We study the influence of different physical properties on the effectiveness of CO 2 storage in aquifers. We present the results of a numerical sensitivity analysis using experimental design to quantify and compare the contribution of the most important parameters to the trapping of CO 2 .The work focuses on the impact of dissolution and residual trapping. Simulations using a reservoir model with properties and geometries representative of the Stuggart Formation in Ketzin (Germany) demonstrate how different trapping mechanisms are influenced by gravity segregation, fingering, and channeling.These studies show that horizontal permeability is the most influential parameter on the total amount of CO 2 dissolved, as it facilitates the lateral migration of CO 2 , enhancing dissolution into the brine. Residual gas saturation S gr is found to be the greatest contributor to the amount of residual CO 2 . As expected, higher S gr will reduce CO 2 mobility, producing a higher residual trail left by the CO 2 plume as it migrates. In addition, permeability heterogeneity is a major contributor to both trapping mechanisms.After a suitable geological site for CO 2 storage has been selected, our studies suggest that with appropriate well placement and injection strategy, at least 80% of the stored CO 2 can be trapped within a few decades of the end of injection.

With the production declining trends and dwindling reserves for a 35-year-old Samarang offshore field, Samarang Redevelopment Project was kicked-off with a vision to implement Integrated Operations (IO) as Asset Management Decision Support tool. To realize the expected reserves and optimize the production, an ЉIntegrated Asset ModelЉ (IAM) concept is introduced with a state of the art modeling techniques to treat the asset as a whole unit rather than isolated silos as was being done traditionally. Understanding the complex interactions and synergies between reservoirs, production networks and process facilities was the key in the decision making process, where strategies implemented and decisions taken on the production networks would greatly impact the reservoirs' performance and vice versa. This was achieved by creating an Integrated Asset Model that included the eight reservoir simulation models, together with a common production network model of around 80 strings and a complex process facilities model. This new business process is supported by an underlying system that keeps model up-to-date with the current reservoir and production changes. This innovative approach for long term production planning is used to better manage and plan the continuous production flow stream from reservoir to field export point. The main objectives for the Long Term Production Planning approach are:• Obtain more accurate and reliable forecasts by having the reservoir, surface network and process models integrated. • Recognize the complex interactions between reservoir and production networks and understand facilities constraints and potential bottlenecks. • Compare different EOR, redevelopment strategies scenarios thereby obtaining the optimal scenario. • Increase collaboration and reduce communication time between different domains to enhance the decision making process from an integrated asset management perspective.This approach has been implemented recently for the Samarang long term asset management strategy and has revealed very remarkable results which would help the asset team for improvising the short and long term strategies. The paper also divulge how the underlying foundation platform has been set-up to run such integrated studies followed by capabilities to run the various optimization scenarios to assist the development strategies especially after introduction on enhanced oil recovery (EOR). This innovative approach delivers value with the enhanced asset management by focusing on decisions to improve production and operations performance. Forecast production profiles reported from the subsurface models now incorporates the impact of network and process facilities, which allows for more efficient decisions leading to maximization of the production and reduction of CAPEX/OPEX costs.Some of the key benefits and early value gains of an Integrated Asset Model for Long Term Production Planning (LTP) are:• Realized the promised reserves expected by the EOR program by optimizing the production. • Cross-domain collaboration a...

