bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sampling with Multiphase Flowmeter in Northern Siberia - Condensate Field Experience and Sensitivities
Authors: Afanasyev Vitaliy , Theuveny Bertrand , Jayawardane Sylvain , Zhandin Alexander , Bastos Vlamir , Guieze Paul , Kulyatin Oleg , Romashkin Sergey 
Published: October 2008

Abstract
Multiphase well testing has been acknowledged worldwide as a state-of-the-art technology for metering stream of oil, gas and water without prior phase separation, and provides in many cases much more accurate picture of the transient evolution of flow and more accurate picture of the volumes and rates especially in cases of condensate and heavy oil environment, where traditional means of measurements are impaired by the difficulty to separate the phases. Furthermore, in-line multiphase flowmetering brings significant benefits to the ease of deployment, especially in harsh regions such as the one encountered in Northern Siberia.
One of the past challenges of multiphase well testing has been the ability to collect representative fluid samples for analysis. The paper presents a solution to this problem and results obtained in number of well tests performed in Russia, complemented with experiences from operations in other countries.
This paper documents new type of sampling device that allows collection of samples, determination of in-situ volumetric ratios and determination of dry gas properties that can minimize an uncertainty propagated by the incorrect input of key fluid parameters in the computation algorithm of multiphase flowmeter.
Not only does this state-of-the-art device allows to capture fluid samples bridging the gap in fluid sampling in a multiphase environment but also supplements for carrying out real-time compositional analysis and basic Pressure-Volume-Temperature (PVT) measurements at wellsite, allowing to compute improved flow rates with MPFM. Hence it provisions two major tasks: the fluid sampling, required for any type of well testing to optimize well tests, and capture of samples for further analyses in a PVT laboratorf after sample recombination using improved phase ratios.
The paper describes deployment of such methodology in Northern Siberia in condensate well tests and offers a number of comparison tests against traditional well testing and fluid analysis methodologies. A recap of lessons learnt captures the best practices of the methodology to ensure optimized utilization of the technique.
The paper focuses on the sampling and fluid analysis aspects and utilization of the fluid information for multiphase well testing. The consistency of the multiprate well test information is not covered in still paper, as the analysis of some condensate to gas ratio between chokes is still ongoing at this stage and will be presented in a separate article.
Structure Features of the Paleozoic Complex of East Siberia Based on Results of Complex Seismic and Well Log Data Interpretation
Authors: Nagaeva Indira , Ahunyanova Elmira 
Published: October 2008

Abstract
In this work, a complex approach to studying a Paleozoic base structure of the East Siberian plate is considered. The area of research is dated to the Nurol trough in the tectonical plane, and despite a significant level of exploration maturity by various geophysical methods and drilling, there are many questions and unresolved problems.
Even a question as to correct mapping of pre-Jurassic surface remained opened until now as the roof of a Paleozoic section is changed by a paleodenudation so that the acoustic properties come nearer to the horizons of the bottom Jurassic complex. Also a seismic picture is complicated by a great number of various amplitude and extent tectonic deformations and the phenomenon of an interference connected with discordant bedding of the Jurassic sedimentary formation on the Paleozoic base.
To create an authentic geological model of reservoir structure, detailed interpretation of 3D seismic data combined with geophysical logging data was required. This interpretation includes structural, paleotectonical, seismic, and facial and dynamic analysis of the data being interpreted. The results of the analysis relate a certain regularity in forming a Paleozoic complex and reveal the most prospective areas of oil deposits.
Development of Water Saturation Error Analysis Charts for Different Shaly Sand Models for Uncertainty Quantification of Volumetric In-Place Estimate
Authors: El-Sayed Samiha S. , Daoud Ahmed M. , El-Tayeb El-Sayed A. 
Published: October 2008

