Petroleum Exploration Activities Research Articles

Transplanting shrubs for revegetation of salt-affected soils

Vegetation (secondary) succession is extremely slow on soils contaminated with soluble salts by petroleum exploration activities in arid and semiarid areas. Excessive salt accumulations interfere with seed germination and seedling establishment of most species used for revegetation. Establishment and growth of transplanted fourwing saltbush ( Atriplex canescens) seedlings and rooted stem cuttings, and seedlings of oldman saltbush ( Atriplex nummularia), winterfat ( Ceratoides lanata), and prostrate kochia ( Kochia prostrata) were evaluated on three saline-sodic (EC (electrical conductivity) = 23 − 93 dS m -1, ESP (exchangeable sodium percentage) = 13−46%) oil well reserve pits over a three-year period. Survival of fourwing saltbush seedlings from an accession not adapted to saline soils was only 32%, compared with ⩾ 73% for seedlings or stem cuttings from an accession adapted to saline soil. Oldman saltbush suffered 100% mortality subsequent to subfreezing temperatures during the first winter following planting. Survival of winterfat and prostrate kochia transplants was 61 and 48%, respectively, after three years, and growth of these species was acceptable on the saline-sodic soils. Selection or specific accessions of species adapted to the existing conditions of the site to be revegetated appeared most promising for revegetation under extremely harsh environmental conditions.

TIMOR GAP ZONE OF COOPERATION

On 11 December 1989 the Australian Minister for Foreign Affairs and Trade, Senator Evans, and the Indonesian Foreign Minister, Mr Alatas, signed the Treaty to establish a Zone of Cooperation in the Timor Gap.The Timor Gap Treaty is the most substantial bilateral agreement concluded in the forty year history of Australia's relations with Indonesia. The Treaty negotiations have developed a unique regime to allow joint control of petroleum exploration and development activity in Area A of the Zone, the area of joint development. The Treaty encompasses administrative, maritime and fiscal arrangements, customs, migration and quarantine, search and rescue, environmental protection and pollution control, criminal jurisdiction, employment regulation, marine scientific research, health and safety regulations and procedures for settlement of disputes.Work has now commenced to establish the Joint Authority which will be responsible for the administration of petroleum operations in Area A. Contracts in Area A will be awarded by a work program bidding system.

World Energy Developments, 1988

The papers in this issue review significant petroleum and natural exploration and production activities throughout the world, with the exception of the Soviet Union. In addition, papers on other energy minerals have been included. To prepare these papers, well data, land status, production statistics, and geophysical activity information was accumulated from numerous sources, such as foreign and domestic scouting services, foreign and domestic governmental agencies at all levels, industry organizations, oil companies, individual consultants, and local representatives. 1 fig., 1 tab.

Petroleum Exploration and Development in Pakistan

The paper presents an overview of petroleum exploration activity in Pakistan. Drilling activity has been relatively high in recent years and there are grounds for optimism that with further activity, Pakistan could become self sufficient in energy.

ALASKA CLEAN SEAS: MEETING RESPONSE NEEDS FOR 1987 AND BEYOND

ABSTRACT The Alaska Clean Seas organization's spill countermeasures research program continues, with recently completed or ongoing projects addressing spill response chemicals, shoreline habitat protection, bubble barriers, water jet barriers, in situ combustion equipment, and under-ice oil detection. Lack of petroleum exploration activity in the Bering Sea has brought about a decision to place response equipment dedicated for that area in long-term storage. Training schedules have also been adjusted because of reduced activity, but program quality is being maintained. Participating companies continue to enjoy an excellent spill safety record in Alaska, and Alaska Clean Seas has not been required to take part in any actual spill cleanup operations.

