Mazzlan, Khairul Akmal (PETRONAS) | Chia, Mabel Pei Chuen (PETRONAS) | Tamin, Muhammad (PETRONAS) | Tugimin, M Azri B A (PETRONAS) | Azlan, Ali Al-Amani (PETRONAS) | Michael, Lester Tugung (Schlumberger) | Sepulveda, Willem (Schlumberger) | Cortez V., Juan L. (Schlumberger) | Muhamed Salim, Muzahidin (Schlumberger) | Kalidas, Sanggeetha (Schlumberger) | Chan, Nathanael Vui Kit (Schlumberger) | Biniwale, Shripad (Schlumberger) | Serbini, Feroney (Schlumberger) | Mohd Arifin, Azahari (Schlumberger) | Tan, Tina Lee Ting (Schlumberger) | Tee, Karen Ying Chiao (Schlumberger)
‘S’ field is a mature oilfield located offshore Sabah, Malaysia. As part of the redevelopment plan, ‘S’ field was the first field selected for an end-to-end asset management Integrated Operations (IO project) where multiple workflows have been implemented for the asset operation optimization through monitoring and surveillance. One of the exclusive workflow that will be further elaborated in this paper is on Candidate Selection and Reservoir Optimization.
Although field optimization mission was ongoing, proper knowledge capture and standardization of such techniques were not adequate due to the limited data management. Lack of decision-support mechanism and most importantly the challenge was of understanding and analysing the asset performance. A key to the success of field and reservoir optimization is defining a tailored approach, for selection of right candidate and collaborative decision for well/field intervention.
With an objective of full field revitalization, the project was focused on integrated, collaborative 3R approach – Reliability, Reusability and Repeatability. Reliability component was based on capturing knowledge from experienced professionals from various domains and blending that with traditionally proven analytical techniques. Reusability was emphasized by the development of consistent and robust analysis workflows ready to use. Repeatability was aiming at standardizing the process of candidate selection and decision making to assist junior engineers.
Sifuentes, Walter (Schlumberger) | Mandal, Dipak (PETRONAS) | Kumaran, Prashanth Nair (PETRONAS) | Ibrahim, Ramli (PETRONAS) | Chabernaud, Thierry (Schlumberger) | Ceccarelli, Tomasso (Schlumberger) | Moreno, Juan Carlos (Schlumberger) | Sepulveda, Willem (Schlumberger)
This paper aims to describe the overall EOR GASWAG concept with some of the key findings after first phase execution and some of the measures taken to maintain the project within the planned OPEX to remain economic. Secondly, to describe a comprehensive reservoir management plan which includes a fit for purpose data acquisition plan and more importantly how the remaining challenges are addressed through the RMP optimization to maximize recovery. Finally, this paper outlines the main key challenges to be faced once the injection phase kicks off, highlighting the surveillance and monitoring strategies to overcome them.
Michael, Lester Tugung (Schlumberger) | Lajim-Sayung, Colinus (PETRONAS Carigali Sdn. Bhd) | A, Maisarah Bt. Jamaludin (PETRONAS Carigali Sdn. Bhd) | Ghazali, Rohaizat (PETRONAS Carigali Sdn. Bhd) | Gilbert, Rayner (PETRONAS Carigali Sdn. Bhd) | Sepulveda, Willem (Schlumberger) | Busaidy, Adil (Schlumberger) | Vaca, Juan Cortez (Schlumberger) | Zubbir, Ahmad Uzair (Schlumberger)
Perforation is a key component in a reservoir inflow to recover the most oil production from a reservoir. In Field S, perforating is typically conducted using the principle of overbalanced technique, which is commonly used in the oil and gas industry and is known to result in higher total skin. This paper discusses the first application of a thru-tubing stand-alone dynamic underbalance technique to clean up perforation tunnels in Field S, Malaysia. The dynamic underbalance(DUB) concept creates a rapid drawdown in front of existing perforation intervals to effectively clean up plugged perforation tunnels, thereby reducing perforation skin and increasing the productivity of the wellbore. The plunge in the oil price in 2014 has led to a focus on cost reduction and opex optimizationin production enhancement initiativesin Field S from existing well stock inventory. Through this initiative, two strings (Well XS and XS) have been selectedto increase perforation efficiency via thru-tubing DUB application, as part of the cost optimization in our production enhancement portfolio. The project scope covers a fullcycle production enhancement initiative, starting from candidate selection to job design and preparation, job execution and post-job analysis.
