SpecialReport: Horizontal Wellbore Construction FIGURE 6 Depth DAS and DTS Showing Successful Diversion Time or an acceleration of the dominant fracture. Validation Tools Well C included a borehole pressure gauge to allow for a high-quality post- 64 THE AMERICAN OIL & GAS REPORTER completion interference test with offset wells B and D. Pressure and gas rates were monitored to quantify the amount of interaction between the wells at the current spacing, and wells B and D were shut in for a period of time with no increase in production in the C well. The results from the interference test suggest that the wells are not in communication with one another, with no effective production impact and minimal pressure communication. Given the lack of observed well-to-well communication, it was determined that effective fracture half-lengths do not overlap between bounding wells B and D and middle Well C. The lack of interference between the wells led to increased well density in future spacing pilots. An oil-soluble tracer and a fracture fluid identifier were introduced to the formation during stimulation to provide insight to propped and hydraulic geometries. The fracture fluid identifier was recovered in the well offsetting the treatment well, but oil-soluble tracer was not recovered in the offset. Based on an assumed symmetric fracture half-length, the hydraulic halflength exceeds 0.5 times the lateral well spacing, and propped half-length is less than 0.5 times the lateral well spacing. Rate transient analysis was performed on Well C after three months of productionhttp://www.platts.com/pipeline