bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Effect of Three Nursing Interventions on Thermoregulation in Low Birth Weight Infants
Authors: Lewis Debra A. , Sanders Lynda P. , Brockopp Dorothy Y. 
Published: November 2011

ABSTRACTPurpose: The primary aim of this study was to evaluate the use of three nursing interventions—occlusive wrap, chemical mattress, and regulation of delivery room temperature—singly and in combination in consecutive years on thermo-regulation in six groups of low birth weight infants.Design: A quasi-experimental design was used. Prospective data were collected on 133 infants weighing <1,500 g. Interventions were tested on different groups of infants in each of three years. The control group comprised 295 infants on which retrospective chart data were available over an earlier three-year period.Sample: Infants weighing <1,500 g participated in the study.Main Outcome Variable: The main outcome variable was NICU admission temperatures of infants weighing <1,500 g. For data analysis, infants were divided into two groups: those weighing <1,000 g and those weighing between 1,000 and 1,500 g.Results: For each of the three interventions, the percentage having a normal NICU admission temperature in each intervention group exceeded the control group percentage, but the increase was not significant. Use of each intervention—occlusive wrap alone, occlusive wrap in addition to chemical mattress, and occlusive wrap in addition to chemical mattress and increased delivery room temperature—appeared to influence thermoregulation positively.
Capillary Blood Draws in the NICU
Authors: Phillips Charles , Clifton-Koeppel Robin , Sills Jack , Lomax Jacqueline M. , Rapini Molly , Huffman Matt L. , Modanlou Houchang D. 
Published: November 2011

ABSTRACTPurpose:(1) To determine the rate of damaged and discarded capillary blood draws in the NICU; (2) to compare the rate of damaged and discarded samples between traditional capillary blood draws and the Innovac Quick-Draw device; (3) to determine whether in-service training for nurses on capillary blood draws decreased the rate of damaged and discarded blood samples.Design:During Phase I of the study, the rate of capillary blood draws by the traditional method was determined. At the completion of Phase I, the manufacturer provided in-service training to senior nurses in the NICU with the use of the Innovac Quick-Draw device. Additional in-service training was also provided for the traditional capil-lary blood draw technique. Within a month of in-service training, an openly randomized study (Phase II) was carried out comparing traditional versus Innovac device capillary blood draws.Sample:All infants admitted to the NICU between June 2008 and June 2009 were eligible to be in the study. There were no exclusion criteria based on weight, gestational age, or gender because the sampling method was the only variable being assessed. Phase I lasted two months, whereas Phase II lasted approximately four months.Main Outcome Variable:Occurrence of damaged capillary samples with the Innovac device versus the traditional method.Results:In Phase I, the rate of damaged and discarded samples was 10 percent (28/278). In Phase II, the rate of damaged and discarded samples for traditional and Innovac device was 7.2 percent and 10 percent, respectively. Comparisons between traditional and Innovac for different type of samples were as follows: complete blood count, 11.0 percent (12/104) vs. 13.4 percent (14/104); serum electrolytes, 6.4 percent (6/94) vs. 9.5 percent (9/95); C-reactive protein, 5.7 percent (4/70) vs. 8.0 percent (5/62); and liver panel, 5.3 percent (7/131) vs. 8.3 percent (9/108). There were no statistically significant differences of damaged and discarded samples for the overall or individual sample type comparisons.
Raising the Bar in Completion Practices in Jonah Field: Channel Fracturing Increases Gas Production and Improves Operational Efficiency
Authors: Turner M. , Weinstock C. , Laggan M. , Vogel M. , Rondon J. , Bogdan A. , Peña A. 
Published: November 2011

Abstract
The Channel Fracturing technique was introduced for multi-stage well stimulation in the Jonah Field in 2010. 622 stages have been pumped with this novel technique since. Production increases by as much as 27% (Johnson et al., 2011) have been realized over conventional completion methodologies. In this previous study, each stage was flowed back immediately after each treatment.
The successful introduction of the Channel Fracturing technique prompted a new attempt to optimize completion practices by eliminating immediate flowback of each stage as a necessary step to sustain production performance goals (Cramer, 2008). A field study was conducted to evaluate the performance of five new wells stimulated with the Channel Fracturing technique combined with sequential fracturing treatments without flowback in between stages. Gas production, fluid flowback and treating pressure data was gathered and compared against a sample of 18 offset wells stimulated with conventional proppant placement with immediate flowback after each stage.
Results indicate that the Channel Fracturing technique increased production by up to 28% with respect to the control group. Production gains were obtained without the occurrence of screen-outs for the wells stimulated with Channel Fracturing. Improvements in operational efficiency due to continuous fracturing operations and avoidance of screen-outs led to a reduction in overall operational costs of 18%. Results show that the combination of Channel Fracturing with sequential stage stimulation within a single wellbore can mitigate previously documented production performance issues, reduce operational logistics and reduce the overall impact to the hydraulic fracturing footprint. By virtue of these benefits, well stimulation via multi-stage Channel Fracturing without flowback in between stages has been adopted as a completion practice of choice for wells in the Jonah field.
Cuttings and Waste Injection, Shale Fracturing Pressure Decline, and Domain Mapping
Authors: Shokanov T. , Ronderos J. 
Published: November 2011

