bluuebunny/crossref_metadata_2025_split huggingface dataset:
Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment
Authors: Almohammad Humoud , Al-Derbass Abdullah , Alsubaie Abdulaziz , Bumajdad Mohammed , Al-Khamis Abdulaziz , Alshammari Abdullah , Al-Tameemi Talal 
Published: November 2018

Abstract
An offshore gas field located in a cold area; with an average temperature of 13 Celsius degree and −1.2 Celsius degree under sea level. The reservoir is located 200 meters under the sea floor, where the sea floor is 850-1100 meter depth and 120 Km away from shore. The objective is to develop an offshore production system for the gas field and maintain the necessary production, taking into account flow assurance, economics, and environmental effect.
The required design includes reservoir pressure forecasting, completion design, drilling strategy, and production flowline network modeling. The first step was forecasting the reservoir pressure by trial and error equation, then completion design to calculate the possible production increment from every well and calculate the cumulative produced volume to predict the changes in the fluid composition. The drilling strategy and completion design were carried out under the following assumptions: wells are having same completion design, production rate, and static reservoir pressure. The production network simulated with the designed completions using a steady-state multiphase flow simulator, with the sub-sea template and manifold strategy.
For the flowline network, polyurethane coat was used for each pipe to reduce the heat transfer from the sea water to the flowing fluids. The back-pressure equation was used to develop the IPR model and flash separation to predict the gas composition changes assuming the reservoir is an isothermal system. The base year started with eight wells, to achieve the required production per year, 70 MMSCM per day. Erosional velocity ratio kept under 1 for the designed 16 years. Pipelines coating was required to prevent flowline damage and deal the forming hydrates. A total of 30 wells to be drilled to cover the production needed for each year.
An offshore gas field study is explained in details with the simulation design procedure and pre-planning strategy for harsh cold environment flow assurance concerns and production difficulties. In addition to helpful estimation equations.
The Effect of Temperature on Estimating Free Fluid Index FFI by Nuclear Magnetic Resonance Measurement: Phase 1 Study
Authors: Kwak Hyung , Gao Jun , Harbi Ahmad , SayedAkram Nawaf 
Published: November 2018

Abstract
Since the initial introduction of Nuclear Magnetic Resonance (NMR) Technology into the oil and gas industry as a lithology independent porosity measurement technique, NMR well logging has been providing various valuable Petrophysical reservoir properties, such as porosity, permeability index, pore size distribution, and fluid typing, etc. To increase the reliability of these NMR log data interpretation, core-log integration, combining log and laboratory data, is necessary. For example, T2 cutoff values which determine the bulk volume of movable fluid (BVM) from NMR log data are determined from laboratory NMR measurement since it requires the measurements at 2 different saturation levels which is not possible at the reservoir with current technology. Unlike NMR logging in the field, however, most of laboratory NMR measurements are conducted at room temperature and pressure. Until recently, the temperature effect on NMR relaxation data is considered to be minimal since the surface relaxation is the dominant proton spin relaxation mechanism within confined porous media, such as reservoir rock. There have been a few experimental works during the early period of NMR technology application in well logging shows minimal temperature effect on that in reservoir rocks.
Recently, this phenomena has been re-investigated and been shown there is non-negligible temperature effect on the shift of NMR relaxation time. In the current work, the NMR T2cutoff values at various temperatures for 6 carbonate reservoir rocks with multipore system have been measured. Upon the verification of temperature dependence of NMR T2 cutoff values for reservoir rocks, further investigation of identifying elements that cause this phenomena has been initiated.
A Petroleum Systems Analysis and Characterization of the Frontier Ceduna Sub-Basin in Australia
Authors: Alghuraybi Ahmed , Al Harthi Al Muhanna , Jabry Ahlam Al 
Published: November 2018

Abstract

Objectives/Scope
The Ceduna Sub-basin is one of the few remaining frontier basins in Australia today. Few exploration wells have been drilled in the basin and none have encountered hydrocarbons. The current study aims to investigate the hydrocarbon prospectivity of an area of interest (AOI) within the distal part of the Ceduna Sub-basin, where no well information is available.

Methods, Procedures, Process
The study uses 3D seismic data and employs principles from geophysics, structural geology, sedimentology, sequence stratigraphy, and petroleum systems analysis in a comprehensive investigation to understand the Ceduna Sub-basin. Multiple 2D basin models were created for the AOI to test different scenarios in a detailed risk analysis of the petroleum system and its major controls. They were identified from a comprehensive literature review and after a thorough interpretation of the 3D seismic survey in the AOI.

