Shale Reservoir Decline Lab - Unconventional Well Production & Frac Simulator

Completion Design Kura Shale

Lateral Length 7,500 ft Horizontal wellbore length drilled into target organic-rich shale formation.

Fracture Stages 30 stages Plug-and-perf isolated intervals along lateral length.

Proppant Intensity 2,200 lb/ft Ceramic/sand proppant pumped to maintain conductive fracture aperture.

Net Injection Pressure 9,800 psi Surface treating pressure exceeding minimum horizontal stress $\sigma_{h,min}$.

Matrix Permeability 250 nD Nanodarcy-scale tight rock permeability driving matrix-to-fracture flow.

Arps $b$-Factor (Decline Curvature) 1.25 Hyperbolic transient parameter reflecting long-lived linear flow in tight shale.

STIMULATED RESERVOIR VOLUME: ACTIVE SPACING: 250 FT / STAGE

Peak Rate (IP30)

1,840 BOE/D

30-Yr EUR (Recovery)

1.42 MMBOE

Frac Half-Length ($x_f$)

385 ft

Break-Even WTI

$38.40 /bbl

Production Decline Profile (BOE/Day over 360 Months) Log-Scale Rate

Cumulative Estimated Ultimate Recovery (EUR) Cumulative MBOE

Wellbore stimulation converged. 30 fracture stages propped across 7,500 ft lateral.

Unconventional Physics & International Expansion Mechanics

As energy majors like ExxonMobil export high-efficiency Texas hydraulic fracturing workflows to international frontier shale plays—including Azerbaijan’s overpressured Middle Kura Basin and Argentina’s Vaca Muerta—subsurface engineers model the coupling between stimulated reservoir volume (SRV), natural fracture discrete networks (DFN), and transient linear flow decline.

1. PKN / KGD Fracture Propagation Hydraulic fractures propagate perpendicular to the minimum in-situ horizontal stress ($\sigma_{h,min}$). Higher net injection pressure increases fracture half-length ($x_f$) and height ($h_f$), while proppant intensity guarantees long-term fracture conductivity ($k_f w$) against rock closure stress.

2. Arps Hyperbolic Transient Decline Because nanodarcy shale rock permits only ultra-slow fluid diffusion, wells exhibit prolonged linear flow ($b > 1.0$) lasting 3 to 7 years before transitioning to boundary-dominated flow. The hyperbolic equation $q(t) = q_i / (1 + b D_i t)^{1/b}$ predicts 30-year recovery curves.

3. Overpressure & International Capex Basins like the Middle Kura feature high pore-pressure gradients (>0.75 psi/ft), yielding explosive initial rates (IP30) but demanding heavier proppant and robust surface pumps. International development requires evaluating drilling costs against WTI break-even economics.