Wellbore Hydraulics Optimizer
Analyze and optimize wellbore hydraulics for safe, efficient drilling operations
What You Can Do
You can perform comprehensive wellbore hydraulics analysis by inputting well geometry, fluid properties, and operational parameters. Claude calculates pressure drops across open hole and cased hole sections, determines equivalent circulating density (ECD) for narrow margin windows, identifies flow regime transitions, and provides optimization recommendations that balance ROP, hole cleaning, and well control margins. This enables you to validate designs, troubleshoot pressure anomalies, and make data-driven adjustments to flow rates and drilling fluid specifications before issues impact operations.
Features
computes friction losses across pipe sections, open hole, and annular geometries with full rheological effects
calculates equivalent circulating density for pore pressure and fracture gradient window validation
classifies laminar, transitional, and turbulent flow conditions and recommends velocity optimization
evaluates dynamic pressure effects during pipe connections, tripping operations, and planned pressure changes
validates transport ratios and settling velocity to predict cuttings transport efficiency in deviated wellbores
confirms available pump capacity meets system hydraulics requirements and identifies bottlenecks
accounts for washouts, tight spots, and gauge hole changes affecting pressure and flow behavior
evaluates hydraulics impact of lost circulation, equipment limitations, or operational constraints
Example Output
Scenario 1: Open Hole Section Optimization
- Input: 8.5" open hole at 3,500 ft MD, 12.5 ppg mud, 500 gpm pump rate
- Output:
- Annular pressure drop: 287 psi
- Flow regime: Transitional (turbulent developing)
- ECD at bottom: 13.2 ppg
- Recommendation: Increase to 600 gpm → annular velocity improves to 145 ft/min, ECD stable at 13.4 ppg, hole cleaning enhanced
Scenario 2: Pressure Anomaly Troubleshooting
- Input: Circulating pressure spike from 2,800 to 3,400 psi observed; 9.625" cased hole, 600 gpm baseline
- Output:
- Calculated baseline pressure: 2,795 psi ✓
- Pressure rise attributed to: 200 ft washout (10.5" equiv. diameter) in open hole below casing
- Adjusted ECD: 13.8 ppg vs. design 13.5 ppg (margin reduction identified)
- Action: Reduce flow to 520 gpm → restores ECD to 13.5 ppg and pressure to design baseline
Scenario 3: Narrow Margin Window Design
- Input: 7" cased hole, pore pressure 11.2 ppg, fracture gradient 12.8 ppg, 14 ppg mud required for shale stability
- Output:
- ECD margin: 0.8 ppg operational window
- Critical flow rate: 480 gpm maximum (ECD = 12.8 ppg at bottom)
- Recommended: 420 gpm operational rate with 0.2 ppg safety margin
- Contingency: If washout > 200 ft, reduce to 350 gpm or deploy bridging agent
What's Included
- SKILL.md: Complete instruction framework with wellbore hydraulics methodology and decision trees
- Hydraulics Calculation Template: Structured input format for well geometry, fluid properties, and operational parameters
- ECD Validation Checklist: Pre-well review checklist to confirm margin adequacy and identify risk zones
- Flow Regime Decision Matrix: Quick-reference guide for interpreting Reynolds number and flow behavior
- Scenario Analysis Worksheet: Framework for contingency planning and equipment limitation impact assessment
Who It's For
- Petroleum engineers — well planning, hydraulics design, and real-time well control support
- Drilling engineers — daily operations optimization, pressure trend analysis, and troubleshooting anomalies
- Well site leaders — rig floor decision-making on flow rate adjustments and contingency execution
- Subsurface engineers — pressure window validation and design constraint communication
- Drilling fluid specialists — mud system design and rheological requirement verification
Best For
- Pressure drop calculations across multiple well sections and geometry changes
- ECD determination in narrow pore pressure and fracture gradient windows
- Flow regime transition analysis and hole cleaning optimization
- Troubleshooting abnormal circulating pressures and pressure spikes while drilling
- Pre-well hydraulics simulations and pilot well contingency scenario modeling
- Pump capacity validation and system bottleneck identification
- Wellbore geometry impact assessment (washouts, tight spots, casing wear)
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