bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Approach for Predicting Inhibited Erosion-Corrosion in CO2-Saturated Oil/Brine Flow Condition
Authors: Hassani Shokrollah , Roberts Kenneth P. , Shirazi Siamack A. , Rybicki Edmund F. , Shadley John R. , Joia C. 
Published: June 2014

Abstract
Chemical inhibition is a common method for controlling erosion-corrosion in offshore mild steel pipelines, tubing and pipe fittings. The paper introduces a new approach for predicting inhibited erosion-corrosion in mild steel pipes including the effects of flow and environmental conditions, sand production, and an oil phase.
When sand is produced, sand particle impinging on piping surfaces can decrease the efficiency of corrosion protection systems such as iron-carbonate scale formation or chemical inhibition and result in severe corrosion and even pitting. The need to be able to predict inhibitor performance under sand production conditions is particularly acute when the wells are deep or off-shore because of the difficulty in running coupon tests to evaluate the inhibitor efficiency at critical points throughout a system. Research reported in this paper is aimed at providing producers with information that will help them make decisions on the design of the well given advanced knowledge of the inhibition options and their predicted effectiveness under sand production conditions. Inhibition mechanisms and the relation between inhibitor concentration and inhibitor coverage are described using adsorption isotherms. The Frumkin isotherm showed the best fit to experimental data for an imidazoline-based inhibitor used in sand-free conditions. Flow loop tests indicated that sand particle erosion decreased the efficiency of the inhibitor. However, Frumkin isotherms modified to handle effects of erosivity, temperature, and oil phase were successfully fitted to erosion-corrosion data. Inhibitor adsorption isotherms, for both sand-free and sand production conditions, were integrated into a mechanistic model for prediction of CO2 corrosion rates as a function of inhibitor concentration and good results were obtained as compared with data.
Results of this study show that the inhibitor adsorption isotherm, modified to handle effects of sand production, temperature, and oil phase can be a valuable tool for predicting inhibited metal loss rates under sand production conditions.
The Significance of Particle Shape in Formation Resistivity Factor-Porosity Relationships
Authors: Atkins E.R. , Smith G.H. 
Published: June 2014

Abstract
Results of laboratory tests are presented to show that the value of "m", in the Archie expression is determined by the shapes of the particles in the system. The value of m, "the shape factor", is constant for a system of particles of a given shape for a range of values. Applying this concept, one can predict relationships for mixtures of particles with different shapes, and these predicted relationships are useful in electric log interpretation.
It is suggested that an equation of the form can be used to describe the properties of natural formations containing varying amounts of sand and clay. From this work and values of "a" and "m" reported in the literature, it appears that in many cases rocks in the same geological horizon have a common primary porosity but contain varying amounts of a particular clay. It is concluded that the equation can be applied to a rock-water system only when values of "a" and "m" have been established for the particular system.

Introduction
The petroleum literature contains many reports of the results obtained by determining formation resistivity factor and porosity of rock samples from oil fields all over the world.
Coral Risk Assessment - Tool Development
Authors: Ulfsnes Amund , Møskeland Thomas , Aarnes Øivin 
Published: June 2014

Abstract
Operators and authorities have a need for an assessment of the impacts from drilling activities on vulnerable fauna communities. There is currently lacking a standardized risk method based on an objective method to perform this type of assessment. A suggestion for a risk based approach for planning of drilling operations with regards to drilling location, location of anchor chains and pennant wires etc. in vulnerable areas (such as coral and sponge areas) is therefore developed. The risk based approach basis are GIS (Geographical Information System) analyses, experiences trough performed monitoring projects, data of prevailing currents, estimates of discharges, potential coral structures and their condition, threshold values with regards to sedimentation (literature) and location of anchor corridors. The risk analysis shall be an input to operator's applications to relevant authorities and will strengthen operator's arguments for planning drilling operations with regards to minimize risk of negative effects on vulnerable habitats such as corals and sponges. It is also as a "stand alone" tool for planning a drilling operation where operators can analyse different alternatives with regards to drilling location and anchor corridors with the lowest risk for vulnerable marine bottom fauna. A risk based approach for assessing the impacts from drilling activities on vulnerable fauna is developed. The risk based method can pin point the risk associated with each structure (for example corals) which may be affected by a drilling operation. By looking at different options for the drilling location and the anchor corridors operators can plan such that the risk for vulnerable fauna (for example corals) are affected by the operation is minimized. The proposed method has enabled operators to minimize risk of vulnerable fauna in the planning phase of a drilling operation.
Monitoring of a Drilling Operation Within a Coral Sensitive area - Case Pumbaa ( Norway)
Authors: Møskeland Thomas , Ulfsnes Amund , Sverdrup Line , Moe Jannecke A. , Løkken Morten 
Published: June 2014

