bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Yme Jack-Up with Skirt Foundation
Authors: Eide A. , Tuen K.A. , Beerheim M. 
Published: October 2008

Abstract
The Yme field is developed using the Maersk Giant jack-up as a permanent drilling and production platform. This paper will present the structural and geotechnical design aspect of jack-up with skirts to document this new way of utilising jack-up structures. It will also outline the design of the riser system and installation aspects of the rig, The skirt foundation is an innovative cost effective foundation concept offering substantial opportunities for extending the use of jack-up structures compared to traditional spud-ears foundations. The Yme field development would not have been economically attractive without skirted foundations on the jack-up.

Introduction
The Yme field is located approx, 100 km south-west of Egersund in Block 9/2 offshore Norway. The water depth is 93 m. The field is marginal with an estimated economical lifetime of 70 months. The producible reserves are approx, 10.4 mill Sm3 oil. The maximum production rate is stipulated to 8000 Sm3 pr day.
The drilling and production facilities are provided by means of a converted jack-up platform, Maesk Giant. The rig was equipped with process weighing 1150 tonnes. In addition the hull was modified to provide support for eight production risers.
A converted oil tanker with capacity of 150000 m' oil is utilised as a Floating Storage Unit (FSU). The vessel is located about 2.500 m from the jack-up platform, and offloading is done by shuttle tankers connecting to the stem of the FSU, ref. fig 1.
Jack-up rigs are widely used as mobile drilling units for the exploration of hydrocarbons. At present jack-up rigs have been placed in water depths of up to 125 m, but there is interest in extending their use to greater depths and larger deck weights, To demonstrate the feasibility of standard jack-up rigs for the Yme field Statoil found it necessary to account for the rotational stiffness of the footing in the structural analysis. Small skirts have previously ken used on spud-cans in shallow water to reduce scour. At Yme, the skirts were used to achieve restraint (bottom Fixity) and thereby reducing the leg utilisation drastically. This new Statoil approach of utilising skirts have previously been used in connection with the Sleipner Vest development in the North Sea, but was then used mainly for increasing the bearing capacity ref. /1/.

Foundation
Skirt Geometry. The spud can-skirt arrangement is shown on figure 2. Each spud-can is equipped with skirt extending 4,8 m down from the circumference of the spud can. The skirt was built up of six 30 mm thick half cylinders, welded to the extension of the three chords and to bottom of the thickness of the lower part of the skirt was increased to 60 mm to resist the forces from the installation phase.
Liuhua 11-1 Development-Subsea Conductor Installation in the South China Sea
Authors: Herrmann Robert P. , Coleman Rod A. , Hughes John D. , Mu Huang Chang , Jiang Zhang Ming , Macfariane Andrew M. 
Published: October 2008

Abstract
This paper describes the initial phase of a multi-well subsea development using a building block technique. This phase included the setting of the conductors for all 20 wells, manifold piles and pipeline bases and the drilling of 15 wells to various stages of completion. Offshore operations were conducted in batches to maximize efficiencies and economies of scale. The emphasis of paper is on the jetting operation of the conductors and the positioning techniques used to meet the requirements of the later phases of the building block process.

Introduction
The foremost challenge for deep water operators today is to develop oil and gas fields economically. Using non-conventional techniques, Amoco Orient Petroleum Company, and its partner China Offshore Oil Nanhai East Corporation, and Kerr-McCiee China Petroleum Ltd., have responded to the challenge by developing the Liuhua field in the South China Sea in a low cost, technically innovative manner that doubled drill-rig productivity and eliminated the need for costly subsea templates. OTC paper 8172 (Ref. 1) presents an overview of the Liuhua project.
The Liuhua reservoir, located 120 miles southeast of Hong Kong will produce oil with an average crude gravity of 22° API and a GOR of 20 scf/bbl. The development plan calls for a manifold with 20 horizontal wells arranged in two parallel lime soften each. Refer to Fig. 1 for the field location and Fig. 2 for the field layout. The deviated wells are horizontal in the pay zone and are produced with submersible pumps powered by cables suspended from the Floating Production System (FPS). The subsea equipment will be created building-block style from the manifold outward, as illustrated in Fig. 3. This approach allows the subsea facility to be expanded by adding future wells or tying in remote clusters. The Liuhua field will produce from ten wells initially with a number of wells being added after for oil. The wells are located without the aid of a template. Production lines or jumpers are measured and fitted between wells after setting the guide bases. These jumpers are fabricated aboard the FIN and can be installed before or after setting the horizontal trees, as described in OTC paper 8175 (Ref. 2).
In October 1994, the Reading & Bates semi-submersible, Jim Cunningham, was contracted to commence development of the Liuhua Field. During this initial five-month drilling phase, five wells were scheduled for drilling to TD and conductor pipe was to be drilled and run for the remaining 15 wells and the two manifold piles. These wells and piles required precise positioning to correctly define the field orientation and to facilitate fabrication of the well-to-well production jumper spools on the FPS. The allowable position error for the locations was l2 ft horizontally and vertically relative to the previous conductor. In the field, a target vertical tolerance of was adopted.
Liuhua 11-1 Development-Downhole Completion Program with Electric Submersible Pumps and Wet-Mateable Electrical Connectors
Authors: Rohloff James M. , Bourne Douglas R. , Shan Yao Jun , Reid James , Hay Donald H. 
Published: October 2008

