bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simulation Of A Directly Miscible Vertical Dlisplacement Hydrocarbon Solvent Flood
Authors: Bennion D.W. , Stewart B. 
Published: March 2010

Abstract
A simulation of the performance of the hydrocarbon miscible flood in the Rainbow Keg River ‘E’ Pool is presented. The reservoir has been under continuous hydrocarbon solvent injection since June 1972. The direct contact miscible flood is being conducted downward in a maximum oil column of172 m.
A review of the geology, rock and fluid characteristics is given. The pool was produced on primary depletion from July 1966 to August 1967, and shut-in from August 1967 until the solvent injection commenced in 1972. The black oil model history match of the primary depletion and shut-in is presented. The hydrocarbon solvent flood performance was modeled using J.S. Nolen and Associates' Miscible Vectorized Implicit Program. The simulation study provided an estimate for the efficiency of the hydrocarbon solvent flood of the ‘E’ Pool.

Introduction
The Rainbow Keg River ‘E’ Pool was discovered in March 1966. The discovery well penetrated a small biohermal pinnacle reef of Middle Devonian age located in the Rainbow Lake Area of Alberta (Fig. 1).
The pool began production under primary depletion in June 1966 and was shut-in in August 1967. Due to the initial in-availability of miscible fluid the pool was shut-in for 56 months until May 1972 when injection was commenced.
The solvent injection commenced in May 1972. Solvent breakthrough occurred in the two producing wells two to three years later. The third or last well was drilled and completed in ‘E’ Pool in 1978. This well produced solvent immediately even though it was placed in an area of the pool opposite to the two former wells. The field solvent-oil ratio in late 1982 was 650 m3/m3 with a cumulative oil production of approximately 1100 × 103 m3 or 33% of the original oil-in-place (OOIP).
This paper discusses the rock and fluid properties. It also describes the reservoir simulation history match of the primary and solvent injection periods. Following the history match the future performance of the reservoir was predicted.

History
The discovery well of Rainbow Keg River ‘E’ Pool was the 7-18-109-7 W6M well (Fig. 2). It was spudded on 1966-02-22 and drilled to a depth of 2018 m penetrating 172 m of oil-bearing Keg River Reef. The well was completed 89.8 to 83.7 m above the original oil/water contact (AOOWC) in April 1966 (Fig. 3).
The pool went on production in July 1966 and continued until August 1967 when it was shut-in. The production data are shown in Figure 4. The pool produced 51 × 103 m3 of oil with no water. The gas to oil ratio (GOR) was very erratic.
The initial pool pressure was 17 408 kPa at the mid-point of the perforations (MPP) as shown in Figure 5. There were four pressure surveys during the primary production period. The MPP pressure decreased 3524 kPa to the end of the primary depletion. The pressure was recorded eleven times during the shut-in period. The MPP pressure increased 795 kPa during the shut-in period from September 1967 to March 1972.
Is Gasoline Overpriced?
Authors: Cleland N.A. 
Published: March 2010

Introduction
Changes in the price of gasoline cause more concern to consumers than changes in the prices of almost any other item which are purchased on a regular basis. Recent dramatic decreases in the price of crude oil, of which everybody is aware, have not resulted in the same degree of decline in the price of gasoline. Why is this?
The purpose of this paper is to identify who gets what from the price of a litre of gasoline so that one will be able to answer the question "is gasoline overpriced?". First, the most recent results of the quarterly survey of Ontario gasoline pump prices, made by the Petroleum Resources Communication Foundation, will be compared with the survey results in January 1986, when crude prices were at their peak. Then, these current data will be compared with the results in January 1986 for Quebec and Alberta.
To give a broader overview, Canadian gasoline prices will be compared with the most recent information available for prices in the United States (U.S.) and United Kingdom (U.K.). Like Canada, both of these countries are oil producers as well as oil consumers.
The Petroleum Resources Communication Foundation (PRCF) supplied most of the basic data used in this paper. PRCF was formed in 1975 with the objective of increasing public awareness and understanding of Canada's petroleum industry. It is supported by 100 different companies and has established a reputation for providing factual and objective data on the industry.

Ontario Gasoline Prices
In January 1986, Ontario pump prices for regular unleaded gasoline at full-service stations average 53.5 cents per litre, with an average crude oil price at the wellhead of $37.50 per barrel. In the first week of April 1988, pump prices for the same gasoline in Ontario averaged 48.5 cents per litre with an average crude oil price of $20.66 per barrel. The consumers' reaction is, of course, if crude price fen by 45%, why did gasoline only fall by 9%? Is the consumer being treated fairly?
If the breakdown of gasoline prices is examined, then it can be established if the consumer has received the full benefit of falling world oil prices over the last 27 months. How much of the total price is in fact made up of the cost of crude oil?

