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ExxonMobil is reluctant to join other big oil companies writing down the value of their reserves. It could chop its reserves by 20%, but it has not made a final decision. Its reward for years of struggling to adapt to low prices and weak demand for its oil and gas has been an epic crash. Canadians selling change say it is time to consider possibilities that seemed inconceivable in the past. So many unprecedented changes have occurred in the Canadian oil business that it is impossible to compare the current downturn to anything seen before.
Before the giant Johan Sverdrup field had produced even one barrel of oil, operator Equinor and its license partners set a recovery ambition of greater than 70% for the field. Add Denbury Resources to the list of oil companies filing for bankruptcy protection with a plan that may make for a quick trip through the debt-reduction process. What the industry needs at this stage is a willingness to work together, share best practices, conduct innovative research, and focus on disruptive technologies that lower cost of capture and make our operations more sustainable. The complete paper presents a large-scale work flow designed to take a vast amount of data into consideration. The work flow can be scaled for projects of any size, depending on the data available.
Winning innovators focused on environment, safety, and operational efficiency. Dugong could become a new North Sea production hub says offshore explorer Neptune Energy upon its latest discovery. Despite the global downturn, the long-term transition to net zero presents a major opportunity to create new multibillion industries based around the North Sea. Cross-sector collaboration and major state/private sector intervention, together with strong leadership, will be key. Nearly everything’s on the table as companies aim to shore up portfolios by curtailing investments and dumping low-priority assets.
This page pulls together technology-focused articles from various departments within JPT. Before the giant Johan Sverdrup field had produced even one barrel of oil, operator Equinor and its license partners set a recovery ambition of greater than 70% for the field. The complete paper describes the development of the “digital field worker” at Johan Sverdrup, an initiative that has changed the approach toward not only construction and completion but also operations. The complete paper discusses a floating wind-turbine solution that is particularly cost-competitive for deepwater locations and that can unlock the possibility of deploying large wind-powered generators far from the coastline in deep water. The complete paper is a comprehensive discussion of the development and deployment of the tension leg platform (TLP), one of the four major platform types that also include floating production, storage, and offloading (FPSO) vessels; semisubmersible floating production systems; and spar ...
Add Denbury Resources to the list of oil companies filing for bankruptcy protection with a plan that may make for a quick trip through the debt-reduction process. What the industry needs at this stage is a willingness to work together, share best practices, conduct innovative research, and focus on disruptive technologies that lower cost of capture and make our operations more sustainable. The complete paper presents a large-scale work flow designed to take a vast amount of data into consideration. The work flow can be scaled for projects of any size, depending on the data available. Denbury Resources needs enhanced debt reduction.
Operators celebrate first major deepwater project sanctioned since the early-2020 oil crash. Greg Leveille said he is optimistic that the shale sector will be able to bounce back from its second downturn in 5 years. The trick this time, he says, will be not just investing in new digital technologies but putting them to work. Phase 1 is expected to be operational in 2024. Leaders of Rystad Energy went online recently to talk about the effects of the coronavirus pandemic on the oil and gas industry, and the prognosis isn’t good.
This page pulls together technology-focused articles from various departments within JPT. The complete paper presents a technical discussion of a new microsampling technique for LWD and a corresponding wellsite technique to provide compositional interpretation, contamination assessment, reservoir-fluid compositional grading, and reservoir compartmentalization assessment. The complete paper presents a solution that assesses tight matrices and natural fractures at a level not previously achieved. At the tight-matrix level, advanced nuclear spectroscopy is carried out with a new pulsed-neutron device that achieves simultaneous time- and energy-domain measurements. The paper describes options for hydrate and integrity management and the required modifications to both subsea and topside facilities to enable an operational philosophy change. The traditional subsea tieback model is evolving, supported by advances in flow assurance that allow tiebacks over much longer distances and by the introduction of new technologies that increase overall cost effectiveness. International SOS has led medical services operations on offshore installations globally and has managed clinical cases in which patients presented with signs and symptoms of known infectious illnesses. The complete paper describes a service company’s approach to the development and application of technology and innovative solutions to improve driving performance on the basis of extensive data analysis. In 2015, the world’s first subsea multiphase gas compression system was installed offshore Norway. The system comprises two-off 5-MW machines configurable for serial or parallel compression. This system has now gained considerable and valuable operational experience.
Smalley, P. Craig (Imperial College London) | Muggeridge, Ann H. (Imperial College London) | Amundrud, Sølvi S. (Norwegian Petroleum Directorate) | Dalland, Mariann (Norwegian Petroleum Directorate) | Helvig, Ole S. (Norwegian Petroleum Directorate) | Høgnesen, Eli J. (Norwegian Petroleum Directorate) | Valvatne, Per (Norwegian Petroleum Directorate) | Østhus, Arvid (Norwegian Petroleum Directorate)
We present a novel advanced EOR screening approach, adding to an existing technical screening toolkit powerful new practical discriminators based on: (1) Operational complexity of converting existing offshore fields to new EOR processes; (2) Environmental acceptability of each EOR process, given current field configuration; (3) Commercial attractiveness and competitiveness. We apply the new approach to 14 EOR processes across 85 reservoirs from 46 oilfields and discoveries on the offshore Norwegian Continental Shelf (NCS). When the operational, environmental and economic thresholds were included, 45% of the technical opportunities were screened out, and the overall potential recovery increment was 280 MSm 3 (million standard cubic metres), the top processes being HC miscible, low salinity/polymer, low salinity, CO 2 miscible, gels. Excluding environmental factors (i.e., assuming environmental issues could be solved by new technologies), the increment is 340 MSm 3, indicating a 60 MSm 3 prize for research into environmentally benign EOR methods. The economic thresholds used here were intentionally set low enough to eliminate only severely commercially challenged opportunities; using higher commercially competitive thresholds would reduce the overall volumes by a further 40 MSm 3 . The extension of EOR screening to include operational, environmental and economic criteria is not intended as a substitute for in-depth studies of these factors, but it should help stakeholders make earlier and better-informed decisions about selection of individual EOR opportunities for deeper study, leading to piloting and eventual field-scale deployment. Revealing the sensitivity of each EOR process to operational, environmental and economic factors will also help focus R&D onto the practical, as well as technical, barriers to EOR implementation.
In the past decade, the number of polymer injection projects has greatly increased worldwide, with more and more full field implementations. More recently, the focus has shifted toward the deployment of such technologies offshore which presents very specific constraints in terms of facilities, logistics and produced water treatment.
One restraint is related to the surface facilities and the footprint available to install the required equipment. This can have a great impact on the choice of the chemical form; two forms are usually considered (powder or emulsion) which dictate the type of equipment necessary and the complexity of the injection process.
Other factors come into play when choosing the product form, including weather conditions, available storage, logistics and the existing infrastructure. Many projects are being constrained by the presence of subsea chokes, which can degrade the polymer solution and compromise the economics if not dealt with adequately.
In this paper we will review the existing projects and discuss the offshore deployment philosophies for polymer injection. Then, the focus will be on brown fields and the differences between polymer emulsion and powder forms and how both can be processed in the field. Specific highlights will be on polymer design and selection, equipment and logistics for a real field case.
Recent developments will be presented in relation to viscosity preservation during injection even in the presence of subsea chokes. Different approaches will be proposed including the deployment of non-degrading chokes or the use of Delayed Viscosity Polymer.