Enquest Plc · LSE:ENQ

Enquest — Investor Day (December 2015)

88 slides from Enquest's investor day presentation, Dec 8, 2015

1. Slide 1: EnQuest Capital Markets Day

   EnQuest Capital Markets Day 8 December 2015 0

2. Slide 2: Amjad Bseisu, Chief Executive

   Amjad Bseisu Chief Executive

3. Slide 3: Agenda

   Agenda  Overview & Operations Update Amjad Bseisu, CEO  Financials Jonathan Swinney, CFO  UK North Sea Neil McCulloch President North Sea  Kraken Richard Hall Head of Major Projects  Malaysia Bob Davenport General Manager, Malaysia  Summary Amjad Bseisu 2

4. Slide 4: 2015 H2 operations update

   2015 H2 operations update Strong production. Alma/Galia performing well. Reduction in costs Production  H2 production to end of Nov’ up 39% on H1 35,022 Boepd in  2015 to end Nov’ included 8,654 Boepd from Malaysia 2015 to end Nov’  Included spot rates of c.14,000 Boepd gross from Alma/Galia  Se

5. Slide 5: Strategic priorities in a low oil price environment: delivering on execution

   Strategic priorities in a low oil price environment 1) Delivering on execution  Strong 35,022 Boepd production to end November  Averaged 48,677 Boepd over Oct / Nov  Individual days already over 50,000 Boepd  Alma/Galia reservoir and FPSO performing as expected  GKA achieved over 19,000 Boepd g

6. Slide 6: Strategic priorities: restructuring EnQuest's operating cost base

   Strategic priorities in a low oil price environment 2) Restructuring EnQuest’s operating cost base  Programme to streamline operations more than on track  Now expecting to deliver opex $31-32/bbl in 2015  Anticipating unit opex in $26-28/bbl range in 2016  Further reduction once Kraken is onstre

7. Slide 7: Strategic priorities: strengthening the balance sheet

   Strategic priorities in a low oil price environment 3) Strengthening the balance sheet - good operational performance  Reduced Kraken capex by c.10%  Prioritised investment programme  Internationally: Exited Norway, Tunisia, Egypt  UK: Exited 5 licences, down to interests in 30  Investment appr

8. Slide 8: Production results year to end November 2015

   Production results year to end November 2015 Strong production, up 26% year on year, 41,360 Boepd in H2 so far - up 39% Vs H1 Net production (Boepd) 2014 2015 2014 2015 40000 10000 9,061 9,136 35,022 9000 8,609 35000 8,401 8000 7,818 30000 27,815 7000 25000 6000 5000 20000 4,450 4,046 3,925 4000 150

9. Slide 9: Jonathan Swinney, Chief Financial Officer

   Jonathan Swinney Chief Financial Officer

10. Slide 10: Guidance to the market: Full Year 2015

    Guidance to the market Full Year 2015  Reaffirming production guidance between 33,000 Boepd and 36,000 Boepd  Unit production and transportation operating expenditure will now be $31-32/bbl; ahead of target  Cash capex in 2015 will include additional c$150m  Extension of the well programme in Th

11. Slide 11: Guidance to the market: Outlook

    Guidance to the market Outlook  Production guidance between 44,000 Boepd and 48,000 Boepd for 2016  Average unit opex anticipated to be in the range of $26-28/bbl for 2016  Cash capex in 2016 is expected to be approximately $700 - $750m, predominantly focused on Kraken  2016 hedge programme of 1

12. Slide 12: Neil McCulloch, President North Sea

    Neil McCulloch President North Sea

13. Slide 13: Strategic priorities in a low oil price environment

    Strategic priorities in a low oil price environment  Production performance on track Delivery  Upper Quartile drilling performance  Ythan delivered one year after taking licence  Production efficiency remains Upper Quartile  Relentless programme of unit opex reduction Streamlining operations 

14. Slide 14: EnQuest Producer

    EnQuest Producer Project to producing asset  First Oil safely achieved on 27 October 2015  Floating Production Storage and Offloading (FPSO) installation performing well  First cargo lifting planned for late December  Full rate production during Q1 2016  First three wells operating with tempora

15. Slide 15: Alma and Galia

    Alma and Galia Performance in line with expectations Galia Alma (GP1) K3Z (AP1) 1 5 Alma K5 (AP2) 1 7 Well performance in line with expectations:  AP1 (K3Z) Zechstein producer ~3,900 Boepd gross  AP2 (K5) Devonian producer ~3,700 Boepd gross  GP1 (Galia) ~ 7,000 Boepd gross Wells to be commission

