bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Practical Compositional Method for Simulation of CO2 Flooding in Porous and Fractured Petroleum Reservoirs
Authors: Di Yuan , Wu Yu-Shu , Ju Binshan , Qin Jishun , Song Xinmin 
Published: January 2012

Abstract
CO2 flooding is one of the most effective and used methods for enhanced oil recovery (EOR) approaches. The number of CO2 flooding projects has increased rapidly in China and around the world. Compositional simulation is required for evaluating CO2 flooding in EOR operations, especially for miscible or nearly miscible flooding when black-oil simulation is no longer adequate. The simulation method proposed here is a multi-dimensional, three-phase, and compositional modeling approach, which is applicable to both porous and fractured reservoirs. In the model formulation, a generalized multi-continuum approach is adopted to handle flow and transport in naturally fractured reservoirs and the mass flux of each mass component is contributed by advection and diffusion processes. In addition, precipitation of heavy oil components and absorption of CO2 on the solid grains are modeled based on reversible linear or nonlinear isotherms. The governing partial differential equations for conservation of each component are discretized using a finite volume method and the resulting discrete equations are solved fully implicitly by Newton-Raphson iteration. The equation of state (EOS) by Soave-Redlich-Kwong is used to calculate the physical properties of fluids. Research has shown that the flash calculations with EOS in compositional simulation are computationally intensive and may not be reliable at near critical conditions. Therefore, a K-value based approach, improved by Almehaideb et al. (2002), is used for partitioning of oil components and CO2 between oil and CO2 phases. In addition, the laboratory measured oil and CO2 phase compositional data can be used alternatively to account for compositional effect in this model. Two numerical examples are presented to show that the proposed modeling method is efficient for simulation of CO2 flooding processes in EOR operations.
The Development of Material Balance Equations for Coalbed Methane Reservoirs
Authors: Firanda E. 
Published: January 2012

Abstract
This paper presents the development of material balance equations (MBE) for coalbed methane (CBM) reservoirs. This method is appropriate for determining Original Gas In Place (OGIP) and predicting fluid mechanisms in coalbed methane reservoirs. Previously, material balance for coalbed has been developed by G.R. King and several researchers. King’s MBE has considered water expansion, rock (cleat) compaction and water influx. In this paper, author added some new aspects such as gas expansion, water connate expansion, moisture expansion, rock (matrix) compaction and also modified King’s p/Z*. Author also explained the derivation of average water saturation equation that hasn’t been explained before. The author used actual data to validate the equation and the results were compared with King’s MBE results. These comparisons are used to determine the magnitude effects between these equations. The proposed material balance provides more accurate results and more options of variables which can be considered and applied as a new equation for simulation.
Advanced Technologies and Practical Guidelines for Challenging Drilling Applications
Authors: Jellison Michael , Chandler R. Brett , Sanclemente Leianne 
Published: January 2012

Abstract
Critical wells exceed the capabilities of S-135 drill strings. Drilling teams are evaluating advanced technologies to expand the drilling envelope. The paper details the development of ultra-high strength UD-165 drill pipe, provides comparisons with S- 135, Al and Ti drill pipe and provides field trials summaries. New developments are necessary to drill and complete deeper and longer-reach wells. Rotary shoulder connections offer significant advantages when coupled with high-pressure seal technology for completion pipe and intervention risers. The paper provides details on critical applications that benefited from new connection technology.
With water depths over 10,000 ft, well depths exceeding 34,000 ft, and extended-reach targets over 35,000 ft, operators are setting larger diameter and heavier casing. These casing strings require landing strings with setting capacities approaching 2.5-million pounds that extend the limits of tubular manufacturing and handling capabilities. The paper describes the technology advancements required to develop and implement an ultra-high capacity landing string system. A 6-5/8 in. drill pipe based riser system for offshore completion and intervention work has been successfully used for several years. The primary advantage of the drill pipe based system relates to the rotary shoulder connections (RSC). RSC makeup and breakout quickly, are rugged, and are superior at resisting galling and handling damage compared to casing connections that are often used for risers. The use of these intervention risers in sour gas areas has been prevented because there were no fully Sulfide Stress Cracking resistant tubular systems with RSC. This paper presents the successful result to develop and qualify an SSC resistant friction weld for intervention risers. Industry advancement has led to an increasing trend of drill stem downhole friction heating failures. The paper includes characteristics of these failures with case histories and prevention methods.
Development of New Sand Consolidation Fluid and Field Application in Shallow Gas Reservoirs
Authors: Fuller Michael J. , Gomez Ricardo A. , Gill Joel , Guimaraes Cesar , Abdurachman Ardestya Ferta , Chaloupka Vladimir , Descapria Rio 
Published: January 2012

