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Well control intro presentation
This document provides an introduction to well control from Kingdom Drilling Services. It discusses primary and secondary well control, including maintaining pressure and monitoring flows. Loss of primary control can occur through pressure changes or lost circulation. Secondary control indicators include increased flow rates or mud pit volume changes. Methods for controlling kicks include circulating or bullheading. The document also covers well control terms, blowout prevention, shallow well hazards, and lost circulation detection and remedies.
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Well control intro presentation
- 1. Drilling & wellengineering Introduction to Well Control Peter Aird: Kingdom Drilling Services.
- 2. 2009 rev 1Kingdom Drilling Services Well control • Primary – Prevention, where 1oz of primary control prevention is generally far better than the cure? • Secondary – Safely managing and regaining control of the well when primary control is lost.
- 3. 2009 rev 1Kingdom Drilling Services Drilling with ‘Primary’ control
- 4. 2009 rev 1Kingdom Drilling Services Primary control principles • Primary well control – Flow in/out – Pressure – Volumes • Pumping • Displacement – Drilling parameters – Mud logging
- 5. 2009 rev 1Kingdom Drilling Services Primary control loss? 1. Losing pressure column causing change in pressure balance e.g. shallow water flow 2. Pressures induced causing a change in flow regimes e.g. ECD, surge, swab, inducing lost circulation, borehole ballooning etc. 3. Losing circulation causing loss of hydrostatic and flow to occur e.g. drilling into an under-balanced or depleted formation 4. Loss of measurement and control causing losses or gains to occur e.g. swab pressure causing pressure reduction less than formation pressure.
- 6. 2009 rev 1Kingdom Drilling Services Primary control issues 1. Personnel at the required level of competency 2. Fit for purpose tools and equipment 3. Adequate supplies and materials 4. Systems for maintaining good records and reports (and using them to learn) 5. Maintaining and controlling down hole pressures EMW=MW +/- ECD 6. Monitoring, evaluating and determining swab, surge, pressure effects etc. 7. Tripping and circulating practices
- 7. 2009 rev 1Kingdom Drilling Services Loosing ‘ Secondary’ control
- 8. 2009 rev 1Kingdom Drilling Services Secondary control indicators • Increase in flow rate? • Gain or loss in mud pit volume? • A drilling break and > ROP • Pump pressure reduction
- 9. 2009 rev 1Kingdom Drilling Services Well control contributors 1. Degree of under-balance or overbalance 2. Formation permeability 3. Length of the formation exposed 4. Time the formation is allowed to flow or lose.
- 10. 2009 rev 1Kingdom Drilling Services Secondary methods • Circulating – Weight and weight – Drillers method – New methods • Non circulation – Bull-heading – Volumetric
- 11. 2009 rev 1Kingdom Drilling Services Well Control terms • Kick – Unplanned entry of FORMATION fluids into the wellbore, of sufficient volume quantity to require shutting in the well. • Lost circulation – Unplanned loss of DRILLING fluids to the wellbore, of sufficient volume quantity to require shutting in the well. Often then associated with a ‘Kick’ • Blowout – Loss of control of wellbore ‘drilling and/or formation fluids’ resultingin severe lost circulation and/or a kick
- 12. 2009 rev 1Kingdom Drilling Services Wells out of control
- 13. 2009 rev 1Kingdom Drilling Services Blow out preventers ‘BOP’
- 14. 2009 rev 1Kingdom Drilling Services Drilling Instrumentation • Drilling • Tripping • Well control – Kicks – Loss circulation • Wellbore difficulties – Hole cleaning – Instability – Stuck pipe
- 15. 2009 rev 1Kingdom Drilling Services Blowouts
- 16. 2009 rev 1Kingdom Drilling Services Blowouts
- 17. 2009 rev 1Kingdom Drilling Services Well Control • Blowout – Surface – Underground • Blowouts caused by – equipment failure – human error
