East Coast Offshore Research Articles

Thermal history modeling of the Georges Bank, U.S.A.: thermal inversion of transmittance color index (TCI) and vitrinite reflectance (VR) data

Using a one-dimensional basin analysis model for the COST G-2 well in the Georges Bank area, offshore East Coast, U.S.A., thermal inversion of measured Vitrinite Reflectance (VR) data and of the Transmittance Color Index (TCI) converted to an equivalent VR value yielded essentially identical paleoheat flux variations with time. The paleoheat flux showed two peaks at ∼175 Ma BP and at 125-75 Ma BP. The earlier event corresponds to continental breakup and the beginning of the rift phase. The latter event corresponds to continued drifting of the continents and formation of new oceanic basement. Beside answering some important tectonic questions, the observations corroborated the theoretical and empirical connections between TCI and VR found for the G-2 well and for other wells in different geological settings. This fact, together with the fact that TCI measurements on physically amorphous organic material can be made on rocks devoid of vitrinite or spores and pollen (carbonates, pre-Late Silurian rocks, and siliceous black shales), should promote the utility of TCI as an effective geothermal history indicator.

Oil and Gas Developments in Eastern Canada in 1989

Exploration activity in Canada's east coast offshore region declined dramatically in 1989. Just 2 wells were completed during the year, both located in the Newfoundland offshore, 1 of which resulted in a new significant discovery of natural gas and oil. As a result of this discovery and revisions of previous estimates, the best current estimate of discovered resources in the east coast offshore is 258.9 million m3 (1.6 billion bbl) of oil and condensate, and 313.4 billion m3 (11 tcf) of gas. Eight new exploration licenses were issued in 1989, divided between the Sable Island area and the Jeanne d'Arc basin offshore Newfoundland, suggesting a possible increase in activity in the next 3-4 years. Lasmo announced plans in 1989 to develop the Cohasset and Panuke light oil pools west of Sable Island. It is hoped that production can begin in 1992. The Canada-Nova Scotia Offshore Petroleum Board was established in early 1990 following proclamation of the Canada-Nova Scotia Offshore Petroleum Resources Accord Implementation Act. The board is responsible for regulation and management of all Nova Scotia offshore petroleum activities. Activity in Ontario decreased significantly in 1989 with drilling completed at a total of only 100 wells. The decrease is attributed to the termination of CEDIP, and to low oil and gas prices received by Ontario producers during 1988. Drilling of Ordovician targets, however, decreased only marginally from 1988 and dominated activity in the province, accounting for nearly half of all exploratory and development drilling in 1989. Drilling of Ordovician targets resulted in 14 new oil producers, including 1 new-pool discovery. New production from recently developed Ordovician reservoirs resulted in a 29% increase in annual oil production in Ontario in 1989. Production totaled approximately 244,000 m3 (1.5 million bbl), a new record for annual oil production in Ontario. he previous record was established in 1966. There was a large increase in geophysical exploration and area held under oil and gas licenses and leases in Quebec in 1989. Several companies were active in the province.

North American Drilling Activity in 1988

This is the 53rd consecutive annual report on drilling activity for the United States. Canadian drilling data have been included with these annual reports since 1948; Mexico provided data for the period 1948-1980. For 1988, Canada showed a 25.5% increase in total wells drilled (8,886 wells) and an 18.1% increase in the amount of footage drilled (33,497,448 ft). The 66 new-field wildcat discoveries represented a success rate of 30.4%. Of these discoveries, 26 were in Alberta, 20 were in Saskatchewan, 16 were in British Columbia, 2 were in Quebec, 1 was in the Northwest Territories, and 1 was in the East Coast offshore. New-field and new-pool wildcats accounted for 33.4% of the 1,642 exploratory discoveries. In Canada, 55.6% of the 2,953 exploratory wells drilled were successful. In the United States, total drilling activity during 1988 increased 1.1% (to 36,307 wells), and footage drilled increased 4.8% (to 31,919 mi) compared with 1987. There were 469 new-field discoveries--a 7.3% decrease from 1987. The ratio of new-field dry holes to producers was 6.38:1, and the success rate was 13.6%. Estimates of ultimate reserves reported as discovered in 1983-1988 in the United States are being reviewed by the Joint Task Group on Statistical Integrity of the Committee on Statistics of Drilling. Results of this study will be published in a later issue of the Bulletin.

