bluuebunny/crossref_metadata_2025_split huggingface dataset:
Compulsion under the Mental Health Act 1983: audit of the quality of medical recommendations
Authors: Mason Julian , Roberts Hannah , Northridge Rebecca , Fountoulaki Garyfallia , Andrews Emma , Watcyn-Jones Cassie , Manion Terri , Chalmers Julie , Davison Phil 
Published: January 2012

Aims and methodTo audit the quality of medical recommendations for detention under the Mental Health Act 1983, Section 2 and 3. The recommendations were tested against a gold standard based on the statutory criteria. Two cycles were completed, the first containing 214 recommendations, the second 202. Relevant education took place after the first cycle.ResultsThe percentage of medical recommendations containing clear statements of why each of the statutory criteria was met increased in the second cycle. It reached 87% for mental disorder; 87% for nature and/or degree; 75% for why community treatment was not possible; 64% for why detention was in the interests of health; 60% for safety; 55% for protection of others; and 70% why informal admission was not possible.Clinical implicationsDoctors, scrutineers and approved mental health practitioners welcomed clear guidance about what is expected in a medical recommendation for detention and endorsed the gold standard described. Armed with a better understanding of what is expected and a template to follow, there was an improvement in the reasons given for detention.
An innovative service but will it work in practice? Commentary on … Fair Horizons
Authors: Tyrer Stephen Patrick 
Published: January 2012

SummaryThis commentary discusses the proposed service, Fair Horizons, a new development designed to ensure comprehensive mental healthcare coverage. Although the aims of the new service are laudable and derive from recent seminal papers on changes in the National Health Service, the proposed initiatives are so far untested and there is uncertainty about how far costs will be reduced under this new system. Success is more likely to result if clinicians are committed to the new service and work harder.
Added Value From High-end NMR Measurements to Reservoir Characterization: MREX deployment in GB field a Case Example
Authors: Udofia Abasiubong , Uguru Chukwuma 
Published: January 2012

Abstract
There was not a little apprehension within the GB Team when Baker_Hughes service reps informed the team that their nuclear magnetic resonance tool, the MRIL (Magnetic Resonance Image Log) was no longer available and was being replaced by their new tool, the Magnetic Resonance Explorer(MREX). Understandably, the discomfort lay in the fact that at the time the new tool was as yet untested in the African region and the subject well GU10 was a key well whose results would define the Nodal Development strategy for the nearly $2billion GB Integrated oil and Gas project. The uncertainties to be resolved by the GU10 well were the reservoir development, quality and character in the untested western flank of the field, the fluid type below the "Gas Down Tos" (GDTs) recorded for two key reservoirs, hydrocarbon-water contacts and the producibilityof the gas reservoirs. The classification of two key reservoirs either as non-associated gas (NAG) or associated gas (AG) was the critical uncertainty that impacted the most on development options. Though it shares the credit with an assortment of other tools, the MREX as promised, played a key role in reducing these uncertainties through providing lithology independent porosity and permeability as well as precise fluid typing that has been corroborated by samples taken from the same well. The results are shared in this paper and indicate that the target reservoirs, theD6 and the D8 have significant oil rims whose volumetric and economic significance must be assessed and possibly developed before the gas caps become available as feedstock for Nigeria’s LNG projects.
Case Study: Innovative Application Of Automated Drilling System With Hybrid Coiled Tubing Drilling Rig Excels In Cost-Sensitive Environment
Authors: Hadiputro Bimo , Corson Carl , Toner Troy , Doubek Lindsey , Fernandez Frank 
Published: January 2012

