bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pioneering Rigless Perforating, Clean-Up Operation, Well Testing with MPLT and Bottom Hole Sampling in Remote Platform
Authors: Preveen Preveen Kumar , Adhi Adhi Naharindra , Shazana Shazana M , Mior Mior Yusni , Nurbaiti Nurbaiti Baharuddin 
Published: November 2018

Abstract
Optimization of mature fields in maximizing the hydrocarbon recovery has been a major concern for exploration and production companies including Malaysian oil companies. Field A was discovered as gas field in 1980. A minimum sized 4 slot remote wellhead jacket with no processing facilities and helideck was installed for the development of the field. Oil bearing reservoirs were encountered in two blocks at Zone 5 during the gas development drilling and was not part of the original PSC.
As part of commitment to Malaysian host authority after taking over the field from an Independent Oil Company, the Project Management Team (PMT) were required to submit the Project Field Development (PFD) for oil reservoir development. Thus, perforation, sampling, well testing and logging were planned at well 1 to obtain representative fluid sample for PVT analysis and flow assurance studies. Considering the current downturn in the industry, critical decisions were made to conduct this campaign without the assistance of a drilling or workover rig which led to challenging phase of planning and execution within limited time frame. Through further optimization, the campaign kick started with a stringent budget and selection of concept which eliminated the requirement of a rig in order to achieve the objective set. A conventional Well Testing package with independent power source, lifting capability, wax management and heat radiation control was selected in order to meet the objective with the full capability to conduct well clean up, Multi Rate Test, Memory Production Logging and bottom hole PVT sampling.
The strategy of execution had led to a successful campaign with no HSE issues and fast tracked the project delivery by minimizing operation duration up to 1 month which resulted in 49% of cost saving (compared to the total planned project cost). The objectives of testing the reservoirs and understand the flow behavior of stacked layers of sand were achieved with sufficient bottom hole samples collected for facilities studies and field development " Figure 1Map offshore Malaysia
Sand Containment in Deep Gas Fields
Authors: Al Kindi Osama Mohammed , Dobroskok Anastasia , Pande Shriram , Mahruqi Salha , Regan Timothy , Winchester Arlene , Lawati Basayir 
Published: November 2018

Abstract
In the central area of the Sultanate of Oman, gas and condensate from five different fields are processed through one gas production station which has been in operation for over 10 years. Despite the highly consolidated nature of these deep sandstone reservoirs, sand was observed in the inlet separators. This work will: Illustrate the methods used to identify the source of sand (field, well, and formation).Establish short, medium, and long term solutions.
A strategy was created to investigate the source of sand and the extent of damage inflicted on the facility. Mitigation measures in the form of short to long term solutions were also implemented, addressing issues arising both in the surface and subsurface. Monitoring included clamp-on sand detectors and Sonic MPLT with camera with mitigation work including modification of the inlet separator and desander installation upstream the inlet separator
Two fields were identified to be the potential source of sand, based on the clamp on sand detection campaign. One field has commingled production from three reservoirs and was later confirmed to be the true source of sand; the second field was identified to be producing frac proppant only. Different techniques were used to narrow down the sand producing reservoir by comparative study of the minerology of existing core and produced sand samples, sonic MPLT with camera, modeling of formation stress mechanics, and other means of WRM interventions. Results concluded that sand production was not limited to a single reservoir yet the deepest is the major contributer.
To maintain the integrity of the facility, both surface and subsurface mitigation measures were assesed.
Due to limitations in the existing well completions, surface solutions were preferred.. By evaluating the facility, it was decided to modify the design of the inlet separator to trap the sand and clean it out periodically. In addition, well flow rates were constrained to below the erosion critical velocity to avoid any loss of containment. Finally, an integrity test was conducted to the flowline and equipment (from wellhead to export line), to create a surveillance and maintenance strategy to prevent facility damage. In summary: Modern technologies including Sonic MPLT with Camera proved capable of identifying the formation responsible for sand production under the conditions of fluid clarity and flow condition (Turbulent.Deep, well consolidated sandstone reservoirs are capable of sand production due to depletion and or water production.The facility downstream was protected by means of a simple modification to the inlet separator, demonstrating a simple and unconventional solution.Sand management system usage enabled sand removal from the inlet separator water stream during production, preventing loss of production.
Integrated Geological Modeling for Higher Confidence Development Decisions, Sultanate of Oman
Authors: Lars Hendrik Bellmann 
Published: November 2018

