bluuebunny/crossref_metadata_2025_split huggingface dataset:
Economic Comparison Between ESP and Rod Pump for Same Rate Wells
Authors: Pandit Akchay L. , Abdelaziz Issa Yasser , Khamis Mahmoud Bakr , Quttainah Riyad , Al-Ajmi Rakan N 
Published: October 2015

Abstract
In Oil Wells the design for each feasible artificial lift method is determined before running the economic analysis to better determine the efficiency of a particular installation. Consideration of the applicable artificial lift method helps to generate the necessary information for the net present value (NPV) analysis.
In this paper, a study is carried for economic comparison of the wells with same design production rate considering two artificial lift methods i.e., ESP (Electrical Submersible Pump) and rod pump. In order to increase the operational window in general, units with expected higher run life and robust construction are preferred. Therefore, in this paper firstly, it is discussed for rate comparison between conventional beam pump and unconventional extra-long stroke rod pumping units. Secondly, simulation result of ESP for the same production rate as is achievable by unconventional rod pumping unit is discussed and thirdly an economic comparison is carried between them. It will be clearly seen for the economic variation by production either through Unconventional rod pump or ESP lift method for same target rate and same pump setting depth.
To use the NPV comparison method, it is important to have a good idea of the associated costs for each system. This requires to evaluate each system carefully for the particular well and be aware of the advantages and disadvantages of each method and any additional equipment (i.e., additional costs) that may be required.
Therefore, in this paper comparison is carried for the operating expenses (OPEX) for two replacement choices—a smaller-size ESP and a long-stroke pumping unit, and its NPV. Comparative plots are obtained for rate Vs cost to generate NPV at different depths and corresponding rates. The results obtained is a valuable data base for economic comparison between ESP and rod pump for same rate wells.
Steam Injection Tracking System
Authors: Najaf Abdulaziz , Altarabulsi Khadhr , Taha Abdalla , Alsarraf Zahra 
Published: October 2015

Abstract
The state of Kuwait is developing its unconventional heavy oil fields. Currently, the Kuwait Oil Company KOC which is the national oil company of Kuwait is implementing a pilot project which utilizes the cyclic steam stimulation CSS Technology in accordance with different artificial lift methods to test the feasibility of applying the CSS technology in different areas of these fields. Moreover, it tests the effect of multiple steam cycles on wells and evaluates the performance of the wells with the selected artificial lift methods.
During the pilot stage, numerous numbers of data is being received daily from the well site. Integrating and analyzing these data manually requires huge efforts. Thus, a Steam Injection Tracking System is created to serve both management and operation sides by integrating all the well data including operational and financial parameters. The system will represent all these parameters graphically which helps the engineers to better understand the performance and economics of this pilot. This will be impacted for the best prediction of this pilot project and the unconventional fields' developments.
The results of implementing this system exceeded all expectations. It provided an excellent understanding and management for the pilot. On the management side, the main page of the software shows and summarizes automatically the historical and current status of each well in the pilot with its economics. Also, it helped in selecting the proper zone to utilize the CSS technology by showing the zones which responded profitably to that technology. On the other side which is related to the operational, it helped in selecting the proper well completion with its proper artificial lift method by presenting the historical production, expenditures, and profits. Moreover, it visualized all the essential daily well parameters such as steam quality, flow rate, and pressure readings associated with the occurrence of operational problems such as shutdowns and leaks. Finally, it allowed the engineers to style a customized sensitivity studies by graphing any parameter with respect to others.
Over Four Decades' Experience With Gas Dewatering at Naturally Fractured Gas Reservoirs in South-Sichuan, China, What Have We Learned?
Authors: Xueqing Tang 
Published: October 2015

Abstract
Early water breakthrough occurs frequently in naturally fractured gas reservoirs. To minimize the impact on gas production, gas dewatering technology has been applied successfully since 1969 in South-Sichuan gas sector, China. During past over 40 years, gas dewatering technology has been utilized in 326 naturally fractured gas pools, including pilot tests at individual wells and field wide applications in entire gas reservoirs at both initial geopressured and late pressure-depleted development phases, forming systematic and mature practices. This paper presents and analyzes five typical, innovative dewatering practices:
1). Water and gas production simultaneously from updip wells in massive gas reservoirs with weak edge water.
2). Gas production in updip wells while water production from downdip wells with strong bottom water drive.
3). Water and gas production simultaneously in downdip wells in geopressured formation below gas/water contact.
4). Combination of water/gas co-production in downdip wells near gas/water contact and pure gas production in updip wells
5). Newly drilled horizontal wells located below gas/water contact are used for water and gas co-production, in order to bring updip, prolific, and watered-out gas wells back production.
The results are that production decline trends in gas pools at different stages have been arrested and flattened out, offsetting previous double-digit decline. The best field case is plateau production rate sustained for eight years without additional drilling, with peak off-take rate of above 8%, relatively stabilized flowing wellhead pressures, gas flow rates and gas/water ratios. The paper also addresses some of the lessons learned and the criteria of the optimal practice for selecting and designing gas dewatering technology.
Subsea Field Development Optimization Using All Electric Controls as an Alternative to Conventional Electro-Hydraulic
Authors: Hasan Z. , Kapetanic N. , Vaughan J. , Robinson G. M. 
Published: October 2015

