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Collaborating Authors
Bashir, Aamir
Abstract PETRONAS D Field, discovered in 1981, is a brownfield located offshore Terengganu, Malaysia in the West central part of Malay Basin. The field has been on production for over 30 years. It is an E-W trending anticline consisting of vertically stacked sandstone reservoirs segmented into several fault blocks, forming structural traps. The field has been producing primarily under a natural depletion drive supplemented by water and gas injection as an IOR strategy. Several development campaigns have been carried out in the past where additional infill wells were drilled to improve recovery. Agile FDP has demonstrated the potential to recover an additional >50MMSTB of oil. The key challenges to overcome were to 1) deliver the project in a tight timeframe which required comprehensive evaluation of infill proposals to ensure reserves attainability; 2) assess the risk in proposed infill wells in view of communication between fault blocks due to juxtaposition of stacked sands across fault planes 3) achieve a reasonable history-match in the presence of a large number of subsurface uncertainties and obtain a probabilistic forecast; 4) insufficient time to investigate full range of development scenarios due to the constraints of on-premises infrastructure. These challenges are addressed by the PETRONAS LiveFDP digital transformation program, through deployment of digital cloud technologies and solutions with scalable High-Performance Computing (HPC) environment. The cloud-based native and Petrotechnical applications enable remote work, ensure full data auditability in an integrated E&P cognitive environment, enable large-scale probabilistic studies, and streamline the automated integration from Reservoir Engineering workflows to Economics Studies. The agile FDP workflows, enabled by unlimited HPC power, accelerate the subsurface studies and facilitate evaluation of a broad spectrum of development scenarios in an accelerated manner. The agile Field Development Planning studies completed within two months using HPC cloud solutions and workflows compared to 1-year timeframe of using on-premises infrastructure. Utilizing cloud solutions and ensemble probabilistic approach, the team has: Achieved project milestone of delivering first-oil one week ahead of the committed date and saved US$5 Million. Project delivered within sanctioned P80 cost and avoided NPT during drilling campaign. Performed detailed investigation into the impact of pressure depletion due to communication with adjacent fault blocks and with nearby "S" field through aquifer. Improved recovery of 0.7MMstb (~US$50 million) by optimizing well location and IOR injection scheme which improved sweep and pressure maintenance in the primary reservoirs. Conducted probabilistic studies of 40 uncertainty parameters by running 250 cases per ensemble in 2 days and significantly improved history-match (over 90% matched quality). Safeguarded 11 MMstb reserves with total project investment of US$328 million and realized additional 350bopd (18% higher than what was pledged in the development plan).
- Asia > Malaysia (1.00)
- North America > United States > Texas > Terry County (0.40)
- North America > United States > Texas > Gaines County (0.40)
- Europe > United Kingdom > North Sea > Southern North Sea (0.40)
- Geology > Structural Geology > Fault (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.68)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Malaysia Government (0.45)
Integrated Approach for Proper Resource Assessment of a Challenging Over-Pressured Gas Condensate Reservoir: Case Study of Analytical and Numerical Modeling of a Central Luconia Carbonate Field
Hajizadeh Mobaraki, Alireza (PETRONAS) | Bashir, Aamir (PETRONAS) | Shen Sow, Chia (PETRONAS) | Deo Tewari, Raj (PETRONAS) | B M Zakei, Amran (PETRONAS)
Abstract Proper and reliable resource assessment of hydrocarbons in-place and recoverable volumes is one of the key factors in field development planning (FDP) and determines the commitments made to the host government for the reserves to be developed (RTBD). Many times, it is critical to update the resources and reserves of a producing asset through full field reviews (FFR) to gauge the production attainment and success of initial forecasts in FDP and also to locate any upside/locked-in potential. Often uncertainties in the field development are expected to reduce as the field produces, but in many cases the results show otherwise due to lack/ inaccuracy of data or existing reservoir complexities. This paper elaborates how an integrated approach utilizing analytical methods (material balance, pressure and rate transient analysis) combined to numerical reservoir simulation is used for accurate resource assessment of an over-pressured gas condensate reservoir that suffers from lack of geological and petrophysical data, faulty production data measurement system and complex fluid and pressure behavior. A comprehensive workflow comprising of different methodologies is used to harness the available geological, petrophysical, production and pressure data. Over-pressured and compressibility corrected gas material balance and pressure and rate transient analysis (RTA) are conducted using static and flowing data to encompass the existing uncertainties on resource numbers and generate low, base and high cases. The results of these methods are then successfully utilized to construct the dynamic reservoir model for evaluation of the upside and near field exploitation (NFE) potential. The results of the full field review lead to a 50% increase in the gas initially in-place compared to FDP volumes and a significant addition in the proven reserve. This increase in volumes was investigated through proactive surveillance for a period of time and was well supported by the reservoir and well performance. A novel approach to numerically model the over-pressured gas reservoirs is developed using a simple concept of compressibility modifications supported by production data history match and analogue core data. The results of the study greatly benefited the production sharing contract (PSC) and lead to production enhancement from the field through a proper debottlenecking project.
