bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sea Water Injection Mobile System (SWIMS) for Waterflooding Marginal Offshore Oil Reservoirs in The Gulf of Thailand
Authors: Suthipintawong Tinnaphund , Zyweck Mark 
Published: May 2016

Abstract
Sea Water Injection Mobile System (SWIMS) is a system that is designed to increase recovery efficiency through waterflooding small marginal offshore oil reservoirs in the Gulf of Thailand (GoT). This portable system consists of a submersible pump to lift sea water, chemical injection unit, water holding tank with the ability to treat with oxygen scavenger and biocide and high pressure pump capable of operating at up to 4,500 psi to achieve high rate injection.
The system has a relatively small footprint and is designed to be mobile and flexible to service multiple offshore platforms. The main target reservoirs for SWIMS are small, high permeability, homogeneous reservoirs with a favorable mobility ratio, which allows injection at a higher rate than the production off-take. This ability enables the waterflood to be processed very quickly. When the reservoir is fully repressured and the targeted sweep is achieved, SWIMS can be mobilized to another platform.
Khursaniyah Gas Plant Experience with Foaming During Startup of Karan Non-Associated Gas
Authors: Al-Qahtani Mohammed Hussain , Garland Paul 
Published: May 2016

Abstract
Methyl di-ethanolamine (MDEA) is one of the most popular solvents for gas treating with several advantages over other amines, especially its ability to remove H2S and slip CO2 from sour gas. MDEA is like other types of amine that can experience major foaming upset, especially in high pressure sweetening units. All amines are subject to foaming in industrial applications given certain conditions and circumstances. This paper describes the investigations that Saudi Aramco pursued to eliminate early foaming incidents during the commissioning stage. The paper emphasizes the need for rigorous process evaluation and the application of fundamental principles in plant trouble-shooting. With a joint effort between Khursaniyah Gas Plant Engineering and the MDEA specialist (INEOS), the root causes of foaming were identified and corrected without any capital investment.
Karan Nonassociated (NA) Sour Gas is a CO2 rich stream. Formulated MDEA (GasSpec SS-3) was selected for Sweetening in Karan Gas treating facilities to enhance the H2S/CO2 ratio in acid gas and to meet the required Sales Gas specification prior to sending it to the Saudi Master Gas System (MGS). The Karan nonassociated sour gas field was discovered by Saudi Aramco in 2006. This newly developed offshore field is located 120 kilometers northwest of Jubail Industrial City in the Eastern Region of Saudi Arabia. Produced sour gas is coblended at a tie-in offshore platform through five 20" subsea flow lines. From the tie-in offshore platform, the gas is being sent via a 38" subsea pipeline to the onshore gas treatment facilities in Khursaniyah Gas Plant (KGP), where new gas processing facilities were constructed. Karan facilities consist of three gas treatment processing trains, each designed to process 620 MMSCFD of NA sour gas, producing sales gas and acid gas.
Fully Retrievable ESP: A New Artificial Lift Concept
Authors: Spagnolo S. , Pilone S. , Corti L. , Liantonio G. , Rizza G. , Tita G.E. , Kitsoukou D.N. 
Published: May 2016

Abstract
The "Fully Retrievable" ESP System is a new technology, which permits the rigless deployment and retrieve of conventional Electrical Submersible Pump (ESP): a wire-line, coil-tubing or rod should perform these actions.
This paper shows the eni experiences in this application and the approach used for the completion design according with the company policy highlighting the benefits and the criticalities faced.
Two Fully Retrievable ESP were installed by eni in the following fields:Alaska - OP18-08 - Nikaitchuq Field - onshore arctic environmentCongo - FOKM 101 - Foukanda field - offshore.
Each of them involved different issues and will be discussed in detail in the following sections.
This paper goes all the way through the well definition, completion philosophy and ESP system selection exploring constraints and limitation of this equipment.
An economical comparison was performed and the conclusion is that the retrievable ESP should be used in all of those fields where the workover cost is high and the deferred production is important due to rig unavailability.
It will be presented that the main benefits of this technology include:Simple ESP retrieving with smaller environmental impactCapability to run temporary systems to clean up or test the wellFine tuning of the ESP based on production data.
The benefits of the technology were tested using an internal eni tools for risk analysis based on Monte Carlo simulation: the results are discussed in the last part of the article and highlighted the above expressed consideration and main criticalities.
3D OBC Seismic Survey Productivity Enhancement with Satisfying Geophysical Requirements
Authors: Nakayama Shotaro , Belaid Kamal 
Published: May 2016

