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AbstractThe surface roughness of hydraulic fractures reflects the fracturing process at the tip. We did an experimental study of hydraulic fracture propagation, in which a characteristic roughness pattern was observed. This roughness developed without shear-or torsional loading in the plane of the pennyshaped fracture. The roughness showed to be determined by material properties and the externally applied stresses on the sample, which represent the effective in-situ stresses. We quantified the roughness, and showed that it correlated well with a measure of the plastic zone size around the fracture tip. New explanations for fracture surface roughness that develops under mode I loading conditions are presented. D.B. VAN DAM AND C.J. DE PATER SPE 56596fracture size to field scale. Depending on the processes that take place, a length scale must be chosen. In our experiments, it is probably best to use the length scale obtained from the fracture toughness.Experimental set-up. We loaded our rock samples in a true triaxial compression machine with stiff loading platens in order to simulate effective in-situ stress states. As this is an open system, we can not apply pore pressure. We used 0.1 mm thick teflon sheets greased with vaseline to reduce friction between the sample and the loading platens. We measured the friction coefficient between the sample and loading platens for this configuration, and found that it is smaller than 1 % (see Ref . 7). This low value is probably caused by the vaseline forming a lubricating layer. The loading platens are mounted on spherical seats, greased with thick grease. The compression machine consists of three uniaxial frames, which move independently from each other. The sample size in our experiments is 0.30 m cubic. The created hydraulic fracture is penny-shaped and has a maximum radius of approximately 0.10 m. Fig. 1 shows a schematic picture of the set-up. The hydraulic fracture is oriented transversely to the wellbore wall, which was sealed with a 0.5 mm thick glue layer. A 3 mm deep notch was sawn in the wellbore wall to control the fracture location. The wellbore radius is 1.15 cm. The confining stress σ c perpendicular to the plane of the fracture is always smaller than both stresses σ h directed parallel with the fracture plane, which have equal values. The deviation of the stress inside the block from the expected value is smaller than 10 %.During fracture propagation, a high pressure pump injects fluid into the wellbore, at whose end a dead string is mounted where the wellbore pressure is measured. An LVDT, mounted with clamps in the wellbore, measures the fracture width with a measuring error of approximately 10 %. The fracturing fluid we use is silicon oil which behaves approximately Newtonian at the shear rates of interest. We did a number of propagation tests, which showed a good reproducibility (see Refs. 7 and 8).We also performed ultrasonic measurements, which yield information about the fracture radius and width 1,7,9