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Статті в журналах з теми "Luconia"

Автор: Grafiati

Опубліковано: 8 лютого 2025

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1

Dudley, John W., Arjan van der Linden, and Kok Gin Mah. "Predicting Accelerating Subsidence Above The Highly Compacting Luconia Carbonate Reservoirs, Offshore Sarawak Malaysia." SPE Reservoir Evaluation & Engineering 12, no. 01 (February 26, 2009): 104–15. http://dx.doi.org/10.2118/109190-pa.

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Summary Sarawak Shell Berhad has a number of offshore gas fields that produce from the Luconia carbonate formation, which can exhibit high-compressibility pore-collapse deformation. Recent accelerated subsidence has been observed at several of these fields, which extrapolates to final subsidence values well above previous estimates. This paper describes a geomechanical study involving core work to determine if the Luconia formation compressibility is sensitive to brine flow from the rising aquifer and a 3D geomechanical finite-element model developed to predict future subsidence and lateral movements for the F23 platform. Compaction tests were performed on the Luconia core from three different gas fields. Tests on twin plugs were conducted—one plug undergoing a standard uniaxial zero-lateral-strain compaction test, while its twin has several pore volumes of simulated-formation brine flowed through it (at virgin in-situ stress conditions) before the compaction loading. Four sets of compaction tests on twin plugs were completed. The higher-porosity samples showed characteristic pore-collapse behavior consistent with previous measurements on Luconia mouldic limestone core. No sensitivity to brine flow was observed. In-situ compaction logs in the field also do not show increased compressibility in sections flooded by the rising gas-water contact (GWC). The geomechanical model uses a relatively simple structural model comprised of four layers—two overburden formations, the Luconia carbonate and one underburden formation. A nonlinear deformation model for the Luconia formation captures the accelerating pore-collapse response observed in the core and in-situ compaction measurements. The model is calibrated to GPS-measured platform subsidence and is consistent with measured core- and field-compaction properties. The results predict that platform subsidence rates with depletion would level off, with a maximum subsidence of 18.5 ft +/- 1 ft at an abandonment pressure of 300 psi. Platform subsidence in the two years following the work continues to follow the predicted values. This work illustrates the importance of integrated geomechanical core testing, field-monitoring measurements, and modeling to accurately predict compaction and subsidence effects in highly compacting environments.

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2

Jamaludin, Siti Nur Fathiyah, Manuel Pubellier, and Benjamin Sautter. "Shallow vs. Deep Subsurface Structures of Central Luconia Province, Offshore Malaysia Reveal by Aeromagnetic, Airborne Gravity and Seismic Data." Applied Sciences 11, no. 11 (May 31, 2021): 5095. http://dx.doi.org/10.3390/app11115095.

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Across the Luconia continental shelf, the nature and structures of the crust are lacking geological understanding and precise characterization. Newly acquired, aeromagnetic, and airborne gravity data were used to assess deep and shallow sub-surface signals within the Central Luconia Province, off the coast of Sarawak, offshore Malaysia. Regional aeromagnetic anomalies appear to primarily reflect deep crustal features while depth (Z) tensors of airborne gravity anomalies evidence shallow subsurface structures. Strike directions of the interpreted structural trend on aeromagnetic and airborne gravity anomalies maps are measured and plotted into rose diagrams to distinguish the structural orientations for all datasets. Signature patterns extracted from the depth profiles were correlated with parallel seismic lines and nearest exploration wells and coincide well with the top of carbonate for Cycle IV/V and structures seen within the Cycle I and II sediments. The orientation of faults/lineaments at shallower depth is dominated by a NW-SE orientation, similar with the faults extracted from two recently published structural maps. Deeper subsurface sections yielded E-W to NWW-SEE dominant directions which were never presented in the published literature. The E-W oriented anomalies are postulated to represent the remnants of the accretion between the Luconia crustal block and southern boundary of the Palawan block. The NW-SE trend follows the same direction as prominent faults in the region. The insight into shallow and deep subsurface structures in Central Luconia Province imaged through airborne gravity and aeromagnetic data should provide guidelines and complementary information for regional structural studies for this area, particularly in combination with detailed seismic interpretation. Further evaluation on the response of Air-FTG® gravity and aeromagnetic could lead to the zonation of potential basement highs and hydrocarbon prospects in this area.

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3

Ho, Francis, Guenter Jaeger, and Piet Lambregts. "Seismic interpretation of carbonate turbidites in Central Luconia." Bulletin of the Geological Society of Malaysia 47 (December 1, 2003): 77–83. http://dx.doi.org/10.7186/bgsm47200306.

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4

Nur Arif Zanuri, Muhammad, Luluan Almanna Lubis, and Askury Abd Kadir. "4D Seismic Feasbility of Central Luconia FOT Field." Journal of Engineering and Applied Sciences 14, no. 8 (December 31, 2019): 2440–49. http://dx.doi.org/10.36478/jeasci.2019.2440.2449.

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5

Hasbollah, Dayang Zulaika Abang, and Radzuan Junin. "Assessment of geological CO2 storage potential in central Luconia province." International Journal of ADVANCED AND APPLIED SCIENCES 4, no. 2 (February 2017): 44–48. http://dx.doi.org/10.21833/ijaas.2017.02.008.

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6

Goh, Vanessa, Kjetil Halleland, René-Édouard Plessix, and Alexandre Stopin. "Application of multiparameter full-waveform inversion in Central Luconia Basin, Sarawak." Interpretation 4, no. 4 (November 1, 2016): SU17—SU24. http://dx.doi.org/10.1190/int-2016-0038.1.

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Reducing velocity inaccuracy in complex settings is of paramount importance for limiting structural uncertainties, therefore helping the geologic interpretation and reservoir characterization. Shallow velocity variations due, for instance, to gas accumulations or carbonate reefs, are a common issue offshore Malaysia. These velocity variations are difficult to image through standard reflection-based velocity model building. We have applied full-waveform inversion (FWI) to better characterize the upper part of the earth model for a shallow-water field, located in the Central Luconia Basin offshore Sarawak. We have inverted a narrow-azimuth data set with a maximum inline offset of 4.4 km. Thanks to dedicated broadband preprocessing of the data set, we could enhance the signal-to-noise ratio in the 2.5–10 Hz frequency band. We then applied a multiparameter FWI to estimate the background normal moveout velocity and the [Formula: see text]-parameter. Full-waveform inversion together with broadband data processing has helped to better define the faults and resolve the thin layers in the shallow clastic section. The improvements in the velocity model brought by FWI lead to an improved image of the structural closure and flanks. Moreover, the increased velocity resolution helps in distinguishing between two different geologic interpretations.

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7

Idris, M. B. "CO2 and N2 contamination in J32-1, SW Luconia, offshore Sarawak." Bulletin of the Geological Society of Malaysia 32 (November 30, 1992): 239–46. http://dx.doi.org/10.7186/bgsm32199214.