Oil and Gas Developments in Australia in 1986

A marked reduction in petroleum exploration and development activity was the direct consequence of the worldwide collapse in the price of crude oil at the beginning of 1986. Drilling in all categories was reduced to a level not seen since 1980, and geophysical activity (except for a dip in marine seismic coverage in 1983) was also at its lowest level since 1980. The downturn also resulted in a heavy loss of human resources to the industry. Most discoveries, albeit small ones, were made in the onshore Eromanga/Cooper basin region, where about half of the 1986 Australian wells were drilled. Offshore, more sizable reserves were indicated in multiple pays of gas and some oil in the Gippsland basin Kipper 1 discovery. Along Australia's North West Shelf, appraisal wells at previous discoveries (Saladin in the Barrow subbasin and Challis in the Vulcan subbasin) have substantiated significant accumulations. The Goodwyn condensate field in the Dampier subbasin, now believed to contain about 200 million bbl of recoverable condensate, will contribute substantial reserves to the nation's inventory as Gippsland basin fields become depleted. An appraisal well in the Palm Valley gas field in the onshore Amadeus basin, drilled directio ally into the axial fracture system of the structure, had an open-flow rate of 137 MMCFGD. This field is now linked by a 1,520-km pipeline to the Northern Territory capital city, Darwin, in the nation's newest pipeline project. With production declining in the Kingfish and Halibut oil fields, the Gippsland basin share of the nation's total oil and condensate production dropped from 86% to 81%. This also reduced the Australian average daily production of crude oil and condensate from the high of 565,000 b/d in 1985 to 515,000 b/d in 1986, even though production of oil and condensate was higher from all other producing areas. Two offshore fields on the North West Shelf came on-stream: Harriet and Jabiru, at modest rates of 8,000 BOPD and 14,000 BOPD, respectively. At year end, contracts were being let to begin an enhanced oil recovery project for the Cooper basin Tirrawarra and Moorari fields.

Utility of Computerized Data Bases of Drill-Stem Test Information in Hydrogeologic Studies: ABSTRACT

The Palo Duro basin, a subbasin of the Permian basin, is being investigated by the Bureau of Economic Geology at The University of Texas at Austin as a potential site for the location of a nuclear waste repository. As the program changes from a regional to a site-specific investigation, it becomes necessary to optimize the expenditure of funds for drilling and testing. Hydrogeologic information is of critical importance in evaluating the long-term stability of a potential repository; consequently, deep multipurpose wells should be drilled in locations that maximize the opportunity to obtain both hydraulic and geochemical data. Prior to our own borehole testing, the only hydrogeologic data available came from petroleum exploration activities, namely, drill-stem test (DST) pressure measurements and brine samples collected with the test. Computer data files of DST information were purchased from commercial sources or obtained directly from operators who had worked in the basin, and the data were merged into a master file. Approximately one thousand tests have been sorted according to geologic formation and lithology. The DST data were then screened and ranked according to their level of confidence based on shut-in pressure characteristics, fluid recoveries, and flowing times. Automatic computer contouring of the selected data produced an unsatisfactory map because of the varied quality of the tests. An objective geostatistical method was subsequently employed to map the regional pressure or hydraulic head distribution in the basin. Geostatistical analysis of the data revealed that a spatial dependency existed which could be modeled by a two-dimensional spherical variogram. The method of kriging was then applied to the data to estimate the regional hydraulic head surface. A chemical equilibrium computer program was used to determine the reaction state of the deep basin flow system, using as input data the chemical composition of the brines collected during drill-stem testing. The program then incrementally added the CO2 lost during collection back into the initial brine composition until it reached the calcite phase boundary. This mass transfer approach results in the computation of the most likely mineral constraints on the brine at measured formation temperatures, pressures, and computed pH conditions. The results of these studies provide interpretations of the regional hydrogeologic processes. Consequently, exploration decisions can be made concerning the location of future test wells to further define the geologic, hydrologic, and geochemical characteristics in this sedimentary basin. End_of_Article - Last_Page 546------------

Recent Foraminifera Around Petroleum Production Platforms on Southwest Louisiana Shelf: ABSTRACT

