bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Upstream Oil and Gas Industry's Initiative in the Development of International Standards
Authors: Thomas G. A. N. , Thorp Geoffrey 
Published: December 2007

Abstract
The paper describes the international work of the oil industry to formalise as International Standards many of the industry standards used world-wide. It also describes how matters have been developing in Europe.
E&P Forum, representing the international exploration and production oil and gas industry, provides a forum for co-ordinating industry standardisation, to ensure that the necessary standards are maintained by the appropriate technical body.
The paper discusses the development of the standardisation programme in ISO/TC67, the Technical Committee directing the transformation of some 70 API Standards into ISO Standards and the relationship to CEN (the European standardisation body).
The objective of the upstream industry is to operate world-wide to consistent international standards. Company standards can then concentrate on functional and performance requirements. This will facilitate international trade and communication, open competition and the global market. For a practical realisation of this objective the oil industry must foster a special relationship between the relevant US bodies, ISO and CEN. The sustained support of all sides of industry is required.
Standardisation of Tubular Goods – For Worldwide Application
Authors: Jones W. T. , Dharma N. 
Published: December 2007

Abstract
For many years the American Petroleum Institute (API) has provided base standards for the oil industry.
Over the past five years, the Oil Industry International Exploration & production Forum (E&P Forum) has worked closely with API, and the International Standards Organisation (ISO). Their goal has been to update Oil Industry standards for worldwide application.
The updating of Standards is required to assist in the harmonisation process which is necessary to meet the worldwide needs of the industry.
The paper will concentrate on the worldwide technical requirements for Tubular Goods, i.e. Casing, Tubing, Drillpipe and Linepipe.
The harsh environmental and climatic conditions of the North Sea reflect one geographic perspective. The established Tubular Goods Standards were originally developed within the USA and such harsh conditions were not envisaged. To address this, the Forum Work Group raised several technical issues initially with API, and more recently with ISO.
A number of technical issues are discussed, including the following:
Fracture toughness Ovality/outside diameter Gas tightness (Premium Connections etc) Use of PSL's
The paper will comment on the recent updates to API 5CT, and the more accelerated progress on the ISO Casing & Tubing Standard plus its potential adoption by CEN.
Linepipe Standardisation has advanced with the publication of the new CEN standard EN 10208 which will be covered at the end of this paper.
Optimal Perforation Design for Horizontal Wells in Reservoirs With Boundaries
Authors: Marett B. P. , Landman M. J. 
Published: December 2007

ABSTRACT
Wellbore production rates can be significantly influenced by the frictional pressure drop in long inclined or horizontal wells, particularly in high permeability reservoirs with small pressure drawdown. In this paper, a steady-state model is presented which couples the Darcy flow into perforations from the reservoir with the frictional flow in the wellbore.
Reservoir-perforation behaviour is modelled by flow into discrete well perforations within a homogeneous, anisotropic reservoir bounded by infinite parallel planes. By considering the flow into individual perforations, the importance of adjacent boundaries, well inclination, perforation density, perforation phasing and crushed zone damage can be studied. Wellbore flow, specified as either single or multiphase, accounts for the pressure drop along the wellbore due to well inclination, pipe friction and perforation inflow.
To enable flexible wellbore design, the well is partitioned into segments each with its own inclination, length, and number of perforations. Perforation distributions can be user-defined or optimized through various optimization strategies; for example, maximization of wellrate, or uniformity of specific inflow. The model described in the paper has been implemented in software and is currently being used as a design tool.
Testing of the Oseberg Gamma North Horizontal Well
Authors: Søgnesand Sigmund 
Published: December 2007

ABSTRACT
This paper describes the testing and production of the Gamma North horizontal well in the Oseberg Area. The 753 m long horizontal well section is located 11 ± 1 m above the oil-water contact in a 26.5 m thick oil zone with overlying gas cap. The Gamma North well is primarily a gas producer with a subsea completion tied into the Oseberg C platform. The reservoir development plan involves optimization of the oil recovery prior to the period of gas production from the gas cap.
Drilling of the well did not result in any major problems, and the horizontal section was drilled within 7 days. A prepacked screen is used to avoid sand production. Gas and water breakthroughs occurred a few months after production startup.
The Gamma North well was tested as a part of the initial completion program. The test sequence comprised of a cleanup flow, a stabilization period, and a shut-in period. The buildup data shows that no unique interpretation can be obtained. The analysis is based on reduction of variables, and the calculated parameters are in agreement with the geological well model.
Effective Fracture Stimulation in High-Permeability Formations
Authors: Elphick J. J. , Marcinew R. P. , Brady Barry 
Published: December 2007

