bluuebunny/crossref_metadata_2025_split huggingface dataset:
Using the SPE/WPC/AAPG/SPEE/SEG PRMS To Evaluate Unconventional Resources
Authors: Chan Phillip , Etherington John R. , Aguilera Roberto 
Published: June 2014

Summary
It is the intention of the SPE/World Petroleum Council (WPC)/ American Association of Petroleum Geologists (AAPG)/ Society of Petroleum Evaluation Engineers (SPEE)/ Society of Exploration Geophysicists (SEG) Petroleum Resources Management System (PRMS) to provide a consistent approach to estimating petroleum quantities, evaluating development projects, and presenting results within a comprehensive classification framework. The reserves and resources definitions and application guidelines are designed to be applicable to both conventional and unconventional petroleum accumulations, regardless of their in-place characteristics, the extraction method applied, or the degree of processing required to yield a marketable product.
The fact that unconventional resources are usually pervasive throughout a large area and are not significantly affected by hydrodynamic influences may require different approaches in evaluation. Assessments may include an increased sampling density to define uncertainty of in-place volumes and the variations in quality of reservoir and of hydrocarbons and their detailed spatial distribution for the design of specialized extraction methods.
This paper summarizes the special problems in the estimation and evaluation of shale gas. However, similar procedures can be used for other unconventional resources. The material is largely drawn from the recently published SPE Application Guidelines to the PRMS, supplemented with illustrations from actual field examples.
The rapidly advancing exploitation of unconventional resources has opened up many development opportunities, especially in North America. Shale gas and bitumen have already caused major impact on energy supply. We anticipate these opportunities will expand rapidly throughout the world. Achieving a better understanding of the special problems in unconventional-resources evaluation will help us build on PRMS to develop a more consistent approach to classification and categorization, accounting for unique project risks and uncertainties.
The PEARL Initiative: Producing, Sharing and Managing blended On line, Mobile and Instructor Led Learning Content within the Oil Industry
Authors: Cardinali Fabrizio 
Published: June 2014

ABSTRACT
This paper is authored by Fabrizio Cardinali, board member of the European Learning Industry Group and the IMS Global Learning Consortium and CEO of Giunti Labs, a leading provider of Mobile and Learning Content Management and Digital Repository Solutions, (www.giuntilabs.com) in collaboration with the Petroleum Training Alliance, PetroSkills (www.petroskills.com), and with one of its leading oilfield services company members, Baker Hughes (www.bakerhughes.com).
This paper introduces the need to better compete in the contemporary Petroleum Labor provisioning and Skills training sector; analyzing solutions to better produce, assemble, distribute and share open knowledge resources across open and interoperable networks while personalizing them for different skill gaps, personal media and location of use.
This paper introduces the need for a commonly referenced Petroleum Engineering Abstract Reference framework for producing, managing, sharing and distributing standard & blended Learning materials. It defines present and future learning scenarios and services in an abstract way, starting with the proposal of common standards and protocols (Application Profile) for the sharing and reuse of standard learning, reference and knowledge materials within and across the oil vertical together with their best implementation practices and showcase implementations.
Quantitative Formation Evaluation in High Angle and Horizontal Wells Using LWD Measurements: Field Application of Integrated Log Modeling Workflows
Authors: Mendoza Alberto , Gaillot Philippe , Mardon Duncan , Zhou Jinjuan , Guo Pingjun , Wertanen Scott , Yin Hezhu 
Published: June 2014

Abstract
Quantitative petrophysical evaluation in high-angle and horizontal (HA/HZ) wells has remained elusive primarily because of the presence of complex log responses and lack of appropriate modeling capabilities. Recent advances in numerical simulation of nuclear and resisitivity logs in HA/HZ wells have significantly improved interpretation of log responses in complex borehole-formation geometries. Additionally, developments in fast simulation methods have enabled application of log response modeling in conjunction with field measurements. Although a full understanding of nuclear and resistivity logs response in HA/HZ wells is yet to be resolved, application of advanced interpretation techniques to field measurements yields more reliable petrophysical analyses.
In this paper, we implement processing methods that more effectively combine short- and long-spaced density measurements together with forward modeling of azimuthal nuclear and scalar resisistivity logging-while-drilling (LWD) logs to construct a common subsurface model. This log response-coherent model constructed from field measurements is then used for conventional petrophysical analysis. To demonstrate our workflow, we analyze four horizontal wells penetrating sand-silt sequences in the Chayvo field (northeast coast of Sakhalin Island, Russia) with apparent dip angles ranging between 80 and 90 degrees. The wells were drilled with oil-base mud (OBM) and include standard LWD triple-combo logs.
Field-based log response-coherent models of resistivity, density, and neutron measurements are used to estimate lithology volumetrics, porosity, and water saturation. Results from depth coherence processing and forward modeling show improved resolution and estimation of formation layer petrophysical properties which yield more accurate estimates of reserves in place compared to those initially estimated from field logs. Additionally, the average properties in high- and low-net intervals from the HA/HZ wells are compared to properties estimated in near offset vertical wells, which include core samples.
Exploration of Non-Common Petroleum Targets
Authors: Koblov E. G. , Tkacheva N. A. , Kharakhinov A. V. 
Published: June 2014

