rig crew for petronas level 2

7/27/2019 Rig Crew for Petronas Level 2

1/73

11767 Katy Freeway Suite 1030 Houston, TX 77079 www.atbalance.comThis document is intended solely for the person or entity to which it is addressed and may contain confidential and/or privileged information. Copying,

forwarding or distributing this message by persons or entities other than the Atbalance is prohibited. If you have received this document in error, pleasecontact the sender immediately and delete the material from any computer. This document may have been monitored for policy compliance.

Managed Pressure Drilling TrainingLevel 2 - Rig crew


2/73

Agenda

Opening Remarks & Introductions What Are We Going to Do?

Teamwork

MPD Basics

MPD Objectives for KMB-1 Example Well Pressure Profile

Flow Control System Equipment

Connections

Reacting to Unplanned Events

Tripping

Kick Detection & Well Control

Other MPD Issues


3/73

What Does Annular Pressure Control System Do?

Apply Annular Pressure

Accurately Measure Return Flow & Compare w/ Flow In

Accurately Measure Annular Pressure

Calculate BHP Real Time

What are we going to do


4/73

Conventional Drilling vs Annular Pressure Control (APC) Drilling

Conventional drilling basically uses two bottomhole pressures whendrilling

A high when pumps are on (ECD)

A low when pumps are off (like on connections - no ECD)

If the high BHP approaches fracture pressure, losses and/orballooning occurs.

If the lower BHP is too low, influx, high connection gas and/orborehole instability can all occur.

The problems associated with low BHP are further exaggerated whenpipe is pulled and swab occurs.

By using annular pressure control, a single BHP is used which is abovethe conventional low (when pumps are off), yet below theconventional high (when circulating).

A single optimum pressure is used and the problems associated withconventional drilling are largely mitigated.


5/73

MPD - An Engineering Solution

Its All About the Bottomhole Pressure

The Hard part is Keeping it There

Need to Find the Sweet Spot & Keep It There

MPD Provides Another Tool for Doing That


6/73

What Affects Bottomhole Pressure?

Trajectory

Temperature - Pressure

Pipe Movement - Swab/Surge

Influx

Hole Cleaning

Losses

Pack Offs

Equipment Failures - Washouts - Twist Offs

Mud Weight & Rheology

RPM - ROP

Circulation - GPM

Geometry

Annular Pressure

Slugs

Ballooning


7/73

DAPC Drilling - Pumps On


8/73

DAPC Rig Pumps Off


9/73

Teamwork Discussion
http://www.halliburton.com/ps/default.aspx?navid=1650&pageid=202&prodgrpid=MSE::1045856833756550&AdType=HALSPSDL


10/73

Onsite Organizational Chart

Company Man

Tool Pusher

Driller

MPDSupervisor

Control System

Technician

RCD

Technician

These will be the mostcommon lines of

Communication during

MPD procedures

Include MPD Supervisor

in forward planning for

MPD issues


11/73

MPD Supervisor

Ensure equipment is rigged up and correctlycommissioned

Advise Client Rep on optimal down hole pressure /ECD during operations

Advise Client Rep on MPD / DAPC specificprocedures during operations

Supervise @Balance personnel

Daily reporting as agreed with Manti.

HSE ie toolbox talks, PTW etc.

Guide Driller when applicable


12/73

Control Systems Technician

Responsible for rig-up/ down computer controlsystem.

Operate system via user interface so that pressuresare maintained within the margin defined by the MPD

Supervisor and DSV. (reference: user manual DAPCsystem)

Communicate with Driller as set forth in procedures.

Maintain, troubleshoot and repair electroniccomponents.

Ensure all HSE requirements are complied with.


13/73

Driller

Responsible for applying all standard drilling practicesWOB, ROP, RPM etc

Rig focal person for applying MPD procedures while drilling.

Coordinate with, Client and @Balance personnel duringdrilling operations.


14/73

Responsible for monitoring Well conditions.

Contact Co-man and @Balance with any unforeseenWell conditions.

Mud Loggers


15/73

Responsible for maintaining an accurate MW and Properties

Call out MW every 30 minutes or Co-Man requirement

Mud Engineer


16/73

Communications

Good communication between the Driller and @Balance is critical.

All communication over the radio must be clear and coherent.

Ensure the radio button is pressed before you start talking

Address the person first before giving the instruction. Confirm that you heard the instruction, repeat back if necessary.

