bluuebunny/crossref_metadata_2025_split huggingface dataset:
BIOMARKER SIGNATURES IN TRIASSIC COPROLITES
Authors: UMAMAHESWARAN RAMAN , PRASAD G.V.R. , RUDRA ARKA , DUTTA SURYENDU 
Published: October 2019

ABSTRACTCoprolites are traditionally analyzed from a morphological perspective. Few studies exist from an organic geochemical perspective, and most of these consider recent specimens. This study represents an analysis of coprolites from deep time, using both traditional one-dimensional and also two-dimensional gas chromatography-mass spectrometry. We find organic molecules preserved in coprolites from the Triassic, and that both dietary habits of the defecators and paleoenvironment can be interpreted using comparative distributions of biomarker abundances in the coprolites. Steranes having 27 carbon atoms are known to be derived from animal steroids whereas those with 29 carbon atoms are known to be derived from plant steroids. The predominance of steranes with 27 carbon atoms over those with 29 carbon atoms in a non-marine environment was interpreted as evidence for the defecator(s) being predominantly carnivorous or possibly omnivorous. A series of tricyclic terpanes ranging from C19 to C28 was examined to determine the environment. The present study suggests that one or possibly all of the defecators may have been small-medium carnivores that lived in an aquatic or near aquatic setting.
Gas/Condensate Fields Development : Subsea to Shore Cost Effective Solution
Authors: Riviere Luc , Boireau Clement , Mackenzie Rory 
Published: October 2019

Abstract
In remote offshore locations or in harsh environment, the development costs of gas/condensate fields must be reduced, in order to keep them economically viable.
For these offshore gas/condensate fields, the best economic solution is often a Subsea to Shore scenario, as the cost of a stand-alone development is very high and as the operations in these locations are quite complicated.
The Subsea to Shore scheme for gas/condensate fields can either be a conventional one (as already implemented in North Sea, mainly in Norway), or an innovative one - installing new subsea technologies, using subsea processing and implementing alternative production strategies that reconsider the distribution of facilities between subsea and onshore.
Through an existing gas/condensate field example, operated by TOTAL in the North Sea, in harsh environment and in a remote location, this paper examines the impact on development costs of the following innovations : –an innovative hydrate management strategy (continuous injection of LDHI Anti-Agglomerate instead of MEG continuous injection),–an innovative production strategy (such as subsea pigging instead of having two production lines allowing the pigging),–an innovative subsea technologies (such as all electrical technology for subsea production systems instead of hydraulic systems),–and innovative subsea processing (such as subsea chemical storage and injection instead of complicated and costly umbilical).
This paper shows that a combination of alternative production strategies and new subsea technologies can significantly improve the economics of gas/condensate fields, for remote offshore fields or for fields in harsh environment, without jeopardizing HSE performance or production availability.
Successful Application of Scale Squeeze Inhibitor in Tengiz Field
Authors: Kamispayev Akylbek , Gazizova Elima , Skopich Anton , Munbayev Timur , Neubauer Edward , Clarke John 
Published: October 2019

Abstract
The deposition of scale in the near-well formation and production string can result in a significant decrease in well productivity. Properly designed scale inhibitor squeezes can successfully prevent scale deposition and extend well performance. Even though most wells in the Tengiz field produce virtually water free oil (less than 1% watercut (WC)), inorganic scales have been observed in many of these wells. Frequent acid stimulations are required to maintain the optimum well performance.
An extensive research project was initiated to reduce the need for frequent acid treatments and still maintain well deliverability at sustained rates. To identify an effective scale inhibitor product, inhibitor-brine compatibility testing and dynamic tube-blocking performance testing were conducted. Field application of the selected inhibitor in both low and high rate wells has verified the effectiveness of the squeezes. Treatment with the scale inhibitor attained sustainable well productivity and delayed the need for subsequent acid stimulation treatments.
This paper will share the best practices in scale inhibitor design, inhibitor selection, identification of well candidates, the execution and post treatment surveillance stages. Case studies shown to illustrate the performance of scale inhibitor squeezes in Tengiz.
Using of Ultra Deep Reservoir Mapping and Formation Evaluation Technologies for Exploration of Northern Caspian Field by ERD Well
Authors: Shtun Sergey , Golenkin Mikhail , Shtun Artem , Golubtsov Ruslan , Dovgopolyy Victor , Kuzakov Vitaly , Mityagin Artem , Shaymardanov Niyaz 
Published: October 2019

