bluuebunny/crossref_metadata_2025_split huggingface dataset:
The First Subsea Completion by an Operator in KN Field, Offshore Malaysia
Authors: Mahadi K. , M. Nizam M. Izzat , Ogbonna C. , Jadid M.B. 
Published: March 2015

Abstract
The KN field in KM cluster is located approximately 200km offshore, at water depths ranging from 59–102m. The field is part of the KM Cluster Integrated Development Plan, where the primary objective for KN field development is to recover the reserve from fringing pinnacle reef carbonate reservoir, expected to be achieved through two deviated 7-inch open-hole monobore subsea wells. KN field is expected to deliver around 200 to 300 MMSCF/day to the LNG plant to help relieve an anticipated gas shortage, as such failure to deliver the target would definitely upset the gas supply.
Besides cost savings, the shallow water subsea development concept is part of the company's long-term vision to train its staff with new technologies and prepare them with basic guidelines for future development especially in deepwater. Although this is already considered a norm in other parts of the world, subsea completion is relatively a new experience in the company operation.
The open-hole sections were drilled using Potassium/Sodium formate fluids with calcium carbonate as weighting and bridging agent and later the wells were completed with Cessium formate. Based on extensive laboratory test, it was found that this formate fluids allow for thin mud filter cake that can be remove effectively with differential pressure alone, excluding the need for filter cake breaker. High rate acidizing was planned as contingency should the wells failed to deliver the targeted well deliverabilities. Based on transient simulation using OLGA, high rate clean-up were planned to ensure effective filter cake break-up, removing debris and confirming the technical potential of the wells. With high rate, the duration of well clean-up is shorter and effective thus saving rig time.
This paper details the planning and execution towards achieving the successful project of KN field, the 1st subsea development in the company
Natural Gas Vehicles Will Develop Greatly in China
Authors: Wang Zugang , Lv Jianzhong , Rao Libo , Yang Yan , Gao Hui 
Published: March 2015

Abstract
Increasingly abundant natural gas is under consideration as a replacement for fuel in transportation because of the high oil prices. The number of natural gas vehicles (NGV) in China is over 1 million. The use of compressed natural gas (CNG) is growing in short-haul urban fleets, and the liquefied natural gas (LNG) is the best alternative for long distance passenger and cargo vehicles which represent most of truck diesel demand. In this paper, we analyze the driving force of NGV to make inroads and the challenges of development, and draw a conclusion that NGV with the supporting industry in China will develop rapidly in the coming years.
The great development of China automotive industry leads to the tremendous increase of vehicles in recent years. The automobile emission coming from the increasing consumption of gasoline and diesel has become an important source of air pollution and climate change. Natural gas (NG), a kind of clean energy, which can greatly reduce air pollution and promote the low carbon economy, has drawn more and more attention all over the world. Natural gas vehicle (NGV) with great prospect grows rapidly in China because of the advantages of cleanliness, efficiency, economy and security.
Real-Time Modeling-While-Drilling for Optimized Geosteering and Enhanced Horizontal Well Placement in Thin and Complex Reservoirs
Authors: Saikia Kalyan 
Published: March 2015

