bluuebunny/crossref_metadata_2025_split huggingface dataset:
CREB3 subfamily transcription factors are not created equal: Recent insights from global analyses and animal models
Authors: Chan Chi-Ping , Kok Kin-Hang , Jin Dong-Yan 
Published: February 2011

Abstract
The CREB3 subfamily of membrane-bound bZIP transcription factors has five members in mammals known as CREB3 and CREB3L1-L4. One current model suggests that CREB3 subfamily transcription factors are similar to ATF6 in regulated intramembrane proteolysis and transcriptional activation. Particularly, they were all thought to be proteolytically activated in response to endoplasmic reticulum (ER) stress to stimulate genes that are involved in unfolded protein response (UPR). Although the physiological inducers of their proteolytic activation remain to be identified, recent findings from microarray analyses, RNAi screens and gene knockouts not only demonstrated their critical roles in regulating development, metabolism, secretion, survival and tumorigenesis, but also revealed cell type-specific patterns in the activation of their target genes. Members of the CREB3 subfamily show differential activity despite their structural similarity. The spectrum of their biological function expands beyond ER stress and UPR. Further analyses are required to elucidate the mechanism of their proteolytic activation and the molecular basis of their target recognition.
Place of Cabergoline in Acromegaly: A Meta-Analysis
Authors: Sandret Laure , Maison Patrick , Chanson Philippe 
Published: February 2011

Context:
Cabergoline is widely considered to be poorly effective in acromegaly.

Objective:
The aim of this study was to obtain a more accurate picture of the efficacy of cabergoline in acromegaly, both alone and in combination with somatostatin analogs.

Design:
We systematically reviewed all trials of cabergoline therapy for acromegaly published up to 2009 in four databases (PubMed, Pascal, Embase, and Google Scholar). We identified 15 studies (11 prospective) with a total of 237 patients; none were randomized or placebo-controlled. A meta-analysis was conducted on individual data (n = 227).

Results:
Cabergoline was used alone in nine studies. Fifty-one (34%) of the 149 patients achieved normal IGF-I levels. In multivariate analysis, the decline in IGF-I was related to the baseline IGF-I concentration (β = 1.16; P &lt;0.001), treatment duration (β = 0.28; P &lt; 0.001), and baseline prolactin concentration (β = −0.18; P = 0.01), and with a trend toward a relation with the cabergoline dose (β = 0.38; P =0.07). In five studies, cabergoline was added to ongoing somatostatin analog treatment that had failed to normalize IGF-I. Forty patients (52%) achieved normal IGF-I levels. The change in IGF-I was significantly related to the baseline IGF-I level (β = 0.74; P &lt; 0.001) but not to the dose of cabergoline, the duration of treatment, or the baseline prolactin concentration.

Conclusion:
This meta-analysis suggests that cabergoline single-agent therapy normalizes IGF-I levels in one third of patients with acromegaly. When a somatostatin analog fails to control acromegaly, cabergoline adjunction normalizes IGF-I in about 50% of cases. This effect may occur even in patients with normoprolactinemia.
The State of Crayfish in the Pacific Northwest
Authors: Larson Eric R , Olden Julian D 
Published: February 2011

Abstract
We summarize the state of knowledge on crayfish in the Pacific Northwest region of the United States and Canada, emphasizing distributions and conservation status of native species, as well as known introductions and distributions of alien crayfishes, and reviewing fishing regulations relevant to crayfish across five states and provinces. We found the present distribution and ecology of native crayfishes in this region to be poorly known, inhibiting accurate conservation assessments and management. The number of alien crayfishes established in the region, ranging in distribution from localized to widespread and including several major invasive species, now exceeds the diversity of native crayfishes. The treatment of crayfish by fishing regulations and laws varies among states and provinces, potentially impairing successful management and conservation of these species in shared ecosystems such as the Snake and Columbia rivers. We conclude with recommendations for crayfish management and regulation, and a call for more research on the ecology of crayfish in the Pacific Northwest.
The Aquarium Trade as an Invasion Pathway in the Pacific Northwest
Authors: Strecker Angela L , Campbell Philip M , Olden Julian D 
Published: February 2011

