bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of a Marginal Field Through Leased Facilities
Authors: Kieft T G 
Published: December 2007

Abstract
Fife is a small offshore field that is remote from existing infrastructure and offers the potential to recover some 34 mmbbls of 34° API crude oil over an anticipated life of 4 years. Capital investment in the full field development facilities cannot be amortised to provide an economic development in this timeframe. This paper addresses the application of leased production facilities to enable commercial development of the reserves and examines the relationship necessary between oil company and contractors to achieve a successful project.
The Two Phase Development of the Hudson Field
Authors: Fielding MP 
Published: December 2007

Abstract
Development of the Hudson field took place over the period December 1992 to January 1995. This was a time of generally low oil prices and one in which the combined effects of oil price, smaller discoveries and diminishing reserves but increasing development and operating costs, were being faced by the industry.
The Hudson field development was conceived under these circumstances and demanded that a cost effective solution be identified in order to make the development viable. Initial studies of conventional stand-alone and tie-back options, whilst endorsing the commerciality of the project, failed to maximise its economic potential or to meet the business-driven objectives of the co-venturers. In light of this, an innovative two-phase development was devised, utilising a leased FPSO for the first phase of production and a subsea tie-back to the Tern platform for the second phase. This gave the benefits of an optimised reservoir development plan for the second phase, minimum capital outlay at the front end and early production and generation of cash-flow, which effectively financed the main field development.
In addition to this novel facilities solution, the development also implemented many of the concepts which have since become synonymous with the industry's CRINE initiative, most notably the use of functional specifications, standard components, minimum operator intervention in contractor/supplier activities, minimum size of operator's management team and a novel contracting strategy, giving greatest opportunity for cost savings.
The net result of these various initiatives was completion of the facilities installation and commissioning two months ahead of the targeted first oil date and at a cost of 29% below the original budget.
How a North Sea EPS was Fast Tracked to Achieve First Oil 19 Weeks from Project Sanction
Authors: Kozicz J. R. , Unsworth M. , Oldfield G. A. 
Published: December 2007

Abstract
A semi-submersible based Early Production System (EPS), currently exporting production via subsea flow line to a dynamically positioned tanker was on-line 19 weeks after receiving project sanction. This paper describes the process by which this was achieved.
Safety Research for the Offshore Industry: Progress with Implementation of HSE's Strategy
Authors: Sharp J V , Supple W J 
Published: December 2007

Abstract
Introduction
Research has played an important role in helping ensure safety in the offshore oil and gas industries and will continue to do so. It has always been a high priority in Offshore Safety Division (OSD) with the objective of keeping the Division aware of all developments with a potential bearing on the health and safety of the offshore workforce. Consequently, the Health and Safety Executive (HSE) is currently funding a major research programme aimed at increasing safety offshore by investigating a broad range of factors which govern the integrity of engineering design, technology, management and operations. Annual HSE expenditure on this endeavour is of the order of £6.5m but taking into account that about one third of the projects are funded jointly with the offshore industry the combined programme consisting of over 300 live projects has a value exceeding £50m. The large majority of the research is undertaken by external contractors based in the UK and abroad.
The main objectives of this offshore safety research programme are to: assess the extent and nature of the risks involved in work offshore;support specific enforcement activities, policy initiatives or accident investigations;produce information to develop technical guidance to support legislation;inform national and international standards making;validate models (including computer models) enabling risk calculations to be made and inform regulatory decisions;produce necessary health and safety information where the structure of the industry prevents it being produced by the industry (at least in an appropriate timescale).
Operating Emerald – The Experience and Lessons of a Marginal Field
Authors: Pollard Ian C. 
Published: December 2007

Abstract
Midland & Scottish Resources PLC (MSR) is a company which was established to exploit production opportunities in marginal fields, with a combination of reusable facilities and a management structure which directs and responds through short and effective lines of communication. As owner and licensed operator of the Emerald Field, MSR's wholly owned subsidiary Midland & Scottish Energy Limited (MSE) had to develop and apply realistic strategies for ensuring safe and stable operations in the face of a declining asset The paper deals frankly and openly with the experi-ence gained and lessons learned from developing and applying innovative techniques to meet this challenge.
From the outset, the Safety Case and a Total Quality Management System were used as both focus and drive for a company strategy that demanded change in both workforce attitude and management practice. It provided an opportunity for fostering workforce involvement but tech-niques and procedures had to be developed in order to demystify terms such as ALARP and to make them usable in the workplace. A system was conceived and developed by the company to enable workplace risk assessments to be performed and demonstrated. This approach has not only improved risk management but also led to generation and continuous renewal of operating procedures that are effec-tively targeted to critical activities and visibly linked to the Safety Case.
Innovations in the production and treatment of safety management system documentation, that enabled their active ownership, were also deyelnned. These were intended to facilitate accurate translation of policy into practice and underpin the Safety Case by ensuring it faithfully reflected operational activity.
Difficulties arose for some, in the acceptance and understanding of devolved authorities and in determining the appropriate authority ieveis for certain decision making. Cautionary lessons were also learned when certain innova-tive changes to safety management practices were misund-erstood. The paper concludes by outlining the next stages of development for the management systems in order to deliver improved mechanisms for change control, performance standards and competency.
Preparation of Combined Operations Safety Cases: Experience and Lessons Learnt
Authors: Hart P. M. I. , Smith D. W. , Thomas E. J. 
Published: December 2007

