Control and Modeling of Fluid Leakoff During Hydraulic Fracturing
Authors: Penny Glenn S. , Conway Michael W. , Lee Wellington 
Published: December 2007

Summary
This work examines the variability in fluid leakoff rates measured under static and dynamic conditions. Laboratory-generated-data are compared to field-measureddata, and the conditions under which static and dynamic data should be used for fracture design are examined. Control of fluid leakoff in both the low-permeability matrix and highly permeable natural fractures is examined on formation cores under a variety of conditions. The control mechanism offered by various fluid-loss additives isevaluated by examining the fluid-matrix and fluid-filter-cake interactions.

Introduction
Fluid leakoff during hydraulic fracturing can exceed 70%of the injected volume if not controlled properly. A consequence of high leakoff can be the severe curtailment of production because of formation matrix damage, adverse formation fluid interactions, or altered fracturegeometry. An overwhelming amount of fluid can berequired to achieve a desired fracture geometry in a massive hydraulic fracturing treatment; thus, fluid efficiency cangovern the economic success of the treatment. A knowledge of the leakoff characteristics of aparticular formation is essential both to select proper fluid particular formation is essential both to select proper fluid loss control measures for the treatment and to predictfracture geometry. Advances in pressure analysis have made possible theestimation of formation fluid-leakoff rates from pressuredecline following injection. The method depends ona knowledge of gross fracture height; therefore, the method is best applied in formations with a large net permeable height. Using changes in fracture gradient to permeable height. Using changes in fracture gradient to estimate leakoff rates during pumping has been proposedrecently. Leakoff rates obtained from field measurements areimportant not only because they provide realistic numbersfor the prediction of fracture geometry and job design, but also because they provide a yardstick for laboratory measurements of leakoff and the development of fluid-loss control methods and additives. When such field data are not available, laboratory wall-building coefficient (C.) and spurt data are generated by applying the fluid in question to formation core samples. The conditions under which these tests are run candictate the resulting leakoff coefficient. Apart from effortsto simulate actual pumping conditions, wide variations canresult from simple static testing procedures. In the workdescribed herein, several factors affecting the outcomeof fluid-loss tests have been identified. Once those factors are controlled satisfactorily, various dynamic methodsof testing are compared. An attempt is made to correlate field-measured leak offdata with laboratory results. Both field and laboratory datashow the overriding influence of leakoff to natural fractures and/or high-permeability streaks. Once the highleakoff to these areas is curbed, leakoff to thelow-permeability matrix is influenced strongly by the shearrate within the fracture, particularly in high-rate jobs inthe early part of the pad where fracture widths arerelatively small. This can lead to changing leakoff ratesthroughout the treatment. To account for variations in C, during a treatment, Crawford 4 suggests multiplyinglaboratory values by a factor of. Characteristics of a particular formation can dictate the fluid-loss additive or combination of additives required to achieve necessary leakoff control. Particulate additivesare essential in controlling leakoff to high-permeability streaks or formations, while liquid hydrocarbon additives function well in low-permeability matrix control. The interaction of each of these additives with the formation and filter cake affects their performance. This work looks indetail at the interaction of hydrocarbon with complexed fluids and low-permeability formations.

Discussion
The leakoff rate during a hydraulic fracturing treatmenthas a marked effect on the final geometry of the fracture. With higher-efficiency fluids, less fluid is required toachieve a desired fracture length. For example, when thefracture is contained within zone, decreasing C., from0.001 to 0.0001 ft/min 1/2 [0.03 to 0.003 cm/min 1/2]increases the efficiency from 30 to 90%, and makes itpossible to use one-third as much fluid to achieve a desired possible to use one-third as much fluid to achieve a desired fracture length (Fig. 1). Using the same example, increasing fracturing fluidefficiency also increases closure time (Fig. 2). Ninety-percent fluid efficiencies alone become impractical, sinceit is desirable for the fracture to close on the proppantbefore gel degradation to minimize proppant settling. Ina large number of fracture treatments, where the fluidstability and/or break rate is tailored to 12 to 24 hours, fluid efficiencies of no greater than 70% are advisable.
JPT
P. 1071