The goal for mature fields, is to efficiently close the gap between its existing production and its maximum available capacity. For the mature field offshore Borneo, with timeworn infrastructure, old technology and manual data processing, the big challenge was understanding and analyzing the asset performance. With multiple operational locations, dispersed teams and domain experts working in silos, not all the reservoir-production-facility system interactions were considered for strategic decisions. Amount of time spent in the model updates has not only resulted in limited time for engineering analysis, but also resulted in longer decision cycle time. The lack of model readiness in time to respond has led to reactive decisions rather than proactive asset management. The core challenge was – how to leverage investment in real-time operational data to continuously update discipline-specific models facilitating accurate predictions of key events, possible system upsets, and support engineers to proactively manage their production systems to optimize current production while improving overall recovery. This triggered adoption of an Integrated Asset Modeling (IAM) methodology for end-to-end asset optimization. This was achieved by creating an IAM framework that includes the 8 reservoir simulation models, coupled with a common production network model of around 80 strings integrated with a complex process-facilities model. This new business process is supported by an underlying system that keeps model live/up-to-date with the current reservoir and production changes creating Integrated "Live Asset Model" (LAM) for the asset optimization. IAM approach has resulted in accurate metering, debottlenecking and boosting production operational efficiency. End-to-end surveillance of the system and full understanding of hydrocarbon pathway was the key for successful implementation of IAM for the asset optimization. The technique was not only implemented for the short term planning to improve the production using well intervention & optimization techniques, but also for improving reserves by injection of liquids/gases into the reservoir or Enhanced Oil Recovery (EOR) techniques. This case study illuminates the effective use of an IAM approach in the complex mature asset for improved asset production forecasting. Some of the key benefits and early value gains are – Realized the promised reserves expected by the EOR program by optimizing the reserves and production.Delivered integrated solution with a holistic view of the asset, by breaking down the barrier between different disciplines.Accurate estimation of production potential, with a rigorous scientific approach, by integrating reservoir, network, and process models without losing any of the details of the individual models. Promoted collaborative decision making by bringing people, process and technology together via collaborative work environment (CWE)Assessing how the existing surface pipeline network and facilities impact on the overall asset performance.Enhanced development planning by simulating various optimization scenarios and validating the impact of additional/infill wells and quantifying its production gains. The IAM model results emphasize the criticality of such an approach in making decisions for declaring reserves and production profiles throughout field life. It is the first field to implement Integrated "Live Asset Model" concept by automating the relevant time model updates. Leveraging CWE to bring experts across multiple locations, teams and domains for improved quality decisions.

The reduction of greenhouse gas emissions in order to decelerate the global warming process could be achieved through the emerging process of geological CO2 storage. Also in terms of Enhanced Oil Recovery (EOR) the injection of CO2 as a pure component or as part of a mixture has proved to increase the productivity of oil and gas reservoirs. Optimization techniques have been applied independently to the reservoir and surface models, leading to non-optimal solutions due to the non-dynamic integration between models. A recent trend of the industry is the integration of sub-surface and surface simulators to have a better representation of the fluid production/injection, taking into account the constantly changing interaction between systems. The integrated approach has been used to integrate multiple reservoirs with common and advanced surface facilities to properly model the fluid flow behavior of the asset. Different injection variables, facilities, well completion, number of wells have been included in the analysis and numerical reservoir simulation models have been integrated with a network. As CO2 is captured, it is transported and re-injected to neighbor reservoirs, as an enhancement process for productivity or for storage purpose. After proving the feasibility of facilities for CO2 injection as EOR process or storage, the integrated approach has shown a more comprehensive solution that could be used for the design and further optimization of this type of projects. Analysis of reservoir properties as permeability, temperature, etc. is also taken into account in order to asses the viability of the CO2 optimal injection and storage strategy, while minimizing cost. Finally, integrated asset modeling also shows the flexibility to represent different types of settings such as CO2 source (reservoir and/or fossil fuel power plants), types of reservoirs and network scenarios. Introduction Global warming is becoming one of the most important problems of the mankind. Precipitations have been reduced considerably and the sea level and ocean temperature have risen. One of the most likely causes is the emission of anthropogenic greenhouse gases into the atmosphere, where carbon dioxide appears as one of the main components. As a consequence, several mitigation options have arisen in order to reduce the CO2 emissions. One of the most current and important options is Carbon Capture and Storage (CSS) where the CO2 is captured and separated from energy-related sources, transported and final storage in a proper location. There are two important scenarios for storing CO2 emissions, namely, ocean storage and underground geological storage. The first scenario is still a very immature technology, but environmental concerns have slowed down its development and more knowledge in the area is required. The second scenario, geological CO2 storage, is currently available through several commercial or pilot projects. Geological storage injects CO2 into either oil or gas reservoirs, aquifers or coal beds. CO2 has been used in the oil industry as a method to enhance the recovery of hydrocarbons and this knowledge has contributed to extending the use of CO2 not only for enhanced oil recovery but also for long-term storage.

This paper aims to describe the overall EOR GASWAG concept with some of the key findings after first phase execution and some of the measures taken to maintain the project within the planned OPEX to remain economic. Secondly, to describe a comprehensive reservoir management plan which includes a fit for purpose data acquisition plan and more importantly how the remaining challenges are addressed through the RMP optimization to maximize recovery. Finally, this paper outlines the main key challenges to be faced once the injection phase kicks off, highlighting the surveillance and monitoring strategies to overcome them.