bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Relative Attractiveness of US LNG Exports - Is the Threat to Australian Projects Real?
Authors: Chandra V. 
Published: October 2015

Abstract
The competitiveness of Australian LNG projects versus US projects has been a subject of much debate. However, as oil prices have fallen since mid-2014, the debate has shifted from the relative pricing terms of the LNG sales contracts to the relative cost of supply. Falling oil prices has decreased the price of LNG in traditional oil-linked price markets of Asia. Lower cost of LNG will increase the demand for gas, especially in the power generation sector. New gas supply will be required to meet increased demand – but the new supply must be at a competitive cost. The market price will be set by the marginal cost of incremental supply. Legacy projects in SE Asia, Middle East and Australia are unable to increase their volumes. The only other source of incremental supply that can profitably sell at these lower prices are new projects in the US Gulf Coast. Australian greenfield projects will not be able to sell at these prices. Australian greenfield projects suffer from high capex, high feed gas prices, and high operating costs. By contrast, US Gulf Coast LNG projects are being constructed as significantly lower unit costs, have access to massive low-cost shale gas volumes, and will operate at low costs using standard technology. These projects are ideally placed to operate in the lower priced environment, irrespective of the pricing index of the LNG sales contracts.
Transportation of Metal Oxide Nanoparticles Through Various Porous Media for Enhanced Oil Recovery
Authors: Bayat Ali Esfandyari , Junin Radzuan 
Published: October 2015

Abstract
Recently, considerable attention has been focused on the application of nanoparticles (NPs) for enhanced oil recovery (EOR) purposes. Previous studies on NPs transportation in porous media were conducted in subsurface alluvial zones and sandy soils which did not cover the whole conditions in oil fields. Besides, issues of how and where these materials distribute into the porous media remain major challenges. In this study, mechanisms governing the transport and retention of three metal oxide nanoparticles (NPs) namely Al2O3, TiO2, and SiO2 through limestone and quartz sand porous media were firstly investigated. Then, the named NPs were applied for enhanced oil recovery purpose in these porous media. For this aim, the nanopowders were dispersed in de-ionized water at concentration of 0.005wt%. Vertical columns were packed using limestone, and quartz sand grains in the range of 125 to 175µm. Breakthrough curves in the columns effluents were measured by UV-VIS spectrometry. It was found that the mobility of named NPs through mentioned porous media strongly depends on the NPs surface charge and stability as well as porous media surface charge and roughness. The obtained results from transport experimental tests were found to be in agreement with the classical filtration and Derjaguin-Landau-Verwey-Overbeek (DLVO) theories. Moreover, amount of oil recovery by the NPs was found to have direct relationship with their mobility through porous media where NPs with higher mobilities cause higher oil recoveries.
Successful Co-Development of Oil and Gas Reservoirs, A Case Study
Authors: Xueqing Tang , Ruifeng Wang , Xiunian Liu 
Published: October 2015

Abstract
Jake field, discovered in July, 2006, contains 10 oil-producing and 12 condensate gas-producing zones. The total number of drilled was 19, including 5 updip wells penetrated oil and gas zones, the remaining 14 downdip wells completed at principal oil zones. A unique co-development project of oil and gas had been performed since the start-up of field in July, 2010, including three phases:
Phase I: Prior to start-up of the field, In-situ gas injection was initiated. Single tubing string completion was utilized in updip wells, packer isolated oil and gas zones so that high-pressure gas could produce from the tubing and oil could produce from the annulus. After commencement, gas from updip wells was injected into downdip wells to maintain reservoir pressure and minimize water influx. The remaining gas was used to gas-lift at updip wells.
Phase II: Following pressure depletion of oil and condensate gas zones, gas-lift wells became inefficient. The packerless tubing string was extended to the bottom of perforations for commingling production of oil and gas condensate zones at updip wells. Well stream was produced from the casing annulus while recycling gas was injectied from compressors into the tubing for gas lift. Nitrogen injection was conducted at downdip wells.
Phase III: After water breakthrough, infill wells between updip and downdip wells were drilled for nitrogen injection to mitigate the water cut rising trend.
Actual production performance of oil and gas co-development is better than sequential production of oil and gas. Initial well production at two producers reached over 10,000 BOPD, Current recovery factor for oil is 25% and gas is 36%. Oil is producing at the level of 18,000 BOPD with average offtake rate of 5.8%. Simulation confirmed that ultimate recovery factor for oil could be over 50%.
Successful Deployment of Large Diameter Hybrid Drill Bit with Optimized Drilling System in Exploration Well Leads to Breakthrough in Days Savings
Authors: Omar Marwa , Touny Shrief El , Taha Mohammed , Lee Roger , Holliday Alan , Al-Foudari Saud J , Al-Sarraf Adel , Abdullah Meshal , Mahalanobis Partha 
Published: October 2015

