bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated management and Application of Horizontal Well Water Flooding Technology in a Large-scale Complicated Carbonate Oilfield Containing High permeability Streaks
Authors: Dandan Hu , Rui Guo , Songhao Hu , Yuanbing Wu , Zhaowu Zhang 
Published: October 2015

Abstract
AD oilfield in Iraq is a large-scale complicated carbonate oilfield with mid-high porosity and low permeability, of which OOIP is 3.5 billion barrel. The lithology and property for the oilfield is featured with strong heterogeneity, especially high permeability streaks and dissolution existed partially. In Middle East fewer examples are successful in application of horizontal well water flooding technology for the similar oilfields. Integrated management is the fundamental for the application of horizontal well water flooding technology.
The paper put forward an integrated management system of horizontal well water flooding technology for the complicated carbonate oilfield. Water breakthrough mechanism and injection timing for horizontal water injection are studied based on numerical simulation, pilots and laboratory experiments. Production management system has been established to evaluate productivity, analyze production law for ESP producers and the change for reservoir pressure, which also timely diagnosis abnormal condition for producers and injectors. Evaluation and optimisation system are put forward including multiple indexes evaluation model for horizontal well water flooding's development effect, classification charts for horizontal well with different changing law, cause analysis for abnormal water cut increasing, and optimization for pressure and production/injection parameters. The relevant optimization and adjustment measures have been recommended and implemented in time to maximize single well production through the integrated system.
The production capacity has been constructed up to 7 million ton per year and achieved stable yield of 3 years continuously in AD oilfield, of which 6% was increased by horizontal well water flooding. The ultimate recovery factor of horizontal well water flooding has been predicted about 40%, nearly 2% higher than that of the overall field development plan in 2011. The integrated management of horizontal well water flooding technology will provide significant technical support for longer stable production with 70 million ton per year in AD oilfield. The application result has significant reference for the development of complicated carbonate reservoirs containing high permeability streaks in Middle East.
A New Advance in Window Exit Milling Using Aluminum Casing
Authors: Butler Ben , Benson Cole , Steele David , Sherston Mitchell , Metz Stephen , Lehner Jeffry 
Published: October 2015

Abstract
Two methods are commonly used to produce window exits in multilateral wells. One implements premilled window technology, while the other involves steel casing milling. Steel casing milling generates steel cuttings that can be challenging to circulate to surface during wellbore cleanout and can hinder equipment in subsequent downhole operations. Premilled windows eliminate steel debris; however, they require that the main bore casing string be oriented. This paper describes an additional approach that does not create steel milling debris nor requires orientation of the casing string, which can result in significant time savings and risk reduction.
This approach involves an all-aluminum casing exit joint (hereon referred to as ACE joint) coupled to a lower coupling with a latch profile in which service tools can be landed to perform junction construction. This new technology, including design rationale, development, installation procedures, subsequent testing, and field trial results are discussed within this document. The ACE joint was designed, manufactured, and deployed in a multiwell, TAML 5 multilateral field development containing bilateral and trilateral wells. To create the window exit, the ACE joint and latch coupling are made up to the main bore production casing and cemented in hole. An orientation tool is then run in hole (RIH) and latched into the joint latch coupling, obtaining coupling orientation. The whipstock and mill assembly is then configured at surface to the desired millout orientation, RIH, and latched into the ACE joint for subsequent milling operations.
Lab testing has been performed to qualify the ACE joint for suitable milling performance, corrosion resistance, and drilling wear resistance; all with positive results. Field installations have also been successful, with bi and trilateral wells having laterals exceeding 2000 m in length being created without problem. The tests and field installations demonstrate the ACE joint is now a proven technology, confirming the window geometry post millout to be acceptable for lateral drilling and completion operations.
This new approach to window millout technology represents an improvement to existing steel casing milling technology, providing a more suitable solution for removal of milling debris and a more simple installation process.
Reducing Risk and Improving Efficiency of Extended Reach Drilling Through Use of Sampling While Drilling Technology
Authors: Lean Jonathan , Ying Tan Chi , Fey Scott , Pop Julian , Indo Kentaro , Varughese Jimmy , Megat Amanda , Liu Chun Lin 
Published: October 2015