Abstract
Thermal EOR projects are technically and economically challenging projects. Improving the geological understanding and implementing these geological concepts into the static model were key to increase the robustness of, not only the geological model but also of the dynamic simulation.
The initial believe was that fine grained and mm scale laminated sediments act as vertical baffles for the steam distribution. The fine grained sands were low in permeability and the lamination were further reducing the vertical permeability. Grain size had the main impact on permeability and grain size was correlated with V-shale. Then, V-shale was used as a proxy for grain size and was integrated into a V-shale base porosity-permeability transformation.
After modeling the baffles explicitly, it was shown that against the initial belief, the main control on fluid flow was not a patchy baffle distribution. Instead the reservoir was overall reduced in vertical permeability. A lager impact had the V-shale base poro-perm transform, predicting an order of magnitude permeability range for a given porosity. Reducing the impact of the facies also reduced overall the uncertainty and improved the predictive power of the models. This in turn, helped to take development decisions with much higher confidence.
Innovative Approach to Enhance Reservoir Sweeping Efficiency Using Open Hole Swellable Packers in Gas Injector to Isolate Undesired Reservoir Section in Carbonate Reservoir Field of Abu Dhabi, UAE
Authors: Soufi Abdulrahman , Prahawinarto Bambang , Abdussalam Fouad , M. Khan Asif , Ashour Samer , Baudot Pascal , ElBarbary Abdalla , Salama Sheirf 
Published: November 2018

Abstract
Gas Injector Well is part of the project to improve the pressure communication between peripheral gas injectors and nearby producers in the Northern Part of Unit G WAG Patterns. This well was injecting gas only to upper part of Unit G reservoir based on the PLT and TGT results. Based on the study using tracer chemical injection, this upper Unit G reservoir was found to be in connecting with another nearby different reservoir.
The initial plan was to re-horizontalize the well and place injector in the proper reservoir, later this was changed and revised to use this innovation technology by installing blank liner with isolating packer to isolate the upper part of Unit G reservoir and let the lower part of open-hole remained open and connected to the required layer of reservoir.
After extensive discussion with vendors and performing simulation runs, finally agreed to run this kind of swell packer. Vendor custom designed this kind of innovative packer at their USA facility and transported to ADNOC Onshore yard just before the execution phase. First run the swell packer on blank pipe and placed it at desired depth in the open hole, later run upper completions and sting into the top packer of lower completion.
This way, we were able to inject gas into the lower part of reservoir Unit-G only, whereas the upper part was remained isolated completely. Using this technique saved company additional 2 million and extra time for re-horizontalization.
Well Placement Assessment Using Sequence Stratigraphic Zonation in a Complex Carbonate Reservoir
Authors: Salahuddin Andi A. , Khan Karem A. , Al Ali Reem H. , Al Hammadi Khaled E. 
Published: November 2018

Abstract
The paper is continuation of our previous work published in the SPE-192896. This work illustrates horizontal well placement sensitivity analysis that was conducted on a complex Valanginian (Cretaceous) unsaturated oil carbonate reservoir with strong water drive. Existing producer wells are 80% horizontal and the remaining 20% are vertical to deviated producers. The production history is the approximately 20 years and currently a peripheral water injection is implemented, all injector wells are horizontals. The well placement is very challenging due to the presence of some thin high permeability streaks intervals with permeability value of up to 1 Darcy. Early water breakthrough encountered in the existing oil producers is a serious problem which results in lower recovery factor and costly lifting treatment. In addition, premature breakthrough would leave behind the potential oil accumulation. Therefore defining the optimum placement location of the producers is a crucial decision to be decided during well plan and field development.
In this paper we applied novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution using a pre-defined High Resolution Sequence Stratigraphy (HRSS) model subzonation. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties. In this study, we apply integrated geosciences, geostatistical, and flow simulations to assess options for well placement.
This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target.
Flow simulation was used to analyze the performance of the well considering horizontal the well azimuth, well inclination, wells length, wells position relative to the sequence stratigraphic zonation, and well position relative to the water contact. In addition, multi-scenarios of well placement were created to see the impact on the oil rate, plateau, and water breakthrough time. Some producers in the studied reservoirs have been drilled using the multidiscipline study recommendation. Actual property and rate derived from the newly drilled wells displayed a very reasonable match to the expected property from the model.
Successful Installation of Tubing Patches to Restore Well Integrity Leads to Remarkable CAPEX Saving at Water Disposal Well WDW
Authors: Siddiqui Muhammad Ali , Hassan Syed Saadat , Mubasher Muhammad , Latif Saqib , Dar Usman Anjum 
Published: November 2018

