bluuebunny/crossref_metadata_2025 huggingface dataset:
Text-Mining Maintenance Records to Automate the Identification and Grouping of Failure Modes
Authors: Christopher Pereira Paul
Published: April 2020

The investigation of failure data typically involves manual interpretation of free text maintenance system records. Even if failure classification codes exist within an organization's system, they often do not include enough detail or accuracy to group or identify trends. The objective of this study is to develop an automated method to identify functional failures from maintenance record data. The result is a reduction in workload for manual analysis, as well as improved identification of failures and trends.

This study's methodology involves the sequential arrangement of multiple text-mining techniques. The techniques include: term frequency-inverse document frequency (TF-IDF), clustering, association rules, term matrix creation, and lexicon development for pre-processing text. In isolation these techniques have shown to be effective in non-industrial pursuits, such as marketing and retail sales. This study serves to apply them in the domain of equipment reliability. They are iteratively implemented and refined on maintenance system records, including work orders (which may or may not represent failures), as well as failure report records. The ability to identify failure modes, failed components, and trends is then evaluated.

The techniques were successfully implemented, and the effectiveness was evaluated for each when applied to science of equipment reliability. Text mining was shown to be partially effective in the pursuit of identifying failure modes from maintenance record free text. Certain sub-techniques were shown to be quite effective, in particular the clustering technique's ability to group failed components and failure modes. Hierarchical clustering is a promising technique for technical and industrial themed free text. It was also shown that the outputs of clustering can achieve different and valuable insights based on the types of text records implemented, and the types of pre-processing available to the organization. The association rules method was somewhat effective relative to clustering, as it was able to identify certain failure modes; however, this method still requires a degree of manual intervention and interpretation at this time. The overall results are promising. There is great opportunity for continued study along multiple fronts, including additional techniques such a sentiment analysis and topic modelling.
A Digital Twin of Drilling Fluids Rheology for Real-Time Rig Operations
Authors: Samnejad Mahshad , Gharib Shirangi Mehrdad , Ettehadi Reza
Published: April 2020

In drilling operations, the rheological properties of the drilling fluid (‘mud’) are measured at rigsite at ambient temperature using sensors in real-time. These measurements, however, are required to be reported at the API standard temperature (120/150 oF). As the rheological properties of the drilling fluids vary significantly with temperature, it is essential to calibrate sensor measurements at the ambient temperature to the API standard. Previous attempts in the literature to build data-driven frameworks for predicting drilling fluids behavior demonstrate limited success due to restrained data access, neglect of the physics, and/or use of improper algorithms, such as neural networks which are shown to perform poorly despite their popularity. In this work, we develop a digital twin to calibrate the rigsite rheology measurements for obtaining the API standard properties by exploring the use of a set of promising machine learning algorithms. A dataset composed of various drilling fluids composition with rheological measurements at both rigsite and API conditions is collected. Our results demonstrate that the ensemble algorithm outperform other commonly used methods, such as regularized regression, polynomial regression, and neural networks. The optimized integrative model is deployed on a platform at rig for use at real-time drilling operations.
On the Development of an in-House Fines Stabilizer to Control Formation Damage
Authors: M. Ibrahim Jamal Mohamad , Mat Piah Mohamad Faizzudin , Panuganti Sai Ravindra , Salleh Intan Khalida , O. Hussein Adil Mohamed
Published: April 2020

Almost all Malaysian hydrocarbon-bearing sandstone reservoirs contain minerals which are potential sources of mobile fine particles. For this reason, formation damage in injection and production wells has been frequently associated with the migration of fines in reservoir pores. In this work, an effective, novel, environment friendly and cost beneficial fines stabilizer is formulated in-house.

The developed chemical works on the principles of coagulation and flocculation. Different coagulant and flocculant chemical combinations are trialed, and the understanding of their performance is shared using turbidity and zeta potential testing. The developed fines stabilizer chemical is later tested for compatibility with reservoir fluids and production chemicals of a field which is planning to apply fines stabilizer. Based on the potentiality in static screening results of turbidity, zeta potential and compatibility, a fines stabilizer is chosen for dynamic testing.

The constraint of critical flow rate for fines migration is addressed in dynamic study using core flood experimentation. Critical flow rates are determined by forward and reverse injection into core samples. Accordingly, the performance of in-house synthesized fines stabilizer is judged by enhancement in critical flow rate in comparison to untreated and commercial fines stabilizer treated cores. Since the constraint from the critical rate effects injectivity and productivity, modification of this constraint and increase of the critical rate consequently provides more economic benefit. The additional revenue from oil production by using the in-house developed fines stabilizer chemical is estimated, and the costs are compared with a commercial fines stabilizer.