Results, Observations, Conclusions
Results show that the best reservoir is located within the low stand systems tract (LST) deposits of the Hammerhead Sandstone (Ss) and Top Tiger Ss. The potential source rock occurs in the condensed high stand system tract (HST) deposits in the Base Tiger Ss and White Pointer Ss. 1D modeling showed that these source rocks may have generated hydrocarbons as their depth is &lt;9 km. The critical moment during the source rock history was at 80 Ma coinciding with the deposition of the Hammerhead Ss.
Based on the regional structural framework, faults were initiated after source rock deposition. Several growth faults may pose a risk in terms of hydrocarbon leakage. Different 2D models have advanced the understanding of the petroleum systems in the AOI. The results showed that the most prospective areas are within a rollover anticline play and those areas where intra-formational seals are present. The model confirms that fault integrity represents the prime risk across the basin.

Novel/Additive Information
The current study contributes to understanding of the Ceduna Sub-basin by identifying two different plays in the AOI: rollover anticline and tilted fault block. Probability analysis of the different petroleum elements shows that the rollover anticline play has the highest geological probability of success.
Improved Imaging for Fault and Fracture Characterization: Southwest Onshore Abu Dhabi Case Study
Authors: Vargas Jose Edgardo , Shaukat Kashif , Elila Abusaa , Kumar Pankaj 
Published: November 2018

Abstract
The oil and gas industry has advanced over time in terms of seismic data acquisition. From conventional data acquisition to full/wide/multi-azimuth broadband data, there is an abundance of subsurface information aimed mainly at enhancing structural resolution, for improved prospect definition. Conventional seismic imaging tends towards the higher amplitude specular/continuous part of the seismic dataset for generating reflection events. During this process amplitudes or energy related to small scale features and faults can be contaminated, therefore in order to capture that information, it is essential to preserve the wavefield while imaging.
New Advanced PVT Course Helps Masters Students to Find Solutions to Real Industry Challenges
Authors: Williams John M. 
Published: November 2018

Abstract
This paper describes an educational case study covering the development and presentation of a new petroleum engineering master's course in advanced phase behaviour. Emphasis was placed on current industry challenges, interpretation of real data and visits to industry facilities. Special attention was given to fluid sampling experience. A variety of challenges and possible solutions are covered, and benefits to both full and part-time students, the next generation of industry professionals, are described.
The PE graduate program saw increasing numbers of students so more industry-related technical elective courses were required. Several courses were proposed and the Advanced PVT course was selected based on student preferences. The course was developed with a mix of lectures, computer laboratory classes, information group use, industry visits, presentations, and semi-obligatory attendance at local SPE meetings. Assignments included literature searches to find interesting publications about sampling, and personal project assignments. These were excellent for practising engineers who could analyse and report on field case studies.
Due to students’ various backgrounds, course content was modified to review material that is more basic. Industry students benefited from the opportunity to concentrate on specific challenges, discuss issues outside their company and learn from other participants, but had to manage the pressure of work. Full time students had more time for studies and out-of-classroom teamwork, but had little experience to share.
Choice of suitable course textbook is discussed, with details given of other supporting literature used, especially in the areas of fluid sampling and compositional analysis, where common phase behaviour texts are very limited. The course syllabus, detailed delivery techniques, example assignments and teaching tips are provided.
This is believed to be a novel case study, with no similar subject being found in SPE OnePetro publications. With continuing shortages in university PE schools, this material can help young faculty and adjunct faculty develop new courses more efficiently. Teaching at Masters level was seen to increase faculty access to students starting thesis research projects. A selection of industry participants’ recent experience in fluid sampling in the UAE is given and it is intended to incorporate it in future best practice procedures.
Gulf of Mexico Gas Export Modification Pipeline Installation – A Two Vessel Solution for PLEM Initiation Without a Pile
Authors: Samimi Mohammad , Aden Gerard , Guynn Richard Carl , Duffy Rebecca 
Published: November 2018