Gasoline
The price of gasoline is shared as follows:

Dealer Margin
This is the amount charged by the service station operator. In Ontario, this margin varies from station to station with a range from 0 to 10 cents per litre. The average for the four major companies was 3.9 cents per litre in April 1988. It has declined by 0.6 cents per litre since January 1986. All the costs of operating the service station come from this margin of 3.9 cents.

Provincial Tax
This tax varies from province to province, with the lowest tax in Alberta at 5 cents per litre and a maximum of 14.4 cents per litre in Quebec.
Bending Stresses In Otherwise Straight Sucker Rods
Authors: Bellow D.G. , Howe R.K. 
Published: March 2010

Abstract
In many cases sucker rods fail in the upset portion near the pin end. This may be due to bending stresses resulting from lack of straightness in the rod, even though it was manufactured to be within the API Specification 11B. A number of new, unused rod coupling pairs were analyzed for straightness and a model was developed to predict the bending stresses. It was found, that for some rod coupling configurations, there existed bending stresses as high as 68% of the axial stress. This suggests that the API 11B Specification may not be stringent enough.

Introduction
Research into sucker-rod problems has been ongoing for 50 years or more, resulting in several significant improvements in rod-coupling performance. Nevertheless, failures of rod strings continue to be a problem for the oil producer. As down-hole components get older and well conditions become more corrosive this problem will become more severe. However, there are three avenues which can be followed to alleviate the problem:Reduce the loads on rods appropriate to the specific well conditions (dog-leg, etc.) and environment (i.e. apply more stringent design service factors).Replace current rods using materials with improved properties.Improve the current design and manufacturing techniques to eliminate the weaknesses inherent in existing rod strings.
While (1) above may not be practical except under a total replacement program and (2) requires long-term research and careful examination, (3) may provide the most benefit In the short term but, like (1), would only apply to replacement rods and strings.
The purpose of this paper is to describe a problem related to the third category involving the lack of straightness in suckerrods which are made within API 11B Specification(l). It will be shown that non-straight rod ends can lead to undesirable bending stresses near the upset pin-end.

Statement of Problem
For the purpose of this study, a rod end is defined as the length from the pin end to a point 860 mm (34 in.) back towards the rod body. The rod end is defined as non-straight if its centre line deviates from a theoretical centre line with extends through the pin.
To examine bending stresses in non-straight rod ends, a dimensionless bending stress ratio (DB) is dermed as:
Equation (Available In Full Paper)
The dimensionless bending ratio (DB) can be defined in terms of the axial load P, second moment of area I, cross-sectional area A, and y the distance from the theoretical straight line to the rod centre. Thus,
Equation (Available In Full Paper)
In an earlier work(2) it was shown that bending stresses can be determined in rods of uniform cross section with sharp bends in them by considering elementary beam theory where the bending moment M is given by
Equation (Available In Full Paper)
and yo-y = deflection of bar from the unloaded position, EI is the rod stiffness and z the distance along the rod as measured from the pin end.
Injectivity Enhancement In Tar Sands A Physical Model Study
Authors: Sufi Arshad H. 
Published: March 2010

Introduction
Thermal recovery continues to be the most successful tertiary oil recovery technique in use today. The method bas been successful in numerous California heavy oil reservoirs, where heat from the injected steam is used to reduce the oil viscosity in situ, allowing it to flow more easily. The Canadian heavy oil deposits contain oil that is generally more viscous. Consequently, he Canadian heavy oil deposits present additional problems associated with injection and production. The extreme case is tar sands where the initial oil viscosity exceeds 1000 PaS (1 000 000 cp).
An experimental program was developed to investigate the steamflood performance of tar sand reservoirs. This program included the building of a scaled physical model with which to study the various aspects of steam injection into a tar sand reservoir. This was done in conjunction with numerical studies dealing with steamflooding of tar sands. The next section describes the strengths and weaknesses of each type of study.