Abstract
Amoco Orient Petroleum Company, in partnership with China Offshore Oil Nanhai East Corporation and Kerr- McGee China Petroleum Ltd. is installing the first field-wide, subsea electric submersible pump system in the Liuhua Field. Located in the South China Sea, the Liuhua project uses many existing stand-alone technologies, but has created a unique situation by combining them in the development of one field.
As with other subprojects within the overall Liuhua development, Amoco and partners brought in LasalIe Engineering to provide expertise in completions and especially ESP applications, Selection of the completion equipment suppliers and the specific equipment was a joint decision by the partners and Lasalle Engineering.
The equipment selection criteria were driven by the concept of 'fit for purpose,' meaning: 'select the most appropriate supplier and equipment to fit the specific Liuhua Field requirements.' Supplier and equipment selections were based on a matrix of criteria, including:Information case histories of the recommended equipmentWork history in ChinaThe company's safety philosophyQA planTraining philosophyFailure analysis philosophycostsOther factor
Lasalle's compensation for the completion equipment is based on an incentive scheme that results in Lasalle sharing significant risk. Essentially, if the equipment is available for production, a daily rate is paid. If it is not available, then payments stop. The actual daily rate value diminishes with every new installation, thereby requiring increasingly longer operating-run lives to recover their investments.
This paper describes some of the unique completion equipment requirements, the equipment selection methodology, and the completion equipment incentive contract scheme used for the Liuhua Field.

Liuhua Field Description
The Liuhua Field is located in the South China Sea approximately 120 miles (200 km) southeast of Hong Kong (Fig. 1). The field is located in approximately 1,020 ft (310 m) of water. Liuhua was discovered in 1987, and appraisal and delineation drilling occurred through 1989. Amoco Orient Petroleum Company, and partner China Offshore Oil Nanhai East Corporation (CONHE) received approval for the development of the Liuhua Field in 1993 (Refs. 1 and 2). The field development plans include 20 subsea horizontal wells, all incoporating ESPS for artificial lift. As shown in Fig. 2, the offshore facilities include a floating production system (FPS) described in OTC 8187 (Ref. 3), a subsea production system described in OTC 8175 (Ref. 4), and a floating production, storage, and offloading (FPSO) vessel described in OTC 8188 (Ref. 5). The FPS is a semi-submersible drilling unit that has been retrofitted to house the subsea facility control system and provide the power generation for the wells. The FPSO is a 143,000 dwt tanker that has been retrofitted to include the field's process equipment, oil storage, and offloading.
NORSOK Standards -Replacing Company specifications in the North Sea.
Authors: Johansen A.R. , Langeland T. , Tangen T.A. , Haugland T.J. 
Published: October 2008

ABSTRACT
The rising cost of offshore development and reduction in oil prices required new initiatives for the business to survive.
Therefore, the Norwegian oil industry has, as a part of the NORSOK initiative, developed a set of new industry standards to replace individual company specifications. The ultimate goal is to develop a set of international (ISO) standard for the industry.