Abstract
The fields in the northern part of the Caspian Sea are characterized by a complex geological structure, which increases the level of uncertainty and risks associated with the planning and drilling of production wells. These problems are most evident in the development of fields with a thin oil rim, where the position of the profile of producing wells in relation to fluid contacts and fracture failures becomes critical for subsequent production. The experience of drilling in this region shows that even in the case of brown fields, there are areas with high structural and lithological uncertainties, which require additional geological study before making decisions on drilling of new production horizontal wells. If a significant area of the field needs to be further explored, drilling of a vertical or inclined pilot hole is often a common practice in the industry may not be informative in compartmentalized reservoirs. In such conditions, it seems reasonable to use extended horizontal wells as pilot holes, as it will allow to obtain information about the geological structure from a much larger area.
In the case of horizontal pilot hole drilling through the reservoir rocks within the oil-saturated zone, it is possible to determine the position of the top and bottom either by fluctuations of the trajectory between the reservoir boundaries or by application of ultra-deep electro-magnetic methods of geological section imaging.
The paper presents the method of drilling ERD horizontal pilot sections with the use of the latest technologies in local exploration of structural plan, which is well established for detailed improvement of the geological model, under the condition of its integration with seismic data, as well as for the estimation of residual reserves for planning new production horizontal wells.
Digital Twin of a Research Organization: Approaches and Methods
Authors: Khasanov Mars , Krasnov Fedor 
Published: October 2019

Abstract
Competition urges business to adopt the concept of digital twins. In some industry sectors, digital twins are already firmly in place: there are digital twins of plants and cities. However, in the industries where the core product is knowledge, digital twins are not yet in great demand. There is no doubt that research organizations have a backbone, corporate culture, values which help them carry out their unique work. By modeling these internal hidden features of an organization, we can get unique tools for forecasting and managing the technology strategy. A digital twin of a science and technology center may be viewed as a special system model type, which uncovers such hidden phenomena as creation of new branches and schools of thought and the extent of creative burnout and fatigue of the team.
Prototyping, as an engineering discipline, has been in existence for over 30 years and, at first glance, is doing the same thing. However, unlike the prototype, the digital twin does not aim to quickly implement basic functionality to analyze the operation of the system as a whole.
Therefore, in order to understand the advantages of digital twins, it is necessary to understand the new opportunities they offer. Going from general to specific, the authors chose a science and technology center as a focus for their analysis, considered the approaches to building a digital twin, and then summed up those approaches. As a result, they have current research hypotheses that have to be checked before creating the digital twin of an organization or its part aiming to produce new knowledge.
Finally, we provide the results of the simulation of the digital twin model.
Future Geosteering and Well Placement Solutions from an Operator Perspective
Authors: Hermanrud Kristine , Antonsen Frank , Teixeira De Oliveira Maria Emilia , Agerlin Petersen Steen , Constable Monica 
Published: October 2019

Abstract
Innovative interpretation methods based on efficient measurements to map structure and fluids around high angle and horizontal wells while drilling are critical for future success in a marginal, but increasingly strategical, business on the Norwegian Continental Shelf (NCS). A high number of infill wells are expected to prolong the operational life of assets for the coming decades. Success of horizontal infill wells targeting bypassed zones are challenged by uncertainties in the subsurface description and by fluid content variation generated by differences in sweep efficiency over time. Optimizing well placement of such producer wells has a direct impact on cost and recovery. This could also potentially unlock targets not accessible today with currently used methods and technologies.
Driven by the advanced integration of subsurface information, the capacity of 3D mapping and characterization of the reservoir features has reached an unprecedented understanding level. Through the incorporation of data from real time LWD measurements, 1D and 2D ultra-deep azimuthal resistivity inversions, all the way to 3D and 4D surface seismic, it is now possible to describe in detail not just the structural and stratigraphic components but also the reservoir properties and fluid distribution along horizontal wells.
The key challenge is to establish more efficient workflows for advanced integration of subsurface information through new digital solutions transforming future geosteering and well placement solutions with 3D mapping and characterization real-time. Key elements of the integrated workflows and potential benefits in all phases of a well placement job will be discussed in this paper with examples from real cases from NCS.
Modelling of Fracture Geometry to Reduce the Risk of Intercepting Drilling Induced Fractures When Designing Sidetrack Trajectories
Authors: Allan Fergus , Shepherd David , Abbasov Abbas , Villinski Jennifer , Majidi Reza , Bagir Ibrahimov 
Published: October 2019

