Well testing provides useful data for reservoir characterization during various stages of field life, from exploration, development to production. The key information that are typically can be obtained are, information on reservoir properties, deliverability, and pressure data. However, if the data acquisition during the well testing is compromised it can also lead to incorrect data and could lead to a wrong understanding of the reservoir and could results in sub-optimal field development. Therefore, it is important to emphasize on the quality of the data being acquired. This paper captures the experiences gained for a high-pressure-high-temperature (HPHT) exploration well DST where data acquisition was compromised in the 1st well drilled in the structure. A combination of temperature transient effect and tubing movement in the well during shut in resulted in data quality which can't be interpreted with confidence. The lessons learnt from the same was captured and addressed successfully in the subsequent well which enabled quality data acquisition. The objective of this paper is to share the challenges and mitigation strategies for a HPHT DST with the help of two DST operation where the challenges resulted in less-than-optimum data quality and the one where they were mitigated. The range of challenges came from planning, to gauge placement, to identify potential problems early, and even having proper contingency plans to cater for unplanned events. The paper also deals with some of the best practices which can help with any DST program. Key examples are pre-job modeling, accurate temperature measurement and modeling, real-time data acquisition, and a special focus on sampling as a part of a successful DST program. Disclaimer All parameters cited in this paper are purposely made in ambiguous manner to maintain confidentiality of the data.
Strategic vision and long-term view of upstream development plan is one of the key directives entrusted to Malaysia Petroleum Management (MPM) to secure sustainable production for the nation. The Sarawak Area Development Planning (SK ADP) is one such critical study aimed at identifying the inventory of hydrocarbon resources, potential outlook on projects' commercial viability, as well as shaping the portfolio mix strategy to deliver the long-term business growth. This SK ADP study also keeps Petroliam Nasional Berhad (PETRONAS) well-positioned to steer Petroleum Arrangement Contractors (PACs) in developing and maximizing the full value of resources. This includes outlining opportunities to collaborate in project sequencing and cost optimization efforts. This paper illustrates the methodology, process workflow and key takeaways from the SK ADP study. The SK ADP study was conducted to establish a development blueprint based on overall available resources and projects' first hydrocarbon sequencing for the short-term and long-term development planning in the Sarawak region. The key objective of the study was to identify the most optimum and technically viable integrated development plans, whilst also incorporating the agreed commitments and existing limitations inclusive of technology application and replications. The process workflow consisted of identifying six focus areas to further enhance the Sarawak Portfolio, maximizing the assets' value and ultimately meeting overall supply and demand requirements. These focus areas act as guiding principles to mature the overall development plan for the area, relating to generating an inventory basket, facilities optimization, clustering strategy, technology evaluation, contaminant management and risk assessment. Cross-discipline integration plays a pivotal role in shaping the final roadmap for each of the focus areas coupled with holistic validation. With the SK ADP in place, it can function as a key reference document and kept updated with the latest developments to maintain PETRONAS' agility in the pursuit of both business sustainability and continuous growth in the region. Key deliverables from this ADP can be turned into actionable insights for field implementation and help boost overall resource management in the region for long-term production delivery. This paper presents the best practices adopted for region level development planning in alignment with strategic vision for business growth.
Formation evaluation quality and cost efficiency are crucial in ultra-deepwater reservoir evaluation. Reservoir properties such as fluid composition, formation pressure, and sand producibility are critical in the exploration and appraisal phases of the well life and represent a key input to comprehensive production and reservoir engineering studies in the development phase. In addition, contaminants measurement including hydrogen sulfide (H2S), carbon dioxide (CO2), and mercury are important to address challenges in the planning and utilization of equipment and production facilities. This work is based on recent experience in South-East Asia that demonstrate prudent operatorship in maximizing value of information (VOI) from exploration drilling and evaluation. These formation testing is conducted to address the inherent uncertainty in reservoir characterization; particularly reservoir connectivity, producibility and presence of fluid's contaminants. Integrated measurements such as core data, log analysis, image logs, pressure data and fluid sampling were utilized to better characterized the reservoirs. Advanced sampling method was conducted to evaluate presence of contaminants including H2S, CO2, and mercury in the reservoir. Onsite lab services were utilized to handle and analyze the captured sample on location for better contaminants evaluation. In addition, formation mini-DST testing was also conducted to further understand interval rock and pressure properties at larger scale. The application of this proposed approach is critical to reduce the subsurface uncertainty especially on reservoir and fluid properties; which inputs are used to prudently design future field development facilities. Field data and workflow demonstrating formation evaluation techniques will be presented in this paper. Lesson learned and best practice will also be explained supported by lab analyses and results.
A two-way coupled 4D geomechanical simulation was conducted for two adjacent deep-water fields, located in South East Asia, to investigate the impact of reservoir compaction over the production profile of the reservoirs. The results of the 4D geomechanical model were also used to calculate the stress path, surface subsidence and evaluate the risks associated with reservoir compaction over the life of the fields. The 4D geomechanical model is a finite element (FE) model which was prepared from the structural geology model, surface seismic data, offset well geomechanical models and laboratory core tests. A Drucker-Prager/Cap material model was considered for the reservoir layers to calculate the compaction associated with pore collapse in high depletion zones. The 4D geomechanical model was two-way coupled with the reservoir dynamic simulation for predefined simulation steps over the life of the fields. The impact of the reservoir compaction on the reservoir performance was evaluated by comparing the results of the coupled reservoir dynamic simulation against the uncoupled simulation. The results indicated that the impact of reservoir compaction and pore collapse is negligible for the expected level of depletion. The importance of conducting field-scale 4D geomechanical studies to have a better understanding of the reservoir response over the life of the field is demonstrated in this paper. The obtained results are particularly important for decision making in the field development planning stage.
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