bluuebunny/crossref_metadata_2025_split huggingface dataset:
High Strength Proprietary Low Alloy OCTG Applicable in Severe Sour Environment
Authors: Souma A. , Ohe T. , Amaya H. , Ueda M. , Omura T. , Kobayashi K. 
Published: December 2014

Abstract
Environmental cracking susceptibility of high strength low alloy steel oil country tubular goods (OCTG) (110 ksi SMYS proprietary sour grade and 110 ksi SMYS non sour grade) in severe sour environment was investigated. Environmental cracking resistances of materials were investigated in high H2S pressures using four-point bend beam tests in autoclaves. The H2S pressures and testing temperatures were varied from 10 bar H2S – 100 bar H2S to 24 °C - 150 °C. 110 ksi sour grade remained crack free in all tested conditions. Some localized corrosion occurred after one month exposure on sour grade material in higher H2S in the higher temperature conditions, but these corrosion initiations did not propagate after long term (3 months) immersion test. It was concluded that the 110 ksi proprietary sour grade tested in this research would be used up to 100 bar H2S and up to 150 °C, as opposed to API P110 material (110 ksi non sour grade) which suffered SSC (Sulfide Stress Cracking) below 66 °C when exposed to 10 bar H2S. Consequently the proprietary 110 ksi sour grade evaluated in this research can be considered as a validated high H2S environment SSC resistant material usable for casing applications anywhere within Regions 1, 2 & 3 of ISO 15156-2 Figure-1 (pH versus H2S partial pressure diagram) and more than 10 bar H2S environment, that is in any combination of H2S partial pressure and temperature under in site pH occurring in oil & gas production environments.
Additionally, the SSC susceptibility of newly developed 125 ksi SMYS proprietary sour grade was investigated under SSC region 3 environments of ISO 15156-2 Figure-1 by NACE TM0177-2005 Method A. New 125 ksi proprietary sour grade survived at 0.05 bar H2S - pH2.7, 0.1 bar H2S - pH3.5 and 1 bar H2S - pH4.0. On the other hand, new 125 ksi proprietary sour grade showed SSC at 0.1 bar H2S - pH3.0, 1bar H2S - pH3.5. The SSC susceptibility of new 125 ksi proprietary sour grade increased with an increase in H2S partial pressure and a decrease in pH. From these results, the SSC resistance limitation for newly developed 125 ksi proprietary sour grade has been clarified.
Pore Pressure Prediction in Ultra-Deep Salt Formation in Tarim Basin
Authors: Yu Fu , Jin Yan , Chen Mian , Chen Gang , Lu Yunhu , Hou Bing , Yang Pei 
Published: December 2014

Abstract
One of the major challenges during drilling in ultra-deep salt formation in Tarim basin is to predict pore pressure accurately. The salt formation buried at 6000-7800m, which had been affected by tectonic events. Currently, the industry mainly relies on the empirical relations, such as velocities and resistivity trends, to predict pore pressure. Consequently, many investigators have shown these methods are largely based on shale behavior, which reduces the reliability of purely trend-based methods in predicting salt formation overpressure.
In this paper, pore pressure mechanism can be obtained from the existing wells data--including the characteristics of geological structure, pore pressure distribution and logging response directly pertinent to the salt formation. A new model for pore pressure prediction in salt formation is proposed based on the small deflection bending theory of thin plate and poroelasticity theory. This model includes in-situ stress state, tectonic deformation curvature and elastic modulus which were not included in the existing models.
According to the field data analysis, the tectonic compression is the primary overpressure generation mechanism. This approach, based on a rock-physics model, is an improvement over existing pore-pressure prediction methods, which mainly rely on empirical relations. Moreover, it is the fundamental to understand the mechanism of the overpressure generation.
With more than 45 wells predicted with this proposed model, the average error is less than 8%. Thus, recommendations for drilling in salt formation can be given.
Apprenticeship Programs Opens up New Vistas for National Staff Training
Authors: Yakout Akram 
Published: December 2014

