New approach to productivity calculation of horizontal wells with multiple hydraulic fracturing taking into account the fracture trajectories under ultra-dense infill drilling conditions

UDK: 622.276.66сг

DOI: 10.24887/0028-2448-2026-3-42-49

Key words: geomechanical modeling, well productivity, brownfield, hydraulic fracture, hydraulic fracturing, multistage hydraulic fracturing, fracture trajectory, fracture interaction, formation stress state, pressure gradient

Authors: A.I. Fedorov (Branch of RN-GRD in Ufa – BashNIPIneft, RF, Ufa); N.R. Kondratieva (Branch of RN-GRD in Ufa – BashNIPIneft, RF, Ufa); M.R. Minibaev (Branch of RN-GRD in Ufa – BashNIPIneft, RF, Ufa); V.P. Miroshnichenko (RN-Yuganskneftegaz LLC, RF, Nefteyugansk); G.A. Schutsky (RN-Yuganskneftegaz LLC, RF, Nefteyugansk); A.V. Sergeychev (Rosneft Oil Company, RF, Moscow)

Under conditions of increased density of infill drilling, a critical issue is assessing the interference between new and existing wells. This paper presents a new approach to evaluating the productivity of horizontal wells, accounting for fracture trajectories during refracturing operations in densely drilled areas. With high well density and long-term production, hydraulic fracture trajectories become sensitive to both the pressure gradient in the target zone and to pre-existing, propped fractures from earlier stages. Considering these factors enables a more reliable productivity forecast and helps to identify the risks of fracture-driven interactions (fracture hits) with offset wells. In some cases, this enables to adjust fracturing parameters to achieve the desired geometry under conditions of highly heterogeneous local pressure and stress distribution. Fracture trajectory modeling was performed using a module developed as part of an innovative project at Rosneft Oil Company. Well productivity was assessed by integrating predicted fracture orientations for two completion methods: open hole and cemented plug-and-perf (PnP). Both technologies are applicable in formations with either low or high in-situ stress contrast. The study demonstrates that the primary risk in low-contrast environments is fracture interference with neighboring wells, while in high-contrast environments the main risk is the inability to achieve the designed fracture geometry.

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