bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pre-Tensioned Pipeline Bundles Design Challenges and Solutions for HPHT Field Development
Authors: Qadir K. S. , Morris K. , Goodlad M. 
Published: March 2016

Abstract

Objectives/Scope
High pressure-high temperature developments are on the rise globally as operators are pushing the current limits by investing in technology for the future, for e.g., Total West Franklin and ConocoPhillips Jasmine Pipeline Bundles. Pipeline Bundles have been designed and installed by Subsea7 for over 35 years globally and have been utilised where fluid transport requirements have made other technical solutions uneconomic. The Pipeline Bundle product has been incrementally developed over the years to the current pressure & temperature record of (604bar and 160°C). The next stage in development is to increase the temperature and pressure range for the product through the use of pre-tensioning. For HP/HT fields pre-tensioned Pipeline Bundles offers a technical and commercial key advantage, they reduce the build-up of unacceptable axial forces, mitigate the need for expansion/cooling spools and hence provide an economic fully integrated HP/HT solution.
This paper outlines the general benefits of Bundles and how mechanical and thermal methods can be used to set the pre-tension in-to the PIP (Pipe in Pipe) and their comparison. If EHTF (Electrical Heat Traced Flowlines) are integrated in the Bundle these might also be used to set the pre-tension and test the electrical heat trace system.

Methods, Procedures, Process
The base case for a comparative study is Total West Franklin which had design pressure of 604bar and 160°C temperature. Pre-tensioning calculations with varying combinations of pressure and temperatures are utilised to assess the impact on design of the Bundle based on the Total West Franklin Bundle. The effects of pressure and temperatures up to 1379bar and 220°C respectively are evaluated during the R&D project using calculations and advanced FEA with Abaqus. The paper will also outline the effect on the HP/HT design of changing the thickness of the production pipe by utilising displacement controlled and limit based design codes in combination with advanced FEA to assess the design, moreover requirements in regards to fracture mechanics are determined.

Results, Observations, Conclusions
In regards to HP/HT pre-tensioned pipeline Bundles, the design codes PD-8010 and DNV-OS-FlOl are not developed for Bundles and hence further work in developing an advanced FEA methodology for HP/HT Bundles, which is integrated with these codes would yield further benefit. A thick walled pipe might be beneficial for pressure containment and reduce overall stresses but in combination with higher temperatures also results in amplified compressive loads due to expansion. It can be established from results that a pipe with pre-tensioning and detailed flowline integrity analysis will enable design with higher temperature usage and optimise the pipe thickness.

Novel/Additive Information
It is expected that a technically feasible and economically advantageous solution for HP/HT developments will be realised for operators by pre-tensioned Pipeline Bundles.
Seismic Sensitivity Studies for Fixed Offshore Platforms
Authors: Sari Ali , Ramana Ekkirala , Cai Wenyu , Nguyen Hieu , Azimov Umid 
Published: March 2016

Abstract
Nonlinear dynamic response of offshore structures under seismic loading is a challenging and interesting problem to structural engineers. Fixed offshore platform under intensive ground shaking may undergo deformations well into the inelastic range. The first part of this paper discusses the seismic analysis methodology we developed considering the following effects (1) Soil radiation damping; (2) Soil-pile gapping; (3) Multi-level excitation and (4) direction of seismic loading. The second part of the paper uses case studies to demonstrate the methodology. These case studies involve a representative fixed offshore platform, Platform A. Platform A was analyzed against 10,000-year earthquake events. These 10,000-year events are based on actual earthquakes. The ground motion records were scaled up so that the resulting earthquakes would have a return period of 10,000 years. Time history simulations were carried out using the nonlinear dynamic structural analysis program USFOS. Results show that (a) the effect of soil radiation damping is not negligible; (b) Soil-pile gapping and soil radiation damping may cause opposite effects on the platform response; (c) Direction of seismic loading affects soil-structure interaction as well. The goal of the paper is to discuss and illustrate the methodology for advanced nonlinear dynamic analysis of fixed offshore platforms during 10,000-year earthquake events.
Novel Subsea Boosting Solutions to Increase IOR
Authors: Micali Salvatore , Abelsson Christian 
Published: March 2016

