Abstract

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 207146, “Conceptual Field Development Plan for X Field,” by Khadijah Ibrahim, SPE, Petrus Nzerem, and Ayuba Salihu, SPE, Nile University of Nigeria, et al. The paper has not been peer reviewed. _ The development plan of a new oil field discovered in a remote offshore environment in the Niger Delta was evaluated. Because the oil in place was uncertain, a probabilistic approach was used to estimate the stock-tank oil originally in place (STOOIP) using low, base, and high cases. The base model is recommended for further implementation. The quantity of oil produced is estimated at 15,000 STB/D, which will require a separator that has the capacity of holding a liquid rate of approximately 20,000 STB/D. The authors find that this developmental plan is cost-effective. Introduction Field X is offshore Nigeria in water depths of 330 ft. The field has an uncertain oil in place, with a possibility of low, base, and high cases. The field reservoir information is available from the exploration and seismic well data provided. The field size (i.e., STOOIP) is estimated at 95 million (low), 145 million (base), and 300 million (high) STB, with an irreducible water saturation of 22%. The reservoir depth is 7,400 ft true vertical depth subsea (TVDSS), with a net pay thickness of 45 ft. The aquifer supporting the reservoir has a strength of 9, with a permeability of 200 md and a porosity of 18%. Generally, the reservoir has permeability and compressibility of the rock formation obtained from the log results of 250 md and 3.5×10–6 psi–1. The reservoir pressure is measured to be 3,400 psia. The field development plan will incorporate production forecasts from the target date of first production, 1 January 2023, through 1 January 2038, for a 15-year field life. The complete paper presents the field development strategies and economic analysis of different well models to evaluate the most-efficient modeling profile for the new field. Methodology Well-Modeling Profile and Performance Analysis. It is assumed that the field will be produced using a platform with a wellhead reference depth of 20 ft above the rotary kelly bushing. The well is assumed to be a vertical well with no deviation. The skin value is estimated to be 1, thereby having a slight effect on the productivity index. Pressure/volume/temperature (PVT) data were available for the oil in place. Using commercial software, the fluid parameters for bubblepoint pressure, oil volume factor, and oil viscosity were matched in the PVT analysis at a reservoir temperature of 170°F and a pressure of 3,400 psia. The measurements of formation volume factor, gas/oil ratio, and oil viscosity at this pressure were used to provide a single match point for the generation of PVT data.

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