bluuebunny/crossref_metadata_2025_split huggingface dataset:
Cascade and Chinook Fields: Integrated Overview of the Reservoirs
Authors: Syrio Julio Cesar , da Cruz Paulo Sergio , Nguyen Nhom Vince , Navarro Alonso , Becker Mauro , Watkins Elizabeth Ann , Riera Ladimir Alberto , Leite Renato 
Published: May 2013

Abstract
This paper is based on the work performed during the design, implementation and operation of Cascade and Chinook fields and it provides an overview of the Cascade and Chinook fields' reservoirs, part of the emerging Ultra-Deepwater Wilcox Trend in the Gulf of Mexico. A general picture of the structure, stratigraphy, depositional facies, and petrophysics of each field will be given. Reservoir engineering parameters will also be discussed as well as the initial field development.
The main result of this work is a consistent integration of all available data, following a recommended workflow process, aiming to build a geologically coherent and realistic reservoir models for these fields. The match of real field production information with the dynamic flow models allows the reduction of uncertainties of the scenarios and better support for the production forecast. From the integration of seismic, logs, fluids, cores and production data has emerged structural models similar for both fields: a faulted salt-cored anticline divided roughly into western upthrown and eastern downthrown blocks, populated with amalgamated-to-stacked turbidite sands. The petrophysical model developed considers the geologic background and supports the dynamic flow model.
The main technical contribution of the work presented in this paper is an overview of the reservoirs that have pioneering production from the Lower Tertiary (Wilcox) Ultra-Deepwater trend (Walker Ridge area). These fields are the first analogues for a mostly untested trend which is still projected to have significant production potential. Currently, numerous oil & gas companies have several Wilcox fields, prospects, and plays in varying stages of development in the area. The information provided and the modeling approach used in this paper can be applied as guidelines for similar Lower Tertiary reservoirs developments in the deepwater Gulf of Mexico.
Large Bore Expandable Liner Hanger provides Reliable, Cost-Effective Solution for Liner Placement in Critical Well Path
Authors: Johnson Michael (Rick) , Ardoin Kevin Wendell , Sweep Miles Norman , Wyatt Nathan Barrett , Benet Paul 
Published: May 2013

Abstract
This document reviews challenges and solution to previously overwhelming issues regarding 14-in. liner placement in the Gulf of Mexico. Necessity and considerable effort are required to deal with multiple mobile/active tar zones, associated with fault zones throughout the sediment sections and below the base of salt. Deploying liners to the desired depth through such hole sections have resulted in costly non-productive time (NPT). The large bore expandable liner hanger drilling/washing capabilities provides a reliable method to assist the operator in reaching their targets.
Advancements in casing connection technology have provided enhanced torque capabilities for some time. Today, the large-bore expandable liner hanger (LBELH) system provides the capability and reliability to deliver torque to the liner shoe. This added rotation and reciprocation capability while circulating is at the heart of NPT reduction.
The running tools to deliver such a system have the capacity to provide 110K foot pounds of torque at top of liner (TOL). Reaming/drilling attachments to the liner shoe have advanced to a point that allows operators to take advantage of the technique to deliver the liner to its target depth.
This combination of equipment allowed a major Gulf of Mexico operator to wash and ream a 14-in. liner through tar and shale, inside their 16-½-in. borehole. Two successful attempts totaling 7-½ hours of reaming resulted in gains of 335 feet. The final effort was to wash and ream the liner down inside the 14-½-in. pilot hole. This was an additional 30 feet of " drilling conditions" to total depth (TD), requiring an additional 45 minutes of torque and vibration.
The liner was cemented and the hanger was set and tested. The operator commented: " Excellent results", [and that he was]"Very pleased to get this critical and difficult section cased off". (Benet, 2012)