16. Slide 16: Greater Kittiwake Area (GKA)

    Greater Kittiwake Area (GKA) A key hub  Platform installed 1990 (CRINE)  16 well slots (rig removed)  Oil capacity 36,000 Boepd (pumps 27,500)  Water injection 50,000 Boepd  Oil via Forties Pipeline System  Gas to Fulmar 15

17. Slide 17: GKA hub strategy

    GKA hub strategy Improve margins and maximise value  Increase Production Efficiency Maximise base  Reduce opex, reduce cost/bbl production Maximise  Execute scale squeezes base production  Manage Supply Chain  2014 Mallard workover Infill drilling  2015 Gadwall sidetrack success  2016 Scolty

18. Slide 18: GKA

    GKA Transformed performance after taking operatorship 17

19. Slide 19: Scolty/Crathes sanctioned

    Scolty/Crathes sanctioned Synergies with Kittiwake realised Scolty & Crathes EnQuest 50% MOL 50%  Two-well subsea development, north of 9 km Kittiwake Greater Kittiwake Area  High-quality reservoirs, c. 7 Mmboe (net) 2P 16 km EnQuest 50% Dana 50% reserves  Capex reduced by 40% through ‘value engi

20. Slide 20: Significant Prospectivity Around GKA

    Significant Prospectivity Around GKA 19

21. Slide 21: Thistle / Deveron

    Thistle / Deveron High production efficiency, cash-flow returned from drilling programme  High production efficiency of mid-80s%  Three well programme extended and activities complete in 2015 :  A61 accessing updip target against Thistle bounding fault A59 & w/o  A62 twin of A41 (plugged due to

22. Slide 22: Dons / Conrie

    Dons / Conrie  YTD production significantly above budget in 2015  High production efficiency of mid- W1 Conrie – S7 80s%  High levels of water injection W2 efficiency following increase in W5 W3Z S6 injection capacity in March S13 S9  Scale treatments carried out on S12Z West Don W4 and W1, allo

23. Slide 23: Ythan onstream a year after taking licence

    Ythan onstream a year after taking licence Performance Ahead of Expectations NE Extension  Fast track development schedule: Ythan Core Area  Licence acquired Q2 2014  FDP approved Q3 2014  First oil 25 May 2015  Ythan production significantly above expectation with initial rates of more than 8,

24. Slide 24: Heather / Broom

    Heather / Broom High levels of operational uptime 2/0 Else 5- 15 H42 H33 Erica 2/05-21 H61Z 2/0 2/0 (BW3) 5-6 H46 5-5 H64 H41 2/05-23 2/0 2/05- (BR4) 5- H66 Viking 17 2/05-20 19Y H62Y (BR1) 2/05-25 H60 (BR2) H07 H38 H63 Furzey 2/05-27 H56 2/05-20 (BR8)  High production efficiency of mid-80s% (BX5)

25. Slide 25: North Sea OPEX/BOE 2015

    North Sea OPEX/BOE 2015 Cost reduction programme firmly on track: 60 Sullom SullomVoe VoeTerminal shutdown Terminal shutdown  Lower unit rates - Scale treatments, 50 subsea inspection, repairs and maintenance, logistics, equal time 40 rotas and reduced contractor rates $/boe 30  Incentivised contr

26. Slide 26: Northern North Sea (NNS) Infrastructure

    Northern North Sea (NNS) Infrastructure Operational Gas Group (OGG)  Reliable, cost-effective source of fuel gas secured by innovative industry “group buy”  Cost reduced by almost 50% for Heather/Broom Sullom Voe Terminal (SVT)  EnQuest’s NNS transportation costs reduced from $10/bbl in 2014 to $

27. Slide 27: Outstanding drilling performance

    Outstanding drilling performance ESTIMATED FINAL WELL COST vs. Budget vs. RUSHMORE UPPER QUARTILE (£MM Gross) Wells commenced in 2015 (rushmore data 2010-2015) 60 180 Cumuulative Budget / Cumulative Estimated Final Cost Budget / Estimated Final Well Cost £MM 50 150 40 120 30 90 £MM 20 60 10 30 0 0 G

