The first horizontal oil well was drilled through an anticline structure in the Block-7E of East Flank, S-field, penetrating three production sands Sand I, Sand II and Sand III. Based on a comprehensive pre-drill study through steady-state and 3D dynamic time lapse simulation, Inflow Control Device (ICD) with integral sleeve (on/off function) attached to the ICD's joint is the optimum development of the fault block that maximizes zonal control for contrasting water encroachments. Due to the unconsolidated nature of the target reservoir, this well is designed for Open-Hole Gravel Pack (OHGP) with specialty 3D filtration screen to manage sanding issue. This paper highlights 2-in-1 application of ICD with enabled zonal shut-off sleeves and the OHGP completions with external screen. A pre-drilled ICD dynamic modeling is constructed to evaluate the well performance with ICD configuration. The design criteria for an optimum ICD design configuration is based on number of compartments and size, packer placement, ICD nozzle sizes and numbers. This dynamic single well model was used to justify the technology value which resulted in production improvement (maximizing oil and minimizing/delaying water). However, during the drilling of this well, the pre-drilled model is then updated in real time with the input of actual petrophysical data from Logging While Drilling (LWD) measurements along the OH section. Actual well trajectory and structure adjustment encountered while drilling were also co-utilized to determine the final optimum ICD design for the field run-in-hole (RIH) completion. Target fault block in S-Field East Flank requires optimum development strategy for its economic viability (Kumaran, P. N et al. 2017). Only one open-sea discovery well proved the oil bearing sands to-date, but a lot of uncertainties remains: geological structure, fluid contacts, fluid characterization, existence and nature of an aquifer, etc. Hence, all these uncertainties are incorporated in the ICD optimization through sensitivity analysis and uncertainty range estimation. Oil production improvement with water reduction while delaying water encroachment are key in the optimization of the ICD design, which is achieved by evaluating the impact of ICD's influx balancing throughout the horizontal section. Study shows that water encroachment is effectively controlled with 9 compartmentalization zones along the horizontal section, each one separated using oil swellable packer. After 7 months of stable flow, well test is showing zero-water and zero-sanding to surface with well controlled production rate that can produce more if required. This is the testimonial of the deployment success from its initial conceptual design to its ultimate completion.
A new Oil Country Tubular Goods (OCTG) Corrosion Resistant Material (CRA) 17-Chrome (17CR) was introduced in late 2011. The corrosion resistance performance of such material was claimed to be comparable to a higher grade material of duplex stainless steel 22-Chrome (22CR) under a given aggressive corrosion environment. In addition to that, 17CR was expected to be significantly competitive and commands shorter delivery lead time compared to 22CR as it does not require cold-drawing process to achieve the required high yield strength. PCSB had evaluated this new material for one of its massive LNG development projects through a series of qualification testing. These LNG carbonate fields were highly corrosive with CO2 and H2S content up to 22 mol% and 140ppm respectively. Maximum bottom hole temperature anticipated was more than 180 degrees Celsius. Material selection for production tubing was therefore of paramount importance in such severe well condition to ensure that long term well integrity was not compromised with this newly developed material. Through the establishment of a multidisciplinary team, PCSB had established a set of rigorous qualification test procedure, fully aligned with industry standards to ensure that the identified risks were mitigated from both material and connection perspectives. This paper will describe the systematic approach that was used to evaluate the reliability of the new material with a premium connection under the defined worst case conditions; discuss the corresponding results which led to significant cost savings for the mentioned project.