Oil and Gas Developments in Eastern Canada in 1988

Exploration activity on Canada's east coast offshore region continued at a steady rate in 1988. A total of 10 wells were active: 1 exploratory well offshore Nova Scotia, and 5 exploratory wells and 4 delineation wells offshore Newfoundland. The highlights of 1988 were Mobil's discovery of a new gas and condensate pool south of Sable Island offshore Nova Scotia, and successful delineation drilling results offshore Newfoundland by Petro-Canada at Terra Nova and by Husky Oil Operations at Whiterose. Based on these successes, the estimates of discovered oil and gas resources for the region have been revised upwards to 235 million m3 (1.5 billion bbl) of oil and condensate and 309.4 billion m3 (10.9 tcf) of natural gas. A significant step was made toward development of the Hibernia oil and gas field with the signing of a Statement of Principles by the governments of Canada and of Newfoundland and Labrador with Mobil Oil Canada and its partners. Also Petro-Canada is undertaking a preliminary engineering study to evaluate alternative development scenarios for Terra Nova field. Studies are also in progress on possible schemes to develop the several natural gas discoveries and the 2 small oil discoveries in the Nova Scotia offshore. Legislation required to implement joint federal-provincial resource management offshore Nova Scotia has been passed by the Canadian Parliament and the provincial legislature and will likely be proclaimed in 1989. At that point, a new resource management board will assume responsibility for the Nova Scotia offshore. This arrangement is identical to that established in the Newfoundland offshore in 1987. The future looks bright for the East Coast given the stable resource management regime, the regular schedule of rights issuances, and the large remaining potential. Steps to development of the best of the discoveries will lead to an increase in the pace of exploration in the early 1990s. Activity in Ontario in 1988 was at its highest level since 1980, with drilling completed at a total of 188 wells for an aggregate length of nearly 107,000 m (350,000 ft). Activity was paced by a record amount of drilling of Ordovician targets, as interest in this very successful play continued to increase. Drilling of Ordovician targets was reported to be complete at 25 exploratory wells, 15 development wells, and 2 stratigraphic tests, resulting in 21 new oil producers and 4 gas producers. Oil production in Ontario increased dramatically in 1988, due entirely to production from new Ordovician reservoirs discovered since 1983. Production totaled approximately 190,570 m3 (1.2 million bbl) compared to 135,635 m3 (853,000 bbl) in 1987. Further production increases a e expected in 1989. Activity in Quebec in 1988 was concentrated in the Basse-Terres region near Trois Rivieres in the St. Lawrence lowlands, and on Anticosti Island. Five exploratory wells and 6 natural gas storage wells were drilled. Two of the exploratory wells resulted in discovery of an accumulation of natural gas in unconsolidated glacial sediments beneath Lake St. Pierre on the St. Lawrence River. There was no drilling activity in onshore portions of Prince Edward Island, Nova Scotia, New Brunswick, or Newfoundland in 1988.

Canadian Natural Gas Industry An Overview

Abstract The Canadian natural gas industry has undergone a transition from near total government control to a "Free market" system of direct negotiations between buyers and sellers. Complete deregulation of natural gas prices became effective on November 1, 1986; however, partial regulation of market access remains in place. The transition has occurred during a period of significant oversupply in the North American market coupled with dramatically reduced commodity prices for competing energy sources. As a result, there has been severe competition for the markets causing substantial downward pressure on prices to the consumer as well as on the gas sales by the traditional marketers. Introduction This paper provides a brief review of the current Canadian natural gas resource base as well as recent industry activity including the following:Existing supply sourcesDrilling activityHistorical Canadian natural gas salesurrently contracted reservesShut-in reservesSpecific purchaser considerationsTrans Canada Pipelines LimitedAlberta & Southern Gas Co. Ltd.Supply/demand projections. As Alberta accounts for 85% of Canada's conventional natural gas reserves, the detailed discussion will be limited to Alberta's reserves. However, the conclusions drawn are deemed to be applicable to Canada's total conventional natural gas industry. A variety of data sources have been accessed to develop the analysis presented herein, each with varying effective dates. In all cases, the most recent data available from each source has been utilized. Where only partial year data was available, full year values have been estimated by the author. Existing Supply Sources The National Energy Board(l) (NEB) has estimated Canada's remaining established natural gas reserves at December 31, 1985 to be 95 exajoules (2557 109m3 at 37.4 MJ/m3); Table 1 summarizes the NEB reserve estimates by region. The NEB does not currently book any eastcoast offshore reserves due to concern regarding the economic viability of the area. As the frontier reserves currently account for only 18% of Canada's remaining established reserves and production is not forecast by the NEB to commence until the mid-1990s, this analysis will be restricted to the conventional producing areas. Figure 1(2) presents an historical summary of NEB's estimates of Canada's remaining conventional reserves, with 1985 marking the third consecutive year in which new discoveries have failed to replace production. Alberta is the dominant source of conventional natural gas in Canada both in terms of reserves (85%) and production (86%). Therefore, the following discussion of currently available supply will be limited to Alberta. Figure 2 presents Alberta's historical remaining established reserves of marketable natural gas as determined by the Energy Resources Conservation Board (ERCB)(3). As would be expected, the remaining established reserve profile is consistent with the NEB's data for total Canadian reserves. It is worth noting that 1983 was essentially the first year on record in which reserve additions failed to match production with 1986 marking the fourth consecutive year in which the industry has failed to replace production in Alberta. Over-all, Alberta's remaining established reserves have declined over seven percent since 1982.