Abstract
Having explored many methods to improve efficiencies in conventional drilling processes, operators in the traditional North American land market are ever more attracted to innovative and cost effective means to drill wells. These innovative operators have turned to coiled tubing directional drilling (CTDD), with its promising inherent efficiencies in tripping and connection times, and with its smaller, logistically simpler footprint to optimize the drilling process even further. New downhole drilling technologies found in the conventional drilling arena are being applied to this operation to overcome the intrinsic limitations associated with the non-traditional slide-only drilling method associated with coiled tubing drilling. Together with innovative modifications to traditional CT rigs to address the fit-for-purpose needs of drilling, this novel approach to cost reduction is being applied in a cost-sensitive land market in the Rocky Mountain region of the US.
This paper provides an overview of the drilling application faced by the operator, of the specialized hybrid Coil Tubing drilling rig and of the novel application utilizing the modern, non-rotating rib-steering downhole drilling tools. The paper will benchmark the performance of the built-for-purpose operation compared to previous wells drilled with conventional rigs and directional motors, as well as other CTD systems. Additionally, a well to well performance of the drilling operation over a multi-well period will be evaluated, together with a discussion on lessons learned and a presentation of potential future improvements. The application of automated drilling systems with coiled tubing drilling heralds in a new age in developmental drilling in low spread cost markets.
Worldwide Pore Pressure Prediction: Case Studies and Methods
Authors: Tang Haixiong , Luo JunFeng , Qiu Kaibin , Chen Yingru , Tan Chee Phuat 
Published: January 2012

Abstract
The paper presents methods and multiple examples of published case studies of pore pressure prediction in worldwide deepwater exploration. The case studies show that seismic data were mostly used to carry out predrill pore pressure prediction, especially for wildcat frontier areas. It is critical to process seismic data to obtain more reliable fit-for-purpose velocity models and to apply appropriate pore pressure models. Real-time updating with newly acquired data allows the uncertainties of the predrill pore pressure prediction to be reduced ahead of the bit. This paper gives a brief introduction on worldwide deepwater exploration activities, provides a summary of the most common and frequently used pore pressure and fracture gradient methods, and captures best practices on pore pressure prediction for deepwater exploration.
Capturing Composition Variation in a 3,800-ft- Thick Gas Condensate Reservoir: How We Done It
Authors: Ryzhov Sergey , Tan Tina Lee , Ratanavanich Suvaluck , Tongpenyai Yothin 
Published: January 2012

Abstract
Conventionally, to define variation in fluid composition one needs to have results of a compositional laboratory study for each reservoir in the field or in a fault block of the field. The number of composition determinations, however, can be reduced if there is a clear depth or stratigraphic trend that allows interpolation of composition between available determinations. None of these, unfortunately, could be applied in the case of the studied field. This field is located in the Gulf of Thailand and is associated with a horst-graben pair of fault blocks that represent an alteration of some 50 sandstone reservoirs saturated with gas, gas condensate, and oil. The productive interval is subdivided into five main zones and the total thickness of all zones exceed 1000 m. In addition, the field is subdivided into two fault blocks that more or less double the number of individual hydrocarbon accumulations. Three pressurevolume-temperature (PVT) samples were taken in the field but full set of PVT experiments was performed for only one. For the other two, laboratory analysis was limited to the composition study.
With the limitations imposed by the data availability, an alternative approach to PVT characterization had to be introduced. It was based on the results of production data analysis and used a map of production condensate-gas ratio (CGR) prepared by production engineers to guide the composition variation in the field. Close cooperation between reservoir and production engineers from both the operator and service company was the key factor allowing successful implementation of this alternative.
Stick Slip Mitigation Plan to Improve Drilling
Authors: Zakuan Ahmad , Junaida Azreen , Subroto Bramanta , Hermawan Heru , Fatakh Abdul , Halim Abdul 
Published: January 2012