28. Slide 28: Wells delivery excellence

    Wells delivery excellence Achieved through:  Unwavering focus on delivery - keeping it simple, focusing on the detail - getting it right first time  Managing the cost base down and maintaining contractor performance  Smart use of Well Services to perform offline intervention work, de-risking rig

29. Slide 29: Summary

    Summary  Excellent production delivery, portfolio meeting guidance, Kittiwake now delivering Upper Quartile performance in line with NNS assets  Opex/boe ahead of guidance and set to be in the high $20s/bbl in 2016  Alma/Galia complete with minor activities and spend in Q1 2016  Drilling costs/p

30. Slide 30: Richard Hall, Head of Major Projects

    Richard Hall Head of Major Projects

31. Slide 31: Kraken overview

    30 Kraken overview Field summary  2 fields located in Block 9/2b  350km NE of Aberdeen  Field area ~12 x 3.5 km  Water depth of 110m  Heavy oil (14 Deg API) but good flow properties  Low sulphur content and not waxy  FDP approved by DECC with two heavy oil tax allowances confirmed  Developin

32. Slide 32: Kraken development: development plan and field layout

    Kraken development Development plan and field layout  4 integrated ‘Template/Manifold’ Type Drill Centres  14 horizontal producers up to 1000m  All manifolds can accommodate expansion / step out  2 single service integrated 4 slot  11 horizontal injectors up to 1400m manifolds at 3 drill centre

33. Slide 33: Kraken development: key deliverable of buoy achieved on schedule

    Kraken development Key deliverable of buoy achieved on schedule 32

34. Slide 34: Kraken development: FPSO module location

    Kraken development FPSO module location 33

35. Slide 35: FPSO Armada Kraken

    FPSO Armada Kraken Construction continues Installed greenwater protection Installed flare tower E-House & laydown installed on main deck Helideck & loading hose/reel installed 34

36. Slide 36: Kraken development: FPSO overall view

    Kraken development FPSO overall view 35 35

37. Slide 37: Kraken development: FPSO swivel

    Kraken development FPSO swivel 36

38. Slide 38: Kraken development: FPSO overall view

    Kraken development FPSO overall view 37

39. Slide 39: Kraken development: M70A & B power generation

    Kraken development M70A & B power generation 38

40. Slide 40: Kraken development: M30B separation

    Kraken development M30B separation 39

41. Slide 41: Kraken development: FPSO 2016 forecast module lifting dates

    Kraken development FPSO 2016 forecast module lifting dates 25-Feb-16 Lifted Lifted 22-Feb-16 20-Feb-16 Lifted Lifted Lifted 28-Jan-16 Lifted Lifted Lifted 09-Feb-16 17-Feb-16 30-Jan-16 20-Feb-16 40

42. Slide 42: Kraken development: Deep Energy installing pipeline end termination

    Kraken development “Deep Energy” installing pipeline end termination (April 2015) 41

43. Slide 43: Installation of Submerged Turret Production buoy and DC1 risers

    Installation of Submerged Turret Production (STP)buoy and DC1 risers Buoy/turret lift from transportation vessel STP buoy/turret pre-ballasting DC1 riser and buoyancy module installation 42

44. Slide 44: Kraken development: 2016 subsea programme to first oil

    Kraken development 2016 subsea programme to first oil  Subsea programme/timings – “Subsea  Drill Centre DC3 Umbilicals, Risers, Flowlines” (SURF)  Install water injection & production “Integrated Template Structures” (ITS)  Drill Centre DC2  Install water injection & production  Install water

45. Slide 45: Kraken development: Wells/drilling

    Kraken development Wells/drilling D3 D2 B2 Wells drilled through reservoir 44

46. Slide 46: Kraken: Wells progress summary 2015

    Kraken Wells progress summary 2015 Drill Centre 1 Drill Centre 2 (DC1) (DC2) Topholes – complete 7 @ DC1, 6 @ DC2 17½” – complete 7 @ DC1, 6 @ DC2 12¼” – to date 1 @ DC1, 2 @ DC2 8½” – to date 1 @ DC1, 1 @ DC2 Kraken Summary end November 2015 42” hole – 2,400ft drilled 17½” hole – 23,000ft drilled 1

47. Slide 47: All wells drilled to date in line with expectations

    All wells drilled to date in line with expectations Well B2 Dataset: BBK2012 – PGS Extended Far JJB Pseudo Density Geosphere canvas at TD 10/8/15 Depth 46

