bluuebunny/crossref_metadata_2025_split huggingface dataset:
Case Study on Longitudinally Fracturing Horizontal Wells in the Barmer Hill Porcellinite Rajasthan India
Authors: Nagar Ankesh , Tibbles Raymond , Goenka Sharad Kumar , Guha Rupdip , Chidambaram Prasanna , Sinha Ankaj , Pathak Shashank , Agarwal Prashant , Misra Anurag , Ranjan Amit , Ranjan Vishal , Tiwari Shobhit , Dwivedi Nikhilesh 
Published: November 2016

AbstractCairn India Ltd & ONGC completed a joint venture appraisal of the Barmer Hill (BH) field in the Rajasthan block of India in 2015. The objective was to evaluate the effectiveness of horizontal multi-frac completions. The Barmer hill field is a moderate permeability (0.5 – 4 mD) oil bearing porcellanite with alternating sequences of tight shale. To produce this reservoir economically, hydraulic fracturing was the obvious choice of stimulation and was performed on a number of vertical wells (see Shaoul et al. 2007). To better evaluate the development strategy, completions using either transverse or longitudinal fracture treatments were successfully designed, executed, and evaluated. In the appraisal phase, four vertical and four horizontal wells were drilled to appraise the Barmer Hill reservoir in the Mangala field. Two of the horizontal wells were drilled along the maximum horizontal stress direction and completed with multiple hydraulic fracturing stages, which generated longitudinal fractures along the lateral wellbore. The fracture orientation with respect to the wellbore was confirmed with micro-seismic monitoring. This fracture treatment strategy provided the opportunity to decrease the number of frac stages and exhibited lower treating pressures as predicted by standard elastic rock mechanics theory.While the initial productivity of the transverse fractured wells was expected to be almost 2.5 times more than the longitudinally fractured well, it only produced about 40% more. In addition, the EUR of the longitudinally fractured well is almost the same as the transversely fractured well. Based on the generated fracture geometry, theoretically these longitudinally fractured horizontal wells may also provide better effective sweep efficiency when converted to a water injector from a field development concept.
A Novel Methodology to Optimise the Parameters of Hydraulic Fracturing in Gas Condensate Reservoirs
Authors: Tariq Zeeshan , Al-Hashim Hasan S. , Sadeed Ahmed , Janjua Aneeq Nasir 
Published: November 2016

When the pressure falls below the dew point in a condensate reservoir, condensate banking starts build up adjacent to the wellbore, the relative permeability of gas closes to the wellbore badly affected, ultimately causes the reduction in the well productivity index. In these cases, the influence of condensate blockage can be abridged by enhancing the inflow area and attaining linear flow rather than radial flow in the wellbore proximity. These characteristics can only be accomplished by conducting hydraulic fracturing job.
However, the performance of hydraulic fracturing treatment is highly dependent on the operational parameters. Estimation of optimal operational parameters of hydraulic fracturing is typically a difficult job for reservoir engineers. Enhancing the fracture half-length improves the well productivity but this scenario is misleading sometime. Fracture face skin is always associated with the fracture length that may induce additional pressure drop surrounding the fracture and can cause the gas condensate buildup. This happen because as the length of the fracture increases the damage surrounds the fracture cause by permeability impairment also increases, so there must be an optimum fracture length above which increasing the length of fracture is no more efficacious.
This research work presents a new methodology to quantify the amount of fracture face skin associated with the length of the fracture and determine optimum parameter for hydraulic fracturing in a gas condensate reservoir. To achieve the objective of this study a gas condensate simulation model has been created and the parameters associated with the hydraulic fracturing has been deeply investigated, particle swarm optimization has been used as an optimization technique to optimize the parameters that has been investigated.
After optimizing the parameters, the new approach has been proposed that suggests the optimum fracture parameters. This new approach is highly promising and can serve as very handy tool for reservoir engineers to determine the optimum operational hydraulic fracturing treatment parameters for a gas condensate reservoir.
Integrated Study of Core and Image Log for Characterisation and Production Optimisation in Unconventional Basement Reservoir of Padra Field, Cambay Basin, India
Authors: Sarkar Jayanta , Mukherjee Sanjoy , Das Sourav , Bhattahcarya Titas , Kalita Deepika 
Published: November 2016

