OverviewofDPMServices 8-6-11

(1)

Introduction to Dynamic

Pressure Management Services

for

Talisman UK

Atul Singh Bhadauria Drilling Engineer

[email protected]

(2)

Confidential – do not distribute.

Topics Covered

• Introduction to DPM Segment • Overview of MPD Technology • Global Experience

• Drilling engineering services • MPD systems and products • Integrated D&M –DPM Services

• Constant Bottom Hole Pressure Case Histories • Faster Response

• Unplanned Events • Drilling

• Connections

• Pump Failure Event • Emergency Events

(3)

Introduction to DPM Segment

The Schlumberger DPM segments provides MPD and UBD products

and services . This segment was started after merger with Smith

International.

DPM Segment provides



Rotating Control Devices –High Pressure RCDs, Intermediate Pressure RCDs

and Low Pressure RCDs.



Control Systems- Automated , Manual systems for reactive and proactive

pressure control systems , Dynamic swab and surge compensation



Kick detection with multiple automated indicators



Separation -Multiphase separation vessels



Nitrogen generation and injection



Pressure Control Equipment- Chokes, Chokes Consoles, Carbon tracker,

(4)

Introduction to DPM Segment

In addition to the MPD and UBD products and services, the Schlumberger DPM

offers

1. UBD / MPD Drilling Engineering

2. UBD/MPD Well planning

3. UBD/MPD Project Management

4. UBD/MPD Drilling Optimisation

5. Trainings

(5)

Confidential – do not distribute. EAF SLR NAL MEA LAM ASA NAO CAL USL PCE MCA NGC AKA NAG NSG ASE RUS ARM ING CHG EAG

GeoMarket Operations

BRZ

(6)

Overview of MPD Technology

Pressure Related Drilling Risks

• Lost circulation

• Gas influx / kicks

• Ballooning / breathing

• Wellbore instability

– Stuck pipe – Annular pack-off – Twist-off

• Swab / surge

• Unplanned cement jobs

• Unplanned sidetracks

(7)

Proactive MPD Methods to Mitigate Risks

– Constant bottom hole pressure

• Requires RCD & automated control

– Mud cap (pressurized or floating cap)

• Requires RCD & manual control

• Drill without returns

– Downhole Pumps

• No RCD required but limits drilling

– Continuous Circulation

• No RCD required but requires backup BHP control

– Dual Gradient

(8)

Deep Water _HorizontalERD Mature Depleted_{On & Off Shore} HPHT _ReservoirsFractured

•Kick detection •Narrow margin •ECD reduction •Loss avoidance •Wellbore stability •ECD reduction •Loss avoidance

•Stuck pipe avoidance

•Hole cleaning •Drilling optimization •Narrow margin •ECD reduction •Loss avoidance •Wellbore stability •Kick detection •Drilling optimization •Reservoir damage •Wellbore breathing avoidance •Kick detection •Narrow margin •Wellbore stability •Loss avoidance •Pressure environment detection (Dynamic Flow-in/Leak-Off) •Kick detection •Controlled losses •Reservoir damage

MPD Technology for extreme environments

(9)

Performance Benefits Summary

• Extend the life of a mature producing fields

• Increase productivity in tight pressure margins

• Expand drilling in marginal fields

• Prevent reservoir damage

• Construct wells with difficult, even impossible, to drill margins

• Eliminate lost circulation in narrow margins

• Increase wellbore stability

• Minimize risk of costly, unplanned well control events

• Improve drilling safety

• Avoid unplanned sidetracks

• Reduce non-productive time

• Increase drill rates

(10)

Global Experience

(11)

Deepwater Experience

Global DW experience:

• 1st _{approved use by MMS (Minerals Management Services) of automated MPD system in GOM} • 1st _{approved use of automated MPD with statically underbalanced mud in DW GOM}

• 1st _{closed loop automated bottomhole pressure control with PWD on WDP} • 1st _{use of automated MPD in west Africa}

(12)

HPHT Experience

Global HPHT experience:

• 1st _{use of automated MPD geothermal reservoir} • 1st _{use of automated MPD in North Sea HPHT} • 1st _{use in south Texas to drill HPHT with CwD}

(13)

HPHT Experience

 7 Projects (300-400 Deg F)-10k to 20k psi BHP 3 Projects (400 – 500 Deg F) – up to 25k psi BHP

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Primary Pressure Barrier

BHP

_static

=

P

_mud

Pumps-off



BHP

_dynamic

=

P

_mud

+

P

_friction

Pumps-on



BHP

_dynamic

=

P

_mud

+

P

_friction

+

P

_bp

Pumps-on



BHP

_static

=

P

_mud

+

P

_bp

Pumps-off



Managed Pressure Drilling

Conventional Drilling

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Pressure Limits

Plot of PP, stability, and FP showing depleted zone in 6” hole. Maximum allowable margin is 0.8 ppg.

