bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unconventional Shale Gas Development: Application of USA Key Success Factors to other Countries in International Markets
Authors: Zeid A. , Lee J. 
Published: November 2016

Abstract
The USA began exploiting unconventional gas resources 40 years ago, eventually leading to a domestic shale gas production increase from 4% to 56%, 2005 to 2015. Many countries and major oil and gas companies strive to match this success.
Using public information to research USA key success factors helped establish a holistic framework to assess and expedite shale gas development in other countries. This framework is intended for international market experts now guiding their countries and companies toward similar success. The framework has been applied to China and Poland to provide highlights, lowlights and specific recommendations for conditions in those countries.
The analysis splits six factors into two categories: 1) subsurface factors related to exploration, development, drilling and fracturing of the prolific shale-system; and 2) technical and non-technical surface factors including the involvement of the State (which has consistently directed and stimulated unconventional gas development), the roles of oil companies and service companies, the availability of required materials and water and the related logistical capability, and the gas market and infrastructure.
The findings highlight the importance of abandoning conventional oil and gas mindsets and processes in favor of proven unconventional shale gas development approaches.
CO2 Storage in the Nisku Aquifer in the Wabamun Lake Area, Canada - The Effect of Site Characterization Data on Caprock Integrity Modeling
Authors: Goodarzi S. , Settari A. 
Published: November 2016

Abstract
The geomechanical factors put significant constraints on CO2 storage in terms of injection pressures that may be limited by fracture propagation, injection rates that can be achieved without compromising the seal and excessive fracture propagation, and the CO2 placement affected by fracturing.
Goodarzi et al (2012) investigated the feasibility of securely storing CO2 in Nisku geological formation located in Wabamun Lake area (Alberta, Canada) using a coupled flow, thermal and geomechanical model. Due to lack of field and lab measurements, the results of the study were reported as pessimistic. This paper utilized recently recorded well log, well test and lab measurements specific to the study area to build porosity, absolute and relative permeability, thermal, mechanical property and stress profiles required for refining the results of the aforementioned study.
The results show that injection in the Nisku aquifer (below or at fracture pressure with 1–2 Mt/year) causes only small surface heave in the range of 2–3 mm. Injection above the fracture pressure at 2 Mt/year results in higher well injectivity but also increases the possibility of caprock fracturing. The degree of vertical propagation strongly depends on the caprock stress state and mechanical properties. The importance of the proper site characterization is highlighted by comparison of our current results with our earlier work on the same site reported in Goodarzi et al. (2012), in which estimates were used for many parameters. The predicted fracture dimensions based on updated fluid and rock mechanical properties in the current work are significantly larger than the dimensions reported in the 2012 study. The primary reason for this is the lower initial fracture pressure and higher stiffness of the reservoir rock formation used in this study.This causes smaller fracture width and lower leak-off which will be compensated by larger extent of fracture both horizontally and vertically..
Thermal effects of cold CO2 injection reduce significantly the fracture pressure and enhance the horizontal fracture propagation. The vertical extension of fracture in the thermal model was shown to be smaller than in the isothermal model due to the confining stress contrast created by thermoelastic stresses. This in turn resulted in larger horizontal propagation of fracture in the thermal model. The reduction of fracturing pressure due to thermal effects will reduce the well injectivity if the well is to be operated below fracture pressure, and increase fracture propagation if fracturing is allowed. This aspect needs to be taken into account by operators as well as by regulatory agencies. If it is required to operate below fracturing, the time-variation of fracture pressure under injection condition can be determined using geomechanicaly coupled model and its historical minimum value should be taken as the maximum operating pressure.
Thin Oil Rim Development Challenges and Opportunities for a Carbonate Reservoir in Offshore Abu Dhabi
Authors: Khoury P. Al , Ali M. Abou , Hassall J. K. , Sinha A. K. 
Published: November 2016

Abstract

Objective
It is challenging to increase oil recovery from a reservoir with a thin oil rim and large gas cap after a long depletion of the gas cap. Gas or water breakthroughs are commonly seen and are responsible for disappointing oil recovery. The development becomes more challenging when resources are needed to control depletion and maintain reservoir pressure.
This paper deals with challenges encountered in developing a thin oil rim and compares the recovery of the development scenarios.

Methods, Procedures
The field under study is an offshore Carbonate reservoir consisting of multiple stacked thin porous layers separated by less porous layers. The gas cap was developed first, as at that time the oil rim was only poorly understood, and its potential was not fully recognized. Oil development only started after a prolonged period of gas depletion. Post depletion, gas injection has been introduced to control the depletion and to permit further development of the oil rim. The process followed in this study is summarized as follows:

Results
A representative fit for purpose sub-surface model to capture the high reservoir heterogeneities and the dynamic behavior was crucial.
It is demonstrated that despite the challenges inherent in this reservoir, it will be possible to increase the oil recovery. A number of locations for new oil production wells are identified and these allow recovery of additional oil through sustainable production.
Zones of high CGR in the reservoir are a good target to enhance condensate production. For gas recovery reservoir pressure is the main factor controlling recovery.