Oil and Gas Developments in Eastern Canada in 1987

Exploration and development activity in eastern Canada continued at a moderate pace in 1987. In the Canadian east coast offshore region, drilling was completed at 5 exploratory and 3 delineation wells, drilling was suspended at 1 well, and drilling was in progress at year end at 1 well offshore Newfoundland. No new discoveries of oil or gas were made, but drill-stem tests were very successful at the 3 delineation wells, confirming the extent of reserves on previous discoveries. An extended drill-stem test of 1 of these wells, Panuke F-99, resulted in the first shipment of oil from an east coast offshore discovery, and also served as a test of possible commercial production techniques for small offshore oil pools. Discovered resources in the region, on a best current-esti ate basis, are now estimated at 203.9 million m3 (1.3 billion bbl) of oil and condensate and 307.3 billion m3 (10.9 tcf) of natural gas. In Ontario, 104 wells were drilled in 1987 (43 exploratory, 32 development, and 29 service). The exploratory drilling resulted in 17 new discoveries (6 gas and 11 oil). Exploration for Ordovician oil reservoirs continued to be the highlight of activity in the province in 1987. Seventeen wells were drilled to Ordovician targets with 10 wells completed as oil producers and 1 as a gas producer. The 65% Ordovician success rate was a dramatic improvement from the 19% success rate of 1986. Oil production in Ontario remained constant at 135,653.3 m3 (853,119 bbl), and production of natural gas declined by 4% to 511,171 million m3 (18.04 tcf). Eight wells were drilled in Quebec in 1987. No new discoveries were reported at the 7 exploratory wells. One development well was successfully completed as a gas producer in a test of an abandoned gas reservoir in unconsolidated sediments in the Louisville area southwest of Trois Rivieres. Gas production from St. Flavien field increased to 16.666 million m3 (588 mmcf) from 13.95 million m3 (493 mmcf) in 1986. There was no drilling activity in onshore portions of Prince Edward Island, Nova Scotia, New Brunswick, or Newfoundland in 1987. Production from Stoney Creek field in New Brunswick declined to 495 m3 of oil (3,113 bbl) and 1.737 million m3 (61.34 mmcf) of natural gas.

Canada's East Coast Offshore Exploration And Development

Abstract Canada's east coast offshore continental shelf is extensive and has excellent oil and gas potential. Numerous Mesozoic sub-basins have been explored, and the principal targets are Late Jurassic to Early Cretaceous clastic reservoirs found in a variety of plays and trapping modes. Exploration activity has only taken place over the past 20 years, with approximately 250 wells drilled. Some 41 discoveries have been made containing an estimated total recoverable resource of about 1.3 billion barrels of oil and 10.0 TCF of gas. The Hibernia oil discovery, offshore Newfoundland, and the Venture area gas Discoveries, offshore Nova Scotia, are the accumulations most likely to be developed in the near future. Introduction This paper gives a generalized overview of the geological setting, the exploration history and the hydrocarbon development potential of Canada's east coast offshore. There have been several excellent papers written over the past 15 years describing Canada's east coast offshore geology. This paper attempts to summarize the major findings of these earlier works in a generalized overview. Although references are not quoted, readers are referred to a recent publication by Grant, McAlpine and Wade (AAPG Mem. 40, 1986, pp. 177–205) for an excellent geological synthesis of the Atlantic offshore margin of eastern Canada. The subject area (Fig. 1) encompasses the offshore continental margin of Atlantic Canada from northern Labrador to southern Nova Scotia, a distance of over 3500 km. The continental shelf out to the 1000-m isobath covers a vast area readily drillable with modern technology. This accessible shelf can be subdivided into four regions, each with its unique physiographic setting, underlying geology and exploration history. These are the Labrador Shelf, the northern Grand Banks/northeastern Newfoundland Shelf, the southern Grand Banks and the Scotian Shelf. Common to each of these areas is a wedge of Mesozoic/Cenozoic sediments that expands seaward from a zero edge to thousands of metres in thickness in specific Mesozoic sub-basins or depocentres. These Mesozoic sub-basins or "thicks " tend to be elongated, fault controlled and separated by basement-cored shelf areas or arches. The Mesozoic sub-basins have been the focus of exploration activity, and are the areas where practically all the significant discoveries have been made. Surrounding the sub-basins, structurally monotonous shelf areas and arches are covered by a much thinner veneer of Mesozoic sediments and are only marginally prospective. Offshore areas such as the Gulf of St. Lawrence, Bay of Fundy and Baffin Bay have been less intensely explored and are only briefly mentioned. The petroleum industry has been seriously exploring the east coast offshore for only the past 20 years. During that time there have been approximately 250 wells drilled and over 800 000 km of seismic shot. This has resulted in a tremendous increase in the geological understanding of the area. The discovery of significant accumulations of oil and gas has confirmed its hydrocarbon potential. Canada's east coast offshore is, however, an extremely hazardous and costly frontier in which to explore. The rewards have not always justified the finding costs and interest and activity levels have fluctuated over the past two decades.

