bluuebunny/crossref_metadata_2025_split huggingface dataset:
New Techniques for Metal Sulfate Scale Removal from Production Pipelines and Wellbore Case Study Sidi Kerir for Petrochemical Co.
Authors: Salah Mohanad 
Published: November 2019

Abstract
This research present case study of sulphate scales found at water treatment unit, cooling water system and heat exchangers at Sidi Kerir Petrochemical Company Alexandria, Egypt, which declined overall production by 6%, about 250 million US. Dollar in losses 2018 due to unit's shutdown and flow restriction in pipelines. We tried many techniques like mechanical jet blasting using high-pressure water to crack the scale but it was a time-consuming root and need special equipment and large labour although it was not that efficient in areas with heat exposure and it cannot reach some areas. So we moved to next root for removing scales by chemical cleaning based on inorganic acid like hydrochloric acid, sulphuric acid,,, etc. although it can dissolve the scale in very limit efficiency but we didn't accept this method because those chemicals were very corrosive to metal surface like cast iron and stainless steel grade 304/316 also using those chemical present hard handling problem for adding or dilution. Therefore, we had to take the challenge to develop our new chemical cleaning methodology that combines between efficiency and safety. In new methodology, we developed new chemical formula based on mild organic acid mixture combined with sequencing agent, anti-re-deposition agent, wetting agent and pickling agent to chemically dissolve the scale in efficient and safe way.
The chemical cleaning technique was successful to dissolve the scale in very short time and in safe way to metal surface like cast iron and stainless steel. This invention is useful for the removal of sulphate scale like iron sulphate, calcium sulphate, barium sulphate and strontium sulphate from process equipment including pipes, pumps and storage tanks. It is also can be used to the removal of these scale deposits from other equipment such as boilers and heat exchangers.
HFE Implementation Journey in PDO, Benefits and Challenges
Authors: AlRashdi Abeer 
Published: November 2019

Abstract
Major process safety incidents such as Deepwater Horizon, BP Texas City and Piper Alpha have revealed that understanding Human Factors Engineering (HFE) is one of the biggest challenges faced in Oil & Gas Industry. PDO historical database has also identified high frequency of design-induced human errors resulting in incidents, which could have been prevented by proper integration of HFE at early design phases.
Whilst efforts to minimize incidents have conventionally concentrated on machinery and technology, prevention measures today also recognize the importance of HFE as a major contributor to operational safety and to the optimization of system performance.
The journey of implementing HFE design in PDO projects has focused on the following: Developing in house HFE expertise,Mandating HFE requirements at early design phases of projects through following a systematic process (Discipline Control Assurance Framework DCAF),Ensuring proper HFE awareness level is cascaded to all relevant stakeholders in projects at early engineering phases,Applying relevant learning's from previous audits/projects/incidents,Initiating online HFE simplified tools to aid the process of implementation,Emphasizing on formal HFE inputs during model reviews and,Verifying compliance to HFE design as several stages of projects.
However, the process of implementation, on the other hand, has faced several challenges and obstacles. Lack of integrating HFE at the design phase can be attributed to a host of factors including lack of appreciation of HFE core values by engineers and managers, limited HFE expertise in the industry, and other challenges. This results in a general reluctance to spend the time and money when it comes to HFE design related issues, and eventually, resulting in poor HFE integration in projects.
This paper explores the step-by step journey of implementing HFE requirements in PDO projects along with the challenges faced in inculcating good HFE design in projects and it highlights the lifecycle advantages of incorporating HFE in design. In addition to that, a story of success for implementing HFE requirements in major projects is showcased; which set out a roadmap for enabling future projects in oil and gas industry to achieve full compliance with HFE requirements.
New Opportunities and Challenges to Discover and Develop Unconventional Plays in the Middle East and North Africa: Critical Review
Authors: Ba Geri Mohammed , Ellafi Abdulaziz , Flori Ralph , Belhaij Azmi , Alkamil Ethar H. 
Published: November 2019

