drilling-hydraulics-a.ppt

PETE 203DRILLING ENGINEERINGDrilling Hydraulics

Drilling HydraulicsEnergy BalanceFlow Through NozzlesHydraulic HorsepowerHydraulic Impact ForceRheological ModelsOptimum Bit Hydraulics

Nonstatic Well ConditionsPhysical Laws: Conservation of Mass Conservation of energy Conservation of momentumRheological Models Newtonian Bingham Plastic Power Law API Power-LawEquations of State Incompressible fluid Slightly compressible fluid Ideal gas Real gas

Average Fluid Velocity

Pipe Flow Annular FlowWHERE v = average velocity, ft/s q = flow rate, gal/min d = internal diameter of pipe, in. d2 = internal diameter of outer pipe or borehole, in. d1 =external diameter of inner pipe, in.

Law of Conservation of EnergyStates that as a fluid flows from point 1 to point 2:In the wellbore, in many cases Q = 0 (heat)r = constant{

In practical field units this equation simplifies to:p1 and p2are pressures in psiris density in lbm/gal.v1 and v2are velocities in ft/sec.Dppis pressure added by pump between points 1 and 2 in psiDpfis frictional pressure loss in psiD1 and D2are depths in ft.

where

Determine the pressure at the bottom of the drill collars, if(bottom of drill collars)(mud pits)

Velocity in drill collars Velocity in mud pits, v1

Pressure at bottom of drill collars = 7,833 psigNOTE: KE in collars

May be ignored in many cases

Fluid Flow Through Nozzle Assume:

IfThis accounts for all the losses in the nozzle.Example:

For multiple nozzles in //Vn is the same for each nozzle even if the dn varies! This follows since Dp is the same across each nozzle.&

Hydraulic HorsepowerHHP of pump putting out 400 gpm at 3,000 psi = ?

PowerIn field units:

Hydraulic Impact ForceWhat is the HHP Developed by bit?

Consider:

Impact = rate of change of momentum

Newtonian Fluid ModelShear stress = viscosity * shear rate

Laminar Flow of Newtonian Fluids

Newtonian Fluid ModelIn a Newtonian fluid the shear stress is directly proportional to the shear rate (in laminar flow):

i.e.,The constant of proportionality, is the viscosity of the fluid and is independent of shear rate..

Newtonian Fluid ModelViscosity may be expressed in poise or centipoise..

Shear Stress vs. Shear Rate for a Newtonian FluidSlope of line = m.

Example - Newtonian Fluid

Example 4.16Area of upper plate = 20 cm2

Distance between plates = 1 cm

Force reqd to move upper plate at 10 cm/s = 100 dynes.

What is fluid viscosity?

Example 4.16

Bingham Plastic Model

Bingham Plastic Modelt and ty are often expressed in lbf/100 sq.ft

Power-Law Model

Power-Law Modeln = flow behavior indexK = consistency index

Rheological Models1. Newtonian Fluid:

2. Bingham Plastic Fluid:What if ty = 0?

Rheological Models

3. Power Law Fluid:

When n = 1, fluid is Newtonian and K = m We shall use power-law model(s) to calculate pressure losses (mostly).K = consistency indexn = flow behavior index

Velocity Profiles(laminar flow)Fig. 4-26. Velocity profiles for laminar flow: (a) pipe flow and (b) annular flow

It looks like concentric rings of fluid telescoping down the pipe at different velocities3D View of Laminar Flow in a pipe - Newtonian Fluid

Summary of Laminar Flow Equations for Pipes and Annuli

Fig 4.33: Critical Reynolds number for Bingham plastic fluids.

Fig 4.34: Fraction Factors for Power-law fluid model.

Total Pump PressurePressure loss in surf. equipmentPressure loss in drill pipePressure loss in drill collarsPressure drop across the bit nozzlesPressure loss in the annulus between the drill collars and the hole wallPressure loss in the annulus between the drill pipe and the hole wallHydrostatic pressure difference (r varies)

Total Pump Pressure

Types of FlowLaminar Flow

Flow pattern is linear (no radial flow) Velocity at wall is ZERO Produces minimal hole erosion

Types of Flow - LaminarMud properties strongly affect pressure lossesIs preferred flow type for annulus (in vertical wells)Laminar flow is sometimes referred to as sheet flow, or layered flow:

* As the flow velocity increases, the flow type changes from laminar to turbulent.