Abstract
Padra Field, located in the eastern margin of south Cambay Basin, India is known for oil and gas production from unconventional fractured basaltic Deccan Trap. Earlier studies of Padra Trap showed moderately weathered basalt as the reservoir rock. However a thorough study integrating core and high resolution image log for characterizing the volcanic reservoir was yet to be ventured. Fracture modeling on PETREL™ platform was attempted using point data from wells and the resultant model was found to be in agreement with production data from wells. Difficulties faced during fracture coding based on FMI™ data owing to highly scattered fracture dip azimuths necessitated the present study to integrate FMI™ with core data.
Integrated Water Management Challenges
Authors: Al-Shammari H. , Bora A. 
Published: November 2016

Abstract
As reservoirs mature, producing more oil out of maturing reservoirs entails more water production. For maturing reservoirs, it is, therefore, essential for a successful water management process to be introduced – one that can handle substantial volumes of water produced and result in increased oil production.
Water management was not a major concern for Kuwait Oil Company (KOC) in the past. Most of its crude oil production were from Greater Burgan and other oil fields which were producing mostly dry, easy crude with little water production. With the ageing of Kuwait's oil fields, KOC is now experiencing an increase in water production from its maturing reservoirs. This increase is caused by both planned development and field maturity.
Water production impacts the economics of oil field exploitation in number of areas like production volume, corrosions, crude quality, disposal, separation and metering. The accurate prediction of future water production trends is one of the most challenging tasks for KOC. A holistic approach to water management requires working out optimized development plan, enhanced oil recovery requirements, improving sweep efficiency, assessment of future total water injection and disposal needs, and surface handling facility requirements for both oil and water.
Focused multilevel surveillance program, real time data gathering, tracking of water front movement, use of analytical models are part of several techniques used for water injection monitoring techniques to improve water flood conformance in KOC reservoirs.
KOC is currently working an integrated water management plan to improve the overall performance of its reservoirs and establish synergy between different assets to utilize all its resources optimally.
Completion Design for Enhanced Oil Recovery Programs in Brown Fields
Authors: Ibrahim Azhar , Fuzi Nur Azliza Mohd 
Published: November 2016

AbstractMature field oil production performance based on conventional field development plan(s) dating back to early 1970s and 1980s is challenged by the inability to fully maximize oil recovery over total field life.An enabling application that is being widely considered and implemented to some extent in more recent years to address the challenge above is to pursue enhanced oil recovery (EOR) through optimized completion design.This paper elaborates on several key completion design factors that were evaluated and implemented to enable EOR for two mature fields' offshore Malay basin (Field A and Field B); these key design factors included: Well completion design to maximize zonal production contribution through use of Inflow Control Devices (ICDs) or Interval Control Valves (ICVs) to improve sweep efficiencyFit for purpose well material selection for injectors and oil producers (OP) to last throughout the well lifeOpenhole completion with swell packers and standalone screens to maximize sandface contactApplication of chemical tracer technology to identify water breakthrough for any future zonal isolation plan, zonal contribution estimation and reduce need for wireline intervention to obtain production logging data
Oilfield Corrosion Failures Analysis: Lessons Learned from Pitting Morphologies
Authors: Martin Richard L. , Stegmann Donald W. , Sookprasong P. A. 
Published: November 2016

