FREE · PRIVATE · BROWSER-BASED
GEOLOGY TOOLS
Practical utilities built for wellsite geologists, geosteering teams and drilling professionals. Your files stay in your browser and are not uploaded to our servers.
01 / FEATURED TOOL
Online Well Log Digitizer
Load an image, define the plot limits, then click along a curve. The traced points are converted to calibrated depth and curve values in real time.
Well log digitizer
27 / MAP DIGITIZING
Contour & Structure Map Digitizer
Turn a referenced map into coordinate-based contour lines. Mark your section boundary and well centre, calibrate the map, then trace each contour independently.
Loading the map workspace… JavaScript is required for local digitizing.
02 / FEATURED TOOL
2D Horizontal Structure Digitizer
Convert an office-supplied planned-wellbore versus structure image into usable XY geometry. The planned wellbore and each formation horizon are traced and managed independently.
2D structure digitizer
26 / LOG INTERPRETATION REFERENCE
Logging Device Response Chart
03 / DATA
LAS Quick Viewer
Open a LAS 2.0 file locally, review the well information and plot any numeric curve.
Source depth units
Drag to pan; wheel zooms around the cursor. Double-click or Home resets. Focus the plot for +/− zoom and arrow-key pan. Escape cancels a drag. Use buttons on touch screens.
04 / TRAJECTORY
Directional Survey Workbench
Calculate a complete directional survey using minimum curvature. Paste or import MD, inclination and azimuth stations, then inspect TVD, displacement, vertical section and dogleg severity in synchronized section and plan views.
| Station | mMD | Inc ° | Azm ° | mTVD | mN | mE | mVS | DLS °/30m |
|---|---|---|---|---|---|---|---|---|
| No calculated stations. | ||||||||
05 / CIRCULATION
Lag & Annular Velocity Calculator
Build the complete bit-to-surface annulus from multiple hole, casing, drill-pipe and BHA sections. Calculate section capacities, annular velocities, lag volume, bottoms-up time, pump strokes and a field-ready sample arrival schedule.
Need to move a lag-corrected feature on the log? Open the Lag Alignment Helper and worked example →
Circulation
Choose units in the dropdown on the right of every numeric entry, including section geometry and sample scheduling. Switching units converts the existing value; metric, US and Imperial inputs can be mixed. US and Imperial gallons are separate; bbl means 42 US gallons. Results and CSV headings retain their stated units.
Annular sections
Sections are measured from surface toward the bit.
| Section | Path | From MD | To MD | Hole / ID | String OD | Washout (diameter) |
|---|
Sample catch schedule
Arrival times are estimates. “Volume to sample depth” uses the entered fixed-depth geometry; review BHA lengths and changing flow before field use.
Section results
Effective diameter includes the entered diameter washout.
| Section | Length m | Eff. ID mm | Capacity m³/m | Volume m³ | Velocity m/min | Travel min | Strokes |
|---|
Sample arrival schedule
Cut time includes estimated drilling and connection time.
| Sample mMD | Cut time | Lag volume m³ | Lag min | Lag strokes | Expected at surface |
|---|
Planning estimate only. Confirm actual hole condition, string dimensions, pump output, flowline/gas-trap volume and operational delays against current rig data. Cuttings and gas may trail calculated fluid lag because of slip, beds, eccentricity, inclination and washout.
25 · GEOLOGY HELPER
Lag Alignment Helper
Gas or samples plotting too shallow or too deep? Check the direction of a software lag correction, then test a matched-depth scenario.
First, check what “AV” means in your software. Annular velocity (m/min) and annular volume (m³) change lag in opposite directions. This helper reassigns an already lag-corrected arrival record; it does not change imported logs or rig settings.
Try an example
Your lag scenario
CALCULATED SCENARIO · UPDATES AS YOU TYPE
Requested depth move
Adjustable lag
Software AV setting
Show the calculation and assumptions
Changing units converts your entries. Switching velocity / volume restores a separate setting for each basis; verify it before use.