Abstract
Deepwater corals (Lophelia) were identified in the vicinity of the location of the exploration well Pumbaa (NOCS 6407/12-2) on the Norwegian Continental Shelf where a drilling operation was carried out by the GDF SUEZ E&P Norge AS (GDF SUEZ). Det Norske Veritas AS has on behalf of GDF SUEZ conducted an environmental monitoring of drilling activities at Pumbaa (NOCS 6407/12-2).
Because of registrations of deep water corals (Lophelia) in the Pumbaa area, and due to specific requirements - a relatively comprehensive monitoring of the drilling activities was carried out. Only the drill cuttings from the top hole sections were discharged at the sea floorThe generated cuttings and used mud from deeper well sections were not discharged to sea. In order to increase the distance to the nearest corals from the discharge point, a Cuttings Transport System (CTS) was used to transport discharges from the top hole sections and all discharges were at 300m distance NNW (310 degrees) of well location. The main objective of the monitoring was to assess effects from the drilling activities on the corals south (and nearest) of the drilling location. The monitoring program included measurements of current, turbidity and sedimentation, as well as sampling of sediments from the seafloor. Sediment samples from the seafloor and sedimentation traps were analyzed for heavy metals and physical parameters. Coral structures were visually inspected before, during and after drilling operations.
Propping Fractures with Aluminum Particles
Authors: Kern L.R. , Perkins T.K. , Wyant R.E. 
Published: June 2014

Abstract
This paper presents information on the use of a new propping agent (malleable aluminum particles) which has been used successfully for producing high-conductivity fractures.
The conductivity of a packed fracture depends oil the width of the fracture as well as the permeability of the propping material. It is significant that the flow capacity of a propped crack is often increased many fold by propping the crack with a sparse distribution of particles. However, the flow capacity of a sparsely propped crack can be limited by two phenomena:crushing of the propping particles, andembedment of the propping particles in the formation walls.
Malleable aluminum particles exhibit interesting properties which tend to overcome these limitations. As high loads are applied to the particles they will deform slightly, rather than shattering. The deformation results in a greater bearing area against the formation wall. This reduces the stress on the particle and reduces particle penetration into the formation.
The behavior of aluminum particles under load and the bearing capacities of several formation rocks have been measured in the laboratory. By properly using these data, as explained in this paper, the flow capacities of aluminum-propped cracks can be calculated for a variety of conditions.
Aluminum particles have been used successfully in the field to prop fractures. Where high-conductivity fractures were needed, the aluminum-propped fractures have given greater well stimulation than could have been expected for conventional fracturing processes.

Introduction
The purpose of a hydraulic fracture treatment is to create a conductive channel from the wellbore out into the oil or gas formation. The word conductive is emphasized because we believe that the fracture conductivity (flow capacity) is one of the most important factors influencing fracturing results.
Previous papers have pointed out the additional well stimulation that can sometimes be achieved by increasing fracture conductivity. Several years ago, we investigated in some detail the effect of fracture conductivity on productivity increases to be expected from vertical fractures. Both electrical analog and theoretical studies of unsteady-state flow behavior were made. A discussion of the electrical analog equipment and some of the results of the study were given in a previous paper by Dyes, Kemp and Caudle. Further details were given recently by McGuire and Sikora.
Phase Behaviour of C3H8/n-C4H10/Heavy-Oil Systems at High Pressures and Elevated Temperatures
Authors: Li Huazhou , Yang Daoyong (Tony) 
Published: June 2014

