bluuebunny/crossref_metadata_2025_split huggingface dataset:
Texaco''s Expanded Bonnie Glen Solution Gas Processing And NGL Fractionation Facilities
Authors: Eastlick B.K. 
Published: March 2010

Introduction
When Texaco Canada Resources Ltd. opened the $40 million addition to its Bonnie Glen gas processing facHities in June 1982, the three-plant complex located 80 km southwest of Edmonton, became one of Canada's largest natural gas liquids producers. The new Bonnie Glen Solution Plant No.2 can handle 1.4 million cubic metres of gas a day, including a 2780 cubic metre a day fractionation train. The new solution gas processing plant was completed on time and on budget under an engineering, procurement and construction turnkey contract.

The Oilfields
Texaco's Bonnie Glen complex serves two of Canada's most prolific oilfields, Wizard Lake and Bonnie Glen, discovered within a year of each other in the early 1950s.
The Wizard Lake oilfield, about 11 km north of the Bonnie Glen Gas Plant, has an original oil-in-place of 61.2 million cubic metres and has been under pressure maintenance since 1969. The Wizard Lake Miscible Flood is one of the largest and most successful enhanced recovery projects of its type in the world. The project increased the field's recoverable oil by 11 million cubic metres to an estimated 84% of the original oil-in-place. Over the years, some 4.4 million cubic metres of LPG solvent has been injected into its miscible slug. The field, 100% owned by Texaco, can produce up to 8700 cubic metres of oil per day.
The Bonnie Glen find differed from Wizard Lake because it had an original primary gas cap overlying the 119 million cubic metres of oil-in-place. This pool, 74% Texaco owned, is not under pressure maintenance. However, ultimate recovery is still expected to be 71% of the original oil-in-place with a production capability of 1300 cubic metres a day. In 1975, the gas cap was unitized and a cycling scheme was brought on-line which has successfully minimized retrograde losses and improved ultimate pool recovery by 4.3 million cubic metres.

The Processing Complex
The Bonnie Glen gas processing complex today includes three facilities: two solution gas plants, Nos. 1 and 2, each with a 1.4 million cubic-metre-a-day capacity and a cycle plant which has a 3.9 million cubic-metre-a-day capacity to extract natural gas liquids as part of the gas cap cycling project (Fig. 1).
The original Bonnie Glen Solution Plant No. 1 came into operation in 1954 with the capacity to handle 790 000 cubic metres of gas a day. It was one of the first gas plants built in Alberta, installed at that time for conservation purposes. Plant No.1 had five integral compressors, a mine sweetening and ambient temperature lean oil absorption systems and a fractionation facility.
By 1969, the plant's rated capacity was increased to 1.4 million cubic metres a day through a series of improvements which included the addition of compression, a propane refrigerated gas fractionator downstream of the lean oil absorber and a second depropanizer. Then as now, Plant No.1 extracted more NGL than it could fractionate. The excess raw NGL formed one of the solvent streams injected in the Wizard Lake Miscible Flood.
The Development Of CNG As A Vehicular Fuel
Authors: Buchanan J.J. 
Published: March 2010

Introduction
The development of compressed natural gas (CNG) as a vehicular fuel is leading toward new markets for natural gas.
It takes two things to develop a new market successfully. One is product suitability —your product must be able to do the thing you are claiming it can do. The second is market acceptability —people have to be convinced that they want, and can obtain, that product. The development of CNG as a vehicular fuel will depend on the successful combination of these two elements.

Product Suitability
Let me start with the suitability of the product itself for this intended use. We are now in a time when, because of the rising price of gasoline, a number of other fuels are being proposed as alternatives for vehicular use. Each has its place in the over-all search for ways to reduce Canada's dependence on oil. However, the only fuel suitable for any mass conversion away from gasoline is natural gas.
Four factors combine to make it very suitable —supply; cost to the end-user; the inherent properties of the fuel; and the technology for its application.

Supply
First, supply. Canada has an overwhelmingly abundant supply of natural gas. For the last several years, we have been adding over 5 TCF per year to our proven reserves of natural gas. In 1980, we used 1.6 TCF domestically and exported an additional 1.8 TCF to the U.S., leaving us with a net addition to surplus of about 2.7 TCF. Given markets and reasonable returns to the producer, we can continue to add another 5 TCF a year to our proven reserves-indeed, by 1990, with contributions from the frontier areas, a more realistic figure would be 8 to 9 TCF. Yet by that same date, according to National Energy Board estimates, our domestic market will need less than 3 TCF-even taking into account increased demand following completion of the proposed pipeline to the Maritimes. It is estimated that 0.1 TCF would provide enough natural gas to fuel 500,000 vehicles for a year.
There is a second point to be made about supply. It is one thing to have a reserve of a given natural resource-it is another thing to be able to distribute it economically to the customer. In other words, supply is a matter of both availability and deliverability. CNG also passes the deliverability lest very handsomely.
Natural gas rises up out of the ground. passes through a gas processing plant (usually located right at the field), goes via transmission lines to major distribution networks and is piped directly into homes and commercial enterprises. As most service stations throughout this land already have natural gas lines into the premises, the addition of CNG to their product range requires only one further step: compression. The delivery system is already in place.

