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Collaborating Authors
Al Marzooqi, Hassan
Hidden Success of Unconventional Oil Play Behind Robust Integration of Subsurface G&G Data. A Case Study of Shilaif Unconventional Oil Play, Abu Dhabi, UAE
Alharthi, Amena (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Baig, Muhammad (ADNOC) | Van Laer, Pierre (ADNOC) | Al Hashmi, Abdulla (ADNOC) | Brooks, Trevor (ADNOC) | Al Blooshi, Abdullah (ADNOC) | Al Braiki, Mohammed (ADNOC)
Abstract The hidden insight of the success comes sometimes from the hard learning obtained after a taken risk. Testing an unconventional exploration well without a full deep understanding of subsurface was a good lesson learned to unlock the hidden insight of a successful approach to integrate subsurface G & G data for better evaluation and decision-making. An exploration well (X) was drilled in one of Abu Dhabiโs basins to test the potential of unconventional Shilaif Oil play. Shilaif Formation is a Cenomanian carbonate source rock deposited in intrashelf basin setting. The Formation comprises of three main stacked sequences, each contains source and clean tight limestone. Well "X" was drilled with 633ft of core covering entire Shilaif Formation. Before completing the core analysis and full data integration, the well was tested with limited regional understanding/data. Later on, another well (Y) was drilled with 210ft of core aiming to better evaluate part of Shilaifโs potential in the same basin. Core analysis was completed with advanced analysis including key elements such as NMR T1/T2, TRA, 2D/3D SEM, etc. and integrated further with logs and other subsurface data. Well "X" testing results obtained pre-core integration and full understanding, were limited and inconclusive to evaluate the formation. Once the full core analysis completed and integrated with logs, it was found that the tests were run in high uncertain zones mostly associated with bituminous part of TOC. To reduce the uncertainties and better evaluate the UC oil play, well "Y" evaluation and decision approach were adjusted. Comprehensive integration was completed with advanced core analysis, logs, multiple subsurface data and regional understanding. This comprehensive integration resulted in identifying multiple potential zones with movable fluids and better rock properties tested with positive results. After the hard learning, our strategy of exploration has been amended particularly for the brand-new exploration areas which are far from the nearest cored wells. The comprehensive integration was a key approach to identify the potential zones for further evaluation. The knowledge obtained from core and log integration can be transferred to nearby un-cored future wells for better understanding as well as cost optimization.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Geochemistry (0.92)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.36)
- (2 more...)
Subsurface Integrated Unconventional Reservoir Characterization - A Case Study of Diyab Carbonate Source Rock from Onshore Field, Abu Dhabi, UAE
Alharthi, Amena (ADNOC) | Baig, Muhammad (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Al Hashmi, Abdulla (ADNOC) | Van Laer, Pierre (ADNOC) | Brooks, Trevor (ADNOC) | Al Blooshi, Abdulla (ADNOC) | Coscia, Marco (ADNOC)
Abstract As the demand for natural gas is increasing, the exploration and appraisal activities for unconventional gas resources is expanding and becoming significant to fulfill the global demand. These Unconventional resources are known to have complex geochemistry and rock physics. Understanding the complex nature of unconventional rocks is challenging and requires comprehensive integration with an advanced reservoir characterization approach. In this study, a comprehensive integrated rock characterization workflow was designed to understand the challenges and uncertainties associated with the Diyab Formation unconventional rocks. More than 800 ft of unconventional cores were analyzed to characterize the Jurassic carbonate succession of Jubaila, Hanifa and Tuwaiq Mountain Formations through an integrated workflow. The workflow includes core and OH logs based initial rock classification through machine learning known as "Heterogeneous Rock Analysis" (HRA). Based on HRA, the samples selection for Unconventional and advanced Geomechanical core analysis was applied, followed by core data interpretation, core to logs integration and refining reservoir quality. Unconventional and advanced core analysis in this workflow include but not limited to following types, liquid TRA, TOC, HAWK, Vitrinite Reflectance (VR), Core-NMR T2, MICP, 2D/3D SEM, Dean Stark, XRD/XRF, Geomechanics (Brazil Tensile Strength, Unconfined Compression (UCS), Single (TXC) and Multi Stage Triaxial (MTXC), Multi-Stress Compression (MSC), Biot coefficient test), etc. Core analysis results were interpreted and integrated with the logs to better understand and characterize the unconventional reservoir qualities. Sample selection was performed using all available data, to capture the