Which way should I adjust AV?
| Move the plotted event | Lag time | AV = velocity | AV = volume |
|---|---|---|---|
| Shallower · left on horizontal MD / up on vertical MD | Increase | Decrease | Increase |
| Deeper · right on horizontal MD / down on vertical MD | Decrease | Increase | Decrease |
Directions assume MD increases to the right or downward and software assigns source depth by subtracting travel time from the arrival time. Check your software convention. Velocity uses a fixed equivalent path; volume uses fixed flow.
Before applying a correction
- Use a verified matched event and retain the original curve, previous setting and correction basis. A gas response can legitimately differ from GR or ROP.
- Check pumping changes, connections, circulation stops and time synchronization. One ROP value cannot reconstruct a variable drilling history.
- Review gas-line and surface-system delay, cuttings slip, hole enlargement and recirculated gas separately. Fluid, gas and cuttings can have different effective lags.
- A tracer released at surface travels down the drillstring and back up. Separate that down-time from the annular return component before using this calculation.
- Downhole sensor-to-bit offsets require separate depth correction. Do not change rig pump settings to make curves match.
Need a geometry-based starting point? Open Lag & Annular Velocity for segmented volumes, flow and bottoms-up calculations.
Definitions and references
Definitions checked against the SLB Energy Glossary on 18 September 2026: annular velocity, lag time, and tracer / carbide lag test. The depth-shift scenario is calculated from the stated constant-ROP assumptions; it is not a manufacturer-specific calibration procedure.
06 / DATUM
TVD / Subsea Converter
Use positive elevations above mean sea level. Subsea elevation is negative below mean sea level. TVD must use KB as its reference; MD is not interchangeable with TVD.
07 / STRUCTURE
Formation Dip Calculator
Use 90° for a flat formation: 91° = +1° from horizontal, and 89° = −1°. Apparent formation angle uses the same baseline (π/2 rad or 100 gon = flat). Dip azimuth defines the positive-down reference direction; both azimuths use the same north reference. Positive vertical bed change is downward over the horizontal interval.
08 / DRILLING
Hydrostatic Pressure
Calculate static pressure for a uniform-density fluid column using TVD. Excludes surface pressure and circulating friction; this is not ECD or a well-control instruction.
09 / REFERENCE
Oilfield Unit Converter
Convert commonly used drilling and geological measurements.
Converted value
m³ means cubic metres. US and Imperial gallons are distinct; an oilfield bbl is 42 US gallons. Volume and flow conversions retain the same temperature and pressure basis. NIST conversion reference
10 / MUD-GAS EVALUATION
Mud-Gas Ratio Helper
Import or enter lag-corrected C1–C5 chromatograph data, calculate transparent gas ratios and flag changes worth correlating with lithology, GR, ROP and drilling events.
1 · Qualify the gasConfirm component basis, lag, background, detector range and event type.
2 · Compare ratiosReview wetness, balance, character and Pixler trends—not one isolated value.
3 · Correlate the showCheck cuttings, total gas, GR, ROP, mud system and repeatable offset behavior.
DATA CONTEXT
Well and chromatograph setup
Background subtraction
Enter a representative circulating background on the same component basis. Net values are floored at zero and both raw and corrected values are retained in export.
ADD READING
Depth and components
Paste or import chromatograph data
CSV/TXT headers may include MD, C1, C2, C3, C4, C5, iC4, nC4, iC5, nC5, total gas and event. All components must use the same basis.
RATIO TREND
Wetness and balance vs depth
C1–C5
Add or import data
Add or import data
WetnessBalanceW/B crossover
READING INVENTORY
Calculated gas ratios
| Depth | Net gas | Wh | Bh | Ch | Screen | QC | |
|---|---|---|---|---|---|---|---|
| Add or import chromatograph readings to begin. | |||||||
Interpretation aid—not a fluid test or reserves estimate. Ratios are qualitative screens and are strongly affected by extraction efficiency, mud system, ROP, flow, bit size, lag, recycling, detector calibration/saturation and component quantification limits. Western Canadian tight reservoirs may under-release heavy components, so traditional Haworth and Pixler relationships can misclassify fluids. Correlate trends with cuttings, total gas, GR, resistivity, pressure and test data. Files remain in this browser.
