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Clean-up and well start-up operations are often considered as routine operations. This paper provides insights on the proper planning processes to manage several potential contingencies during the initial flow of new wells in deep water environments. Examples of ill-planned operations quantify the downtime, reservoir damage and permanent productivity impairments. A review of the last 25 years of operations in deep water in various regions from the Gulf of Mexico, Brazil, Angola, East African, India, and Black Sea has led to a significant enhancement of the planning processes and execution techniques of initiating and displacing completion fluids out of the well bores. A weighed ranking of the individual causes of operational unconformities provides a prioritization of the necessary contingency plans that need to be addressed. They rank from MetOcean challenges (wind, heave, rain) to human induced activities or to well, reservoir or fluids "surprises". The key to the success of these operations lies mainly in the early determination of the mitigation's procedures. Unplanned shut-in during the early part of the clean-up (less than three hours) can lead to significant back flow of unwanted fluids to the formation and potential damage to the near well bore zone. The initial step of the process involves the ranking of the potential disruption that could occur in the specific operating area/fluid/geology settings. Next, the proposed methodology involves the systematic utilization of transient well bore models coupled with a near well bore model to simulate the various scenarios that may affect the flow. Sensitivities on parameters uncertainties or operational flexibility enable the determination of the worst-likely case scenario and for each of these (or combinations of), a workaround / contingency solution is virtually tested and verified. The cost/benefits of each contingency plan are evaluated and mapped in a traditional risk/frequency matrix. As a support to the well clean-up/start-up, an expected pressure / temperature / rate history is provided with dynamically set high and low alarm levels to enhance the governance of any operational unconformities. Real time monitoring of downhole and surface information allows the confirmation of the status of the clean-up/flowback at all time, and reduces the number of potential contingencies as the well is getting more and more cleaned-up. The paper provides a novel approach to define the global efficiency of clean-up and allows a computation of the environmental footprint of the operation and its contribution in terms of carbon intensity. Wells have been cleaned-up since the beginning of the petroleum industry.
Clean-up and well start-up operations are often considered as routine operations. This paper provides insights on the proper planning processes to manage several potential contingencies during the initial flow of new wells in deep water environments. Examples of ill-planned operations quantify the downtime, reservoir damage and permanent productivity impairments. A review of the last 25 years of operations in deep water in various regions from the Gulf of Mexico, Brazil, Angola, East African, India, and Black Sea has led to a significant enhancement of the planning processes and execution techniques of initiating and displacing completion fluids out of the well bores. A weighed ranking of the individual causes of operational unconformities provides a prioritization of the necessary contingency plans that need to be addressed. They rank from MetOcean challenges (wind, heave, rain) to human induced activities or to well, reservoir or fluids "surprises". The key to the success of these operations lies mainly in the early determination of the mitigation's procedures. Unplanned shut-in during the early part of the clean-up (less than three hours) can lead to significant back flow of unwanted fluids to the formation and potential damage to the near well bore zone. The initial step of the process involves the ranking of the potential disruption that could occur in the specific operating area/fluid/geology settings. Next, the proposed methodology involves the systematic utilization of transient well bore models coupled with a near well bore model to simulate the various scenarios that may affect the flow. Sensitivities on parameters uncertainties or operational flexibility enable the determination of the worst-likely case scenario and for each of these (or combinations of), a workaround / contingency solution is virtually tested and verified. The cost/benefits of each contingency plan are evaluated and mapped in a traditional risk/frequency matrix. As a support to the well clean-up/start-up, an expected pressure / temperature / rate history is provided with dynamically set high and low alarm levels to enhance the governance of any operational unconformities. Real time monitoring of downhole and surface information allows the confirmation of the status of the clean-up/flowback at all time, and reduces the number of potential contingencies as the well is getting more and more cleaned-up. The paper provides a novel approach to define the global efficiency of clean-up and allows a computation of the environmental footprint of the operation and its contribution in terms of carbon intensity. Wells have been cleaned-up since the beginning of the petroleum industry.
