Production In December Research Articles

Production of Calanus chilensis in the upwelling area of Antofagasta, northern Chile

Salinities, temperatures, chlorophyll a (chl a), and quantitative samples of Calanus chilensis were obtained at -17 d intervals from June 1996 to June 1997 at 3 stations in the Bay of Mejillones, northern Chile, and from 53 stations in a broad-scale survey of surrounding waters from 17 to 21 December 1996. Temporal variability in cohort structure precluded direct estimates of production from samples. However, lack of relationship of eggs per female and stage-frequency distribution with chl a in the broad survey, the apparently continuous development (and presence of adult males) during the time series, and the seasonal correlation of female body size with temperature, but not chl a, all suggest that food supply did not determine production rates. Therefore, temperature-dependent production was estimated, from sample biomasses and from laboratory rearings of C. chilensis and other species, as 45 mg C m -3 yr -1 . This is substantially lower than comparable estimates for C. finmarchicus off eastern Canada and northeastern USA. However, broad-scale production in December 1996 was much higher than that at the 3 time-series stations. A production:biomass ratio of 45, compared with 8 for C. finmarchicus off eastern Canada, is compatible with the general view that the upwelling area off northern Chile is part of one of the world's most productive marine systems.

Norphlet geology and 3-D geophysics: Fairway Field, Mobile Bay, Alabama

The Upper Jurassic Norphlet system in the Mobile Bay area has been the subject of considerable exploration intrigue during the last 20 years. Fairway Field, which came on production in December 1991, lies in the restricted access area of the main Mobile Bay shipping fairway leading to the city of Mobile, Alabama, and is comprised of state blocks 113 and 132.

Petroleum Investment Opportunities In Manitoba-A Geological, Engineering And Economic Perspective

Abstract Southwestern Manitoba' occupies part of the northeastern) flank of the Williston Basin. Paleozoic, Mesozoic and Cenozoicrocks form a basinward thickening-wedge of sedimentary strata j that reach a total thickness of 2,300 m in the southwest-comer of the province. To date, oil production in Manitoba is restricted to the sand-stones of the Jurassic Melita and Amaranth formations, the Mississippian-Bakken Formation and the carbonates of the Mississippian Lodgepole and Mission Canyon formations. The; deeper Ordovician, Silurian and Devonian formations-the Winnipeg, Red River, Stony Mountain, Interlake, Winnipegosis, Dawson Bay, Souris River, Duperow arid Birdbear (Nisku)- offer oil and gas potential but remain largely undrilled. Manitoba enjoyed a resurgence in petroleum activity, in 1993 and 1994. In total, 184 wells were licensed over the last twoyears, compared to an annual average of 61 wells licensed over the previous five years. Over 70%; of the Crown land currently disposition has been leased at land sales during the past two years. Low Crown land price is one competitive advantage enjoyed by Manitoba producers. Other advantages include: low drilling and completion costs, low drilling density, a competitive andstable fiscal regime, drilling and exploration incentives, and unrestricted access to markets. This paper presents a brief description of the geology and reservoir characteristics, of Manitoba's producing horizons. Recent activity in Manitoba and exploration' and developmentprospects are reviewed. Sample economics are included to illustrate the attractiveness of vertical and horizontal drilling opportunities in Manitoba. Introduction Oil was discovered in Manitoba in 1951. At year-end 1994 there were 1,568 producing wells in 125 designated oil pools in Manitoba. Manitoba enjoyed a resurgence in oil activity in 1993 and 1994; 154 wells were drilled including 28 horizontal wells. Production in December 1994 was 1,905 m3/d, the highest since October 1991. At Manitoba's Crown land sales in 1993 and 1994, a total of 42,918 ha were disposed under leases and exploration reservations. Not since 1980 - 81, has this much land been disposed in a two-year period. Manitoba Energy and Mines has undertaken a number of initiatives to ensure the province maintains a competitive investment climate. The province's petroleum legislation has been consolidated and simplified under the new Oil and Gas Act. The Manitoba Drilling Incentive Program provides a Crown royalty and freehold production tax free holiday oil volume for new wells. The Major Workover Incentive Program provides a Crown royalty and freehold production tax free holiday oil volume for re-entries, deepenings, recompletions and casing repairs on marginal wells. The Manitoba Mineral Exploration Incentive Program has been replaced by the Petroleum Exploration Assistance Program which provides assistance, to a maximum of 20%, for eligible exploration costs. A project to digitize the province's oil and gas well geological and engineering data is underway. Historical production data and general well data is now available in digital form. These initiatives, and an increased awareness of Manitoba's petroleum potential, resulted in 20 companies, new to Manitoba, acquiring or drilling wells in the province during the last two years.