Cost
The second of the four factors under the heading of suitability is the cost to the end-user. The cost of CNG to fuel a vehicle for a given distance is only about one half that of gasoline.
Corporate Barter —The Business Of The Eighties
Authors: Sanderson A. 
Published: March 2010

Abstract
OLD FASHIONED and impractical as it may seem, in a world said to be profoundly technological and endlessly complex, barter sounds less efficient than the use of cash and it is. However, barter or counter trade has returned from a state of near non-existence in the early 1970s to a revitalized concept amounting to several billion dollars annually.
All modern economics are based on the ideas that the direct exchange of goods and services is too cumbersome and restrictive. Hence the use of money.
At first, money worked well. Its value was the direct consequence of productive effort and with it the artisan could make his products and would not have to wait until someone came along with some food stuffs to ply his trade. Throughout history, governments have controlled money and have tried to use it to make an unearned value. At first rulers would shave the edges off coins to make up the unearned value. Governments more recently have tried to print more currency to solve their economic problems, and have met with disastrous results.
Governments, whether they be communist or capitalist, control the supply of money rather than have money produced as a consequence of productive effort. Currencies therefore have become deflated and are not precisely redeemable for anything concrete.
Countries and companies still use cash as the major medium of exchange, but more and more commodities: from oil to land, wheat to gold are becoming the real "hard" currencies, everywhere rising in value while the value of paper monies steadily decreases.
With the deflation of currencies, and the scarcity of international liquidity, barter has become one of the fastest growing segments of today's business community. The Wall Street Journal reports that 65% of the manufacturing companies listed on the New York Stock Exchange barter as standard business practice. In fact, barter has shown an astonishing growth from approximately 2% of world trade in 1978 to an estimated 20% in 1982.
As banks continue to cut back on their lending to eastern European and developing countries, many countries have turned to barter to conserve cash reserves. Romania, for example, brought barter back dramatically in 1980 with a law saying all trade must be on a barter basis. Poland is using its own barter system to survive a collapsing currency and Mexico is now trading oil to the United States in exchange for products and technology.
Finland has the top growth rate of western countries of the Organization for Economic Co-operation and Development. Counter trade with the Soviet Union is cited as one of the keys to their success. Finns exchange high quality manufactured goods and services for much needed oil. The trade agreement has kept Finnish factories productive while the rest of Europe has slowed.
Major corporations, that at one time would not even consider barter, are now finding it an essential part of their business and are forming counter trade divisions to handle this growing market.
General Electric, the United States" largest exporter, set up its counter trade department in 1979.
Will Reversion Of Deep Rights Lead To A Resurgence In Exploration In Alberta?
Authors: Holubowich F.J. 
Published: March 2010

Abstract
THE CROWN in right of the Province of Alberta, owns the minerals in approximately 80% of the lands in the province. Up to July 1, 1976, when the governing legislation was changed, the holder of a Crown petroleum lease was entitled to rights from the surface to the centre of the earth. Most of the producing fields in the province had been discovered over the 23-year period since the discovery of Leduc on February 13, 1947. Thus the deeper rights were sheltered by relatively shallow productive geologic zones held by relatively few oil and gas companies under leases granted to them for terms of ten or 21 years. Because the legislation then in effect did not compel a lessee to explore all potential geologic formations underlying his lease, the deeper formations tended to remain dormant. The lessee was usually content to produce the shallower zones rather than accepting joint-venture or farm-in proposals from other companies wishing to explore the deeper zones. Under the rules in effect until July 1, 1976, the lessee knew that the shallow producing zones would ensure retention of all rights.
In the large producing fields with deeper zone potential, Pembina for example, the major oil companies, as lessees, diverted their exploration in the late 1960's away from Alberta to the frontier areas, particularly the Arctic. Alberta activities tended to be restricted to development of oil and gas from proven fields. Their departure from Alberta led to an explosion in the formation of many new, but small, Canadian companies who were eager to carry out exploration for oil and gas in the province but could not always get a piece of the action.
The need for amending the Act to provide for a more open land tenure system became increasingly apparent as Alberta entered the 1970s. Departmental officials were besieged with verbal complaints from the smaller companies seeking drastic changes in the legislation to provide for a more rapid turnover of unexplored Crown petroleum and natural gas rights. And these complaints grew in number with the growth of the number of companies.
In the summer of 1973, shortly after assuming his position as Deputy Minister of the Department of Mines and Minerals, as it was then called, Dr. G. B. Mellon commissioned Seaton-Jordan and Associates to study the existing land tenure system. The resulting report triggered a complete review of Part 5 of the Mines and Minerals Act dealing with Crown petroleum and natural gas rights. Initially, only the senior officials in the Department were involved in developing new concepts, but ultimately the Land Committees of both the Canadian Petroleum Association (CPA) and the Independent Petroleum Association of Canada (IPAC) were invited to provide input.
The initial reaction from the CPA, representing the major oil and gas companies, was negative. CPA favoured retention of the existing tenure system as it would continue to preserve the preeminence of the majors in the Alberta scheme of things.
Long March II
Authors: Wong James F. 
Published: March 2010