Types of FlowTurbulent Flow

Flow pattern is random (flow in all directions)

Tends to produce hole erosion

Results in higher pressure losses (takes more energy)

Provides excellent hole cleaningbut

Types of flowMud properties have little effect on pressure losses

Is the usual flow type inside the drill pipe and collars

Thin laminar boundary layer at the wall Turbulent flow, contdFig. 4-30. Laminar and turbulent flow patterns in a circular pipe: (a) laminar flow, (b) transition between laminar and turbulent flow and (c) turbulent flow

Turbulent Flow - Newtonian FluidThe onset of turbulence in pipe flow is characterized by the dimensionless group known as the Reynolds numberIn field units,

Turbulent Flow - Newtonian FluidWe often assume that fluid flow is turbulent if Nre > 2,100

PPUMP = DPDP + DPDC

+ DPBIT NOZZLES

+ DPDC/ANN + DPDP/ANN

+ DPHYD

Q = 280 gal/min

r = 12.5 lb/gal

Pressure Drop CalculationsPPUMP

DRILLPIPEDRILL COLLARSBIT NOZZLESANNULUS2103

Chart1

2102.9670499035

1437.5969525543

1210.8178961575

184.7500822564

153.1521751633

0

Distance from Standpipe, ft

"Friction" Pressure, psi

"Friction" Pressures

Equations

Wellbore Pressures in SMD

14-Jun-99

Microsoft Equations - DrillstringMicrosoft Equations - Annulus

LAMINAR

alt

Conv. Pressure Profile

Pressure Drop CalculationsSummary of ResultsConventional Well Control Kill SheetProcedures (simplified)ASSUMPTIONS

Before Kick Circulation Rate280gal/minStandpipeTVD0ftKWM0.0lb/gal

2,103psiPressures DropsWithWithKick Intensity =1lb/galTimePressure1Kick is detected (assume SMALL kick)Water Depth0ftSeawater Hydrostatic0psi

Old MudKill MudDifference= 0.052 * 1 * (11,400+600)624psiMinpsiOld MW0lb/galFinal MLP Inlet Pressure0psi

Circulation Rate280gal/min2Slow down MLP until influx stops.Kick Intensitylb/galFinal Annulus Hyd. Pressure0psi

Pressure Drop in Drillpipe665psi704psi39psiStart Circulating02,727At this point the actual (dynamic) BHP is equal to the pore pressure.New Pore Pressure0psiPore Pressure0psiPressure Drop In Circular Pipe

Kick Intensity1lb/galPressure Drop in Drill Collars227psi240psi13psiOld Mud Hydrostatic in Annulus7,800psiKWM at Bit24.32,271

Pressure Drop Across Bit Nozzles1,026psi1,108psi82psiNew BHP8,424psiKWM Filling Annulus282,2713Slow down Rig Pump while increasig MLP Inlet Pressure by0psiPressure Drop In Circular Annulus

Mud Propertiesto compensate for loss of AFP.Circulation Rategal/mingal/minASSUMPTIONS

Density12.5lb/galPressure Drop in DC/Hole Annulus32psi32psi0psiDrillpipe Capacity158bblBHP remains at0psiAnnular Friction w/OWM0psi

3Pressure Drop in DP/Hole Annulus153psi153psi0psiDC Capacity3.6bblAnnular Friction w/KWM8psiCirculation Rate300gal/minASSUMPTIONS

20TOTAL Drillstring Capacity161.9bbl4Measure SIDP0psi

39Total Pressure Loss2,103psi2,237psi134psiMud PropertiesCirculation Rate280gal/min

65Standpipe Pressure2,103psi2,237psi134psiTime to top of DC = Capacity/Rate23.7min5Kill Rate Circulating Pressure0psiDensity16lb/gal

Time to top of Bit = Capacity/Rate24.3min130Mud Properties

Wellbore GeometryTime to Bottom of Hole24.3min6ICP = KCP + SIDP0psiPRESSURE CHANGES with Change in MW230Density16lb/gal

Drillpipe OD4.5inAnnulusSummary of PressuresAt this point the circulating BHP0psi11

Drillpipe ID3.78inStandpipe Pressure2,103psi2,237psi134psiKCP =2,103This exceeds the pore pressure by the AFP (OWM) by0psiPipe LengthPipe ID5.965in60

Drillpipe Length11,400ftAt Top of Drill Collars8,848psi9,536psi688psiSIDP (underbalance) =624psipsipsipsiftPipe Length29,100ft

