bluuebunny/crossref_metadata_2025_split huggingface dataset:
BD Field Development: First Kujung Horizontalnear HPHT - Critical Sour Wells Offshore Indonesia
Authors: Lian J. , Tian Y. , Yang Z. , Yustendi K. , Rizkiani D. , Nurdin S. , Mcken D. R. , Etuhoko M. O. , Jiang K. , Diemert A. P. , Fadil M. , Utomo P. P. , Mahry A. , Yudento S. D. 
Published: October 2017

Abstract
The Company had successfully drilled 4 challenging BD Development Wells (1 vertical and 3 horizontal). BD Field reservoir is aKujung 1 limestone reef, considered near HPHT and critical sour with 8,100 psi Bottom Hole Pressure (BHP), 300℉ Bottom Hole Temperature (BHT), 5.5% CO2 and 5,000 ppm H2S. This paper highlights the design phase and well deliverability covering pressure window, casing design, material selection, wellhead and Christmas tree, directional drilling planning, drilling fluid, cementing consideration, well completion, annulus pressure management, and project challenges.
The data from two offset wells with surface location radius fewer than 2,000 ft from BD Platform were used as reference for lessons learnt and design for the casing seat selection. Based on the Wellbore Stability Study and the offset wells data, there exists a narrow mud weight window between pore pressure and fracture pressure. The directional plan was developed to have sufficient well separation in the upper hole section and enable fewer dog leg severity requirement to drill in the down hole section. Material selection for casing was designed based on the expected life of the well and reservoir properties in accordance to the requirements of NACE. Drill-in fluid system (Potassium Formate and Manganese Tetraoxide) with mud weight of 14.9 ppg was used to drill the limestone reservoir section providing minimal damage to the reservoir. Production casing cement was tested and analyzed in the laboratory for 60days in the HPHT chamber simulating reservoir properties. Open Hole Monobore Completion approach was selected to complete the well. In order not to compromise well integrity, annulus pressure management technique was fully implemented during drilling, completion, and well clean up phases.
The wells were successfully executed despite several challenges which required unique mitigations to manage. During well clean ups, all wells were able to exceed the Absolute Open Flow (AOF) expectations.
An Analytical Model for Multilayer Well Production Evaluation to Overcome Cross-Flow Problem
Authors: Hakiki Farizal , Wibowo Aris T. , Rahmawati Silvya D. , Yasutra Amega , Sukarno Pudjo 
Published: October 2017

Abstract
One of the major concerns in a multi-layer system is that interlayer cross-flow may occur if reservoir fluids are produced from commingled layers that have unequal initial pressures. Reservoir would commonly have bigger average reservoir pressure (pore fluid pressure) as it goes deeper. The phenomenon is, however, not followed by the reservoir productivity or injectivity. The existence of reservoir with quite low average-pressure and high injectivity would tend experiencing the cross-flow problem. It is a phenomenon of fluid from bottom layer flowing into upper layer. It would strict upper-layer fluid to flow into wellbore. It is as if there is an injection treatment from bottom layer. The study deploys productivity index an approach parameter taking into account of cross-flow problem instead of injectivity index since it is a production well. The analytical study is to model the reservoir multilayer by addressing to avoid cross-flow problem. The analytical model employed hypothetical and real field data to test it. The scope of this study are: (a) Develop mathematical-based solution to determine the production rate from each layer; (b) Assess different scenarios to optimize production rate, those are: pump setting depth and performance of in-situ choke (ISC) installation. The ISC is acting as an inflow control device (ICD) alike that help to reduce cross-flow occurrence. This study employed macro program to write the code and develop the interface. Fast iterative procedure happens on solving the analytical model. Comparison results recognized that the mathematical-based solution shows a good agreement with the commercial software derived results.
Novel Application of Capacitance-Resistance Model for Reservoir Characterisation and Zonal, Intelligent Well Control
Authors: Prakasa Bona , Shi Xiang , Muradov Khafiz , Davies David 
Published: October 2017