Abstract
Nowadays, as the worldwide consumption of hydrocarbon increases, while the conventional resources beings depleted, turning point toward unconventional reservoirs is crucial to producing more additional oil and gas from their massive reserves of hydrocarbon. As a result, exploration and operation companies gain attention recently for the investment in unconventional plays, such as shale and tight formations. A recent study by the U.S. Energy Information Administration (EIA) reported that the Middle East (ME) and North Africa (NF) region holds an enormous volume of recoverable oil and gas from unconventional resources. However, the evaluation process is at the early stage, and detailed information is still confidential with a limitation of the publication in terms of unconventional reservoirs potential. The objective of this research is to provide more information and build a comprehensive review of unconventional resources to bring the shale revolution to the ME and NF region. In addition, new opportunities, challenges, and risks will be introduced based on transferring acquiring experiences and technologies that have been applied in North American shale plays to similar formations in the ME and NF region. The workflow begins with reviewing and summarizing more than 100 conference papers, journal papers, and technical reports to gather detailed data on the geological description, reservoir characterization, geomechanical property, and operation history. Furthermore, simulation works, experimental studies, and pilot tests in the United States shale plays are used to build a database using the statistic approach to summarize and identify the range of parameters. The results are compared to similar unconventional plays in the region to establish guidelines for the exploration, development, and operation processes. This paper highlights the potential opportunities to access the unlocked formations in the region that holds substantial hydrocarbon resources.
An Integrated Approach to Optimize Field Development Plan Based on Uncertainty Analysis in a Giant Offshore Field
Authors: Zhao Wenyang , Al-Neaimi Ahmed Khaleefa , Sarsekov Arlen , Saif Omar Yousef , Abed Abdalla Abdel , Al-Feky Mohamed Helmy 
Published: November 2019

Abstract
With an increased maturity and complexity of the reservoir, an optimized field development plan implementation is critical to achieve the planned target and to ensure an optimum field recovery. The paper presents an optimized process with uncertainty analysis based on Monte Carlo Simulation for the purpose of optimizing the Medium Term Development Plan (MTDP) implementation.
The five year development plan of this giant offshore field has been successfully assessed based on this optimized approach. The integrated workflow consists of four main parts, including actual field technical rate tracking, DBC optimization, simulation results, and effective capacity with Monte Carlo simulation embedded. The dynamic situations could be taken care with these seamless coupled tools. The actual field technical rate has been tracked on a monthly base through a systematic and automated process. The reference decline ratio has been assumed based on historical production decline analysis. Besides, a floating decline based on simulation results is also added in order to capture the well closure due to gas production limitation. Field technical rate is the fundamental input for field development plan to derive the field sustainable oil production rate. It is dependent on both existing wells' performance and future wells' planning. Both the expected gain and drilling schedule of the planned wells are crucial to achieve the production target with reservoir pressure appropriately supported. Voidage Replacement Ratio has been applied to balance production and injection. Drilling plan could be revised accordingly. The production and injection balance can be visualized in the effective capacity tool, which will be used to further optimize the producer and injector plans. The requirements of producers and injectors are summarized and imported into the DBC optimization tool to evaluate new drilling schedule, which will be used in the effective capacity tool for an iteration loop.
Uncertainty analysis is critical to assure a field development plan. Uncertainties have been evaluated based on the factors' most probable range. Five major assumptions, including expected gain from new wells, drilling duration, decline ratio, put-on-production time, and operating efficiency, have been evaluated to assess the uncertainty. Mitigation actions could be proposed to assure the production plan.
Biogenic Gas Potential in Abu Dhabi
Authors: Taher Ahmed , Al Hanaee Ahmed , Frsnco Bernardo , Chitrao Amogh , Abdelaal Atef , Popa Desdemona 
Published: November 2019

Abstract
Recently there has been a growing interest in gas exploration, much of this focus has been directed toward thermogenic gas derived from cracking kerogen in the highly mature kitchens. However, a significant proportion of the global gas reserve is not thermogenic but of bacterial origin (Katz, 1995). Biogenic gas is an important exploration target because it occurs in geologically predictable circumstances, in areally widespread area, and in large quantities at shallow depths as free gas (Schneider et al, 2016).
The recent exploration wells drilled in the northeast onshore Abu Dhabi showed elevated total gas readings during the drilling of the Gachsaran formation. Consequently, mud-weight was increased to control the gas flow. In addition, the recorded wireline logs indicate the presence of relatively high hydrocarbon saturations in several high porous zones of Gachsaran and Asmari formations.
To assess the productivity and commerciality of the Biogenic gas potential in Abu Dhabi, several exploration wells are planned to be drilled before the end of 2019. The positive results of these wells will open the door for a new era of sweet gas exploration activities in Abu Dhabi and its surrounding areas. The primary gas reservoirs are thin carbonate and clastics layers in the Gachsaran Formation at a depth that ranges between 1600-5200 feet below sea level.
Organic carbon isotopes, Rock Eval analysis, TOC log data and gas shows analysis indicated that the methane gas found in the Gachsaran Formation is of a biogenic origin and sourced mainly from the organic-rich argillaceous limestone of the Middle Gachsaran.
Gachsaran formation is comprised of alternating thin layers of anhydrite, limestone, marl and shale sediments in addition to the presence of salt layers in the lower part. This mixed lithology resulted in the reservoirs property deterioration in particular by shale and anhydrite nodules cementation.
The biogenic basin areal extent, significant thickness of the Gachsaran in this basin and the organic richness distribution, conclude possible generation of a huge volume of biogenic gas in northeast onshore Abu Dhabi. However, additional work is required to estimate the volume of gas that is accumulated and that can be produced from the Gachsaran and Asmari formations.
Completion Solutions to Enable Well Kick-Off and Liquid Unloading for Downhole Gas Compression Applications
Authors: Lastra Rafael , Montoya Cesar , Bussear Terry , Strattan Scott 
Published: November 2019