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Pressure Limits

High mud weight required for stability – makes ECD greater than FP. Lost circulation is unavoidable.

(18)

Pressure Limits

MPD solution: reduce ECD by reducing MW below PP. Use MPD for constant BHP control.

ECD 1.0 ppg

Safety margin 0.3 ppg

(19)

19

0

MPD Back Pressure Principle

Conventional

Dynamic Pressure Static Pressure

MPD

Static Pressure

Surface Back Pressure (BP)

Dynamic Pressure + BP Static Pressure + BP

Drilling window

Dynamic Surface Back Pressure

Higher dynamic gradient, therefore reduce

Back Pressure while drilling

Pressure

(20)

Existing Rig System for Conventional Drilling

20

Rig Pump

Rig Mud System

BOP

(21)

Additional Equipment for MPD

21

Rig Pump

Rig Mud System

RCD

Choke

(22)

Rotating Control Device

22

Rig Pump

Rig Mud System

RCD

Choke

(23)

RCDs In Wellhead

(24)

24

Choke Manifold

Rig Pump

Rig Mud System

RCD

Choke

(25)

Additional Equipment for @balance Automated MPD

25

Rig Pump

Rig Mud System

Automatic

Choke

Back Pressure

Pump

Hydraulic Model

&

Automated Control

RCD

BOP

Flow meter

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26

Typical Modular MPD Surface Equipment

(27)

MPD Systems Layout

(28)

MPD Systems Layout

(29)

Drilling Engineering Services

• Opportunity assessment

• Engineering analysis

• Well planning

• Well execution

• Well summary

(30)

Drilling Engineering Services

• Opportunity assessment

– Identify drilling problems

– Define client objectives

– Gather offset & planned well data

– Perform engineering quick look

recommendation

• Engineering analysis

– Develop well pressure profile

– Hole section analysis and design

– Configure system

– Recommend rig interface

PP FG

Static BHP

PP

Surface

(31)

Drilling Engineering Services – Assessment

• Review

– Offset drilling data and reports

– Anticipated pressure related problems

– Potential trouble zones and well control hazards

• Analysis

– Well plan and geometry

– Pressure profile and margins

– Hydraulics and drilling fluids

(32)

Drilling Engineering Services – Assessment

• Recommendations

– Rig survey – preparation and installation

– Pressure limits and equipment requirements

• Planning

– HazID / HazOP

– Procedures and contingencies – drilling, tripping, testing

– Personnel training

(33)

Drilling Engineering Services

• Well planning

– Rig survey

– Equipment layout

– Define roles and responsibilities

– Develop procedures and

contingencies

– Hold HazID / HazOP workshops

– Train rig crew

– Conduct contingency scenarios

Rig elect-tech to spot j-box & pwr supply for DAPC manifold & pump

480v/225amp

Spot DAPC choke, pump and flow meter here, aft end of cantilever deck, near Shaker Box

Possible location of spares container and cabin if no room in ML unit. Place MPD control in ML unit, if room.

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Drilling Engineering Services

• Operations support

– Hydraulics model updates

– Engineering program updates

– Plan and supervise dynamic

leak-off / flow tests

– Manage and analyze drilling

events

(35)

Drilling Engineering Services

• Well summary

– Performance summary

– After action review

– Event analysis

– Best practices and lessons

learned

– Operations and drilling

(36)

DPM – MPD Systems

• Rotating control devices

• Control Systems

(37)

Rotating Control Devices

Flow line

RCD

4”/6” x 5kpsi line to choke manifold

Hydraulic valve 7 1/16” x 5K

(38)

Rotating Control Devices

• HOLD 25

– Two piece design

– Hydraulically operated remote

lock-down RCD

– Eliminates need for RCD personnel

to climb the wellhead

– Low pressure riser connects to rig

bell nipple

– Dual sealing elements

HOLD 25 RCD Operating Parameters

Parameter Value

Rotating Test Pressure 2500 psi* Static Shell Test Pressure 5000 psi* Static Pressure Rating 2500 psi** Stripping Pressure Rating 1250 psi**

Bearing through-bore ID 12 ¼”

Mounting spool through-bore ID 13 5/8” Side Outlet - Diverter 7 1/16”