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8

Madon, Mazlan, and John Jong. "Geothermal Gradient And Heat Flow Maps Of Offshore Malaysia: Some Updates And Observations." Bulletin of the Geological Society of Malaysia 71 (May 31, 2021): 159–83. http://dx.doi.org/10.7186/bgsm71202114.

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An update of the geothermal gradient and heat flow maps for offshore Malaysia based on oil and gas industry data is long overdue. In this article we present an update based on available data and information compiled from PETRONAS and operator archives. More than 600 new datapoints calculated from bottom-hole temperature (BHT) data from oil and gas wells were added to the compilation, along with 165 datapoints from heat flow probe measurements at the seabed in the deep-water areas off Sarawak and Sabah. The heat flow probe surveys also provided direct measurements of seabed sediment thermal conductivity. For the calculation of heat flows from the BHT-based temperature gradients, empirical relationships between sediment thermal conductivity and burial depth were derived from thermal conductivity measurements of core samples in oil/gas wells (in the Malay Basin) and from ODP and IODP drillholes (as analogues for Sarawak and Sabah basins). The results of this study further enhanced our insights into the similarities and differences between the various basins and their relationships to tectonic settings. The Malay Basin has relatively high geothermal gradients (average ~47 °C/km). Higher gradients in the basin centre are attributed to crustal thinning due to extension. The Sarawak Basin has similar above-average geothermal gradients (~45 °C/km), whereas the Baram Delta area and the Sabah Shelf have considerably lower gradients (~29 to ~34 °C/km). These differences are attributed to the underlying tectonic settings; the Sarawak Shelf, like the Malay Basin, is underlain by an extensional terrane, whereas the Sabah Basin and Baram Delta east of the West Baram Line are underlain by a former collisional margin (between Dangerous Grounds rifted terrane and Sabah). The deep-water areas off Sarawak and Sabah (North Luconia and Sabah Platform) show relatively high geothermal gradients overall, averaging 80 °C/km in North Luconia and 87 °C/km in the Sabah Platform. The higher heat flows in the deep-water areas are consistent with the region being underlain by extended continental terrane of the South China Sea margin. From the thermal conductivity models established in this study, the average heat flows are: Malay Basin (92 mW/m2), Sarawak Shelf (95 mW/m2) and Sabah Shelf (79 mW/m2). In addition, the average heat flows for the deep-water areas are as follows: Sabah deep-water fold-thrust belt (66 mW/m2), Sabah Trough (42 mW/m2), Sabah Platform (63 mW/m2) and North Luconia (60 mW/m2).

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9

Manogaran, Roodra, Ain' Natasha Mohd Nasir, Nurul Nadirah Mohd Shukri, Grisel Paola Jimenez Soto, Mirza Arshad Beg, Sarah Rahman, Bing Bing Saw, and Chee Meng Choong. "STRUCTURAL MODEL & SEDIMENTOLOGY ANALYSIS OF THE EX CARBONATE FIELD, CENTRAL LUCONIA PROVINCE, SARAWAK." Platform : A Journal of Science and Technology 4, no. 1 (May 31, 2021): 59. http://dx.doi.org/10.61762/pjstvol4iss1art10243.

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Central Luconia Province displays various structures in different parts of the basin attributed to extensional, strike-slip, and wrench tectonics. This affected the growth of the EX carbonate platform, the heterogeneity of carbonate facies, and lithological properties variations in the EX field. Such complexities restrict the understanding of the structures and sediments and may lead to well placement problems during a development stage. This research aims to study the carbonate growth of the EX field in accordance with the structural deformation and to analyse the field’s sedimentology. Detailed research of the structures in the EX carbonate platform was done using seismic interpretation to determine the nature of the relationship between faults and carbonate formation. Concurrently, a comprehensive sedimentary analysis was conducted using core and thin section studies to interpret facies characterization and depositional environment. The spectral decomposition attribute was used to study the seismic response of the lithologies in this field by demonstrating the anomalies of the carbonate platform using frequencies ranging from 328 Hz to 356 Hz. This research contributed to the interpretation of individual faults and the generation of a conceptual growth and structural model based on a seismic, attribute, and structural interpretation. The anomalies were used to identify the EX carbonate body and features such as the rim of the build-up through the spectral decomposition attribute. The sedimentary analysis from the EX-4 well also improved facies distribution and depositional environment, ranging from a deeper lagoon to a reef environment. This research can be used as an input for further correlation studies of the Central Luconia basin at a regional scale. Keywords: carbonate platforms, tectonics, spectral decomposition, carbonate core

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10

Fathiyah Jamaludin, Siti Nur, Mukhriz Mubin, and Abdul Halim Abdul Latiff. "Imaging of karsts on buried carbonate platform in Central Luconia Province, Malaysia." IOP Conference Series: Earth and Environmental Science 88 (October 2017): 012011. http://dx.doi.org/10.1088/1755-1315/88/1/012011.

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11

Ab Rahman, Siti Sarah, Maman Hermana Husen, Grisel Jimenez Soto, Saw Bing Bing, Nur Huda M. Jamin, Redwan Rosli, and Michael C. Poppelreiter. "Application of Spectral Decomposition Technique to Delineate the Evolution of Karst on Carbonate Platforms of Central Luconia, Offshore Sarawak, Malaysia." Applied Sciences 11, no. 24 (December 8, 2021): 11627. http://dx.doi.org/10.3390/app112411627.

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Karstification in carbonate platforms of the Miocene age in Central Luconia province, offshore Sarawak, Malaysia, has been discussed since the onset of exploration and initial discoveries in the region, with over 200 mapped platforms to date. An extensive drilling program over the last decade confirmed the existence of karst during the drilling process where issues such as total loss circulation and bit drops were common. Karst in Central Luconia has been proposed by several authors; however, detailed quantitative description of the observed features have not yet been conducted. This study involves systematic mapping of loss circulation depths, chalkified/rubble/vuggy zones described from cores, and vugs of >2 mm in size and moldic porosity observed on thin sections of the Jintan platform. These data supplement the interpretation of karst from multiple 3D seismic attributes. Seismic interpretation of the Jintan and M1 platforms revealed an extensive dendritic pattern which is on average 70–100 m deep and 3–5 km long, and circular geobodies of 1 km in width that exist on the upper part of the platform. Spectral decomposition, also known as time-frequency analysis, was used to enhance the interpretation of karst features on seismics within a specific wavelength. In this study, a comparison of three spectral decomposition methods applied on the 3D seismic cube of the Jintan and M1 platforms was undertaken to determine the method which allowed for better delineation of the karst features. The results show that the short-time Fourier transform (STFT) method using frequencies of 46, 54, and 60 Hz delineated most of the karst features compared to the continuous wavelet transform (CWT) Morlet and CWT Ricker wavelet methods. This paper aims to discuss the dimensions, evolution and geometry of the karst features quantitatively on three selected karst horizons named “K1”, “K2”, “K3”. Interpretation revealed that the dendritic karst features were found to be most prominent on the K2 horizon which lies below a conspicuous change of the external geomorphology of the platform. Backstepping of the platform margin by 12 km is observed in both platforms. Quantitative seismic interpretation shows that the karst observed in M1 platform is approximately 70–100 m deep, and the dendritic features are around 1–2 km in length and approximately 500 m wide; whereas, in the Jintan platform the dendritic features observed are up to 5 km in length with several 1 km wide circular/sinkhole features. More than 20 dendritic features orientated SE and NS were mapped mainly in the transitional area as well as the center of both platforms. The nature of the karst morphology in Central Luconia remains controversial; however, it is proposed to be of mixing zone karst origin.

