MPD Drill Undrillable

Primary funding is provided by

The SPE Foundation through member donations and a contribution from Offshore Europe

The Society is grateful to those companies that allow their professionals to serve as lecturers

Additional support provided by AIME

Society of Petroleum Engineers

Distinguished Lecturer Programwww.spe.org/dl

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Managed Pressure Drilling:

Drill the Un -Drillable

Lecturer’s Name: Hani Qutob

Reservoir Engineering & UBD/MPD Advisor

Senergy GB Limited – Dubai, UAE

Society of Petroleum Engineers

Distinguished Lecturer Programwww.spe.org/dl

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• Reservoir Engineering & Advanced Drilling Technolog y

• Advanced Drilling Technology Variations

• What is Managed Pressure Drilling?

• Optimal Redefined Time/Cost line

• Variables that can be Manipulated during MPD

Presentation Outlines

• Variables that can be Manipulated during MPD

• What Are the Main MPD Benefits?

• Managed Pressure Drilling Variations.

• Health, Safety and Environment Issues

• Case Histories obtained worldwide.

• Conclusions

• Acknowledgement

3

Advanced Drilling Technology® (ADT®) & Reservoir Benefits

How ADT® can increase reserves and improve recovery

� Minimizes Formation Damage - UBD.

� Accesses Challenging Reservoirs - MPD.

4

� Improves Reservoir Characterization - UBD

� Identifies Missed Pay – UBD.

� Increases Production & Enhances Recovery

- UBD / MPD

By: Accessing Challenging Reservoirs

The single biggest reserve contribution of MPD is found to be access to reservoirs that could not be drilled conventionally.

In almost all cases, MPD is used in challenging or partially depleted reservoirs, only after conventional wells prove

How Managed Pressure Drilling – MPD Benefits the Reservoir?

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depleted reservoirs, only after conventional wells prove expensive, unsuccessful or un-drillable

Some reservoirs that could be difficult to access using conventional drilling techniques are:

1. Low pressure & depleted reservoirs2. Vuggy/fractured carbonates where OB circulation is

impossible3. Reservoirs with a narrow margin between fracture

pressure and pore pressure - kicks/losses cycles

ADT® Variations

ADT® is an adaptive drilling process which enables a more precise control of wellbore pressures through the use of

engineered equipment & processes.

Advanced Drilling Technology® (ADT®)

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Air DrillingImprove Drilling Economics - Intent is to invite surface flowPrimarily non-liquid hydrocarbon formations

Underbalanced Drilling:Maximize Reservoir Value - Intent is to invite surface flow

Managed Pressure Drilling:Optimize Drilling Process - Intent is not to invite surface flow

What is common in ADT Variations?

7

Personneland

Equipment

UBD , MPD & Conventional

8

What is Managed Pressure Drilling?

A closed and pressurizablemud-return system, a Rotating Control Rotating Control Head, and choke.

operations provide precise control of the wellbore pressure profile.

9

Reactive vs Proactive MPD

Effective on “standby” basis as an enhanced form of passive well

Used to mitigate drilling hazards and reduce NPT by changes to fluid,

Reactive Proactive

form of passive well control to help manage unexpected downhole pressure.

by changes to fluid, casing and open-hole programs

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Collapse

Fracture

Overburden

Dep

thWe like prospects with big drilling windows…

11

CollapsePore

Pressure

Dep

th

EMW Must Stay Within Drilling Window For Drilling To Progress

Remaining prospects not cooperating very wellVery narrow or relatively un-known margins

Difficult or impossible to drill conventionally

When MPD is used?

• Kick -Loss ScenariosFracture

Overburden

Collapse

• Kick -Loss Scenarios

• High mud bill

• Excessive casing string(s)

• Drilling NPT – Exceeding AFE

• Environmental issues

• Failure to reach TD with large enough hole for optimum well production

• Or…simply ….“not drillable”12

Pressure

Dep

th

Pore

Bot

tom

Hol

e C

ircul

atin

g P

ress

ure

Small Drilling “Window”

Fluid Losses Fluid Losses

Constant Bottom Hole Pressure

Fracture Pressure

Bot

tom

Hol

e C

ircul

atin

g P

ress

ure

Time

Influx – Tight Hole Influx – Tight Hole

Pore Pressure – Collapse Boundary

13

5000000

5500000

6000000

6500000

0 1 2 3 4 5 6 7 8 9 10 1112 13 1415 16 17 1819 20 2122 23 2425 26 2728 29 30 3132 33 3435 36

Time (days)

Acc

umul

taed

cos

t

2100

2200

2300

Mea

sure

d D

epth

(m

)