Abstract
Difficulty in finding technically qualified local resources that fit the drilling specific industry requirements is a global reality. This challenge also applies when searching for technically qualified expatriate resources in the global market especially in these days of unprecedented surge in drilling activity. With more owners chasing a small pool of experienced qualified technical staff the situation is attractive for the employee in the short term but is not helping the industry and certainly not fulfilling sustainability aspirations. The situation is further complicated due the fact that the skills demanded by some positions in the drilling industry are not typically taught in universities and colleges. Training institutions are few and the demand remains high.
With governments of oil producing countries placing emphasis on national content quotas to ensure that a significant number of their citizens are employed within their country in critical positions a solution needs to be found, it has to be fast.
Taking a leaf out of the shipping industry approach that has for decades trained the officers using well established apprenticeship programs, NDC put in place a robust program of training employees for these difficult to recruit positions using a combination of classroom, practical and on-the-job training while treating these employees as apprentices, thus ensuring that the integrity of operations. Once fully trained, assessed and ready for assuming operational roles, the apprentices were inducted on rigs for a defined period and assessed by experienced mentors till they were finally put in place for independent operations.
Crude Oil Processing Optimization Initiative — from Concept to Successful Implementation and Sustainment
Authors: Amminudin K. A. , Mehlisi A. S. 
Published: December 2014

Abstract
The Khurais Central Processing Facility (KhCPF) has undergone various optimization initiatives since it was commissioned in June 2009. One of the major achievements in this effort is to maximize crude oil yield from its oil train facility. This paper shares its experience in implementing the optimization initiative from exploring such a simple concept of crude flashing to sustaining the optimum performance. It adopts a systematic approach from desktop assessment to performance test. The performance test demonstrates that additional stabilized crude oil production can be realized at the expense of lower gas and condensate yields from the facility. Even though the crude oil gain and gas loss is relatively insignificant — considering the production rate it is mandated to produce — the initiative has resulted in value creations to the Khurais production in general. First, the initiative is purely a low-hanging fruit type, and yet, at the prevailing crude oil price the initiative has contributed to positive net revenue. Second, it avoids spending unnecessary capital to build a new pipeline for injecting back the condensate into the stabilized crude oil. With the promising findings together with the anticipated benefits, the team decided to adopt the proposed initiative in actual operation.
Today, the plant is on the operational mode with greater emphasis on sustaining optimum performance through an effective performance monitoring effort. This in-house monitoring tool has the capability to quantify the performance gap, prioritize the gap closure efforts and diagnose the potential root cause of the performance gap. Along this line, the crude yield key performance indicator (KPI) was introduced where the team monitors the crude specifications, mainly hydrogen sulfide (H2S) and Reid Vapor Pressure (RVP), to ensure the crude oil yield is maximized within the acceptable limits. Finally, the plant successfully commissioned the Advanced Process Control (APC) application to automate the sustaining effort online. The results so far have been very encouraging in sustaining crude oil yield value, minimum product giveaway and energy efficient operation.
Tangible Value from Smart Fields
Authors: Jakeman Simon , Al-Azawi Bahir , Alkarbi Ahmed , Bin Amro Ahmed , Ur Rahim Ihtisham , Albelazi Abobaker , Eldjabri Mamar , Abdul-Jalil Saleh 
Published: December 2014

Abstract
Although the implementation of Smart Fields, or Digital Oil Fields is at last gaining momentum, many companies continue to place the measurement of benefits in the ‘Too Difficult’ category. It seems to make sense that the combined capability of a Smart Field should allow more value to be extracted from the field, but measuring value from a large programme of interdependent projects can be difficult. Attempts to allocate benefits to individual projects can be misleading and often results in double-accounting between different stakeholders, and some of the ‘high value’ benefits associated with additional recovery are difficult to quantify and are typically realised many years into the future.
This paper addresses some of the tangible benefits that have been identified in ADCOs first Smart Field development, together with the expected benefits in implementing similar capabilities across the other assets. It explains how several different levels of wellhead instrumentation and control were evaluated to determine the level of smartness which generated the highest business value.
The results of the assessment have been used to support the roll out of a corporate wide, integrated Smart Fields programme, covering well instrumentation and control, an upgrade to the telecoms infrastructure, analytical / visualisation applications and collaborative work environments.
Lessons Learnt from Drilling Multi-Lateral Infill Wells on a Mature Field
Authors: Pearce Adrian , Dangin Thibaut , Lescoeur Maurice , Blondeau Christophe 
Published: December 2014

Abstract
Total has been operating oil and gas production from a series of heterogeneous reservoirs offshore Abu Dhabi since 1974. The recovery efficiency is already one of the highest in the industry compared to analogous carbonate reservoirs worldwide and the lessons learnt on this field can be usefully applied in the future on other less mature fields in the region.
Since the drilling of the first multilateral well in 1996 most of the infill wells drilled are multilateral with up to 6 drains per well slot targeting different reservoir layers. The layers have different permeabilities, porosities, oil quality, depletion and residual oil saturation. A database containing 20 years of production data from ca. 130 horizontal or multi-lateral penetrations cross-referenced with log and core data now exists.
This paper describes how Total has applied pragmatic technologies in a challenging environment to give itself the best chance of economic success when drilling this type of well. In particular, issues such as target choice, anti-collision with existing wells, flexibility to make "last-minute" target changes, keeping the well within thin layers and the production benefits of zone selectivity will be discussed.
In a 40 year old water-flooded reservoir with diminishing infill targets scattered across the field it has been important to maximize the chances of economic success by maximizing the use of existing data and introducing flexibility in the drilling proposal and well design.
Testing Results: Erosion Testing Confirms the Reliability of the Fluidic Diode Type Autonomous Inflow Control Device
Authors: Greci Stephen , Least Brandon , Tayloe Gordon 
Published: December 2014

