bluuebunny/crossref_metadata_2025_split huggingface dataset:
High-Rate Pre-Packing Using Non-Viscous Carrier Fluid Results in Higher Production Rates in South Pass Block 61 Field
Authors: Patel Y. K. , Troncoso J. C. , Saucier R. J. , Credeur D. J. 
Published: December 2007

Abstract
Production in South Pass Block 61 field is from Pliocene age sand reservoirs. Over the years different sand control techniques have been employed to maximize production rates and reserve recovery. In an effort to improve the productivity of our completions, we have employed High Rate Pre-Packing using non-viscous carrier fluids (High Rate Water Packing). The term "prepacking" is used to describe the process properly recognized as "outside casing packing". This paper will describe procedural aspects of the technique and present a possible explanation of the downhole process taking place using a pseudo 3D frac model. The post-job evaluation and comparative productivity data presented in the paper will clearly show the positive results of this economically attractive and simple procedure. We have used B-26 ST#1 (referred to subsequently as B-26) as an example well. Figure 1 shows the interval treated in B-26.
Combined Stochastic and Deterministic Reservoir Characterization Leads to Faster History Matching of a Horizontal Well in a Complex Fluvio-Lacustrine Environment
Authors: Calatayud P. M. , Petit F. M. , Tessier Philippe , Norris R. J. , Coffin Philippe , Alabert F. G. 
Published: December 2007

Abstract
An example of how to treat a complex fluvio-lacustrine reservoir, characterized by both continuous and discontinuous multi-scaled heterogeneities is presented. A detailed geological description was prepared, the heterogeneities were described and quantified, and discriminated in correctable or discontinuous levels. The discontinuous levels were geostatistically modelled and up-scaled, whilst the correctable ones were deterministically represented. The history matching process was very rapid, allowing greater time and confidence in sensitivity studies. The whole study is clearly a multi-disciplinary project, involving geology, geostatistics, up-scaling and simulation.
Moxa Arch Frontier Formation Development Success Through Increased Fracture Conductivity
Authors: Schubarth S. K. , Chabaud R. A. , Einhorn R. B. 
Published: December 2007

Abstract
Successful development of the Frontier formation in southwest Wyoming begins with the hydraulic fracture treatment design and implementation. Without a design to effectively stimulate the Frontier formation and a proper implementation of that design in the field, production rates will be limited. This paper will detail the efforts of the authors in the development by Bannon Energy Incorporated of a significant number of Frontier completions.
Information from over 100 fracture treatments and the production response from over 400 wells will be used to demonstrate the significant improvement in gas production resulting from the fracture treatment designs and implementation methods employed. A first year gas recovery improvement of over 50% was achieved when compared to offset production. The use of intermediate strength proppants along with other design and implementation methods have significantly improved production from this "tight" gas sand.
To Tender, Re-Negotiate or Partner: Strategies for Contracting Service Companies
Authors: Gouldie T. A. 
Published: December 2007

Abstract
The contracting of oilfield service companies by petroleum exploration and production operating companies is different than the contracting of civil engineering, construction or other project-oriented contractors. The relationship between operating companies and oilfield service companies has had a long and unique history which has evolved since the first oil wells were drilled over a century ago.
The process of contracting service companies by operating companies for petroleum exploration and production work can be split into three distinct stages: Decide what it is that should be contracted out and what should be kept "in house,"Determine the method to use to select the contractor(s) to perform the work, andAgree to the contractual structure to best reflect the relationship the operating company and the service company wish to initiate and maintain.
As there are ongoing changes to the business structures and corporate thinking of both operating and service companies, there are also evolving changes to what are considered "core businesses" and the methods of selecting and contracting service companies by operating companies.
Operating companies are recognizing the high costs of tendering for contractor services in terms of personnel time and administrative effort, and are relying more on negotiating and rolling-over existing contracts with their suitable, capable contractors. Partnering, in its many forms and levels, is increasingly being recognized as a useful method to get better work done at cheaper overall costs.
Bekasap Field Hybrid Streamtube Model Study
Authors: Rahardja Agus , Gerbacia W. E. , Pristiwanto H. P. 
Published: December 2007

