68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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Fort Berthold Bakken Results to Date Long Laterals (9,000 ft. 24 frac stages) Type Curve Actual 4 Well avg Short Laterals (4,500 ft. 12 frac stages) Type Curve Actual 5 Well avg Average 30 day initial production (bbls/day) 1,100 – 1,200 1,250 550 – 650 730 Expected Ultimate Recovery (Mbbls) 600 – 800 300 – 400 Cost/Well ($/MM) $8.5 $8.5 $6.0 $6.0 120 day Cumulative Production (bbls) 81,000 100,000 40,000 59,000 Expected Net Present Value (12%, $MM)* $11.2 - $18.0 $3.9 – $7.4 Expected Netback* ($/bbl) ~$50 ~$50 Expected Payout Period (years) 1.3 – 0.8 2.2 – 1.3 Expected F&D ($/BOE) $13.00 - $9.75 $18.50 - $13.50 *Based on February 14, 2011 forward price Royalties average 20%, plus state production tax of 11.5%, op costs of $4/bbl, Differential assumption of $10 - $12/bbl 19
Fort Berthold Results Long laterals are 35% ahead of the average type well prediction Short laterals are 45% ahead of the average type well prediction 160,000 Barrels 140,000 120,000 100,000 Actual Short Bakken Laterals (5 Wells) Actual Long Bakken Laterals (4 Wells) Cumulative Short Type Well Cumulative Long Type Well 80,000 60,000 40,000 20,000 - 0 30 60 90 120 150 180 Days Producing 20
Page 1 and 2: The Game Plan Enerplus Corporation
Page 3 and 4: Corporate Profile • Trading Symbo
Page 5 and 6: Significant Portfolio Repositioning
Page 7 and 8: 2010 Year-End Reserves Summary P+P
Page 9 and 10: Added Meaningful Upside Potential C
Page 11 and 12: 2011 Capital Focus Resource Play Ca
Page 13 and 14: Financial Outlook 900 800 Oil Gas A
Page 15 and 16: Crude Oil
Page 17 and 18: Bakken & Three Forks Geology Middle
Page 19: Fort Berthold, North Dakota Key Fac
Page 23 and 24: Significant Future Production Growt
Page 25 and 26: Waterfloods Key Facts OOIP P+P Rese
Page 27 and 28: Waterflood Development Plans • 20
Page 29 and 30: Marcellus Shale Gas Overview • Cu
Page 31 and 32: Marcellus Performance - Cumulative
Page 33 and 34: Marcellus Drilling Activity To Date
Page 35 and 36: Future Production Growth in the Mar
Page 37 and 38: Long-Term Strategy for Enerplus •
Page 39 and 40: 2011 Guidance Summary of 2011 Expec
Page 41 and 42: Cash Flow Sensitivity The sensitivi
Page 43 and 44: Reserves and Contingent Resources P
Page 45 and 46: Enerplus Ownership Canadian US & Fo
Page 47 and 48: Long-Term Debt ($ 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 and 70: Supplemental Marcellus Information
Page 71 and 72:
Marcellus Well Design • Drilling
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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