This paper has the recommended procedures to be carried out in each phase: Surface, Intermediate I and II, horizontal and completion with frac string, for Unconventional Appraisal HP/HT wells across Deyab formations in Abu Dhabi (UAE), as well as the technology to be used and avoid, to drill the wells saving time and money helping to make a rentable project. Due to the information received of the zone was scarce, in addition the first well in the area (offset well and taken as a reference) had many operational problems. The operations during drilling the next three wells in PAD # 1 were recorded, analyzed and optimized, resulting in a learning catalog for the area, saving a considered quantity of rig days with a huge impact in the budget and the most important, the exposure of the crews/people at the location was minimized to this hazard environment. The PAD# 1 has 03 horizontal wells, the design is Heavy Casing Design, where each phase has its characteristics to be drilled and cased. The reservoir consists of 03 cl early identified formations: Jubaila, Hanifa and Tuwaiq Mountain into the range from ± 12330 ft. TVD to ± 12900 ft. TVD. Reaching the targets with horizontal wells from 16,000 ft. MD to 17,500 ft. MD. After analyzing each section and getting the recommendations from different service companies and specialist, the changes were implemented in the next well regarding drilling fluid MW, BHA's design, bit type & design, wiper trips, slurries, trajectories, etc. taking as result drilling wells more complicate d without operational issues, in deepest formation, drilling more than 1000 ft. MD and 600 ft. TVD, and saving 3.25 MM$ and 15.2 days per well The PAD # 1 in Deyab field, is the pioneer for the initial development of fracking in UAE. There hasn't had a drilling procedure in detail to reach the target without having issues. This new concession has been already of interest to be developed in conjunction with the National Company, so create a Drilling Learning Catalogue as add value at the moment to handover the wells is a must.

To meet the current oil and gas market challenges, there is an industry need to optimize cost by safely drilling longer horizontal wells to maximize well productivity. Drilling challenges include the highly deviated trajectory that starts from the surface sections and wellhead, the high DogLeg Sevirity (DLS) profile with collision risks, and the thin complex geological structures, especially in new unconventional fields where numerous geological and geomechanical uncertainties are present. To mitigate for those challenges, reviewing the existing drilling techniques and technologies is necessary. To compete in the current Hi-Tech and Automation era, the main challenges for directional drilling service providers are to reduce well time, place wells accurately, and improve reliability, reducing repair and maintenance costs and helping the customer reduce time and costs for the overall project. Offset wells analysis and risk assessments allowed identifying the main challenges and problems during directional drilling phases, which were highlighted and summarized. As a proposed solution, the new generation of intelligent fully rotating high dogleg push-the-bit rotary steerable system has been implemented in the UAE onshore oil and gas fields to improve the directional drilling control and the performance. This implementation reduced the Non-Productive time (NPT) related to the human errors as the fully automation capabilities were being utilized. The new rotary steerable system has the highest mechanical specs in the market including self-diagnosis and self-prognosis through digital electronics and sophisticated algorithms that monitor equipment health in real-time and allow for managing the tool remotely. As a result, the new intelligent RSS was implemented in all possible complex wellbore conditions, such as wells with high DLS profile, drilling vertical, curve, and lateral sections in a single trip with high mud weight and high solid contents. Automation cruise control gave the opportunity to eliminate any well profile issues and maintain the aggressive drilling parameters. Using the Precise Near-bit Inclination and Azimuth and the At-Bit Gamma real-time data and high-frequency tool face measurements in the landing intervals where required for precise positional control to enable entering the reservoir in the correct location and with the correct attitude helping the customer's Geology and Geophysics department to place wells accurately while maintaining a high on bottom ROP.

A PDC design containing updated fracturing elements and utilizing in-bit sensing to optimize parameters can deliver improved ROP and drill a challenging heterogeneous section containing massive chert in one run compared to previously used PDC. The demonstration is supported by a real field case from an unconventional gas exploratory field project in Abu Dhabi. In this unconventional field, seven wells have been drilled using three bits on average to complete the 12 ¼″ section (tricone and PDC) where the presence of chert has resulted in additional trips due to bit life. The content of cherts are large, at approximately 2,000 ft thick, which is the reason why it was decided to think of a new customized PDC bit design and use it in well number seven. The plan is to prove that is possible to achieve one run to TD by fracturing cutter development and optimized drillers roadmap using in-bit sensing. The new unique PDC shaped cutter, with increased point surface area and thicker diamond table, makes the overall design more impact resistant and reduces vibrations while drilling. In bit sensing data is utilized to increase the efficiency in rock interaction through optimized parameters. It will be used in the ongoing exploratory project to demonstrate its advantage in terms of cost saving and rig time reduction. The study will compare the data with previously used bit and create a basement for the exploratory field in 12 ¼″ section. A strong hypothesis is that this bit will complete the well in this particular area and optimize drilling costs in development studies. Where such non-homogenous formations containing massive cherts can be crossed and have detrimental impact on the bit life, the novelty is to bring to the stage an enhanced combined PDC and parameter solution, which will be able to offer a different alternative by reducing torque, having healthier wells, and optimizing drilling cost in this unconventional field where drilling CAPEX reduction are paramount.

