bluuebunny/crossref_metadata_2025_split huggingface dataset:
Predicting sandbody distribution and porosity for Callovian to late Oxfordian succession; Block 9/13 UKCS: an integrated approach
Authors: WOOD M. , BINGHAM G. , MITCHELL P. 
Published: April 2010

Middle to Upper Jurassic clastic deposits of the Block 9/13 area show an evolution in their sedimentary characteristics and depositional style, which are attributable to the interplay between rising relative sea-level, decreasing sediment supply and the development of an extensional fault framework. An understanding of the temporal and spatial relationship between fault activity and sediment supply is critical in determining reservoir distribution. Four evolutionary stages are identified: (a) Bajocian–Bathonian fluvio–tidal deposits: sedimentation occurred in a simple N–S trending extensional system, comprising discrete fault segments, coupled with high rates of sedimentation with a southerly provenance. (b) Callovian–Oxfordian submarine channel to pro-delta deposits: axially transported sediments are deposited in hanging wall lows of N–S orientated fault segments. Sediment supply is outstripped by the creation of accommodation space. (c) Mid–late Oxfordian submarine gravity flow deposits: axially transported sediments were deposited in closed synclinal lows created by the intersection of N–S and NW–SE, SW–NE fault trends, resulting from ramp-relay collapse. (d) Kimmeridgian–Volgian debris flow deposits derived from the footwalls of uplifted fault blocks.
A case study is presented, integrating post-stack seismic inversion with more conventional datasets, to provide increased confidence in the Callovian–late Oxfordian geological model. The gross stratigraphic package between the Callovian and late Oxfordian is easily distinguished using conventional seismic data. However, with conventionally processed seismic data individual sandbody distribution and geometry is difficult to determine because of a combination of non-unique seismic responses at sand–shale interfaces and resolution limitations. Recent success has been achieved using post-stack seismic inversion of a wavelet-processed volume, to distinguish sand within a particular porosity range from all other lithologies, to an acceptable level of confidence.
Hydrocarbon systems modelling of the Norwegian Central Graben fairway trend
Authors: TAYLOR M. S. G. , LeROY A. , FØRLAND M. 
Published: April 2010

The known hydrocarbon accumulations in the Norwegian Central Graben Fairway trend are forward modelled in this study. Particular attention is paid to the petroleum phase in the reservoirs as commercial and economic models of Central Graben prospects are closely linked to hydrocarbon type, especially in the less explored downdip areas.
Detailed seismic structure grids and well data are utilized in Finesse, an integrated 2D horizontal plane modelling program to simulate the maturation of source rocks and the expulsion, migration, and entrapment of generated hydrocarbons through time. All known Jurassic, Cretaceous, and Paleocene fields and discoveries were used to calibrate the model.

The study focused on migration through multiple layers defining vertical conduits between layers based on modelling seal capacity failure and fracturing rather than using faults as conduits. The maturity indicator used was the total transformation ratio (TTR) (the sum of the oil and oil to gas cracking transformation ratios) rather than vitrinite reflectance (R
0
). TTR is an accurate reflection of the state of source maturity whereas Ro is an indication of the thermal stress applied to the source.

The results show that 2D horizontal plane models can be used to predict known hydrocarbon accumulations over large regions and highlight areas of future prospectivity. This allows the explorationist to effectively focus on specific areas where more detailed 2D or 3D modelling can be applied.
The Jurassic petroleum system of the West of Britain Atlantic margin – an integration of tectonics, geochemistry and basin modelling
Authors: HOLMES A. J. , GRIFFITH C. E. , SCOTCHMAN I. C. 
Published: April 2010