Abstract
With the growing demand for hydrocarbons, enhanced horizontal well placement resulting from optimized geosteering is becoming increasingly important. Optimal geosteering is accomplished by selecting the proper combination of logging-while-drilling (LWD) and measurement-while-drilling (MWD) tools as data acquired from these tools are directly deployed for interpreting and monitoring the well. In fact, achieving maximum success in geosteering is only possible through real-time interpretation and modeling of MWD/LWD data while drilling. Additionally, real-time 3D model updates while drilling deliver maximum guidance and assistance in geosteering to the proper well position by predicting the geology ahead of the bit. As a result, well placement risk is reduced because the associated uncertainty is quantified.
A meaningful modeling-while-drilling campaign is greatly dependent on three main factors:uninterrupted real-time data transmissionuse of appropriate software modelingselecting adequate modeling techniques
Log modeling and 3D geocellular property modeling-while-drilling are two widely used variants of modeling-while-drilling. Log modeling generates a series of modeled log responses along the planned well path considering the offset well information. Whereas 3D geocellular property modeling-while-drilling is comprised of two steps i.e., fine layering and gridding (FLG) followed by property simulation and regular model updates with new real-time log and well pick information. Each of these techniques requires MWD/LWD data, well picks, and surface grid information as input and uses different algorithms to complete the modeling. But, to obtain effective results both the simplicity and the adequacy of the modeling technique play a very important role in the procedure.
In this paper, examples from two complex and challenging wells are described in terms of the advantages and benefits of using log modeling and 3D geocellular property modeling-while-drilling. It is concluded that modeling-while-drilling is extremely useful in optimizing horizontal well paths, maximizing well productivity, and reducing rig lost time. In addition, it allows professionals from different disciplines, to work together in an integrated manner for improved well placement.
Thru-Tubing Gravel Pack Experiences in Malaysia
Authors: Saebi Shahryar , Rivero C. Maria Elba , Gornescu Bogdan Claudiu , Veysalli Elshan , Sepulveda Willem , Zaini Muhamad Zaki , Kikuchi Masato , Tsangueu Barbara 
Published: March 2015

Abstract
Thru-Tubing Gravel Pack Techniques have been receiving an increasing attention in the recent years as a cost effective solution for sand producing wells with either failed gravel packs or zones that started sand production at a later stage during the life of the well especially in mature fields with marginal reserves as the conventional workover operations are usually not economically justified. In most cases, because of the marginal reserves available and the high cost of mobilizing a workover rig to perform a conventional gravel pack completion, the operators chose to recomplete the wells using rigless techniques. This paper covers some of the applications that the gravel pack has been placed through the existing completion tubing. It will review the successful installations performed in Malaysia, including the engineering design, completion operations, real-time decisions, and results. The proposed solutions and the lessons learned in these projects could change the sandface completion practices for sand prone wells that are either shut-in or not producing up to their potential in the mature fields.
From Well-Driven Seismic Data Processing to Seismic Reservoir Characterisation by 3D Seismic Imaging of Ordovician Karst Caves in West China
Authors: Tian Jun , Lei Xue , Cai Zhenzhong , Yuan Yuchun , Han Xiaoli , Tong Yanming , Miao Qing 
Published: March 2015

Summary
Accurate idenfication of oil bearing caves within Ordovician Karst carbonate formation utilizing conventional low-fold 3-D seismic data has been a rigorous challenge. We executed a well-driven seismic data processing workflow which includes prestack time migration and reservoir characterization by prestack simultaneous AVO (amplitude variation with offset) inversion for estimation of physical rock properties and postmigration multi-attribute analysis. Delineation of oil bearing caves is achieved by the interpretation of the inverted attributes, postmigration attributes, and attenuation factor analysis with angle stacks. As a result of this work, two highly productive wells were drilled which and successfully reached the target of oil bearing caves.

