bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Role of Pilot Projects in the Development of Unconventional Resources
Authors: Addis M. A. , Freitag H-C. , Mendez A. , Ceccarelli R. 
Published: November 2015

Abstract
This paper addresses the challenges that sub-surface and asset managers face when evaluating shale and tight gas developments during the E&A stage of a project, of having limited confidence in the production predictions, and consequently the potential revenue stream, whilst needing to quantify the sub-surface uncertainties through the commitment of a large number of wells—and costs—to assess and develop the resource.
Conventional field developments rely upon both well production tools and dynamic reservoir models to estimate the production from development wells through the life of the field. In sharp contrast, the development of unconventional resources, in practice, is less reliant on these models as they currently lack the underlying physics and functionality to model the additional complexity associated with unconventional resources. Additionally, much of the required input data for these models (such as the desorption isotherms, the hydraulic fracture geometry and performance as well as the natural fracture geometries and conductivities) are absent particularly during early appraisal and development.
The approach commonly used to reduce the uncertainty of these developments at the evaluation stage is a modification of the stage-gate process, through the inclusion of structured pilot projects. This provides a commercial basis for full field developments in the absence of reliable ‘class A’ production models.
The paper also considers key technical uncertainties for shale gas and tight gas developments which can be assessed through pilot projects, in order to quickly evaluate the viability of a development: Of primary importance in these unconventional resources is the absence of a significant natural permeability and lateral and vertical heterogeneity, the economic consequences of which affect the methods by which these resources are assessed and developed. Sub-surface and project uncertainties that may impact the viability of developments are discussed including; water and fluid management and environmental impact assessments. Data gathering and monitoring and surveillance requirements are reviewed based on current technology in the context of reducing project and development uncertainties.
The paper describes the approaches through which the production potential for an unconventional resource is evaluated through a multi-well commitment, while limiting the risk and cost exposure for the operating company.
Successful Delivery of Downhole Measurements from Abu Dhabi Giant Offshore Field
Authors: Newton Daniel , Pandian Senthil , Katheeri Zaid Al , Kofoed Curtis , Gurses Sule , Demyanov Alexandr , Kozin Anton 
Published: November 2015

Abstract
The paper presents successful installation of Permanent Downhole Gauges (PDGs) and Distributed Temperature Sensing (DTS) technologies for the first 13 wells, data transmission method of gauges data via mobile network and application used to receive and store the data with visualization software in an Abu Dhabi giant offshore field.
As a part of the plans to increase production and reserves recovered from the field, extended reach wells are planned to be drilled off four artificial islands. The project includes a series of oil producer wells along with water injectors. Gas lift will help to sustain the production level after the initial period of natural flow. During the planning phase, it was identified that efficient management of gas lift operations can be achieved through DTS. In addition, 2 single-point pressure and temperature data points from PDGs were to be acquired to assist in reservoir management efforts and calibration of the DTS.
The solution provided for each well was to deploy tandem high resolution tubing pressure and temperature gauges run on a hybrid permanent downhole cable containing tubing encapsulated conductor (TEC) plus fiber optics for DTS. The hybrid cable serves as a power and communication line to the gauges installed above the production packer at measured depths varying from 10,000ft to 20,000ft as well as providing distributed temperature measurements across the upper completion through a multi-mode fiber. The temperature data will be used for gas lift operations surveillance and optimization. An additional fiber is installed for distributed acoustic sensing for future well integrity surveillance purposes.
As of August 2015, the first 13 wells have been installed successfully in the field with PDGs and Fiber Optic monitoring. The gauge data (pressure and temperature) is planned to be delivered through a GSM network transmission system into the onshore office node at the operator headquarter (HQ). The focus has been on integration of different components of surface system like Data Acquisition Unit, Remote Terminal Unit (RTU), GSM Modem, Virtual Machine (server located in the onshore office) and fully customized Human Machine Interface (HMI) software. The new approach allows for continuous real time monitoring of data at the HQ and taking necessary actions in a timely and efficient manner.
Initial stage of project implementation has shown successful results with all PDGs and Fiber Optics operational in all wells and improved execution efficiency of field installation. Well completion designs are planned to continue with the same gauge and fiber optic design for the duration of the field development.
Integration of Young UAE Nationals in Commissioning Grass Root Refinery
Authors: Alhammadi Adel Ali 
Published: November 2015

