A Cost Effective, Fit-for-Purpose Single Well Producer-Injector Completion Strategy for Improved Recovery of Oil: Case Study in Niger Delta

Abstract

An optimized completion design that addresses gaps in the existing single well Producer-Injector (P-I) concept is presented. Field development scenarios based on the optimized P-I concept and conventional waterfloods were implemented using full-field 3D simulation models. Detailed review of the existing single P-I well concept revealed gaps in the completion design with regards to feasibility of data acquisition, ease of well intervention and well safety/control. The existing design utilizes a Single-String-Single (SSS) with through-tubing water injection and oil production through annulus, whilst the optimised design is a Two-String-Dual (TSD) incorporating the flexibility of independent injection/production, zonal isolation for interventions & data acquisition and additional safety completion jewelleries. A fit-for-purpose reservoir candidate was selected by assessing it's suitability for waterflooding. The reservoir belongs to the paralic sequence of the Agbada Formation of the Niger Delta basin - a sequence of interbedded sandstones and shales. The reservoir is an elongated anticline bounded by W-E oriented faults and exhibiting channelized shoreface sediments. Porosity and permeability ranges are 17-31% and 200mD-2200mD respectively. Shale baffles strongly limits the influence of the aquifer. The simulation model comprises an oil reservoir with weak aquifer with the P-I well producing oil and injecting into the aquifer in tandem. Performance of the single P-I well strategy was then benchmarked against conventional waterflood patterns to effectively capture the recovery efficiency and production forecast for each scenario. Results from the simulation model five-parameter experimental design, indicate Ultimate Recovery is most impacted by horizontal permeability, injection rate, flow barrier transmissibility and vertical permeability with the least influence. Dynamic model show waterflood front propagating principally in the horizontal direction from the injector, providing important reservoir boundary pressure support and minimizing the chance for injected water short-circuiting at the sandface. Ultimate Oil Recovery of 5spot/line drive patterns and P-I strategy were similar, 48% and 42% respectively. Well completion costs and forecasts were fed into simple economics spreadsheet to test which technique provides the most value and it showed that P-I concept provides better value (NPV 1.0 and VIR 0.04) than 5 spot/line drive patterns (NPV -44 and VIR -0.34).

AAPG Datapages/Search and Discovery Article #90267 ©2016 AAPG/SPE Africa Energy and Technology Conference, Nairobi City, Kenya, December 5-7, 2016