Oil and Gas Developments in Eastern Canada in 1986

Exploration and development activity in eastern Canada had a dramatic decline in 1986, especially in the offshore regions of the east coast, and Lake Erie in the province of Ontario. Reasons for the decline include the current depressed prices for oil on international markets, the termination of the Canadian government-sponsored Petroleum Incentives Program, and completion of exploratory drilling required to validate exploration agreements on the east coast offshore. In addition, uncertainties connected with deregulation of the Canadian natural gas industry had a major negative effect on exploration and development of natural gas in Ontario. In the Canadian east coast offshore region, drilling was completed at 10 exploratory wells and 6 delineation wells, drilling was suspended at 1 well, and drilling was in progress at another well at year end. Three new discoveries were reported: 1 gas and 1 oil discovery offshore Nova Scotia, and 1 oil discovery offshore Newfoundland. Discovered resources in the region are currently estimated at 198.6 million m3 (1.25 billion bbl) of oil and condensate, and 297.4 billion m3 (10.5 tcf) of gas. In Ontario, a total of 113 wells were drilled in 1986: 60 exploratory, 29 development, and 24 service wells. Only 4 wells were drilled in Lake Erie, compared to 75 in 1985. Forty-five percent of the exploratory wells and 83% of the development wells were successfully completed as oil and/or gas producers. Oil production increased substantially for the second year in a row, to 135,816 m3 (854,257 bbl), compared to 112,953 m3 in 1985. The increase in 1986 was again due almost entirely to new production from Trenton-Black River carbonate rocks of Ordovician age. Production of natural gas declined by 10% to 532.435 million m3 (18.8 bcf). Only 9 wells were drilled in Quebec in 1986, compared to 23 wells in 1985. These consisted of 4 development wells, 4 service wells, and 1 exploratory well. Gas production from Saint Flavien field increased marginally to 13.95 million m3 (492.5 mmcf). In New Brunswick, 1 exploratory well was drilled in 1986, and it was abandoned without encountering any hydrocarbons. Production from Stoney Creek field totaled 640 m3 (4,025 bbl) of oil and 1.822 million m3 (64.3 mmcf) of natural gas. There was no drilling onshore Newfoundland, Nova Scotia, or Prince Edward Island in 1986.

WIND SPECIFICATION FOR SPECTRAL OCEAN-WAVE MODELS

This paper investigates the utility of winds obtainable from a numerical weather prediction model for driving a spectral ocean-wave model in an operational mode. Wind inputs for two operational spectral wave models were analyzed with respect to observed winds at three locations in the Canadian east coast offshore. Also, significant wave heights obtainable from the two spectral models were evaluated against measured wave data at these locations. Based on this analysis, the importance of appropriate wind specification for operational wave analysis and forecasting is demonstrated.

Offshore Reservoirs--A Different Engineering Approach Is Required

Abstract An increasing number of Canadian companies are becoming involved in East Coast offshore exploration. This exposes more petroleum engineers, for the first time in their careers, to the unique complexities of offshore petroleum engineering. Experience in Western Canada has given engineers a well founded knowledge of onshore oil and gas development however, when faced with offshore field assessment this experience often cannot be directly applied. The engineer is faced with relatively familiar engineering problems but in an unfamiliar context. The solutions to these problems are unlikely to be identified intuilively. This paper attempts to identify the different approach required to solving offshore petroleum engineering problems. The cost benefits of sophisticated data acquisition programs, and the need for extensive pre-development engineering are addressed. Introduction Although there is, as yet, no offshore production in Canada there have been a number of significant discoveries which are involving petroleum engineers in field appraisal and development studies. A petroleum engineer whose experience has been obtained in Western Canada should have no major problems in undertaking an evaluation of an offshore reservoir however there are significant differences, which must be appreciated by the engineer. Development constraints dictate that those offshore reservoirs which can be developed are typically large, deep and have high deliverability. Oil reservoirs generally contain medium to high gravity crudes. Such reservoirs may not be familiar to some engineers, however, the differences faced by the engineer relate more to the opportunities for, and importance of, reservoir data acquisition and the level of subsequent interpretation of the data required prior to production start-up. This paper attempts to explain why a different approach is required when evaluating offshore wells and conducting subsequent reservoir studies. It is based on the author's experience of North Sea fields and Western Canada oil and gas operations. There are references to previously published material, produced by engineers involved in the early days of North Sea development in particular. North Sea reservoir developments provide excellent examples of the problems petroleum engineers wilt face in developing East Coast fields. In attempting to demonstrate the differences in engineering approach to offshore fields, there are no new theories expounded but an attempt is made to remind engineers of the principles of reservoir evaluation in order to avoid applying Western Canada experience where it is not appropriate. The paper makes a case for good petroleum engineering practice which is equally applicable to onshore oil and gas fields. It hopefully does not promote over-engineering but attempts to justify the appropriate level of engineering given the impact on the development process. The paper is subdivided into three pans for the readers benefit. A discussion of the principles of offshore reservoir appraisal and development is followed by details of offshore well evaluation and lastly by offshore development planning. There is an emphasis on oil fields in this paper due to the more severe technical problems associated with development on the Grand Banks.

