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This 2-day course is an introduction to the role and impact of flow assurance on field life from the exploration, development, and operation phases. The course will cover reservoir fluid sampling / lab analysis, fluid phase behaviour, thermal-hydraulic issues of multiphase flow, and managing hydrate, asphaltene, wax, emulsion and scale. For each topic, the course will cover laboratory testing methods, overview of the fluid and flow modelling, identifying flow assurance issues and methods to mitigate them, and finally, how they are implemented. The course will also cover systems integration issues impacting other engineering disciplines. A fast-emerging area is carbon capture and storage which will be broadly covered, where the course will address the thermophysical and transport properties of Carbon Capture Sequestration (CCS) fluids (with and without impurities) and the flow assurance of the CCS pipeline.
asia government, asphaltene, assurance engineer, Australia, climate change, Engineering, expertise, exploration, flow assurance, hydrate, malaysia government, operation, Petronas, project management, strategic planning and management, subsurface storage, tulsa usa, united states government, University, Upstream Oil & Gas
Country:
- North America > United States (0.19)
- Asia > Malaysia (0.19)
SPE Disciplines:
The Flow Assurance Technical Section presents this event detailing how subsea developments are continuing to escalate in quantity and complexity as the E&P companies ramp up exploration of deep water and ultra-deepwater reservoirs with complex formations in harsh environments. The challenges are exponentially increasing as we go not only deeper but also further into sea. Dr. Kondapi is going to give an overview on some significant flow assurance challenges and various state-of-the art flow assurance technologies. In his talk, he will summarize the current state of key technologies and areas for potential improvement which may have major impact on both production and cost effectiveness. This webinar is categorized under the Projects, Facilities, and Construction discipline.
Genre:
- Overview (0.76)
- Instructional Material > Course Syllabus & Notes (0.59)
- Instructional Material > Online (0.39)
SPE Disciplines: Facilities Design, Construction and Operation > Flow Assurance > Precipitates (paraffin, asphaltenes, etc.) (0.66)
Abstract Block H, located in 1,300 meters of water depth at offshore Sabah, consists of Rotan and Buluh fields. The subsea trees, jumpers, manifold, umbilicals, risers and flowlines were installed and tied-back to an FLNG facility. The objective of this project was to develop most practical and effective solutions to overcome flow assurance challenges owing to low seabed temperature and high-pressure gas to achieve 1 gas from the first deepwater gas field in Malaysia. A model was built in OLGA software with all field conditions to run simulations and predict process parameters at every critical point in subsea wells, risers and flowlines as well as topside facilities. Besides, all constraints from the subsea wells, jumpers, risers and flowlines all the way to topside inlet receiving facilities were carefully reviewed and optimized with an abundance of caution to determine the stepwise approach by utilizing the high-pressure gas from wells to remove around 1,000 m of pre-filled MEG fluid out of the flowline, called ‘DeMEG operation’ before feeding gas to LNG process operations. With 200-230 barg pressures from deepwater gas wells and 2-4°C temperature at seabed as well as pre-existing water content in saturated gas given by reservoir aquifer, this start-up operation would expect to be in the hydrate zone. One of the unavoidable potential consequences was a hydrate formation and could result in plugging of jumpers, risers or even flowlines. The DeMEG operation results indicated the lowest temperature at the downstream of the subsea choke was −23°C due to Joule-Thompson cooling during the cold start. One mitigation strategy was to inject a batch of MeOH at the subsea wellhead until the temperature is above the hydrate point. After the gas flowed along the flowlines, it would cool down to the seabed temperature during the steady state condition. Hence, additional mitigation was to continuously inject Mono Ethylene Glycol (MEG) as another thermodynamic hydrate inhibitor mixed with gas stream. The MEG affixed water molecules and thus deterred them from forming a cage around gas molecules to prevent hydrate formation. A multi-stage DeMEG operation was carefully planned to overcome liquid handling capacity at topside and eventually executed at offshore until the remaining MEG in the flowline was as low as reasonably practical to proceed with gas production from the field. With an excellent collaboration from the team and proper planning, the DeMEG solution together with hydrate mitigation strategy were proven to be effective and the commissioning operation was successfully completed as per the plan until the 1 gas was achieved on 6-Feb-21 and supplied to FLNG. The 1 LNG drop subsequently came in 7 days later. This field has increased production volume around 270MMSCFD, equivalent to 45,000 barrels of oil per day to PTTEP and JV partners.
asia government, Deepwater gas Field, FLNG, flow assurance, flow assurance challenge, flowline, international petroleum technology conference, iptc-22824-ea, jumper, kiertkul, malaysia government, MEG, operation, overcoming flow assurance challenge, pre-filled meg, sub-sea system, thailand government, topside, Upstream Oil & Gas, valve
Industry:
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.68)
- Government > Regional Government > Asia Government > Thailand Government (0.52)
Oilfield Places:
- Asia > Indonesia > Java > Central Java > Blora Regency > Asset 4 Area > Trembul Block > Trembul Field > Ngrayong Formation > P1 Well (0.99)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block H > Rotan Field (0.94)
- Asia > Malaysia > Sabah > South China Sea > Sabah Basin > Block H > Buluh Field (0.94)
A live discussion with experts in an interactive location to bring to the oil and gas community a topical conversation on mature field operations, the criticality of flow assurance – scale in particular.
Industry:
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.47)
SPE Disciplines: Management > Asset and Portfolio Management > Field development optimization and planning (0.40)
Given the important role production profiles play in key decision making and the inherent uncertainty and bias existing in the process of building them, it is essential that theQA/QC process is sufficient to test the robustness of the forecast range and ensure there is a shared understanding and buy-in of the assumptions behind it across the stakeholders involved in an asset. Getting other qualified professionals not directly involved in the development of this particular forecast to review inputs, methodology and outputs of the forecast. This is a powerful tool, particularly in mitigating the effects of human bias. Each reservoir and development is unique so there are likely to be different approaches that should all be considered. As has been mentioned throughout this document, it is essential to compare your forecast to the historical production of the field if it is already on production and appropriate analogues if it is not in production.
SPE Disciplines:
Technology:
- Information Technology > Modeling & Simulation (0.92)
- Information Technology > Communications > Collaboration (0.42)
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