bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of a Large-Bore Monobore Completion System for Gas Production
Authors: Simonds Randy , Swan Tom 
Published: December 2007

AbstractTraditionally, monobore completion techniques have been able to provide operators with a high degree of flexibility for maintenance needs since the tubing imposes no restriction to any tool that may be deployed in the liner as sometimes happens when completions have tapered production strings. Unfortunately, the traditional monobore completion advantages may not be realized until later in the life of the well. While maintenance is always important, the general volatility of oil prices has forced the industry to target operational strategies that can also offer quicker returns on investment. Since the completion system discussed in this paper employs large-diameter production tubing, it provides the maintenance benefits of a monobore system but with added advantages that a large flow area can provide. The increased flow area 1) allows the number of wells to produce a given reservoir to be reduced and 2) enables production rates to be increased, which in turn, reduces long-term operating expense since the reservoir can be depleted in a shorter period of time.The specific benefits of the large-bore monobore completion are as follows: No restrictions are imposed on productionProduction rates are maximizedGas turbulence areas are eliminatedNo restrictions on any service/intervention toolsTubing retrieval to the liner top is allowedFull access to the liner for squeezing or mechanical isolation of the perforations is allowedAncillary equipment requirements are minimized.
Underbalanced Horizontal Drilling: A Field Study of Wellbore Stability in Brazil
Authors: Falcao José L. , Fonseca Carlos F. 
Published: December 2007

Abstract
This paper discusses the design and wellbore stability considerations to drill four underbalanced horizontal wells in a mature, pressure-depleted and high permeability reservoir in the onshore Estreito field-Northeast of Brazil. To do so, it was determined the minimum mud weight that produced the minimum ECD below reservoir pressure, but above the lower collapse pressure, that keeps the wellbore integrity. For that, two approaches were employed: an in-house linear elastic stability simulator, named SEST, and a poroelastic simulator that takes into account the plastic yielded area around the wellbore.
The main operational aspects related with stability of the first two horizontal underbalanced wells are also discussed. Finally, the results indicate that the methodology adopted in the design was successfully applied in the field.
Value-of-Information - from Cost-Cutting to Value-Creation
Authors: Koninx Jean-Paul M. 
Published: December 2007

Abstract
Value-of-Information analyses are a powerful tool for short- term rationalisation of data acquisition costs. But even more so the longer-term added value of proper VOI analyses lies in the process of constructing the analysis, and in the insight it gives into risk and opportunity management. A rigorous VOI analysis generally spans the full life cycle of E&P, and as such requires input from a multi-disciplinary team. A thorough scrutiny about where data adds value will lead to value optimisation and creation.
In order to unlock this value, implementation of a rigorous and easy-to-use methodology is critical. Such an implementation has progressed in Woodside, and has already led to a shift in mindset. VOI analyses are less regarded as cumbersome and fuzzy, but more and more as an essential part of data acquisition and data analysis. As a result, sizeable reductions in well data acquisition costs have been achieved, and data acquisition and analysis has become more focused.
Well Construction and Intervention Engineering Using a Relational Database
Authors: Thomson S. M. , Manifold C. B. 
Published: December 2007

Abstract
The management of information and the work-flow process associated with completions, workovers and other well- intervention activities in a large hydrocarbon-producing basin can be improved with a consistent and controlled system. Santos' Petroleum Engineering Operations group in Queensland, together with Advanced Well Technologies, have developed a FileMaker Pro™ database to streamline the work- flow processes required to manage the completions, workovers and other well-intervention activities effectively.
New Workover and Completion Technology Utilised in Bass Strait
Authors: Eaton M. L. , Barry A. G. , Schoemaker S. 
Published: December 2007

Abstract
As production from the Gippsland Basin in Bass Strait Australia passes the 30 year mark, the need to find innovative techniques to maximise production from this world class maturing basin is a principle priority for the operator. To address this issue, Esso Australia, on behalf of the 50:50 joint venture with BHP, recently embarked on a concentrated program to trial and evaluate several new technologies being developed by industry.
This paper discusses several technologies that were employed to increase production, enhance reservoir recovery and improve well integrity. Varying degrees of success were achieved during these trials and the successes, failures and lessons learned will be outlined.
The technologies discussed include: Scab liners with inflatable packers set through tubing in horizontal wells to isolate water/gas production;Gas and water shut off techniques utilising polymer technology;Wellhead leak sealing technology using differential pressure-set coagulating polymers;Wirelineless completions using expendable plugs and perforating gun hanger systems on space limited platforms (during infill drilling operations);Through-tubing deep penetration perforating charges used to stimulate production from wells with extensive near wellbore damage; andMini-fracturing gas stimulation technology used on poor performing reservoirs.
The high level of mechanical success combined with encouraging reservoir success in some instances is promoting a continued search for further production enhancing techniques.
Monitoring and Control of Water Influx in Strong Aquifer Drive Gas Fields Offshore Sarawak
Authors: Veeken C. A. M. , Chin H. -V. , Ross R. W. , Newell M. D. 
Published: December 2007

