bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated EOR Approach via Application and Installation of Distributed Fiber-Optic Technology
Authors: Chin M. W. S. , Woon G. C. , Wood K. , Gorgi B. 
Published: March 2016

Abstract
This paper describes the successful permanent installation of the first distributed-temperature-sensing (DTS) system in an enhanced oil recovery (EOR) field and processes used in the workover completion. Successful installation was achieved through a combination of effective planning and field execution before and during the completion period. This paper also describes engineering challenges and unique solutions applied to overcome them. The DTS data analysis techniques used for the initial injectivity test are briefly discussed.
The full-field offshore application of an immiscible water-alternating-gas (WAG) process involves simultaneous injection of water and gas to the reservoir formation. Using a sweeping mechanism, water displaces hydrocarbon downwards while gas displaces hydrocarbon upwards, thereby, achieving an efficient microscopic and macroscopic sweep. Thus, the requirement for a technology that can provide both injection profiling and geothermal delineation is essential. DTS surveillance is not a new technology; however, its application in production-optimization process is new and provides insight on sweep efficiency. Higher lift costs and lower oil prices make it even more critical that installations are trouble-free and executed on time.
The number of EOR projects has been growing in Malaysia in recent years. Malaysia's first large-scale EOR project was recently completed offshore Terengganu, representing an investment by a local profit sharing company (PSC) and successful collaboration with a service company for execution. It is a priority that specific criteria are set to ensure the execution process does not only provide required reliability but also complies with health, safety, and environmental (HSE) standards. Thereby, as a continuous and progressive step, project management is of utmost importance in ensuring strategic planning is unique and reliable throughout the duration of the project, specifically for each respective operator.
Challenging Well Completion and Intervention Technique for Multizone Offshore Brown Field Well
Authors: Chandak K. , Anand S. , Patil B. , Sarma P J , Koshy N. , Vadapally S. , Nayak J. 
Published: March 2016

Abstract
XX-1 is a newly drilled well in Ravva field in eastern coast of India deviated to 70 deg and completed with a 6? Open-hole section. The initial completion plan for the sand prone well was to complete with stand alone screens for a single pay zone. During drilling, additional pay zones were encountered which necessitated completing the well with zonal selectivity using sand-screens with SSD. Selective completion required thru tubing intervention to operate the SSDs and produce selectively.
Due to high deviation, intervening with slick line was very challenging whereas coiled tubing operations had its own limitations which are discussed in the paper. Hence it was decided to use Electro-hydraulic stroking tool along with motorable tool sections to convey tools in the high angle well.
While shifting SSDs with hydraulic stroking tool, frequent held ups and stuck points were observed across all SSDs which made it difficult to confirm shifting key location with reference to SSD sleeve profile and hence confirm SSD opening. This resulted in unsuccessful attempts and tool failures. A detailed analysis was carried out to ascertain the probable cause of multiple held ups within the screen SSDs and to find out other ways to shift the sleeve. Trouble shooting was performed by combining video recording of shifting attempts at surface in an unused screen section along with engineering drawings of the screen. Based on trouble shooting results, shifting procedures were modified accordingly to precisely engage the shifting tool with SSD profile and SSDs were successfully opened. The stroker system also proved useful in opening a circulation SSD which enabled the well to be brought on line.
This paper describes operational difficulties encountered and innovative ideas implemented to shift SSDs. It also reviews job planning, trouble shooting and execution, as well as reports the lessons learnt to derive best practices for future similar operations.
Cement Isolation Packer - An Economic Method of Accessing Bypassed Marginal Reserves in Offshore Brown Field
Authors: Koshy N. S. , Anand S. , Patil B. , Singhal A. , Chandak K. B. , Vadapally S. V. , Sabharwal V. 
Published: March 2016