Abstract
Inflow Control Devices (ICDs) have become a common technology in horizontal completions for balancing oil influx and delaying water and gas breakthrough which allows total oil recovery to be maximized. ICDs are commonly used in both sandstone and carbonate formations. When ICDs are applied to sand control applications typically only the sand screen needs to be varied according to the specific application. The screen is designed to filter most sand particles while allowing finer sized particles to pass.
An Autonomous Inflow Control Device (AICD) is a next generation ICD which upon breakthrough of the unwanted fluid will autonomously change behavior, creating a greater pressure restriction. An AICD has no control lines or communication to the surface. The AICDs work as a system in the reservoir causing greater flow restriction at high gas and water zones.
ICDs and AICDs alike need to be able to survive real well conditions in a sandstone application. This paper presents erosion testing of the fluidic diode type AICD. Water-sand slurries were circulated through the device at high sand concentration levels to accelerate the lifetime well testing. Pre- and post-erosion flow performance tests are compared to show the change in flow performance over time as erosion occurs.
Implementing Smart Electronic Permit to Work System
Authors: Tolba Wagih 
Published: December 2014

Abstract
Smart Electronic Permits to Work system (ePTW) is a business critical solution which was developed to enforce ADCO's Health, Safety and Environment (HSE) manual and procedures.
ADCO operations are considered to be of high risk, handling flammable and toxic materials, making hazardous incident more prone to occur. Hence, ADCO sought a solution for enabling the employees and contractors to efficiently issue permissions prior to handling the dangerous jobs. Employees and contractors will issue such permissions through having a complete automated system, where they submit their requests for handling dangerous jobs.
Electronic permits and certificates are regarded as statements indicating that all hazards and risks are handled safely and eliminated from the work area prior to job execution and how that job can be carried out safely.
The smart ePTW system should ensure that authorized and properly trained people have thought about foreseeable risks and that these are avoided by using suitable precautions.
System's main features: ▪Ensure work takes place under safe conditions▪Inform workers of potential hazards and rules for working safely▪Control authorization of work with effective delegation▪Visibility of work in progress▪Provide audit trail▪GIS Integration▪PDA mobile version▪Extensive Reports
New Play Concepts and Innovative Corporate Social Responsibility (CSR) Re-vitalising Exploration in the Gulf of Thailand (GoT)
Authors: Spuij Roland , Restrepo-Pace Pedro , Soeteber Angela 
Published: December 2014

Abstract
Exploration in Thailand's offshore Tertiary basins is hampered by the perception that the exploration efforts have reached a mature stage and by increased difficulties related to environmental approvals and stakeholder relations. Petroleum activities in Mubadala Petroleum's concessions in the GoT, although not situated close to the coast, are subject to review by a wide range of stakeholders, including coastal communities, local and national administrations and institutions, and NGO's. At the same time technical work has revealed the possibility of exploration upside, but proving this potential, in addition to the nearly 7.5 BBOE already found, depends on a license to operate and therefore CSR approach and execution are key.
We will demonstrate that, while developing a prospect inventory based on innovative play types and complex/subtle trapping models, with combined structural and stratigraphic elements, we also developed a timely, clear and transparent CSR approach, which focuses on local needs combined with active stakeholder engagement by working in partnership with communities, local administrations and organizations on a tiered, repeatable and sustainable long-term footing. There is strong and genuine synergy between an exploration agenda which focusses on play and trap types away from the conventional faulted 3-way in heavily dissected and compartementalised traps concept, and CSR partnering initiatives. Failure to focus on both is restrictive and disadvantageous as they are genuinely complementary.
In our view Thailand's perception of exploration maturity may be more related to the operational approach to finding hydrocarbons, rather than actual depletion of the resource. We will illustrate the exploration potential with a regional and biostratigraphic recalibration and with examples of complex play-trap systems and will demonstrate how we are successfully engaging with coastal communities and institutions to address socio-economic, educational and environmental challenges facing the communities around our operations in the GoT.
Novel Hydraulic Fracturing Technique Application in Egypt
Authors: Emam Mourad , Knight Roger , Bezboruah Pearl , Sweedan Ahmed 
Published: December 2014