153psidAbove Bit9,011psi9,717psi706psiICP = KCP + SIDP =2,727psi7Follow Drillpipe Pressure Reduction Schedule while filling Drillstring with KWM.Pipe/Hole Annulus - outer dia.12.25in

Drill Collar OD6.5in32psidBelow Bit (BHP)7,985psi8,609psi624psiFCP = KCP * (KWM/OWM) =2,271psiDrillpipe000inPipe/Hole Annulus - inner dia.8in

Drill Collar ID2.5inAt Top of DC/Hole Annulus7,563psi8,156psi593psi8Keep Drillpipe Pressure Constant while filling Annulus with KWM.HW000inPipe/Hole Annulus - Length.300ft

Drill Collar Length600ftAt Top of DP/Hole Annulus (Surface)0psi0psi0psiDC00032ndsPressure Drop inside Pipe378.48psi

DSV000~0

Nozzle Sizes1132ndsDrillstringBit Nozzles000~0Pressure Drop in Annulus=9.16psi

1132ndsKill Sheet wo/Effect of Density on ViscosityTOT. Drillstring0000=0.8226

1232ndsConstant BHP = New Pore Pressure=3.930

665psid=3.440ft/sec=0.4841

Hole Size8.5in8,848psig2,727psiStandpipeStandpipe=201.384=25.508

227psidTimePressureTimePressure=1512.9=1.3274074074ft/sec

1,026psid9,011psigChange in DP Hydrostatic593psiMinpsiMinpsiAnalysis of CONVENTIONAL Kill SheetIf Laminar=0.0105756=414.700cP

7,985psigHydrostatic Pressures:Change in DP Friction39psidP/dL=0.013006psi/ft=202

0.02,5420.02,727=378.48psiIf Laminar=0.118818

Summary of Pressure DropsPressure at Top of Drillpipe0psiChange in DC Hydrostatic31psi23.71,98823.72,173From above, ICP0psiIf Turbulenta=0.0769042438dP/dL=0.030538psi/ft

Inside Drillpipe665psiAnnular Hydrostatic =7,800psiPressure at Top of Drill Collars7,410psiChange in DC Friction13psi24.31,97024.32,155FCP = KCP * (KWM/OWM)0psib=0.2621125441=9.161psi

Inside Drill Collars227psiAnnular Friction =185psiPressure at Entrance to Bit7,800psi24.32,05224.32,237=0.0112845If Turbulent a=0.072298

Across Bit Nozzles1,026psiBHP =7,985psiBottomhole Pressure7,800psi82psi29.32,05229.32,237StandpipedP/dL=0.0138779b=0.29502

In DC/Hole Annulus32psiAnnulus Pressure at Top of Drill Collars7,410psiTimePressure=403.85psi=0.015101

In DP/Hole Annulus153psi0ftPressure at Top of Annulus (Surface)0psiMinpsidP/dL=0.00388

NOTE: Annular friction (Old Mud) =185psiStart Circulation00=1.16psi

Total Pressure Loss2,103psiKWM at Bit0.00

Standpipe Pressure2,103psiKWM Filling Annulus0.00

Summary of Pressures

Standpipe Pressure2,103psi

At Top of Drill Collars8,848psi

Above Bit9,011psi17/16 =1.0625=>6.25%

Below Bit (BHP)7,985psiActual Wellbore Pressures Including Hydrostatics:Standpipe

At Top of DC/Hole Annulus7,563psiTimePressureTimeBHP

At Top of DP/Hole Annulus (Surface)0psiPressure at Top of Drillpipe2,103psiMinpsiMinpsi

11,400ftPressure at Top of Drill Collars8,848psiStart Circulation0000

Pressure at Entrance to Bit9,011psiKill Sheet w/Effect of Density on ViscosityKWM at top of HW24.3024.30

Bottomhole Pressure7,985psiConstant BHP = New Pore PressureKWM at top of DC24.3024.30

Annulus Pressure at Top of Drill Collars7,563psiKWM at top of DSV29.3029.30

CalculationsAnnulus Pressure at Surface0psiKWM at top of Bit0.000.00

KWM Below Bit0.000.00

KWM Filling Annulus0.000.00

1. Pressure Drop Inside Drillpipe2,727psiStandpipe

DepthTimePressure

Change in DP Hydrostatic592.8psiMinpsiTimePressure

0.0%Change in DP Friction0.00psiMinpsi

=0.7365411,400ft0.02,72700

600ftChange in DC Hydrostatic31.20psi23.72,1340.00

0.0%Change in DC Friction0.00psi24.32,1030.00

12,000ftpsi24.32,103

=2.01730.00psi29.32,103Conventional: ICP - FCP =0psi

okSMD, for Const BHP: ICP - FCP =0psi

okDifference =0psi

okNOTE: Annular friction =184.75psi

=7.9953ft/sec

Maximum Difference between BHP and Pore Pressure =0psi

AFP =0psi

Difference =0psi

Pressures Excluding Hydrostatics:

