bluuebunny/crossref_metadata_2025_split huggingface dataset:
Application of Well Factory Drilling Technology in Shale Gas Development in the Sichuan Basin
Authors: Yang Liu , Ping Chen , Shou Ma Tian 
Published: October 2017

Abstract
The shale gas field in Sichuan Basin is located in a complex mountains and hilly areas, and the predrilling and drilling operation are difficult and costly due to well site logistical limitations. Therefore, based on many successful case histories of factory drilling and completion work in the North Amercia, and considering the terrain and the geologic and development characteristics of shale gas reservoirs in the Sichuan Basin, an applicable "factory drilling" model was established. In this case, "factory drilling" involved standardizing predrilling engineering, optimizing design of exploration and drilling operations, streamlining engineering, launching an assembly-line drilling operation, establishing a comprehensive utilization of resources and uniform and integrated crew management as its foundation. The standardization of predrilling engineering contained well patterns arrangement and well site deployment, well patterns adopted cluster well with single or double row, 8 wells at the most in a single well pad and the maximum distance between wells is 600m. The drilling engineering optimization design included well trajectory design and interwell anti-collision calculation, the extending direction of the horizontal section was orientation of the maximal horizontal principal stress. The engineering module included the PDC bit selection, drilling methods and matched technical modules. Assembly-line drilling operation involves batch drilling in the same section and reclaiming the waste drilling fluid according to the situation. The field test results indicated that factory drilling could help increase rig operation efficiency, shorten well construction cycle, improve the comprehensive utilization rate of resources, and reduce the waste fluid discharge in the working areas. In WeiYuan shale gas district, there was a sharp decrease in the average well construction period, from original 149d (well W201H3) to the present 72d (well W204H1-3), the corresponding ROP improved from 2.67m/h to 8.35 m/h, and recycling rate of drilling fluid are reached 70%. This study provided a new idea and a reliable technological means to achieve the high-efficiency and low-cost exploitation of unconventional natural gas resources.
Unlocking Reservoir Potential through Rigorous Surveillance and Field Review Post FDP: Case Study on Central Luconia Carbonate Gas Field
Authors: Sow Chia Shen , Bashir Aamir , Chowdhury Utpal , Hajizadeh Alireza , Ridzuan Ahmad Idriszuldin 
Published: October 2017

Abstract
For E&P upstream player, the most exciting oil and gas development project is to transform a commercial hydrocarbon resources into readiness for production to meet the company investment portfolio. It involves field development planning, design, technology, procurement, construction, drilling and start-up prior to handover to production operations.
Most of the times, economic evaluation, assessment of risk and return on investiment (ROI) from the project are the key factors to determine the fate of the project during feasibility study and/or before the Final Investment Decision (FID) phase. Moreover the project cost, schedule, reserves to be developed and production profile are the key parameters to dictate the cash flow and net present value.
The general practice is that once the project completed, the reservoir model will be updated with new findings and surprises observed during drilling phase and include in post drilling evaluation report. After this stage, the project team will be disbanded and most companies will be lacking a single point of accountability for delivering production as promised1. Once all the requirements and expectation have been met, the project is considered to be successfully delivered.
In this case study, the real time production and survelliance data were analysed. Although initial production did not meet the FDP delivery target due to project delays and subsea facilities downtime which causes production deferment, the stabilized production trends with time indicated a potential reserves gain by about 50%.
In summary, the analysis shows the value of analyzing the production and surveillance data by a dedicated team to assess the current field performance compared with the forecast profile from FDP study. The deviation can be a triggering point for revision on the resources figures, future infill opportunities and may contribute to the future cluster development within the same PSC.
Production Optimization of Raageshwari Field Using Network Modelling
Authors: Bhardwaj Charu , Godiyal Preeti , Mathur Mohit , Ranjan Amit , Verma Saurabh K. 
Published: October 2017

