According to the 2010-2011 annual statistical bulletin issued by the OPEC oil reserves in Venezuela reached 296.5 MMMBls, positioning the country with the biggest proven oil reserves worldwide. Most of these reserves are in the FPO (Orinoco Oil Belt) as part of the ambitious project PDVSA Magna Reserve.The produced oil in the FPO is 8-10° API, high viscosity and located in shallow reservoirs so horizontal type wells are constructed to increase well productivity. The artificial lift system of choice is predominantly progressing cavity pump (PCP).During the pumping operation conditions are generated that affect the performance and run life of the main elements of the pumps. T o manage and improve the run life a prudent field operator should implement specific methods to trace each pump component from delivery to the field until the final failure report is completed. This abstract describes the recommended steps, including; manufacturer quality assurance, installation documentation and completion diagram, operational data, and workover completion. The failure database should include all details: well information, bench test data, operating parameters such as torque, intake and discharge pressures, production data, operating days and accumulated revolutions, among others. At this point it is important to mention that this work will be specified only regarding the process of handling of pump failures without specifying actual statistical data that belongs to the joint venture Petropiar PDVSA (PDVSA 70% and Chevron 30%).This methodology allows clearly identifying the weak point in the chain of the process regarding this artificial lift method. The use of it has documented properly the history of pump field failures and also serves as the basis for the completion of a significant destructive and non-destructive analysis of failed pumps with the different suppliers.For the above and considering that only in the FPO are currently more than 3,000 wells with this system, it is necessary to manage a process to ensure the completion of the failure analysis of this equipment in a safe and technically reliable manner.
Including "smartness" in your field does not necessarily add additional expenditures. ADNOC Offshore piloted a new well completion design combining Interval Control Valves (ICVs) in the shallow reservoir and Inflow Control Devices (ICDs) in the deeper reservoir, both deployed in a water injector well for the first time in the company. The objectives were to improve reservoir management, reduce well construction complexity and achieve one of the main business targets of cost optimization. This paper covers the subsurface study, detailed well construction design, completion deployment, well intervention and overall well performance in commingled injection mode. A multi-disciplinary study was conducted based on updated reservoir data available after the first two years of production in a heterogeneous multi reservoir field. This study showed the possibility of replacing the upper horizontal drain by a deviated perforated section. The authors identified the need of completion compartmentalization to overcome challenges such as high reservoir heterogeneity and uneven pressure depletion enforced by non selective acid stimulation. As part of the evaluation, a simulation was performed to evaluate the expected injection performance across the four zones with different combinations of ICVs and ICDs in order to cater for different injection scenarios. As a result of the integrated analysis, a new well completion design was deployed to optimize a Dual Horizontal Water Injector into a Single Smart Completion with 3 Inflow Control Valves (ICVs) covering the upper perforated zones and 14 Inflow Control Devices (ICDs) with sliding sleeves across lower lateral reservoir. Cost savings and reduction of rig time was achieved with this new completion design demonstrating very pro-active participation from all involved teams, ADNOC Offshore and Service Companies. The requirements to complete high and low permeability zones in one single well can be successfully accomplished. Firstly, mitigation of early water breakthrough is achieved by incorporating surface water injection control in high permeable zones and secondly, the injection target for the low permeable reservoir is also delivered. Building on the successful results and captured lesson learnt, this new well completion design provided the capabilities to optimize the water injection plan while reducing costs. Therefore, the project has passed the trial phase and the team proposed its implementation.
As global energy market conditions demand more reliable energy sources, fields with lower productivity reservoirs struggle to provide cost-effective production options. Multilateral technology (MLT) has been used to improve per-well deliverability and economics, i.e., by increasing the drainage area with less surface footprint. The objective of this work is to review the state-of-the-art of selected completions to provide insights for adoption of MLT technologies including lessons learnt, experiences and some recommendations. Six globally selected demonstrative applications were reviewed to validate the technical assumptions for selecting a particular MLT concept. The first step was to review earlier applications in similar formations to identify the degree of success of these wells and to research possible better candidate reservoirs. Secondly, a screening tool analyzes specific reservoir production conditions where the application of MLT would be compelling. The research was focused on reservoirs with noticeable high-economic potential interest in the application of such technologies. We propose a workflow combining both technical and economic criteria to guide the selection of MLT vs single lateral wells, providing a cost-effective and lower risk decision support tool. We introduced a process to identify the MLT applicability window based on the Activation Index (AI) and the mother to Lateral cost ratio. Our proposed method is likely to be beneficial for operators which struggle to make smart decisions on MLT well concept selection. We show that MLT completions can reduce between 10 and 30% the D&C cost requirements while enhancing field development NPV in the range of 1-21%, and with the potential of promoting fields that were otherwise uneconomic. We discuss here the success factors to make this possible. In addition, one key advantage of MLT is the acceleration of production since multiple zones are available for production much earlier compared to the single zone wells. Furthermore, the implementation of MLT completions is enabling the recovery of reserves on fields where the surface space is constrained due to either a high number of wells or a geographic limitation or even a combination of both.
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