Abstract
Ocean Bottom Cable (OBC) seismic survey has several technical advantages over conventional towed-streamer technique as it enables the acquisition of wide azimuth and high fold datasets having long offsets and less spatial discontinuities. However, its usage is still limited because of requirement of relatively large operational efforts which likely results in more survey cost and duration. Consequently, optimization of OBC seismic survey productivity is essential to narrow the business gap with towed-streamer acquisition and enhance widespread applicability of OBC techniques.
Due to the decoupled aspect of the source and receiver lines, OBC survey can inherently form numerous survey designs. Our study is conducted with the aim to find efficient OBC seismic survey designs that still satisfy established geophysical objectives among infinite selections.
We introduce survey designing criteria on the basis of sampling of OVTs (Offset Vector Tile) which allows us to achieve desired offset and azimuth distributions in final imaging.
Productivity analysis is then performed based on current equipment availability enabling a variety of survey designs and geometries which were not feasible previously. We also adapt several geometry options including two dual source-vessel operations:Distanced Separated Simultaneous Shooting (DS3); andDual Source-Vessel Flip-Flop Shooting (DSVFFS).
Applicability of dual source-vessel operations to OBC survey has not been well described unlike marine towed-streamer and land cases. Thus, we analyse the impact of dual source-vessel operations on OBC survey efficiency. Additionally, we discuss technical challenges resulting from the relationship between OBC survey designs and the resultant interference noise wave fields not generally associated with other acquisition techniques.

Introduction
In spite of technical benefits of OBC surveys, time and cost are often regarded as the determining factor for the type of acquisition employed. In general and where applicable, the conventional towed-streamer survey is still the preferred business option. Therefore, further improvement of survey efficiency is important to narrow the business gap with towed-streamer acquisition and enhance widespread applicability of OBC techniques.
Quantitative Formation Evaluation in High Angle and Horizontal Wells - A Step Change in Reservoir Characterization
Authors: Zhou JinJuan , Guo Pingjun , Mendoza Alberto , Passey Quinn , Wertanen Scott , Gaillot Philippe 
Published: May 2016

Abstract
Advanced directional drilling technology has made it possible to drill extended reach wells with long horizontal displacements, resulting in optimally placed wellbores within reservoirs and more economical hydrocarbon production. Logging-while-drilling (LWD) technologies provide new opportunities to improve reservoir characterization and geologic models however, the complicated wellbore and formation geometries in highly deviated wells impose difficulties for quantitative interpretation of well logs using conventional petrophysical analysis methods. LWD log interpretation in high-angle and horizontal wells is often limited to geosteering in well placement applications and qualitative reservoir description.
We developed a state-of-the-art formation evaluation toolkit for quantitative interpretation of well logs in high-angle and horizontal (HA/HZ) wells. Starting with wellbore images and standard triple-combo field logs, the workflow consists of: 1) 3D and 2D displays for well path, wellbore images and field logs to quality control the data; 2) comprehensive image and log analysis to build a 3D geometrical earth model; 3) depth coherence analysis to effectively correct the recorded wellbore images of various logging tool sensors with different depths of investigation; 4) 3D joint inversion to accurately model and interpret gamma-ray, neutron, density and resistivity logs in order to build a common petrophysical earth model; and 5) populating the common earth model with bedding geometries and rock- and fluid-property distributions.
The toolkit has been successfully applied to a field example to illustrate its applications in quantitative reservoir characterization of net-to-gross (N/G), porosity (???), and water saturation (Sw). Incorporating more accurate descriptions of bedding dips and azimuths from HA/HZ wells within the earth model results in improved geologic models for reservoir simulation. Sensitivity analysis in the workflow defines the uncertainties in wellbore image analysis and wellbore directional surveys.
Additional uplift in reservoir characterization includes quantifying lateral variations and improving reservoir facies classifications, along with delineating potential calcite zones and quantifying stratigraphic bedding and orientation. The results include bed thickness distributions and guidance to appropriate petrophysical cutoff values.
Well Accessibility Considerations in Well Completion Designs for Long-Reach and Deviated Offshore Wells
Authors: M. Jeffry Suzanna Juyanty , Shivananthan Dinesh Mohan , Roh Cheol Hwan 
Published: May 2016