Novel/Additive Information
This paper shows that despite the early depletion of the gas cap there is a room to enhance oil rim recovery of thin oil rim reservoirs underlying extensive gas caps, by means of a development which targets remaining oil, complemented by injection to control reservoir pressure depletion or Low well head pressure system to produce from low pressure reservoir.
The post gas cap production scenario shows that theoretically there is an opportunity to recover oil after gas cap production.
The Positive Impact of Operations Excellence in the Management of Aging Facilities
Authors: Hall G. F. , Cuthbert T. , Geraghty A. , Chamberlain M. A. 
Published: November 2016

Abstract

Executive Summary
National oil companies are being increasingly challenged on how they manage assets running beyond their design life. In the Middle East alone there are 700-800 fixed offshore platforms and bridges, of which more than 70% are older than 25 years (DNV, 2016). In the past costs attributed to poor asset integrity management were minimal compared to the profit margins attained, but as income diminishes as it has in the last two years, the costs become too great and inefficiencies are highlighted. As a result the optimisation of life extension has to be an integral part of asset strategy.
Knowing where best to invest in assets, and where to reduce costs, can be tricky and confusing without comparable information to hand. It has therefore become increasingly important for operations to be driven by a central strategy that aligns everyone to the same objectives and priorities.
So how should oil companies refocus their strategies then on the challenge of managing ageing assets?
Frequently consultants comes across operators lacking a co-ordinated approach to their ageing asset. The solution involves a three pillar approach to deliver Operations Excellence based on the individual assets concerned.
Asset Life Extension Management (ALEM) Production Excellence Maintenance Excellence
A study of the asset's situation is followed by a project implementation in these three workstreams built around a central and co-ordinated strategy. Based on previous projects this has proven highly beneficial for operators by extending the life of the asset in a cost effective manner, increasing production by 10-20%, and reducing operations Capital Expenditure by 15-25%. However, the result of implementing Operations Excellence is not only improved performance but more importantly provides the Client with clear and concise information in order to make well-informed decisions on where to best invest and get the most buck from their assets. Developing human capital in line with this new strategy is critical for success.
Findings and Challenges of High Permeability Zone on Water Injection Pilots in Iraqi Carbonate Reservoirs
Authors: Liu Lang , Zheng Xiaowu , He E , Liu Fang , Luo Hong 
Published: November 2016

Abstract
Mishrif carbonate formation is widely developed in Iraq and other areas of Middle East. When it comes to carbonate reservoir water injection development, the high heterogeneity commonly existed in carbonate reservoirs makes water flow complicated and performance of water injection differed from reservoir to reservoir. The existence of high permeability stripes and zones would make the problem more complicated and always result water early break through and poor sweep of the reservoir. Water injection pilots started recently in Mishrif carbonate reservoirs in M Field and N Field in southern Iraq. The objectives of these pilots were to investigate the feasibility to conduction water flooding in the Mishrif carbonate reservoirs, including test the injectivity and its change through time, sweep efficiency, responses from offset producers, investigate the methods that can be applied to tackle the problems brought by high permeability zones in water injection. The pilots were carried out in two different well patterns in the two fields, one is inverted nine spots pattern and the other is vertical-horizontal well pattern with vertical well as injector. In one pilot, separated injection was applied to avoid water channeling and improved producer performance. 3D numerical model was applied to track and monitor water sweep during the pilot. It was found out that directional connectivity and high permeability zones were developed in these reservoirs and resulted in early water breakthrough and quick increase of water cut in offset producers. This effect impact vertical and lateral sweep greatly and lower recovery potential in future field water flooding development if not well learned and handled. The challenges are to make description of these directional connectivity and distribution of high permeability zones in reservoir description and modeling and find effective ways in field operations to avoid the negative impact of them in field scale water flooding. To tackle the challenges, integrated reservoir study of multi-discipline is necessary in order to make full description of high permeability zones and reservoir heterogeneity and understand their mechanism on water sweep. It is suggested to pay additional attention to high permeability zone as a key factor in reservoir development of these kinds of reservoirs and integrated the study results into the design of field development plan in an early stage, to narrow the uncertainties brought by them and reduce development risks.
A Novel Water Control Method for Erd Wells in Fractured Carbonate Using Chemical Zonal Protection
Authors: Ghosh Dr. Bisweswar , Adi Samhar 
Published: November 2016