In the spring, summer, and winter of 1978-79, 673 samples were taken from around petroleum production platforms and control sites on the southwest Louisiana continental shelf to assess the effects of long-term petroleum exploration, drilling, and production activity on marine organisms. The 64,326 living Foraminifera recovered represent 51 species and 35 genera. Standing crops are high (up to 3,294 living Foraminifera per 10 cm2), because of the large quantities of available food supplied by the Mississippi River, and because a wet picking method was used that preserved juvenile and delicate tests. Species diversity is generally low; two species, Nonionella basiloba and Buliminella bassendorfensis, account for nearly 76% of the total population. The species composition varies somewhat with season, water depth, and physical conditions. The statistical analyses show little negative effects of petroleum operations on the benthic Foraminifera of this area. The foraminiferal populations are controlled by the physical parameters of this naturally stressed environment, especially by water depth, temperature and salinity fluctuations, sediment movement, and dissolved oxygen values. Proximity to platforms appears to cause no adverse effects on the organisms. End_of_Article - Last_Page 1433------------

PETROLEUM EXPLORATION IN DEVELOPING COUNTRIES AND CONSIDERATIONS ABOUT ITS FINANCING

Although the rate of petroleum produced per foot drilled is much greater in the developing regions of the world, levels of petroleum exploration activities in the these areas are much lower than in the United States. Although exploration levels in the developing countries might have been expected to rise after the 1973/74 price increase, they actually tended to decrease. Classification of the developing countries in terms of the levels of exploration and development they have attained reveals that the greater part of the area with good petroleum potential (57 per cent of non‐OPEC countries) is comprised of countries where significant exploration has already taken place. There is a need for international assistance to increase exploration levels in the developing countries. A schedule of priorities for various forms of international assistance is suggested.

Petroleum Exploration Activities, Present and Future; A Review

Worldwide petroleum exploration and development activities are moderatly active.Crude oil reserves in the Middle East occupy more than half of world reserves and its role for world petroleum supply is very important in short and middle terms. However, undiscovered petroleum potential in this area is limited, because so much exploration works had been done and many giant fields were already discovered there. Mexican petroleum potential is very big, however future petroleum supply from Mexico is not clear at the present exploration stage in this country. Russia has some shortages in the fields of technology and infra-stracture, therefore it will be not expected that production to raise considerably in future even though the petroleum potential in this country is very huge. Many international oil companies are participating into Chinese offshore petroleum exploration activity.It is general anxious that the petroleum supply worldwide would not be enough for increasing demand in near future. Therefore, the exploration activities in the frontier areas are essential for the human living. The frontier areas include remote areas on-shore, deep waters, arctics and antarctics. Amounts of petroleum distributing in these areas are expected to be immense even though the exploration cost is thought to be expensive.Recovery efficiency from oil reservoirs is generally low, therefore the techniques to increase the recovery are progressevely advancing. The enhanced oil recovery techniques include thermal flooding, carbon dioxide flooding and surfactant/polymer flooding. They are the promising future under the circumstances of raising oil prices worldwide.

Petroleum Developments in Central and Southern Africa in 1978

This review presents developments on petroleum exploration and production activity during 1978 in 45 countries of central and southern Africa. Petroleum was produced in 7 countries with a cumulative production of 851,285,310 bbl (2.33 million b/d), an 8.6% decrease from the 1977 production level. Production increases were reported in Cameroun (93%), where the Ekoundou field went on stream at the end of 1978, and Congo (25%). Ghana recorded its first production from the Saltpond field in October 1978. These increases were offset by larger decreases in Angola (21%), Gabon (6%), Nigeria (9%), and Zaire (20%). Total annual gas production decreased 15% to 510,600 MMcf (1,399 MMCFGD). Surface exploration work increased 34% to 210.75 party-months, including 185.1 party-months of seismic, 13.6 gravity, 10.05 magnetometer, and 2 geology. A total of 252 wells was drilled, an increase of 7 wells (3%) from 1977. Exploratory drilling was 114, the same as in 1977; 48 of the exploratory wells were discoveries, a success rate of 42%. New-field discoveries were reported in Nigeria (22), Cameroun, Gabon, Angola, Chad, Ivory Coast, Congo, Ghana, and Zaire. A total of 66 unsuccessful wildcats was drilled in 10 countries. Development drilling amounted to 138 wells in Nigeria (69), Congo, Cameroun, Gabon, Angola, and Ghana, with a 91% compounded success rate. Total wildcat and development footage was 2,084,694 (635,417 m). At year end 34 rigs were operating.

