IPM Well control Basic

INTEGRATED PROJECT MANAGEMENT Well Control Drilling Essentials Objectives On completion of this module you will be able to:  Describe the causes, detection, prevention and minimization of kicks  Understand the concept of ‘U’ -tube and how it applies to well control  Be familiar with the Shut -in procedures  Explain the function of various Well control equipment  Understand Constant BHP well control and other methods of well control Well Control Incident Main “Root Causes” in Well Control Incidents No compliance with standards and procedures Lack of knowledge and skills of rig personnel Lack of commitment and leadership of the Person In Charge Poor work practices Inadequate well design Not followingdrillingparameters trends No alignment with service providers Inadequate risk management / management of change process Lack of communication / clarification of work instructions Definitions Influx: Intrusion of the formation fluids or formation gas into the wellbore Kick: Influx of formation liquids or gas that results in an increase in pit volume is It physically observed by the well flowing (i.e kick) as a result of insufficient overbalance.Without corrective measure, this condition can result in a blowout Blowout: An uncontrolled flow of well fluids and/or formation fluids from the wellbo or into lower pressured subsurface zones (underground blowout) Underground Blowout: An uncontrolled flow of formation fluids in the wellbore from higher pressure zone into a lower pressure zone, The flow is most likely to travel u the wellbore, but can on occasions travel down the wellbore to the receiving formation Well Control Primary well control :  The use of the drilling/completion fluid’s weight to provide sufficient hydrostatic pressure to prevent an influx Secondary well control:  When primary well control is lost, BOPs are closed and a kick control method (usi kill mud weight) is implemented to kill the well “Tertiary” well control:  Relying on the formations’ strength below surface to contain the wellbore fluids  (Gunk) plugs, barite plugs, cement plugs may be used, and ultimately well capping and / or a relief well Barriers Typically, where drilling is in progress, the following barrier status will normally exist: A (primary) barrier consisting of a homogenous mud column with a hydrostatic overbalance on the pore pressure A (secondary ) barrier consisting of a cemented casing, wellhead, pipe ram or annular preventer and drill string with kellyvalve or check valve During testing, completion, workover and P&A operations (Plugging and Abandonment), the principle of a double barrier remains similarly applicable Well Control Equipment BOP Stack BOP Stack Configuration No hard rules are given regarding the BOP stack arrangement (relative position of the different elements) All stack arrangements have pros and cons, and it is the project responsibility to decide which arrangement best suits the project requirements Refer to APIST 53 for some recommended arrangements Driller’s Method Step 1: circulate gas out holding constant BHP CDPP First circulation (original mud) CDPP = Constant until influxis out of the hole P1 = P2 Driller’s Method:1st Circulation Drill Pipe Casing Driller’s Method:1st Circulation The maximum shoe pressure is when the top of the influx reaches the shoe Driller’s Method:1st Circulation When the influx is passing the casing shoe, the shoe pressure will decrease Driller’s Method:1st Circulation • When the influx is above the casing shoe, the shoe pressure will remain constant Driller’s Method Step 2: circulate KMW in holding constant BHP Second circ.: kill mud Circulation pressure decreases from initial circ pressure to final circ pressure (while heavier mud fills up the DP) Final circ constant until the kill mud reaches surface P1 = P2 Driller’s Method: 2nd Circulation Drill Pipe Casing Wait and Weight Method Circulate gas out with KMW in holding constant BHP Onlyone circulation: Circulation pressure decreases from initial circ pressure to final circ pressure (while heavier mud fills up the DP) P1 = P2 Pressure Changes at Casing Shoe Case Driller’s Method First circulation Case Wait and Weight (No gas migration) Case 3a Case 3b Wait and Weight (Gas migration) Driller’s Method Advantages: Simplicity– Lesscalculationsare requiredthan Waitand Weightmethod Canstart circulationimmediately– Effectof gas migrationreduced Removesinfluxand stabilizeswellborepressureat earliestpossibletime Viableoptionif limitedbariteis available Disadvantages : Methodwillrequireat least two circulations Undercertainconditionsthe highestshoe pressure Twocirculationsmaycause damageto wellcontrolequipment Wait and Weight Method Advantages: In some circumstances,it generates the lowest pressure on the formationnear casing seat Ina longopenholesection,it is the least likelymethodto inducelost circulation Requiresone less circulation,thereforeless damageto equipment ‘Defacto’standardformajorityof ourClients Disadvantages : Requireslongest waiting period prior to circulation In a case where a significant amountof hole is drilledpriorto encounteringthe kick,the cuttingsmaysettle out and plugannulus Gasmigrationis a problemwhilethe densityof the systemis increased [...]... Configuration AP SBR PR HCR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you have a leak in the PR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SBR by another type of PR? 6 Is it possible to kill the well using the Driller’s... Configuration AP SBR HCR PR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you are repairing the LPR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SBR by another type of PR? 6 Is it possible to kill the well using the Driller’s... Configuration AP SBR HCR PR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you are repairing the LPR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SBR by another type of PR? 6 Is it possible to kill the well using the Driller’s... AP PR SBR HCR PR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you are repairing the LPR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SBR by another type of PR? 6 Is it possible to kill the well using the Driller’s... Configuration AP PR BR HCR PR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you are repairing the LPR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SR by another type of PR? 6 Is it possible to kill the well using the Driller’s... AP PR SBR PR HCR The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 If you are repairing the LPR and the well starts flowing, can you shut-in the well? 5 Is it possible to replace the SBR by another type of PR? 6 Is it possible to kill the well using the Driller’s... Is it possible to kill the well using the Driller’s Method? AP PR SBR HCR BOP Stack Configuration The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 Is it possible to replace the SBR by another type of PR? 5 Is it possible to kill the well using the Driller’s Method?... BOP Stack Configuration The well is under pressure: 1 Is it possible to repair the side outlets? 2 Is it possible to replace the PR by new ones? 3 Is It possible to replace the packing element on the annular BOP? 4 Is it possible to replace the SBR by another type of PR? 5 Is it possible to kill the well using the Driller’s Method? AP SBR PR HCR BOP Stack Configuration The well is under pressure: 1 Is... kill RAMS line valves BLIND UPPER RAMS BOTTOM RAMS Inner/Outer choke line valve MIDDLE RAMS BOTTOM RAMS Outer/Inner kill line valves LOWER RAMS BOTTOM RAMS Stack connector Wellhead Choke line Annular  Close/seal on any object in the wellbore  Sizes from -1/16 7 to 29-1/2 in  Pressures from 2K to 20K psi  Often called “theHydrill ” Annular Preventer Annular Preventer Packing Unit Pipe Ram Pipe ram... pressure from below Pipe ram Variable Bore Ram Top Seal Body Packer Variable Bore Ram Shear/Blind ram  Both shears drill pipe and seals the hole  Capacity to cut through 5” drill pipe  Emergency equipment  Top seal and side packers  Can seal on open hole Top seal Side Packers Large frontal area Shear/Blind ram Top Seal Upper Shear Ram Blade Side Packer Lower Shear Ram assembly Face Seal Shear/Blind