variations in petrophysics as well as geomechanics and geochemistry, particularly organic matter content, and mineralogy within each identified petrophysical rock class. Core logs, plug analysis, and wireline data have been integrated and generally showed excellent agreement within the range of associated uncertainties, which can be attributed to rock tightness and resolution variations. Geochemistry (TOC, HAWK & VR) shows high concentration of kerogen, initially of type IIS but presently with low HI in which maturity reflects the dry gas window and possible condensate. Porosity ranges from 2.7% to 8% with a maximum reading reported from MICP data. The 2D & 3D SEM images provided some key findings, associated with different porosities either connected, isolated and/or organic matter porosity systems in given samples. These complex porosities systems cannot be captured by only conventional methods. The organic type of porosity is important as it provides further support to matrix porosity connectivity. Integrating this knowledge with logs, geochemistry, petrophysics and mineralogy helped to refine the initial characterized rock properties. In addition, the geomechanical understanding took the integration step further to identify potential zones for fracking and testing based on the classified stress regime.
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.91)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.68)
- (2 more...)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Diyab Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Araej Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Arabian Basin > Jafurah Basin > Tuwaiq Mountain Formation (0.94)
- (3 more...)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Core analysis (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.88)
Fracture Conductivity Enhancement; A Key to Unlocking Potential of Unconventional Tight Oil Resources in the UAE
Elazab, Sherif Abdelaziz (ADNOC) | Useche, Franklin (ADNOC) | Van Laer, Pierre (ADNOC) | Baig, Muhammad Zeeshan (ADNOC) | Brooks, Trevor (ADNOC) | Al Hashmi, Abdulla (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Alharthi, Amena (ADNOC) | Coscia, Marco (ADNOC) | Goiran, Pierre Olivier (ADNOC)
Abstract Economical hydrocarbons production from unconventional resources is intrinsically related to stimulation effectiveness and capacity of the created hydraulic fractures to drain the target resource in an efficient manner, this is certainly without overlooking the significance of other resource geological, petrophysical, geomechanical, and other rock quality aspects. Considering the unique characteristics of each unconventional resource and the varying rock qualities and geological features, each resource should be considered separately when attempting to define the most optimum stimulation design approach that yields the best well productivity results and best EUR's, this means that a stimulation design approach that was successful in a specific play might not yield the same success if applied in a different play. In general, the overall stimulation effectiveness in unconventional horizontal multi-stage completions requires a good understanding of the geological, petrophysical, and geomechanical characteristics of the asset in hand as well as an understanding of the natural fracture's distribution, rock heterogeneity, and other aspects, eventually integrating those understandings to design an effective stimulation approach that similarly considers cost and operational efficiency parameters. Efficiency of the stimulation treatments requires an optimal placement of perforation clusters, with reasonable spacing that allows for creating the target fracture geometry/complex fracture network while considering fracture interferences, and other geometry controlling aspects. One of the most important considerations when designing a fracture treatment is fracture conductivity which is the ability of fractures to convey produced fluids into the wellbore (fracture permeability multiplied by fracture width (md-ft). In general, fracture conductivity along the created fracture network as well as in the near-wellbore area defines how effective is the fracture in delivering hydrocarbons into the wellbore, the target fracture conductivity values however vary with respect to formation rock permeability ranges and nature of produced fluids. This paper presents a comparative study of fracturing design and operational execution approaches for two exploration wells drilled in the oil-bearing Shilaif unconventional formation in the UAE, both wells are drilled targeting the same rock sequence and both possess very similar rock qualities. The paper covers aspects studied to analyze the suboptimal performance of the first well and the adjustments made to the fracturing design and fracture conductivity improvement of the second well, and how it entirely changed the productivity profiles and significantly improved the EUR for the target resource, which in turn had made this asset much more attractive for future full development plans.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.48)
