bluuebunny/crossref_metadata_2025_split huggingface dataset:
Achieving a Step Change in Well Duration and Cost in a HPHT Tight Gas Field
Authors: Smit Jeroen , Adawi Anwar , Hinai Faisal , Khayari Mustafa , Abri Mohammed , Kiyumi Hassan , Nakireddi Naidu , Yousef Hamada 
Published: November 2017

Abstract
This paper discusses the journey of drilling excellence in Khulud field, one of the most challenging fields in Sultanate of Oman and the Middle East. It highlights the changes in well design, drilling optimization and efficiency improvement which resulted in significant cost and time improvement in the development campaign.
Amin formation is the target reservoir, at about 5,000 meters in depth, with some of the hardest rock formations in the area in excess of 50 Ksi compressive strength. The reservoir pressure gradient is approximately 18 kPa/m (1.84 SG) and static downhole temperature is around 178 °C.
An integrated approach was taken to address the challenges as the field transitions from appraisal stage to development. This involved the selective deployment of technology along with improved operations, and implementation of several initiatives which resulted in a significant improvement in well durations and cost in excess of 40% within a year. The well design was altered from a five casing string design in the exploration and appraisal phase to a three string slim design with liner top completion. Additionally, a cemented completion design was introduced and executed successfully, involving the implementation of a specially designed degradable packer fluid to reduce the burst loads on the casing in the frac and production phase of the wells. The bit selection and drive type was changed from turbine drilling with an impreg bit to motor drilling with a PDC bit application specially designed for the field and its challenging conditions. The change led to major improvement in ROP (Rate of Penetration) and accordingly reduced time to drill the final 8 3/8" hole section. Furthermore, the implementation of Lean practices and following the well delivery process stages played a crucial role in aligning all parties involved together. A Performance Improvement Plan (PIP) was developed and implemented to capture the different initiatives in well design and operational excellence and was used as a vehicle for continuous improvement.
The results show significant reduction in well cost and time by 40 % compared to well cost before implementing these changes. Recent wells have beaten the Best Composite Time (BCT) set in the field and reduced the overall duration from 260 days in the exploration stage to 55 days in the recent wells delivered in 2017.
The cemented completion with degradable mud was a first time application in PDO, requiring in-house development and testing. The PDC bit used in recent wells was specifically designed for Khulud to replace the impreg bit and enhance ROP.
Optimum Selection & Application of Hydraulic Jet Pump for Well-1A: A Case Study
Authors: Kalwar Shuaib Ahmed , Awan Abdul Quddos , Qureshi Fahad Aziz 
Published: November 2017

Abstract
In the current era, a major challenge facing the oil industry is to keep up production and maximize reserves especially in mature oil fields. The application of artificial lift systems to improve productivity, whilst ensuring the most effective use of existing reserves, should optimize the petroleum resources. However, the selection of the most feasible lift system plays a crucial role in restoring production rate to normal levels and to maximize ultimate recovery. The decision of which artificial lift method to use is very important to the long-term profitability of the field.
This paper presents screening criteria on the different artificial lift techniques and discusses why the choice was confined to jet pumping as the most suitable technique applied in the well. Well–1A was spudded in November, 2008 and was drilled as a slanted well to the depth of 8665 ft. The well was completed with a sucker rod pumping unit and flowed initially at the rate of 130 BOPD. However, the well was optimized by changing the lift method from sucker rod to jet pump. The base development plan included hot crude injection with the help of water bath heaters, which made crude of 18 degree API and high wax content, heated up to 150°F used as power fluid for jet pumping. Both injection and return lines were insulated till the storage tank in order to maintain the temperature. The jet pump was run in hole with 11A Nozzle/Throat combination in freestyle after ensuring a sufficient liquid level within the wellbore.
The jet pump provided the required drawdown and helped in sustaining the deliverability of the well for such waxy crude, and produced an average of 270 BOPD. Jet pump performance was monitored continuously in order to enhance the production up to desired potential by considering all the parameters related to the lift system. In addition to this, the jet pump can easily be re-optimized by reversing it out to change the nozzle and/or throat without requiring a slick-line job.
Analysis of IOR Pilots in Bakken Formation by Using Numerical Simulation
Authors: Alfarge Dheiaa , Wei Mingzhen , Bai Baojun , Alsaba Mortadha 
Published: November 2017