ABSTRACT
The application of fracturing to high permeability formations is presented.
The economic rationale for fracturing high permeability formations is different from conventional fracturing. The principal reasons for fracturing these formations are reviewed. Design and execution methods for these fracture treatments are presented where they differ from conventional fracturing.
High permeability formations often have a tendency to produce sand. The effect of fracturing on the sanding tendency and the potential of using fractures as a sand control method are discussed.
Bigbore Well Completions: A New Completions Technique for Arun Field
Authors: Cannan W. L. , McKenna D. L. , Sukup R. A. , Calvert D. G. , Quitzau R. , Sardjono S. , Ellison P. C. 
Published: December 2007

ABSTRACT
The prolific Arun Field in North Sumatra, Indonesia continues to produce substantial amounts of natural gas and condensate. However, the massive carbonate reef reservoir is beginning to require special measures for more complete exploitation and recovery of the large quantities of hydrocarbon remaining in the formation. Optimization of production requires combined efforts from Arun geologists, reservoir, production, drilling, and operations personnel as well as technical advisors.
Although the Arun Field wells typically produce 30 to 100 MMSCFD per well, increased production rates are being achieved by utilizing larger bore wells and modifying the drilling and completion techniques accordingly. Substantial increases in gas and condensate production rates are being realized with a savings in investment over previous Arun Field drilling and completion methods utilizing conventional 7″ completions.
Previous completion techniques utilized 7" production tubing with either cased or open hole completions. The "Big Bore" completion technique has 9-5/8″ production tubing with an open hole completion to maximize deliverability. The primary purpose of the technique is to boost field productivity in order to meet gas demand, enhance condensate optimization, and allow flexibility in operations. This new completion technique required extensive equipment design and testing to meet anticipated production and stimulation conditions. This is the first time a completion of this type has been utilized in Indonesia, and as far as we know, these are the largest bore, gas producing well completions in the world. This paper discusses the performance of the wells and the various components utilized in this new "Big Bore" completion technique.
Processing Of Geological And Engineering Data Multipay Fields For Evaluation
Authors: Bankhead Charles C. 
Published: December 2007

Introduction
Recent oil and gas property trade involving multi-reservoir fields have required that studies be made within stringent time limitations. The evaluation of these fields has necessitated the evolving of a streamlined method of gathering, cataloguing, processing, and interpreting the basic geologic and engineering data. Methods are herein outlined for the rapid processing of such data and for the preparation of structure and thickness maps suitable for the engineer's use in estimating reserves, in predicting reservoir performance, in determining development of the field for optimum primary and secondary recoveries, and establishing the bases for optimum future operating methods.

TIME AND BUDGET SCHEDULE
Before a study is undertaken, the geologist is often required to submit a budget estimate and a provisional time schedule covering the geological part of a reservoir study.

CATALOGUING AND CHECKING
The geologist's role in expediting the engineer's work in evaluating a single or multipay field starts immediately with the arrival of all of the client's available information. The mass of data received from the client must be checked in and catalogued. This is generally handled by a secretary-technician, referred to in this paper as a statistician. The geologist aids in segregating material which can be transmitted immediately to the engineers and that which is essential or useful for preparing the necessary geological maps for the engineer's use. The material is then checked against a gathering data list comprised of most of the items listed below, and any missing items are ordered.

DATA ROUTING
Engineers: The engineers are generally given the following items immediately:Copy of the schedule of lease and wells.A preliminary work copy of a well and lease location map.Schedule of income and expense interests.Schedule of oil and gas prices and trucking charges.Schedule of operating expenses and ad valoremtaxes.Core descriptions, copy of core data, and special core analysis reports.Fluid data including fluid sample analyses, surface fluid sample data, GPM tests, gas analyses, and water analyses.Production data-oil, water, and gas by leases and/or wells by months.Special well tests on oil wells, deliverability tests on gas wells, GOR and watercut tests.History of reservoir performance including data and curves of BHP, GOR, and rates vs. cumulative production.Any engineering committee reports, reports on reservoir studies, outside consultant reports, and MER data.
All the foregoing data will permit the engineers to start their tabulations and studies simultaneously with the geological section.
Geologists:The geological basic data generally includes the following:Schedule of leases and wells.Maps and location plots, including client'sstructure and isopach maps.Client's cross sections and regional data.Logs (electrical, sonic, induction, micro, gammaray-neutron) and completion cards.Well completion data, including DST data, mechanical data, and other significant well file data.
Field Optimization of Steam/Foam for Profile Control: Midway-Sunset 26C
Authors: Gauglitz P. A. , Smith M. E. , Holtzclaw M. I. , Duran H. 
Published: December 2007