Abstract

Objectives
The objective of this paper is to highlight the development & role of young Emiratis during commissioning of new refinery with integrated process units. This opportunity provides them the right platform to play a vital role & to create futuristic national manpower with strong national integrity, competence & leadership to adopt modern technology, a culture of participation and ultimately to contribute as proud Emiratis.
Lab Experiments and Simulations for Multiphase Flow Splitting from a Single Flowline into a Dual Riser
Authors: Henkes R. A. , Worthen R. A. , Ellepola J. H. 
Published: November 2015

Abstract
A possible new development concept for Floating LNG may include a single flowline along the sea floor that splits into dual or more flexible risers. Since the gas co-produces condensate and water, design rules are needed for the splitting of the phases at the riser base manifold. Multiphase flow splitting is much more complex than single-phase flow splitting. The latter is fully determined by the back pressure on each riser, but for multiphase flow the phase split (Liquid-Gas Ratio) into each of the risers may also depend on other factors, such as the flow regime in the riser/flowline, the precise geometric details of the splitting configuration and other parameters (e.g. the momentum flux ratio in the flowline). Ideally the phase volume ratio should be fully equal over the two risers and remain the same as in the flow line. To find the proper design rules for multiphase flow splitting, which ensures equal phase volume split, we have set up a research programme that includes lab experiments and simulations using Computational Fluid Dynamics. The hypothesis is that phase maldistribution can occur if the gas flow rate in the risers is so low that it gives churn flow or hydrodynamic slug flow in the risers, whereas an equal phase volume split is expected if the gas flow rate is sufficiently high to produce annular flow in both risers.
The flow facility at the Shell Technology Centre in Amsterdam transports air and water through a 2", 100 m long flowline, splitting into dual, about 15 m high, risers, having a diameter of 2". The pressure is atmospheric at the riser top. For the splitting configuration, we used a symmetric lay-out, which is a so-called Impacting Tee. We created the splitting curve by systematically changing the opening of the chokes at the top of the risers. At low gas flows a non-symmetric flow split was found, with flip-flopping and hysteresis in the risers. For example, a stagnant liquid flow could develop in one riser, and churn flow in the other riser, with a sudden swap of flow behaviour between the two risers. This maldistribution gradually disappeared as the gas flow rate was increased.
CFD simulations were carried out with the Fluent package using a Volume of Fluid approach for the multiphase flow through the symmetric splitter. As in the experiments, the CFD simulations also give the preference of all flow to be produced through a single riser, with a stagnant liquid column in the other riser. In the experiments this maldistribution disappeared for a sufficiently high gas throughput. For the first flow rate where an equal split is found in the experiments, however, the CFD model still predicts that all of the flow exits through only one of the two risers.
Addressing the Challenges of Sourcing Water for Hydraulic Fracturing by the Use of Membrane Technologies
Authors: Basu Shiladitya , Franks Rich , Shin David , Boda Roman , Bartels Craig 
Published: November 2015

Abstract
Operators in the Middle East have embarked on projects to explore and produce oil and gas from unconventional reservoirs by hydraulic fracturing (fracing). Many unique challenges exist for each reservoir under consideration but one that is common amongst all of these operations is the access to water to frac with. Companies responsible for conducting the frac have learned a lot about water management through the experience gained in North America about using sources other than fresh water such as brackish water, flowback water, and produced water but often the required level of treatment is minimal. This is because there is access to fresh water, which allows for dilution to get the waste water to the minimum required level for use in a frac. This coupled with advances in the development of high salinity tolerant frac fluid chemicals (Lebas et. al. 2013) eliminates the need to use advanced water treatment processes such as membranes.
In contrast, there are many barriers to similar long term access to fresh water sources in the Middle East. Therefore other water sources must be considered, such as subsurface brackish water or seawater, and subsequently other treatment options must be considered, such as membranes. These technologies are mature in many other applications but for this particular application, there are challenges with implementing and deploying these systems resulting from the required flexibility of the systems and the environment in which the systems are to be operated.
In order to overcome these obstacles, it is important that the stakeholders openly communicate the expectations to develop a mutual understanding for the requirements of these systems such that design measures can be implemented and operating protocols can be developed to make the systems fit for the purpose. The authors of this paper have taken the approach of identifying likely issues and providing an approach to the design of the process and operational protocol for these applications to provide guidance to those considering utilizing these processes. Also, references are made to similar challenges faced in other applications to those in this application to help with identifying possible solutions. The goal of this paper is not to provide solutions to each and every scenario, because it is impossible to do so, but rather to identify the critical factors that should be considered to enable the project stakeholders with the tools for development of a good design and operating protocol. By providing some clarity to the risks and potential solutions it is the authors’ ambition that those who make the investment in the technology are able to obtain the expected results and return on their investment.
Evolution Of An Integrated Production System Model (IPSM) In A Greenfield Oil Environment
Authors: Al Jumah Ali , Lalji Farhad , Johan Josey , Hindawi Kareem , Al-Ibraheemi Abdulameer Turki , Tahir Abed Basim 
Published: November 2015

