WELL Control and procedure

Nippling up diverter onshorePolicyA class D diverter stack shall be installed on the conductor and/or next casing string for all exploration wells and development wells in the shallow gas area of areas where offset data indicates shallow gas wells.All other onshore areas do not need a diverter.In addition,this diverter stack will also be required on the conductor of all offshore exploration wells and wells where offset data indicates possible shallow gas.The diverter lines shall consist of Schedule40steel piping.This line shall be securely anchored and terminate in the reserve pit or overboard.Saudi Aramco requires two6”minimum ID,full bore valves and10”lines.All lines must be as straight as possible and all turns targeted to minimize erosion.The emergency pump in connection shall be a3-1/8”2M flanged connection,located90 degrees offset from the diverter lines(as noted in figure B-8.1below).The kill line shall be connected directly to the mud pumps or to the stand pipe manifold.Slow pump rate dataPolicy slow pump rate shall be recorded in the IADC tour book1)Tourly2)After a mud weight change3)After a bit nozzle of BHA change4)After each500`of depth5)After a drilling or completion fluid type change6)Whenever mud properties significantly changeNOTE:All flow checks shall be at least15minutes.Tripping pipePulling Out Of HolePOLICY The following procedure is required when POOH1)Ensure a full opening safety valve,inside BOP,closing wrench,and crossover subs are on rig floor2)Record data on trip sheet every5stands for DP,2stands for HWDP,and every stand for DC3)Compare data to expected displacement valuesNOTE:Avoid pulling a wet string whenever possible.RUNNING IN HOLEPOLICY The following procedure is required when RIH1)Ensure full opening safety valve,inside bop,closing wrench,and crossover subs are on rig floor2)Run in hole approximately one minute per stand3)Record data on trip sheet every5stands for DP,2stands for HWDP,and every stand for DC4)Compare data to expected displacement values5)Fill drill pipe every10to20standsNOTE:Use the trip tank when running casing.Performing flow checks while drillingPolicy A flow check shall be performed whenever1)Decrease in pump pressure2)Increase in pump strokes3)Decrease in mud weight4)Increase in chlorides5)Gradual increase in drill rate6)Drilling breakNOTE:All flow checks shall be at least15minutesPERFORMING FLOW CHECKS WHILE TRIPPINGPOLICY:A FLOW CHECK SHALL BE PERFORMED WHENEVER1)When the hole is not taking the correct amount of fluid2)Before pumping a slug3)*Before pulling out of the hole4)*After pulling5to10stands5)When bit enters casing shoe6)*Prior to pulling last5stands7)Prior to pulling the BHA*Indicates additional flow checks required when a hydrocarbon zone is open.NOTE:All flow checks shall be at least15minutes.Displacing to brine on horizontal wellsPOLICY The following SHALL BE required1)A brine density that will provide the same overbalance(at bottom hole temperature) as mud weight utilized2)Measurement of brine density in/out to verify that both are the same at same temperature3)A minimum of one hour to wait/observe well after displacing to brine4)Pumping out of the hole for minimized swabbing,continued fill-up,and improved gas displacement in the horizontal open holeShutting in wellShutting in well without a flow checkPOLICY Immediate action should be taken to shut in well whenever there is:1)An increase in pit gain2)An increase in flow rateShutting in well while DrillingPOLICY Shut-in procedure(HARD SHUT-IN)1)Space OUT(SPOT TOOL JOINT)2)Stop mud pumps3)Close annular or upper ram preventer4)Confirm well is shut in and flow has stopped5)Open HCRShutting in well while trippingPOLICY Shut-in procedure(HARD SHUT-IN)1)Stab full open safety valve2)Close safety valve3)Space out(spot tool joint)4)Close annular or upper ram preventer5)Confirm well is shut in and flow has stopped6)Open HCRNOTE:DO NOT attempt to run in hole with the well flowing.Shutting in well while BHA across BOP StackPOLICY Shut-in procedure(HARD SHUT-IN)1)Set slips2)Install crossover to full open safety valve3)Stab full open safety valve4)Close safety valve5)Close annular6)Confirm well is shut in and flow has stopped7)Open HCR8)Install inside BOP9)Open safety valve10)Reduce closing pressure on annular and strip-in a stand of drill pipeNOTE:In the event of a failure in the annular(with BHA across bop stack)and uncontrolled flow,the BHA should be dropped and well shut in with the blind rams.Shutting In On Pre-Perforated Liner with Drill PipePOLICY Shut-in procedure1)Set casing slips2)Install XO`s to DP3)Make up a stand of DP and RIH4)Stab full open valve and close valve5)Install inside bop and open safety