Abstract
The Bekasap Field is located in the Riau Province of Central Sumatra, Indonesia. It produces mainly from three major formations, Bekasap, Bangko, and Menggala. The average field production in 1993 was 18,000 BOPD at a water cut of 86%.
A waterflood project is being evaluated for this field. The top two formations, Bekasap and Bangko, are being targeted for this project, since reservoir pressure has declined due to a partial support from an edge waterdrive mechanism.
A reservoir model of the top two formations was done using a hybrid fmite-difference/streamtube method, to forecast field oil recovery under several producing strategies. This paper presents a discussion of the hybrid streamtube results, including history matching and forecasting of field performance.
Recovery of Condensable Liquids From Flare Gas
Authors: Jones J. A. , Grey P. C. 
Published: December 2007

ABSTRACT
Esso Australia is currently installing a facility to recover hydrocarbon liquids and gas that are presently flared from the Esso/BHP Petroleum Longford Crude Stabilisation Plant and Gas Processing Plant #1.
The project recovers and sells LPG and condensate, reduces carbon dioxide emissions and conserves valuable energy resources.
After an extensive review of process options, a combination of compression and condensation of the recovered gaseous hydrocarbons was chosen as the optimum configuration to fulfill the project's economic and environmental objectives. The project is under construction at the Victoria plant.
Development Planning: A Systematic Approach
Authors: Cockcroft Peter J. , Grant John N. , Moore Kevin S. , Warnohardjo Gita N. 
Published: December 2007

ABSTRACT
A primary goal of an oil or gas field development is to maximize the present value of the investment. A systematically-prepared Plan of Development (POD) can assist operators in achieving this goal by ensuring that all factors are considered in evaluating, planning, and carrying out the field development.
A POD should contain an evaluation of all major events that realistically may occur during the field development cycle. By considering these events in the planning stage their probability of occurrence, effect on operations, and risk-weighted financial impact can be analyzed before field development begins. Depending upon the financial impact of the event, the field development strategy can be planned to alter the probability of occurrence or to reduce the consequences of the event.
The contents of a systematic plan of development are presented and discussed: Design Basis, Exploitation, Operations & Maintenance, Engineering, and Economics. Two Southeast Asian Field examples are used to illustrate how field economics would have been enhanced had a development plan been prepared using a systematic approach.
Moomba Lower Daralingie Beds (LDB) Gas Storage Project: Reservoir Management Using a Novel Numerical Simulation Technique
Authors: Jamal F. G. 
Published: December 2007

ABSTRACT
Engineers managing underground gas storage projects are often faced with challenges involving gas migration, inventory variance, gas quality and inventory-pressures. This paper discusses a unique underground gas storage project where sales gas and ethane are stored in two different but communicating regions of the same reservoir. A commercially available reservoir simulator was used to model the fluid flow behaviour in this reservoir, hence, providing a tool for better management and use of the existing gas storage facilities.
Reservoir Engineering Aspects of Fracturing High Permeability Formations
Authors: Hunt James L. , Soliman M. Y. 
Published: December 2007

Abstract
High permeability formations are not usually the realm of hydraulic fracturing. However, recently there has been a resurgence of interest in stimulating these reservoirs. Reasons for the interest include fracturing past damaged zones, controlling and preventing sand production, and generally providing better control over the wellbore.
In studying this problem, several factors need to be considered. One factor is the productivity improvement aspect of the fracturing treatment. Under certain conditions, fracturing can provide a significant production increase even in a very highly permeable formation. Therefore, production versus time is important. A second consideration is pressure as a function of distance. This factor is important in the sand production aspect. Fracturing can decrease the pressure drop and gradient within the formation and thus sand production can be controlled or even prevented.
This paper presents results of a study performed to investigate the effect of various parameters on well and fracture performance in a high permeability reservoir. These parameters include formation permeability, degree and depth of damage, fracture length, fracture conductivity, and fracture face damage. Conclusions from the study provide guidelines for candidate selection and fracture design as well as insight into the effect of stimulation of high permeability reservoirs.
A Unique Experience With Foamed Cement
Authors: Piot Bernard , Ferrière Rémi , Fraboulet Bernard 
Published: December 2007