Pressure at Top of Drillpipe2,103psi

Pressure at Top of Drill Collars1,438psiProposed Kill Sheet (for discussion)

=52.989cpPressure at Entrance to Bit1,211psi

Bottomhole Pressure185psiStandpipe

Annulus Pressure at Top of Drill Collars153psi1. Include Annular Friction in ICPTimePressure

Pressure at Top of Annulus (Surface)0psiMinpsi

2. Consider Increase in Viscosity with Mud Weight

=6,616.00.02,727

23.72,134

24.32,103

24.32,103

29.32,103

2,271-2,103=168

=0.0024184

Dist. from

StandpipePressure

ftpsi

02,103

11,4001,438

11,9991,211

12,000185

dP/dL=0.019807psi/ft12,600153

24,0000

=225.80psi

Dist. from

StandpipePressure

ftpsi

00

11,4007,410

11,9997,800

=0.075943901412,0007,800

12,6007,410

24,0000

=0.268972133

=0.00712622

dP/dL=0.0583658

Dist. from

StandpipePressure

ftpsi

02,103

11,4008,848

11,9999,011

665.37psi12,0007,985

12,6007,563

24,0000

665.37psi

Shear

Rate at=221.21

the Wall

2. Calculate Pressure Drop inside Drill Collars

=0.73654

=2.0173

=18.278ft/sec

=38.218

=13,870

If Laminar=0.0011536Dist. from

dP/dL=0.074665psi/ftStandpipePressure

=44.799psiftpsi

If Turbulent a=0.07594402102.9670499035

b=0.26897114008847.5969525543

=0.0058397119999010.8178961575

dP/dL=0.37797120007984.7500822564

=226.78psi126007563.1521751633

240000

Pressure Drop inside the Drill Collars

=226.78psi

PressureDepth

psift

Shear2102.96704990350

Rate at=238.248847.596952554311400

the Wall9010.817896157511999

7984.750082256412000

PressureDepth

psift

00

7563.152175163311400

7984.750082256412000

PressureDepth

psift

00

741011400

780012000

Alternate Wellbore Pressure Profile:

Pressure at Top of Drillpipe2102.9670499035psi

Pressure at Top of Drill Collars8847.5969525543psi

Pressure at Entrance to Bit9010.8178961575psi

Bottomhole Pressure7984.7500822564psi

Annulus Pressure at Top if Drill Collars7563.1521751633psi

Pressure at Top if Drill Collars0psi

3. Calculate Pressure Drop Across Bit Nozzles

=1,026.07psi

Pressure Drop Across Bit Nozzles

=1026.07psi

4. Calculate Pressure Drop in DC/Hole Annulus

=0.54131

=6.33599

=3.8080ft/sec

=55.207cp

=1,600.3

=0.014998

dP/dL=0.052663psi/ft

48.2493054698

=31.598psi1.1096118473

53.538000973

=0.073269

=0.28808

=0.0087470

dP/dL=0.0307146

18.429psi

31.60psi

Shear

Rate at=351.62

the Wall

5. Calculate Pressure Drop in Drillpipe/Hole Annulus

=0.54131

=6.3360

=2.197ft/sec

=97.645

=1,044

If Laminar=0.0229893


=153.152psi

If Turbulent a=0.073269

b=0.28808

=0.0098923

dP/dL=0.00578

=65.90psi

Pressure Drop in Drillpipe/Hole Annulus

=153.15psi

Shear

Rate at=101.43

the Wall

Shear Rate at the Pipe WallShear Rate in Annulus

Shear RateReynolds No.