Abstract
The Raageshwari field is situated within the RJ-ON-90/1 Contract Area. Of the seven producers which have been completed, six flow naturally and one is on artificial lift.
A network model was created to verify the maximum producing potential of the field as well as identify any bottlenecks in the system. The model could then be used to evaluate de-bottlenecking options before going into full field implementation.
The production potential of each well was categorized into three parameters: Reservoir Maximum Production Potential (RMPP) i.e. the maximum theoretical production that the reservoir can deliver at the sand-face, Well Maximum Production Potential (WMPP) i.e. the maximum production that well can deliver from sand-face to choke valve, and Plant Maximum Production Potential (PMPP) i.e. the maximum production that the surface facilities downstream of choke valve can handle. These values were generated using the Network Model and the lowest of these was termed as Lowest Maximum Production Potential (LMPP). Sensitivities were carried out in the model to identify constraints limiting the production potential of the field. The model was then used to predict the effect on production of removing these constraining factors. These predictions were then evaluated based on the cost to implement and their economic value. The study indicated that the field production can be increased by 20% with payback time of 7 to 10 days. This workflow for production optimization can be applied to similar marginal fields.
Flexible Cement Extends Wellbore Life with an Integrated Approach to Zonal Isolation
Authors: Kumar Animesh , Gupta Gaurav , Mehra Rohit , Tambe Romana , Ahuja Gopal 
Published: October 2017

Abstract
Sustained casing pressure (SCP) is a major risk encountered in most wells in India, particularly in developmental oil and gas fields situated in the northwest area of the country. The inability of conventional cement systems to withstand cumulative stresses from completion and production phases might be one of the primary reasons for the failure of expected barriers during zonal isolation, which can lead to SCP. This case study reviews a flexible cement system used in an oil and gas field located in northwestern India, including extensive laboratory evaluation, operational design, execution, and well evaluation.
The field requirement was to design a gas-tight, lightweight slurry for a production zone to treat losses and address issues of SCP. A finite element analysis (FEA) structural simulation was performed, which modeled the lifetime operation of the well. Including elastomeric and tensile strength enhancement materials in the cement system was recommended based on results from structural simulation to reduce risks of SCP. Incorporating these materials can enhance a cement system's mechanical properties (i.e., increase Poisson's ratio and tensile strength and decrease Young's modulus). The slurry was designed with cement, hollow spheres, lost circulation material (LCM), a tensile strength enhancer, and elastomeric material; the cement slurry was batch mixed to ensure homogeneity.
The case study examines the impact of the fluid rheological hierarchy, pump rates, and multiple bottom plugs on cement slurry displacement efficiency using computational fluid dynamics (CFD). A finite-difference, three-dimensional (3D) displacement simulator was used to predict the flow behavior of fluids, both inside and outside the casing, throughout the operation using actual operational parameters. Based on two-dimensional (2D) hydraulics analysis, various factors, including rheology, pumping rates, and fluid density, were adjusted to maintain equivalent circulating densities (ECDs) below the fracture pressure to help avoid losses.
A tailored cement design, which created a stable gas-tight resilient cement system, helped minimize risks to production by achieving effective zonal isolation. This was confirmed through a post-operation review. The cement bond log, including a microseismogram and circumferential visualization, indicated that the cement was adequately placed around the casing.
The increase in the cement system tensile strength helped ensure wellbore integrity, even in high-stress/strain load cycle production environments. Cementing operation success was confirmed by excellent cement bond logs and zero SCP observed between the production and surface well casing annulus.
The life-of-the-well tool is an engineered, proactive, and interventionless zonal isolation solution to help extend well economic life, thus preserving production while reducing or even eliminating costly remediation (Ravi et al. 2002).
Success and Lessons Learned from ASP Flooding Field Tests in China
Authors: Guo Hu , Ma Ruicheng , Kong Debin 
Published: October 2017