Abstract
In Kuwait's largest reservoir, the Burgan Field, exploration wells have large potential for drilling optimization and savings; specifically a 22 inch hole, that is drilled conventionally using multiple roller cone bits in multiple trips through challenging inter-bedded formations. Hybrid drill bit technology, roller cone combined with Polycrystalline Diamond Compact, was introduced in search for an economically viable solution to deliver wells faster and achieve yearly operator targets. This paper analyzes the breakthrough drilling performance achieved by a 22 inch hybrid bit in comparison to conventional roller cones offsets and provides conclusions on economic viability.
The main challenges drilling the 22 inch section are drill bit durability and drilling vibrations through 2,000 ft. of inter-bedded limestone, shale and sandstone. In addition to curing fluid losses in certain porous formation layers that negatively affect Rate Of Penetration (ROP). Typically two roller cone bits are used on rotary drive to drill this section at 15 feet per hour, consuming seven drilling days. Using Polycrystalline Diamond Compact (PDC) bit with a performance motor to increase ROP performance is not an economically viable solution. Using hybrid drill bit on rotary drive combines the benefits of PDC blades’ durability and higher cutting efficiency with the cones’ stability by grinding and gouging into the formation.
The deployment of the hybrid technology was a collaboration project between a national oil company and a major oil services company. The teams focused on optimizing the complete drilling system including the bottom hole assembly, hydraulics, drilling parameters and geological factors to match the hybrid drill bit mechanism.
The hybrid design selection and drilling optimization resulted in a 142-percent ROP improvement from offsets average performance. The hybrid design drilled the 22 inch hole after casing shoe to section total depth at 31 feet per hour, using one bit, in three drilling days in comparison to seven days average performance. The total operator savings from this section was approximately USD 175,000 in the first deployment. Such remarkable economical savings and technical optimization proved that the hybrid technology is the viable solution for Burgan 22 inch application.
An Empirical Correlation to Predict the SAGD Recovery Performance
Authors: Dong Xiaohu , Liu Huiqing , Hou Jirui , Chen Zhangxin , Zhang Tianlin 
Published: October 2015