Abstract
Quantifying the uncertainty in the volumetric estimation of original oil in place (OOIP) is an important process in evaluating the field potential and hence in designing the proper and the most economical subsurface and surface facilities to produce the field reserves. This uncertainty in the OOIP estimate results from uncertainty in reservoir areal extent, net reservoir thickness, porosity, and hydrocarbon saturation. In this work, a methodology is presented to assess the uncertainty in the hydrocarbon saturation estimated from open hole logs using the commonly used empirical and theoretical shaly sand models.
This technique is based on development of water saturation error analysis charts for the commonly used water saturation models (Simandoux, Indonesian, Waxman & Smits, Dual Water, and Effective Medium) due to the uncertainty in the different input parameters to each model separately. Both analytical and numerical error analysis techniques were used to develop these charts and hence used as a forward tool to quantify the uncertainty in the hydrocarbon saturation due to the uncertainty in the petrophysical and electrical rock properties.
Fifteen wells with 1300 shaly sand points from Alam Bewab formation, in Western desert of Egypt, were used as our data base in generating these error analysis charts. The uncertainty in input data was assumed from ± 5 to ± 15%. The results showed a significant range of uncertainty in hydrocarbon saturation estimate from ± 0.3% reaching to ± 85% in some models.
General water saturation error analysis charts were developed, for each model, based on the above mentioned database and validated mathematically. These charts can be easily used to predict the uncertainty in hydrocarbon saturation estimate due to uncertainty in the input data. In addition, it can be considered as a useful screening tool to select the best saturation model to be used depending on the input data uncertainty.
An Innovative Acid Stimulation Technique for Reviving Dead Wells in the Ghawar Field of Saudi Arabia - A Holistic Approach
Authors: Haldar Surajit , Al-Jandal Ahmed A. , Al-Driweesh Saad M. , Al-Eid Mufeed H. , Ramanathan Venkateshwaran , Ovtchinnikov Kirrill 
Published: October 2008

Abstract
The Uthmaniyah field is one of the biggest sub fields and older producing sections in the giant Ghawar structure. A few wells have been dead for sometimes due to high water cut (60 to 80%). In all cases the target interval was only 5’-10’ at the top of the dominating water producing zones. There was no scope of water shut-off and artificial lifting. The pilot stimulation comprised of trials in a number of such wells with similar reservoir producing conditions. Isolation of bottom intervals by conventional gel-plug method was not very suitable here because of very marginal target interval. Even slightest inaccuracy of the coil tubing depth meter or depth correlation could be detrimental due to very close water producing interval.
The treatment involving the use of high viscous visco-elastic surfactant (VES) diverter technology and controlled bullheading placement was designed to achieve effective acid diversion during acid stimulation. Stages of high viscous VES was pumped as a diverter to temporarily plug the dominating water zones, followed by considerably low strength HCl acid to achieve shallow wormhole growth. All the wells responded to the treatment with sustained oil gain. Although water cut remained high, the well head pressure increased substantially to flow the well naturally.
This paper discusses the planning and design processes leading to the successful implementation of the technique, the experience during the stimulation treatment execution and the excellent post-stimulation results. Considering no cases of matrix acid stimulation in high water cut wells in the field, this technique promises to deliver in similar wells here and elsewhere. The significance of the new well stimulation technique is to revive dead wells with very high water cut and also to enhance oil recovery from these wells in a cheaper, easier and effective way.
Using Resistivity Log Invasion Profiles, Multiple Porosity Logs, Core and Test Data to Determine Lithology, Porosity and Permeability in Pre-Cambrian Sandstones of Eastern Siberia
Authors: Prasse Eric M. , Hornbrook J. W. , Tye R. S. , Putnam Timothy W. 
Published: October 2008