Abstract
Ravva is a mature field located offshore east coast of India with over 20 years of production history from Middle Miocene sandstone reservoirs. During the development phase of the field, Late Miocene (LM) sands were intersected in few wells at shallow depths. Due to the presence of more promising and critical zones below, these sands were not completed and fell above the production packer and behind the production casing. The marginal reserves in these sands did not justify workover operation to complete it. Rigless options were studied and a shut-in well was selected for implementation.
In order to safely complete and access the bypassed shallow sands, a vessel based pumping operation was planned to place a cement packer in the tubing – casing annulus. The slurry was circulated into the production casing/tubing annulus through a circulation SSD installed above the production packer.The cement packer was thus placed across the zone of interest. Designing of the cement slurry was based on reservoir parameters and the setting time was optimized to prevent reversing of the slurry back into the tubing. The cement mix had a bonding agent to exhibit good metal-cement bonding providing prolonged endurance of the cement with the capability of holding the expected pressure differential. The cement packer emulated a production packer providing zonal isolation for the new completion.
Size of the platform precluded spotting of the complete Coil Tubing spread on the platform. High cost prohibited catenary coil tubing operations. As an alternative, the pump spread was placed on a DP vessel and the coil tubing unit was spotted on the platform. A high pressure hose running up from the vessel to a standpipe on the main deck of the platform formed the main conduit for fluids being pumped from the vessel into the CT or wells. Onsite mixing of the cement slurry on the vessel required detailed planning and execution. The well was activated & tested at rates of 1500 bopd with no integrity concerns till date.
This paper will emphasize on the operational procedure and challenges of successfully completing the zone and bringing the shut-in well online. The execution of this operation was done at 1/10th of the cost of a rig based workover. This has also opened up new opportunities to access similar bypassed reserves resulting in incremental production from reservoirs which would have otherwise been left untapped.
A Study of a Novel Inter Pipe Coating Material for Paraffin Wax Deposition Control and Comparison of the Results with Current Mitigation Technique in Oil and Gas Industry
Authors: Rashidi M. , Mombekov B. , Marhamati M. 
Published: March 2016

AbstractHydrocarbon liquid consists of a range of components with different physico-chemistry characterization. Sometimes there are heavy component with crude oil such as asphaltene, naphthenic and paraffinic wax components and etc. Deposition of wax in both onshore and offshore pipelines presents a costly problem in the production and transportation of oil. There are several parameters contributing to wax deposition in multiphase crude oil flow, e.g. pressure drop, flow rate, pipe internal body surface roughness, surface energy of the pipe, liquid wetting of pipe wall as well as temperature difference between fluid and surroundings [1,2]. Application of internal coating of subsea pipelines can reduce wax deposition. The aim of the present work is to experimentally study the wax deposition in Malaysian waxy crude oil, where the data set studied was gathered from several experiments. Most of the methods can be used to remove the paraffinic wax deposition after it occurs. However, insulation systems yielded in better performance as it was found to help in the prevention of heat loss and solid deposition during flow conditionsThis study utilized flow loop apparatus. This paper compared the wax deposition behaviour with temperature, roughness and flow rate within the tested pipes [Polyvinyl Chloride (PVC), Ethylene - TetraFluoroEthylene (ETFE), and steel as a reference material]. Moreover, the prevention of temperature loss from liquid to surrounding and corrosion control significantly affects pressure drop across the pipeline [3]. The conducted experiments concluded that ETFE had a better effect on the paraffin wax deposition control. Moreover, ETFE as a novel polymer based coating material was economically feasible to be utilized in the oil and gas downstream and upstream systems exposed to wax deposition.
Improved Casing Integrity Evaluation Enables Multiple Strings Metal-Loss Profilling in Aging Wells
Authors: Zaini A. Bin Ahmad , Ali A. Md , Razak M. Abdul , Samaile E. , Busaidy Adil , Wa Wee Wei 
Published: March 2016

Abstract
BNX field is a mature oil field with complex wells targeting multiple reservoirs across the field. The introduction of an Enhanced Oil Recovery (EOR) project has set a new challenge on determining the integrity of aging wells. In the past, comprehensive downhole casing integrity testing was rarely done with the exception of conventional pressure integrity checks. Such methods may have limited effectiveness in analyzing wells with multiple strings and complex completion configuration, and cannot precisely locate or quantify the magnitude of metal loss. Convention is to run a Multi-fingered caliper inspection tool to evaluate the single tubing inner metal loss, but again this has limited value as it could not measure tubing thickness or more importantly the condition of the casing behind the tubing. A solution was needed that could allow the evaluation of tubing and casing to be done offline and simutaniously.
An innovative approach with a combination of slim-hole ultrasonic borehole imaging tool and electromagnetic imaging tool is deployed to provide a new insight in the casing integrity evaluation in the field of study. The idea being that the borehole imager would accurately describe the tubing string while the electromagnetic tool would describe the total metal, both tubing and casing, subtracting the tubing thickness from the total metal measured would then leave an accurate measurement of the casing thickness. Three well candidates were identified, each well was planned for a sidetrack, but before moving a rig onto these old wells the team wanted to know if the 9 5/8? casing was in good enough condition to use. And for the first time, the thickness of multiples strings up to 13.375 inch casing was evaluated simultaneously utilizing a low frequency electromagnetic and a high resolution ultrasonic measurement. The ultrasonic tool provides comprehensive metal loss evaluation for inner most string while the electromagnetic tool provided the total metal thickness of both strings. The combined interpretation of these two through-tubing evaluation outputs provides a viable technique to evaluate metal loss profile for first two strings under study without the need to pull the inner most string. The overall casing evaluation operation is further optimized by the maiden deployment of an e-line light weight unit.
The successful application of this newly integrated casing integrity evaluation technology has greatly reduced the intervention related risks, costs and time. The case study presented will serve as the critical pilot to extend the same workflow to other wells across the field. In addition it paves the way for the next generaltion of EM and slim ultrasonic tools discussed at the end of the paper.
A Systematic Dynamic Characterization Method for Abnormally High-Pressured Gas Reservoirs
Authors: Li Yong , Li Baozhu , Zhang Jing , Xia Jing , Jiao Yuwei , Peng Hui , Xiao Xiangjiao , Wang Hongfeng 
Published: March 2016

