bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Case History of Heavy Oil Separation in Northern Alberta: A Singular Challenge of Demulsifier Optimization and Application
Authors: Wylde Jonathan J , Coscio Steven 
Published: October 2008

Abstract
This case history tracks the continual improvement cycle for the fluid separation process of a heavy oil / oil sands production facility in Northern Alberta over a period of three years. The major challenge posed by the operator of this 13 - 16° API crude oil was to move away from injection of two separate demulsifier formulations to a single product. This was not an easy task due to the very different conditions that existed at the two injection locations. The first location was at a series of injection points upstream of the gathering stations, prior to separation, where temperatures could reach sub-zero conditions and the second was at the battery receiving facility where heating increased temperatures to 100°C. Water cut and shear were also very different and the operator required a very strict 0.2% BS&W on the crude exiting any of the four treater tanks; to further complicate issues crude oil viscosity ranged from 500 - 5000 cP.
A unique bottle testing method was developed and used to simulate the field conditions as accurately as possible. Details are given on the chemistry of the individual components of the demulsifier determined to be so crucial to adequate performance and how this was optimized in the field after being identified from the bottle tests.
Results show how careful consideration needed to be given to the concentration of the demulsifier bases in the blends and the curious observation that dilution of the final product made a big difference to the final performance in the field. Elaboration is given on potential mechanisms explaining the dilution effect and the paper goes on to conclude how careful design of field testing followed by field implementation can indeed solve complex separation issues and address individual well, battery and field requirements.
Successful Field Application in Continuous DTS Monitoring Under Harsh Environment of SAGD Wells Using Improved Optical Fiber Technology
Authors: Kaura Jiten , Sierra Jose 
Published: October 2008

Abstract
The use of optical fibers in the oil and gas industry is becoming more viable for several permanent monitoring applications, such as distributed temperature sensing (DTS) and optical pressure transducers. However, long-term performance of fibers, especially at elevated temperatures, is still an issue yet to be fully resolved. This problem is critically important in steam-assisted gravity drainage (SAGD) applications, where wells operate in extreme conditions of high temperatures, often exceeding 250°C, as well as in high pressures within a hydrogen-rich environment.
Optical fiber performance is seriously affected by many factors, including:
Hydrogen ingression Thermal resistance of the materials Mechanical resistance of the fiber
Exposure of optical fibers to hydrogen changes the performance of the fibers through what is referred to in the industry as "hydrogen aging" or "hydrogen darkening." Hydrogen darkening is increased absorption or light loss due to various chemical species in the glass fiber resulting from the presence of hydrogen.
Thermal Efficiency and Acceleration Benefits of Cross SAGD (XSAGD)
Authors: Stalder John L. 
Published: October 2008

Abstract
Two characteristics of XSAGD that accelerate bitumen recovery and improve thermal efficiency are discussed in this simulation study.
First, it is well understood that the significant oil mobilization process during SAGD occurs at the periphery of the steam chamber where steam transfers heat to the reservoir rock and bitumen. However, once the SAGD steam chamber is well established, it tends to have a low surface area to volume ratio due to its generally cylindrical geometry. In contrast, XSAGD tends to have a higher ratio of surface area to volume once its multiple steam chambers are well established. This allows a given amount of heat injected as steam in XSAGD to contact bitumen faster than the same amount of heat injected in SAGD after the initial steam chamber formation period.
Second, fluids moving through the parallel horizontal wells in SAGD follow pathways that remain relatively stable in temperature throughout the life of the operation. Conversely, fluid flow through the perpendicular arrangement of wells in XSAGD exposes cooler portions of the reservoir to conduction heat transfer from hot steam flowing in the injectors or heated bitumen and steam condensate flowing in the producers. This heat transfer accelerates heating in the reservoir and reduces the heat that is produced back to the surface so that more of the injected heat is beneficially applied to the reservoir compared to SAGD. The heated areas close to the wells accelerate the development of lateral displacement pathways promoting more rapid spreading of the steam chambers in XSAGD.
The increased thermal efficiency and acceleration of recovery of XSAGD are more pronounced for thinner pay and for lower pressure operation compared to SAGD. However, XSAGD retains some economic advantage even as pay thickens and injection pressure increases.
Offshore Connectivity and Ultra-Long Tiebacks Solutions for Oil and Gas
Authors: Lecroart A. , Michel R. , Odier J. P. 
Published: October 2008