The uniqueness of this endeavor is in developing an in-house fines stabilizer chemical which can be used after acidizing, enhanced oil recovery treatment, in production and injection wells. The synthesized in-house formulation is more effective and cost saving compared to commercial fines stabilizer.
The Tension Leg Platform: from Hutton to Big Foot
Authors: Leverette Steven J. , Hodges Stephen B.
Published: April 2020

This paper is one of seven papers that will be included in the special session: Floating Memories – Look Back to Leap Forward. The focus for this paper is on the Tension Leg Platform (TLP), one of the four major platform types that include the Floating Production Storage and Offloading platform (FPSO), the semisubmersible floating production system (Semi) and the Spar platform.

The paper summarizes the evolution of the TLP over three and half decades, and provides a thirty-five year retrospective of the progression of TLP technology, including hull shapes, tendon connectors, flex elements, and riser systems. It will walk through the evolution of understanding, analytical methods, and model testing to assess the complex global performance of a TLP, and the unique challenges of system dynamic resonant excitation, the so-called "ringing" and "springing" phenomena.

The TLP was a game-changer in bringing dry tree wells to floating platforms, leveraging dry tree drilling and well control methods from a generation of fixed platforms, and enabling multiple top- tensioned production and drilling risers in close proximity due to the limited tensioner stroke not possible on a drill ship or semisubmersible. The TLP has shown its applicability in water depths from the Hutton TLP (1982) in barely 150 m of water in the North Sea, to the Big Foot TLP installed in 1584 m of water in the Gulf of Mexico in 2018, the deepest TLP to date. And it has shown its flexibility in size ranging from the smallest mini-TLP's of 10,000 tonnes displacement, to the North Sea concrete hulled Heidrun TLP of 290,000 tonnes.
Fire and Blast in 1 Edition of API RP-2TOP Standard
Authors: Parihar Arun , Sari Ali
Published: April 2020

The main objective of this paper is to present and discuss the Fire and Blast design methodology for offshore platform topsides with reference to the API RP-2TOP Standard. The first edition of the API RP-2TOP standard has been published recently and consists most up to date provisions for the tospides design for fire and blast loads. The paper focuses on the key aspects of the topsides design of offshore platforms for fire and blast loading as addressed in the API RP-2TOP standard, summarizes the design recipe and highlights the differences between the API RP-2TOP and corresponding API RP-2FB provisions. A risk matrix is provided as a means to determine the acceptability of the risks from accidental events of fire and blast and can primarily be used as a means of screening low-risk events that do not need further investigation. In addition, a detailed and structured methodology is provided for structural assessment from fire and blast events. The fire and blast scenarios should be developed as part of the process hazard analysis.
A Preview of the Digital Component in the New Wireline Formation Testing Era
Authors: Garcia German D. , Dumont Hadrien , Chen Li , Eberhardt Scott , Babin Chris , Pfeiffer Thomas , Edmundson Simon
Published: April 2020

Wireline formation testing has been routinely used for reservoir characterization in the Gulf of Mexico. The significant impact that fluid composition has on designing and operating production and processing facilities for these complex reservoirs requires comprehensive fluid sampling during exploration and appraisal. Vertical and lateral connectivity, fluid compatibility when commingling to meet production targets, or asphaltene onset potential along the production flow path are examples of the need for thorough understanding of fluid property variations.

This case study combines the use of the newest generation of formation testing platform with innovative workflows to acquire critical fluid data and refine the geological reservoir model in near real time. Conveyance difficulties foreseen in the S-shaped well suggested that the use of a shorter, lighter tool could increase the chances of success in a field where past keyseating episodes left few reliable alternatives for conveyance apart from drillpipe-conveyed logging. The application of the smart sampling platform capabilities introduced important changes to the standard protocols used in these cases.

The increased cleanup efficiency of the new formation testing technology enabled fast investigation of reservoir fluids at multiple depths with robust metrology for specific properties. The outstanding sample purity formed the foundation of advanced interpretation workflows. With its high-quality fluid data, this case was used to perform a "proof of concept" of advanced interpretation workflows aimed at updating geological and fluid models in near real time once the downhole fluid analysis data become available at the end of each sampling station.

The formation testing data and the near real-time answers expedited tailoring the completion of the well, which involved a nontrivial commingle decision. The fluid information also provided clarity for the geological model in a section of the field where the current seismic interpretation had shown uncertainty for the reservoir architecture in the downthrown block of the field.

