bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experimental Investigation and Correlation of Treatment in Weak and High-Permeability Formations by Use of Gel Particles
Authors: Al-Ibadi Adnan , Civan Faruk 
Published: October 2013

Summary
Near-wellbore formation treatment by injection of suspensions of deformable gel particles is explored as a method of prevention of lost circulation of drilling fluids, handling of reservoir permeability heterogeneity, and controlling water production in mature waterflooded oil fields containing highly permeable and weak zones. Conditioning and plugging of such formations and the resulting permeability impairment occurring during injection of suspensions of deformable gel particles are investigated experimentally. The effect of concentration, flow rate, and gel-particle sizes of suspensions on the prevailing pore-plugging processes is inferred by flow tests conducted with 3,800-md 16- to 20-mesh sandpacks. Prevailing particle-entrapment and -permeability-impairment mechanisms are identified under various conditions by means of specially formulated diagnostic equations. Appropriate dimensionless groups are used to develop several empirical correlations of the experimental data, which can assist in choosing suitable gel-particle suspensions and proper application conditions required for effective near-wellbore-formation treatment. This reveals valuable insights and information about the functional trends of sandpack plugging by gel-particle suspensions, which can help in successful design and mitigation of formation-plugging treatments in the field.
The Impact of Non-technical Risks on Oil and Gas Activities in Alaska's Arctic
Authors: Southam Anne L. 
Published: October 2013

Abstract
This paper presents Alaska as a case study for evaluating the impact of non-technical risk on oil and gas exploration and development in the Arctic. Stakeholder relationships, regulatory uncertainty, government funding, listing species under the Endangered Species Act, cumulative impacts, and litigation are all non-technical risks that can delay oil and gas projects. Since 2005, there have been over a dozen legal challenges to oil and gas activities due to non-technical risks. The magnitude of costs associated with project delays due to non-technical risks in Alaska’s Arctic is on the order of billions. The February 2008 Chukchi Sea Lease Sale 193 attracted 667 bids totaling almost $3.4 billion, the most for any offshore lease sale in Alaska’s history. In 2012, according to a United States Department of Interior report, approximately three-quarters of Alaska’s offshore leases (3.7 million acres) were subject to litigation. As a result of legal challenges, agency staff must respond to court orders rather than process permits and authorizations required for exploration and development. With permit applications sitting idle, company profit margins are diminished and public trust deteriorates. In recent years, three major oil companies have reported spending over $75 million over five years to collect environmental data, yet data gaps are still perceived to exist. In particular, the absence of a regional assessment of cumulative impacts of development activities is leaving companies and authorizing agencies vulnerable to stakeholder scrutiny and litigation. Despite these issues, sustainable project exploration and development is possible. Understanding what non-technical risks exist, and then integrating methods to minimize them at the strategic leadership level during the pre-feasibility stage can minimize delays and lay the foundation for sustainable oil and gas projects.
Experience of Application of Extended Logging Suite and Formation Testers for characterization of Jurassic Age Deposits of the Em-Egovsky Field
Authors: Martinov M E , Kozlov A V , Platunov A A , Filimonov A Y , Ezersky D M , Egorov S S , Charupa M V , Tsiklakov A M , Mikhalteva I V , Weinheber P 
Published: October 2013

Abstract
In a recent Em-Egovskoe well an extended logging suite was performed with the aim to evaluate the petrophysical properties of Jurassic and Paleozoic formations as well as to improve the structural geological model of this part of the oilfield and to do detailed characterization of the dynamic model by desired properties of formations and fluids. Apart from a standard "triple combo" logging suite the following advanced technologies were applied in the well: neutron-gamma spectroscopy, nuclear magnetic resonance, formation micro imager, formation testers in different modes of reservoir and fluid properties evaluation. Noteworthy, the zone of interest was considered to contain only oil-saturated reservoirs – no gas cap was expected. Indeed on the initial triple combo log data there were no routine gas attributes were observed. Gas-saturated reservoirs were only observed based on integrated analysis of standard and advanced log data, particularly, nuclear magnetic resonance and cross-dipole sonic measurements. Gas-saturated intervals were fully proven by formation tester using downhole fluid analysis (DFA) As a result, one of the Jurassic layers was acknowledged as gas/gas-condensate saturated down to the bottom and the rest of Jurassic intervals were found to be oil saturated.
The Abalak formation was also encountered in this well and evaluated. Thin carbonate streaks were identified with the micro-imager and were tested with the dual-packer module of the wireline formation tester. The result was the first ever Abalak oil sample in this field. Furthermore, based on pressure transient analysis of the build-up from the pressure test it was suggested that these tight streaks are laterally discontinuous.
Finally, we created a stress profile in the Jurassic and Paleozoic layers. Based on formation micro-imager and acoustic scanning measurements the maximum horizontal stress directions and magnitudes were estimated. Then dual-packer formation tester micro-stress measurements were made to acquire direct measurements of fracture closure pressure. These measurements were used to calibrate our stress model.
Geosciences and Reservoir Integration – Key to Better Predict Behavior Of Complex Fractured And Karstified Kharyaga Field
Authors: Shchukina Natalia , Neumann Catherine , Nely Georges , Spina Vincenzo , Debroux Jean-Luc 
Published: October 2013