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12

Varatharajoo, Sharanya, and Maman Hermana. "FEASIBILITY STUDY OF SQS ATTRIBUTE APPLICATION FOR POROSITY ESTIMATION IN CARBONATE RESERVOIR, CENTRAL LUCONIA." Platform : A Journal of Science and Technology 2, no. 2 (December 30, 2019): 11. http://dx.doi.org/10.61762/pjstvol2iss2art5539.

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This study shows the reliability of an improved attribute or elastic properties, namely SQs and SQp to estimate porosity in a carbonate reservoir. Both SQp and SQs attributes are reliable to predict porosity in a carbonate reservoir. However, SQs shows a better correlation (0.96662). Thus it was selected as an input to calculate empirical equation which, was later used to create a porosity model. The model was compared with actual porosity from the real well data, which yielded a high correlation of 0.961911. Thus, SQs is highly reliable to estimate the porosity in the carbonate reservoir through the empirical equation. Keywords: Elastic properties, Porosity, SQp and SQs, Central Luconia

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13

Refael, Siti Nur Fathiyah Jamaludin, and Abdul Halim Abdul Latiff. "Compaction history based on porosity, pressure and temperature relation in Central Luconia province, offshore Sarawak." IOP Conference Series: Earth and Environmental Science 1003, no. 1 (April 1, 2022): 012001. http://dx.doi.org/10.1088/1755-1315/1003/1/012001.

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Abstract This study investigates the role of porosity in relation to temperature and pressure within Miocene-Pliocene sediments in Central Luconia province. The main objective is to understand the effect on porosity loss within Miocene-Pliocene sediments as part of the compaction of the sediments through time. The methodology involves seismic interpretation of 2D seismic lines and analysis of four wells over the central complex in Central Luconia province. Thick sedimentation was found within the clastic sediments of Cycle VI, indicating major clastic influx from the deltas and onshore of Sarawak during Pliocene. These clastic sediments had become a major source of weight in the offshore basin, inducing compaction within the older formations. Porosity distributions based on the wells showed that Cycle VI had the highest porosity in LH1 well with 33.77% porosity, while porosity within Cycle IV & V limestone showed an average porosity of 22% in all wells. Porosities within Cycle III and Cycle II were observed to be average of 16%. The porosity within the reservoir rock was reduced as the depth increased. This porosity reduction was relatively due to the compaction of the sediments, linked with the changes of pressure and temperature indicated by several evidences found in each well. Overpressure zone affects irregularity of porosity reduction with depth, whereas high temperature promotes diagenetic reaction that causes sudden porosity loss. Nevertheless, a sudden increase in porosity was also observed at the top of Cycle IV & V limestone due to a major drop in the sea level during the Early Late Miocene, which had encouraged the karstification process, inducing secondary porosity. This study has proved that compaction within Miocene-Pliocene sediments is not only related to the loss in porosity, but it involves changes in pressure and temperature regime of sediments and is highly dependent on the natural changes of sea level.

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14

Jiménez Soto, Grisel, Abdul Halim Abdul Latiff, Wael Ben Habel, Saw Bing Bing, and Michael Poppelreiter. "Integrated Carbonate Rock Type Prediction Using Self-Organizing Maps in E11 Field, Central Luconia Province, Malaysia." Applied Sciences 12, no. 15 (July 30, 2022): 7688. http://dx.doi.org/10.3390/app12157688.

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Reducing uncertainty in 3D carbonate rock type distribution is a critical factor that profoundly impacts field development for hydrocarbon or carbon capture and storage (CCS) projects. Miocene carbonate reservoirs in the Central Luconia offshore region are economically important global gas reservoirs. The nature of these carbonate rocks can be visually distinct in the core and the multiscale reservoir heterogeneity might vary in scale from the 100-m scale to the sub-millimeter scale. This work presents a series of steps workflow to obtain spatial information about the organization scheme of carbonate rock types, and capture the most important petrophysical and sedimentary controls on rock property distribution in the E11 field, a carbonate buildup, located in Central Luconia Province, offshore Malaysia. The spatial data were generated from a supervised neural Kohonen algorithm. The rock types predicted with this workflow were propagated using IPSOM probabilized self-organizing maps SOM. This tool is used for classifying multivariate data samples according to “patterns” or multivariate responses. The workflow includes several steps: A Step 1—Core data description, B Step 2—Thin section description, C Step 3—Well log interpretation, and D Step 4—IPSOM probabilized self-organizing maps for facies prediction SOM. The depth plots of the predicted rock type showed close correspondence to the core-based rock types in terms of the stratigraphic organization of tight and reservoir layers, proportions, and juxtaposition. This result is sufficient to merit the application of the rock type logs into a future porosity model of the E11 field, and to understand the lateral and vertical distribution of tight and reservoir rock types of distribution. The results can be used to build a future realistic digital twin of the subsurface, and in digital geological modeling.

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15

Jamaludin, S. N. Fathiyah, Manuel Pubellier, and David Menier. "Relationship between syn-depositional faulting and carbonate growth in Central Luconia Province, Malaysia." Bulletin of the Geological Society of Malaysia 60 (December 1, 2014): 77–83. http://dx.doi.org/10.7186/bgsm60201408.

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16

Jamaludin, Siti Nur Fathiyah, Manuel Pubellier, and David Menier. "Structural Restoration of Carbonate Platform in the Southern Part of Central Luconia, Malaysia." Journal of Earth Science 29, no. 1 (November 15, 2017): 155–68. http://dx.doi.org/10.1007/s12583-017-0812-y.

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17

Mohammed, Hassan Salisu, and Siti Nur Fathiyah Jamaludin. "INTEGRATED ANALYSIS FOR ASSESSMENT OF DEEPER HYDROCARBON PLAY POTENTIAL IN REBAB-1, CENTRAL LUCONIA PROVINCE, SARAWAK." Platform : A Journal of Science and Technology 6, no. 1 (June 30, 2023): 12. http://dx.doi.org/10.61762/pjstvol6iss1art22847.

