bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrity Management and Life Extension of Flexible Pipe
Authors: Saunders Chris , O'Sullivan Tim 
Published: December 2007

Abstract
During 2002, UKOOA issued a guidance note titled: "Monitoring Methods & Integrity Assurance for Unbonded Flexible Pipe". Since 2002 a number of lessons have been learnt by the industry in terms of the management and ongoing operation of flexible pipes. Based on practical / field experience and lessons learnt in providing integrity management to a number of worldwide operators, this paper presents an update to the UKOOA document and shows through examples these learnings and key points for consideration.
This paper discusses the monitoring requirements for flexible pipe, including consideration of the value offered by conventional GVI inspection techniques. Examples of alternative technologies which have been developed are discussed, presenting how they can reduce the requirement for GVI when supplemented with an integrated integrity management strategy.
Further, given the advances in flexible pipe analysis, some of which were developed under the RealLife JIP, the paper demonstrates that through proper asset management, flexible pipe technology service life can be extended beyond the original design criteria. Similarly, flexible pipe that had previously been considered damaged and requiring early replacement can be justified for extension to beyond the original design life.
Consideration has also been given to the potential for the re-use / redeployment of flexible pipework and the hazards which can arise from this activity including recovery, storage, testing and installation. The key stages required to manage this process safely have been outlined.
Understanding a Teenager: Surveillance of the Draugen Field
Authors: Langaas K. , Grant A. D. , Horvei N. A. , Cook A. , Klokk H. M. , Flatval K. B. 
Published: December 2007

Abstract
Production from Draugen started in 1993. In its 14th year Draugen faces declining oil and increasing water production and is around halfway in its production life. The field development with water injection and relatively few wells has proved to be very successful. This paper shows how well and reservoir surveillance has been set-up in the Draugen field. Interesting features of this set-up are Structured and automatic data integration. Information providers for the important subsurface risks and uncertainties have been mapped, which has resulted in a better understanding of the value of surveillance activities. Integration of laboratory data, production well test results and model-based-rates are enablers for improved production allocation to individual wells. "Data-to-information" work processes have been mapped and automated as a natural part of the collaborative work environment between the platform and the offices.Use of time-lapse seismic. Draugen acquired seismic of excellent quality in 1998, 2001 and 2004. The data has been a key enabler to understand the water flood and to manage the reservoir. This paper shows how visualisation methods and discipline integration have maximized the information of the 4D surveys, and how this has been used to improve the reservoir simulation model.
The paper provides clear examples of how surveillance is supporting reservoir management and production optimisation in the field.
Interference Testing with Horizontal Wells in Layered Reservoir
Authors: Faizal Syed Abu , Al-Hashim Hasan S. 
Published: December 2007

Abstract
Interference testing with horizontal wells has become a valuable tool for characterization of heterogeneous reservoirs. However, the current methods of analysis of interference tests with horizontal wells in layered system use single-layer homogeneous model. This can result in significant errors in the estimated average reservoir properties.
This paper presents the results of a study carried out to investigate the effect of layering on the pressure response at the observation well in horizontal well interference testing in a two-layer reservoir.
A numerical approach is employed to study the effect of parameters like omega, kappa, vertical permeability and distance between the horizontal wells on observation well pressure response in an interference testing with horizontal wells in a two-layer reservoir.
The results of the study show that the observation well pressure response form interference testing in two-layer system deviates from the equivalent single-layer system response. This deviation depends on the contrast in transmissibility and storage between the two layers. The deviation is found more pronounced when Omega is small and Kappa is large. It was also found that, as the distance between the active and observation wells increases, the deviation of the observation well response from the equivalent single-layer system response decreases. Vertical permeability has considerable effect on the observation well response when the contrast in transmissibility and storage between the layers is large.
Lessons Learnt From Managing and Engineering an Integrity Project
Authors: Rodgers Mike , Windle Dave , Wilson John , Duinhoven Jan 
Published: December 2007