Abstract
The prediction of the recovery performance for Steam-Assisted-Gravity-Drainage (SAGD) process is becoming increasingly important as the SAGD projects all over the world continue to increase. The prediction of SAGD recovery performance should go back to the theory basis developed by Butler (1978). Afterwards, based on his model, many modified models are proposed. But most of these models are analytical or semi-analytical methods, and the predicting process is much complicated. In particular for the SAGD projects in some irregular thick heavy oil reservoir, it will be a hard work. Thus, a quick and easy method is needed to screen the heavy oil reservoirs for potential SAGD project.
In this study, based on the grey system theory, we developed a weighted grey correlation model firstly. Through this model, aiming at a typical thick heavy oil reservoir from Bohai offshore oilfield, China, the influences of reservoir/fluid parameters and operation parameters on SAGD recovery performance were comprehensively evaluated. And a sensitive sequence of each parameter was derived to reflect the sensitive degree. Thus a static multi-parameter nonlinear correlation is proposed to predict the oil recovery, recovery rate and cumulative oil-steam ratio (COSR) of SAGD process. Then, this correlation is used to predict the SAGD recovery performance in some potential thick heavy oil reservoirs of Bohai oilfield and the results is compared against the numerical simulation model. During this process, we also make a survey on the successful SAGD projects around the world and analyze the development features. Through the modification to the proposed correlation above, it is validated.
From the simulation results, it is indicated that the SAGD recovery performance is more sensitive to the parameters of reservoir thickness, permeability (including horizontal and vertical), net-to-gross value and steam chamber pressure. Based on the gray related degrees and the sensitivity results, we proposed a six parameters nonlinear correlation to predict the recovery indicators of SAGD process. Thus, using this correlations, the recovery performance of several SAGD projects are predicted, and the correlation results are in good agreement with those obtained from numerical simulation. The prediction error of recovery factor and COSR is controlled within 10%. Furthermore, from the validation results, we found after a modification process, our correlation could be used. Our correlation is a static method to predict the recovery performance of SAGD process in heavy oil reservoir, and it could be used to successfully predict the recovery performance of SAGD projects in heavy oil reservoirs. Through the utilization of this correlation, the SAGD recovery performance in candidate oil reservoirs could be rapidly obtained.
Utilization of Modern Technology Yields Potential Recovery of 936 Million BOE from Mature Fields Portfolio
Authors: Gibson M. 
Published: October 2015

Abstract
This paper portrays the methodologies utilized to yield potential "barrier reserves" of 936 million BOE from an Operator’s mature fields’ portfolio.
The paper reviews the whole project in overview and will also go into detail for one particular asset to appraise readers of the pertinent details associated with how each particular methodology yielded the "barrier reserves" it did, including the economic value and risks associated with each mature field.
Precise Well Integrity Diagnostic Delivers Production Sustainability, Cost Reduction and Regulatory Compliance
Authors: Leong Chua Hing , Khairul Anuar Khairina Bt , Batumelai Sathish Kumar , Bin Mahmud Ahmad Fitri 
Published: October 2015

Abstract
This paper is a case study of a well intervention performed by PETRONAS Carigali Sdn Bhd (PCSB) in Sarawak region to investigate and rectify a breach in well integrity. The review and discussion demonstrate that the intervention not only ensured compliance with existing well bore risk management guidelines but also reduced operational rig cost and enabled increase in production.
The paper identifies the aspects of what appears on first view to be a straightforward well integrity diagnostic process, but which on deeper evaluation exposes the wider and acute impact of the outcomes of such a diagnosis.
The nature of the diagnostic technique is examined, and the interrelated impact on PCSB HSE requirements, platform operating efficiency, and field-wide production.
The well intervention and the subsequent targeted rectification made possible by the precise nature of the diagnosis, enabled PCSB to bring this well back online and restore its gas production. This gas production is vital for several of the gas lifted wells in the field. Restoration enabled PCSB to increase field production significantly.
The study concludes that accurate, reliable and rapid integrity diagnostics should not be evaluated as only relevant as a means of HSE management but also a means of cost management and in sustaining or increasing overall production.
Estimation of Fracture Characteristic within Stimulated Rock Volume using Finite Element and Semi-Analytical Approaches
Authors: Maulianda B. T. , Wong R. C. , Gates I. D. , Eaton D. 
Published: October 2015

Abstract
Hydraulic fracturing increases the drainage area and effective permeability of unconventional oil and gas reservoirs by creating a fracture network or stimulated rock volume (SRV) within the reservoir rock. The dimensions of the SRV and its permeability are the key parameters that enhance the unconventional reservoirs' performance after the hydraulic fracture operation. Simulation of the SRV to obtain its dimension and permeability can be used to determine the optimum hydraulic fracture treatment parameters and production. In this study, finite element analysis is employed to determine the SRV characteristics based on field data from a hydraulic fracturing job in a horizontal well penetrating the Glauconite formation in Hoadley field, Alberta, Canada. The dimensions of the SRV are calibrated from the microseismic data. The fracture propagation pressure of the finite element model is matched to the field value by altering the permeability of the SRV. The matched model is used to obtain the in-situ stress changes and the pressure drop within the SRV. The SRV permeability and the pressure drop are used to calculate the aperture, the number, and the spacing of the fractures within the SRV using a semi-analytical approach. The final outputs can be used to optimize the future hydraulic fracture design at the Hoadley field or at other fields that have similar geomechanical properties. It could also be used to predict the reservoir production after the hydraulic fracturing and to provide estimates of changes in the in-situ stresses around the stimulated horizontal wellbore.
Inter-Well Sandstone Prediction and Facies Evolution by Multidisciplinary Integration: An Example from G Gas Field in Jabung Block in South Sumatra Basin
Authors: Mu Longxin , Zhang Ming , Ren Bin , Xia Zhaohui , Zhang Xiaoling , Zhang Wenqi , Li Chunlei , Zheng Yabin 
Published: October 2015

