as well as the penetration of the acidic materials into the reservoir rock and thereby enhance the permeability of the formation and the flow rate of the injected water. 
     BACKGROUND OF THE INVENTION 
     It is a common practice to employ acid stimulation of low-permeability or damaged carbonate reservoir formations in order to enhance the flow and production of hydrocarbon fluids from the formation surrounding the wellbore. Acid treatment of water injection wells is similarly employed to enhance the permeability of the reservoir. However, the effectiveness of the acid treatment can be seriously reduced if the wellbore contains formation damage caused by incursions of drilling fluids, or mud, and other foreign matter. This problem is particularly pronounced in water injection wells through tight carbonate reservoir formations and results in acid treatments that are less successful than those carried out in relatively high permeability water injection wells. 
     The effectiveness of the acid treatment is directly proportional to the injection rate (e.g., barrels of water/minute) and inversely proportional to the injection pressure, i.e., a lower pressure is required for a given injection rate following an effective acid treatment. 
     It has been found that hydrochloric acid which can effectively dissolve the calcium carbonate minerals present in both the filter cake and the formation is not capable of dissolving or degrading some of the formation-damaging polymer components present in the drilling fluid, such as xanthan gum and starch. The xanthan gum is used to increase viscosity and the starch to control fluid loss. Three different damage mechanisms associated with drilling fluids are filtrate invasion, solid invasion (internal filtercake) and external filtercake. Other materials used in assembling the drilling pipe can also cause damage to the surrounding formation. Pipe dope applied to the couplings and other fittings used in assembling the drilling pipes and associated components can also cause damage to the surrounding formation. 
     As used herein, the term “undesirable materials” will be understood to refer to formation-damaging polymers, other chemical substances, debris and other materials which interfere with the flow of formation fluids from the walls and adjacent reservoir rock of the well bore and thereby reduce the productivity/injectivity of the well. The inherent formation pressure is the pressure of the fluids in the pores of a reservoir created by the weight of the overburden, water injection and any underground withdrawal. 
     As used herein, the term “wellbore” if not otherwise modified, will be understood to mean the combined vertical section and the open-hole horizontal section of the well. 
     It is therefore an object of the present invention to provide a method of substantially eliminating or greatly reducing the presence of formation-damaging materials, such as polymer components and pipe dope residue that interfere with the effectiveness of an acid stimulation treatment in an open-bore horizontal water injection well, to thereby render the subsequent acid treatment of the formation more efficient and effective. 
     SUMMARY OF THE INVENTION 
     The method of the present invention comprehends the inclusion of an additional step or pre-treatment stage prior to the introduction of the pressurized acid treatment of a water injection well in which the injection portion of the horizontal open-hole wellbore is subjected to flowback of the formation fluids for a period of time that is sufficient to remove a substantial portion of the undesired materials from the walls of the wellbore and from the adjacent formation. In some formations, the flowback stage can be achieved as a result of the inherent reservoir pressure and once the application of pressure on the drilling fluid is discontinued at the surface, the formation fluids will flow into the open-hole bore with sufficient force to displace the introduced wellbore fluids back up through the vertical wellbore and produce the formation fluids and the undesirable materials to the surface through the production/injection tubing. 
     The rate and time allowed for the flowback is controlled at the wellhead. In such a case, the flowback can be achieved by depressurizing the wellbore fluid to atmospheric and opening the wellhead valve to discharge the wellbore fluid. 
     The formation fluids produced during the flowback step can include brine, hydrocarbon liquids and/or gases and will initially include damaging mud-induced solids introduced under pressure into the wellbore during the drilling of the wellbore and the liquid that was forced into the pores of the reservoir rock. The portion of the reservoir occupied by solids faulted on the horizontal open-hole bore surface and the solids and liquid penetrating the formation around the bore are referred to herein as the infiltration zone. 
     In the event that the inherent reservoir pressure is not sufficient to raise the wellbore fluid, formation fluids, debris and undesirable materials to the wellhead at the earth&#39;s surface, the flowback is achieved by reducing the hydrostatic pressure of the completion fluid in the production zone to a pressure that is less than the inherent pressure of the formation fluids proximate to the production zone. The hydrostatic pressure of the fluid is reduced by displacing a portion of the fluid from the vertical section of the wellbore to the earth&#39;s surface. 
     In one preferred embodiment of this aspect of the method of the invention, the wellbore fluid is displaced by the use of a “nitrogen lift” process in which nitrogen gas is circulated through the production/injection conduit and into the wellbore to displace liquids and to thereby reduce the hydrostatic pressure created by the fluid column that extends to the wellhead at the earth&#39;s surface. Nitrogen lifting is well known and is a commonly used technique for initiating production in a well following acidizing treatments or over-balanced completions. 
     The quality of the completion fluid, debris and undesirable materials, along with any produced formation fluid(s) are monitored at the wellhead during the flowback stage. Samples of the formation fluids are subjected to periodic physical inspections. When the amount of undesirable materials is reduced to a predetermined acceptable level, the flowback stage is terminated. 
     Following termination of the flowback stage, the wellbore is prepared for the acidizing treatment stage in accordance with standard and customary procedures. This typically includes a preflush step which consists of water, a mutual solvent and water-borne wetting surfactant is next used to condition the wellbore for the acid treatment. The acidizing treatment stage of the process can include a 20% by weight emulsified HCl solution injected under pressure followed by a spacer of non-emulsified HCl and appropriate additives, which is then followed by a diverting agent. 
    