Abstract
The Verkhnechonskoye field was discovered and appraised during the late 1970s and early 1980s. One hundred legacy wells and three modern wells have been reevaluated and results used to construct a static model that matched test results and was used to forecast field potential. The Verkhnechonskoye field is currently operated by TNK-BP.
Cores in the three modern wells were studied to determine lithology, depositional facies, and mineralogy. Results were applied to crossplots of sonic and neutron log data. These crossplots showed six different lithofacies: basement, weathered-basement, high permeability sand, low permeability sand, salt/anhydrite-cemented sand, and carbonate. Sand was subdivided into relatively high and relatively low permeability sands using the laterolog and microlaterolog, based on the observation that sand with microlaterolog values less than 10 ohm-m were observed to be highly productive on test. To calculate porosity, the neutron, sonic, and core porosity were compared. Preliminary porosity was calculated using a field-wide solution from a combined crossplot of sonic log values and core data. Well by well analysis indicated that the sonic logs often underestimated porosity and that neutron logs tended to match core porosity better. Petrographic analysis confirmed that widespread secondary porosity was not detected by sonic logs. Single-well porosity solutions based on neutron logs were used together with sonic porosity calculations to finalize porosity estimates. For permeability, high and low trends were calculated for sands using the microlaterolog to define high permeability and low permeability sands. A relatively high permeability to porosity relationship was applied to sands with microlalaterolog values less than 10 ohm-m and a relatively low permeability to porosity relationship was applied to sand with microlaterlog values greather than 10 ohm-m.. A significant number of core permeability measurements were available and these points were honored after depth-shifting. Finally, log derived permeability was modified to match average permeability derived from well test results.
Identification of multiple lithologies and calibration of porosity and permeability to core measurements and well test results signficantly reduced uncertainty in calculated results.
Appraisal of a Precambrian Oil and Gas Field: Verkhnechonskoye Field, East Siberia, Russian Federation
Authors: Tye R. S. , Hornbrook J. W. , Prasse E. M. , Robinson G. C. , Lowe D. R. , Morozov V. V. 
Published: October 2008

Abstract
To evaluate uncertainty in property distribution and reservoir connectivity, resource size, and development plans for Verkhnechonskoye, a large Precambrian oil field, three geologic models were built employing: 1) Sequential Indicator Simulation (SIS) and Sequential Gaussian Simulation (SGS); 2) Object Modeling; and 3) Seismic-Attribute Modeling. Reservoir models were based on seismic and wireline-log, core, and well-test data from over 100 wells.
The reservoir consists of sandstone, mudstone, and rare conglomerate deposited on a broad alluvial plain fringing an igneous and metamorphic continental island. Coarse-grained sediments were deposited in channels that prograded and aggraded the alluvial plain that terminated downdip into a lacustrine or epicontinental sea. In places, lagoons and poorly developed beaches fringed the alluvial plain. Relative base level created upward-coarsening and upward-fining successions that onlap the basement. Shale beds create flow barriers while, porosity and permeability are primarily controlled by evaporate, quartz, and calcium carbonate cements.
Buildup and interference tests were designed using estimated average reservoir properties. Test results discriminated among the three geologic models for use in field-development planning. Partial field-simulation models were upscaled from each geologic model and used to match the buildup and interference tests. The SIS model surpassed the Object and Seismic models in matching well performance. This better match of well performance from the SIS model occurred because sandstones are better connected and exhibit more homogeneous rock properties as compared to the Object or Seismic models. It was concluded that the SIS method of facies and property distribution is preferred for future modeling in the field.
Can Gas Hydrates Provide a Solution to Gas Utilisation Challenges in Russian Oil Fields?
Authors: Azarinezhad R. , Valko I. , Chapoy A. , Tohidi B. 
Published: October 2008