11 / OFFSET CORRELATION
Offset Formation-Top Correlator
Bring nearby offset picks onto one subsea reference, screen the spatial support and create a traceable top prognosis for a proposed well.
1 · StandardizeUse one projected coordinate system, formation name and vertical datum convention.
2 · QualifyCheck pick confidence, distance, faults, datum elevation and TVD—not MD.
3 · PrognoseReview the distance-weighted mSS estimate and structural spread before adopting it.
TARGET WELL
Location and calculation controls
ADD OFFSET
Well and formation top
Paste or import offset tops
Use easting and northing in metres. Supply top_mss directly or both top_tvd and datum_elev. Formation may be omitted to use the target formation.
PLAN VIEW
Offset support and residuals
OFFSET TOPS
Add or import wells
Add or import wells
Shallower than estimateDeeperOutside radius / excluded
OFFSET INVENTORY
Standardized formation tops
| Use | Offset well | Distance | Top TVD | Datum elev. | Top mSS | Residual | Confidence | |
|---|---|---|---|---|---|---|---|---|
| Add or import offset tops to begin. | ||||||||
Screening prognosis—not an approved formation forecast or structural model. Use one verified projected coordinate reference system and the same vertical datum convention. Top mSS is calculated as datum elevation minus top TVD; MD is not accepted. Distance weighting does not model faults, dip domains, erosional truncation, thickness change, velocity error or inconsistent stratigraphic nomenclature. Separate fault blocks where appropriate and confirm against controlled offset logs, seismic interpretation, the approved prognosis and qualified geological judgment. Files remain in this browser.
12 / RESERVOIR PRESSURE
Pressure Gradient & Fluid Contact Helper
Import or enter formation-pressure stations, fit separate gas, oil and water trends, and screen their intersections with the evidence and uncertainty kept visible.
1 · Qualify stationsUse pressure points with defensible seal, buildup and depth.
2 · Fit trendsKeep fluids, compartments and pressure regimes separate.
3 · Review contactsTreat intersections as screening estimates, especially outside measured depth.
WELL CONTEXT
Pressure and depth basis
ADD STATION
Qualified pressure point
Paste or import pressure stations
Header row required. Use depth_m or explicitly tvd_m / mss_m, plus pressure_kpa, pressure_mpa or pressure_psi. Optional: station, group/fluid, include and note.
PRESSURE–DEPTH PLOT
Qualified stations and fitted trends
PRESSURE GRADIENTS
Add or import stations
Add or import stations
GasOilWaterOther
STATION INVENTORY
Pressure points and residuals
| Use | Station | mTVD | Pressure | Trend | Residual | Evidence / note | |
|---|---|---|---|---|---|---|---|
| Add or import pressure stations to begin. | |||||||
Screening interpretation—not a pressure survey, proven fluid contact or reserves estimate. Ordinary least-squares trends assume the included pressures represent the same connected compartment, fluid column and reference conditions. Supercharge, poor seal, short buildup, depletion, capillary transition, phase or PVT changes, gauge/depth error, faults and separate pressure regimes can create misleading slopes or intersections. Never combine MD with TVD, gauge with absolute pressure, or unrelated pools. Confirm with qualified reservoir/geological review and the original pressure-test evidence. Files remain in this browser.
13 / DRILLING PERFORMANCE
Drilling Break & Corrected d-Exponent Helper
Import or enter on-bottom drilling data, normalize changing operating parameters and review deviations from a user-selected normal trend.
1 · Qualify dataExclude connections, slides, reaming, dysfunction and sensor failures.
2 · Compare like with likeKeep bit, BHA, lithology and operating regime changes visible.
3 · CorroborateInvestigate trend changes with flow, pits, gas, cuttings and drilling response.
WELL CONTEXT
Calculation basis
ADD READING
On-bottom drilling point
Paste or import drilling data
Header row required: depth_m, rop_m_h, wob_kn, rpm, bit_mm and mud_kg_m3. Optional: include and note.
