bluuebunny/crossref_metadata_2025_split huggingface dataset:
Critical Intra-Field Pipelines Inhibition Technology Using Batching Pigs
Authors: Sukhnat Yegor Yu. 
Published: October 2008

Abstract

Introduction:
Intra-field pipelines is the most critical constituent of pipeline network used by subsoil users in Khanty-Mansiisk Autonomous District–Yugra. Total length of pressure pipelines in TNK-BP spans 2,965 kilometers: 9% of the total web is corrosion-resistant whereas remaining 2,706 kilometers in operation are not protected against corrosion. Average life of a pipeline is 12 years. A pipeline break, if occurs, may not only drive to shut-down of a field but also have serious technogenic and environmental implications. The Company has developed and put in place a prioritization program, which classifies this group of pipelines as critical. According to the program, these pipelines require time and efforts to assure integrity and longer service life.

Goal:
The goal is to develop and implement a technology of intra-field pipeline inhibition with the use of batching pigs.
This goal sets the following objectives.

Objectives:
Assess operational and economic efficiency of the existing and proposed intra-field pipeline inhibition technologies; Select corrosion inhibitor with adequate properties; Develop Instruction Pigging and Inhibition of Pressure Oil Pipeline between DNS-24 and KSP-1 4 using Batching Pigs Develop an operational procedure for pressure oil pipeline DNS-24 – KSP-14; Run field trials of the proposed technology in the pressure oil pipeline between DNS-24 and KSP-14, OJSC TNK-Nizhnevartovsk.

Project description:
There are two (2) inhibition methods in use in the Company: continuous dozing and shock treatment. When inhibiting lengthy pipelines, these two technologies have shown their major week point – inhibitor is difficult to deliver to the cleaned metal surface that consequently leads to the small probability of generating a reliable protective film.
The proposed system ties together two existing technologies extending pipeline service life: pipeline pigging and inhibition. This technology represents a set of below successive operations:
launching of a solid pig; injection of calculated volume of corrosion inhibitor during specific time set in the Instruction; launching of a polyurethane foam pig to tail.
The proposed inhibition technology with the use of batching pigs allows coating of pigged metal surface with inhibition film (PД, 39-23-1082-84). As records state, cleaned metal surface coated with strong inhibitor solution increases inhibition effect by 15-20%.
Effect of Fluid Volume and Production Rate on Oil Recovery in Oil Field Development by Waterflooding Methods
Authors: Diyashev R. N. , Blinov A. F. 
Published: October 2008

Abstract
The five large oil fields found in the Russian Republic of Tatarstan have been producing from the Devonian sandstone reservoirs for more than fifty years. Currently all of them have entered the maturity stage. In all five fields waterflooding methods have been applied since the very start of production. And though the principal development approaches and strategy do not differ, development rate, volumes of fluid produced, actual and design oil recovery factor (ORF) do differ. The largest of the five fields, Romashkinskoye, has been developed in independent areas divided by injection wells’ rows. There are 21 such areas. Comparative analysis of these areas’ performance is of specific interest.
To make a generalized estimate of production performance of the five fields, we have ranked them by a number of geologic parameters. The same ranking has been performed for all areas of the Romashkinskoye oilfield. For the purpose of analysis these areas have been further divided into seven groups by a common integral geologic parameter.
The investigation method involves a correlation analysis of the fluid production and oil recovery profiles at different stages of development of both fields and areas; as well as evaluation of the present-day status of development, in that number with account for the tendency towards operating assets’ change.
It has been demonstrated that the oil recovery factor and its behavior at different development stages depend to a large extent on reservoir geology. Besides, there is a close correlation between fluid and oil production rates. In mature fields very important factors are status of assets and producing wells’ density. Fields and areas have been identified which call for immediate rejuvenation operations.
Development of Effective Numerical Model for Heavy Oil Production Using Steam-Assisted Gravity Drainage
Authors: Klemin D. , Pimenov V. , Rudenko D. 
Published: October 2008