Abstract
This paper presents an integrated Geosciences and Reservoir work approach used for complex fractured and karstified carbonate Kharyaga field. Synthesis is fulfilled for all available data, such as seismic interpretation, static well data, well tests etc. It has been launched on Kharyaga field mid 2012. Kharyaga field is a NW-SE elongated anticline lying 60km north of the Artic polar Circle, in Nenets Autonomous Territory on Kolva regional swell. Total E&P Russie (TEPR) is operating Object 2 and 3 of this field. The Object 2 accumulation, subject of this study, is characterised by oil bearing Devonian carbonate reservoir with a gross thickness of 160–250m with high vertical and lateral heteregenity. Current production from Object 2 is around 23 kbopd.
The purpose of the synthesis is to create new and more reliable geological and dynamic models in order to better optimize next development phase and fine tune production profiles estimation. Geosciences and Reservoir synthesis imply the following: gathering all available information starting from newly reprocessed seismic data, various static well data and ending by well tests and production history over the whole life of the field,depth analysis and putting in coherence of all information in order to better address the various heterogeneity scales and reservoir characterization.
There are two main challenges related to characterization of existing heterogeneities: defining the fault pattern including sub seismic faults, understanding karst and fractures distribution,defining vertical and lateral sedimentary heterogeneity as well as reservoir extension.
Many experts and specialists are involved in this synthesis. The joint approach between geologist and geophysicist, based on tectno-stratigraphic timing and stress field combined with seismic attributes and thickness map, allowed to proposed a new fault pattern which honors FMI data and dynamic interference tests recorded during the 14 years of field production. Interpretation of newly reprocessed seismic data helped the sedimentologists in inter-well correlation. Looking just at seismic amplitudes cubes, it was possible to propose a new sedimentary model and change inter-well correlation accordingly. This led to the updated vision of the reservoir.
Geospline: Mathematical Model of 3D Complex Geological Medium
Authors: Maximov G.A. , Larichev V.A. , Lesonen D.N. , Derov A.V. 
Published: October 2013

Abstract
The original approach and releasing software GEOSpline for modeling of complex 3D geological structures are developed. The joint use of parametric b-splines for approximation of arbitrary distributed in space data, to build separate geophysical surface, and volume splines for approximation of continuous volume properties together with special tree-hierarchial structure for ordering of separate surfaces in the model and cutting of their intersecting parts are the original approaches of the development. The developed mathematical model for construction of 3D geological structures with faults allows to create complex geological structures by real data with their 3d visualization, to build adaptive grids for finite-difference and finite element modeling, as well as to make calculations of seismic and other fields in real geological structures.
Introduction
When the current structure of oil reserves is regressing (number of big reservoirs with high capacity collectors is decreasing, their geographical location is worsening) the requirements to detail and accuracy of the geological medium description increase. These requirements are determined by necessity of searching and determinating of thin and structurally complex oil and gas collectors. All of this causes necessity of creation of more accurate and detail models of the geological medium for solving of direct and invers geological and geophysical problems.
The modern level of detail and accuracy of the geological medium description, what is necessary for searching and selection of prospective oil and gas horizons, requires the using of three-dimensional models of geological structures to solve both direct and inverse problems of seismic profiling. Thus, the three-dimensional geological modeling of complex structures with internal boundaries of real arbitrary distributed data for further three-dimensional visualization and calculation of geophysical fields in such structures is an actual problem.
The Principles of Selection and Optimization of Drilling Fluid for Drilling Operations in the Vankor Field in Eastern Siberia
Authors: Kharitonov A.. , Burdukovsky R.. , Pogorelova S.. , Sidubaev S.. 
Published: October 2013

