Organic shale reservoirs have very low matrix permeabilities. An extensive conductive hydraulic fracture network is necessary to impose a pressure drop in the formation to produce hydrocarbons at an economic rate. In addition, horizontal wells permit the initiation of multiple hydraulic fractures within the reservoir section of the organic shale. The location of the lateral landing point can have a significant impact on hydraulic fracture geometry.

The stimulated fracture system is influenced by the extensive horizontal laminations that are pervasive in shale reservoirs. The laminations will strongly influence the hydraulic fracture height because of the difference in rock mechanical properties measured normal and parallel to the bedding planes. In order to accurately predict fracturing height from logs in this environment, these mechanical property differences must be taken into account.

A series of sonic logs have been run in organic shales and the stress profile generated from these logs has been estimated, accounting for the difference in mechanical properties in the vertical and horizontal directions. This stress profile has been calibrated to measured closure stresses acquired in-situ via micro-fracturing of multiple intervals in vertical, openhole environments. The results show that ignoring the impact of mechanical property anisotropy can lead to significant errors in the estimation of hydraulic fracture height. Correspondingly, the optimal landing point of a horizontal wellbore may not be selected when ignoring this effect. This can result in excessively high fracture initiation pressures, difficulty achieving injection rate or proppant placement, and unexpected fracture height growth. Simulations of hydraulic fracture width indicate that thin high-stress intervals can create pinch points that limit vertical fracture conductivity. Each of these factors can result in un-optimized hydrocarbon productivity.