48. Slide 48: Kraken development: Schedule of work for 2016

    Kraken development Schedule of work for 2016 Wells available pre-first oil : 4 producers & 4 injectors  Rig Programme – Transocean Leader  Drill Centre 1 (DC1)  Drill and complete six wells to finish DC1 drilling programme  DC3  Batch drill and run intermediate casing in five wells  DC2  Batc

49. Slide 49: Kraken development: Schedule to first oil

    Kraken development Schedule to first oil 48

50. Slide 50: Kraken development: Total project capex (gross basis)

    Kraken development Total project capex (gross basis) $3,500 WELLS CONTINGENCY $3,000 (Deterministic) P50 CONTINGENCY $2,500 Sanction Current WBS DRILLING & WELLS ($mm) ($mm) (excluding WHs & XTs) $2,000 MAN-POWER + G&A 243 232 $mm INSURANCES $1,500 STUDIES 45 37 PRE-OPS + PRE- PRODUCTION SUBSEA - SU

51. Slide 51: Kraken development: Capex reductions achieved through planning and execution

    Kraken development Capex reductions achieved through planning and project execution  Extensive planning pre-sanction including 2  Well defined contracts/contractual scopes FEEDS1 for FPSO and subsea FEED with attractive payment profiles  Comprehensive detailed WBS2 for total project  Third party

52. Slide 52: Kraken development: Project status

    Kraken development Project status  FPSO conversion on schedule for 2017 first oil  Drilling/well programme ahead of schedule  Excellent reservoir correlation with subsurface expectations  Further Reservoir upside discovered by Tyrone/Tiree appraisal well to west of field  Submerged turret/buoy

53. Slide 53: Bob Davenport, General Manager, Malaysia

    Bob Davenport General Manager, Malaysia

54. Slide 54: Malaysia: Ground floor opportunities aligned with our strategy

    Malaysia Ground floor opportunities aligned with our strategy Decision to leverage EnQuest’s proven expertise in managing mature offshore assets by extending footprint beyond the UK Southeast Asia – and particularly Malaysia – selected as ideal target for next growth hub PM8/Seligi  June 2014 – Acq

55. Slide 55: Malaysia: Right place, right time, right owner

    Malaysia Right place, right time, right owner Low operating costs Progressive national oil company, regulator Remaining reserves of c. 8-10 Bnboe Over 3,500 energy sector companies World class oil and gas infrastructure Steady supply of skilled professionals 800 Evolution of Malaysia’s oil industry

56. Slide 56: EnQuest Malaysia: World class resource with significant remaining upside

    EnQuest Malaysia World class resource with significant remaining upside PM8/Seligi fields (50% WI)  2.2 Bnboe HIIP  Produced 680 MMboe (31% recovery factor)  Gross reserves: 2P 38 MMboe; 2C 105 MMboe  Peak production 160,000 Boepd – once the largest field in peninsular Malaysia PM8 fields  Curr

57. Slide 57: PM8/Seligi Asset

    PM8/Seligi Asset @nQuest

58. Slide 58: PM8/Seligi: A producing hub with capacity for future growth

    PM8/Seligi A producing hub with capacity for future growth PM8 fields  5 producing fields: Lawang, Langat, Serudon, Yong, North Raya  4 unmanned platforms – supported from Seligi  10 producing, 25 idle oil well strings  All production flows to Seligi, lift gas from Seligi Seligi field  2 manned

59. Slide 59: PM8/Seligi: Improved performance with minimum spend

    PM8/Seligi Improved performance with minimum spend  EnQuest assumed operatorship October 2014  Average gross production increased from 12,400 Boepd to 15,100 Boepd (+22%)  Production efficiency enhanced from 82% to 95% (+13%)  Improved by focusing on:  Facility integrity  Gas compressor reliab

60. Slide 60: PM8/Seligi: Ensuring facility integrity for safety and reliability

    PM8/Seligi Ensuring facility integrity for safety and reliability PM8/Seligi facilities Field testing new inspection technology for temporary pipeline wraps  Average asset age 21 years 84 inspected  2 manned and 11 satellite platforms 60% of all piping done  370 km of pipelines 9 completed  Comp

