Over 60 horizontal wells have been drilled and completed with slotted liners in Prudhoe Bay, Alaska using a low solids or solids-free clarified xanthan/brine drill-in fluid.As previously described the drill-in fluid demonstrates a functional true yield stress (TYSI in the circulating fluid.' The yield stress is also present in the filtrate. limiting depth of filtrate invasion.The fluid has been further described as being viscoelastic (VEI under stat!c conditions and at the low shear rates exisiting in an expanded plug flow region. This plug flow region is persistent over a wide range of flow rates and is a function of polvmer concentration and brine salinitv. The exhibits both time-indepent and pseudoplastic IS -MS s*~w~rn~by M IADt2spE PrOgrm COmmmee bWng -of inf-m contained in M fibWaCf uhffWDd W~W($). me matwml, u pmemad, does not nmca&llY mnecf any pmtim of me IAOC w SPE. tiw offcem c+ m~p-s v~@ lA~~pE m~lw~Or* wqec! IO puilKa!r2n revmw by EdficfiaI Commliieed of the IADC and SPE Perrmsmon 10 copy IS re$ltiti 10 an *W@ Of nof mom mm 300 ti% lthJ*rat~$ may noi M coped me abstract shodd conmn compcwus acknWd&gem~t ol where and by whom the P-IS pre$entti. Wtie bb~l~spE. p O~x -. Rchntism. TX 793-3. U.S.A. TOIW. 1~45 $pEuT
Historically, return permeability testing has become a standard to establish minimally damaging fluid properties. This single number is typically focused upon for its simplicity, however the testing procedure and intermediate data provide much more than just this value. The process provides insight into formation damage mechanisms and their overall impact on potential well performance.The variable nature of procedures and apparatus as well as interpretation of data is regularly limited to the percent return permeabilitya potentially misleading value in fluid selection. A thorough review of existing literature and experience on recent projects details the recognized potential for variability as well as misperceptions in interpreting results. Examples of test data are reviewed to capture damage mechanisms where fluid formulations require further optimization. In many cases conclusions are drawn and fail to identify why differences in the percent return permeability yields a particular result. Prior published work assessing formation damage tends to focus upon formation characteristics. This paper details the results and data typically provided with these analyses. These data include: fluid loss, initial return permeability, and techniques used to determine the damage mechanism. Test results are reviewed to illustrate where the risk of unwarranted conclusions occurs. Recommendations for appropriate analysis of both final return permeability and intermediate data are provided for optimized fluid design. Through the techniques discussed, testing procedures have the potential to provide the maximum insight into fluid-formation interactions on the core material available.
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