Production optimization for mature hydrocarbon fields face several challenging tasks, including the long process of decision making when inactive and low performing wells are being evaluated. The lack of necessary data integration and evaluation of valuable strings, wells, reservoirs can vary between departments making it challenging to bring a prompt and standardized solution. Therefore, an automated decision-making system has been developed with an open source software with capturing the logics and innovations of subject matter experts and managers. The current assessment is focusing on the automated re-evaluation of inactive strings, low performance wells as well as interventions candidates. Automation process initially starts with proper data analysis and integration. The advisory system consists of unique, fully automated workflows consuming several data sources. Essential part of data integration is to find the most relevant input parameters, which can be used by the optimization system, and provide recommendations to the end user. A hierarchical control system is added in parallel to data import, providing a long-term and easily sustainable data set for evaluation of wells, reservoirs and fields. This approach leads to a long-term and easily sustainable solution platform, which can be updated and extended whenever new resources are available. A scoring system is provided encountering the historcal and current performance of the existing entities like equipment, wells and reservoir including problems faced during operations. Individual well performance (including down-time, losses, status) is assessed by identifying contributing factors of production decline and failures using data-driven machine learning and fundamental analytic models.
Well double barrier envelope policy is a common industry practice and main philosophy of well integrity discipline. It is well-explained in well integrity related international standards: API RP90 (1 & 2), Norsok D10, ISO 16530 (1 & 2). It states that all wells with positive pressure at surface capable to flow naturally should have primary and secondary barrier envelope. Primary barrier envelope consists of well equipment which is continuously in direct contact with hydrocarbon and is pressurized. In case primary barrier failure (leak through the tubing, packer, or other completion equipment element), secondary barrier envelope is the one that holds the pressure and prevents further escalation of the incident outside of well boundaries. The content of this paper is related to such kind of wells that comply to the double barrier policy and are equipped with production packers. Conventional process of curing packer leak is to re-complete the well during rig intervention – the workover. During this process old completion is retrieved and new completion is installed. This operation can be repeated multiple times. Failure of any element of the primary barrier envelope results in the sustainable pressure in annulus "A" – SAP pressure. Such SAP wells is a violation from double well barrier policy and create a hazardous situation.
Developing mature reservoirs is associated with challenges and limitations both in surface and subsurface. In This paper we will tackle the area of developing reservoirs with Maximum Reservoir Contact (MRC) wells by introducing our experience in combining it with LEL completion and introduce initial results in unlocking the potential of our reservoir with reduced capital expenditure (CAPEX). Conventional wells with 3000 ft open hole length become more challenging as development of the field progresses and especially with drilling new wells. Congestion and anti-collision at surface and subsurface limitations arise more often let alone the cost, manpower and environmental issues. We are going to introduce Maximum reservoir contact MRC wells with extended open hole length of around 10,000 ft. which allow to maximize gain from this well while optimizing other parameters (well spacing, cost…etc.). Measurement of rate and pressure, pre and post acid stimulation controlled by LEL completion as well as comparison with conventional water injectors in the vicinity were performed before to evaluate the performance of the MRC well. It was confirmed that MRC well injectivity surpasses the conventional injectors with shorter open hole length in relatively tight areas of the reservoir which have low permeability especially if equipped with LEL completion. Initial results show Injectivity improvement compared with nearby water injectors plus additional gain in injectivity noticed after acid stimulation with the LEL completion. The MRC well performance after stimulation showed well head injection pressure decreased drastically after the acid stimulation with increased injected volumes of water. This shows that smart completion solutions well help to improve performance and optimize acid stimulation which highlights the importance of combining MRC with LEL to maximize gain and enhance performance to take the maximum benefit. Through our success with MRC well with LEL completion the community of petroleum engineering will be able to take decisions regarding implementing this method and technology to optimize their drilling which will have positive impact in cost, planning and environment.
Permit TL/2 in the Carnarvon Basin, Western Australia, presents several challenges for top hole drilling and casing running operations. Previous experience showed that drilling the 16" hole section and running 13-3/8" casing was typically a time consuming phase of the well due to fluid losses and tight hole conditions consequently requiring the use of Seawater to drill, back reaming, wiper trips and occasional spotting of pills.The initial solution delivered to the operator as an alternative method to get 13-3/8" casing to TD was to employ a casing drill bit to ream the casing to bottom whilst also delivering an improved drill-out time. This would be coupled with a sophisticated, unique, reliable and simply-operated top drive casing running system that was already installed on the rig. Pending a review of the service company capabilities, Total Depth Solution systems with cost & time savings analysis, the operator was certain that the application of a complete drilling with casing system (DwC TM ) would mitigate the known hole problems and yield a safe and more cost effective surface hole operation, reducing non-productive time (NPT) significantly.This paper fully reviews the problems that were traditionally encountered during conventional surface hole drilling and casing running operations; the decision making process that the operator followed prior to employing DwC TM technology along with the hazard mitigation & economic benefits realized through a one way trip to Total Depth of +/-1,000 m TVD RT; breaking to date the longest Weatherford 13-3/8" DwC TM interval globally by the service company & operator.
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