M Mabror, M Agus Nukman (PETRONAS Carigali Sdn Bhd) | B Ahmad, Zul Izzi (PETRONAS Carigali Sdn Bhd) | Lajim - Sayung, Colinus (PETRONAS Carigali Sdn Bhd) | M Som, M Kasim (PETRONAS Carigali Sdn Bhd) | Sepulveda, Willem (SCHLUMBERGER) | Muhamed Salim, Muzahidin (SCHLUMBERGER) | Ahmad, Azhar (SCHLUMBERGER) | Kumar, Ram (SCHLUMBERGER) | Biniwale, Shripad (SCHLUMBERGER) | Rabtah Seruji, Nur Erziyati (SCHLUMBERGER) | Zhao, Jingmei (SCHLUMBERGER) | Wolfswinkel, Onno van (SCHLUMBERGER) | Kimsaas, Andreas (SCHLUMBERGER) | Borovik, Julia (SCHLUMBERGER)
This paper discusses a case study of a 42-year-old mature offshore oilfield. For this field, with declining production trend and timeworn equipment and technology, understanding and analyzing the transient flow is not a well-defined process. The Integrated Operations (IO) project was kicked-off in 2012 in order to deploy an Asset Management Decision Support tool. One of the focus areas was ‘Flow Assurance Management’ to overcome challenges of well slugging, liquid surge management and to establish guidelines for Start-Up and Ramp-Up processes.
Traditionally in this field, most decisions were based on steady-state well and network modelling without much emphasis on transient behavior. Moreover, lack of instrumentation and manual data processing and model updates made it difficult to estimate current reservoir/operating conditions accurately to support real-time decision making. To overcome these issues, a Dynamic Production Management System (DPMS) was designed and implemented based on a dynamic flow model describing multi-phase flow in the gas lifted wells of the field. This paper describes the system and how it aids in better understanding of flow performanxce issues, collaborative decision making, and improved communication between various operational locations and disciplines.
As part of the IO project, Real-Time field measurements (pressure, temperature, flow etc.) were captured at high frequency (seconds) & validated to ensure the desired data quality. These measurements were automatically used as boundary information by the model which calculates pressure, temperature, flows and volumes in real time throughout the field. The model is used in different modes: (1) For real-time surveillance, the online model provides a series of virtual instruments at locations without actual instrumentation in the field. (2) For advance warning, a separate transient model is executed faster than real-time to predict future events for Slug/Surge Management. (3) Finally the model is also used for planning activities, such as Start-up/Ramp-up or pigging and can predict any alarming issues during these operations. Thus DPMS assists production engineers and operators to make proactive decisions for effectively managing flow assurance challenges and adds value in various areas. Surveillance: Continuous, real-time monitoring of operating conditions within the network, along with prediction of future conditions within the inlet separators. Safety (HSE): Prevention and mitigation of facility trips/shut-down due to slug and surge issues during start-up/ramp-up Efficiency: Improved utilization of engineers' time and experience with increased focus on data analysis instead of data manipulation. Production Gain: Proactive field management for improved production, rather than reactive decisions that lead to deferred production. Dynamic PMS: The system will help to fully optimize wells, networks and facilities in order to produce and operate asset to its fullest potential by minimizing unexpected downtimes
Surveillance: Continuous, real-time monitoring of operating conditions within the network, along with prediction of future conditions within the inlet separators.
Safety (HSE): Prevention and mitigation of facility trips/shut-down due to slug and surge issues during start-up/ramp-up
Efficiency: Improved utilization of engineers' time and experience with increased focus on data analysis instead of data manipulation.
Production Gain: Proactive field management for improved production, rather than reactive decisions that lead to deferred production.
Dynamic PMS: The system will help to fully optimize wells, networks and facilities in order to produce and operate asset to its fullest potential by minimizing unexpected downtimes
It's one of the first fields in Asia to implement an integrated DPMS using the online transient model concept as a basis for effective, real-time and proactive decision support.
Ahmad, Zul Izzi B (PETRONAS Carigali Sdn Bhd) | Aloysius, Debbie (PETRONAS Carigali Sdn Bhd) | Aziz, Hisyam (PETRONAS Carigali Sdn Bhd) | M Som, M Kasim (PETRONAS Carigali Sdn Bhd) | Gambaretto, Agustin (SCHLUMBERGER) | Sepulveda, Willem (SCHLUMBERGER) | Salim, Muzahidin Muhamed (SCHLUMBERGER) | Ahmad, Azhar (SCHLUMBERGER) | Manorian, Andi Bayu (SCHLUMBERGER) | Biniwale, Shripad (SCHLUMBERGER) | Seruji, Nur Erziyati (SCHLUMBERGER) | Muniandy, Satyaraj (SCHLUMBERGER) | Hassan, Muhammad Firdaus (SCHLUMBERGER) | Maduako, Ikechi Vera (SCHLUMBERGER) | Kahar, Izzati (SCHLUMBERGER)
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 security Powerful surveillance: Provides effective KPI tracking, detecting and flagging any data issues and abnormal well behaviour aids entire performance management and decision-making process Proactive 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 improvement Excellence: Trustworthy and accessible data, streamlined workflows, and application integration have thus provided engineers with faster, better, and confident proactive decision making.
