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Results
Petrophysical Evaluation Of Complex Gas Reservoirs In North-West China
Lu, Wendong (Schlumberger) | Murray, Doug (Schlumberger) | Wang, Yuxi (Schlumberger) | Li, Wei (Schlumberger) | Yang, Lei (Schlumberger) | Desport, Olivier (Schlumberger) | Xiao, Chengwen (Chinese National Petroleum Company) | Wei, Guo (SinoChem Corporation)
ABSTRACT: Gas reservoirs of north-west China are characterized by deep burial, complex lithology, high-angle beds, low porosity, low permeability, and high water salinity. As such, reservoir evaluation with conventional logging tools like resistivity and neutron-density have a high degree of uncertainty. Incorporating more modern logging techniques like nuclear capture spectroscopy, epithermal neutron measurements, borehole imaging, and dipole sonic reduces uncertainty and helps identify gas-saturated reservoirs. Lithology evaluation of the complex sandstone reservoirs in north-west China is significantly improved with the addition of nuclear spectroscopy logs. Nuclear capture spectroscopy data indicate that the sandstone formations contain both calcite cement and disseminated anhydrite. An accurate understanding of lithology is critical for porosity estimation and is particularly important for the low-porosity formations encountered. The low-porosity reservoirs also contain dissolved pores, intergranular pores, and fractures. Reservoir water analysis indicated that formation water salinity is approximately 200,000 ppm. Compared to thermal neutron measurements, the epithermal neutron shows reduced environmental effects due to both high salinity and clay volume and thus provides more representative measurements of formation porosity. Computed formation dips from borehole image data ranged from 30° to 70°. The combination of a complicated pore structure and environmental effects makes traditional approaches of determining fluid saturations from resistivity logs problematic. The paper highlights a practical approach in these complicated reservoirs for fluid identification and saturation estimation with the addition of modern logging tools. INTRODUCTION Gas reservoirs of north-west China are characterized by deep burial, complex lithology, high-angle beds, low porosity, low permeability, and high water salinity. These complex reservoirs have traditionally been evaluated with conventional well logs and a relatively simple lithology model of sand/shale. Errors in lithology determination can lead to errors in the computation of porosity, a key formation evaluation parameter.
- Asia > China (1.00)
- North America > United States > Texas (0.29)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.57)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
ABSTRACT: A new method is presented for the estimation of the fast shear direction using a crossed-dipole sonic tool. This technique does not require the two orthogonal dipole transmitters to be matched in their excitation, nor does it require the transmitters to be colocated or depth aligned. A significant processing advancement with this algorithm is that it can be applied to just a single set of in-line and cross-line dipole waveforms from one dipole transmitter under favorable conditions. In such cases, anisotropy can be confirmed independently by processing the orthogonal dipole transmitter set of inline and crossline dipole waveforms. Also, time windowing of the waveform data is not required, as the processing is done in the frequency domain using the flexural dispersion over the full bandwidth of the data. The fast shear orientation is obtained by minimizing an objective function defined by the difference between the inline and crossline signal spectra from a flexural wave-splitting model and the corresponding measured waveform spectra as a function of azimuth. This approach uses the fast and slow flexural dispersion curves, which can be obtained from the waveform data either by the modified Prony or matrix pencil algorithm (Ekstrom, 1995) or by other approaches, such as a recently developed flexural dispersion estimation algorithm (Wang, 2006). Fast and slow shear slownesses are determined from the estimated fast and slow flexural dispersion curves after rotation of the waveform data. Hence, the estimate of anisotropy is a quantitative indicator of anisotropy based on slowness. Examples comparing this new anisotropy method with Alford rotation demonstrate this is a robust technique for estimating both fast-shear orientation and fast and slow shear slownesses. Results come from a vertical well where stress induced anisotropy is present and a horizontal well where polar anisotropy is dominant.
