bluuebunny/crossref_metadata_2025 huggingface dataset:
Challenges and Achievements in Safe Sampling and Accurate Analysis of Sour Gas
Authors: Veerakumar Ukkirapandian , Ali Jasim Josham , Abbas Ahmad
Published: December 2014

Sour gas contains hydrocarbons ranging from C1 up to C9+, carbon dioxide, nitrogen, oxygen, hydrogen sulfide etc and its composition depends on the source, operating conditions etc. A novel technique of sample collection with strict safety regulations and adequate protective equipments is implemented to avoid exposure to toxic H2S gas. Right configuration of sampling point connected to flare system with control valves and tools help us to extract a representative sample without any leak into atmosphere. An extended training in handling such toxic gas is provided to the staff performing sample collection and analysis. The conventional method for analysis of sour gas composition is GPA 2261 using gas chromatograph which is inadequate and the gas composition is incorrect due to fractionation or condensation of heavier fractions.

We have changed the configuration of the gas chromatograph adapted a modern technique of sample stabilization using a temperature controlled oven and enabled automatic injection of several samples through programmed sequential operation. The results show good repeatability and high sensitivity for heavier fractions and other components. The equipment is calibrated before testing the sample with a primary standard of known composition. The results of both detectors (TCD for inert and permanent gases and FID for hydrocarbons) are combined using i-pentane and n-pentane as bridge compounds and calculated the relative response factors for each component and the gas composition.

Applying the novel techniques of designing proper sample points, using right tools and modern instrumentation, we could ensure that the sample is homogeneous and representative of the bulk supply in plant. We could completely eliminate exposure to toxic H2S gas by using appropriate personnel protective equipments and avoid any leak in to atmosphere by connecting it to flare. Changes in the configuration of gas chromatograph, test conditions and parameters helped us to improve the accuracy and precision of measurement.
"ISO 50001-Energy Management Systems Accreditation, ADCO Safeguards the Environment with Efficient Energy Utilization"
Authors: Daoud Mohamed , Zamzam Montaser , Helmy Ayman , Rageh Adnan
Published: December 2014

Hydrocarbons will remain essential to global economic development and prosperity for decades to come. Meeting rising energy demand needs to be reconciled with the goals of energy security and environmental protection. Energy efficiency and conservation can make a major contribution to moving the world onto a more sustainable energy path. Most of the potential for saving energy lies with end users, however the oil and gas industry continues to invest heavily in further improving the energy efficiency of its own operations, reducing waste and helping final consumers to use less fuel. Major challenges remain, notably in countering the increased use of energy to exploit less accessible crude oil resources and to meet tougher fuel-quality standards. The oil and gas industry, as a stakeholder in the energy debate, will play its part in further promoting rational energy use all along the supply chain for the good of everyone.

Energy management system is important for any company's decision makers to have important information on how to identify trending in energy use for its operations. This helps major decision makers of a company to be able to generate sound conclusions and prepare for consequences.

This paper looks at the energy used by the oil and gas industry in general and focuses on ADCO journey in managing the energy within its operations and assets and its developed energy management system.
Multiphase Flow Performance of Inflow Control Devices – Characterizing Downhole Flow Behavior in Lab Experiments
Authors: Mayer C. S. , Spiecker P. M. , Shuchart C. E. , Burkey R. , Ufford A. , Brysch J.
Published: December 2014

In recent years, the industry has been pushing the application window for inflow control technology, e.g. inflow control devices (ICDs), to harsher environments, including low-permeability formation rock, high-rate stimulation, and stricter inflow conformance for improved reservoir management. These trends result in significantly increased pressure drops and flow velocities across the equipment leading to an increased failure risk due to mechanical limitations and higher erosion/corrosion potential, as recently observed in a Middle East application. To understand long-term reliability of the equipment, accurate predictions of ICD performance are crucial.