Abstract
Downhole wet gas compression technology (DHWGC) is a relatively new artificial lift concept for gas wells that aims to boost production, maximize recovery and delay onset of liquid loading. By definition, wet gas compressors are capable to handle certain amount of liquids entrained in the gas, however, there are some circumstances where large amounts of liquids accumulate below the compressor and need to be removed to allow the gas well to flow. Liquids can accumulate below the downhole compressor after well intervention or as result of condensates accumulation during normal production. To this end, a means to enable liquids removal for Downhole wet gas compression applications must be developed.
The objective of this study was to identify completion solutions that enable liquids unloading below the compressor. This paper introduces a new concept with a simple well architecture that will enable continuous operation and eliminate needs of additional well interventions to remove liquids accumulation that occur during well shut-in operations.
Operations Readiness and Assurance - A Practical Example
Authors: Khan Umar Ali 
Published: November 2019

Abstract
This paper discusses the actual implementation of the Operations Readiness & Assurance (OR&A) process through the life cycle of a brownfield project in OMV's existing operations in black sea region. Importance of operations readiness and assurance, what it really is and how it is implemented are also elaborated briefly in this paper.
OMV's has a well-defined operations readiness and assurance system in place with detailed guidelines and steps for its implementation in any project that exceeds the threshold value of 20 mn Euros. Projects of lesser value can also utilize the system at a smaller scale.
The success of operations readiness and assurance implementation is only visible through the commissioning and into the operate phase of the project as this is the primary focus of the OR&A process. Ideally, a project should have a flawless startup and operation, however in the practical world some teething issues may appear during and after startup in major or complex projects even the ones in which OR&A is implemented. However as long as those teething issues are resolved soon and don't result in much production loss then the project can be termed to have had a relatively satisfactory implementation of operational readiness and assurance principles.
While many companies may consider OR&A as an additional overhead and while it may be difficult to measure the benefits of OR&A in financial terms, however the reality remains that an effective implementation of the principles of OR&A can have good result with respect to the success of the project with respect to delivering its objective
Surveillance Approach of Steam Management in Heavy Oil Reservoir-Oman
Authors: Mahruqi Hajer Al , Habsi Ali Al , Mohammed Hassan 
Published: November 2019

Abstract
Steam injection is one of the most common EOR methods adapted in heavy oil reservoirs. Steam improves the heavy oil mobility by reducing its viscosity via temperature increase. Steam Flood and Steam Cycle are the primary approaches applied widely in a steam EOR project.
Profit maximization of steam flood projects require good reservoir management practices including regular reviews to optimize steam injection. Steam management adjustments are both simple and complex. The steam management adjustments react against performance expectations, such as early or late production response at the production wells
An integrated work effort by the reservoir management team is imperative in the daily surveillance work. This work requires using geological maps, fence diagrams, permeability maps for identifying possible sand channels and preferential steam path, injection profile logs, injection rates/pressure and production data. Synthesizing all this data determines best locations to redistribute available steam. Expected response is lower steam oil ratios, lower wellhead temperature and lower well water cut rates.
This paper, it summarizes the workflow used for steam optimization process in one of Oman steam flood project. The workflow covers the identification through implementation phase where steam adjustments are required. These phases include review of geological description, petrophysical properties, and production and injection trends. This paper also discusses final KPI measures used to judge successful steam management adjustments.
Reservoir Modelling in the Shale Gas Reservoirs Based on Horizontal Wells and Seismic Inversion
Authors: Gai Shaohua , Jia Ailin , Wei Yunsheng 
Published: November 2019