Q =0gal/min

Drillpipe00MW =0lb/gal

HW Drillpipe00

Drill Collars000

DC/Hole Annulus00

HW/Hole Annulus00

DP/Hole Annulus00

DP/Casing Annulus00

Total Pressure Drop in Drillstring =

665.37psi

+226.78psi

+1026.07psi49%

=1918.22psi91%


31.60psi

153.15psi

=184.75psi9%


2102.97psi100%

Pressure Drop CalculationsSummary of Results

with Kill Mud in Hole

2,237psi

Pressure Drop in DP/Hole Annulus153psi

Circulation Rate280gal/minPressure Drop in DC/Hole Annulus32psi

Pressure Drop Across Bit Nozzles1,108psi

Kick Intensity1lb/galPressure Drop in Drill Collars240psi

Pressure Drop in Drillpipe704psi

Mud Properties

Density13.5lb/galDist. from

3Pressures Excluding Hydrostatics:StandpipePressure

20ftpsi

39AnnulusPressure at Top of Drillpipe2,237psi02,237

65Pressure at Top of Drill Collars1,533psi11,4001,533

Pressure at Entrance to Bit1,293psi11,9991,293

Wellbore Geometry153psidBottomhole Pressure185psi12,000185

Drillpipe OD4.5in32psidAnnulus Pressure at Top of Drill Collars153psi12,600153

Drillpipe ID3.78inPressure at Top of Annulus (Surface)0psi24,0000

Drillpipe Length11,400ft

Drill Collar OD6.5in

Drill Collar ID2.5in

Drill Collar Length600ft

Drillstring

Nozzle Sizes1132ndsDist. from

1132ndsHydrostatic Pressures:StandpipePressure

1232nds704psidftpsi

Pressure at Top of Drillpipe0psi00

Hole Size8.5in9,536psigPressure at Top of Drill Collars8,003psi11,4008,003

240psidPressure at Entrance to Bit8,424psi11,9998,424

9,717psigBottomhole Pressure8,424psi12,0008,424

1,108psid8,609psigAnnulus Pressure at Top of Drill Collars8,003psi12,6008,003

Pressure at Top of Annulus (Surface)0psi24,0000

Summary of Pressure Drops

Inside Drillpipe704psiAnnular Hydrostatic =8,424psi

Inside Drill Collars240psiAnnular Friction =185psi

Across Bit Nozzles1,108psiBHP =8,609psi

In DC/Hole Annulus32psi

In DP/Hole Annulus153psi0ft

Total Pressure Loss2,237psi


Summary of Pressures


At Top of Drill Collars9,536psi

Above Bit9,717psiDist. from

Below Bit (BHP)8,609psiActual Wellbore Pressures Including Hydrostatics:StandpipePressure

At Top of DC/Hole Annulus8,156psiftpsi

At Top of DP/Hole Annulus (Surface)0psiPressure at Top of Drillpipe2,237psi02,237