This paper presents the initial part of a comprehensive program to characterize the performance and operational envelope of commonly available ICDs. The focus of the current work is on two-phase (immiscible liquid) flow performance testing using water and three oil viscosities (2–60 cP at a test temperature of 200 °F) and on single-phase gas testing using nitrogen. As a test sample, a 6-5/8 inch liner is used with perforation diameters similar to commonly available ICD nozzle sizes. For the two-phase flow testing, data for five different water cuts and five pressure drops for all three viscosities will be presented, while for the single-phase gas testing, performance correlations for several upstream pressures and five different ratios of upstream to downstream pressure will be discussed. The detailed experimental setup and the testing methods will be outlined in order to highlight the necessary factors that need to be considered to approximate downhole flow behavior in a laboratory environment. Moreover, the results will help to establish standardized testing procedures for inflow control devices in order to provide operators reliable data mandatory for ICD completion design, long-term well performance and completion lifetime predictions.
Developing A Field with Asphaltenes Risks: From Diagnosis to Cure
Authors: Rondon-Gonzalez Marianna , Kane Moussa , Quintero Carlos , Passade-Boupat Nicolas , Zhou Honggang
Published: December 2014

We follow step-by-step the course of a new development, from a fluids and production chemistry perspective, focusing specifically on asphaltenes. Information and data from reservoir geochemistry, PVT, fluids characterization are combined to estimate and locate asphaltenes fouling risks all the way from downhole through the process and up to export.

The overall workflow (characterization techniques, risk assessment method, selection of mitigation or prevention measures) provides a framework for dealing with fields with asphaltenes issues.

The asphaltenes risk assessment is based on an in-house method, which we will describe. This method uses PVT properties of the live oil and an easy asphaltene characterization procedure ('ASCI rating'). Further investigation is limited only to fluids which present a real risk of precipitation.

By implementing the approach developed we were able to attain a balanced estimation of the risks (linked to the fluids themselves and their compatibility, but also to certain process choices) and to propose appropriate mitigation measures. Chemical treatment with asphaltenes inhibitors was suggested for this field. For selecting the chemical, a capillary blocking experiment was developed, a technique believed to be better suited than the conventional tube flocculation test. In those places where the specific process itself created an increased risk, a careful analysis of re-dissolution effects showed that the system was ‘self-healing’.
A combined integrated multi-method approach for the assessment of the thermal maturity of sedimentary basins
Authors: Di Paolo L. , Corrado S. , Romano C. , Aldega L. , Di Genova D. , Grigo D.
Published: December 2014

The reliable assessment of thermal maturity of sedimentary successions is crucial for the evaluation of hydrocarbon generation/expulsion. Uncertainties in thermal maturity assessment up to 0.2-0.3% of vitrinite reflectance values can occur according to commonly adopted parameters (eg., vitrinite reflectance, Tmax, etc.) especially when exploring Lower Paleozoic shale gas targets that are devoid of vitrinite macerals. This level of uncertainties is not acceptable in thermal modelling and can negatively influence decisions on the development of prospects.

This contribution provides a new methodological workflow to assess thermal maturity of organic matter dispersed in sediments and hosting sedimentary succession to largely reduce such uncertainties.

The multi-method approach consists in combining optical analysis and Raman and FTIR spectroscopy of organic matter dispersed in sediments with X-ray diffraction of the inorganic fine-grained fraction of sedimentary successions.

The four techniques have been systematically compared in diagenesis for the first time. Results are from an about 3000 m deep Cretaceous-Silurian section that shows a regular and highly resolved trend of increasing thermal maturity with depth on the base of spectroscopic and XRD data, and a general agreement among vitrinite reflectance, FTIR quantitative and qualitative indexes, pyrolysis and Raman indexes. Levels of thermal maturity of dispersed organic matter range from immature-early mature stages of hydrocarbon generation in the Cretaceous-Jurassic section to mid-late mature in the Triassic and Silurian units. Moreover, fine grained sedimentary rocks record an increasing trend of thermal maturity from early diagenesis in the Cretaceous-Jurassic section to late diagenesis for the Triassic and Silurian sections.
Flawless Startups in Iraq - Majnoon Oil Field Achieves First Commercial Production
Authors: van Huysduynen Tom Hooft , Ames Simon , Tierney William , Verspoor Remco
Published: December 2014

The Majnoon Field was discovered in 1976 and brought online in 2002 by the Iraq South Oil Company (SOC). In December 2009, during the Ministry of Oil's 2nd Petroleum Licensing Round, Shell won the right to develop the field under a Development and Production Services Contract. Shell Iraq Petroleum Development BV (SIPD) became operator for the Majnoon Field (45%), with partners Petronas Carigali (30%) and Missan Oil Company (25%).