LEGAL CONTROLS OVER PETROLEUM EXPLORATION AND DEVELOPMENT OFFSHORE WESTERN AUSTRALIA

Increased petroleum exploration and development activities offshore Western Australia will continue to attract the focus of many companies, contractors and investors who will find that their exploration and development activities and operating practices are controlled by a mixed regime of State and Federal legislation. This mixed regime has its sources in international and constitutional law.Working within these controls is not assisted by the complexity of State and Commonwealth jurisdictional problems in respect to offshore areas. Certain governmental arrangements between the State and the Commonwealth, however, facilitate continued exploration activity offshore, whilst some of the legal issues remain to be resolved. Some guiding principles as to what laws apply offshore and to what extent, are indicated.The consultative arrangements between the State and the Commonwealth under the Offshore Petroleum Code allow for Commonwealth ownership and State control of offshore petroleum resources to co-exist. These are commented upon and the Petroleum (Submerged Lands) Acts are analysed with respect to the nature and security of petroleum titles; the setting, performance and variation of work and monetary obligations; the range of administrative discretion in relation thereto; the transferability of petroleum interests and the rate and calculation of royalties.Directions regulating offshore operations generally and covering exploration, reporting, platforms, pipelines, production and work practices are explained. Some of the environmental controls are also mentioned.

Petroleum Developments in Central and Southern Africa in 1977

This review presents developments on the petroleum exploration and production activity during 1977 in 45 countries of Africa. Petroleum was produced in 6 countries with a cumulative production of 930,959,959 bbl (2.5 million b/d), a 3.8% increase from the 1976 production level. Production increases were reported in Angola (41%) and Nigeria (13.5%). Cameroun recorded its first production from the Kole field in November 1977. Slight decreases occurred in Congo, Gabon, and Zaire. Total annual gas production decreased 18% to 604,200 MMcf (1,655 MMCFGD). Surface exploration work decreased 19% to 139 party-months, including 120.22 party-months of seismic, 17.40 gravity, 1.33 geology, and some magnetometer. A total of 245 wells was drilled, an increase of 14 (5.7%) from 1976. Exploratory drilling increased 39% to 114; 43 of the exploratory wells were discoveries, a success rate of 38%. New-field discoveries were reported in Cameroun, Nigeria, Angola, and Gabon. A total of 71 unsuccessful wildcats was drilled in 12 countries. Development drilling amounted to 131 wells in Nigeria, Congo, Gabon, Cameroun, Ghana, and Zaire, with a 94% compounded success rate. Total wildcat and development footage was 1,948,016 (593,757 m). At year end, 39 rigs were operating.

Appraisal of Present Petroleum-Exploration Activities in Philippines: ABSTRACT

Appraisal of Present Petroleum-Exploration Activities in Philippines: ABSTRACT

Petroleum Developments in Central and Southern Africa in 1976

This review presents information on the petroleum exploration and production activities during 1976 in 45 countries or provinces of Africa. Petroleum was produced in 5 countries with a total production of 897,220,937 bbl (2.4 million b/d), a 12% increase from the 1975 production level. Production increases were recorded in Congo, 11%, and in Nigeria, 16%. Total annual gas production increased 13% to 737,918 MMcf (2,022 MMCFGD). Surface exploration work decreased by 38% to 170.6 party-months including 132.1 party-months of seismic, 26.0 gravity, 0.5 geology, 3.5 magnetometer, 5.5 structure drilling, and 3.0 photogeology. A total of 231 wells was drilled, a decrease of 116 (33%) from the 1975 figure. Exploratory drilling decreased by 44% to 70; 25 of the exploratory wells were discoveries, a success rate of 36%. New-field discoveries were reported in Cameroun, Chad, Gabon, Nigeria, and Zaire. A total of 16 unsuccessful wildcats was drilled in 6 other countries. Development drilling amounted to 161 wells in Angola, Congo, Gabon, Nigeria, and Zaire, with an 88% success rate. Total wildcat and development footage was 2,250,263 (685,880 m). At year end 24 rigs were operating.