Rate Transient Analysis RTA and Its Application for Well Connectivity Analysis: An Integrated Production Driven Reservoir Characterization and a Case Study
Ataei, Abdolrahim (PETRONAS) | Motaei, Eghbal (PETRONAS) | Yazdi, Mohammad Ebrahim (PETRONAS) | Masoudi, Rahim (PETRONAS) | Bashir, Aamir (PETRONAS Carigali Sdn Bhd)
Abstract Rate Transient Analysis (RTA) has been used in gas reservoirs as a proven method for reserve estimation, well diagnostic and production performance evaluations. The authors have demonstrated several case studies showing the application of production analysis (PA) for reservoir characterization in gas and single phase oil reservoirs previously (Motaei, 2017, Ghanei and Ataei 2017, Ataei 2018). The adopted method for Integrated Production Analysis (IPA) works well in those case studies after combining the available data from RTA, PTA, or Material balance and basic reservoir engineering tools. The RTA found to be completing those is based on simple production data analysis using flowing data rather than limited shut in and less accurate ones. With benefit of continuous monitoring of FBHP using PDG, it is possible to evaluate the interferences and boundary in distance beside conventional reservoir properties like permeability and skin. These methods were found to be extremely powerful and popular particularly with the high resolution data from pressure downhole gauges (PDG). In this paper we have analyzed the available production data from a gas reservoir in offshore environment in South East Asia. It has been developed with five high PI wells and smart completion and monitored closely with PDG and other surveillance data to understand the contact movement during the production history. Due to the complexity of the field, different methods of production data analysis were used to understand the production performances. The recent advances in RTA allows us to apply the classical single well analysis method to a multiple well and multiple phase flow using Generalized Pseudo Pressure (GPP). The previously published workflow by the authors (Ghanei and Ataei, 2017) is used for this case study. We evaluate this technique for a multi well gas field with advancing aquifer. The connected volumes as estimated by single well analysis will be used for a group of wells which are communicating and have interference. We have also used a simple reservoir modelling approach to define scenarios which fit the production data and can be used for forecasting which can potentially save study teams time when deciding on the potential value and defining the targets of a major infill drilling project.
Unlocking Reservoir Potential through Rigorous Surveillance and Field Review Post FDP: Case Study on Central Luconia Carbonate Gas Field
Sow, Chia Shen (PETRONAS Carigali Sdn Bhd) | Bashir, Aamir (PETRONAS Carigali Sdn Bhd) | Chowdhury, Utpal (PETRONAS Carigali Sdn Bhd) | Hajizadeh, Alireza (PETRONAS Carigali Sdn Bhd) | Ridzuan, Ahmad Idriszuldin (PETRONAS Carigali Sdn Bhd)
Abstract For E&P upstream player, the most exciting oil and gas development project is to transform a commercial hydrocarbon resources into readiness for production to meet the company investment portfolio. It involves field development planning, design, technology, procurement, construction, drilling and start-up prior to handover to production operations. Most of the times, economic evaluation, assessment of risk and return on investiment (ROI) from the project are the key factors to determine the fate of the project during feasibility study and/or before the Final Investment Decision (FID) phase. Moreover the project cost, schedule, reserves to be developed and production profile are the key parameters to dictate the cash flow and net present value. The general practice is that once the project completed, the reservoir model will be updated with new findings and surprises observed during drilling phase and include in post drilling evaluation report. After this stage, the project team will be disbanded and most companies will be lacking a single point of accountability for delivering production as promised. Once all the requirements and expectation have been met, the project is considered to be successfully delivered. In this case study, the real time production and survelliance data were analysed. Although initial production did not meet the FDP delivery target due to project delays and subsea facilities downtime which causes production deferment, the stabilized production trends with time indicated a potential reserves gain by about 50%. In summary, the analysis shows the value of analyzing the production and surveillance data by a dedicated team to assess the current field performance compared with the forecast profile from FDP study. The deviation can be a triggering point for revision on the resources figures, future infill opportunities and may contribute to the future cluster development within the same PSC.
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
- Reservoir Description and Dynamics > Reserves Evaluation > Estimates of resource in place (0.94)