Introduction
In October, 1934, Mao Tse-Tung led his armies on a 6,000-mile march across China. This gruelling one-year trek known as "The Long March" crossed 18mountain ranges and 24 rivers and was one of the heroic events in China'smodern history that culminated in her liberation on October 1, 1949.
Another trek is now taking place in China - Long March II - the arduousjourney to industrial growth and economic prosperity. And, leadinginternational corporations and businessmen are joining in on Long March II.
China is surviving the current world recession well. Where other countriesare foundering under enormous debt loads, China remains virtually debt free.Intensely competitive foreign suppliers of goods and services are beating apath to her doors thus ensuring a huge storehouse of products at bargainprices.
"China is a tough market" say both experienced and novice China watchers andtraders. And yet, the hotels of Beijing (Peking) are crammed with businessmen, year round, all hoping to close deals with this stirring giant. Think of onebillion people in an area slightly smaller than Canada, all eager for theimplementation of policies to improve their standard of living. The growingawareness and demands of one-quarter of the world's population for food, shelter and consumer goods is staggering.
Directly related to the desire for an improved standard of living is thedemand for energy and China's ability to develop her energy resources in stepwith this growing demand. Over the next 20 years, a World Bank study estimates China will spend $420 to $480 billion to develop its energy infrastructureincluding offshore petroleum exploration and production, onshore enhancedrecovery, oil and gas pipelines, coal mining facilities and hydro-electric andnuclear power stations.
The Esso Caisson-Retained Island Data Acquisition System
Authors: Der C.Y. 
Published: March 2010

Abstract
In the fall of 1983, Esso Resources Canada Limited will construct a Caisson-Retained Isiand (CRI) at Kadluk 0–07 in the Beaufort Sea. Upon completion of this new island, a $2 million instrumentation system developed by the Esso Research Department will be put into operation to gather environmental and performance data.
Approximately 300 sensors will monitor the island's structural and geotechnical responses to the environmental forces. These sensors will be connected to a network of data acquisition subsystems controlled by three distributed computers. The data collected will be used to add to the safety of operations on the island. It will also allow Esso to optimize the design of future Beaufort Sea offshore structures, and will extend our insight into the environmental conditions in this area.

Background
Esso Resources Canada Limited has been very active in Beaufort Sea exploration for more than a decade4 During this time, Esso has pioneered the design and construction of sacrificial-beach, artificial islands (eighteen to date). Recently the lack of local (Western Beaufort) sources of fill materials having good soil propeties, and the poor economics of long haul distances have directed Esso's ongoing research toward alternative artificial·island technologies. This led to the development of Esso's first Caisson-Retained Island (CRI).
Figure I shows the complete ring of linked, steel caissons which will form the outer perimeter of the island. The ring is made up of eight caissons each weighing approximately 50,000 kN (5000 tons) when fully ballasted. The caisson ring is set down on a prepared subsea foundation (berm) and the interior of the ring is filled with dredged sand. This type of island has the advantage of requiring significantly less sand fill as compared to sacrificial-beach islands. In addition, the caisson ring can be disconnected and moved to other locations for re-use.
Simultaneously with the design and construction effort of the CRI, the Esso Research Department designed an extensive $2 million instrumentation system for the island. This system is currently in its final development stage and will be operational by the fall of 1983 when the CRI is installed at its first location. The entire instrumentation program for the CRI is expected to require a commitment of eight to ten man-years over the next three years.
The requirement for an instrumentation system was identified early in the CRI project to accomplish the following:ADD to the safety of island operations;OPTIMIZE the design of future caissons, or other Arctic structures; andSUPPORT Arctic research studies using the caisson island as an observation platform:
To achieve these objectives, the system was designed to collect data on key environmental and CRI performance parameters, such as:local and, global ice forces;ice sheet and rubble movements;geotechnical forces and" movements;caisson stress and movement;wind and current velocities; andwave heights.
Financing Oil, Gas And Coal Projects
Authors: Peterson R.B. 
Published: March 2010

