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.


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".


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 sq km 

  • Terrain:   Land/Swamp/Immediate Offsho

  • No. of Fields:  200+

  • Listed Undeveloped Reservoirs:   +/-6,000

  • Size of targeted Reserves/Reservoir:

    • For Black Oil: 2.0 - 200 mmbbl

    • For C5+ -rich Gas: 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 provided 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.