Abstract
Drilling performance becomes inefficient by the presence of vibrational effect which is stick and slip. This situation is a source of failure which reduce penetration rate, increase operating time, and contribute to increase drilling operating costs.This is due to the surface alternating between sticking to and sliding over each other, with a corresponding change in the force of friction. Only if kinetic friction is bigger enough to encounter this static friction, it can cause a sudden jump in the velocity of the movement, condition characterized by fluctuations in the rotational speed of BHA. The main objective is to come out with a solution in reducing stick and slip.First, the problem is encountered by means of the alignment of different drilling parameters, such as rotary speed, drilling torque and weight on bit. This conventional control technique required expertise from driller. Second, by introducing a roller reamer, the more effective control methodology. Roller cutters from the roller reamer rotate around the wall and it is able to provide low torque point of stabilization. It transforms the interaction between borehole and contact points by introducing a low-friction bearing between BHA and borehole wall.As a result, implementation of roller reamer shows the constant transmission of rotational energy, thus able to improve the weight to the bit. Two offset wells have been selected for this case study, with well #1 exercising conventional method while well #2 makes use of roller reamer. Stick slip effect reduces from 180% srpm to 30% srpm. Furthermore, it is able to save 40% of drilling time on that particular section. This paper focuses on the practical solution by implementing roller reamer to mitigate stick slip effect base on actual field scenario. A comparisons and conceptual models are provided as well as the illustration of its configuration.
Managed Pressure Drilling Enables Drilling Beyond the Conventional Limit on HP/HT Deepwater Well
Authors: Arnone M.. , Toralde J.. , Carr D.. 
Published: January 2012

AbstractThis paper describes some successful applications of Managed Pressure Drilling on exploration wells drilled in deep waters. Building upon successful experience utilizing MPD from HPHT jack-up wells, the Operators transferred the experience across to deepwater exploration projects.Extensive engineering, training and development of procedures were carried out prior to spud for each project. Specific techniques were developed to handle floating drilling operations. The resulting benefits associated with MPD led to improvements in drilling performance, and eliminated many of the traditional problems faced on other HPHT wells in the area. MPD has now become an integral part of the well operating philosophy and has established new standards for drilling wells of this type in the area.Some critical wells were classified as wildcats with considerable pore pressure unknowns, coupled with narrow pore-fracture drilling window characteristic of HPHT conditions. MPD was able to minimize the problems faced on the wells by enabling various techniques to be utilized. These techniques included the use of pressure build up analysis to quantify formation pressures, the application of dynamic flow checks, dynamic formation strength limits, and the application of constant bottom hole pressure during dynamic and static drilling fluid circulation conditions. The planning, development and execution phases of the MPD projects are detailed in this technical paper.
Extending the Life of Mature Field by Light Workover Cementing Technique
Authors: Hadiaman Farid , Neto Nilo Bianchi 
Published: January 2012

Abstract
Handil field is a giant mature oil field in Indonesia. It’s been producing since 1975, being the current recovery factor for oil 49% and 57% for gas. Cumulatively, the total oil produced is around 855 MMstb and gas around 1.68 Tcf. Today, oil is being produced at 20,000 bopd, gas at 75 mmscfd and water at 130,000 bwpd.
Enhanced oil recovery projects, infill wells and light workover of existing wells are key elements to maintain field production. This paper describes an innovative light workover intervention, called Annular Squeeze Cement that helps keeping Handil field production performance at its best level.
It covers the field study analysis that led to this the technique, some precautions and current challenges concerning the cementing operation as part of light workover activity. It also share lessons learnt from the field execution and evaluation. A case study is also presented for a full understanding how this cementing placement technique contributes to the field performance.
This technique was successfully implemented and acts also as one of the important element to extend the life of a giant mature field where economic and success ratio becoming a paramount parameter.
Successful Approach of Scale Cleaning Using Organic Dissolvers To Delay Scale Re-Deposition at Pariwali Well # 5: A Case Study
Authors: Rana Muhammad Arif , Ahmed Riaz-ud-din , Dar Afnan A 
Published: January 2012