Abstract
THE GOOD NEWS is that recovery, albert slow, is underway in the Canadian petroleum industry.
Earnings at last are starting to recover. Indeed, the percentage increases from the disastrous levels of the last few years are impressive. They are going to look big in the headlines-and that could be the bad news.
It's a fact of life that Canadians are distrustful of profits-especially those made by oil companies. So our industry should be prepared. It won"t be easy to gel attention (at least until those headlines on profits appear) because Canadians are no longer interested in energy issues. They want attention focused on matters they consider far more critical-the worst unemployment levels since the Depression.
When I make these statements about public attitudes, I am Quoting research reports by some of the best people in the survey business. They tell us Canadians now have little or no worry of Canada suffering future energy shortages. They tell us Canadians still see multi-national companies taking huge profits out of the country, with little or no benefit to Canadians in terms of investment and jobs.
So we have our work cut out for us. We must show skeptical Canadians that they have a false sense of energy security. Despite the current glut at the gasoline pumps, the fact of the matter is that our country is running short or conventional reserves of oil: the present reserve life is about 12 years. Industry is only able La replace 15 per cent of the oil that's being withdrawn from conventional reserves each year.
So where can we turn? Either we continue to increase imports of oil from unstable sources-whose own reserves are also depleting. Or else we turn to the Arctic and the Atlantic, those Canadian Frontiers which have been very stubborn about releasing their secrets, and to the Alberta oil sands.
That's the energy side of its current sources of oil are depleting; we have to develop new ones. And that brings me to the profits.
One encouraging aspect of the research on Canadian attitudes is finding that the people recognize the petroleum industry as a potential major contributor to national economic recovery. They also want Industry to be permitted to "get on with the job."
What's needed to "get on with the job"? The answer is in just three words: restore investor confidence. Investors must see acceptable" returns on prior investment before they"ll seriously consider future investments.
In recent years, earnings in our industry have provided a return as low as one per cent on capital assets. So much for those huge profits! You could do at least 15 Limes better by pulling money in Canada Savings Bonds. To finance the minimal expansion which it was undertaken, the industry has had to borrow heavily.
But at last, things are improving. Governments have begun to realize that they had tried to share in too much, too fast, and they are easing off. Industry is also working very hard to increase efficiency and productivity.
A Mechanism For Initiation of Bitumen Displacement From Oil Sand
Authors: Takamura Koichi , Chow Ross S. 
Published: March 2010

Abstract
According to an oil sand structure recently proposed in this laboratory, connate water in high-grade oil sand appears in at least two types of configurations: as pendular rings at grain-to- grain contact paints, and as a roughly 10 nm thick film which covers the sand surface.
The aqueous film exists due to the double layer repulsive forces between the bitumen and sand surfaces. The study has now been extended to include a theoretical model regarding the separation of bitumen from oil sand aggregates immersed ill aqueous solutions. The model describes the displacement mechanism in terms of the capillary forces at the bitumen/aqueous interface, the viscous drag of the bitumen and the stability of the aqueous film on the sand surfaces. The model successfully explains the observed results of the crumble test;a high rate of crumbling on an oil sand pellet was observed in a NaOH solution, but the presence of Ca++ caused a dramatic decrease in the effect of NaOH. The theory was further confirmed by a microscopic disintegration experiment. Here the bitumen displacement from individual sand grains was observed and video-recorded under a high resolution optical microscope.

Introduction
The previous paper(l) dealt with an accurate description of the microscopic structure of in-situ Athabasca oil Sand; especially the manner In which connate water and bitumen are distributed in the void space between the sand grains.
In-situ, the sand grains occupy roughly 65% of the total volume. In the case of high-grade oil sand, the pore space is filled with bitumen and water. The water occupies between 10 and 15% of the pore volume and forms pendular rings at the contact points between the sand grains. These pendular rings (bulk aqueous phase) cover roughly 30% of the sand surface and the remaining 70% of the surface is covered by a thin film of water (film aqueous phase), which connects the bulk aqueous phase. The thickness of this aqueous film is of the order of 10 nm. In lower-grade oil sand, clusters of fine particles exist within the framework formed by the coarse sand grains. These clusters of fine particles are saturated with water. Thus the amount of connate water in oil sand increases linearly with increasing fines content. The main features of the structural model of the Athabasca oil sand described above are schematically shown in Figure 1.
Theoretical considerations demonstrated that the aqueous film has been held in place throughout geological times due to the double layer repulsive forces between the negatively charged sand and bitumen surfaces. Recently, similar analysis was also reported by A.C. Hall et al(2,3). It has long been recognized that the presence of the aqueous film is the single most characteristic and fortunate feature of the Athabasca oil sands(4,7). Without this aqueous film or the hydrophilic nature of the sand, the hot water extraction process of bitumen would not work. The above model provides good grounds for the existence of this aqueous film.