- 18. 2009 rev 1Kingdom Drilling Services • Shallow well control • Over pressured zones. • Low fracture pressures • Shallow prospects Shallow well control hazards 36" Pipe
- 19. 2009 rev 1Kingdom Drilling Services Shallow well control drilling 1. Operating margins between pore pressure and formation integrity is small 2. Penetration rates are difficult to control 3. VOLUME control can be very difficult indeed. 4. Dynamic gas invasion can quickly occur 5. Gas above BOP can quickly result
- 20. 2009 rev 1Kingdom Drilling Services Prediction, detection, prevention • Geophysical prediction, • Pore pressure, fracture gradient prediction, • Operational strategies, – Drilling, tripping, cementing • Remedial operations – Well flow dynamics
- 21. 2009 rev 1Kingdom Drilling Services Seismic systems Seismic systems; target depths 50-500 metres Mini seismic source Very good 3D high resolution Very Good Seismic systems; target below 200 metres 2D high resolution Good 3D seismic Can be good 3D seismic re-processed Can be good
- 22. 2009 rev 1Kingdom Drilling Services Shallow well control prevention • Site specific location for lowest risk – Multidisciplinary approach • Subsurface geo-hazard avoidance • Geo hazard mitigation
- 23. 2009 rev 1Kingdom Drilling Services Shallow well control detection 1. Drilling trends 2. Pressure while drilling monitoring and control 3. LWD/MWD (Resistivity, gamma) detection 4. Increase/decrease in mud flow and/or volumes 5. “Best” Connection & Tripping practices 6. Safe and/or dynamic circulating procedures
- 24. 2009 rev 1Kingdom Drilling Services Pressure management
- 25. 2009 rev 1Kingdom Drilling Services Flow show’s • Losses & gains – While drilling – Drilled – Swabbed / surged – High pressure – low volume – Well instability
- 26. 2009 rev 1Kingdom Drilling Services Tripping and circulating • Every effort must be made to ensure control and stability of the well bore at all times while tripping, circulating and/or when applying rotating practices. • “Best Practices” must be maintained and controlled at all times.
- 27. 2009 rev 1Kingdom Drilling Services Special considerations • Casing design and setting depths • Mud programme • Cement programme • Fishing, milling, casing cutting • WBM, OBM, SBM, Brines • Well servicing, work-over, re-completion
- 28. 2009 rev 1Kingdom Drilling Services Well Control • Engineers in office can aid in well control by: – Provide pressure profiles for all pending wells – Provide offset information such as logs, bit records, mud reports, drilling records. – Provide support and assistance personnel on location.
- 29. 2009 rev 1Kingdom Drilling Services Lost circulation detection 1.Establish loss rate. 2.Check all surface equipment 3.Check no mud has been dumped/transferred or no solids control equipment has been switched on. 4.Check that the riser slip joint packing is not leaking.
- 30. 2009 rev 1Kingdom Drilling Services Lost circulation actions • Establish dynamic and static loss conditions. (instantaneous, gradual) – Depth & formation type – Establish loss rate – Check surface equipment – Check with logger / driller – Check marine riser components – Leaking casing? • Losses on bottom of further up the hole?
- 31. 2009 rev 1Kingdom Drilling Services Curing Lost Circulation • Reduce mud weight • Reduce pressure effects • Use lost circulation material – Fibrous materials – High Fluid Loss Slurries – Reinforcing Plugs and Cement • Special formulation’s
- 32. 2009 rev 1Kingdom Drilling Services Lost Circulation w/Flow Well Flow AfterWell Flow After Losses?Losses? YesYes Displace PillsDisplace Pills Squeeze DPSqueeze DP & Annulus& Annulus Secure WellSecure Well Hole onHole on Vacuum?Vacuum? Fill Pipe & AnnulusFill Pipe & Annulus Until Pills ReadyUntil Pills Ready LossesLosses Cured?Cured? YesYes Circulate KickCirculate Kick PillsPills NoNo NoNo YesYes Circulate KickCirculate Kick SpecialSpecial PillPill LossesLosses Cured?Cured? LossesLosses Cured?Cured? NoNo NoNo YesYes Circulate KickCirculate Kick