Abstract
The objective of writing this success story is to demonstrate how technology, in particular low cost solutions, are key to economically sustain and secure production from mature fields. Tubing Patch technology has been successfully utilized in Pakistan for the first time to restore the well integrity and saved huge CAPEX by avoiding expensive rig workover.
Tubing-Annulus pressure suddenly increased in one of water disposal well (WDW). Annulus pressure varied directly with variations in Injection rates which were the clear evidence that tubing-annulus communication had been established and basic check ascertains that well had integrity issue. Being the only injector in area all production and processing of gas is majorly dependent on its injection reliability and integrity. After detailed in-house working it was decided to run diagnostic logging with spinner (quantitative) & temperature log (qualitative) to identify the leakage points precisely. All potential leakage paths (packer, tubing, tool joints) were considered while selecting the diagnostic techniques to have conclusive results. Based on diagnostic logging three leakage points were identified. Before proceeding for remedial measures to restore the well integrity, it was mandatory to check health of old carbon steel tubing string therefore it was planned to acquire corrosion log. Based on corrosion logging results, completion tubular was established in good condition which steered to install tubing patches best Techno-Economical solution across the leaks to restore well integrity instead of rig workover for re-completion.
Consequently, three tubing patches, were successfully applied using wireline in water disposal well and integrity of well was restored. C-Annulus was pressure tested even after six months of installation and no pressure drop was observed during this interval.
Downhole High-Power Laser Tools Development and Evolutions
Authors: Batarseh Sameeh , San Roman Alerigi Damian , Reece John , Othman Haitham 
Published: November 2018

Abstract
The objective of this work is to present the development and evolutions of different high-power laser tools and their subsurface applications. These tools provide innovative and non-damaging alternatives to current downhole conventional technologies. In the lab, the laser technology has been proven to improve the flow properties and communication between the wellbore and formation. To achieve this efficiently in the field it is necessary to develop different tool designs and configurations, manufacture prototypes, conduct extensive tests, and optimize each part before upscale for field operations.
The laser source is mounted in a coil tubing rig at the surface; the coil contains the optical fiber cable used to convey the energy to the downhole tool. The tool combines mechanical and optical components to transform, control, and direct the laser beam. The design and configuration of each tool assembly varies depending on the targeted application. For example, the perforation tool converts and splits the beam into several horizontal beams; whereas the drilling tool emits a straight beam with controlled size for deeper penetration. They also incorporate purging capabilities to circulate gas or fluid to clean the hole from the debris and carry the cuttings. The entire assembly must be made to fit in slim holes as small as four inches. And finally, ruggedized to operate in a complex environment with high pressure and temperature.
The technology improves reach and provides versatility in a compact and environmentally friendly manner. For example, it is a waterless technology when it is used for fracturing, and a non-explosive based perforation when it is used to perforate. The unique features of the technology enable a precise, controlled, and oriented delivery of energy in any direction, regardless of the reservoir stress orientation and magnitude. Thus, it enhances reach to produce from pay zones that are bypassed by current conventional technologies and practice. The motivation to search for alternative technologies is the advancement of technologies including high power lasers, also the need to enhance several applications in deeper wells in an environmentally friendly manner.
First Abu Dhabi 2D/3D Seismic Merge. Fast Track Approach For Seismic Data Integration at Regional Scale in Exploration Studies
Authors: Parra Humberto , Caeiro Maria Helena , Neves Fernando , Gomes Jorge 
Published: November 2018