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.68)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Understanding Elastic Properties And Acoustic Anisotropy At the Pore/grain Scale
Arad, Alon (Research School of Earth Sciences) | Christy, Andrew G. (Research School of Earth Sciences) | Madadi, Mahyar (Australian National University) | Sheppard, Adrian P. (Australian National University) | Averdunk, Holger (Australian National University) | Knackstedt, Mark A. (Australian National University, DigitalCore)
ABSTRACT: This paper focuses on two main aspects of reservoir rock characterisation. The first is the use of imaging techniques including optical microscopy, scanning electron microscope (SEM), 3D X-ray computer tomography (CT) and image processing software to evaluate grain orientations and grain contact information for real and model rock samples. We investigate this data for various types of directional behaviour, and look for correlations between anisotropy of the sample fabric and that of seismic velocities. Secondly, we apply Finite Element Methods (FEM) to our processed 3D images of samples in order to calculate elastic constants and hence acoustic velocity behaviour of reservoir rock. Finally, we combine these two techniques and coupled petrographical/geological information, to correlate data from the simulation of elastic properties of the reservoir rock to obtain more reliable predictive behaviour. INTRODUCTION Elastic wave propagation in sedimentary rocks depends on two sets of rock properties; the volume fractions and elastic constants of the mineral phases that are present (quartz, clay, feldspar, etc.) and also geometrical aspects of the microstructure such as grain contacts, pore aspect ratio, grain cementation, and contact orientations. Previous applications of 3D image analysis have concentrated on accurately characterising the volume fractions and elastic properties of simple outcrop sandstones. In particular, resistivity and flow properties of the rock have been predicted directly from numerical simulations on 3D image data, and compare well with experimental results (1). Model acoustic properties have been accurate for well-cemented sandstones and ideal glass sphere packings. However, these idealized datasets are not appropriate analogues for reservoir sandstone samples (2). In this paper, we describe a methodology for obtaining micron-resolution 3D image data from samples, and processing the image to locate individual grains and grain boundary surfaces. We present results of this analysis for three samples, which exhibit complex triaxial acoustic anisotropy.
- North America > United States (0.46)
- Oceania > Australia (0.28)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.66)
- Geology > Mineral > Silicate > Tectosilicate (0.55)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
ABSTRACT: Dielectric measurements have been used over the past thirty years in a variety of reservoirs to determine flushed zone water-filled porosity in formations with fresh or unknown water salinity. This measurement is particularly useful in heavy oil reservoirs because little invasion occurs, making oil saturations of the uninvaded and invaded zones approximately equal. A new dielectric measurement provides dielectric permittivity and conductivity at multiple depths of investigation as a result of multiple frequencies, receiver spacings, and polarizations. This next-generation dielectric measurement is collected over a large range of operating frequencies using an array of antennas with two separate orientations. A total of nine measurements of attenuation and phase shift are made at four different frequencies, allowing for a true measure of dielectric dispersion. Inversion of these measurements computes a simple water-filled porosity, as was done with older generation dielectric tools based on a single permittivity measurement. By measuring permittivity and conductivity at different frequencies, antenna spacings, and orientations it is possible to construct a water-filled porosity invasion profile. Inverting all the measurements makes it possible to solve for salinity, invasion depth, and other environmental parameters that led to unpredictable results with previous-generation single-frequency tools. Further processing will make it possible to solve for textural parameters such as saturation and cementation exponents or caution exchange capacity. Formation evaluation in the oil fields of California has always been challenging. Probably the biggest challenge faced by log analysts years ago was the difficulty of distinguishing oil from fresh formation water. This was further complicated by the inability to distinguish producible oil from oil that was not movable. Recovery factors were often 20% or less, which led to many attempts at enhanced oil recovery, of which steam floods have proved to be the most successful.