In September 2013, first oil from the combination of newly built and the refurbished existing facilities & wells, was established. In accordance with the terms of the contract, a minimum average flow rate of 175k bpd over a period of 90 days was achieved in order to meet the First Commercial Production (FCP) target and thus allow Shell to begin cost recovery.

This paper will be based on Shell's experience executing the Majnoon field development in South Iraq. The project scope was completed in challenging circumstances, with very little subsurface information available to confirm design assumptions. As a result, a number of execution risks were transferred to the commissioning & initial start-up operations. The team ultimately relied on experience, planned contingencies and intelligent workarounds to achieve the FCP production target.

The key startup challenges will be discussed in this paper that are relevant to the audience, particularly those involved in field start-up & operations. Conclusions will relate to how the team overcame flow instabilities (slugging) from daisy chained pipelines (linking the multiple wellpads), crude foaming in the process facilities, welding debris in the flare system, dealing with export curtailment (process stops and re-starts) and establishing custody transfer measurement with SOC.

In addition, this paper will present a selected number of Majnoon lessons learned during the commissioning & startup period and how Shell improves Project Delivery in subsequent projects to achieve Flawless Startups to meet the original project premises of safe, reliable production under specified costs and schedule constraints.
Transporting Sour Gas in a Non-Corrosive Form through use of Remote Dehydration Units
Authors: Jain Kirti , Sreenivasan Venkatesh , Djordjevic Ljubisa
Published: December 2014

A major challenge faced by many natural gas developments in the MENA and CIS regions is transporting raw, wet, sour gas from wells to the Central Processing Facility (CPF). The presence of H2S or CO2 and H2O in raw wellhead fluids creates a highly corrosive environment, which dictates the use of expensive corrosion resistant materials such as nickel alloys or stainless steel.

Petrofac designed, built and commissioned a sour gas processing plant in the CIS region, which includes remote, unmanned Gas Treatment Units (GTUs). The GTUs are located up to 16 km away from the CPF, and receive sour raw gas from the wells for treatment using conventional TEG dehydration. The main function of gas dehydration is to dry the gas, thereby eliminating one of the components that causes corrosivity of the gas. This avoided the requirement for cladding the large bore, sour gas transfer pipelines with corrosion resistant alloys (CRA), which would have resulted in high costs, mitigating schedule and construction challenges involved in the installation of CRA pipelines.

Dealing with raw, wet, sour gas is a global challenge faced in many plants worldwide, and has been a major cost and schedule challenge due to the use of corrosion resistant materials. The development solution illustrated in this document depicts an innovative method for transporting sour gas for treatment without the use of large bore CRA pipelines, and can reduce costs of construction and procurement substantially. Similar applications can be made in large scale natural gas processing plants where sour gas and H2O combinations exist, provided that thorough cost analysis is performed to determine the technical and financial viability of the option.

GTU operating data in the form of online water content measured by dew point analysers are documented in this report. Laboratory analysis of the dry sour gas and lean TEG are also included, with the results demonstrating the successful performance of the GTU design.
Fire Dynamics Simulation in Oil and Gas Tanks: A Key Parameters Study
Authors: Al Mezaini I. A. , Ali M. I. , Shatilla Y.
Published: December 2014

In the current economical market, sustaining a great level of process and company protection is a serious apprehension. Makers can reduce expenses by diminishing destruction to apparatus and exterminating incidents that affect individuals and the atmosphere. Oil and gas industries in recent times have need to meet the challenges with alternative resources being explored by the human mankind. That mandates for producing oil and gas with zero losses. One of the major contributing factors that accounts for increase in cost of production are fires. Fires in oil and gas industries can be mitigated if the potential threats and foreseen consequences are known to the operators. Fire Dynamics Simulator (FDS) software is an appropriate tool that should be implemented at project planning stage by the designers and it should be a part of mandatory requirement implied at approval stage of an oil and gas project.