Abstract
The rapid expansion of cuttings and waste injection operations into major E&P regions throughout the world, and millions of barrels of drilling cuttings and waste injected in complex shale formations dictate understanding of uncertainties regarding its actual downhole placement and footprint in so-called disposal domain. The disposal domain is defined as area of influence created by hydraulically induced fractures that accumulate the bulk volume of cutting solids from repetitive cuttings slurry injections.
In spite of outstanding milestones achieved by cuttings and waste injection in recent years, the subsurface risks involved demand constant assessment to ensure thorough understanding of the injection and complex fracturing process. Limited understanding and characterization of the hydraulically induced fractures and waste domain footprint could potentially have a considerable environmental impact.
Understanding of past assessments of the cuttings and waste injection disposal domain provides alternative means of reevaluating shale gas complex hydraulic fracturing. This involves past assessments of multiple fracturing complex systems along the lines of the uniform disposal domain and a system of interconnected dendrite fractures with bifurcations from the flank of the fracture, and its evaluation in terms of minimum and maximum in-situ stress change in a localized near-wellbore fracture area, in distance perpendicular and along the preferred fracture plane.
This paper presents a comprehensive review of the historical waste disposal domain evolution from early developments -- the Mounds Drill Cuttings Experiment (MDCE) by Moschovidis et al. (2000) -- to current understanding derived from microseismic observations in the Barnett, Haynesville and Marcellus shale gas fracturing. Particular discussion is presented around the presence of fissures in shale formations and its impact on refracture initiation, extension and branching, together with an alternative assessment of the disposal domain from microseismic observations that took place during the MDCE. In addition, non-ideal bottom-hole pressure signatures reported in the past from observations during regular cuttings and waste injection are re-visited and re-aligned within a complex disposal domain model. Explanations and understanding of pressure anomalies are discussed.
The paper demonstrates that a true level of assurance and risk control can be achieved for cuttings and waste injection disposal (and also shale gas fracturing for stimulation) around mapping of the fracture - waste disposal - storage capacity via proactive integration of pressure monitoring and analysis with microseismic. This is the valuable information required by environmentalist and regulatory authorities to ensure that fracturing for disposal can be performed in an environmentally safe and technically sound manner.
Maximizing the Resources by Managing the Risks among Oil, Gas and Coal Production
Authors: C Bakhtiar Nofti , Imantyoko Agung , Adnan Alkifli 
Published: November 2011

Abstract
Indonesia has many fossil fuel resource fields widespread in its territory. Some of them located at Kalimantan, shore and offshore. Commonly, exploration & production (E&P) of oil & gas are different area than coal mining, but in fact in many areas overlap of mining. One is the field Tapian that overlaps between the sectors of E&P oil and gas to coal. Government of Indonesia intends to produce all the fossil fuels in order to encourage the economic stability and development. To produce all the fossil fuels resource is complexs. Oil & gas sector and coal mining sector are different activities. It's related with many issues such as mining zone restrictions, funding, the handover of assets and also health, safety & environment. It's challenging to compromise and mitigate each sector impact so all the E&P fuels can be achieved. Tapian area is the most good success story how to manage and coordinate all the risk so the E&P of oil, gas and coal mining can be realized. It's all started with negotiating the Plan of Development (POD) of each sector, discussion, lobby, risk assessment and ended with Memorandum of Understanding (MOU) of all sectors that involved. Pertamina also attempted to mitigate all the risks that exist. Some of them include blasting effect, slope stability, road access safety, increasing settlement & social friction, water scarce, environment quality and lighting "attack". With the good management and precaution, both sector succes to mitigate all the risks. Nowadays, Tapian is producing approximately 197 BOPD, 0.246 MMSCFD of gas and 20 MT coal per year.
How "Fracture Conductivity is King" and "Waterfracs Work" Can Both be Valid Statements in the Same Reservoir
Authors: McDaniel B. W. 
Published: November 2011