Abstract
The problem of oil and gas content of the fractured reservoirs in the North Sakhalin has appeared at the beginning of the thirties years on the morrow of opening the natural oil shows in the Pogranichny downthrown block in argillo-siliceous deposits of the Pilengsky suite. The intensive degree of these displays (only in the area of Pogranichny settlement, there were discovered above 100 natural shows of mainly oil by means of the subsequent works), and the significant range of their spread permitted even then to make a proposal about the second (the lower-miocene) oil-and-gas bearing series in the section of the North Sakhalin.
The industrial oil content of this series (according to the present-day concepts, it is related to the upper oligocene) was established in 1971 by opening of the petroleum deposit in the fissured silicite of the Pilengsky suite at Okruzhnoye field.
Experimental Characterization of Production Behaviour Accompanying the Hydrate Reformation in Methane-Hydrate-Bearing Sediments
Authors: Ahn Taewoong , Park Changhyup , Lee Jaehyoung , Kang Joo M. , Nguyen Hieu T. 
Published: June 2014

Summary
This paper experimentally analyzes the production characteristics of hot-brine stimulation accompanying hydrate reformation in the presence of methane hydrate. Many attempts have been made to recover methane hydrate commercially, such as depressurization, thermal stimulation, and inhibitor injection. Hot-brine injection coupled with thermal recovery with inhibitor injection has been investigated as an efficient production scheme, but the hydrate reformation during the dissociation is problematic, and it negatively influences the recovery rate.
An experimental apparatus divided the sediment sample into 12 blocks not only to describe 1D dissociation effectively but also to control the temperature accurately. The specified amount of methane hydrate was formed artificially in unconsolidated and packed sediments where the average particle size, absolute permeability, and porosity were 260 µm, 4.4 darcies, and 42%, respectively. The production trends were observed in the temperature range of approximately 283.85 - 303.15 K and with injection rates of 10 and 15 cm3/min. Methane hydrate reformed in all the tests; the reason for this may be the recombination of water and the dissociated methane in the downstream zones. In the early time, the production rate was low, but it increased significantly in later time. The former was why most of gas that dissociated in the upstream zones was consumed to reform hydrate in the downstream areas, while the latter came from the dissociation of initial and reformed hydrate. The dissociation front moved fast at the higher temperature and injection rate. The production efficiency of the test at 15 cm3/min and 294.55 K was similar to that of the test at 10 cm3/min and 303.15 K. The results confirmed the production behaviour of methane hydrate under the reformation phenomenon and could provide the fundamentals to develop an efficient production scheme based on hot-brine stimulation.
Bacterial Survival in Fractured Shale-Gas Wells of the Horn River Basin
Authors: Moore Sherry L. , Cripps Colin M. 
Published: June 2014

Summary
Traditional ideology on the upper temperature limits of life suggest that extreme temperatures such as those observed in the Horn River Basin shale-gas formation (i.e., up to 175°C) should alleviate microbiologically influenced corrosion and souring concerns associated with hydraulic-fracturing procedures. The present case history investigates the accuracy of this theory. Horn River basin wells currently in the flowback or production stage and the source water used to fracture these wells were studied for the presence and identity of viable bacteria. The effectiveness of two biocides (one glutaraldehyde-based and the other cocodiamine-based) in eradicating these bacteria in both the field and the laboratory was also studied. The results show that source ponds are highly contaminated with bacteria. Furthermore, the high-temperature, high-pressure downhole conditions in this region are not sufficient for eradicating bacteria introduced during the fracturing process. These bacteria survive and establish viable, proliferating communities. Biocide, applied continuously "on the fly" during fracturing, was effective at mitigating the downhole bacteria concern. Laboratory studies further showed that more-established bacterial communities were much more resistant to biocidal treatment. Therefore, early mitigation strategies will likely be key in the prevention of microbiologically induced corrosion and souring.
Natural-Gas Potential in the St. Lawrence Lowlands of Quebec:A Case Study
Authors: Lavoie Jean Yves , Marcil Jean Sebastien , Dorrins Peter , Lavoie Jeremie , Aguilera Roberto 
Published: June 2014