11,400ftPressure at Top of Drill Collars9,536psi11,4009,536

Pressure at Entrance to Bit9,717psi11,9999,717

Bottomhole Pressure8,609psi12,0008,609

Annulus Pressure at Top of Drill Collars8,156psi12,6008,156

CalculationsAnnulus Pressure at Surface0psi24,0000

1. Pressure Drop Inside Drillpipe

Depth

=0.7365411,400ft

600ft

12,000ft

=2.0173

ok

ok

ok

=7.9953ft/sec

Dist. from

Alternate Wellbore Pressure Profile:StandpipePressure

ftpsi

Pressure at Top of Drillpipe2236.6841790976psi02236.6841790976

Pressure at Top of Drill Collars9535.6068525176psi114009535.6068525176

Pressure at Entrance to Bit9716.9033212696psi119999716.9033212696

=52.989cpBottomhole Pressure8608.7500822564psi120008608.7500822564

Annulus Pressure at Top if Drill Collars8155.9521751633psi126008155.9521751633

Pressure at Top if Drill Collars0psi240000

=7,145.3

PressureDepth

psift

2236.68417909760

9535.606852517611400

9716.903321269611999

8608.750082256412000

=0.0022392

PressureDepth

psift

00

8155.952175163311400

8608.750082256412000

dP/dL=0.019807psi/ftHydrostatic:PressureDepth

psift

00

8002.811400

842412000

=225.80psi

=0.0759439014

=0.268972133

=0.00698022

dP/dL=0.0617436

703.88psi

703.88psi

Shear

Rate at=221.21

the Wall

2. Calculate Pressure Drop inside Drill Collars

=0.73654

=2.0173

=18.278ft/sec

=38.218

=14,979



=44.799psi


b=0.26897

=0.0057201

dP/dL=0.39984

=239.90psi

Pressure Drop inside the Drill Collars

=239.90psi

Shear

Rate at=238.24

the Wall

3. Calculate Pressure Drop Across Bit Nozzles

=1,108.15psi

Pressure Drop Across Bit Nozzles

=1108.15psi

4. Calculate Pressure Drop in DC/Hole Annulus

=0.54131

=6.33599

=3.8080ft/sec

=55.207cp

=1,728.3

=0.013887


48.2493054698

=31.598psi1.1096118473

53.538000973

=0.073269

=0.28808

=0.0085552

dP/dL=0.0324444

19.467psi

31.60psi

Shear

Rate at=351.62

the Wall

5. Calculate Pressure Drop in Drillpipe/Hole Annulus

=0.54131

=6.3360

=2.197ft/sec

=97.645

=1,127



=153.152psi


b=0.28808

=0.0096754

dP/dL=0.00611

=69.61psi

Pressure Drop in Drillpipe/Hole Annulus

=153.15psi

Shear

Rate at=101.43

the Wall

Shear Rate at the Pipe WallShear Rate in Annulus

Shear RateReynolds No.

Q =0gal/min

Drillpipe00MW =0lb/gal

HW Drillpipe00

Drill Collars000

DC/Hole Annulus00

HW/Hole Annulus00

DP/Hole Annulus00

DP/Casing Annulus00


703.88psi

+239.90psi

+1108.15psi50%

=2051.93psi92%


31.60psi

153.15psi

=184.75psi8%


2236.68psi100%

Conv. Pressure Profile




Conv. Kill Sheet


Hydrostatic Pressure, psi

Hydrostatic Pressures in the Wellbore


Pressures, psi

Pressures in the Wellbore

Pressure, psi

Depth, ft

Wellbore Pressure Profile


Pressures, psi






Hydrostatic Pressure, psi

Hydrostatic Pressures in the Wellbore


Pressures, psi


Pressure, psi

Depth, ft

Wellbore Pressure Profile

11

Pressure Profiles

Kill Sheets

Procedures

Friction Pressure in Pipe

Friction Pressure in Annulus

Main Menu

Main Menu

Circulating Time, min

Standpipe Pressure, psi

Conventional Kill Sheet

1

1

PORE PRESSURE

ACTUAL BHP


Pressure, psi

Conventional Kill Sheet

Main Menu

Main Menu

Pressure Drop with Kill Mud



Conventional Well Control Sheet



Well Control Sheetsno viscosity/density correction

4009.06729668944009.06729668943519.5516618895

3576.73975815153626.85781788152987.6467847831

3603.07699191423626.85781788152978.2806676126

3697.30770951743072.5113852158

3697.30770951743072.5113852158

CONVENTIONAL

CONSTANT BHP= PORE PRESSURE

CONVENTIONAL

CONSTANT BHPwith viscosity/density correction

CONSTANT BHPwo viscosity/density correction



Well Control Sheetsw & wo viscosity/density correction

0

0

0

22.1526835574

22.1526835574

24.3

22.6626823648

22.6626823648

28

22.6626823648

22.6626823648

28

28

3519.5516618895

3519.5516618895

4009.0672966894

3087.2241233516

2987.6467847831

3626.8578178815

3113.5613571143

2978.2806676126

3626.8578178815

3207.7920747175

3072.5113852158

3207.7920747175

3072.5113852158

CONVENTIONAL


BHP = PP + AFP







Pressure Drop CalculationsConventional Well Control Kill Sheet

14-Jun-99Standpipe

Assume Kick Intensity =1lb/galTimePressure

= 0.052 * 1 * (11,400+600)624psiMinpsi

Circulation Rate300gal/minCirculation Rate300gal/minCirculation Rate300gal/min

04,009

Mud PropertiesMud PropertiesMud PropertiesOld Mud Hydrostatic in Annulus8,736psi24.33,627

Density14lb/galDensity15lb/galDensity15lb/galNew BHP9,360psi283,627

R39.00R39.00R312.19

R10049.00R10049.00R10066.35Drillpipe Capacity158bbl

R300117.00R300117.00R300158.43DC Capacity3.6bbl

R600214.00R600214.00R600289.77TOTAL Drillstring Capacity162bbl

Wellbore GeometryWellbore GeometryWellbore GeometryTime to top of DC = Capacity/Rate22.2min

Drillpipe OD4.5inDrillpipe OD4.5inDrillpipe OD4.5inTime to top of Bit = Capacity/Rate22.7min

Drillpipe ID3.78inDrillpipe ID3.78inDrillpipe ID3.78inTime to Bottom of Hole22.7min