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The basin history, thermal maturity, and hydrocarbon entrapments of Rebab-1 Well in Central Luconia have been relooked through the study of seismic, well log, and geochemical data to find new hydrocarbon potential in the deeper section of the well. The quality of source rocks in this area was based on assumptions, and hydrocarbon exploitation only occurs on shallow hydrocarbon plays making the potential for deeper plays difficult to ascertain. This study was conducted based on two 2D seismic lines, integrated with well lithological and stratigraphy data and geochemical data such as total organic carbon, pyrolysis, and vitrinite reflectance. Integration of these data was used to determine the deeper hydrocarbon play of Rebab-1 in Central Luconia Province. The seismic data were interpreted using Petrel software with validation from the report. Cross-plots from bulk geochemical analysis data were interpreted for the source rock's organic richness, kerogen quality, hydrocarbon-generating potentials, and thermal maturation levels. The results of seismic interpretations showed that extensional and compressional tectonics shaped the field of Rebab-1, with structures mainly trending to the NW-SE and NE-SW directions. Geochemical analysis showed that the total organic carbon content (TOC) of the samples analysed ranges between 0.06 and 2.98 wt.% indicating fair to very good source rocks producing mainly type II and mixed type II-III kerogen as the dominant kerogen. These types can generate mainly gas and mixed oil and gas accumulations upon attaining thermal maturation level. Also, Rebab-1 shows fair to very good hydrocarbon-generating potentials. The vitrinite reflectance (Ro) and Tmax results showed that the analysed samples are generally plotted in the immature, mature, and post-mature stages of oil generation but still within the gas generation window. Overall, source rocks from Rebab-1 can be said to have attained maturity at the youngest during depositions of Cycle III to older than that, and faulting and folding serves as hydrocarbon trap systems, indicative of potential in having deeper hydrocarbon plays in Rebab-1 well.

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18

Jamalullail, Aqilah Amir, Ong Swee Keong, Nik Ruzaimi Akmal Nik Ruhadi, Tengku Mohd Syazwan Tengku Hassan, Detchai Ittharat, Phalaphoom Thamniyom, Suphawich Thanudamrong, Zulkarnain Anas, and Stanley Kampit. "Unravelling an abandoned giant in Central Luconia Province, offshore Sarawak, Malaysia — Success story of Lang Lebah." Leading Edge 39, no. 8 (August 2020): 566–73. http://dx.doi.org/10.1190/tle39080566.1.

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In 1994, two exploration wells were drilled consecutively to explore for gas prospectivity in Lang Lebah, a Miocene carbonate buildup in the geologic province of Central Luconia located in the Sarawak Basin in Malaysia. High overpressure and operational problems prevented both wells from fully evaluating the target. Postdrill analysis concluded that Lang Lebah has limited potential due to poor reservoir quality, small gas column, and challenging drilling conditions. For these reasons, it was left dormant for 25 years. In 2016, new 3D broadband seismic acquisition and megamerge reprocessing of 3D seismic data sets followed by an integrated application of multidisciplinary workflows successfully derisked key petroleum system elements of the Lang Lebah structure, yielding a more optimistic view of its potential. A new well was justified at Lang Lebah and resulted in one of the major gas discoveries of 2019.

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19

Tariq Janj, Hammad, Ahmed Mohammad A, and Deva Parsed Gho. "Sedimentology and Reservoir Geometry of the Miocene Carbonate Deposits in Central Luconia, Offshore, Sarawak, Malaysia." Journal of Applied Sciences 17, no. 4 (March 15, 2017): 153–70. http://dx.doi.org/10.3923/jas.2017.153.170.

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20

Sim, Donald, and Guenter Jaeger. "Tectonostratigraphy and trap styles of the Half-Graben sub-province in West Luconia, offshore Sarawak." Bulletin of the Geological Society of Malaysia 49 (April 1, 2006): 107–10. http://dx.doi.org/10.7186/bgsm49200617.

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21

JANJUHAH, Hammad Tariq, José Antonio GÁMEZ VINTANED, Ahmed Mohamed Ahmed SALIM, Ibrahima FAYE, Mumtaz Muhammad SHAH, and Deva Prasad GHOSH. "Microfacies and Depositional Environments of Miocene Isolated Carbonate Platforms from Central Luconia, Offshore Sarawak, Malaysia." Acta Geologica Sinica - English Edition 91, no. 5 (October 2017): 1778–96. http://dx.doi.org/10.1111/1755-6724.13411.

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22

Zampetti, V., W. Schlager, J. H. van Konijnenburg, and A. J. Everts. "3-D Seismic Characterization of Submarine Landslides on a Miocene Carbonate Platform (Luconia Province, Malaysia)." Journal of Sedimentary Research 74, no. 6 (November 1, 2004): 817–30. http://dx.doi.org/10.1306/040604740817.

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23

Noad, Jon. "The Gomantong Limestone of eastern Borneo: a sedimentological comparison with the near-contemporaneous Luconia Province." Palaeogeography, Palaeoclimatology, Palaeoecology 175, no. 1-4 (December 2001): 273–302. http://dx.doi.org/10.1016/s0031-0182(01)00376-5.

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24

Henglai, Puntira, Rattanaporn Fongngern, and Arthur Saller. "The growth and demise of a Middle Miocene carbonate platform in Central Luconia, offshore Malaysia." Marine and Petroleum Geology 163 (May 2024): 106763. http://dx.doi.org/10.1016/j.marpetgeo.2024.106763.

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25

Chalabi, Aicha, B. Pierson, and Jasmi Ab Talib. "Remote Sensing Analysis of Recent Carbonate Platforms, East of Sabah: Potential Analogues for Miocene Carbonate Platforms of the South China Sea." Indonesian Journal on Geoscience 7, no. 3 (September 28, 2012): 123–35. http://dx.doi.org/10.17014/ijog.7.3.123-135.

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DOI: 10.17014/ijog.v7i3.141Recent carbonate platforms may provide useful analogues for fossil platforms and reefs, and could allow the generation of quantitative tools for the prediction of facies distribution, reservoir volumes, and reservoir quality. Data from these modern analogues would greatly enhance our ability to construct more reliable and calibrated reservoir models for carbonate fossil fields, such as the Miocene carbonate platforms of Central Luconia Province, Sarawak. In this study, carbonate facies maps and quantitative reservoir data will be generated by using remote sensing techniques. Satellite imageries over the carbonate platforms east of Sabah have been acquired and processed for generating facies maps. In order to produce a reliable facies map, the composition and grain size distribution of the sediments that make up individual facies must be known in order to determine the classes that have been identified on the initial facies maps. Samples collected from the Gaya and Selekan platforms were analyzed and the results of grain size analysis are illustrated.

