A Data-Centric Omnichannel Digital Platform for Configuring Subsea Field Developments

2021 ◽  
Author(s):  
Rhys Gareth Morgan ◽  
Thomas Parenteau ◽  
Hemant Priyadarshi ◽  
Sachin Vijay Mathakari ◽  
Malo Le-Nel ◽  
...  
Keyword(s):  
Data Model ◽  
Data Transfer ◽  
Development Planning ◽  
Qualitative Comparison ◽  
Digital Platform ◽  
Field Development ◽  
Optimal Development ◽  
Development Scenarios ◽  
Base Data

Abstract Subsea field development planning can be a complicated undertaking requiring the coordination and collaboration of multiple engineering and commercial disciplines with competing objectives. Thus, finding the optimal development solution can be challenging. To combat this, a data-centric omnichannel digital platform for configuring subsea field developments has been created. The study workflow orchestrated by the digital platform is detailed along with an overview of the data model, functionality, and deliverables. A case study is presented to demonstrate the value delivered using this digital platform. The digital platform is inherently collaborative as it orchestrates specialist engineering tools and their workflows around the same data for study teams to configure subsea development solutions. The platform is composed of: A web-based graphical user interface that allows discipline and product engineers to collaboratively configure the system, products, planning and costing for an entire subsea field development scenario, leveraging the same base data i.e., a single source of truth. A proprietary data model covering system, product (e.g., hardware or equipment), activity planning and costing breakdowns, and; Microservices that directly attach engineering tools and their workflows to the digital platform to automate product design and analysis. A case study is presented to demonstrate the use of the digital platform on a subsea field development prospect and a qualitative comparison with the conventional way of working is made. The case study illustrates the use of a digital hardware configurator (subsea tree system configuration) and the automated planning workflow for an EPCI (Engineering, Procurement, Construction, and Installation) prospect enabled by the digital platform. The results of the case study demonstrate the platform values and benefits the digital platform delivers. The benefits are underpinned by the automated data transfer, the versioning functionality, software logic, and the common base data used by the microservices. The benefits that have been found when compared with the conventional way of working include: Faster validation of alternative development scenarios, meaning that more concepts and sensitivities can be investigated in the same length of time; A reduction in the overall lead time and person hours required to configure and optimize a field development solution; Design risk reduction, and; Efficient and consistent transition of data via virtual handovers. This paper demonstrates a new approach for subsea field development planning using a data-centric omnichannel digital platform called Subsea Studio™ FD, which is shown to deliver benefits over the conventional document-centric way of working. The digital platform brings multiple engineering disciplines together to configure optimal development solutions, accounting for competing objectives. It initiates the digital thread through the project lifecycle and will ultimately culminate in a digital twin during project execution, which can be leveraged throughout the life-of-field to optimize operations.

Subsurface-to-Economics Closing the Loop on Uncertainty Analysis

2021 ◽  
Author(s):  
Galvin Shergill ◽  
Adrian Anton ◽  
Kwangwon Park
Keyword(s):  
Measurement Errors ◽  
Oil And Gas ◽  
Uncertainty Modeling ◽  
Weather Forecast ◽  
Oil And Gas Industry ◽  
Development Planning ◽  
Gas Field ◽  
Field Development ◽  
Development Scenarios ◽  
Uncertainty Model

Abstract We are all aware that our future is uncertain. Although some aspects can be predicted with more certainty and others with less, essentially everything is uncertain. Uncertainty exists because of lack of data, lack of resources, and lack of understanding. We cannot measure everything, so there are always unknowns. Even measurements include measurement errors. Also, we do not always have enough resources to analyze the data obtained. In addition, we do not have a full understanding of how the world, or the universe, works (Park 2011). Every day we find ourselves in situations where we must make many decisions, big or small. We tend to make the decisions based on a prediction, despite knowing that it is uncertain. For instance, imagine how many decisions are made by people every day based on the probability of it raining tomorrow (i.e., based on the weather forecast). To have a good basis for making a decision, it is of critical importance to correctly model the uncertainty in the forecast. In the oil and gas industry, uncertainties are large and complex. Oil and gas fields have been developed and operated despite tremendous uncertainty in a variety of areas, including undiscovered media and unpredictable fluid in the subsurface, wells, unexpected facility and equipment costs, and economic, political, international, environmental, and many other risks. Another important aspect of uncertainty modeling is the feasibility of verifying the uncertainty model with the actual results. For example, in the weather forecast it was announced that the probability of raining the next day was 20%. And the next day it rained. Do we say the forecast was wrong? Can we say the forecast was right? In order to make sure the uncertainty model is correct; we should strictly verify all the assumptions and follow the mathematically, statistically, proven-to-be-correct methodology to model the uncertainty (Caers et al. 2010; Caers 2011). In this paper, we show an effective, rigorous method of modeling uncertainty in the expected performance of potential field development scenarios in the oil and gas field development planning given uncertainties in various domains from subsurface to economics. The application of this method is enabled by using technology as described in a later section.