Abstract
The aquarium trade moves thousands of species around the globe, and unwanted organisms may be released into freshwaters, with adverse ecological and economic effects. We report on the first investigation of the ornamental pet trade as an invasion pathway in the Pacific Northwest region of the United States, where a moderate climate and a large human population present ample opportunities for the introduction and establishment of aquarium trade species. Results from a regional survey of pet stores found that the number of fish (n=400) and plant (n=124) species currently in the aquarium trade is vast. Pet stores import thousands of fish every month, the majority of which (58%) are considered to pose an ecological threat to native ecosystems. Our propagule pressure model suggests that approximately 2,500 fish (maximum 21,000 individuals) are likely released annually to the Puget Sound region by aquarists, and that water temperatures in many parts of Washington are suitable for establishment of populations. In conclusion, the aquarium trade may be a significant source of past and future invasions in the Pacific Northwest, and we recommend enhanced public education programs, greater regulation of the aquarium industry, and improved legislation of nonnative species in the ornamental trade.
Unique Hydrajet Tool Provides Cost Savings and Improved Performance in Placing Many Perforations and Proppant Fractures in Horizontal Wellbores
Authors: Van Gijtenbeek K. A. , Surjaatmadja J. B. , Heitman C. 
Published: February 2011

Abstract
Hydrajet perforating and subsequent fracturing-stimulation placements using jointed pipe to sequentially create many propped fractures in a horizontal well can be challenging. When proppants are pumped through hydrajetting equipment for initial cutting and then also for the fracturing operation, tool failures could occur, possibly leading to a situation whereby the complete bottomhole assembly (BHA) needs to be replaced several times during these treatments. A service provider conducted an extensive analysis of some of these failures that revealed multiple damage mechanisms that could lead to internal and external erosion of the hydrajetting equipment. This analysis resulted in the design and construction of a new-concept hydrajetting tool that addresses these erosion issues adequately. This has been demonstrated by several recent case histories showing that the newly designed tool drastically outperformed the old-style tools, resulting in considerably fewer requirements for BHA replacements throughout the job. In fact, most cases have only required one trip in the hole, even for very large proppant volumes being pumped. This has provided considerable cost savings to the well operators.
Application of Nitrogen Foam for Profile Modification in a Heterogeneous Multi-layer Sandstone Oilfield
Authors: He Liu , Peng Ye , Wei Li , Li Song , Yan Zhong 
Published: February 2011

Abstract
Daqing Oilfield is a heterogeneous multi-layer sandstone oilfield. The main pay zone of the oilfield has entered into high water-cut (over 90%) development stage after more than 30 years of water injection. According to intrusive mercury tests on 104 pieces of sealed coring samples, permeability increased by 32% after water flooding; the pore volume increased by 5.9%. This may indicate a change in pore structure affected by long-term water injection. In thick layers, water bypasses oil and flooding efficiency decreases.
Fine geology research results show that in main pay zones and thick layers of non-main pay zones, there are certain amounts of remaining oil. Vertically, the remained oil gathers on the top of positive rhythm thick formations. For this portion of the remaining oil, it is difficult to develop by conventional stimulation measures. Therefore, study on nitrogen foam injection technology was carried out to control fingering. Core experiments indicated that nitrogen foam injection is suitable for enhancing oil recovery rate of heterogeneous reservoirs. Field pilot gave positive results.
This paper briefly introduces profile modification mechanism of nitrogen foam to control fingering and enhancing oil recovery rate. Static tests of foam adaptability to temperature, salinity, and oil saturation are evaluated in the paper.
Nitrogen foam can select automatically the high permeability zone and high water cut layer and realize fluid diversion after foam plugging, and then the gas component may provide gravitational differentiation when the foam bubbles break off, so as to increase the sweep volume and enhance the flooding efficiency[1][2] [3] [4] [5]. At present, Sabei Oilfield in Daqing has entered into the extra high water-cut development with its total water-cut up to 96%. Vertically, the water out behavior in layers differs greatly and massive water injected advances suddenly along high permeability positions, resulting in serious channeling. Therefore, in view of the geologic characteristics and fluid properties, three sets of foam system are developed, and the field pilots for nitrogen foam injection technology to control water fingering are conducted successively in Xing 7-1-33 and Bei 2-Ding 2-59 well cluster in Sabei Oilfield.
Understanding First, Simulation Later: Using Basic and Modern Reservoir-Engineering Techniques to Understand Reservoir Dynamics: A Proven Case
Authors: Alonso Gomez 
Published: February 2011