Abstract
The Oil and Gas Industry is forced to go in deeper and deeper water further and further offshore to find new oil or gas. For the Oil Co., this means operating offshore facilities safely, reliably and efficiently in harsh environment far from shore.
Alternative development scenarios involve the implementation of subsea facilities and ultra-long tiebacks.
At the same time, the industry is placing more and more emphasis on integrated operations driven from onshore control centres.
Highly reliable communications solutions are required to enable Oil Co to fulfil these objectives. Large bandwidth and low latency links between the offshore facilities and the shore are essential as well as ubiquitous communications to all company personnel and contractors engaged in the offshore field development area.
This paper describes the overall solutions to address these needs. It reviews available technologies to address connectivity and communications needs that are particularly suited to deployment in offshore environment, in particular submarine fiber optics and radio including Wimax, and present Alcatel-Lucent vision on the application of these technologies to respond to the needs of the Oil and Gas Industry. The paper describes in more details, for both offshore connectivity and ultra-long tiebacks, possible optical data and electrical power architectures together with the products and their heritage, including the submarine 10kW DC-DC power converter, optical in line repeater, sub sea transponder and last mile connections. The hardware breakdown structure, technology gaps and solution costs are reviewed and discussed.
A New Flooding Scheme by Horizontal Well in Thin Heavy Oil Reservoirs
Authors: Liu Huiqing , Zhang Hongling , Wang Zenglin , Wang Man 
Published: October 2008

Abstract
It is possible to set a special packer within the long completion horizontal interval to establish an injection zone and a production zone, and a new flooding scheme of simultaneous injection and production in a single-hole horizontal well drilled for developing thin marginal heavy oil reservoir or small block reservoirs or offshore reservoirs. In field practice, the fluids injection rate can be controlled with either concentric or parallel tubing strings. Reservoir numerical simulation was used to determine the formation thickness lower limitation for different viscosity reservoir and the optimum time to start steam flooding after steam soak by economic oil/steam ratio. The optimum time to start steam flooding is at the 7th cycle. There exists a peak recovery efficiency of steam flooding when the length of separation section ratio is 0.15-0.2. Oil recovery rate can be enhanced by increasing steam injection rate, but pressure difference also increase and the pressure difference increases sharply, and separation section by packer will not be in a stable state in the steam flooding process. A steam injection rate of 2.4t/(d.ha.h) was suitable for steam flooding under practical injection-production conditions. All the results could be useful for the guidance of steam flooding project.
Effect of Ultrasonic Intensity and Frequency on Oil/Heavy-Oil Recovery from Different Wettability Rocks
Authors: Naderi K. , Babadagli T. 
Published: October 2008

Abstract
Using acoustic energy in enhanced oil recovery is not a new idea but yet is categorized as an unconventional method. In previous studies at our institution, the effect of ultrasonic radiation on capillary imbibition recovery of light oil from a water wet medium was widely investigated. Upon promising results, the study was extended to more challenging cases such as oil wet matrix (with and without initial water) and heavy oil. The effects of ultrasonic intensity and frequency were also included.
Cylindrical sandstone cores were placed into imbibition cells where they contacted with aqueous phase. Each experiment was run with and without ultrasonic radiation keeping all other conditions and parameters constant. The experiments were designed to investigate how the presence of initial water saturation can affect the recovery (Swi=0 to 40%), and also how the recovery changes for different oil viscosities (35 to 1600 cp). Furthermore, the samples were tendered oil-wet by treating with dryfilm to quantify the effects of wettability. In addition, the specifications of acoustic source such as ultrasonic intensity (45 to 84 W/ sq cm) and frequency (22 and 40 kHz) were also changed. An increase in recovery was observed with ultrasonic energy in all cases. This change was more remarkable for oil-wet medium. The additional recovery with ultrasonic energy became lower as the oil viscosity increased.
The results revealed that the ultrasonic intensity and frequency are very critical on the performance. This is a critical issue as the ultrasonic waves have limited penetration into porous medium and the intensity reduces while penetrating into porous medium. This is a major drawback in commercializing this promising process for well stimulation. Hence, we designed a set-up to measure the ultrasonic energy penetration capacity in different media, namely air, water, and slurry (sand+water mixture). A one-meter long water or slurry filled medium was prepared and the ultrasonic intensity and frequency were monitored as a function of distance from the source. The imbibition cells were placed at certain distances from the sources and the oil recovery was recorded. Then, the imbibition recovery was related to the ultrasonic intensity, frequency, and distance from the ultrasonic source.
Injection of Multi-Azimuth Permeable Planes in Weakly Cemented Formations for Enhanced Heavy Oil-Recovery
Authors: Hocking Grant , Cavender Travis , Schultz Roger L. 
Published: October 2008