Integrated Approach for the Quantification of Best Reservoir Quality (kerogen Vs Bitumen) and Production of Unconventional Oil Play - A Case Study From Onshore Abu Dhabi - UAE
Ibe, Eziulo (Baker Hughes) | Jha, Bhawesh (Baker Hughes) | Uluyuz, Sila (Baker Hughes) | Kerrouche, Nawal (Baker Hughes) | Panchakarla, Anjana (Baker Hughes) | Kulkarni, Aditee (Baker Hughes) | Van Laer, Pierre (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Alharthi, Amena (ADNOC) | Baig, Muhammad (ADNOC) | Al Hashmi, Abdulla (ADNOC) | Brooks, Trevor (ADNOC)
Abstract Several challenges are associated with reservoir characterization of organic-rich, unconventional plays, most significantly with estimating producible hydrocarbons and identifying potential zones to land horizontal wells and subsequent stimulation. This paper illustrates integrated approach towards successful characterization of the Cretaceous carbonate major source rock-a lateral seal Shilaif formation in the recently developing area of syncline shape field in Onshore UAE. The Shilaif formation that was deposited under intra-shelf basinal conditions, contains sediments of argillaceous limestone, mostly fine-grained packstones and shaly lime mudstone-wackestones with subordinate calcareous shales in the lower part. Presence of bitumen and low permeability indicate the requirement to stimulate the wells effectively. Quantification of bitumen and light hydrocarbon through integration of advanced and conventional log data with core data and mud logs plays a critical role in the evaluation and development of these organic-rich reservoirs. Extensive data acquisition was planned with a wireline suite that included resistivity/density/neutron/spectral gamma ray; acoustic logs; resistivity image; nuclear magnetic resonance (NMR); advanced elemental spectroscopy; and dielectric technologies to characterize the hydrocarbon potential of organic-rich Shilaif unconventional play. NMR and Spectroscopy were used to refine lithology and porosity, which reduces the associated uncertinity in the evaluation of total organic carbon (TOC) and volumes. The advanced elemental spectroscopy data provided the mineralogy, the amount of carbon in the rock, and consequently the associated organic carbon within the Shilaif formation. The NMR technology provided lithology-independent total porosity and moveable versus non-moveable fluids quantification when integrated with density/neutron. NMR technology in this present case study was used to identify and differentiate the organic matter and hydrocarbon presence within the Shilaif formation. The water filled porosity and textural parameter from dielectric inversion results helped in more accurate water saturation estimation in the tight formation. Acoustic data results and high-resolution resistivity image logs were used to evaluate the geomechanical properties. In addition, Resistivity image data provided detailed knowledge of geological features, faults and natural fracture networks within the study zone to enable optimization of development scenario based on the reservoir properties. The data integration work illustrated in the paper is a key for unconventional reservoir characterization that enabled identification of the potential zone/zones of interests for horizontal wells and the successful development of the organic rich rocks of the Shilaif formation.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.89)
- Asia > Middle East > Saudi Arabia > Eastern Province > Arabian Basin > Jafurah Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Block 6 > Al Khalij Field > Mishrif Formation (0.99)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (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)
Integrated Reservoir, Geology and Geomechanical Characterization for Unconventional Development: Application to the Diyab Play
Pourpak, Hamid (TotalEnergies) | Hernandez, Eider (TotalEnergies) | Higelin, Maxime (TotalEnergies) | Jaber, Maysaa (TotalEnergies) | Mansoor, Khalid (TotalEnergies) | Sullivan, Luther (TotalEnergies) | Baud, Emmanuelle (TotalEnergies) | Su, Kun (TotalEnergies) | Zeeshan Baig, Muhammad (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Van Laer, Pierre (ADNOC) | Alharthi, Amena D. (ADNOC) | Al Hashmi, Abdulla Ali (ADNOC) | Brooks, Trevor Daniel (ADNOC) | Al Arbai, Mohamed Elsayed (ADNOC)