Do not cut in on a radio conversation unless very critical.

Do not hold idle chat on the radios. They are for operations purpose only,not to discuss lunch or crew changes.

BHP O ti Wi d Hi h P P C ti l D l


17/73

10000

10500

11000

11500

12000

12500

13000

13500

14 14.5 15 15.5 16 16.5 17 17.5 18 18.5 19

BHP Operating Window - Higher Pore Pressure - Conventional Drlg

LOSSES

Frac Pressure

HydrostaticECD

Pore Pressure-

Well Bore Stability

BHP O ti Wi d U i B kP (MPD)


18/73

10000

10500

11000

11500

12000

12500

13000

13500

14 14.5 15 15.5 16 16.5 17 17.5 18 18.5 19

BHP Operating Window - Using BackPressure (MPD)

ADD 250 psi BP onConnections

Pore Pressureor Stability Frac Pressure

HydrostaticECD


19/73

From 2736 m MD to 4739 m MD

900 gpm Flow Rate

Mud weight: 10.2 ppg to 14 ppg SBM (Stability requirements)

12 SECTION DESIGN


20/73

Section starting mud

weight: 10.2 ppg

At 3980 m MD: 11 ppg





21/73


22/73

500 gpm Flow Rate

Drilling Fluid: SBM

Mud weight: 16.8 ppg 18.2 ppg

Primary well targets H831 to H910 sands

Tight PP-FG margin: 17.8 ppg 18.1 ppg

Mud weight to be designed to be statically overbalanced atall times

8 X 9 SECTION DESIGN


23/73


24/73


25/73

At around 4500 m MD:

T Annulus = T Formation

When Circulation Stops:

Depth > 4500 m MD

T Decrease => DensityIncrease

Depth < 4500 m MD

T Increase => DensityDecrease

This results in an increase inESD @ TD


26/73

The mud weight has to be designed to be staticallyoverbalance at all times

The maximum we can drill to is 5030 m MD, 4528 mTVD (New section TD)

PP-FG Window: 17.34 ppg 18.1 ppg


27/73

Decreasing annular friction losses:

Open the hole to a larger diameter(Hole opened to 9

diameter)

Use a tapered drill string (incorporated 2000 m of 4 DP in the drill string) (Negligible effect on ECD)

Decrease the Flow Rate (Decreased from 500 gpm to450 gpm)

Use a lower Rheology (To be evaluated)


28/73

MPD Objectives

Drill intervals with a single, near constant BHP which issafely below FG to mitigate losses

Kick and loss detection is enhanced by the use of the AtBalance kick/loss detection system using a mass/flow meterinstalled in line down stream of the chokes

Formation ballooning is controlled by dynamically holding APon the wellbore annulus when making connections.

Hole instability caused by bottomhole pressure fluctuationsthat flex and relax the formation during pump on/off cyclesis minimized.

Constant annular pressure when stripping drill pipe outthrough the Rotating Control Device can be maintained whilepulling out of the hole to mitigate swab.

MPD techniques used for planning trips and placement of tripweight mud and swab-surge mitigation.


29/73

On Connections

Annular Pressure Using FCS

Maintain Constant BHP

Dynamic Annular Pressure Control

While Drilling

Rotation Effect (RPM)

Annular Friction (GPM-Mud Properties)ROP (Cuttings)


30/73

Watch the Cuttings!!!

Cuttings are easy to recognize when drilling with PDC bit

Splintered cuttings if underbalanced

Tabular cuttings from bedding planes

Angular, blocky cuttings from stress induced instability

Watch for Changes!! - Shaker hand may be most important guy on rig


31/73

Managing Swab - Surge

One of the Keys to Success

When the drill string is picked up to make aconnection or trip out of the hole, the mud in theannulus must fall to replace the volume of pipepulled from the well

The hydrostatic pressure is momentarily reducedwhile the mud is falling in the annulus (negativeECD).

Surge is the opposite - Acts like ECD.