Abstract
The ∼18 km long 10" pipeline was installed by MCDERMOTT as part of a gas export modification development in the Gulf of Mexico. The pipeline was initiated with a 97 Te dual-hub PLEM at a water depth of 1535 m. The fast track nature of the project required the PLEM design and fabrication to be carried out in a short time in collaboration with the installation analysts to ensure installability. Initiation of the heavy PLEM at the end of a thin wall pipe in deep water posed considerable challenges in developing an installation methodology. After evaluation of all alternatives, employing an LCV to help with PLEM initiation in a flooded condition was deemed necessary. The LCV crane was deployed after PLEM reached a certain height over the seabed. A sequence of LCV and LV-NO105 movements, pipelay tower angle alteration, and pipe and LCV crane wire payout was followed to transfer the PLEM weight to the LCV crane and rotate it to horizontal. The rigging from a clump weight, which had been installed earlier as merely a contingency hold-back device, was then connected to the PLEM. A sequence of LCV movements, LV-NO105 movements, pipe and crane wire payout was followed to land the PLEM safely on the seabed. The crane wire was disconnected after laying a short length of pipeline on the seabed. The installation procedure was developed such that the sling between the contingency clump weight and PLEM remained slack. The PLEM weight was sufficient to provide the necessary horizontal holdback, after landing in the target box, for normal pipelay. The LCV crane operated in various modes (constant tension and active heave compensation) to ensure a smooth initiation process. Maintaining a smooth synchronization of activities shared between LCV and LV-NO105 was crucial to success of the project.
Tracking the Performance of Strategically Significant EOR Pilot: Zooming into Inter-Well Connectivity
Authors: Al-Qenae Amna , Chetri Hom , Kumar Priya Ranjan , Orjuela Jaime 
Published: November 2018

Abstract
North Kuwait has planned EOR activities to boost ultimate recoveries in multiple reservoirs. The reservoir with the highest priority on the EOR activity Gantt chart is Alkaline Surfactant Polymer (ASP) flood for Sabiriyah Mauddud due to significant incremental recovery estimated based on past SWCT tests. Prior to the initiation of ASP injection, slated pilot area is under intensive plumbing for insights into the inter-well connectivity. The paper proposal aims to share the actions taken up, analysis done and tracking of dynamic data for the area located within & adjacent to the EOR pilot area.
Data acquisition for the pilot area wells (4 injectors; 2 observation wells & 1 producer) has been done in two phases — (a) during the drilling of the wells, cores/ RFT pressures/ Log suites/ PVT samples have been taken and (b) during the injection of sea water into the EOR pilot injectors, time lapse pressure-production data/ surveillance information & tracer sampling/ analysis have been done to understand the inter-well connectivity; flag the uncertainties and de-risk the EOR pilot as a preparatory background for studies & ASP injection.
Connectivity between wells within the pilot & surrounding area under active water flood has been established. Pathways for quick fluid/ flux movements have been identified and calibrated with the petrophysical data. Tight zones or compartments within the pilot area have been examined. Uncertainty regarding thief zones within & outside the pilot area has been evaluated. A comprehensive data integration indicates that continuing with ASP injection will be optimal, with minimal losses/ escape to the area outside the 5-spot EOR pattern.
De-risking the upcoming ASP injection via proper data acquisition, interpretation & integration during the preliminary water flood flushing stage is one of the best industry practice.
Electrical Energy Savings in NGL Extraction Plant by Implementing ON/OFF Sequence Logic Control for Fin Fan Coolers
Authors: Bametraf Rashed 
Published: November 2018

Abstract
This presentation describes the efforts undertaken by ADNOC Gas Processing's Buhasa site to save electrical energy in the NGL extraction plant by minimizing fuel gas consumption in power generators. This also contributes to a reduction in flue gas emissions.
During 2017, ADNOC Gas Processing pursued actions to save electrical energy in air fin coolers by implementing a sequential ON/OFF control logic to achieve a saving of 1,265,600 kWH. The implementation did not occur any costs, as the project was realized completely with in-house resources.
Successfully Deploying & Retrieving 6,200ft of Perforating Guns Over Six Challenging HPHT Wells
Authors: Gopalan Bathmanaaban , Craig Steven , Chong See Yung , Bouzaine Cherif , Pouget Pascal 
Published: November 2018

Abstract
A six wells campaign to single-run perforate long completion intervals was undertaken in Brunei. The offshore field presented inherent challenges due to high pressure, temperature and long perforating intervals. A major challenge was to perforate underbalance to reduce potential permanent formation damage. The solution proposed for this high pressure and high temperature (HPHT) perforation was to use a high grade of coiled tubing (CT) with live-well gun deployment and retrieval system. The live-well gun deployment system utilizes perforating connections designed to support the gun weight, firing shock loads and ballistic transfer. The connection and break-out are facilitated via specialized rams in a dedicated BOP body in live well conditions. A 130-ksi yield strength CT string was engineered to withstand high tensile forces from running up to 1,150-ft of guns to depths of 18,000-ft in near vertical wells and provide a suitable safety margin when high collapse pressures were present. However, when perforating with long gun lengths, high dynamic shock loads will be experienced by the CT string. Thus, for all the wells, two software systems were used, traditional CT force analysis program and a gun force software for the short duration transients present during perforating. There were numerous continual improvements implemented during the duration of the campaign and one of them was maximizing the underbalance perforation up to 5,500-psi. Although such high underbalance was not a standard practice in the industry with CT, it was carried out after a comprehensive study and review to perform the operation safely and efficiently. There were no recordable safety issue throughout the two years campaign where more than 6,230-ft of guns were ran and live-well reverse deployed. The campaign was successful and operator expectations met. This paper outlines the characteristics of this campaign from the planning stage up to operational execution and efficiencies recorded over the six wells campaign. Well control mitigation practices and general contingencies will be detailed. This paper will act as a suitable reference for future operations.
Comprehensive Methodology to Evaluate Blowout Probability Through the Combination of Geological Uncertainties, Human Errors and Equipment Reliability
Authors: Zausa Fabrizio , Spelta Andrea , Lorefice Roberto 
Published: November 2018