Cost

Time - Depth

10.3% of total cost

Stuck pipeFishing

MPD VALUE - VISUALIZATION

Real Well – Case 1

LossesCement squeeze

6500000

7000000

7500000

8000000

8500000

Acc

umul

taed

cos

t

2400

2500

2600

2700

0 1 2 3 4 5 6 7 8 9 10 1112 13 1415 16 17 1819 20 2122 23 2425 26 2728 29 30 3132 33 3435 36

Time (days)

Mea

sure

d D

epth

(m

)

11.0% of total cost

Stuck pipeWell flowing

Well control, 10%

Circulating, 23%

POOH, 3%

RIH, 4%

Reaming, 5%

Stuck pipe, 55%

NPT distribution

900000

1400000

1900000

0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64

Time (days)

Mea

sure

d D

epth

(m

)

1800

1900

2000

Acc

umul

ated

cos

t

10.5%

2.3% Time - Depth

Real Well – Case 2

MPD VALUE - VISUALIZATION

Cost

2400000

2900000

3400000

3900000

Mea

sure

d D

epth

(m

)

2100

2200

2300

2400

0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64

Time (days)

Acc

umul

ated

cos

t

17.7% of total cost

20.9% total costLossesCement squeeze

Gas kick, well controlCement plugSidetrack

LossesCement plug

Total lossesGas flow

Effective time, 55%

NPT, 45%

Time distribution (well)

Optimal Redefined Time/Cost line

Optimal time

Conventional drilling (NPT)

Con

vent

iona

l cos

t due

to h

igh

NP

TMPD application is focused on achieving

0

100

200

300

400

500

600

Pore P. Frac. P.Saving in Drilling Time

Sav

ing

in D

rillin

g C

ost

Opt

imal

Cos

t

Con

vent

iona

l cos

t due

to h

igh

NP

T

Dep

th

Case

focused on achieving the well construction

“Optimal time and Cost” as objective

600

700

800

900

1000

1100

1200

1300

1400

1500

1600

1700

1800

1900

$ vs NPT

$ vs NPT

Sav

ing

in D

rillin

g

16

Conventional DrillingBottom hole circulating pressure is manipulated by only two variables.

BHCPconventional = Hydrostatic Pressure

+ ∆∆∆∆Pfriction

Affected by Density

Affected by density and flow rate

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Managed Pressure Drilling.

BHCPMPD = Hydrostatic Pressure Affected by density

+ ∆∆∆∆pfriction

+ Choke

Affected by density and flow rate

Manipulatedfrom surface

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Variables that can be Manipulated

Mud density

Mud viscosity Rotating Control HeadChoke Manifold

Variable Equipment

Mud viscosity

Flow rate

Trapped Pressure

Friction Pressure

Choke ManifoldMud pumpsDownhole pump

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In what cases can MPD add value?

�Drilling Exploratory, Appraisal or Challenging Development wells

Drill to the target

� Drill conventionally “Un -drillable” tight Pore

/Collapse /Fracture pressure gradients

� Drill “Un -drillable” vuggy/ fractured carbonates

where Over Balanced circulation is impossible

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What Are MPD Benefits?

• Reduced number of loss/kick occurrences

• Reduced time spent dealing with well control events

• Earlier kick / losses detection

Cost Saving

• Earlier kick / losses detection

• Optimized number of casing strings

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• Trip safely

• Remove H2S hazard from rig floor

• Drill HPHT wells safely

Improved Safety

Geo-mechanical Issues

MPD – Added Drilling Performance Value

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MPD Variations – Visualization

Constant Bottom Hole Pressure (CBHP)

Returns-flow -control (HSE )

MPDPressurized mud -cap drilling

Dual gradient MPD

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An adaptive drilling process used to precisely control the annular pressure profile throughoutthe wellbore. The objectives are to ascertain the downhole pressure environment limits and tomanage the annular hydraulic pressure profile accordingly. MPD is intended to avoidcontinuous influx of formation fluids to the surface. Any influx incidental to the operation willbe safely contained using an appropriate process.

Drilling Connection Drilling – Change in required BHP

Required BHP (Pore Pressure + Margin)

Drilling Connection Drilling – Change in required BHP

Required BHP (Pore Pressure + Margin)

MPD Official Definition

Hydrostatic

Pressure

Circulating

Friction

Hydrostatic

Pressure

Reduction

in BHP

Circulating

Friction

Hydrostatic

Pressure

New

Hydrostatic

Pressure

New

Circulating

Friction

Hydrostatic

Pressure

Circulating

Friction

Hydrostatic

Pressure

Circulating

Friction

Hydrostatic

Pressure

Same

Hydrostatic

Pressure

Same

Circulating

Friction

Surface

Backpressure Modified

Surface

Backpressure

Surface

Backpressure

New

Surface

Backpressure

Required BHP (Pore Pressure + Margin)

Time / Depth

Equ

ival

ent C

ircul

atin

g D

ensi

ty (

ppg)

Conventional Drilling PracticesTime / Depth

Required BHP (Pore Pressure + Margin)

Managed Pressure Drilling

Risk Management

With all MPD operations a detailed risk assessment as well as a HAZID and HAZOP should be carried out with the rig crew supervisors and the relevant service providers and operator staff.