Abstract
Shell Exploration & Production in Europe is currently implementing the "Upgrade Project" to ensure the integrity of safety critical equipment on all of its older platforms in the North Sea for their remaining life. The project scope addresses remedial work on around 40 platforms in the Dutch, UK and Norwegian sectors.
The project was initiated by carrying out an audit of safety critical equipment. From this, emerged seven key areas or "themes" for remedial action: Sub-structure, topside structure, Piping, HVAC, electrical, fire & gas & process. Looking at total scope on a theme basis, enabled consistency and lateral learning between platforms.
Learnings from the Upgrade Project about brownfield integrity restoration have included: Strike the right balance between useful detail and duration/cost when specifying survey and inspection work.Don't carry out inspection as a separate project activity. Integrate with the asset inspection team to ensure buy in and a legacy of quality data.Get the balance right between fixing the most critical areas– to optimise spend vs. time-and efficient packaging of work.Work contingency planning is harder when dealing with older installations with limited access, such as NUI's.
Within the project a clear Continuous Improvement mindset has been introduced to ensure the safe and efficient execution of the project. Each of the Themes has shown improvement in design, procurement and installation. The improvements vary by Theme and some, like handrails and gratings, have produced improvements every time they have gone through the ‘review and improve’ loop.
Keys to successful continuous improvement are: Management drive and commitmentCommercial alignment for the different stakeholders with the continuous improvement driveA dedicated team to help enable improvement, but the responsibility for improvement always remains with the line
Team buy in
The challenge for the remaining part of the project is to continue with the Continuous Improvement and to share the learnings with the wider organisation, making sure the improvements are sustainable within the Engineering and Maintenance organisation.
Transport of CO2 for Carbon Capture and Storage in the UK
Authors: Downie Martin , Race Julia , Seevam Patricia 
Published: December 2007

Abstract
Carbon Capture and Storage (CCS) has been receiving increasing recognition as a short to medium term measure for closing the energy gap whilst a portfolio of carbon neutral technologies is developed to provide power for the UK. This has been accompanied by an increasing political will and a developing policy framework to achieve it. If the UK is serious in its intentions, the necessary economic drivers will also be put in place. It remains to identify and resolve the technical issues that apply peculiarly to the UK. In recent years the capture technology has developed to the point of viability and storage has been accepted to be safe and ecologically sound, but relatively little work has been carried out on CO2 transport. In the US naturally occurring CO2 is routinely transported considerable distances overland through mostly sparsely populated regions for the purpose of enhanced oil recovery. There is also some limited transport of anthropogenic CO2. In the UK a number of suitable offshore CO2 sinks have been identified in the North and Irish Seas for EOR or simply for storage. It has been commonly assumed that the transport of CO2 from UK sources to offshore sinks is straightforward, and may even be able to make widespread use of existing infrastructure. However, there are significant differences between the US experience and the UK transport requirements. The UK will be dealing with anthropogenic CO2, mostly from power plant, which will impose constraints on the hydraulics that have not yet been fully explored. Considerable proportions of the transport system will be subsea, of which there is as yet virtually no experience. There are questions as to the suitability of much of the existing infrastructure and the desirability of using it. There is little experience with multi-source transport systems through densely populated regions.
This paper will address some of the technical issues that need to be considered for the development of a UK CO2 transport infrastructure, in the post demonstration phase of carbon capture and storage, capable of mitigating the emission of green house gases whilst allowing the continued use of fossil fuels.
An Innovative Approach for Long Term Zonal Isolation in HT/HP Gas Wells
Authors: Al-Yami A. S. , Nasr-El-Din H. A. , Al-Saleh S. H. , Al-Humaidi A. , Al-Arfaj M. K. , Al-Shehri D. A. 
Published: December 2007

Abstract
Cementing a string in one stage is a challenging task, especially in the presence of weak formations. Cement slurry losses during placement is highly possible if the equivalent circulating density (ECD) exceeds 11 lb/gal during placement. A conventional method to overcome this challenge is to use multi-stage cementing by setting the stage tool above the loss circulation zone. However, field data indicate that the tool can fail, thus causing serious delay and economic loss. In addition, stage tools are considered weak point and not good for long term seal. A second method for zonal isolation is to use low density cement.
In this study, we considered cementing the intermediate and production casings in HP/HT BJD (dolomite) formation in a single stage using a lower density cement based on hollow microspheres at 9.35 lb/gal. The objective of this work was to compare hollow microspheres cements to bentonite cement which are used in multistage cementing. The tests included shrinkage, compressive strength, porosity, gas and brine permeability. There are potential hole problems that are faced while drilling for the casing point in BJD. These problems such as water flow which might have H2S require good cement durability to provide zonal isolation.
The total vertical depth (TVD) of the casing point in BJD is ± 10,000 ft and the mud density is ± 9.09 lb/gal. Testing conditions were temperature of 260 ºF, crushing pressure of 5,000 psi, and confining pressure of 3000 psi. No work was done before to investigate hollow microspheres cements at these conditions. The testing was performed in Saudi Aramco facilities to improve current cementing practices in oil and gas fields.
Data generated during three months supported the use of the hollow microspheres to cement casings at the conditions tested. The compressive strength did not change significantly with an average of 1400 psi; neither shrinkage nor liquid permeability was observed during the three months of testing. The use of the hollow microspheres cement will help to bring cement to surface in one stage which will save time and cost to current drilling operations in Saudi Arabia.
The Largest Acid Stimulation in a Dual Lateral Power Water Injector in Saudi Aramco
Authors: AL-Rufaie Y. A. , Al-Buali M. H. , Al-Otaibi M. A. , AL-Mulhim A. K. 
Published: December 2007