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Zampetti, Valentina, Wolfgang Schlager, Jan-Henk Van Konijnenburg, and Arnout-Jan Everts. "Depositional history and origin of porosity in a Miocene carbonate platform of Central Luconia, offshore Sarawak." Bulletin of the Geological Society of Malaysia 47 (December 1, 2003): 139–52. http://dx.doi.org/10.7186/bgsm47200311.

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Nakashima, Keishi, and Koktho Chow. "Gas migration and accumulation systems in Miocene carbonate build-ups, Central Luconia area, offshore Sarawak, Malaysia." Journal of the Japanese Association for Petroleum Technology 64, no. 3 (1999): 219–32. http://dx.doi.org/10.3720/japt.64.219.

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Janjuhah, Hammad Tariq, Abubaker Alansari, Deva Prasad Ghosh, and Yasir Bashir. "New approach towards the classification of microporosity in Miocene carbonate rocks, Central Luconia, offshore Sarawak, Malaysia." Journal of Natural Gas Geoscience 3, no. 3 (June 2018): 119–33. http://dx.doi.org/10.1016/j.jnggs.2018.05.001.

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Hamdan, N. Haziqah, and S. N. Fathiyah Jamaludin. "Reservoir characteristics of carbonates build-ups in southern Central Luconia Province: A study based on different scales." Bulletin of the Geological Society of Malaysia 66, no. 1 (December 1, 2018): 99–105. http://dx.doi.org/10.7186/bgsm66201813.

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Bashir, Yasir, Muhammad Amir Faisal, Ajay Biswas, Amir abbas Babasafari, Syed Haroon Ali, Qazi Sohail Imran, Numair Ahmed Siddiqui, and Muhsan Ehsan. "Seismic expression of miocene carbonate platform and reservoir characterization through geophysical approach: application in central Luconia, offshore Malaysia." Journal of Petroleum Exploration and Production Technology 11, no. 4 (April 2021): 1533–44. http://dx.doi.org/10.1007/s13202-021-01132-2.

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AbstractA substantial proportion of proven oil and gas reserves of the world is contained in the carbonate reservoir. It is estimated that about 60% of the world’s oil and 40% of gas reserves are confined in carbonate reservoirs. Exploration and development of hydrocarbons in carbonate reservoirs are much more challenging due to poor seismic imaging and reservoir heterogeneity caused by diagenetic changes. Evaluation of carbonate reservoirs has been a high priority for researchers and geoscientists working in the petroleum industry mainly due to the challenges presented by these highly heterogeneous reservoir rocks. It is essential for geoscientists, petrophysicists, and engineers to work together from initial phases of exploration and delineation of the pool through mature stages of production, to extract as much information as possible to produce maximum hydrocarbons from the field for the commercial viability of the project. In the absence of the well-log data, the properties are inferred from the inversion of seismic data alone. In oil and gas exploration and production industries, seismic inversion is proven as a tool for tracing the subsurface reservoir facies and their fluid contents. In this paper, seismic inversion demonstrates the understanding of lithology and includes the full band of frequency in our initial model to incorporate the detailed study about the basin for prospect evaluation. 3D seismic data along with the geological & petrophysical information and electrologs acquired from drilled wells are used for interpretation and inversion of seismic data to understand the reservoir geometry and facies variation including the distribution of intervening tight layers within the Miocene carbonate reservoir in the study area of Central Luconia. The out-come of the seismic post-stack inversion technique shows a better subsurface lithofacies and fluid distribution for delineation and detailed study of the reservoir.

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Kosa, Eduard, Georg M. D. Warrlich, and Guy Loftus. "Wings, mushrooms, and Christmas trees: The carbonate seismic geomorphology of Central Luconia, Miocene–present, offshore Sarawak, northwest Borneo." AAPG Bulletin 99, no. 11 (November 2015): 2043–75. http://dx.doi.org/10.1306/06181514201.

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32

Koša, Eduard. "Sea-level changes, shoreline journeys, and the seismic stratigraphy of Central Luconia, Miocene-present, offshore Sarawak, NW Borneo." Marine and Petroleum Geology 59 (January 2015): 35–55. http://dx.doi.org/10.1016/j.marpetgeo.2014.07.005.

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33

Rankey, Eugene C., Markus Schlaich, Sofiyah Mokhtar, George Ghon, Syed Haroon Ali, and Michael Poppelreiter. "Seismic architecture of a Miocene isolated carbonate platform and associated off-platform strata (Central Luconia Province, offshore Malaysia)." Marine and Petroleum Geology 102 (April 2019): 477–95. http://dx.doi.org/10.1016/j.marpetgeo.2019.01.009.

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34

Janjuhah, Hammad Tariq, Ahmed Mohammad Ahmed Salim, Mumtaz Muhammad Shah, Deva Ghosh, and Abubaker Alansari. "Quantitative interpretation of carbonate reservoir rock using wireline logs: a case study from Central Luconia, offshore Sarawak, Malaysia." Carbonates and Evaporites 32, no. 4 (June 29, 2017): 591–607. http://dx.doi.org/10.1007/s13146-017-0361-6.

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35

Janjuhah, Hammad Tariq, Abubaker Alansari, and José Antonio Gámez Vintaned. "Quantification of microporosity and its effect on permeability and acoustic velocity in Miocene carbonates, Central Luconia, offshore Sarawak, Malaysia." Journal of Petroleum Science and Engineering 175 (April 2019): 108–19. http://dx.doi.org/10.1016/j.petrol.2018.12.035.

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36

Zampetti, Valentina, Wolfgang Schlager, Jan-Henk van Konijnenburg, and Arnout-Jan Everts. "Architecture and growth history of a Miocene carbonate platform from 3D seismic reflection data; Luconia province, offshore Sarawak, Malaysia." Marine and Petroleum Geology 21, no. 5 (May 2004): 517–34. http://dx.doi.org/10.1016/j.marpetgeo.2004.01.006.

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37

Vahrenkamp, Volker C. "Miocene carbonates of the Luconia province, offshore Sarawak: implications for regional geology and reservoir properties from Strontium-isotope stratigraphy." Bulletin of the Geological Society of Malaysia 42 (December 30, 1998): 1–13. http://dx.doi.org/10.7186/bgsm42199801.

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Vahrenkamp, Volker C., Yusoff Kamari, and Syed Abd. Rahman. "Three dimensional reservoir geological model and multiple scenario volumetrics of the F23 Miocene carbonate buildup, Luconia Province, offshore Sarawak." Bulletin of the Geological Society of Malaysia 42 (December 30, 1998): 15–26. http://dx.doi.org/10.7186/bgsm42199802.

