Engineering Excel files for your workflow

Core plug data to rock types: least-squares k–φ transform, RQI/FZI rock typing, Winland R35 and Pittman R25, five permeability transforms compared against core, and Lorenz, Dykstra-Parsons and Gini heterogeneity.

Systematic QC for every curve in your log suite: quality ratings and range flags computed from the data, depth coverage and casing-shoe checks, N-D, M-N and GR-density crossplots, histograms, and an environmental corrections checklist.

Four Vshale methods, a 5×5 cutoff sensitivity heat map, and Thomas-Stieber shale distribution analysis, all from your GR and porosity logs.

Full Sw toolkit: dual-method calculation, Pickett crossplot with Sw iso-lines, Buckles BVW plot, cementation exponent sensitivity, and Indonesia shaly-sand comparison.

Find the bulk core-to-log depth shift by cross-correlation, check porosity before and after the shift with bias, RMSE, max error and R², and QC power-law and Winland permeability transforms against core.

Determine OOIP and OGIP from production/pressure history using Havlena-Odeh, P/z straight-line, and drive energy index methods in one integrated workbook.

All four Arps methods with a terminal-decline switch, nominal or secant-effective decline input, rate-cumulative plots, Monte Carlo P90/P50/P10 EUR, and a live EUR sensitivity matrix.

Deterministic OOIP/OGIP for four zones with a ±25 % low/high case, a 1,000-trial Monte Carlo giving P90/P50/P10 OOIP for a zone, and a Bg vs pressure PVT table.

Full pressure buildup analysis suite: Horner, log-log diagnostic with Bourdet derivative, an independent MDH check, and a radius-of-investigation calculator.

Identify your reservoir energy source with four material-balance drive indices, track GOR and WOR, estimate recovery factor by mechanism, and quantify permeability heterogeneity with the Dykstra-Parsons coefficient.

Full-cycle well economics: 20-year DCF, NPV10/NPV15, payout period, F&D cost, oil price sensitivity ($30–$120/bbl), and three-scenario side-by-side comparison.

Track a well AFE line by line: budget vs actual and committed, a flag and severity on every line, forecast at completion, a revised AFE that includes approved change orders, and live earned value (CPI, SPI, EAC, ETC, VAC).

Track monthly LOE by five cost categories, split fixed and variable cost, calculate NOI and NOI margin, and compare your $/BOE with an illustrative seven-basin benchmark table.

Quantify geological chance of success as a five-factor product, risk EUR and NPV, run a decision tree EMV with DRILL/NO-DRILL calls, and find the risk factor that drives COS with a tornado diagram.

Wireline MDT and RCI station analysis: pressure–TVD gradients, fluid contacts, mobility-based permeability estimates, and a one-page summary, all formula-driven Excel.

Convert lab Pc–Sw data to a saturation-height model with J-function normalization, a model-vs-log Sw check at the FWL, and Leverett crossplots, auditable capillary pressure workbook.

Interpret NMR T2 distributions: partition clay-bound, capillary-bound (BVI) and free-fluid (FFI) porosity, estimate permeability with Coates and SDR models, and QC against conventional porosity.

Full PVT correlation suite: Rs, Bo, dead and live oil viscosity, gas Z-factor and Bg, from API gravity, gas gravity and temperature.

Fit Corey exponents to lab Kr data by least squares with the end points honoured, see the true fit error, compare exponent pairs, and check hysteresis, crossover and a screening wettability indication.

Screening-grade production nodal analysis: composite PI/Vogel IPR, a no-slip VLP computed down the tubing, a solved operating point, and live WHP and tubing ID sensitivity. Not well test transient analysis.

Estimate aquifer water influx with Carter-Tracy and Fetkovich models, compare results, and link to material balance drive energy, dedicated aquifer workbook.

Track waterflood pattern performance: monthly WOR, instantaneous and cumulative voidage replacement ratio from reservoir volumes, recovery factor against the pattern's hydrocarbon pore volume with the implied sweep, and like-for-like benchmark targets.

Screen well spacing and drainage area from DSU geometry and well coordinates: nearest-well drainage partition with a colour map, equivalent drainage radius, spacing sensitivity for vertical grids or horizontal laterals, lease-line setback checks and live interference flags. A geometric tool, no reserves or DCF.

Screen rich gas and condensate fluids: Nemeth-Kennedy dew point from composition, Hall-Yarborough z and a Bg table, and screening estimates of CGR and retrograde liquid dropout below the dew point.

Calculate NRI from working interest and the burden stack (lessor royalty and ORRIs), and split revenue across a full deck that totals 100%, without a full DCF model.

Allocate AFE costs by partner WI, reconcile billed vs calculated shares, and audit JOA joint account billing: partner accounting, not earned-value AFE tracking.

Estimate oil and gas severance tax by US state with built-in rate tables, monthly production input, and annual effective rate benchmarking.

Allocate commingled tank battery volumes to individual wells from well tests corrected for test hours and days on, with a measured-vs-theoretical proration check per stream and oil/water/gas reconciliation QC.

Score plays on trap, reservoir, charge, and seal elements, then rank them by risked resource (play chance × volumetric recoverable resource): play-level screening, not single-prospect COS/EMV.

Weighted multi-criteria matrix for basin entry decisions: resource, cost, infrastructure, and regulatory scores with proceed/hold/exit gates.