A re-appraisal of the Mesozoic and Cenozoic evolution of the Atlantic margin basins has been integrated with new data on source-rock kinetics, oil-source geochemistry and fluid inclusion studies to calibrate the petroleum systems of the study area and model these systems utilizing 2D modelling software.
The high β factors that are reported from these basins are cumulative estimates. Superposition of rifting events and evidence of prolonged rifting until the early Paleocene demonstrate that heat flow patterns associated with a ‘cool’ rift model are most appropriate.
New kinetic models for ‘Kimmeridge Clay’ and Middle Jurassic source-rock samples from released wells and BGS shallow boreholes allow more precise maturation modelling. Prolific oil-prone, Type I and Type I/II Middle Jurassic source rocks, together with fast-reacting Type IIS Upper Jurassic–Lower Cretaceous source rocks have been identified and indicate the range of kinetic models that must be considered during sensitivity analysis.
In the Faeroe–Shetland area, complex mixing of both ‘fresh’ and biodegraded oils from different source rocks as well as different facies of the same source-rock formation are recognized. Gas chromatography–mass spectrometry (GC–MS) and compound specific isotope analysis (CSIA) of oil samples and petroleum fluid inclusions are used to differentiate between oil families and also to separate oils within a sample.
A number of regional seismic sections were utilized for 2D modelling which was calibrated from well or pseudo-well models and incorporated new heat flow and kinetic data. These results and regional mapping indicate that the respective location of Lower Tertiary versus Upper Cretaceous depocentres is critical in determining the timing of maturation. Peak oil maturation occurs from mid Cretaceous to the present-day. Migration pathways initially focus hydrocarbons to Mesozoic (or older) highs. Early Tertiary faulting, mid Tertiary uplift and gas flushing then control re-distribution of hydrocarbons.
Managing reservoir uncertainty after five years of field life: Britannia Field
Authors: SUMNER W. R. , LOUTIT S. , TOHILL E. , WAY D. , CRIDDLE D. , PALFREY A. , HAKES W. G. , ARCHER S. , COLLERAN J. , SCOTT A. , KAISER K. , HARDING A. , CASTELLINI A. , CLARK J. , LIANSHUANG QI 
Published: April 2010

The Britannia Field, located 210 km northeast of Aberdeen, is the largest Lower Cretaceous condensate gas accumulation in the North Sea. The field spans four UK blocks (250km
2
) and is a combination structural/stratigraphic trap. Assessing the remaining uncertainty in a field the size of Britannia is crucial to future development planning scenarios. After five years of field life, it has proved vital to take the ‘reservoir pulse’ and to evaluate the key reservoir parameters that impact the future development of the field.

The Britannia reservoir consists of deep-water mass-flow sandstones, ranging from high density ‘clean’ turbidites to non-reservoir facies consisting of ‘mixed-slurry’ and debris flows. Post-depositional remobilization and slumping have modified the original depositional fabric; however, a wealth of core data (over 20000 ft), along with 63 logged wells and dynamic production data, have allowed refining of the flow unit definition within the reservoir. A rigorous re-correlation study based on the integration of biostratigraphy, chemostratigraphy and pressure data has defined an overall sheet-like reservoir architecture, with some units exhibiting a more complex channel-like geometry (Zones 30/40).
The Britannia reservoir teamhas capitalized on recent advances in reservoir modelling technology, including a more rigorous approach to uncertainty analysis in both the static and dynamic realm. The results from a dynamic uncertainty study have provided key information on the range and magnitude of key petrophysical parameters and their impact on reservoir performance and ultimate recovery. Weighing the impact of a deterministic versus stochastic approach has also been a critical factor in the facies distribution. The major uncertainties in the dynamic reservoir model that impact reserves and recovery factor are (1) original gas in place, (2) fault and/or stratigraphic transmissibility ‘baffles’, (3) effective permeability, and, (4) condensate banking. In the static geological model, Jacta – a Gocad uncertainty module – has led to over 300 realizations of the full field model. In the dynamic realm, experimental design was used to monitor reservoir performance by capturing the variables having largest impact on dynamic flow behaviour and gas recovery.
Judy Field: rejuvenation through a second phase of drilling
Authors: KELLER T. , BAYES R. , AULD H. , LINES M. 
Published: April 2010

