The so-called Digital Oil Field (DOF) is a somewhat ill-defined, misunderstood and abstract concept. The associated functional content, scope of work and terminology is variable from company to company and vague within companies. Consequently it is unclear how to gauge DOF degree of success, business benefit and effective organizational penetration. It is also sometimes unclear what the ultimate goals and associated road-maps are. With clear objectives, clarity of purpose and sufficient business justification there is a reasonable chance of meeting these goals, without clarity all is shrouded in mystique and uncertainty. Hence the purposes of this paper are to: Define precisely what is meant by the DOF; Describe the current operational status quo and compare and contrast with the ideal DOF; Define metrics that can be used to gauge the success of DOF initiatives. This will be achieved by illustrating what the DOF is, and what it is not, in terms of oil and gas field infrastructure, applications and experiences. Application of the metrics defined will allow users to determine whether it is "the beginning of the end, or the end of the beginning for their DOF."
The emerging trend in Oil and Gas industries for multi-disciplinary teams spread across diverse geographical locations is virtual team working. This concept is a key enabler in a digital oilfield environment where real time communication enables efficient decision making between field and office operations. The Shell Smart Fields Program, Shell's digital oilfield initiative, has deployed the use of Collaborative Work Environments (CWE) as an enabler to optimize operational value across its operating units globally.The fundamental pillars supporting a CWE implementation are 1) People, 2) Work Process, 3) Tools and Applications and 4) Facility. During the design and implementation phases of building a CWE, emphasis is typically placed on work process, tools and applications, and facility while the people aspect is embedded within other improvement areas. The Smart Fields Program has observed that integration of the People aspect is critical to ensure a CWE's success. Without an effectively and efficiently trained workforce, the new CWE processes will not flow as intended. To address this, Shell has developed a tested methodology focused on driving the required behavioral change to achieve the necessary performance. This paper will focus on the importance of the people aspect in a CWE implementation, based on a 2009 improvement effort centered on Human Factors Integration (HFI) and behavioral change coaching. In particular, this paper will address:• The role of HFI / coaching in CWE implementations • Identification of relevant people issues • How to provide continued / ongoing support to the 'digital' workforce • Identification within the organization of ownership for the new collaborative behaviors • The necessary organizational structure required to support new ways of working • Required behavioral changes to support the future workforce • Key differences between staffing operations in a current oilfield versus a digital oilfield • Lessons learned from deployment of above points
A super-giant carbonate field in Abu Dhabi has most of its remaining reserves in carbonate build-up and prograding basinmargin deposits of Lower Cretaceous age (Shuaiba Formation). To guide further field production, a sequence stratigraphic framework was developed based on integration of core, log and seismic data. This framework is the cornerstone for building a new reservoir model and provides the key for a better understanding of facies and flow unit continuity guiding present and future field production and performance.Approximately 730 wells, wireline logs and the latest core descriptions were integrated for this study. Another key element was the incorporation of 3D seismic data coupled with several iterations between well log and seismic picking. Detailed seismic interpretation led to the delineation of 3rd and 4th order sequences. The picking of higher order sequences was based on well data guided by the seismic surfaces. This study provides an excellent example of extracting maximum information from seismic and the full integration of geoscience and production data to provide a new 3D framework.The sequence framework uses a consistent nomenclature based on the Arabian Plate Standard Sequence framework for the Aptian (van Buchem et. al., 2010). The Shuaiba is subdivided into six 3rd order sequences (Apt 1, 2, 3,4a, 4b, and 5) which, based on stacking patterns, record a complete 2nd order cycle of Transgressive, Highstand, and Late Highstand systems tracts (Apt 1-4b). The Bab Member (Apt 5) and Nahr Umr Shale form the Lowstand to Transgressive systems tracts of the next Super-sequence.The third order Apt 1 sequence and the Apt 2 TST form the 2nd order transgressive systems tract, characterized by backstepping and creation of differential relief between the Shuaiba shelf and Bab intra-shelf basin. These sequences are dominated by Orbitolina and algal/microbial Lithocodium/Bacinella fossil associations.The Apt 2 HST and Apt 3 Sequence form the 2nd order early highstand systems tract during which the platform area aggraded and the topographic split into platform, slope and basin became most pronounced. Sediments are extremely heterogeneous and varying properties introduce significant problems in understanding fluid flow. During the regressive part of the Apt 3 sequence accommodation space was limited and deposition switched to progradation at the platform margin. The platform top is characterized by thin cycles of rudist floatstones/rudstones separated by thin cemented flooding and exposure horizons, whilst the platform margin received large quantities of rudstones, grain and packstones organized in clinoform sets. Clinoforms are separated by thin stylolitic cemented layers, which are transparent on seismic.The Second Order late highstand systems tract is composed of 3rd order cycles Apt 4a and Apt 4b. These are detached from the main buildup, which probably stayed largely exposed, and form strongly prograding slope margin wedges composed of alternating dense mudstones (TST) and grainstone/packstone sequences...