61. Slide 61: PM8/Seligi: Improving compressor reliability

    PM8/Seligi Improving compressor reliability for higher production efficiency October 2014 November 2015 Gas Power Compress Gas Power Compress Gear Box Gear Box Turbine Turbine or Turbine Turbine or Excess Train A Train A hours Excess Train B hours Seized Train B Overhaul ongoing Excess Train C Train

62. Slide 62: PM8/Seligi: Well interventions have added 3,000 Boepd from idle wells

    PM8/Seligi Well interventions have already added 3,000 Boepd from idle wells 2015 campaign  Added 3,000 Boepd gross by restoring idle wells to production  Focus on mechanical jobs only – sand cleanout, gas lift reinstatement, surface valve repairs  Reservoir surveillance to support future work 

63. Slide 63: PM8/Seligi: Multiple avenues for growth

    PM8/Seligi Multiple avenues for growth Serudon near Pantai field development cluster development PM8 gas development Peta & Peta-Kiri cluster development East Raya cluster development Seligi field  Idle well restoration  Workovers  Infill drilling  Waterflooding 62

64. Slide 64: PM8/Seligi: Forward work plans to convert contingent resource

    PM8/Seligi Forward work plans to convert contingent resource to production* *Subject to PETRONAS approval Technical studies, contracting, mobilization 63

65. Slide 65: Seligi field: World class resource with significant remaining upside

    Seligi field World class resource with significant remaining upside  Seligi discovered in 1971; first oil in 1989  1.9 Bnbbl STOIIP; produced 560 MMbbl  Recovery factor 30% to date  Peak production 160,000 Boepd in 1995  Current production 10,000 Boepd gross  44 active and 206 idle oil well st

66. Slide 66: Seligi field: J-18/20 reservoir

    Seligi field J-18/20 reservoir: surveillance drives recompletions, infill drilling and waterflooding J-18/20 Type Log  Seligi field’s largest reservoir, J- J-18/20 Top Structure Map 18/20, has c. 715 MMbbl STOIIP  Recovery to date is 42%  Excellent to marginal quality sandstone:  Porosity: 21% -

67. Slide 67: Seligi field: J-15/16 reservoir pilot

    Seligi field J-15/16 reservoir pilot to evaluate Seligi waterflooding potential  The J-15/16 reservoir has c. 390 MMbbl STOIIP  Recovery to date is 31% J-15/16 Type Log  Thin, laminated sandstone:  Porosity ~21%; permeability ~ 250 md; net sand 3 m – 8 m  Weak-moderate aquifer drive, thin gas c

68. Slide 68: Seligi field: Targeting K, L and minor J reservoirs

    Seligi field Targeting ‘K’, ‘L’ and minor ‘J’ reservoirs for infill and horizontal drilling  Collectively, the ‘K’, ‘L’ and K-10/20/25 Type Log minor ‘J’ reservoirs have c. 775 MMbbl STOIIP  Recovery to date is only 18%  Typical layer characteristics:  Porosity: 15% - 22%  Permeability: 100 md

69. Slide 69: PM8 fields

    PM8 fields Ongoing field reviews and remapping following 2013 seismic survey Yong Field Seismic Section  5 producing and 3 undeveloped fields  348 MMboe HIIP; produced 120 MMboe  Recovery factor 34%  First oil in 1998; peak production 50,000 Boepd in 2003  Current production 5,000 Boepd gross 

70. Slide 70: The PM8/Seligi production sharing contract

    The PM8/Seligi production sharing contract Revenue-Over-Cost PSC model  Royalty is 10%  The remaining oil is split between cost and profit oil based on R/C ratio  Cost oil is used to pay EnQuest’s costs  Profit oil and unused cost oil is divided among EnQuest and Malaysia  Profit oil is subject

71. Slide 71: The PM8/Seligi production sharing contract: natural hedge

    The PM8/Seligi production sharing contract A natural hedge against oil price Entitlement barrels before Share of production after supplemental taxes tax Malaysia Malaysia Malaysia take share Malaysia take c. 26% c. 28% share c. 31% c. 41% EnQuest EnQuest EnQuest entitlement share EnQuest entitlement

72. Slide 72: Tanjong Baram Asset

    Tanjong Baram Asset @nQuest

73. Slide 73: Tanjong Baram field

    Tanjong Baram field Leveraging EnQuest’s proven execution capability  EnQuest (operator, 70%), UZMA (30%)  Developed under a risk services contract (RSC)  Located 6 km off the coast of Miri, Sarawak in 10 m water depth  Wellhead platform with 2 wells tied-back to West Lutong complex via 8 km fle