Abstract
Production drop caused by down hole scale deposition is becoming a serious problem not only in wells producing with high water cut but also in deep, hot, sour gas wells with very low water cuts(trace to 6%).
This paper presents a case study of CaCO3 & CaSO4 scale deposition in a sour well in north of Pakistan that resulted in substantial production drop. HCl (15%) was used to dissolve/wash the scale obstruction in the tubular and clean the perforation of well. Although the treatment was successful in dissolving the scale and restoring the production, yet these production gains were lost rapidly. Scale dissolver treatments followed by scale inhibitions were also implemented but no appreciable results were achieved. A detailed in house study was carried out by POL for scale analysis and its removal techniques. Scale monitoring by produced water analysis, gauge cutter runs, production & WHFP fluctuations, gas analysis and review of seven scale cleaning jobs guided to carry out organic scale dissolving job.
It was concluded that 15% HCl acid pumped to dissolve the scale precipitate out due to increase in PH and Bi Carbonate decomposition caused by CO2 evolution. Scale removal with organic dissolvers (Acetic acid) proved successful because it maintained low PH which prevented re-precipitation of acid products. With this approach scale re-deposition was delayed ranging from nine days to nine months.
Experimental and Numerical Investigation of Steam Flooding in Heterogeneous Porous Media Containing Heavy Oil
Authors: Ashrafi Mohammad , Souraki Yaser , Tor Joergen Veraas , Karimaie Hassan , Torsaeter Ole 
Published: January 2012

Thermal recovery methods and especially steam flooding have long been considered as the most effective methods to unlock heavy oil reservoirs. These highly viscous hydrocarbon deposits are proven to constitute a huge proportion of total world oil reserves. Large volumes of heavy oil are located in heterogeneous porous media containing high permeable wormholes or non-permeable shale barriers. High permeable zones can be the results of sand migration in loose and unconsolidated sandstones. There is a question of how these non-homogeneities can possibly enhance or hinder the flow of high viscous oil, steam and condensed water under a steam injection process.
This paper addresses experimental and simulation study of steam flooding in heterogeneous porous media that contains Athabasca heavy oil. Some PVT properties of Athabasca crude oil have been measured experimentally and simulation study was accomplished using a numerical thermal reservoir simulator. A horizontal layer of high porosity and permeability was assumed in the middle of a core to verify the performance of steam injection in a 20 cm long sandstone core with a permeability of 640 mD saturated with Athabasca heavy crude. High permeable zone had a permeability of 5 D. Different shale barrier configurations were also considered to examine the effect of these no flow layers. Considering a heterogeneous system, sensitivity analyses were focused on the effect of injection rate, porosity, permeability contrast and thickness of high permeable zone. Different steam temperature and quality cases for core flooding experiment in this system were also investigated.
The most important conclusion is that there is an optimum steam temperature and quality for most efficient steam injection. It was figured out that shale barriers in the model can hinder the flow of oil and cause high residual oil, but their impact is dependent on permeability distribution in the core.
The permeability contrast between the high and low permeable layers should be smaller considering both oil production and steam oil ratio (SOR), which is a measure of economy. Although core permeability of 640 mD provides satisfactory recovery and SOR, higher permeability can cause faster recovery and lower SOR, since the injection can stop earlier. Porosity of the model is found to have an inverse relation with the oil recovery and SOR. Results also clearly show that higher injection rates improve the oil recovery. However, SOR should also be considered at the same time. There is a trade-off between recovery and SOR. It is also clear that lower thickness for the high permeable zone results in better recovery while causing high injection pressure at the inlet. This corresponds with lower permeability contrast case.
Improving ESP LifeTime Performance Evaluation by Deploying an ESP Tracking and Inventory Management System
Authors: Bougherara N. E. , Ahmed K. Si , Algdamsi H. A. 
Published: January 2012