This paper analyzes risks of fire whirl when it is occurred at oil and gas platforms. The study hopes to show how fire patterns are influenced by circulation of air. The fire whirl process over liquid fuel is simulated using FDS, Which produces the development of fire and the change of the radiation intensity and flame height in the case of fire whirl. Also, consequences of fire and wind interaction are considered in this paper. The study results provide reference data and theoretical guidance for fire protection design and firefighting tactics in case of fire whirl. In addition, findings of this study will deliver an optimal safe design for oil and gas facilities.
From Surface To Subsurface: Cenozoic And Mesozoic Carbonate Reservoir Sequences From North Of Erbil, Kurdistan Region Of Iraq
Authors: Conradi Florian , Sauer Roman
Published: December 2014

We aim to demonstrate the use of high-resolution sedimentological data during the early phase of the exploration cycle. The data reviewed included more than 1300 m of log sections taken North of Erbil. This was combined with field mapping, a microfacies study and the acquisition of routine core analysis data from plugs to provide a more complete analysis. Subsurface data included lithological information from two wells and 2D seismic lines with a total length of 487 Km.

The study focussed on carbonate sequences including potential and known hydrocarbon reservoirs, notably the Qamchuqa-, the Shiranish-, the Khurmala- and the Pila Spi Formations. As a result a refined stratigraphic and depositional framework for the Lower Tertiary and Upper Mesozoic sequences has been established. The Cretaceous sequences analysed herein display a series of distinct lithofacies types ranging from shallow marine to deeper marine environments, which can be attributed to different main depositional complexes. The Paleogene sequences show a high diversity of lithotypes that relate to fluvial, fluvio-marine, mixed siliciclastic - carbonate shelf and inner platform depositional environments.

Outcrop samples from both Tertiary and Cretaceous dolomites inherit the highest porosities thus presumably best reservoir quality in the subsurface. However, the effect of fracturing cannot be assessed in detail from surface data alone.

A 3D facies model has proven useful in displaying the spatial relationship of the well and outcrop data. The display of facies probabilities improves the recognition of cyclicity within homogeneous dolomite sections. Possible extent and connectivity of geobodies could be assessed with the model.

The results have been compared with, and put into a regional context with data from literature and proprietary selected subsurface data. The outcrop data have been incorporated into a workflow that supported other G&G subsurface disciplines during the exploration phase.
Impact of Competency Management Program on Job Satisfaction
Authors: Mahmood Sadaqat , Mushtaq Saman , Hussain Jamila , Khan Mehwish N.
Published: December 2014

Massive developments have transformed the field of Human Resource Management into a vast new field of study. All HR practices are now based on strategic application with real effect on business. Human Resource of any company is considered to be the greatest asset and having a competent workforce always lead tangible results to the organization. Significance of Competency mapping and management is inevitable and has been studied invariably as part of applied sciences. A competent employee is considered to be well performing one as well as highly satisfied. Job satisfaction itself is said to be the most discussed topic in the field of organizational psychology while competency has been progressively successful in terms of its pragmatic implementation within the organizational arena; but the relation between these two is not much explored. This paper has laid foundations of determining this relationship. We selected the company that specializes in oil field service industry and has successfully established a competency management system. Using questionnaire as tool, we have found that there has been very positive effect of having a Competency Management System on Employee Job satisfaction. Considering the exploratory nature of the study, we see that it focuses only on two parameters i.e. Competency management system and job Satisfaction and has left room for future researches. Question statements were driven from the literature defined as well as tools established by previous researchers. This can be carried forward by measuring the overall effect on job satisfaction by all organizational factors including pay and benefits. This will help us calculate the importance of having a Competency management System within an organization.
Deployment of High-Resolution Reservoir Simulator: Methodology & Cases
Authors: Cominelli A. , Panfili P. , Casciano C. , Rotondi M. , Delbosco P. , Trajtenberg H. D. , Thompson A. M.
Published: December 2014

The oil industry is developing more and more complex reservoirs, often lying in difficult environments like deep or ultra-deep water. At the same time, brown fields are systematically studied to implement IOR and EOR processes to increase the ultimate recovery factor. In this context one of the challenges is to simulate highly detailed models and provide robust answers for corporate decision making processes. Because conventional reservoir simulators are not very well suited for these purposes, new generation reservoir simulators are tempting solutions. During recent years eni is implementing a step-change in the way reservoirs are modeled and simulated, deploying a new generation, high resolution simulator for the most critical and complex assets. The purpose is twofold: computational efficiency on one side and enabling the development of more accurate models on the other one. The process is run in a selective manner, aimed at identifying opportunities when conventional simulators do not meet expectations.