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Rock Type (0.96)
- North America > United States > California > San Joaquin Basin > San Joaquin Valley > Tulare Formation (0.99)
- Europe > Norway > Norwegian Sea > Åre Formation (0.99)
- North America > United States > California > San Joaquin Basin > Kern River Field (0.93)
- North America > United States > California > Cymric Field (0.93)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.87)
Determining Formation Dip From A Fully Triaxial Induction Tool
Wu, P. (Schlumberger) | Barber, T. (Schlumberger) | Homan, D. (Schlumberger) | Wang, G. (Schlumberger) | Johnson, C. (Schlumberger) | Heliot, D. (Schlumberger) | Kumar, A. (Schlumberger) | Ruiz, E. (Schlumberger) | Xu, W. (Schlumberger) | Hayden, R. (Schlumberger) | Jacobsen, S. (Schlumberger) | Das, R. (Brigham Oil)
ABSTRACT: A fully triaxial multiarray induction logging tool has been developed recently. The tool has six full triaxial arrays, each of which acquires a 3×3 measurement tensor that is sensitive to the formation dip and resistivity anisotropy. One important petrophysical application of triaxial induction measurements is to identify low-resistivity pay zones and reduce the uncertainty of water saturation (Sw) calculations in thin-bed reservoirs. This application has been well documented in several previous publications. In this paper, we focus on the geological applications of the triaxial induction tool: determining formation dip as well as identifying geological features such as faults, slumps, and unconformities. The sensitivity of the triaxial induction measurements to the formation dip and anisotropy for a wide range of horizontal resistivity is presented. Synthetic data are used to demonstrate the accuracies of the dip magnitude and azimuth obtained from inversion of the triaxial induction measurement. This paper presents both oil-base mud (OBM) and water-base mud (WBM) case studies in which dips obtained from borehole images and triaxial-induction-computed dips show good agreement. We also discuss some of the circumstances in which they can differ. The quality of high-resolution borehole images and accuracy of image-derived dips deteriorate in zones of borehole rugosity. This paper demonstrates that the triaxial-induction-inverted dips can be used as an effective and efficient complementary resource for geologists to construct high-quality structural cross-sections. Through synergetic use of both imaging and triaxial tools, we can have a more complete interpretation of the geology. INTRODUCTION Multicomponent induction tools (Kriegshauser et al. 2000) and triaxial induction tools (Rosthal et al. 2003; Barber 2004) were introduced by the logging industry in the last decade. A true triaxial array consists of three orthogonal, collocated transmitters and three orthogonal, collocated receivers and bucking coils as shown in the diagram of Figure 1.
- North America > United States > Texas (1.00)
- Asia (1.00)
- Europe (0.68)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.51)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
A New Gas Detection Method For Multiphase Flows Using Acoustic Resonance Spectroscopy In A Piezoelectric Cylindrical Cavity
Che, Chengxuan (State Key Laboratory of Acoustics, Institute of Acoustics, Chinese Academy of Sciences) | Wang, Xiuming (State Key Laboratory of Acoustics, Institute of Acoustics, Chinese Academy of Sciences) | Chen, Dehua (State Key Laboratory of Acoustics, Institute of Acoustics, Chinese Academy of Sciences) | Cong, Jiansheng (State Key Laboratory of Acoustics, Institute of Acoustics, Chinese Academy of Sciences) | Wang, Xiaomin (State Key Laboratory of Acoustics, Institute of Acoustics, Chinese Academy of Sciences)
ABSTRACT: The resonance characteristics of a piezoelectric cylindrical cavity, located in a borehole, are strongly influenced by borehole fluid properties, such as the borehole fluid densities and velocities. This is true especially for a gas-liquid mixed fluid. In this work, the numerical calculations for resonance frequencies of piezoelectric cylindrical cavity filled with the mixed gas-liquid fluids with various gas volume ratios are conducted. Also, an experimental measurement system is established, including a simulated production borehole filled with gas bubbles to measure the resonance frequencies. The gas bubbles follow the normal distribution with the diameter varying from 1.0mm to 5.0mm, approximately. The resonance frequencies of the piezoelectric cylindrical cavity at various gas fluxes are measured, and their influencing factors are studied. The experimental results show that the resonance frequencies of the piezoelectric cylindrical cavity decrease with the increase of the gas flux in an exponential form in the simulated borehole, which is qualitatively consistent with the numerical results. The research paves a novel way for gas volume and gas flux detection in multiphase flows in production wells. INTRODUCTION Recently, with the development of the oil and gas exploitation, the gas-liquid medium presents widely in production wells. It's very important to know the gas volume or gas flux accurately thus each phase holdup is known for oil/gas reservoir management and development optimization. However, due to the complexity and randomicity of multiphase flows, there has not been a perfect method that can be used to measure the gas volume or gas flux in production wells accurately. For example, the radiometric method is harmful to our bodies and the extracting and separating method is expensive to make use of, while the dynamical differential pressure signals technique is strongly affected by the geometric parameters of the tube, and so on.
