Thru-Tubing Gravel Pack Techniques have been receiving an increasing attention in the recent years as a cost effective solution for sand producing wells with either failed gravel packs or zones that started sand production at a later stage during the life of the well especially in mature fields with marginal reserves as the conventional workover operations are usually not economically justified. In most cases, because of the marginal reserves available and the high cost of mobilizing a workover rig to perform a conventional gravel pack completion, the operators chose to recomplete the wells using rigless techniques.This paper covers some of the applications that the gravel pack has been placed through the existing completion tubing. It will review the successful installations performed in Malaysia, including the engineering design, completion operations, real-time decisions, and results.The proposed solutions and the lessons learned in these projects could change the sandface completion practices for sand prone wells that are either shut-in or not producing up to their potential in the mature fields. TX 75083-3836, U.S.A., fax +1-972-952-9435

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIn general, mature oilfields have a good portion of the remaining reserves still trapped due to inefficient drainage, production decline, increase in water cut and sand production and aging of the existing systems. This paper addresses techniques and initiatives to optimize development plans in a mature field. For Bokor Field in particular, there have been identified and implemented opportunities such as Infill drilling and workover optimization, dynamic underbalance perforation (DUP), matrix acidizing and propellant stimulation, water shut-off mechanical (WSOM), sand management, through tubing stand alone screens, deployment of electrical submersible pumps (ESP) and gas lift NOVA valves, real time surveillance (DHG, DTS and LiftWatchers*) and optimization, and microbial EOR.Before the implementation of these techniques, this field had a daily oil production equivalent to 10 MSTBD (after fields decline) and the current production is 26 MSTBD. The two main reason for this increase are:• New technologies were employed in this oil field with dramatic results incorporating new hydrocarbon reserves, via 3D seismic techniques, high resolution stratigraphy and better static and dynamic simulation models. • Multidisciplinary integrated studies to increase field ultimate recovery factors by improvements in drilling, workover, stimulations, facilities and EOR methods.

Gas lift has been the primary artificial lift method for wells in an offshore brownfield in Malaysia for the past 30 years. However with depleting and unstable gas lift supply coupled with the increase in water production, an alternative artificial lift strategy needed to be developed. A revisit to the Field Development Plan (FDP) in 2003 has found that Electric Submersible Pump (ESP) could be the solution to overcoming the field's overwhelming dependency on gas lift. During a workover campaign in 2008, 3 ESPs were installed -marking the first production ESP in Malaysia. The ESPs have increased the well production from the gas lift baseline production and on top of that, there is a 66% additional incremental production from the re-allocation of approximately 1 MMSCFD of lift gas from the ESP wells. The success of the three ESPs has developed interest from the field operator to have more units installed.By end of 2011, a total of 5 ESPs has been installed in the field. They consisted of conventional ESPs, followed by an ESP in a pod with a Distributed Temperature Sensor (DTS) cable and a dual ESP with bypass tubing. Another 3 installations have been planned in the near future. The operator is also looking at the potential and feasibility of a rigless deployment for the ESP -either by using coiled tubing or a standard slickline service. In an offshore environment where rig cost and rig availability is of concern to well uptime and project economics, alternative ESP deployment has been seen as the next frontier of ESP technology to increase revenue. The transformation of artificial lift strategy in the field -from gas lift to ESPs -has been very progressive and profoundly significant to the operator's continual technological advancement in the industry.

During the asset management life cycle, one needs to deal with a range of operational problems on a day-to-day basis that are associated with various domains. This consists of handling of massive increment in data streaming per millisecond, real-time data processing, quality control and model feed for proactive problem identification and finally accurate allocation and prediction. The success is still measured by how the investment in real-time systems is leveraged effectively for real-time optimization while minimizing operating expense (OPEX) and improving the profitability of the project. This paper explains with a case study that this cannot be possible just by implementation of integrated data management system, but understanding the business process and streamlining the decisions in fully automated way is the key to success. The case study talks about a mature offshore oilfield, where a lean team was handling around 26 ad-hoc reports manually spending 3-4 hours daily, combining many different data sources, spreadsheets and still prone to human error, inconsistencies and reactive decisions. After thorough business process mapping and key performance indicator (KPI) mapping study, a new streamlined "To-Be" process was designed to deliver analytical production and operational reporting system. Based on full workflow automation, the system is deployed for data acquisition, allocation, reporting and analysis. This has increased accuracy, accountability, and timely availability of quality data, which has helped end users to improve productivity. The comprehensive reporting tool provides access to operational and production reports online, secured approvals and automatic notifications via e-mail for managers. Output reports are available in various formats for nontechnical users without direct access to the core application. The framework allows a streamlined data flow for dynamic updates of well and simulation models, improving process integration and reducing the run-time cycle. A successful deployment of an integrated analytical management system based on application assimilation and workflow automation is helping to improve overall productivity on various levels – Improved data management: Consolidated central database enabling easy data integration and sharing with various processes and applications and reducing the downtime & heightened securityPowerful surveillance: Provides effective KPI tracking, detecting and flagging any data issues and abnormal well behaviour aids entire performance management and decision-making processProactive management: alarms and notifications on operation issues, helping engineers to make proactive operational decisions.Faster cycle times: Business decision cycle times have been reduced from few hours to minutes resulting over 62% efficiency improvementExcellence: Trustworthy and accessible data, streamlined workflows, and application integration have thus provided engineers with faster, better, and confident proactive decision making. Leveraging investment in digital oilfield for quick value delivery by streamlined corporate business process geared towards achieving operational excellence.

This paper will outline and discuss the processes involved from planning to conceptual design, detailed design, equipment preparation and onsite execution that has contributed to the successful offshore installation of Malaysia's first dual ESP system. It will also highlight the challenges and issues encountered throughout the project. The well was originally completed in 1989 as a single producer with gas lift. It is closed in 2004 due to high solid production. A workover operation was carried out in end of May 2011 to revive the well. The current producing zone was plugged and abandoned and the shallower producing interval is opened up and completed. Instead of continuing with the status-quo, gas lift strategy the well is completed with a Dual ESP system with bypass tubing, making it the first ever dual ESP installation in Malaysia. Gas lift has been predominantly used as the main artificial lift strategy in the region. It's relatively ‘cheap’ resources and simple application has been the main driver for oil operator to continue using it as their preferred option. However as the water cut increases and lift gas supply become limited there is a need to have a look on the so called ‘commodity’ artificial lift application. ESP has been seen as one of the most attractive alternatives. The field's first conventional ESP installation with a backup gas lift system in 3 wells was installed in late 2008. In 2010 another ESP with pod configuration was installed. Ever since then, Bokor Project Management team has started to explore on the advancement of ESP system in order to find the optimized design for Bokor Field. However there are several challenges to be addressed. Justification to use a dual ESP system rather than a conventional gas lift system or single ESP configurations that has been done previously in 4 other wells, especially in term of initial cost.The complex installation of a dual ESP system complete with bypass tubing and gas lift backup system which is not a common practice in the areaDesign considerations and challenges for a successful installation. A complete design of a dual ESP for well specific application.Installation challenges of Dual ESP system with bypass tubing and backup gas lift system utilizing a hydraulic workover unit which has limited handling capacity compared to a conventional rig.Surface requirement and limitations of the existing facility for ESP commissioning and startup. Among others, the paper will discuss on the justification and technical solutions that have been proposed for the installation of the dual ESP system in Bokor field. Lesson learned from the project is also compiled in this paper for any future similar installation in the field