The Judy Field pre-Cretaceous reservoirs produce from a series of tilted fault blocks that form a complex northwest-plunging horst in Block 30/7a, UK Central North Sea. The primary producing reservoir of this field is the Middle to Late Triassic Joanne Sandstone Member of the Skagerrak Formation with secondary contributions from the Middle Triassic Judy Member of the Skagerrak Formation and the Late Jurassic Fulmar Formation. Fluid properties and contacts vary throughout the field. Currently the field is producing from ten development wells.
Based on core studies, the depositional environment of the Triassic Skagerrak Formation has been identified as ephemeral fluvial while the Jurassic Fulmar Formation is transgressive shallow marine. Sedimentological interpretation of core data from seven wells in the field indicates that the Joanne and Judy Sandstone Members comprise four major facies associations: fluviatile channel sandstones, sheetflood sandstones, argillaceous sandstones and lacustrine mudstones. The complex architecture of these four facies associations makes it difficult to accurately predict absolute reservoir productivity without recourse to long-term production tests. Although the reservoir complexity was appreciated from an early stage in the field development, the initial reservoir models proved to be somewhat simplistic and overestimated the length of the production plateau.
Anew, longer offset 3D dataset was acquired in 1999 to replace the original pre-development 1986 3Dseismic volume. The 1999 data were designed to enhance the imaging of the pre-Cretaceous reservoirs and help define areas of additional potential, which could be developed through new high angle platform wells. Mapping of reflectors below the Base Cretaceous Unconformity with the newdata remains problematical due to poor signal to noise ratio and short period multiples. Despite these difficulties, a revised interpretation of the crestal portion of the Judy structure was completed. This new interpretation was coupled with the results from a detailed review of the geochemical, pressure and fault seal data, to create a petroleum charge model which accounted for the variations in fluid types and contacts throughout the field and identified three fault blocks (30/7a-P16, P17 and P18) in the crestal portion of the field for infill drilling. The fault blocks were successfully drilled in 2001 and 2002 despite significant drilling challenges posed by depleted reservoir zones above the target formation.
Submarine fan morphology and lithology distribution: a predictable function of sediment delivery, gross shelf-to-basin relief, slope gradient and basin topography
Authors: HADLER-JACOBSEN F. , JOHANNESSEN E. P. , ASHTON N. , HENRIKSEN S. , JOHNSON S. D. , KRISTENSEN J. B. 
Published: April 2010

Over the last decade comprehensive exploration for turbidite plays has been rewarded by a significant number of hydrocarbon discoveries. However, the industry is still critically challenged with respect to appropriate and refined prediction of sand/shale distributions within these depositional systems. Along with a strong and sustained commercial interest in these plays, extensive subsurface datasets, including a new generation of core- and well/log-calibrated seismic facies suites, have become available.
Based on this valuable information, systematic 2D and 3D seismic sequence stratigraphical analysis with particular focus on seismic facies and seismic geomorphology was performed in five different basins along North and South Atlantic margins. Each subsurface example was characterized with reference to its relative sequence stratigraphic order within a hierarchy. Evolving geological parameters like shelf accommodation, shelf-break position, slope gradient, slope and basin bathymetry/topography and third-, fourth- and occasionally fifth-order stacking patterns were assessed within second-order cycles in each case. Based on these observations, recognition criteria for subsurface lithology prediction were derived. Conceptual knowledge from outcrop analysis was an essential and integral part of the interpretation process throughout the study.
The subsurface recognition criteria, highlighted in this study, emphasize similarity and variability between two end-member basin styles: high shelf-to-basin relief/sediment under-filled basins where sand-prone nearshore systems do not prograde over deep-water fan systems in a second-order cycle context; low shelf-to-basin relief/sediment over-filled basins where sand-prone nearshore systems do prograde over deep-water fan systems in a second-order cycle context.
The most striking contrast with respect to deep-water reservoir sandstone distribution in the two basin categories relates to the fourth- and fifth-order stacking patterns of fan building-block cycles within second- and third-order cycles, which tend to show low progradation/aggradation ratio in the high relief basins and high progradation/aggradation ratio in the low relief basins. Given an understanding of geological context, these seismically identifiable patterns provide more accurate prediction of sand and shale distribution within deepwater clastic systems.
The reservoir development of the Late Maastrichtian–Early Paleocene Ormen Lange gas field, Møre Basin, Mid-Norwegian Shelf
Authors: GJELBERG J. , MARTINSEN O. J. , CHARNOCK M. , MØLLER N. , ANTONSEN P. 
Published: April 2010

