DRILLING UNIT CONVERTER

DRILLING UNIT CONVERTER

In oil and gas drilling, calculations span two measurement systems that don't always play nicely together. Mud weight is reported in pounds per gallon on US rigs and in kilograms per cubic metre or specific gravity on international projects. Pressure may be given in psi in one report and bar or kilopascals in another. Depths shift between feet and metres depending on which operator, which contractor, and which decade the well plan was written in. This converter handles all of those translations in a single page, with every field updating in real time as you type.

Whether you're a drilling engineer reconciling a well programme, a mud engineer checking fluid density across supplier datasheets, or a student working through drilling calculations for the first time, having all the common unit conversions in one place removes a persistent source of error on the rig and in the office.

MUD WEIGHT: PPG, SG, PSI/FT AND KPA/M

Mud weight — also called drilling fluid density — is the single most important parameter in well control. It must be heavy enough to provide hydrostatic pressure that overbalances pore pressure and prevents a kick, but not so heavy that it fractures the formation and causes lost circulation.

In North America, mud weight is almost universally expressed in pounds per gallon (ppg). Internationally, specific gravity (SG) is more common, representing the ratio of the fluid's density to that of fresh water. A 10 ppg mud has an SG of roughly 1.198. The pressure gradient equivalents — psi per foot and kilopascals per metre — are used directly in hydrostatic pressure calculations and appear frequently in formation evaluation and well control worksheets.

Converting between these units by hand introduces rounding errors that compound over deep wells. A conversion tool that locks all four representations together eliminates that risk entirely.

PRESSURE: PSI, BAR, KPA AND MPA

Wellbore pressure appears in every corner of a drilling operation. Standpipe pressure, casing pressure, formation pressure, and fracture pressure are all measured and reported in pressure units. The problem is that those units vary by geography and by discipline. Reservoir engineers often work in psi. European operators prefer bar. Academic literature frequently uses MPa or kPa. Directional and MWD reports may mix all of them.

The conversions are straightforward once you know the factors — 1 psi = 0.0689476 bar = 6.89476 kPa — but under time pressure on the rig floor, mental arithmetic on numbers like those is where mistakes happen. This converter keeps all four pressure units synchronised so you can move between system conventions without breaking your workflow.

WHAT ELSE THIS CONVERTER COVERS

• Length (metres / feet) — for TVD, MD, casing setting depths, and string tallies
• Volume (barrels / litres / m³) — for pit volumes, cement slurry, and displacement calculations
• Temperature (°C / °F) — for BHT, mud temperature, and cement hydration planning
• Flow rate (bpm / lpm / gpm) — for pump rate and annular velocity
• Weight (tonnes / pounds / kg) — for hook load, WOB, and string weight
• Torque (ft-lbs / Nm / kNm) — for make-up torque, rotary torque limits, and BHA design
• Bit size (inches / mm) — for matching bit records to metric hole size specifications
• Dogleg severity (°/30m / °/100ft) — for comparing survey data across metric and imperial well plans
• Pump output (bbl/stk / L/stk) — for lag time and bottoms-up calculations
• Pipe dimensions (inches / mm) — for matching OD and ID specs across tubular catalogues