The combination of new formation testing hardware and short-cycle workflows makes this case study the first of its kind. The proof of hardware performance and data processing/interpretation capability cements the case for higher-density data streams and a shortened data life cycle. It serves as a preview of how digitally enabled formation testing operations will be conducted in the future to provide new insights to reservoir understanding.
Subsea Wellhead Retrieval Tool Uses New Technologies to Successfully and Efficiently Complete Abandonment Operations
Authors: Olstad Delaney
Published: April 2020

The objective of the campaign was to safely and efficiently complete a plug-and-abandonment (P&A) operation in a harsh Norwegian North Sea well using a high-performance conductor-recovery tool. The operation used the newly reinvented, second generation mechanical, outside-latch, single trip (MOST) tool system. Along with recovering the subsea wellhead, the associated casing strings and conductor were to be cut and retrieved.

The standard MOST tool is a field-proven system, which latches externally to the wellhead, then cuts and recovers subsea wellheads. The newly released second generation system is a reinvented P&A tool that includes several innovative technologies to increase tool capabilities and performance. The latest release of the MOST tool includes a newly designed tension-cut mandrel, nonrotating flexible stabilizer (NRFS), large-diameter cutter, and high-angle knives. The system confirms the cut without the need for tripping, easily latches and releases to inspect the cutting knives, and does not cause damage to the internal wellhead sealing profile. Furthermore, the external-latch mechanism helps to prevent swarf buildup by allowing more flow area in the high-pressure wellhead, which permits the cuttings to easily exit. The latch and unlatch function can also be visually confirmed using a remotely operated vehicle (ROV) on the seafloor. External latching provides superior lateral support for the wellhead assembly to eliminate any lateral whipping that might impede cutting. The second-generation design of the MOST tool, with the tension-cut mandrel, provides pulling capabilities up to 1,000,000 lb (453,592 kg) and fail-safe features, which enable the outside latch to be released by the ROV, if needed.

The newly deployed system successfully recovered multiple subsea wellheads in Norway and demonstrated its operational effectiveness with reduced cutting times compared to traditional cut-and-pull operations. With advanced features, the subsea wellhead-retrieval system reduces rig time by cutting and retrieving multiple cemented or uncemented strings in a single trip. The NRFS and large-diameter cutter increase stabilization and minimize vibration during cutting, and the high-angle knives increase cutting efficiency when compared to traditional retrieval systems. The MOST system supports quick wellhead recovery, minimizes operational expenditure, and reduces rig time.

The new developments to the next generation MOST tool system give the customer several additional application choices. The various interchangeable components allow for a wide range of cutting options including abrasive cutting, tension cut, motor cut, and umbilical support for laser cutting.
New Innovative Technique for Scale Management During Water Flooding in Offshore Reservoirs
Authors: Salah Mohanad Ahmed
Published: April 2020

Offshore reservoirs EOR present new challenges every day, during water flooding the primary injectant is sea water which is the mostly used fluid in Egyptian offshore wells in Mediterranean sea and Red sea which demonstrate undesirable problems to overall oil recovery process, main problem is scale deposits formation, specially of metal sulfate scale.

Scale deposition was found in many offshore wells in injection tubes and production well and both surface and subsurface equipment causes production declines and costing millions of dollars every year

In this study we developed unconventional techniques to remove and control scale formation during using sea water in injection, That techniques must be efficient and consider all reservoir and water compatibility aspects.

When scales found in either in water flooding pipelines or oil production pipelines and surface equipment's, the conventional way to remove those scale and regain efficient flow is mechanical jet blasting using high-pressure water to crack the scale but it was a time consuming root and need special equipment and large man power although it wasn't that efficient in areas with heat exposure and it can't 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 we didn't accept this method because those chemicals was 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.
Automated Facies Identification Using Unsupervised Clustering
Authors: Hong Youngjun , Wang Shinjo , Bae Jeehoon , Yoo Jaeyoon , Yoon Sungroh
Published: April 2020

The interpretation of well logs is crucial for understanding subsurface geological formations and reservoir characterization. Categorizing subsurface into several geological facies types assists in identifying potential locations of hydrocarbon resources. Geologists interpret each well log feature such as gamma ray, sonic velocity, neutron porosity and resistivity, based on logging characteristics and their petrophysical domain knowledge. By integrating with core analysis result, well logs interpretation result becomes accurate, and geologists finally determine rock types of subsurface for the target well.

Recently, various studies propose to leverage the power of machine learning algorithms for facies classification to reduce laborious interpretation work. Most works utilize supervised learning algorithms that require input/label paired data for training. In case of facies classification, however, the accurate core analysis for determining facies is an expensive process, and the other methods require hard work and often result in noisy data.

In this paper, we develop an unsupervised facies identification model based on deep neural networks. Our model is purely unsupervised, which do not require facies label for input well logs. Because well logs response from the same rock type would have high similarity, we apply an unsupervised clustering algorithm, where data points with similar traits are assigned to the same group, while dissimilar data points are assigned to the different groups.