Objectives/Scope Moving to digitalization era in the current low oil price environment, paradigm shift is really crucial in managing brownfield development and production. The challenge is to select the best technology to harvest the optimum production from the field but at the same time reduce potential capital and operating expenditure. Methods, Procedures, Process The paper highlights the technology evaluation of Digital Intelligent Artificial Lift (DIAL) system. This includes it's working principles, candidates screening, risk mitigation plan as well as technology success criteria developed specifically for the technology. DIAL system is an in-well gas lift system that can overcome the well design and operational limitations of existing side pocket mandrels and valves. DIAL enables a better gas lift well design as well as able to interconnect downhole and surface monitoring & control in real-time. It provides opportunity for automation, better subsurface and surface integration as well as minimizing well intervention requirement. Based on the promising technology evaluation, one pilot well was identified by the team at DL field. The well was part of DL drilling campaign executed in Q2 2018. Details of the well design & scope, as well as gas lift design for the well will be shared. Commercial comparison was demonstrated between conventional side pocket mandrel system and the DIAL system. Results, Observations, Conclusions The case study at DL field will be discussed in details, starts from their wells’ design, technology deployment strategy, installation, production test result as well as lessons learnt during installation and operationalization of the system. Moving forward from the pilot application, root cause failure analysis was done, lessons learnt were identified, design improvements were proposed and continuous monitoring of the system will be done, according to the success criteria outlined. Potential replication candidates have also been identified by the team with at least 10 promising potential candidates to be installed within the next 2 years. Novel/Additive Information The technology deployment was the result of collaborative works between PETRONAS, Silverwell Energy and Neural Oilfield Service.
PETRONAS completed Well H16 in BS field, East Malaysia with a Digital Intelligent Artificial Lift (DIAL) – an improvement to the current applied gas lift system in the field for production optimization system. This DIAL installation represents the first ever successful installation of the technology in an Offshore oil well for Dual String production. This paper provides the details of the installation planning, designing stages, operational process, well unloading and production undertaken to achieve this milestone. DIAL is a unique technology that enhances the efficiency of gas lift production. Downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention which will be challenging in high deviation well (more than 60-degree deviation). With remotely operated, non-pressure dependent multi-valve units, the technology removes the challenges normally associated with gas-injected production operation in a dual completion well i.e., gas robbing and multi-pointing. DIAL introduces a paradigm shift in design, installation and operation of gas lifted wells. This paper will briefly highlight the justifications of this digital technology in comparison with conventional gas lift techniques. It will consider value added from the design stage, through installation operations, to production optimization. Digitization and automation have become the new concepts in managing the operations in order to boost efficiency that reflected in long-term cost savings especially in Operating Expenditure (OPEX). This paper focusses on a well completed in November 2020, the fourth well to be installed with the DIAL technology across PETRONAS Assets. The authors will provide details of the well strategy, installation process and production phases: system design, pre-job preparations, improvements implementation, run in hole and surface hook-up. The results of well unloading while utilizing the DIAL system to start up the well and lifting the completion brine will be explained in detail in this paper. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits. Despite the additional operational & planning complications due to COVID-19 restrictions, the well was completed with zero Non-Productive Time (NPT) and Loss Time Injury (LTI). Once brought online, this DIAL-assisted production well can be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS’ upstream digitization strategic vision.
PETRONAS completed well H-X on B field in Malaysia with a Digital Intelligent Artificial Lift (DIAL) gas lift production optimization system. This DIAL installation represents the first ever successful installation of the technology in an Offshore well for Dual String production. This paper provides complete details of the installation planning and operational process undertaken to achieve this milestone. DIAL is a unique technology that enhances the efficiency of gas lift production via downhole monitoring of production parameters informs remote surface-controlled adjustment of gas lift valves. This enables automation of production optimization removing the need for well intervention. This paper focusses on a well completed in November 2020, the fourth well to be installed with the DIAL technology across PETRONAS Assets. The authors will provide details of the well and the installation phases: system design, pre-job preparations, improvements implementation, run in hole and surface hook-up. For each phase, challenges encountered, and lessons learned will be listed together with observed benefits. The DIAL system introduces a paradigm shift in design, installation and operation of gas lifted wells. This paper will briefly highlight the justifications of this digital technology in comparison with conventional gas lift techniques. It will consider the value added from the design stage, through installation operations, to production optimization. This successful installation confirms the ability to implement the DIAL technology in a challenging dual string completion design to enable deeper injection while avoiding interventions on a well with a greater than 60-degree deviation. With remotely operated, non-pressure dependent multi-valve in-well gas lift units, the technology removes the challenges normally associated with gas-injected production operation in a dual completion well – gas robbing and multi-pointing. Despite the additional operational & planning complications due to COVID-19 restrictions, the well was completed with zero NPT and LTI. Once brought online, this DIAL-assisted production well will be remotely monitored and controlled ensuring continuous production optimization, part of PETRONAS' upstream digitization strategic vision.
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