74. Slide 74: Tanjong Baram field: First oil production in only months

    Tanjong Baram field First oil production in only 14 months Net pay exceeded pre-drill expectations  March 2014 – signed RSC  Feb 2015 – platform substructure installed and spud of first well  April 2015 – completed installation of subsea pipeline  May 2015 – platform topsides installed  June 20

75. Slide 75: Tanjong Baram fiscal terms

    Tanjong Baram fiscal terms Based on the risk services contract (RSC) model Comparison between RSC and PSC models Tanjong Baram RSC PM8/Seligi PSC Production EnQuest production entitlement from cost oil Production belongs to PETRONAS entitlement and profit oil Reserves Ownership retained by PETRONAS

76. Slide 76: EnQuest Malaysia: World class resource; sustainable growth

    EnQuest Malaysia World class resource; sustainable growth World class resource  2.2 Bnboe in-place; only 31% recovered to date Multiple avenues for material growth  Interventions from c. 230 idle strings  Workovers, infill drilling, waterflood Already delivering  PM8/Seligi production increased

77. Slide 77: Summary

    Summary j@ @nQuest

78. Slide 78: Strategic priorities in a low oil price environment

    Strategic priorities in a low oil price environment Operating on the assumption of lower for longer  Delivering on execution  Streamlining operations  Strengthening the balance sheet Institutionalising lower opex/barrel, leveraged for high future cash flow growth 77 77

79. Slide 79: EnQuest is the company to turn maturing assets around

    EnQuest is the company to turn maturing assets around Turning field decline into production growth and economic field life extension PM8/Seligi gross production Thistle production Heather net production 6,000 Heather New Wells SVT Shutdown 5,000 Heather Base Sales Oil Rate bopd 4,000 SVT Shutdown 3,

80. Slide 80: Repositioned for resilience now and for sustainable growth

    Repositioned for resilience now and for sustainable growth Delivering strong compound annual growth rates 15% to end 2014, expecting c.24% in 2015, c.33% in 2016, then further substantial increases beyond Average net production (Boepd) 50000 50,000+ 4,000 45000 44,000 40000 3,000 35000 33,000 30000

81. Slide 81: Q&A

    Q&A Thistle/Deveron Dons Northern Producer Heather/Broom Alma/Galia EnQuest Producer 80

82. Slide 82: Delivering sustainable growth

    Delivering sustainable growth On course for over 50,000 Boepd Exploiting our Commercialising existing reserves & developing discoveries Dons, Thistle/Deveron, Heather/Broom, Ythan Alba Scolty/Crathes Alma/Galia Kraken PM8/Seligi Greater Kittiwake Area, PM8/Seligi Converting contingent Making selecti

83. Slide 83: EnQuest's growing North Sea asset base

    EnQuest’s growing North Sea asset base As at 30th June 2015 The Dons Production and Thistle / Deveron developments Discoveries Other licences Heather/Broom Kraken Alba Avalon Scolty / Crathes Greater Kittiwake Area Alma/Galia 82

84. Slide 84: Thistle, Conrie and The Dons infrastructure

    Thistle, Conrie and The Dons infrastructure 83

85. Slide 85: Heather / Broom infrastructure

    Heather / Broom infrastructure 8484

86. Slide 86: The EnQuest Team: Biographies

    The EnQuest Team Biographies Amjad Bseisu, Chief Executive Amjad Bseisu holds a BSc Honours degree in Mechanical Engineering and an MSc and D.ENG degree in Aeronautical Engineering. From 1984 to 1998, Amjad worked for the Atlantic Richfield Company (ARCO), eventually becoming president of ARCO Petro

87. Slide 87: The EnQuest Team: Biographies

    The EnQuest Team Biographies Richard Hall, Head of Major Projects Richard Hall graduated from Leeds University with a BSc in Chemical Engineering and spent the first 10 years of his career gaining experience with operating oil companies (Amoco, Hess and Murphy Petroleum) as a supervisor in offshore

88. Slide 88: Forward Looking Statements

    Forward Looking Statements This presentation may contain certain forward looking statements with respect to EnQuest’s expectation and plans, strategy, management’s objectives, future performance, production, costs, revenues, reserves and other trend information. These statements and forecasts involv

EnQuest — Investor Day (December 2015) on 6ix