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39

Fyhn, Michael B. W., Stig A. S. Pedersen, Lars O. Boldreel, Lars H. Nielsen, Paul F. Green, Phan T. Dien, Luong T. Huyen, and Dirk Frei. "Palaeocene–early Eocene inversion of the Phuquoc–Kampot Som Basin: SE Asian deformation associated with the suturing of Luconia." Journal of the Geological Society 167, no. 2 (March 2010): 281–95. http://dx.doi.org/10.1144/0016-76492009-039.

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40

Warrlich, Georg M. D., Erwin W. Adams, Artur Ryba, Tommy Tam, King King Ting, and Hooi-Koon Tang. "What matters for flow and recovery in carbonate gas reservoirs: Insights from the mature Central Luconia Province, offshore Sarawak, Malaysia." AAPG Bulletin 103, no. 3 (March 2019): 691–721. http://dx.doi.org/10.1306/09051817219.

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41

Salman, Nurul Fatin Izzatie, Mohamed Elsaadany, and Abdul Halim Abdul Latiff. "Karst geomorphology analysis for geohazard assessment via seismic relief and dip attributes in Jx carbonate field, Central Luconia Province, Malaysia." Bulletin of the Geological Society of Malaysia 78, no. 1 (November 30, 2024): 39–57. http://dx.doi.org/10.7186/bgsm78202405.

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Carbonate reservoirs in the Central Luconia Province of Malaysia underwent significant karstification during the Miocene. Such features have a detrimental impact on drilling operations, as has been reported for over 40 years in this province. This implies that the karst architecture and geometry may exhibit potentially high-risk behaviours during drilling activities, necessitating a thorough investigation of the features. This study aims to achieve several objectives using Jx field subsurface data, i.e., 3D seismic data and well data, including (1) analysing the interrelationship between karsts and faults, (2) examining the appropriate and effective attributes for analysing the geomorphology of the karst surfaces, and (3) conducting comparative and analog studies to gain a comprehensive understanding of karst formation and characteristics. This research attempted to determine the dimensions and extent of the faults and karsts, which were discovered to be highly connected, and this endeavor is critical for assessing the potential hazardous risk features within the platform. The major fault lineaments that bound the study field were interpreted using the Automatic Fault Extraction (AFE) module application combined with the manual fault-picking technique in the PaleoScan 2022 software. Four main horizon surfaces within the carbonate interval were selected for evaluating karst geomorphology using appropriate seismic attributes, as geomorphology is an important subject that requires serious attention, particularly when determining low-risk regions for drilling programs. Two attributes were extracted from the horizon surfaces: seismic relief and dip attributes, which efficiently distinguish the karst features and define the structural morphology of karsts. Dendritic karst networks, as well as karst collapses or sinkholes, are the most common karst features observed. These features exhibit discontinuity form and synclinal expression (high dip magnitude) when viewed in seismic and using the applied attributes. The comparative and analog study was conducted in Niah Caves, Miri, Sarawak, Malaysia, using karst interpretation employing digital elevation model (DEM) maps and fieldwork. Most of the delineated karst features observed on the DEM map of the Niah Caves are similar to those discovered in the Jx field; however, their dimensions vary between the two carbonate buildups.

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42

Madon, Mazlan, and John Jong. "Multi-phase subsidence history of the Sarawak continental margin and its regional significance." Bulletin of the Geological Society of Malaysia 76 (November 30, 2023): 81–99. http://dx.doi.org/10.7186/bgsm76202307.

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Subsidence analysis of Sarawak Basin using stratigraphic data from a selection of exploration wells revealed a multi-phase history of crustal extension (rifting), subsidence and uplift. A relatively rapid subsidence during the early rift phase from Eocene to Oligocene (ca. 37–28 Ma) was followed by a gradual decrease in subsidence rate as the extended lithosphere underwent post-rift thermal relaxation (ca. 28–22 Ma). A second phase of extension during the Early Miocene (ca. 22–17 Ma) resulted in an increase in subsidence rate, which coincided with a major episode of compressional deformation, uplift and localised erosion. This deformation event culminated in a major unconformity dated ~16 Ma, known as the Middle Miocene Unconformity (MMU), which is recognised throughout the Bunguran Trough and North Luconia regions of Sarawak Basin as a major stratigraphic hiatus spanning the Early to Middle Miocene. Since the Late Miocene, there had been an increase in the subsidence rate, probably due to progradation of the Sarawak shelf to its present-day configuration. The complex subsidence history of Sarawak Basin is similar to those reported from other parts of the South China Sea margin. The subsidence histories indicate a common, underlying tectonic factor which is probably related to rifting and sea-floor spreading in the southwestern prong of the South China Sea oceanic basin.

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43

Salleh, Nur Farhana, Maman Hermana, and Nik Nur Anis Amalina Nik Mohd Hassan. "Reducing the risk of low saturation gas using controlled-source electromagnetic (CSEM) in K-Field, Central Luconia: a forward modeling case study." IOP Conference Series: Earth and Environmental Science 1003, no. 1 (April 1, 2022): 012045. http://dx.doi.org/10.1088/1755-1315/1003/1/012045.

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Abstract The application of controlled-source electromagnetic (CSEM) in hydrocarbon exploration significantly facilitates the detection of economic hydrocarbon. The method captures anomalies through the resistivity contrast between the overburdens and hydrocarbon-bearing lithologies. In most cases, the resistivity contrast is only prominent when there is sufficient hydrocarbon saturation. K-Field is situated on the continental shelf of Sarawak Basin, a sub-mature area for oil and gas in the Central Luconia province. Despite the low saturation of the gas in the Cycle VI sand, the seismic data shows a strong amplitude in the shallow section. Therefore, this study is conducted to assess the change of resistivity and CSEM response to the gas saturation and thickness variations of thin-gas sand in the K-Field. 3D resistivity models and three exploration wells are provided and two main methods are implemented in this study comprising the resistivity and CSEM forward modelings. The resistivity modeling is conducted using the Indonesia water saturation equation for different gas saturation scenarios and subsequently, the modeled resistivity is inputted in 1D and 2.5D CSEM forward modeling. The modeled CSEM response analysis is done by normalizing the modeled CSEM amplitude to the background or also known as normalized amplitude response (NAR). In gas saturation variation, the modeled resistivity showed an insignificant resistivity increase from 0.45Ωm to 0.55Ωm from wet case to 5% of gas and strongly increases to 35Ωm at 90% of gas saturation. The 1D CSEM NAR shows a very weak response of less than a 3% increase for 5% of gas and up to 230% increase for 90% of gas. In gas thickness variation, the CSEM NAR is weak and less than a 15% cutoff for all the tested thicknesses for 5% and 45% of in-situ gas. At 70% of gas, 25m is the minimum detected gas thickness with a 17.5% response increase, and at 90% of gas, the response is already strong at a minimum 5m thickness with a 35% increase. The modeled 2D CSEM responses also show that only 70% and 90% of gas sand layers in the K-field were delineated distinctively by the inline receivers with a 40% and 200% response increase respectively.