Abstract
During a market condition that is characterized by volatile oil price, there is a strong incentive in the Oil & Gas Industry on maximizing the hydrocarbons recovery from existing fields, rather than initiating new field developments.
For offshore deep water field applications, subsea boosting technologies are considered to be a solution to improve the field recovery, while also acting as enabling technology that allows for development of deep, harsh and stranded reserves, which otherwise deemed non-accessible.
This paper presents the performances and application area of two novel subsea boosting solutions developed by Aker Solutions: The boosting of condensate and oil as well as pressure increase by water injection through high pressure subsea pumpsThe subsea boosting of gas flow with associated liquid, though high performance subsea compression.
Special focus is given to the subsea centrifugal pump and compression technologies and how these new solutions can solve the existing challenges represented by providing high performance pressure boosting for both oil production with high gas content, as well as gas production with high liquid content.
Highlights on the key features of these novel technologies are provided, with specific focus on the benefits the technology brings to the market, like the high differential pressure generated together with the high efficiency and mechanical stability. These are all game changers for deep water IOR developments.
Conceptual Design of Offshore Surface Facilities in Marginal Field at Heavy Traffic Ultra Shallow Water Using Shallow Water Subsea Wellhead for CAPEX Optimisation in O-Field Development
Authors: Yananto H. , Girindra Y. 
Published: March 2016

Abstract
Some Oil and Gas fields in Indonesia, particularly in offshore have not been explored due to field economics. The absence of a thorough study of a potential development in the entire reservoir at a Production Working Area contributes the high cost of the development. The O-field would be the object of study with emphasis on the development of conceptual study for surface facilities. Some challenges that must be overcome for the development of this field, including the O-field is comprised of several small reservoirs and scattered. It is located in shallow waters and is in the area of export tankers for shipment of oil and other chemicals. The development of this field also becomes complex because its dependency to an existing facility.
Prediction of Individual Waves Based on Multi-Point Measurements
Authors: Wada R. , Mondal R. , Sakurai Y. , Takagi K. 
Published: March 2016

Abstract
We propose a system for predicting the near future wave elevation at the ship position using data observed around the ship. Our aim is to predict individual wave heights using ad hoc point observation system, such as drones, and utilize it to increase safety and efficiency of operation. This work extends the previous method for long crested wave prediction to the application for short crested wave. We elaborate on the prediction method with multi-points measurement data, and evaluate the computed prediction data for some cases to show the capability of our method.
Holistic Sand Management Methodology: A Multi-Disciplinary Team Approach to Cater Sub-Surface & Surface Aspects of Sand Production and Optimization
Authors: Gupta A. , Borhan N. , Kamat D. B. , Mat A. , Singh R. , Sunnapu R. , Baghdadi F. , Jadid M. B. , Gong M. , Madon B. B. 
Published: March 2016

Abstract
Sand Management refers to management of sand from its onset downhole till the handling of produced sand in the top side followed by the disposal while continuously taking safety aspects into account. It is apparent that a single discipline cannot execute this methodology as it requires a multi-disciplinary processed approach to safely produce, handle and dispose the sand. Moreover, for an operator managing multiple assets and each asset having similar issues, it is difficult to work in silos and this also increase the redundancy in tackling the issues. Furthermore, with increase in sand issues all across the regions, ad-hoc solutions became prevalent consuming more money and time.
To overcome the challenge of managing the produced and handled sand in an effective and systematic way, initiative was taken by the Operator to formulize the Central Sand Team (CST) involving various disciplines to centralize the entire effort. The objective was to avoid redundancy, standardize the efforts and efficient knowledge sharing. Each region further developed their own Regional Sand Team (RST) with representatives from each discipline. This team will then appoint a Sand Focal Points that will act as the liaison between CST and the RST. Roles and responsibilities were demarcated to both the CST and RST. The Central Sand Team (CST) focus is more on planning the strategy, developing guidelines or procedures, encourage knowledge sharing, being the centralized contract holder for few services and maintaining effective communication with regions' Sand Focal Points. Regional Sand Team (RST), on the other hand are the ones implementing the guidelines & documents and focus on sand related issues & mitigation more apparent in their own region.
The holistic approach of assimilating the entire sub-surface and surface disciplines under one umbrella to manage the sand proved effective in reducing the redundancy and coming up with effective solutions. The methodology has also proved a good knowledge transfer tool across disciplines. The sand issue which was usually tackled by individual disciplines is now being tackled collectively with proper data and complete understanding of the sand cycle.
The development of Integrated Sand Management Guidelines covers surface and sub-surface aspects. This is a unique concept resulted in a robust and comprehensive document. In addition to that, the sand erosion and transport softwarer is being developed as an application for sand erosion calculations and risk analysis. The methodology in itself is unique and can be blue print for many other operators with sanding issues.
Comprehensive Well Integrity Solutions in Challenging Environments Using Latest Technology Innovations
Authors: Alaref Omar , Rourke Marvin , Khabibullin Murat , Yakupov Alfir 
Published: March 2016

