Heidrun CTD Campaign #1 - spe-uk.org CTD Campaign #1 ICoTA European Intervention Conference,...

Heidrun CTD Campaign #1

ICoTA European Intervention Conference, Aberdeen

12th & 13th Nov 2014Bård Marius Johansen, Statoil CTD Engineer

AGENDA

• Heidrun and the CTD project

− Bård Marius Johansen (4 min)

• Equipment and methods

− Manfred Sach (13 min)

• Operational results and future for CTD

− Bård Marius Johansen (13 min)

• Q&A

2

Heidrun CTD project

• Motivated by the need for more drainage points.

• Independent and parallel operations with the main rig.

• Extensive topside equipment development/modification.

− Mud plant positioned on Equipment Support Frame

− Well Intervention Tower reinforcement and modification

− Work-Over Riser Tensioner

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2014-064 Classification:

Three-well pilot campaign

5

• 5 ⅞” hole drilled through 7” tubing and completed with 3 ½” tubing / OH screens

• Overbalanced drilling with WBM and mud-pulse telemetry for communication

• Three-well learning curve with increasing complexity:

• Success criterion for CTD 1: One completed well in three attempts

Well OHlength

EOHC*length

FormationAt KOP

Dog-legseverity

A-19 A 263 m n/a Ile sandstone 7.7º/30m

A-9 C 336 m 105 m Ror shale 10.0º/30m

A-33 A 350 m 70 m Springar shale 10.9º/30m

* Expandable Open Hole Clad

Primary objective: Learning

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Planned CTDwell A-33 A

7

Over to Baker Hughes

Manfred’s slides

BJ Services Company

Heidrun CTD Campaign 1ICoTA Well Intervention Conference, Aberdeen 12th & 13th Nov. 2014

Norway GeoMarket

Manfred Sach | CTD Project ManagerBaker Hughes | Norway Geomarket | Pressure [email protected]

http://www.bakerhughes.com | Advancing Reservoir Performance

© 2014 Baker Hughes Incorporated. All Rights Reserved. ICoTA Well Intervention Conference, Aberdeen 12 & 13th Nov. 2014

Agenda

• The nature of the project

• Services provided

• Equipment developed and used

• Summary

Agenda

© 2014 Baker Hughes Incorporated. All Rights Reserved. 2 ICoTA Well Intervention Conference, Aberdeen 12 & 13th Nov. 2014

• No CT Drilling in Norway since many years

– Norsk Hydro - Hermod (Grane) 1995

– Statoil Gullfaks 1997 and Saga Snorre 1998/99

• Largest CT project ever undertaken by Statoil

• Scope not comparable to any current CTD project around the world

• Covers the scope for 3.5 / 4.0” drillpipe TTRD

– Through 7” monobore completion

– Using 2 7/8” CT

• Do what a drilling rig does !!!

– Well preparation

– Casing exit

– Drilling

– Completion

The nature of the project


Agenda Services provided

• Baker Hughes provided services – surface and downhole

– Coiled Tubing

– Fluid pumping and handling

– Wellbore intervention / preparation, casing exit and fishing

– Tubular handling services – BHA’s and completion

– Directional drilling

– MWD

– Completion / screen services

– Beacon onshore support – data integration – onshore evaluation / optimisation


Agenda Equipment developed /used

• Baker Hughes provided services - surface

– Hybrid, heavy duty CT unit – 120 k injector head

• Complete new build - mainly run on electric – verified working envelope as expected in electric mode

• Performed very well with exception of injector-head

• Full data integration and remote functionality for all equipment (fibre network ring)

• Data transfer onshore for remote analysis / supervision / decision making



• Baker Hughes provided services - surface– Data integration from / to Coiled Tubing / pumping / mud system / directional drilling / mud

logging

– Data transfer onshore for remote analysis / supervision / decision making



• Baker Hughes provided services - surface

– Purpose build, portable / temporary mud system

• Complete new build - performed very well – allows independent operation of platform rig’s mud system

• Required it’s own support structure due to weight and size

• Accompanied by purpose build, continuous service, portable mud pumps - very well suited for the type

of operation



• Baker Hughes provided services - downhole

– 2nd generation spoolable DuraLinkTM CT connector (patented)

• Required to reduce weight of 2 7/8” CT reel from 45t to within platform crane capacity of 32t

• Performed extremely very well – no premature change-out of connector

• Facilitated pass-through of wireline cutter (RCT) for recovery of stuck CT

Picture above shows spoolable

DuraLinkTM CT connector during FEA

bending simulation




– Abrasive CT cutter for stuck pipe

contingencies (patented)

• Development originated from identified high

risk of stuck CT

• Saved about 8 days of downtime on A-33

and avoided cutting of CT at surface when

leak above release tool developed

• Great safety improvement, avoiding CT crew

working above injector head (at height)

• Excellent planning focus on stuck CT

contingencies

Picture shows CT end recovered after activation of abrasive CT cutter




– New 5 3/8” Delta Whipstock system implemented

• Required size did not exist

• Compatible with drilling BHA dog-leg capability

• Two reliable casing windows created

• Very CT friendly system – mills / swarf – not adopted from

an existing drillpipe system




– First time use of 4.75” AutoTrakTM , SENTIO and acoustic caliper on CT

• Great interfacing between CT and DD/MWD – 4.75” top part of CT BHA

• Very efficient data integration between surface an downhole

• A rotary steerable drill-pipe BHA on CT

• Good interaction between DD and CT Driller

Mod Stab

CoPilot AutoTrak Steering Unit

UBHStabilzerMotor Top Stab

OnTrak Mod. Motor

BCPM (Pulser & Power supply)

X/O StopSub NCxx x T2

PDC

CT interface• Quick-Connect• Circulation sub.• Release tool etc.


