Patent Abstract:
The present invention relates to water-based drilling fluids having decreased corrosion properties which comprise, in addition to alkali metal carboxylates, boron compounds and, if appropriate, clays, polymers and coinhibitors.

Full Description:
FIELD OF THE INVENTION 
     The present invention relates to an alkali-metal-carboxylate-containing drilling fluid which has decreased corrosive properties due to the addition of boron compounds. 
     DESCRIPTION OF THE RELATED ART 
     When deep drilling is carried out, generally use is made of suspensions of clay in salt water for discharging the cuttings. These drilling fluids further comprise polymers for forming protective colloids, as well as weighting materials, such as barite or chalk. These weighting materials, as solids, can adversely affect the Theological properties of the drilling fluids. Therefore, the prior art also includes soluble weighting materials. As such, use is made of alkali metal halides and alkaline earth metal halides, zinc bromide and alkali metal carboxylates, in particular formates, acetates and propionates of potassium and sodium. These salts exhibit a high solubility in water, and it is possible to prepare from them aqueous solutions of high density which nevertheless have a low viscosity. 
     J. D. Downs, SPE Paper No. 25177 discloses the use of alkali metal formates in drilling fluids. EP-A-0 572 113 discloses the use of potassium carboxylates and cesium carboxylates as drilling fluid aids. 
     Alkali metal carboxylates, however, have a serious disadvantage in certain cases in industrial use. When drilling passes through rock strata which comprise naturally occurring inorganic ion exchangers, such as zeolites, free carboxylic acids form from the carboxylates. The free carboxylic acids can lead to considerable corrosion on the drilling tools, in particular, since the drilling is carried out at high temperature. 
     The object of the present invention was thus to provide alkali-metal-carboxylate-containing drilling fluids which cause reduced corrosion on drilling tools. 
     Surprisingly, it has been found that the addition of boron compounds to alkali-metal-carboxylate-containing drilling fluids greatly decreases their corrosivity to metallic materials. 
     SUMMARY OF THE INVENTION 
     The invention relates to a water-based drilling fluid which comprises at least one alkali metal carboxylate and at least one soluble boron compound. 
     The invention further relates to the use of boron compounds in drilling fluids which comprise alkali metal carboxylates to decrease the corrosivity of these drilling fluids. 
     Alkali metal carboxylates are salts of lithium, sodium, potassium, rubidium or cesium with monobasic or dibasic carboxylic acids. Preferred carboxylic acids in this case are formic acid (alkali metal formates), acetic acid (alkali metal acetates) and propionic acid (alkali metal propionates). Preferred alkali metals are sodium, potassium and cesium. 
     DESCRIPTION OF THE PREFERRED EMBODIMENTS 
     Particular preference for the drilling fluids according to the invention is given to the alkali metal formates and here, particularly, potassium formate. 
     The corrosive properties of the alkali metal carboxylates are diminished by boron compounds. Preferably, the boron compounds are boric acids, borates, boron oxide or organic boron compounds. 
     Suitable boric acids are, in particular, orthoboric acid B(OH) 3 , metaboric acid HBO 2  and complex boric acids which are obtainable by adding polyhydric alcohols (e.g. mannitol) to orthoboric acid. 
     As borates, preference is given to salts which comprise meta(BO 2   − ), ortho(BO 3   3− ), poly(B n O 2n−1   (n−2)− ) or per(BO 3   − ) borate ions. Among the polyborates, tetraborates are particularly preferred. As cations, preference is given to Na + , K + , Mg 2+ , Ca 2+  and NH 4   + . Examples of preferred berates are sodium tetraborate, potassium tetraborate, calcium metaborate, potassium metaborate and sodium perborate. 
     Suitable organic boron compounds are those which do not have a tendency to spontaneous decomposition in an aqueous medium. Those which are suitable in particular are esters of boric acid with monohydric or dihydric alcohols, such as trimethyl borate, boric monoethanolamine ester or boric triethanolamine ester. 
     The amount of alkali metal carboxylates present in the drilling fluid is determined according to the type of the alkali metal carboxylate and according to the type and amount of the other constituents of the drilling fluid. Preference is given to an amount of alkali metal carboxylates which corresponds to 30 to 100% of the saturation level in the drilling fluid. 
     The drilling fluid according to the invention can also comprise other constituents, in addition to alkali metal carboxylates and boron compounds. 
     In a preferred embodiment, the drilling fluid according to the invention comprises clays to modify the viscosity. The clays can be added to the drilling fluids, or the clays can be bored solids. Among the clays, in particular, preference is given to those whose main constituents are magnesium silicate or aluminum silicate (bentonites). They are preferably used in amounts of from about 10 to 150 g/l of drilling fluid. 
     In a further preferred embodiment, the drilling fluid according to the invention comprises polymers of natural or synthetic origin which are capable of forming protective colloids. Such polymers are, for example, cellulose ethers, such as hydroxyethyl cellulose or salts of carboxymethyl cellulose or carboxymethyl hydroxyethylcellulose, starch and its derivatives and biopolymers (for example XC polymer, manufacturer: KELCO). Cellulose derivatives correspond, for example, to the formula                           
     where 
     R 1  is —CH 2 —(OC 2 H 4 ) n —OH where n=1 to 5 or —CH 2 —OCH 2 COO □  and R 2  and R 3  independently of one another are hydrogen or —(C 2 H 4 O) n —H where n=1 to 5. X is preferably of a value such that the mean molecular weight of these cellulose derivatives is between 10,000 and 1,000,000 units. 
     If, in the drilling fluid according to the invention, use is made of synthetic polymers, these are generally homopolymers or mixed polymers of ethylenically unsaturated compounds. Preference is given to those polymers which comprise structural units which can be derived from acrylic acid or its derivatives. In addition, preference is given to those polymers which comprise structural units which can be derived from vinyl-containing compounds. 
     Examples of monomers which can be used to prepare suitable polymers include: (meth)acrylic acid and its esters, (meth)acrylamides, acrylamidomethylpropanesulfonic acid, N-vinylpyrrolidone, acrylonitrile, N-monosubstituted and N-disubstituted (meth)acrylamides, acrylamidosulfonic acids, acrylamidobutyric acid, N-methyl-N-vinylacetamide, hydroxyalkylacrylates, vinylsulfonic acid, vinylcarboxamides. 
     If the drilling fluids according to the invention comprise polymers, the concentration of these polymers in the finished drilling fluid is preferably between 0.5 and 70 g/l, in particular from 3 to 30 g/l. 
     In a further preferred embodiment of the invention, the drilling fluid comprises a coinhibitor which intensifies the action of the boron compound used according to the invention. Preferred coinhibiters are alkali metal carbonates, alkali metal silicates, mono- and dicarboxylic acids, alkali metal benzoates, benzotriazoles, tolyltriazoles, alkali metal nitrites and alkali metal nitrates. Preferably, the coinhibitors are used in amounts of from 0.5 to 4% by weight, based on the weight of the finished drilling fluid, in particular in amounts of from 1 to 3% by weight. 
    