Abstract The Diyab Formation is an organic-rich carbonate rock with low permeabilities and is one of the first unconventional targets to emerge in the Middle East. Vertical and horizontal exploration wells were drilled during the past years with proven productivity in the United Arab Emirates (UAE). Coupled geomechanical and reservoir characterizations of the Diyab formation are crucial for the successfulness of Stimulated Rock Volume (SRV) Creation and hydraulic fracturing operations which can have a direct impact on production performance. The objective of this study was to perform a full characterization of the Diyab formation based on extensive datasets that include logs and cores. The outcome of this integrated characterization work is used to assess the behavior of the Diyab formation across the concession block. First, we present the geology and general context of the studied area. Next, we detail the current understanding of the structural lineaments and natural fractures across the block. Then, based on full characterization work originating from data acquired on exploration and appraisal wells, we show how the results of geomechanical characterization together with the analysis of reservoirs quality/geological data allow us to suggest a vertical sub-division for Diyab formation. We explain further how the reservoir/geology, geomechanical parameters and natural fractures change laterally between wells. Reservoir characterization work concluded that there are some lateral variabilities in Diyab formation such as the change in the thickness/mineralogy of the carbonate bench and thickness of the porous wackestone. Some lateral variations in geomechanical/SRV parameters are observed within the block, resulted mainly from change in natural fractures density and properties of the carbonate bench and porous wackestone. This work is the first result of the integration of the current available data and the knowledge on Diyab formation, which could potentially evolve with the acquisition of new data and analyses. The combination of a full geomechanical characterization with a reservoir quality and structural geology study allows to propose a detailed reservoir and geomechanical sub-division for the Diyab formation. This approach will aid to better understand the lateral variability of facies, reservoir quality and geomechanical properties within the block which are crucial for successful development of this unconventional play.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Diyab Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Araej Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Arabian Basin > Jafurah Basin (0.99)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Naturally-fractured reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Management > Energy Economics > Unconventional resource economics (1.00)
Subsurface-Integration a Key Step Towards Understanding an Unconventional Oil Play; A Case Study from Onshore Abu Dhabi, UAE
Alharthi, Amena (Abu Dhabi National Oil Company) | Baig, Muhammad (Abu Dhabi National Oil Company) | Van Laer, Pierre (Abu Dhabi National Oil Company) | Al Hashmi, Abdulla (Abu Dhabi National Oil Company) | Brooks, Trevor (Abu Dhabi National Oil Company) | Al Marzooqi, Hassan (Abu Dhabi National Oil Company) | Coscia, Marco (Abu Dhabi National Oil Company) | Al Bannay, Aamer (Abu Dhabi National Oil Company) | Al Blooshi, Abdulla (Abu Dhabi National Oil Company) | Al Jaberi, Fatema (Abu Dhabi National Oil Company)
Abstract As unconventional resources gain pronounced interest in the Middle East, the understanding and the assessment of these resources becoming widespread. The complex nature of unconventional rocks introduces challenges when it comes to understand reservoir characterization. In this paper, we are illustrating an integrated reservoir characterization workflow of the Shilaif formation which is one of the main unconventional oil resources in the region. The Shilaif formation is the primary source rock of the underlying, lateral and overlying conventional reservoirs. The integrated workflow is designed to gain a more comprehensive understanding of Shilaif potential by implementing robust integration of different sets of data including drilling, well logs, core analysis, frac and flowback results. The Shilaif formation is a regionally extensive carbonate unconventional play. The multi-stacked play comprises 3 depositional cycles, each with organic rich facies at the base, shallowing up to tight cleaner limestone. A pilot well (Well A) was drilled to characterize and test hydrocarbon type and the potential within each sequence. Drilling data, logs, geochemical, petrophysical and geomechanical data were integrated and utilized to assess the reservoir and select potential intervals for testing. In addition, the slabbed core of well A was available for physical core viewing (UV & WL) to identify oil saturated intervals and natural fractures which further helped in selection of the test intervals. Three intervals were frac'ed and tested with flow back results showing different potential across the 3 zones, which are aligned with the initial subsurface models. This alignment confirms the power and importance of integrating the subsurface data in assessing the unconventional plays during exploration & appraisal phase. Pre frac interpretation was integrated with post frac flowback data (including frac height, reservoir fluid composition and deliverability) to land a horizontal well in the best interval. Following drilling, frac'ing and flowback, the horizontal well showed the highest oil rate production during exploration & appraisal of the unconventional oil plays in UAE. This further confirms the importance of the integrated reservoir characterization approach.