Abstract
One of the modem technologies for heavy oil and bitumen recovery is SAGD (Steam Assisted Gravity Drainage), which use two horizontal wells, one above the other with spacing 5-10m. Upper well is used for steam injection and creating the high-temperature steam chamber (SC). On the SC boundary the steam is condensing and water together with the heated oil flow downward into production well.
Pressure and temperature (P/T) measurements in injection and production well are used to control production process. This data contains only indirect information about the steam chamber parameters and oil inflow profile along the well length, therefore various mathematical models should be used to interpret measurement results.
P/T measurements interpretation, optimization of steam injection regime and analysis of reservoir heterogeneity influence on SAGD parameters are commonly performed on 3D models, which need tremendous computational resources and provide results within an inapplicable time (several days and even weeks) for field usage.
Present work is devoted to development of the effective SAGD numerical model. It is based on the well admitted in literature assumption, that horizontal steam flow along the injection well prevail over the horizontal steam flow along the reservoir. Thus 3D simulation can be substituted for by the 1D simulations for the injector/producer connected with N 2D cross section reservoir models which are connected only through injection and production boreholes (an example is in paper4). Injection well model provides steam pressure/temperature profiles for 2D cross section models. In turn these models calculate profile of steam injection rate which is an input data for injection well model. Developed 1D + N*2D SAGD model can be used for fast SAGD simulation and for injectivity profile inversion from P/T data recorded in injection well.
1D model of injection well with tubing inside the well for steam injection at the heel and/or at the toe was developed. It assumes two phase (water/vapor) flow with ‘drift flux’ and heat exchange between tubing and annulus flow. Nevertheless, analysis of field data recorded by DTS in injector shows that assumption of joint flow of the water and vapor along the injector, and hence simultaneous injection of the vapor and the water in reservoir can be violated in some cases. Modification of the 1D injection well model with separated distributed vapor/water injection in the reservoir was developed. Simulation results obtained obtained with modified model are able to reproduce qualitatively field data behavior.
Geological field classification of reservoir rocks of Ardat horizon, Rodnikovsky field, Orenburg Oblast
Authors: Nemirovich T.G. , Shakirov V.A. , Luzina L.A. , Virskiy D.A. 
Published: October 2008

Major production zone on Rodnikovskoye field is Ardatov terrigenious deposit (D3 reservoir). At Brownfield stage when main reserves are recovered, more attention is paid to cross-section improvement. Typically, maximum oil is produced from reservoirs with good reservoir properties.
Many researches describe the relationship between SP relative amplitude and silty and clay material in the reservoir. V.S.Muromtsev sufficiently describes reservoir classification method based on grain size and aSP (Nedra 1984). The feature of spontaneous polarization method (SP) in terrigenious rocks allows to identify shale volyme and grain size effect, i.e. define two main lithological parameters. They help to determine terrigenious rock deposition settings and evaluate rock properties.
Table 1 shows rock type determined by authors vs. lithotype determined by V.S.Muromtsev. There is some discrepancy in prevailing sandy fraction. According to grain size analysis, the core samples are fine-grained sandstone which is due to insufficient quantity of samples taken in high aSP zones. Therefore, based on relative curve parameter aSP=0.75–1.0, coarse and fine-grained sandstone was associated with rock type I; based on V.S.Muromtsev classification, aSP=0.6–1.0 sandstone is divided into two types: coarse-grained and fine-grained. The range of aSP=0–0.25 corresponds to shales, aSP=0.25–0.5 corresponds to siltstone and argillaceous-silty rocks. Mixed rock type (sandy-siltyargillaceous) corresponds to average level of aSP=0.5–0.75. Thus, the grain size-typing study performed in TNNC does not contradict other investigators' data.
Modern Scientific and Technical Concepts for Oil Production and Processing
Authors: Muzipov Halim N. , Erka Boris A. , Savinykh Yury A. , Dvinin Anatoly A. 
Published: October 2008