Abstract
AA is a new gas field located offshore Sarawak currently under field development planning phase. The elongated field structure consists of multi-stack reservoirs that are located up to 15,000 ft tvdss. Two options for developing the shallow Phase 1 wells (down to H800) have been assessed; completing at either one or two wellhead platforms. To decide between the two options, the team needed to be confident about the ability to safely intervene these wells in future, which triggered detailed accessibility analyses for all wells considering various intervention methods.
Four main intervention methods assessed were slickline, braided line, electric line (E-line) and coiled tubing (CT). This paper provides the details of well accessibility analyses conducted during development planning stage. Sensitivities on the types of intervention activities, bottom-hole assemblies and friction factors were also studied. The findings from the study has significantly changed the well completion designs of the long reach deviated wells justifying use of smart wells. This systematic well accessibility approach was applied for the first time in PCSB to replace the traditional rule of thumb of simple 60 degree deviation used as a cut-off for well accessibility.

Field Background
AA Field is located offshore Sarawak within Baram Delta province. It is one of the deepest resources that are currently being developed in this area. The 6-km elongated field structure has multi-stack reservoirs, with the targeted reservoirs located some 10,000 - 15,000 ft tvdss (Figure 1).
The large pressure differential and different water encroachment in each reservoir increase the level of complexity in developing these resources since zonal isolation is required. Well creaming exercise found that 5 development wells are sufficient to drain the reserves of Phase 1 shallow reservoirs down to H800 (Figure 2).
Factors That Affect Gas-Condensate Relative Permeability
Authors: Kalla Subhash , Leonardi Sergio A. , Berry Daniel W. , Poore Larry D. , Sahoo Hemant , Kudva Ryan A. , Braun Edward M. 
Published: May 2016

Abstract
When the pressure in a gas condensate reservoir falls below the dew point, liquid condensate can accumulate in the pore space of the rock. This can reduce well deliverability and potentially affect the compositions of the produced fluids. Forecasting these effects requires relative permeability data for gas-condensate flow in the rock in the presence of immobile water saturation. In this study, relative permeability measurements have been conducted on reservoir rock at a variety of conditions. The goal has been to determine the sensitivity to interfacial tension (which varies with pressure) and fluid type (reservoir fluids, pure hydrocarbons, and water). The results show a significant sensitivity to fluid type, as well as an interfacial tension sensitivity that is similar to that reported by other researchers. For obtaining relative permeability data that is applicable to a specific reservoir, we conclude that laboratory measurements should be conducted at reservoir conditions with actual reservoir fluids.
The measurements reported here used a state-of-the-art relative permeability apparatus of in-house design. The apparatus uses elevated temperature and pressure, precision pumps, and a sight glass with automated interface tracking. Closed-loop recirculation avoids the need for large quantities of reservoir fluids and ensures that the gas and liquid are in compositional equilibrium.