Abstract
The M3 and M1 gas fields offshore Sarawak experience exhibit aquifer support that is stronger than expected and markedly non-uniform in nature. This has resulted in rapid water breakthrough in 4 out of 7 development gas wells in M3. This paper describes the surveillance and remedial activities that were implemented to respectively monitor the aquifer rise and the associated water production and to reduce the detrimental impact of water breakthrough on gas well capacity.
Critical Wellbore Considerations for Successful Carbon-Oxygen Log Applications: Benefits of a Teamwork Approach
Authors: Tran Thanh Binh , Fox Phil , Adnyana I. Gede , Nguyen Chuong 
Published: December 2007

Abstract
For many of Asia Pacific low salinity medium to high porosity oil reservoirs, carbon-oxygen (C/O) logging has provided an effective method of through casing reservoir surveillance. This technology has been applied for well over two decades to provide saturation characterizations in conditions that are often challenging even in the openhole environment. To be successful, however, close attention must be paid to strict criteria during stages of problem identification, candidate review, well preparation, data acquisition, data processing and tool response interpretation.
A joint team was formed last year between operating company and service provider personnel. The charter of this group was to form standing best practices designed to optimize results from this technology. Case examples1 of interest related to this effort included: comparison of calcium yields to the open-hole caliper in a washed-out boreholeC/O responses in an apparent extensive exterior borehole cavern that potentially was a result of formation sandingtime-lapse, post cement-squeeze, near-wellbore fluid displacement recovery observed with monitor logging runspotential misinterpretation from log responses through an oil-filled cement sheath channelinter-reservoir cross-flow flushing induced saturation distortion resulting in failure to evaluate true reservoir hydrocarbon volumetricsestimation of reservoir saturation from within a hydrocarbon-rich boreholeeffects of formation lithology on C/O log responsesusing C/O to locate bypassed reserves in coning reservoirsusing C/O to monitor water and steam flood fields as an input to reservoir description modelingeconomic gains realized from recent C/O log applications
This paper presents a short C/O technology overview, historical review of past practices, a review of joint discussions between team members providing and using the associated log application techniques and describes the ongoing Carbon-Oxygen Workshop Forum (COWF) review series. Additionally, some key C/O best practices developed from over 150 logging experiences in Indonesia are highlighted.
Design and Execution of a 3000-ft Horizontal Gravel-Packed Completion (A Kazakhstan Case History)
Authors: Tibbles Raymond , Blessen Elton , Qian Xiang , Steven Bill , Pardo Carlos , Hurst Gary , Kubota Randall , Mysko Peter 
Published: December 2007

Abstract
This paper discusses the planning, design and successful execution of the first horizontal gravel pack in Texaco's remote North Buzachi field. Well NB4Z, located on land in Kazakhstan, presented extreme challenges that greatly affected the planning of the completion process.
Example of the challenges include the following: The combination of a 3000-ft-long openhole lateral section in a shallow reservoir meant that the screen would be over 1000 ft into the openhole before the gravel-pack packer was connected on the rig floor.The location had a limited supply of water for completion operations. Disposal of water was also a problem.The shallow reservoir made the screen placement problematic and made the torque and drag calculation much more critical.Because of the limited number of evaluation wells, everything had to work correctly the first time; i.e., there were no learning curve opportunities.
All aspects of the gravel-pack design are discussed (drilling fluid selection, torque and drag calculations, screen selection, selection of gravel-pack method, and pumping design). The successful executions of various completion phases are compared with the initial designs, and postcompletion well production is discussed.
This horizontal completion set several records. Among them are records for the longest slurry pack, the longest horizontal well to be gravel packed without washpipe and the longest gravel pack using shunt screen technology. The design took an existing technology, enhanced it and stretched its application to a new limit, in the process obtaining a successful result.
Emerging Techniques in Gravel Packing Open-Hole Horizontal Completions in High-Performance Wells
Authors: Parlar M. , Bennett C. , Gilchrist J. , Elliott F. , Troncoso J. , Price-Smith C. , Brady M. , Tibbles R. J. , Kelkar S. , Hoxha B. , Foxenberg W. E. 
Published: December 2007