Abstract

NEW PUMPING EQUIPMENT
B. A. Erka, A. A. Dvinin
VANE PUMP
In view of oil production restraints, such as high viscosity, high gas-oil ration, entrained solids, etc., current oil production methods are limited because low-pressure area is required at the submersible pump inlet for the subsequent compression and pumping of reservoir fluid into tubing.
The implication of this new artificial lift method is that vane pump is used instead of submersible pump (Fig.1) [1], as vane pump retrieves reservoir fluid without low-pressure area created at the pump inlet as the working elements (vanes) can operate directly in reservoir fluid.
INFORM Knowledge Hub
Authors: Muratov Fedor 
Published: October 2008

Abstract
In the modern world the development of informational technologies is going on at a breakneck pace. Often the company that starts implementing them in the business earlier surpasses its competitors by far in all key indicators. Based on this, the decision to develop and deploy the state-of-the-art information technology in OFS subsidiaries was taken. This system was named INFORM.
INFORM system is a multi-functional intranet portal that stores and processes important operational information of OFS subsidiaries. INFORM consists of key sections, such as Drilling, Workover, Technical Maintenance and Repair, Quality Management System, Operational Forum, and Training Programs. Thanks to INFORM, rig toolpushers can enter daily operations reports, and HQ managers can review operational performance at all wells based on these data. The portal has a great number of reference operational data, Field Operations Manuals, and the results of rig audits. The interactive map of Russia can show you the location of each rig and get the contact data of every toolpusher. All operational incidents in every subsidiary are stored in INFORM, so toolpushers have the opportunity to prevent them in their own crews. INFORM's Operational Forum has important operational issues discussed and information shared. The information contained in INFORM is Company's property: all TNK-BP users have the access to this site, while the operational data of INFORM is available only for the registered users.
So INFORM is the system we have designed to allow OFS to collect, organize and share knowledge which allowed for accelerating the process of decision making in OFS.
While implementing INFORM project team achieved next results:
– Evaluated the availability and quality of communication channels at the rigs, In case no communication channels are available, they were built with the optimum capacity using satellite technologies – Purchased and installed the required server and computer equipment in the subsidiaries and rigs. – Held a tender among IT companies on the development of System according to TNK-BP and OFS standards – Developed the interface of the future portal – Entered all data into INFORM. Obtain data from the services: HSE, HR, Quality, Technology department, etc.
Testing and Analysis of Wells Producing Commingled Layers in Priobskoye Field
Authors: Davletbaev Alfred , Ozkan Erdal , Slabetskiy Andrey , Nikishov Vyacheslav , Usmanov Timur 
Published: October 2008

Summary
This paper discusses a Downhole Flow Control (DHFC) technology and describes its application for injection and fall-off testing of commingled layered reservoirs. The Simultaneous Separate Injection (SSI) technology has been successfully applied in over 150 injection wells by the Rosneft Oil Company in the Priobskoye Oil Field. The SSI assembly is a cable tool consisting of valves, packers, and pressure transducers and provides the ability to distribute the surface injection rate into individual layers in a controlled manner. The ability to control layer injection rates is intended for effective flooding of poor-injectivity layers. The concurrent measurement of layer pressures also provides the opportunity to simultaneously test multiple layers. Currently, the SSI assembly only regulates the distribution of the layer injection rates but does not measure the bottomhole injection rates. Valves on the SSI assembly are preset at the surface based on the spinner tests to determine the injection profile. The main advantage of this technique is the drastic reduction of test time and cost to obtain estimates of individual layer properties and injectivities. This paper focuses on the use of the SSI assembly in pressure-transient testing of commingled, multi-layer reservoirs. The application of the testing technology and the analysis of measured test responses are demonstrated on examples from the Priobskoye Field. Also presented are the results of the Single-Layer Steady-State Injection Tests. These tests are useful to understand the fracture development during injection and the resulting injectivity increases. This information is used to regulate the layer injection rates with the SSI technology and the in the design of the injection and fall-off tests.
Formation Hydrofracturing Experience on Horizontal Wells of Rosneft
Authors: Haidar Azat , Vafin Ilnur , Borisov Gleb , Dzhabrailov Ajndi , Nikitin Alexey 
Published: October 2008