- Research Report > New Finding (0.67)
- Research Report > Experimental Study (0.49)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Multiphase flow (0.94)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (0.67)
ABSTRACT: Borehole stratigraphic interpretation of high-resolution microresistivity images enables interpretations to enhance glacial reservoir modeling based on cores, seismic data and conventional open hole logs. The borehole stratigraphic interpretation process involves identification of sedimentary lithotypes and sedimentary structures, which one can use as an input to determine depositional environments within the glacial formation, such as glaciofluvial and glaciolacustrine. Glaciofluvial deposits include sands and gravels sorted by ice melt water; glaciolacustrine deposits range from shales and diamictites to sands and gravels, which accumulate from ice melt water and floating ice. The lithotypes of glacial deposits, such as diamictites, sandstones, pebbly sandstones and conglomerates, exhibit specific textures in microresistivity images. Sedimentary structures, such as slumping, disrupted bedding and cross bedding, relate directly to the evolution of glaciofluvial and glaciolacustrine depositional environments. Glacial reservoirs, which are uncommon and poorly understood worldwide, exhibit lateral variability and completely unpredictable geology. Due to extreme lateral variability of lithofacies and poor seismic resolution, we used a four-stage approach to identify the reservoir geology of glacial deposits: palynological zonation of sidewall samples, lithological identification from cores and log response, correlation, and detailed reservoir modeling. With the advent of high-resolution microresistivity image tools, one can carry out lithological identification and correlation using this four-stage approach with much greater confidence. This significantly enhances detailed reservoir modeling while reducing associated risk and uncertainty. The case study we present demonstrates an integrated borehole image interpretation within six vertical wells that enhanced previous glacial reservoir modeling. The four steps we performed were:detailed sedimentary structure interpretation of the images through all intervals in all six wells, borehole structural dip interpretation in the shales and current bedding analysis in the sandstones, sedimentary lithotype identification and facies association analysis, and correlation and reservoir modeling.
- Geology > Sedimentary Geology > Depositional Environment > Continental Environment > Glacial Environment (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.45)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Asia > Middle East > Oman > South Oman > South Oman Salt Basin > Al Khlata Formation (0.99)
- Asia > Middle East > Oman > Al Wusta Governorate > South Oman Salt Basin > Mukhaizna Field (0.99)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Borehole imaging and wellbore seismic (1.00)
ABSTRACT: The Green River formation in Southwestern Colorado is known as one of the world's richest oil shales and is the target for several oil companies' programs aimed at developing and evaluating technology to assess and develop the resource. Petrophysical evaluation of the potential liquid hydrocarbon yield is challenging due to the complex mineralogy that includes high and variable concentrations of minerals seldom encountered in conventional reservoirs. We present a case study of the evaluation of a comprehensive wireline and core data set that included capture and inelastic spectroscopy, natural gamma and NMR logs, and many hundreds of feet of core-derived elemental and mineralogical analysis supplemented by Fischer Assays and RockEval pyrolysis measurements of the liquid hydrocarbon con-tent. The borehole was shallow, on gauge and filled with a low salinity drilling fluid, and the logs were acquired slowly, resulting in optimum log data quality, particularly in the case of the spectroscopy logs. The dataset therefore offered an opportunity to assess the relative accuracy of the elemental yields from natural and induced spectroscopy in the most favorable conditions likely to be encountered in oilfield operations, and as such represents a valuable reference for more general use of these logs. We showed that the tools' accuracy varied considerably from element to element, and used this information to select the elements used as inputs in the detailed mineralogical analysis that followed. This step included transformation from liquid hydrocarbon in gallons per ton of the assay samples to the more familiar barrels per acre-foot of the gross rock volume. This enabled us to determine the value of the additional data acquisition in terms of the reduced prediction uncertainty obtained with the more comprehensive log and core data set and detailed analysis.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline (1.00)
- North America > United States > Wyoming > Green River Basin Oil Shale Field > Green River Basin Oil Shale Field (0.99)
- North America > United States > Utah > Green River Basin Oil Shale Field > Green River Basin Oil Shale Field (0.99)
- North America > United States > Colorado > Green River Basin Oil Shale Field > Green River Basin Oil Shale Field (0.99)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Determining The Oil-Water Contact While Drilling Above The Transition Zone In Long Horizontal Wells - Combining 4d Seismic And Advanced Resistivity Geosteering For Improved Wellbore Placement