Abstract
This paper describes the experience of a North Sea operator in preparing a combined operations safety case. The safety case structure and work done to develop the combined operations description, safety management system and carry out hazard identification and risk assessment are described. Success factors are identified.A streamlined methodology for more rapid hazard identification and risk assessment is described for future application.
Leman Field Facilities Rationalisation
Authors: Palmer R. T. , Hall R. N. , Hall A. V. 
Published: December 2007

Abstract
This paper describes the re-configuration of the Shell Expro operated part of the Leman gas field in the UK Southern North Sea. The substantial modifications implemented will enable the field to be operated safely and cost-effectively through its post plateau decline. Identification of a new Op-erations Philosophy, subsequent demanning of production satellite platforms, the rationalisation of compression facilities and contracting strategies are discussed.
Cost Effective Methods to Maintain Gas Production by the Reduction of Fouling in Centrifugal Compressors
Authors: Guinee M. J. , Lamza E. W. 
Published: December 2007

Abstract
Fouling of centrifugal compressors can dramatically reduce the gas throughput of a production platform. Deposition of solids within compressor internals has reduced flow and, in extreme circumstances, resulted in total seizure. Substances deposited include iron carbonate and salt.
The fouling can affect the ability to meet gas sales agreements with potentially severe financial penalties. Significant operating expense is also incurred to remove fouling material.
A mix of proven and innovative fouling control techniques has been applied including; well management, process modifications, selective use of corrosion inhibitor, internal coating of the compressor internals and on-line water wash systems.
Snubbing Units: A Viable Alternative to Conventional Drilling Rig and Coiled Tubing Technology
Authors: Hodgson R. 
Published: December 2007

Abstract
Several North Sea Operators are now using Snubbing Units to undertake operations previously regarded as only within the scope of a drilling rig (such as the running of 7" completions and the undertaking of gravel-packing operations).
Snubbing Units are also increasingly being used to access and service horizontal and extended reach wells which coiled tubing cannot access.
With the use of a Snubbing Unit, through-tubing sidetracking and underbalanced drilling is no longer limited by the technology of Coiled Tubing Drilling. Additional margins are available if a ‘SnubdrilT option is adopted and these are quantified with the presentation of the results a ‘SnubdrilT Case Study.
Snubbing Units can therefore now be regarded as an established means of providing an Operators with a versatile and unique device which offers many advantages over both Derrick Equipment Sets and Coiled Tubing Units.
Tubing Conveyed Perforating in the Greater Ekofisk Area using the Halliburton Select Fire System
Authors: Kleppa E. , Nilsen R. , Bersaas K. 
Published: December 2007

Abstract
Required safety factors in pressure activated perforating systems have in practice limited the number of independent gun sections on one run to at the most two. The Halliburton Select Fire System eliminates this limitation by allowing as many gun sections as desired to be independently activated by applying the same level of activation pressure each time. Potential cost savings derived from the system can be divided into two groups; reduced operational time due to reduced number of runs, and greater versatility of the perforating system, allowing for new approaches in planning and execution of the perforating operations.
The paper reviews three different cases were the system has been used in the Greater Ekofisk Area.
Well Completion Design and Operations for a Deep Horizontal Well with Multiple Fractures
Authors: Chambers M. R. , Mueller M. W. , Grossmann A. 
Published: December 2007

Abstract
Economic development of deep tight gas reservoirs is a challenge our industry has struggled with for many years. This paper describes how a very deep (15688', 4783 m TVD) well with a horizontal section (over 86°) of over 630 m (2,066') was completed for stimulation with multiple fractures. Multiple packers and sliding side doors provided isolation for 4 separate fracs and a 5th zone containing 52m (171') of perforated interval in the 7" casing. Extreme overbalance perforating techniques using tubing conveyed perforating guns and high pressure nitrogen were used to perforate and break down each of the 0.6m (2') of perforated intervals for the 4 fracs and 853 perforations in the 5th unstimulated zone. To achieve a high shot density, a special perforating tubing anchor was designed to allow two different perforating guns to perforate exactly the same interval in one trip. An open annulus treating system was used with a 4½ frac string for observation of the bottomhole treating pressure during fracture operations. A total of over 2 million pounds of high strength proppar.t was pumped into the 4 fracs at rates in excess of 5.6m’/min (35 BPM). High bottomhole temperatures (290°F, 143°C), reservoir pressures (9000 psi, 620 bar), and bottomhole treating pressures (16000 psi, 1100 bar) added to the complexity of design and operation of equipment. Over 5,700m (18,70001 of ¾" coiled tubing was run to TD and used in conjunction with a downhole force generator to open and close the sliding side doors.
Novel Techniques for Monitoring and Enhancing Dissolution of Mineral Deposits in Petroleum Pipelines
Authors: Gunarathne G. P. P. , Keatch R. W. 
Published: December 2007

