The first application of hydraulic fracturing in the offshore Abu Dhabi was executed safely and successfully. This achievement will be a valuable foothold to expand the field development target toward more challenging reservoirs such as deep tight sand in this region. There were huge amount of operational difficulties to carry out this hydraulic fracturing due to various operational restrictions, limited data availability and high-pressure & high-temperature (HP/HT) condition. Finally, these difficulties were successfully overcome by an intensive designing study on well completion, surface equipment, and operation associated with hydraulic fracturing for a tight gas reservoir.In this paper (Part 2), the key factors that led this trial to the first successful hydraulic fracturing in the offshore Abu Dhabi are described against the difficulties from operational point of view such as well completion design, arrangement of fracturing and surface testing equipment and acquired lessons learnt. However hydraulic fracturing design optimization from subsurface point of view is discussed in the other paper described by Kuroda, et al. (2014) as Part 1. Well completion design and equipment arrangement were optimized to overcome an extremely wide range of pressure and temperature condition with multi stage fracturing. Fracturing and testing equipment of high specification were arranged on the limited space of both the off-shore jack up rig and the fracturing vessel, and then these well-prepared equipment contributed to safe and accurate operation. Acquired lessons learnt will contribute to other offshore tight-sand gas reservoirs development in the offshore Abu Dhabi. These outcomes will be especially applicable in this region to optimize offshore hydraulic fracturing for tight HP/HT reservoirs in order to enhance the well productivity and enable economical development of marginal fields.

Simultaneous Operation (SIMOPS) i.e. concurrent execution of two or more activities at the same time and place, which due to their interaction result in increased operational complexity and level of risk.While challenging existing practices, team has benchmarked Company practices with shareholders, other OPCOs and Service Providers. All the activities having major impact on Production/Injection shut down were captured. Industry standard risk management approach followed to assess all the risks associated with each individual activity. After reviewing all the hazards and safeguards in place, activities were declared as Permitted / Restricted /Not Permitted.In total 17 activities were reviewed, 11 activities assigned as ЉPermittedЉ, 4 activities as ЉRestrictedЉ and 2 activities remained ЉNot PermittedЉ under SIMOPS.By enhancing SIMOPS efficiency by 30%, expected 3 Million Barrels of additional Oil production per year and increased injection rates. Saving above 150 Million USD per year (using current oil price of 50$/bbl). Benefits will further magnify after full scale implementation of multiple SIMOPS per field and increased rig activities in future.Enhanced SIMOPS efficiency helped the Company to increase effective production capacity and achieve its sustained production assurance milestones without any compromise on safety and with no additional cost.

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