We demonstrate that our unsupervised facies identification model outperforms other unsupervised clustering algorithms for facies identification. Particularly, our clustered result shows highly similar distribution to the true facies distribution, which suggests future development of automated facies identification.
Gas Hydrate Mitigation Using an Organic Extract in a Simulated Offshore Environment
Authors: Elechi Virtue Urunwo , Ikiensikimama Sunday Sunday , Akaranta Onyewuchi , Ajienka Joseph Atubokiki , Onyekonwu Mike Obi , Okon Okon Efiong
Published: April 2020

As deep-water activities and development into deeper operations (depth of 6,000ft or more) increases, temperatures and pressures become favorable for hydrate nucleation and growth. This results in additional risk and challenges as to how to prevent formation of gas hydrates. This paper takes a look at the performance of a local surfactant derived from plant material in a laboratory mini flow loop made of a 0.5-inch internal diameter 316 stainless steel pipe enclosed in a 4-inch PVC pipe mounted on an external metal frame work. The performance of the local surfactant (Surf. X) was compared with that of the conventional hydrate inhibitor N-Vinyl Caprolactam (N-VCap). Varying weights of Surf. X were evaluated in the laboratory mini flow loop. Pressure versus Temperature, change in Pressure versus Time plots showed that Surf. X performed better than the conventional N-VCap in almost all the concentrations considered (except at 0.04wt %). The optimum concentration for inhibition was 0.02wt% with inhibition efficiency of 81.58% while that of N-VCap was 77.19%. The inhibition efficiency of Surf. X for 0.01, 0.03 and 0.04wt % were 72.81% and 75.44% respectively. Surf. X is locally sourced, readily available in commercial quantity and also eco-friendly because it is plant based unlike the N-VCap which is toxic and expensive. It is advised that the local surfactant X be developed as an alternative to the conventional inhibitor for gas hydrate inhibition.
Offshore EOR Initiatives and Applications in Brazil: An Operator Perspective
Authors: Vieira Raphael A. M. , Pizarro Jorge O. S. , Oliveira Leonardo A. , Oliveira Diego F. B , Passarelli Fábio M. , Pedroni Lucas G.
Published: April 2020

Implementing deep-offshore Enhanced/Improved Oil Recovery (EOR/IOR) is not an easy task. Bigger reservoirs, larger well spacings, injection/production/logistics constraints and difficulties to quantify benefits are some of the challenges that may be faced.

This paper presents the status and future vision for the main offshore EOR/IOR research and field application initiatives of a brazilian Operator. Most promising technologies and issues will be described. Overall research structure, as well as adopted strategies to test and implement those techniques will be addressed. Difficulties eventually faced will be mentioned.

The most promising methods in terms of water-compatible EOR are customized-composition waterflood, novel conformance control solutions and optimal reservoir management. Regarding gas-based technologies, the focus is on WAG flood, foam, subsea gas/liquid separation/reinjection and gas injection optimization.
Leveraging CFD in Earlier Design Stages to Capture Critical Effects and Sensitivities with Simple Cost Effective Approaches to Explosion Modeling
Authors: Clutter James Keith , Staszak Andrew James
Published: April 2020

Computational modeling (CFD) has made great strides in the last 20 years in fighting and overcoming its "expensive" stigma. The oil & gas industry has embraced the use of CFD to assess everything from the design of equipment, optimization of process flows, and hazards modeling of fire and explosion events all in an effort to strive for the goal of inherently safer designs. In current offshore facility design, CFD modeling, to assess the consequences of vapor cloud explosions has been established as common practice.

For most major projects, CFD explosion modeling is used heavily in Feed and Detailed (later) stages of design. At these stages hundreds of scenarios are simulated and combined with extensive probabilistic and statistical calculations to define design loads of critical systems and assess risk. The primary advantage of using CFD is that it incorporates more details of the design and provides more realistic and design specific analysis. In the case of explosions, CFD provides valuable data for design, particularly explosion data that is significantly more accurate than that from simple open field models.

Despite this adoption within the design process and decades of advances, CFD modeling practitioners still admit that there are increases of cost and time, when compared to the ever-present phenomenological approaches. This has kept many design processes from utilizing CFD in the earliest stages; namely Concept and pre-Feed. The arguments have traditionally been along the lines of:The design is progressing and changing too fast to allow time for CFD models to be built.,There is insufficient model detail to construct viable CFD models.,The early stage concerns can be captured "well enough" with simple approaches., etc.

Modeling representations and approaches can be simplified and streamlined, while still providing the advantages of CFD. Variability in geometric representations can be captured with physics representations rather than needing to create predictive CAD geometry. These types of simplifications can increase the ability to simply change and update models and conduct early stage sensitivities in projects, while still capturing critical explosion effects.