AbstractGravel-packing of open-hole highly-deviated or horizontal wells is increasingly becoming a common practice, especially in deep water and sub-sea completion environments where production rates may reach up to 50,000 BOPD or 250 MMSCFD. In these wells, reliability of the sand face completion, in addition to other factors, is of utmost importance due to the prohibitively high cost of intervention or side-tracking and the very high hydrocarbon recoveries required per well. To date the norm in gravel-packing such wells is water-packing or shunt-packing with water-based fluids. With both techniques, filter-cake removal treatments are conventionally done through coiled tubing after gravel packing, pulling out of the hole with the service tool and running in with the production/injection tubing. Furthermore, because conventional gravel-pack carrier fluids are water-based (brine or viscous fluids), water-based drilling fluids are traditionally used to drill the reservoir section to ensure compatibility and improve wellbore cleanup, even if the upper hole is drilled with a synthetic/oil-based drilling fluid.In this paper, we discuss several novel techniques that can substantially improve return on investment in gravel packing of open-hole horizontal completions, through reduced cost and process time, improved fluid management practices, increased productivity and/or reduced risk of future interventions, so mitigating against the risk of sand face completion failure or under-performance. The proposed techniques include: Simultaneous gravel-packing and filter-cake removal with water-based carrier fluids when the reservoir is drilled with a water-based drilling fluid: laboratory data relevant to gravel-packing are given and field case histories are discussed in detail.Simultaneous gravel-packing and cake cleanup with either water or a synthetic/oil-based carrier fluid when the reservoir is drilled with a synthetic/oil-based drilling fluid: laboratory data on cake removal while gravel packing are presented for both water-based and oil-based carrier fluids along with data on kinetics of cake removal.a new service tool that utilizes wash-pipe as continuous tubing and thus allows spotting of breaker treatments immediately after gravel packing: detailed description of the tool and its operation is given.Gravel-packing of highly-deviated or horizontal wells above fracturing pressure.Benefits offered by each of the proposed techniques are discussed in detail along with their current limitations.
The Mutable Distributed Team: A New Business Risk in the Information Age
Authors: Goldthorpe W. H. 
Published: December 2007

Abstract
The power of Internet-based technologies has created work environments that are shaping a new type of team structure - the mutable distributed team. To take full advantage of the new information systems and to manage changed team dynam- ics, the problems and risks faced by such teams and their lead- ers need to be understood and new skills need to be learnt. This paper analyzes and provides examples of the class of business risks that arise from the management of mutable dis- tributed teams in the so-called Information Age.
An Innovative Approach for PSC and GSA Discussions/Negotiations
Authors: Seong Chen Kah , Kario Mohamed Wahid 
Published: December 2007

Abstract
PETRONAS undertook a group-wide re-engineering exercise in 1996. Following that, PETRONAS Exploration & Production Sector and PETRONAS Carigali (upstream operating arm of PETRONAS) were merged under a single E&P Business Unit. PETRONAS Exploration & Production Sector was renamed as Petroleum Management Unit (PMU) and was given the role as the custodian of PETRONAS' ownership of the nation petroleum resources. The re- engineering exercise, with PMU's key tasks well defined, has reduced the manpower of PMU by more than 50%. As such, new model had to be formulated for Production Sharing Contract (PSC) and upstream Gas Sales Agreement (GSA) negotiations with Contractors.
Discussions and negotiations on a commercial arrangement for the development of gas fields for supply to a gas utilisation project in Peninsular Malaysia (PGU Project) commenced in May 1996. Following parties agreement on the main principles of gas development and supply, PETRONAS signed the Main Terms of EPMI/Carigali Gas PSC (GPSC) with EPMI and CARIGALI in June 1997. The Main Terms of GPSC form the basis for formulating the PSC and GSA, which was signed in November 1998. The scope of the contract includes the exploration, development and production of natural gas resources from 22 fields for supply to PGU Project. The total fields development cost is estimated at USD 4.2 billion nominal dollar.
This paper will discuss on the following; brief review of the re-engineering exercise and PMU's key tasks after the re- engineering exercise, the model adopted by PETRONAS towards the PSC and GSA negotiations and will attempt to explain how is this different from the previous negotiations.
Inhibition of Lead and Zinc Sulphide Scale Deposits Formed during Production from High Temperature Oil and Condensate Reservoirs.
Authors: Jordan M. M. , Sjursaether K. , Edgerton M. C. , Bruce R. 
Published: December 2007