Improved data management: Consolidated central database enabling easy data integration and sharing with various processes and applications and reducing the downtime & heightened security
Powerful surveillance: Provides effective KPI tracking, detecting and flagging any data issues and abnormal well behaviour aids entire performance management and decision-making process
Proactive 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 improvement
Excellence: 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.
Setiawan, Toto (PETRONAS Carigali Sdn Bhd) | Ghazali, Rohaizat B (PETRONAS Carigali Sdn Bhd) | Granados, Leidy Pitre (Schlumberger) | Chandrakalatharan, Jayasharadha (Schlumberger) | Zubbir, Ahmad Uzair (Schlumberger) | Mukrim Mohamed Hanafi, Muhammad (Schlumberger) | Sepulveda, Willem (Schlumberger)
Since 2010, Samarang Alliance, a partnership between Petronas Carigali Sdn Bhd and Schlumberger SPM, has been redeveloping the Samarang field (offshore). The objective of the Alliance is to maximize asset value through implementation of technology, processes and practices that enable infill drilling, reservoir management, EOR, Integrated Operations (IO) and production enhancement activities (PE).
Since the beginning of this partnership, the number and complexity of production enhancement initiatives via well intervention has increased greatly. As expected in an aging asset, the well integrity condition is a fundamental piece of information to achieve operational success and consequently incremental oil. The well intervention activities scope range from routing surveys to complex pumping operations.
As part of execution preparation and planning, all production enhancement initiatives (in active and/or idle wells) must have tubing and well integrity checks as early as possible. The loss of downhole tubing/well integrity is one of the biggest and most common challenges faced during the preparation and execution of the PE jobs. In those cases where there are severe tubing integrity problems, well activities can either be cancelled or classified to be performed using costly workover operation, and in the worst case overlooking those issues lead to failures in planning and execution, followed by sunk cost or losing a well.
The Samarang detection techniques portfolio currently consists of surveillance techniques such as pressure monitoring using surface and downhole pressure gauges and manual sampling with subsequent lab tests, Slickline interventions such as running Flowing Gradient Survey (FGS), Multifinger Imaging tool, Leak/Flow point tool (a combination of Pressure, Temperature and Acoustic gauges), Ponytail tool, and setting mechanical barriers (plug) with subsequent inflow tests, E-line or digital slick line conveyed Optical Cable, Wireline leak detector (WLD) and Water Flow Log, Surface testing tools such as pumping equipment to facilitate Tubing/Casing Integrity Tests.
Setiawan, Toto (PETRONAS Carigali Sdn Bhd) | Ghazali, Rohaizat B (PETRONAS Carigali Sdn Bhd) | Granados, Leidy Pitre (Schlumberger) | Sepulveda, Willem (Schlumberger) | Chandrakalatharan, Jayasharadha (Schlumberger) | Zubbir, Ahmad Uzair (Schlumberger) | Hanafi, Muhammad Mukrim Mohamed (Schlumberger) | Vaca, Juan Cortez (Schlumberger) | Yildiz, Rasim (Schlumberger)
Since 2010, Samarang Alliance, a partnership between Petronas Carigali Sdn Bhd and Schlumberger SPM, has been redeveloping the offshore Samarang oil field. The objective of the Alliance is to maximize asset value through implementation of technology, processes and practices that enable infill drilling, reservoir management, EOR, Integrated Operations (IO) and production enhancement activities.
One of the focus areas upon resource extraction initiatives of Samarang Alliance is through rigless intervention activities for production enhancement. The dynamics of Production Enhancement (PE) portfolio in Samarang requires the use of engineering and statistical tools to track their efficiency to be able to channel and strategize resources aiming for the highest return on investment (ROI).
The Samarang Well Intervention Performance Evaluation (WIPE) methodology enables the user to assess the profitability of a given well intervention activity over time. Productive layers, time and job type are plotted which helps to triangulate the best avenues for investment. Incremental production is specifically calculated for different time-lines. "Budget Cycle" (Calendar year) to evaluate the efficacy of the current year planned work budget. "PE Cycle" when referring to the duration encompassing one year (12 months) to compare similar PEs irrespective of the month of execution. "PE Life" for the entire duration that the well production will be impacted by the PE. Additionally the calculation of Unit Enhancement Cost (UEC) for the different time-lines is considered, which provides a numerical estimate of the economic value of each PE.