This subject Well was drilled as water alternative gas injector in Al Nouf field to optimize and support the pressure sustainability of multiple producer wells across reservoir formation based on MRC / ERD approach. The well have high departure so in order to attain the subsurface targets the production casing needs to be extended. This paper will outline the planning and execution of successfully deployed the longest production casing in ADNOC Onshore well using hydraulically rotating shoe. Planning of this well commenced by meetings and collaboration with subsurface operation and reservoir team with the common objective of drilling a smooth section of over 16,473ft as tangent with max inclination of 83 deg. All the associated risks were highlighted and mitigated by proper planning and engineering analysis such as trajectory, additional wipers trips, collision risks, BHA, hydraulics and casing design. Inhouse research was done to find a quick solution to cater challenge in deploying long production casing down to section TD. A hydraulically operated reamer shoe was then selected to encounter the challenge with some risk mitigation in place. The 9 5/8" casing was successfully landed at the target depth of 16,473 feet and subsequently cemented. All the efforts of hole cleaning, dedicated wiper trip played important role in deploying long intermediate case to section TD. Utilization of rotating shoe played a significant role in clearing the ledges and tight hole due to challenging formation. Rotating shoe was the first deployment in the well where it was identified as a challenging well context and had limited regional experienced. Several previous cases casing being held up in the first run. Despite the fact that a wiper trip has smoothened the hole condition, the parameters that were captured during the running. The detailed analysis and operation feedback from casing running job and subsequent operation will be beneficial to provide other operators in assessing the minimum requirement and suitability of this technology utilization to overcome the drilling challenge. This technical paper will show the importance of this project, with the lessons learned, challenges and its mitigation explained in this paper will support the idea to plan and drill the pilot hole and data acquisition in re-entry wells efficiently with key cost savings also will lead to many more successful dual casings exits for future wells. Successful Deployment Of Longest 9 5/8" Production Casing Across Highly Deviated ERD Well

The understanding of salt beds has been significantly improved over the years; however, certain operational challenges still persist. Conditions encountered during drilling salt formations may lead to stuck Logging While Drilling (LWD) and or wireline tools, which, at times, can contain radioactive sources. As data gathering remains a primary requirement in exploration wells, cost optimization, beside risk mitigation, is a further challenge in today’s economic landscape. A holistic approach is proposed to address these main objectives. The conventional procedure required drilling and formation evaluation (LWD and or wireline) in the section above the interbedded salt formation, followed by rotary steerable (RSS) only in the interbedded salt formation sections of the well. Considering the shallow depths of the well and the proximity to the aquifers, the threat posed by losing radioactive sources in the well is significant, therefore, formation density and neutron porosity logging operation is often compromised due the inherent risk. Logging While Tripping, a method in which tools record open hole data from inside the pipe, resolves this compromise, as the risk of lost in hole (LIH) is virtually eliminated. The empty LWT collars are run in the last bit trip or reamer run, as they do not affect the drilling operation. Once the well’s total depth is reached, the LWT logging tools are pumped from surface, safely inside of the pipe, and data is acquired while tripping the drill pipe out of the well. If the situation is evaluated as risky, drilling operation may continue without data acquisition. In case the logging tools already were deployed, they can be retrieved at any time by wireline or slickline. Prior to the introduction of the LWT in the drilling/data acquisition procedure, only gamma ray - sonic data was acquired over the challenging formation sections. Compressional and shear data may be important to improve modelling accuracy; however, they may be negatively affected by various factors such as drilling noise, mud properties, washouts and gas in the formation, particularly reservoir rocks interbedded with thick salt beds. When compared to the Neutron-Density porosity, sonic porosity is noticeably inferior, showing limited formation signature. Neutron-Density porosity correlates well with core data.