Abstract
Corrosion of oilfield equipment and processing facilities is a common occurrence that can pose a serious threat to the integrity of the facilities. When failures occur, the leaking substances can be very dangerous to lives and be very harmful to the environment for a long time. Direct total costs due to corrosion, its preventive measures, repairs and litigations are in the billions of dollars each year.
Identifying the type of corrosion is the first step in the analysis and prevention of corrosion-related failures. Visual inspection of the pit morphology can give insights into the type of corrosion that is occurring.
This paper describes how to identify the corrosion mechanism based on the pit orphologies. Descriptions and diagrams of pit morphology of each type of corrosion along with actual pictures of the typical corrosion or failures are included.
The Effect of Shallow Water Demultiple to Prospective Interpretation for Australian Vulcan Sub-Basin of Timor Sea
Authors: Ittharat D. , Taweesintananon K. , Sulaeman E. , Sa-nguanphon S. , Pimthong S. , Wardoyo A. , Guo M. 
Published: November 2016

Abstract
Among major seismic imaging challenges in Vulcan Sub-basin of Timor Sea, Australia, the presence of thick, high-velocity, and faulted Tertiary carbonates in the shallow section overlaid with low acoustic impedance contrast within a soft Cretaceous claystone at the target reservoir makes shallow water multiples the most prominent seismic artifacts in this exploration area. The challenge in this frontier shallow water environment is mainly from inefficient water-layer-related multiples (WLRMs) attenuation. The primary low acoustic impedance at target reflectors are contaminated with short period multiples pose the geological structure uncertainty and incorrect resource and reserve estimation during prospect evaluation process. Unlike conventional demultiple techniques such as Tau-p deconvolution and surface-related multiple elimination (SRME), Shallow Water Demultiple (SWD), developed by CGG, is an efficient tool to attenuate WLRMs in the Vulcan Sub-basin prospect and the result shows significant uplift from the seismic reprocessing project for PTTEPAA.
Improved Oil Recovery Technology Based on Emulsion with SiO2 Nanoparticles and Gelled Acid
Authors: Sergeev V. V. , Kinzyabaev F. S. 
Published: November 2016

Abstract
Results of analysis of reservoir stimulation technologies in carbonate and terrigenous formations, which have been into development a long period of time are presented in article. There were determined main reasons of low effectiveness of bottomhole zone stimulation technologies by compositions that were developed for intensification of oil production (IOP) in depleted zones. Up-to-date classification of physico-chemical methods for reservoir stimulation is presented. Also, results of the analysis of wells operation monitoring (Pashninsky oilfield) after complex reservoir stimulation technology implementation are presented. Based on the monitoring analysis the most effective technologies were educed and determined their disadvantages. Ways of improvement of solutions that applies into complex technology of reservoir stimulation based on invert-emulsion solution (IES) and acid composition were proposed. Based on laboratory test the most effective gelling agents are chosen for acid compositions. Based on different type of emulsions (oil in water emulsion and invert-emulsion) the new water-blocking solutions with SiO2 nanoparticles content were developed.
Drilling Depleting Reservoirs: Case Study from a Bruneian Field on Diminishing Drilling Windows and Stress Paths
Authors: Rai Udai Bhan , Kumar Rajan , Adwani Akash , Fokker Peter , Schoofs Stan 
Published: November 2016