Abstract
In this paper is described a mature field in which water production is seen very early on in production life and rapidly increased to the current level of 80%. At well level a similar behavior has been a noticed, high initial oil rates with subsequent strong decline once water breakthrough occurs. This type of behavior has been observed in most of the wells completed among the different reservoirs that make up the field. Long term production data and modern decline analysis strongly indicated the presence of two systems in the reservoir.
Initially it was considered normal water production behavior. Petrophysical interpretation indicated the presence of five different facies. The production data was imported directly into the simulation model and with some "adjustments" a reasonable match was achieved. This resulted in highly optimistic forecasts, never reproduced by the new wells. This paper presents an analysis and explanation of the production behavior observed in the field. Which proved to be in line with the subsequent acquisition of field data. Indicating the reservoir shows a behavior similar to a dual porosity dual permeability one, with two systems dominating the production behavior in the wells.
This paper shows how important it is to have a strong understanding of reservoir dynamics before using 3D reservoir simulation models, and specially in this case, how the use of simple and modern analytical techniques, like for instance Chan plots, transient tests, conventional and modern decline analysis among others, can provide the reservoir engineer with a enough background to confidently take the next step. This paper also describes how pseudo-steady state calculations provided information regarding the characteristics of the second system. Which helped to optimize the original petrophysical interpretation in the static model. This represents a simple approach at the time to consider how detailed a geological model should be to reproduce production behavior.
This work had a direct impact on completion strategies and future IOR projects to be evaluated through the use of reservoir simulation, and it clearly represents a new "way of thinking" by integrating and making sense of different analytical techniques as input for building new models (static and dynamic). Similar production behavior has also been observed in other fields in the same area, which can be explained following the methodology here presented.
Improved Technique for Wireline Oil Sampling of a Tight Carbonate Reservoir in the Partitioned Zone (Kuwait/Saudi Arabia): A Case Study
Authors: Omar Mosaad Hamdalla , Bouyabes Ahmed , Al-Haimer Mohamed Salem , Al-Busairi Ahmed , Boon Cheng Cheong , Rampurawala Mansoor Ali , Hussein Azhar 
Published: February 2011

Abstract
The South Fuwaris Field is located in the Partitioned Zone of Kuwait and Saudi Arabia. The main reservoir is the Lower Cretaceous Ratawi, which commenced production in 1963. The reservoir is an elongated anticlinal structure, with good porosity (15-20%) but low permeability (1-10 md). The Ratawi Oolite was historically ranked as a lower priority compared to Ratawi Limestone due to poor productivity from the vertical wells. In recent years, the well performance has improved significantly through the use of open hole horizontal wells and Electric Submersible Pumps (ESPs). The reservoir is currently undergoing further development, with critical reservoir inputs being reviewed to enhance the reservoir model. One of the key model uncertainties is related to oil properties, as no representative PVT samples had been available.
Multiple attempts to collect downhole oil samples using Wireline Formation Tester (WFT) in this reservoir had failed due to low formation permeability, low fracture density and high pressure drawdown. A new technique was developed from comprehensive review of log and core data including:
Nuclear Magnetic resonance (NMR) for identification of mobile hydrocarbons, presence or absence of bitumen, estimation of oil viscosity, pore size distribution and permeability with core data integration. Review of sonic and core data to optimise perforation design. Open hole perforation in the zone of interest to bypass the damaged zone, increase the area open to flow and intersect natural fractures. Reduction of perforation damage due to mud reinvasion, through reduction of hydrostatic overbalance (from WFT pressure data) and the replacement of the wellbore mud system with clean completion fluid, during perforation and sampling operations.
This paper presents a case study of successful downhole oil sampling in a very tight carbonate reservoir through the use of innovative techniques and detailed job planning. The potential of applying this technique to heavy oil reservoirs within our asset portfolio is under evaluation.
Numerical Study of PDL-Induced Fracture-Face Damage Using a Fracturing Mimicator
Authors: Gdanski Rick 
Published: February 2011