Abstract
Having worked in the field of Hydraulic Fracturing for forty years has allowed the author an opportunity for close observation of several cycles of conceptual applications of hydraulic fracturing. In 1970, the oilfield was using quite a plethora of varying frac fluids from Slick Water to heated asphalt, gelled diesel, emulsion frac fluids, linear gels, and a few crosslinked fluids, although there was some separation between applicable fluids for gas reservoirs and oil producers.
By the mid-1970’s we had witnessed the death of heated asphalt as a frac fluid while emulsion fluids and Slick Water fracs were mostly put out to pasture. The age of the crosslinked gels had begun to dominate most of the fracture stimulation technology landscape, mostly because it was judged that this fluid type was able to suspend and place high concentrations of proppant. The emphasis on achieving high Fracture Conductivity with more effectively propped fractures became dominant. The 1980’s saw the industry fracturing technology and laboratory testing migrate toward more realistic test conditions for evaluation of packed proppant bed conductivity, especially with longer testing times, using elevated test temperatures, and by the latter part of the decade to incorporate the presence of frac fluids and their residue.
However, in the late 1980’s, a few operators in tight sandstone applications in East Texas started re-inventing Slick Water fracs. Even though pumping rates and treatment volumes were 2x- to 4x larger than previous crosslinked gel fracturing treatments, they typically were placing only 15–25% of the proppant volume, yet claiming improved well economics. To add further consternation, in the next decade, George Mitchell found a unique application in the Barnett Shale for Slick Water fracs and eventually showed the world that some of these hydrocarbon-source shales can actually be commercial producers themselves.
This paper will discuss much of the "frac fluid history" mentioned above, review historical highlights of laboratory fracture conductivity testing and field applications trying to illustrate the need for high conductivity as investigators began finding much lower predicted conductivity as they began seeking to emulate insitu reservoir conditions. Back then and still today, we continue to ask: Are we abandoning one of our most significant beliefs, Fracture Conductivity is King, every time we use Waterfracs?
Analysis of the First CHOPS Pilot for Heavy Oil Production in Kuwait
Authors: Sanyal Tirtharenu , Al-Sammak Ibrahim 
Published: November 2011

Abstract
Heavy oil contribution is considered a key requirement for delivering the challenging 2030 strategic production targets of Kuwait. Different production technologies have been considered for meeting this challenge. Initially the cold production technology of CHOPS (Cold Heavy Oil Production with Sand) has been tried through a pilot. The present paper summarizes the performance of the first CHOPS pilot performance and analysis of the pilot results. The analysis of the performance data from the pilot provides important clue for understanding the reservoir description issues as well as sand production characteristics. The result of the study has relevance for sand management strategies in the planned future thermal development of the field as well. The wealth of information available from the pilot helps developing an improved dynamic reservoir description.
The paper demonstrates that the CHOPS process has an intimate relationship with rock mechanics, fluid viscosity and the flow potential of the formation. It is also demonstrated how the field surveillance data can be used to investigate the enigmatic subject of "Foamy Oil" (Alshmakhy et al. 2007). The results can also help in developing an improved completion strategy for the wells, especially in the area of sand management. The paper provides important field performance data and analysis of the CHOPS pilot performance from Kuwait that can be used for taking decisions on applicability of the process in other similar reservoir set ups. The analysis also helps firming up an optimized sand management strategy for this reservoir.
Sweep Efficiency Improvement by Alkaline Flooding for Pelican Lake Heavy Oil
Authors: Dong Mingzhe , Ma Shanzhou , Li Aifen 
Published: November 2011

Abstract
In this paper a laboratory study was reported for investigating a method to improve sweep efficiency by applying alkaline flooding for Pelican Lake reservoir. This included interfacial tension measurements, micromodel observatios and channelled sandpack flood tests. In total, 48 flood tests were conducted in channelled sandpacks to evaluate the chemical formulas and injection strategies for Pelican Lake oil. The first 14 sandpack flood tests were carried out to assess the potential of the alkaline flooding for the oil. The results suggested that 0.4 wt% NaOH and 0.2 wt% Na2CO3 was the optimum combination to maximize the oil recovery efficiency in the channelled sandpacks. Based on industry interest in using a NaOH-only slug injection, in the second step 34 flood tests were conducted with the injection of only NaOH solution. For Pelican oil, 0.6 wt% NaOH was the optimum concentration to maximize the oil recovery efficiency (~15% IOIP recovery) in NaOH-only injection. The sandpack flood results obtained in this study showed that formation of water-in-oil dispersion and improvement of sweep efficiency in channeled sandpacks did occur in the tertiary recovery process through the injection of NaOH-only solution.
Potential Sinks for Geological Storage of CO2 in Saskatchewan
Authors: Derakhshanfar M. , Nasehi M. , Ahmadi F. , Baimyrza Z. , Sherk G. 
Published: November 2011