Abstract
Stimulation of weakly cemented formations is not the same fracturing process that occurs in hard rocks because the weak formations have minimal strength and basically zero fracture toughness. It has been demonstrated conclusively that vertical planes can be injected in weakly cemented formations with control of the plane's azimuth, and multiple planes can be injected at differing azimuths, both sequentially and simultaneously in a single well. Laboratory and near-surface experiments involving injection from a perforated casing have yielded random injected geometries that are not repeatable and do not develop a planar-injected feature. On the other hand, if the casing is dilated during the injection process, repeatable consistent vertical planar-injected geometries are formed with control of the azimuth of the injected planes. These experiments have been conducted in laboratories at numerous shallow-field sites involving excavation of the injections and at deeper field sites with the injected geometry determined by real-time imaging using the active resistivity method. The specialized casing system is conventionally drilled and cemented in place, sub-surface resistivity receivers installed, the casing dilated during injection, and the subsequent injected geometry imaged in real-time during the injection process. The application has field demonstrated both simultaneous and sequential multi-azimuth, vertical planar injections from a single casing horizon. The method has significant potential in soft rock formations for production enhancement in both shallow gas and shallow heavy oil reservoirs. This paper presents field injection experiments of multi-azimuth, injected, vertical planar geometries in a variety of weakly cemented formations and describes the application of the method to shallow petroleum soft rock reservoirs, especially for thermal and solvent recovery of heavy oil.
Utilizing Natural Gas Huff and Puff to Enhance Production in Heavy Oil Reservoir
Authors: Wenlong Guan , Shuhong Wu , Jian Zhao , Xialin Zhang , Jinzhong Liang , Xiao Ma 
Published: October 2008

Abstract
L Block is a super-deep heavy oil reservoir with the degassed oil viscosity of 9,680∼12,000mPa.s @50☐, 2800∼3300 m deep with normal pressure system and 80∼95☐ in the reservoir. The GOR is 12m3/m3 and the initial bubble point pressure is only 4MPa. High oil viscosity and low flowability result in low production and rapid decline of primary development. This paper will review mechanisms, feasibility and pilot test of utilizing natural gas huff and puff to enhance production in L Block. Firstly, the paper will detail the lab experiments which include the conventional PVT and unconventional PVT. The conventional PVT shows that the natural gas dissolved in the oil can greatly decrease oil viscosity by 1∼2 orders of magnitude and enhance the flowability in one hand, in other hand, it can large the volume coefficient and add the elastic energy. The unconventional PVT shows that the heavy oil can effectively entrap the gas for more than several hours because of its high viscosity. There exists a pseudo bubble point pressure far lower than bubble point pressure in the manmade foamy oil, which is relative to the depressurization rate. Under the condition, the elastic energy could be maintained in a wider pressure scope than natural depletion without gas injection. Secondly, the paper will introduce a special experiment apparatus which can simulate the process of gas huff and puff in the reservoir. The huff and puff experiment shows that in this process the foamy oil can be seen and most of oil flows to the producer in pseudo single phase, which is one of the most important mechanisms of enhancing production. Finally, the paper will brief the pilot test of single well, which shows that the oil production is increased to 5∼6 m3/d from 1∼2m3/d by natural gas huff and puff and the stable production period is prolonged to 91days in the first cycle and 245 days in the second cycle from 5∼10 days before huff and puff.
Thermal Transient Analysis Applied to Horizontal Wells*
Authors: Duong Anh N. 
Published: October 2008

Abstract
The effectiveness of heat injection into a target formation has a great impact on the efficiency of bitumen and heavy oil recovery and energy savings under many steam heating processes such as the startup phase of SAGD (Steam Assisted Gravity Drainage) (Butler 1991). However, this parameter is hard to calculate due to many unknown variables such as variations in operational conditions and steam saturation along the horizontal wellbores, heat return rates, and losses to the vertical section above the target formation.
This paper proposes a new technique to estimate cooling time and formation thermal diffusivity by using thermal transient analysis (TTA) along the horizontal wellbore under a steam heating process. A novel concept of a heating ring is also introduced to measure the heat storage in the heated bitumen at the time of testing. Heating ring can be considered analogous to a drainage area in a conventional pressure transient analysis.
The proposed cooling time and formation thermal diffusivity calculated along the horizontal wellbore can be used to assess the effectiveness of the conduction heating. Cooling time in this paper is defined as the theoretical time required to cool the heated formation to the initial formation temperature. A longer cooling time indicates a higher net heat gain in the formation while the calculated thermal diffusivity is used to predict wellbore conditions and the type of fluid saturation along the horizontal wellbore. Thus, a combination of cooling time and formation thermal diffusivity can be employed to assess the effectiveness of heat injection during various steam heating processes.
By knowing the effectiveness of each heating scenario, the process can be selected and optimized not only to save heat energy and steam consumption but also to enhance bitumen recovery. This paper is limited to the new heating operation processes.
Well Performance Relationships in Heavy Foamy Oil Reservoirs
Authors: Kumar Rahul , Mahadevan Jagan 
Published: October 2008