Numerical vs Physical Simulation
Numerical simulation is based on discretizing a reservoir into finite blocks. Heat and fluid flow between the blocks is governed by equations that are coded into the simulator. These equations and their corresponding approximations have been tested, in general, for lighter oil reservoirs. When extremely viscous oil is encountered, it is not certain that all of the conventional concepts of fluid flow are valid. In a scaled experiment, the predominant forces interact and move fluid and heat independent of equational constraints. This allows the experiment to reveal behaviour which might otherwise go ndetected in a numerical model.
In numerical simulation errors can be introduced due to the size and the number of grid blocks used. These errors have been minimized using various schemes. However, the solutions exhibit fewer problems for mobility ratios less then 50. With heavy oils, the mobility ratio is invariably greater than that, making the solution more difficult and increasing the possibility of errors. A physical model does not have errors associated with grid block size.
The numerical simulator approximates the actual dimensions of the reservoir. The physical model is a scaled-downversion of the reservoir. In scaling down, compromises have to be made regarding a few of the parameters. An example of this is that viscous, gravity and capillary forces cannot be scaled simultaneously in a steamflood model. Any two can be selected for the scaling. In general, capillary forces are neglected. In a numerical simulator, equations for all three of the forces can be programmed into the model.
Experiments with a physical model are time-consuming. For each run, model loading, running and subsequent cleaning can take up to three weeks. A numerical simulator can be used without these delays. Hence, more parameters can be studied using the numerical simulator in a limited time period. The two types of studies can be used interactively. This was considered when making the decision to build a scaled physical steamflood model.
Upgrading Alberta Ngls - Some Preliminary Ideas
Authors: Onn William D. 
Published: March 2010

Abstract
The objective of this paper is to provide an overview as to why Alberta should be looking at NOL (natural gas liquid) upgrading. There are a number of factors in the global NGL environment as well as in Alberta that point to the need to add value. In addition, several approaches to NGL upgrading which have not been commercialized in Alberta or Canada are described. The emphasis will be commercial, not technical, and an attempt is made to put the project in an Alberta context. It should be noted that the projects described are examples only, and that there are a number oj other processes and projects which could add value to Alberta's NOLs. Finally, it must be emphasized that the analysis particularly the economics, should be considered directional and preliminary.

Introduction
There are several trends under way in the industry which may result in excess, NGL supply and pressure on NGL pricing.

Increased Worldwide NGL Availability
Since the late 1970s/early 1980s, many countries, particularly the major OPEC producers, have built facilities to extract NGLs from gas produced in association with oil. Saudi Arabia's "Master Gas System", with capability of approximately 38 000 m3/d of LPG (liquid propane gas), double previous capacity, is a prime example of this development. The facilities were built when OPEC was producing nearly double the amount of oil produced today, and when continued growth was expected. With much lower oil production, significant OPEC NGL extraction capacity, estimated at about 95 000 m3/d of LPG excluding Iran and Iraq, is underutilized. This represents roughly 15% of current consumption. As OPEC oil production increases over time, this capacity will be used to produce additional LPG, whatever the conditions of the market at the time.
One result may be continuing pressure on prices, particularly prices relative to other energy products. The impact of excess LPG production may already be materializing as evidenced by the LPG/crude oil price trend. LPG and crude oil are roughly at price parity on a BTU basis, significantly lower than the approximate 1.2 ratio during the latter half of the 1970s and the 1.1 to 1.5 ratio over the last ten years. While price volatility makes it difficult to be precise about this trend, it does appear that a long-term drop in the ratio is under way.

Reduced Gasoline Volatility in U.S.A.
Because ozone levels in the U.S. exceed legal limits in areas containing over 40% of the country's population, the Environmental Protection Agency (EPA) has proposed to significantly reduce gasoline volatility. The mechanism would be to reduce the gasoline Reid Vapour Pressure (RVP) during the mid-May to mid September period in two steps: a 1 RVP drop in 1989 followed by an additional 1.5 reduction in 1992. This is a significant change in relation to the current RVP average of approximately 11. The easiest approach to reducing RVP is to back out direct blended n-butane from the gasoline pool. While n-butane has a high octane and is relatively inexpensive, it has a very high RVP, approximately 52.
International Trade Implications For U.S.S.R. Sulphur In The 1990S
Authors: Wenzel Werner J.M. 
Published: March 2010

