The vertical and lateral distribution of pore pressure, as well as fracture pressure, is of great interest in the petroleum industry. An appropriate model of these pressure values can lead to successful drilling and production operations in all stages of the hydrocarbon Field lifecycle. This work aims to model the vertical distribution of pore and fracture pressures of the giant El Morgan oil Field in the Gulf of Suez region. Two development wells were analyzed to interpret the pore and fracture gradients along accumulative 4200 m of a sedimentary section ranging from Early Miocene to Recent age. Wireline logs, downhole measurements, and drilling events were incorporated together in the modeling process, and the standard industry Eaton's methods were used for the calculation process. An average of 17 ppg (EMW) lithostatic gradient has been modeled for El Morgan Field. The fracture pressure of the Middle Miocene sandstone reservoirs was observed to range from 11.92 to 13.12 ppg. The pore pressure modeling indicates strong overpressure against Late Miocene shale deposits with a magnitude of 10.6 ppg. Mild overpressure of 9.6 ppg equivalent gradient has been defined in Middle Miocene shales. The primary hydrocarbon reservoirs reveal sub-hydrostatic or (sub-normal) conditions resulting from production-related depletion. An appropriate casing seat design was developed according to the developed model.

孔隙压力的垂直和横向分布以及断裂压力在石油工业中引起了极大的兴趣。这些压力值的适当模型可以导致在油气田生命周期的所有阶段成功进行钻井和生产作业。这项工作旨在模拟苏伊士湾地区巨大的El Morgan油田的孔隙和裂缝压力的垂直分布。对两个开发井进行了分析，以解释从中新世到近新纪年期沉积剖面累计4200 m的孔隙和裂缝梯度。在建模过程中将电缆测井，井下测量和钻井事件结合在一起，并且将标准行业伊顿的方法用于计算过程。已为El Morgan Field建模了平均17 ppg（EMW）的岩石静力梯度。砂岩储层范围为11.92至13.12 ppg。孔隙压力模型表明对中新世晚期页岩沉积物有10.6 ppg的强烈超压。在中新世页岩中已定义了9.6 ppg当量梯度的轻度超压。原始油气藏显示出与生产有关的消耗所致的低于静水压力的条件或（低于正常）条件。根据开发的模型，开发了合适​​的套管座设计。