Abstract
Extended reach wells are drilled to access large areas of reservoir from a relatively small surface footprint. As a secondary zone becomes a target, other zones in the openhole drilled section may have already been subject to pressure depletion. These two challenges significantly increase the risk of conducting comprehensive formation evaluation.
Logging-While-Drilling (LWD) technologies have evolved over the last 25 years to provide much of the required formation evaluation data. In situations where conveying wireline tools would be difficult, LWD tools are incorporated into the drillstring and provide formation evaluation data. They also have much higher ratings for tension and compression and, coupled with the ability to rotate, reduce the risk of differential sticking. A key LWD technology developed recently is formation sampling while drilling (FSWD). FSWD is an evolution of formation-pressure-while-drilling (FPWD) tools that, in addition to making formation pressure measurements, can also capture and analyze samples ofdownhole fluid in the same manner as current wireline formation testers.
This paper recounts an FSWD operation conducted offshore Malaysia. The primary sampling objective was to collect representative in-situ samples of gas and water, which were not previously captured in this reservoir. Of key importance was the quality of the water samples in order to accurately measure salinity, refine water saturation calculations, and provide assays for corrosion considerations related to completion design and production planning.
Previously, a time-consuming operation—using a wireline formation tester conveyed on drillpipe—would have been the only way to capture quality downhole samples, but a major concern was differential sticking, caused by a highly deviated wellbore, that would potentially intersect depleted zones. As an alternative, the FSWD tool was deployed to measure formation pressures (used to infer large-scale reservoir connectivity) and to collect gas and water samples, all in a single drilling run.
Results demonstrated that in high-risk wellbores, FSWD tools could capture high-quality downhole fluid samples. Also, the real-time data transmitted using mud pulse telemetry was sufficient to identify fluid type during the pumpout, and tool controllability enabled fluid sampling in single-phase condition. Using FWSD tools eliminated unproductive time associated with a dedicated drillpipe conveyed wireline run, along with the associated additional openhole exposure time that could have jeopardized the success of the completion. The samples acquired with the FSWD tool were of a quality high enough that the operator was able to cancel wireline sampling operations planned for two additional wells, further saving time and reducing risk.
Drill String Torque Reducing Technology Improves Drilling Efficiency in Horizontal Well
Authors: Yim M. , Healey S. , Leedham R. , Giuliano M. , Weber M. , Pitre D. 
Published: October 2015

Abstract
Horizontal wells have proven highly beneficial to the Oil and Gas Industry by enabling operators to tap into reservoirs previously deemed inaccessible by conventional drilling practices. This inaccessibility was particularly evident when drilling unconventional reservoirs; the efficient penetration and successful production of oil and gas from low permeability formations was economically impossible. While horizontal wells provide many benefits, there are several limiting factors challenging the industry as it pushes for longer ERD wells. Drill string torque capacity and top drive torque capabilities are two of the most common limiting factors.
In 2012, Beach Energy Limited encountered challenges drilling the 8 ½″ horizontal section of an Australian gas well (Well-A). The main challenge faced was the well profile's significant surface torque, as a result of side forces exceeding 2,000lbs. These factors led to damaged equipment, compromised wellbore quality and drilling inefficiency.
To improve drilling efficiency, Beach Energy Limited utilizes torque reducing subs in the horizontal section of the subsequent well (Well-B). The 8 ½″ horizontal section of Well-B was drilled over three times faster than offset Well-A by effectively reducing surface torque by an average of 23%. This section was successfully drilled utilizing torque reduction subs to protect the drill string from the high side forces in open hole; prevent drill pipe tool joints from contacting the wellbore, thus enhancing the drilling response and reducing surface torque; and improve BHA stability yielding better wellbore quality. The end result of the project was a longer horizontal wellbore placed in the payzone with significant rig time savings.
New Generation Cutters Boost Hybrid Bit Performance in Volcanic Basement in Northeast China
Authors: Wan Jun , Lan Zhongxiao , Guo Hongyan , Gao Chunliang , Sheng Simiao , Valbuena Franklin , Zeng Jun 
Published: October 2015

Abstract
Development blocks around Daqing, P.R. China are challenging directional drilling applications. Xushen comprises the largest volcanic gas reservoir in the Ying Cheng formation among 5 development blocks. The formations are hard and abrasive and include a volcanic basement of rhyolite, tuff and breccia with unconfined compressive strength (UCS) up to 30 kpsi.
Polycrystalline Diamond Compact (PDC) bits experience high vibrations and premature wear and bit ring-outs. Overall, PDC performance results in short footage and very low rates of penetration (ROP). For a decade, heavy-set roller cones, IADC 617 to 637, were believed to be the correct alternative to drill this hard, heterogeneous formation. However, roller-cone bits are slower than PDC bits and have a limited bearing life. A detailed engineering analysis was undertaken to increase both the penetration rate and distance drilled.
As a result of this study, a hybrid bit which combines the advantages of a fixed-cutter and roller-cone was employed to drill in this application. The PDC portion of the hybrid bit design also included a new cutter edge geometry to reduce spalling and impact damage observed on historical PDC runs. The first run in the Ying Cheng group increased ROP by a record 115%, with nearly two times the distance drilled compared to roller-cone bits in the same section. This revolutionary new bit and cutter technology improved reliability and increased drilling efficiency for the duration of the project. After the introduction of this new hybrid bit to the drilling campaign, the operator performed 16 bit runs and saved multiple runs per section.
This paper presents a case study of the hybrid bit runs in both the directional and horizontal sections on the wells in northeast China. The detailed analysis of the drilling data also presents the economic benefits of the project and the potential impact of the new technology for the industry.
An Efficient and Parallel Scalable Geomechanics Simulator for Reservoir Simulation
Authors: Luo Jia , Chen Zhangxin , Wang Kun , Deng Hui , Liu Hui 
Published: October 2015