Abstract
Geological storage of CO2 in underground formations has the potential to be a major component of any viable solution to reduce atmospheric emissions of greenhouse gases. There are different options for long-term storage of CO2 in subsurface formations currently being considered by both government and industry. In general, the potential sinks for geological storage of CO2 include storage in depleted oil and gas reservoirs, deep saline aquifers, coal beds and salt caverns as well as injection for enhanced oil recovery (EOR). Suitable geological conditions as well as availability of CO2 sources provide a vast potential for geological storage of CO2 in Saskatchewan, Canada.
This paper examines and summarizes the potential sinks for geological storage of CO2 in Saskatchewan. More specifically, the potential for CO2 storage in locations throughout Saskatchewan along with estimated storage capacities are discussed in detail. The possible sinks in each storage category have been identified through creation of a database of the available information, screening the sinks according to the appropriate criteria for each category, and evaluating their potential in terms of CO2 storage capacity. The database includes a significant number of oil pools in different stages of development, saline aquifers, and coal beds throughout Saskatchewan. Southeastern Saskatchewan contains deep saline aquifers in addition to several light and medium oil pools which offer a great potential for CO2 EOR and storage. Extensive unmined coal beds also exist in the southern and western parts of the province which can be possible candidates for coal bed methane production and CO2 sequestration. The identification and analysis of the potential sinks for geological storage of CO2 in Saskatchewan will contribute towards the development of integrated CCS infrastructure. This will also help to meet climate change mitigation objectives by reducing CO2 emissions through developing practical applications for geological storage of CO2.
Modeling In-Situ Upgrading of Extraheavy Oils/Tar Sands by Subsurface Pyrolysis
Authors: Kumar Jitendra , Fusetti Luc , Corre Bernard 
Published: November 2011

Abstract
In order to enhance extra heavy oils and tar sands recovery, steam injection has become popular as it decreases bitumen viscosity via increase of formation temperature. However, such process comes with some drawbacks such as the necessity to dispose of substantial nearby quantity of water, the impossibility to 100% recycle this water, and the co-generation of a significant quantity of acid gases. Moreover the resulting hydrocarbons are still extra heavy oil/bitumen with all the constraints it implies in terms of pipe transport and refining.
For these reasons, the development of the process of In-Situ Upgrading (IUP) by Subsurface Pyrolysis is debated. The idea would be to sufficiently heat the formation in order to pre-upgrade the oil in-situ; instead of just temporarily decreasing its viscosity. The process can be highly energy consuming but would offer multiple potential advantages such as production of a higher quality product with already a high commercial value, reduction of required infrastructure and expenses on production site for dilution or pre-upgrading before pipe transport, and no use of water, etc.
This study presents the feasibility of such IUP process by performing a core experiment under reservoir conditions. First, a compositional kinetic model is developed in order to correctly predict the products composition during pyrolysis; which is then validated using laboratory data. This is a key element in an IUP process as the results of kinetic model gives an idea of better designing the core experiment, who can properly mimic reservoir behavior. The experimental results are promising in terms of upgraded oil production i.e. light cuts, acid gases, pyrobitumen with proper thermal front propagation. It showed that with time and temperature there will be production of large quantity of light components, light cuts, and while generated pyrobitumen will remain be in the core. This means that at constant temperature, sufficiently higher for pyrolysis; longer the duration of the experiment more will be the production of light cuts due to cracking of heavy components. These results provide key elements to extend the approach to a larger scale for field test application.
Effect of Heterogeneity in a Horizontal Well With Multiple Fractures on the Long-Term Forecast in Shale Gas Reservoirs
Authors: Nobakht M. , Ambrose R. , Clarkson C. R. 
Published: November 2011

Abstract
Shale gas reservoirs have become a significant source of gas supply in North America owing to the advancement of drilling and stimulation techniques to enable commercial development. The most popular method for exploiting shale gas reservoirs today is the use of long horizontal wells completed with multiple-fracturing stages (MFHW). The stimulation process may result in bi-wing fractures or a complex hydraulic fracture network. However, there is no way to differentiate between these two scenarios using production data analysis alone, making accurate forecasting difficult.
For simplicity, often hydraulic fractures are considered bi-wing when analyzing production data. A conceptual model that is often used for analyzing MFHWs is that of a homogeneous completion; in which all fractures have the same length. However, fracture lengths that are equal in length are rarely if ever seen (Ambrose et al., 2011).
In this paper, production data from heterogeneous MFHW (i.e., all fracture lengths are not the same) drilled in extremely low permeability reservoirs is studied. First, the simplified forecasting method of Nobakht et al. (2010) developed for homogeneous completions is extended to heterogeneous completions. For one specific case, the Arps decline exponent is correlated to the heterogeneity of the completion. It is found that Arps’ decline exponent to be used after the end of linear flow increases with the heterogeneity of the completion. Finally, it is shown that ignoring the heterogeneity of the completion can have a great effect on the long-term forecast of these wells.