Background and challenges
The production is mainly from the epikarst (the uppermost weathered zone) and the caves whose scales vary from tens of centimeters to over ten meters. Drilling experience demonstrates coexistence of oil bearing, oil and water bearing, water bearing, and shale-filled caves. High drilling success rate is associated with epikarst targets while high production rate is associated with oil bearing cave targets (Fangjian Xue, 2010) in the area. High-production rate is the primary objective -for our study area.
The 3-D survey includes three blocks overlapping conventional 3-D data sets during the last fifteen years with different parameters. Normal fold in the two blocks is 24 and 72 in the third block. Based on the spectral analysis of the raw data, recoverable signal band at the target level is about 8–40 Hz in one block and 6–45 Hz in the other two blocks. The legacy seismic processing datasets show poor image with very low resolution and fair signal to noise (S/N) ratio at the target interval. Additional available data include several vertical seismic profiles (VSP), check shots and complete log measurements from dozens of wells, five dipole sonic measurements for the Ordovician and the overlain partly clastics carboniferous sections, and various well test data.
Various processing challenges (Wang et al., 2011) associated with poor acquisition and complex subsurface geology (Feng et al., 2011) affect the accuracy of the seismic image. Nevertheless, there are no significant lateral velocity variations above the target level that would require prestack depth migration. Main challenges in reprocessing the 3-D seismic data sets are (1) ensuring consistency of seismic amplitude, frequency and phase in merging the three survey data sets, (2) enhancing S/N ratio, (3) improving seismic image and relative amplitude preservation, and 4) improving seismic resolution. Additional challenges are AVO inversion and identification of fluid properties in the caves.
Air Quality Control Initiatives
Authors: Al-Ameer Hassan , Al-Alawi Hijji , Al-Balawi Abdulrahman 
Published: March 2015

Abstract
The intent of this paper is to share the successful operational story in controlling air quality at Saudi Aramco, Uthmaniyah Gas Plant energy efficiency program. Obligation with environmental regulations becomes, nowadays a challenge to the industry fields. UGP was committed to comply with the government and Saudi Aramco environmental standards by implementing several ideas to enhance the air quality. The first idea is Wet Hydrocarbon Recovery System which eliminates the continuous use of burn pit for Wet HC from eth blow down system and re-injects back into the HC crude lines. Beside this modification will allow UGP to comply with environmental regulations by eliminating the continuous flaring of Wet HC, it will reserve the life time of the burn pits and protect the ground water aquifer from contaminations. The second idea is upgrading the Sulfur units from CLAUS process to SUPERCLAUS process to achieve 98.7 % of sulfur recovery and reduce SO2 emissions by installing new condenser with coalser and changing the type of converters' catalysts. All of these modifications resulted in decreasing the SO2 emissions by 25 %. The third idea is Flare Gas Recovery System which the system will recover the flare gases from the flare headers and then compressed the gas to 260 psig for feeding the plant low pressure sour gas header. The ultimate goal of this idea is to avoid visible smoke and flame from flaring system and comply with environmental regulations. The system is very attractive not only reducing flares' emissions but also it would recover the valuable gases being wasted to the flare stack. This paper discusses, in details, all ideas objectives, processes and benefits.
Comprehensive Evaluation of Hull Form Design for an Icebreaking Vessel in the Kashagan Field
Authors: Putorti E. , Cijan A. , Trincas G. 
Published: March 2015

Abstract
Both the ice-going and structural capability were analyzed in a comprehensive way for the IBEEV, a small-sized, shallow draft icebreaker vessel, equipped with two pulling type thrusters and operated by AGIP KCO in the Kazakhstan sector of the Northern Caspian Sea. To this end, a number of activities involving Navalprogetti and Krylov Shipbuilding Research Institute was implemented, encompassing analytical and numerical computations, model tests in open water, shallow water and ice towing tanks and full-scale measurements in ice.
To evaluate performance of IBEEV all year long, the power-speed relationship was estimated in both open water and ice conditions. As regards open water, the ultra-shallow water depth showed dramatic influence on the vessel's resistance, hull-propeller interaction, and bollard pull capability. The performance in ice was analyzed through analytical and numerical models, experimental model testing and full-scale trials. The full-scale campaigns allowed determination of (i) maximum ice-breaking capability of the vessel in level ice, (ii) gyration radii of the vessel running both ahead and astern, and (iii) capability of channel break out for the vessel.
Finally, to determine service restrictions of IBEEV based on hull ice strength a number of strength criteria was identified, namely, not-exceed the service line load under normal operation; value of the ultimate strength of ice strengthening structures, and damage limits to avoid water leakage. To this end, theoretical analyses were carried out by means of the hydrodynamic model of the vessel impact against the ice. The numerical results were validated by full-scale experimental results and confirmed that IBEEV complies with given constraints.
The Eagle Ford Shale Play, South Texas: Regional Variations in Fluid Types, Hydrocarbon Production and Reservoir Properties
Authors: Tian Yao , Ayers Walter B. , McCain William D. 
Published: March 2015