Abstract
Fractured carbonate reservoirs are prone to premature water cut production at the early stage of water flood recovery. Conventionally completed long horizontal wells, suffering from high water cut through fractures need reliable, cost effective and out-of-the-box treatment solutions to control water entry, without damaging oil saturated segments. In such cases, polymer gel squeeze in the conventional way is not the option as the gel treatment needs damage protection of oil producing zones, which is a difficult task because of the complexity of fracture geometry and the enormity of the number of zones that may seek protection. This paper describes an approach in which mechanical zonal isolation devices is substituted by self-selective chemical isolation technique, designed for carbonate formation which can enable the water shutoff treatment to be performed without deployment of costly work-over rig. Through extensive laboratory investigation a three-chemical system is developed, to be placed in a sequence. The first fluid is designed to protect the low permeable and presumably zones of high oil saturation, by creating an impermeable filter cake while the water conductive fractures remain open for further treatment. This would be followed by a second fluid, designed to invade, solidify and seal off the fractures. The third fluid is a bio-enzyme chemical breaker designed for uniform degradation of the filter cake on matrix zones created by the first fluid and bring the well back to production. In laboratory simulated core flood studies, excellent production profile is achieved. Depending on the fracture geometry, effective brine permeability is reduced by 74 – 91% while the oil effective permeability is reduced only by 12 – 17%. Finally, the paper discusses the key elements for field implementation in terms of fluid composition, pumping pressure, flow rate and onsite monitoring, and also suggests the downhole equipment necessary to improve the success rate.
Development of New Smart Drilling Fluids Using Nano-Materials for Unconventional Reservoirs
Authors: Li Shulian , Osisanya Samuel , Haroun Mohammed 
Published: November 2016

Abstract
Drilling fluids used for accessing unconventional reservoirs need new focus because the fluids used to exploit conventional reservoirs need without some modifications or new formulations. New smart-fluid formulations were developed and optimized using nano-materials. Three nano-materials were added to the generic water-based fluids. Scanning electronic microscope tests were performed to check the size quality of the nano-materials. Rheology properties, pH and filtration tests were performed to evaluate the smart drilling fluids. Mud cakes formed by each smart drilling fluid were collected and scanned.
For practical field applications, the smart drilling fluids were tested against two rock samples by performing dispersion, barite sag and aging (stability) tests. The rocks were characterized using scanning electronic microscope (SEM), cation exchange capacity (CEC) and adsorption tests. Results showed that the developed fluids exhibited excellent rheological properties and the filtration losses were reduced after adding nano-materials. Mud cakes formed by each smart drilling fluid were collected and scanned. Thin, tight, and well textured mud cakes were formed. The mud cakes' thicknesses were reduced significantly after adding nano materials. The barite sag tests indicated the fluids to be excellent for cutting suspension. No sedimentation was observed after aging for three days, which indicated a good cleaning and suspension of drilled cuttings. The rheology and filtration properties of smart drilling fluid system remained stable under static condition after three days of aging. Results showed reduced shale dispersion, excellent suspension capacity, and stability. The cost comparison between the developed smart drilling fluids with nano-materials and base (generic) drilling fluids shows that that the smart fluids are relatively inexpensive even though they are excellent for preventing wellbore instability and for used in the environmentally sensitive areas.
Use of Advanced Molecular Microbiology Methods to Manage Microbial Corrosion Issues in Topside Facilities.
Authors: Poulsen Morten , Sanders Peter Frank , Thomsen Uffe Sognstrup , Lundgaard Thomas 
Published: November 2016

Abstract

Objectives/Scope
Microbial growth in topsides facilities (water injection, oil production and distribution systems) is a widely recognized phenomenon leading to a range of impacts, for instance microbiologically influenced corrosion (MIC). MIC typically occurs as localized pitting and can develop rapidly (and measured in mm per year), leading to unexpected production shutdowns, environmental impact due to leaks, major unplanned repairs and increased chemical treatment costs. In severe MIC cases, the system may even need to be replaced, sometimes with corrosion resistant alloys, with marked economic consequences to operators. The threat of MIC has traditionally been very difficult to assess due to its rapid, localized, nature and due to the challenges of getting reliable information about microbial communities from system samples.

Methods
Recent advances in molecular microbiology technologies, particularly with respect to next generation sequencing technologies and quantitative PCR assays targeting functional and phylogenetic marker genes, have now made it possible to reliably identify and quantify a range of oilfield MIC-related microorganisms.

Results and Conclusions
Through case studies, this paper demonstrates how these molecular microbiology technologies can be used for monitoring, diagnosing and managing MIC on a routine basis focusing on key MIC indicator organisms and applying new approaches to interpret the MIC threat from the derived data. This paper furthermore suggests how MIC assessments can be integrated into existing corrosion management programs to target and tailor mitigation actions, minimizing the overall risk related to MIC.