DEPTH TREND
Corrected d-exponent and fitted normal trend
d-EXPONENT TREND
Add or import readings
Add or import readings
READING INVENTORY
Inputs, d and corrected d
| Use | mMD | ROP m/h | WOB kN | RPM | Bit mm | Mud kg/m³ | d | dc | Δdc | Note | |
|---|---|---|---|---|---|---|---|---|---|---|---|
| Add or import drilling readings to begin. | |||||||||||
Trend-screening aid—not a pore-pressure calculation, kick detector or well-control instruction. The Jorden–Shirley relationship was empirical and is sensitive to bit type/wear, lithology, hydraulics, differential pressure, motor/RSS contribution, sliding, dysfunction, WOB/RPM measurement and data averaging. Corrected d uses a user-entered reference mud density divided by actual mud density; use ECD only when its basis and measurement are consistent. Do not compare across bit/BHA, lithology or operating-regime changes without qualified review. A trend departure must be corroborated with flow checks, pit volume, gas, cuttings, torque/drag, standpipe pressure and the approved well-control program. Files stay in this browser.
13 / REPORTING
Geological Operations QC Report Builder
Document the evidence behind a field or laboratory data-acceptance decision. Choose a report type, review each control, flag concerns or failures, and export a traceable report package.
LIVE DISPOSITION
Incomplete
Review the applicable controls to determine disposition.
0% reviewed
Focus your review
Filters change only this screen. Disposition, saved drafts, full CSV/JSON and Print/PDF always include every control. Follow-up exports include all unresolved controls, independent of filters.
No controls match. Clear filters to see the whole checklist; a blank view does not mean the report is complete.
Evidence index
Record the exact files and references reviewed. Local files are fingerprinted in this browser; file contents are not stored in the report or uploaded.
Maximum 25 records. Files up to 64 MB receive a SHA-256 fingerprint; larger files retain explicit name, size and modified date with “not hashed — size limit.” Fingerprints identify bytes only—they do not verify provenance, completeness or technical acceptance.
Report conclusions
Professional review aid only. Apply the approved program, operator requirements, service-company procedures, jurisdictional rules and qualified technical judgment. A completed checklist does not certify data or replace well-control, radiation, pressure-control or HSE procedures.
14 / STRATIGRAPHIC PICKING
Formation Top Pick Helper
Build or import the well prognosis, add an optional gamma-ray curve, and generate location-aware guidance for depositional setting, expected cuttings and a defensible top-pick criterion.
1 · Set regional contextEnter a field, nearby town, DLS location or area.
2 · Build the prognosisAdd formations manually, paste a list or import CSV/TXT.
3 · Compare the evidenceReview samples and GR character, then confirm—not blindly accept—the pick.
WELL CONTEXT
Location and formation list
Paste or import a formation-top list
One formation per line. A second value may contain its prognosed depth, for example Cardium, 2440.5. CSV headers such as formation, top and planned_md are recognized.
WELL PROGNOSIS
Formation tops
| Formation | Prognosed | Suggested | Confirmed | |
|---|---|---|---|---|
| Add or import formations to begin. | ||||
OPTIONAL LOG EVIDENCE
Gamma-ray top viewer
GR
LAS or CSV
LAS or CSV
Gamma rayPrognosed topSuggested pickConfirmed pick
Select a formation row to focus its search window. Click or tap the plot to stage a manual depth, then choose Set confirmed pick to save it.
Interpretation aid—not an automated stratigraphic authority. Formation tops are operational interpretations. Confirm picks against the approved prognosis, local naming convention, offset/type logs, sample lag, drilling parameters, mud-gas response, resistivity and other available evidence. The browser-side assistant uses a researched public-source library and transparent GR-change scoring; files remain on this device and are not uploaded.
15 / SAMPLE EVALUATION
Drill Cuttings Description Helper
Start with source-backed regional formation context, then work from sample integrity through hand-lens, microscope or thin-section observations to discriminating tests and a consistent interval description. Regional expectations remain separate from observations to reduce confirmation bias.
