After 40 years of depletion drive, a mature, giant and multi-layer carbonate reservoir is developed through waterflooding. Oil production, sustained through infill drilling and new development patterns, is often associated with increasingly higher water production compared to earlier development phases. A field re-development plan has been established to alleviate the impact of reservoir heterogeneities on oil recovery, driven by the analysis of the historical performance of production and injection of a range of well types. The field is developed through historical opportunistic development concepts utilizing evolving technology trends. Therefore, the field has initially wide spacing vertical waterflooding patterns followed by horizontal wells, subjected to seawater or produced water injection, applying a range of wells placement or completion technologies and different water injection operating strategies. Systematic categorization, grouping and analyzing of a rich data set of wells performance have been complemented and integrated with insights from coarse full field and conceptual sector dynamic modeling activities. This workflow efficiently paved the way to optimize the field development aiming for increased oil recovery and cost saving opportunities. Integrated analysis of evolving historical development decisions revealed and ranked the primary subsurface and operational drivers behind the limited sweep efficiency and increased watercut. This helped mapping the impact of fundamental subsurface attributes from well placement, completion, or water injection strategies. Excellent vertical wells performance during the primary depletion and the early stage of water flooding was slowly outperformed by a more sustainable horizontal well production and injection strategy. This is consistent with a conceptual model in which the reservoir is dominated by extensive high conductive features that contributed in the early life of the field to good oil production before becoming the primary source of premature water breakthrough after a limited fraction of pore volume water was injected. The next level of analysis provided actual field evidence to support informed decisions to optimize the front runner horizontal wells development concept to cover wells length, orientation, vertical placement in the stratigraphy, spacing, pattern strategy and completion design. The findings enabled delivering updated field development plan covering the field life cycle to sustain and increase field oil production through adding ~ 200 additional wells and introducing more structured water flooding patterns in addition to establishing improved wells reservoir management practices. This integrated study manifests the power, efficiency and value from data driven analysis to capture lessons learned from evolving wells and development concepts applied in a complex brown field over six decades. The workflow enabled the delivery of an updated field development plan and production forecasts within a year through utilizing data analytics to compensate for the recognized limitations of subsurface models in addition to providing input to steer the more time-consuming modeling activities.

This paper describes and demonstrates how a patented new wellbore intervention solution can be deployed in long horizontal wells holding Fibre Optic Sensing devices including DTS (distributed temperature sensing), Point Pressure and Motion sensors performing logging services to evaluate the Inflow Performance along the reservoir sections. The paper also provides a description of the intervention system with a short introduction on how the final system emerged from the idea stage. Also, we provide two Case Histories - a horizontal oil producer with 2-phase flow, and horizontal water injector. The planning- and operational execution phases are briefly described. The paper closes with a brief conclusion of what has been achieved and what more this technology may be able to in the near future. The methodology describes can be seen as a 3rd wellbore intervention method, in addition to coiled tubing (CT) and wireline. Introduction Known technology today for accessing long reach horizontal wellbore sections to perform logging and remedial work typically requires coiled tubing or wireline "tractor", where both these methods have constrains. Monitoring tools for use during fracturing and acid stimulation is also technology that is of limited availability (Ref SPE 106507). By adding Fibre Optic Sensing System to this technology we have been able to access horizontal wellbores for logging purposes demonstrating our capabilities to re-capture Inflow & Injection Performance evaluations similar to the today's conventional methods for Cased Hole Logging Services, where these tools also are used for Flow Interpretations in open hole sections. This paper describes the third well intervention method recognized in this industry developed and successfully applied to a number of wells. It is based on pushing a semi-stiff and spoolable carbon rod into production & injection wells. There is no similarity to logging tools that is added to the end of this conveyance method, but the logging results of reservoir behavior converted to Inflow Performance Analysis has been proven to be comparable.

Smart Fields solutions add a lot of value to further field development and well, reservoir, and facility management. Over the years, Shell has developed and deployed many integrated Smart Fields solutions. However, as each field is different, with more complex field development types, ‘stacking’ of different solutions is becoming common, we need to ensure that we identify and deploy the right balance of solutions. The "Appropriate Level of Smartness" (ALoS) describes the desired stage. The focus of the Smart Fields programme has therefore shifted from "selling" individual solutions to achieving ALoS in all our key projects (help assets know and implement the balanced mix of solutions). In this paper, we describe how we screen, decide applicability, and deploy Smart Field solutions for the Shell portfolio. The screening identifies the relevant Smart Fields Solutions for a project or asset that will maximize the project value and help reduce its key business uncertainties, taking a full lifecycle view. Deployment will help projects to ensure that the value opportunities identified through the Screening are materialized into solutions deployed at the asset, realizing the value to Shell. Solutions need to be tailored for the specific field, production type, purpose, or environment (Archetype). We have developed a framework to ensure that we deploy the right Smart Field solutions for each type of field and asset. As guidance, we make use of a newly built Solutions Advisory. This advisory, for example, highlights which solutions are standard in which environment, meaning that you would have to justify why not to implement. At the end, we will show how Smart Fields has already added substantial value in brownfields, whilst ALoS guarantees our future value and effectiveness of greenfield projects, ensuring that we do it right from the beginning, so no retrofitting is required.