Introduction
With proven expandable technology already in place due to problems experienced with traditional liner hangers in difficult well-bore scenarios, the time had come to push toward large-bore expandable liner hangers (Cantu et al, 2004; Nida et al, 2004). The main components of the expandable liner system are an integral liner hanger/packer assembly combining an upper tie-back receptacle with elastomeric elements, which are bonded directly to the body of the hanger.
Figure 1 shows the basic components of the original expandable liner hanger (ELH) system compared to a conventional " casing hanger". The bonded elastomeric elements compress against the internal diameter as the hanger expands which virtually eliminates any leak paths between the liner, liner hanger, and previously run casing, maintaining the pressure integrity of the well bore (Moore et al, 2002).
Mooring System Life Extension Using Subsea Inspection Technologies
Authors: Pederson Tia Anne , deGier Tyler SC , Hall Anthony David , Allan Scott 
Published: May 2013

Abstract
The need for quantifiable inspection methods to evaluate the potential for life extension has become increasingly important for a large number of floating production facilities nearing the end of their design life. This paper discusses the use of a risk-based progressive inspection methodology to identify, quantify and analyze the condition of mooring systems and ultimately determine fitness for purpose.
Due to an increase in mooring system failures and the growing knowledge of failure mechanisms, many operators are moving towards more comprehensive inspection plans in addition to the minimum requirements as set by Class. Using a risk-based inspection plan and focusing on known areas of vulnerability allows for a higher probability that issues are identified before they become catastrophic.
Welaptega's experience with in-service mooring inspection has exposed numerous cases worldwide where mooring systems have been severely degraded due to accelerated and unexpected deteriorative mechanisms. In each case a decision to either replace the moorings or keep them in service had to be made.
Inspection programs using a number of Welaptega's measurement and modelling tools has allowed operators to identify the most severely degraded sections in a mooring system. Data collected makes it possible to produce 3D models of chain links which are used to evaluate the extent of material loss. The application of finite element analysis enables the client to quantify the residual strength of the mooring chain and estimate remaining fatigue life; from here a decision to extend the life of the mooring system can comfortably be made. In the past, finite element analysis combined with break testing has proven that even severely degraded mooring chain may still be fit for purpose in some circumstances.
The ability to provide high quality and quantitative subsea intelligence will continue to allow operators to make risk-based decisions, increasing the economic viability of field life extension without compromising asset integrity.
A Nonlinear Dynamic Substructuring Approach for Efficient Detailed Global Analysis of Flexible Risers
Authors: Dib Michel W , Cooper Philip Adrian , Bhat Shankar , Majed Arya 
Published: May 2013

Abstract
This paper presents a significant methodology advancement that addresses one of the industry's most challenging problems: the accurate prediction of detailed local stresses in unbonded flexible risers. Flexible risers exhibit highly nonlinear dynamic behavior due to the stick/slip interaction between the pipe wall layers in compliant systems that undergo large three-dimensional translations/rotations. Practical, accurate prediction of critical flexible pipe component responses requires an efficient method capable of incorporating detailed flexible pipe models into a global nonlinear dynamic analysis. Current industry practice is a two-step global/local approach involving a global nonlinear analysis with 1D centerline models, which may include bending hysteresis effects, followed by local analysis of a detailed model segment to the global results to predict critical response items such as armour wire stresses.
A Nonlinear Dynamic Substructuring (NDS) framework is developed that expands the classical methods of dynamic substructuring and component-mode synthesis to geometrically and locally nonlinear problems. This evolution/integration of capabilities enables the computationally efficient inclusion of detailed flexible pipe models into, and recovery of detailed response/stress time-histories directly from, the global nonlinear analysis itself. The NDS methodology is benchmarked against published work involving the large deformations static and dynamic global analysis of a flexible riser. The full potential of the method is then demonstrated by efficiently incorporating 3D detailed flexible pipe substructure models, with bending hysteresis, into a global system nonlinear analysis and recovering stress time-histories in tensile armour layers.