Summary
Major expansions in the processing capacity of natural gas and crude oil are bringing the U.S.S.R. into the forefront as one of the largest producers of recovered elemental sulphur. Annual production capacity for elemental sulphur, oil and gas processing and mining in the U.S.S.R. may be expanding from 5.7 Mt/yr in 1987 to almost 12 Mt/yr by the year 2000.
The U.S.S.R. is preparing to enter offshore export markets. A major sulphur prilling, storage and rail car loading facility is to be built at the large Astrakhan gas plant complex located northwest of the Caspian Sea. Initial annual export capacity of 1 Mt can be expanded to 3 Mt at a later date. An offshore sulphur terminal is planned for a port near Odessa on the Black Sea.
Tenders for prilling, storage and rail car loading facilities were submitted late in 1987. As of this date no commitments to commence construction have been made. Construction and commissioning is estimated to take 1.5 to 2.5 years.
It is currently estimated that the U.S.S.R. could participate in the world market with relatively modest volumes of sulphur by 1991 and increase its presence judiciously thereafter following a build-up of strategic inventories.
In the longer term and about the year 2000, the U.S.S.R. is likely to balance supply and consumption of sulphur in all forms at the 14 Mt level and net exports may be insignificant. The U.S.S.R. is, in the foreseeable future, unlikely to become a major long-term exporter of sulphur.

Introduction
In this paper estimated sulphur production is probed in various forms and estimated sulphur consumption in all forms in the U.S.S.R. to the year 2000.
Long-term predictions about the production and consumption of sulphur anywhere in the world are certain to be incorrect. Like Columbus, the best that can be done, is chart a likely course and correct frequently, using the best information obtainable.
Technological changes related to the manufacture of fertilizers and industrial goods, advances in genetic plant engineering, changes in world weather patterns, fossil fuel energy demands, energy and transportation costs, reservoir behaviour and econopolitical upheavals are only a few of the variables that make predictions indeed a difficult task.

Production of Elemental Sulphur
Production of elemental sulphur in the U.S.S.R. is derived from three sources: desulphurization of natural gas and oil, Frasch mining and open pit mining. Other forms of sulphur are derived mainly from pyrites.
TABLE 1. Estimated supply of sulphur in all forms in the U.S.S.R. (000 tonnes). Available in Full Paper.
Table 1 provides an overview of estimated sulphur supply in all forms to provide a better all encompassing overview that can be compared to sulphur consumption in all forms.
Table 2 gives an overview of the major producing sources of recovered sulphur. Growth in the U.S.S.R. sulphur production can be attributed almost solely to gas and oil processing capacity expansions now under way or planned.
An Overview Of Bank Security For The Oil And Gas Professional
Authors: Laffin Michael J. 
Published: March 2010

Introduction
Initially involvement by banks in the oil and gas industry was limited to production loans. However, in today's climate of mergers, takeovers, megaprojects, relatively low oil prices, and because of the need for external financing, banks are becoming increasingly involved in financing oil and gas undertakings. Therefore, it is incumbent on well-informed and interested engineers and geologists to be aware of what security banks will request before they lend money to an oil company, and the advantages and disadvantages of each type of security. This paper presents an overview of the various types of security that banks request from an oil company before they advance money to that company, in an effort to provide technical professionals with a working knowledge of concepts and documents they may encounter when dealing with banks.
The first section of this paper examines debenture security with a view to explaining what is a debenture, the various types of debentures, and what happens should a borrower default under the terms of a debenture.
Section 177 security is addressed in the second section of this paper. This type of security, while once the only type of security taken by lending Institutions when dealing with oil and gas properties has given way to the debenture and is now used primarily as a corollary to debenture security. Section 177 security raises several questions and has numerous potential uncertainties, some of which will be examined in this section.
In addition to debenture security and Section 177 security, banks often request that borrowers execute assignments that allow a specific revenue stream or several revenue streams received by the borrower to be diverted to the bank. Section 3 of this paper examines a few of these types of assignments.

Debenture Security
In almost every commercial transaction, whether it be a loan by a bank to a company or a sale of shares and/or assets from one company to another, certain basic documentation is used to secure repayment of the loan or the payment of the purchase price for the shares or assets - one of the most fundamental documents used to secure repayment is the debenture.

What is a Debenture?
The broad definition given to the term "debenture" is that it is a written document evidencing the indebtedness of the company issuing the debenture, which is either secured or unsecured and which may be negotiable. A debenture is "secured" if it gives the holder of the debenture a mortgage or other security on the assets of the company issuing the debenture that may be used should the debtor fail to make payment. An "unsecured" debenture is merely evidence of the debt, and upon default by the borrower the lender has no recourse other than to sue on the debenture. A document is "negotiable" if it is legally capable of being transferred by endorsement or delivery, for example, cheques, stocks and bonds, and promissory notes are usually negotiable in that they can be transferred or sold freely and without notice from one corporation or person to another.