Novel/Additive Information
These new advanced molecular microbiology tools, if properly integrated in corrosion management programs, hold potential for improving asset protection and cost savings for oilfield operators.
Benefits of Integrated Design of Gas Processing Units to Achieve Optimal Project Economics
Authors: Chilukuri Pavan , Bowerbank Gary 
Published: November 2016

Abstract
The development of natural gas reserves containing harder-to-remove sulphur species has increased in recent years, while sulphur limits for treated gas and stack sulphur dioxide (SO2) emissions have continued to tighten. This combination has resulted in significant increases in the complexity of acid gas removal units (AGRU) and sulphur recovery units (SRU). With standalone designs for AGRUs and SRUs, licensors may be able to optimise the process units individually. However, based on Shell's experience as licensor and operator, additional capital and operating expenditure benefits can be realised through integrated AGRU and SRU designs.
This paper focuses on the value of integrated process line-ups aimed at: creating new cost-effective modes of operation;reducing plant complexity;dealing with a wide range of feed gas contaminant uncertainties; andmeeting stringent emission requirements.
The case studies below illustrate how the above benefits can be achieved by using a structured integrated approach to gas processing designs: using a heated flash in the AGRU to create a better quality acid gas feed to the SRU;integration of AGRU/acid-gas enrichment unit (AGEU) off-gas with SRU tail gas treating (TGT) units to handle benzene, toluene, ethylbenzene and xylene (BTEX) destruction effectively in SRUs; andcascading of semi-lean solvent from the Shell Claus off-gas treating (SCOT®) absorber to the main AGRU absorber.
Implant Gigi One-Piece vs Two-Pieces dalam Praktek Sehari-Hari
Authors: Kurnia Dian Lestari , Ramadhani Amilia , Hudyono Rikko 
Published: November 2016

Saat ini, implant merupakan pilihan terbaik untuk menggantikan gigi yang tanggal, akan tetapi prosedur pemasangannya terbilang rumit dan memerlukan prosedur bedah kedua untuk pemasangan prostetik. Beberapa komplikasi seperti screw patah atau longgar dan adanya celah mikro pada batas pertemuan implant dan abutment dapat menyebabkan kegagalan implant. Studi kasus ini bertujuan untuk membahas mengenai keuntungan dan kerugian desain implant gigi one-piece dan two-pieces. Kasus pertama, seorang wanita berusia 43 tahun datang untuk mendapatkan perawatan implant pada region 16. Ketinggian tulang alveolar yang tersedia adalah 5 mm. Prosedur pengangkatan dasar sinus transalveolar dilakukan dengan pemberian allograft sebanyak 0,5 cc dilanjutkan dengan pemasangan implant gigi one-piece sepanjang 12 mm. Kasus kedua, seorang wanita 24 tahun datang untuk mendapatkan perawatan implant pada regio 46. Ketinggian tulang alveolar yang tersedia adalah 12 mm, kemudian dilakukan pemasangan implant gigi two-pieces sepanjang 10 mm. Implant gigi one-piece menawarkan berbagai keunggulan yaitu: hanya diperlukan sekaliprosedur bedah dan prosedur prostetik lebih sederhana. Desain ini juga meniadakan celah mikro pada perbatasan implant dan abutment. Desain implant gigi one-piece memiliki keterbatasan pada pilihan prosedur prostetik apabila dibandingkan dengan desain implant gigi two-pieces. One-Piece Versus Two-pieces Tooth Implant In Daily Practice. Implant had been a gold standard to replace missing tooth. However, implant marketed today was considered complex, and needs a second surgery. Complications may occur such as screw loosening or fracture and the presence of micro gap at implant-abutment-junction that is found causing fixture failure. The one-piece-implant design may offer some advantages. Purpose: this paper was aimed to discuss the pros and cons of one-piece-implants and two-piece-implants. Case 1 A 43-year-old woman came to place an implant on #16. The available bone height was 5 mm. A trans alveolar sinus lift procedure was performed with 0,5 cc allograft. A 12 mm one-piece-implant was inserted. Case 2 A 24-year-old woman came to place an implant on #46. The available bone height was 12 mm and a 10 mm two-piece-implant was inserted. Discussion: One-piece-implant offers some advantage. It needs no second surgery, easier placement protocol, and more natural prosthetic procedures. The design is preventing the failure in implant-abutment-junction failure. The absence of micro gap in one-piece-implant seems superior in preventing crestal bone resorption. However, the prosthetic option was limited in one-piece-implant. Two-piece-implant offers more choices in prosthetic abutment. Conclusion: One-piece-implant was easier and provide simple protocol with limited choice on prosthetic.