Abstract
One of the most popular and efficient artificial lift mechanisms is the electrical submersible pump (ESP). According to recent statistics, there are more than 100,000 ESPs worldwide. With the increasing number of wells equipped with ESPs, operators are making substantial efforts to improve ESP performance and achieve longer runlife. The primary focus has been on tracking ESPs sensors real-time data, along with failures prediction as proactive measures. It is however, still difficult to keep track of historical ESP pull and run jobs, ESP equipments, and benchmark pump runlife. Typically there are no structured datastores for ESP movements. ESP runlife statistics are stored in multiple individual spreadsheets and are resource-intensive to compile.
This paper presents a solution that enables to track within database software ESP operations, equipments movements and failures along with classical production data to enable better ESP lifetime evaluation and equipments management. The solution encompassed ESP operations and equipment tracking within a next-generation production volumes management system. The software and database were expanded to ensure that data was generated through a single point of reference, so that operators could capture and store downhole and surface equipments tracked via serial-number along with operations details and failures. ESP runlife, failure and equipment statistics were also calculated and reported graphically. More accurate ESP lifetime was calculated using well production uptime, installation and pull dates. Using these key statistics, the asset team was able to benchmark equipments and vendors. Each time the team needed to design or redesign an ESP, the solution enabled them to browse current and historical production, ESP operations, and both installed and warehoused equipments data. Used equipments historical installations can be tracked to make informed decisions before any reinstallation in other wells. In addition, the solution allows through reports to track wells with longer pull operations time providing input to improve rig workover planning. In summary, the proper capture, validation, data browsing, and accurate performance evaluation enabled by the pilot solution reduced routine work time, positively impacting the asset team. More time could thus be dedicated to recurrent problems identification, in-depth investigations for remedial actions for underperforming ESP wells.
A Current Mapping and Predicting of Indonesian Flow Assurance Challenges Based on Fluid Physical Characteristics
Authors: Nengkoda Ardian , Supranto Supranto , Sulistyo Hary , Prasetyo Imam , Amijaya Hendra 
Published: January 2012

Abstract
A domain of "flow assurance" is a key concern in the oil and gas industry, and refers to the need to guarantee the flow of oil or gas from reservoirs to processing facilities in the face of a number of engineering challenges, especially in offshore environment. The Indonesian next future exploration and production predicting to be more to deep water offshore, remote production, floating gas production-supply and will face more difficult fluid impurities to be dealt with such increasing volume of produced water, inorganic/ organic scale, mercury and H2S/ CO2. As preliminary, a comprehensive quick review of production and operational problems across the regions both onshore and offshore and PVT fluid data base have been done. These early information on fluid physical characteristics and chemistry can be beneficial to see the potential of tight emulsion, hydrate problems, inorganic scale precipitation or asphaltene/ wax deposition. It is important for flow assurance perspective, to gather all lesson learnt across the offshore production, where these information can be useful for the next future oil and gas exploration and production strategy. As one case, for example, in one of the offshore field in East Kalimantan and Madura East Java, the emulsions were unusual tight where oil-water are difficult to separate and creating a process up set and in the end, creating such lost of production. However, if we look detail across regional geological basin, the emulsion tendency from formation fluids of offshore Kalimantan ever been identified. Furthermore, in the deepwater environment especially, the produced fluids tend to cool significantly, thereby losing the benefit of heat-induced demulsification and causing waxes to precipitate start from downhole, sub sea, trough the surface facilities. The initial base line study have been performed to pick early flow assurance problems base on quick fluid physical characteristic and chemistry from early stage exploration sampling (DST or MDT/PVT). It involves an "integration work flow" of understanding better the physical fluid characteristics from the reservoir and its journey from pore to process facility and it relations to production flow assurance problems. Other important production chemistry and flow assurance issues from Indonesia oil and gas offshore production that being addressed include: gas hydrate, inorganic scale, emulsion, H2S/ CO2 corrosion, reservoir souring (due to waterflood), asphaltene and wax deposition and mercury corrosion. Finally, as a finding, basic reservoir fluid information can be link to the future production problems and flow assurance study has an important role in maximizing the production and minimizing the facility bottle necking.