Oil and Gas Developments in Eastern Canada in 1985

Exploration activity in Canadian east coast offshore regions was at a record level in 1985. Drilling was completed at 20 exploratory wells, 6 delineation wells, and 1 relief well. At year end, drilling was still in progress at 2 exploratory and 3 delineation wells. Seven new discoveries were reported: 3 oil discoveries and 1 oil and gas discovery off the coast of Newfoundland, and 3 discoveries of natural gas on the Scotian Shelf. In addition, 2 of the delineation wells encountered significant amounts of oil offshore Newfoundland, and 2 encountered significant amounts of natural gas offshore Nova Scotia on the Scotian Shelf. Estimated resources in the 39 offshore discoveries made to the end of 1985 are 205.1 million m3 of oil and condensate and 279.8 billion m3 of natural gas. There are currently 66 exploration agreements in effect throughout the region, covering a total of over 16 million ha. Two exploratory wells were drilled in west-central Hudson Bay in 1985. Both wells were plugged and abandoned without testing. In Ontario, drilling activity continued at a steady pace with 192 wells drilled: 67 exploratory wells, 100 development wells, and 25 wells classed as other. Sixty-three wells were completed as gas producers and 24 as oil producers. Oil and gas production in 1985 increased 25.1% and 7.8%, respectively, from 1984, to 112,952.9 m3 of oil and 589,746.6 thousand m3 of natural gas. The increased oil production was due almost entirely to new production from Trenton-Black River carbonates. In New Brunswick, 4 wells were drilled in 1985. Three of these wells are waiting on completion; the fourth, a development well completed in Stoney Creek field, was abandoned as a dry hole. In Quebec, drilling activity increased, as 23 exploratory wells were completed in 1985. Nineteen of these wells were reported as oil shows. Gas production from Saint-Flavien field was reported as 13,489 thousand m3.

Research Into Enhanced Oil Recovery Technologies

Introduction Enhanced oil recovery (EO R) from the conventional reservoirs of western Canada, Ontario and eastern Canada onshore could contribute very significantly to Canada's future domestic crude oil supply. However, this potential in excess of 3600 million m3 (21.6 B bbls), is highly dependent on a broad spectrum of economic and technological considerations and constraints which will require the concerted attention of industry, government and research organizations in order for the nation to fully realize the benefits of this vast resource. The following statistics(Table 1) focus on the essential, indeedcritical role that enhanced recovery has and will have to play in the future to maintain Canadian crude production. This is in the face of diminishing exploration returns in western Canada and the uncertainty in timing of the inauguration of frontier production from the Beaufort Sea. Mackenzie Delta, the Arctic Islands, and the East Coast Offshore region. It is estimated that synthetic crude from bitumen and extra heavy oil will be a major if not dominant crude oil supply source in Canada within 20 years. The Alberta Energy Resources Conservation Board estimated that at the end of 1982, emaining established reserves of crude bitumen were 5.2 billion m3 (32.7 B bbls), while synthetic crude oil remaining reserves were 3.9 billion m3 (24.5 B bbls). Estimates of reserves in Alberta's Cretaceous sands are calculated at 186 billion m3 (1,170 B bbls) and 90 billion m3 (566 B bbls) in the Grosmont carbonates, being equivalent in size to nearly half the combined occurrences of conventional oil reserves in the world. In Saskatchewan, the Department of Energy and Mines estimated about 4 billion m3 (25 B bbls) of heavy oil in place(3). The development of enhanced oil recovery processes applicable to thin, unconsolidated sand reservoirs could mean the recovery of about 635 million m3 (4 B bbls) of heavy oil. Also, applying EOR to conventional oilfields could add about 95 million m3 (600 M bbls) to Saskatchewan's established reserves of 70 million m3 (440 M bbls). The potentialfor the development of EOR technologies is clear and compelling. EOR Methods Enhanced oil recovery is here defined to include all recovery techniques other than those which utilize only the natural energy for the reservoir, (known generally as primary techniques(1)). EOR includes infill drilling, waterflooding or other more exotic methods such as thermal, miscible and chemical processes. The increasing emphasis on enhanced oil recovery is evincing itself in research and development of appropriate technologies by producers, institutional and independent research organizations. One of the latter is Amerigo Research and Development Limited. Other research efforts are underway at the Petroleum Research Institute, Alberta Research Council, and several Canadian universities. EOR processes are sensitive both to reservoir conditions and to rock and fluid parameters. Research programs are directed toward identifying suitable locations for tests of laboratory proven EOR processes for technical feasibility and economic viability. Consistent with these objectives, Amerigo has been active in formulating and field testing of chemical compounds.