Abstract
A tetrahedron-grid based parallel geomechanics simulator is developed and presented in this paper. Parallel computing is employed to handle large scale problems by benefiting from its features of distributed memory storage and efficient runtime reduction. This simulator aims to describe rock matrix deformation and its interactions with pore fluid. In the consideration of the feasibility in coupling with a variety of existing reservoir simulators, the modularized geomechanics simulator is designed to be a library. Through interfaces provided by the library, conventional reservoir simulators can get geomechanics effects involved.
In this paper, the framework of a parallel geomechanics simulator and the strategy for coupling with a reservoir simulator are presented. Iteratively coupling approach is employed to make geomechanics modeling more independent and flexible. The procedure for solving solid mechanism and calculating coupling parameters is general, which can be applied to more complicated constitutive laws and rock property descriptions. A parallel strategy is proposed to improve the computational efficiency of solving the coupled problem. To verify the utility and efficiency of the geomechanics simulator, simulations coupled with a three-phase black oil model are performed. Expected geomechanical phenomena are illustrated by numerical experiments. In addition, for testing the scalability behaviour, field scale problems with millions reservoir and geomechanics grid blocks are performed. We use an increasing number of processors to run the cases, respectively, and the results indicate an encouraging speedup.
Development of Discontinuous Galerkin Methods and a Parallel Simulator for Reservoir Simulation
Authors: Wang Kun , Zhang Linbo , Chen Zhangxin 
Published: October 2015

Abstract
The classical discontinuous Galerkin (DG) methods are designed for elliptic (parabolic) problems and hyperbolic problems. For reservoir simulations, the pressure equation from the black oil model is elliptic (parabolic), while the equations for saturations are hyperbolic. Due to this special property, it is difficult to directly apply the discontinuous Galerkin methods to the black oil model. In this paper, we extend the discontinuous Galerkin methods to reservoir simulations. In our schemes, the local discontinuous Galerkin (LDG) method is used to discretize the black oil model. The upwind concept is combined with the numerical flux term of the LDG method to simulate the direction of propagation of the multiphase flow in reservoirs to avoid the unphysical solutions. We also extend the Peaceman model to the discontinuous Galerkin methods on unstructured grids. Based on the extended discontinuous Galerkin methods, we employ the iterative implicit pressure-explicit saturation (iterative-IMPES) and fully implicit (FIM) methods to solve the coupled nonlinear black oil model. A parallel simulator is implemented using the parallel adaptive finite element package, Parallel Hierarchical Grid (PHG), and validated by testing the first and ninth SPE Comparative Solution Projects. The parallel scalability of our simulator is also tested by a large scale case.
Two Dimentional NMR Analysis and Evaluation of Oil or Gas Shale
Authors: Wang Zhizhan , Qin Liming , Lu Huangsheng , Li Xin , Du Huanfu , Gai Shanshan , Niu Qiang , Yang Peiqiang 
Published: October 2015

Abstract
Oil or gas shale is characterized by Nano-scale porosity, self-source-reservoir and complex lithology. Both Conventional NMR analysis method and petro-physical model are not suitable for this formation evaluation. So, based on increasing investigation resolution of the Nano-scale pores and signal to noise ratio, the field frequency is added from the 2~5MHz to 11MHz and TE is decreased from 0.6ms to 0.06ms. Therefore, the pore scale resolution in T2 spectrum is improved from 0.1ms to 0.01ms in order to satisfy for the oil shale exploration. In addition, the petro physical model of oil shale is established to distinguish the organic pore, inorganic pore and micro fracture. Through this method, the reservoir quality can be evaluated, such as physical property, hydrocarbon generation, and pore pressure to provide the effect support for the reservoir fracture, plan design and fracture assessment.
A New Mechanistic Model for Predicting Dynamic Corrosion-Erosion in Gas Production Pipeline under the Influence of FeS Scale
Authors: Santoso R. K. , Fauzi I. , Rahmawati S. D. 
Published: October 2015