    
     EXAMPLES 
     Results are shown below which confirm the suitability of the drilling fluid according to the invention. 
     For all experiments, a drilling fluid was prepared comprising 
     
       
         
               
               
               
             
           
               
                   
                   
               
             
             
               
                   
                 350 ml 
                 of potassium formate solution 50% 
               
               
                   
                 3% by weight 
                 of SWDC (salt water drilling clay) 
               
               
                   
                 3% by weight 
                 of Rev-Dust ® (simulated cuttings solids) 
               
               
                   
                 3% by weight 
                 of polymer of the type specified in the table. 
               
               
                   
                   
               
             
          
         
       
     
     Corrosion protection: 
     1=1% by weight of borax+2% by weight of K 2 CO 3    
     
       
         
               
             
               
               
               
             
               
               
               
               
               
               
               
             
           
               
                 TABLE 1 
               
             
             
               
                   
               
               
                 Viscosity of drilling fluids in mPas 
               
             
          
           
               
                 Corrosion 
                   
                 Polymer 
               
             
          
           
               
                 protection 
                 Test conditions 
                 Absent 
                 CMC LV 
                 CMHEC LV 
                 VS-VA copolymer 
                 Starch 
               
               
                   
               
               
                 none 
                 16 h/125° C. 
                 26 
                 53 
                 130 
                  83 
                 122 
               
               
                 1 
                 16 h/125° C. 
                 40 
                 90 
                 124 
                 102 
                 164 
               
               
                 none 
                 16 h/150° C. 
                 34 
                 52 
                 120 
                  77 
                  58 
               
               
                 1 
                 16 h/150° C. 
                 56 
                 82 
                 143 
                  78 
                  91 
               
               
                 none 
                 16 h/170° C. 
                 41 
                 33 
                 104 
                 155 
                  26 
               
               
                 1 
                 16 h/170° C. 
                 42 
                 78 
                 112 
                 179 
                  76 
               
               
                 none 
                 16 h/200° C. 
                   
                   
                   
                  95 
               
               
                 1 
                 16 h/200° C. 
                   