Abstract
The impact of corrosion on the oil, gas and geothermal industry is big and affects both capital and operational expenditures (CAPEX and OPEX). There is a growing public awareness and rising concerns with well integrity and health, safety and the environment (HSE).
One of the first steps for corrosion mitigation is to evaluate downhole tubular. The reduction of metal thickness leads to a loss of mechanical strength and structural failure. When metal pitting accelerates in localized zones, very considerable structural weakening may result from a relatively small amount of metal loss. Additionally, the alteration or loss of surface properties including erosion, increased fluid flow friction at the pipe surface, surface reflectivity or heat transfer across a surface, cause such weakness.
Corrosion evaluation using electric-line logging is of growing importance in the industry. Technologies that can evaluate multiple barriers are vital for cost-effective evaluations as rig time is saved by not having to retrieve the completion to evaluate production casings. This is the case especially in the offshore environment where the casing design is generally more complicated and consists of extra number of casing strings. Current technologies available include magnetic flux leakage or eddy current, or to some extent ultrasonic which has some limited capability of multi-barrier evaluation.
A multi-sensor electromagnetic corrosion tool (EM) has been developed especially for multi-barrier evaluations; the technology is based on pulsed eddy current physics. When combined with conventional multi-finger calipers and other tools such as radial cement bond logs or noise detection technologies, it offers a better understanding of well integrity.
Comparison of CO2-EOR Performance between Offshore and Onshore Environments
Authors: Ghanbari S. , Mackay E. J. , Pickup G. E. 
Published: March 2016

Abstract
Despite a successful history of CO2-EOR onshore, its application has been limited offshore. There are fundamental differences between offshore and onshore environments. Offshore, reservoirs are typically bigger and are characterised by larger well spacing. There are also other important differences in terms of prevailing reservoir conditions. This study compares the performance of CO2 flooding between these environments and investigates how the combinations of these differences affect the performance of CO2-EOR offshore compared to onshore. Two synthetic box models with different dimensions, each representing a relevant environment were constructed and the CO2 flooding process were simulated. Onshore model represents a United States CO2 flooded reservoir, while offshore model represents a North Sea reservoir. The offshore model is thicker and has larger well spacing. The same injection and production rate in terms of pore volume and the same flood strategy were applied in both models. Identical flooding strategy ensures that both models experience the same average pressure evolution during simulations and the injected CO2 volumes remain comparable. This also makes the results comparable between them. The results show that, larger well spacing offshore favourably affects the pressure evolution of the system. The higher injection pressures offshore coupled with high CO2 compressibility, makes CO2 and reservoir fluid densities become comparable offshore, which reduces the gravity segregation of CO2 and increases CO2 and reservoir fluids compositional interactions. The same rate of depletion in a larger well spacing environment translates to higher fluid velocities inside the reservoir, which makes the flow less affected by gravity. Offshore, the model thickness is comparable with well spacing which retards the gravity segregation of CO2.
The inclusion of other differences mainly reservoir temperature and formation permeability characteristics of offshore environment adversely affects the CO2 flood performance offshore. This poor performance however can be compensated by operating the flood at higher pressures. The results show that the CO2 flood offshore is less gravity dominated and WAG does not bring the same benefit offshore as it does onshore. Numerous simulations confirmed that there is always a correlation between EOR and CCS performance of the system. Scale differences can bring improvements for CO2 application offshore characterised by thicker pays and larger well spacing. However this improvement may not be able to compensate for the adverse effects of the prevailing reservoir conditions. Given other considerations regarding CO2 application offshore (e.g. production problems) the in-situ reservoir conditions may make the EOR performance of the CO2 flood so poor that further motivations like CCS will be required to bring CO2 injection offshore.
Development of Degradable Seal Elements for Fully Degradable Frac Plugs
Authors: Takahashi Takeo , Takahashi Shinya , Okura Masayuki 
Published: March 2016

Abstract
Demand for hydrocarbons is continuing to grow, leading to an increase in the stage count of hydraulic fracturing in unconventional reservoirs. The plug-and-perf system is a typical stimulation method that uses frac plugs for zone isolation. Conventionally, the plugs must be milled out to recover the flow path for hydrocarbons after fracturing is complete. Fully degradable frac plugs would eliminate the need for milling out, and this in turn allows for longer wellbores in the lateral direction, lower costs, and reduced risk in well completion. A key material for fully degradable frac plugs is a sufficiently degradable rubber with good sealing properties for the seal elements of the plugs. This paper presents the fundamental properties of degradable rubbers developed in a comprehensive materials study. The degradation behaviors of the degradable rubbers were investigated under various temperature and fluid media conditions. The mechanical strength was compared with that of conventional nitrile rubber. Nonlinear, three-dimensional multi-body contact analysis and qualification testing were integrated to estimate the sealing performance of seal elements made of the degradable rubbers.
Effective Water-Injection Measurement in Deepwater Operation Using Field Tested Tool
Authors: Udofia Emmanuel , Eruja Femi , Benjamin Obong 
Published: March 2016