Abstract
Bakken is the most productive formation among unconventional plays in North America. This formation has 7.4 billion barrels of recoverable oil. However, the primary oil recovery is still low as 5-10%. Miscible natural gas and carbon dioxide (CO2) might be the most two potential strategies to improve oil recovery in such complex play. In this study, some of the IOR pilots which have been conducted in Montana, North Dakota, and South Saskatchewan have been presented. The performance results of these pilots in US-Bakken versus Canadian-Bakken have been compared. Moreover, the reasons beyond the successful IOR pilots in Canadian-Bakken versus US-Bakken have been discussed. Then, numerical simulation models have been constructed to mimic the results of these pilots. Two different compositional models have been built for two different formation-oils. Furthermore, two different models, single porosity model and dual permeability model have been created to match the performance of some pilot-tests. Implementation of molecular diffusion mechanism has been conducted in both of single porosity and dual permeability model. Finally, continuous miscible gases injection versus huff-n-puff protocols have been compared and investigated.
The results showed that the performance of natural gases generally over-performed the CO2 injection technique's in Bakken formation. Although the diffusion flow is dominant, the diffusivity of the injected CO2 into formation oil is slow due to its large molecules as compared with the small pore throats of these porous media. Accordingly, miscible CO2-EOR might be not beneficial in huff-n-puff as compared to continuous flooding process. However, success of natural gases does not have that strong functionality of molar diffusivity. Therefore, their performance was much better than CO2 performance in the field scale of these tight formations. Furthermore, the numerical simulation of this study concluded that the spacing between the production wells and injection wells should be minimized, for the continuous flooding process of miscible-gases EOR, to enhance their performance. Although the permeability of Canadian-Bakken has permeability of 1-2 order higher than the permeability of US-Bakken, the spacing between injectors and producers in Canadian Bakken is interestingly much shorter than that for US-Bakken, which might be the reason beyond the EOR success in Canadian Bakken. Finally, the activation process for the highly intensive natural fractures might be the key to enhance the diffusivity of CO2-EOR. Otherwise, natural gases are highly recommended to be the most potential EOR in these types of reservoirs. This study explains how diffusion mechanism of miscible gases affects their performance to improve oil recovery in these plays since they are more complex and very different from conventional formations. Also, it suggests that CO2 flooding process would be a good practice to overcome the limitations of CO2-diffusion rate in these reservoirs.
Assessment of Petrol Filling Stations Hazards Risk in Abu Dhabi, UAE - GIS Applications
Authors: Periyasamy Punithat , Yagoub M M , Al Hader Mahmoud 
Published: November 2017

Abstract
In the emirate of Abu Dhabi, the transportation vehicle is growing at rapid rate every year which in turn increase the requirement of the petrol filling stations (PFS). This growth rate plays a major role in increasing the fire and explosion hazards risk than ever before. When the fuel is not handled safely, it has the potential to cause not only a serious fire and/or explosion hazard and also harmful to health which can cause damage to skin, eyes on contact, dizziness and respiratory problems, if it is inhaled. Hence, petrol storage and operation is controlled by legislation, guidelines and standards all over the world. With this in mind, an attempt has been made to identify the PFS hazards risk in the capital city of UAE using various international guidelines and standards. Land use and Land cover is prepared for Abu Dhabi using Landsat 8, 2017 data to demarcate the highly urbanized area within the emirate where Abu Dhabi city is chosen for the study. The planning criteria for location, guidance for establishment, planning policy, legislation, published reports from the regulatory reforms & association and literatures from various developed and developing countries are studied to identify the most important risk parameters associated with PFS for analysis and inference.
The thematic maps are prepared based on the minimum requirement mentioned in the guidelines & standards which are proximity to the road, sight distance, distance limitation between two stations, if the stations are located within the same cadastral unit & different cadastral areas, staggered length if the two stations are opposite to each other, distance to residential buildings and distance to vulnerable places such as prayer halls, libraries, markets, hospitals, schools, higher education, banks, shopping malls, post office, public play grounds, recreational areas and fire brigade. The potential hazards of each filling stations are estimated by assessing both refueling services and the other related internal hazardous activities such as availability of LPG storage area, cooking facility, oil change, car care (automatic and manual) car wash which is then categorized into 7 types.
ArcGIS 10.1 acts as a powerful spatial analysis tool to find out the hazards risk in the PFS by means of weighted overlay analysis. Each individual parameter of the thematic map is ranked and weighted in accordance with their compliance with the international legislation & regulations. The real risk associated with each station are classified viz., High, medium, low and no violation with its identification numbers respectively. The outcome of this research helps local authorities in terms of land management, so that necessary measures can be established around PFS which are operated under high risk.
Data Driven Analysis for Rapid and Credible Decision Making: Heavy Oil Case Study
Authors: Kaushik A. , Kumar V. , Mishra A. , Tummala P. 
Published: November 2017