In this paper we present the methodology used by the Company in the selection of field cases, together with the results achieved for some of the most interesting and complex assets. In particular, comparative results, with respect to conventional simulators, are presented for: deep-water reservoirs, a tight oil development, CO2 injection schemes, and a large scale heavy oil project. The analysis is performed using key computational and engineering performance indicators. The deployment is run in cooperation with the technology provider: cases, logic, issues and solutions are discussed together in a critical manner.

The process is run on the basis of long term corporate objectives, targeting the simulation of EOR processes and complex assets in a computationally efficient and accurate manner.
Enhancing the Value of Sulphur: Using Sour-To-ACid as Field Development Concept
Authors: Gierman M. , Lebel M. , Micone P. , Carrillo E.
Published: December 2014

In order to meet future growing gas demands, resource owners will develop more complex gas fields which contain relative large quantities of sulfur containing components. A critical aspect of sour gas field developments is the disposal method selection for the sulfur. Traditionally the sulfur containing components are converted into solid sulphur. Production of large quantities of solid sulphur makes sour gas field development costly and challenging.

In this paper, the application of Sour-To-Acid as alternative field development concept for sour gas fields is presented. In comparison with conventional field development concepts where solid sulfur is produced, the Sour-To-Acid concept converts sulfur containing molecules from the wellhead directly into sulfuric acid.

Sulfuric acid is globally the most produced and traded chemical. Driven by the increase in population and living standards, the sulfuric acid demand will rise steadily over the coming years. The Sour-To-Acid concept links sour gas developments with the sulfuric acid demand increase.

It is demonstrated that the Sour-To-Acid concept – enabled by Cansolv SO2 scrubbing technology - can form a competitive and alternative concept for sour gas field development. Considering the overall value chain, both savings in investment and operational costs can be achieved by application of the Sour-To-Acid development concept. Additionally, the sustainable footprint of sour gas field developments can be improved. All together, the Sour-To-Acid concept enhances the value of the sulfur present in the reservoir.
Lesson Learnt from Implementing Hse Equipment and Systems in Accordance with Adnoc Cop V6-01
Authors: Basha R.
Published: December 2014

ADGAS has gone through the implementation cycle of the HSE critical equipment and systems (HSECES) in line with ADNOC directive issued in code of practice COP V6-01. The COP stipulates all Abu Dhabi National Oil Company (ADNOC) group companies must identify equipment and systems that will contribute, cause or protect against a major accident hazard, covering the whole life cycle of the plant, from conceptual design right through to decommissioning. HSECES Assurance processes and procedures are developed and implemented to ensure the mitigation of the risk in the case of equipment failure contributing to Major hazard and assurance of the functionality of equipment and systems protecting against a major hazard. In ADGAS HSECES compliance is monitored through the issuance of equipment and systems compliance exceptions report, highlighting noncompliance of HSECES and recommending remedial actions, a series of audits are planned annual audits are conducted by each Independent competent person to ensure the effectiveness and compliance of HSECES's against the performance standards.

The paper will share ADGAS's experience and lessons learned from the implementation process of COP V6-01, identification of HSECES systems and equipment, development of performance standards. Establishing exceptions reporting system for equipment and systems as well as spares inventory monitoring and closing the loop through internal and external compliance assurance.
Global Buckling and Pipeline Walking Interaction - A Unique Challenge
Authors: Hakim M. Abdel , Azouz A. M. , Yehia M.
Published: December 2014

Pipeline walking is a phenomenon known to affect ‘short’ high temperature subsea pipelines subject to cyclic loading such as startup / shutdown cycles. Pipeline walking is a form of ratcheting response in the pipeline axial displacement under certain conditions such as seabed slopes and thermal gradients. Unfortunately, the industry's understanding of pipeline walking is still developing due to the complexity of the walking mechanism as well as limited availability of operational verification for the design predictions.

Pipeline walking is in many cases overlooked for ‘long’ HPHT pipelines which are typically susceptible to global buckling. Hence, for such lines the global buckling design is carried out without due consideration of pipeline walking. However, global buckles effectively divide a ‘long’ pipeline into a number of ‘short’ pipeline segments which may be susceptible to walking. The interaction between pipeline walking and global buckling may affect the long term development of the global buckles as well as the pipeline end expansions.

