Well Performance Optimization Analyzer
Diagnose well performance issues and generate quantified optimization recommendations
What You Can Do
This skill systematizes well performance analysis by organizing production metrics, pressure surveys, and operational data into structured diagnostics. You input well data and operational parameters, and Claude identifies underperformance drivers—from mechanical constraints to fluid property issues—then generates ranked optimization recommendations with quantified economic justification. Each proposal includes projected incremental production, estimated intervention costs, and implementation priority based on recovery potential.
Features
identifies performance bottlenecks from pressure drops, fluid properties, mechanical constraints, and operational factors using nodal analysis principles
prioritizes intervention candidates by economic impact, comparing workover costs against incremental recovery volumes and timeline to abandonment
forecasts production trajectories and well economic limits to inform intervention urgency and workover timing decisions
analyzes bottomhole surveys and pressure test data to diagnose skin damage, permeability reduction, or wellbore flow restrictions
quantifies recovery uplift and ROI for specific treatments (chemical stimulation, tubing reduction, artificial lift conversion, perforation optimization)
traces recent production changes to operational modifications, equipment failures, or fluid chemistry shifts with diagnostic decision trees
evaluates multiple wells simultaneously to allocate limited intervention resources to highest-return opportunities
Example Output
Example 1: Pressure-Limited Well Optimization
Input: Well producing 150 bbl/day at 800 psi flowing pressure; offset well producing 320 bbl/day at same depth.
Analysis Output:
- Root Cause: Wellbore skin factor +4.2 (likely scale/paraffin damage); permeability reduction vs. offset well
- Primary Recommendation: Bullheading acid treatment (cost $45K) → projected recovery 85 bbl/day incremental → 18-month payback
- Secondary Options: Reduce tubing diameter (cost $120K) → recovery potential 120 bbl/day if skin cannot be removed
- Economic Case: Continue current decline → abandonment in 3.2 years (NPV $180K); acid treatment → extends economic life to 5.1 years (NPV $580K)
Example 2: Decline Analysis & Workover Prioritization
Input: 12-well portfolio with declining production; limited capital for 3 workovers this year.
Analysis Output:
- Well A: Mechanical restriction (tubing grade failure); 210 bbl/day recovery potential; $95K cost; 7-month payback → Priority 1
- Well B: Depleting permeability trend; 65 bbl/day recovery potential; $180K stimulation; 18-month payback → Priority 2
- Well C: Natural decline trajectory; 30 bbl/day recovery; 24-month payback → Defer (schedule for Q4)
Example 3: Artificial Lift Economics
Input: Flowing well with 280 bbl/day production; declining below 150 bbl/day within 8 months; bottomhole pressure trending toward static reservoir pressure.
Analysis Output:
- Problem: Insufficient pressure gradient; natural flow ending within 8 months
- Recommendation: Install ESP (cost $280K) → sustain 180 bbl/day for 3+ years; 14-month payback; prevents 4-month production loss during conversion
- Alternative: Rod pump option (cost $140K) → sustained 150 bbl/day; 11-month payback; accept 30 bbl/day loss vs. ESP
- Timeline: Install within 6 months to avoid production gap and equipment mobilization delays
What's Included
- SKILL.md: Complete instruction file with well performance analysis methodology
- Well Data Analysis Template: Structured spreadsheet/checklist for organizing production metrics, pressure surveys, and fluid sample data
- Nodal Analysis Framework: IPR (inflow performance relationship) diagnostic checklist and pressure drop calculation reference
- Optimization Recommendation Matrix: Decision framework ranking interventions by recovery potential, cost, and implementation timeline
- Decline Curve Projection Worksheet: Production forecast template for economic limit and abandonment scenario analysis
Who It's For
- Petroleum Production Engineers — diagnosing underperforming wells and preparing optimization proposals for operations planning
- Well Optimization Specialists — conducting systematic well audits and identifying intervention candidates across asset portfolios
- Production Supervisors/Foremen — evaluating workover priorities and economic justification for capital allocation decisions
- Reservoir Engineers — supporting field-level production enhancement initiatives and well remediation case studies
- Asset Managers — comparing well intervention ROI across portfolios and forecasting production impact of optimization spending
Best For
- Diagnosing sudden production declines and tracing root causes to mechanical, fluid, or operational factors
- Prioritizing workover candidates across a portfolio using cost-benefit and economic limit analysis
- Interpreting pressure transient tests and bottomhole surveys to quantify skin damage and flow restrictions
- Evaluating economic payback periods for specific interventions (stimulation, tubing changes, artificial lift conversion)
- Forecasting well decline trends and establishing abandonment timelines to inform long-term planning
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