Abstract
ASP flooding is proven a great success in China due to its large number of field tests and incredible oil production. Latest progress of ASP flooding field tests and application in China is summarized. Incremental oil recovery of ASP flooding can be as high as 30%, much higher than all the other chemical enhanced oil recovery (CEOR) techniques. Although one recent surfactant-polymer flooding (SP) field test is reported 18% incremental oil recovery, other SP flooding field tests are not so successful. More incremental oil recovery does not always ensure more economic benefits. With progress of surfactant production technology in Daqing, alkali NaOH was finally proven better than Na2CO3. Too high polymer concentration may block low permeability strata. The allowable maximum polymer parameter (molecular weight and concentration) is key to success, especially when emulsification is taken into consideration. There is no one-fit-all ASP formulation and the dynamic adjustment is necessary in ASP flooding. Why pre-slug is used is still worth investigation. The average cost of ASP flooding can be lower than SP flooding due to more oil produced.
Online Monitoring and Automatic Control for Zonal Polymer Injection Wells
Authors: Fuchao Sun , Xiaohan Pei , Deli Jia , Guanglei Gao , Guoqin Li , Xiaoyan Wang , Chongjiang Liu 
Published: October 2017

Abstract
Polymer flooding has been improved an effective way for EOR in China. Comparing with waterflooding, zonal pressure and flowrate change much larger for polymerflooding duo to its high viscosity. Reservoir engineer are required to adjust flow allocation scheme frequently when pressure change. However, traditional zonal polymer injection technique can not obtain zonal parameters during injection process. The flowrate adjustment has been done by fishing downhole choke by steel wire. Usually, the fishing operation was implemented many times. The efficiency is poor. This paper introduced an online monitoring and automatic control technology. A instrument was used to realize zonal polymer measurement and adjustment. There is no need for downhole fishing tool. Considering viscosity decrease control, a downhole streamline slot adjustable choke was development. The lab test indicated the viscosity decrease rate can be controlled within 10% when flowrate vary from 10-60m3/d. At the same time, the flowrate can be adjusted according to set point by instrument. And it can also be regulated at any time manually just needing pushing the mouse in the office. This technology has been applied more than 200 wells in Daqing. The downhole instrument is mainly consisted of mechanical arms, control part, measuring part and guiding mechanism. Comparing with waterflooding, the torque output for polymer injection well is much larger. Torque output of water flooding is only 3-5N.m, however, it can increase by more than two times to 8-12N.m for polymer flooding. Meanwhile, on-line torque monitoring function is added to effectively prevent excessive current that damages the motor and adjustment success rate. Considering the flowmeter based on internal magnetic may result in polymer blocking, external magnetic type flowmeter was used to avoid affects due to polymer plugging. The technology has been applied in 60 polymer injection wells by the end of 2016 and the test time of average single well is shortened from 5.2 days to 2.5 days which means the efficiency is more than two times higher. At last, a case study was introduced.
Modelling and Analysis on High-Fidelity Fine-Scale Reservoir Simulation in Mature Waterflooding Reservoir
Authors: Shuhong Wu , Jiangyan Dong , hua Li , Qiaoyun Li , Baohua Wang , Tianyi Fan 
Published: October 2017

Abstract
Today the oil development in the world goes into a new area, in which the complex and special oil reservoir are becoming the main development objects gradually to meet the ever-growing need for energy. Especially in china, most of the oil reservoirs are located in continental basins characterized by serious heterogeneity. And many mature reservoir entered into high water-cut stage after several decades' development. Thus, with the increase of the complexity of the reservoir and its development, reservoir simulation becomes increasingly very complicated. A high-fidelity and fine-scale reservoir simulation with high performance is needed to analyze the complex flow process, simulate the production history and forecast the future performance.
In this paper, the high-fidelity and fine-scale reservoir simulation focus on three aspects, which are flow modeling, fine grid and high-performance mathematic method. The flow and formation model is designed to actually describe the complex flow process of oil, water and gas as well as time-dependent variation of reservoir properties such as permeability and porosity in mature water-flooding reservoir, such as fault, pinch and heterogeneity, which is helpful to simulate water-flooding front and water channeling. The computational mathematical method with high-level pre-conditioners is designed to ensure solving the large simulation mathematic problem with high speed and high performance.
The results shows that the fine-scale simulation is helpful to identify the water displacement front, especially, water channeling which might occur and result in sudden water cut increase during the water-flooding. Also, the high-fidelity and fine-scale modeling more accurately describe the remaining oil and better match the production performance such as the oil and water production trend. As an auxiliary tool, it helps to identify the location of new well in the rejuvenation of mature field. Thanks to the high-fidelity and fine-scale simulation, two new wells are designed and drilled in the area of high remaining oil of ZY reservoir, which both get encouragingly high daily oil production and low water-cut.
Highly Efficient Nano Boron Crosslinker for Low-Polymer Loading Fracturing Fluid System
Authors: Wang Kun , Wang Yanling , Ren Jinheng , Dai Caili 
Published: October 2017