The giant Ormen Lange Gas Field is situated in the Møre Basin, Norwegian Sea, at water depths around 1000 m. The reservoir interval consists of a lower heterolithic unit mainly of Maastrichtian age (Jorsalfare Formation) and an upper sandstone unit of Danian age (Egga Member, Våle Formation), separated by a widely distributed mudstone unit (‘Våle Tight’), and consists of both high and low density turbidites in association with fine-grained background sediments. The reservoir interval spans the Cretaceous–Tertiary boundary, without any major stratigraphic breaks. The main architectural elements of the reservoir are: channel-dominated deposits, channelized lobe deposits and non-channelized frontal splay or fan fringe deposits. The spatial distribution of these facies elements indicates a dynamic system with changing sediment supply through time. Core and log studies from the wells have been integrated with high-resolution biostratigraphy to develop a dynamic depositional model.
During latest Cretaceous and Paleocene times, a series of subtle sub-basins developed along the southeastern Møre Basin margin as a result of differential subsidence above Jurassic extensional faults. The sub-basins created a stepped slope topography that influenced the flow pattern of turbidity currents.
In a landward position, east of the Ormen Lange Field, the Cretaceous–Tertiary boundary is characterized by a major unconformity, implying erosion and sediment by-pass. In early Danian time, uplift and rotation of the provenance area to the east (Norwegian mainland) led to extensive erosion and redistribution of sandy sediments into the Møre Basin and caused deposition of the Egga Member. The turbidites filled the intraslope basins initially in a basinwards-stepping sense, but later sedimentation switched landward.
Onshore structural, provenance and geomorphological data, combined with offshore structural, seismic and sedimentological data, yield an integrated interpretation of the deep-water depositional system in the greater Ormen Lange area. Present fjords at Møre, controlled by the Møre–Trøndelag fault zone, were valley systems that fed sands to a point source updip of the Ormen Lange area. The point source was located at the transition/relay zone between a narrow shelf area in the south and a broad shelf area in the north. In addition to being a key transition zone for both Caledonian and Jurassic structures, this zone area is also the ‘landing’ point of the major oceanic Jan Mayen Fracture Zone.
Using multicomponent seismic data to better characterize and manage reservoirs
Authors: KRISTIANSEN P. , WAGGONER J. 
Published: April 2010

Multicomponent seismic data (3C on land/4C on seabed) have unique information content that has proven to be useful in structural interpretation. As such, development of 3C/4C seismic acquisition, processing, and interpretation systems has increased over the past few years within the geophysical community. These improvements have shown that 3C/4C seismic information has application beyond structural interpretation, and can reveal internal reservoir characteristics that are directly useful in understanding and managing the reservoir.
After reviewing the principles, applications, benefits and recent advances in 3C/4C seismic technology, all from an engineering perspective, this paper concludes that 3C/4C seismic has utility beyond the known niche applications such as imaging beneath gas clouds, to applications with broader benefit, such as fracture characterization and drilling hazard identification, as well as better reservoir property prediction and the ability to discriminate lithology (sand/shale) and fluid (water, gas, fizzy water). These conclusions are illustrated with recent case studies.
Role of H2O2 in RET/PTC1 Chromosomal Rearrangement Produced by Ionizing Radiation in Human Thyroid Cells
Authors: Ameziane-El-Hassani Rabii , Boufraqech Myriem , Lagente-Chevallier Odile , Weyemi Urbain , Talbot Monique , Métivier Didier , Courtin Françoise , Bidart Jean-Michel , El Mzibri Mohammed , Schlumberger Martin , Dupuy Corinne 
Published: April 2010