This paper presents the ongoing development planning, by semi-vertical short-radius extensions (a.k.a fishbones) and infill drilling of a mature waterflooded carbonate reservoir in Oman. Given 35 years of production and water injection into the reservoir, a key focus in the development philosophy is maximizing reserves recovery from existing wells. Many of these wells have reservoir zones with significant oil saturation behind pipe. Two development options were considered attractive for the existing horizontal well stock: adding perforations and creating vertical fishbones targeting the by-passed and attic oil. A total of 52 wells have been identified for additional perforations and 25 wells as fishbone candidates. Additionally, by-passed oil targets have been identified for infill drilling. Infill drilling of the by-passed oil targets proved very successful. Ten out of the eleven opportunity areas where infill drilling was completed encountered economic by-passed oil. The single failure still highlights the remaining challenges in tapping the by-passed oil targets in this giant waterflood oil field. In particular, this paper discusses the results of the past three years of tapping undeveloped reserves using fishbone extensions and infill drilling. Sector modeling and analytical analysis methods supported by surveillance data high-graded 8 opportunities targeting attic oil. Following the initial poor success, mainly due to operations related problems, subsequent improvement in setting and retrieving whipstock has significantly improved the success rate. Liner integrity has been found to be the main setback of this development option. Background The field was discovered in 1963 and is situated in north Oman ca. 450 km WSW of Muscat. Production is mainly from the Lower Cretaceous Shuaiba formation. The Shuaiba formation is heavily faulted and consists of intra-shelf basin floor carbonate muds. Production commenced in 1969 and gradually built up to peak production in 1997. The historic production review showed that production gradually decreased in the first 10 years of production due to a lack of water injection support. When sufficient injection support became available in the early eighties, production slowly increased to peak production. Water production sharply increased in 1997 at the onset of high density, horizontal infill drilling. Since 1997, production decreased rapidly, to ensure that the remaining value of the field is maximized; a study has been initiated to design the next phase of field development. The study was kicked off by a "volume to value" (V2V) peer assist in November 2000, and in 2004 a new development plan for the field was issued. The Shuaiba field Development Plan document is aimed at capturing the uncertainty related to STOIIP and reserves with the objective to maximize the future recovery of the Shuaiba reservoir. An extensive amount of effort in the last 5 years focused on increasing knowledge, data gathering, integrated modeling and field applications has improved the understanding of the Shuaiba reservoir and resulted in improved wells reservoir management and successful placement of infill producers and injectors. The integrated modeling has gone through several generations using models at various scales including single well models, conceptual 3D models, sector models, coarse full field model, detailed of full field model and large sector model extracted from the detail full field model. The data gathering that has taken place in order to build these models and the cumulative knowledge base established from the results have led to the field development plan of the field.

This paper presents an overview of how the Shell Group of Companies has implemented the Well, Reservoir and Facility Management (WRFM) methodology in its Upstream assets. It discusses the different parts of the WRFM Value Loop, and presents case histories and successes from within the Group. Effective Well, Reservoir and Facility Management requires the integrated contributions of Petroleum Engineering, Production, Facilities and Process Engineering, and Well Services. The detailed WRFM plan defines the type and frequency of the surveillance and data acquisition activities that need to be carried out in order to optimise the production from the asset, and to manage the uncertainties that remain in the development of the asset. WRFM is a structured and integrated approach to data gathering and data management, modeling and interpretation, identification of production enhancement opportunities, and intervention to deliver the opportunities to maximise asset value. This process is represented as the WRFM Continuous Improvement loop, or Value Loop. WRFM targets are set on a yearly basis and progress is measured against the targets. Information and best practices are shared laterally and through the company's global WRFM team. The various segments of the WRFM loop are presented below in detail, and are illustrated by appropriate case histories. Rigorous application of the WRFM methodology has resulted in considerable improvements in production gains and water injection performance.