The purpose of this paper will be to show how these simplified approaches can be used in an effective and efficient manner in early stages of design. That the traditional arguments against early adoption of CFD can be countered, with the end result being greater early stage information and influence on the design. Allowing effective change at a time in the process when it is not cost prohibitive and other controls have yet to prohibit design changes. The result being a continued improvement in the goal of inherently safer design.
A Risk Informed Approach to Testing and Qualification of Materials for Sub-Sea Applications
Authors: Ramgopal Thodla , Cao Liu , Li Xiaoji , Chandra Ashwini , Gui Feng , Sridhar Narasi
Published: April 2020

Oil and gas production applications demand high reliability, which implies low failure probability over the lifetime of the components. The service environments encompass high pressure high temperature (HPHT) conditions inside and seawater with cathodic protection (CP) systems on the outside. New material combinations are being employed, including thermo-mechanically processed low alloy steels and corrosion resistant alloys (CRA). Additively manufactured (AM) alloys are also entering the market, creating further variability and directionality in properties. Material qualification involves two types of accelerated, laboratory tests – standard and fit-for-purpose. However, the acceleration vectors used in these types of tests are usually not clearly identified. Relating the materials qualification tests to service performance requires a systematic approach that considers the uncertainties in the acceleration vectors such as, loading conditions, environmental compositions, operating parameters, and material microstructures. In this paper, we describe the acceleration vectors typically used in qualification tests and a risk framework that may be used to relate the test results to long term service performance. The benefit of a risk informed approach is not only avoidance of unnecessary testing, but also investing the testing resources to attain highest reliability.
Challenges and Recommendations for Environmental Compliance for Marine Renewable Energy: Avoiding Issues Early for Efficient Permitting and Practicable Mitigation
Authors: Courbis Sarah Shelby
Published: April 2020

Marine renewable energy is a relatively new phenomenon that is becoming cost-competitive with traditional sources of energy. Marine hydrokinetic energy (MHK), as it moves to commercial scale, will be subject to myriad laws and regulations associated with wildlife impacts and efforts to avoid unsustainable adverse effects. At the same time that MHK is developing in this arena in the U.S., regulations and policies are changing, creating a moving target and affecting already established industries, such as oil and gas. To ensure that MHK can be cost-effective and to reduce risks of delays and impracticable project adjustments and mitigation in the U.S., early consideration of laws governing wildlife and how they are applied will be key. Planning to address wildlife priorities associated with statutory needs and industry/stakeholder goals can drive development of technology, engineering choices, siting, planning, mitigation, and adaptive management practices. Other marine industries have been recently affected by U.S. wildlife laws. For example, offshore wind is experiencing delay on the U.S. East Coast in part due to challenges with environmental statutory requirements and agency concerns about impacts. In oil and gas, it is unclear how new regulatory requirements, such as the Incidental Take Regulation pending for geophysical surveys in the Gulf of Mexico will affect the industry. MHK and other marine energy industries can leverage proactive planning and agency engagement to reduce risks of delays and costs that could significantly affect proposed projects.
How to Gain a Competitive Edge with the Digital Twin
Authors: Norinder Jonas
Published: April 2020

With the move towards IIoT and the Digital Age, companies in the process industry are looking to digitalize processes. One critical element in this development is the increased adoption of the Digital Twin (DT), which is being deployed in all phases of a product, plant, or process lifecycle from design to operations to maintenance.

A DT is a virtual representation of a physical product or process used to understand and predict the physical counterpart's performance characteristics. They are used throughout the product lifecycle to simulate, predict, and optimize the product and production system before investing in physical prototypes.

The concept is not new. For more than 30 years, product and process engineering teams have used 3D renderings and process simulation to validate manufacturability. What is new, however, is that several factors have now converged to bring the concept of the DT to the forefront as a disruptive trend in the process industry. This will be demonstrated using relevant use cases featuring organizations that have seen increases in efficiency improvements after employing digitalization and the DT

By incorporating simulation, data analytics, and machine learning, the DT is able to demonstrate impacts of usage and training scenarios in a virtual setting. This enables identification of any potential issues in the design phase as opposed to the commissioning phase as is very common today. Process and sensor data from physical objects are collected and analyzed to determine real-time performance and operating changes over time. Feeding this data back into the product lifecycle, the DT is continuously updated to reflect changes to the physical counterpart. This creates a closed-loop of virtual feedback that makes products, production, and performance optimization possible at minimal cost.
Jet Fire Consequence Analysis
Authors: Colella Francesco , Ibarreta Alfonso , Hart Ryan J , Morrison Trey , Watson Harry AJ , Yen May
Published: April 2020