Two 126 level 3-component 3D-VSP's (Vertical Seismic Profiles) were acquired coincident with a high-resolution surface seismic survey. Figure 1 shows the location of the first 3D-VSP on the crest of the field and the second 3D-VSP on the flank of the field. Using the surface seismic sources, 11712 shot points were used per VSP to collect 4.5 million traces per VSP, which produced a 6–9 km2 final 3D-VSP image around each of the two wells. Due to the large offsets and high density of traces available it was possible to experiment with acquisition and processing methodologies to produce images that resolve thinner beds, see more structural definition and improve reservoir characterization. Results from the first phase of processing are very encouraging and show the 3D-VSP images to be able to resolve subtle faults that were not seen in older surface seismic data and have higher frequency content than the new 640 fold, high resolution surface seismic data. Source and receiver decimation tests are aiding in efforts to better understand how to acquire high quality 3D-VSP's in the future with minimal effort and cost. Efforts to expand the size of the 3D-VSP volumes around the wells have been successful. The largest image produced so far has been able to image more than 1.5 km away from the wellbore. The high quality VSP images and the fact that VSP's can be repeated at much lower cost than surface seismic makes this technology very attractive for future time-lapse reservoir monitoring studies.
An important carbonate oil field, located onshore Abu Dhabi, has been producing from the Upper Cretaceous (Maastrichtian) Simsima Formation since 1983. To optimize and increase production of the field, seismic and high-resolution sequence stratigraphy was integrated by tying fourth-order, high-frequency sequences identified from core to 3-D seismic data. To establish the sequence stratigraphic framework, a new detailed sedimentological and high-resolution sequence stratigraphy study had been carried out, integrating approximately 7,000 feet of core material, approximately 3,500 thin sections, and all available well-log data from 46 wells. Core description, together with semi-quantitative petrographic examination of thin sections, established a new depositional model for the Simsima Formation. Sixteen lithofacies types (LF1 to LF16) representing a wide variety of depositional environments, ranging from upper ramp, rudist-bioclastic shoals to open marine mid to outer ramp mud-dominated settings. The newly developed, high-resolution sequence stratigraphic framework suggested that the Simsima Formation comprises one complete third-order composite sequence and the transgressive systems tract of an overlying second third-order composite sequence. These third-order composite sequences include seventeen high-frequencies, fourth-order sequences (HFS). HFS-1 to HFS-12 build the older third-order composite sequence, HFS-13 to HFS-17 form the transgressive system tract of the overlying, younger third-order composite sequence. 3-D seismic cross-sections show that fourth-order high-frequency sequences HFS-1 to HFS-6 of the older third-order composite sequence clearly show onlap on a pre-existing high (pre-Simsima unconformity surface), whereas the top part of the Simsima Formation (high-frequency sequences HFS-13 to HFS-17) show various degree of erosion. The established high-resolution sequence stratigraphic framework provides the layering scheme for the next generation Simsima 3-D static model, which will be used as input for the reservoir flow (dynamic) model. Introduction Large oil accumulations have been discovered and produced from the Upper Cretaceous (Maastrichtian) Simsima Formation in Abu Dhabi since 1983. The Simsima Formation was deposited on an actively growing paleo-high in shallow marine environment. It is capped by the basal shale member of the Umm Er Radhuma Formation and overlies the crest of partly eroded former structure of the Aruma Group. It ranges in thickness from 323 ft in the crest of the field structure to 628 ft in the flank. Recently, approximately 7,000 feet of core and 3,500 thin sections along with well-log data from 46 wells were studied. A total of sixteen lithofacies types were identified. As a result of the core study, seventeen high-resolution fourthorder sequences were established. They constitute a complete third-order composite sequence and the transgressive systems tract of an overlying second third-order composite sequence. The high-resolution sequence stratigraphy identified from cores was integrated with the 3-D seismic by tying the fourth-order sequences to the seismic data. An integrated layering scheme will be used for the next generation Simsima 3-D static model, which will be used as input for reservoir flow (dynamic) model.
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