## 1 Introduction  
In the United States, wells drilled horizontally into tight oil and shale gas formations account for an increasing share of crude oil and natural gas production. By the end of 2018, about 96% of U.S. crude oil production in tight oil formations came from horizontal wells. In the Permian Basin, oil well density reaches up to 56 wells/km\({}^{2}\)[1]. In a typical design of section development of horizontal wells, the laterals have regular spacings and are aligned in consideration of the formation characteristics such as the in-situ principal stresses, permeability, and poroelasticity, etc. [2]. In the normal fault regime, hydraulic fractures (HFs) open in the direction of the minimum horizontal principal stress (\(\sigma_{\text{hmin}}\)-dir) and propagate in the direction of the maximum horizontal principal stress (\(\sigma_{\text{Hmax}}\)-dir). Therefore, an ideal horizontal well is designed to be parallel to the orientation of \(\sigma_{\text{hmin}}\) to induce \"transverse fractures\", i.e., perpendicular to the wellbore [3]. In general, transverse fractures provide a higher stimulated reservoir volume (SRV) than longitudinal fractures [4]. However, in the target field of this study, the Forty Niner Ridge field located in the Permian Basin in Eddy County, four horizontal wells were drilled orthogonally to each other from 2006 to 2014. In 2011, studies on the Barnett and Marcellus formations that analyzed the efficiency of hydraulic fracturing according to the drilling azimuth of a horizontal well were published [5, 6]. In fact, it was shown that in terms of the efficiency of the hydraulic fracturing treatment (hereinafter described as HFT) method, the more the horizontal wellbore deviated toward the \(\sigma_{\text{Hmax}}\) direction (\(\sigma_{\text{Hmax}}\)-dir), the lower the estimated ultimate recovery (EUR). Then, [PERSON] et al. (2016) conducted a performance comparison study of transversely and longitudinally fractured horizontal wells over varied reservoir permeability [7]. They found that horizontal wells with transverse fractures are preferable over the entire permeability range of their study (50 nD-5 mD) in oil reservoirs. However, the productivity was predicted assuming that the fractures have the same physical properties and were placed either transversely or longitudinally. A hydraulic fracture induces a stress shadow (SS) in the surrounding rock; in turn, the increased stress causes a reduction in width for an adjacent HF that propagates within the stress shadow effect (SSE) region or causes the fracture path to change [8; 9; 10; 11]. [PERSON] et al. (2014) used downhole geophones to monitor microseismic events associated with hydraulic fracturing in horizontal wells with different completion stage spacings in the Middle Bakken Play and the Utica Play. They found that hydraulic fractures in closely spaced stages interfere with each other by cyclically bouncing out-of-zone. In addition, the authors attributed the bouncing phenomena to the SSE that accumulated stress forced subsequent fractures preferentially propagate upward, which could have a significant impact on the production-efficient contact area as fractures could be created outside the target production area [12]. [PERSON] et al. (2019) deployed dual microseismic arrays to monitor fracture geometry in Vaca Muerta shale of North America and observed that due to the SSE among neighbor stages, the regional tectonic stress direction before hydraulic fracturing changed and the stress regimes varied between strike-slip and reverse faulting after the stimulation [13]. Several modeling approaches have been developed to simulate complex fracture networks [14; 15; 16; 17; 18]. [PERSON] et al. (2020) and [PERSON] et al. (2020) applied a phase-field fracture method, evaluated as robust and efficient, that predicted the propagation behavior of fractures in anisotropic heterogeneous material and the corresponding pressure changes [19; 20]. Meanwhile, [PERSON] et al.