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  Economics : Type Curve

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WILLISTON BASIN - FORT BERTHOLD WELL PERFORMANCE Maintaining strong well performance at lower cost Enerplus well performance Total well costs Cumulative oil production per well (Mbbl) (USMM)(1) 34% 600 8.6 WELL COST REDUCTION SINCE 2018 US2.9MM 500 5.7 REDUCTION IN WELL COSTS 400 SINCE 2018 300 2018 2019 2020 2021e 200 EFFICIENCY GAINS Drilling days (spud to rig release) Completions (stages/day) 100 Normalized to 20,700 ft depth IMPROVEMENT IMPROVEMENT 16% SINCE 2018 160% SINCE 2018 - 0 100 200 300 400 500 600 14.6 Producing days 12.2 13.0 2017 wells 2018 wells 2019 wells 2020 wells 2021 wells 4.9 2017 Avg 2018 Avg 2019 Avg 2020 Avg 2021 Avg 2018 2021 2018 2021 18 1) Total well cost includes drilling, completion and facilities costs.
Enerplus Corp
November 2021

TOP-TIER BAKKEN; EARLY PERMIAN RESULTS IMPRESS NYSE American: NOG High-grading of well locations has led to improved well recoveries across both basins Consistent Williston Basin Productivity Permian Basin Productivity 300,000 300,000 (1) 2017 Cum (1) 2020 Cum (1) 2018 Cum (1) 2021 Cum 250,000 2019 Cum (1) 250,000 (1) 2020 Cum Cum Production (Boe) Cum Production (Boe) (1) 200,000 2021 Cum 200,000 150,000 150,000 100,000 100,000 50,000 50,000 0 0 - 30 60 90 120 150 180 210 240 270 300 330 360 - 30 60 90 120 150 180 210 240 270 300 330 360 Days Online Days Online HIGHER RECOVERIES + STABLE COSTS = PROLIFIC RESULTS + DECREASING COSTS = IMPROVED CAPITAL EFFICIENCY IMPROVED CAPITAL EFFICIENCY 2020s program the strongest in company history Early results at or above Williston performance 2021 program starting out strongly (1) Wells assigned to years based on year in which they started producing. Cumulative type curves comprised of the following numbers of (1) Wells assigned to years based on year in which they started producing. Cumulative type curves comprised of the following numbers of gross wells: 2017 291; 2018 479; 2019-460 ; 2020-259; 2021-49. Includes producing wells as of March 31, 2021 gross wells: 2020-7; 2021-1. Includes producing wells as of March 31, 2021 (2) Production normalized to 10,000 23
Northern Oil and Gas, Inc.
June 2021

Bakken: Consistent and Low Cost Performance Click to edit Master title style Delivering Repeatable Results Alongside Significant Structural Well Cost Savings Bakken Projected to Deliver 70%+ ROR(1) and Another Year of Repeatable Well Performance in 2021 Improving Capital Efficiency(2) through Structural Cost Savings Enhanced Drilling Operations Reducing Cycle Times Optimizing Completion Designs Capitalizing on Lower Cost Production Lift Designs Targeting 7% Lower Bakken Well Costs YoY in 2021 1. At 60 WTI and 2.75 HH. 2. Capital efficiency is the cumulative 12 month net Boe (6:1) divided by net Capex, in thousands, per well, averaged per program year based on the date a well is put on line. Down days included. Excludes wells impacted by shut ins. 3. 10,000 Average Bakken lateral length. PROPERTY OF CONTINENTAL RESOURCES, INC. REPRODUCTION AND DISTRIBUTION WITH WRITTEN PERMISSION ONLY 7
Continental Resources, Inc.
April 2021

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