Abstract
Numerical reservoir simulation is a valuable, computationally expensive, tool for the design, evaluation and operation of hydrocarbon fields. Such reservoir models are complex, time consuming to build, yet uncertain; being based on limited information. The use of alternative models based on the field's production history data to reliably quantify inter-well connectivity and support well control decisions is preferred. This paper extends their application to a field with Intelligent production Wells (IWs) equipped with downhole monitoring and flow control. A field with IWs is a natural candidate for closed-loop, reservoir model update and field optimisation.
The Capacitance-Resistance Model (CRM), one type of data-driven models, has proved to be effective for making well production optimisation decisions in a single-layer, mature, water flooded reservoirs. This study extends the application of CRMs to a multiple-layer, heterogeneous reservoir being developed by IWs. The optimisation strategy was further extended to include both injection and production control at the level of an IW zone. The resulting, CRM-based, proactive optimisation strategy using zonal production/injection history data proved to be capable of delaying water breakthrough and increasing recovery.
This paper describes and compares the reliability of three CRMs in synthetic, single- and multi-layer, reservoir models. The optimum CRM complexity is a function of the reservoir's geological complexity and the complexity of the chosen optimisation strategy. The CRM calculated inter-well, layer connectivity results can be used to suggest changes to the operation of one or more IW zone's injection or production rate. The CRM can be updated once sufficient further injection and production data has accumulated.
A comprehensive CRM -based, closed-loop workflow of data gathering, history matching and optimisation has thus been described. The workflow, programmed as a spreadsheet, is a complementary tool to numerical reservoir simulation, providing insights into both reservoir characterization and production control in intelligent and conventional field developments.
Development of Well Integrity Management Tool in Mahakam Block
Authors: Priwanza H.. , Saputra R.. , Manalu D.. , Muryanto B.. , Nuryanto Y.. , Dirgantoro A.. , Maharanoe M.. , Sari K.. , Sayogyo B.. , Hutahean R.. , Dewanta D.. , Wibowo A.. , Limawan V.. , Darma R.. 
Published: October 2017

Abstract
Total E&P Indonesie (TEPI) has been the operator of Mahakam Block in East Kalimantan since 1968. In a mature field with aging wells, well integrity becomes a vital aspect to ensure all wells are operated within the design envelope during well's life cycle. This paper discusses development of well integrity management tool in the Mahakam Block to manage more than 2000 wells with various integrity threats.
The well integrity management tool developed in TEPI is called SWIM (Smart Well Integrity Module). SWIM acts as a systematic follow-up tools and single database for concerned entities within the Company. On the well integrity management tool logic, NORSOK D-010 barrier concept is applied for a universal approach to all types of well in production regardless of the well completion date as a means to assess the integrity.
Three main components will be assessed to determine integrity status of the well, which are: Two barrier envelopes (External and Internal), and Annulus Pressures as its behavior indicates well integrity issue. The software processing logic will then generate the Well Integrity status depends on the status of barrier component or annulus pressure condition. The general well integrity conditions are then represented by assigning color codes. Four color codes, Green/Yellow/Orange/Red, are utilized for visualization purpose of criticality ranking. Green and Yellow are indicating acceptable well integrity status, meanwhile Orange and Red are highlighting one or several integrity issues on the well and prioritization to perform a restoration job.
The SWIM as single portal and integrated software provided with accurate data inputis beneficial for Company in terms of criticality rankings and data reliability for monitoring thousands of well integrity condition, allowing proper assessment, fast-follow up, and data gathering to propose suitable intervention or repair if required.
First Fiber-Enabled CT with Reservoir Saturation Tool in Asia to Unlock Behind-Casing Opportunity in Offshore Myanmar
Authors: Mohallem R.. , Jenie J.. , Hami Z.. , Nazri A. Mohamad , Zaman N. Kamarul , Salleh K.. , Htun Y. Min 
Published: October 2017

Abstract
An infill drilling campaign in offshore Myanmar was facing challenges to accommodate well intervention activity in order to achieve additional production targets; therefore, there was a need to search for an alternative, cost-effective solution in the current environment. A well with potential behind-casing opportunity was identified, and an innovative solution was proposed using coiled tubing (CT) fiber-optics real-time telemetry combined with the latest high-power battery cartridge technology to convey a tool capable to identify the reservoir saturation and conclusively detect the bypassed zones.
As a result of rig-up constraints, a standalone wireline unit could not be used to deploy the reservoir saturation tool on the selected well. The innovative solution was to convey the reservoir saturation tool using CT fiber-optics real-time telemetry along with the latest-technology high-power battery cartridge system, allowing real-time logging with CT, including additional safety precautions and radiation hazard controls while using the pulsed neutron generator device.
The intervention was performed concurrently with drilling operations on an adjacent well. A major effort was put in place to plan and execute this operation, especially because open well deployment was needed to address the rig-up height issue while doing the job below the rig floor; this was in addition to the extensive HSE risk mitigation for using the radioactive pulsed neutron generator device. The well was killed successfully, and the reservoir saturation tool was conveyed with CT to the target zone where two logging passes were made. Data were then sent for interpretation, and the CT was pulled back to surface after confirmation of data quality. As a result, the operator obtained conclusive data, and the decision was made to shut off the existing perforated zones and perforate the identified BCO. The simultaneous intervention and drilling operations, reduced footprint, and the additional production from this well saved the operator up to USD 2 million. With the integration of CT and wireline technologies and the introduction of a novel battery system for high-consumption logging tools such as the reservoir saturation tool, the operator efficiently and cost-effectively acquired data without nonproductive time (NPT) or compromising safety during operations.
An innovative and first-time operation in the entire region (Asia), the use of CT fiber-optics real-time telemetry combined with the latest high-power battery cartridge technology to deploy the reservoir saturation tool overcame operational challenges and enabled successful identification of the bypassed zone. The combination of these technologies can benefit other regions and other similar operations.
Breaking Boundaries in Portfolio Management
Authors: Gama B. , Macmillan F. , Roithinger J. , Gieles T. R. , Bulgariu R. 
Published: October 2017