Oil and Gas Developments in Eastern Canada in 1984

Exploration activity continued at a brisk pace in Canadian east coast offshore regions in 1984. Twenty-six wells were spudded, and drilling and/or evaluation continued on another 10 wells. Results were 4 oil wells, 7 gas wells, 1 oil and gas well, 10 dry wells, 1 well under a tight-hole status, 1 relief well, and 12 wells continuing drilling and/or evaluation at year end. Twenty-eight exploration agreements were negotiated, 17 of which were between the Canadian Oil and Gas Lands Administration (COGLA) and various oil and gas exploration companies and cover 9.6 million ha. with a commitment to 17 wells. Eleven exploration agreements were between the Canada-Nova Scotia Offshore Oil and Gas Board and the petroleum industry and cover 2.5 million ha. with a commitment to 14 we ls. In Ontario (including Lake Erie), drilling activity declined slightly from 1983 with 200 wells drilled. Results were 54 gas wells, 26 oil wells, 80 dry holes, 12 suspended wells, and 28 wells classified as other (includes 9 stratigraphic tests, 9 natural-gas storage wells, 4 brine wells, 2 disposal wells, 2 water injection wells, 1 re-entry, and 1 LPG storage well). Oil and gas production in Ontario increased 6.5% and 19.3%, respectively, to 90,376 m3 of oil and 548,166 × 103 m3 of gas. In Quebec, 2 of 12 shallow wells drilled were completed as oil producers. Another well was drilled in Saint Flavien field, but it proved to be dry and was abandoned. Production in Saint Flavien field increased 166% to 11,841 × 103 m3 of gas.

Perspective On Canada Lands

Abstract Two and a half years have passed since the Canada Oil and Gas Lands Administration was formed to oversee oil and gas activities on Canada lands and I signed on as its Administrator. We are now at least half-way through the term of most of the new exploration agreements negotiated with companies. These have replaced their previous and existing exploratory permits and leases. Thus this is as good a time as any to take stock of how things are shaping up. COGLA's mandate is to manage all oil and gas activities on Canada lands, an area of approximately 10.2 million square kilometres which includes the Yukon, Northwest Territories, Hudson Bay and east, west and north coast offshore regions. It is carried out under the legislative authority of the Canada Oil and Gas Act and the Oil and Gas Production and Conservation Act. Objectives under federal energy policies include aggressive frontier exploration based on the goal of self-sufficiency in oil by the 1990s, plus the "need to know" the extent of hydrocarbon resources on the Canada lands. A fair opportunity for Canadians to participate in and realize the greatest possible benefits from petroleum activity including employment is another objective. Equally important are the needs to preserve traditional ways of life in communities near oil and gas projects, the serious consideration of northern concerns in the approval of projects, and human and environmental safety. The Government of Canada has also resolved that petroleum activity will not interfere with negotiations involving native land claims. Just what has been achieved so far? Firstly, virtually all existing rights covering some 125 million hectares have been converted to new exploration agreements in accordance with the provisions of the Canada Oil and Gas Act. These agreements. 164 in total, have been approved by Ministers while another 31 remain to be concluded, including 25 in areas of world moratoriums. (87 are in the east coast offshore. 20 in the Arctic Islands; 34 in the Mainland Territories; and. 23 in the Beaufort Sea/Mackenzie Delta region). These agreements have an average term of four years and require the drilling of at least one wildcat well in that time. The 164 exploration agreements announced to date include commitments to drill over 200 wells at a cost of about $8 billion. A number of factors-the Petroleum Incentives Program, work requirements under exploration agreements, and the fact that 50 per cent of the lands must be relinquished during the terms of the agreements, has stimulated an unprecedented level of frontier oil and gas activity which is just now building to a peak. Exploration Over 300 000 km of seismic has been carried out over the past 3 1/2 years. A total of 103 exploratory wells have been drilled, including 22 in 1981, 23 in 1982,33 in 1983 and 25 in the first five months of 1984.

Depositional and diagenetic relatinships between Gulf of Elat (Aqaba) and the Mesozoic of the United States east coast offshore

Depositional and diagenetic relatinships between Gulf of Elat (Aqaba) and the Mesozoic of the United States east coast offshore

Depositional and Diagenetic Relationships Between Gulf of Elat (Aqaba) and Mesozoic of United States East Coast Offshore