Abstract
Guar gum and its derivatives based-gels crosslinked with boron have been utilized in hydraulic fracturing for decades. However, these gels have a noticeable limit-large polymer loading which causes problems including large quantity of residues and low regained permeability. Besides, to achieve optimal thermal stability, conventional boron crosslinker must be utilized at high pH. To overcome the above limitation of conventional boron crosslinker, we proposed highly efficient nano boron crosslinker for low polymer loading fracturing fluids.
Boron-modified nanoparticles were synthesized by two-step surface modification as nano boron crosslinker (NBC). First, (3-Aminopropyl) triethoxysilane was coated onto the silica nanoparticles surface obtaining amino-modified nanoparticles JT-1. Second, Organic boron (OBC) was coated onto JT-1 resulting in boron-modified nanoparticles (NBC). Characterization was given using FTIR spectroscopy to prove the presence of surface modifier and transmission electron microscopy (TEM) to study the particle size. The effect of pH and mass ratio of JT-1 and OBC on rheological properties of hydroxypropyl guar (HPG) gels crosslinked with NBC was investigated. The microstructures of NBC crosslinked-gels was visualized via Scanning Electron Microscope (SEM).
The results of FTIR spectroscopy illustrate the presence of amino on the surface of JT-1 and OBC was bounded onto the surface of JT-1 by B-N. The particle size of NBC ranges from 20 to 40 nm. NBC crosslinked0.3 wt.% gels exhibit a unique rheological performance at 100°C. The viscosity of OBC crosslinked-gels shows a tendency of first increase and then fall as pH ranges from 7 to 14 and peak viscosity was achieved at pH 10. Whereas, viscosity of NBC crosslinked-0.3 wt.% gels increased continuously from 44.72 mPa•s to 327.8 mPa•s as pH rises from 7 to 14. The remaining viscosity (viscosity after shearing at 170s−1 for 60 min) at 100 °Cof NBC-crosslinked 0.3 wt.% HPG gels remains higher than 50 mPa•s at pH 8 -14, indicating that NBC crosslinked-gels possessed great thermal stability at low polymer loading over a wide pH range. The difference between microstructures of NBC crosslinked-gels at different pH may be responsible for the effect of pH on the thermal stability of NBC crosslinked-gels. Gels crosslinked at higher pH gave a more coiled 3D microstructures with considerably higher structure density compared with those crosslinked at pH 7.
The hydraulic fracturing fluid system crosslinked with surface modified nano boron crosslinker showed great thermal stability at low polymer loading (0.3 wt.%) over wide pH range (8-14). Due to its unique crosslinking properties with HPG, nano boron crosslinker may provide an excellent solution to the limits of conventional boron crosslinked gels.
Statistical Analysis and Mapping of Oil and Gas Operating Cost Based on Field Development Plan in Indonesia
Authors: Azizurrofi A. Abdul , Asnidar A. A. , Galih D. R. , Hermawan A. H. , Buana Y. S. , Firdaus R. R. 
Published: October 2017