Abstract
This paper presents a study about corrosion-erosion phenomenon in natural gas production pipeline when FeS scale is formed on the inner surface of the pipeline. FeS scale is chosen here because its reaction is faster and more reactive than the other scale such as FeCO3.
A literature study was firstly conducted to develop the idea of corrosion-erosion model. Several phenomena were considered to be the best to describe corrosion-erosion process. Then, the mathematical model to calculate corrosion-erosion rate was derived. The corrosion-erosion process was divided into two steps: fluid flow and heat transfer phenomena to establish corrosion-erosion environment and diffusion phenomena to make the corrosion-erosion happened. The first phenomena were modeled using Thermodynamics equation with considering Joule Thomson effect and gas flow equation (Katz for vertical-inclined tubing and Panhandle-B for horizontal pipeline). The second phenomena consisted of mass transfer equations including erosion process to evaluate scale growth. Finally, the model was applied to calculate an example case of gas well. The result was then compared with several simulators' result.
Pressure profile, temperature profile, liquid distribution, scale formation rate and erosion rate are generated as the first phenomena simulation and become the basis to evaluate the corrosion-erosion rate value. The simulation of second phenomena will provide the value of corrosion-erosion rate for each segment in production pipeline. Corrosion is mainly caused by the reaction of iron in pipe and corrosive agents in produced fluid such as CO2 and H2S. Supporting by erosion process, corrosion will badly damage the pipeline. Moreover, the simulation's result shows that at early time, corrosion and erosion simultaneously occurs because of the absence of FeS scale. However, at time t, when the FeS scale has been formed, the corrosion rate is reduced. If the erosion rate is larger than the scale formation rate, corrosion and erosion will conjunctly occur as at the early time. In addition, the difference in model and simulators' result is primarily caused by the effect of considering the scale growth process.
Corrosion and erosion are critical problems which need to be early prevented. An accurate prediction determines the effective prevention action. This paper gives a more accurate prediction by considering Joule Thompson effect and scale formation process. A segmented corrosion-erosion rate as the result of this paper can be considered to choose an effective action.
Tie Back Liner Mechanism Application at North Senoro Drilling Gas Field Development Project
Authors: Widyatmoko Antya Bagus , Rahmadona Desmawati 
Published: October 2015

Abstract
North Senoro Gas Field is located onshore, operated by JOB PERTAMINA – Medco E&P Tomori Sulawesi. The aim of North Senoro Development is to produce gas from limestone reservoir (Mentawa reef), member of Minahaki formation to fulfill gas supply commitment to Donggi Senoro LNG Plant. This field was discovered by Well A wildcat well in April 1999. Afterward, five successful delineation wells have been drilled and tested in year 2001, 2003, 2005, 2007, and 2009 named Well B, Well C, Well D, Well E, and Well F. Those wells used 7" liner carbon steel material.
Fluid analysis shows existence of H2S up to 0.06 Mol %, CO2 up to 2.16 Mol % in gas stream and Cl− content in produced water up to 15,531 mg/L. Reservoir pressure is 2900 psi and temperature is 2120 F.
Based on North Senoro reservoir fluid characteristic which have H2S and CO2 content, best recompletion method should be chosen to convert old exploration wells into production wells with good performance and cost effectiveness.
Well known recompletion methods are Monobore and Side Track. Recompletion methods using Tie Back Liner Mechanism was an alternative solution utilize in this project to convert 3 existing/exploration wells into production wells with good performance and cost effectiveness.
Recompletion method using tie back liner mechanism was successfully installed in 3 wells. Those wells had been produced since December 2014 to supply Donggi Senoro LNG Plant.
An Improved Numerical Simulator for Surfactant/Polymer Flooding
Authors: Yang Jing , Jin Baoguang , Jiang Liangliang , Liu Fang 
Published: October 2015

Abstract
Due to the high demand to increase oil production combined with the huge potential in enhancing oil recovery, surfactant/polymer (S/P) flooding is under increasing interest and importance in recent years. Numerous studies have shown that interactions between surfactant and polymer can be extremely important to the final displacement performance of S/P flooding, since the desired effect of polymer and surfactant may be enhanced or degraded as various slugs become mixed underground. Nevertheless, as far as we know none of the available commercial numerical simulators can account for the impact of these interactions.
The study focuses on constructing an improved S/P numerical simulator. A series of experiments were performed on S/P mixed system and flooding process. The results show significant influence of S/P interactions on viscosity, interfacial tension, and adsorption, and the interactions can be totally different when injected into different S/P systems. Quantitative relationships of the interactions were then provided based on the results. Then, an S/P flooding mathematical model was established on the basis of mass conservation, with the description of various important phenomena during flooding process being included, especially for the interactions between surfactant and polymer. Adaptive implicit method was applied to solve the equations and a simulator was developed. The simulator was finally used to perform the numerical study of different S/P mixed systems, in which synergistic promotion, non-interaction and competitive repulsion were respectively presented. The displacement performance was the best when synergistic promotion existed between surfactant and polymer, followed by non-interaction, and competitive repulsion. In summary, a new method for the treatment of interactions between surfactant and polymer in numerical simulation was derived in this work. The improved simulator could enhance the matching degree between mathematical model and field data.