Berle, Alf E. (Baker Hughes) | Thorsen, Arve K. (Baker Hughes) | Gjengedal, Jakob A. (Statoil) | Ahmadhadi, Faram (Odin Petroleum)
ABSTRACT: In thin oil reservoirs with a water drive below and an expanding gas cap above, it is vital to know the distance from the wellbore to the oil water contact (OWC) at all times while drilling. Achieving the correct stand-off to the oil-water contact during drilling is dependent on deep-reading MWD/LWD measurements, most commonly resistivity measurements. The Troll Field is one of the largest offshore gas fields in the world, as well as one of the most significant oil fields offshore Norway. The thin oil leg in the western part of the field (Troll West) is produced by means of long horizontal wells at or immediately above the oil water contact. However, aquifer movement is considerably larger than average in some areas on the flank of the field. In this case, the optimum horizontal wellbore placement is approximately 2m above the OWC, i.e. 1–2m more than normal. In the present case study, four horizontal branches of approximately 3000m length each were drilled in an area of the field where there has been large movements of the oil-water contact. 4D seismic analysis was used extensively in the planning phase to evaluate the area. In high quality target sand, the wellbore would mostly be placed above the transition zone, making the accuracy of the conventional models for saturation resistivity versus height above OWC uncertain. To improve the accuracy of horizontal wellbore placement relative to the OWC, recently developed azimuthal propagation resistivity (APR) measurements were used in combination with standard, omnidirectional multiple propagation resistivity (MPR) measurements. Analyses indicate that the desired position relative to the OWC was successfully achieved in approximately 70% of all four horizontal legs, despite considerable variations in the contact position. The stand-off data were also used to optimize the completion string design.
- Geology > Rock Type (0.94)
- Geology > Geological Subdiscipline > Stratigraphy (0.93)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.34)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (1.00)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Europe > United Kingdom > North Sea > Central North Sea > Moray Firth > Moray Firth Basin > Block 13/22a > Captain Field > Captain Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Sognefjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Heather Formation (0.99)
- (16 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
Integration Of Mud Gas Analysis With Conventional Logs To Aid Fluid Typing In Thinly-Bedded, Argillaceous Clastic Reservoirs
Liew, Yee Yung (Brunei Shell Petroleum Company Sendirian Berhad) | Fornasier, Ivan (Brunei Shell Petroleum Company Sendirian Berhad) | Hartman, Axel (Brunei Shell Petroleum Company Sendirian Berhad)
ABSTRACT: Development and management of the Champion West Field in Brunei Darussalam has been challenging due to a combination of sub-surface structural and reservoir interpretation, complex fluid fill, and well orientation. The fluid interpretation is especially challenging from the intermediate-deep reservoirs below 2500mTVDSS, due to the nature of the light oil (38–40 API) and condensate-rich gas in laminated and dispersed shalerich, thinly-bedded clastic reservoirs. While the tidallyinfluenced, near-shore marine setting provides fair confidence in regional reservoir unit correlation, the variable frequency of storm-deposits in these reservoirs adds complexity in correlation and increases the potential for cross-flow between blocks. Recent advances in mud gas logging have enabled the quantitative assessment of gas chromatographic data (C1-C5) and qualitative analysis of longer chain hydrocarbons (C6-C8). Published work indicates that gas logs have been used in combination with traditional logs to improve reservoir field models, optimise fluid sampling and / or pressure sampling programe, and to identify fluid contacts. Some studies have suggested a positive correlation of PVT samples with mud gas data. This paper summarizes the development of methodologies and applications that have been developed from more than 15 wells/sidetracks to define unique finger-prints for the various fluid facies in the Champion West Field, in wells drilled with oil-based mud (OBM). The acquisition of this advanced mud log data in complicated well trajectories, such as snake wells, has had positive economic impacts, as the data has been successfully utilised in near real-time to drive completion decisions, especially when LWD log data has not been available in real time due to insufficient mud pulse or tool failure. INTRODUCTION Champion West Field is situated offshore Brunei Darussalam, comprising approximately 1200m of vertical reservoir sequences with over twenty five separate pressure cells defined to date with complex and variable fluid distributions (Fig. 1).
- North America > United States > Texas (1.00)
- Asia (1.00)
- Geology > Geological Subdiscipline > Geochemistry (0.95)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.40)
- Well Drilling > Drilling Measurement, Data Acquisition and Automation > Mud logging / surface measurements (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Fluid Characterization (1.00)