**1. Introduction**

The recent findings of the Hydraulic Fracturing Test Site I industry consortium (HFTS 1) are well summarized in the September 2018 *Journal of Petroleum Technology*  article titled "*Real Fractured Rock is So Complex it's Time for New Fracturing Models*" [1]. 600 ft. of core taken in a hydraulically fractured Wolfcamp reservoir in the Permian Basin, USA showed a more complex reality than what is accounted for in most hydraulic fracturing design and analysis software. This includes the interaction between hydraulic and natural fractures, which is largely ignored or poorly accounted for in most software currently used to model hydraulic fractures and their resulting geometry. Rassenfos [1] emphasized in his summary of multiple recent publications describing HFTS 1 findings, that the "*fracture height is overrated.* 

*While microseismic testing indicated that fractures grew up about a 1000ft, the height of the propped fractures- the fractures most likely to produce oil and gas was about 30ft*." Rassenfos [1] summary article discusses the important role played by the natural fractures but misses multiple other challenges facing the realistic modeling of hydraulic fracturing. Among the most noticeably and urgent challenges is the lack of data to better characterize the key inputs needed by any hydraulic fracturing modeling approach and the role of interfaces and their impact on vertical fracture growth.

The nature of the unconventional revolution, and ensuing extensive use of hydraulic fracturing, is the prevalent belief that the majority of the wells need to be drilled and stimulated in a "factory mode" where useful data such as wireline logs are not acquired at a statically significant rate. This philosophy, exhibited by many major unconventional players, has left a void of data in most major fields, greatly undermining optimization efforts necessary to economically produce said fields. A solution exists in the use of surface drilling data, which is available at every well. These drilling data are acquired by all drilling contractors around the world and are used qualitatively and quantitively during drilling operations. The surface drilling data include torque (T), rate of penetration (ROP), weight-on-bit (WOB). Since this drilling data is available at any old, current and future well and most operators dealing with unconventional reservoirs are not acquiring wireline logs at all the wells, the authors investigated the possibility to estimate pseudo-logs from surface drilling data. Using surface drilling data to infer rock properties, pore pressure, and stresses, comes with multiple challenges, which when overcome, open the door to improvements to the physics used in modeling hydraulic fracturing.
