Material Balance Application for Brownfield Development

Filed in Articles by on July 6, 2021

Material Balance Application for Brownfield Development


The need to re-develop one of the Brownfields located in the Niger Delta area of Nigeria was necessitated by the fact that there are still three undeveloped reservoirs in the field. A total of six stacked reservoirs,

A100 to A600 (all oil-bearing with associated gas) were penetrated between 8552 ft and 10652 ft by the APV-1 well. Reservoir blocks A200 and A600 are the largest in the field accounting for 77% of the total field STOIIP.

The well was completed with a Two String Multiple (TSM) on the two levels, with the short string producing from the A200 reservoir and the long string producing from the deeper A600 reservoir, A300 behind the sleeve.

The purpose of this research is to identify the best developmental plan to produce the reservoirs, either with a TSM completion or with a Smart well completion based on the economics.

There are many single well fields in the Niger Delta area of Nigeria that have not been optimally produced, hence this study seeks to maximize the life of this field. The reservoirs were simulated and the production forecast carried out amounted to 14.55 MMstb for a period of 16 years.

After the economic analysis was performed, the Net Present Value for the TSM and the Smart well completion were the US $MM 241.9 and 248.88 respectively, and an Internal Rate of Return of 155% and 202% respectively, hence the Smart well development plan is recommended.


Petroleum reserves are declining, and fewer noteworthy discoveries have been made in recent years (Abdus, 1990). The need to increase recovery from the vast amount of remaining oil and to compete globally require healthier reservoir management practices (Abdus et al, 1994).

However, technological developments in all areas of petroleum exploration and exploitation, along with fast increasing computing power, are providing the tools to better develop and manage reservoirs to maximize the economic recovery of hydrocarbons (Abdus, 1990).

A reservoir’s life begins with exploration, which leads to discovery; reservoir delineation; field development; production by primary, secondary, and tertiary means; and abandonment (Figure. 1.1).

Sound reservoir management is the key to the successful operation of the reservoir throughout its entire life. It is a continuous course, unlike how the baton is passed in traditional E&P organizations (Abdus et al, 1994). Reservoir Management is all about excellence in the Operate phase of an E&P project life cycle.

This is the only phase (Operate) that earns income, to provide the return on investment and it is the longest of the four (4) E & P business phases (Exploration, Appraisal, Development and Operate) spanning decades. (Shell WRM Operational Excellence, 2010).

Complete reservoir management requires the use of both human and technological resources for maximizing profits (Abdus et al, 1994). It requires good coordination of geologists, geophysicists, production, and petroleum engineers to advance petroleum exploration, development, and production.

Also, technological advances and computer tools can facilitate better reservoir management as well as enhance the economic recovery of hydrocarbons. Even an 11 small percent increase in recovery efficiency could amount to significant additional recovery and profit.

These incentives and challenges provide the motivation to sound reservoir management. Reservoir simulation is the way by which one uses a numerical model of the geological and petrophysical characteristics of a hydrocarbon reservoir to analyze and predict fluid behavior in the reservoir over time.


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