Abstract
Shell Egypt and the joint Venture partners Vegas and GDF Suez are currently developing the Karam gas field by drilling 4 new wells, working over two existing wells and installing surface facilities to process and export this new production. The field is operated by Bapetco (a Shell/EGPC Joint Venture) on behalf of the Joint Venture Partners.
The Abu Roash G reservoir is approximately 4400 meters deep and with reservoir pressures and temperatures in excess of 9500 psi and 310 deg Fahrenheit respectively it is technically challenging. The reservoir is over pressured and Calcium Bromide brine was required to kill the wells for the work over activities.
Post-workover well productivity was significantly below expectations with very high well skins observed. The root cause for the productivity loss was believed to be from formation damage due to losses during the workover operations but relative permeability effects (water blocking) was also suspected as a potential productivity damage mechanism. Laboratory tests were carried out which showed the creation of a sever emulsion between the completion fluid used during the workover (CaBr, CaCl, CaCO3) and reservoir fluids.
A novel technical solution, a methanol Channel Fracturing treatment was developed to restore well productivity. This was a world first application of this treatment utilizing the Channel Fracturing treatment technology to reduce the required pump rate/pressure to place the treatment and methanol as the carrying fluid to minimize the water block effect.
The well was tested after the methanol Channel Fracturing stimulation at a constrained rate of 35 MMscf/d and 3000 bpd condensate compared to the pre-stimulation gas rate of 2 MMscf/d.
This paper will discuss planning, execution and production results making recommendations to improve the effectiveness of future Channel Fracturing applications.
PREP: Growing Future Talent for Azerbaijan
Authors: Karamov Jeyhun J. , Mammadova Elnara 
Published: December 2014

Abstract
The document will present a unique programme designed by BP in Azerbaijan. The Petro-technical Resource Entry Programme (PREP) was specifically created to develop young, local AGT talents in subsurface, drilling, and engineering disciplines over a 12 month period. The training programme is tailored to equip the trainees with improved English communication and technical skills to increase the Oil and Gas (O&G) workforce in the near future. As a result, the programme helps BP Azerbaijan-Georgia-Turkey Region meet its long-term graduate recruitment needs in support of growing business and nationalization targets.
The business case for PREP was defined by an extensive needs assessment conducted by BP Upstream Learning. The results also determined the programme design considerations and both will be presented in the document, for example, the need for innovative collaboration with leading global educational and training providers to ensure the preparation of trainees was developed from a global point of view.
To demonstrate that the programme achieved quality and positive impact measurements, qualitative interview results (with graduates and other key stakeholders within BP) and quantitative survey results (conducted among trainees) are included as internal programme research. In addition, comparative data will be presented to show the impact of the programme on graduate recruitment. As an example, in 2013, 48 out of 53 trainees completed the programme and joined BP (45 joined BP's Global Challenge Programme).
Most importantly, PREP provides a unique transition from university graduation to professional employment with an international O&G company; a preliminary step allowing graduates to prepare for a long-term professional career.
Achieving Drilling Excellence through Next Generation Workflows Enabled by Integrating Historical Drilling Data and Real Time Data
Authors: Mohan David Richard , Bermudez Martinez Rafael , Aillud Gary Stefan 
Published: December 2014

Abstract
In the quest of increasing production capacity to meet future demands E&P companies have embarked in the journey of re-developing their matured assets. This is enabled using several field development programmes that include in-fill drilling, horizontal drilling, underbalanced drilling and drilling unconventional reservoirs. These programmes require high quality offset well data along with real time data for better planning and execution to successfully manage drilling risk, reduce non-productive time and cost to achieve the field development objective.
Historically a huge volume of operational data has been acquired from the large number of wells drilled. Data include well trajectories, casing points, casing analysis, drilling risks, drilling events, BHA performance, operational window, cost, time etc. Maintaining the historical offset drilling data systematically in a well organized manner is vital to unlock its business value and enable better drilling data analysis along with real time data. Technology aided programs such as collaborative well planning, geo steering, real time operations center, require offset well data integrated into real time data for integrated and optimized workflows during planning and execution. This includes building better engineering models and earth models.
This paper discuss present data challenges and the approach towards building an Drilling Integrated Workflow Environment (DIWE) comprising of high quality drilling knowledge base, real time data enabled by data standards and the framework to support next generation well planning and drilling workflows.
DIWE enables improved planning and execution by supporting integrated workflows that aim to mitigate drilling hazards, improve operational awareness, optimize well design, cost effective construction, and better well placement moving towards achieving drilling excellence