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44

Janjuhah, Hammad Tariq, Abubaker Alansari, and Priveen Raj Santha. "Interrelationship Between Facies Association, Diagenetic Alteration and Reservoir Properties Evolution in the Middle Miocene Carbonate Build Up, Central Luconia, Offshore Sarawak, Malaysia." Arabian Journal for Science and Engineering 44, no. 1 (June 6, 2018): 341–56. http://dx.doi.org/10.1007/s13369-018-3341-9.

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45

Carpenter, Chris. "Leakage Rate Modeling in Depleted Gas Fields Safeguards Well Integrity, CO2 Storage." Journal of Petroleum Technology 74, no. 01 (January 1, 2022): 84–86. http://dx.doi.org/10.2118/0122-0084-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 205537, “Safeguarding CO2 Storage by Restoring Well Integrity Using Leakage Rate Modeling Along the Wellbore in Depleted Gas Fields Offshore Sarawak,” by Parimal Patil, SPE, Prasanna Chidambaram, SPE, and M. Syafeeq B. Ebining Amir, Petronas, et al. The paper has not been peer reviewed. Ensuring the long-term integrity of existing plugged and abandoned (P&A) and active wells that penetrated a studied CO2 storage reservoir was key to reduction of leakage risks along the well path for long-term containment sustainability. With a goal of developing depleted gas ﬁelds as carbon dioxide (CO2) storage sites in oﬀshore Sarawak, determining the complexity involved in restoring the integrity of these P&A wells, as well as the development wells, is critical. Leakage-rate modeling (LRM) was performed to identify and evaluate the associated risks for designing the remedial action plan. CO2 Storage Challenges in Central Luconia Storage sites in this study include three major depleted gas reservoirs in the Central Luconia gas ﬁeld oﬀshore Sarawak. Hydrocarbons from deeply buried reservoirs were produced through drilling of vertical and deviated wells. Thirty-eight wells were drilled in these three depleted gas reservoirs, of which 11 are exploration wells that had been P&A; 27 wells include active producers, water injectors, and idle wells. By estimating the performance of well-barrier elements in the legacy P&A wells and existing development wells, an assessment of well integrity analysis was performed. The casing, as well as the cement, may degrade with time depending on the downhole temperature, pressure, stress conditions, and formation ﬂuids. Degradation of wellbore cement in the presence of carbonized acid ﬂuids poses a risk of creating leakage pathways. Understanding the local stress conditions acting on the cement/casing/formation sheath is important to increase knowledge regarding leakage-pathway creation, together with geochemical and geomechanics processes. CO2 Storage Well Integrity Risk Assessment Once the locations of the existing P&A wells were identiﬁed, site-inspection data helped deﬁne the preparation required to assess possible gas seepage or the existence of leakage pathways along these wellbores. The measured leakage amount of gas/CO2 could then be used to backfeed the simulation model to identify the leakage system along the wellbore. The method uses desktop modeling studies together with site surveys using a remotely operated vehicle (ROV) or side scan sonar. The modeling helps simulate various leakage scenarios, while actual ﬁeld measurements for any bubbling at the seabed provide the critical inputs to reﬁne the modeling work to deﬁne the risk associated with each well. To gauge the integrity of storage sites for each well, a comprehensive understanding of critical factors and dominant criteria had to be considered as part of the data-evaluation process. Tables 1 and 2 of the complete paper define the risk-assessment elements for the existing P&A exploration and appraisal wells and development wells, respectively, used for the risk-assessment exercise. The risk-assessment process includes identification of risk, risk analysis, and risk evaluation. All wells that penetrated the CO2 storage reservoir were benchmarked as a baseline for a corrosive storage environment. Such data are useful for forecasting the possible leakage rates at the CO2 sequestration site.

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46

Carpenter, Chris. "Three-Way Coupled Modeling Evaluates CO2 Sequestration in Depleted Reservoir." Journal of Petroleum Technology 75, no. 01 (January 1, 2023): 64–66. http://dx.doi.org/10.2118/0123-0064-jpt.

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_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 206156, “Importance of Three-Way Coupled Modeling for Carbon-Dioxide Sequestration in a Depleted Reservoir,” by Prasanna Chidambaram, SPE, Pankaj K. Tiwari, SPE, and Parimal A. Patil, SPE, Petronas, et al. The paper has not been peer reviewed. _ Three major depleted gas reservoirs in the Central Luconia field offshore Sarawak, Malaysia, are being evaluated for future carbon-dioxide (CO2) storage. A three-way coupled modeling approach that integrates dynamic, geochemistry, and geomechanics models is used to obtain the cumulative effect of all three changes. This integrated model provides a more-accurate estimate of CO2 storage capacity, caprock-integrity evaluation, CO2-plume migration path, and volume of CO2 stored through different mechanisms. Background The CO2 storage sites being evaluated are depleted gas reservoirs that have been in production for a few decades. At the end of their producing life, they have the potential to be converted into CO2 storage sites. The Central Luconia sedimentary basin is in a seismic-free zone with limited faults and consists of shale interbedded with high-sand-content sediment, making it ideal for CO2 storage. These reservoirs provide the required geological characteristics and volume needed to ensure long-term CO2 storage in a safe and economical way. The depleted gas reservoirs have an in-place volume of approximately 1.5–3 Tscf. Their thickness ranges from 100 to 150 m, with a porosity of 15–32% and permeability of 10–1600 md. These fields are believed to be supported by a regional aquifer several thousand feet thick. Large seafloor subsidence has been observed in these reservoirs. Storage-Capacity Estimation Storage capacity of a depleted hydrocarbon reservoir is affected by several factors including voidage created; aquifer influx and efflux during the production and CO2-injection phases, respectively; maximum injection pressure; rock compressibility; and geochemical effects. Depending on which of these factors are prominent in the storage reservoir, CO2-storage capacity may be estimated using a simple material-balance model or may require a more-complex approach to capture these effects. Use of the Three-Way Coupled Model Injected CO2 is anticipated to react with reservoir rock, leading to either dissolution of reservoir rock or precipitation of solids that are products of the geochemical reactions, causing a net change in porosity and permeability. With regard to geomechanical effects, uplift is anticipated to occur during CO2 injection. The degree to which subsidence is reversed depends on whether compaction of the reservoir is fully elastic or if plastic deformation has occurred. During production, reduction in porosity and permeability has occurred because of subsidence. Conventional or stand-alone reservoir simulation does not capture geochemical and geomechanical effects. Hence, it is critical to use an integrated model that captures the effects of dynamic, geochemical, and geomechanical changes caused by CO2 injection in order to evaluate suitability of the reservoir for long-term CO2 storage. A three-way coupled modeling approach that integrates dynamic, geochemistry, and geomechanics models provides a more-accurate estimate of CO2 storage capacity, along with estimation of subsidence. In three-way coupled modeling, the dynamic model is at the center, which passes input parameters to the geochemical and geomechanical models. Once it receives updated porosity and permeability values back from the geochemical and geomechanical models, the dynamic model incorporates these changes before proceeding to the next simulation timestep.

