Company: WBI
Filing Date: 2025-09-18
Form Type: 424B4
Source: 0001193125-25-206805
Chunk: 195

Company: WaterBridge Infrastructure LLC
Filing Date: 2025-09-18
Form: 424B4
Chunk 195
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. We believe that this growth in production activity will require increased produced water handling capacity, as the amount of produced water from wells in the Delaware Basin significantly exceeds the amount of the related oil and natural gas production. Specifically, for every barrel of oil produced in the Delaware Basin in 2024, approximately 3.7 barrels of associated water were produced, according to Enverus. Produced water volumes have increased as oil and natural gas production has increased in the Delaware Basin over the last several years. From 2014 to 2024, produced water in the Delaware Basin grew from approximately 1.6 million bpd to approximately 13.2 million bpd, a CAGR of approximately 21%. Historical and forecasted Delaware Basin produced water volumes as of December 31, 2024, including the anticipated incremental increase in produced water volumes that could be recycled or handled in existing or new produced water handling facilities, are shown in the graphic below, in each case according to Pickering Energy Partners and B3 Insights.

<div align='center'>Delaware Basin Produced Water Volumes</div>

Note: As of June 30, 2025. Source: B3 Insights and Pickering Energy Partners analysis.

The amount of available pore space and the permeability of a geological formation are essential for successful produced water injection. Porosity affects storage capacity and permeability affects fluid movement, while both together affect formation pressure. Lower formation pressure allows for more water to be injected, and as more volume is injected into the geological reservoir, formation pressure increases. Once a certain limit of formation pressure is reached, injection is limited both operationally and by the applicable injection permits issued by state regulatory agencies. Produced water handling facilities are legally constrained by permitted maximum daily injection rates and maximum wellhead pressures. In some instances, the operational capacity of a produced water handling facility is restricted by formation pressure, preventing the facility from achieving its full permitted capacity. The sequestration of produced water volumes in high pore pressure areas is operationally restricted due to a lack of available pore space for the injected water. These operational capacity restrictions are more common in geographic regions with higher concentrations of produced water handling facilities. Continued injection of produced water in these regions is expected to further increase formation pressure and result in further declines in these facilities’ operational capacities over time. There are two sandstone formations in the Delaware Basin that are suitable for long-term produced water injection: a relatively shallower layer called the Delaware Mountain Group, which is located

<div align='center'>131</div>

approximately