- Research Report > Experimental Study (0.49)
- Research Report > New Finding (0.48)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics (0.48)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.35)
Advanced Multi-Disciplinary Simulation Workflow for Well Placement, Hydraulic Fracturing and Production Optimization Applied to the Diyab Unconventional Play in Onshore UAE
Pourpak, Hamid (TotalEnergies) | Taubert, Samuel (TotalEnergies) | Theodorakopoulos, Marios (TotalEnergies) | Lefebvre-Prudencio, Arnaud (TotalEnergies) | Pointer, Chay (TotalEnergies) | Wu, Yang (TotalEnergies) | Hernandez, Eider (TotalEnergies) | Al Marzooqi, Hassan (ADNOC) | Z. Baig, Muhammad (ADNOC)
Abstract The Diyab play is an emerging unconventional play in the Middle East. Up to date, reservoir characterization assessments have proved adequate productivity of the play in the United Arab Emirates (UAE). In this paper, an advanced simulation and modeling workflow is presented, which was applied on selected wells located on an appraisal area, by integrating geological, geomechanical, and hydraulic fracturing data. Results will be used to optimize future well landing points, well spacing and completion designs, allowing to enhance the Stimulated Rock Volume (SRV) and its consequent production. A 3D static model was built, by propagating across the appraisal area, all subsurface static properties from core-calibrated petrophysical and geomechanical logs which originate from vertical pilot wells. In addition, a Discrete Fracture Network (DFN) derived from numerous image logs was imported in the model. Afterwards, completion data from one multi-stage hydraulically fracked horizontal well was integrated into the sector model. Simulations of hydraulic fracturing were performed and the sector model was calibrated to the real hydraulic fracturing data. Different scenarios for the fracture height were tested considering uncertainties related to the fracture barriers. This has allowed for a better understanding of the fracture propagation and SRV creation in the reservoir at the main target. In the last step, production resulting from the SRV was simulated and calibrated to the field data. In the end, the calibrated parameters were applied to the newly drilled nearby horizontal wells in the same area, while they were hydraulically fractured with different completion designs and the simulated SRVs of the new wells were then compared with the one calculated on the previous well. Applying a fully-integrated geology, geomechanics, completion and production workflow has helped us to understand the impact of geology, natural fractures, rock mechanical properties and stress regimes in the SRV geometry for the unconventional Diyab play. This work also highlights the importance of data acquisition, reservoir characterization and of SRV simulation calibration processes. This fully integrated workflow will allow for an optimized completion strategy, well landing and spacing for the future horizontal wells. A fully multi-disciplinary simulation workflow was applied to the Diyab unconventional play in onshore UAE. This workflow illustrated the most important parameters impacting the SRV creation and production in the Diyab formation for he studied area. Multiple simulation scenarios and calibration runs showed how sensitive the SRV can be to different parameters and how well placement and fracture jobs can be possibly improved to enhance the SRV creation and ultimately the production performance.
- South America > Argentina > Patagonia > Neuquรฉn > Neuquen Basin > Vaca Muerta Shale Formation (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Ruwais Diyab Unconventional Gas Concession > Block 1 > Ruwais Field > Thamama Group Formation (0.98)
- (3 more...)
