classVIBuckeye 2
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Tenaska

Buckeye 2

The Buckeye CCS project is a large-scale carbon capture and sequestration initiative in Jefferson and Harrison Counties, Ohio, developed by Tenaska as part of the Tri-State CCS Hub. The project aims to capture CO2 from regional industrial facilities and transport it via pipeline to deep underground storage sites, effectively reducing the carbon footprint of the Ohio River Valley’s industrial corridor. By utilizing 20 proposed Class VI injection wells in total across the project area, the initiative intends to permanently sequester approximately 5 million metric tons of CO2 annually. The sequestration process targets the Knox Formation, a saline reservoir located between 8,500 and 12,000 feet below the surface. This formation is protected by multiple impermeable cap rock layers, such as the Rochester Shale, which act as natural seals to prevent the upward migration of CO2. The project is also supported by a $69 million grant from the U.S. Department of Energy.

State

Ohio

Country

United States of America

Region

us

Project name

Buckeye 2

Overview

Full Project Overview

All key information and technical data related to this project

Overview

Company:
Project name:
Buckeye 2
Project categories:
class_vi
County:
Jefferson and Harrison
State:
Ohio
Country:
United States of America
Region:
United States
EPA region:
5
Applicant name:
Tri-State CCS
Status:
Pending
Well applications:
20
Injection rate (Mt/year):
2,830,000
Injection years:
60
Total storage capacity (Mt):
130,200,000
Announcement date:
2025-10-29
Data

Wells

Data for injection rates, perforation, and other well-related metrics.

TB2-AOB-19

API
34067218680000
Well class
Stratigraphic
Permit date
2025-09-22

Jefferson County Stratigraphic Test Well

API
34081210290000
Well class
Stratigraphic
Permit date
2025-12-23

TB2-1

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-2

Injection rate (Mt / year)
150,000
Injection years
60
Well class
Injector

TB2-3

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-4

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-5

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-6

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-7

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-8

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-10

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2_9

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-11

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-12

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-13

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-14

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-15

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-16

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-17

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-18

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
10,508 - 10,584 & 6,445 - 6,628
Well class
Injector

TB2-19

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector

TB2-20

Injection rate (Mt / year)
150,000
Injection years
60
Perforation intervals (feet)
11,597 - 11,711 & 6,262 - 6,420
Well class
Injector
Data

Geology

Subsurface data for carbon storage.

Medina

Gross thickness (ft)
168
Depth TVD (ft)
6895
Porosity
5.4%
Permeability (md)
8.26
Datum Depth (ft)
8,443
Temperature (°F)
184.8
Pressure (psia)
4,480
Salinity (ppm)
265,000
Krw @ Sgr
1
KrCO₂ @ Swr
0.95
Water exponent
9
CO₂ exponent
9
Residual water saturation
0.22
Model
Corey-Brooks

Rose Run

* Graph available
Gross thickness (ft)
93
Depth TVD (ft)
10341
Porosity
5.4%
Permeability (md)
39
Salinity (ppm)
320,833
Krw @ Sgr
1
KrCO₂ @ Swr
0.95
Water exponent
9
CO₂ exponent
9
Residual water saturation
0.22
Model
Corey-Brooks
Relative Permeability Graph
Download

Permitted Documents

Official approval, consent, and compliance documents issued by authorities, confirming the project is authorised to proceed.