Superimposed with intervention history and reserve estimation, WIPE plots enables the user to find a specific profitable intervention solution to declining production. The "Opportunity Cost" can be calculated to a degree of high accuracy which supports the selection of new candidates and fulfills the requirements of a Signature Field like Samarang. Supported on available medium like Microsoft Excel, this powerful tool improves the decision making and planning processes for Brown Field redevelopment.
Izzami, M. Hafez (PETRONAS Carigali Sdn Bhd) | Ahmad, Zul Izzi B. (PETRONAS Carigali Sdn Bhd) | Sepulveda, Willem (Schlumberger) | Salim, Muzahidin Muhamed (Schlumberger) | Wong, Lee Hin (Schlumberger) | Som, M. Kasim M. (Schlumberger) | Biniwale, Shripad (Schlumberger) | Rodriguez, Nelson (Schlumberger) | Kumar, Ram (Schlumberger) | Wilson, Matthew (Schlumberger) | Eradajaye, Iroro (Schlumberger)
Samarang is a 35-year-old offshore oilfield in Malaysia, operated by PETRONAS Carigali Sdn Bhd (PCSB). Samarang Redevelopment Project was kicked-off in 2010. Integrated Operations (IO) was planned as an Asset Management Decision Support solution by implementing a real time production, reservoir and process surveillance system. Samarang field was the first field selected for end-to-end asset management IO project. The main objective of IO implementation is to focus at the whole asset operation rather than working in silos. The overall asset optimization is achieved through the levels of monitoring and surveillance, diagnosis, optimization and operations transformation.
IO Implementation involves identification of various intelligent asset decision processes referred as workflows in various reservoir, production, and operation domains such as Flow Assurance, Well Performance, Artificial Lift, Production and Facility Planning and Enhanced Oil Recovery (EOR) Optimization. Optimization in Samarang covers a wide spectrum of scenarios from Artificial Lift (Gas Lift, Electric Submersible Pump), separation process, reservoir sweep (Waterflood, GASWAG EOR scheme). The main business driver is to enhance production and improve reserve recovery in order to ramp up the production of Samarang field.
Hybrid Steady-State and Transient-State Total Asset Optimization is designed for implementation through Steady-State model based simulation while the Transient-State model continuously predicts short term transient production effects, as a result asset team can better manage the short term production upset to ensure optimization target is achieved. The transient normally manifests as "Flow Assurance" events such as slugging and surges and these manifestations are to be predicted through transient-state modeling and hence, allow corrective action to be taken through Tri-Node Collaborative Working Environment (CWE).
The hybrid modeling techniques treat the asset as a whole unit instead of isolated silos, simulating the complex interactions between reservoir, production networks and process facilities where decision taken on the production network will propagate the impact to reservoir performance and vice versa.
Zulkapli, Mohd Hanif (PETRONAS Carigali Sdn. Bhd.) | Salim, Muzahidin Muhamed (Schlumberger) | Zaini, Muhamad Zaki (Schlumberger) | Rivero Colmenares, Maria Elba (Schlumberger) | Curteis, Charles (Schlumberger) | Sepulveda, Willem (Schlumberger)
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.
Bokor field is located 45 km offshore Sarawak, East Malaysia. It was discovered in 1974 and started production in 1984. The field reaches its peak production of 30000 barrel of oil production in 1990.
Bokor field comprises of 3 production platform which are BODP-A, BODP-B and BODP-C, one processing platform (BOP-A) and one compressor platform (BOK-A). BODP-A, BODP-B and BOK-A are interconnected by bridge link while the BODP-B and C are only accessible via boat. Power generation is located in BOK-A and limited to BODP-A and BOP-A. The rest of the production platforms have solar power system limited to the platform’s Supervisory Control And Data Acquisition
(SCADA) system and basic utility.
Due to the field unconsolidated formation sand, all of the wells in the early years were completed with cased hole gravel pack. Strong water aquifer in Bokor provides good and continuous pressure support, however increasing water cut becomes a severe problems to the surface facilities and increased demand to the lift gas. As an initiative to boost productions in the field, the operator ties a new relationship with Schlumberger to be its technical partner in 2002. The main objective of the partnership is to produce the incremental oil from the field.
Bokor field comprises of more than 100 strings of oil wells with half of them is idle and the rest are producing on gas lift with several string on natural flow.
Saebi, Shahryar (Schlumberger) | Rivero C., Maria Elba (Schlumberger) | Gornescu, Bogdan Claudiu (Schlumberger) | Veysalli, Elshan (Schlumberger) | Sepulveda, Willem (Schlumberger) | Zaini, Muhamad Zaki (Schlumberger) | Kikuchi, Masato (Schlumberger) | Tsangueu, Barbara (Schlumberger)
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.