                   
                   
                 121 
               
               
                   
               
             
          
         
       
     
     
       
         
               
             
               
               
               
             
               
               
               
               
               
               
               
             
               
               
               
               
               
               
               
             
           
               
                 TABLE 2 
               
             
             
               
                   
               
               
                 API water loss in ml 
               
             
          
           
               
                 Corrosion 
                   
                 Polymer 
               
             
          
           
               
                 protection 
                 Test conditions 
                 Absent 
                 CMC LV 
                 CMHEC LV 
                 VS-VA copolymer 
                 Starch 
               
               
                   
               
             
          
           
               
                 none 
                 16 h/125° C. 
                 &gt;25 
                 4.7 
                 3 
                 8.3 
                 1.8 
               
               
                 1 
                 16 h/125° C. 
                 &gt;25 
                 6.5 
                 4.1 
                 9 
                 18 
               
               
                 none 
                 16 h/150° C. 
                  51 
                 5.5 
                 3.2 
                 9 
                 5.5 
               
               
                 1 
                 16 h/150° C. 
                  35 
                 15.5 
                 5.2 
                 12 
                 4.8 
               
               
                 none 
                 16 h/170° C. 
                 137 
                 22 
                 4.8 
                 4.4 
                 47.0 
               
               
                 1 
                 16 h/170° C. 
                 190 
                 27 
                 5.2 
                 5.3 
                 4.0 
               
               
                 none 
                 16 h/200° C. 
                   
                   
                   
                 4.5 
               
               
                 1 
                 16 h/200° C. 
                   
                   
                   
                 12.5 
               
               
                   
               
             
          
         
       
     
     
       
         
               
             
               
               
               
             
               
               
               
               
               
               
               
             
               
               
               
               
               
               
               
             
           
               
                 TABLE 3 
               
             
             
               
                   
               
               
                 Corrosion rate of the drilling fluid according to the invention on C-steel (DIN 1.1203) in mpy 
               
             
          
           
               
                 Corrosion 
                   
                 Polymer 
               
             
          
           
               
                 protection 
                 Test conditions 
                 Absent 
                 CMC LV 
                 CMHEC LV 
                 VS-VA copolymer 
                 Starch 
               
               
                   
               
             
          
           
               
                 none 
                 16 h/125° C. 
                 12.6 
                 10.2 
                 8.8 
                 40.5 
                 9.7 
               
               
                 1 
                 16 h/125° C. 
                 0.3 
                 0 
                 0 
                 0 
                 0.3 
               
               
                 none 
                 16 h/150° C. 
                 29.6 
                 24.3 
                 23 
                 35.2 
                 23.7 
               
               
                 1 
                 16 h/150° C. 
                 0 
                 0.3 
                 0 
                 2.4 
                 0.3 
               
               
                 none 
                 16 h/170° C. 
                 21.6 
                 35.6 
                 32.0 
                 59.6 
                 46.0 
               
               
                 1 
                 16 h/170° C. 
                 0.3 
                 0.3 
                 0 
                 10.4 
                 0.3 
               
               
                 none 
                 16 h/200° C. 
                   
                   
                   
                 135 
               
               
                 1 
                 16 h/200° C. 
                   
                   
                   
                 38 
               
               
                   
               
             
          
         
       
     
     
       
         
               
             
               
               
             
               
               
               
               
               
               
               
             
               
               
               
               
               
               
               
             
           
               
                 TABLE 4 
               
             
             
               
                   
               
               
                 Comparison of the properties for various concentrations of potassium formate 
               
             
          
           
               
                   
                 Polymer 
               
             
          
           
               
                   
                 Test conditions 
                 Absent 
                 CMS LV 
                 CMHEC LV 
                 VS-VA copolymer 
                 Starch 
               
               
                   
                   
               
             
          
           
               
                 Corrosion [mpy] 
                 Potassium formate 
                   
                 0 
                 0.3 
                 none 
                 0 
               
               
                   
                 solution 70% strength 
               
               
                 Viscosity [mPas] 
                 Potassium formate 
                   
                 94 
                 66 
                 soluble 
                 290 
               
               
                   
                 solution 70% strength 
               
               
                 API water loss [ml] 
                 Potassium formate 
                   
                 10 
                 42 
                   
                 2.8 
               
               
                   
                 solution 70% strength 
               
               
                 Corrosion [mpy] 
                 Potassium formate 
                  0 
                 0.3 
                 0 
                 2.4 
                 0.3 
               
               
                   
                 solution 50% strength 
               
               
                 Viscosity [mPas] 
                 Potassium formate 
                 56 
                 82 
                 143 
                 78 
                 91 
               
               
                   
                 solution 50% strength 
               
               
                 API water loss [ml] 
                 Potassium formate 
                 35 
                 15.5 
                 5.2 
                 12 
                 4.8 
               
               
                   
                 solution 50% strength 
               
               
                 Corrosion [mpy] 
                 Potassium formate 
                   
                 0 
                 0.3 
                 0 
                 0.3 
               
               
                   
                 solution 30% strength 
               
               
                 Viscosity [mPas] 
                 Potassium formate 
                   
                 74 
                 125 
                 66 
                 58 
               
               
                   
                 solution 30% strength 
               
               
                 API water loss [ml] 
                 Potassium formate 
                   
                 15.5 
                 5.3 
                 9.5 
                 36 
               
               
                   
                 solution 30% strength

Technology Classification (CPC): 8