Abstract
The available hydraulic fracturing (HF) techniques for horizontal wells (HW) allow stimulating one or several HW intervals, as well as creating fractures lying at various angles to the horizontal wellbore. The simplest of these methods available to operators is conventional HF; besides, operators may make use of different interval-wise HW stimulation techniques – both with and without packer systems.
During 2006-2007, Rosneft Oil Company performed over 20 HW HF operations. Two HF technologies have been tested: Conventional Frac and multiple-point Hydrajet stimulation. The obtained results demonstrate the efficiency of HF on Rosneft fields, in West Siberian geological conditions: HF has allowed reactivating a number of wells.
The considerable stock of horizontal wells has made it possible to analyze the influence of various factors affecting HF efficiency, such as completion, wellbore orientation, and formation permeability. Several operations were successfully carried out against weak water and gas barriers.
This paper presents Rosneft's experience of HF in horizontal wells and adaptation of conventional HW hydrofrac techniques to West Siberian geological conditions. The article features also some details of HF operations and the results arrived at; HW HF risks and limit conditions for different technologies are defined. Some criteria for HF candidate selection are given.
The Pilot Project: Application of Methods of Oil and Gas Geochemistry for Localization of Petroleum System of the Western Caucasus Basin
Authors: Jurevna Suslova Ellina 
Published: October 2008

Abstract
In 2007 our company has begun work above the East-Black Sea project. Its basic purpose - allocation and localization petroleum system of the Black Sea region for a gain of a raw-material base. In view of that within the limits of considered water area are not drilled wells, the forecast of petroleum system it is spent on the basis of studying regional oil and gas system of adjacent territory - Western Caucasus basin.
On the basis of complex studying Jurassic and Cretaceous source rocks with use of modern methods of organic geochemistry (pyrolysis Rock-Evals and also were analyzed for aliphatic biomarker hydrocarbons (n-alkanes, i-alkanes and aliphatic isoprenoids) and cycloaliphatic hydrocarbons of sterane and terpane series using gas-liquid chromatography and chromatography/mass spectrometry) it is established:
the highest oil and gas potential are peculiar to locally widespread titon (J3) and senoman (K2) source rocks;
in overwhelming majority low Cretaceous source rocks are carried to a category petromaking, low and middle Jurassic to a category petromade, except for middle Jurassic source rocks of the East-Kuban hollow;
the generated petroleum and natural gas are expelled from the source rock can be take place on depth (from 20003000 - up to 6000 metres);
in a quantitative sense the greatest contribution to generation liquid hyqrocarbons have brought Jrassic and Cretaceous source rocks of axial parts of depressions.
Introduction
The Western Caucasus basin is administratively dated for Krasnodar region - large area with the developed infrastructure (Fig.1). At the present stage the most part of oil and gas pools have lost the profitability - they are considerably developed or are in a finishing stage of development. Objects of search can be deposits in less studied mesozoic source rocks, both within the limits of a continental part, and in the Azov and Black seas. Presence of oil fields and gas in Jurassic and Cretaceous petroleum system allow to consider them as perspective.
Gas/Oil Reservoir Pressure Maintenance by Way of Gas Injection
Authors: Romanov A. S. , Zolnikova E. F. 
Published: October 2008