SUMMARY
An extensive laboratory program showed that foamed cement was the only technically feasible solution to prepare a "floating" cement plug for solving severe lost circulation problems in big caverns. The technique had, however, to be adapted to fit well conditions that are relatively unusual in the oil field: the cement slurry should not become diluted and destabilized upon exiting the drill pipe and entering the 60-plus inches wellbore and the huge caves, several feet in radius, both filled with sea water. Moreover, the foam had to remain stable, even when surrounded by large volume of water, until cement setting.
Therefore a technique of using "protective" fluids was devised. In addition, logistics dictated the use of compressed air rather than nitrogen to prepare the foamed slurry. Therefore special gas metering and regulation devices were used for the first time in the oil field in order to automate the process and get a perfect control of the slurry density whatever the slurry mixing and pumping rates.
Before field implementation, the metering and regulation device was successfully yard tested, the gas phase being supplied by nitrogen bottles. The successful field implementation with air compressors, together with the "protective" fluid technique to combat lost circulation in loose coral reef and in highly fractured dolomitic formation, is described.*
Geologic Factors Which May Affect the Occurrence of Natural Gas in the Oklahoma Panhandle; with Notes on Gas Analyses in Uinta Basin, Utah
Authors: Moore Carl A. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Introduction
The Oklahoma Panhandle has produced major amounts of gas for 50 years. Initial production came from shallow rocks of Permian production came from shallow rocks of Permian age the Herington, Krider and Winfield porous limestones located on the northwest flank of the Anadarko basin.
Beginning in the early 1950's, additional reserves of gas have been proved in the Panhandle from deeper horizons in Pennsylvanian Panhandle from deeper horizons in Pennsylvanian and Mississippian age rocks. Of these newer horizons, the Morrow sands are by far the most important, followed in importance by the Chester (Mississippian), then the Hoover, Tonkawa and Topeka in approximate equal proportions. This newer production has added significant reserves to the earlier reserves, making the Oklahoma Panhandle a major segment of the Panhandle a major segment of the Amarillo-Hugoton gas field.

REGIONAL GEOLOGY
The subsurface structure at the base of the Pennsylvanian system of rocks across the Oklahoma Panhandle is illustrated in Fig. 1. In Cimarron County, the western of the three Panhandle counties, depths to the Panhandle counties, depths to the pre-Pennsylvanian sequence of rocks average about pre-Pennsylvanian sequence of rocks average about 1,000 ft below sea level. Much of this county is not well recognized because of the lack of well control. Recent tests near Boise City are expected to provide additional information. Keyes Dome is situated within the closing contour in the northeastern corner of the county.
Across Texas County, the middle county, subsurface elevations range from 1,000 to 4,000 ft below sea level. Most of this difference in elevation is related to the prominent faults along the western county line. prominent faults along the western county line. East of these faults the shelf area of the Anadarko basin dips fairly uniformly backward.
Beaver County, the eastern county, lies on the hinge line between the shelf area of Texas County and the steep basin flank that drops southeastward into the Anadarko basin trough. In the basin, each formation is expected to be found in full or maximum thickness. Moving out of the basin, past the hinge line and onto the shelf, each individual formation becomes thinner either by onlap or by erosion. Along the hinge line, environmental conditions are in optimal development for the deposition of porous/Permeable beds. Thus, Beaver County contains a large number of multiple stratigraphic pinch-outs or traps, any of which are potential reservoir beds, and hence capable of becoming a producing field.
Drilling to the Limit / Long Reach Oil Strike Extended Reach Appraisal/Development Well Tern TA-05
Authors: Meertens Rob , Harst Taco van der , Kloss Peter 
Published: December 2007