AbstractCompared to the normal clastic gas reservoirs, abnormally high-pressured gas reservoirs in China have some distinctive characteristics: deeper buried depth, higher productivity of single well, more heterogeneous formation, stress sensitive rock and more difficult to develop. It's not feasible to identify and characterize this kind of reservoirs only based on one method. This paper presents a systematic method of dynamic characterization for abnormally high-pressured gas reservoirs, which mainly involves material balance analysis, rate transient analysis and well test interpretation in combination with geological analysis results.This paper firstly establishes a new equation suitable for abnormally high-pressured gas reservoir with aquifer support. Then the systematic method mainly using material balance analysis, rate transient analysis and well test analysis are detailed presented. The systematic method can fully integrate the long-term low accuracy data of dynamic production and short-term high-precision data of transient well testing. And the three methods can be combined and constrained to each other, in order to correctly evaluate well and reservoir properties, such as the formation permeability, well skin, oil drainage radius, gas in place and so on. Also the methods have the diagnostic function to aquifer influx, which can predict water breakthrough in gas wells. Furthermore, based on the evaluation results, the "dynamic numeric model" can be built and all three methods can be used to predict the performance of the wells.M1 abnormally pressured gas filed in China is taken as an example to elaborate the details of this method. The calculated well drainage radius shows that some well production is interfered by surrounding wells, while some wells are not. Also transmissibility of faults are evaluated and used in the numerical model building. Based on the evaluated properties, "dynamic numerical model" of the gas reservoir are established and applied to the well performance prediction, which are validated by actual gas well performance. It can be seen that these three methods are fully integrated and constrained with each other, which can generate a reliable result.This systematic technique has been successfully applied to "M1 gas field Adjustment and Optimization Plan", which provides a reliable foundation for the effective development of M1 gas field. Furthermore, the systematic method can be used for reservoir evaluation and performance prediction in any other abnormally pressured gas fields.
Step Riser Configuration for Deepwater Application
Authors: Tan Zhimin , Yuan Jiabei , Hou Yucheng , Clevelario Judimar 
Published: March 2016

Abstract
An innovative step riser configuration and its variations are presented for use in deep or ultra deepwater field developments. The configurations are based on existing proven technologies and free-hanging catenary configurations. The step riser configuration is characterized by the utilization of buoyancy tanks/modules array to generate over hundreds of tonnes net uplift buoyancy, directly exerting that buoyancy force to the riser midline connection rather than the riser body. This technology enables significant improvements in the stress utilization and fatigue performance of a flexible riser. In addition, the reduced tension loads greatly decrease installation vessel requirements. The large buoyancy system not only reduces the top tension but also decouples the motion passing from the upper section to the lower section. As a result, high compression and over-bending issues near the touchdown zone can be mitigated.
This paper also investigates step riser configuration performance and its variations, step wave and tensioned step riser configuration, to address the specific issues associated with different deepwater applications. Parametric studies are performed using commercial software to predict and compare the behavior of the stepped riser system in various dimensions. Also discussed is a scaled step riser model test to validate the performance of the step riser configuration. The step riser model was towed horizontally at varying speeds to investigate the riser's tension, curvature and vortex induced vibration (VIV) responses.
The study indicates that the step riser configuration and its variations are a practical cost effective solution for flexible riser systems in deepwater applications with severe metocean conditions.
Sand-Silt-Clay Evaluation Models: Which One to Use - A Case Study in the Malay Basin
Authors: Gaafar Gamal Ragab , Eltunbay Michael Mehmet , Aziz Shaharudin B A , Najm Ehab 
Published: March 2016