ABSTRACT
Chevron conducted a steam-foam trial in Midway-Sunset 26C to optimize the use of steam-foam, without the addition of a non-condensible gas, for improving profile control in a steam injection well. The field experiments were designed to find the optimal surfactant concentration and liquid volume fraction (LVF), or steam quality, for improving injection profiles with steam-foam. The effect of the total steam injection rate on the ability to generate a foam was also determined by using three chokes of different size. In all these tests, nitrogen was not added, because the goal was to develop a low-cost foam process. We also collected new laboratory data to determine the ability of low concentration foams to divert flow from higher to lower permeability sands.
Radioactive tracer measurements gave injection profiles with foam injection under ten different conditions, and five profiles were measured without foam injection. Downhole pressures were measured during these tests and under other conditions. Results show that increasing the steam LVF by blending water with the steam dilutes the surfactant, but improves foam generation and gives better profile improvement. Steam-foam improved the injection profile for concentrations greater than about 0.1 weight percent (wt.%) Chaser™ SD1020 at a steam LVF of 0.02 for the well tested. For surfactant concentrations below about 0.1 wt.%, the injection profile was changed but not improved. Tests showed that increasing the total steam injection rate from 180 to 630 BPD-CWE gave a larger pressure response due to foam for a range of surfactant concentrations. The test showed that profile improvement can be achieved with surfactant injected at about half the rate that was previously shown as necessary for in-depth foam applications, and this was accomplished without the addition of nitrogen.
The Effect of Steam/Foam Injection in a Steamfiood Experiencing Downdip Steam Migration
Authors: Bautista L. S. , Waninger E. A. 
Published: December 2007

ABSTRACT
A one pattern steam foam field trial was conducted in the Amnicola sand in the steamfiood of Section 26W, Cymric Field. The pattern was located in an area in which downdip steam migration occurred, soon after steam injection began, as a result of well spacing (which skewed injectors closer to downdip producers) and channeling (due to vertical permeability stratification).
The primary objective of the trial was to economically minimize the downdip steam migration, and consequently improve the sweep efficiency of the steamfiood. Chevron Chaser™ SD1020 was continuously injected with steam and nitrogen for approximately seven months. Reservoir conditions and production were monitored and analyzed to determine the effectiveness of steam foam as a mobility control agent.
The field trial also identified non-foam alternatives effective in reducing downdip steam migration. Operating strategies employed in the steamfiood to accelerate early oil production were analyzed to understand their effect on the reservoir, given skewed well spacing and vertical permeability variation.
The In-Situ Formation of Bitumen-Water-Stable Emulsions in Porous Media During Thermal Stimulation
Authors: Bennion D. B. , Chan M. Y. S. , Sarioglu Gurk , Courtnage Dave , Wansleeben John , Hirata Toshiyuki 
Published: December 2007

Abstract
The formation, production and handling of highly viscous bitumen-water emulsions is a significant problem in the operation of many heavy oil thermal stimulation projects. This paper documents an extensive study examining the in-situ emulsification of bitumen and water under conditions of simultaneous flow In an unconsolidated preserved state porous media at full reservoir pressure conditions and at a temperature of 200° C. Various co-injection ratios from 100% bitumen - 0% water to 100% water and 0% bitumen were examined in both water saturation increasing and decreasing directions (drainage and imbibition). The test results indicate that in-situ emulsification does occur, that certain simultaneous flow ratios cause a localized increase in the severity of emulsification, and that the degree of emulsification appears to be related to the relative flowing proportion of fluids inside the porous media. Some evidence of directional hysteresis effects on emulsion quality were also observed.
Comparison Between Political and Economic Country Risk Factors
Authors: Proehl T. S. 
Published: December 2007

Abstract
Political risk analysis, or country risk analysis is one of the more contentious topics in the petroleum economics universe. Overseas investors have several choices with regard to country risk analysis. Ignore itDelegate analysis to outside expertsCalculate it themselves
In the real world, investors would probably choose to avail themselves of outside counsel AND calculate risk factors themselves, provided a suitable method to do so exists. Ideally, the process of consulting experts and performing internal assessment of potential risks facing an investment proposal would produce chance factors for various scenarios which could be utilized in expected-net-present-value calculations.
Economic investments always occur in a political environment Economically sensible projects should encounter political acceptance. Foreign investment projects ultimately must make economic sense to host nation governments and their populations, as well as to investors. Political risks tend to materialize whenever large, organized groups within a host nation perceive foreign investment as something which ceases to make economic sense to them. More specifically, whenever people perceive foreign investment as being detrimental or neutral toward their economic interests, the potential for political risk events increases.
Future Oil Production in the North Sea
Authors: Takin Manouchehr 
Published: December 2007