Maximum RPM 150 rpm

(39)

Rotating Control Devices

(40)

Rotating Control Devices

• Optimal

– Compact high pressure design

– Integrated sealed bearing RCD

– Robust, long life seals

– Dual sealing elements

with bearing without bearing

psi / MPa in / mm in / mm in / mm in / mm in / mm RCD3 3,000 20.68 11 279.4 7 1/16 179.4 11 279.4 7 1/16 179.4 40 1/2 1028.7 RCD5 5,000 34.47 13 5/8 346.1 9 1/16 230.2 13 5/8 346.1 Two: 7 1/16 & 2 1/16 179.4 & 52.4 44 1/2 1130.3

Lateral outlet size Height Model Pressure Rating Bottom Flange Size Bore Diameter RCD5 2000 psi @ 100 rpm RCD3 1000 psi @ 100 rpm

(41)

Rotating Control Devices

Especificaciones

Presión Estática 5,000 psi

Presión Dinámica 2,500 psi @ 120 RPM

Alto y Ancho 44.5” (1.13 m) / 30” (0.76 m) Paso 9 1/16” con balero_{13 5/8” sin balero}

(42)

Rotating Control Devices

(43)

Rotating Control Devices

• Low Pressure RCD

– Low pressure RCD for

onshore applications

– Sub-compact, single piece

designs

– Robust bearing assemblies

LP 7368, low pressure RCD for land rigs LP 7068, short profile, low pressure RCD

(44)

Control Systems

• @balance DAPC

– High degree of control

– Fast, precise automated response

– Real-time hydraulics model

– Automated back pressure pump

– Safety critical Dynamic Pressure

Relief to manage weaker zones

– Safety critical Manual Over Ride

• M-I SWACO LPAC

– Accurate, low pressure manual

control

– Small, economical footprint

– Fast, precise autochoke response

LPAC control console in front, manifold behind

DAPC system rigged up on DW GOM platform

(45)

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Managed Pressure Drilling Systems

EnSure DAPC system rigged up on HPHT well in Libya

(48)

MPD Early Kick Detection System

• @balance Kick Detection

– Coriolis meter measures flow out

– Direct link to the MPD system

eliminates delays

– System monitors and tracks

delta-flow and issues alarms when it

exceeds preset limits

– Early detection reduces kick

volume

– Meter active during connections

when backpressure pump on

– Early detection used for dynamic

leak-off and flow tests

KDS used to detect flow during PP determination test with the DAPC system

Flow detected with meter (step 8 & 9)

(49)

Integrated D&M –DPM Services

Remote Operations

The minimum requirements are:

• Dedicated phone line with dedicated 256-kb/s bandwidth

• Dedicated static internet protocol (IP) address • Remote access permission to wellsite IT staff • Ties to wellsite telecommunications systems beneficial to remote support.

Wired Drill Pipe

•Addresses limitations of mud-pulse and E-mag •Enabler for ERD, UBD, MPD, deep water & automated drilling

•Enabler for RT drilling optimization, well placement, wellbore stability

•Maximize drilling efficiency and risk mitigation •Improved reliability via advanced real time troubleshooting

•Enabler for active formation testing and sampling

Automation & Remote Ops Improved Drilling Performance , Improved Safety , Shared Knowledge Remote Ops 24/7 Wired Drill Pipe Automated RSS,M/LWD Automated Pressure Control (DAPC)

Dynamic Annular Pressure Control (DAPC)

•Safety critical process technology •Early kick detection

•Automated choke operation & switching •Redundant, fast acting chokes

•Automated backpressure pump •On-demand backpressure supply •Real-time hydraulics modeling •Continuous model calibration* •Remote operation and control •Pressure stability within +/- 50 psi

•Programmable alarms and trend monitoring

Automated Rotary Steerable

• Better bore hole Quality •Faster ROPs

•Remote downlinks therefore Driller more focused

•DD works remotely with well Engineering team

•Improved Drilling Performance •Opportunity to assist younger DDs remotely

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Example 1 Managing the Barrier during Transitions

-Connections

(52)

Example-2 Managing the Barrier during Transitions –

Pump Failure

(53)

Example-3 Managing the Barrier during Transitions – Fire

Drill

Unannounced Fire Drill

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Example 5: GOM HPHT - Loss Determination

Start of leak-off test EMW=18.38 ppg EMW increased to 18.48 ppg Backpressure increased to 185 psi Backpressure increased to 330 psi EMW increased to 18.58 Observed immediate losses

