Add to Calendar2019-11-12 08:00:002019-11-13 00:00:00Europe/OsloReservoir & Production Management 2019Sola Strand hotell, Nordsjøvegen, Axel Lundsv. 27Norsk PetroleumsforeningReservoir & Production Management 2019_2019-11-12 08:00:00
12. to 13. Nov 2019
Reservoir & Production Management 2019
Reservoir & Production Management Conference
The Norwegian Petroleum Society is once again hosting its traditional two-day Reservoir & Production Management Conference in Stavanger.
The conference is a popular meeting and knowledge-sharing event for the Norwegian reservoir and production industry.
Our industry recently faced significant economic challenges and innovations in reservoir and production management emerged from these difficult times. This year’s conference will cover strategy and business-oriented topics illustrating how these innovations, together with a more favourable economic environment, will take us forward.
Field examples, updates on recent achievements, changes and new developments on the Norwegian Continental Shelf will be an important part of the conference, and invited speakers will also share some highlights from outside Norway.
Delegate profile range from reservoir engineers, petroleum engineers, geologists and geophysicists with the North Sea as a field of work. This conference will cover topics concerning reservoir and production, both on green and brown field.
We hope this event will enhance your knowledge and your business opportunities within Reservoir & Production management.
We look forward to seeing you at Sola this November!
Special Offer for Young Professionals:
Bring a colleague under 30 for half price! Participant no. 2 or more under the age of 30 from the same employer receives a 50% discount on the conference fee. Contact the project manager email@example.com for registration.
Chair: Vincent Kretz, ONE-Dyas Norge & Alexander Shadchnev, Schlumberger
Draugen Rejuvenation – the OKEA way
Håvard Morset, Okea
Taxation and extraction rates
Petter Osmundsen, University of Stavanger
When designing petroleum taxation, attention is on the sanctioning decision. The tax system should not make projects unprofitable. The presentation is about decisions that are not addressed. The tax system also impacts project design. Cheaper and less flexible development concepts, less pre-drilling and fewer wells lead to lower extraction rates
Digitalisation in Reservoir Management
Going Digital – change the industry
Bjørn Kvanvik, Petoro
The evolution of reservoir modeling on Johan Sverdrup
Per Olav Eide Svendsen, Equinor
While reservoir modeling plays an important role in subsurface digitalization, digitalization is also changing reservoir modeling. Tech and tools are important, but how we work, how we integrate and how we think is also changing. Keywords are ensemble-based methods, automation, Agile, Lean, transparency, T-shaping, web-apps, open source, APIs, a bit of chaos, some friction and lots of fun.
Digitalisation journey in reservoir management – from promise to performance
Alexander Shadchnev, Schlumberger
Digital technology promises solutions for the E&P industry, but we need to make them real – fast, scalable, and cost-efficient. No single organization or system has all the answers. We need to break down barriers to deliver the transformational change digital promises. Operators, service companies, developers, start-ups, tech giants – everyone has a part to play. The digital future is about openness and new partnerships, working together, in order to deliver superior return-on-investment, efficient exploration, capital efficient projects and profitable production in our industry.
Christian Rambech Dahl, Vår Energi & Kari Nordaas Kulkarni, Equinor
Using Machine Learning for Production Optimization and Chalk Influx Mitigation
Johan Hatleskog, Cognite
This presentation will showcase how Cognite used Machine Learning to develop and make available data-based recommendation tools and applications for Aker BP’s production staff to detect and mitigate chalk influx, enabling increased production efficiency. Leveraging tools for visual inspection, ML, and physics simulators Cognite and Aker BP can detect chalk influx events at Valhall wells in the early stages: Using labeled data to identify low- and high-risk operational regions and giving recommendations about mitigation actions when identifying ongoing events like choke back and adjust gas lift.
Brage Digital Twin
Peter Kronberger, Wintershall Dea
Digital transformation of existing processes using technologies such as big data, advanced data analytics, machine learning, automation and cloud computing will enable continuous performance improvements within the operational sphere. The application of the technology will link the physical and digital world, providing a digital model of physical assets and processes. It will represent the evergreen, wholly integrated digital asset model - from reservoir to export pipeline. The Brage operations team identified processes with the highest potential for digital transformations during an initial opportunity framing workshop. Based on business needs clear emphasis is in the areas of production & well performance optimization, live-data implementation and handling, as well as database integration and dashboarding.
IOR / EOR projects
Water Shut-Off with Polymer in the Alvheim Field
Kåre Langaas, Aker BP
A drilling-grade xanthan polymer was bullheaded in an Alvheim production well, causing reduced well productivity but also changed water cut trend. The field pilot, follow-up laboratory studies and integrated reservoir modelling point to a potential method for water shut-off and EOR for Alvheim and similar fields.
Extended Screening Tool for EOR on NCS
Sølvi Amundrud, Norwegian Petroleum Directorate
In 2017 NPD performed a technical screening of the EOR potential on the NCS. The technical potential is close to 700 MSm3, when 46 of NCS’ largest oil fields and discoveries are screened for 14 EOR methods. The screening study is now extended to include operational, environmental and economic criteria. The presentation shows the results of this extended screening.
OGA’s role in getting EOR projects realised on the UKCS
Panteha Ghahri, Oil & Gas Authority UK
This study look at the current state of UKCS EOR projects, OGA activities and collaboration with industry and universities. The OGA currently supports number of EOR joint industry projects (JIPs) and carrying a lab study work to screen low sal EOR for the number of UKCS fields. The results of the first screening test fluid-fluid are out and show a positive response.
Balder X, with 4D!