Abstract
The Eagle Ford Shale is one of the most active U.S. shale plays; it produces oil, gas condensate, and dry gas. To better understand the regional and vertical variations of reservoir properties and their effects on fluid types and well performance, we conducted an integrated, regional study using production and well log data.
Maps of the average gas-oil ratio (GOR) of the first three production months identified four fluid regions, including black oil, volatile oil, gas condensate, and dry gas regions. Maximum oil production occurs in Karnes County, where first-month oil production of most wells exceeds 5,000 barrels (bbl). The most productive gas region is between the Stuart City and Sligo Shelf Margins, where first-month gas production of most wells exceeds 60 million cubic feet (MMcf).
Eagle Ford Shale petrophysical properties were analyzed in individual wells and were mapped to clarify the regionally variations of Eagle Ford Shale reservoir properties and their controls on fluid types and well performance. In comparison to the upper Eagle Ford, the lower Eagle Ford Shale has high gamma ray, high resistivity, low density, and long transit time values; we infer that the lower Eagle Ford shale has higher total organic carbon and lower carbonate content than the upper Eagle Ford Shale.
Integration of production and geological data shows that thermal maturity and structural setting of the Eagle Ford Shale strongly influence fluid types and production rates. Plots of GOR vs. time for individual wells were constant in different reservoir fluids. Results of this study clarify causes of vertical and lateral heterogeneity in the Eagle Ford shale and the regional extents of fluid types. Understanding of the reservoir property differences between upper and lower Eagle Ford Shale should assist with optimizing completion design and stimulation strategies. The results may be applicable to similar developing shale plays.
Saudi Arabia's Value Adding, Record-Breaking Coiled Tubing Interventions Travel Farther than Mount Everest
Authors: Arukhe James , Ghamdi Saleh , Dhufairi Mubarak , Duthie Laurie , Almari Abdulrahman , Elsherif Tamer , Othman Bassem 
Published: March 2015

Abstract
Coiled tubing (CT) deployment with hydraulic tractors in extended reach open hole horizontal wellbores has been a challenging technology in the oil industry for reasons ranging from wellbore conditions like washouts to restrictions imposed by the completions. Consequently, delivering cost-effective well interventions solutions, for example through acid treatments to enhance well performance, or production logging to understand inflow profiles in deep injector wells have been particularly demanding.
The authors examine how rigorous pre-job planning and teamwork were enablers to realizing the deepest CT reach at 30,365 ft (9.26 km) measured depth (+1,336 ft longer than the height of Mount Everest at 29,029 ft) in a mega-reach open hole horizontal power injector well using a CT tractor to facilitate effective stimulation in Saudi Arabia. Among the operational challenges overcome in the well was tar accumulation on the tool string including the tractor during the well intervention. The tar accumulation on the string was part of a laterally extensive high viscosity tar layer between the overlaying oil column and aquifer. From a reservoir standpoint the tar layer posed a challenge in assuring sufficient aquifer support to the oil producers because of their partial sealing nature.
The author discusses how the challenges imposed by tar restrictions and other operational concerns were overcome to ensure successful acidizing. The wells showed a marked injectivity improvement from acid stimulation thus demonstrating the benefit of informed decisions from real time fiber optic distributed temperature sensing (DTS) in fluid placement. The tractor traversed a difficult down hole environment overcoming washouts and H2S environments within the wellbore conveying the CT for an industry record tractor reach for open hole CT intervention at 30,365 ft. Concrete applications of these outcomes include the ability to employ real time information for cost-effective stimulation and real time log acquisition from extended reach open hole horizontal wells.
Overview of Key Zonal Water Injection Technologies in China
Authors: He Liu , Yang Gao , Fuchao Sun , Fangchao Liu , Xuebing Cui , Qinghai Yang 
Published: March 2015