Abstract
Extensive laboratory testing was conducted to qualify new internally catalyzed consolidation system. The tests were conducted both using sand packs and core samples and were to measure post treatment compressive strengths, regained permeabilities, rheological properties and working time of the fluid. The results of the above tests are presented as well as fluid field trials performed in shallow gas reservoirs in Tunu giant gas field located in the Mahakam river delta in the province of East Kalimantan, Indonesia.
The development of the fluid and its field application were driven by the search for an effective alternative to conventional primary sand control methods that would allow developing marginal reserves where the conventional methods might not be economical. Unconsolidated sand packs treated with the new consolidation fluid led to high compressive strengths and regained permeabilities. The tests performed on Tunu core samples showed similar improvements in unconfined compressive strength (UCS) and regained permeability. This was despite the fact that these formations can have very undesirable properties for sand consolidation as per common industry belief with high shale content up to 25 % and d50 of formation being as low as 30 μm.
Two treatments were successfully performed on shallow unconsolidated layers using coil tubing. The reservoirs produced at gas rates up to 2.8 MMscfd and 4.0 MMscfd sand free.
The new consolidation fluid was successfully qualified through a series of core flooding tests and field tests. As opposed to the comparable products currently available on the market, the fluid has low flammability rating significantly improving the safety aspects of the treatment. The treatment using this new consolidation system showed that it can provide a viable primary sand control option for developing marginal gas reserves.
Effect of Alkalis on Phase Behavior of Mixtures between Single and Double Tail Anionic Surfactants
Authors: Nguyen Ngoc T. , Bae Wisup , Dang Cuong T. , Ryoo Won , Lu Vi D. 
Published: January 2012

Abstract
Alkaline–Surfactant–Polymer (ASP) flooding is considered as a promising method for enhanced oil recovery since 1980’s. Even though the concept of ASP is straight forward, but it is a very complicated process due to complex of chemical slug. Moreover, the success of ASP is mostly demonstrated in laboratory conditions; thus, it is necessary to investigate this process in hostile reservoir conditions for achieving a wider and successful implementation. This paper presents a comprehensive evaluation of the phase behavior of ASP systems, which is successful, the key of ASP process in high temperature reservoir.
The experimental results prove that the mixtures of single tail anionic surfactant and double tail anionic surfactant would be adequately overcome the challenge of high temperature condition of reservoirs. These mixtures are also more compatible with polymer and increase the optimum salinity. In other words, the developing of new advanced surfactant mixture allows apply ASP flooding in high salinity reservoir.
Next, we examine the important role of alkaline in ASP process. Three alkalis such as including sodium carbonate, sodium metaborate, and sodium metasilicate were tested in phase behavior experiments at high temperature condition (90°C) for both synthesis (dodecane) and crude oils. The results indicate that alkaline in the ASP systems can react with some acidic components of the crude oil to form in-situ surfactant, which then would help lowering the IFT between oil and water phases. It reduces the cost of process because alkaline is cheaper than synthesis surfactant. Besides alkaline also affect on interfacial tension and phase behavior of ASP systems.
Optimal Placement of Horizontal Wells in Ultra-High Resistivity and Stacked Channel Sandstones: A Case Study from the Mangala Field, Rajasthan, Western Onshore India
Authors: Singh Amit Pal , Mishra Sumit , Tandon Rohit , Majumdar Chandan 
Published: January 2012

