Previous Projects
Project 1: Shallow Offshore Water Development,
Niger Delta, Nigeria (EA and Eja fields)
Project 2: Shell's Condensate-rich Gas Development
Project 3: Integrated Development of Undeveloped Reserves
of Liquid Hydrocarbons
Project 1
In the period 1997-1999, the principal partner was
responsible for bringing two fields, the EA field
and the nearby Eja field, to FID for an oil major
by September, 1999.
EA field is in 13 to 27 metres
of water, off the western coast of the Niger
Delta of Nigeria. The structure consists of a large,
moderately faulted, and elongated rollover anticline
bounded
to the north by a regional growth fault. Field
hydrocarbons underlie an area of 65 square km spread
over 90 reservoirs.
66 of these held reserves of less than 0.5 million
barrels each. Since discovery in 1965, 17 appraisal
wells were drilled but the field remained undeveloped.
The nearby Eja field, discovered 3 years later,
occurs in a less faulted setting and was partially
appraised
by 4 wells.
In the preceding 30+ years, several
attempts were made by the oil major's staff to bring
EA field to FID,
but without success. As from October 1997, the principal
partner led a multi-discipline team which, by applying
the principles laid out in the downloadable
report,
successfully brought the development to FID by September,
1999.
The FID was based on an investment of US$1.1 billion
for a brand new FPSO-based development with fixed drilling
platforms and some 48 wells.
The field has since been developed and by mid 2003,
was producing at over 100,000 bbl/d of oil, and still
rising.
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 Project 2
Between October 1999 and end 2001, the principal partner
led another multi-discipline team to work on turning
an oil major's condensate-rich gas reserves (with
CIIP of a few billion barrels found in multi-reservoirs
scattered in over 60+ fields in the Niger Delta of
Nigeria) to sound business.
The principal partner once again adopted the same
approach as stated in the downloadable
report, and
built a team that went beyond the traditional upstream
oil and gas industry to include investigations of onshore/offshore
LPG fractionation, product transfer pricing, as well
as the marketing of condensate and LPGs.
He was thereby able to table proposals that established
the foundation for a very attractive LPGs/Condensate
business for all the stakeholders. This ranged from
a $1.2 billion investment in the "base scheme",
involving two fields and dedicated field, transportation,
process, storage and export facilities, and on which
incremental developments from other fields could ride,
down to a $185 million scheme that would require only
a limited investment - a single field, no gas injection
facilities, but with C5+ spiked into the existing crude
oil stream and the C4- injected into a planned gas
supply pipeline to an LNG plant close to 200 km away.
Such limited initial investment would provide early
income while additional investment could be directed
into the realization of the "base scheme".
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Project 3
Driven by License Expiry concerns, the principal
partner took on the challenge of finding a rational,
focused and timely manner to accomplish an integrated
development of the as yet undeveloped liquid hydrocarbon
reserves of one of the oil majors in the Niger
Delta region.
Geographical spread of the Undeveloped Reserves |
+/-70,000 km2 |
Terrain |
Land/Swamp/Immediate Offshore |
No. of Fields |
200+ |
Listed Undeveloped Reservoirs |
+/-6,000 |
Size of targeted Reserves/Reservoir:
For Black
Oil
For C5+ -rich Gas |
2.0 – 200 mmbbl
1.5 – 100 mmbbl |
Undeveloped Reserves of Black Oil and C5+-rich
Gas |
>> 10 mmmbbl |
The
study conducted by the principal partner captured
90% of the reserves in 25% of the reservoirs, and
its proposals included:
- Integrated development of black oil
and condensate-rich gas from the reservoir level
all the way through central processing facilities
to the storage and export points.
- A dedicated C5+-rich export stream
of a significant 8 year plateau, in addition
to providing for the spiking of condensate
into the black oil stream where the former
could not economically be brought to join the
C5+–rich export stream.
- Export of the “lightened” black
oil through 4 export points, i.e. 2 shore-based
terminals and 2 FPSOs that also double up as
FSUs.
- The extended “first phase” of
the development would capture some 71% of the
undeveloped reserves of black oil and condensate-rich
gas, with the rest employed in production plateau
maintenance.
The
proposals provide a basis for moving each of the
30+ Projects of different magnitudes to FID in a
rapid and coherent manner so as maximize the reserves
recovery prior to the License Expiry date of well
below 20 years.
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