Abstract
This paper describes the overall aspects of an all-electric controls system using an eSolutions approach describing advantages of eSolutions over conventional control systems and associated challenges. Illustrations and conclusions are provided from technical evaluation studies for esolutions conducted for several applications globally. In addition, actual field experience of eSolution systems gained to date including installation, commissioning and operation is discussed.
Global oil and gas discoveries offshore are getting deeper with increased tieback distances. This is driving the development of all electric subsea production systems to enable extraction and transportation of hydrocarbons to the shore and or host facilities. At present, the oil & gas industry is predominantly using electro-hydraulic subsea control systems which are likely to continue as the system of choice for some time. The need for simpler and lighter subsea equipment will increase the opportunity to use all-electric subsea production control systems. Therefore it is important to understand how all electric control technology will impact performance, risks, costs and attractiveness of the subsea production system in the future. The advent of Subsea Processing and associated electrical power consumers on the seabed as well as the need for fast acting control systems is an enabler to have more electrical power available on the seabed for use.
Case studies including alternate field layouts with various step-out distances have been performed using an all-electric control system versus an as-built electro-hydraulic control system. Recommendations for all electric control system architecture and associated products required for the system were established from the performed studies. For eSolution system the subsea tree design was modified to use an electrically operated actuator, eSCM and removal of all controls tubing and compensator chests to allow comparison with an existing electro-hydraulic tree.
Benefits for eSolutions as related to simplification of assembly and test as well as fabrication will also be discussed.
An Electromagnetic Wave Based Water Cut Meter and the Influence Factors of Measuring Accuracy
Authors: Qinghai Yang , Xiaohan Pei , Fangchao Liu , Lianyu Wang , Jianwen Yan , Jinqi Wang 
Published: October 2015

Abstract
Most of oil fields in China have stepped in the development stage of high water cut. The accurate measurement of downhole water cut is the key to master the developing status, upon which injection and production adjustment could be implemented to improve oil recovery. This paper proposed an electromagnetic wave based water cut meter, which can realize full-range measurement of the water cut with high resolution and accuracy. The measuring sensor is equipped with two coaxial cylindrical conductors, the oil-water mixture flows between the two conductors during the measurement. When electromagnetic wave transmits in the coaxial sensor full of mixed fluid of water and oil, the wave phase shifts regularly. The water cut of the mixed fluid is calculated through the measured phase variation. Based on the analysis of polarization principle, dielectric property, transmission law, and the circuit implementation, this paper established the mathematical model of electromagnetic wave phase variation, and determined the frequency of electromagnetic wave. Then an electromagnetic wave based water cut meter was proposed. Through simulations and experiments, the paper studied the influence factors of measuring accuracy, including the mixed fluid's temperature, salinity, pollution to the conductors, and emulsive state. The temperature and salinity show associated effects on the measuring result. If the salinity is low, the response of water cut meter decreases with temperature rising. If the salinity is high, the response is just the opposite. Under different emulsive states, the response frequency of the mixed fluid exhibit same tendency, although the frequency value may show some difference. The oil films adhered to inner or outer conductor both give rise to measuring errors, while the pollution to the inner conductor produces more obvious influence. The response characteristics of water cut meter were also summarized in the paper and the compensation methods to eliminate or reduce the interference were confirmed. At present, in most cases, the downhole water cut are measured during well logging or separate-layer producer testing. This paper proposes an electromagnetic wave based water cut meter, which can be equipped in the downhole production regulator and realize automatic production adjusting.
Foam Hammers Enhanced the Performance of Hammer Drilling in Potential Water Formations
Authors: HU Gui , MENG Qinkun , LIU Xinyun , Tao Ye , WANG Xiangdong 
Published: October 2015