Abstract
Inflow performance in some heavy oil reservoirs is not well understood as the fluid properties differ from conventional behavior. In this work, we develop an expression for inflow performance as a function of properties of foamy oils such as density, viscosity, solution gas-oil ratio and formation volume factor. We define two parameters, the end point entrained gas fraction and the apparent bubble point, adapted from previous studies, to account for the extent of entrained gas fraction in the liquid. The fluid properties are modified to account for the entrained gas and then incorporated in the equations describing flow from a reservoir at pseudo-steady state.
The results of our study show that the entrained gas and the apparent bubble point impacts the fluid properties and therefore the inflow performance at the bottom-hole conditions. In the presence of entrained gas, the density of the fluid decreases and the formation volume factor increases. Both these parameters show an inflection below the bubble point pressure and the solution gas oil ratio shows a constant value until the apparent bubble point is reached. The inflow performance curve, therefore, displays an inflection as opposed to the monotonically changing curve normally seen with conventional oils. The outflow performance curve is lowered when the effect of entrained gas is included and hence, the nodal systems analysis predicts a greater production rate for a foamy oil reservoir compared to a conventional reservoir.
Hot Rock Energy Projects-Australian Context
Authors: Goldstein B. A , Hill A. J. , Malavazos M. , Coda J. , Budd A. R. , Holgate F. L. 
Published: October 2008

Abstract
Hot rocks have potential to fuel competitive, emission free and renewable electricity for centuries to come. This potential is stimulating Hot Rock projects worldwide, calling upon integrated expertise from the petroleum, minerals and power industries.
Converting just 1% of the Australia's estimated crustal energy from depths between 150°C and 5 km (190 million PJ) to electricity would supply 26,000 years of Australia's 2005 primary power use, and that neither takes into account the renewable characteristics of hot rocks, nor resources below 5,000m.
Factors that distinguish Australian Hot Rock resources are:
Very radioactive granites are abundant, as in South Australia where the mean heat flow is 92µWm-2 compared to a global continental average of 51µWm-2. Areas of recent volcanic activity and hot aquifers above hot granites also constitute targets; and Australia is converging with Indonesia on a plate scale – giving rise to common, naturally occurring sub-horizontally fractured basement rocks that are susceptible to hydraulic fracture stimulation.
Most projects are focused on hot rocks to develop Enhanced (Engineered) Geothermal Systems (EGS) to fuel binary power plants. Roughly 80 percent of these projects are located in South Australia. Australian government grants have focused on reducing critical, sector-wide uncertainties and equate to roughly 25% of the cost of the private sector's field efforts to date. A national hot rock resource assessment and a road-map for the commercialisation of Australian hot rock plays will be published by the Australian Government in 2008.
Portfolio management methods can usefully be adapted to underpin decision-making by companies and governments seeking to respectively push and pull hot rock energy supplies into markets.
This paper describes the challenges and prospects for hot rock projects in Australia as a proxy for projects anywhere in the world.
Integrated 3D Geology Modeling Constrained by Facies and Horizontal Well Data for Block M of the Orinoco Heavy Oil Belt
Authors: Longxin Mu , Baojun Xu , Shancheng Zhang 
Published: October 2008

Abstract
It is very difficult to obtain the right variograms in the geostatistics to build an exact 3D geological model for the fluvial facies reservoir. This paper discusses how to calculate respectively the horizontal and vertical variograms based on the horizontal well data and vertical well data and then integrate with the 3D seismic data to get the reasonable variograms for the 3D geological modeling of the Block M. There are 95 horizontal wells and 21 vertical wells and the high resolution 3D seismic data of real amplitude and wide band reprocessed by the end of 2007 in the Block M of the Orinoco heavy oil belt. It especially emphasizes to do the sedimentary microfacies analysis and to use the sedimentary microfacies maps to constrain the sandbody distribution in the property modeling. These methods can clearly describe reservoir heterogeneities in geostatistical model and result in more accurate reservoir model.
Based on the high precision 3D geological model, the OOIP in the block is calculated. The 3D geological model has been successfully used to locate the horizontal well position and to direct the best orientation of horizontal wells in this Block.