Therefore, ADMA-OPCO has initiated a detailed assessment of global buckling and pipeline walking interaction on a recent subsea pipelines project. The assessment showed that the interaction between the two phenomena can have a significant effect on the pipeline response in terms of the expansion behavior and buckle growth. The key findings of the assessment are presented along with an overview of the design process and the typical mitigation techniques to be considered for similar subsea pipeline projects.
Recruitment and Retention of Emirati Gen Y in the Petroleum Industry: A Gender Comparative Study
Authors: Lim Hwee Ling
Published: December 2014

The United Arab Emirates (UAE) petroleum industry needs to secure talented professionals in a difficult labor market due to the retirement of older workers and the entry of a large younger Generation (Gen) Y cohort. Moreover, young women professionals remain an underutilized source of human capital even as oil-gas companies have made progress in Emiratization. Since there is limited research on Gen Y professionals at work in the UAE, this study investigated gender differences in the work motivators of Emirati Gen Y in the energy sector and compared factors affecting their recruitment and retention. Surveys (face-to-face and online) and interviews (individual phone interviews) were conducted with respondents from a major UAE petroleum company. The sample comprised 45 employees, born 1980 to 1990 (aged 22 - 32 years in 2012), both genders, holding technical and administrative positions in the company. Quantitative and qualitative data were obtained and the findings showed that intrinsic and extrinsic work motivators were most important in the Gen Y professionals' vocational decisions. The results also showed changes in the importance placed on specific intrinsic and extrinsic motivators, by each gender, in recruitment compared to retention. The findings contributed to the field of human capital development and Emiratization in the UAE. The study added to current understanding of the work motivators of Gen Y who are vital to the future of the energy industry. The recommendations for the effective recruitment and retention of Gen Y provided can be used to guide companies, not just limited to those in the petroleum industry, formulate personnel policies that will positively influence Gen Y professionals' decision to join and continue working for the organization.
Viscoelastic Surfactants Based Stimulation Fluids with Added Nanocrystals and Self-Suspending Proppants for HPHT Applications
Authors: Aggarwal Avi , Agarwal Soham , Sharma Shubham
Published: December 2014

With dwindling resources and mushrooming energy demands worldwide, HPHT field development has come under the limelight of the industry. Thus for expanding the existing horizons, new frontiers in HPHT stimulation advancements are being anticipated for economical harnessing of hydrocarbons. From more than a decade, surfactant fluids had been extensively employed in completion and stimulation operations as the surfactants arrange anatomically to form very long worm-like micelles, maintaining considerably low formation damage levels, and simultaneously exhibiting brilliant rheological properties, viscosity and proppant transportability. High fluid leak off and its inability to withstand temperatures greater than 200°F, have limited its HPHT application. Similar is the case for proppants where significant advancements have been made to increase its strength, but with better strength it has become heavier, causing early screenout, making it unable to reach deeper-complex fractures and requiring more viscous fluids.

This paper discusses in detail an extensive review of the application of nanoparticle and hydrogel polymer technology to enhance fluid – proppant performance in conditions with temperatures nearing 275°F and brine density up to 14.4ppg. This can be achieved by developing nano-sized crystals, which colligate with VES rod-like micelles to yield a virtual viscous filter cake that significantly curbs the fluid loss rate, thus demonstrating wall building on the porous media, rather than usual viscosity dependant leak off control. When internal breakers are applied, VES micelle structures degrade rapidly, leaking off VES fluid and the pseudo filter cake will then split into brine and nanoparticles, thus producing formations remains intact. To augment its performance proppants can be encapsulated with a thin hydrogel polymer layer which will hydrate on coming in contact with water. This layer smoothens the proppant, adsorbs the fines, and makes the proppant self-suspending. This wonder layer is resilient to high pressure high temperature conditions and exhibits excellent characteristics which are elucidated in this paper.

When applied, nanotechnology can reduce requirement of VES fluid volume by 60% and permeability range of VES fluid application is extended upto 2000md. While the incorporation of self-suspending proppants (SSP) can significantly bring down the requirement of additives and enable fracturing of challenging formations with maximum retained conductivity.
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

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

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

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

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

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

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

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

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

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.