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Howard County Inventory and Well Performance Howard - Key Stats and Acreage Position Highlights 2022 development program entirely focused on Howard County Net Acres 33,000 Borden Consolidated acreage position facilitates drilling of more capital Q1-22A Net Production (MBOE/D) % Oil 35.8 72% efficient longer laterals LSS / WCA Locations1 130 Integrating eight Middle Spraberry wells into the 2022 MS Locations1 35 development plan Howard Total Development Locations1 165 Avg. Lateral Length (ft.) 11,500 Avg. WI (%) 92% North Howard Central Howard Avg. LSS/WCA Well Performance2 Middle Spraberry Performance2 200 120 Thumper D 4MS North Howard Thumper B 2MS 175 Central Howard (Wider-Spacing) Production per Well (MBO) Production per Well (MBO) Central Howard (Tighter-Spacing) 100 Cumulative Gross Oil Cumulative Gross Oil 150 80 125 100 60 75 40 50 20 25 0 0 0 90 180 270 360 0 30 60 90 120 150 Producing Days Producing Days 1Gross operated location as of January 2022 (adjusted for 2021 completions); 2Production data normalized to 10,000 lateral length, downtime days excluded 6
Laredo Petroleum Inc.
May 2022

Anadarko Basin Overview 2019 2020 2021 CTRA Acreage Position Reduced Anadarko Strategic acreage swaps; Sold non-core acreage; development capital; focused on acreage delineated Lone Rock with Currently running 2 rigs & 1 completion crew allocation to Permian Basin continuity in core areas Carel/Elder development increased results below 2022 Woodford developments in Downdip and Updip areas offer opportunity to unlock additional value DOWNDIP UPDIP Carel/Elder v Legacy Lone Rock Development Outperforming legacy Lone Rock offset development 32% after 210 days of production, driving increased capital efficiency and higher returns 18 Carel/Elder Cumulative equivalents production per lateral foot (20:1 Boe per foot) 16 LONE ROCK 14 12 Legacy Lone Rock 10 offset development 8 6 COTERRA ACREAGE (182K NET ACRES) 4 WOODFORD MERAMEC 2 Miller Trust: 4 well development 66% WI, 3Q22e TIL 0 0 50 100 150 200 Leota Clark: 6 well development 97% WI, 4Q22e TIL Days Online 13
Coterra Energy
May 2022

MIDLAND BASIN NEW COMPLETION DESIGN DRIVING HIGHER EUR AND NPV PER WELL Miracle Max . Optimizing EUR and NPV by 3 wells with new completion design employing data analytics Actual Production New Design (64 Bbls/ft fluid and Aggressive test of completion size over the past 800,000 2,980 pounds/ft sand loading) three years with fluid loadings ranging from 31 to 67 700,000 Bbls/ft and sand from 1,655 lbs/ft to 3,362 lbs/ft +50% Cumulative Oil Production 600,000 Improvement At current development spacing, larger completions (Barrels of Oil) 500,000 are driving stronger performance and better 400,000 economics Estimated Production 300,000 Base Design (45 Bbls/ft fluid and Approximately 83 wells in 2021 employed proppant 1,860 pounds/ft sand loading) . 200,000 loadings of 2,300+ lbs/ft with some testing 3,300 lbs/ft; 35% also paired with higher fluid loadings 100,000 2022 completions: frac designs with expected 0 average fluid loading of 60 Bbls/ft and 2,800 lbs/ft of May-21 Jun-21 Jul-21 Aug-21 Sep-21 Oct-21 Nov-21 Dec-21 Jan-22 Mar-22 Apr-22 June August October December April 2021 2021 2021 2021 2022 sand 15
SM Energy Company
April 2022

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