Abstract
Having less data is challenging as it adds to the uncertainty around our understanding. On the contrary, huge volume of existing data with continuous additions poses challenges to incorporate them into subsurface models. Data analytics involving integration of large volume of geology, production and surveillance data at a single platform, analysis of data and data trends depicting a physical process can be used to come up at technically robust results in a short time.
Data driven analysis and forecasting is carried out for a mature steamflood. Firstly, all data including production, injection, pressure, well test, well, static models, petrophysical logs, GIS data are integrated on a single data analytics platform. Trends in data are established and visualized based on the production, injection and geology enabling production performance analysis at various aggregated levels. The established trends are studied to understand the effectiveness of steam injection recovery mechanism, interference and are then forecasted.
Data like PLT and static model information earlier analyzed in silos are integrated and now examined together with production data. Due to data integration at a single platform, connecting and visualizing time series data with spatial location to arrive at certain aggregation or cluster is now rapid and credible. Observations and outcomes from data driven analysis correlate well with the recent years of historical data for well groups with mature production and injection history. For well groups with new and upcoming wells, data driven method may get more biased towards existing but sparse performance thus not capturing the full uncertainty in forecast. Data driven analysis method becomes effective when sufficient data is available to infer trends and results that can be validated with alternate estimation or new data.
This technique finds wide application in brownfields with huge data that are either not analyzed or integrated with other information to develop a holistic understanding of subsurface uncertainties. Aided with effective visualization, this technique provides an alternative methodology to enable rapid decision making.
Multidimensional Evaluation for Safe and Efficient Killing Using Dynamic Kill Method: A Case Analysis in China
Authors: Zhou Yunjian , Li Xiangfang , Wojtanowicz Andrew K. , Miao Yanan , Chen Jingde 
Published: November 2017

Abstract
Well control in gas reservoirs with high pressure has been of growing interest in the industry in recent years. It has been widely recognized that challenges of well leakage and ground equipment damage will be faced in well-control work. Unfortunately, current well-control procedures do not allow us to kill with confidence and serious accidents occur sometimes. To ensure a safe and successful kill operation, before drilling, utilizing multiple well-control approaches to simulate the kill operation and after blowout, determining reasonable kill parameters to accomplish the kill should be of great significance. In this study, the Qing Xi 1 well was taken as an example to perform the first and second dynamic kill simulations by the Drillbench software to evaluate the effectivity of different kill operations with various choke pressures. The feasibility analysis of the dynamic kill was conducted by switching the displacement of mud pump, ascertaining the values of laminar coefficient A and turbulence coefficient B skillfully, and employing the known parameters of pump pressure, gas influx from formation and fracture pressure. The simulation results demonstrated that, under the limited geological conditions and the site environment of the Qing Xi 1 well, the second killing scenario will succeed when 40MPa choke pressure was employed in the dynamic kill operation, which differs dramatically from the realistic failure of the second killing scenario in the site of the Qing Xi 1 well. Accordingly, the maximum of choke pressure should be suggested in the future site operation of killing scenario when the equipment conditions are allowable. Although higher choke pressure may make the well leak-off, it will generate smaller losses compared with serious blowout out of control. In addition, a reliable pre-prevention and post-processing well-control procedure for implementation of our method was proposed, which is the most efficient and easy to apply. Our work in this paper should provide a basis for guiding field operations involving kill efficiency and should assist engineers in ensuring personal and property safety.
Reaping the Benefits of the Mega Water Flood Project in North Kuwait - Production Enhancement Opportunities Tracking & Implementing
Authors: Saleh Nada , Chetri Hom , Al-Twaitan Tasneem , Al-qenae Amna 
Published: November 2017

Abstract
Sabiriyah Mauddud and Upper Burgan are two of the giant reservoirs in North Kuwait(NK) under active water flood since 2000. About 400 MBWPD of water is currently being injected to maintain the reservoir pressure & improve the production/recovery. A comprehensive workflow process was developed and implemented to understand the waterflood performance, pressure-production response trends and map the opportunities to encash the benefits in terms of quick oil gains. The paper discusses the best practices adopted to increase production from two of the water flooded reservoirs in NK.
Sound workflow process was created by integrating the technical inputs under collaborative environment from subsurface & surface teams. Series of segment reviews are conducted to understand the connectivity between producers & injectors, duly integrating all surveillance data. Analytical diagnostic tools have been used to distinguish between the good water and bad water and improve the VRR & sweep. Live ESP data is monitored and tracked at intelligent field collaboration centre to decide about the actions for the wells requiring ESP upsizing, downsizing and VSD/choke optimization. Wells with running ESPs were identified for VSD & choke optimization, using rationalized technical criteria. Wells with failed ESPs are reviewed for smart replacements with water shut off/ water flood conformance & ESP re-design. Simultaneous actions for the well model creation; running sensitivity and scheduling in the workover rig are taken up.
ESP upsize, along with VSD installation/ choke optimization, was implemented in number of wells with significant oil gain (about 11% enhancement within a short time frame). As a part of the process established, this activity has become a regular practice in NK. Such wells are under constant monitoring so that water injection actions in nearby injectors, if needed, could be taken up such as allowable management, arresting the declining trend etc. The benefit of mega water flood activities have been reaped in terms of production enhancement adhering to the best reservoir management practices.
Quick understanding of the Water flood response and relignment of actions on the associated wells via rigless and rig workovers is the key to the success for significant ramp of the NK production within a short time window of 6-7 months. Several work flow processes established during the campaign are now deeply imbeded within NK asset.
DFN Modeling Aided Reservoir Characterization
Authors: Karatalov N. , Stefaniak A. , Vaughan L. 
Published: November 2017

