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Hamid, Mohd Ridzuan (PETRONAS Carigali Sdn Bhd) | Meor Hashim, Meor M. (PETRONAS Carigali Sdn Bhd) | Norhashimi, Lokman (PETRONAS Carigali Sdn Bhd) | Arriffin, Muhammad Faris (PETRONAS Carigali Sdn Bhd) | Mohamad, Azlan (PETRONAS Carigali Sdn Bhd)
Abstract The recent global pandemic is an unprecedented event and took the world by storm. The Movement Control Order (MCO) issued by Malaysia's government to halt the spread of the deadly infection has changed the landscape of work via a flexible working arrangement. The Wells Real Time Centre (WRTC) is not an exception and is also subjected to the change. WRTC is an in-house proactive monitoring hub, built to handle massive real-time drilling data, to support and guide wells delivery effectiveness and excellence. The functionality of the WRTC system and applications are embedded in the wells delivery workflow. The centre houses drilling specialists who are responsible for observing the smooth sailing of well construction and are tasked to intervene when necessary to avoid any unintended incidents. WRTC is equipped with myriads of engineering applications and drilling software that are vital for the operations. Such applications include monitoring software, machine learning applications, engineering modules, real-time data acquisition, and database management. These applications are mostly cloud-based and Internet-facing, hence it is accessible and agile as an infrastructure that is ready to be deployed anytime anywhere when it is required. The strategy for WRTC mobility started as soon as the MCO was announced. This announcement mandated the WRTC to operate outside of the office and required the staff to work from home. The careful coordination and preparation to transform and adapt WRTC to a new norm was greatly assisted by the infrastructure readiness. All of these factors contributed greatly to a successful arrangement with zero to minimal downtime where a workstation was set up in each personnel's home, running at full capacity. This transformation was done within one day of the notice and completed within hours of activation. Despite the successful move, few rooms for improvements such as redundancy of VPN use to access applications and limited access to some proprietary software can be enhanced in the future. WRTC is ready to be mobile and agile to support the drilling operations remotely either in the office or from home. The quick turnaround is a major indicator that WRTC infrastructure and personnel are ready and capable for remote operations without interruption.
Rosli, Azlesham (PETRONAS Carigali Sdn Bhd) | Mak, Whye Jin (PETRONAS Carigali Sdn Bhd) | Richard, Bobbywadi (PETRONAS Carigali Sdn Bhd) | Meor Hashim, Meor M (PETRONAS Carigali Sdn Bhd) | Arriffin, M Faris (PETRONAS Carigali Sdn Bhd) | Mohamad, Azlan (PETRONAS Carigali Sdn Bhd)
Abstract The execution phase of the wells technical assurance process is a critical procedure where the drilling operation commences and the well planning program is implemented. During drilling operations, the real-time drilling data are streamed to a real-time centre where it is constantly monitored by a dedicated team of monitoring specialists. If any potential issues or possible opportunities arise, the team will communicate with the operation team on rig for an intervention. This workflow is further enhanced by digital initiatives via big data analytics implementation in PETRONAS. The Digital Standing Instruction to Driller (Digital SID) is a drilling operational procedures documentation tool meant to improve the current process by digitalizing information exchange between office and rig site. Boasting multi-operation usage, it is made fit to context and despite its automated generation, this tool allows flexibility for the operation team to customize the content and more importantly, monitor the execution in real-time. Another tool used in the real-time monitoring platform is the dynamic monitoring drilling system where it allows real-time drilling data to be more intuitive and gives the benefit of foresight. The dynamic nature of the system means that it will update existing roadmaps with extensive real-time data as they come in, hence improving its accuracy as we drill further. Furthermore, an automated drilling key performance indicator (KPI) and performance benchmarking system measures drilling performance to uncover areas of improvement. This will serve as the benchmark for further optimization. On top of that, an artificial intelligence (AI) driven Wells Augmented Stuck Pipe Indicator (WASP) is deployed in the real-time monitoring platform to improve the capability of monitoring specialists to identify stuck pipe symptoms way earlier before the occurrence of the incident. This proactive approach is an improvement to the current process workflow which is less timely and possibly missing the intervention opportunity. These four tools are integrated seamlessly with the real-time monitoring platform hence improving the project management efficiency during the execution phase. The tools are envisioned to offer an agile and efficient process workflow by integrating and tapering down multiple applications in different environments into a single web-based platform which enables better collaboration and faster decision making.
