drill bit parameters 090725040952 phpapp02
DESCRIPTION
drill bitTRANSCRIPT
MONITORING DRILLING BIT
PARAMETERS PARAMETERS
ALLOWS
OPTIMIZATION OF DRILLING RATES
V.C. KELESSIDIS - P. DALAMARINISsk l1@h tm il [email protected]
Technical University of CreteMineral Resources Engineering
SGEM 2009SGEM 2009Albena, June 14-19, 2009
Research aim
Optimization of drilling ratesLess expensive and safer drilling practicesH d b th l i i t ll Hydrocarbon, geothermal, mining, water well drillingMultitude of parameters affecting drilling performanceperformanceAvailability of data and proper modeling softwareOptimum combination better drilling ratesOptimum combination better drilling rates
22
The problemDrilling allows for access to subsurface target areastarget areasPythagoras saying ‘whoever digs, finds, he who never digs will never find’never digs, will never findDrilling is expensiveOptimum drilling practice arrive to target in the most economical way, but with safetyy yMain monitoring parameter – Penetration Rate (m/h)(m/ )Depends on two main groups
FormationFormationDrilling parameters 33
Main parametersFORMATION
Local stressesLocal stressesRock compactionMineralogical contentFluid pore pressureFlu d pore pressure
DRILLINGDRILLINGWeight on bit and torqueRpmHydraulic parametersy p mBit condition
44
Modeling drilling process - TealeRock-bit interactionEnergy to the bitEfficiency of energy transferff y f gy f
( )( )( )AWOBDRPMWOBSE bitt
/8 μ+=ENERGY PER
ROPASE
bitt +
UCS
UNIT VOLUME
ROCK-BIT MODEL tSEeff
UCS=
( ) ( )( )WOBUCS
AbitWOBDRPMROP =/)(8 μ
55AbitWOB
effUCS
−
Payzone simulatorDeveloped by G. Cooper, UCBSimilar to Teale’s model predictionsAdjustable parametersj p mUse of historical data for tuning
SPE 30213 36660
))()()()()(( GlengthtoothRPMtyaggressiviCfactorflowROP =
SPE 30213, 36660
))(_)()()()(_( GlengthtoothRPMtyaggressiviCfactorflowROP =
⎤⎡ ⎞⎛⎞⎛curv
( ) ⎥⎥⎦
⎤
⎢⎢⎣
⎡⎟⎟⎠
⎞⎜⎜⎝
⎛⎟⎠⎞
⎜⎝⎛−−=
lengthtoothDUCSWOBG
curv
*4.012exp1 5.2
66
( ) ⎥⎦⎢⎣ ⎠⎝⎠⎝ g_
Comparison of models with lab data
77
Use of historical data
88
Data neededLithologyBit records and bit typesCasing scheduleCasing scheduleDrilling parameters
WOB, RPM, FLOW RATE, PRESSUREPRESSUREROP
Drilling fluid
99
Adequate simulation
1010
Case study analysisDrilling in Norwegian Continental ShelfReconstruct drill time logReconstruct drill time log1917 – 2414 mFour main lithologies, 18 formation intervals
1111
Base case and two scenarios
1.Normal drilling curve1.Normal drilling curve 2.Drilling curve with
RPM+50 rpmRPM+50 rpm3.Drilling curve with
WOB+45 kNWOB+45 kN
1212
Full scenarios
1 B d illi ti l t1.Base drilling time plot2.Simulated drilling time
l t b h i t 4 5plot by having extra 4.5 tons, extra 50 RPM and
t 200 lextra 200 lpm
1313
Increase in UCS by 50%
Increase may range between 58y gand 96%, giving an overall increase in total drilling time for
1414
gthe sections chosen for the simulation of 82%
ConclusionsPenetration rate – the most sought after
t f d i f ll d illiparameter for design of well drillingAttempts to simulate the process – none very successfulRecent advances, flexible simulators that , fcould be used on sitePayzone is one of them (G Cooper)Payzone, is one of them (G. Cooper)Drilling advance model, few adjustable parametersparametersCan be tuned via use of prior historical data f th i d th fi ldfrom the region and the field
1515
ConclusionsData: WOB, RPM, Flow, well geometry, drill bit record, ROP, LithologygyNormally monitored – need to monitor in non-critical wells alsocritical wells alsoCan be used to effectively model and describe the drilling processthe drilling processRe-engineering and re-drilling possible, no reat difficultiesgreat difficulties
Increase in WOB, RPM, Flow -> beneficial ff d b bi effect, need to worry about bit wear
Increase (error) of UCS by 50% decrease yin ROP by 82%
1616