EMW reduced to 18.48 ppg

EMW reduced to 18.38 ppg

Pumps off EMW 18.22 ppg Pumps on Time (h) Eq uiv ale nt Mu d W eig ht (pou nd s pe r ga llon )

(56)

Example-6 Wellbore Breathing Eliminated

Connection #5 – wellbore breathing eliminated BHP constant

(57)

Example-7 Malay Basin Drilling Challenges

• Borehole instability: requires high mud weight which gives high ECDs – up

to 2000 psi overbalance

• Severely depleted zones then create differential sticking

• Narrow margins (Stability v Frac Gradient) with losses

• Coal beds: Unstable & troublesome in most wells

• Hole cleaning Non-Productive Time (NPT):

– Cuttings deposits & annular loading – Back reaming 3x per stand

– High viscosity sweeps – Bottoms-up circulation

(58)

ECD in 8.5” Conventionally Drilled Hole

8.5” hole – upper section drilled conventionally with

10.2 ppg mud

Highly variable ECD – swab/surge spikes - increasing

from 11.0 to over 12.2 ppg through hole section

(59)

ECD in 8.5” Hole with MPD

8.5” hole – lower section drilled with automated MPD

control & 9.0 ppg

(60)

Swab / surge in 8 ½” hole w/ MPD

(61)

Offset Non-productive Flat Time

NPT / back ream cost: 2.2 days @ $375,000 per day = $825,000

NPT due to hole cleaning

80 stands

Back reaming:

2-3 Xs per stand

40-50 min/stand

53 hrs (2.2 days)

(62)

Reduced flat time for hole cleaning

35 stands Back reaming: 1-2 Xs per stand 30 min per stand +/-17.5 h

WW w/MPD: Drilled 520 m/d

Offset w/o MPD: Drilled 275 m/d

BKC-WW ST Depth VS Time w/ MPD

Saved 1.7 days @ $375,000 per day = $637,500

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Example -8 Far East Exploration Well

Project Challenges:

• Low shoe strength

• Narrow Pore Pressure/Fracture Window

• Shallow hazard depth

• Potential Risks

– Large volume of gas at shoe & in

riser

– Shut-in pressure breaks down shoe

– Gas seepage to seafloor

– HSE risk to people and rig

Customer Decision:

• Well undrillable within HSE management

system with standard technology

• Requires intelligent, rapid-response,

automated bottom hole pressure control

system

(64)

Well Location

• Operator evaluated 3 locations relative to gas cap

• Final location (Opt 3) placed shoe 100 m below crest

(65)

MWD Assembly with PWD

• Update rate

– 2 sec updates needed for

Annular PWD

• Power

– Selectable sources

– Flow independent battery

power

– Mud pulse turbine to save

battery

• Downhole programmable

Courtesy Baker Hughes INTEQ

Critical MWD features

for closed loop MPD:

(66)

Drill String Telemetry

• Data cable fixed in drill pipe

• Inductive coupler in each joint

• Battery powered repeater ~ 500m

• Telemetry rate of 57.6 kbps (up to 2 Mbps)

• Surface transmission via Swivel sub

Courtesy IntelliServ Inc.

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68

Highly Accurate Bottom Hole Pressure Control

Pump rate (gpm)

Bottom hole Pressure (psi) Back pressure (psi)

Fully automated system delivered <10 s response time

Bottom hole pressure held within +/-50 psi at connections

Back pressure held within +/-15 psi during drilling

(68)

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70

Conclusions

– Many applications for Automated MPD technology in drilling

operations

– Many synergies with existing SLB segments

– Automated Back-Pressure MPD gives reliable, precise

downhole pressure control

(70)

71

SPE Papers

– SPE 130313 Managed Pressure Drilling Brings Added Value to Production Casings Cementing Operations Increasing Success Rates and Quality in HPHT Fractured Narrow Window Wells

– SPE 130312 A simplified and highly effective method to identify influx and losses during Managed Pressure Drilling without the use of a Coriolis flow meter.

– SPE 130316 Managed Pressure Drilling Avoids Losses while Improving Drilling and ECD Management in the Gulf of Thailand

– SPE 128923 New Scaled-Down Automated Control System Manages Pressure and Return Flow While Drilling and Cementing Production Tubing in Depleted Onshore Field

– SPE 140255 Development of an Automated System for the Rapid Detection of Drilling Anomalies using Standpipe and Discharge Pressure

– SPE 112651 Successful Implementation of First Closed Loop, Multiservice Control System for Automated Pressure Management in a Shallow Gas Well Offshore Myanmar

– SPE 122281 Managed-Pressure Drilling: What It Is and What It Is Not

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