Abstract
Simulations with a fit-for-purpose fracture-cleanup model have previously explored the impact of matrix relative-permeability quality on cleanup and productivity in tight-gas sands. Gas-water relative-permeability curves that have a crossover in the range of 0.1% of rel-perm have a region of "rel-perm jail." Previous simulations demonstrated that water invasion in such situations can cause cleanup problems. However, a low rel-perm quality should also act as a fluid-loss-control mechanism during fracturing, thereby preventing deep invasion in the first place. The fracture-cleanup model was upgraded to mimic fracturing treatments to explore the impact of rel-perm quality on fluid efficiency, fluid invasion, and cleanup. The model explored certain aspects of pressure-dependant leakoff (PDL) that might bypass rel-perm jail restrictions.
The causes and prevention of poor-performing fracturing treatments in tight-gas sands have plagued the industry, with many mechanisms suggested and various solutions attempted as cures. Verifying the mechanisms and solutions often requires a trial- and-error approach because of the physical and chemical complexities involved. This model has a unique capability of exploring physics of flow and chemical physics of overall complexity that cannot be effectively studied in the laboratory. The upgraded model was used to study a new mechanism by which PDL might induce fracture-face damage.
Fracturing and PDL were successfully modeled using the method of pressure-dependant porosity and permeability for the fracture and matrix. Details of the method are presented. Simulations show that in the absence of PDL, poor quality rel-perms provide effective fluid-loss control and should prevent deep-matrix invasion. Under certain circumstances, PDL can bypass the fluid-loss-control mechanism causing rel-perm-induced matrix damage once the fracture has closed. Fortunately, there is currently no strong evidence that this damage mechanism is common.
Petrophysical Evaluation for Enhancing Hydraulic Stimulation in Horizontal Shale Gas Wells
Authors: Buller Dan , Hughes Simon , Market Jennifer , Petre Erik , Spain David , Odumosu Tobi 
Published: February 2011

Abstract
The economic recovery of gas from shale reservoirs requires optimal multistage hydraulic stimulation in horizontal wells. Important parameters to consider in shale-gas evaluation include gas-filled porosity and total organic content. Mechanical rock properties, including a calculated brittleness index, along with mineralogy, are also required to target and design individual horizontal fracture stages in the best zones. This type of formation evaluation in horizontal wells requires careful correlation and calibration to petrophysical measurements obtained in either vertical pilot holes or direct offset wells. This paper presents a comprehensive approach to the evaluation of an unconventional resource play drilled in the Haynesville Shale in east Texas.
Using openhole and logging-while-drilling (LWD) logs, conventional core analysis, and a chemostratigraphy analysis of drill cuttings, a shale analysis linking mineralogy, free gas, effective porosity, a shale brittleness index, and a clay linked transverse anisotropy is verified on separate vertical and horizontal control wells. Beyond that, pulsed neutron spectroscopy logs were run to develop a cased-hole evaluation solution from N-N (neural network) modeling that could replicate openhole wireline or LWD logs, and chemostratigraphy mineralogy results.
Subsequently, two horizontal wells were logged with LWD tools and afterward, through casing, using the pulsed neutron log and neural network calibration. Fracture stages for the logged horizontal wells were then evaluated vs. the log data. Generally, lower normalized treating pressures per fracture stage are noted where lower clay volumes exhibit less transverse anisotropy and a higher calculated shale brittleness index. Radioactive tracer and production log data also confirm lower amounts of gas production from zones that are apparently fractured, but are more ductile and clay-rich.
Production Enhancement of Hilly Terrain Onshore Remote Field
Authors: Hanbzazah Shadi M. , Merwat Mohammed N. , Al-Khamis Mohammed N. 
Published: February 2011

