Engineering tools,
ready to use.

Arps DCA — exponential, hyperbolic, harmonic, and linear decline. Input production history, get b-factor, Di, and EUR automatically. Filter by well or field.

Field-level gas & oil well surveillance dashboard. For gas wells: Coleman-Turner critical rate, Arps DCA, liquid loading detection, intermittent producer detection. For oil wells: water cut & WOR trends, Reciprocal Rate Method & Ershaghi X-plot for reserves/EUR, Chan diagnostic (coning vs channeling auto-classification). Monitors well health states — Stable, Warning, Critical, Shut-in — with intervention recommendations and autonomous AI alerts. Password-protected.

Three coupled physics layers in one canvas: reservoir material balance (multi-tank with inter-layer transmissibility), well inflow (Darcy + Nodal calibrated from multi-rate tests), and surface gathering network (Weymouth pipes + Cullender-Smith VLP propagating backpressure from sales meter to wellhead). Build the field topology by dragging components onto the canvas; upload real history CSVs to calibrate each component; forecast the whole system end-to-end. No empirical decline curves — every rate is physics. 100% client-side, sub-second forecast for 50-well networks.

Upload pressure–production history (CSV or Excel) and the tool computes Z-factor, fits P/Z, auto-detects the drive mechanism, and projects OGIP and recovery factor at your chosen abandonment pressure. Cole plot with Fetkovich aquifer auto-fit for water drive; Roach correction for geopressured / HPHT cases; Wichert–Aziz handling for sour gas. All client-side — no data leaves your browser.

Complete production system analysis: IPR (Linear, Vogel, Fetkovich, Backpressure) meets VLP (Beggs-Brill, Hagedorn-Brown) at the operating point. Full PVT correlations (Standing, Dranchuk-Abou-Kassem, Lee-Gonzalez-Eakin), choke models (Gilbert, Achong), pressure traverse, and sensitivity sweeps across tubing ID, wellhead pressure, choke size, reservoir pressure, water cut, and GOR. Diagnose whether the well is IPR-dominated, VLP-dominated, or balanced. 100% client-side.

Upload production time-series (CSV or Excel) and the tool recovers contacted in-place plus permeability and skin — all from flowing data. Flowing material balance returns OGIP/OOIP across gas, oil and gas-oil (solution-gas-drive two-phase MBE) systems; Blasingame split uses the transient infinite-acting period for k and boundary-dominated flow for skin, with radial superposition time so variable-rate data analyses correctly. Real-gas pseudo-pressure m(p) and pseudo-time throughout; honest non-convergence when the depletion signal is too weak rather than a fabricated number. 100% client-side.

Six-method rock typing in one dashboard: Winland R35, FZI / HFU (Amaefule), PGS (Permadi–Susilo / Wibowo–Permadi / Hakiki), Modified Lorenz Plot (Gunter), Leverett J-function, and ML log-based classifier (kNN with leave-one-out CV). Upload core data, get pore-type populations, heterogeneity scores, flow-unit detection per well, and AI-generated interpretation narratives. Each method ships with an expert guide modal explaining theory, equations, and trade-offs. 100% client-side computation. Companion tool to the Rock Typing Reimagined blog article. Password-protected (shared sign-in with GWIS / Nodal).

Systematic Enhanced Oil Recovery candidate selection using established screening criteria from Taber, Martin & Seright (1983) SPE-12069, NPC (1984), and Green & Willhite (1998) SPE Textbook Vol. 6. Eight EOR methods scored against eight reservoir parameters — CO₂ Miscible, N₂ Miscible, HC Miscible, WAG, Steam Flooding, In-Situ Combustion, Polymer Flooding, Surfactant/ASP. Each parameter scored against published acceptable and ideal ranges. Disqualification logic auto-applied when any parameter falls outside absolute bounds. Expandable parameter breakdown per method with individual scores. 100% client-side.

Probabilistic OGIP/OOIP estimation with Monte Carlo simulation. Define input parameter distributions (Triangular, Normal, Lognormal, Uniform) for area, net pay, porosity, water saturation, formation volume factor, and recovery factor — then get P10/P50/P90 reserves with histogram, CDF, and tornado sensitivity. Supports multi-zone aggregation (independent LHS sampling per zone). 10,000 trials by default, configurable up to 100k. 100% client-side, deterministic seeding for reproducibility.