ABSTRACT
The North Sea is generally considered a high cost oil province; thus the price of oil and the cost of production are the two key parameters which will control its future production profile. A detailed study was carried out on more than sixty new fields in the Norwegian and the UK sectors. For each field, the investment intensity (Dollars per daily barrel) and the fully-built-up lifetime unit cost of production were estimated. The results cover a wide range but reach more than $30,000 per daily barrel for the investment intensity and more than $30 per barrel for the unit production cost. By comparing the costs with future oil price scenarios, it is estimated that the level of oil production in the North Sea could be between 3.6 and 5 million barrels per day in 1995 and between 1.6 and 2.9 million barrels per day in the year 2000. These production estimates include the incremental production from the new fields and the contribution from the existing fields. It is interesting to note that some high cost fields are undergoing development although the present outlook for oil prices may not justify their development. This may suggest three possible reasons: the companies investing in these fields anticipate higher future oil prices, they put a considerable emphasis on supply security and political stability in the North Sea, or they are hoping to achieve significant reduction in costs.
The Value of a Seismic Option
Authors: Stibolt R. D. , Lehman John 
Published: December 2007

Abstract
Exploration and production agreements worldwide typically include seismic surveys and exploratory drilling obligations as key contractual provisions. In some jurisdictions, most notably the United States, agreements typically do not include drilling obligations. The lessee holds a right rather than an obligation to drill and, therefore, may relinquish acreage without drilling if the results of seismic surveys or other geological tests prove unfavorable. It is often possible in other jurisdictions to negotiate such a "seismic option" in exchange for less favorable treatment with respect to other contractual provisions such as profit share. An implicit option may also exist to the extent that a reduction in exploratory well commitments can be obtained by offering additional seismic work. In the case of such trade-offs, the ability to quantify the value of the seismic option is a necessity. This paper presents a framework for this valuation.
Commodity Price Swaps: A Tool for Asset Management
Authors: Winslow D. J. , Porges D. L. 
Published: December 2007

Abstract
In comparison with the pricing mechanisms that prevailed for crude oil and natural gas from the 1940s through the 1960s, the current price environment is exceedingly volatile. In response to this volatility, financial products called derivatives have been developed in the last decade. Of these, the commodity price swap is finding acceptance as a tool to manage price risk. This paper is an introduction to commodity price swaps for those individuals whose responsibilities include managing a portfolio of oil and gas assets, but who have not had direct experience with swaps. In addition to a description of the basic fixed-for-floating swap and its variations, the historical evolution of swaps is outlined. The significant contract terms and the special problems associated with swaps are also summarized.
Selected applications of commodity price swaps which may be useful in managing a portfolio of petroleum assets are described. These applications include: Locking-in Project EconomicsSwaptionsPrepaid swapsSynthetic oil (or gas) fieldsBTU swaps
Swaps have experienced a rapid growth rate since their introduction in the interest rate and currency exchange markets in the early 1980s. Commodity swaps offer promise as a new tool to those firms which hold a portfolio of petroleum resources, developed or undeveloped.
Note that this paper is not intended as an authoritative reference with respect to the legal, tax and accounting issues associated with commodity swaps. Given the rapidly changing legal and regulatory context of swaps, it is advised that readers seek current opinions from their appropriate legal and accounting advisers.
The Cost Recovery Oil in a Production Sharing Agreement
Authors: Muscolino Riccardo , Rizzo C. A. , Mirabelli Giuseppe 
Published: December 2007

Abstract
Apart from some exceptions, everywhere the State is the owner of the natural resources in its territory.
Therefore, the exploration for oil and gas, being natural resources; entails the execution of agreements between the Oil Companies and the local governments.
Such agreements are governed by a proper contract setting out different items: the area, the duration, the work and/or expenditure commitments, the possible taxation and/or the sharing of production.
Reduced Environmental Impact and Improved Drilling Performance with Water-Based Muds Containing Glycols
Authors: Reid P. I. , Elliott G. P. , Minton R. C. , Chambers B. D. , Burt D. A. 
Published: December 2007

ABSTRACT
Concern over the environmental impact of drilling operations – in particular the disposal of whole mud and contaminated cuttings – is leading to a major reappraisal of acceptable mud types and the way in which they are used. Strict control over the use and discharge of fluids is exercised in, for example, the USA, the North Sea, the Adriatic and the CIS. Government agencies in almost every area of the world are conscious of the potential damage caused by drilling mud and cuttings discharges and are legislating accordingly.
In addition to these legislative pressures, increasing demands are placed on fluids as the industry drills more extended reach, horizontal and high temperature/high pressure wells. These new challenges are in addition to existing ones – such as the need to control reactive shales, provide good fluid loss control and minimise formation damage – which remain critically important to the success of a well.
Given these requirements asked of the fluid, many operators are convinced of the benefits of continuing to use oil based mud (OBM). Hence the industry, including companies such as BP, is committing considerable resources to developing ways of using OBM which comply with good environmental practices. These methods, such as cuttings cleaning and cuttings injection, are discussed by Minton, 1992 and Minton, Begby et. al., 1991.