    
     
       BRIEF DESCRIPTIONS OF THE DRAWINGS 
       The invention will be described below in further detail and with reference to the attached drawings in which: 
         FIG. 1  schematically depicts a typical open-bore horizontal water injection well completion of the prior art in which the method of the invention can advantageously be practiced; 
         FIG. 2  is a detail of a representative portion of the open-bore well of  FIG. 1  schematically illustrating the formation damage; 
         FIG. 3  is a detail similar to  FIG. 2  schematically illustrating the effect following application of the method of the invention; and 
         FIG. 4  is a schematic diagram of a completion similar to  FIG. 1  illustrating the positioning of apparatus for applying a nitrogen lift to raise the formation fluids to the wellhead. 
     
    
    
     DETAILED DESCRIPTION OF INVENTION 
     Referring to  FIG. 1 , a water injection well completion in accordance with the prior art is illustrated that includes a vertical well bore section  10  extending from the earth&#39;s surface  9  that includes a series of casing elements, generally identified as  14 . As illustrated, the casing  14  includes section  14 A extending from the earth&#39;s surface having a diameter of about 24 inches. A representative series of concentric casing elements having the indicated diameters are also illustrated as follows:  14 B (18⅝″),  14 C (13⅝″),  14 D (9⅝″) and  14 E (7″). An injection tubing  12  terminates in supporting element  16 . It will be understood by one of ordinary skill in the art that the length of the vertical section  10  can be many thousands of feet. 
     The horizontal section  20  of the open-hole well bore is also of indeterminate length and is defined by the curved transitional heel portion  22  and the completion end, or toe,  24 . Note that the casing  14  terminates at region  15  which defines the beginning of the open-hole portion of the well in the carbonate formation  40 . 
     Also shown in  FIG. 1  is sampling point  80  located at the earth&#39;s surface that includes control valve  82  and suitable sampling, inspection, testing, recording and alarm apparatus  84 . As noted above, the term “open-hole” refers to the fact that well casing  14  terminates at  15  and no well casing pipe is installed in the horizontal section, as it is in the vertical portion of the well bore  10 . As will be described in more detail below, the drilling fluid which is very dense to begin with contains undesirable materials, some of which infiltrate even a tight carbonate formation. Solid materials infiltrate beyond the surface of the horizontal bore hole and the liquid components penetrate the tight formation even further while displacing the reservoir fluids, due to the greater hydrostatic pressure of the drilling fluid in the vertical portion of the well. A layer of the solid undesirable materials also builds up in the surface of the bore hole and is referred to as the external filtercake. 
     The problem of mud damage mechanisms is illustrated in the enlarged cross-sectional schematic diagram of  FIG. 2  which shows a portion of the tight carbonate formation  40  that is represented by the matrix of circular elements having small pores or passages between them. During the drilling operation, drilling fluid, or mud  50 , is introduced under pressure into the upper end of the vertical wellbore  10  for the purposes of lubricating the drill bit (not shown) that is attached to the downhole end of the drill pipe and also, of equal importance, to carry the fragmented formation rock away from the drill bit and up to the surface. Since the drilling fluid  50  is very dense and extends the entire length of the wellbore to the earth&#39;s surface, it produces a significant pressure on the open-hole bore in the horizontal drilling phase. 
     As a result of the over-balanced pressure, an internal filtercake  54  as represented by the small particles in  FIG. 2  infiltrates the pores of the reservoir rock  40 . In addition, an external filtercake is formed and appears as a uniform dark coating  52  on the walls of the open-hole bore  20 . Also as shown in the illustration of  FIG. 2 , the lighter area  56  extending from the external filtercake  52  represents drilling fluid liquid filtrate which displaces any reservoir fluids  42  which are represented by the darker area. 
     In accordance with the method of the invention, the reduction of the wellbore fluids overpressure, i.e., by the use of the nitrogen lift that is described in more detail below, will allow the inherent reservoir pressure on the reservoir fluids  42  in the injection zone to cause the reservoir fluids to flow-back into the open-hole bore  20  and thereby flush the filtrate  56 , and most, if not all of the internal filtercake  54  and external filtercake  52  from the surrounding reservoir rock. 
     The formation fluids produced during the flow-back stage of the process of the present invention can include brine, hydrocarbon liquids and/or gases, in addition to the drilling fluid filtrate. As schematically illustrated in  FIG. 3 , following flow-back, substantially all of the external filtercake  52  and most of the internal filtercake  54  and filtrate  56  are flushed from the reservoir rock  40  by the reservoir fluids  42  flowing into the open-hole bore. 
