bluuebunny/crossref_metadata_2025_split huggingface dataset:
Manifa Oil Field Development Program – Onshore And Offshore Shallow Water Development
Authors: Aldossary Ghassan 
Published: April 2015

Abstract
The Manifa Oil Field is located approximately 200 km northwest of Dhahran and lies mainly offshore in shallow waters. The field was discovered in 1957, and was brought on-stream in 1964. Due to low crude oil demand, the production from the Manifa Oil Field was stopped in 1984, and the facilities were mothballed in 1985. In 1995, the existing GOSP facilities were dismantled.
In 2006, Saudi Aramco embarked on the development of a mega-project at the Manifa shallow water offshore oil field to develop the field and construct the required infrastructure and facilities for a production capacity of 900,000 barrels per day of Arab Heavy crude oil. This new development at Manifa can be classified as being a true grassroots venture, as it converts an offshore field into an onshore project, which is the largest extended reach project of its kind in the world.
During the project execution, the team navigated through many challenges considering the extremely large magnitude of the program. Such challenges include oil field development options, the integration of the drill sites with the pipeline system, the causeway design and options, the crude transportation pipelines configuration, compatible facilities metallurgy, the electrical power system architecture and the collection, transportation, integration, analysis and reporting of data collected from the drill sites through the massive RTU and SCADA systems.
Once the conceptual development design for the program was complete and agreed by all stakeholders, the sequence of facilities completion had to be planned in a manner to support the project completion schedule. The integrated activities schedule had to interlink with the well's drilling activities, flow lines installation and the onshore plant readiness simultaneously, overcome the limited space in the man-made island, work through simultaneous operations between drilling and the construction agency, while also monitoring the environmental marine life in the shallow waters of the Manifa bay and enforcing high levels of safety standards by performing periodic safety drills.
This paper covers mainly the design of the offshore facilities and the Manifa Causeway and does not discuss in detail the onshore facilities and infrastructure, which is another large aspect of the overall Manifa Program.
Adaptation of Coiled Tubing for Deep and Ultra-Deep Water Commissioning: Focus on Fatigue and Ancillary Equipment
Authors: LIROLA François , PIONETTI François-Régis 
Published: April 2015

Abstract
The installation of flowlines in ever deeper and remote areas requires the usage of specific technologies in order to carry out pre-commissioning operations. As the water depth increases, the weight of the conventional equipment to be deployed to perform the required operations becomes a major issue and alternate solutions are thus required. An option lies in using Coiled Tubing. Coiled Tubing consists of continuous pipe that has been coiled around a reel and can be deployed and recovered according to operational needs.
So far, offshore operation of coiled tubing has been limited to small diameters and to short operational duration. The pre-commissioning operations can require the Coiled Tubing to be deployed several times for durations sometimes exceeding a month, and also requires larger diameters (typically 3.5"). As the duration of operations increases, a suitable way of assessing the fatigue of Coiled Tubing and of mitigating is required.
In order to address these challenges, SAIPEM has initiated an extensive fatigue campaign aiming at characterizing the fatigue behavior of Coiled Tubing under combined Plastic and Elastic fatigue. This testing campaign is being performed on actual coiled tubing samples made of CT-80 steel. The paper will present an overview of the testing matrix as well as an insight on the results obtained during this fatigue testing campaign.
In addition, in order to mitigate fatigue during offshore operations, SAIPEM has also developed an innovative bend stiffener design in order to control the stress levels in the Coiled Tubing at the hang-off location on the ship. This bend stiffener design allows for safe and easy operation of Coiled Tubing offshore while allowing the deployment of all required equipment and doesn't interfere with the deployment and recovery of the coiled tubing. A feedback on the utilization and performance of such equipment offshore will be provided.
Low-Heave Semi-Submersible Enabling Dry-Tree Field Development
Authors: Muehlner Edmund , Banumurthy Surya 
Published: April 2015

Abstract
The objective of this paper is to present the new Offset-Pontoon Semi-submersible (OPS) for use as a drilling and production platform. The new semi-submersible features pontoons that are offset to the outside of the columns which lends the vessel a low heave response and enables the use of top tension risers with dry trees. Other advantages of the OPS are a shallow quayside draft, a large payload capacity and the ability to operate in ultra-deepwater.
The primary design challenge for dry-tree semi-submersibles is to make their heave motions compatible with the stroke range of existing riser tensioners. Increasing the vessel draft to reduce the heave motions is constrained by installation requirements and stability limits. However, vessel heave motions can be reduced by modifying the hull shape.
The OPS has a longer heave natural period and a smaller heave response than a conventional deep-draft semi-submersible. The heave performance of the OPS was compared with a conventional semi-submersible using frequency- and time-domain analyses.
In this paper we also present a design study of the OPS for dry-tree field development offshore Brazil. The vessel was sized to support thirteen top-tension risers and a 30,000 ton topside. The paper describes design of the vessel and its global performance. Focus of the study was the wellbay loayout and the tensioner stroke requirements. For the selected design case we found ram-style riser tensioners with a stroke range of 30 ft sufficient. Integration of the hull and topside by float-over is also described.
Intelligent Wired Near Bit Underreamer Connects Measurement While Drilling Tools to Rotary Steerable System While Eliminating the Under Gauge Rathole at TD
Authors: Valverde Eduardo , Goodwin Alex 
Published: April 2015