Introduction
Gas condensate fields are valuable resources under high natural gas prices due to expanding gas markets. They are also valuable under low gas price markets because of the produced liquids. Gas condensate reservoir development is similar to developing dry gas reservoirs with two significant differences: condensate flow in the reservoir near the wellbore and significant liquid production over the life of the reservoir. These factors influence the number of wells and the size of the surface facilities and thus importantly the project economics. Significant liquid accumulation in the pore space around the wellbore, where larger pressure drop and gas flux are encountered, affects the gas flow due to two-phase flow. High gas flux can also lead to inertial non-Darcy effects and, along with multiphase flow effects, decreases the well deliverability. The flow behavior of gas condensate reservoirs leads to increasing liquid saturation (an imbibition process) around the wellbore. This is the reverse of typical gas-oil drainage processes such as gas cap expansion and gas flooding, in which the liquid saturation decreases. Reliable prediction of gas deliverability or liquid recovery over the life of a reservoir needs reliable information on flow behavior of both gas and condensate phases through the reservoir rock.
Collaborative APC Project Management
Authors: Singh Pawandeep 
Published: May 2016

EXTENDED ABSTRACT

BACKGROUND
LNG Industry is in next era of optimizing and maintaining huge LNG capacities, where QATARGAS is contributing 42 MMTPA out of QATAR'S Visionary delivery of 77 MPTA LNG. Mega trains also brings together range of complex technologies and a challenge to automate and cruise control by these technologies with emphasis on reduction in emissions, better asset utilizations, energy efficient operations and controlled product specifications.
QATARGAS operates its world class facilities with state of art optimisation tools implemented on On-Shore facilities starting with Inlet reception unit, Condensate Stripper, Fractionation Units, Liquefaction Units, Acid Gas Treating Units, Scrub Column, Acid gas enrichment units and Sulphur recovery units.
QATARGAS operates its 7 LNG trains with 62 such large APC controllers and overall asset wide linear plant wide optimizer to negotiate and control various constraints within different units with an objective to maximize revenue with minimum energy index operating with the defined operating /optimisation envelop of operating assets.

DESCRIPTION
This paper clearly highlight the ways and methods of implementing world class APC applications, best practices in LNG Industry, skills sets required for successful project implementation, problem solving methodology adopted, tools assessment and evaluation methodology, New Collaborative Vendor Management, Training and Operations, Software standardization, measures of benefit and Futuristic Performance Analysis /Audits and development of Performance Systems.

Methodology Adopted
A detailed stepwise methodology was adopted for Project Management. Key milestones identified are as follows:-Step 1 : Functional Engineering DesignStep 2 : Offsite Testing on Dynamic Simulation platformStep 3 : Finalise Control Structure and implementation StrategyStep 4 : Real plant detailed control strategy designingStep 5 : Pretesting and Process Modeling at SiteStep 6 : Plant Test Data AnalysisStep 7 : Review Control Structure Real plant v/s simulated platformStep 8 : Implement and commission final control structure at siteStep 9 : Analyse and review the benefits of implementationStep 10 : Establish Performance KPI's
Study of Damage Evaluation of Hydraulic Fracturing to Reservoirs
Authors: Du Linlin , Chen Shouyu , Song Bo , Xiu Shuzhi 
Published: May 2016