Abstract
Vankor is the flagship mine of the Rosneft Oil Company in Eastern Siberia. Developmental drilling began there in mid-2006. The pace of the construction of wells and surface facilities has been among the fastest in Russia, with a 15 to 20% acceleration in annual drilling activities.
The Vankor field is located in the northwest of the Krasnoyarsk Territory in the Turuhansk area, near the Arctic Circle, and it is quite removed from population centers (the closest populated area being the town of Igarka at a distance of 142 km away). Motorized transportation is used on winter roads from December to May only. Because of these conditions, strict criteria must be applied in the planning and selection of drilling fluid for the drilling of wells. These criteria include environmental, technical, technological, geological, logistical, and economic aspects that are not satisfied when using classical potassium chloride (KCl) inhibited solutions.
This paper discusses the selection process for the drilling fluid used in the Vankor field, the evolution of its formulations, and laboratory studies of various geological samples. It also discusses the application expertise required, as well as the technical and economic benefits and advantages of using a highly effective, inhibited, non-dispersed drilling fluid system based on a fresh water solution at the Vankor field.
Hybrid Drill Bit For Horizontal Drilling In Highly Interbedded Formations Of Timano-Pechora Arctic Fields
Authors: Kamatov K.. 
Published: October 2013

Abstract
Timano-Pechora is one of the fast growing hydrocarbon-containing areas of Russian Federation, possessing reserves of already discovered and being developed fields, as well as high offshore potential. Operators’ goals on intensive area development and increased well production rates were followed by a splash of lateral and sidetrack drilling in recent years. Doubtless, the upcoming huge regional projects would require a multiple increase of horizontal drilling work scope at an early date.
On this background, it’s necessary to distinguish a range of oilfields with highly interbedded terrigenous and carbonate rocks in their structure. Just 5 years ago drilling companies ran only insert cone bits of high IADC code with enhanced gauge protection due to hardness and abrasivity of rocks. Such a conservative method led to low ROP and high NPT for additional round-trips. Modern generations of PDC drill bits allow successful passing of homogeneous carbonate interval with a displacement motor (PDM) in few runs. However, deeper lying frequent interbeds of shale, siltstone, limestone and dolomite cause unpredictable torque on PDC bit, severe bottomhole vibrations and loss of BHA steerability. Therefore, drilling and service companies are forced to run roller cone bits to ensure planned build-up rates and hole quality. The conducted analysis of field data outputs that no type of drill bit (i.e. roller cone or PDC) can be effective enough under described conditions.
This paper depicts alternative combinations of BHAs and drill bits to provide higher technical and economical drilling indicators. It mainly focuses on the pair of conventional PDM with hybrid drill bit utilizing combined PDC and roller cone bits elements. Recommendations on drill bit selection are given based on case studies in similar conditions from two wells of Canadian Arctic oilfield.
"Secure Drilling" Services for Safe and Effective Drilling
Authors: Kulikov Stanislav , Veliev Gurban , Bakhtin Andrey , Zakomoldin Vitaliy 
Published: October 2013

Abstract
In the past few decades, well depths and conditions have grown significantly, and the regulatory environment has become more comprehensive. High temperatures and pressures, and narrow-to-nonexistent drilling windows have hindered the development of assets and substantially increased risks and the cost of hazard mitigation generated by high drilling costs and time spent on well control incidents.
From land rigs to semisubmersibles, closing the loop opens the door to a flexible set of drilling capabilities that improve safety of personnel, environment, and equipment while optimizing economics. In each drilling operation the key to success is the use of versatile closed-loop drilling methodologies to meet varied operational and economic objectives.
In Arctic conditions, the challenges are to overpass potential risk of environmental spills and optimize AFEs through mitigation of NPTs. Rotating control devices (RCD), which has secured a strong position in the industry, will be a considerable source to hit above targets. RCDs—whether as a top on the BOP stack or as an integral part of a riser system — is a safe and easy way to monitor pressure within the closed loop and divert the drilling fluids safely from the rig floor.
Integration of RCD in conjunction with early kick/loss detection and control systems through manipulation of surface backpressure, allows access to more accurate real-time downhole data, resulting in the ability to better manage downhole pressures. Changing choke settings results in a rapid modification of bottomhole pressure throughout the wellbore without the cost and effort of changing mud weight.
The closed loop method cuts across operational and economic applications to enable, for instance, the drilling of previously undrillable.
Development of Solutions for Arctic Offshore Drilling
Authors: Wassink Alain , van der List Remco 
Published: October 2013