Integration Success Story in Shilaif Shale Oil from Vertical Pilot to Horizontal
Alharthi, Amena Dhawi (ADNOC) | Van Laer, Pierre (ADNOC) | Brooks, Trevor (ADNOC) | Goiran, Pierre Olivier (ADNOC) | Baig, Muhammad Zeeshan (ADNOC) | Lazreq, Nabila (ADNOC) | Abdelhalim, Hamza (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Coscia, Marco (ADNOC)
Abstract The development of unconventional target in the Shilaif formation is in line with the Unconventional objective towards adding to ADNOC reserves. For future optimization of development plans, it is of utmost importance to understand and test and therefore prove the productivity of the future Unconventional Horizontal Oil wells. The Shilaif formation was deposited in a deeper water intrashelf basin with thicknesses varying from 600 to 800 ft from deep basin to slope respectively. The formation is subdivided into 3 main composite sequences each with separate source and clean tight carbonates. The well under consideration (Well A-V for the vertical pilot and Well A-H for the horizontal wellbore) was drilled on purpose in a deep synclinal area to access the best possible oil generation and maturity in these shale Oil plays. Due to the stacked nature of these thick high-quality reservoirs, a pilot well is drilled to perform reservoir characterization and test hydrocarbon type and potential from each bench. Fracturing and testing are performed in each reservoir layer for the primary purpose to evaluate and collect key fracturing and reservoir parameter required to calibrate petrophysical and geomechanical model, landing target optimization and ultimately for the design of the development plan of this stacked play. Frac height, reservoir fluid composition and deliverability, pore pressure are among key data collected. The landing point selected based on the comprehensive unconventional core analysis integrated with petrophysical and geomechanical outcomes using post vertical frac and test results. Well A-H was drilled as a sidetrack from the pilot hole Well A-V. This lateral section was logged with LWD Triple Combo while Resistivity Image was acquired on WL. Based on the logging data the well stayed in the target Layer / formation, cutting analysis data for XRD and TOC was integrated with the petrophysical results in A-H well. Production test results from subject were among the highest rate seen during exploration and appraisal of this unconventional oil plays and compete with the current commercial top tier analog unconventional oil plays. Achieving those results in such early exploration phases is huge milestone for ADNOC unconventional exploration journey in UAE and sign of promising future development.
- North America (0.68)
- Europe > Norway > Norwegian Sea (0.45)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.18)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.61)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.46)
Shuaiba Lagoon and Basinal Facies Exploration Potential in Abu Dhabi
Taher, Ahmed (ADNOC Upstream) | Celentano, Maria (ADNOC Upstream) | Franco, Bernardo (ADNOC Upstream) | Al-Shehhi, Mohammed (ADNOC Upstream) | Al Marzooqi, Hassan (ADNOC Upstream) | Al Hanaee, Ahmed (ADNOC Upstream) | Da Silva Caeiro, Maria (ADNOC Upstream)
Abstract In early Aptian times, subtle tectonic movements may have been activated along the NW-SE strike-slip faults and have resulted in a vertical displacement along these faults. The displacement would have allowed the carbonate-producing organisms to colonize along the shallower southern margin and generate well developed reservoir facies. The basinal facies were deposited to the north of the shelf margin, which is known to be the Bab Basin. Significant oil was discovered in the Shuaiba shelf facies. However, the lagoonal and basinal facies have potential for discovering a significant volume of hydrocarbon, especially in the fields that are located in the Upper Thamama hydrocarbon migration pathways. This potential is supported by the absence of an effective seal separating Thamama Zone-A from Shuaiba basinal facies above, which allowed for the Zone-A hydrocarbon to migrate vertically into the Shuaiba basinal facies. In addition, this potential was supported by the hydrocarbon shows while drilling and by the interpreted well logs, which confirm the presence of movable hydrocarbon in the Shuaiba lagoonal and basinal facies. The Shuaiba Formation is comprised of two supersequences (Azzam and Taher, 1995, van Buchem et al., 2010 and Lyndon et al., 2010) that were deposited during the Aptian time. The lower sequence started at the early Aptian time and mainly included Hawar Member, Thamama