Abstract
Developing and producing remote fields in a hilly terrain environment economically and effectively poses a great challenge to oil operators1. Transporting hydrocarbon fluids in these fields from the wells to the processing facilities and then to shipping terminals requires a detailed assessment of the flow hydraulics of the entire production network2–6. Moreover, a viable optimizing flow option needs to be considered and thoroughly evaluated prior to implementation for cost optimization, effectiveness and long-term impact on reservoir sweep7.
Saudi Aramco has recently embarked on the development of several fields, including remote fields, such as Shaybah, which is located in a remote, hilly terrain desert area in the Empty Quarter of the Arabian Peninsula. The crude from Shaybah oil producing wells must travel a long distance from wellheads located in Sabkhah (flat terrain) to the Gas-Oil Separation Plant (GOSP), passing across high sand dunes rising up to 200 meters, and then through a 638 km cross- country pipeline to reach a final stabilization facility. Due to the aberrant topography of the area, high back pressure and changes of flow regime leading to huge slugs have been observed, affecting the overall performance of the wells and the operation of the processing facilities. Consequently, three innovative technologies: Horizontal Thrust Boring (HTB), Multiphase Pumps, and Drag Reducing Agents, have been evaluated and implemented to circumvent these problems.
This paper will discuss in detail the realized benefits from these three technologies where results have shown a reduction in the flow and pipeline pressure drops of 230 psig and 300 psig from the application of HTB and drag reducing agents, respectively. Moreover, an overall production increase of about 50 thousand barrels of oil per day (MBOD) was realized from the utilization of HTB technology and an incremental increase of 250 MBOD in the capacity of the 638 km cross- country pipeline from the utilization of the drag reducing agent. On the other hand, the results of the trial test of the multiphase pump have indicated unsatisfactory performance due to the frequent maintenance needs and pump failures.
Evaluating Hydraulic Fracture Effectiveness in a Coal Seam Gas Reservoir from Surface Tiltmeter and Microseismic Monitoring
Authors: Johnson Raymond L. , Scott Michael P , Jeffrey R. G. , Chen Zuorong , Bennett Les , Vandenborn Craig , Tcherkashnev Sergei 
Published: February 2011

Abstract
In developing new coalbed methane (CBM) or coal seam gas (CSG) fields or reservoirs, the effect of many parameters are important in understanding the success or potential areas for improvement of hydraulic fracturing treatments. Estimating fracture geometry relative to the reservoir architecture is critical to understanding production variability. The Walloon Coal Measures, in the Surat Basin of Eastern Queensland, Australia, are a complex reservoir containing interbedded sandstone, siltstone, carbonaceous shale and coal seams where initial attempts at hydraulic fracturing in early pilot areas of the Surat Basin yielded poor results. Thus, when a hydraulic fracturing program was planned for this reservoir, it was decided to integrate a group of diagnostics that would be useful in understanding past results as well as deriving future improvements.
Data is presented from two wells in the Walloon Sub Group (WSG) where tiltmeters and microseismic monitoring were used to evaluate fracture effectiveness relative to the reservoir architecture and to assist further design work. The treatments carried out in the studied wells were typical of CSG frac treatments used in other producing areas, incorporating stages of treated, gelled and crosslinked-gelled water with increasing concentrations of sand, up to six (6) lbm/gal. During the treatments, complex fractures were inferred based on analyses of data from both tiltmeter and microseismic monitoring methods. The collaborative data set for these wells also included a large amount of other analyses and diagnostic data. It was only possible to fully explain the treatment results through the combination of multiple diagnostics and an in-depth understanding of how the created fracture interacted with the complex reservoir and stress environment.
In this paper, we outline the steps used to plan the monitoring program and describe how geological data was integrated to better understand the results observed during the treatments. We describe each of six (6) stages performed across the two wells, and how the diagnostics did or did not support the overall conclusions as to the effectiveness of each stage. Finally, this paper presents a logical framework to evaluate and integrate these technologies for use in future CSG well stimulation.