Investment in The Coconut Industry by Nancy Cheruiyot
CO2 Injection/Storage Site
1.
2. Washington
County
The CO2 capture unit at Alabama Power’s
Citronelle Dome
(Southern Co.) Plant Barry became
operational in 3Q 2011.
CO2 Injection
Site
A newly built 12 mile CO2 pipeline from
Plant Barry to the Citronelle Dome
completed in 4Q 2011.
Mississippi
Alabama
CO2 Pipeline A characterization well was drilled in 1Q
2011 to confirmed geology.
Plant Barry
Mobile
County Two injection wells were drilled in 4Q 2011.
100 to 300 thousand metric tons of CO2 will
be injected into a saline formation over 2 to
3 year period beginning in summer of 2012.
3 years of post-injection monitoring.
Mobile
3. •! Proven four-way closure at Citronelle
Dome
•! Injection site located within Citronelle
oilfield where existing well logs are
available
•! Deep injection interval (9,400 ft)
•! Numerous confining units
•! Base of USDWs ~1,400 feet
•! Existing wells cemented through
primary confining unit
•! No evidence of faulting or fracturing,
based on oilfield experience, new
geologic mapping and
reinterpretation of existing 2D
seismic lines.
4. Baseline reservoir characterization:
•! Analysis of over 80 existing oilfield well logs
for porosity, thickness and depositional style.
•! Sand mapping to determine “open” or
“closed” sand units.
We collected new geologic data on the Paluxy reservoir and confining
unit with the drilling of the project’s three new wells:
•! 210 feet of whole core and 70 percussion sidewall cores
•! Full set of open hole logs on all three wells (quad combo, MRI, spectral gamma,
mineralogical evaluation, waveform sonic, cement quality, pulsed neutron
capture)
•! Baseline vertical seismic profiles and crosswell seismic collected in Feb 2012
5.
6. CO2 Plume Extent
10 yrs after End of Injection •! Inject at maximum injection rate
during for three years (500
tonnes per day).
9460
CO2 Saturation
•! Plume area in topmost sand is
(v/v) 9520 0.35mi2 (225 acres)
•! Most of the CO2 enters the
9570
upper Paluxy sands due to
9710
9540 higher permeability and
injection gradient
9900 9740 •! These results are used to
design injection (well design,
9800
9970 completion program, monitoring
program)
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7.
8. 1. 16” Conductor Pipe set at 60’.
1
2. 10-3/4” Surface Casing @ 2,520’,
set in 13 1/2” hole; 45.5 lb/ft J-55
STC; Cemented to ground surface.
2
3. 7” Protection Casing @ 11,780’,
3
set in 9-7/8” hole; 26.0 lb/ft L-80
LTC; Cemented to ground surface 4
(2 stage).
4. 2-7/8” Injection Tubing @ 9,300’; 5
6.5 lb/ft L-80 with NTS-8 threads
and TK-805 internal coating.
5. Annular Fluid: 8.4 lb/gal inhibited
fresh water.
6. Injection Packer @ 9,358’; 7” x 2
7/8” AS1-X Pryor nickel plated
packer.
7. Tailpipe Below Packer, base at 6
9,391’ (33’ long)
7
8. Perforations (0.40” charges @ 2
shots per foot): 9,436’ to 9,800’. 8
9. Cast Iron Bridge Plug at 10,800’ 9
capped with cement. 10
10. Total Depth @ 11,780 ’.
9. The Anthropogenic test will use five
deep wells to track the CO2 plume plus
three shallow water monitoring wells:
•! Near-surface and deep reservoir fluid
sampling.
•! In-zone and above-zone pressure and
temperature monitoring.
•! Cased-hole neutron logging.
•! Crosswell seismic and VSP.
•! Surface soil flux and tracer surveys
Results will be used to periodically
update the reservoir model and UIC
Area of Review.
10. •! Baseline monitoring began in late 2011
•! Permission to inject anticipated in May 2012
•! CO2 injection operations begin in June 2012, continue for 1 to 2 years
•! 3+ years of post-injection monitoring, then close site
10