Abstract
This paper will discuss the largest coiled tubing acid stimulation operation completed on a water injection well in Saudi Arabia. Stimulation design, field execution and the well performance before and after the treatment as well as massive planning, logistics and coordination are the key elements of this discussion. Furthermore, the authors would like to briefly review the future plans for other long/ multilateral wells in the area.
This job was conducted on a dual lateral horizontal power water injector. The objective of this job was to stimulate the formation of both laterals by pumping 20% hydrochloric acid (HCL) and 20% strength diesel-emulsified acid and diverting it with 20% viscoelastic surfactant based acid on using Coiled Tubing (CT) and a Multilateral Tool (MLT). A total of 10,335 ft horizontal interval was successfully stimulated with 362,700 gallons of treatment fluid in 27 stages using 2 3/8" CT. On this job the MLT was successful in locating each lateral. The post-acid injection rate has been increased by more than double, higher than initial expectations. Consequently, the injectivity index has been increased drastically above the field average.
Based on success of this stimulation job, the concept of designing and treating other Maximum Reservoir Contact (MRC) injectors using this technique becomes a recommended intervention process. The key to enhance future jobs lies on the ability to effectively capture and use the lessons learned from this massive operation. The continuous success of these jobs will help to improve the water injection system in Ghawar field and will enhance oil recovery.
Extending ERP to Wells For Various Techno-commercial Analysis: An Innovative Application of ERP
Authors: Adhikari Debdulal , Chaudhury Partha Pratim , Kumar Sanjiv 
Published: December 2007

ABSTRACT
Description:
A major upstream company of India implemented ERP (Enterprise Resource Planning) in its entire business portfolio, applying various ERP modules. One of the modules was PP-PI (Production Planning- Process Industries), primarily aimed for processing plants. This module was customized to capture production from CTF (Central Tank Farm). In this process, GGSs (Group Gathering Stations) and the oil Fields were configured as ‘storage locations’. In next step, ‘Z-Table (Customized Tables developed on the adopted ERP platform)’ developments were done to capture Well test data, Well flow-hour data and Well no-flow hour data of each well. Critical testing parameters like ‘Variable Separator Pressure’ and ‘Shrinkage Factors’ were also addressed in the program algorithm.
Application:
The development was applied at various onshore and offshore installations of the company at two different stages with slight variations in the design (final allocation program was different for onshore and Offshore, because of some differences in data capturing). Few parameters, like Sand data, Field data were introduced at later stages for some more specific analysis.
Observations and Result:
For the expected results, interlinking of MM and PS (ERP logistics modules for Material Management and Project System) had to be done. After rigorous testing and calibrations, the design was implemented at onshore and offshore locations of the company. The data, normally uploaded at the installation level, could be accessed for various analysis at any level. Regional as well as Corporate Planning departments are using the data for analyzing various field problems, variations in production performance, status of flowing and non-flowing wells, the reasons of no-flow etc. enabling better and efficient decision making. This application of IT in oil and gas production fields coupled with SCADA (could be an interesting development for real time monitoring of oil-field.
Significance of the Subject matter:
This is an innovative application of ERP, a business application tool, for the techno-commercial analysis of wells and oilfields.
Practical Considerations in Ensuring Cost Minimization in the Design and Operation of Sulfate-Removal Systems
Authors: Davis Roy A. , Southwell George 
Published: December 2007

Abstract
The removal of sulfate from injected seawater for waterflood and pressure maintenance operations has become widely accepted for reservoirs with sulfate scaling potential. The technology has been found to be exceptionally useful in deep water and subsea operations where scale controls using scale inhibition squeeze treatments become prohibitively costly. Twenty five sulfate removal facilities are now operating or being built off the cost of West Africa, Brazil, and in the North Sea. Experience with these existing facilities has identified methods to minimize the size of the sulfate removal facility with accompanying weight and space savings which often exceed the capital cost of sulfate removal system itself. Similar savings and trends have been identified by the availability and successs of auxiliary pre-filtration equipment. Operation cost reduction and improved reliability have been achieved by selecting raw seawater intake reduction and improved reliability have been achieved by selecting raw seawater intake locations, the re-design of sulfate removal system. The careful selection and evaluation of sulfate removal system components, including fine filtration and deaerators, have resulted in significant savings by extending membrane life up to twice the warranty period and by reducing operation costs of 25% than originally projected.
Indonesia Deepwater Field Development Technical, Contracting, and Execution Challenges
Authors: Korloo Jafar 
Published: December 2007