Abstract
Air hammer drilling technique has long been considered an effective approach to improve the rate of penetration (ROP) in hard formations. However, when being used in wet or water formations, air hammers are easy to output less energy or to be failure to work; in addition, the formation fluids would flow back into the gas chamber cylinder of air hammer when the gas circulation was stopped during the pipe connection time. In potential water formations, the operators would worry the possible failures of air hammers, thus quit the air hammer drilling technique and choose a comparatively safe drilling technique even with a lower ROP.
A kind of foam hammers was developed. It is suitable for both dry gas and wet gas (misted gas or foam) drilling media with high energy output compared to the air hammers. Furthermore, with the installation of anti-backflow device, the foam hammer can effectively seal the formation fluids and prevent their backflow into the gas chambers of hammer.
Two field tests were carried out. The lithology of the both cases’ targeting formations was hard rocks and the ROP was no more than 1.5 m/h in mud drilling. Air hammer drilling technique might be the best choice and the ROP might be increased by 5-10 times. However, due to the potential water strata contained, the operators had no confidence to employ air hammer drilling technique firstly. If the wet formations were encountered in advance with a short dry interval and needed to change to misted gas or foam drilling technology, an overwork of bit-change is needed and the short interval of gas drilling would not bring economical benefits. The foam hammer drilling technique can solve this problem. With the foam hammer, there was no need to trip out/in the BHA when changing into misted gas drilling or foam drilling due to the water formations. The results in two cases showed that the ROP of foam hammer in gas drilling medium was 5~10 times higher than traditional mud drilling, and the ROP in foam medium was 2~3 times higher than traditional mud drilling without reservoir fluids backflow into the hammer's gas chamber.
With the foam hammer, the operators may firstly apply the gas drilling technique in dry formations. If the encountered strata contain water, they can immediately transformed into wet gas drilling medium such as misted gas or foam with no tripping out/in to change the bits. Thus, improve the drilling performance compared to air hammer drilling.
Application of DOWS (Downhole Oil Water Separation) Technology Used in High Water-Cut Oilfield: Case Study
Authors: Yang Gao , He Liu , Feng Li , Yong Zhang , Bo Yu , Haoyu Lu 
Published: October 2015

Abstract
High water-cut is a common problem affecting oilfield stabilized production in the late period of oilfield development. Downhole oil water separation (DOWS) technology provides an effective way for the long-term economic development of high water-cut oilfield. DOWS can separate the oil and water in the wellbore directly with a hydrocyclone. The oil-rich stream is produced to the surface while the water stream is injected into the water-injection layer or abandoned layer. DOWS technology has made new developments in China as the progress of downhole date monitoring and control technique. The DOWS system consists of hydrocyclone, downhole date monitoring system, two pumps used for lifting and injection respectively. Hydrocyclone contour line was optimized and increased the separation efficiency to 98% or more. Date monitoring system includes flow meter and pressure gauge to surveil the flow and pressure of injection layer in real time. These dates can be transmitted to the ground through the cable and then to the remote terminal by GPRS modem. Engineers can monitor working situation of the DOWS system and control the separation effect using PC or mobile phone in the office. The inlet of hydrocyclone and the injection pump was designed to adapt to the limited space in 5½" casing well. This paper reports the characteristics of DOWS technology used in China and the latest advances we developed. This technology has been used in high water-cut blocks in Daqing Oilfield and Jidong Oilfield in China. Field tests show that DOWS technology can reduce the ground water production more than 75% and maintain the oil production unchanged in high water-cut oilfield. DOWS system has worked properly more than 400 days.
Electronic Control Separate Layer Flooding – A Case Study in Jilin Oil field
Authors: Lichen Zheng , Xiaohan Pei , He Liu , Dong Chen , Jiaqing Yu 
Published: October 2015

Abstract
Oil production from low-permeability oil reservoir plays a more and more important role in oil production. Separate layer waterflooding is an effective method in improving the oil recovery, but because of low adsorptivity of low-permeability reservoirs, single layer flow rate is too small to be measured accurately, the interlayer interference makes it more difficult to get right flooding rate, and the smaller water nozzle is easily blocked by contaminant.
A new electronic control water flooding technology is presented in this paper. Powered by DC battery, the system has a gear motor acting as adjustment element, flat nozzle as flush control, swing-rod flowmeter as test gauge, a pressure sensor installed behind nozzle to supervise the reservoir pressure, and a temperature sensor to supervise the downhole temperature. The whole system is controlled by microcomputer, realizing automatic calibrate of flow. Synchronous testing and adjusting process has been invented to eliminate the interlayer interference, and the nozzle will be opened fully periodically to let out the contaminant.
This new technology has been tested in Jilin Oilfield and proved to be effective. The swing-rod flowmeter can test small flow rate as low as 1.5m3/d, which can meet the requirement of low-permeability reservoir flooding. Synchronous testing and adjusting process has solved the interlayer interference problem and improved the testing and adjusting efficiency greatly, a testing and adjusting period can be finished in 5 minutes. The periodically opened nozzle solves the block problem and prevents the system from failure because of contaminants.
The new electronic control water flooding technology provides an effective way for low-permeability oilfield flooding. The newly invented swing-rod flowmeter has solved downhole flow measurement problem, and the synchronous testing and adjusting process has addressed the interlayer interference problem and improved the calibration efficiency greatly.
New Correlation for Predicting Asphaltene Deposition
Authors: Sulaimon A. A. , Govindasamy K. 
Published: October 2015