Abstract
During drilling operations fractures can be induced for a number of different reasons. When such a situation occurs it may be the favoured option to sidetrack from a shallower depth. In order to avoid intercepting the fracture it is useful to be able to model the plane of the fracture to inform sidetrack trajectory design. This paper will demonstrate an integrated approach to the design of such trajectories using the following techniques. Determination of maximum horizontal stress (SH) Orientation: This is obtained from a variety of sources. Caliper logs, Image logs, LWD image logs, and X-dipole sonic are all interpreted to provide the direction of SHmaxValidation of SHmax orientation: The above techniques are valid in near-vertical wells with deviation up to 20°. At higher deviations an understanding of the magnitude of SHmax is required. SHmax needs to be high enough to support the premise that breakout orientations still reflect the SHmax orientation at the higher deviations encountered. This validation is obtained by Geomechanical modelling which is calibrated to observations of breakout orientation and width.Fracture Detection: As well as knowing the orientation of the fracture it is important to identify the location and extent. The loss interval can be detected using time-lapse LWD resistivity. The as-drilled resistivity logs can be compared with repeat passes of resistivity logs post-losses to identify the loss interval. This can then be compared with the suspected loss zone from pre-drill pore pressure-fracture gradient (PPFG) model.Sidetrack Trajectory Design: Once the location and orientation of the fracture are known a model of the existing wellbore and fracture can be made. The trajectory of the sidetrack can be chosen to minimize the possibility of encountering the fracture and repeating the loss event.
Several examples will be presented where by following the proposed workflow sidetracks have been successfully drilled without issue.
Technological Opportunities to Increase Efficiency of Primary Recovery of High Viscous Oil
Authors: Maksimenko Andrey , Sherstoboev Eugene , Osipenko Aleksey , Akhmetov Aleksey , Demenev Roman 
Published: October 2019

Abstract
Oil reservoir of East-Messoyakha field formed of continental deposition environment is characterized by large degree of uncertainty and heterogeneity, observed even at a short distance from the wells. Other complicating factors are high viscous oil (110 centipoise), the presence of an active aquifer and a gas cap. In conditions of high uncertainties, as the geological concept of the field becomes more complex, the involvement of hard-to-recover reserves could be achieved by development of well drilling and well completion. Initially, there was information about the reservoir as a homogeneous reservoir with a thick gas cap and rim of highly viscous oil: the optimal row horizontal well pattern was chosen after calculations. Further studying of the reservoir clarified the idea of reservoir compartmentalization: the reservoir was divided into 3 cyclothems. For draining the maximum oil-saturated thickness from all of cyclothems, it was decided to drill low-angle well through them. With the next update of the conceptual model, theory of multiple-contact reservoir was supposed: development scheme was changed to primary drilling on cyclothem C with parallel study of the overlying objects. Based on the accumulated experience, Workflow was made. By a number of geological and technical criterias the design of well and completion type could be chosen. Besides, development scheme of the neighbor field analog is planned using this workflow. Using workflow allows choosing the optimal development system for a field with large lateral and vertical variability. Implemented development approaches that have changed in the course of a change in the geological concept can serve as experience in the initial assessment of the analogue-field development scheme.
Application of Alternative Tracer Technologies for Production Logging
Authors: Shestakov Dmitry , Galiev Marat , Badrtdinov Ilshat , Khamidullin Vadim , Ovchinnikov Kirill , Malyavko Evgeny 
Published: October 2019

Abstract
The present article highlights a new approach to solving objectives aimed at efficient and rational development of oil and gas fields based on conducted production logging of Kogalymneftegaz TME, LUKOIL-Western Siberia LLC horizontal wells with the application of marker-based technology Quantum PLT.
Well logging technology using markers is based on the application of quantum marker-reporters precisely indicating oil and water inflows. The placement of markers in the well implies two alternative technological solutions – application of marked proppant during MFrac or application of downhole cassettes with markers installed in the lower completion of the horizontal well. The advantages of the technology involve no necessity of well shut-in during downhole operations and the possibility to obtain an unlimited number of analytical data for a long period of time.
Marker-based technologies produced by different manufacturers differ in physical principles of operation, as well as in the methods of markers placement in the well or reservoir. The results of two alternative marker-based systems application in one well are shown in this article. This approach allowed us to compare the results and to evaluate the advantages and disadvantages of these two technologies. The well was completed by MFrac with the possibility of further ports control with the application of coiled tubing service. Each of five well intervals was equipped with two marker cassettes fixed on both sides of the MFrac port. Three months later MFrac with pumping marked proppant was performed on the well.
As a result of the world-first field application of alternative marker-based systems, valuable analytical material was obtained on the quantitative analysis of various markers, the performance of different polymers, the stability of the markers allocation in the formation fluid. The data obtained confirmed the character of the marked proppant pack washing out with the formation fluid in comparison with cassettes with markers.
Moreover, the efficiency of conducted stimulation was evaluated, specific horizontal well inflow profile types were identified, the degree of the reservoir management system impact on the inflow profile was evaluated.
It has been demonstrated, that received analytical data based on horizontal wells production logging enable addressing the issues of field digitalization at a totally new level, including: –visualizing recovery in hydrodynamical models;–control of hydrocarbon recovery, also by improving water flooding efficiency and better management of injection wells;–efficient planning of well intervention and stimulation techniques;–optimization of horizontal sections length and the number of MFrac ports;–adapting the relevant geological and hydrodynamic models considering analytical data related to production logging data, etc.
HSE Orientation Process - Green Hat
Authors: Krujalo Aleksandra , Hasanguluyev Ayaz 
Published: October 2019