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47

Ong, Poh Yee, and Siti Nur Fathiyah Jamaludin. "Fracture Network Analysis of Karstified Subis Limestone Build-Up in Niah, Sarawak." Applied Sciences 13, no. 22 (November 7, 2023): 12110. http://dx.doi.org/10.3390/app132212110.

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Understanding complex carbonate fracture networks and karstification at various geological scales is challenging, especially with limited multi-scale datasets. This paper aims to reduce uncertainty in the fracture architecture of Central Luconia karstified reservoirs by narrowing observational gaps between seismic and well data by using the discrete fracture models of exposed limestone outcrops as analogues for the subsurface carbonate reservoir. An outcrop-based fracture network characterisation of a near-surface paleo-karst at Subis Limestone combined with lineament analysis was conducted to extract fracture parameters. The karst structure was first delineated using a digital elevation map and outcrop examination. Then, topology analysis was performed, following the creation of two-dimensional discrete fracture models. Two main fracture sets oriented northeast–southwest and northwest–southeast and 79 potential dolines were identified. Fracture intersections, northeast–southwest major orientations, and drainage systems highly influenced the karst features. The Subis Limestone fracture model revealed that the highest number of fractures and total length of fractures were concentrated in the northern part of the Subis Limestone build-up (X: 250–350, Y: 150–250) and became denser towards the northwest direction of the outcrop (X: 600–800). The fractures in the Subis paleo-karsts appear isolated, with I-nodes ranging from 0.74 to 0.94. Hence, it is crucial to incorporate matrix porosity into multiple scales of fracture network modelling to improve upscaling and the modelling of fracture–vug networks, as well as to minimise the underestimation of discrete fracture networks in fractured and karstified limestone.

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48

Janjuhah, Hammad Tariq, George Kontakiotis, Abdul Wahid, Dost Muhammad Khan, Stergios D. Zarkogiannis, and Assimina Antonarakou. "Integrated Porosity Classification and Quantification Scheme for Enhanced Carbonate Reservoir Quality: Implications from the Miocene Malaysian Carbonates." Journal of Marine Science and Engineering 9, no. 12 (December 10, 2021): 1410. http://dx.doi.org/10.3390/jmse9121410.

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The pore system in carbonates is complicated because of the associated biological and chemical activity. Secondary porosity, on the other hand, is the result of chemical reactions that occur during diagenetic processes. A thorough understanding of the carbonate pore system is essential to hydrocarbon prospecting. Porosity classification schemes are currently limited to accurately forecast the petrophysical parameters of different reservoirs with various origins and depositional environments. Although rock classification offers a way to describe lithofacies, it has no impact on the application of the poro-perm correlation. An outstanding example of pore complexity (both in terms of type and origin) may be found in the Central Luconia carbonate system (Malaysia), which has been altered by diagenetic processes. Using transmitted light microscopy, 32 high-resolution pictures were collected of each thin segment for quantitative examination. An FESEM picture and a petrographic study of thin sections were used to quantify the grains, matrix, cement, and macroporosity (pore types). Microporosity was determined by subtracting macroporosity from total porosity using a point-counting technique. Moldic porosity (macroporosity) was shown to be the predominant type of porosity in thin sections, whereas microporosity seems to account for 40 to 50% of the overall porosity. Carbonates from the Miocene have been shown to possess a substantial quantity of microporosity, making hydrocarbon estimate and production much more difficult. It might lead to a higher level of uncertainty in the estimation of hydrocarbon reserves if ignored. Existing porosity classifications cannot be used to better understand the poro-perm correlation because of the wide range of geological characteristics. However, by considering pore types and pore structures, which may be separated into macro- and microporosity, the classification can be enhanced. Microporosity identification and classification investigations have become a key problem in limestone reservoirs across the globe.

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49

Babasafari, Amir Abbas, Yasir Bashir, Deva Prasad Ghosh, Ahmed Mohammed Ahmed Salim, Hammad Tariq Janjuhah, Sayed Hesammoddin Kazemeini, and Masoumeh Kordi. "A new approach to petroelastic modeling of carbonate rocks using an extended pore-space stiffness method, with application to a carbonate reservoir in Central Luconia, Sarawak, Malaysia." Leading Edge 39, no. 8 (August 2020): 592a1–592a10. http://dx.doi.org/10.1190/tle39080592a1.1.

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Pore geometry plays an important role in the elastic response of carbonate rocks. Diagenetic processes in carbonate sediments generate a range of pore-type distributions. Hence, the petroelastic modeling (PEM) of carbonate rocks is more complex than for clastics. Petrophysical properties connect to elastic properties through PEM or, in general terms, rock-physics modeling. Pore types cause variation in P-wave velocity — up to 40% for a given porosity. A variety of pore types with different aspect ratios such as vuggy, moldic, interparticle, intraparticle, fracture, and crack makes the porosity-velocity relationship complex, and empirical models fail to handle it properly. We propose a new, easy-to-implement approach for PEM of carbonate rocks that leads to more accurate elastic properties estimation. It offers a novel PEM method that reduces the number of defined parameters and equations. In it, the Xu-Payne rock-physics modeling equations are replaced with an extended pore-space stiffness equation. Instead of including a pore's aspect ratio as is done when using the Xu-Payne inclusion model formulation, in our proposed technique only the appropriate value of pore-space stiffness for each pore type is considered, together with the corresponding volume fraction of pore types. However, parameters are optimized by calibrating the estimated elastic properties with corresponding information from well-log measurements. This inclusion model yields acceptable predictions of elastic properties at wells that do not have measured elastic logs. The method was tested using well data from a carbonate reservoir in Central Luconia, offshore Sarawak, Malaysia. Here, one well has a complete suite of log data needed to calibrate the model. The calibrated model was then used to predict the missing shear velocity log in the other well. Next, simultaneous elastic seismic inversion was performed on 3D seismic data covering the area of the carbonate reservoir, and elastic property volumes (acoustic impedance and VP/VS ratio) were estimated. From these results, a posterior probability distribution of stiff pore types was determined, which validated the outcome of this approach using a blind test.

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50

Xu, Junjie, Jianye Ren, and Pan Luo. "The evolution of a gravity-driven system accompanied by diapirism under the control of the prograding West Luconia Deltas in the Kangxi Depression, Southern South China Sea." Marine Geophysical Research 40, no. 2 (March 26, 2019): 199–221. http://dx.doi.org/10.1007/s11001-019-09384-8.

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