Abstract
This paper presents a summary of work carried out and the results achieved in developing novel ultrasonic techniques for monitoring and enhancing dissolution of mineral scale deposits in petroleum pipelines. Problems of conventional ultrasonic techniques with respect to testing pipes are analysed. The development of mathematical and experimental models to extract the characteristic features from ultrasonic scans representing the acoustic properties of the mineral deposits beneath the pipe wall are described.
These properties are compared with stored data to identify the type of deposits and hence assess their growth which aids performance optimisation of remedial scale dissolver and preventative scale inhibitor treatments. The process of de-scaling is further enhanced by ultrasonic irradiation and methods for monitoring the dissolution process in real-time are proposed.
Alternate Acid Blends for HPHT Applications
Authors: Van Domelen Mary S. , Jennings Alfred R. 
Published: December 2007

Abstract
Protecting completion and production equipment is of utmost concern during acidizing. The higher the temperature, the more difficult it is to protect metal against corrosion, and the required inhibitor loadings increase with temperature, resulting in greater likelihood of formation damage. In addition, the protection times are reduced dramatically, which can potentially limit well stimulation treatments (for example, fluid volumes caused by pump time limitations). These problems become increas-ingly severe in formations with bottomhole temperatures greater than 250°F (120°C).
Even if adequate corrosion protection can be achieved during stimulation, post-treatment production of chlorides associated with the injected HCl-based acids remains a prob-lem. There is increasing concern when the wellbore contains high-alloy metals, such as stainless and duplex steels, which are susceptible to hydrogen embrittlement and chloride stress cracking. When combined with the possibility of erosion corrosion caused by high production rates, acidizing high- pressure, high-temperature (HPHT) wells poses risks.
A combination of organic acids (acetic and formic) can be used instead of hydrochloric acid (HC1) to minimize corrosion problems in high-temperature applications. The blends are designed so that the dissolving power is equivalent to HC1 with significantly reduced corrosion rates and the absence of Cl' ions. Some of the gelling agents developed for HC1 yield higher viscosities in organic acids on an equivalent polymer-loading basis. The end result is an organically based, high-temperature acid system that uses existing technology and is technically and economically more attractive than an HCl-based system.
The example application includes the use of an organic acid blend to effectively stimulate the 350°F (175°C) Arun limestone formation in Indonesia. A total of 17 large-scale acid fracs and a similar number of large matrix-acidizing treatments have been performed over the past 3 years. Rheology and corrosion data will be presented with the details of the treat-ment procedures and production responses.
Subsea Well Intervention from a Monohull Vessel
Authors: McGennis Eamonn 
Published: December 2007

ABSTRACT
Subsea wireline well intervention has been performed from the Multi functional Support Vessel (MSV) Seawell since 1988. In a joint Coflexip Stena Offshore (CSO) and Cameo venture, an impressive track record in wireline work and abandonment has been created. Despite this, there is a growing need for developing the range of services to provide deep water well intervention and coiled tubing activities. This paper presents Coflexip Stena Offshore's current capability and experience and future strategy. This includes extending the range of the existing system for operations in water depths down to 3,300 ft (1,000m) and modifying it to allow for riser and coiled tubing compatibility.
The CSO Seawell is certified as an offshore installation capable of handling hydrocarbons at surface. Utilising a derrick structure, situated above a dedicated 22fl (7m) x 16 ft (5m) moonpool, well re-entry, wireline, pumping and abandonment tasks can be performed. Such tasks include gas lift logging, perforating, cementing and setting plugs. Observation Remote Operated Vehicles (ROV) are an integral part of every well senicing operation, and the vessel can be equipped with a work-class Multi Role Vehicle (MRV).
The first stage of developing Coflexip Stena Offshore's integrated subsea well intervention services is to extend the range of the existing system from 600 ft through to 3.300 ft Modifications required include a new umbilical, incorporating an MRV operated panel on the lubricator and upgrading the lubricator winch wire and the four guide wires. The existing MRV unit has been successfully utilised in deep water diverless pipelay operations and can be fully equipped for well servicing operations
Following the above modifications a coiled tubing and tie-back riser system will be developed. This new system will allow for a smooth subsea changeover from normal wireline to tie-back riser activities by incorporating a high angle connector on the lubricator, compatible with the tie-back riser and the lubricator stuffing box. Coiled tubing equipment will be efficiently located on the vessel by modifying the existing equipment and vessel handling systems This will include a purpose built injector head lifting frame to allow the injector assembly to be racked back into the derrick when not in use. A hydraulic control system will be required to power the coiled tubing equipment and will be a permanent feature on the vessel. Thus only an injector head and tubing reel would have to be mobilised for standard coiled tubing jobs, reducing time for overall mobilisation.
The development of this integrated service from a dynamically positioned monohull will place Coflexip Stena Offshore in a unique position to take up the challenges of deep water West of Shetland and world wide.
Coiled Tubing Stimulation Treatment in an Offshore Injection Well: A Case History
Authors: Boyle David , Bell Gavin J. , McGinn Paul 
Published: December 2007