Jet fires are a significant hazard for the Oil & Gas industry and can cause both injuries to personnel and failure of equipment and structures. Current jet fire consequence analyses rely almost exclusively on empirical models that use a simplified flame geometry and fixed emissive power to determine the thermal radiation load on a target. The available empirical models provide acceptable radiation load estimates for hypothetical scenarios that are comparable to those used during model development. Computational Fluid Dynamics (CFD) represents an alternative solution for evaluating jet fire geometric features and radiation loads. CFD has been used historically in a wide variety of applications, including but not limited to the aeronautics and automotive industry, the biomedical industry, and in a wide range of industrial applications involving heat transfer and fluid mechanics. With recent advancements in computer power, CFD has become a mature tool that can be used reliably for evaluating the impact of fires. During the facility design process, CFD offers flexibility in evaluating the effect of design changes and provides information to assist in making data-driven design decisions.

This paper describes the current state-of-the-art for jet-fire consequence analysis as well as review publicly available experimental data. A few representative test cases are used to compare empirical models and CFD results with published experimental data.
Evaluation of a Robust, In-Situ Surface Treatment for Pipeline Solids Deposition Mitigation in Flowing Systems
Authors: Pickarts Marshall A , Delgado-Linares Jose , Brown Erika , Veedu Vinod , Koh Carolyn A.
Published: April 2020

The formation/precipitation and deposition of pipeline solids, such as gas hydrates, asphaltenes, and waxes have long plagued production fields. Given the vast differences in chemistries of these solids, any current prevention or mitigation strategy, particularly for cases where multiple issues are a concern, is likely to involve an extensive assortment of undefined chemical additives that are both costly and add complexity to the system. Surface treatments (coatings), on the other hand, present a relatively new viable option for management strategies. A chemically and physically robust surface treatment with the ability to address deposition issues for multiple pipeline solids could not only decrease the operating expenditures for a field through material cost savings and obviation of downstream separation, but could also simplify produced fluids by eliminating additional chemicals from the mixture.

The purpose of this study is to explore the feasibility of a particular surface treatment as part of a solids management strategy. This work utilizes an omniphobic surface treatment to probe its effects on gas hydrate, asphaltene, and wax deposition. Specifically, high pressure rocking cells are employed to study gas hydrate nucleation and deposition. A bench-scale flowloop filled with crude oil and heptane is used to quantify the deposition of crude oil and asphaltenes after a set time period. Lastly, a mechanical shear device measures the adhesion force of wax deposits on untreated/treated surfaces.

The gas hydrate rocking cell tests demonstrate an increase in induction time and occasional elimination of hydrate nucleation with the surface treatment. Moreover, the same apparatus indicates that the critical shear to avoid hydrate deposition may be lowered in the presence of the surface treatment compared to untreated pristine carbon steel coupons. A custom-built asphaltene flowloop then establishes that this surface treatment is effective in dramatically reducing the deposition of the aliphatic components of a crude oil, with a moderate reduction in the asphaltene fraction. Finally, mechanical adhesion force measurements for solidified paraffin wax display trends in agreement with the asphaltene results. The surface treatment on both pristine and corroded surfaces is able to reduce the adhesion of wax deposits to values below a pristine, untreated surface.
Industrialization Of Additive Manufacturing For Oil & Gas Through Process Control
Authors: Vendra Lakshmi , Dobrowolski Thomas , Linares Maximino , Avagliano Aaron
Published: April 2020

Additive manufacturing is classified as disruptive technology that has the capability to meet new marketplace demands in speed, agility and respond rapidly to fluctuating customer requirements. Applying the design freedom that Additive Manufacturing naturally offers, it is possible to produce complex geometries designed for functionality that are not limited by conventional manufacturing constraints. Speed and efficiency of producing end use parts particularly using metal Additive Manufacturing has significant impact on transforming global supply chain, for offshore segment of oil and gas industry. Metal Additive Manufacturing has been widely adopted in aerospace, defense and medical device industries and is an emerging technology in oil and gas where it is gradually gaining acceptance. However, industrialization of the technology requires process repeatability with efficient workflows and reliable part production. Every step in the process chain has an effect on the integrity and quality of the end product, therefore implementing process control across the Additive Manufacturing value chain is essential to enable its use as mainstream manufacturing technology. This article reviews available and evolving methods to achieve a controlled Additive Manufacturing process for metallic materials.
Demanning Offshore Process Facilities
Authors: Dyson Richard , Varney James
Published: April 2020

De-manning of offshore processing facilities presents an opportunity for significant CAPEX and OPEX savings for operators, is inherently safer and may be an enabler for marginal oil and gas developments.