A Novel Holistic Workflow for Field Development Planning in Green Field Environment: A Case Study

2018 ◽  
Author(s):  
Mohamad Alkhatib ◽  
Abdulla Ali Al Ali ◽  
Muhammad Mukhtar ◽  
Sangseok Park ◽  
Kassem Ghorayeb ◽  
...  
Keyword(s):  
Development Planning ◽  
Field Development ◽  
Field Environment

Collaborative and Multidiscipline Field Development Planning – A Caspian Case Study

2019 ◽  
Author(s):  
Ekaterina Eliseeva ◽  
Fabien Hauchart ◽  
Scott Wilson ◽  
Sergey Mukhin
Keyword(s):  
Development Planning ◽  
Field Development

Integrated Subsurface Study for Gas-Oil Communicating Reservoirs: From Structural Synthesis to Optimum Co-FDP

2021 ◽  
Author(s):  
Mohamad Yousef Alklih ◽  
Andi Ahmad Salahuddin ◽  
Karem Alejandra Khan ◽  
Nidhal Mohamed Aljneibi ◽  
Coriolan Rat ◽  
...  
Keyword(s):  
Decision Making ◽  
Reservoir Characterization ◽  
Development Planning ◽  
Co2 Injection ◽  
Oil Reservoir ◽  
Discounted Cash Flow ◽  
Field Development ◽  
Development Scenarios ◽  
Pressure Depletion ◽  
Field Management

Abstract This paper presents an integrated subsurface study that focuses on delivering field development planning of two reservoirs via comprehensive reservoir characterization workflows. The upper gas reservoir and lower oil reservoir are in communication across a major fault in the crest area of the structure. Gas from the upper reservoir, which is not under development, is being produced along with some oil producers from the oil reservoir as per acquired surveillance data. Pressure depletion is observed in observer wells of the upper reservoir, which substantiate both reservoirs communication. The oil reservoir is on production since 1994, under miscible hydrocarbon water alternating gas injection (HCWAG) and carbon dioxide (CO2) injection. The currently implemented development plan has been facing several complexities and challenges including, but not limited to, maintaining miscibility conditions, sustainability of production and injection in view of reservoirs communication, reservoir modeling challenges, suitability of monitoring strategy, associated operating costs and expansion of field development in newly appraised areas. In this study, an assessment of multiple alternative field development scenarios was conducted; with an aim to tackle field management and reservoir challenges. It commenced by a comprehensive synthesis of seismic, petrophysical (including extensive core characterizations), geological, production and reservoir engineering data to ensure data adequacy and effectiveness for development planning. The process was followed by evaluation of the historical reservoir management, HCWAG and CO2 injection practices using advanced analytics to identify areas for improvement and accelerate decision making process. The identified areas of improvement were incorporated into a dynamic model via diverse set of field management logics to screen wide range of scenarios. In the final step, the optimal scenarios were selected, in line of having strong economic indicators, honoring operational constraints, corporate business plan and strategic objectives. The comprehensive and flexible field management logic was set up to target different challenges and was used to extensively screen hundreds of different field development scenarios varying several parameters. Examples of such parameters are WAG ratio, injection pressures for both water/gas and CO2, cycle duration, well placement, reservoir production and injection guidelines, different co-development production schemes coupled with static and dynamic uncertainty properties against incremental oil production and discounted cash flow. The simulation results were analyzed using standardized approach where a number of key indicators was cross-referenced to produce optimal field development scenarios with regards to co-development effect of both reservoirs, miscibility conditions, balanced pressure depletion, harmonized sweep as well as robust discounted cash flow. Strong management support, multi-disciplinary data integration, agility of decision making and revisions in a controlled timeframe are considered as the key pillars for success of this study. The adopted workflow covers subsurface modeling aspects from A-Z and following reservoir characterization and modeling best practices. The methodology applied in this study uses an integrated subsurface structured approach to tackle reservoirs challenges and co-development, generate alternative development options leveraging on data analytics techniques and advanced field management strategies.

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