DVALIN FIELD DEVELOPMENT

DVALIN FIELD DEVELOPMENT14 OCTOBER 2020TORE ØIAN

HSE OVERVIEW

DVALIN FIELD DEVELOPMENT – SPE STAVANGER – 14 OCT 2020PAGE 3

DVALIN PROJECT SAFETY TRIANGLE

FIELD OVERVIEW

GENERAL INFORMATION


• Located NW of Heidrun

• Tieback to Heidrun

• Production through Polarled to Nyhamna

• Discovered 2010 / 2012

• Partners:

• Petoro (35%)

• Edison Norge (10%)

SUBSURFACE

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DVALIN FIELD DEVELOPMENT – SPE STAVANGER – 14 OCT 2020

Dvalin

Dvalin

DVALIN DEVELOPMENT

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DVALIN DRILLING AND COMPLETION

DVALIN FIELD DEVELOPMENT – SPE STAVANGER – 14 OCT 2020

DVALIN D&W ORGANIZATION

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WELLSITE

Logistics CoordinatorThomas Søreide

HSEQ AdvisorAnne Mork

TransoceanTom Sande

Operations Geologist

Kristian Tellefsen

Drilling Superintendent

Mark Gast

Cost ControllerAngus Bruce

Procurement CoordinatorThomas Evjen

Aker SLSNils Nagevik

Drilling EngineerTrenton Hirsch

Rig Intake Bjørn Engeseth

Well Team LeadJens Storhaug

Drilling ManagerTore Øian

Completions EngineerRobert Ritschel

Well Test / Completion Engineer

Duncan Bertram

Sr. Subsea EngineerScott Wood

Sr. Completions Engineer

Garbhan Gibbons

Sr. Drilling SupervisorBjørn Engeseth, Per Martin Kleven,

Guy Coleman

Drilling SupervisorRobert Ritschel, Henrik Grønne, Håkon Vatnebryn, Per Atle Flytle

Drilling EngineerIda Mo, Stefan Sonntag,

Karim Soliman, Denise Karlsen

Sr Drilling EngineerPiotr Byrski

GeologistDavide Duranti

Production Engineer

Reidar Birkeland

Subsurface Manager

Neal Hughes

PetrophysicistGeorge Lawrence

GeophysicistManuel Gelhaus

Reservoir Engineer

Eirik Jensen

Wellsite GeologistCompletion Engineer

Subsea EngineerPerformance Coach


Challenges• SR capacity

• Boost pressure facility removed by OEM• VDL capacity

• Heavy mud and 9 7/8 casing• Fluids capacities

• 2x mud systems, slops and brine• SPP limited to 5000 psi• Crane capacity vs heavy lifts

Highlights• Established CMS and SMS• Reliable personnel and equipment• Low operational cost• Low WOW cost

DVALIN DRILLING RIG – TO ARCTIC


TO ARCTIC – RIG INTAKE AND MODIFICATIONSRIG INTAKEConducted jointly with Cairn Utilised integrated DEA/Cairn rig intake document Included OWS and XT equipment integration testing

RIG MODIFICATIONSUpgrade XT skid and elevator to 110t

- Existing system rated to 70t – EDP/LRP assy weighs 100tModify cellar deck XT storage area

- To accommodate Dvalin XT and EDP/LRP assyVDL enhancement (added 600t!)

- Detailed lightship survey, inclining test, - Reduce sand trap volume, remove redundant eqt/structure

Increase Brine Storage (add second brine tank)– Convert pontoon drill water tank to brine tank

XT Umbilical LARS- Install XT A frame and winches on STB side

IWOCS and OWS- Platforms, 10k annulus line, sheaves, etc

Dvalin rig intake process and modifications executed during TOA SPS and completed within time and budget


CRITICAL ELEMENTS

› HPHT Environment

› Large bore for high production rates

› Ceramic sand screens

› Reservoir drill-in fluid

› Clean up to rig

› Flexible schedule allowing for changes

WELL DESIGN


Damage to Formation• Impairment of formation permeability due to mud/filtrate invasion

Damage to Lower Completion• Blockage of screens/lower completion due to mud solids

Failure in 9 7/8 in cement job• failure to qualify as barrier

Lower Completion Screen Failure• Sand production

CRITICAL RISKS

Incorrect Placement of Lower Completion• reduced productivity

Gas Leakage During Well Clean Up• explosion/fire

Insufficient Rig Variable Deck Load• Increased operational risk/cost

Loss of Wellbay Slot• delayed delivery of 4th well/increased cost

DVALIN D&C PERFORMANCE


Z1 over AFE with 51% NPT/WOW

• 135 dys actual vs 85 dys AFE

• 48 dys WOW

Z4 under AFE with 32% NPT/WOW• 79 dys actual vs 85 dys AFE

Z3 under AFE with 22% NPT/WOW• 66 dys actual vs 85 dys AFE

Z2 under AFE with 4% NPT/WOW• 76 dys actual vs 85 dys AFE• Drilled 700+m extra horizontal section

P50 Budget Actual

Days % Days %

Productive 233 68 243 68

NPT 75 22 50 14

WOW 34 10 64 18

subtotal 342 100 357 100.0

Mob/demob 8 11

D&C campaign within 5% of AFE time

D&C campaign under AFE cost

50 dys NPT vs 75 dys NPT in AFE

64 dys WOW vs. 34 days WOW in AFE

DRILLING & COMPLETION - MAJOR NPT EVENTS

DVALIN FIELD DEVELOPMENT – SPE STAVANGER – 14 OCT 2020 PAGE 17

Event Days Description

WOW 64.0 43.5 days in Jan/Feb 2020LMRP disconnect events = 4

Pull BOP to repair acoustic controls

9.3 Includes 4.1 days WOW

Repair failed BOP crane winch

4.6

Failed SSR plug –unable to test casing

4.4 2 events – Z4 and Z3

Unable to set VMB plug

2.4

Failed Welltec tractor 5.5 7 runs total

Failed TCO plug 1.8 TCO plug failed to open on Z1 after 65 dys

Multiple failures in Franks eqt

1.7

Wait on parts for prod test

1.0 31 dys of 50 dys total NPT

DRILLING & COMPLETION - RUSHMORE

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DRILLING CAMPAIGN - OVERVIEW

DVALIN FIELD DEVELOPMENT – SPE STAVANGER – 14 OCT 2020SLIDE 19

• No major HSE incidents• 3 out of 4 wells delivered ahead of AFE• Drilling campaign delivered within 5% of AFE time

(360 days)• Average cost per well below MNOK 500• Drilled 715m (4%) more than initially planned• 64 days WOW accounted vs. 34 days in the AFE• Drilled 18.23 km of Open Hole• 917m geo-steered• Z2-H horizontal well from decision to drill < 4weeksZ4

Z1Z2

Z3

DVALIN D&C LESSONS LEARNED

DVALIN D&C LL ITEMS – TOP SIXApplicability of horizontal drainage strategy

• Discounted in PDO due to well control, RSS and ROP

Use of separate contracts for subsea equipment procurement and installation

• Use of Conventional LLS instead of OWS

Employ fit for purpose third party equipment and service providers

• DD/LWD delivered top quartile performance

Use of BaraECD RDIF together with OH ceramic screen completion

Optimised production test installation to achieve 3m+ flow rates

Use of third generation rig

• Plus : low unit cost, WH fatigue, WOW

• Minus : SR’s, MP’s, setback, efficiency

DVALIN FIELD DEVELOPMENT

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