Abstract

Description
The field in question is a super giant oil field located in Southern Iraq. Historically, the field had 27 wells, along with surface facilities capable of processing ca. 100kbbl/d of oil. An additional processing facility was installed and some 18 additional wells were drilled and completed in the period 2012–13 to increase production levels in the field to more than 200kbbl/d, referred to as First Commercial Production (FCP). The field was shut-in for approximately 14 months during the pre-FCP period.
Initially, only scarce historical pressure, well test and production allocation data existed and so an approach to prove up, manage and optimize field production performance was developed using Integrated Production System Modelling (IPSM). This involved both surface and subsurface disciplines collaborating to integrate stand-alone models and discipline data from operations, production technology, reservoir engineering, petrophysics and production geology into a single integrated model for proving up well capacity, field surveillance and optimization. Initially, the individual discipline model definitions were based on design case and oil field theoretical assumptions combined with single point(s) of actual data points. As more field data was collected the various models were updated and re-calibrated to ensure a maximum deviation of 10%.
Over the past 3 years, as the field has transitioned from the pre-startup phase to the stable production phase and with this has been the evolution of the uses and application of the IPSM. This paper will describe the data gathered, process of model calibration, uses of the model in the four key phases to date along with the future aspiration case:
Generally speaking, the main objectives of building and maintaining an integrated production system model are:
Begin with the End in Mind- Delivering Commissioning Assurance through Pro-active Stakeholder Alignment
Authors: Sreekanth S. P. , Al Naqbi Sulaiman Ahmed , Ramana Narra Venkata , Khan Aqrar Ahmed , Al Katheeri Nashmi Abdul , Mukkamala Srinivasa Rao , Kowtha Ravi kumar , Kroosh Abdalla Mohammed 
Published: November 2015

Abstract
Projects Handing over to Assets/Operations is always a challenge.To Deliver Commissioning Assurance through stakeholder pro-active Alignment and smooth Handing over of Project to Assets/ Operations, we have identified the Commissioning requirements to embed in FEED Scope of work and developed an Internal Commissioning & Hand over strategy as follows:
At FEED stage of the project, all Commissioning requirments, Start-Up sequence, Performance Test Run requirements & Acceptance criteria are identified and ensured that the same are embedded in EPC scope of work.
At early stage of Project Execution an Internal Commissioning & Hand over strategy is developed by covering Roles and responsibilities of all involved stake holders, Hand over protocol, Inerfaces, Startup sequence, Performance test run requirments and Acceptance criteria.
An agreed hand over procedure/process is developed by covering Operational spares, Final documentation, Punch List dispute resolution mechanism and Warranty Claim Managmenet procedure and aligned all stake holders.
A Holistic Stimulation Approach to Unlock Potential of Horizontal Open Hole Completion in Tight Carbonate: Optimization of Acidizing Treatment and Successful Diversion in Real-Time Using Distributed Temperature Sensing.
Authors: Salah Mohamed , Bereak Ahmed , Gabry Mohamed , Shaheen Tarek , Kewan Mona 
Published: November 2015

Abstract
Abu Roash-D is characterized as a carbonate reservoir in Abu Gharadig field, Western Desert of Egypt. It has a good lateral continuity, contains natural fractures with poor connectivity in addition to formation tightness. To further increase the production from the field, a full development plan for Abu Roash-D carbonate reservoir was initiated with drilling of horizontal wells. The main objectives of drilling such horizontal wells was to develop the tight unconventional reservoirs and increase production by dramatically increasing the contact area with the producing interval, maximizing drainage volume around a well and link the natural fractures network thus, achieving an economically production targets.
The effective placement of sufficient acid volume along the open-hole section of such horizontal wells provides significant challenges in acid diversion due to the high permeability streaks that requires a very effective diversion technique for optimal acid distribution a long the open hole lateral for a successful acid stimulation treatment.
A fiber optic enabled coiled tubing attempts to tackle some of these limitations. This new approach deploys downhole sensors with fiber optic telemetry inside the coiled tubing string provides a real time temperature, pressure and correlated depth measurments. The fiber optic telemetry allows distributed temperature surveys recording for obtaining temperature profiles across the entire wellbore. Monitoring the distributed temperature sensing (DTS) profiles accompined with downhole pressure data interpretation enables real time diagnostic of downhole events between the stimulation stages providing an important aid to further optimize and improve the performance of stimulation treatments.
This paper presents case histories of the first time implementation of horizontal wells in Abu Roash-D tight carbonate reservoir in Egypt's western desert in which fiber optic enabled coiled tubing was utilized to optimize stimulation treatment. The real time monitoring of downhole distributed temperature sensing profiles allowed the identification of both high permeability zones as well as tight zones across the entire openhole lateral. This enabled the operator to take pro-active decision on where to spot diverter or acid, select the best diversion technique and allow for treatment optimization.
Identify the Key Uncertainties Which Influence Production Performance and Recovery by Using Global Analogs
Authors: Lu Xiaoguang , Sun Shaoqing , Jenkins David 
Published: November 2015

