CO₂ storage site plan

One editable plan: your storage site, injection plan and the project summary model together. Saved to your account when signed in, otherwise in this browser. Showing starting values — replace them with your site's data.

Storage layer

Site nameTop depth (ft)Thickness (ft)Dip (°)Storage rock typePorosity (fraction)Permeability (md)Surface temperature (°F)Temperature gradient (°F/100 ft)Pressure gradient (psi/ft)

Mid-depth: 160.8 °F, 2,620 psi. Rock types fill typical porosity/permeability — not measurements.

Seal (caprock)

Seal rock typeSeal thickness (ft)Seal permeability (md)Seal CO₂ entry pressure (psi)CO₂ column under seal (ft)

Injection plan

Injection rate per well (t/yr)Injection period (yr)Well spacing (ft)Target trapped CO₂ (t)Years after injectionS_gr,max (trapping curve)Residual brine saturation S_wr

Wells needed

CO₂ injected

22 Mt

CO₂ trapped

10.32 Mt

Site area

14,080 acres

Peak pressure at a well

247 psi

Added by a neighbor

53 psi

Seal check

Column held: the 100 ft CO₂ column pushes 19.4 psi against 100 psi entry pressure; the seal holds about 515 ft at most (Watts 1987).

Injection overpressure near a well (300 psi, well + one neighbour) is above the seal entry pressure — CO₂ could enter the seal near the wells.

Brine density 1050 kg/m³ is an assumption. Seal thickness and permeability are saved but don't change this check.

Wells on a square grid at your spacing; circles are each well's plume when injection stops (to scale, before up-dip migration).

Whole-field grid: CO₂ and pressure from every well

Year 10 of 110 · 0 yr after shut-in

Wells22

Area holding CO₂2,169 acres

Highest pressure rise in field+973 psi

Most-loaded well (itself + all others)+1,112 psi

Drift up-dip0 ft

Point at a cell to read it.

Dark = mobile CO₂ (70% of pore space); light = trapped CO₂ left behind (32.8%, Land 1968).

48×48 cells, each 514 ft across. Pressure in every cell adds up the Theis (1935) rise from every well, not just one neighbour. CO₂ in each cell comes from each well's plume in the same trapping and migration model (Hesse et al. 2008; MacMinn et al. 2011). Simplifications: even rock, plumes move straight up-dip and don't merge or push on each other — where they overlap the cell shows the higher saturation; brine 0.5 cp and compressibility 1e-5 per psi are assumptions.

Also available as a standalone page: Seal check · CO₂ field grid.

One well: plume migration and pressure

Dashed: plume when injection stops. Shaded: mobile CO₂ now. Hatched: swept by returning brine — CO₂ left there is trapped. The plume has moved past its starting outline; brine has re-entered all of it.

Pressure rise above starting reservoir pressure. Solid: at the well. Dashed: 1 mile out. Blue line: the time you picked.

Each well: 1 Mt injected, 0.47 Mt trapped (46.9 %), brine re-entry 100.0 %.
Reservoir temperature 161 °F from depth and your gradient; CO₂ density 601.7 kg/m³ (Span-Wagner 1996).
Trapped share is residual trapping only (Land 1968, S_gr,max 0.382); solubility and mineral trapping are extra.
Pressure is Theis (1935) in brine: 10 yr injection, brine 0.5 cp, compressibility 0.00001 per psi — assumptions, not your data.
Plume diameter (2310 ft) fits inside the 5280 ft spacing.
The site-totals neighbour figure counts one well at the spacing distance; the whole-field grid above adds every well.