68. RETAILTexasmarketingpresentationFINAL.pdf - Enerplus

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Freda/Skinner/Neptune, SK - Ratcliffe & Bakken • Approximately 115,000 net acres of Ratcliffe rights • Majority overlay Bakken rights • Oungre/Ratcliffe zones at a 1,600 - 1,800 metre depth • Current Ratcliffe production ~1,700 BOE/day • Internal best estimate contingent resource of 9.0 MMBOE, 70% of our booked 2P reserves <strong>Enerplus</strong> Ratcliffe Rights Average working interest > 98% Ranging from 70 –100% • Current reserves are booked to 26% • Bakken results to date disappointing – further analysis required • Positive success in the Ratcliffe 65
Freda Lake Ratcliffe Unit Freda Lake Ratcliffe Voluntary Unit #1 99.86% WI Key Facts OOIP 55 MMBOE Recovery Factor to Date ~14% Cumulative Production P+P Reserves (Dec. 31, 2010) 8 MMBOE 10.2 MMBOE (booked to 31%) Best Est. Contingent Resource 2.3 MMBOE (+4% RF) Oil Quality 2011E Exit Production 32° API 1,900 BOE/day oil (+40% vs 2010) <strong>Enerplus</strong> Ratcliffe Rights 2009/10 Development Locations 2011 Development Locations 2011 Injector Conversions Horizontal wells and waterflood optimization unlocked major resource • Discovered 1967 & developed on 80 acre vertical well spacing, acquired in 2003 • Peripheral waterflood implemented mid 1980’s • New wells attract lower royalties • Historical decline ~ 4%, RLI ~40 years • Injection conversions increasing oil production from surrounding producers • Recent single and dual leg HZ wells producing at 150-300 bbl/day with 37-65% water cuts vs a previous pool average of over 90% 66
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: 2011 Development Capital Plans at M
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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