Abstract
In early 2016, oil price has fallen to its lowest level (31.68 US$/bbl) over the last 12 years. Since then, petroleum exploration and exploitation activities are decreasing worldwide due to high production cost and low oil prices.
As of November 2016, there were 403 field development plans (FDPs) approved by the government of Indonesia in 2003 – 2016 period. In 2015, there were 57 approved FDPs, which became the largest number of FDPs approved since 2003. The increasing number of approved FDPs indicates that the fall of oil price had no big impact on the number of projects (FDPs) in Indonesia. The oil and gas industry in Indonesia is still considered attractive by contractors.
Before investing in the oil and gas industry in Indonesia, there are some of ways that can be done by investors to minimize risk of loss and maximize revenue such as, searching, finding and collecting data of cost expenditure (Capital and Operating Expenditure) and commercial reserves across Indonesia, analyzing social issue that may occur in oil and gas exploitation area, considering infrastructure and geographical area (remote area or not), etc. This paper will collect and evaluate the operating cost of production of 403 approved FDPs and analyze the correlation between the operating cost of 403 FDPs and the world oil price, and create maps showing the distribution of operating cost in each clustered area in Indonesia.
For the purpose of this paper, the geographical areas of Indonesia were divided into 6 different areas (Sumatera, Natuna Sea, Java, Kalimantan, Sulawesi and Papua). Then, the data that related with Operating cost of oil and gas production from 403 FDPs was collected and then the operating cost was calculated and distributed to those aforementioned areas. Finally, areas that had the lowest and the highest operating costs of oil and gas production were defined.
Based on analysis of 403 FDPs, the western area of Indonesia had the highest Operating cost of oil and gas production. The highest Operating cost was equal to 7.91 US$/bbl and located in Sumatera, meanwhile the lowest Operating cost was equal to 3.22 US$/boe and located in Kalimantan.
Hopefully, this paper will provide contractors (Investors) with a quick look at oil and gas industry in Indonesia especially related to cost of oil and gas productions and help them to build their oil and gas portfolios before making decision to invest in the oil and gas industry in Indonesia.
Capillary Pressure Drainage Curves: Modelling and Prediction of Capillary Entry Pressure
Authors: Behrenbruch Peter , Kennaird Tony , Duy Bui Khang , Do Huu Minh Triet 
Published: October 2017

Abstract
Capillary pressure (CP) measurements on core samples generally deploy one of three tests: porous plate (PP), centrifuge (CF) and mercury injection (MI). The first two mentioned tests are most often used to directly determine a CP relationship and the PP procedure most closely conforms to reservoir situations. CF test results may be superior for certain types of plugs and testing conditions, not to mention that testing is considerably faster. MICP tests are typically used for determining pore size distributions but may also be used to generate CP curves, with best results obtained by validation against the other two tests. MI tests also have the shortest timeline.
CP curves have been modelled (fitted or matched) over the years with many alternative formulations, from the well-known J-function approach (Leverett, 1941) to more recent methods. Some formulations can realistically match the low pressures of CP profiles, including capillary entry pressure, while others do not cater for it at all. When the low-pressure part of CP curves exhibit a "roll-over effect (concave downward profile), entry pressure prediction may require high frequency data from MICP testing to give more definition.
This paper examines several CP data sets, comparing PP and MI results, in light of pore throat distributions. Seven formulation are used to match entire CP profiles from PP data and are subsequentlyexaminedfor being able to represent capillary entry pressure. Various types of pore structures are discussed: homogeneous (narrow distribution), broad (poorer sorting) and bimodal (two distinct distributions) where the smaller pores are often related to pore-fill. It is shown that the Modified Carman-Kozeny Purcell (MCKP) formulation (Behrenbruch et al, 2011) is excellent in capturing the level of entry pressure for narrow pore throat size distributions or homogeneous plugs while entry pressure prediction for poorer sorted plugs tends to be less accurate, partially due to variation in samples.The detailed modelling of the roll-over effect requires a separate model. A new and improved correlation for (model) capillary entry pressure has been derived, showing results from Australian and other fields.