Abstract
The challenges currently faced by the E&P industry are unparalleled. Subdued hydrocarbon prices and an increased pressure to minimise cost structures provides a convincing reason for managers to implement effective portfolio management technologies. The objective of this paper is to provide a practical portfolio management framework which balances the often conflicting requirements of managing short term financial stresses and long term strategic growth.
Expanding Innovative Approach of Sand Production Well Remediation - Case Study of First Downhole Ceramic Sand Screens for a Gas Well in Malaysia
Authors: Musa M Nizar , Ismail W Rokiah , Roh Cheol Hwan , Zulkifli Shahrul Anwar , Hui Nicholas Foo , Jackson R.. , Gundemoni B.. , Barth P.. 
Published: October 2017

Abstract
The current state of oil and gas economics has emphasized focus in managing and optimizing production from mature fields. It is estimated that approximately 70% of the world's oil and gas production are contributed by mature fields. Sand production is common as pressure declines and water breakthrough takes place. Clastic reservoirs with unconsolidated formation sand with moderate and high permeability are prone to produce sand under these conditions. In gas producing environments, conventional sand control can place demands for continued expensive remediation investment through the wells producing life as high gas velocity increases the chances of erosion and failure of downhole equipment. Gas reservoirs have always been an integral part Malaysia's oil and gas business. As the well the portfolio expands to cater for the regional energy demand, focus on fit for purpose sand control in gas wells is crucial in ensuring continuous production delivery to customers. As a current practice, sand production has been handled by standalone metal screens or combined with gravel packing. One of the cheaper options available in the market is the ceramic sand screen that allows for rigless installation while providing durable material which is resistant to erosion caused by high gas velocity for a continuous production as the ceramic material is 10 times harder than steel (Jackson et al., 2015) and it is more resistant to corrosion in comparison to steel (Wheeler et al., 2014).
This paper will focus on the revival strategy of a gas well with a currently damaged screen due to erosion. As this is the first through tubing ceramic sand screen deployment in a gas well in Malaysia, a feasibility process was put place to ensure safe operation and deployment success. Depending on the current well completion profiles, the assessment includes selection of sand screen specification, actual installation sequence, methodology in ensuring safe and successful deployment of ceramic sand screen downhole are focused. The study and assessment has provided future reference for superior downhole sand control options in gas well applications.
Hydraulic Fracture Design and Well Spacing Optimization for Gas-Condensate Reservoirs
Authors: Abdul-Latif Benson Lamidi , Hikmahtiar Syouma 
Published: October 2017

Abstract
In state-of-the-art production data analysis and computational methodologies applied to multiphase lease condensate flow, condensate-banking effect is usually neglected to enable easier analytic treatment. However, neglecting the amplified role of condensate banking in multiphase flow in unconventional formations may generate misleading analytical results and calculations during hydraulic fracture design and optimization.
This work proposes a semi-analytical model eminently applicable to unconventional reservoirs to incorporate the effect of condensate banking in hydraulic fracture design and well spacing. Analytical models for Darcy flow above and below the dew point pressures were considered whilst estimating the optimum fracture design in gas condensate reservoirs using Schechter's approach and incorporating the effects of the condensate blockage radius.
The validity of the series of proposed semi-analytical solutions that capture condensate-banking effect in unconventional reserves is verified by discussing a number of cases and comparison against full-scale numerical simulation data.
Integrated Reservoir Analysis and Geomodeling on Shallow Zone of Handil Field, a Key to Identify Un-Swept Area for Future Development of Mature Oil Field
Authors: Benidiktus G. Massuka , Andar Trianto , Sinto Yudho , Bayu Setyo Handoko , Iswahyuni F. Hayati 
Published: October 2017