Introduction
The accurate prediction of local stresses in flexible risers has been an industry objective for some time. Flexible pipe has a complex structure composed of multiple interacting pipe wall layers (Figure 1). The stick/slip friction hysteretic behavior of these layers is directly coupled to the global large displacements of the overall compliant system resulting in a highly nonlinear problem. A common approach for analyzing flexible risers is to conduct the global analysis with standard line elements utilizing the flexible pipe's unpressurized linear bending stiffness.
Stranded Gas Field Development with Cluster LNG Technology
Authors: Eisbrenner Kathleen , Lee JungHan , Choi DongKyu 
Published: May 2013

Abstract
There are many small scale onshore and offshore gas fields and there are also many diverse small LNG consumers around the world. However, smaller unit of gas fields could not be practically developed due to unfavorable unit price competition with larger ones. Therefore, many stranded gas fields are still waiting for new viable technology for the small unit production. In order to have unit production cost competitiveness, CAPEX and OPEX should be reduced. Cluster LNG technology based on increased pressure liquefaction has distinct advantages in OPEX and CAPEX with inherent high liquefaction efficiency together with superior environmental performance. One of the potential gas consumers for the small capacity LNG would be fuel oil fired diesel engine or gas turbine power plant operators who eagerly attempt to change the fuel source to natural gas due to high fuel oil price. Most of the cases, power plants are located far away from the gas fields, so efficient gas transportation solutions have to be provided. LNG is efficient means of gas transportation between 2 different locations. On the other hand, it requires complicated gas treatment and liquefaction systems which results in high delivery cost. Considered that gas engines need gas as final form not as LNG one, if the interim product of LNG liquefaction is simplified, it would be beneficial to overall project economy. As an application example, extensive economic studies for 0.5 MTPA Cluster FLNG, LNG transportation vessel, and 350 MW capacity LNG power plant have been carried out. Typical distance from the gas field to power plant is 2,000 Km though it can have competitiveness up to around 5,000 Km. The smaller unit LNG production system with high competitiveness would activate developments of stranded gas field, and it would change business paradigm by bringing flexibilities and diversities in the industry.
Gulfstar Spar VIM Responses in Flume Tank
Authors: Antony Arun George , Halkyard John , Huang Ken , Park Young Chan , Islam Mohammed , Moideen Hisham , Herrington Paul 
Published: May 2013

Abstract
The Gulfstar® FPS utilizes a standard Classic spar hull form (full depth, cylindrical hull) with a significantly shallower draft than previous Classic spars. Vortex Induced Motion (VIM) is a well-known but complicated phenomenon for cylindrical hulls and model testing is still the norm to determine the platform's VIM response characteristics.
Towing-type tests are widely accepted and employed for VIM model tests; however this test method only simulates a uniform current profile with depth. In the actual ocean environment, only sheared currents are present so the tow test method over-predicts the loading on the cylinder from current, particularly in the deeper portions of the hull. To achieve more realistic test results for VIM testing, it is desirable to use sheared currents, especially for deep draft floaters, such as a Classic spar.
Recent advancements in generating good quality sheared currents involve using a Flume Tank where the model is stationary and the water flows past with its velocity varied with depth. This paper describes a recent test program using this technology in a Flume Tank to explore effects of sheared currents on the VIM response characteristics of the Gulfstar® FPS. In addition to the capability of generating sheared currents, the Flume Tank, completely removes the constraints of towing tank length and the number of realizations for each test case. For benchmarking purposes, a uniform current is also generated in Flume Tank.
Distinct VIM responses have been observed in both types of current profiles. These findings are presented and discussed in this paper.
The value for the offshore industry from better predictions of VIM responses using model tests would be hard to overestimate. Being able to test using sheared currents is a valuable step toward obtaining more accurate test results for VIM type responses.