The Construction of Artificial Islands in the Beaufort Sea

Arctic petroleum exploration has moved offshore into the ice-covered waters of the Beaufort Sea. Artificial earth-fill islands have been used successfully as temporary shallow-water drilling platforms. Introduction Petroleum exploration activities in the offshore Arctic Petroleum exploration activities in the offshore Arctic were initiated in the mid-1960's, when permits covering acreage on the Arctic continental shelf were issued to several petroleum exploration companies (Fig. 1). At that time, Imperial Oil Ltd. obtained permits in the shallow waters of the Beaufort Sea adjacent to the Mackenzie River delta. Preliminary studies of offshore drilling feasibility that were undertaken during the late 1960's soon brought to light the tremendous dearth of knowledge concerning the offshore Arctic environment. It was apparent that the major problems to be solved while developing the technology required to support offshore Arctic drilling were (1) the definition of forces exerted on stationary structures by the mobile annual and multiyear ice; (2) the influence of violent, shortduration summer storms; (3) an apparent scarcity of easily accessible construction materials; and (4) the mobilization of suitable construction equipment that would be effective during the short open-water operating season. In 1969 Imperial initiated data-gathering and ice-testing programs; these were followed in succeeding yens by many additional studies sponsored by Imperial and other interested Arctic operators. Numerous concepts, both conventional and unique, were considered for Arctic offshore drilling. These concepts included artificial islands, bottom-founded mobile structures, monopods, cones, and ice-breaking floating vessels. These are all viable concepts and may have application for a specific set of conditions. However, Imperial determined that the dredged artificial island was the safest and most economically attractive type of structure for use in support of its exploration drilling program. In 1971 a permit was received from the Canadian ept. of Indian Affairs and Northern Development authorizing construction of an experimental island at what was later to become Imperial Immerk B-44 wellsite. Construction began early in Aug. 1972 but, under the terms of the permit, drilling operations were not to take place until the stability of the structure under winter ice conditions had been assessed adequately. This initial island proved to be a stable and competent platform. To date, Imperial has drilled eight exploratory platform. To date, Imperial has drilled eight exploratory wells from islands constructed in water depths ranging from 5 to 25 ft (Fig. 2). Environment Very few regions of the world experience greater extremes of weather conditions than those encountered in the Arctic. During the summer months of July through September, temperatures may reach a high of 80 degrees F, dropping to −60 degrees F for much of the winter period. Strong winds and shifting ice during both summer and winter add to the difficulties of working in this harsh and inhospitable climate. The environment of the shallow shelf north of the Mackenzie River delta is influenced by two dominant factors: the polar ice cap, and outflow from the Mackenzie River system. JPT P. 365

Petroleum Developments in Central and Southern Africa in 1974

This review covers the petroleum exploration and production activities in 45 countries or provinces of Africa, excluding Morocco, Algeria, Tunisia, Libya, Egypt, and Sudan. Surface exploration work increased 23% to 485.8 party-months of which seismograph was 299.4, surface geology 73.8, gravimeter 63.8, photogeology 22.5, magnetometer 21.5, and structural drilling 2.8. Exploratory drilling increased from 112 to 120 wildcats with 29% success, slightly less than in 1973. New-field discoveries were reported in Angola, Cameroon, Congo, Gabon, Ghana, Ivory Coast, and Nigeria. A total of 22 unsuccessful wildcats was drilled in 7 other countries. Development drilling amounted to 277 wells in Angola, Congo, Gabon, and Nigeria, with an 89% success ratio. Total wildcat and development footage was 3,537,519 (1,078,236 m). Average well depth was 8,910 ft (2,716 m) compared to 8,763 ft (2,670 m) in 1973. At year-end 51 rigs were operating. Total annual oil production increased 11.4% from 878.3 to 951.8 million bbl, with an average rate of 2.6 million BOPD. Production increases were recorded in Angola 7.6%, Congo 19.8, Gabon 1.1, and Nigeria 8.7. Total annual gas production was up 4.7% to 799,669 MMcf (2,191 MMCFD).