Abstract
This paper describes a new methodology to identify the un-swept areas for future infill well location in Handil shallow zone. This methodology has been proven by more recent Handil shallow oil (HSO) wells results.
Handil shallow oil zone plays an important role as it contributes to 60% of today’s Handil oil production. Shallow zone was initially produced in 1977, reached its peak of production 37,000 BOPD, in 1981 and continued to decline until the lowest level of 2,500 BOPD in 2005. The re-development project was started in 2005 to revive the contribution from shallow zone. The project has delivered 42 HSO wells to date with cumulative production of 26 MMstb and current average production of 10,000 BOPD.
The reservoirs are fluvio-deltaic sand with strong aquifer support which maintains the reservoir pressure in hydrostatic level. The compartmentalization of the reservoir by faults and facies heterogeneity, combined with HSO wells production impact, resulted in variation of water movement within the same stratigraphic layer in one reservoir segment. The tilting oil water contact (OWC) was observed and it reveals the opportunity to find un-swept areas in mature field. This phenomenon was observed in HSO wells drilled since 2005 to 2015. The behavior of fluid contact was analyzed from log, confirmed by formation tester and from production logging tool (PLT) in existing production wells.
A new methodology was introduced to identify the un-swept areas for future infill well location. Detail reservoir correlations within individual deltaic cycle of more than 400 wells, integrated with reservoir dynamic synthesis, were performed to define the reservoir architecture and to characterize the water movement (actual and future OWC). The 3D reservoir model was built according to these syntheses and an individual dynamic region with similar OWC movement within the same stratigraphic layer was created to honor the compartmentalization of reservoirs. This has led to the identification of un-swept areas in top structure and also in the flank areas with less production activity.
The methodology has become a game changer in finding remaining oil. More infill well locations are identified by using this approach for future Handil field development.
Pressure Transient Analysis for Cold Water Injection into a Reservoir with a Coupled Analytic Wellbore Model
Authors: O'Reilly D. I. , Haghighi M. , Flett M. A. , Sayyafzadeh M. 
Published: October 2017

Abstract
In this short technical note we lay out an analytical framework to assess the impact of transient temperature changes in the wellbore on pressure transient response of cold water injection wells. We focus attention on the falloff period of an injector following injection. Historically, these pressure data have been used to calculate reservoir properties concerning flood efficiency and completion properties, e.g.: formation permeability-thickness, mechanical skin and fluid bank mobilities. One key question addressed in this paper is whether the effects of thermal heating of wellbore fluids during a falloff survey can mask the pressure signature of a two-zone composite reservoir. The pressure deflections required to detect mobility changes may be relatively small compared to pressure changes induced by temperature effects in the well. The framework proposed in this paper allows for the numerical evaluation of the contribution of each.
Previously, researchers have studied multiple bank transient injection problems extensively for the case of reservoir flow and pressure drop, even for non-isothermal problems. The effect of temperature changes in the wellbore and overburden are seldom discussed, however. It is demonstrated in this paper that these effects can, in some cases, be substantial and it is worthwhile to incorporate them into an interpretation model.
The results of this paper are useful for planning and designing a pressure falloff survey to minimise the adverse effect that heating of wellbore fluid by overburden rock may have on the pressure transient signature. The theory can also be used to analyse existing data affected by the phenomenon.
First Application of Residue-Free Fluid System for High Temperature Fracturing Treatment in Saudi Arabian Carbonate Formations
Authors: Rahim Zillur , Al-Kanaan Adnan , Zeghouani Mohamed , Khalifa Mohamed , Krich Driss 
Published: October 2017

Abstract
Acid Fracturing technique is an alternative to propped fracturing in acid soluble formations. Factors controlling the effectiveness of acid fracturing are the etched fracture penetration and conductivity. Large volumes of acid and the dissolution of large volumes from thefracture faces with excessive acid leak off result in negative net fracturing pressures and less optimized etched fracture length. This paper describes the first application in Middle East area of a nitrogen assisted residue-free fracturing fluid system to successfully stimulate a carbonate formation.
Bio-Inspired Superhydrophobic Coatings with High Performance for Subsea Petroleum Equipment
Authors: Jin Xu , Chen Yu , Li Jianming , Wang Xiaoqi , Bi Lina , Bai Jie , Wu Juntao 
Published: October 2017

Abstract
Bio-inspired superhydrophobic Polyphenylene sulfide/Polytetrafluoro-ethylene (PPS/PTFE) coatings were prepared by a simple curing process. The surface morphology characterization by SEM shows that these superhydrophobic coatings have the similar macro-nano-structures to that of lotus leaf. Effect of the content of PTFE as well as the curing condition on the water contact angle of the superhydrophobic coating surface was then systematically studied. A series of tests show that the superhydrophobic coatings exhibit high cohesional strength, excellent impact resistance and high thermal stability. Moreover, we studied the stability of chemical resistance of the as-prepared superhydrophobic PPS/PTFE coatings, and the electrochemical impedance values kept on a high level even after 8 days. The superhydrophobic PPS/PTFE coatings with high performance have potential applications in subsea petroleum equipment fields.