Summary
Since the announcement made in April 2008 concerning the shale-gas potential of the southern Québec lowlands, 30 new wells have been drilled in the area. The calcareous and organic-rich Middle Ordovician Utica shale is the main target of this recent exploration effort. Current knowledge of the area's geology has led operators to subdivide the shale-gas potential into different play types. To date, most operations have been performed in approximately one-third of the shale basin in the medium-to-deep thermogenic shale-gas play (1000 to 2000 m), located in the central part of the Saint Lawrence lowlands. With original-gas-in-place (OGIP) estimates ranging from 120 to 160 Bcf per section, the deep play is considered to be promising. Current efforts focus on determining the highest gas-prone unit within the Utica. The remaining two-thirds of the shale basin has not been largely tested yet, but the potential remains promising.
On the basis of exploration work carried out over the past 5 years in southern Québec, four other play types have been described: (1) shallow-to-medium-depth thermogenic shale gas, (2) overthrusted shale gas, (3) biogenic shale gas, and (4) Intra-Appalachians subbasin shale gas. They are less explored than the deep-shale play, but also present interesting potential.
This paper describes the previously mentioned plays using basin geology, shale mineralogy, organic-matter type, gas geochemistry, structural style, and infrastructure access. The characteristics of the previously described plays are reviewed from geological, geochemical, structural, and production perspectives. Results of evaluations using the concept of flow units, and volumes of OGIP calculated by various organizations, are compared with a recent evaluation using the petroleum resources management system (PRMS).
It is concluded that there is promising hydrocarbon potential in the Saint Lawrence lowlands of Québec that continues to stimulate operators to pursue the exploration and development of these plays.
An Analytical Model To Predict Cumulative Steam/Oil Ratio (CSOR) in Thermal-Recovery SAGD Process
Authors: Miura Kohei , Wang Jin 
Published: June 2014

Summary
This paper presents a simple yet sophisticated analytical model to predict cumulative steam/oil ratio (CSOR) using material/energy balance and gravity-drainage theory in which CSOR is a function of average reservoir properties (porosity, permeability, heat capacity, and thermal conductivity) and time-dependent variables (injection temperature, rising chamber height, chamber oil saturation, and produced-fluid temperature) to mimic practical steam-assisted gravity-drainage (SAGD) processes. This model has been applied to predict CSORs of typical wells in the JACOS Hangingstone SAGD project. History-match results show the reliability and accuracy of the model at different geological conditions. The analytical model has proved to be satisfactory in predicting CSOR by reasonably adjusting a limited number of reservoir parameters, such as formation permeability, effective net pay, and operational parameters.
Effect of Initial Water Saturation on the Thermal Efficiency of the Steam-Assisted Gravity-Drainage Process
Authors: Oskouei S. Javad P. , Maini Brij B. , Moore R. Gordon , Mehta Sudarshan A. 
Published: June 2014

Summary
The commercial viability of the steam-assisted gravity-drainage (SAGD) process is affected negatively by several undesirable reservoir features, such as pronounced heterogeneity, low vertical permeability, thick and areally extensive shale barriers, and steam thief zones. The efficiency of SAGD projects is also affected by the presence of higher water saturation in the target zone. Although the presence of small mobile-water saturation is not considered harmful, reservoirs with high water saturation may be poorly suited for the SAGD process. Nonetheless, SAGD remains the only practical technology for in-situ extraction of oil from oil-sand reservoirs, even when mobile water is present. This raises the question of how much mobile water is prohibitive.
To investigate the effect of water saturation on SAGD performance, high-pressure physical-model experiments were carried out. Different levels of water saturations were established in the model by modifying the packing and saturating techniques. SAGD experiments were carried out by injecting superheated steam at controlled rates and producing the oil from the production well at constant pressure. The injection rate was selected to keep the pressure difference between the injector and the producer at a low level.
The oil-production behavior was analyzed to evaluate the effect of water saturation on the thermal efficiency of the process. On the basis of the results of low- (immobile) and high- (mobile) water-saturation experiments, it was observed that the oil-recovery factor dropped by 6.6% when the initial water saturation was increased from 14.7% to 31.8%.
Permeability Prediction Based on Capillary Model
Authors: Susilo Agus 
Published: June 2014