32/73

Swab/Surge

4 1/2 DP Displacement = =0.0082bbl/ft

Pull 90 Drill Pipe in 3 minutes

4 1/2 DP X 8 5/8 casing = 0.0305bbl/ft

Annular Velocity = 8 fpm

P = 2 psi per stand

If we are pulling 230 stands = 460 psilower BHP

Typical Misconceptions

That the bit & stabs cause the swab -piston effect

Swab is not felt all the way to TD

Swab effect - .2 ppg @ 3 mins a stand


33/73

ppg @

Ballooning


34/73

Ballooning

Can be attributed to mud being lost into fractures --- or ---

Can be attributed to the elasticity of the formation thatballoons the well by the amount of annular friction

When pumps are stopped and there is no annular friction ---

Fractures close up and squeeze mud back into the hole -- or ---

The wellbore returns to the original size

By using CBHP MPD, ballooning goes away since BHP is thesame if pumps are on or pumps are off

Fractures are charged to ECD BHP - If pumps are shut downand well is shut in; pressure can increase to difference between

ECD and static - Appears to be under balance condition

Ballooning


35/73

Ballooning

Ballooning Misinterpreted as flow fail to bleed-offadd weight Repeat cycle induce losses

potentially induce well control as a result of lost

mud column.


36/73

FCS System Components

Basic FCS System

RCD (Rotating Control Device)Automated Choke Manifold

Annular Pump

Control Cabin

Piping

Computers & Software

Return Flow Meter


37/73

B i P d h ld ti


38/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

300 psi

Bring Pumps down hold connection pressure

Bleed line

DAPC Chokes

Rig Pump300 psi

Cl A l Bl d ff f


39/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

0 psi

Close AnnularBleed off surface pressure

Rig Pump300 psi

Remove RCD Element


40/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

0 psi

Rig Pump300 psi

Install New RCD Element


41/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

0 psi

Rig Pump300 psi

Equalize Pressure Between Annular and Surface


42/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

Equalize Pressure Between Annular and Surface

300 psi

DAPC Chokes

Rig Pump300 psi

Open Annular / Drill Ahead


43/73

Rotary Bushing

13 5/8" 5000#

Hydril "GK"

Pipe Rams

Pipe Rams

DAPC Chokes

7 1/16, 5000

13 5/8" 5000#

H.C.R.

300 psi

300 psi

Open Annular / Drill Ahead

DAPC Chokes

Flow Control System Choke


44/73

Level 1 DAPC training, 2005 At Balance-Houston Slide 44 of 44 .

Flow Control System - Choke

Flow Control System Pump


45/73

Flow Control System - Pump

Flow Control System Coriolis Meter


46/73

Flow Control System - Coriolis Meter


47/73

1. SET SLIPS AND INFORM ATBALANCE READY TO RAMP DOWN RIG PUMP TO MAKE CONNECTION

2. RAMP DOWN PUMPS AT A SMOOTH CONTROLED RATE AS PER ATBALANCE

3. INFORM ATBALANCE WHEN MUD PUMPS ARE OFFLINE

4. BLEED OFF STANDPIPE PRESSURE, CONFIRM THAT STANDPIPE IS ZERO

5. MAKE CONNECTION

6. INFORM ATBALANCE THAT CONNECTION IS COMPLETE AND READY TO RAMP UP PUMPS

a) IF NO SURVEY - PULL OFF OF SLIPS, START ROTARY TO BREAK GELS IN WELLBORE.

b) IF SURVEY STOP ROTATION 1 MIN CLOSE TO CONNECTION POINT. SET SLIPS. BLEED SPP. MAKE

CONNECTION.

7. PUMP 75-100 GPM TO FILL DRILL STRING.

8. ONCE DRILL STRING IS FILLED AND STANDPIPE PRESSURE MATCHS ANNULAS BACKPRESSURE BEING

HELD BY ATBALANCE, CONTINUE RAMPING UP PUMPS AT A SMOOTH CONTROLED RATE TO DRILLING RATE

AS PER ATBALANCE

9. WAIT FOR RETURNS TO THE SHAKERS, SURVEY COMPLETE THEN RETURN DRILLING

Connections


48/73

Connections

Ramp Down Pumps

BHP Eq ppg

13.8 ppg Surface Mud Weight

Maintaining 14.4 ppg BHP for Stability

GPM

Annular Pressure

Ramp Up Pumps



49/73

Keep Borehole (BHP) Pressure Constant


At Balance Manages Annular Pressure

Driller Manages Annular Friction by Controlling GPM

Must have one or the other or combination to maintain constantBHP

What we dont needAnnular friction & annular pressure both go up leading to

formation breakdown

Losing both annular friction & annular pressure leading to influxor instability

Always Think about what has changed, then communicate & takeaction


50/73

Managed Pressure DrillingContingencies Procedures

11767 Katy Freeway Suite 1030 Houston, TX 77079 www.atbalance.com

This document is intended solely for the person or entity to which it is addressed and may contain confidential and/or privileged information. Copying,

forwarding or distributing material contained in this document by persons or entities other than Atbalance is prohibited. If you have received this document

in error, please contact the sender immediately and delete the material from any computer. This document may have been monitored for policy compliance.