Saharuddin, Mohamad Kamil (Setegap Ventures Petroleum Sdn Bhd, now with Hyperseal Solutions Sdn. Bhd.) | Md Jusoh, Nur Zulaikar (PETRONAS Carigali Sdn Bhd) | M Effendi, Shahrul Nizam (PETRONAS Carigali Sdn Bhd) | Kamaruddin, Izam Ikhwan (Setegap Ventures Petroleum Sdn Bhd) | Mohd Yusof, Lydia (Setegap Ventures Petroleum Sdn Bhd)
Abstract High annulus pressure in old producing wells in offshore Malaysia has become a serious issue when it reaches a limit that breaches a well’s integrity pressure envelope. According to the outlined criteria in the Operator Well Risk Management 3.0 (WRM), the operator will perform lubrication work using heavy brine. This action will temporarily reduce the annulus pressure but soon the annulus pressure will start to build up to the original threshold limit hence rendering lubrication using brine a failure, requiring operator to raise Management of Change (MOC) to keep well flowing with numerous action items needed to be in place while looking for the proper solution. Currently the usage of epoxy resin technology for leak repairs has become a regular practice in the industry. The idea of squeezing resin to seal off the micro-annulus leaks in well casing cemented annuli has become widely accepted in leak repairs. This integrity barrier entails placing and squeezing special epoxy resin into the annuli, filling up the void inside the sealed annuli and squeezing adequate volume of resin gels into the cement micro annuli. Placement of the resin gels can be difficult to execute due to the micro size path; therefore, high pressure is needed to be applied and maintained during pumping. Since 2016, the operator has had experiences in treating annulus leaks using lubrication methods and also the current deployment of epoxy resin in filling up voids and micro annulus which has enabled the operator to standardize the method to ensure high success. Surveillance logging data was utilised to determine the source of pressure and to estimate the maximum squeeze pressure to be applied during the treatment. Six wells were pilot tested and treated with this special epoxy resin squeeze, with four wells showing a complete seal while the other two wells have shown gradual pressure build up. This paper outlines the laboratory verification works on the resin mixtures to adapt to the field application in sealing the leaking annuli and describes all the six pilot tested wells that were carried out in one of offshore fields in Malaysia. The various considerations during the design of the rectification treatments as well as the experiences and lesson learnt during the execution phase are also highlighted.
Lee, Jin Ming (Petronas) | Bt Mohd Zain, Siti Nur Mahirah (Petronas) | AB Malek, Anas B. (Petronas) | B. Nordin, M. Haikal (Petronas) | Rahaman, Ammar Thaqif B. A. (Petronas) | Hermawan, Heru (Petronas) | B. Nasrudin, Khairul Anwar (Petronas)
Abstract X-1 well is one of the wells from project X, a field development project located offshore Peninsular Malaysia. The well has become the signature well for project X as it managed to achieve single digit (in million dollar) well cost, a rare occasion for offshore Malaysia development wells. Project X wells team has taken several initiatives and strategies to reduce well cost and ultimately achieving low cost well (LCW) status as defined by the company's wells department. Since year 2014, crude oil price has fallen from its heyday to as low as USD27 per barrel in 2015. Oil and gas (O&G) operators around the world have been struggling to make profit and fulfill their capital commitment. The company's wells department has since came out with criteria for LCW to be benchmarked by the company's projects. To be recognized as LCW, a well needs to be below USD 15 million with minimum depth of 1500 m and key performance indexes (KPIs) better than or equal to Malaysia Petroleum Management's (MPM) Drilling Minimum Standard without compromising operational safety, reserve development, well integrity and environmental aspects. In the quest to achieve LCW, project X wells team has engaged several strategies to ultimately reduce X-1 well cost by 40% from initial estimated. These strategies involved the optimization of critical areas such as well design & engineering, well planning and operations. After painstakingly planned and implemented above cost saving strategies within restricted time frame, project X wells team has successfully reduced 40% of initially estimated X-1 well cost. The reduction has proven that with focused planning and execution, coupled with full support from management especially with new contracting strategy, LCW is possible and able to help O&G operators to improve their bottom line. Low oil price environment has appeared to be the silver lining in O&G operators’ efforts to drive down cost as it appears to provide the opportunity for operators to re-evaluate their current contracts, planning and operation practices.
Abstract Located offshore East Malaysia, S-C Field is considered a marginal oil field with first development in 2008. While it is a shallow marine with storm and wave influence setting, the reservoir sealing is provided by the unconformity and Major Fault in the west side and further split into three major sub-blocks namely North, Middle and South Block. Middle Block carries two third of total field production as it also carries 80% of total oil volume making it the biggest producing block in S-C field. The field separation into sub-block came as a surprise during the development drilling which has totally impacted the production strategy and oil recovery as the field is initially expected to be a single buried hill with two separate major oil accumulations. Sand discontinuity and multi-stacked nature of the reservoir proved to be major challenges during development drilling and production phase. Despite the successful drilling and production from most of the development wells, excessive sand production lurks as major threat to oil production and well life. Careful implementation of drawdown limit and sand count monitoring was implemented, nonetheless the oil recovery remained low and the need for additional drainage points was assessed to unleash the full field potential. This paper captured the case study on this marginal oil field redevelopment which has substantially revived its oil production and successfully overcame the production challenges despite the geological surprises, lesser in-place volume, unoptimised completion and forecasted lower recovery compared to initially prognosed. From the early identification of potential additional infill candidates, project acceleration and economic improvement, the post-production performance has indicated a huge transformation towards realising more oil incremental at reduced cost. Additionally, there were significant lessons learned on subsurface planning and project execution. These were then highlighted for way forwards plan for S-C field and S Cluster in general to further sustain production and extend the field life.