Abstract
Determining the correlation between permeability and porosity is very crucial in reservoir characterization and description. Generally, the correlation is utilized to predict a permeability value from porosity data which results from logging or coring for uncored zones. Difficulty in building a general correlation between permeability and porosity became the developmental background of the hydraulic conductivity method. This method lies on the classification of the permeability and porosity relationship, based on pore size and geometry.
The purpose of this study is to generate grouping of rock samples based on zonation of permeability and porosity correlation with characteristics of pore structure and geometry. The capillary pipe model is the basis for developing the method. This method can be used to determine permeability in positions only having porosity data from the log. This paper also presents a method to determine the value of effective hydraulic pore diameter dH, by employing the Gauss-Newton method.
This study has used 145 core samples originated from multi-stacked sandstone reservoirs. The core samples have very wide ranges of porosity (0.042 – 0.46) and permeability (0.1 – 7442 mD). Analysis of both the data and the correlation generates new understanding about pore structure and geometry. Application of the developed method to all the core samples results in very good permeability prediction.
Keyword: Hydraulic Conductivity, dH, Gauss-Newton.
A Mathematical Analysis of the Mechanism of Ultrasonic Induced Fluid Percolation in Porous Media: Part I
Authors: Najafi I. 
Published: June 2014

Abstract
This work concerns with experimentally and analytically investigation of free gravity drainage process in porous media under the influence of ultrasonic wave radiation. Glass beads ranges from 70 to 100 mesh sizes were packed and used in the tests. The working fluids consist of distilled water, kerosene and Doroud and Paidar crude oils as wetting and air as non-wetting phase. The measured oil recovery data along with Hagoort (1984) backward methodology were used to determine and to compare the relative permeability of wetting phases in presence and absence of ultrasonic radiation. In addition the relative permeability of non-wetting phases for both cases were calculated from inverse modeling of provided data. The results showed that wave enhanced the relative permeability of phases, except than for the case of Paidar crude oil, which is asphaltenic and the oil recovery decreased by sonication. The momentum conservation equation, as well as Darcy's and Stokes’ laws were combined and a new model for predicting absolute permeability of porous media radiated by ultrasonic waves is developed. The surprising result of developed model is that the permeability of porous medium is independent to the wave parameters. Investigating the influence of ultrasonic wave radiation on viscosity of the fluids and capillary pressure, showed that the radiation acts in opposition to capillary pressure effect, meaning while there is a period of radiation time at which the oil viscosity is decreasing, and after which it is increasing. Finally, the obtained flow parametrers under the influence of wave radiation applied in conventional model of gravity drainage. Well mached observed between predictions of model modified by this method and measured recovery data confirmed the applicability of flow parameters modification method for predicting the gravity drainage behavior under the influence of ultrasonic wave.
Effect of Various Injected Gases on Methane Recovery and Water Production in Enhanced Coalbed Methane Operations
Authors: Jamshidi Marjan 
Published: June 2014

Abstract
Methane production from coalbed methane (CBM) fields started as a method for keeping coal mining safe from explosions. Major CBM fields are located in San Juan, Powder River, Forest City, Black Worrier and Illinois. Majority of the US natural gas production comes from coalbed methane formations. These formations also have the potential of carbon dioxide (CO2) storage through enhanced gas recovery operations. Enhanced coalbed methane (ECBM) recovery by injection of gases such as CO2, nitrogen (N2) or a mixture of both gases has been proven to recover additional natural gas resources.
Most of the coalbed methane formations contain large amounts of water or can be in communication with an aquifer. As a result a large amount of water is often co-produced during the natural gas extraction. The water being produced from deep formations is not high purity water and contains nitrate, nitrite, and chlorides and has high level of total dissolved solids.
Production of methane from CBM is facilitated by the reduction of the methane partial pressure in the coal seam by either pumping the formation water to the surface or by injecting a dissimilar gas. The produced water contains a lot of harmful impurities which should be removed. Therefore, disposal of the produced water is an environmental challenge and accordingly, a reduction of the produced water is enviable.
In this paper we present a detailed numerical investigation of the potential reduction in water production during ECBM operations while increasing the methane production. We employ a three-dimensional coalbed model with an aquifer located on the bottom to investigate the amounts of gas and water produced in ECBM operations per volume of coal seam as a function of aquifer strength, cleat spacing and sorption characteristics of the coal. The amount of gas/water that is produced varies extensively depending on the aquifer strength. We demonstrate that injection of CO2 and/or N2 in some settings reduces the water handling problem substantially.
CBM is an essential energy source with a lot of formations being exceptional candidates for ECBM recovery processes. The analysis we present in this paper on the water production reduction by using the injection gas which relatively produces less water provides new strategy for future operations.