Abstract
Simultaneous drilling and hole enlargement is a common practice in deepwater Gulf of Mexico projects where tighter casing tolerances are required. Hole enlargement via underreaming is the most common practice, because it provides a larger diameter hole to ensure that casing reaches its required total depth (TD). Hole enlargement creates sufficient annular space to allow casing to be delivered to planned depth as well as for a properly executed cement job. The most accepted bottom hole assembly (BHA) design for hole enlargement while drilling (HEWD) places an underreamer above both the measurement while drilling / logging while drilling (MWD/LWD) and rotary steerable system (RSS) packages. This placement ensures proper installation of the activation ball in the underreamer and connectivity of the RSS and MWD/LWD so that directional work can be executed. However, this placement also leaves up to 200 feet (61 m) of under gauge rat hole to total depth (TD), forcing the operator in many cases to make a second dedicated run to underream the remaining under gauge rat hole.
An alternative underreamer technology that is gaining interest is designed to run directly above the RSS, but below the MWD/LWD package. Known as the intelligent wired underreamer, this design allows for a much shorter under gauge rathole to TD, while circumventing several common deployment challenges with conventional underreamers. Historically, placing an underreamer below the MWD/LWD prevented the operator from pumping an activation ball through the restricted internal diameter of the MWD/LWD tools. Another challenge of placing the underreamer near the bit is the fact that connectivity is severed between the MWD/LWD and RSS, which makes it impossible to use certain RSS in the BHA.
A deepwater operator drilled a development well in the Gulf of Mexico which required such a solution to simultaneously drill and enlarge the 18 1/8" and 16 ½" sections of the wellbore to 22" and 20", respectively. The intelligent wired underreamer, with its radio frequency identification (RFID) and pump-cycle activation capabilities, allowed the operator to run the underreamer directly above the RSS and below the MWD/LWD package and successfully activate and deactivate the underreamer, without ball drop. A wire through the underreamer connected the MWD/LWD and the RSS, providing full connectivity and directional control. And the use of an intelligent wired reamer in this application eliminated a potential round trip to ream the rathole and allowed the operator to successfully drill and ream both sections to planned TD.
Future Changes in Gulf of Mexico Hurricane Impacts
Authors: Done J. M. , Bruyère C. L. , Holland G. J. 
Published: April 2015

AbstractMeeting industry demand for assessments of future changes in Gulf of Mexico hurricane impacts is a challenge that extends beyond simply improving hurricane science. There remains a need to translate the latest hurricane science to industry impact assessments. The National Center for Atmospheric Research is actively engaged in a collaborative project with the Research Partnership to Secure Energy for America, the CASE-EJIP JIP, and Willis Re to align the latest hurricane science with the requirements of industry.Loading on structures in the Gulf of Mexico is a complex function of wind, wave, and current. Simple empirical relationships miss some of the essential physics, particularly under extreme conditions, resulting in errors in design criteria such as the 100-year load. To account for these important processes, a modeling approach is designed that reconstructs historical hurricane wind fields that are then used to drive dynamical wave and current models. Using this approach, historical hurricanes is simulated under current and future climate conditions, and potential future changes to wind, wave and current are assessed.An alternative and complementary approach to assessing hurricane damage is developed. This approach uses empirical relationships between the large-scale environment and hurricane parameters that are known to cause damage (intensity, size and forward speed) to assess future hurricane damage. This approach projects a future decrease in mean tropical cyclone damage potential of 15 percent by the 2070s with a range of +2 percent to -57 percent. This combination of approaches is anticipated to lead to better planning guidelines that will enable improved design of structures and operating procedures, which in turn will provide more efficient future oil and gas production and aid in the minimization of environmental and safety risks.
Methodologies for In Situ Detection of Subsea Meter Fouling
Authors: Zanker Klaus 
Published: April 2015

The increasing global importance of subsea production drives the need for better accuracy in subsea measurements to allow precise reservoir management while ensuring accurate royalty assessment and production allocation. The work described here resulted from the previous RPSEA Project 1301, which showed that flow measurement errors of 10 to 20 percent were possible when meters were subject to scale or erosion. The objective of this work under RPSEA Project 4304 is to identify ways of detecting fouling in multiphase and wet gas meters, so that corrective measures can be taken before large errors occur.

