Drilling Kpi Analyzer

Drilling KPI Analyzer

What this skill does

Extracts, computes, and benchmarks drilling key performance indicators from daily drilling reports, morning reports, and bit records. Produces section-level and well-level performance summaries including ROP, MSE, flat time, NPT classifications, and cost per foot. Benchmarks against offset wells when context is provided.

When to use

• User uploads daily drilling reports (DDRs), morning reports, or bit records
• User asks to analyze drilling performance, compute KPIs, or benchmark a well
• User wants to identify performance improvement opportunities
• User needs a drilling performance summary for end-of-well reporting

Trigger phrases

• "Analyze drilling performance for this well"
• "Compute drilling KPIs from these DDRs"
• "Benchmark ROP against offset wells"
• "How does our drilling efficiency compare?"
• "Summarize NPT breakdown for the past 30 days"
• "What is the flat time percentage for this section?"
• "Calculate mechanical specific energy for this bit run"
• "Generate end-of-well drilling performance report"

Inputs

• Daily drilling reports (PDF, DOCX, TXT)
• Morning reports
• Bit records or bit performance sheets
• Drilling parameter time series (CSV, XLSX)
• Optional: offset well KPI benchmarks
• Optional: AFE cost data for cost-per-foot calculation

Outputs

• Section-level KPI summary (surface, intermediate, lateral per section)
• Well-level KPI summary
• NPT breakdown by category with Pareto ranking
• Flat time analysis (tripping, circulating, WOC, rigging)
• ROP comparison by formation and bit type
• MSE trend if WOB/RPM/torque/ROP data available
• Cost per foot if AFE or day rate data provided
• Benchmark comparison table if offset data provided
• Quality flags and data gap warnings

Core KPIs extracted

Drilling efficiency

| KPI | Definition | Units | |---|---|---| | Average ROP | Total footage / rotating hours | ft/hr | | Instantaneous ROP | Per-stand or per-30-min interval | ft/hr | | Mechanical ROP | ROP during pure rotary drilling | ft/hr | | Slide ROP | ROP during motor sliding | ft/hr | | Slide percentage | Slide footage / total footage | % | | MSE | Mechanical Specific Energy = (480 × RPM × Torque + WOB) / (ROP × bit area) | psi |

Time distribution

| Category | Description | |---|---| | Rotating time | Drill string rotating, bit on bottom | | Sliding time | Downhole motor, bit on bottom, string not rotating | | Reaming time | Rotating but not drilling new formation | | Tripping time | Pulling out of hole or running in hole | | Connection time | Per-stand time including wiper trips | | Flat time | All non-drilling time (tripping + connections + NPT) | | NPT | Non-productive time with cause classification |

NPT classifications

• Mechanical failure (equipment)
• Wellbore instability (stuck pipe, tight hole, washout)
• Mud/fluid related (losses, gains, influx)
• Directional issues (stuck BHA, survey problems)
• Rig equipment (top drive, pump, hoisting)
• Weather / environmental
• HSE / safety stop
• Waiting on orders / personnel
• Third-party service failure

Cost performance (when AFE data available)

• Day rate cost per foot
• Service company cost per foot
• Projected vs. actual AFE
• Cost overrun by NPT category

Output schema

{
  "well_summary": {
    "well_name": "string",
    "rig_name": "string",
    "spud_date": "string",
    "total_depth_ft": 0.0,
    "total_drilling_days": 0.0,
    "overall_rop_ft_hr": 0.0,
    "total_npt_hrs": 0.0,
    "npt_percentage": 0.0,
    "flat_time_percentage": 0.0,
    "rotating_percentage": 0.0
  },
  "sections": [
    {
      "name": "string",
      "from_depth_ft": 0.0,
      "to_depth_ft": 0.0,
      "footage_ft": 0.0,
      "avg_rop_ft_hr": 0.0,
      "rotating_hrs": 0.0,
      "sliding_hrs": 0.0,
      "tripping_hrs": 0.0,
      "npt_hrs": 0.0,
      "slide_pct": 0.0
    }
  ],
  "npt_breakdown": [
    {
      "category": "string",
      "total_hrs": 0.0,
      "event_count": 0,
      "percentage_of_total_npt": 0.0
    }
  ],
  "bit_runs": [
    {
      "run_number": 0,
      "bit_size_in": "string",
      "bit_type": "string",
      "from_depth_ft": 0.0,
      "to_depth_ft": 0.0,
      "footage_ft": 0.0,
      "rop_ft_hr": 0.0,
      "avg_wob_klbs": 0.0,
      "avg_rpm": 0.0,
      "dull_grade": "string"
    }
  ],
  "benchmark": {
    "offset_well_avg_rop": 0.0,
    "this_well_rop": 0.0,
    "rop_delta_pct": 0.0,
    "offset_well_npt_pct": 0.0,
    "this_well_npt_pct": 0.0
  },
  "quality_flags": ["string"]
}

Calculation notes

ROP calculation

• Use rotating + sliding hours only (exclude tripping, flat time)
• If hourly data unavailable, compute from depth intervals between DDRs
• Report separate ROP for each bit run and each wellbore section

MSE calculation

MSE (psi) = (480 × RPM × Torque_ft-lbs) / (ROP_ft_hr × Bit_area_in²) + WOB_lbs / Bit_area_in²

MSE < 2× UCS (unconfined compressive strength) indicates efficient drilling. Flag runs where MSE exceeds 3× formation strength.

Flat time

Flat Time % = (Total hours - Rotating hours - Sliding hours) / Total hours × 100

NPT percentage

NPT % = Total NPT hours / Total elapsed hours × 100

Industry benchmark: best-in-class unconventional wells achieve < 5% NPT.

Benchmarking logic

When offset well data is provided:

1. Match sections by formation or depth range
2. Compute ROP percentile (P10/P50/P90) for the offset population
3. Identify which NPT categories are outliers vs. offset average
4. Flag bit runs with significantly below-P50 ROP as improvement opportunities

Example response

DRILLING KPI SUMMARY — Wolfcamp B 3H
═══════════════════════════════════════
Well Total Depth:     12,450 ft MD
Total Drilling Time:  18.3 days
Overall Average ROP:  147 ft/hr
Total NPT:            12.8 hrs (2.9%)
Flat Time:            22.4%

SECTION BREAKDOWN
─────────────────
Surface (0–2,400 ft):       Avg ROP 45 ft/hr, NPT 0.5 hrs
Intermediate (2,400–7,200 ft): Avg ROP 92 ft/hr, NPT 3.2 hrs
Lateral (7,200–12,450 ft):  Avg ROP 168 ft/hr, NPT 9.1 hrs

NPT PARETO (Lateral Section)
─────────────────────────────
1. Mechanical failure (pump liner)  4.8 hrs  (53%)
2. Wellbore instability (stuck pipe) 2.5 hrs  (28%)
3. Third-party (MWD tool failure)   1.8 hrs  (20%)

Source & license

This open-source skill is cataloged on AgentStack and links to its original source — we do not rehost the code.

• Author: ttracx
• Source: ttracx/oil-and-gas-claude-skills
• License: MIT

Install and usage instructions live in the source repository linked above.