Abstract
The most significant threat to oil exploration and development is an uncontrolled release of reservoir fluids during drilling operations, commonly called a blowout. Besides its tragic environmental and human impacts, Macondo accident fostered the awareness in the industry that blowout risk goes further the idea of an implicit risk of drilling activities: blowout is an operative risk to be properly assessed, as reported in the European Directive 2013/30/EU on offshore operations. In order to tackle such request, Eni developed a standardized methodology called e-wise™ (eni Well Incident Systematic Evaluation) that provides an objective and reliable assessment of blowout risk.
As a prelude, the common criteria based on statistical occurrence of blowout was considered neither exhaustive, nor accurate. Actually these statistics are suffering from many limitations: limited time span, outdated technologies, inconsistent environment (now deeper wells), variety of technical approaches, and no consideration of risk exposure duration.
ENI decided to measure blowout probability with a comprehensive methodology accounting for the three key elements affecting blowout occurrence: geological uncertainties, equipment reliability and human errors. The methodology put together automatically in properly designed fault tree, the three root causes and it applies them on specific well designs.
The result of this approach is a standard way to calculate blowout risk that can be applied on rig/rigless operations, supporting well engineering and permitting process. This solution, named e-wise™ is able to generate two types of standard outputs: full breakdown of blowout frequency by section/flowpath and extensive bow-tie for communication and certification purposes.
The full breakdown of blowout frequency allows the engineering and the operations to focus their attention on the most critical phases of the well. The model can be used for further sensitivity analyses foreseeing alternative operating procedures or additional safety technologies in order to have an univocal assessment of their benefits in term of blowout probability reduction. As a matter of fact, specific R&D programs are assessed through e-wise™ to address their potential value in terms of safety improvement.
The bow-tie depiction of the results provides a synthetical representation of all detailed calculations, where some models encompass more than 20 scenarios, each one having dozens of sub components. A bow-tie supports the communication of the results toward management and authorities by giving a complete vision of the blowout with the relative reliability of safety barriers and the different impact scenarios including containment and relief strategies.
Optimization of Design Using Computational Fluid Dynamics Technique for New P&A Down Hole Milling Technology - Case Studies of Rig Run Comparisons Validating Design Changes
Authors: Haq Mohammed , Deshpande Kedar , Imtiaz Khalid , Smalley Michael 
Published: November 2018

Abstract
Hydrocarbon migration after plug and abandonment (P&A) operations negates well integrity and threatens the environment. A section milling procedure for P&A that achieves rock to rock bond eliminates the risk of releasing fluids and gases to surface. This section milling procedure usually involves milling a window in the inner casing and then creating another window in the adjacent outer casing. The tool developed for this process is commonly known as dual string section milling (DSSM) tool. Simulations using advanced finite element analysis (FEA) and computational fluid dynamics (CFD) prior to prototype manufacturing is an extremely useful guide for predicting performance, optimizing design and avoiding costly oversights. This results in higher quality of design of pioneering or innovative products while reducing development costs and time to deliver tools to field.
The scope of this paper is to discuss design optimization using CFD that resulted in efficient flow distribution leading to elimination of wash out issues during field runs, while highlighting case studies summary based on design changes made to the new dual string section milling tool. Initial testing of dual string section milling tool design was done on test drilling rig that revealed some erosion prone areas in the tool; this design was modified using CFD to eliminate these erosion prone areas. However, during field runs in salt dome reservoir applications, the erosion issues reappeared in critical flow areas. Further CFD analysis was conducted to eliminate erosion in critical areas to formulate the final product design. The goal was to develop an optimized design delivering extended milling times when the section window requirements were 100 feet or more without any washout or erosion issues while using high pump flow rates.
This paper discusses the optimized dual string section milling technology using advanced computational techniques. The development of this technology is an enormous time saving for operators versus using conventional methods- in one offshore field case it resulted in more than 20 days savings in milling time.