Unmanned wellhead platforms are common, however de-manning of significant oil and gas processing facilities has not been achieved to-date.

This paper presents a conceptual design for a Normally Unmanned Installation (NUI) with full processing of well fluids to export specifications. By using novel and innovative solutions, a design with reduced equipment count, platform weight and attendance is proposed. The design is technically ready for implementation whilst meeting the functional requirements of an offshore processing facility.

A functional specification was developed for the platform; it was important that the design is transferrable, therefore this functional specification was kept broad. The platform was expected to process well fluid to typical pipeline export specifications. To test the design, commerciality was tested against a "Reference Case", traditional manned platform. Full subsea processing was investigated but discounted due to a lack of technical readiness.

Traditional approaches to platform design were challenged at every level, from platform access methods to the requirement for platform power generation. The key drivers for manning were investigated, identifying the target areas for simplification. An optimal platform design was then identified integrating the latest techniques and technology.

The NUI CAPEX was compared versus the Reference Case. Ground-up OPEX estimates were prepared to quantify the reduction in attendance and achievable savings.

The resulting NUI design achieves an approximate 60% reduction in equipment weight compared with a traditional manned platform, leading to a CAPEX reduction of around 30%. Significant reduction is achieved by removal of living quarters, and therefore life support systems from the facility. Power import allows maintenance-heavy power generation to be removed.

The optimised NUI delivers a reduction in OPEX of around 50% when compared to a traditional manned facility. Digital strategies such as predictive maintenance, robotic inspection and remote monitoring reduce the reactive maintenance hours offshore by up to 85% while maintaining platform availability. Walk-to-Work platform access is a mature technology and offers cost savings when compared with helicopter access and there is the potential for sharing of walk-to-work systems between assets and industries. Walk-to-Work access has the advantage that no permanent living quarters are required. A significant reduction in fabric maintenance manhours is achieved by carrying out inspection remotely.

The truly innovative and disruptive solution for unmanned facilities is the subsea factory on the floor. At the time of writing, the technology is not of the required maturity and it does not offer a viable solution. As this technology matures the potential exits to create a truly differentiated, facility of the future.
Shell Appomattox Model-Based Operations from Design to Production: A Game Changer in GoM Deepwater Operation
Authors: Tulalian Robert , Keever Evan , Rastogi Ankur
Published: April 2020

Driven by lower-for-longer cost of operations, companies continuously look for effective ways to increase efficiency and support smarter decision-making. This paper will show how large operations such as Appomattox can use an integrated dynamic simulation-based solution throughout the project lifecycle to aid in design verification, operator training, startup support, and real-time surveillance. The recommendations and findings in this paper can be applied to similar project implementation efforts elsewhere in the oil and gas industry.

Appomattox is a four-column semi-submersible production platform located 80 miles off the coast of Louisiana in approximately 7,200 ft of water and features a subsea system with six drill centers, 15 production wells, and five injection wells. Appomattox produces from two deep-water fields – Appomattox and Vicksburg, with potential for asphaltene precipitation and scale formation due to high reservoir temperature and sour service.

The Appomattox project team decided in the design phase that dynamic simulation would be a useful tool to assist with operator training due to the complexity of the distributed control system (DCS) and the need for operators to gain familiarity with the combined cycle steam system, a first in the Gulf of Mexico. A multi-purpose dynamic simulator (MPDS) was developed that integrates high-fidelity subsea and topsides models together with the Appomattox control system to provide an environment where one can operate or test without the risk of upsetting the actual process.

Prior to integration with the control system, the MPDS was used for engineering studies that resulted in design changes well before first oil, generating significant cost savings when compared to finding these issues at startup. Once integrated, it was able to be used for operating procedure validation and multiple rounds of operator training prior to first oil. Other applications have included controller loop tuning – which generated an initial set of tuning parameters for use at startup, and leak detection algorithm testing by introducing subsea leaks of various sizes. The MPDS currently resides in Shell's Remote Operations Center for production support.

The MPDS model has been cloned to be used as a Real-time Surveillance System (RTS), running in parallel with the live facility and connected via Open Platform Communications (OPC) to its historian. The Appomattox RTS sits in Shell's Azure cloud, accessible to Shell users from anywhere. Current RTS applications include virtual multiphase metering, blockage detection in wells/flowlines due to asphaltene/scale deposition, and a performance monitoring system for topsides process coolers designed to predict exchanger fouling/plugging. All key calculated values are sent to Appomattox's historian where they are visible on surveillance screens.
Study on the Integrity Assessment and the Prevention Measures for High Temperature and High Pressure HT&HP Wellbores
Authors: Wang Yanbin , Gao Deli , Wang Jinduo , Meng Chenyu
Published: April 2020

With the increase of well depth and recovery difficulty in oil and gas development, the downhole temperature and pressure rise unceasingly. The wellbore is simultaneously subjected on the non-uniform in-situ stress and high temperature and high pressure (HT&HP) under this complicated operation environment, which will seriously threat the wellbore integrity and bring huge economy loss. So, give a comprehensive analysis of wellbore integrity and propose corresponding prevention measures are of important significance for the safe and economic operation of HT&HP wells.

