Juru Bor (Driller) cheat sheet

Hierarchy of control in order: elimination, substitution, engineering controls, administrative controls, PPE; PPE is the last resort and never a substitute for engineering control.

Permit-to-work applies to hot work, confined space entry, work at height, excavation, and energy isolation; the permit is invalid once conditions change or the shift ends unless formally revalidated.

Gas test order for confined space entry: oxygen first, then flammables (LEL), then toxics such as H2S and CO; entry requires O2 19.5-23.5% vol and LEL below 10% (often 5% for hot work).

H2S is heavier than air, flammable from about 4.3% to 46% vol in air, and deadens the sense of smell above roughly 100 ppm; SCBA is required above the IDLH of 100 ppm.

Energy isolation (LOTO): identify all stored and residual energy, isolate, lock and tag by each worker, verify zero energy by test, and only the person who applied a lock may remove it.

Dropped-object control: exclusion zones under the derrick, tool tethering above the rotary table, and hard hats with chin straps are standard controls on the drill floor.

Environmental rules: no discharge of oil-based mud or oily cuttings without treatment; rig drainage is segregated (clean rain versus contaminated deck drains) and spill kits are staged at transfer points.

Noise action level commonly 85 dB(A) 8-hour equivalent; hearing protection and audiometric testing are triggered at or above it, and the derrick area frequently exceeds 90 dB(A).

Drill string load path: hook load = buoyed string weight + drag + overpull; the deadline anchor and crown block are rated for the maximum anticipated hook load, not the static weight alone.

API drill pipe grades: E-75, X-95, G-105, S-135; the number is minimum yield strength in ksi, and pipe is derated for slip crushing and for H2S service (NACE/IRP limits).

Tubing and drill pipe inspection classes: new, premium, Class 2; premium pipe tolerates less wall loss and is required for critical/high-pressure wells.

Traveling block and crown block safety: crown-o-matic (crown saver) must be tested and functional; the anti-collision device stops the block before it strikes the crown.

BOP stack components: annular preventer for stripping and shut-in, ram preventers (pipe, blind, shear) for hard shut-in; shear rams must be capable of cutting the specific pipe in the hole.

Drawworks brake types: mechanical band brake plus dynamic (hydraulic/electromagnetic) auxiliary brake; brake test and adjustment are part of the pre-tour checklist.

Rotary hose and standpipe: pressure-tested to rated working pressure; a hose with cover damage exposing the reinforcement wire must be removed from service.

Kelly or top drive: top drive torque and speed limits are set by the manufacturer; make-up torque for connections follows the pipe tally sheet, not operator judgment.

Mud density controls formation pressure; equivalent circulating density (ECD) = static mud weight + annular friction loss, and ECD must stay below fracture pressure at the shoe.

Kick detection in flow: pit gain, flow with pumps off, and a change in pump pressure at constant stroke rate; a positive flow check with pumps off confirms influx.

Mud weight up = formation pressure plus trip margin; mud weight down when losses occur, then cure losses with LCM before drilling ahead.

Filtrate and filter cake: high fluid loss thickens the cake, causes tight hole and stuck pipe; API fluid loss is measured at 100 psi for 30 minutes (standard test).

Yield point and gel strengths govern hole cleaning; low-shear-rate viscosity (6 rpm reading) predicts cuttings transport better than funnel viscosity.

Lost circulation types: seepage, partial, total; remedies in order: reduce ECD, add LCM, set a plug, cement, or use a liner.

Gas-cut mud lowers effective density slightly but does not by itself cause a kick; circulate out and condition before resuming.

Water-based versus oil-based: OBM gives better shale inhibition and lubricity but requires cuttings treatment and stricter environmental handling.

Weight on bit, rotary speed, and flow rate set rate of penetration; excessive WOB causes bit balling, stick-slip, and drill string buckling.

Stick-slip is identified by torque oscillation and erratic surface rpm; remedy is to change rpm, reduce WOB, or adjust mud lubricity.

Bit hydraulics: nozzle total flow area (TFA) and pump pressure determine bit horsepower; optimized hydraulic horsepower per square inch (HSI) is commonly 2.5-5 HSI.

Pump output (gpm) = pump displacement per stroke x strokes per minute x volumetric efficiency.