Abstract
The expanding demand for primary energy has pushed exploration and production activities towards more challenging environments, such as the north slope of Alaska, Siberia and deeper oceans. In many cases associated gas could be a limiting factor in the field developments. While stabilised oil could be transported by pipelines and/or tankers, the options for gas and associated gas is rather limited and/or not economical.
There are strict limitations on flaring due to environmental/economical concerns, and most of the available options for gas utilisation (e.g. gas to liquid, gas to wire, compressed natural gas…) require considerable CAPEX. Recently, we have proposed HYDRAFLOW, which is a Cold Flow solution for avoiding gas hydrate problems. This could provide a solution for gas transportation.
The concept of HYDRAFLOW is based on allowing/encouraging gas hydrate formation, but preventing their agglomeration and pipeline blockage by using chemicals and/or mechanical means. The aim is to eliminate/minimise the gas phase by converting it into hydrates and dispersing hydrates in oil and/or aqueous phase. Water could be added to maximise gas conversion into hydrates and/or adjusting the slurry viscosity. Furthermore, a loop concept has been developed where part of the liquid phase could be recycled, minimising chemical discharge to the environment.
As HYDRAFLOW basically converts gas into hydrates and transport it as slurry in a liquid phase, it could provide a solution for gas utilisation for fields where the ambient temperature and pipeline pressure are inside the hydrate stability zone. In this communication, after introducing the HYDRAFLOW concept, the latest results of laboratory tests at subzero conditions are presented as well as an economical evaluation and a pipeline transportation simulation on one of the West Siberian oil fields. These simulations demonstrate that the concept is viable, and suggest that HYDRAFLOW technology could offer significant benefits over existing flow assurance strategies, providing a novel low CAPEX/OPEX solution for gas utilisation.
"Pumping up the Life" of Electric Submersible Pump Systems, Russian Federation
Authors: Borling Daniel C. , Sviderskiy Sergey V. , Gorlanov Sergey F. 
Published: October 2008

Abstract
This paper is the first in a series describing results and lessons learned from longer run life across 13,176 Electric Submersible Pump (ESP) systems in TNK-BP. ESP artificial lift is the dominant method for producing approximately 90% of TNK-BP's oil volume, which averages more than 200,000 tons (1.5 million barrels) per day.
A sustainable economic benefit for TNK-BP was defined during 2006, and this benefit directly results from increased ESP run life. The 5-year value was estimated at $350 million and long-term forecast was $1 billion. An indirect benefit from longer run life was better HSE performance due to reduced exposure to oil field hazards from fewer rig days pulling ESPs.
Since 2006, TNK-BP has gradually changed the way it thinks about ESP run life and lessons learned are provided in this paper as a case history.
ESP run life was about 300 days MTBF when the project started and the 5-year goal was set at 600 days MTBF by year end 2011. Elements for success included leadership structure, coordinated teamwork across multiple internal business segments and continuous equipment improvement using root cause failure analysis. Reducing frequent failures was a basic priority as was technical equipment innovation and pilot project expansions.
Results have been impressive with run life steadily increasing each month. Run life improved to 410 days MTBF during August 2008 from 296 days in January 2006. This 114 day run life increase has already prevented 550,000 tons (4 million barrels) of deferred oil, reduced $50 million of operating costs and saved rig time. The $350 million project value did not include redeployment of rigs to complete other oil enhancing work such as hydraulic fracturing and acid stimulations.
During 2004, TNK-BP joined the ESP-RIFTS Joint Industry Project. The ESP-RIFTS System allowed TNK-BP to further develop and implement a unified way to classify and analyze ESP data for a huge well stock. The result was strategic operating changes, one of which was stopping the purchase of the lowest reliability equipment. Failure analysis was fundamental in helping TNK-BP with its initiative to get the right equipment into the right well.
Development of Fields with Complex Environmental History – Key Engineering and Technological Solutions
Authors: Matevosov A. R. , Diyashev I. R. , Kruchkova T. V. , Maslennikova Yu. V. , Zubareva A. V. 
Published: October 2008

Abstract
This paper is dedicated to the key engineering solutions concerning development of the Kumzhinskoye field. The focus is put on the field development principles related to its complex environmental history.
The challenge we face in this field results from an accident that occurred while drilling well 9 in the crest of the structure due to failure to meet regulations on integrated gas and gas-condensate well testing procedures with regard to well production rates through orifices of certain size and duration of well production at those rates. Abnormally high gas flow rates amounted to 807 thousand m3 per day. The problem and severe pollution near the well resulted from a nuclear explosion 1500 m deep aimed at shearing the wellbore due to displacement of a rock mass. However, instead of the accident remediation the explosion increased the area of gas and condensate blowouts. As a result, a huge damage was inflicted to the environment and the Pechora river delta ecosystems. Exploratory wells are exposed to aggressive hydrogen-sulfur medium. Poor cementing creates the conditions for gas crossflows from natural reservoirs to overlying water bearing zones forming human-induced gas deposits. Accident remediation took almost 15 years.
It is important to realize that environmental challenges of this field are so huge that it is useless to handle them from the surface. Solution of environmental problems requires an integrated approach to the field development.
First, the primary reservoir is to be depleted to make its pressure drop below the pressure in the secondary induced deposits (200 Atm) and shut down the upward gas migration. Second, shallow slim holes are to be used to deplete induced deposits. To minimize the environmental damage, we are planning to ensure complete gas recovery using only 18 horizontal wells. We shall drill those wells from only 2 well pads minimizing land allotment for industrial purposes. In addition, these well pads are located in dry elevated areas outside the national reserve territory.
First results of Exploration Works in the West Ural Fold-and-Thrust zone of the Pre-Ural Foredeep
Authors: Danilov Vladimir N. , Ivanov Victor V. 
Published: October 2008