The tectonic setting and depositional environments along the ancient margin during the Mesozoic of the East Coast of the United States may have been similar to those in the present Gulf of Elat (Aqaba). The Gulf of Elat (Aqaba) is the northern continuation of the Red Sea rift zone, where carbonates are accumulating contemporaneously with clastics under arid conditions. Clastics are deposited primarily in alluvial-fan complexes which spill out onto a narrow shelf. Carbonate deposits, including reef complexes, occur along the shelf break. In comparison, along the United States East Coast margin, Triassic to Early Jurassic rifting coincided with carbonate and clastic deposition. The Middle Jurassic and Cretaceous strata reflect the transition from synrift to postrift stages f tectonic evolution. Seismic and well data of the Jurassic and Cretaceous sections show an increase in the carbonate content approaching the United States East Coast shelf break. A discontinuous belt of carbonate buildups is inferred along the United States East Coast shelf and slope. The Gulf of Elat (Aqaba) represents an analogous model for the Early Jurassic East Coast margin of the United States. Beginning in the Middle Jurassic, the East Coast shelf-edge carbonate sequences were being deposited on a passive margin. Carbonate growth may have outpaced subsidence and may be similar stratigraphically to the Gulf of Elat (Aqaba) where carbonate deposits are prograding seaward. In the Gulf of Elat (Aqaba), calcium carbonate cementation has significantly reduced the porosity (28%) and permeability (0.01 md) of still-submerged carbonate reefs. However, Pleistocene carbonates on uplifted blocks in the adjacent onshore have undergone leaching and development of secondary porosity as a result of dissolution by meteoric fresh water. The uplifted carbonates contain high secondary porosity (60%) and permeability (10,000 md). Emergent carbonate strata exposed to percolating meteoric waters generally develop such high porosities. In the subsurface, former emergent surfaces are recognized as unconformities; among examples of Mesozoic carbonate reservoirs formed during subaerial exposure and marked by unconformities are the Casablanca (Upper Jurassic, Spain) and Golden ane (Cretaceous, Mexico) oil fields. Unconformities in the Mesozoic carbonate rocks of the United States East Coast suggest that potential carbonate reservoirs (one Jurassic and one Cretaceous) formed during periods of subaerial exposure. Hydrocarbons generated during the Early or Late Cretaceous may have moved into the reservoirs prior to deep burial, possibly inhibiting further subsurface diagenesis, including porosity and permeability changes, and preserving the reservoirs.

The Law Applicable to the Canadian East Coast Offshore

This article examines the current uncertainty as to jurisdiction over offshore oil and gas explorations in Canada and canvasses the solutions other countries have formulated. The author then suggests that the Federal law of Canada should be extended to the offshore with the law of the province adjacent the area incorporated by reference to supplement the Federal law where necessary.

Physical Environmental Monitoring In the Offshore

Abstract A summary and review is presented of certain components of a Physical Environmental Monitoring Program conducted by Mobil Oil Canada, Limited. This program is in support of Mobil's East Coast drilling operations. The various meteorological and oceanographic program components are described with specific reference to the use of the data collected by this monitoring program.to collect, record and transmit data on meteorological and oceanographic conditions; andto assist and advise operational personnel on the various meteorological and oceanographic conditions that affect the performance of rig operations. Introduction Physical environmental monitoring is associated with all East Coast offshore exploration drilling operations. Although this paper addresses, in summary form, some components of Mobil on Canada's Environmental Monitoring Program, the program as presented here is in line with those of other offshore operations and fairly representative. The objectives of such a program are four fold:to monitor, in real time, meteorological and oceanographic parameters that influence on-going offshore operations;to record data that can be used to more accurately model and forecast future meteorological and oceanographic parameters that may influence these operations;to archive data for future potential design considerations; andto obtain and retain government approvals to explore and develop. These objectives, in part, are satisfied by Environmental Monitoring Program components, namely:Offshore Ice/Weather Observer ProgramAutomatic Environmental Weather Station ProgramWave Measurement ProgramCurrent Measurement Program Ice/Weather Observer Program The first program component, the Ice/Weather Observer Program, is the cornerstone for a large portion of this environmental monitoring work. Two trained ice/weather observers are stationed on each Mobil contracted drilling rig on a 24-hour basis. Their basic duties are:to collect, record and transmit data on meteorological and oceanographic conditions; andto assist and advise operational personnel on the various meteorological and oceanographic conditions that affect the performance of rig operations. Depending on the drilling area the rig is in. they may also act as the rig's radio operators. This case applies only to Mobil's drilling operation near Sable Island. Some of the duties of the ice/weather observers are carried out in accordance with practices set down by the Atmospheric Environment Services (AES) of the Canadian Government. However, other duties are specific to an offshore drilling operation and are carefully supervised and monitored by Mobil. The most important function of the ice/weather observer is to make meteorological and oceanographic observations. The observations are called MANMAR measurements; MANMAR stands for " Manual of Marine Weather Observing". Observations are generally made every three hours. They are recorded in a report titled " Selected Ships Meteorological Log", which is supplied by AES. An individual observation entails anywhere from 23 to 44 pieces of information. Figure 1 shows the various parameters measured, observed and recorded on this regular schedule. This includes information on winds, waves, and other weather parameters such as low cloud ceiling, visibility, temperature, barometric pressure, ice and icebergs-just about any weather parameter you can