Abstract
Separated layer water injection is the important technology to realize the oilfield long-term high and stable yield. Through continuous researches and technological innovations, series separated layer water injection technologies have been developed to meet the technology needs of the different oilfield development stages to solve the interlayer problems, achieve high efficient of water injection, and solve the bottlenecks in different water injection stages. Oilfield water injection gradually comes to separated layer water injection, separate minilayer water injection and fine water injection stages from the early stage commingled water injection. Water injection technologies have experienced five main stages: commingled water injection, concentric water injection, eccentric water injection, integrated water injection and intelligent water injection. Every stage of the technology has played an important role for the oil field development. With the development of the separated layer water injection strings, downhole tools and supporting testing and conditioning technologies for the separated layer water injection, separated layer water injection technology has played an important role in evenly exploiting each reservoir and improving the producing extent of the bad reservoir. This technology has realized zonal production of the multilayer reservoir, and provided the technical support for keeping the oil production from the water flooding taking up more than 80% of the total.

Introduction
Water injection is the base of oilfield development. Separated layer water injection technique has play an important role in realizing the oilfield long-term high and stable yield and improving oil recovery. And it is also the inevitable choice to maintain oil production rate for water flooding reservoirs with high water cut. In order to satisfy the needs of different oilfield development stage, a series of water injection technologies have established to handle conflicts between layers and realize water injection effectively. The water injection strings have experienced stationary separated layer water injection, eccentric water injection, concentric integrated water injection and eccentric separated layer water injection from the early stage commingled water injection. Supporting testing and conditioning technologies for the separated layer water injection have come to cable testing and conditioning, ground control downhole water choke stepless regulation from steel wire free dropping and fishing technology. After 60 years development of separated water injection and supporting testing and conditioning technology, the separated layer water injection technology has come to "eccentric separated layer water injection + cable testing and conditioning", which has improved the recovery ratio of the water injection wells as a main water injection technology in China.
Dynamic Characterisation of a Chinese Fluvial Tight Gas Reservoir
Authors: Boutaud de la Combe Jean-Luc , Jaffrezic Vincent , Loizel Herve 
Published: March 2015

Abstract
South Sulige block, located in the Ordos Basin in China, is classified as Tight Gas Reservoirs with permeability ranging from 0.01 md to 2 md and porosity rarely exceeding 10%. Potential gas production intervals were identified in the Shihezi Formation and Shanxi Formation.
Four of the existing hydraulically fractured wells, were re-tested by Total.
Total drilled four new wells on this block, stimulated them with hydraulic fractures and performed extensive tests.
The main objectives of well testing were:To reduce the uncertainties on well productivity, mainly permeability and skin.To characterize reservoir extension: no flow boundaries, channel width.To estimate the dynamic connected volumes which are linked to the extent and interconnectivity (amalgamation) of the sand bodies (fluvial sand bars/channel width).
Extended dual build-up tests were designed (from 8 to 18 months) ended by a long duration build-up (from 3 to 10 months) to characterize well productivity and connectivity. As no signature of radial flow, appeared on derivatives, permeability-thickness values were strongly uncertain. Dual build-up tests were designed to allow us to reduce uncertainties on permeability-thickness product. The test analyses have revealed the presence of channel margins to match transient depletion between build-ups.
The results of these extended tests highlighted that channel widths determined by pressure transient analysis were much smaller than expected, compared to outcrop description, except for one well (Y3). This implies that internal heterogeneities, not visible on outcrops, play a major role in the well drainage. These results have to be taken into account to optimize the development scheme, combining the good productivity in the Y3 area and more standard well behaviour elsewhere.