Summary
Phase behaviour of C3H8/n-C4H10/heavy-oil systems at high pressures and elevated temperatures has been experimentally and theoretically investigated. Experimentally, a versatile pressure/volume/temperature (PVT) system is used to determine the liquid/vapour phase boundary (i.e., saturation-pressure lines) and swelling factors of C3H8/n-C4H10/heavy-oil systems with varying compositions at high pressures up to 5030.0 kPa and elevated temperatures up to 396.15 K. During the experiments, heavy oil is added continuously into the solvent and the injection process can be terminated within a short period. No noticeable asphaltene precipitation has been observed throughout the measurements for the four mixtures. The viscosities of the corresponding solvent(s)-saturated heavy-oil systems are measured by using a customized capillary viscometer at 298.85 K. Theoretically, the volume-translated Peng-Robinson equation of state (PR EOS) (Peng and Robinson 1976) with a modified alpha function is used to model the experimental phase behaviour of C3H8/n-C4H10/heavy-oil systems. Two binary-interaction-parameter (BIP) correlations, respectively developed for the C3H8/heavy-oil system and n-C4H10/heavy-oil system, are incorporated into the volume-translated PR EOS model. The two BIP correlations together with the volume-translated PR EOS are found to be capable of predicting the saturation pressures and swelling factors of the C3H8/n-C4H10/heavy-oil systems with a good accuracy, although the prediction accuracy is reduced at temperatures close to the critical temperature of a pure solvent. In addition, comparison of five commonly used mixing rules indicates that the Lobe's mixing rule (Lobe 1973) is more appropriate to predict the viscosity of heavy oil diluted by C3H8 and/or n-C4H10.
Effect of Temperature on VAPEX Performance
Authors: Haghighat Parnian , Maini Brij B. 
Published: June 2014

Summary
Incorporating some heat injection along with solvent injection appears to bethe most viable option for improving the oil-drainage rate of vapour-assistedpetroleum extraction (VAPEX) in extraheavy-oil formations. This study wasintended to quantify the maximum possible increase in VAPEX drainage rate thatcan be obtained by heating the formation to a target temperature. Theexperimental phase of this study involved conducting VAPEX experiments in alarge high-pressure physical model, packed with 250-darcy sand, using propaneas the solvent. The physical model was preheated to 40, 50 and 60°C, andpropane was injected at the same test temperature but different injectionpressures to observe how injection pressure affects oil-drainage rate atelevated temperatures. In the experiments at elevated temperatures, but withoutincreasing the injection pressure, higher rate of oil production was achievedin the early stages of the process. However, a stabilized rate of oilproduction did not show pronounced improvement caused by a lower solubility ofpropane in the oil at higher temperatures. Increasing injection pressure alongwith increasing the test temperatures was successful in accelerating the oilproduction. The oil used in these experiments was found to become mobile withthe increase in temperature even without solvent dissolution. As a result, thetotal rate of oil production appeared to be controlled by two mechanisms: (1)by solvent dissolution and oil mobilization at the boundaries of the vapourchamber and (2) by pure free-fall gravity drainage beyond the vapour chamberwherever gravity head was sufficient to push the mobile oil toward theproduction well. The results of this these tests define the upper limit of oilrates achievable with heated solvent injection. They can also be used to assessthe applicability of VAPEX to warm reservoirs naturally (e.g., in Venezuela)and reservoirs with mobile oil in place.
New Software for Processing of LWD Extradeep Resistivity and Azimuthal Resistivity Data
Authors: Sviridov M.. , Mosin A.. , Antonov Yu.. , Nikitenko M.. , Martakov S.. , Rabinovich M.B.. B. 
Published: June 2014

SummaryIn petroleum exploration, reservoir navigation is used for reaching a productive reservoir and placing the borehole optimally inside the reservoir to maximize production. For proper well placement, it is necessary to calculate in real-time the parameters of the formation we are drilling in and the parameters of formations we are approaching. On the basis of these results, a decision to change the direction of drilling could be made. Modern logging-while-drilling (LWD) extra-deep and azimuthal resistivity tools acquire multicomponent, multispacing, and multifrequency data that provide sufficient information for resolving the surrounding formation parameters. These tools are generally used for reservoir navigation and real-time formation evaluation. However, real-time interpretation software is very often based on simplified resistivity models that can be inadequate and lead to incorrect geosteering decisions.The core of the newly developed software is an inversion algorithm based on transversely isotropic layered Earth with an arbitrary number of layers. The following model parameters are determined in real time: horizontal and vertical resistivities and thickness of each layer, formation dip, and azimuth. The inversion algorithm is based on the method of the most-probable parameter combination. The algorithm has good performance and excellent convergence because of its enhanced capability of avoiding local minima. This capability enables interpretation of real-time resistivity data, including azimuthal and extra-deep measurements.A graphical user interface (GUI) was developed to provide an interactive environment for each stage of the resistivity data interpretation process: preview of input resistivity logs, initial preprocessing and filtering of raw data, creation of initial guess, running inversion and viewing inversion results, and quality-control indicators. Applications of the developed software will be shown on a series of synthetic examples and field data from the North Sea and Gulf of Mexico (GOM). This newly developed software is currently in use for real-time reservoir navigation and post-well analysis.
Optimised Solids Control in Arctic Environments
Authors: Dahl Bjørn , Omland Tor Henry , Saasen Arild 
Published: June 2014