51/73

INDEX

1. RIG PUMP/S GO DOWN

2. ATBALANCE ANNULAR PUMP GOES DOWN

3. RCD ELEMENT LEAKS4. LEAK IN FLOW CONTROL SYSTEM

5. ATBALANCE CHOKE PLLUGS

6. ANNULUS PACKS OFF

7. ATBALANCE SYSTEM IS INOPERABLE

8. LOST CIRCULATION

9. INFLUX10. ATBALANCE STROKE COUNTER NOT FUNCTIONING

11. DRILL STRING WASH OUT OR PART


52/73

1. RIG PUMP / S GO DOWN

ELECTRICAL OUTAGE, POP OFF, SWAB LEAKING

CAN BE UNCONTROLLED {ELECTRICAL} OR CONTROLLED.

IF CONTROLLED, DRILLER ALERTS ATBALANCE OF RIG PUMP RAMP

DOWN JUST LIKE CONNECTION.

PUMPS GO DOWN {UNCONTROLLED} ATBALANCE SYSTEM

AUTOMATICALLY CLOSES CHOKES AND ADDS ANNULAR PRESSURE

IF ATBALANCE SYSTEM DOSENT RESPOND, DRILLER CAN BOTTLE UP

{DISCUSS LATER}


53/73

2. ATBALANCE ANNULAR PUMP GOES DOWN

ATBALANCE PUMP GOES DOWN {UNCONTROLLED} DURING

CONNECTIONCHOKES WILL CLOSE TO TRAP PRESSURE

OR

ADJUST ANNULAR PRESSURE THROUGH DP OR KILL LINE WITH RIG

PUMP

ORUSE RIG PUMP AS ANNULAR PUMP

OR

USE RIG PUMP WITH TOP DRIVE SCREWED IN, RESUME CIRCULATION

SELECTION OF THE CONTINJENT PROCEDURE TO RESTORE BHP IS

BASED ON THE WHERE WE ARE DURING THE CONNECTION AND WHAT

IS THE MOST EFFICIENT WAY OF SECURING THE WELLBORE

3. RCD ELEMENT LEAKS


54/73

ATBALANCE FLOWOUT WILL DECREASE INDICATING DOWNHOLE LOSSES

BUT ELEMENT COULD BE LEAKING.

IF LEAKING, RETURNS LEAK BY ELEMENT & OVER TOP RCH & INTOPOLLUTION PAN.

WILL SEE DROP IN FLOWOUT ON ATBALANCE FLOW METER

WILL SEE FLOW FROM POLLUTION PAN.

MAINTAIN BHP IN WELL.

DEVELOP STRATEGY FOR WHEN TO CHANGE OUT THE ELEMENT

USUALLY A TOOL JOINT IN THE ELEMENT WILL HELP SEAL IT AND ALLOW

ATBALNCE TO ADD ANNULAR PRESSURE DURING RIG PUMP RAMP DOWN IN

ORDER TO TRAP PRESSURE FOR ELEMENT CHANGE OUT.

THE GOAL, IS TO DRILL THE ENTIRE HOLE SECTION WITHOUT CHANGING THEELEMENT.

IF THE ELEMENT LEAKS WHEN DRILLING w/o ANNULAR PRESSURE, BUT WILL

NORMALLY HOLD WHEN PRESSURE IS APPLIED, WHICH ALLOWS US TO

CHANGE OUT ELEMENT WHILE HOLDING PRESSURE UNDER THE ANNULAR

REFER TO ELEMENT CHANGE OUT PROCEDURE.


55/73

4. LEAK IN FLOW CONTROL SYSTEM

REACTION BASED ON SIZE OF LEAK.