The effort consisted of two major parts:

An examination of the state of the art in sensor and meter technology was conducted for the purposes of detecting and/or quantifying meter fouling. A number of ideas were considered.

An evaluation of these and other technologies was performed to ultimately select the three most promising methods from the technology review. The criteria for choosing the most promising methods are discussed. The chosen methods were:
The results of these developments show promise, can be used in parallel and are discussed in the paper.
Offshore Production Units for Pre-Salt Projects
Authors: de Andrade Ana Maria Teixeira , Vaz Célio Eduardo Martins , Ribeiro Jônatas , Lopreato Luiz Guilherme Roquette , do Nascimento Rafael Fernando Soares 
Published: April 2015

Petrobras and partners have been developing Brazilian Santos Basin Pre-Salt ultra-deepwater areas through the use of Floating Production Storage and Offloading Units (FPSOs), equipped with topside facilities designed to receive produced fluids and process them to generate end streams to export and injection.
The large hydrocarbon volumes in Santos Basin Pre-Salt areas, which have been successively confirmed by the results of exploratory and productions wells, have encouraged Petrobras and partners to choose an aggressive development strategy over a more conventional one. Based on this decision, FPSOs were chosen, mainly due to crude oil storage capability thus not requiring the construction of long-length oil pipelines, and also because of other characteristics that allow a short term completion with economic advantages. Therefore, the topside process plant conceptual design had to deal with uncertainties in the reservoir fluid compositions and production profiles. This means a wide range of CO2 and H2S contents, oil API gravity, flow rates and arriving fluid pressures and temperatures, in order to guarantee an adequate nominal capacity and turndown, and also the proper performance within the established design cases.
The main purpose of the topside facilities is to gather and treat the produced fluids to be sent ashore. The treated oil is routed to cargo tanks, the produced water is treated and discharged overboard, an dthe bulk treated gas stream is exported through a gas pipeline network, which allows to send the stream to three different gas processing sites onshore. The separated CO2-rich stream is injected back to the reservoir.
Besides the production units specially designed for Santos Basin Pre-Salt features, some Pre-Salt reservoirs from Campos Basin have been also being produced, by connecting new wells to existing production units. The main approaches regarding these units and its production in Campos Basin Pre-Salt are also part of the scope of this paper.
As a result of these different strategies and due to the daily efforts to overcome the forementioned challenges, more than six hundred thousand barrels per day of crude oil, as a monthly average, have been produced in Brazilian Pre-Salt areas, after only eight years since the early developments of the area.
The Contribution from an Operator's Global Subsea Hardware Standardization Program to 10K Subsea Hardware on Parque das Conchas (BC-10)
Authors: de Carvalho Thiago Palmeira Freire , Olijnik Luiz , Labes Alan 
Published: April 2015

AbstractThe Parque das Conchas field in Campos basin offshore Brasil is a phased ultra-deepwater heavy oil development tied to the Esp rito Santos floating, production, storage and offload (FPSO) vessel, moored at a water depth of 1,780-meters. The subsea system utilizes a subsea boosting and separation technology, enhanced recovery through water and gas injection, subsea sampling, enhanced vertical deepwater trees (EVDT), steel lazy wave catenary risers, and high voltage multiplexed electro-hydraulic steel tube umbilicals. During its nine year development since sanctioning, the professionals, installation contractors, commercial and contractual conditions have changed and played their role on the successful deployment of the subsea systems architecture. The project's successful track history to date is largely attributed to the development and consistent application of standardized subsea hardware throughout its three distinct and independently developed phases.This paper addresses the standardized features applied to the 10,000-psi (10K) rated subsea system components at BC-10: EVDT systems and tooling, including the upper completion tools which allowed deployment through either a subsea or surface blow-out preventer; completion and intervention riser systems on the lower riser package; retrievable flow modules and flow meters; production and injection jumper kits; manifolds; subsea boosting and separation; subsea control modules; umbilicals and subsea distribution hardware. This paper also addresses how these features fit within the operator's global subsea hardware standardization program, and provides examples on how continuous improvement, lessons learned and innovations are implemented in that program.
Water Hammer in Upstream Production
Authors: Danielson Thomas J. , Gokcal Bahadir 
Published: April 2015

