Determination of Production Operation Methods in Naturally Fractured Reservoirs

Abstract There are many naturally fractured reservoirs in the world, but few of them are developed optimally. In fact, it is difficult to characterize naturally fractured reservoirs and predict their oil production, let alone determine their appropriate production operation methods (POMs). Although there exist some formulas for evaluating well performance, few are derived on the basis of production test data. In this paper, several general formulas are developed to evaluate inflow performance of both vertical and horizontal wells, based on the production test data of three naturally fractured reservoirs. The rock compaction and the inertialflow resistance in the naturally fractured reservoirs are taken into account in these equations. Furthermore, theoretical models are presented to consider reservoir engineering, production performance, and surface facility performance. These models are then applied to evaluate and determine the POMs for two naturally fractured reservoirs. These two field applications show that stable flowing performance can be predicted accurately, and that artificial lift methods, such as sucker-rod pumps, can be mployed efficiently under certain reservoir conditions. The detailed field application results indicate that most of the POMs, as suggested by the theoretical models, are technically feasible and economically viable. Introduction Naturally fractured reservoirs are found in all types of lithologies and throughout the geological stratigraphic columns. However, the initial high oil rates seen in these reservoirs have misled petroleum engineers, in many instances, to overestimate their future production performance. Thus, the development of naturally fractured reservoirs has resulted in numerous economic failures(1). Meanwhile, field practices show that the selection of appropriate production operation methods (POMs) is critical to the long-term profitability of most producing wells(2–8). An improper choice can not only substantially reduce oil production, but also greatly increase operating costs. Once a POM is employed in a producing well, usually this POM remains unchanged, regardless of whether it will still be the optimal choice under subsequent conditions. Therefore, both the accurate prediction of well inflow performance and the appropriate selection of POMs are of great benefit to the optimal development of naturally fractured reservoirs. In general, it is difficult to characterize naturally fractured reservoirs, predict their oil production, and further determine suitable POMs. The well inflow performance relationship (IPR), which represents the well deliverability to produce fluids, is the first component to be considered in the process of selecting POMs(9). In the literature, although there are some formulas available for evaluating well performance, few are derived on the basis of production test data. Gubkina(10) presented a formula for evaluating the vertical well inflow performance in naturally fractured reservoirs, which was later improved by Bacnev et al.(11) However, the effect of well completion on well inflow performance was neglected. Joshi(12) and Karcher et al.(13) developed models to evaluate the horizontal well inflow performance in naturally fractured reservoirs. Mullane et al.(14) improved Joshi's method to achieve better forecasts. Other formulas(15–17) were developed, in which several unknown quantities are difficult to obtain from oil fields.

Fetched live from OpenAlex and de-inverted. Abstracts are not stored in this database: the inverted indexes are 8.6 GB of the frame’s 9.3 GB of text, and the host has 13 GB free.