Abstract
A significant cost issue is related to solids control ant the affiliated waste production during drilling. This cost issue includes the reduced drilling efficiency due to poor solids control when the drilling fluid temperature is low. The primary solids control device is the shale shakers. The preferred shakers have two or three decks that all separate particles from the drilling fluid. Especially when the temperature is low, the flow through the screens on these shakers is limited leading to a large discharge of drilling fluid along with the drilled cuttings.
To increase the efficiency of the shakers a new header box is developed that change the direction of the drilling fluid entering the shakers top deck. On several North Sea operations this device has successfully been used to divert the flow onto the entire top deck screen. This made it possible to run the equipment with finer screens than usual; leading to operating with cleaner drilling fluids than usual and thereby faster drilling rate at the same time as the occupational hygiene in the shaker room was significantly improved. The paper describes in detail how the shakers were modified with the header box and how the shakers were run to optimise drilling performance even when the drilling fluid was cold.
The Estimation of Filtration Reservoir Properties with Log Data
Authors: Kozhevnikov D. A. , Kovalenko K. V. , Deshenenkov I. S. , Petrov A. N. 
Published: June 2014

Abstract
This paper is devoted to the development of capillary pressure and relative/phase permeabilities petrophysical models for different lithotypes of granular reservoirs. Proposed models describe core analysis data better than widely used models (Brooks-Corey model, J-function, Tiksie model, Burdine model). Models are verified on the representative core samples collections (over 200 samples) – sandstones with complex mineral composition from different fields worldwide (Western & Eastern Siberia, Caspian region, Middle East, Alaska). For described formations effective porosity is single value reservoir indicator. Control parameters of developed models have strong correlations with reservoir properties.
Effective and dynamic porosities, hydrocarbon saturation in effective pore space (effective hydrocarbon saturation) determined with well logging data provide evaluation of relative/phase permeability values and hydrocarbon distribution in transition zones.
The adaptive well logging data interpretation technology is applied for effective porosity and saturation determination. This technology is based on the effective porosity petrophysical model of granular reservoirs. It provides prediction of effective porosity values in reservoir conditions with standard well log data interpretation (spontaneous potential log, formation density log, gamma-ray log, neutron log and sonic log). The adaptive technique of resistivity log data interpretation is established for determination of effective hydrocarbon saturation. Proposed models of capillary pressure and relative/phase permeabilities are used in dynamic reservoir properties prediction algorithms with well logging data. Dynamic properties are transferred in digital geological and hydrodynamic models for reservoir development process simulation.
Fluid filtration and mass transfer processes are the basis of the oilfields development for reservoirs with complex structure. Obtained results are applied for fluid filtration processes modeling and reservoir development technology design.
Investigation of Abrasive-Laden-Fluid Method For Perforation and Fracture Initiation
Authors: Pittman Forrest C. , Harriman Don W. , St. John James C. 
Published: June 2014

ABSTRACT
This paper mentions briefly the history of hydraulic jetting as applied to perforating and fracture initiation. It points out the advantages of hydraulic perforation and undercutting as an aid for creating a fracture at the point desired rather than depending upon the weakest point in the formation for breakdown.
It describes early experimental work with jet nozzles in search of better nozzle materials. The effect of splash-back damage and its subsequent influence on jet body and tool design during this work is discussed.
A series of cutting-rate curves for jets cutting steel and steel-cement-formation combinations is presented to show the effect of hydrostatic head and the point of diminishing returns with respect to cutting time.
There is a series of photographs showing various types of rock formation in which perforation and undercutting tests were made. These stones were drilled and the casing cemented in place as in an actual well. The casing was perforated and circularly cut as if preparing for a fracturing job.
The conclusion reached in the paper is that hydraulic jetting with sand-laden fluid can be used for perforating and undercutting casing, cement and formation rock for the intended purpose of inducing the formation to fracture at a desired point.

INTRODUCTION
Hydraulic jetting as a means of cleaning a formation during acidizing has been used for many years. The acid-jet gun was used to clean formation and for drilling cement from casing with acid. This tool was dropped to a seating ring installed on the tubing and could be retrieved by reverse circulation or wire line. In this process, the fluids were directed against the formation to clean and penetrate beyond the mud-damaged area. After the development of the hydraulic fracturing process, interest in jetting the formation with abrasive-laden fluid was renewed. The cutting action of abrasive fluid on pumping equipment, which is a well known problem, has been utilized to perforate and undercut casing, tubing and formation. In this process, surface areas are provided in the formation on which the fracturing pressures may work to produce a fracture at the location desired.