valve6)Shut upper pipe rams7)Open HCRNOTE:If this procedure can not be accomplished due to the amount of flow(or inner string),the liner shall be dropped(by closing pipe rams,hanging off,and opening pipe ram)and shutting the blind rams.Kill Sheets and Related CalculationsNormal kill sheetPre-recorded DataOriginal mud weight(OMW)_______________________________________ppgMeasured depth(MD)________________________________________ftKill rate pressure(KRP)_________________psi@________________spmKill rate pressure(KRP)_________________psi@________________spmDrill String VolumeDrill pipe capacity________________bbl/ft x___________length,ft=______________bblDrill pipe capacity________________bbl/ft x___________length,ft=______________bblDrill collar capacity________________bbl/ft x___________length,ft=______________bblDrill collar capacity________________bbl/ft x___________length,ft=______________bblTotal drill string volume_____________________________bblAnnular VolumeDrill collar/open holeCapacity________________bbl/ft x___________length,ft=______________bblDrill collar/open holeCapacity________________bbl/ft x___________length,ft=______________bblDrill pipe/open holeCapacity________________bbl/ft x___________length,ft=______________bblDrill pipe/casingCapacity________________bbl/ft x___________length,ft=______________bblTotal barrels in open hole______________________________bblTotal annular volume______________________________bblPump DataPump output____________________bbl/stk@_________________%efficiency Surface to bit strokes:Drill string volume______________bbl÷__________pump output,bbl/stk=______stk Bit to casing shoe strokes:Open hole volume______________bbl÷__________pump output,bbl/stk=______stk Bit to surface strokes:Annulus volume______________bbl÷__________pump output,bbl/stk=______stk Maximum allowable shut-in casing pressure:Leak-off test________psi,using ppg mud weight@casing setting depth of_________TVDKick dataSIDPP___________________________________________psiSICP____________________________________________psiPit gain_________________________________________bblTrue vertical depth________________________________ftCalculationsKill Weight Mud(KMW)=SIDPP_______psi÷0.052÷TVD__________ft+OMW_________ppg=___________ppgInitial Circulating Pressure(ICP)=SIDPP_________psi+KRP________psi=___________psiFinal Circulating Pressure(FCP)=KMW__________ppg x KRP________psi÷OMW_________ppg=__________psiPsi/stroke(ICP psi-FCP)__________psi÷strokes to bit________=_______psi/stkPressure ChartStrokes Pressure0<Initial circulating pressureStrokes to bit><Final circulating pressure Equivalent Circulating Density(ECD),ppgECD,ppg=(annular pressure,loss,psi)÷0.052÷TVD+(mud weight,in use,ppg) Maximum Allowable Mud Weight from Leak-off Test Data MAMW=(Leak-off Pressure,psi)÷0.052÷(Casing Shoe TVD,ft)+(mud weight,ppg)Slug volume=(Mud x ft of dry pipe)÷(Slug wt-mud)x dry pipe capacityAccumulator testsThese tests are for the purpose of determining the operating condition of the accumulator and BOP system.They shall be performed every14days,at the same time the BOP equipment is pressure tested,and at any other time deemed necessary by the Saudi Aramo Foreman.the results shall be noted on the Saudi Aramco BOP Pressure Test Report(see Test Form).To analyse the performance of the accumulator,the results of recharge time indicates an immediate need for a thorough examination of the accumulator*Record the accumulator capacity and useable volume*Record the accumulator pressure*Record the pre-charge pressure and last date checked*Record the closing and opening times for each componentNOTE:Alternate accumulator bi-weekly tests between the main nitrogen unit(with charging system isolated)and air/electric back-up system(with bottle banks isolated).Preventer functions should also be operated remotely to insure proper operation of all functions from the remote stations.The accumulator test shall also comply Saudi Aramco`s general requirements as follows: *Closing time for ram preventers should not exceed30seconds*Closing time for annular preventers(less than18-3/4”)should not exceed30seconds*Closing time for annular preventers(18-3/4”and larger)should not exceed45seconds *The accumulator must have enough stored fluid under pressure to close all preventers,open the choke hydraulic control gate valve(HCR),and retain50%of the calculated closing volume with a minimum of200psi above pre-charge pressure,without assistance of the accumulator pumps.*The accumulator-backup system shall be automatic,supplied by a power source independent from the power source to the primary accumulator-charging system,and possess sufficient capability to close all blowout components and hold them closed.。