Introduction
The Gulfstar FPS® is a standard floater solution for the Gulf of Mexico region. The Gulfstar hull has a diameter of 25.9m (85ft) and a draft of 159.7m (524ft) making it much smaller as compared to other classic Spars in the Gulf of Mexico. Cylindrical structures such as Spars are known to exhibit Vortex Induced Vibration (VIV) or Vortex Induced Motions (VIM). VIM has increasingly become critical to the design of riser and mooring system. Low frequency fatigue in mooring system and risers due to VIM often drives the design of riser and mooring systems. Even though VIV has been investigated extensively over past three decades, prediction tools for VIV/VIM response of various systems are still very limited. Model testing is still the industry standard for determining the VIM performance of floaters. VIM is also observed on column stabilized units such as TLPs and Semi-submersibles [18], though not as significant as Spars.
Exploitation and Production of Gas Condensate Reservoirs
Authors: Vega Riveros Gina 
Published: May 2013

Abstract
Latin America countries have shown a great interest for increasing the reserves of gas and gas condensate reservoirs in mature fields. However, the production per well in some cases is very low with an elevated cost of production. It has pushed in some countries to adopt a long work strategy to handle multi-research studies oriented the enhancement of the field production in pre-selected mature fields.
In the Eastern Venezuela, gas reserves are concentrated in Anaco area, Anzoategui State. Anaco has been one of the most important operational districts and it has a high number of gas condensate reservoirs. However, a good portion of the remaining reserves are still trapped due to inefficient drainage and low production. Due to the importance of exploitation in these fields, it is fundamental the development of new technologies that allow their exploitation and production.
This paper presents an analysis method to accelerate production, as well as, recover additional reserves based in the detection of connected pay sands known as hydraulic units. The integration of the geology, seismic, petrophysic, geochemical study, fluids and reservoir properties identified the existence of hydraulic units through both areal and vertical communication. The reserves were evaluated using analytical methods, volumetric analysis, empirical correlations, P/Z material balance and probabilistic analysis. From static model, well correlations identified stratigraphic coalescence between G and H sands. The dynamic model detected that the four reservoirs are hydraulically connected showing an increase of gas condensate in place GCIP of 231.99 BCF in comparison official data. Based on the analysis of well spacing, there was a good opportunity to increase the daily production rate via adopting infill drilling.
The development strategy proposes the exploitation of several sands by hydraulic units, fracturing, pumps, workovers, infill drilling, well highly inclined and horizontal well in order to contact higher reservoir volumes and accelerate the operational process. A compositional simulation study was recommended to evaluate the factibility of injection EOR fluids, recycling gas and water-flooding as a secondary recovery project. This will increase the recovery factor and help to maintain the reservoir pressure.

Introduction
Many of the fields of the traditional areas of eastern Venezuela still contain important gas reserves but the majority is not economically viable for production because the principal productive sands are partially depleted. As it is well known, government regulations have established that each reservoir should be completed and produced individually. However, the production of some wells of gas condensate reservoirs is very low (between 40 and 60 STBD per well) with an elevated cost of production.
Projecting Shuttle Tanker Fleet for Gulf of Mexico FPSOs: Discrete Event Simulation
Authors: Majhi Sai , Feng Jeffrey , Kulkarni Makarand , Fales Raymond 
Published: May 2013