Abstract
A coiled tubing stimulation treatment featuring a new high flash-point solvent was performed on an offshore injection well in the Ninian Field. This stimulation treatment was performed to remove hydrocarbon residue and deep clay damagestimulate low-permeability zonesincrease water injection rates in an offshore well
The target zone was treated with 587 bbl of sequential HF acid to prevent swelling of near-wellbore fines, solids, and clay. The application of sequential HF acid increased permeability 10-fold over standard HF acid treatments. An inflatable packer was placed between the upper zones and suspected weak tubing, confining the treatment to the target zones. The treatment successfully reduced the formation skin factor, which increased the injection rate by 100% (0.25 bbl/min to 0.5 bbl/ min) and reduced the surface pressure by 3%.
Managing Seismic Exploration in a Nearshore Environmentally Sensitive Area
Authors: Macduff-Duncan C. R. , Davies G. 
Published: December 2007

Abstract
Esso/Shell were awarded 4 exploration blocks in June 1993 in the North Irish Sea. This is an environmentally sensitive, nearshore area where several environmental groups were opposed to exploration taking place. The area is of ecological importance with a diverse wildlife and supports several hundred thousand migrating birds during the winter. Commercial fishing is also of importance to the local communities. An added complexity is that the area is adjacent to three separate authorities, eg. Scotland, England and the Isle of Man.
Our challenge and that of our contractors was to demonstrate that we could operate safely and in an environmentally sound fashion. A project manager was appointed to oversee all aspects of the Exploration programme.
An environmental review was carried out prior to licence award and an environmental assessment prior to the seismic operation. All environmental sensitivities, eg. birds, fish and sea mammals etc. were assessed and all potential sources of inputs/disturbances from the seismic operation were reviewed.
In order to understand local concerns and communicate our plans in an area not familiar with oil exploration an extensive communication programme was also undertaken.
The next step was to develop ways in which to mitigate the potential impact on the environment and local marine users. This was done by working with the local authorities, fishing and environmental groups and the seismic contractor to establish acceptable operating practices. Procedures were then incorporated into the seismic contractors plan. The key sensitivites in the area are commercial fishing, seabirds and the Ministry of Defence (MOD) who have a Gumnery Range in the area, Some examples of procedures adopted to protect these features were slow start-up of airguns, the use of an onboard bird/mammal observer, the use of local fisning iiaison skippers and local chaseboat, reduction of exhaust smoke emissions, distribution of survey area maps to key people, and a safety review of MOD range operations and procedures.
At the start of the survey a safety/environmental review meeting was held with the seismic crew on board the survey vessel to increase their knowledge of the area and gain their commitment to the operational procedures established.
The survey took 80 days to complete and finished without significant incident. The procedures put in place were practical, and cost effective and ultimately successful considering the pressures on operators in nearshore sensitive areas.
Drill Cuttings Disposal into a Producing Sandstone Formation
Authors: Wood G. L. , Hulbert G. , Cocking D. 
Published: December 2007

Abstract
Thirty thousand barrels of slurried drill cuttings waste, generated during the Wytch Farm Extended Reach Drilling programme, have been successfully injected into a producing sandstone formation as an environmentally acceptable means of disposal. Injection was through an existing water injection well into the producing formation because alternative shallow disposal horizons contain fresh water aquifers used to supply local drinking water. The disposal well continued to inject water in die periods between injection of the individual cuttings slurry batches, thus minimising the impact on the field management strategy.
Detailed monitoring data indicated that there was a significant increase in local formation stress at the injection well dining the operation, raising injection pressures, but that these had fully relaxed within five months of die end of the operation. Fracture growth was seen to be contained by die stress contrasts induced (thermoelastically) in the disposal formation by the long period of water injection prior to die cuttings injection operation. This provided confirmation that there had been no risk of contamination of die shallow fresh water aquifers by the slurry through vertical fracture growth.