Abstract
Describing the dynamic performance of Naturally Fractured Reservoirs (NFR) is challenging. Numerous studies often cite sparse data with regard to the static description of fractures, and success of dynamic prediction often proves problematic. Discrete Fracture Network models (DFN) provide more robust prediction of flow characteristics but due to their complexity and size, DFN models are often unsuitable for field-scale predictions.
This paper describes sensitivity analysis on fracture effective properties aimed at bracketing the uncertainty in NFR modeling. We have developed over 200 realizations of a sector model that bracket variables associated with fracture characterization and representation of the fractured system in a 3D cellular model. The fracture characterization parameters include aperture, intensity, length and the impact of conjugate fractures. Reservoir modeling considerations include model cell size in XYZ dimension and different upscaling methodologies. Expectedly, a sensitivity study of the results indicates the top three most important variables in the following order: fracture aperture, upscaling method, and fracture intensity.
We propose a methodology that can be universally applied to any NFR. By constraining fracture intensity and aperture, the methodology provides bracketed effective properties which can be incorporated in more traditional reservoir models. The transition can be done effectively for quick and efficient reservoir characterization of NFRs without a need for resource-intensive efforts often associated with DFN models.
Drilling Safe Wells through Efficient, Rapid and Site Specific Planning to Manage Risks & Improve Performance
Authors: Tayab Muhammad R , Valappil Suhail Kunnath , Prieto Gerardo , Nuaimi Ammar Humaid 
Published: November 2017

Abstract
Well planning is one of the most demanding aspects of drilling engineering requiring integration of engineering principles, HSE philosophies and learnings from incidents. Although well planning methods and practices may vary but the key objective is a safely drilled well meeting operational requirements. As per Drilling HSE requirements, well development is subjected to Site Specific Safety Plan (SSSP) and the purpose of this Site Specific Safety Plan (SSSP) is manage risks associated with release of well bore gases or fluids and to ensure a quick and effective response to emergencies that can be implemented. A web based Electronic Well Delivery Process (e-WDP) was developed to facilitate generation of SSSP using QRA data base for efficient and fit for the purpose SSSP.
Carbonate Rocks: A Case Study of Rock Properties Evaluation Using Multi-Scale Digital Images
Authors: Sun Huafeng , Di Dejia , Tao Guo , Vega Sandra , Li Kesai , Liu Luofu , Belhaj Hadi 
Published: November 2017

Abstract
Three-dimensional (3D) information of rock microstructures is important for a better rock characterization at the micro-scale. The development of imaging technique makes this possible. For instance, in recent years, significant progress of digital rock physics (DRP) following the X-ray computed tomography (XCT) scan techniques has been made. This technique can be used to predict rock properties such as porosity, permeability, elastic moduli, and electrical conductivity. In most cases, the simulated results from rock images agree well with their lab measurements. However, some properties, such as the effective elastic moduli, strongly depend on the microstructural details of rock, which can lead to a dissatisfied comparison between numerical simulations and lab measurements. In addition, there is a clear trade-off between physical sample size and image resolution, which means that it is almost impossible to predict rock properties with single resolution image for heterogeneous carbonate rock sample.
In this paper, we present a case study of rock properties evaluation using multi-scale CT images of two heterogeneous carbonate rock samples. Different image resolutions, including 40.00μm/voxel, 4.00μm/voxel, 2.00μm/voxel, 1.00μm/voxel, and 0.50μm/voxel, are used to obtain the CT images of whole core samples and their corresponding subsamples. For each resolution image of subsample, eight sub-volumes are selected to do the simulations. The rock properties including porosity, permeability and elastic properties are calculated by some effective methods such as voxel-based method (VBM), parallel lattice Boltzmann method (PLBM) and rotated staggered grid finite difference method (RSG-FDM). The results show that: 1) the simulated porosity and permeability agree well with the lab measurements; 2) the simulated P- and S-wave velocities and their lab measurements have a relatively big difference with maximum value of 62.43%; 3) the unresolved phase can reduce P- and S-wave velocities in the rocks; 4) the rock properties are well evaluated by rock images, lab measurements and numerical simulations.