Abstract
Limited data is available for a new discovery at the preparatory stage for the plan of development (POD). Uncertainties exist such as the depositional environment of the reservoir and individual sandbody type, reservoir heterogeneities and fluid properties. This paper presents an innovative and unique method for the qualitative and quantitative evaluation of the influences of these uncertainties on production performance and final recovery factor.
The developed methodology enables reservoir engineers and development geologists to conduct uncertainty assessment on production performance and final recovery factors by using a global analogs database and proprietary analytical software tools, including performance forecasting, characterization and attribute cross plotting, etc. The process consists of four steps: (a) selection of the analog reservoirs, (b) performance forecast, (c) uncertainties evaluation, and (d) analysis of key drivers impacting performance and recovery factor. In our case study, Field A is in its POD study stage. Based on available information, reservoir sand in Field A potentially consists of sandbodies of either fluvial channel (FC), distributary channel (DC) or combined fluvial and distributary channels (CFDC). Uncertainty evaluation results indicate that the sandbody of FC, DC and CFDC will produce ultimate recovery factors of 35.9%, 37.9% and 39.7% respectively for the medium-case scenario and 52.4%, 54.3% and 59.2%, respectively for the high-case. The various sandbody types also have a great influence on performances of life-cycle production profile, peak production rate and water-cut variations. Analog analysis of the same sandbody type reveals the impact of three group specific attributes on the ultimate recovery.
Compared with the normal approach of conventional geological modeling and reservoir simulation, the analog solution using the proprietary software tool is an efficient process and provides reasonable results.
Improved Polymer Membranes for Sour Gas Filtration and Separation
Authors: George G. , Bhoria N. , Mittal V. 
Published: November 2015

Abstract
This paper contributes to the interest of natural gas industry. It is well known that a scientist continually faces challenge to purify the natural gas (NG) from impurities such as acid gases (CO2 and H2S). The polymer membrane based gas separation has materialized as a promising field of research. There is a need for stiff backboned polymer membranes that can withstand potential membrane swelling and degradation for a cost effective use of the material and the technology.
The polymer used is thermoplastic elastomers poly(ether-b-amide); popularly known as PEBAX (P) that holds a number of properties that makes it potentially useful membrane materials. Room temperature ionic liquids with high selectivity towards acid gas were selected. The careful selection of cations includes 1-Butyl-3-methylimidazolium and 1-(2-etoxy-ethyl)-3-methylimidazolium whereas anions were selected from BF4, PF6. Subsequent supported ionic liquid membrane systems (SILMs) and SILM-nanocomposites were successfully prepared by incorporating nanofiller. The morphology, structure, and stability of these membrane materials were characterized by various techniques. The polymer has rigid polyamide segments which are spaced with malleable polyether segments. The amide segment delivers the mechanical strength, while the soft ether block contributes to the gas transport capabilities. Polymer SILM allows the freedom to effectively tune the structure-property relationship of polymer and ionic liquid in membranes towards its permeability and selectivity of sour gases. Our research discusses the effect of the incorporation of selective ionic liquids to polymer membranes. In particular, we focus on the structure-property relationship of the polymer and room temperature ionic liquids on the gas separation.
The modulus values decreases on addition of ionic liquid. The flexible polyether phase of the polymer gets plasticized by ionic liquid and thereby the elongation also gets reduced. This polymer's backbone was further strengthened by successfully employing either of two strategies such as molecular chain extension/crosslinking or a bulk modification using nanofiller which can impart enhanced mechanical properties as given in figure 1a.