Understanding the sequence of events and when to initiate MPD operations and discussing the rig up, pressure testing and operational aspects of a job together with all of the procedures will help to ensure the maximum success for an MPD operation.

Health, Safety and Environment Issues

• HAZOPs and HAZIDs are both systematicprocesses to identify hazards.

• “You cannot manage what you don’t know .”26

No Compromise on Rig safety – all rig safety Equipment Remains unchanged

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Case History 1 – Middle East

8 3/8” Section Performance

Offset Well

MPD Well

Total days spent on drilling the 65 40

�To reach the target depth with minimum NPT�To avoid uncontrolled event by maintaining a

constant bottom hole pressure

Objectives

on drilling the section

65 40

Total days spent on well control events (NPT)

7.6 1.1

Total days spent on tight hole/reaming

2.8 days

19 hours Saudi Arabia

(Onshore)28

Case History 2 – North AfricaAlgeria – drilling through high fractured zone

Un-drillable Reservoir Drilled

A total of 191 m weredrilled with a very smalldrilling window .drilling window .

Zero LTI’s or near missesrecorded on this well.

Avoided kick/loss cycles &Improved ROP.

MPD Added Value

NPT reduced to 1 daycompared to 10 daysexperienced in the threeprevious wells drilled.

Case History 3: Offshore India

LOC & Fluid lossesminimized to 290 BBLcompared to 4000 BBLon previous wells.

Avoided kick/loss cycles& Improved ROP.

Case History 4 – South AmericaPetrobras Colombia Limited,

MPD Added Value�No Loss of Circulation �significant cost savings

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Case History 5 – CanadaNortheastern British Columbia,

MPD Added ValueReduced AFE by approximately 19% (saving Can$ 2 Million).

Drilling efficiency was improved by lowering the mud weight and by lowering the mud weight and doubling the ROP .

Considered MPD techniques to increase drilling effectiveness in this field.

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MPD application in VietnamBIEN DONG POC HPHT Gas Condensate Development

BLOCK 05-2 & 05-3 Offshore -Vietnam

Why MPD on this project? �Narrow margin of PP/FG pressure in both fields.

�Early kick detection & control. �Early kick detection & control.

�Better well control in HPHT wells.

�Drill wells to target depth and eliminate additional casing string.

�Providing CBHP during static and dynamic conditions which mitigates stress caging (SC). 33

Project Overview

Phase-1: total sixteen (16) wells:�6 wells in block 05-3 (Moc Tinh)�10 wells in block 05-2 (Hai Thach)�10 wells in block 05-2 (Hai Thach)

Contract status: singed for 4.5 years + potential extension.

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Conclusions

The challenging hydraulics of the world’s remaining prospects indicate MPD will evolve to become a key enabling technology.

Managed Pressure Drilling technology is increasingly being applied in reservoirs that are difficult to drill conventionally (Un-drillable), deep water and High Pressure, High Temperature (HPHT) wells to access HC reserves, enhance operational safety and efficiency.

All “first adopters” of MPD offshore plan future wells.35

Conclusions (cont’d)Managed Pressure Drilling can reduce well costs as a result of;– Reduced number of casings = Smaller

casings = smaller rig – Less consumables (mud and cement)– Less materials and logistics cost– Less materials and logistics cost

Additional Benefits of MPD:– Faster drilling– Reduced formation damage– Improved productivity = improved recovery– Reduced environmental impact

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Proper candidate screeningProper candidate screening is a deliberate process, and is a critical step in the design of a successful ADT ope ration.

Detailed economic analysis is an important step to determine the benefit that MPD could provide compar ed to competing conventional drilling & completion techno logies.

Wrap-Up

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Poor screening and planning results in an over-enthusiastic misapplication of the technology, and possibly fail ure.

Proper Project management , engineering and execution is a key factor for a successful MPD operation .

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Speaker contact details

Hani QutobReservoir Engineering & UBD-MPD AdvisorSenergy GB LimitedDir: + 971 4 387 3022 Dir: + 971 4 387 3022 BB: +971 5 0622 4513 M: +971 5 0657 7328F: +971 2 667 0408 E: Hani.Qutob@senergyworld.comW: www.senergyworld.com

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