Drillpipe Length11,400ftDrillpipe Length11,400ftDrillpipe Length11,400ft

Drill Collar OD6.5inDrill Collar OD6.5inDrill Collar OD6.5inSIDP (underbalance) =624psi

Drill Collar ID2.5inDrill Collar ID2.5inDrill Collar ID2.5inICP = KRP + SIDP =4,009psi

Drill Collar Length600ftDrill Collar Length600ftDrill Collar Length600ftFCP = KRP * (KWM/OWM) =3,627psi

Nozzle Sizes1132ndsNozzle Sizes1132ndsNozzle Sizes1132ndsCHECK: FCP =

1132nds1132nds1132nds

1232nds1232nds1232nds

Kill Sheet wo/Effect of Density on Viscosity

Hole Size8.5inHole Size8.5inHole Size8.5inConstant BHP = New Pore Pressure

3,520psiStandpipe

TimePressure

Change in DP Hydrostatic592.8psiMinpsi

Summary of Pressure DropsSummary of Pressure DropsSummary of Pressure DropsChange in DP Friction60.90psi

Inside Drillpipe1160.30psiInside Drillpipe1221.19psiInside Drillpipe1320.77psi0.03,520

Inside Drill Collars416.02psiInside Drill Collars437.86psiInside Drill Collars473.56psiChange in DC Hydrostatic31.20psi22.22,988

Across Bit Nozzles1319.23psiAcross Bit Nozzles1413.46psiAcross Bit Nozzles1413.46psiChange in DC Friction21.83psi22.72,978

In DC/Hole Annulus78.85psiIn DC/Hole Annulus78.85psiIn DC/Hole Annulus106.77psipsi22.73,073

In DP/Hole Annulus410.66psiIn DP/Hole Annulus410.66psiIn DP/Hole Annulus556.07psi94.23psi28.03,073

Total Pressure Loss3,385psiTotal Pressure Loss3,562psiTotal Pressure Loss3,871psi

Standpipe Pressure3,385psiStandpipe Pressure3,562psiStandpipe Pressure3,871psiNOTE: Annular friction =489.52psi

Summary of PressuresSummary of PressuresSummary of Pressures

Standpipe Pressure3,385psiStandpipe Pressure3,562psiStandpipe Pressure3,871psi

At Top of Drill Collars10,524psiAt Top of Drill Collars11,233psiAt Top of Drill Collars11,442psi

Above Bit10,545psiAbove Bit11,263psiAbove Bit11,436psi

Below Bit (BHP)9,226psiBelow Bit (BHP)9,850psiBelow Bit (BHP)10,023psi

At Top of DC/Hole Annulus8,710psiAt Top of DC/Hole Annulus9,303psiAt Top of DC/Hole Annulus9,448psi17/16 =1.0625=>6.25%

At Top of DP/Hole Annulus (Surface)0psiAt Top of DP/Hole Annulus (Surface)0psiAt Top of DP/Hole Annulus (Surface)0psi

Kill Sheet w/Effect of Density on Viscosity

Constant BHP = New Pore Pressure

3,520psiStandpipe

TimePressure

Change in DP Hydrostatic592.8psiMinpsi

13.8%Change in DP Friction160.47psi

0.03,520

Change in DC Hydrostatic31.20psi22.23,087

13.8%Change in DC Friction57.54psi22.73,114

psi22.73,208

94.23psi28.03,208

NOTE: Annular friction =489.52psi

Proposed Kill Sheet (for discussion)

Standpipe

1. Include Annular Friction in ICPTimePressure

Minpsi

2. Consider Increase in Viscosity with Mud Weight

0.04,009

22.23,577

22.73,603

22.73,697

28.03,697

3,627-3,697=-70

Main Menu

Main Menu

Main Menu

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Conventional Well Control Sheet