Abstract
In February this year, Shell Expro drilled an extended reach platform well (21,082 ft AH) to a small hydrocarbon prospect. The well proved the expected oil accumulation and a long term production test is in progress to verify extent and productivity of the accumulation and thus scope for further development.
The project presents a milestone in low cost appraisal and up front oil production, key factors in the development of marginal accumulations in a mature oil province. The experience gained has increased confidence both in long reach drilling capabilities and in the viability of small accumulations around existing facilities.
Gannet C: Geological Risks in a Marginal Field Development
Authors: Oppermann R. H- J. , Grant C. J. 
Published: December 2007

ABSTRACT
This paper reviews the means by which geological uncertainty has been addressed in a complex marginal field development. The Gannet C field development carries a significant element of risk resulting from a challenging drilling environment and large geological uncertainty due to poor structural definition on seismic. By creating extreme high- and low-case structure maps during a re-mapping exercise following completion of the first drilling round, a better grasp of the possible up- and down-sides to the development has been obtained. This case study shows that targeting horizontal wells using high- and low-case scenarios enables the geologist to optimise the well location within the confines of available data and to anticipate and react confidently to the unexpected drilling result.
Montrose: A case study of innovative, cost effective field rejuvenation
Authors: Andrews I. J. , Hennington E. R. 
Published: December 2007

Abstract
Since 1992, Montrose, a mature waterflood field, has been rejuvenated through a multi-disciplinary full field reevaluation and the innovative, cost effective application of completion technology. Workover opportunities and areas of potentially incomplete recovery, have been identified by the full integration of all field performance, reservoir and geological data. Then workovers incorporating innovative cost effective gaslift/velocity string completions, which addressed the concerns of weak and potentially non gas-tight casing, were carried out to rejuvenate the field.
This multi-disciplinary team approach to the rejuvenation of the Montrose field, has significantly increased field wide production rates, und dramatically reduced production costs per barrel, so allowing economic production in today's low oil price environment and the fulfillment of the fields long term potential.
In addition the study has identified many techniques/lessons that can be readily applied to other similar mature field studies.
Rob Roy Reservoir Management: Old Field, More Oil, Same Data!
Authors: Currie Susan , Lane R. L. , Woods J. S. 
Published: December 2007

ABSTRACT
Between 1985 and mid-1993 estimates of STOUP in the Rob Roy Field varied from 89 mmbbls to 110 mmbbls. In 1993 three well workovers resulted in a significant increase in dry oil production from the field. This increased production could not be history­ matched to the existing simulation model of the field.
This paper summarises the subsequent geoscience and engineering work which has led to a new STOIIP estimate of 143 mmbbls, a significant revision of the field reservoir simulation model, and a substantial increase in estimated oil reserves. These were achieved principally by a reinterpretation of the same geophysical dataset that was available at the time of the Annex B in 1985.
Oil Fields Waterflooding with the Help of Water-Gas Micronucleoud Solutions
Authors: Ametov I. M. , Bogopolsky A. O. 
Published: December 2007

ABSTRACT
The paper presents mathematical models of one- and two-phase flow mass transfer of micronucleus water-gas solutions in non-uniform porous media and results of numerical simulation aimed at optimization of micronucleus flooding.
Offshore Refining: A Cost-Effective Approach for Treating Associated Gas
Authors: Antia D. D. J. , Seddon Duncan 
Published: December 2007

Abstract
A cost effective approach is outlined which can be used to remove the need to reinject associated gas (5 to 100 MMCF/D) on small, marginal, or remote North Sea oil fields by using a new application of a proven Fischer-Tropsch refining process to convert the gas into a high value synthetic crude oil which can be blended into the main crude oil stream. Additional offshore refining of the blended crude oil stream can be used to enhance its market value (by about $3/Bbl) for minimal additional cost (&lt;$0.1/Bbl).
REGNAR - Development of a Marginal Field
Authors: Thalund K. M. , Brodersen F. P. , Roigaard-Petersen B. 
Published: December 2007