Abstract
One of the main challenges in the execution of regional studies is the integration of large amounts of data coming from different sources and different disciplines. Even within the geophysical domain, integration of thousands of 2D seismic lines and dozens of 3D seismic volumes is a very demanding task. The aim of this paper is to provide a description on the use of fast track methodologies for the integration of 3D and 2D seismic data at country level for regional studies.
This approach relies on a pragmatic way of merging seismic, processing data as point sets instead of traces, providing the flexibility of handling seismic information inside the geomodelling and geostatistical domain, where a grid of points can be resampled, reoriented, and ultimately merged into any desired geometry and resolution. The technical challenges include different spatial sampling, grid orientations, frequency contents and event timings. A preconditioning step has been included in the workflow in order to homogenize the data into a common ground, addressing compatibility issues of the different vintages through amplitude scaling, noise reduction and frequency balancing.
Merging in a practical approach different 2D/3D seismic data sets into a single volume reduces drastically the amount of time spent in the data analysis and interpretation of geological features at regional scale. In this case of study, the workflow enables a feasible path for merging all seismic data acquired in Abu Dhabi over the past seven decades. The integrated volume helps geophysicists and geologists to carry out better seismic interpretations and perform proper structural analysis and prospect assessments. Finally, the seismic data has been integrated into a unique survey by interpolating the 2D and 3D seismic data to fill the gaps and generating a pseudo 3D survey at country scale. This regional scale single 3D seismic data allows better understanding of the geological and structural trends present in Abu Dhabi.
This innovative approach offers a major advantage for regional data integration, expediting subsequent stages of seismic interpretation and description of the geological features at large scale for exploration assessments, prospect generation and 3D reservoir characterization.
Opportunities for CO2 Utilization Other Than EOR
Authors: Singh Prachi , Geuzebroek Frank 
Published: November 2018

Abstract
The historical agreement on international climate change at COP21 in Paris in December 2015 by 196 nations has accelerated the efforts to lower impact on climate change. The agreement contains the ambitious long-term global goal to limit global warming to "well below 2°C above pre-industrial levels and to pursue efforts to limit the temperature increase to 1.5°C". The International Energy Agency (IEA) has clearly stated that limiting global temperature rise to 2°C will require the energy sector to deploy carbon capture and storage (CCS). Hence, CO2 capture and suitable CO2 utilization option should be explored.
Proactive Application of Human Performance Science in Risk Assessment Process within Dynamic Operations of an Oilfield Service Provider
Authors: Yasseen Abdelsalam , Peresypkin Sergey 
Published: November 2018

Abstract
Human performance principles, which are well developed in aviation and healthcare, still represent an emerging science within the oil and gas industry. The industry managed to significantly reduce injuries over the last decade with multiple programs ranging from HSE Leadership to Behavior-Based Safety to the point when the incidents plateaued according to IOGP and IADC incident statistics. This triggered a deeper look into human performance best practices and their applicability within the oil and gas sector. This paper aims to provide an alternative approach to adopt Human Performance science to the dynamic operations risk assessment process within an Oilfield Services Company. After the analysis of the existing human reliability assessment tools, a decision was made to adopt a human performance tool known as Human Error Assessment & Reduction Technique (HEART) into a service provider’s risk assessment process with a primary focus on Error Producing Conditions (EPC). An internal survey was undertaken to define Error Producint Condition, which are most relevant to the dynamic nature of oil and gas services operations and couple them with the Reasons’s performance modes and their effect on error appearance. This approach allowed to significantly simplify the risk assessment process and adequately focus on key factors known to produce conditions for human error. This naturally integrated into our existing qualitative risk assessment to recalculate the overall risk of a certain task and enhanced workers’ ability to recognize potentially dangerous external and internal factors.
The field tests of the improved human performance risk assessments reshaped the standard risk assessment practices, moving the focus to and targeting the inherent unreliability of the task as a result of error producing conditions caused by unavoidable human interactions within the complex systems. This approach proved effective in improving the overall understanding of dynamic human reliability related risks among the front line employees by around 30%. The hypothesis is that by introducing key human performance factors to the day-to-day risk assessment will help build awareness of human factors and their relationship to the probability of an existing risk. At the same time, utilizing an already effective system – risk assessment – to introduce human factors methods will help avoid the complexity associated with its implementation of an additional human reliability tool and still get the benefit of key elements of a well-established method.
This approach has undertaken to combine two existing effective systems: a standard risk assessment with integrated human factors under a customized umbrella fully suitable for Oilfield Service Company’s work specifics. This paper provides insights on how human factors can impact the level of risk and outlines the control measures targeted at such factors that can be missed if a standard risk assessment is applied.