Evaluation of Attic Oil Recovery Schemes For the Fenn West Leduc D-3E Reef Reservoir

Abstract Reservoir simulation was employed to evaluate various attics oil recovery schemes for the Fenn West Leduc D-3E reef reservoir. Based on geological and seismic data, a three-dimensional reservoir model was constructed to represent the pinnacle-reef reservoir and the adjoining bottom aquifer. The reservoir model was calibrated by history matching the production performance of the two vertical wells in the pool. Model calibration results indicated that water production from the pool is mainly attributable to a rising oil-water contact in the reservoir. Furthermore, the current oil production from the pool results from a reverse oil coning mechanism in the attic portion of the reef. Various attic oil production schemes were investigated, including increased liquid withdrawals, reactivation of a shut-in vertical well and horizontal well production from the structurally highest location in the pool. Prediction results indicated that these attic oil production schemes will not recover any significant incremental oil reserves from the pool, but will shorten the remaining producing life of the pool by five to 21 years. Introduction The Fenn West Leduc D-3E pool, located in Township 36, Range 21, West of the Fourth Meridian (Figure 1), is a pinnacle reef reservoir containing light gravity oil (34 °API). Discovery well 08-11-36-21 W4M commenced production from the pool in January 1983, at an initial oil rate of over 300 m3/d (Figure 2). After producing clean oil for over four years, a series of well recompletions was conducted to arrest the increasing water production from the well (Figure 2). In September 1991, the well was suspended due to a high watercut of about 98%. Another well, located at 07-11-36-21 W4M, commenced production in December 1985. The well produced clean oil for over three years and is currently producing at an oil rate of about 12 m3/d and a watercut of about 86% (Figure 3). A third well, located at 09-11-36-21 W4M, previously produced from the Nisku Formation and was converted to a water disposal well in 1987 (Figure 1). Based on pool pressure and production data, the main recovery mechanism in the pool is an active bottom water drive. To April 1992, about 483,500 m3 of oil, 262,900 m3 of water and 38,600,000 m3 of gas have been produced from the pool. Based on data from the Energy Resources Conservation Board (ERCB)(1), the volumetric estimate of original oil-in-place (OOIP) for the pool is about 1,480,000 m3. Correspondingly, the current oil recovery is about 33% of the OOIP. The objective of this study was to evaluate various attic oil recovery schemes for the pool including increased pumping rate for well 07–11, reactivation of well 08–11 and horizontal well production from the structurally highest location in the reservoir. FIGURE 1: Pool location map: Fenn West Leduc. D-3E pool. (Available in full paper) Geology The Fenn West Leduc D-3E pool is extensively dolomitized, resulting in a very high quality reservoir. The average porosity is about 6% and the average horizontal permeability is in the order of several Darcies.

CIE integrated system for the CPCM (coupled pickle line and tandem cold mill) at Dofasco's Hamilton Works

The CPCM at Dofasco's Hamilton Works (Canada) began commercial production in December 1991. This plant is one of the most modern of its kind in the world, combining a pickle line with a tandem cold mill for improved productivity and quality. Toshiba Corporation supplied the computer, instrumentation, and electrical or CIE integrated control system for this facility. The control system consists of the three major subsystems communicating over a high-speed LAN (Local Area Network). One of the main features of the CIE integrated control system is that the computer, instrumentation, and electrical control systems are independently allowed efficient and free access to the data running through the LANs. Other features include an integrated controller for control of both instrumentation and electrical systems and a man-machine interface providing the operator access to data from all three systems.< <ETX xmlns:mml="http://www.w3.org/1998/Math/MathML" xmlns:xlink="http://www.w3.org/1999/xlink">&gt;</ETX>

Spatial and temporal distribution of phytoplankton and primary production in the western Bransfield Strait region

Studies on phytoplankton were one component of the multi-disciplinary RACER program which had 69 stations within a 100 × 250-km rectangle in the southwestern Bransfield Strait and contiguous waters. Data were acquired during eight cruises between December 1986 and March 1987. All deep stations north of the continental shelf break were low in phytoplankton biomass (<41 mg Chl a m −2) and in rates of primary production (mean of 0.34 g C m −2 day −1) as compared to stations in continental shelf waters. Phytoplankton biomass exceeded 700 mg Chl a m −2 at some stations in shelf waters, with rates of primary production in December exceeding 3.0 g C m −2 day −1. The mean rate of primary production at the shelf stations for the 4-month period was 1.05 g C m −2 day −1. Greatest phytoplankton biomass was found at stations in Gerlache Strait and in nearby Bransfield Strait. Dramatic seasonality in phytoplankton crop size was observed, as massive blooms during December to January declined abruptly to low levels in February to March. As the decrease in phytoplankton biomass was much more abrupt than the corresponding decrease in incident solar irradiation, light does not appear to be the major factor involved in decline of the bloom. Except for stations in Gerlache Strait, nutrient levels remained sufficiently high (> 10 μM inorganic nitrogen) that nutrient depletion is not likely to have caused the rapid decline of the phytoplankton bloom. Grazing, sinking and advection all appear to be important mechanisms of massive bloom decline. Phytoplankton populations appeared to be low-light adapted, as they showed low P max values (1.1 mg C mg Chl a −1 h −1), low saturating ligh values ( I k ∼ 18 μEins m −2 s −1), high initial slope [ α = 0.06 (mg C mg Chl a −1h −1/ μEin m −2 s −1)] and a compensation point for net light-activated fixation of CO 2 of ≈ 1.0 μEin m −2 s −1.