Abstract
The paper discusses the origins and development of a portfolio of Arctic mobile offshore drilling unit designs, comprising both jack-up type and drillship type solutions. These designs are developed to address the specific challenges of exploratory and development drilling in the Arctic, and are developed to cover the full extent of the Arctic, from the very shallow to the deep water. The paper describes both challenges and proposed solutions, as well as providing an outline of the designs.
Drilling offshore in the Arctic poses many challenges to the field operators and drilling contractors alike. More capable and bespoke solutions than available today are required to enable commercially feasible exploration and field development in the Arctic. The key factor to the drilling part is total well cost, which requires an integral solution for the drilling system to be deployed, as opposed to the traditional day rate model of the industry. The design of the drilling rig plays a central role in this, and new designs for Arctic MODUs will be required to achieve this goal.
One of the dominant factors in total well cost in the Arctic is the length of the drilling season and subsequently the ability to drill one or more wells in a season. Lowering well cost by extending the season or even enabling year round drilling is a key factor. Efficient MODU designs, allowing maximum use of the available drilling season can further enhance economics.
The paper discusses the main challenges, such as harsh environmental conditions, ice loads, shallow water challenges and logistics, and their influence on the design of Arctic MODUs. It also discusses the main principles applied in development of these designs, related to subjects such as technology qualification, safety and environmental concerns. Finally, it provides an overview and outline of the proposed design solutions.
Optimized Particles Size Distribution Lightweight Cement at Low Temperatures: Case Study from Eastern Siberia, Russia
Authors: Malyshev Alexander , Doronina Tatiana , Popov Mikhail , Ryabchikov Alexander , Shulga Vladimir 
Published: October 2013

Abstract
Verkhnechonskoe oil field is situated in Eastern Siberia, Russia. This field is quite unique due to low formation temperatures –the bottom hole static temperature does not exceed 13 degC. This low temperature environment together with low formation fracture gradient present unique challenges for cementing operation. Conventional lightweight system extended by sodium silicate does not meet client well acceptance criteria – no sustained casing pressure (SCP) and successful annular space pressure test due to delayed compressive strength development and relatively high permeability of set cement stone. Failure to meet those criteria’s result in remedial cementing operations and delay of putting wells in production. To overcome this challenge new lightweight cement system based on optimized particles size distribution is successfully introduced for primary cementing of production casing on Verkhnechonskoe field. Implementation of the novel lightweight cement system with high solid volume fraction has allowed client to overcome highlighted issues. Rapid compressive strength development also helped in reduction of well construction time due to shorter wait-on-cement period.
This paper outlines an approach based on the usage of optimized particles size distribution lightweight cement system in low temperature environment included three steps of cementing operation: design of cement system, implementation and evaluation results.
A Novel Approach to Fluid Selection to Drill Pay Zones in Eastern Siberia: An Engineered Oil-in-Water Emulsion
Authors: Kharitonov Andrey B. , Burdukovsky Ruslan , Pogorelova Svetlana , Rodin S. V. , Kostarev N. A. , Usenko A. Yu. , Khampiev E. D. 
Published: October 2013

Abstract
The majority of promising oil and gas fields in Russia are located far north in remote, sparsely populated areas lacking infrastructure. The Srednebotuobinsky oil and gas field is one such example with stringent well construction, planning, and design requirements, particularly related to the selection of drilling fluids.
Drilling fluid selection is essential to help: achieve successful well construction, ensure wellbore stability, carry out and suspend cuttings, establish hydrodynamic equilibrium in the "wellbore-reservoir" system, prevent the ingress of gas, oil, and water, plug permeable formations, and preserve reservoir properties of the productive formation.
The main criteria for selecting a drilling fluid includes compatibility with the geological section, meeting design parameters, and environmental compliance/personnel safety. Projects in the far north are subject to additional criteria related to logistics, such as the ability to transport necessary materials by truck, the availability of roadways limited to the winter months, and abnormally low ambient temperatures.
This paper presents optimization results for a drilling fluid selected for penetration into a productive formation with an abnormally low reservoir pressure in the Srednebotuobinsky field. Also included are drilling fluid formulations, laboratory testing results, hydraulic calculations, and the technical and economic benefits of using a novel mud, which is a direct emulsion of mineral oil in water with biodegradable polymers.
Complex of New Solutions for Well Cementing in Deep North Conditions
Authors: Korostelev A. S. , Beley I. I. , Gilfanov V. R. 
Published: October 2013

Abstract
The development of Arctic offshore and outer continental shelf outlines for specialists a series of complex technical tasks related, in addition, to well construction (drilling and casing). Poorly developed transport infrastructure, severe climate conditions, permafrost zones and other complications require the application of an integrated approach to well drilling and construction design.
The description of innovation integrated of production solutions and approaches, applied at well cementing in the fields of the Yamal Peninsula, including the solution of a cementing unit with mixing and pumping systems (with an integral dry mixture pneumatic system) integrated into the echelon rig, is presented in the paper. And also the description and analysis of application of the unified compositions of cement slurries and preflushes, specially developed for this "on-the-fly" mixing system, that enable to facilitate materials’ delivery and storage operations at remote locations and encourage simplifying cementing technologies.