Abstract
Clastic-reservoir characterisation of the Malay basin poses numerous challenges resulting from the silty and clayey nature of its reservoirs. To date, different practitioners use shale volume (Vsh) and clay volume (Vcl) in an exchangeable fashion, where the former is rock and the latter is defined as either size or mineral content. Inaccurate quantification of Vcl magnifies the errors inbound in the calculation of porosity and saturation because of the impact of clay density and conductivity in relevant equations.
Different models were developed to evaluate sand, silt, and clay reservoirs, which may be applicable in some local areas and not applicable in others. One of the more common caveats in some of the available models is the mix between the silt volume, Vsilt, and the volume of dispersed clay, Vcl_disp, which has an impact on the effective porosity and water saturation calculations, Sw, especially when evaluating lowresistivity/low-contrast (LRLC) zones using the Thomas-Stieber model.
In the presented study, the same data set was treated with three different deterministic models to solve for sand, silt, and clay volumes. These models include: 1) the sand-silt-clay-water model, also known as the Malay or SSC model; 2) a model that uses maximum porosity to calculate the silt volume; and 3) a technique that uses nuclear magnetic resonance (NMR) clay-bound and capillary-bound volumes from the NMR porosity model.
To select the most accurate and reliable petrophysical approach, the results were compared with X-ray diffraction (XRD) analysis results in the area of the study, and a comparison of grain-size distributions of actual data with grain-size distributions obtained from NMR T2 measurements by a recently developed model was made.
The proposed technique helps in selecting maximum sand and shale porosities as one of the essential parameters in the Thomas-Stieber model for typifying and quantifying the shale and for deciding whether the laminated-dispersed or laminated-structural shale model should be used.
The refined sand, silt, and clay volumes and porosities along with tensor resistivity data were then input into the tensor model for a petrophysical evaluation across anisotropic sand intervals.
The proposed model will help to minimise the uncertainty as a fit-for-purpose approach by improving the accuracy in the calculated mineralogy, porosity, saturation, and consequently, reserve estimations.
Agile Activated Circulation Sub: Flexibility Risk Mitigation in Unconventional Wells
Authors: Tahoun Ahmed , Aljaafar Karam , Khalil Abdul Mushawwir , Fauzi Nurfaridah Bt Ahmad , Ahmad Hassan Bin 
Published: March 2016

Abstract
Agile activated circulation sub is presented, with design advantage of being able to open and close numerous times and there is no limitation to the number of tools run in the string. The tools now being field tested are designed to perform complete needed cycles in one trip, with the total number of cycles limited only by the battery life.
The standalone tool system activated by sensing its environment (Flow, Pressure or RPM), working internal logics before being in a position to receive surface signal to operate in desired mode. The tool has application in any well where it operates the first position for partial bottom-hole-assembly (BHA) bypass increasing annular flow and second, full bypass, position for dumping lost-circulation-materials (LCM) or fast wellbore clean up, the final, downhole barrier isolate drill string above the tool from downhole pressure in well control situation.
Restrictive BHA limits the flow rate and annular velocity required to clean the hole during drilling or displacement operations. BHA restrictions can also limit the size and concentration of LCM and wellbore strengthening material needed to seal troublesome zones. The tool helps driller reduce risks associated with hole cleaning by improving annular fluid velocity with the ability of running multiple tools in same BHA in hole cleaning mode. Each tool can be operated independent of all other tools, allowing driller to optimize hole cleaning hydraulics, as well, tools can be configured with suitable side port nozzle to achieve the desired pressure drop and flow split according to well program. The tool presents advantages over the industry's current system is that there are no restricting ball seats, flow chokes or ball catcher subs in the tool. This paper presents the design, engineering, testing, field trial results, application and function of this new circulation valve
The novelty of the tool is in the ability provided for driller to overcome circulating challenges efficiently and effectively irrespective of tool depth or well profile in reasonable time using variation of RPM, or variation of flow rate. When circulation is not possible or when string is stuck, the tool can be operated to assist driller resume circulation using pump pressure without need for flow.
FSI Analysis for Sloshing Structural Assessment of LNG CCS by Multiphase Fluid Model
Authors: Hwang Se Yun , Lee Jang Hyun , Kim Yooil 
Published: March 2016

AbstractIn design process of the LNG (liquefied natural gas) CCS (cargo containment systems), it is very difficult to determine the effects of sloshing impact and the corresponding response of the CCS. The reliable sloshing assessment methods for LNG CCS are important to satisfy the structural strength of the systems. Since compressibility of the sloshing impact may limit the maximum pressure, mixture model of multiphase is required to represent the sloshing physics. A multiphase CFD model has been introduced to simulate the impact of the LNG sloshing by considering the two phases of gas and liquid. The scheme of CFD model is tried based on the Eulerian domain model that employs the CVFEM. It includes the interphase momentum interaction between liquid and gas. For verification of numerical model, sloshing impact in a rectangular insulation box is simulated to compare the sloshing impacts induced by inhomogeneous multiphase model. Also, the numerical model is applied to localized FSI model for strength assessment of LNG CCS.