AbstractThere are many cases when operators are forced to deviate from the conventional bottom-up approach for the development of multiple stacked reservoirs, thereby being exposed to the challenges of drilling through depleted reservoirs. The field under study, called Field X in this paper, presents similar challenges with shallow, fault-bounded depleted reservoirs (depletion of several MPa) underlain by (overpressured) reservoirs at virgin pressure.Reservoir pressure changes (ΔPp) are accompanied by changes in the total principal stresses (Sv = vertical stress, Shmin = lesser compressive horizontal stress, Shmax = greater compressive horizontal stress), characterized by the three stress path coefficients (γv = ΔSv / ΔPp, γshmax= ΔShmax / ΔPp and γshmin= ΔShmin / ΔPp). From drilling perspective, the two horizontal stress path coefficients (γshmax and γshmin) are the key for accurate borehole collapse pressure and fracture pressure prediction in the depleted reservoirs. However, field measurements and theoretical descriptions have focused only on the change in the minimum horizontal stress. Constrained by opportunities for direct measurement and calibration, the changes in the total stresses in the horizontal plane are often assumed symmetric, i.e. γshmax = γshmin. This paper explores the stress path computed for the depleted reservoirs in Field X from full-field numerical simulations and its implications on future drilling activity. The major findings are:The numerical model suggests significant anisotropy in the two horizontal stress path coefficients.The model also predicts variations in the two horizontal stress path coefficients with time at different stages of depletion despite a linear-elastic reservoir constitutive model.The onset of production is defined by a relatively higher γshmin compared to γshmax. This is seen to reverse with a higher γshmax compared to γshmin at the later stages of reservoir development.These insights on the evolution of horizontal stresses in Field X favorably affect future development options in Field X. The paper discusses the causes and implications of the temporal variations in the horizontal stress path coefficients in Field X, which are also applicable to other small fault bounded reservoirs.
Novel Approach to Repairing Cement Channeling Between Two Reservoir Sand Bodies with Differential Pressure Gradient
Authors: Damasena Edwin , Flew Steve , Ravichandran Narindran , Busaidi Adil , Ambrose Jonathan , Kristanto Tutus 
Published: November 2016

Abstract
Channeling behind casing connecting two sandstone reservoirs in well 13 was suspected due to poor cement job, possibly due to the high angle well of 76 deg. Avoiding communication behind casing between two sands is detrimental for field reservoir management where reservoir pressure maintenance with water injector wells is paramount for continuous production. This paper describes the treatment background, engineering approach, laboratory testing and QA/QC procedures, fluid design stage and job execution using the propriety low viscosity polymer system to seal off channeling behind casing. Cement bond log performed in well 13, a 76 deg. directional well drilled offshore Peninsular Malaysia showed very poor bond behind casing. An injectivity test conducted by setting a retrievable packer in between perforation intervals of the two sand bodies near the suspected channeling confirmed communication between the two sands. Repair alternatives were evaluated opting between cement or polymer gel squeeze. Hydraulic calculation based on the injectivity test result, roughly set the equivalent channel diameter as 0.15 in. Cement squeeze was therefore rejected in view of the small and long cement channel of 109 m. An alternative method to squeeze a low viscosity polymer system into the channel behind casing was hence designed for the purpose of sealing off the channel. The procedure developed was to create a single perforation in between the two perforations in both reservoirs and squeezing the polymer. A retrievable bridge plug and a retrievable packer straddled the squeeze perforation interval and a polymer gel squeezed through the said perforation. After several squeezes each followed by a curing time, pressure tight seal isolating the two reservoir sands was obtained. This was confirmed by setting a retrievable packer above the lower most perforation in the reservoir sand followed by injecting brine while monitoring for returns through the upper perforation, which were none. This unique method, never applied before, to repair a 109 m continuous cement channel between two reservoir sands separated by a thick shale layer using cross linked gel was successful. Two years later the seal is still intact with production from this dual completion well continuing trouble free. The proprietary gel applied is a cross linked low viscosity polymer which cures under downhole temperature to form a tough seal. It is learned that running a retrievable bridge plug and a retrievable packer in tandem in high angle well best not be attempted in future, instead, both should be run separately. Acidizing through the squeeze perforation will assist to improve squeeze pressure. Application of cross linked gel to repair cement channel has been proven to be a viable alternative to cement squeeze.
Methane Leakage Survey Techniques for Environmental Benefits
Authors: Suwagul P. , Borvornyanyong P. , Prakthong P. , Pornsakulsakdi L. 
Published: November 2016