An important aspect of well test and well clean-up operations is the need to produce and responsibly manage the hydrocarbons, typically through flaring, which is potentially an environmental concern. This challenge has received significant attention over the past few decades and remains a major concern today, especially in offshore environments, considering rising requirements for safe disposal of large volumes of crude and gas as well as completion fluids and possibly formation water produced. Despite multiple alternative fluid disposal methods available today, in some cases, conventional hydrocarbon flaring may still be an optimum, cost-effective solution for a short duration of welltest or well clean-up operations. The high-efficiency burners and flare tips used today have proven their efficiency over the years; however, due to the dynamic nature of the well test operations, fast wind direction changes, variation of fluid types and properties, and the inefficiency of the fluid separation process, the actual operational efficiency often can be compromised increasing the risk of health, safety, and environment (HSE) incidents. These incidents can be prevented by a continuous dynamic flare monitoring system. The inefficiency of the fluid disposal process can significantly constrain the operations, limiting achievable objectives and increasing the risk of HSE incidents. The combustion performance efficiency of modern high-efficiency burners used today has been practically proven over the last several decades and well studied and can now be modelled for operating conditions and create an operating burner envelope by using proprietary flare monitoring software. This software can also be used to estimate the required number of air compressors prior to the test to achieve high operating efficiency. Many factors influence burning and flaring efficiencies, such as the composition of production fluid, wind speed, and wind direction; these affect the requirements of air supply and must be monitored for efficient flaring. Integration of the software used for determining the operating envelope and dynamic flare monitoring and surveillance with new-generation data acquisition software acquiring information from additional sensors and cameras pointed on the flare and using AI algorithms enables the evaluation and adjustment of the burner and flare efficiencies in real time according to actual operating conditions. Proprietary algorithms used by the software can estimate the environmental emission of CO2, CH4, and CO2e in real time during the well test operations. This paper describes an innovative platform that is based on the unique combination of hardware and software and provides an integrated solution for dynamic flare monitoring and emission reporting during well test operations. The paper also summarises the results and lessons learned from the application of the dynamic flare monitoring system during multiple welltest and well clean-up operations performed offshore and onshore.
Today many exploration, appraisal, and development well test operations are performed in new frontiers, remote locations, deepwater offshore environments, and complex gas-bearing reservoirs. Deepwater welltest and well cleanup operations are presenting unique challenges related to flow assurance aspects that are beyond the standard welltest playbook. Several failures and operational issues related to flow assurance such as the plugging of pipelines and/or tubing by wax or hydrates have hindered the interpretability of data, compromised well test objectives, significantly increased the total costs, or led to serious health safety and environmental (HSE) incidents. Several past experiences have shown that it is nearly impossible to perform a proper deepwater well test with achieving well test objectives without an appropriate test design, equipment selection and operations planning. The assessment and mitigation actions to reduce the risk of hydrate formation are of paramount importance in such welltest design activities. Hydrate formation is one of the most common flow assurance issues during the well test and well cleanup operations in gas and gas-condensate reservoirs, particularly in deep-water offshore environments. Low water column temperature in deep water along the marine riser can cool down the produced fluids considerably. This in turn can trigger hydrate formation introducing significant challenges to the operations while increasing the risk of HSE incidents and therefore compromising the welltest objectives. Well tests and well clean-ups are complex operations performed offshore today that involve multiple expertise across different domains and services including temporary surface well test package, landing string, and drill stem test (DST) string with specialized downhole tools and components or permanent completion. Therefore, the risk assessment of hydrate formation and plan of mitigation actions must be performed in line with the detailed welltest operation sequences and technical capabilities of the equipment used offshore. Today there are no definitive practical workflows available that would guide operators through the process of planning deepwater well test operations effectively with a detailed assessment of the risk of hydrate formation and mitigation plan. During the course of past three years, over twenty-five gas well tests were successfully completed in deepwater and ultra-deepwater environments around the globe. This success is mainly driven by the application of hydrate studies performed with new-generation transient multiphase wellbore flow simulation software. Hydrate studies coupled with fine-scale reservoir models for well test design, enable the evaluation of hydrate formation risks and help operators develop mitigation actions. The selection of an appropriate hydrate inhibitor and optimization of the chemical injection system is essential to achieve the required chemical injection capabilities to prevent hydrate formation. Despite all the mitigation actions against hydrate formation, our experience has shown that rigorous monitoring and quick reaction to early detection of hydrate formation was instrumental in preventing several substantial problems. This paper describes an innovative approach and provides practical recommendations that can be used to assess the risk of hydrate formation and develop mitigation actions during the design stage of well tests. Besides, this paper highlights the results and lessons learned from the multiple welltest operations performed in recent years.
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