The implementation of extended reach horizontal wells in Saudi Aramco, and in the southern area of Ghawar field in particular, is being increased for production and cost optimization. Logging these wells is a challenge, as production profile of a horizontal section cannot be entirely recorded with conventional coiled tubing (CT). This is mainly because of friction forces between the CT and the wellbore, which cause CT to lock-up significantly shallower than total depth (TD). Although with availability of this limited technique, such as metal to metal friction reducer, still CT reach cannot be maximized effectively. This paper will describe a successful utilization of agitator tool with custom designed e-line bypass that helps CT maximize the coverage of the horizontal section for logging purposes. The agitator tool was incorporated into the Production Logging Tool (PLT) and bottom-hole assembly (BHA). It was activated by pumping to cause the CT string to vibrate, and subsequently reduce the friction contact between the CT and the wellbore to allow CT running beyond the normal lock-up depth. The tool was trial tested in an extended reach horizontal well which has a TD of 12,118 ft. The simulator was showing a predicted lock at 10,400 ft while a dummy run proved a lock-up point occurs at 10,800 ft without activating the agitator. The e-line agitator was activated while the well was flowing at a restricted rate which maximized the reach to the TD and reducing the friction coefficient by around 26%. Different conditions and parameters were conducted in order to understand the best performance of the e-line agitator tool. The implementation of the e-line agitator resulted in extending the reach of CT by an additional 1,300 ft and reaching TD. This additional reach was significant as the last part of horizontal section was contributing water. The production log has been reviewed and showed acceptable measurements. This paper will cover the whole cycle of candidate selection, job design, execution, post job evaluation, lessons learned and conclusion. Introduction Drilling strategy has been shifted from vertical to horizontal at most oil fields in Saudi Arabia due to proven advantages in optimizing production and cost. Even the existing vertical wells, they are being converted to horizontal to prolong their life, improve productivity index and delay water encroachment. Furthermore, the drilling strategy is being developed by drilling more complex wells, such as extended reach horizontal wells, to maximize reservoir contact. This type of well is widely implemented in Saudi Aramco, particularly in the Haradh area, which is located at the southern part of the giant Ghawar field. The extended reach horizontal well can be defined as a well with measured depth (MD) to true vertical depth (TVD) ratio that is equal to or greater than 2 (MD/TVD)1, 2. For this particular field, the horizontal well can be considered as extended reach when its horizontal section is equal to or more than 6,000 ft. These wells act as a challenge for most of the rigless well intervention operations, such as acid treatment and logging, using conventional coiled tubing (CT). The challenge came from CT limitation to cover the entire long horizontal section.

Stuck wellhead gate valve at surface offers and demand an extreme well integrity operation. Subsequently; well intervention operation needs more attention and might become more complex using conventional milling techniques. Conventional milling techniques have also fail to meet required well control or found to be lengthy and costly operation. The world's first novel gate valve milling operation using e-line has been performed safely and successfully in Saudi Arabia. Saudi Aramco; land based oil producer well; located in Southern Area of the Ghawar field; was shut-in due to malfunction of Tubing Master Valve (TMV) on closed position for Signal Stack-Up X-Tree. 3,000 BOPD and well accessibility were locked with expected 1,600 psig as shut-in wellhead pressure underneath the stuck valve gate is the case. The objective of this paper is to provide a safer and faster operation solution for milling gate valve that would adhere to the operator's well integrity safely and well control polices. This paper will describe detailed job design, operational steps of this novel milling operation, and other technical considerations that resulted in the successful execution of challenging operation.

Multiphase production logging is essential to identify the contribution of different zones, types of fluids produced and other production related issues in producing wells. Data collected is used to determine if the well requires other services to enhance production or isolate unwanted zones.Locating water production and cross flow between thief zones are common problems for carbonate formations. Remedial well services require costly multiple mobilizations of wireline, coiled tubing (CT) and stimulation units. Results might not be accurate due to the time gap between identifying the problem and implementing the action.The new fiber optic enabled coiled tubing (FOECT) system supports many well intervention services, such as production logging, water shut-offs and/or acid stimulations with a single CT string. Combining FOECT with a real-time multiphase production logging tool (MPLT) reduces well downtime and improves remedial service quality control. Downtime is reduced by using the same surface equipment of FOECT to perform multiphase logging and also remedial work. Only the required bottom-hole assembly (BHA) needs to be changed. This successful logging job for Saudi Aramco allows evaluating remedial well services to be planned right after the production logging job to maximize quality control. This paper documents the implementation of the FOECT system with real-time MPLTs and demonstrates the following improvements for the Ghawar field: 1. First time in a Saudi FOECT system and MPLTs were used to log a wet oil producer well for immediate evaluation of remedial work needed. 2. Significant reduction of well downtime by eliminating multiple mobilizations of wireline, CT and pumping units. 3. Established best practices for production logging with FOECT and multiphase tools, including equipment rig up and single acquisition system setup. 4. Optimize the required equipment by eliminating the electric line (e-line) logging unit.

Electrical Submersible Pumps (ESPs) are widely deployed means of artificial lift methods as they are versatile and adaptable to various well conditions. However, ESP completions have significant installation and operational costs. This paper will address an in-house developed ESP Operational Excellence (OE) initiative that translated into longer run life, increased reliability, and sustained oil production. The objective of this initiative is to unleash the ESPs’ full potentials, and provide structured approach to measure its performance and sustain improvements. The Operational Excellence model is based on asset management cycle of Plan, Do, Check, and Adjust. Production Engineering Team with the support of Artificial Lift Specialty identified two major focus areas; ESP turnaround, and premature failure, as OE candidates. Each focus area was examined in two parts: 1) review of current performance, and 2) review of processes implementation. The current performance was thoroughly reviewed and immediate actions were incorporated and tracked by Key Performance Indicators (KPIs) and driven by results and improvements. In parallel, review of processes implementation was conducted to fine tune current procedure and enforce Best Practices (BPs). ESP turnaround time was significantly reduced through planning ahead required activities, desings, and equipement. This was achieved by setting agenda and streamlined communication with all concerned orginizations. ESP turnaround was done in 20% less days before OE. With the implementation of OE model, oil production was ensured in timely efficient manner without comprising quality as well HSE. The other focus area is premature failure. Once an ESP is properly designed, installed, and operated, the ESP performance is continuously monitored and maintained. The check part of the OE cycle comes into place when the ESP is confirmed failure. Then, the equipment is thoroughly checked using data collected from Dismantle & Inspection Failure Analysis (DIFA) process, with the aim of enhancing performance and deliverability. Based on the detailed investigation, the factors that affected the pump health are integrated and adjusted for the next ESP application. Through DIFA process management, quality assurance activities were conducted to ensure that lessons learned during operation and maintenance, as well as improvements to existing ESP designs are incorporated in new designs; to continuously improve ESP asset integrity and reliability. Therefore, corrective and preventive actions were implemented to resolve common factors that affect ESP performance, such as downhole electrical components including motors and pumps, seals, well conditions and human error during pump installations. By refining these factors, the ESP performance curve was improved and operational excellence was achieved. The implemented Operational Excellence model has shown its significance in optimizing process details from ESP design until operation, which consequently improved ESP run life, increased reliability and sustained oil production.