IF THERE IS AN ENVIROMENTAL RISK

SHUTDOWN RIG PUMP IMMEDIATELY AND ATTEMPT TO TRAP PRESSURE BY

CLOSING. ORBIT VALVE

AFTER CLOSING ORBIT VALVE, ADJUST PRESSURE BY PUMPING DOWN DRILL

PIPE.

-OR-

CIRCULATE THROUGH RIG CHOKE MANIFOLD

-IF THERE IS NO ENVIROMENTAL RISK

RAMP DOWN RIG PUMPS AS PER CONNECTION PROCEDUREAFTER ANNULAR PRESSURE APPLIED, LINEUP RIG CHOKE MANIFOLD TO

CHOKES {CLOSED}, CLOSE ORBIT VALVE AND MONITOR ANNULAR PRESSURE

ON RIG CHOKE CONSOLE.

IF CONSIDERABLE TIME TO REPAIR LEAK, OPEN RIG CHOKES AND CIRCULATE

TAKING RETURNS THROUGH RIG CHOKE MANIFOLD


56/73

5. ATBALANCE CHOKE PLUGS

ALTERNATE CHOKE {B} AND OR {PRC} WILL DYNAMICALLY OPEN TO RELIEVEOVER PRESSURE.

CHOKE WILL AUTOMATICALLY CONTROL AT RELEASE PRESSURE WILL NOT

CAUSE TOTAL LOSS OF ANY REQUIRED ANNULAR PRESSURE.

OPEN BYPASS LINE AND CONTINUE CIRCULATION WHILE DETERMININGCAUSE OF PLUGGING.

DO NOT CONTINUE DRILLING UNTIL ISSUE RESOLVED.

DRILLER SHOULD HAVE ANNULAR PRESSURE ALARMED ON THEIR DATA

SCREEN AND IMMEDIATELY SHUTDOWN PUMPS IF ALARM PRESSURE ISREACHED.

BASED ON FG OF WINDOW {18.1 PPG} SHOE BREAKDOWN WILL OCCUR IF

ANNULAR PRESSURE EXCEEDS {? PSI ECD WITH A 17.8 PPG MW @ ? SHOE}


57/73

6a. ANNULUS PACKS OFF


58/73

ANNULAR PRESSURE INCREASES WHEN FLOW OUT DECREASES.

IF CHOKES PLUGGING, ANNULAR PRESSURE INCREASE WHEN FLOW OUT

DECREASESPICK UP OFF BOTTOM & ROTATE/CIRCULATE.

CONSIDER PUMPING / BACKREAMING TO GET ABOVE PROBLEMATIC ZONE

6b. ANNULUS PACKS OFF


59/73

7. ATBALANCE SYSTEM INOPERABLE

THE ATBALANCE SYSTEM CANNOT HOLD PRESSURE ON CONNECTIONS.

IF POSSIBLE CIRCULATE THROUGH THE ATBALANCE MANIFOLD UNTIL

PROBLEM IS FIXED.

RAISE MUD WEIGHT AND DRILL AHEAD WITHOUT MPD.


60/73

8. LOST CIRCULATION

IF TOTAL LOSSES-----------------SHUT PUMPS DOWN.

KEEP THE HOLE FULL, BY CIRCULATING DYNAMICALLY WITH ATBALANCE.

ATBALANCE IS LINED UP FOR RETURNS TO THE SHAKERS.

CAN FILL HOLE WITH ATBALANCE ANNULAR PUMP THEN DIVERT TO TT FOR

HOLE FILL MONITORING.

RIG WILL RAMP PUMPS DOWN LIKE A CONNECTION.

ATBALANCE CONTROL SYSTEM WILL BE PUT IN MANUAL OPERATION AND OPEN

THE CONTROLING CHOKE 100%.

ONCE ATBALANCES ANNULAR PUMP STARTS, ENTER MANUAL SETPOINT 10

PSI ABOVE LINE HYDROSTATIC OF PT5 {WELLHEAD PRESSURE TRANSMITTER}

TO FILL HOLE UNTIL RIG IS LINED UP TO TT FOR HOLE FILLING.

IF NEED TO FILL HOLE FROM TT, RIG CAN USE KILL LINE AND TAKE RETURNS

BACK THROUGH ATBALANCE TO TT.


61/73

9. INFLUX

ABILITY TO DETECT SMALLER INFLUX ATBALANCE FLOW IN/OUT

DIFFERENTIAL.