Abbreviations
CENEuropean Standardization Organization HTML Hypertext Markup Language ISO International Organization for Standardization MIE Minister for Industry and Energy NCS Norwegian continental Shelf NORSOKThe Competitive Standing of the Norwegian Offshore Sector NPD Norwegian Petroleum Directorate NS Norwegian Standard NSFNorwegian Standards Association NTSNorwegian Technological Standards Institution OLF The Norwegian Oil Industry Association SGML Standard General Markup Language TBL The Federation of Norwegian Engineering Industries

The Initiative
The NORSOK initiative was started in the summer of 1993 by the Norwegian Minister of Industry and Energy, Mr. Finn Kristensen. He established the Development and Production Forum for the Petroleum Sector, with top imaging directors of the oil and gas industry, including the politician and the authorities concerned.
The coat of exploration, development and operation was escalating to m alarming level, while the price of oil was dropping. Exploration drilling in the last few years had turned out few discoveries of larger fields, while many small discover were uneconomical to develop with current technology.
The main aim for the Forum was to identification improvement potentials in cost of field developments and petroleum policies that would make the Norwegian Continental Shelf (NCS) more competitive with other petroleum-producing provinces, in order to attract further investment. Two subsidiary objectives were formulated when NORSOK was launched:A 40-50 per cent reduction in cost and lead time over the next five-year period, baaed on beat practice in 1993.Good results have been obtained from work with safety and environmental protection on the NCS, and Norway's oil industry can reasonably be described as one of the safest in the world. It is intended to maintain this position.
The consequent of this initiative was thus hoped to be a continuation end prolongation of North Sea activities, with continued employment and commercial activities in the oil and gas industry. AS this industry currently provides for a substantial income to the state of Norway, this was very much a political issue as well m an industrial matter.

Organization Of work
Having worked for six months on this task, the Abovementioned Forum proposed to the Minister in February of 1994 to launch 7 workgroups, to identical and implement measures that would improve the competitive standing of the Norwegian petroleum industry, and one of these were to deal with Standard. The work groups were to deliver their reports to the Minister within one year.
Liuhua 11-1 Development-MAXIMO Systematic Maintenance System
Authors: Corrigan Mike M. , van Rooy William , Hong Zhao Tian 
Published: October 2008

Abstract
Amoco Orient Petroleum Company (AOPC) used a systematic approach to develop the maintenance systems and programs for its Liuhua Field located in the South China Sea. The development of the Liuhua Field has presented many exciting and unique challenges from both the engineering and operational perspectives. The Liuhua Overall Development Plan established the mission for the operating company to produce and market the Liuhua crude by providing for the design, construction, and installation of the offshore facilities, and for the drilling and completion of the wells. Development of maintenance and operating systems proceeded in parallel with the engineering and construction of the facilities. AOPC took advantage of the opportunity to develop operating and maintenance systems specifically tailored to the unique requirements of the Liuhua Field. A comprehensive plan for maintenance management was developed shortly after project approval, and was executed throughout the construction phase, This paper provides an overview of the approach taken to develop the maintenance programs and systems, and the steps taken to implement the comprehensive system into AOPC.

Introduction
The Liuhua 11-1 Field is located in the South China Sea, approximately 120 miles (200 km) southeast of Hong Kong. The field development plan includes 20 subsea wells produced through electric submersible pumps (ESPS) powered from a permanently moored FPS. The wells are produced through subsea pipelines to a permanently moored, 143,000 FPSO 1,7 miles (2,8 km) away. A location map and field perspective view are shown in Figs. 1 and 2, OTC 8172 (Ref. 1) presents an overview of the Liuhua 11-1 Field Development, its history and the challenges presented to partners, Amoco Orient Petroleum Company (AOPC), China Offshore Oil Nanhai East Corporation, and Kerr-McGee China Petroleum Ltd
Amoco included a small group of experienced operations personnel in the conceptual design phase of the Liuhua project, who were charged with providing practical operations and maintenance input. Based on Amoco's experience at other locations, it was determined early in the conceptual stage of project planning to use a reliability-centered maintenance (RCM) approach in formulating a maintenance strategy to cover preventive, corrective, and compliance related work, and the development and specification of the supporting spare parts inventories. The main objective of the RCM approach is to maintain the inherent reliability that was designed into the facility. Moubray (Ref. 2) provides a detailed explanation and history of RCM. The RCM methodology is based on the following principles:Identifying system functions and defining how those functions are preservedIdentifying failure modes whereby system functions are lost or degradedPrioritizing the importance of the failure mode in relation to the system affectedSelecting effective maintenance tasks that are applicable and appropriate for the equipment component failure modes that impact the identified function
Efficient High-Permeability Fracturing Offshore
Authors: Phillipi Max , Farabee Mark 
Published: October 2008