1 · Qualify the sample
Check lag, cavings, contamination, washing and representativeness.
2 · Identify from evidence
Compare internal grain, mineral, fabric and reaction—not cutting shape alone.
3 · Describe and qualify
Record what is observed, confidence, limitations and interpreted rock type.
SOURCE-BACKED REGIONAL SYNTHESIS
Formation intelligence
Enter a field, nearby town or Dominion Land Survey location and the formation or member. The tool resolves regional lithology, minerals, depositional setting, possible fossils and their expected appearance in drill cuttings from a library focused on key Alberta and southeast Saskatchewan units.
Match:
Public sources used
Regional reference only—not a sample, fossil or reservoir-quality identification. Fossil absence does not disprove a formation, and recovered fragments may be reworked, caved, lagged or drilling-related. Confirm against the operator prognosis, type logs, offset control, current cuttings, logs and laboratory data. This release uses a researched public-source library in your browser; nothing is uploaded. Avoid entering confidential well names or coordinates.
Loading research library…
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PUBLICATIONS · TYPE & REFERENCE LOGS · DATA REPOSITORIES
Regional reference & type-log library
Explore published reference wells, regional sections and official data holdings across Western Canada and selected international basins. These are curated source links, not downloaded curves or automatic local formation interpretations. The regional synthesis above retains its stated Alberta / Saskatchewan coverage.
No references match these filters. Try a shorter formation name, another area or reset filters. A missing entry does not mean a formation or dataset is absent.
Formal type sections, illustrative reference logs and regional cross-sections are different evidence types. Publication figures require scale/depth calibration before digitization. Confirm access and reuse rights with the custodian; some holdings require registration or payment. No account credentials are collected and no third-party data is fetched automatically. Your shortlist stays in this page until you download it or close the page.
Already have an authorized file? Open LAS Viewer · Digitize a published log image
PRIVATE IMAGE-ASSISTED REVIEW
Analyze a drill-cuttings image
Upload or photograph a representative tray or microscope field. The browser measures visible colour, contrast and texture, then drafts a preliminary observation for geological review.
Image preview
Interpretation limit: Image measurements do not identify a mineral, fossil, porosity type, hydrocarbon show or formation. Wetness, UV/PPL/XPL mode, white balance, shadows, tray colour, mud products, cavings, scale and focus can materially change the result. Confirm using fresh surfaces, physical tests, lag-corrected samples, logs and qualified geological or petrographic review. The image stays on this device and is discarded when removed or the page closes.
Build the sample description
Identification tests and limitations
Record the observed result from hand lens, reflected-light microscope or prepared thin section as applicable. No single test proves a rock type.
Description output
Check the evidence actually observed before using the interpreted rock name.
Method references: AAPG drill-cuttings analysis · British Geological Survey Rock Classification Scheme · Alberta Energy Regulator core and cuttings resources. Hand-lens and reflected-light microscope observations remain field identifications. Polarized-light microscopy requires a representative prepared thin section and trained petrographic interpretation. Confirm material conclusions against the approved operator manual, regional geology, drilling context and laboratory data.
17 / INTERACTIVE LOG WORKSPACE
Composite Log Creator & Viewer
Load depth-indexed drilling data, add formation tops and inspect synchronized geology and drilling tracks. Calculations use only entered or imported values; gaps remain gaps.
COMPOSITE FIELD LOG
Wheel to zoom · drag vertically to pan · click for exact-row readoutSelect a plotted row.
Reservoir / hydrocarbon interval screening
Editable screening examples, not field-calibrated cutoffs. Candidates require low GR, density porosity and deep/true resistivity together. Coal, fresh water, lithology, thin beds and borehole effects can mimic these patterns. Confirm matrix, tool quality, logs, samples and formation fluids before interpreting hydrocarbons. No saturation, net pay or reserves are calculated.
Import LAS to screen wireline intervals.
Reference: SLB · Basic Well Log Interpretation. Cutoffs above are user-editable examples, not thresholds prescribed by this reference.