Zone-A, the Shuaiba shelf facies and its time equivalent Shuaiba basinal facies sediments. The second sequence was deposited after the drop in sea level below the Shuaiba shelf break. This drop caused subaerial exposure of the Shuaiba shelf platform and allowed for the clastics material to influx the fine-grained over the Shuaiba basinal facies area. The clastic influx and the carbonate rich claystone of the Late Aptian sequence sediments may represent the effective top seal for the Shuaiba basinal facies and Zone-A oil accumulation. The Shuaiba basinal facies were deposited in an intrashelf basin that was enclosed by the Shuaiba shelfal facies sediments. This resulted in restricted water circulation, anoxic condition and deposition below the wave base. Such depositional environment is favourable for source rock preservation. Lithologically, Shuaiba basinal facies consist of pelagic lime-mudstone, wackestone and packstone with abundant planktonic microfossils. These facies are characterized by low permeability values, but their porosity can reach up to 20%. The lagoonal sediments consists of a deepening sequence of carbonate sediments, with shallow marine algal deposits at the base and fine hemipelagic to pelagic carbonates in the upper section. The differences between the Shuaiba Shelf and the Shuaiba Basin are mainly in permeability values. By applying the latest technology in horizontal drilling and hydraulic fracturing, the Shuaiba basinal facies will produce a significant volume of hydrocarbon.
- Asia > Middle East > Saudi Arabia (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.56)
- Geology > Sedimentary Geology > Depositional Environment > Transitional Environment > Lagoonal Environment (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.69)
- Asia > Middle East > UAE > Thamama Group > Shu'aiba Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.98)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.98)
- (11 more...)
Stress Testing with Improved Wireline Formation Tester in Low Permeability Unconventional Formation
Povstyanova, Magdalena (ADNOC) | Coscia, Marco (ADNOC) | Van Laer, Pierre (ADNOC) | Makarychev, Gennady (ADNOC) | Al Marzooqi, Hassan (ADNOC) | Leyrer, Karl (ADNOC) | Casson, Neil (ADNOC) | Cig, Koksal (Schlumberger) | Desroches, Jean (Rocks Expert, France)
Abstract In preparation for the hydraulic fracturing campaign, the Unconventional Resources Team at Abu Dhabi National Oil Company (ADNOC) has carried out stress measurements both in open-hole and cased-hole in a number of recently drilled wells. The current paper demonstrates the results of the stress measurements in open-hole in two wells drilled in two different geological settings. The main target chosen was the unconventional Shilaif formation. One well was located on top of an anticline and the other well penetrated the Shilaif formation in a syncline. High breakdown pressures were expected (especially in the syncline). In order to cope with the challenges expected during the stress testing in such environment, a wireline formation tester that included both single packer and dual packer was used to initiate breakdown and achieve measurement of fracture closure pressure. With the expected adverse rock properties, either natural fall-off or rebound technique was employed to obtain closure pressure. The single-packer module extended the differential pressure rating up to 12,000 psia in comparison to 4,500-psia rated dual packer. The single packer was used to initiate the fracture breakdown if dual packer was not considered sufficient. Formation pressures were measured at several depths with the dual-packer operations. The stress measurements were carried out not only in the Shilaif formation, but in the shale formations above (the Tuwayil formation) and below (the Mauddud formation) in order to check if the shales could be stress barriers for a large scale hydraulic fracture. The current paper explains the procedure followed during the stress measurements and shows an example of interpretation of the pressure data acquired with wireline formation tester comprising the single-packer and dual-packer systems. The stress measurements were used to calibrate results of the geomechanical modeling.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Structural Geology > Tectonics > Compressional Tectonics > Fold and Thrust Belt (0.86)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.77)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.54)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Well Completion > Well Integrity > Zonal isolation (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- (5 more...)