Abstract
Offshore operators can more efficiently and effectively perform high-permeability and conventional hydraulic fracture treatments by blending treatment slurries under microprocessor control, adding undiluted acid on-the-fly, and altering sand concentrations and other slurry properties instantaneously. A two-skid system has been designed with these considerations in mind. The system, which can be shipped efficiently in 1S0 containers, has been tested on fluids up to 210-cp viscosity and can step or ramp sand concentrations up to a maximum of 20 lb/ gal. All additives, including acid treatments, are added on-the; leftover additives and acids may be stored for future jobs.
The system may be applied in most conditions, including offshore wells requiring conventional or high-permeability fracture treatments and certain land-based wells in remote areas where a compact skid is needed.
Three significant benefits have resulted from using the compact-skid system:Offshore operators have been able to ship the skid system at 2070 of shipping costs of non-ISO equipment.On-the-fly mixing has prevented material waste associated with batch-mixing.Volumes pumped on actual jobs have closely matched job designs.
Data has been collected from several Gulf of Mexico jobs run with the two-part skid system that has been designed for conducting hydraulic fracture treatments from offshore rigs

Transportation
Since shipment of oilfield service equipment is a significant element of well-completion expense, especially in the Gulf Coast area and remote areas, engineers developing the two-skid set designed it to fit into two 1S0 shipping containers. Figure 1 illustrates a typical ISO stacking arrangement commonly used in the holds or on the decks of ocean-going ships and barges. In this example arrangement, it is possible to transport 60 1S0 containers in the proposed space. If a conventional fracturing skid is shipped in the space, it must be placed on the lowest level and nothing can be stacked on top of it (Figure 2). Since the skid extends past the floor-plan borders of three cargo spaces and spaces are five-high, the skid occupies 15 cargo spaces.
The two-part, 1S0 skid conserves shipping space (Figure 3) because it occupies two standard ISO spaces, which can be anywhere in the 60-space group.

Design Considerations
Several requirements were considered and incorporated into the design of the two-skid system. The equipment was designed to blend sand (at concentrations up to 20 lb/gal) with clean fluids varying from water to 210-cp gels. The capability to pump at a range of delivery rates and to blend highly corrosive acids meant that the equipment needed a variety of liquid additive pumps.
Development of a Self-Equalizing Surface Controlled Subsurface Safety Valve for Reliability and Design Simplification
Authors: Hill Thomas G. , Bhavsar Rashmi 
Published: October 2008

Abstract
Surface Controlled Subsurface Safety Valves (SCSSVS) are normally closed devices that provide control of wellbore fluids, and w-c required in virtually all offshore wells world wide. This paper describes self-equalizing SCSSVS, discusses the evolution of the technology, reviews current design issues, and offers a recent technological advance that places an equalizing passageway in a unique configuration. Procedures required to open non-equalizing SCSSVS are discussed, as well as methods of providing an internal equalizing passageway in the valve, and the inherent advantages and disadvantages of each.
Self-equalizing SCSSVS featuring a 'through-the-hard-seat' equalizing passageway will have wide apply in low to medium pressure offshore wells where operational difficulties may rule out a traditional surface equalizing system. The economics of most producing fields will be enhanced by the lower cost, ease, the simplicity and reliability of this development.
Performance of the valve in cycle testing, sand slurry testing, flow erosion testing and temperature testing is discussed in summary

Introduction
The most common SCSSVS on the market today have flapper closures, and are biased closed by an internal spring. A small diameter control line conveys hydraulic fluid under pressure from a surface pump to a piston internal to the valve, which compresses the spring and holds the valve in the open position, Loss of control line pressure for any reason causes closure of the valve. Pressure builds below the closed SCSSV, while the pressure above bleeds off, and a pressure differential across the flapper is established.
For several reasons, the pressure in all SCSSVS upstream and downstream of the closure must be nearly equal before opening. When the valve is in the closed position, well fluid pressure acting upon the relatively large surface area of the flapper makes opening difficult because the hydraulic area of the operating piston is smaller. This difficulty in opening cannot be easily overcome simply by increasing hydraulic control pressure, The mechanical force exerted against the flapper by the relatively small cross-sectional area of the opening piston and cylinder assembly is simply inadequate to open the valve at normal hydraulic pressures. Increasing the control fluid pressure in an effort to overcome closing forces may burst the control line carrying the hydraulic fluid and/or damage critical internal parts. Even if the flapper could be opened under a differential, the initial flow of well fluid would erode the primary sealing surface of the flapper and/or seat, Any damage to this primary sealing surface is extremely critical because it must remain intact to prevent uncontrolled flow of well fluids when the valve is closed in an emergency, To overcome these difficulties, mechanisms have been developed to allow the pressure above and below the flapper to equalize prior to the complete opening of the flapper.