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  Economics : Type Curve

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Strong early time performance from first Little Knife pads LITTLE KNIFE AREA ENERPLUS ACREAGE 140 Cumulative Oil Production 120 6/7 wells online Hay Draw Pad (1) 100 per well (Mbbls) Hay Draw Pad 80 60 40 Bice Pad 20 0 0 20 40 60 80 100 Normalized Production Day McKenzie 140 Cumulative Oil Production 120 3/6 wells online 100 per well (Mbbls) Bice Pad (1) 80 60 Dunn 40 20 Billings 0 0 20 40 60 80 100 Normalized Production Day 6 1) Non-producing days removed. See Expected well performance in Advisories.
Enerplus Corp
August 2023

3-Mile Laterals Improving Returns Longer Laterals Increase EUR1 CHRD Indian Hills 3-Mile2 Improving Drilling Time3 18 17 600 Days - Spud to RR (3-mile) 250 Cumulative Oil Per Well (MBo) 16 14.2 Basin Avg. 15.2 Cumulative Oil (Bbls) 500 14 43% 200 36% 12 11.6 400 uplift uplift 150 10 300 65% 8 100 uplift 6 200 4 100 50 2 0 0 0 0 10 20 30 40 50 July '22 YE22 June '23 0 50 100 150 200 Producing Months Producing Days Normal (83 wells) Long (29 wells) CHRD 3mi Wells (8 wells - wide spacing) CHRD 2mi Wells (28 wells - wide spacing) 3-Mile Lateral Efficiencies4 CHRD 2mi Wells (53 wells - various spacing) 1,000 861 22% 3-Mile Laterals Drive Better Economics 800 reduction D&C (/lateral ft) 667 55-60% of remaining inventory 3-mile laterals 600 50% of 2023 expected TILs 20% increase in well costs, +40-50% EUR, = 25pt increase in IRR 400 Extensive analogs across Williston validate drilling efficiencies and EUR uplift 200 0 1) FBIR sample data is third-party data from IHS. Long lateral lengths averaged 14.3k lateral feet, normal lateral lengths averaged 10k lateral feet. 2-mile 3-mile 2) CHRD well data. Removes zero and near-zero production days for both 2mi and 3mi. Two-mile 53 well data set includes 28 well wide-spacing data set 9 3) Data from rig supplier for 3-string, 3-mile wells 4) Data from 2023 budget. Reflects estimated 2023 D&C well costs (including facilities and artificial lift capital costs) / expected TILd lateral length
Chord Energy
August 2023

BEST-IN-CLASS BAKKEN; PERMIAN RESULTS IMPRESS NYSE: NOG Strong and consistent productivity from NOGs two largest basins by revenue Williston Basin Productivity Permian Basin Productivity 350,000 2017 Cum (1) 400,000 (1) (1) 325,000 2020 Cum 2021 Cum 2022 Cum (1) 2018 Cum (1) 300,000 2019 Cum (1) 350,000 (1) 275,000 2020 Cum 300,000 250,000 2021 Cum (1) 225,000 2022 Cum (1) Cum Production (Boe) Cum Production (Boe) 250,000 200,000 175,000 200,000 150,000 125,000 150,000 100,000 100,000 75,000 50,000 50,000 25,000 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 1. Wells assigned to years based on year in which they started producing. Cumulative type curves comprised of the following 1. Wells assigned to years based on year in which they started producing. Cumulative type curves comprised of the following numbers of numbers of gross wells: 2020-7; 2021-30; 2022-73. Includes producing wells as of June 30, 2022. gross wells: 2017 291; 2018 479; 2019-460 ; 2020-259; 2021-302; 2022-110. Includes producing wells as of June 30, 2022. Note: Production normalized to 10,000. 15
Northern Oil and Gas, Inc.
August 2022
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