Alexandre Bertrand, Vår Energi
Vår Energi took over the operatorship of Balder and Ringhorne in 2017 and initiated a major redevelopment plan to maximize the area potential by extensive infill drilling, increasing processing capacity and extending field life. In 2018, a new seismic monitor survey was acquired to support this new development phase. Results from 4D processing show high repeatability and have been integrated at various stages of the redevelopment project: 4D history match, target de-risking through monitoring of fluid movements, detailed well planning.
Computational fluid dynamics (CFD) for well inflow modeling
Michael Byrne, Lloyd's Register
End Day 1
Conference Dinner at Sola Strand Hotel
Wednesday 13. November
Coffee and Registration
Challenging Reservoirs, Reservoir Learning and new technology
Chair: Anders Soltvedt, Norwegian Petroleum Directorate & Thom van der Heijden, Equinor
Keynote: A significant resource base providing great opportunities
Ingrid Sølvberg, Norwegian Petroleum Directorate
Valemon, the bewitched King? Who can break the spell?
Marte Ona Høistad, Equinor
Valemon is an HPHT field discovered in 1985, and the PDO was approved in 2011. At the time of the approval, five exploration wells were drilled in the area and were estimated to have proven 20% of the in-place volume. The 80 % of the resources not proven had a probability of discovery larger than 80%, with a large distribution in the in-place volumes and reserves. Today, 16 producers have been drilled; two of these were not completed due to water, and one did not reach the reservoir. The recovery factor, based on the expected PDO reserves/in-place volumes (oil equivalents) was 44% with 11 production wells. With the current 13 producing wells, the predicted recovery factor based on RNB2020 is 28% (oil equivalents). My presentation will focus on some of the main challenges we have had to understand the low recovery factor at Valemon.
The value of well testing
Søren Hegndal-Andersen, Lundin
Well testing has been an integral part of Lundin Norway’s exploration and appraisal strategy for many years. This presentation will illustrate the value and key role well testing has played in the appraisal of Lundin’s discoveries, including the Edvard Grieg and Johan Sverdrup fields.
Ivar Aasen Drainage Strategy and Status after 3 years of Production
Kjell Christoffersen, AkerBP
The presentation will focus on the following key issues: • Drainage strategy • Importance of well design • Water injection challenges • Pressure decline and GOR increase • Drilling 2 new injectors to increase reservoir pressure • Drilling 2 new producers
Gullfaks Shetland the hidden carbonate gem
Elisabeth Iren Dale, Equinor
A fascinating story of a chalk reservoir in the overburden discovered 26 years after the production start of Gullfaks. The presentation will take you through the development from discovery to production, and will describe how Gullfaks manages to maintain production from Shetland without hindering the development of the main reservoir below.
Chair: Vincent Kretz, Dyas Norge & Alexander Shadchnev, Schlumberger
EMBRACE – minimizing prediction uncertainty in reservoir modelling
Vedad Hadziavdic, Wintershall Dea
Groundbreaking and efficient stimulation technique for increased oil recovery on the Norwegian Continental Shelf
Lars Tore Berg, Fishbones
Presentation will view and discuss the three recent (2019) MST installations in the North Sea, in both carbonate and sandstone formations. Multilateral Stimulation Technology (MST) has proven to increase productivity in numerous wells and is experiencing increased attraction in the global E&P industry recovering from the downturn.
CO2 storage, uncertainty in plume migration - CCS Northern Lights project
Szczepan Polak, Equinor
The Northern Lights Project is a part of the full-scale CCS project. It is a result of the Norwegian government’s ambition to develop a full-scale CCS value chain in Norway by 2024. The studies in the project cover capture of CO2 at the waste-to-energy plant and at the cement factory, and the combined transport and storage solution, governed by the collaboration agreement between Equinor, Shell, and Total in the Northern Lights Project. One of the main challenges within underground storage of CO2 is evaluation of its migration in the subsurface after it has been injected. The storage formation in the exploitation license where the project plans to store CO2 has not been previously appraised. This gives high level of uncertainty in the modelling of plume migration.
Sola Strand Hotel,
Nordsjøvegen, Axel Lundsv. 27, 4055 Sola, Stavanger
NPF personal members NOK 7,000 plus 25% VAT
Non-NPF-members NOK 9,000 plus 25 % VAT
Payment can be done upon registration by credit card (Master Card/Visa/AmEx) or by invoice. If the invoice needs to be changed due to wrong or missing information there will added a fee of NOK 150 to the total amount. All international payments must be approved before the conference starts.
The conference fee includes:
Dinner is not included in the conference fee and must be chosen separately when registering. Fee is NOK 800 plus 25% VAT.
Membership of the Norwegian Petroleum Society (NPF)
We offer conference participants to purchase membership of NPF together with registration and payment for the conference:
1 year membership for conference participants – with affiliation to NPF Oslo / Polyteknisk Forening (PF Olje) (NOK 1,600)
1 year membership for conference participants – other local charters (NOK 1,000)
Price per night (incl. breakfast): NOK 1,395 for single room. Hotel is not included in the conference fee and must be paid upon check-out.
It is sometimes necessary to change timing of the programme. The conference organiser will not be liable for any such unavoidable changes.
Cancellations must be received in writing by 29th October 2019, and will be subject to a cancellation fee NOK 2.000 unless a substitute delegate is offered. After this date, the full registration fee will apply, however, substitutions will still be accepted. Substitutions for registered delegates may be made at any time, but we would appreciate prior notification.
In case of cancellation of the conference by the Norwegian Petroleum Society, (NPF), the participant will be refunded the conference fee and/or the exhibition fee. Other expenses the participants may have are not refunded, and is not the responsibility of NPF.