Calculation basis
24 / BUILD, LAND & LOOK AHEAD
Build & Landing Tool
Well plan, actual survey, three offset logs and editable prognosis. Explore curved forward scenarios and their possible hazard encounters.
23 / GEOLOGICAL LOGGING
Editable Striplog Viewer
mMD, mTVD and horizontal mMD logs. Import curves, describe samples, and place compact, coloured GeoNavigate symbols for fossils, minerals, textures, porosity and shows.
18 / CORE DESCRIPTION WORKSPACE
Interactive Core Log Editor
Author core runs and geological intervals beside a hand-drawn field log. Recovery and RQD are calculated from entered run lengths; geological observations remain explicitly user-authored.
GEOLOGICAL CORE LOG
Old-school field sheet · click an interval to edit · wheel zoom · drag to panInterval register
Click a row or the drawn log to load that interval into the editor.
19 / WELL PLANNING WORKSPACE
Operational Well & Directional Program Builder
Build a source-explicit drilling program from surface to TD. Survey coordinates use minimum curvature; formation intersections are reported only inside supplied station coverage.
VERTICAL SECTION
Wheel to zoom · drag to pan · select a survey stationSelect a station.
Calculated directional program
mTVD, mSS, N/S, E/W, vertical section and DLS are calculated from the entered MD / INC / AZI stations.
20 / FIELD CALCULATION LIBRARY · 58 CALCULATORS
Common Drilling Formulas
Select a calculation, then choose metric or field units independently for every input and result. Canadian metric is the starting preset: m³, m³/m, m³/min, kg/m³, kPa, metres and millimetres. Each unit can still be changed independently.
CIRCULATION
AUTO UNITSBottoms-up lag time
Changing this preset converts your current values and sets the units for the next formula. Blank fields stay blank. US and Imperial gallons are separate; bbl = 42 US gal.
Reference equation below uses its stated base units. Entries and results are converted automatically.
Calculated result—Enter all required values.
Reference shelf
This is the first component of the planned Formation Intelligence publication library. Each formula keeps its method and source visible; future geology references can be indexed by basin, area, formation and topic.
IADC WellSharp metric formula sheetPrimary calculation reference · capacities, hydrostatics, ECD, kill density and MAASP
IADC WellSharp field-units formula sheetPrimary reference · buoyancy, tubular forces and completion/workover calculations
SLB Drilling Fluid BasicsTechnical context · drilling fluids, annular losses and ECD
SLB Defining Series: RheologyTechnical context · Bingham, power-law and Herschel–Bulkley fluid behavior
API RP 13B-1 / RP 13B-2Official field-testing scope · drilling-fluid density, rheology, gel strength, filtration and solids
Teale (1965), Mechanical specific energyPrimary method reference · drilling energy per excavated rock volume
Jorden & Shirley (1966), SPE 1407-PAPrimary method reference · normalized drilling response and D-exponent
Rehm & McClendon (1971), SPE 3601-MSPrimary method reference · mud-density correction for D-exponent
LearnToDrill — Drilling Formulas for Oil & GasUser-supplied reference reviewed for formula coverage; equations were independently checked and converted to a consistent metric basis.
Field-use limitation: verify critical well-control, pressure, casing and cement calculations against the approved drilling program, current rig data, operator procedures and a competent supervisor. Geometry-based lag is theoretical and excludes washout, compressibility, surface-system volume and actual tracer response unless entered.
21 / OPERATIONS PLANNING
ICP drill-out & TD timing
Plan milestones with explicit units, dates and assumptions. Print a planning sheet or download a draft. Estimates never substitute for operational release criteria.
NEED THE COMPLETE WORKFLOW?
Move from a free utility into the live well.
GEONAVIGATE ∞ connects well data, striplogs, geosteering, teams and reporting in one online workspace.
22 / DAILY GEOLOGICAL REPORTING
Tour Sheet → Daily Report
Turn a Pason ETS 3.0 XML export into a daily / AM geological report. Review imported operations, confirm mud units and add your interpretation.