Developments in Alaska in 1973

Alaska petroleum exploration activity during 1973 continued at about the same low level as in the previous 2 years. Of the 11 exploratory wells, 8 were drilled in the Cook Inlet region and 3 in the Arctic North Slope region. One of the Cook Inlet tests resulted in a new deep-pool oil discovery. Federal oil and gas lease acreage continued to decline. State oil and gas lease acreage increased 5.3% as a result of 2 competitive lease sales held in the Cook Inlet region. Combined geologic and geophysical field activity increased 5% over the previous year. Geophysical activity increased in the Arctic North Slope and Gulf of Alaska offshore regions in anticipation of federal, native, and/or state lands becoming available for leasing in the near future. Development drilling durin 1973 continued at about the same low level as in 1972. A total of 21 development wells was drilled, 12 in the Cook Inlet region and 9 in the Arctic North Slope region. Oil and gas production at 73,139,415 bbl and 224,507 MMcf respectively was virtually unchanged from the previous year.

Petroleum Developments in Australia and Oceania in 1973

Petroleum exploration activity decreased by 40 to 50 percent in Australia during 1973 relative to 1972. The decrease is attributed to several political and economic factors believed to be unfavorable to the oil and gas industry. Sixty-seven exploration wells and 16 development wells were drilled or drilling in Australia during 1973. About half of the exploration wells were drilled offshore. Offshore, the principal active areas remained the Gippsland basin of Victoria and the northwest shelf of Western Australia. Onshore, there was little significant drilling activity with exception of the Cooper basin of northeast South Australia and southwest Queensland. In this basin there were only 3 exploration tests drilled, but all were gas discoveries. In 1973 Australian oil production was 22,443,266 cu m (141,168,140 bbl) and gas production was 4,343,102,000 cu m (153,832,670,000 cu ft). At mid-1973 Australia's reserves were about 4.5 billion bbl of oil and natural gas liquids and 38 Tcf of gas. Three new-field discoveries and 1 deeper pool discovery on the northwest shelf, together with successful delineation wells on 3 new fields in the Gippsland basin should increase the total reserve. In Papua-New Guinea 2 new areas of exploration drilling not tested previously included the Sepik basin of northern New Guinea and southeast of Papua in the offshore part of the Vogel basin. Geophysical exploration was the principal activity in several parts of Oceania during 1973. Fiji appears to have been the site of greatest activity in this region.

Developments in Alaska in 1971

Alaska's petroleum exploration and development activity was virtually at a standstill during 1971. Only 6 exploratory and 29 development wells were drilled for declines of 78.6% and 49.2%, respectively. One discovery was made on the Arctic Slope; for the third consecutive year, none was made in the Cook Inlet basin. No wells were drilled in Alaska's other major basins. Geophysical and surface geologic investigations totaled 94.5 crew-months, down 45.7% from 1970. Oil production decreased 5.8% and gas production increased 4.7%. Cumulative state production at year end totaled approximately 396,396,757 bbl of oil and 884,992,139 Mcf of gas, of which 356,854,769 Mcf is casinghead gas. Cumulative petroleum industry investments in Alaska through 1971 are estimated to be in excess of $3 billion; 24 competitive state oil and gas lease sales alone have brought bonus payments of $998,107,679. No federal lease sales were conducted, and at year end total Federal land under oil and gas lease was 5,326,815 acres, down 13.7%. Two new Arctic Slope federal units were approved. One competitive state lease sale was held in the Cook Inlet basin. State lands under oil and gas lease at year end totaled 3,945,222 acres, down 5.0%. Vigorous industry opposition by the many conservation and environmental groups throughout the country is the cause of this sharp decline in activity. Over 95% of Alaska's 375 million acres remain locked up by the Federal land freeze, and construction on the proposed trans-Alaska pipeline had not started at year end because of lack of a construction permit. The forecast for 1972 is for a twofold increase in exploratory drilling, a slight decline in development drilling, and a sharp drop in surface geologic and geophysical investigations. Production should remain near the 1971 level with no real increase to be expected until Prudhoe Bay field wells go on production. State and federal lands under oil and gas lease will also decline during 1972. Additional geologic and geophysical investigations directly or largely applicable to petroleum resource evaluation in Alaska during 1971 included 12 crew-months by the U. S. Geological Survey and a 43,932-sq mi aeromagnetic survey by the Alaska Division of Geological Survey.