Abstract
Water hammer, or more properly ‘liquid hammer’ simulations are commonly performed with transient simulation software. However, care must be taken in the setup of such simulations to assure good fidelity with the field operation being simulated. Of critical importance is the realization that a sudden pipeline shutdown has a symmetry where a pressure reduction (which can easily result in the creation of a vacuum strong enough to pull gas out of solution, followed by explosive recompression of that resultant gas phase) occurs at the inlet of the pipe equal in magnitude to the pressure surge at the outlet. Much can be done with ‘pencil-and-paper’ calculations, including a worst-case estimate of surge pressures using the Joukowsky Equation. This equation can be further modified to account for elasticity, as would occur, for example, in a tanker loading hose – in fact, this modification is essential to obtain the correct behavior from the simulation models. This paper presents transient simulations, along with comparisons to pencil-and-paper equations and theory, to come up with a best-practices approach to water hammer modeling.
A Case Study of Asset Integrity and Risk Assessment for Subsea Facilities and Equipment Life Extension
Authors: Carvalho Eduardo , Tang Fei , Allen Eric , Sharma Partha 
Published: April 2015

Abstract
The ever increasing oil and gas exploration and production cost requires highly efficient and safe operation of the existing offshore and subsea equipment and facilities. At the same time, a large number of facilities and parts of the existing infrastructure are quickly approaching or have exceeded their originally designed service life. Many fields, however, still have large amount of remaining recoverable oil and gas reserve which can be profitable if current production equipment's service life can be extended beyond their nominal design, otherwise economic penalty of stopping production or installing new equipment will be too high.
On the other hand, once existing equipment have been operating beyond their design life, unforeseen failure and integrity problems can occur that site personnel may have not previously encountered. In many cases this can cause production to cease unexpectedly, and result in costly emergency repairs to get the asset back online.
To extend asset life and push the design envelop, operators must prove to themselves and often their regulators that the assets are safe to operate with limited and controlled risks. In a scenario like this, the subsea integrity management of ageing assets has become a key issue for the oil and gas industry.
This paper provides an actual case study for asset integrity assessment of subsea facilities life extension, performed by DNV GL and the O&G asset operator team. The study includes the asset integrity condition assessment based on equipment design documentation, operations data, maintenance and inspection analysis data, risk assessment and recommended mitigation of identified threats, engineering critical analysis of high risk equipment, and proposed destructive lab testing of parts retrieved from subsea.
Electrical Power Transmission to Offshore Facilities: A Case Study
Authors: Bari S. J. 
Published: April 2015

Abstract
As the world continues its search for energy, many new advanced technologies are being developed. As a result, there is a surge in the amount of electrical power demanded for operations in the oil and gas industry. Satisfying the power demanded by loads in offshore remote locations is an elaborate process. The technical and economic aspects of the alternatives of HVAC and HVDC power transmission have to be scrutinized, before the complex operation of implementing an offshore power supply infrastructure can be executed. After carefully identifying the requirements of a case, the optimum power supply network through appropriate submarine cables can be determined.
North Sea and GoM Initiatives to Enhance Process Safety
Authors: Pitblado R. 
Published: April 2015

AbstractThe onshore and offshore O&G industry has achieved an outstanding improvement in occupational safety over the past 20 years, however major accident performance has improved much less. The North Sea appears to have a better performance record on major accidents. Process safety initiatives in the North Sea and the Gulf of Mexico are compared and key differences identified in two timeframes - since Piper Alpha and since Macondo. The North Sea since Piper Alpha has been driven by performance style regulations that require detailed risk assessment and definition of critical safety barriers and this is combined with safety management and culture programs, and the idea of a safety case. The USA was more prescriptive until Macondo, but since then some performance style regulations have been adopted - such as SEMS. The industry through API, IADC and COS have supported these initiatives. While SEMS is a valuable initiative, further initiatives such as those demonstrated in the North Sea would enhance process safety further in GoM.
MoC-Based Modeling and Simulation of Foam EOR Processes in Multi-Layered System
Authors: Lee Seungjun , Kam Seung Ihl 
Published: April 2015

Abstract
Foam injection is a promising means to improve field-scale displacement efficiency, especially when a reservoir consists of multiple geological layers, the connectivity of which is minimal or absent due to the shale layers embedded in between. This study is devoted to investigating how foam EOR processes work in such heterogeneous and layered reservoir systems overcoming subsurface heterogeneity by using fractional flow analysis.
This study first shows how to interpret theoretically the injection of surfactant preflush and following foams into a single-layer system at pre-specified rock and fluid properties, and then extends the knowledge gained into multi-layer systems where the properties vary in different layers. The results in general show that the mechanisms of foam displacement strongly depends on foam properties such as gas-phase mobility reduction factors (MRF), limiting water saturation (Sw*), and critical oil saturation (So*) as well as petrophysical properties of individual layers such as porosity (f), permeability (k), relative permeability, capillary pressure (Pc) and so on. The overall sweep efficiency in a multi-layer system is very difficult to predict because of the complexity, but the mathematical framework presented in this study is shown to handle the problem successfully and reliably. A 1D foam simulator developed in this study is used for verification purpose.