Abstract This paper highlights PETRONAS's journey and experience in the Underbalanced Drilling (UBD) fractured basement pilot project, a 2 wells campaign in the Malay Basin. An integrated UBD team, has set best in class performance, applying lessons learnt in the 1 well to the 2 well. Major highlights are the key learnings implemented, challenges turned to opportunities, overall project management, well delivery process, well assurance safety processes, achievements and future enhancements for UBD operation. The process started with a comprehensive UBD Fractured Basement Pilot Project Feasibility study, assisted by risks assessment process which turned into a full engineering and execution plan. Well planning, well constructions and execution of this project will be highlighted. Relevant operational excellence process in PETRONAS such as DWOP, AAR, HAZID, and HAZOP has contributed to excellence in HSE and well delivery performance. Internal assurance process including Wells Peer Review and COP has facilitated a safe and successful project delivery. A multidiscipline and integrated wider scale project execution successfully yielded a noticeable performance improvement in the 2 well in comparison to the 1 well. For a back to back UBD well, the key learnings have been immediately brought forward and implemented in the 2 UBD well. Results were apparent and can be demonstrated by the well KPI performance and benchmarking against other operators in Malaysia within the same class. This UBD pilot project demonstrated the project feasibility to drill a challenging fractured basement using UBD technique, which can be further enhanced and replicated to a similarly suitable projects. Overall, the 2 well was completed 27 days ahead the planned days, with significant cost saving and total NPT of only 4.72%; while managing to drill with additional scope as requested by subsurface. This campaign provided a basic foundation to institutionalize UBD capability and also will open up a new chapter in PETRONAS's involvement in the whole process starting from well planning & engineering, well construction, and post mortem for UBD specific projects in the future. This template will be used, replicated and improvised to suit future UBD drilling campaign particularly in PETRONAS' operations. In line with the dynamism of this Company, and frequent approach for creative & non-conventional technology implementation, it has kept PETRONAS abreast with a niche and most advanced industrial practices for a better & more effective natural resources exploration supporting the ability to maintain the supply of global non-renewable energy demand.
Elliott, Christopher (Petronas Carigali Sdn. Bhd.) | Feroze, Mohd Imran (Petronas Carigali SB) | Ahmad Mahdzan, A.A. (Petronas Carigali) | Tirungnanasambandan, Saradah (Petronas Carigali SB) | Sulaiman, M. Zarkashi (Petronas Carigali SB) | Mohammad, Mahzan (Lundin Malaysia Ltd.) | Hakim, Mulyanto (Total E&P USA, Inc.) | Omar, M. Afiefe (Petronas Carigali SB) | Abdul Aziz, Khairil Faiz (Halliburton) | Paramavathar, Sanggeetha (Halliburton Energy Services Group)
Abstract The demand for high capacity production in deep wells has increased interest inthe monobore concept, and thus, when an anticipated gas shortage was expectedin East Malaysia, this concept was considered as a possible strategy for afield in Malaysia which consists of a 3-well development. The targeted area, located approximately 200 km offshore from Bintulu, is expected to deliver100mmscf/day of gas to the Malaysian Liquified Natural Gas (MLNG) plants atBintulu, East Malaysia. New technology such as a tubing hanger profile, fluid-loss device, and glassreinforced epoxy (GRE) completion for large-bore wells and their firstapplication in this country will be presented along with the well requirements, work-over operations, and the innovative solution design developed. Details regarding the completion design, prior development, pre-job planning, asystem-integration test (SIT), operational challenges, and post-job discussionsconcerning the successful completion of these wells will be discussed, as thistype of completion was a first for Malaysia. The findings from the extensive development of the best solution for operationsand the challenges of the project cost objectives will be used to providelessons and improvements for future applications. Introduction The field developments consist of 10 new fields that will be developed in twophases. The first phase consists of 3 of the fields. The second phase consistsof 7 wells in each field, and these will be completed two to three years afterthe first field campaign. The second phase completion design will be based onthe design review and the lessons learned from the initial development. In each field, the first phase will be developed using 3 separate techniquesthat have been identified for each field. The wells have been chosen to bedeveloped as single monobore completions, whereas the other two fields will bedeveloped as openhole sand-control completions and subsea completions. Eachtechnique was chosen to be part of the Petronas long-term vision to train thelocal project team with new technologies and prepare them with basic guidelinesfor the second phase field development. Although all of these completiontechniques have been installed in other regions by other major oil operators, they were new concepts for the project team, and therefore, would provide newcompletion experience.