Abstract
The Mangala Field is the largest discovered oil field in the Barmer Basin of Rajasthan, India with a STOIIP of over 1 billion barrels contained in stacked clastic fluvial reservoirs of the Fatehgarh Formation (Compton, 2009). The Fatehgarh Formation is divided into two broad reservoir units. The upper Fatehgarh (average net to gross ~40%), consists of low sinuosity channel system sands, and the lower Fatehgarh, consists of 30m to 40m of stacked braided fluvial sands (average net to gross ~90%) having resistivity of more than 5000 ohm-m.
The flow simulation model demonstrated that horizontal wells are the best way to develop the lower Fatehgarh reservoirs. The key challenges in successful drilling of horizontal wells are the uncertainty in formation top, the position of field bounding fault, presence of gravitational collapse faults, and navigating within the ultra-high resistive reservoirs.
Offset well correlation, high resolution sampling of drill cuttings, close monitoring of grain size variations and real-time density image log analyses were used to overcome the challenge of landing the well in target reservoir zone at desired borehole inclination. After landing the well, the strategy was to build borehole angle to ~90° and geosteer within the reservoir zone. The directional resistivity tool used is sensitive to resistivity contrasts providing an early indication of non-reservoir ahead of bit. However the ultra-high resistive reservoirs limited the boundary detection capability of this tool thus reducing the reaction time to take corrective measures. The true stratigraphic position (TSP) of the wellbore was also continuously monitored using gamma ray correlation.
Eleven horizontal wells have been drilled in the Mangala field using various data integration approach. Accurate placement of wells in the best part of the reservoir, avoiding interlayer mudstones, has resulted in more than 90% reservoir contact and an average production of ~10000 bopd/well.
Natural Gas Reserves in the Middle East and India as its Market with Promising LNG Technology for Transportation
Authors: Unni Vaisakh S. 
Published: January 2012

Abstract
The share of Natural Gas in global energy consumption has grown steadily and will continue to rise for the years to come. Forecasted supply of compromised natural gas is in the year 2050 to be 115-120 x 109 toe or 13.4-14% and 228 x 209 toe of remaining ultimate reserves or 12% of the total. Of the world’s two major natural gas provinces, the largest (Russia) is being exploited, while the other (The Middle East) is still rather untapped-hence its bearing on future gas supplies. India with its radiant market and high GDP growth rate promises to provide huge customer base for natural gas industry. Study on natural gas market in India is made in this paper. The paper gives a look into the opportunities arising out of the policy initiatives taken by the Government of India which are welcoming, though skewed development of the market due to regulated market pricing may be deterrent.
Liquefied Natural Gas (LNG) technology is used for natural gas transportation for long distances. The development and implementation of technologies in this field have led to significant growth in worldwide LNG business. Lessons learned in design, implementation and execution of large LNG carriers(trains and ships), as well as overall changes of LNG liquefaction trains in last twenty-five years, have been key to evolving design of LNG value chain.
This paper concentrates on natural gas reserves of Middle East and its potential of becoming the main supplier for the future, natural gas market in India, potential and limitation of gas supply scenario in India and LNG technology for transportation and its challenges in future.
Two-Phase Flow Choke Performance in High Rate Gas Condensate Wells
Authors: Nasriani Hamid Reza , Kalantariasl Azim 
Published: January 2012