IF INFLUX DETECTED, RIG WILL DO HARD SHUT-IN ON ANNULAR TO AVIOD

SPACING OF TOOL JOINT. PICK UP DP FOR SHUT IN

OPEN RIG CHOKE HCR VALVE RIG CHOKES CLOSED.

NOTIFY ATBALANCE & START TO RAMP DOWN RIG PUMPS

ATBALANCE RESET SETPOINT PRESSURE .2 PPG ABOVE DRILLING ECD BUT

BELOW FG.

SYSTEM WILL ADD ANNULAR PRESSURE AS RIG PUMPS ARE RAMPING DOWN

WHEN PUMPS ARE OFF, CLOSE ANNULAR BOP.

ATBALANCE OPEN CHOKES, ROUTE RETURNS TO TT.

ATBALANCE MONITOR FOR ANNULAR BOP LEAKAGE

CIRCULATE OUT INFLUX USING CLIENT / RIG PROCEDURES.

Pujut-1

12 1/4" Section

Surface Pressure

Drilling Connection

0 B k P 300 300 B k P 800 100 B k P 400 400 B k P 800


62/73

0 < Back Pressure < 300 300 < Back Pressure < 800 100 < Back Pressure < 400 400 < Back Pressure < 800

InfluxIndicator

NoInflux

Influx

StateNone

Cntinue Drilling

Influx State None

Stop Drilling

Increase the Mud

Weight (ECD not

Exceeding 16 ppg)

Influx

StateNone

Continue Connection

Influx

StateNone

Increase Mud

Weight

Influx

Rate0 Influx Rate 0

Influx

Rate0

Influx

Rate0

Influx

Duratio

n

0 InfluxDuration

0

Influx

Duratio

n

0

Influx

Duratio

n

0

Gain

Volume0

Gain

Volume0

Gain

Volume0

Gain

Volume0

WithinOperatingLimits

Influx

StateSteady

Stop Drilling.

Pick up off

bottom.

Apply an

additional 100 psi

Back Pressure.

Influx State Steady

By pass MPDEquipment.

Shut in BOP.

Evaluate Next

Action

Influx

StateSteady

Apply an additional

100 psi Back

Pressure.

Influx

StateSteady

By pass MPDEquipment.

Shut in BOP.

Evaluate Next

Action

Influx

Rate< 2 bbls/min Influx Rate < 2 bbls/min

Influx

Rate< 2 bbls/min

Influx

Rate< 2 bbls/min

Influx

Duratio

n

< 10 minInflux

Duration< 10 min

Influx

Duratio

n

< 10 min

Influx

Duratio

n

< 10 min

Gain

Volume< 20 bbls

Gain

Volume< 20 bbls

Gain

Volume< 20 bbls

Gain

Volume< 20 bbls

ECD < 15 ppg ECD < 15 ppg

OverOperatingLimits

Influx

State Steady

By pass MPD

Equipment.

Shut in BOP.

Evaluate Next

Action

Influx State Steady

By pass MPD

Equipment.

Shut in BOP.

Evaluate Next

Action

Influx

State Steady

By pass MPD

Equipment.

Shut in BOP.

Evaluate Next Action

Influx

State Steady

By pass MPD

Equipment.

Shut in BOP.

Evaluate Next

Action

Influx

Rate> 2 bbls/min Influx Rate > 2 bbls/min

Influx

Rate> 2 bbls/min

Influx

Rate> 2 bbls/min

Influx

Duratio

n

> 10 minInflux

Duration> 10 min

Influx

Duratio

n

> 10 min

Influx

Duratio

n

> 10 min

Gain

Volume> 20 bbls

Gain

Volume> 20 bbls

Gain

Volume > 20 bblsGain

Volume > 20 bbls

ECD > 15 ppg ECD > 15 ppg

10 500Conventional kick


63/73

9

9.1

9.2

9.3

9.4

9.5

9.6

9.7

9.8

9.9

19:12

19:19

19:26

19:33

19:40

19:48

19:55

ECD(ppg

0

50

100

150

200

250

300

350

400

450

Pressure(psi),Flow(gpm

ECD setpoint (ppg) ECD estimation model (ppg) Backpressure (psi)

Flow In Rigpumps (gpm) Flow Out Flowmeter (gpm)