Abstract
Classic hydraulic fracturing analysis is based on tensile strength of rock, failure criteria of fracture mechanics or Mohr-Coulomb criteria. The existing hydraulic fracturing theories consider little of permeability of fracture reservoir and effective fracturing range, which is exactly the purpose of fracturing. On the other hand, when evaluating effect of massive hydraulic fracturing (MHF), there may be lots of fracture initiation points and cracks due to large range of MHF, which brings huge challenges to numerical calculation of hydraulic fracturing.
MHF will have an effect on a large range of reservoir and accompany in-line micro-earthquakes, which indicate that lots of hydraulic fractures of different scales and directions are generated. Therefore, there will be difficulties to analyze cracking and propagating and estimate geometrical parameters by tensile criteria or fracture criteria. Even if the classic method is feasible, processing of element grid after rock failures will be a problem.
Aguilera (1995) considered shear failure criteria as failure criteria of rocks and proposes fracturing theory of divergent or branched cracks, and that explains the generation of in-line micro-earthquakes in hydraulic fracturing. But the present analysis is just a qualitative method but not quantitative method.
In fact, the basic goal of hydraulic fracturing is enhancing permeability of reservoirs as large as possible rather than producing one or two fractures. Analysis of fracturing effects is analyzing the influence of effective fracturing range on reservoir permeability. While the existing hydraulic fracturing theories just consider propagations and fracture initiations of one or two cracks but little of the quantitative estimation for effective fracturing range.
Hence it is necessary to find a better mechanical method to make up deficiencies of the existing fracturing analysis and overcome the difficulties of processing element grid after rock failures.
This study introduces continuum damage mechanics (Gurson damage model) to hydraulic fracturing, analyzes theories and techniques of hydraulic fracturing of porous reservoirs in terms of continuum damage mechanics and discusses damage effects of hydraulic fracturing to reservoirs. An analysis evaluation system of hydraulic fracturing continuum mechanics is set up, and by using damage theories, a method of analyzing hydraulic fracturing in fissured porous reservoirs is discussed.

Introduction
Hydraulic fracturing theories are divided into two schools (Aguilera, 1995): The conventional school believes that hydraulic fractures are perpendicular to minimum principal stress and the prior research is the discussion of one or two fractures' initiations and propagations near wellbore. Three problems mainly solved are (Gidly, 1995; Economides, 2000; Wang and Zhang, 1998): fracture criteria, the direction of fracture propagation and the geometry of hydraulic fractures. Fracture criteria includes tensile strength criteria and fracture mechanics criteria.
Integration of a Geospatial Framework With a Suite of Numerical Models for Operational, Environmental and Regulatory Aspects of Cooling Water Usage
Authors: Febbo Eric , Duggan James , Kolluru Venkat , Prakash Shwet 
Published: May 2016

Abstract
Use of complex mathematical models and geospatial information systems (GIS) has traditionally been a mutually exclusive process. Spatial and temporal modeling is performed using a suite of well-established numerical models for a particular domain or area of interest (AOI) and outputs are produced for the same domain framework. GIS, on the other hand, allows integration for managing, storage, analyzing, connecting to perihyls, output (ie. hardcopy, softcopy) map and image products along with visualizing data for interpretation in two dimensions (2D) and three dimensions (3D) from many sources and different formats. A GIS system can include; marine data: biota, sediment types, water quality, hydrodynamic data, and ecological sensitivity information, in addition to atmospheric meteorological data. The ability to project and integrate results from numerical models in a GIS system could potentially be a powerful spatial decision support system (SDSS) for operational aspects of coastal and offshore industrial activities to support environmental management and for regulatory reporting requirements.
The system would incorporate a web-based computing infrastructure where geospatial data can be accessible to many users with access controls set by data owners that are appropriate to needs. The vision is the implementation of integrated diverse multi-scale, multi-disciplinary spatial data with analytical and numerical models for environmental and industrial management. The initial SDSS developed in this stage of work integrates the physical and logical components of the modeling system into a GIS framework such that seamless interaction and functionality amongst existing GIS data sets and cooling water dispersion model scenarios can be further analyzed and visualized in a spatial format. The system will also have the flexibility to incorporate additional datasets, analytical or numerical models, and other decision making tools in the future. Such systems can assist users such as plant managers (adaptive management), emergency response teams (response planning and action) and policy advisors (impact assessment and planning). The recent emergence, although still in a nascent stage, of web-based, spatial referencing GIS tools show promise in many key aspects of environmental and operational management, research and public policy, including data storage, analysis, and decision making. Systems such as the SDSS developed in this work can help facilitate the use of these emerging technologies.