• Rein Atle Edland, Sascha Schwartze

• Øystein Meling, Fernando Parra, Eivind Hagen, Cato Oppheim, Eric Ericcson

• Alistair Macleod, Mike Kuchel, Even Hestnes

• Freddy Jenssen, Iain France, Stephen Young, Jørgen Bruntveit

• Alf Jacobsen, Otto Omundsen

• Henry Egeland

• Terje Øvermo

• Robert Jessiman

• Eva Nilskog

• And many, many more……

Acknowledgements

• Excellent offshore personnel performance– No major HSE issues during the entire campaign – two incidents with low

severity - pinched finger - person stepped into hole on top of ESF structurewith one leg

– 248 days offshore

– KPI of 92.8% for deliveries through CT contract


Summary

• What does an operator get from such project ?– Simplified contractors view after 1st CTD Heidrun campaign

Delivery Benefit

A 2nd, independentdrilling operation

Increased utilisation of offshore platform resourcesMaximising number of side-tracks drilled in a given

timeframeAccelerated in-fill drilling

A method ofcounteracting theproduction decline

More stabilised productionTarget reservoir portions less attractive for platform main rig

and within CTD reach

A reliable futuremethod for reservoirdevelopment

Potential certainly exists, but the jury is still outMost on-shore locations who used CTD on a frequent basis

had to go though significant learning curve

A ’’lightning’’ fastdrilling operation

Equipment and support intense, within complex offshoreenvironment


Questions…later…back to Bård Marius

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CoiledTubing

Fluid pumpingand handling

Wellboreintervention,casing exitand fishing

Tubularhandlingservices

Directionaldrilling

MWDCompletion

ScreensBeacon servicesData integration


A-19 A operation

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3000

3050

3100

3150

3200

325003/09/2013 10/09/2013 17/09/2013 24/09/2013 01/10/2013

Mill and polish window,cure losses, BHA trip.

Wiper trip to surface, BOP test.

Differentially stuck, unstickCT, wait for new mud,displace to 1.12 sg WBM.

Mud pump failure.

Slow progressdue to stringers.

Permanentlystuck duringwiper trip.

A-09 C Operation

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• An old inner completion installed shallower than expected obstructing the KOP

• Attempts to cut and retrieve the inner completion on CT were unsuccessful

• A-09 CTD Cancelled

3275.0

3300.0

3325.0

3350.0

3375.0

17.12.2013 24.12.2013 31.12.2013 07.01.2014 14.01.2014 21.01.2014 28.01.2014 04.02.2014 11.02.2014 18.02.2014

Time-depth curve A-33 A

2014-06-0524 Classification: Open

Mill window.Polish window and extend rathole.

BOP test, change end connector.

Started underreaming pilot hole.

Wiper trip to surface.Wiper trip to surface, changechipped bit. Wait for main rigto pull production riser.

Unable to enter with MFC.

2nd UR run.SDN caliper run.OH Clad run.

2nd Cladexpansionattempt.

2nd MFC run

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CTD #1

BIT / WORT*

Integration of CTD with platform systems / organization

Logistics – material handling

Parallel operation, independent of main rig

Mud plant reliability

Topside CT equipment reliability

Rig-up / rig-down efficiency

Operational efficiency

HSE

Planned and achieved learning points - topside

– demonstrated – demonstrated with need for improvement

* In operation

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A-19 A A-9 C A-33 A

Whipstock / window (single string)

Whipstock / window (dual string)

Drilling – telemetry / directional control

Drilling – hole cleaning

Drilling – differential sticking

OH Clad – installation

OH Clad – expansion N

Completion

Production

Planned and achieved learning points - downhole

– not attemptedN – failed attempt

– demonstrated – demonstrated with need for improvement

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Lesson #1 – Hole Cleaning

• No cuttings came out while drilling, only during wiper trips

• The more frequent wiper trips in A-33 A proved successful in 5 ⅞” hole

• Underreamed and overgauge hole in shale was impossible to clean

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Lesson #2 – Differential sticking

• Both stuck incidents in A-19 A had elements of differential sticking.

• Time consuming displacement operation to free coil on first stuck incident (6 hrs)

• A N2 bubble technique was developed and full-scale tested for use in A-33 A:

− Reduce BHP with N2 bubble unloading well

− BHP controlled to remain in overbalance

• N2 bubble technique test took less than 1.5 hrs to administer

• Not required to demonstrate technique in a drilling scenario

• This technique will be our preferred first contingency to unstick differentially stuck

pipe in CTD campaign #2.

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Lesson #3 – Shale Stability

• 3 SND (ultrasonic caliper log) passes made,

good agreement between passes.

• In-consistent hole geometry

• Sandstone interval at bottom is logged to be 7”.

5 7/8" 7"

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Future for CTD on Heidrun

• Original scope for CTD2 was to drill sidetracks in live wells with comingled

production .

• Adjusted scope after CTD1

− Reduce well complexity

− Success in dead wells need to be proven prior to extending scope

• Many well candidates on Heidrun identified for CTD

• Challenge: When will our candidate wells die?

• Hopefully a second campaign will be initiated in the relative near future

CTD has a future on Heidrun!

Heidrun CTD Campaign #1

Bård Marius JohansenCTD EngineerE-mail [email protected]: +47 995 12 387

www.statoil.com

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