Abstract
Multiphase flow occurs in almost all producing oil and gas/condensate wells. Wellhead chokes are special equipment that widely used in the petroleum industry to control flow rate, to maintain well allowable, to protect surface equipments, to prevent water and gas coning and to provide the necessary backpressure to reservoir to avoid formation damage from excessive drawdown. Accurate modeling of choke performance and selection of optimum choke size is vitally important for a petroleum engineer in production from reservoirs due to high sensitivity of oil and gas production to choke size. Two main approaches have been proposed for prediction of multiphase flow through chokes can be classified as either analytical or empirical and majority of correlations were developed for critical flow conditions.
Although most of the correlations available to petroleum engineers are for critical flow but in lots of high rate gas/condensate wells subcritical flow occurs in large choke sizes.There is no empirical correlation for wellhead choke performance under subcritical condition for high rate gas condensate wells, especially in large choke sizes. The first aim of this paper is to develop a new simple empirical Gilbert type correlation for high rate gas condensate wells under subcritical flow in large choke sizes (40/64 in. to 192/64 in.) using non-linear regression analysis based on 61 field data points of 15 wells from ten different fields. The second is to extend the work of Al-Attar for high rate gas condensate wells flowing through large choke size under subcritical flow conditions and check the applicability and advantages.Finally, statistical comparison between these two approaches is done with different error parameters.
Flow Model Selection for Production Logging Interpretation of Gas Wells
Authors: Jongkittinarukorn Kittiphong , Kerr Robert 
Published: January 2012

Abstract
Water production from gas wells is a major issue in the Gulf of Thailand. Production Logging (PL) is the main way to try to discover the water source and hence shut it off. Sometimes there are clear indications of water entry such as density increases and holdup sensors showing more water entering the flow. For many wells, though, there is no clear water entry and the water rate is a result of the calculations that are very dependent on slippage velocities derived from various flow models. Emeraude from "Kappa Engineering" (Kappa from now on) allows the use of any one of ten different models to derive the slippage from. The problem is that there is no clear way to decide which model is best and the effect on the results of using different models is significant, often moving the water split between zones.
This study uses the surface rates to compare with the rates calculated from the PL data using each of the ten different models. Some 300 PL cases are used to allow a statistical analysis to determine the most precise, accurate with minimum error, models. The best three from this statistical approach go forward to a Discriminant Analysis where the critical factors which governed when a model works best are ascertained. Then the Fischer Discriminant Functions could be calculated for these three models so that this could be used to select which model to use for future Production Log Analysis.
The study comes up with a systematic way to select which model to use. It found the models that were not typically being used in the past should be used so this was quite a big change. The logic was applied to some past PL examples and the recommended models are found to give results more consistent with known shut-off's that the original analysis had done. The method seems to have value and should improve the effectiveness of future water shut-off actions though the number of wells the study has been applied to is small and time will allow further verification of the technique.
Research on Transport of Cuttings in Gas Drilling Horizontal Well and Cuttings Falling-prevent Joint Development
Authors: Zhu Xiaohua , Liu Shaohu , Tong Hua 
Published: January 2012

Abstract
Field experience has shown that inefficient transport of cuttings is a key factor for excessive torque & drag during gas drilling of horizontal well. Therefor, the focus on the transport of cuttings or the hole cleaning operation during gas drilling is essential. The cuttings tend to deposit themselves due to gravity's action, so forming a bed in the annular space between drill string and casing. If the cuttings bed isn't cleaned in time, it may cause the sticking accident, fluid flow interruption, drill string and casing erosion, finally it leads to the economic loss. Transport mechanism of cuttings during gas drilling has been studied based on gas and solid two-phase flow dynamics theory in different annular section of horizontal wellbore. The involved annular sections includes normal well, eccentric annular section formed by the drill string lying on the underground level of casing, diameter enlargement annular section. This paper presents a new tool for improving the cuttings transport efficiency during gas drilling. This tool is named cuttings falling-prevent joint (CFPJ) which has a split-flow nozzle. The structural parameters of split-flow nozzle, such as opening gradient, opening azimuth and nozzle linetype, which influence the CFPJ's sweeping and carrying capability, were studied using computational fluid dynamics technology. The study shows that changing CFPJ's structure parameters can adjust the radial, tangential and axial sweeping & carrying capability, and finally the recommended CFPJs can solve cuttings' falling problem in gas drilling horizontal well.
Produced Water Treatment Improvements in Facing Indonesian Government Regulation on Onshore Disposed Waste Water
Authors: Trusmiyadi Yadi , Kurniawan Farid , Fitria Rila , Elias Esther , Muhyinsyah Ahyat 
Published: January 2012