- 33. 2009 rev 1Kingdom Drilling Services Lost Circulation on Shut-in Attempt CirculationAttempt Circulation Determine Loss RateDetermine Loss Rate Severe orSevere or CompleteComplete Losses?Losses? NoNo ConventionalConventional LCM Pills WhileLCM Pills While Circulating KickCirculating Kick Strip Pipe AboveStrip Pipe Above Loss Zone?Loss Zone? Displace PillDisplace Pill Squeeze DPSqueeze DP & Annulus& Annulus LossesLosses Cured?Cured? YesYes NoNo Circulate KickCirculate Kick Circulate KickCirculate Kick
- 34. 2009 rev 1Kingdom Drilling Services Lost circulation while cementing • Reduce ECD’s – Pump rate – Mud, spacer, properties • Treat the zone • Add LCM to cement • Pull the casing /liner
- 35. 2009 rev 1Kingdom Drilling Services Well Control Terminology • Hydrostatic pressure – = .052 x MW.ppg x TVD.ft
- 36. 2009 rev 1Kingdom Drilling Services Hydrostatic Pressure • Derive HSP equation • Calculate the HSP for each of the following: – 10,000ft of 12.0ppg mud – 12,000ft of 10.5ppg mud – 5,000ft of 11.2ppg mud on top of 6,000ft of 16.5ppg mud
- 37. 2009 rev 1Kingdom Drilling Services Hydrostatic Pressure • Derive HSP equation – Area = A, sq.ft. – Height = h, ft. – Density = MW, ppg • Weight of fluid = – A*h (ft3)*62.4 lb/ ft3 *MW/8.33 – =62.4/8.33*MW*A*h h A MW
- 38. 2009 rev 1Kingdom Drilling Services Hydrostatic Pressure • This weight is equally distributed over an area of A sq.ft or 144*A sq. in. • Pressure = Weight (force)/area • = 62.4*MW*A*h • 8.33*144*A • P=.052*MW*h where h=TVD
- 39. 2009 rev 1Kingdom Drilling Services Terminology • Pressure Gradient – psi/ft = .052 x MW – ppg equivalent • Formation Pressure – Normal pressure – Abnormal pressure – Subnormal pressure
- 40. 2009 rev 1Kingdom Drilling Services Terminology • Overburden pressure – function of rock and fluid above zone of interest • Fracture pressure
- 41. 2009 rev 1Kingdom Drilling Services Terminology • Pump pressure or system pressure loss
- 42. 2009 rev 1Kingdom Drilling Services Terminology • Slow Pump Pressure • Taken: – every tour by each driller – pumps repaired or liners changed – mud properties change – every 500’ of hole – change in BHA – bit nozzles changed
- 43. 2009 rev 1Kingdom Drilling Services Terminology • Surge pressure • Swab pressure
- 44. 2009 rev 1Kingdom Drilling Services Terminology • Shut-in drillpipe pressure - SIDPP – FP = HSPdp + SIDPP • Shut-in casing pressure - SICP – FP = HSPcsg mud + HSPinflux + SICP • Bottom-hole pressure - BHP – BHP = HSP + SIP + Friction + Surge - Swab
- 45. 2009 rev 1Kingdom Drilling Services U-Tube Concept
- 46. 2009 rev 1Kingdom Drilling Services Basic Calculations • Dia, in - cap, bbl/ft dispCapacityWetdisp IDODftwt DCdisp ftwt DPdisp ODID AnnularCap IDCapacity pipehole 10292750 / 2600 / 1029 1029 22 22 2
- 47. 2009 rev 1Kingdom Drilling Services Basic Calculations • Pump Output – Duplex Pump – Triplex Pump effRDLDSLTPOduplex 22 2000162.0 effLDSLTPOtriplex 2 000243.0
- 48. 2009 rev 1Kingdom Drilling Services Basic Calculations
- 49. 2009 rev 1Kingdom Drilling Services Basic Calculations • Kill Weight Mud – KWM = SIDPP/(0.052 x TVD) + OWM – KWM = FP/(0.052 x TVD)
- 50. 2009 rev 1Kingdom Drilling Services Weight material to add to increase density 2.25/ 60 )(2.25 64.17/ 42 )(64.17 96.15/ 38 )(96.15 7.14/ 35 )(7.14 sxGalenaPitGain KWM OWMKWMMudVol sxGalena esxIronOxidPitGain KWM OWMKWMMudVol esxIronOxid sxIlmenitePitGain KWM OWMKWMMudVol sxIlmenite sxBaritePitGain KWM OWMKWMMudVol sxBarite
- 51. 2009 rev 1Kingdom Drilling Services Well Control Introduction Summary • Well control cannot be like looking through your rear view mirror • It is about looking ahead, anticipating the hazards and risks, ensuring you have plans procedures and contingencies in place set to handle any situation or circumstances the well may present to you at the rig-site. • Best practices exist so stick to them!
- 52. www.kingdomdrillng.co.uk Thanks for takingthe time to review this presentation