68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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Marcellus Performance – NE Pennsylvania 21 MARCELLUS HORIZONTAL PRODUCERS Daily Production (Mcf/day) 14,000 12,000 10,000 8,000 6,000 4,000 Lycoming 1 Lycoming 2 Lycoming 4 Lycoming 3 Lycoming 10 Lycoming 11 Lycoming 12 Lycoming 13 Lycoming 14 Lycoming 5 Lycoming 6 Lycoming 7 Lycoming 8 Lycoming 9 Susq. 1 Susq. 2 Susq. 3 Lycoming 15 Lycoming 16 Lycoming 17 Lycoming 18 Average Horizontal Type Curve (EUR 6 BCF) 2,000 0 0 60 120 180 240 300 360 420 480 540 600 660 720 780 840 Days on Production 69
Marcellus Well Design • Drilling (Average 30 days) • Operated • Drilling primarily delineation wells – with vertical pilot, cores and logs • 5 single well pads in Centre County, PA (2 wells ) and Preston County, WV (3 wells) • Lateral length of 4,000’ to 5,000’ • Closed loop system with synthetic mud • Installing water infrastructure • Non – operated • Drilling primarily lease saving operations, rather than pad drilling • Vast majority single well pads with a few 2 to 4 well pads • Longer laterals 3,000’- 5,000’ • Closed loop system with synthetic mud • Completions (2 to 4 weeks) • Operated • 10 – 12 frac stages, 300’ to 400’ per stage • 4 perf clusters per stage • Slickwater frac with multiple sweeps • Non-operated • Fewer frac stages and larger frac intervals 400’ – 450’ • 6 – 9 perf clusters per stage • Still testing 1 month “resting” of wells • Reduced chemical loading Drilling costs range from $2.5 – $3.5 million Completion costs range from $3.0 – $4.0 million 70
Page 1 and 2:
The Game Plan Enerplus Corporation
Page 3 and 4:
Corporate Profile • Trading Symbo
Page 5 and 6:
Significant Portfolio Repositioning
Page 7 and 8:
2010 Year-End Reserves Summary P+P
Page 9 and 10:
Added Meaningful Upside Potential C
Page 11 and 12:
2011 Capital Focus Resource Play Ca
Page 13 and 14:
Financial Outlook 900 800 Oil Gas A
Page 15 and 16:
Crude Oil
Page 17 and 18:
Bakken & Three Forks Geology Middle
Page 19 and 20: Fort Berthold, North Dakota Key Fac
Page 21 and 22: Fort Berthold Results Long laterals
Page 23 and 24: Significant Future Production Growt
Page 25 and 26: Waterfloods Key Facts OOIP P+P Rese
Page 27 and 28: Waterflood Development Plans • 20
Page 29 and 30: Marcellus Shale Gas Overview • Cu
Page 31 and 32: Marcellus Performance - Cumulative
Page 33 and 34: Marcellus Drilling Activity To Date
Page 35 and 36: Future Production Growth in the Mar
Page 37 and 38: Long-Term Strategy for Enerplus •
Page 39 and 40: 2011 Guidance Summary of 2011 Expec
Page 41 and 42: Cash Flow Sensitivity The sensitivi
Page 43 and 44: Reserves and Contingent Resources P
Page 45 and 46: Enerplus Ownership Canadian US & Fo
Page 47 and 48: Long-Term Debt ($ thousands) Decemb
Page 49 and 50: Fort Berthold Development Plans B 1
Page 51 and 52: Fort Berthold Well Costs Long Later
Page 53 and 54: Fort Berthold Production - Gatherin
Page 55 and 56: Supplemental Waterflood Information
Page 57 and 58: Polymer Flood • Polymer is chemic
Page 59 and 60: Dec-14 Dec-13 Dec-12 Dec-11 Dec-10
Page 61 and 62: Giltedge - Polymer Project Costs an
Page 63 and 64: Medicine Hat Glauc C - Production H
Page 65 and 66: 2011 Development Capital Plans at M
Page 67 and 68: Freda Lake Ratcliffe Unit Freda Lak
Page 69: Supplemental Marcellus Information
Page 73 and 74: Gathering Gas in the Marcellus NE P
Page 75 and 76: Supplemental Deep Basin Information
Page 77 and 78: Stacked Mannville Key Facts Key pro
Page 79 and 80: Stacked Mannville Type Curve Econom
Page 81 and 82: Montney Type Curve Economics AECO (
Page 83 and 84: Disclaimers Assumptions All economi
Page 85: Disclaimers NOTICE TO U.S. READERS
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68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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