Trip margin is mud weight added above pore pressure to offset swab pressure while pulling pipe.

Survey intervals and inclination: dogleg severity (degrees per 100 ft) limits are set by pipe and tool; high DLS risks fatigue and key seating.

Connection practice: make up to specified torque, verify with torque gauge, and record on the tally; over-torque damages threads and under-torque risks back-off.

Kick-off and directional work: motor bend angle, tool face orientation, and slide versus rotate are recorded each stand for the directional driller.

Primary well control is hydrostatic mud pressure; secondary is the BOP; tertiary is a relief well or barite plug.

Shut-in drill pipe pressure (SIDPP) plus mud hydrostatic equals formation pressure; SICP higher than SIDPP indicates an influx in the annulus.

Kill mud weight (ppg) = current mud weight + (SIDPP / (0.052 x TVD)).

Slow circulating rate pressure (SCR) is recorded before drilling; kill rate is typically 1/4 to 1/2 of normal pump rate.

Driller's method: circulate the influx out at kill rate with original mud weight, then weight up and circulate kill mud.

Wait and weight method: weight up first, then circulate kill mud in one circulation; the casing shoe pressure is lower with this method.

Hard shut-in is preferred on a kick: close the BOP without opening the choke, then read pressures; soft shut-in routes flow through the choke first.

Kick indicators: flow with pumps off, pit gain, increase in SICP or SIDPP, gas-cut mud, and a change in pump pressure at constant rate.

Sling angle effect: tension in each leg = load / (2 x cos of the angle from vertical); at 60 degrees from horizontal each leg carries the full load.

Working load limit (WLL) = breaking strength / safety factor; wire rope slings commonly use a 5:1 factor, chain slings 4:1.

Rigging hardware inspection: reject slings with broken wires (10 in any lay, 5 in one strand), kinks, bird-caging, or missing tags.

Lift plan required for lifts over 75% of the crane's rated capacity or for tandem and non-routine lifts; tag lines control rotation.

Shackle pins must be fully engaged and moused; hooks need a functioning latch, and side loading of hooks is prohibited.

Manual handling: keep the load close to the body, lift with legs, and use two-person or mechanical aids above roughly 25 kg per person.

Rig floor lifting: use the air hoist or winch for heavy items; never stand under a suspended load or in the bight of a rope.

Hand signals and radio are agreed before the lift; one signaler controls the crane, and the load is not moved until the signal is acknowledged.

Fire triangle: fuel, oxygen, heat; removal of any one side extinguishes the fire; class B (flammable liquid) fires are fought with foam, dry chemical, or CO2.

Well control emergency: sound the alarm, shut in, notify the company man, and muster at the designated point; do not re-enter the floor until the well is stable.

H2S response: move upwind and uphill, do not attempt rescue without SCBA, and administer oxygen to a conscious casualty.

First aid priorities: danger, response, airway, breathing, circulation (DRABC); control severe bleeding with direct pressure before anything else.

Burns: cool with clean running water for at least 20 minutes, do not burst blisters, and cover with a sterile non-adherent dressing.

Fire extinguisher use: PASS (pull, aim, squeeze, sweep); only fight a small fire with a clear escape route behind you.

Muster and headcount: each crew member reports to the muster point; the person in charge confirms all names against the rig list before search and rescue.

Emergency drills: BOP drills, H2S drills, and abandon-rig drills are logged with time to shut in and time to muster.

Tour handover covers well status, mud properties, downhole tools, outstanding permits, and any abnormal pressure or pit behavior.

Pre-job safety meeting (toolbox talk) covers the task, hazards, controls, and each person's role; attendance is recorded.

Stop-work authority: any crew member may stop the job when a hazard is seen; the stop is logged and the job resumes only after the hazard is controlled.

Daily drilling report records depth, mud weight, bit hours, pump strokes, and downtime codes; it is the legal record of the operation.

Kick and BOP drill records include date, time, crew, and time to shut in; they are retained for the well file and audit.

Radio protocol: identify the caller, state the message, and require read-back for critical instructions such as pump rate or pressure changes.

Incident reporting: near misses are reported alongside injuries; root cause analysis follows within the set timeframe, and corrective actions are tracked to closure.

Records for lifting gear and pressure equipment: certificates, inspection dates, and serial numbers are kept on the rig and available for inspection.