In this paper, a new thermal-mechanical coupled model and analysis method for analyzing the mechanical response of casing-cement sheath-formation have been established. The model, which can be simplified to a plane strain problem, has considered the combined actions of temperature, pressure and non-uniform in-situ stress with appropriate boundary conditions. Subsequently, the corresponding equations have been deduced to obtain the mechanical responses of the model under the three kinds of actions mentioned previously. The wellbore integrity has been evaluated by proposed coefficient of failure (COF) defined by the yield criterion of Von-Mises, Drucker-Prager and Mohr-Coulomb. On this basis, the parameter sensitivity analysis of wellbore integrity is presented.

With the increase of formation temperature and non-uniform degree of the in-situ stress, the COF of casing, cement and the contact surface of casing-cement decrease. The Poisson's ratio of cement has no impact on the COF of casing and the contact surface of casing-cement, while the COF of cement increase slightly. If the temperature variation is below 170°C, the cement ring cement is out of failure, and the wellbore integrity is under control. Besides, it is advantageous for wellbore integrity to keep the elasticity modulus of cement 10GPa-20GPa.

This paper has a guiding significance for analysis and control of the wellbore integrity in HT&HP wells, which can allow the engineers to understand the casing failure and wellbore integrity more intuitively, and help them choose reasonable operation parameters to improve the operation life of HT&HP wells.
Hybrid Manufacturing Process Greatly Reduces Production Costs of CNC Machined Plastic Parts
Authors: Hebel James William
Published: April 2020

This paper is an introduction of a new hybrid plastics processing technology known as NNS (Near Net Shape) Technology, that demonstrates significant cost savings in the production of CNC (Computer Numerical Control) machined advanced engineering plastics parts by combining injection molding and CNC machining.

The cost savings of NNS technology and the process is demonstrated with manufacturing examples comparing the traditional process of CNC machining parts from stock shapes such as sheet, rod or tube to the NNS technology process. Included in the examples are detailed production case histories with data supporting significant material cost savings and reduced machine time that are possible when NNS technology is utilized.

NNS technology not only reduces the cost of producing CNC machined plastic parts but gives engineers the option to specify even higher performance plastics that can offer greater life in application. Plastics that offer improved chemical resistance, higher operating temp capabilities, and higher mechanical properties can now be specified that may have been cost prohibitive in the past with traditional CNC machining. NNS allows for initial lower part costs and more importantly lower cost-in-use with improved performance in the application. Common applications that can benefit from NNS include high performance plastic bearing and wear components, structural components, electrical insulating components and numerous other components across a wide range of oil and gas applications from onshore, downhole, offshore and subsea.

Not all CNC plastic parts can benefit from NNS technology. We share the guidelines that we have found successfully help engineers to identify those parts that can benefit from NNS technology to reduce the production cost of CNC plastic machined parts for Oil & Gas applications.
Using Knowledge Graphs to Enhance Drilling Operations
Authors: Danner George Earl
Published: April 2020

The shape of information used to execute drilling operations is rugged. A quick survey of all of the information shows data expressed in test reports, images, time series data, Cartesian data, text, spreadsheets, maps, code, and engineering drawings. Traditional database representations of data as tables with rows and columns does not match the new reality of all of the information forms that must be brought to bear on critical drilling decisions. For us to possess an expansive view of all of the information we must move beyond the limitations of relational data into the realm of graphs.

Representation of data in graph form has become popular in recent years, particularly in those domains where the data is rugged. The medical field was the first to recognize the value of graph forms to create cognitive applications like machine-based automated of disease diagnosis. We contend that the rugged nature of drilling operations also lends itself well to graph representation. The objective here is to create something known as a "corpus"—a repository of data in a wide variety of forms that can be traversed with a query language that is purpose-built for graphs. The ultimate aim is to create a Knowledge System that is suitable for natural language queries by humans.

In our talk we will describe how such a corpus is built and how to apply it specifically to drilling operations, with a focus on what works well alongside the challenges and (temporary) failures.

Knowledge Graphs have a unique character and are appropriate for certain classes of applications. We believe that Knowledge Graphs do deserve a place in the oil and gas industry given these attributes that map well to the characteristics of the industry's data forms.