Abstract
Precipitation and deposition of hydrocarbon solids such as asphaltenes and wax are some of the major challenges facing the oil and gas processing and transportation industry. Deep-water, high pressure and high temperature (HPHT) environment are currently being explored for meeting the ever increasing energy demand and operating companies allocate huge resources annually to mitigate flow assurance problems. The aim of this study was to develop correlations for predicting asphaltene deposition tendency of crude oils since the experimental analyses are both laborious and capital intensive. SARA analyses and refractive index measurements were conducted on four Malaysian crude oil samples and the correlation development is based on the measured Collodal Instability Index (CII), the Refractive Index (RI), molecular weight of oil and the molecular weight of the lumped fraction of the crude oil.
Results from the mathematical correlations developed from the experimental data have proved reliable as predictions compare favourably well with the actual data. Analysis of the results show that the difference between the refractive index (RI) of the crude oil and the refractive index at the onset of asphaltene precipitation for the samples (∆RI) are less than 0.045 while the CII for the four crude oil samples A, B, C, and D are 1.09, 1.43, 5.64 and 5.83 respectively. These indicate that all the oils investigated have high tendency to precipitate asphaltene.
Validation of Drillpipe Rotation Hydraulics Using Drillpipe Eccentricity as a Key Factor
Authors: Hemphill Terry 
Published: October 2015

Abstract
The theoretical study of the calculation of pressure drop with and without drillpipe rotation was recently presented to the industry. In the study, fluid velocities, drilling fluid shear rates, and their corresponding shear stresses were used to model increases in annular hydraulics caused by drillpipe rotation in non-Newtonian fluid flow. No extra modifications (i.e., added exponents, multipliers, etc.) were used in the modeling of circulating shear rates.
It has been known for some time that the position of the drillpipe (in the annular center vs. off-center) has a significant effect on calculated pressure drop. Yet, most conventional pressure drop calculations neglect both drillpipe rotation speeds and drillpipe eccentricity and assume the drillpipe is always in the center of the annulus. It is known that moving the drillpipe from the center of the hole to an off-center position can reduce circulating annular pressure by up to 30%, and these reduced pressures can be increased significantly using increased drillpipe rotation speeds.
Validation of this purely theoretical approach is presented using available field fingerprinting information, where annular pressure changes with fluid velocity and drillpipe rotation speeds were measured using downhole pressure tools. Levels of equivalent circulating density (ECD) were calculated from the changes in pressure drop using standard equations. Hence, this kind of validation is quite different than what has been used previously, for which only some success was achieved in matching the data.
The results presented here show that small ranges in values of drillpipe eccentricity can describe the changes in measured pressure drop for the following: Vertical to near-vertical wellbores (one range set)Deviated wellbores (a second range set)
Using the small ranges in drillpipe eccentricity presented in this study, drilling engineers can better calculate the hydraulic effects of drillpipe rotation in a given drilling situation where no experimental fingerprinting data is available.
Study on Effect of Low Calcium Fly Ash on Geopolymer Cement for Oil Well Cementing
Authors: Sugumaran Maheswaren 
Published: October 2015

Abstract
With the increasing awareness of global warming, geopolymer cement has been identified as one of the methods in reducing the emission of CO2 during oil well cementing operation. However, it is important that geopolymer cement can meet the specific requirement of oil well condition in order to be substitute of current conventional cement system. The use of fly ash in geopolymer based cement can affect the performance of the cement slurry by its properties which yet needs proper study to yield better advantages of it.In this research, the main objective is to study the effect of fly ash in geopolymer cement, by varying the properties which are thickening time, fluid loss and compressive strength. It is identified that the current conventional cement slurry is not environmentally-friendly, and is energy intensive. It is also identified that fly ash produced cannot be recycled and mostly being dumped. Thus, this study can provide the solutions to the problems identified. It involves extensive laboratory work in order to identify the properties of the cement.This project focused on the designation of fly ash based geopolymer cement compositions, the testing of the prepared fly ash based geopolymer with different compositions and different acid concentrations.This report comprises the literature review on the properties of geopolymers, the experimental works and their results, as well as the discussion and recommendations of the project.The tested parameters are water ratio, type and molarity of alkaline activator and alkaline activator ratio.The water ratio is 0.4 with the use of 12M of Sodium Hydroxide and the alkaline activator ratio is 0.4. Sodium silicate and silica fume was added to optimize the compressive strength which proved to have 31% increase of strength. Under low concentration acid, the cement is able to withstand the reaction but failed with higher concentration.The performance of the new blend will be analyzed.