Abstract
In the development of conventional oil and gas projects, inter-well sandstone prediction and facies evolution provide benefit by reducing the number of wells drilled, optimizing well location and maximizing the performance of the wells. However, several particularly thorny issues were encountered in our study. Multi-bedded thin sandstone reservoirs were vertically stacked with thin coal seams. The main sedimentary facies of sandstones in areal and vertical directions varied quickly. This paper summarizes one multidisciplinary integration methodology to predict the distribution of inter- well sandstone and sedimentary facies in the South Sumatra Basin in Indonesia.
To overcome the aforementioned disadvantages, this method included the following steps. First, it made use of multidisciplinary knowledge including mineralogy, sedimentology, lithology, geology, petrophysics and geophysics based on cores, well logs, and seismic data of various source data. Second, sequence strata division and correlation were studied with eleven target layers in order to describe this multi-stack reservoir. Then sedimentary facies system including braided channel and braided delta were identified based on reliable data from sedimentary structure of lithology, facies sequence, Formation Micro scanner Image data (FMI), and sedimentary characteristics of core samples such as: rock color, lithological features, mineral composition, and rock sedimentary structure. Fourth, a sandstone identification assessment standard was established to improve the precision of the reservoir prediction. Fifth, logging data and sedimentary facies were used to establish the facies log patterns. Favorable reservoir facies in strata were outlined based on the study of properties of sedimentary facies. Sixth, a four step procedure including seismic data partitioning, seismic attribute analysis, normalized seismic attributes of three compartments and sandstone thickness calculation was used to identify sandstone inter-well distribution. Seventh, multidisciplinary integration was used to understand facies and facies evolution to arrive at favourable facies and properties distribution which could then be used for geomodel building.
This methodology constitutes a systematic and effective way to delineate the distribution of sandstones and sedimentary evolution for future well planning.
Grassroots Ideas for Sustainable CSR Programs for the Oil & Gas Industry in Indonesia, Lessons Learned From Other Sectors
Authors: Setiadi M. I. , Hoffman M. , Lemain S. , de Groot E. , de Waard P. , Elings C. , Jansen D. 
Published: October 2015

Abstract

Objectives/Scope
In this paper, we present our review on best practices Corporate Social Responsibility (CSR) for the Oil & Gas industry gathering our experiences from industrial sectors such as dairy industry, food & beverages, mining, using worldwide information and experiences but emphasizing on Indonesia.

Methods, Procedures, Process
Large or small, many unintended side effects of human activities continue to have impacts on society and the environment, whether reversible or irreversible, sort term or long term. There are guidelines and safeguards in the oil and gas industry with the objective to manage the impacts. These safeguards and guidelines help to mitigate negative effects and optimize the positive effects of industrial activities in general and oil and gas industry specifically. We will present a review of our international experiences and adding our pilot study in Indonesia such as the Dairy Industry, Food & Beverages, and Mining.