     As previously noted, nitrogen lifting is an operation that is known and that has been commonly used to enable a well to flow initially or to bring a previously flowing well back into production. The nitrogen is introduced into the vertical section of the well bore at the desired location using coiled tubing. The nitrogen gas functions to “unload” or reduce the hydrostatic pressure upstream of the production zone to thereby under-balance the well so that it will flow naturally as a result of the inherent reservoir pressure. 
     Utilizing a simple calculation employing the known reservoir pressure at the production zone and along with the weight or density of the completion fluid in the well, the vertical depth of the well and its average diameter, the amount of overbalance can be estimated and the corresponding minimum depth for application of the nitrogen lift can be identified. The nitrogen can be introduced from a pressurized source at the earth&#39;s surface at a rate of from 300 to 900 SCF/bbl, the pressure being dependent upon the response achieved in the well during the nitrogen lift operation. 
     Referring now to  FIG. 4 , the well completion of  FIG. 1  is shown with the additional apparatus required for performing the nitrogen lift. A specialized vehicle  100  equipped with apparatus for transporting a length of coiled tubing  120  that is sufficient to reach the predetermined desired depth “D” in the vertical portion of the wellbore  10  is disposed adjacent the wellhead  80 . The coiled tubing  120  is poured into the well until the end of the tubing  122  reaches the desired predetermined depth “D” below the earth surface. 
     A source of liquefied nitrogen  130  is also disposed in the proximity of the wellhead and connected to pump  140 , which in turn is connected to the inlet end  124  of the coiled tubing which is typically retained on the vehicle  110 . 
     Once the apparatus has been positioned and secured, the liquefied nitrogen is pumped from its container  130  and through the coiled tubing  120  to be discharged into the vertical section  10  of the wellbore. When the liquefied nitrogen has been discharged from the open end  122  of the submerged tubing  120 , it rapidly expands to fill the wellbore and rises as an essentially continuous plug or block of gas towards the earth&#39;s surface, lifting the well completion fluid/mud out of the wellbore  10 . With this reduction in the hydrostatic pressure, the inherent formation pressure of the reservoir is able to displace the filtrate  56  and the reservoir fluids begin their backflow into the horizontal open-hole wellbore  20 . In addition to displacing the liquid filtrate  56 , the moving fluids also displace the internal filtercake  54  and the external filtercake  52 , respectively, from the adjacent formation and the surface of the open-hole bore. These materials will also be carried to the surface where they can be sampled and physically inspected for their content. 
     In some cases, the inherent reservoir pressure is sufficient to lift the reservoir fluids and any remaining undesired materials and completion fluid/mud to the surface and the injection of the liquefied nitrogen into the vertical wellbore  10  can be discontinued. In the event that the inherent reservoir pressure is not sufficient for this purpose, the nitrogen lift process can be continued while the fluids are inspected at the surface until the desired quality has been observed, after which the nitrogen injection is terminated and the coil tubing withdrawn. Thereafter, the acidizing treatment is initiated and completed as described above. 
     The method of the invention reduces polymer penetration of the tight carbonate formation  40  during the acid treatment, which is one of the main causes of injectivity loss, especially in tight carbonate formations. Laboratory tests have shown that the injection of a reacted solution of 20 wt % HCl acid and the components of a typical fluid used in the drilling of horizontal water injection wells resulted in a loss of more than 80% of the base core permeability. 
     EXAMPLES 
     Application of the method of the invention in three water injection wells produced a significant improvement in their injectivity. A field study was undertaken for the post treatment injection test results for six wells in the same formation in which three of the wells ( 1 ,  2 ,  3 ) were treated with the industry standard acid treatment and the other three wells ( 4 ,  5 ,  6 ) were treated using the method of the invention. The results of these comparative tests showed that the wells treated using the flowback method of the invention had a more than 2-fold increase in injectivity at lower injection pressure as compared to those subjected to the same acid treatment, but without the prior flowback stage. 
     The results of the tests on the six wells are set forth in the following tables, where Table 1 represents the post-acid stimulation treatment injection test without the flowback stage and Table 2 shows the improved results for the series of post-acid stimulation treatment injection tests with the prior flowback stage. In the tables, IWHP is the injection wellhead pressure. 
     