Abstract
The Oil and gas industry has gone through major transformation over the last six years from relatively quiet to extremely dynamic market conditions. The dynamic market condition has introduced new challenges for Operators in terms of field development cost estimates, biding strategy and cycles, project schedule, execution, shortage of equipment, material, and personnel. The same market conditions have also created challenges for contractors in coping with volume of the work and staff turnover.
Determination of the best concept for a deepwater field is not always a clear and an easy task. The final development recommendation is often strongly influenced by non-technical considerations such as the market conditions, maximization of local content, and transfer of technology.
Offshore East Kalimantan, Kutai basin in Makassar Strait is a major oil and gas region. The conditions in the area are unique, offering opportunities and challenges in development of new fields. The water depth in the deep section of the basin extends to approximately 1900m. The environmental conditions in the area are benign with exception of strong persistent currents.
This paper discusses the following topics: Typical deepwater development options and opportunitiesTechnical issues unique to the areaProject sanction challengesContracting issues and market conditionsProject execution challenges from the FEED stage to Engineering, Procurement, Construction and Installation stagesSchedule related challenges and issues.
Gas-to-Hydrate Technology, an Alternative Energy for Low-Level Communities in Indonesia
Authors: Bawono Adam Nur 
Published: December 2007

Abstract
The Low-Level Communities in Indonesia use kerosene as their source of energy for their daily cooking. They use it mainly because the price of kerosene is cheaper than the other source of energy. The price of kerosene is still being subsidized by the Government but due to the increasing world oil price, the Government has decided to cut out the subsidy by replacing kerosene into other source of energy.
One of the alternatives is natural gas. Actually natural gas has been used in the household sector through a distribution pipeline. However, due to the difficulties in developing the infrastructure, the experts try to modify the form of natural gas into a more transportable manner. They invented that natural gas can be transformed into its hydrate form which is solid and easy to be transported. This form is called Synthetic Natural gas Hydrate (SNGH).
SNGH is the hydrate form of natural gas. It is formed by reacting natural gas and water in moderate pressure, 30–50 barg in a small tubular-bubble reactor and then cooled to −25 °C in a refrigeration storage. The product then is depressurized and packed in a plastic bag and after that put into a cold box for keeping the temperature below −10 °C to prevent the hydrate melt. The hydrate is transported via truck to the users. The user can use it by simply placing the hydrate in a storage and let the hydrate dissociate.
The selling price of SNGH has to be set around US $ 8/MMBTU in order to compete with other alternative energy such as LPG and CNG. The production cost is roughly the same as LPG and CNG but the transportation cost can be reduced significantly.
Capturing Remaining Oil in a Giant Mature Carbonate Waterflood Field in Oman
Authors: Al-Sharji Hamed , Behairy Hassan , Van Houwelingen Jacob , Male Peter , Al-Lawati Hassan 
Published: December 2007

Abstract
This paper presents the ongoing development planning, by semi-vertical short-radius extensions (a.k.a fishbones) and infill drilling of a mature waterflooded carbonate reservoir in Oman.
Given 35 years of production and water injection into the reservoir, a key focus in the development philosophy is maximizing reserves recovery from existing wells.
Many of these wells have reservoir zones with significant oil saturation behind pipe. Two development options were considered attractive for the existing horizontal well stock: adding perforations and creating vertical fishbones targeting the by-passed and attic oil. A total of 52 wells have been identified for additional perforations and 25 wells as fishbone candidates. Additionally, by-passed oil targets have been identified for infill drilling.
Infill drilling of the by-passed oil targets proved very successful. Ten out of the eleven opportunity areas where infill drilling was completed encountered economic by-passed oil. The single failure still highlights the remaining challenges in tapping the by-passed oil targets in this giant waterflood oil field.
In particular, this paper discusses the results of the past three years of tapping undeveloped reserves using fishbone extensions and infill drilling. Sector modeling and analytical analysis methods supported by surveillance data high-graded 8 opportunities targeting attic oil. Following the initial poor success, mainly due to operations related problems, subsequent improvement in setting and retrieving whipstock has significantly improved the success rate. Liner integrity has been found to be the main setback of this development option.