SUMMARY
The exploration area comprises the territory of the northernmost depression of the Pre-Ural Foredeep, called the Kosyu-Rogovskaya Depression, adjacent to the regions of the Circumpolar and Polar Urals (fig. 1).
The Pre-Ural Foredeep stretches from the south to the north from the Caspian Sea region to the Pechoromorsky shelf and covers approximately 3,000 square kilometers. Not all zones of this foredeep have sufficient geologic-geophysical data. The outer western zone which is adjacent to the East European Platform and the Pechora Plate is most explored; the central deepest part of the foredeep is less explored except for the largest anticlinal structures; and the inner eastern area characterized by the extensive development of the thrust dislocations has almost no geologic-geophysical data.
Taking into account the worldwide experience in performing works at foredeeps which proved high gas-and-oil presence of such tectonic elements, the fact that 5 subsidiary companies of "GAZPROM" OJSC are situated on the territory of the Pre-Ural Foredeep, considering also the availability of well-developed gas transport system (four gas-main pipelines pass through the foredeep, and the 5-th line is being constructed at present) and ultimate gas consumers the Geological Survey of "GAZPROM" OJSC is developing the Programme for the performance of exploration works on the territory of the Pre-Ural Foredeep.
According to this Programme exploration works including aero-space, geochemical and geophysical surveys and deep prospecting-and-appraisal drilling are performed in two license blocks located in the zone of juncture of the Kosyu-Rogovskaya Depression on the western slope of the Urals (fig.2).
In the first stage of works including remote sensing, geochemical and geophysical surveys the data confirming a great number of structures in the explored territory were obtained, also the traces of hydrocarbon migration were found out. The obtained data allowed to specify the tectonic zoning and determine first-priority objects to perform deep drilling works.
The second stage that provides for drilling of the two first-priority prospecting-and-appraisal wells (one at each license block) and the detailed seismic surveys is underway. One of the wells is already drilled while the second is being drilled. The interpretation of seismic data is being carried out.
The data obtained from the second still incomplete stage of works has already fundamentally changed the idea of: 1) geological structure of the explored territory; 2) mechanisms that form the fold-and-thrust zones of the whole region under consideration.
Research of Conditions and Scopes of Water-Gas Influence on the Layer with the Purpose of Increase in the Current and Final Oil Recovery Factor
Authors: Telkov V. P. , Egorov Yu. A. 
Published: October 2008

Abstract
On a background of the relative well-being connected to the high prices for oil insufficient attention it is given difficult-developing to stocks of oil which share in total amount of stocks constantly increases. In due course it can lead to full development of easy-developing stocks of oil, and the kept need for fuel and raw material for the chemical industry will lead to necessity of development difficult-developing stocks to which it is possible to relate oil in collectors with low permeability and essential heterogeneity, or to oil of the high viscosity.
Displacement of the oil by water, widely distributed in Russia, for fields with difficult-developing stocks it appears insufficiently effective. Therefore, oil recovery of developed deposits decreases.
In these conditions significant interest is shown to gas technologies of increase oil recovery, first of all to the water-gas influence (WGI) allowing not only to receive from a layer additional oil, but also it is useful to use the associated gas now aimlessly burnt on torches.