Abstract
The main objective of the HSE Orientation process - Green Hat (hereinafter Green Hat) is ensuring the awareness of the new hires about the potential hazards at the worksites and increase their safety competency level based on the unique training program connected to the staff performance management and competency assurance systems.
The Green Hat program is comprised of theoretical and on-the-job training phases, which are aligned with the probation period of employees and lasts 3 months. The program covers specific HSE topics related to operations in the O&G services industry. New hires complete the practical part of the program under the supervision of the mentor. To ensure safety of operations, new hires must wear a green hard hat in order to stand out from experienced employees. Once new hires successfully graduate the program, they become eligible to wear a white hard hat and move into the ranks of the regular operations team.
The Green Hat program enables new hires to become fully operational and adapt to the company's Safety culture and HSE standards in the shortest period of time. In addition, the program has generated the following benefits since its application:
Educated employees about safety, including its theoretical and practical aspects, with strong on-the-job training components;
Raised awarness and knowledge of new hires about safety policies, instructions and procedures in the short period of time;
Developed new hires’ skills allowing them to become proactive in all HSE matters, asessed the risk level of potential hazards and implemented adequate preventive actions in their daily activities;
Reduced incidents of safety violations;
Minimized injuries to and caused by new hires;
Improved mentoring and the learning culture at the work sites;
Improved operational performance of the company by reducing NPT and LTI;
Enhanced corporate financial performance by sustaining a strong safety culture and minimizing injuries, accidents, operational losses, and NPTs.
Several external audits have revealed and confirmed the strong safety performance benefits of the Green Hat program. The robustness of the program has been attested successful by ISO 9001, ISO 45001, ISO 14001 certification audits of the company.
Training of new employees on safety topics, achieving their full application of the safety culture and rules of the company at the work sites, on time feedback and assessment of new hires will lead to reduction in the number of accidents and hazards driven by human factors. The Green Hat program presents a full- cycle, cost-effective and feasible HSE orientation system that can be successfully applied in the circumstances of relatively young company operating in developing economies.
Collaborative and Multidiscipline Field Development Planning – A Caspian Case Study
Authors: Eliseeva Ekaterina , Hauchart Fabien , Wilson Scott , Mukhin Sergey 
Published: October 2019

Abstract
The process of creating, maturing and ultimately submitting a field development plan for a given resource is often complex, time consuming, and inefficient; perhaps inextricably linked to its multi-disciplinary nature. The workflow(s) traditionally used in today's industry are domain-centric, involve many discrete software programs resulting in a linear process which limits optimization and prevents cross-domain collaboration. The paper describes an innovative field development planning (FDP) methodology, utilizing deep domain expertise supported by leading-edge software technology and illustrates the benefits through a study case in the Caspian Sea.
Although well-established software tools exist for isolated parts of field layout, no existing platform integrates the equipment selection, systems knowledge, field layout, economics, and software simulations required for the entire planning process from feasibility studies to detail design and optimization. The paper describes an innovative field development planning methodology that combines lean project execution and uses the industry's first cloud-based collaborative subsea FDP software environment, providing efficiency and optimization. This is achieved by combining full-field economics with petroleum engineering disciplines, subsea systems engineering, subsea technology selection and installation knowledge spanning the entire planning process and visualized through a single working environment.
This paper demonstrates how the core value of multi-discipline domain knowledge can be truly integrated through the use of collaborative workflows based upon cloud-based platforms and how it transforms concept development and selection in the upstream industry.
In the early stages of exploitation planning, from the feasibility and concept selection phases, operators plan for the development of a field that will produce for 20 years or more. It is at this early phase that key Tier 1 level decisions are taken often with limited reservoir information and a significant range of uncertainty. The short duration of these initial stages inevitable means that operators rarely have the time or resources necessary to evaluate all possible development scenarios, and decisions are taken with less conviction or assurance than is desirable. As a result of this sub-optimal way of working, exploration and production companies are constantly seeking tools, methods and processes to enable the multi-scenario evaluation and option screening that will improve decision quality in field development planning.
This paper demonstrates this novel approach through a practical example of such an FDP study, focusing on a case study relevant to the Caspian region. The discussion seeks to illustrate how the single working environment improves collaboration between disciplines whilst identifying cost savings and opportunity gains of the recommended development scenario.