Abstract
This paper will present a Discrete Event Simulation (DES) based solution for an optimum shuttle tanker fleet to serve the present and future FPSO based Gulf of Mexico (GoM) production. The simulation takes into account average ‘field lifecycle’ based production rates of specific developments and the sensitivity of ‘offloading availability’ to variables such as shuttle tanker size, loading rate, distance to market etc. A probabilistic representation of downtime associated with wave, wind, currents, maintenance etc. at the FPSOs and random weather and non-weather delays at the receiving terminals have also been considered in this effort.
Despite the impressive pipeline infrastructure available in the GoM, none of it currently reaches some of the newer fields being discovered in over 5000ft water depths in the lower tertiary trends. The high cost of pipeline extensions in ultra-deep water (UDW) and uncertainty in the producibility of reservoirs has multiple operators considering an FPSO - Shuttle Tanker (ST) based solution for production export. This paper would help operators considering this option to understand the limitations and potential options in using shuttle tankers in serving the field(s).
The assessment of offloading availability for shuttle tankers to serve multiple fields would be made on the basis of production rate, loading rate and tanker size using a Discrete Event Simulation (DES) model subject to threshold and offloading operational downtime.
The development of the Cascade-Chinook field at the US GoM has established its viability using dedicated shuttle tankers. However, potential of synergy in using a common fleet of shuttle tankers exists subject to further FPSO based developments in the near future. This paper explores the technical and logistical feasibility of such a possibility.
Operational Experience With a Cylindrical Floater Design Demonstrating the Feasibility of Safe Permanent FPSO/FSO Mooring in Areas With Tropical Cyclones
Authors: Major Fredrik 
Published: May 2013

Abstract
Sevan Marine has successfully pioneered the cylindrical floater concept to the market with 3 FPSOs and 2 MODUs in operation and an additional 4 FPSOs and 2 MODUs in construction. The paper will present these units and the operational experience in harsh environments in the UK Central North Sea. Through studies supported by major oil companies, a concept for safe permanent mooring of a floater through the typical design tropical cyclone in areas like NW Shelf Australia, South China Sea or Gulf of Mexico is demonstrated to be feasible. The paper will present the analysis, model tests and full scale motion recordings, supporting this conclusion. Finally some new methods for offloading to export tankers will be presented, also including systems relevant for LNG offloading to standard LNG tankers from an FLNG unit.

Introduction
Operation of FPSOs in areas exposed to tropical cyclones is today largely based on disconnect-able ship-shaped units. The disconnect requirement has several disadvantages such as production downtime, complexity of disconnect system, requirement for the unit to operate as a navigable ship.
Yearly production downtime will be based on number of disconnects and duration of production downtime due to disconnect. The additional downtime will vary from one area to another, but an additional downtime of 5–10% can be seen in many cases.
Added complexity for the mooring and riser system in order to allow for safe disconnects and re-connects of mooring lines and riser bundle will add in the order of magnitude 30–50% to the turret mooring system.
For operating the FPSO as a navigable ship, a marine crew as well as propulsion and navigation systems have to be in place, adding significantly to both FPSO construction cost as well as cost of daily operation.
Based on the operational experience with the world's 3 first cylindrical FPSOs as well as extensive analysis and model tests carried out, it has been possible to demonstrate that a cylindrical FPSO can be designed for safe permanent mooring in areas exposed to tropical cyclones.
Development of a Monobore, High-Flow, ROV Operable Connector for Gas Lift and other Applications
Authors: Krohn Dan , Kamdar Prashant , Cunningham Michael Thomas 
Published: May 2013

Abstract
The Monobore, High-flow, ROV Operable Connector is a male and female connector and seal system designed for use subsea in small bore gas and fluid piping applications. This system's principle attribute over traditional methods is its ability to be installed in " free fly" fashion, by a typical work class Remotely Operated Vehicle, similar to hydraulic flying leads in production control system applications.
Latching of the type of connector is similar to conventional hydraulic junction plate technology. The tooling required for this operation is also similar to the make-up of hydraulic junction plates utilizing an API 17D class 4 torque tool, flying lead orientation device, and any other easily attachable and detachable stability aides or weights.
To meet these operational scenarios, the connector must be light, made of corrosion resistant materials, and have an extremely reliable sealing mechanism. This system must also be easily configured into a " flying lead", where the tubing or piping is both strong and compliant. This paper describes just such a connector system that is designated as the M5.
For the matter of this paper, the removable half of the connector will be referenced as ‘removable connector’ and the fixed half of the connector will be referenced as ‘fixed connector’.