Abstract
During childhood, the thyroid gland is one of the most sensitive organs to the carcinogenetic effects of ionizing radiation that may lead to papillary thyroid carcinoma (PTC) associated with RET/PTC oncogene rearrangement. Exposure to ionizing radiation induces a transient “oxidative burst” through radiolysis of water, which can cause DNA damage and mediates part of the radiation effects. H2O2 is a potent DNA-damaging agent that induces DNA double-strand breaks, and consequently, chromosomal aberrations. Irradiation by 5 Gy X-ray increased extracellular H2O2. Therefore, we investigated the implication of H2O2 in the generation of RET/PTC1 rearrangement after X-ray exposure. We developed a highly specific and sensitive nested reverse transcription-PCR method. By using the human thyroid cell line HTori-3, previously found to produce RET/PTC1 after γ-irradiation, we showed that H2O2, generated during a 5 Gy X-ray irradiation, causes DNA double-strand breaks and contributes to RET/PTC1 formation. Pretreatment of cells with catalase, a scavenger of H2O2, significantly decreased RET/PTC1 rearrangement formation. Finally, RET/PTC chromosomal rearrangement was detected in HTori-3.1 cells after exposure of cells to H2O2 (25 μmol/L), at a dose that did not affect the cell viability. This study shows for the first time that H2O2 is able to cause RET/PTC1 rearrangement in thyroid cells and consequently highlights that oxidative stress could be responsible for the occurrence of RET/PTC1 rearrangement found in thyroid lesions even in the absence of radiation exposure. Cancer Res; 70(10); 4123–32. ©2010 AACR.
Epidermal Growth Factor Receptor and Mutant p53 Expand an Esophageal Cellular Subpopulation Capable of Epithelial-to-Mesenchymal Transition through ZEB Transcription Factors
Authors: Ohashi Shinya , Natsuizaka Mitsuteru , Wong Gabrielle S. , Michaylira Carmen Z. , Grugan Katharine D. , Stairs Douglas B. , Kalabis Jiri , Vega Maria E. , Kalman Ross A. , Nakagawa Momo , Klein-Szanto Andres J. , Herlyn Meenhard , Diehl J. Alan , Rustgi Anil K. , Nakagawa Hiroshi 
Published: April 2010

Abstract
Transforming growth factor-β (TGF-β) is a potent inducer of epithelial to mesenchymal transition (EMT). However, it remains elusive about which molecular mechanisms determine the cellular capacity to undergo EMT in response to TGF-β. We have found that both epidermal growth factor receptor (EGFR) overexpression and mutant p53 tumor suppressor genes contribute to the enrichment of an EMT-competent cellular subpopulation among telomerase-immortalized human esophageal epithelial cells during malignant transformation. EGFR overexpression triggers oncogene-induced senescence, accompanied by the induction of cyclin-dependent kinase inhibitors p15INK4B, p16INK4A, and p21. Interestingly, a subpopulation of cells emerges by negating senescence without loss of EGFR overexpression. Such cell populations express increased levels of zinc finger E-box binding (ZEB) transcription factors ZEB1 and ZEB2, and undergo EMT on TGF-β stimulation. Enrichment of EMT-competent cells was more evident in the presence of p53 mutation, which diminished EGFR-induced senescence. RNA interference directed against ZEB resulted in the induction of p15INK4B and p16INK4A, reactivating the EGFR-dependent senescence program. Importantly, TGF-β–mediated EMT did not take place when cellular senescence programs were activated by either ZEB knockdown or the activation of wild-type p53 function. Thus, senescence checkpoint functions activated by EGFR and p53 may be evaded through the induction of ZEB, thereby allowing the expansion of an EMT-competent unique cellular subpopulation, providing novel mechanistic insights into the role of ZEB in esophageal carcinogenesis. Cancer Res; 70(10); 4174–84. ©2010 AACR.
Intravital Imaging Illuminates Transforming Growth Factor β Signaling Switches during Metastasis
Authors: Giampieri Silvia , Pinner Sophie , Sahai Erik 
Published: April 2010

Abstract
Transforming growth factor β (TGFβ) has seemingly contradictory roles in tumor progression: it can promote metastatic invasion but also act as a tumor suppressor. Recently, two studies have used intravital imaging to unravel the role of TGFβ at different stages of the metastatic process. TGFβ promotes single cell motility, which enables invasion into blood vessels. However the activation of TGFβ signaling is a transient event and is not maintained at distant sites. The downregulation of TGFβ signaling at secondary sites then permits growth of secondary tumors. In the absence of TGFβ, cells are restricted to collective movement and lymphatic spread. Here, we discuss these findings and their potential implications. Cancer Res; 70(9); 3435–9. ©2010 AACR.