Abstract
Regnar is a small marginal field located some 13 km from the main Dan F complex and is the first subsea completion in Danish waters, operated by Maersk Olie og Gas AS. A short lifetime has been predicted for the field which therefore has been developed as a low cost project, using a combination of subsea technology and minimum topside facilities.
Regnar consists of a subsea x-mas tree producing through a 6" pipeline with a 2 1/2" chemical piggyback line to Dan F. The x-mas tree and the subsea choke valve are controlled from a buoy moored nearby the well. The buoy is radio linked to Dan F.
The Regnar field was brought on stream on September 26, 1993.
Minimising the Cost of Subsea Developments through Technological Innovation
Authors: Eyre Geoff , Loth Bil 
Published: December 2007

Abstract
The paper summarises the results of an extensive study carried out for the UK Government. This assessed the cost and economic impact of technological innovation on subsea and floating developments in the UKCS.
The study covered, innovations that could be applied to subsea developments to significantly reduce cost, including multiwell completions, composite pipelines, compartmented pipelines, pipeline specification breaking and autonomous control systems.
Cost and economic models were used to assess the economic impact of technological innovation on marginal field developments. The results of these assessments were drawn up as a series of ranking lists designed to assist manufacturers and suppliers in establishing priorities for research and development funding.
The study also explored the potential UKCS and World market for innovative subsea technologies and quantified the research and development required to bring key innovations into commercial use.
Not Normally Manned Compression Platforms for the North Sea
Authors: Kumaran K. S. 
Published: December 2007

ABSTRACT
Gas turbine driven gas compressors havebeen widely used on manned offshore facilities. Similarly unmanned gas turbinedriven compressor stations have beeninoperation onshore with major gas transmission companies in Europe, North America and elsewhere. This paper summarises a recent joint industry study to investigate the technical and economic feasibility of Not Normally Manned (NNM) Offshore Compression Facilities in termsof reliability, availability and maintainability.
Classification of not normally manned (or unmanned) offshore facilities in the UK North Sea is in accordance with HSE Operations Notice 8. ON8 specifies criteria for offshore visits, visit hours and number of personnel on board for the operation of NNM platforms. This paper describes a typical Southern North Sea gas platform being considered for NNM compressor application.
The conclusions from the study was that NNM compression is technically feasible with the facilities being able to provide an availability in excess of 98%. Life cycle costs were of the order of 70% of manned facilities thus significantly improving field development economics.
Thru-Tubing Sand Control Circulating Technique
Authors: Pretto L. A. , Treglia Giuseppe , Di Iorlo Maurizio , Patel D. C. , Grigsby T. F. 
Published: December 2007

ABSTRACT
The volatility of oilfield economics has always demanded operational efficiency and a need to put wells on production as quickly as possible. Conditions in today's oil and gas market have further increased these demands. To maintain profitability under current conditions, operators must carefully consider all factors that can impede well productivity, and sand production is one of the most critical of these factors. For this reason, effective sand control methods that can be performed at a reduced cost and do not have to be implemented until needed are becoming increasingly more important in today's operational strategies.
This paper will present one of these methods - a circulating thru-tubing sand control system that can be installed without pulling the production tubing or the downhole completion. This technique can be used for the repair of an original completion that has failed or in wells that are no longer economical to operate at flow rates restricted by sand production. An overview of the development, test, tool description, and installation will be presented.
Field Experience with a Simple Compact Multiphase Flow Meter
Authors: Brown D. , van der Spek A. M. 
Published: December 2007

ABSTRACT
Multi-capacitor multiphase flow meters have been tested at five field locations covering a wide range of crude properties and process conditions. Results of these field tests show excellent repeatability and good agreement with reference measurements, when available. These meters are now being applied at two different locations in Oman as the only means of testing individual wells.