Abstract
Produced water is the largest byproduct generated by the oil and gas industry. Water injection, considered as the best answer for produced water disposal, is not always possible due to reservoir constraints. The secondary produced water treatment facility in Mutiara Central Plant, VICO Indonesia, is a phenol treatment plant (PTP). It is processing approximately 8000 BPD produced water before being released to the Dondang River. A biologically activated sludge process is applied to reduce the pollutant content so the disposed water complies with onshore waste water disposal regulation for oil and gas production industry on Permen LH 04/2007. The process reduces chemical oxygen demand (COD), ammonia, phenol, sulfide, and oil and grease content in the produced water. Frequently since 2008, high COD and ammonia content above the regulated thresholds (200 mg/L for COD and 5 mg/L for ammonia) in disposed produced water has been observed.
A field investigation was conducted to collect integrated data of recent process parameters. The field data were then compared to design conditions, industrial practices, and literature to a determine root cause tree. In addition, a feed batch activated sludge pilot was constructed and study on inlet COD source was performed for comprehensive study.
The field investigation revealed that root causes limiting the phenol treatment performance were higher oil content and COD in the inlet stream, highly fluctuating inlet debit, lack of oxygen supply, and inadequately designed and maintained clarifier and return sludge system. Following minor mitigation actions in January 2010 such as chemical process optimization, adjusting nutrient doses, adding sugar, fresh microbes, and routine maintenance, the effluent quality data has improved to just bellow the threshold. Six major improvements were proposed to improve PTP performance and effluent quality; e.g. repair pre-heater, construct new secondary clarifier, replace existing return sludge pump with proper capacity, install three more aerators, utilize K1 as equalization pond, and repair existing drying bed. VICO Indonesia has committed to commissioning the first four recommendations by the end of 2011.
Field Development and Water Flood Management in Complex Clastic Field in Oman – Case Study
Authors: Al-Harrasi A. , Rathore Y. , Kumar J. , Maharbi A. , Shukaili S. , Al-Subhi H. , Al-Salhi M. 
Published: January 2012

Abstract
X-field located in the west Central Oman is in a mature stage of development from the Permian Gharif formation reservoirs. These stacked reservoirs have been historically produced commingled since 1984 with natural depletion until 1998. Since then the field is under water flood. Produced water is mainly re-injected and gas is used for gas lift and the rest is liquefied and exported.
The need for effective pressure maintenance was recognised only when the field pressure depleted under primary development and GOR increased. The FDP proposes peripheral injection in the NW due to better sand connectivity and pattern injection in areas of low sand connectivity. The artificial lift mechanisms are a mix of ESP and Gas lifted wells.
Water flood management is highly challenging in this complex and heterogeneous reservoir. Water front conformance causes challenges with impact on vertical and horizontal efficiencies. The reservoir sands that are not supported by water injection have issues with wax and scale deposition in the producers. The field separation facilities are constrained by gas handling design capacity. Future challenges are expected with well and flow line integrity issue due to the gaining facilities.
Despite all challenges, the water flood is actively supporting production in most areas. Surveillance is the key to managing this complex waterflood. Additional drilling is used for further development with well and reservoir management practices to target by-passed oil, improve water flood efficiency and increase oil production. The surface and sub surface integrated system optimization is helping stabilize the system and delivering improved oil production and gas export with ongoing implementation of new artificial lift strategy.
This paper documents a case history of waterflood management in X-field and the challenges that have to be overcome.