The Potential For Oil And. Gas Production From Canada''s Frontier Areas

Abstract Introduction The development of Canada's frontier hydrocarbon resources is vital to Canada's future growth and prosperity for several reasons. First, it will help offset the" decline in Canada's' conventional oil reserves. Second, it is necessary if Canada is to become oil self-sufficient. Third, the industrial benefits resulting from development of these northern resources will be extremely significant for many sectors of the troubled Canadian economy. However, the challenges before us related to this development are as formidable as the physical environments in which the reserves are found. The solutions will require creative responses from the petroleum industry, from government and from the Canadian people. This article will outline: the potential oil and gas reserves in Canada's frontier regions; frontier production and transportation options currently under study by Gulf Canada Resources; and some production scenarios and capital investment requirements. The article concludes by summarizing the need for development and identifying issues facing industry that are related to successfully meeting the challenges before us. The Frontier Potential Canada's frontier regions overlie sedimentary basins with an areal extent of approximately 4.5 million square kilometres, and are believed to contain a large hydrocarbon resource base. Two thirds of the Canadain frontiers lie offshore; it is these areas that are thought to contain the majority of resources. The Beaufort Sea and Mackenzie Delta regions have been estimated by Gulf Canada to contain 0.95 billion cubic metres (6 billion barrels) of recoverable oil and 1.4 trillion cubic metres (50 trillion cubic feet) of gas. Since the early sixties in this area, more than 140 exploration wells have been drilled on land, and 30 wells offshore. Crude oil reserves discovered to date nave been estimated at 0.3 billion cubic metres (2 billion barrels) and natural gas at about 0.25 trillion cubic metres (9 trillion cubic feet). In the region of the Northwest Territories excluding the Mackenzie Delta, we estimate there to be 0.3 billion cubic metres (2 billion barrels) of recoverable crude oil, of which 0.1 billion cubic metres (700 million barrels) have been discovered. Of an estimated 0.14 trillion cnbic metres (5 trillion cubic feet) of recoverable gas, 0.8 billion cubic metres (280 billion cubic feet) have been found to date. Exploration has been ongoing in the Arctic Islands for over a decade. Many important finds have been made, and company estimates place discovered oil and gas reserves at 125 million cubic metres (800 million barrels) and 0.4 trillion cubic metres (15 trillion cubic feet) respectively. Arctic Islands sedimentary basins are expected to contain 0.63 billion cubic metres (4 billion barrels) of recoverable oil and 2.25 trillion cubic metres (80 trillion cubic feet) of gas. The East Coast offshore region is estimated to contain 2.54 billion cubic metres (16 billion barrels) of recoverable oil (Figure in full paper) reserves, and a large reserve base of natural gas-2 trillion cubic metres (71 trillion cubic feet).

Oil and Gas Developments in Eastern Canada in 1981

Uncertainty of increased taxation of petroleum revenues proposed under the Canadian National Energy Program continued to effect a slowdown of exploration in eastern Canada. Nonetheless, exploration of the East Coast offshore increased from 12 wells during 1980 to 17 wells during 1981. Three wells were drilled on the Scotian Shelf, 9 on the Grand Banks, and 5 on the Labrador Shelf. Drilling off the East Coast confirmed an extension to the northeast of the Venture structure, introduced the possibility of another major oil field on the Grand Banks, and indicated that the Avalon basin contains potential commercial oil fields. Other significant results of exploration in the Atlantic offshore were the discovery of oil and gas in rocks of Jurassic age, the discovery of oil on th Labrador Shelf, and completion of the well heralded by Oilweek as potentially the most prolific oil producer in Canada. Offshore drilling in Lake Erie decreased 25% to 95 wells during 1981 compared with 126 in 1980. Offshore exploratory drilling in Lake Erie decreased 62% with 19 wells completed, whereas development drilling remained at the same level of activity as in 1980 with 76 wells being completed. Onshore, 5 exploratory wells were drilled in Quebec, 1 in Nova Scotia, and 31 in Ontario. In Quebec, 4 wells were classed as abandoned and 1 as suspended. The single well drilled in Nova Scotia was classed as dry and abandoned. Onshore exploratory drilling in Ontario decreased by 13% in 1981 compared with 1980. The 31 exploratory wells in Ontario consisted of 1 gas producer, 2 suspended oil producers, and 28 dry holes. Fifty-five development wells, consisting of 33 gas producers, 8 oil producers (including 2 suspended wells), and 14 dry holes were drilled onshore in Ontario during 1981, representing an 8% decrease in the onshore Ontario development class compared with 1980. An aggressive seismic exploration program was conducted by Chevron, Standard, and Irving Oil in parts of Nova Scotia, Prince Edward Island, and New Brunswick. Seismic exploration onshore in eastern Canada consisted of 280.1 km in Ontario, 1,181 km in Nova Scotia, 75 to 80 km in Quebec, 945 km in New Brunswick, and 30 km in Newfoundland. Nova Scotia reported 12,600 km of offshore seismic exploration, Quebec 850 km, and New Brunswick 807 km. Onshore hectares under lease or license were 93,581 in Ontario, 1,739,245 in Quebec, 681,463 in New Brunswick, and 2,478,622 in Nova Scotia. Offshore hectares under disposition were 946,639 in Lake Erie, 29,173,457 in the Gulf of St. Lawrence and Atlantic, 30,585,562 in Hudson Bay, and 13,917,223 in the Labrador Sea. During 1981 compared with 1980, production of oil and gas in New Brunswick declined by 47% and 9%, respectively. In Ontario, oil production decreased 3%, whereas gas production decreased 9%. Gas production in Quebec increased by 20% over that in 1980.