Results, Observations, Conclusions
Traditional Health Safety and Environment (HSE) aspects of oil and gas organizations have been put into place but more often now, this is not enough. Deeper societal engagement includes ‘giving back’ to society as a form environmental and social responsibility. In Indonesia, and probably in most developing nations, politics and reputation plays a significant role in the industry, for example its development strategy, its product placement and how the company maintains its relation with the community. To stay on top of the game, organizations in the Oil & Gas Industry can manage social, environmental and reputational risks by a well-implemented CSR program. Unfortunately, we find that often CSR programs are a short term one-time deal and do not reach the targets with the involved stakeholders. CSR programs may sometimes lack a meaningful stakeholder engagement. Taking experience from industries outside the Oil & Gas sector, our approach is more bottom-up, where we work together with primary stakeholders to determine a more strategic and sustainable CSR approach

Novel/Additive Information
Our bottom-up approach lets us work together with primary stakeholders to determine a more strategic and sustainable CSR program. The central way of thinking is that when the stakeholders (may it be local communities, farmers, educators, industry etc.) are meaningfully involved, full ownership of CSR programs is ensured and long term CSR programs are sustained
Introduction and Field Test of a Neutron Porosity While Drilling Tool Using Non-Chemical Source
Authors: Gao Wenkai , Sheng Limin , Lin Yushui , Gao Xuesheng , Ai Weiping , Song Yanchun , Mao Weimin , Jia Hengtian , Fan Jinhui , Cao Chong , Wang Peng 
Published: October 2015

Abstract
Combined with other measurements, neutron porosity tool provide basic and important parameters for real-time formation evaluation and geosteering. In earlier neutron porosity LWD systems, the porosity instruments containe an isotopic chemical source which emit fast neutrons.
Using the chemical neutron source, it should be meeting the problem of handing, shipment, and storage. For radiation safety consideration, non-chemical source based neutron instruments will be the best choice for measurement while-drilling. A new type of non-chemical source based neutron porosity instrument has been developed and prototyped.
The instrument was designed for porosity measurement while-drilling. it consists basically of an accelerator neutron source and several neutron detectors. The accelerator based neutron generator source can be switched on and off by electronic circuit and software control.
The development of new porosity instrument includes two parts - method study and tool design. In method studies, computer modeling was use to tool structure designs and detector parameter choices. Both computer modeling and experimental measurements made in standard formation were used to determine the tool responses. The field test has been made with two prototype tools.
Comparing the measured porosity data with wire-line neutron logging data, they are in good agreement. The preliminary test and data analysis show that the designed tools have many new features over chemical source based neutron porosity tools. This paper will highlight the technical development and present helpful case histories and recommendations.
Corrosion Assessment of Different Production Casings and Material Selection in Sour Gas Wells
Authors: Dezhi Zeng , Naiyan Zhang , Feng Wang , Rui Chen , Tianlei LI , Chengqiang Ren , Junying Hu , Taihe Shi 
Published: October 2015

Abstract
In order to assess the applicability of three steel specimens (T95, 110SS-2Cr and 825 steel) in sour gas well, corrosion tests were conducted in a simulated gas field solution containing both 0.55MPa H2S and 0.75MPa CO2 at 55 °C-100 °C for 72h in an autoclave. Then the corresponding corrosion products were analyzed and compared through EDS and SEM technologies. The stress corrosion cracking (SCC) behavior of three steel specimens had been tested using four point bending (FPB) technique and constant-load test. The results showed that the 825 steel had lowest corrosion rate among all those steels. The corrosion rate of T95 steel was higher than 110SS-2Cr steel for its looser corrosion products. With the increase of temperature, T95 steel and 110SS-2Cr steel corrosion product film thickened, and the trends of crystallization and agglomeration were clear. The main components of the film were FexSy, FeCO3 and compounds containing a small amount of Cr. It could also be found that the Cr content of 110SS-2Cr steel corrosion products was higher than that of T95 steel, which may contribute to its lower corrosion rate. According to the FPB results, all of those three steels did not get broken under 85% stress state in the simulated field condition. The constant load tests also showed that under 72% stress state, the T95 steel and 110SS-2Cr steel were not broken, indicating a good resistance to environmental cracking with low stress corrosion sensitivity. As a result, the 825 steel could be used below the packer of production casing; the 110SS-2Cr steel is appropriate to be used in the middle of production casing; the T95 steel is suitable for the wellhead of production casing.