Abstract
The seismic vertical resolution is too low to identify the vertical boundary and petrophysical properties of the thin shale layers inside the target precisely. This study focuses on structural and petrophysical modeling of shale reservoirs based on horizontal wells and seismic inversion.
Combined seismic trend surface with the well tops on horizontal wells, we calculated the top and bottom surface of the target formation, and obtained the structural surface of each small layer according to the thickness percentage of each layer from few vertical wells. Ultimately, the structural model is made. The horizontal trend of the petrophysical properties can be controlled by the seismic inversion results. The vertical trend of the petrophysical properties can be controlled by well logs. Constricted by the linear combination weighting of the horizontal and vertical trend, the petrophysical model is established.
The results show that the trajectory of the horizontal well in the target layer is accurate, and the layers are not intersected. The thickness of each layer is relatively even in plane, which is basically the same as that of the vertical well, indicating the characteristics of shale stable deposition. The discrepancy between the thickness of each layer in the model and those of the vertical wells is very small, especially in the main production layer 1, less than 0.1m. With the linear combination weighting, petrophysical properties show the bimodal distribution in vertical trend, which is in accordance with the regularities of petrophysical distributions from vertical wells, making up for the seismic low resolution in vertical direction.
The research shows the fine structural and petrophysical modeling of the thin shale reservoirs, which provide the credible spatial distribution network and petrophysical properties for further modeling.
Use of Optical Gas Imaging for Visualizing Gas Leakage and other Thermal Camera Applications in Oil & Gas Sector
Authors: Singh T.P. 
Published: November 2019

Abstract
An insight into Optical gas imaging (OGI) – Complete details on these applications. And apart from just visualizing gas, new age thermal cameras can provide lot of value through operational efficiency and safety in a variety of applications such as Furnace applications, Fire prevention, Fire fighting, electrical/mechanical/refractor, continuous monitoring, tank inspection and flare stack monitoring along with IR window details.
By T. P. Singh, Director (Ins) – Emerging Countries, FLIR Systems, Inc.
Full paper Details
The modern oil and gas industry’s practices – from extraction to refining – are depended on to be socially and environmentally responsible in terms of ecological mindfulness, regulatory compliance, and the safety of both workers and the communities surrounding operations. Thermal imaging, also called infrared (IR) thermography, provides a vehicle toward ensuring all these aims are met, while providing a tangible and justifiable return on investment (ROI). While optical gas imaging (OGI) plays the most recognized role in the oil and gas industry, thermal cameras can serve a variety of non-gas imaging applications in the industry as well.
This article discusses basic concepts of infrared technology and provides specific applications info that details the advantages of using thermal imaging over alternative technologies or methods.
Lets discuss basics first and then we move to different applications.
State of the Art Development in Annulus Evaluation
Authors: Gupta Shilpi , Govil Amit , Obando Guillermo , Winther Tonje , Delabroy Laurent 
Published: November 2019

Abstract
In an oilfield well, when the annulus contents behind the casing are evaluated using ultrasonic measurements, the properties of the borehole mud, such as acoustic impedance and fluid velocity, are critical input for the accurate determination of acoustic impedance of annulus material and its subsequent bond quality. In deviated or horizontal wells, mud settling, and subsequent segregation leads to azimuthal and depth uncertainties in annulus evaluation. Typically, due to gravity, mud segregates, with the light component at the top and heavier component at the lower side of the well. In a non-homogeneous mud, using a single mud impedance value for computing acoustic impedance of the annulus can lead to ambiguous answers with uncertainties. Traditionally, it has been a challenge to accurately measure and apply these variations in acoustic impedance of the mud to precisely interpret the bond quality in the annulus.
A novel pulse-echo processing scheme called R+ inversion, based on a 3-parameter inversion approach, eliminates, to a great extent, the dependence on prior knowledge of the borehole mud. The 3-parameter inversion can also reveal conditions such as mud deposition and segregation in deviated pipes. This new processing enables easier and accurate interpretation of the annular content together with essential information about the logging fluid.
Four case studies established the successful implementation of R+ inversion in deviated wells in the Norwegian Continental Shelf (NCS) with azimuthal uncertainties in the mud acoustic impedance to provide reliable annulus interpretation. These measurements correlate and are validated using sonic logs as well as flexural attenuation measurements, thus providing confidence in the results and decisions. The case studies compare acoustic impedance results using legacy processing and R+ inversion processing. The limitation to use the azimuthal variations of mud in the traditional processing sometimes leave unanswered questions related to the bond quality affecting the intervention decisions expected from the bond log. With the help of R+ inversion, the operator managed to take informed intervention decisions faster, thus saving rig time and cost. Four case studies are explained in the details that demonstrate and validate the importance of R+ inversion when borehole mud settling occurs azimuthally, thus overcoming previous limitations of mud impedance computation and usage.
Cement evaluation using R+ inversion enables accurate and critical decision making during new well construction, intervention, plugging, and abandonment in all conditions, irrespective of the casing sizes and cement types.