Abstract
Bonga deepwater field depends on sustained water-injection for reservoir pressure maintenance for efficient oil production. The field which lies 120km southwest Niger Delta in Nigeria at a water depth of 1000m, has varying flow rates in the producer wells with very fast response to changes in injection rates and has been developed with seventeen water-injectors to provide pressure support for the producer wells. All water injectors are fitted with subsea water-injection meters for measurement of actual injected water. The subsea infrastructure is such that the water injection wells are developed into two wings (Eastside and Westside) and serviced by two flow-header meters into each wing. Each wing consist of several water-injector wells, therefore measurement of water-injection into each well is crucial.
Since early 2011, the individual wells subsea water-injector measurement meters became faulty and we were unable to accurately measure the individual water injector's well rates due to the inconsistency of the subsea meter and efforts to fix the meters were not successful. As a result, the optimisation of oil production based on efficient water-injection was hampered because there was a high uncertainty of the water injection figures.
The proposed solution was to install Field ware Production Universe EOR, which is a state-of-the-art, real-time data driven application for water-injection monitoring. The procedure is to use a multi-rate injection well test from the bulk water-injection meter for data acquisition and build the Production Universe EOR model for subsequent rate estimation for individual water-injectors. The deployment of this application enhances efficient production optimisation effort in Bonga field through accurate measurement of the injected water into each injector well.
The result from this empirically based work shows how a quick solution for estimating water injection into each water-injector could be achieved. This reference tool could be applied to other operating units having similar challenges like Bonga field especially in a deepwater environment with high cost of intervention to replace such faulty measurement meters.
Pressure Transient Behavior of Partially Naturally Fractured Reservoirs
Authors: Qasem Fuad 
Published: March 2016

Abstract
Naturally fractured reservoirs (NFRs) always have flow networks that are more or less irregular, discontinuous, or clustered. NFR with such spatially non-uniform distribution of fractures is called partially naturally fractured reservoir (PNFR). An improved understanding of pressure response is required to characterize PNFR. This paper presents a better understanding of well test pressure response of PNFR.
Stochastic modeling was used to generate various geological models with different fracture intensities. Single phase liquid flow through stochastically generated reservoirs is simulated by a numerical reservoir simulator. Dual-porosity / dual-permeability model was selected to simulate PNFR. A vast database of pressure transient responses of the reservoirs with varying fracture intensity, matrix permeability and fracture porosity is presented in this paper. Pressure derivative was used to analyze the pressure transient responses.
Pressure derivative analysis indicates multiple V-shapes representing various sets of fracture intensities. It is observed that with the increase of fracture porosity V-shape become more pronounced. It is also observed that with the increase of matrix permeability, the duration of composit radial flow is prolonged. The shapes of pressure drawdown plots indicate the level of fracture connectivity of the reservoir. Whereas the fracture connectivity is related to the fracture intensity (FI). The critical value of fracture intensity is observed around 60 percent which results in the formation of connected fracture network.
The interpretation of pressure responses of PNFR becomes very difficult and challenging because the available simplified models do not relate to reality of reservoirs. This paper quantifies the fracture intensity for a broad range of PNFR with the use of pressure transient responses. This quantification is a major contribution to the present literature.
Modern Jack-Up Design Solutions for Mature Markets
Authors: Baan Rutger , van der List Remco 
Published: March 2016

Abstract
In mature oil and gas fields particularly in the Middle East, India, Gulf of Mexico, West Africa and Asia, a specific footprint is required due to earlier campaigns. The key reference is the LeTourneau-116 design. With its specific footprint, it is the most widely used jack-up design in these regions. The CJ43 drilling jack-up, based on its successful predecessors, is the modern replacement and sets a new standard for jack-up drilling rigs used in mature oil and gas fields.
Drilling technology has evolved over the years. The focus has been on drilling equipment reliability, mechanization, partial automation and advanced well control. However, when reviewing the overall jack-up technology – excluding the drilling related equipment – a large part of what has been ordered recently resembles the same design philosophy of thirty to forty years ago. No significant changes on the jack-up design to improve its capabilities in terms of uptime, efficiency, material handling, maintenance, redundancy of critical systems and elements to improve human life on board.
But, when applying innovative technology, a more modern jack-up design such as the CJ43 can be shaped which delivers operational benefits to owners and operators in terms of lower OPEX and higher operational flexibility.