Time is money in the drilling industry. Hallux Talon wants to help you optimize well production by providing products that can significantly increase productivity in high permeability formations by virtually eliminating polymeric damage caused by drill-in and drilling fluid.
Drilling fluid/mud is defined as the fluid used to lubricate the drill string, line, the walls of a well, flush cuttings to the surface and create enough hydrostatic weight to prevent blowouts. It is a special mixture of clay, water and chemical additives pumped downhole through the drill pipe and the drill bit. The mud cools the rapidly rotating bit, lubricates the drill pipe as it turns in the wellbore, carries rock cuttings to the surface and serves as a plaster to prevent the wall of the borehole from crumbling or collapsing. It also provides the weight or hydrostatic head to prevent extraneous fluids from entering the wellbore and to control downhole pressures that may be encountered.
Polymer Damage
Insufficient degradation of drill-in fluid filter cake can significantly impede flow capacity at the wellbore wall, potentially leading to reduction of the well productivity or injectivity. Formation damage, as well as filter cake impairment, must be eliminated to realize the full potential of horizontal completions. Past approaches to minimizing fluid damage have been the application of acids or strong oxidative breaker systems to dissolve filter cake solids and polymers.
Previous laboratory studies have demonstrated that drill-in fluid filter cake can be effectively removed through the application of a newly developed technique incorporating an enzyme-based polymer degradation system. This treatment can be designed to degrade xanthan-based, starch-based or cellulose-based drill-in fluid. Following degradation of the specific polymer, the weighting and/or fluid loss control material is easily removed using smaller, less costly acid treatments.
Case histories of wells treated with the new enzyme technology compared to direct offsets treated with conventional acid or oxidative breaker treatments are available. Field experience has shown that through utilization of this new technology, smaller, less costly treatments can be used to treat openhole intervals to zero-skin potential with dramatically improved treatment efficiency. Production results have indicated that three-fold increases are possible when applying a two-stage enzyme/acid treatment compared to acid treatments alone. Post-treatment production logs have indicated not only increased flow, but also flow throughout the entire openhole interval.
The wells evaluated in our study were drilled using either starch polymer, cellulose polymer or xanthan polymer and sized calcium carbonate. These clean “drill-in fluids” were introduced to minimize the damage to the wellbore when compared to that observed with conventional drilling fluids. Although used to minimize formation damage, testing and experience have shown that insufficient polymer degradation can significantly reduce flow capacity at the wellbore, leading to reduced well productivity or injectivity. Acid treatments are typically applied in attempts to remove or “by-pass” the damage created by the filter cake. These acid treatments are often marginally successful, particularly when applied in extended length intervals.
The recent development of new drilling techniques to maximize wellbore contact with productive intervals has been complimented by the parallel development of drill-in fluids. The drill-in fluids are formulated to provide the functionality of drilling muds to drill through the productive zone while minimizing the associated wellbore damage experienced with conventional drilling fluids.
The standard practice is to drill to the top of the payzone using the conventional muds and then switch to the cleaner drill-in fluids to drill through the pay. The drill-in fluids are typically comprised of either starch, cellulose or xanthan polymer and sized calcium carbonate or salt particulates. The starch or cellulose polymers provide viscosity for friction reduction and lubrication ,while the xanthan polymer enhances cutting transport capabilities. The particulates, which are removable, provide fluid loss control. Although drill-in fluids are inherently less damaging than the conventional drilling muds, relatively impermeable filter cakes are nonetheless still deposited on the borehole wall. Insufficient degradation of the filter cakes resulting from even these “clean” drill-in fluids can significantly impede flow capacity at the wellbore wall. This reduced flow capacity can result in significant reduction of the well productivity or injectivity. Formation damage from drilling fluid leaking off into the formation, as well as filter cake impairment, must be eliminated to realize the full potential of horizontal completions.
Find out more about our patent pending MuddAse™ systems.