Abstract
Carbonate and sulphate scales are the most common types of mineral deposit associated with the recovery and processing of hydrocarbon and associated produced water. In three high temperature fields (&gt;140C) within the North Sea more usual scale types have been observed namely zinc and lead sulphide. Conventional inhibitors cannot control these scale types and their removal by chemical means can result in the generation of toxic gas (H2S). The conditions for the formation of these unusual scale types is described and well as the economic impact these deposit had on hydrocarbon production of these fields. In this paper the development of a novel scale inhibitor package and its successful application in these fields is described.
Field evaluation of the inhibitor types used to control sulphide scale is described in this paper as well as the details on how the field trials were planned, carried out and evaluated. Mechanical and chemical removal are also discussed as an alternative to inhibition.
The finding of this paper significantly increase the industries understanding of sulphide scale deposits in terms of mode of formation and mechanism of inhibition. The paper stresses the critical factors to be evaluated within produced water at the early stage of field appraisal/development that can aid in the assessment of the risk of sulphide scale deposition. The development of a novel zinc and lead sulphide inhibitor gives a cost effective, environment friendly alternative to chemical or mechanical removal of such deposits.
Polymer Gel Squeeze for Gas Shutoff, Water Shutoff and Injection Profile Improvement in Bombay High Pilot Wells
Authors: Jain Prabuddha , Sharma Vinod , Raju A. V. , Patra S. K. 
Published: December 2007

Abstract
In heterogeneous stratified reservoirs with low vertical communication between the layers, the best results are normally achieved if the separate layers are produced with a separate set of Wells. However, in a commingled production with poor vertical sweep due to high permeable thief zones, an improved behavior of such a reservoir can be efficiently attained by controlling the injection and production rates of wells to reduce (or stop) injection in the thief zones, and/or production from high permeable layers with high water cut. Technically this can be done by recompletion of wells or with the application of gel technology.
The problem high GOR & high water cut wells of Bombay High L-III reservoir can be classified into three categories: Wells producing high amount of gas &/or water due to hardware leak and flow behind casing. The unwanted gas/water production here is due to contribution from zones not opened/exposed for production.Wells producing from multiple layers and a single layer producing major amount of gas or water. The unwanted water production may be due to breakthrough of injection water in one or more high permeable layers. The unwanted gas production may be due to cusping.Wells where early breakthrough has occurred due to thin high permeability streaks in a sublayer between Injectors and Producers. Here, the treatment may involve treating a portion of sublayer.
In the past several Chemical water shutoff jobs in Bombay High Field have resulted in failures. The job failure can mainly be attributed to high reservoir temperature and incompatibility of Gel system with reservoir rock. Gel systems were quite sensitive to variations in temperature and pH. Also cross flow in the well bore during shut in conditions was also an important reason in some cases.
An improved polymer gel treatment has been successfully applied in Bombay High Field - a high temperature carbonate reservoir, to control excessive gas or water production and to modify the injection profiles. Ten Wells were treated as a pilot: 6 for Gas Control, 3 for Water Control and 1 for Injection Profile Improvement. All the planned wells exhibited at least one, usually more than one, of the following conditions: At least one interval with vuggy porosity, poor primary cement over at least a portion of pay, additional loss of rock volume due to acidization, reservoir pressure less than hydrostatic in producing wells, differential pressure between zones due to differential depletion or water flood support.
This paper discusses in detail the lessons learnt from the job failures and the successes with the use of polymer gels in such harsh conditions of Bombay high field.
A Risk and Economic Evaluation Tool for Management of Operating Costs
Authors: Harvey Helen E. , Gration Dale P. , Martin Stephen 
Published: December 2007

Abstract
Management of operating costs and resource planning is fundamental to maximising asset value. However, there is a balance between the capture of cost reduction and revenue enhancement opportunities and management of health, safety, environment and integrity risks.
A process is described that allows risk reduction activities to be ranked on an equitable basis with straightforward economic opportunities. The resulting ranked list of ideas forms the basis of prioritisation for input to activity planning, estimates of budget targets to maintain asset integrity and to manage expenditure within budget targets and known levels of risk.
Effective Evaluation and Development of Diabase & Contactite Fractured Reservoir in Luo 151 Area
Authors: Yuan Xiangchun , Xing Zhengyan , Liu Xiantai , Wu Wei , Zhao KaiLian , Guo Sun , Jia Junshan 
Published: December 2007

Abstract
The diabase & contactite reservoir in Luo 151 Area is located in the northern wing of the Luojia nosing structure zone of Zhanhua sag. Multistage invasion formed diabase and contactite. Only poreous Hornfels and fracturted diabase are effective reservoir rock, the reservoir is characterized by strong heterogeneity with complex pore structure, fracture feature and oil-water distribution.
Applying log-constrained seismic inversion technique, and based on 3D seismic, core analyses, drilling, logging, in especial FMI logging and CMR logging, production data, the pre-production evaluation of the fractured reservoir was performed. The emphasis of reserch were put on the detailed correlation of formation, the lithofasics of diabase and Contactite, the petrophisical, especially the spatial distribution and quantitative description of poreous hornfels and fractured diabase reservoir, and the predication of the potential reservoirs. Then, the proved reserves were estimated. Based on the results, four development wells were designed and drilled in favorable oil-bearing area and the expected production were obtained.
This paper discusses the evaluation methods and results of the fractured reservoir in Luo 151 area.