       
         
               
               
             
               
               
               
               
             
               
               
               
               
               
             
           
               
                   
                 TABLE 1 
               
             
             
               
                   
                   
               
               
                   
                 Well No. 
               
             
          
           
               
                   
                 Well 1 
                 Well 2 
                 Well 3 
               
               
                   
                   
               
             
          
           
               
                   
                 Injection Rate, 
                 27 
                 30 
                 20 
               
               
                   
                 bbls/min 
               
               
                   
                 IWHP, psi 
                 1500 
                 1100 
                 1000 
               
               
                   
                   
               
             
          
         
       
     
     
       
         
               
               
             
               
               
               
               
             
               
               
               
               
               
             
           
               
                   
                 TABLE 2 
               
             
             
               
                   
                   
               
               
                   
                 Well No. 
               
             
          
           
               
                   
                 Well-4 
                 Well-5 
                 Well-6 
               
               
                   
                   
               
             
          
           
               
                   
                 Injection Rate, 
                 50.1 
                 61.4 
                 60 
               
               
                   
                 bbls/min 
               
               
                   
                 IWHP, psi 
                 928 
                 663 
                 591 
               
               
                   
                   
               
             
          
         
       
     
     While the process of the invention has been described in detail above and illustrated in the accompanying drawings, modifications and variations will be apparent to those of ordinary skill in the art from this description and the scope of the protection to be accorded the invention is to be determined by the claims which follow.