Abstract
It is undeniable that methane is a highly flammable gas having the Global Warming Potential (GWP) of about 21 to 25 times greater than carbon dioxide; therefore, consequences of methane emissions can cause significant concerns to both safety and environment. In 2013 the Infrared (IR) Camera and Hi Volume Sampler had been introduced for effectively identifying and qualifying the methane emissions from company's activities. The methane emission survey campaign had been conducted at the company's oil production facilities located in Kamphang Phet Province focusing on three emission sources: Fugitive, Leaking Compressors, and Pneumatic Control Devices. The emissions detected from these three sources were about 31.5 MMscf per year, equivalent to the GHG emissions of about 15976.1 tonnes CO2eq, and in response to these emissions several mitigation measures have been implemented, including tightening the loose equipment and replacing the worn-out rod packings, during the major plant shutdown after the survey. In total, the GHG emissions have been reduced by 36% or about 5,800 tonnes CO2eq.
Evaluating Lacustrine Shale Oil Reservoirs by Integrating Reservoir Quality and Organic Matter Quality with Advanced Logging and Core Measurements
Authors: Hou Yu Ting , Xi Sheng Li , Wu Yong , Li Huayang , Zhao Xianran , Wu Jinlong , Zhao Haipeng 
Published: November 2016

Abstract
Unconventional reservoirs oil and gas resources have great potential for development, especially in North America, which has been successfully achieved commercial production. Shale oil is one of the unconventional resources. Most of the shale oil reservoirs have complex lithology, poor petrophysical characteristics, complex pore structure, and so on, especially for lacustrine shale oil formation. This paper describes an approach and workflow to characterize the Chang7-3 member shale oil reservoir in the Ordos basin, China by integrating the high tech digital rock physics core analysis data with other special core analysis data to calibrate the reservoir petrophysical properties. The special unconventional core analysis method taken for this project are Tight Reservoir Analysis technology (TRA), Thin Section scanning (TS scanning), Mercury Injection Capillary Pressure test (MICP), N2 and CO2 Gas sorption test, XRD and Nuclear Magnetic Resonance analysis (NMR), and the new logging technology employed are gamma ray spectroscopy logging (LithoScanner*), nuclear magnetic resonance logging (CMR*), dielectric logging (ADT*). The new core analysis and logging technology not only depict the characters of the shale oil reservoir from microscopic to macroscopic scale, but also guarantee to establish the accurate method for reservoir identification and evaluation. The data analysis from above led to the development of evaluation models for organic matter quality and reservoir quality. Analysis of the production data revealed that the hydrocarbon abundance of the Chang7-3 member lacustrine shale oil reservoir is controlled by both organic matter quality and reservoir quality. A production forecast chart of Chang7-3 Member lacustrine shale oil reservoir was constructed based on the organic matter quality and reservoir quality. The application of the developed methodology and workflow achieved very good results and is supported by the test data from multiple wells drilled in the study area.
A New Artificial Intelligence Based Empirical Correlation to Predict Sonic Travel Time
Authors: Tariq Zeeshan , Elkatatny Salaheldin , Mahmoud Mohamed , Abdulraheem Abdulazeez 
Published: November 2016

Abstract
Sonic logs can be used to estimate rock elastic parameters that are useful in obtaining the in-situ stresses of the rock. In cases where the sonic log is missing, the log values are estimated using empirical correlations. Since conducting sonic logging involves time and cost, the industry relies on empirical models. However, none of the available models are universally accepted by log analysts because each model estimates the sonic log values significantly different from the others. The error in sonic log values affects the elastic parameters, which can result in either underestimation or overestimation of the in-situ stresses.
The objective of this paper is to develop simple and accurate model to determine sonic travel time based on gamma ray, bulk density and neutron porosity because these three logs are generally available for every well. Artificial Neural Networks are used for the development of the model. An attempt has also been done to converge the results into one simple empirical correlation using the weights of ANN model in order to make the model equation universal and usable for field applications.
Several empirical correlations from literature were selected and subjected to same real field well log data as the AI model to predict sonic travel time and the results showed that ANN model was able to predict sonic logs with 96% accuracy with a correlation coefficient of 0.96 while other correlations did the same but with lesser accuracy. In addition, the developed empirical correlation from the weights of ANN model gives exactly the same results as predicted by the ANN model.
The developed model along with the empirical correlation can serve as handy tool to help geo-mechanical engineers detremine the reservoir geo-mechanical parameters and design any operation in cases where sonic logs are not available.