Producción de gramíneas tropicales pastadas en las llanuras húmedas de Toa Baja en la costa norte de Puerto Rico

En abril de 1983 se estableció un experimento en una finca privada cerca de Toa Baja en las llanuras húmedas de la costa norte de Puerto Rico para determinar la producción de forraje y la persistencia en parcelas pequeñas de gramíneas tropicales. Cynodon nlemfuensis var. nlemfuensis Star, C. dactylon Coastcross-1, Brachiaria brizantha Signal, B. ruzuziensis Congo, C. dactylon Toño, Eriochloa polystachya Carib, C. plectostachyus Star, Digitaria decumbens Transvala, Brachiaria radicans Tanner and Panicum maximum Makueni se pastaron a intervalos de 3 a 5 semanas con un grupo de 170 vacas por período de 2 a 3 horas. La producción media de forraje por período fue 1.59 y 1.52 ton./ha. para el primero y segundo años de estudio, respectivamente, sin que arrojaran diferencias significativas (P = 0.05) entre especies y cultivares. La produción de forrajes estuvo relacionada con la distribución de las lluvias, las cuales fueron relativamente bajas durante diciembre de 1983 y abril, octubre y noviembre de 1984, lo cual no es normal en la región. La producción de forraje durante los meses de temperaturas frescas y días cortos de enero a marzo fué alta en todas las forrajeras en 1984 y baja en 1985, tal como se ha observado antes en otros experimentos de pacedura en la región. Esto indica variaciones en temperaturas de un año a otro que deben tomarse en consideración en el cultivo intensivo de estas forrajeras. Por otro lado, la metodología utilizada en este experimento fue modificada de manera que la presión de apacentamiento fue menor, lo cual pudo haber influido en los resultados al examinar numerosas especies y cultivares con una palatabilidad relativa muy diferente. Esto debe tomarse en consideración en el diseño de este tipo de experimentos en el futuro.

FLOUNDER — A COMPLEX INTRA-LATROBE OIL AND GAS FIELD

The Flounder Field is the deepest producing field in the Gippsland Basin. Since discovery in 1968 by Flounder 1, five delineation wells and 15 development wells have been drilled on the structure. The main T-1.1 oil and gas reservoir is trapped at the crest of a highly faulted anticline within the Latrobe Group. The Flounder structure has a complex deformational history with the Latrobe Group sequence undergoing two main phases of deformation. Late Cretaceous to Late Paleocene north-west trending normal faults are overprinted by a Late Eocene to mid Miocene north-east trending anticline. Generally within the Latrobe sequence in the Gippsland Basin, faulting destroys the integrity of the anticlinal features by breaking the lateral continuity of potential intra-formational seals. However, at the Flounder Field, the estuarine sands of the T-1.1 reservoir are overlain by a marine shale of adequate thickness to provide an effective seal across the faults.The T-1.1 oil and gas reservoir has excellent reservoir parameters. Separate gas caps are trapped in the multiple faulted crests of the structure and have had a major influence on the development of the field due to the resultant variation in gross oil column thickness.In addition, several small oil accumulations have been structurally and stratigraphically trapped in sediments filling the Tuna-Flounder Channel and the deeper Latrobe Group sequence.The Flounder Field commenced production in December 1984. Current estimated reserves for the T-1.1 reservoir are 155 billion cubic feet (BCF) (wet) gas and 115 million barrels (MMB) of oil, a dramatic increase over the 1978 pre-development estimated reserves of 86 BCF (wet) gas and 57 MMB oil.

Polyvinyl chloride shakeout gains momentum

One need hardly be told that the polyvinyl chloride market is in a shambles. Production and shipments are well off from what they were last summer, prices are down, and producers are actively seeking to leave the market. The only thing that is keeping producers from getting out is that, as with the product itself, nobody seems very willing to buy a PVC plant. Production of PVC in December hit its lowest point in almost a year and a half, according to figures compiled by the accounting firm of Ernst & Whinney for the Society of the Plastics Industry. Production in December was 321 million lb, a drop of more than 30% from December the year before. Production in December 1981 also was 42.5% below production of 559 million lb in March 1981, which had the highest production of any month last year. For the full year, production of PVC was up slightly from 1980. ...

Petroleum Developments in Europe in 1954

Petroleum production in western Europe increased 20 per cent in 1954, or by the same percentage as in 1953. The daily average production of countries outside the Russian orbit was 87,486 barrels. The outstanding discovery of the year was the Parentis field in southwestern France, producing from Lower Cretaceous and Upper Jurassic dolomite. West Germany continued to be the leading producing nation, with a daily average production of 52,940 barrels. In northwest Germany remarkable success has been achieved in finding oil sands truncated by unconformities, guided by detailed reflection seismic surveys. Two gas and two oil discoveries were made on fault blocks in the sub-Alpine Molasse trough of Bavaria, adding this to the producing basins of Europe. In Italy three major gas ields were discovered in the Po valley, and the Ragusa oil field of Sicily, discovered late in 1953, was placed on full production in December, 1954. A discussion of oil developments in Yugoslavia is included for the first time, and in this report post-war developments in Croatia are summarized.