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INDONESIA
Scientific Contributions Oil and Gas
Published by LEMIGAS
ISSN : 20893361     EISSN : 25410520     DOI : -
Core Subject : Science, Engineering,
Chemical Engineering, Chemistry & Bioengineering Energy
The Scientific Contributions for Oil and Gas is the official journal of the Testing Center for Oil and Gas LEMIGAS for the dissemination of information on research activities, technology engineering development and laboratory testing in the oil and gas field. Manuscripts in English are accepted from all in any institutions, college and industry oil and gas throughout the country and overseas.
Arjuna Subject : Energi (semua kategori) - Teknologi Bahan Bakar
Articles 6 Documents
 1 
Search results for , issue "Vol 31 No 2 (2008)" : 6 Documents clear
ESTIMATION OF WATER SATURATION IN CARBONATE RESERVOIRS WITHOUT RESISTIVITY LOG DATA. PART I: THEORY AND EXISTING MODEL Bambang Widarsono; Heru Atmoko; Ridwan Ridwan; Kosasih Kosasih
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1000

Abstract

This paper presents an observation over a suggested approach for establishing water saturation model that is specifically designed without the need of resistivity log data. One of the main strength of the approach is that the resulting water saturation model can be specifically established for local or specific use only. This is true since the approach can be applied using carbonate rocks that are obtained locally or from specific areas. Another important conclusion is that this approach can also be applied for any carbonate rock classification as long as the classification can clearly group carbonate rocks into groups with distinctive petrophysical properties. This paper – first part of two – presents theory and rock classification that underlines the approach, as well as procedure and the existing models available.
PLEISTOCENE PALYNOLOGY OF THE WAIPONA BASIN, PAPUA Eko Budi Lelono
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1001

Abstract

The Pleistocene sediment from a single well drilled on the back bone of Papua provides good pollen recovery which shows the mixture of the Australian and Asian elements. The well drilled the sediment more than 3000 meter deep which is mostly assigned to Pleistocene age. Only small part of the basal section belongs to Pliocene age. In order to obtain accurate interpretation, the age interpretation is also defined using other disciplines including foraminifera and nannoplankton. The Australian affinity appears as an origin since this island has derived from the Australian continent. On the other hand, the existence of Asian palynomorphs within the studied sediment indicates the dispersal of Asian flora into East Indonesia following the arrival of the Australian plates at about the end of Oligocene. The Asian taxa then migrated to the land mass of New Guinea which rose above sea level from about Middle Miocene onward. In the studied section, shallow marine sediment in the upper interval contains sufficient palynological assemblages which clearly indicate climatic changes from dry or seasonal to wet climate as reflected on the changes of the proportion of dry/ seasonal and wet climate indicators. Unfortunately, due to low pollen recovery, the climate condition of the lower interval can be hardly interpreted. This could have happened because the sediment of the lower interval was deposited in deep marine environment, which was situated far away from the pollen sources in the continent.
INDONESIAN TERTIARY SEDIMENTARY BASIN Djoko Sunarjanto; Sri Wijaya; Suprajitno Munadi; Bambang Wiyanto; Doma F. Prasetio
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1002

Abstract

Since 1980 the number of Indonesian Sedimentary Basin which is officially announced by the government are 60 basins, but informally the variation in the range of less than 60 up to around 66 basins. Based on stratigraphic and tectonics conditions of some areas there are overlapping layers between Tertiary Sedimentary and Pre Tertiary Basin. In general the definition of a sedimentary basin is a region, part of the earth's crust where sedimentary strata have been deposited in a relatively much greater thickness than its surrounding area. The nomenclature for basin is referred more to basinal areas. Based on sedimentary basin classification there are: type of plate where basin exists, basin position in the plate margin, type of plate interaction, time development of basin and basins fill with respect to tectonic and shape of the basin. The updating classification using new technology and knowledge of the basin, can also update previous knowledge because of the limitation of the data and the lack of new concept when the report was published. 63 Tertiary Sedimentary Basins (16 producing basin of oil and gas, 8 drilled basin with discovery, 15 drilled basin with has no discovery yet and 24 basin which has not been drilled yet) could be used as a basic data for development of science and technology, to support government policy and investor, to improve and accelerate oil and gas exploration and production in Indonesia.
UNDERSTANDING NATURALLY FRACTURED RESERVOIRS Suprajitno Munadi; Samsul Hidayat; Julikah Julikah; Oki Hendriana; Eko Susanto
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1003

Abstract

Naturally fractured reservoir differs from clastic reservoirs in the sense that the concepts of porous media which were usually applied for clastic reservoir analysis must be modified. This means that handling naturally fractured reservoir is also different compared to handling clastic reservoir. The porosity may be changed a bit bigger but the permeability is drastically changed. Also at a depth where rock layers are usually tight, naturally fractured reservoirs converts it to become a good reservoirs. Naturally fractured reservoirs can be found in some part of the Indonesian basin which may contribute a considerable additional reserves in the near future.
TESTS OF POLY ACRYLIC ACID (PPA) INHIBITOR ON BARIUM SULFATE SCALE INHIBITION EFFEICIENCY Tjuwati Makmur
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1004

Abstract

Injection water (containing sulphate ion) is injected into reservoir (containing barium ion), mixture of incompatible water types results in barium sulphate scale occurrence.
CHANGING WELLBORE STORAGE IN GAS WELL TESTING Edward ML. Tobing
Scientific Contributions Oil and Gas Vol 31 No 2 (2008)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/SCOG.31.2.1008

Abstract

Extended wellbore storage can be mistakenly interpreted as a reservoir response in gas well testing with surface shut in. This interpretation usually results in false value for permeability, skin and reservoir size and shape. This paper investigates changing wellbore storage in pressure transient testing with surface shut-in in gas well. This study was prompted by the observation, that in gas wells, many of the buildup tests obtained with surface shut-in exhibited complex reservoir model behavior with relatively low skin. The results presented in this paper are based on well test simulation and field data from North Sumatera. This work demonstrates the effect changing wellbore storage on the pressure derivative curve. Knowledge of the expected pressure derivative shape, and duration, will improve the design of buildup tests that will allow enough time for the actual reservoir response to be observed. This will result in a reliable reservoir model and correct estimation of permeability and skin factor.

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