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CONVENTIONAL

CONSTANT BHP= PORE PRESSURE

CONVENTIONAL

CONSTANT BHPwith viscosity/density correction





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CONVENTIONAL


BHP = PP + AFP




MBD0388383C.unknown

MBD077188C0.unknown

MBD077188D0.unknown

MBD077188D8.unknown

MBD077188DC.unknown

MBD077188DE.unknown

MBD077188E0.unknown

MBD077188DF.unknown

MBD077188DD.unknown

MBD077188DA.unknown

MBD077188DB.unknown

MBD077188D9.unknown

MBD077188D4.unknown

MBD077188D6.unknown

MBD077188D7.unknown

MBD077188D5.unknown

MBD077188D2.unknown

MBD077188D3.unknown

MBD077188D1.unknown

MBD077188C8.unknown

MBD077188CC.unknown

MBD077188CE.unknown

MBD077188CF.unknown

MBD077188CD.unknown

MBD077188CA.unknown

MBD077188CB.unknown

MBD077188C9.unknown

MBD077188C4.unknown

MBD077188C6.unknown

MBD077188C7.unknown

MBD077188C5.unknown

MBD077188C2.unknown

MBD077188C3.unknown

MBD077188C1.unknown

MBD038DDE21.unknown

MBD039BFFA1.unknown

MBD039C4DDC.unknown

MBD07715228.unknown

MBD07715229.unknown

MBD076051D7.unknown

MBD039C17F8.unknown

MBD039C3D1C.unknown

MBD039BFFA2.unknown

MBD038E35E4.unknown

MBD0398BB0A.unknown

MBD039BFFA0.unknown

MBD038E3B3F.unknown

MBD038DEB58.unknown

MBD038DF95C.unknown

MBD038DDE22.unknown

MBD038AF8DF.unknown

MBD038DDE1D.unknown

MBD038DDE1F.unknown

MBD038DDE20.unknown

MBD038DDE1E.unknown

MBD038BCEFC.unknown

MBD038DA343.unknown

MBD038B8D77.unknown

MBD038AA3A1.unknown

MBD038AC6E2.unknown

MBD038AF3B8.unknown

MBD038AC1F7.unknown

MBD0389A75A.unknown

MBD038A9BD5.unknown

MBD0388729C.unknown

MBD00090B4A.unknown

MBD02AD8C3A.unknown

MBD0385C2A9.unknown

MBD0385DB01.unknown

MBD0385E331.unknown

MBD0385CF4B.unknown

MBD02AE25FA.unknown

MBD0385AF6E.unknown

MBD02ADBD9D.unknown

MBD02AB4BB3.unknown

MBD02ACC4DF.unknown

MBD02ACC7C0.unknown

MBD02AC4BE0.unknown

MBD02AB0513.unknown

MBD02AB061A.unknown

MBD0250F3F3.unknown

MBD00033CD5.unknown

MBD0003E890.unknown

MBD00089F09.unknown

MBD0008E7D5.unknown

MBD00081C1D.unknown

MBD000378F6.unknown

MBD0003C85E.unknown

MBD00037072.unknown

MBD0001667E.unknown

MBD00025EB0.unknown

MBD000323EA.unknown

MBD0001C168.unknown

Optimum Bit Hydraulics Under what conditions do we get the best hydraulic cleaning at the bit? Maximum hydraulic horsepower? Maximum impact force?

Both these items increase when the circulation rate increases.However, when the circulation rate increases, so does the frictional pressure drop.

Jet Bit Nozzle Size SelectionNozzle Size Selection for Optimum Bit Hydraulics:Max. Nozzle VelocityMax. Bit Hydraulic HorsepowerMax. Jet Impact Force

Jet Bit Nozzle Size Selection Proper bottom-hole cleaningWill eliminate excessive regrinding of drilled solids, and Will result in improved penetration rates

Bottom-hole cleaning efficiency Is achieved through proper selection of bit nozzle sizes

Jet Bit Nozzle Size Selection- Optimization -Through nozzle size selection, optimization may be based on maximizing one of the following:

Bit Nozzle Velocity Bit Hydraulic Horsepower Jet impact force There is no general agreement on which of these three parameters should be maximized.

Maximum Nozzle Velocity

From Eq. (4.31)

i.e.

so the bit pressure drop should be maximized in order to obtain the maximum nozzle velocity

Maximum Nozzle VelocityThis (maximization) will be achieved when the surface pressure is maximized and the frictional pressure loss everywhere is minimized, i.e., when the flow rate is minimized.

Maximum Bit Hydraulic HorsepowerThe hydraulic horsepower at the bit is maximized when is maximized.where may be called the parasitic pressure loss in the system (friction).

Maximum Bit Hydraulic HorsepowerIn general, whereThe parasitic pressure loss in the system,

Maximum Bit Hydraulic Horsepower

Maximum Jet Impact ForceThe jet impact force is given by Eq. 4.37:

Maximum Jet Impact ForceBut parasitic pressure drop,

Maximum Jet Impact ForceUpon differentiating, setting the first derivative to zero, and solving the resulting quadratic equation, it may be seen that the impact force is maximized when,

drilling-hydraulics-a.ppt

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