Abstract
Of all available EOR methods deployed in thin oil rims and gas/oil reservoirs gas intervention techniques seem the most effective1,2,3,4,5. The study of practicability of this method was carried out at one of West Siberia gas/oil reservoirs. Natural pressure depletion is the chosen production method for the reservoir in question. Almost 150 wells were drilled within the limits of the reservoir. The dominant production mechanisms are free flow and gas-lift. By the beginning of 2008 average reservoir pressure dropped to 13.0 MPa from the original 28.0 MPa. Decline of formation pressure well below saturation pressure (19.0 MPa) resulted in wells’ shutting-in and curtailment of producing well stock. Prevailing causes of well problems are flooding and gas coning while in service. Mean water cut is 10%, GOR is 1600 CUM/MT, while oil production rate of available stock does not exceed 13 MT/D against start-up values of about 100 MT/D.
A well drilled next to one of the clusters of the reservoir in question exposed overpressured B4 stratum. Gas flowrates in the well reach up to 106-166 MCUMD with wellhead pressures of 25.0 to 30.0 MPa. This fact encouraged the studies of possibility of gas/oil reservoir pressure maintenance by way of injection of high-pressure natural gas.
Determination of Horizontal Borehole Geometry by Ultrasonic Pulse-Echo Method
Authors: Smirnov Nickolay A. , Varykhalov Aleksey S. 
Published: October 2008

Abstract
The information on the horizontal borehole geometry (size and shape) is needed in well logging interpretation and solving engineering tasks, for example, choosing a place for mounting a casing pipe seal. Direct application of mechanical driven logging devices such as used in a wire line caliper tool is impractical in horizontal boreholes. The borehole geometry can be determined by ultrasonic caliper operating in a pulse-echo pattern. Such techniques have been successfully used in wireline logging for borehole imaging and cement bond evaluation, but meet some obstacles in horizontal wells. A rugous borehole wall and low difference in acoustic impedances of formation and drill mud are the reasons of acoustic pulse high attenuation. In horizontal boreholes the logging tool is always decentralized and consequently the pulse travel time may be less than transducer ringing duration. These concerns with ultrasonic measurements lead to a task of finding a reflected signal amid overwhelming noise.
Using transducers similar to those of wireline scanners and applying robust algorithm to data processing can solve the task. The principal procedure of processing includes regular noise extraction by compiling waveforms of the neighboring depth steps in time domain. The search of reflected pulses in waveforms is provided by time windowing and finding the first reflections in frequency domain.
Application of described techniques in memory logging tool and data processing discovered a durable method of caliper measurements in horizontal boreholes. Field tests have demonstrated the capabilities of proposed logging method in borehole shape determination. Actually in more than a hundred boreholes average diameters were measured without discontinuities. The error of diameter determination was in the range of ±2 mm.
The results of field tests gave a hope for the ultrasonic caliper application to both borehole shape measurements and stress direction determination.
Pilot Project: Remote Monitoring Centre
Authors: Monakhov Vyacheslav V. 
Published: October 2008

Summary
In September 2007 Remote Monitoring Centre (RMC) was established in NK Rosneft-Stavropolneftegaz, LLC, with the following functions:
Operation monitoring of «golden» well stock: Operation analysis of high-flow-rate well stock (Qoil ≥ 20 Tones/day) Organizing supply of supplementary information required – well flow testing, measuring data Spot data check (well flow testing, measuring data, data from ESP control stations) Failure analysis of wells and activities development: Daily cause analysis of failures Supervision of equipment disassembly (commission review), data base maintenance for failure causes due to configuration Activities development in order to increase time between failures for each failed well Designing ESP units Proposals on well operation business process reengineering, introduction of quality management system (TQM).
Reasons for establishing the Remote Monitoring Centre (RMC) are:
Geographical expansion; Declining production and cost escalation; Increasing staff shortage – competing for young people and limited number of experts; Highly feasible potential of production increase, cost reduction owing to both, innovative technologies and improvement of business processes; Inconsistency between organizational structures and production requirements for innovative technologies (reorganization is always late for application of new technologies).
Project Development Phases:
Source information quality improvement (statistics collection and processing) – 3rd quarter, 2007, – 2TB quarter, 2008. Visual problems representation by original software technology (RnWV) – 3rd quarter, 2008. Targeted activities aimed to operation efficiency improvement of artificial lift well stock (ideal equipment selection, abnormal wells, etc.) – 4th quarter, 2008.
Project's Novelty:
Integration of the Company's scientific and production potential; Creating optimum equipment design selection algorithm based on complicating downhole factors (detailed design of equipment components).