64/73


65/73

Kick Detection - 06 Nov 2008


66/73

Kick Detection 06 Nov 2008

0

200

400

600

800

1000

1200

3:07

:00

3:08

:40

3:10

:20

3:12

:00

3:13

:40

3:15

:20

3:17

:00

3:18

:40

3:20

:20

3:22

:00

3:23

:40

3:25

:20

3:27

:00

Flo

(GP

)P

ressure(PSI

010

20

30

40

50

60

70

80

90

100

ECD(PPG

Back Pressure Choke Back Pressure Flow InPum 1 Pum 2 Control ECD Set oint

-Rig Pumps brought down

to Zero - DAPC pumpautomatically started

- Well shut in flow dead

Flow out spike is a reactiion to

Choke Backpressure Increase

Rig Pumps Shut Down

HPHT KICK


67/73

10. LOSS OF STROKE COUNTER

ATBALANCE SYSTEM THINKS RIG PUMP HAS GONE DOWN WHEN PUMP IS

STILL REALLY PUMPING.

CHOKES COULD AUTOMATICALLY TRY TO CLOSE AND ADD BACK PRESSURE

TRYING TO MAINTAIN CBHP LEADING TO AN OVER PRESSURE EVENT.

NEED REDUNDANT STROKE COUNTERS-ATBALANCE INSTALLS THEIR OWN

ATBALANCE SHOULD IMMEDIATELY GO TO MANUAL MODE IF SPM

MALFUNCTIONS

ATBALANCE SHOULD USE WITS SPM ON RIG DATA SYSTEM SO EVERYONE IS

USING THE SAME STROKE COUNTERS.

DRILLER THEN CAN ALARM SPM AND IF THE STROKE COUNTER SUDDENLY

GOES TO 0 THE DRILLER SHOULD BRING THE RIG PUMP OFF LINE UNTIL

ATBALANCE GET THEIR CHOKES IN THE MANUAL OPEN POSITION.


68/73

11. DRILL STRING WASHOUT OR PART

WHEN THE PART OR WASH OCCURS THE B HP WILL DECREASE DUETO LOSS OF CIRCULATION.

THE AMOUNT OF BHP LOSS WILL DEPEND ON THE DEPTH THAT THE

WASH OR PART OCCURRED.

DEVELOP A TRIPPING PLAN. (WEIGHT UP MUD ? HOW MUCH MUD WILLBE CIRCULATED).

IF THE WASH OR PART IS ABOVE THE FLOAT (NRV) IT WILL BE

DIFFICULT TO STRIP OUT OF THE HOLE.

MAY BE ABLE TO PUMP BPV TO PROFILE SUB AT THE TOP OF THEHWDP, THEN STRIP-OUT HOLDING ANNULAR PRESSURE.

THERE WILL BE SEVERAL SCENARIOS BASED ON THE DETAILS OF

THE PROBLEM - CASE BY CASE DECISIONS


69/73

Trapping pressure Bottle Up

Close HCR Valve and or Chokes

Use Rig Pump to pressure up Annulus through DP or

By pumping through Kill line

Can also restore BHP by pumping through Rig Choke Manifold

Tripping


70/73

Tripping

Add Annular Pressure As Needed - Use PWD

Displace with Heavier Mud - ~0.3 ppg

Remove Annular Pressure as Mud Moves Up Annulus

Strip Holding AP to Negate Swab Effect

Slow Pumps Down as Heavier Mud Nears Surface

Have to trip with BHP > Pore Pressure w/ SF

Clean the Hole Up - Remove Cuttings - Reduces BHP

Other MPD Considerations


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Ot e Co s de at o s

PWD Data

Surveys & Downlinking

Trip Fill up Volumes

Flushing AB Equipment

Wits & Data on Geo-Services

Temporary Piping Requirements

Use of Rig Mud Gas Separator

Pressure Sensor Calibration

Float Valves in BHA

Downhole Vibration

Casing Running & Cementing

Summary


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All Our Drilling Tools Have to Work Together to be Successful

Mud Properties - Solids Control

Downhole Tool Reliability - TD with No Trips

Good Drilling Practices

Hole Cleaning, Hole Cleaning, Hole Cleaning

Teamwork & Communication & Safety

Drill String & Rig Reliability

MPD is Only One Tool

It Is In Addition, Not a Replacement

Success Lies in the Details


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TeamSuccess

TeamExecution

Team

Training

Team

Planning

rig crew for petronas level 2

Documents