Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
ADNOC Upstream
Underbalanced Coiled Tubing Drilling: Delivering Well Production Safely in High H2S and Tight Gas Reservoirs, UAE
Khan, Rao Shafin Ali (SLB (Corresponding author)) | Molero, Nestor (SLB) | Alam, Shah Sameer (SLB) | Mishael, Mohammad Basim (SLB) | Basha, Maged (SLB) | Zia, Arslan (SLB) | Zhylkaidarova, Sholpan (SLB) | Abd El-Meguid, Mohamed Osama (ADNOC Onshore) | Al Ali, Abdulrahman Hasan (ADNOC Onshore) | Saleh, Abdalla (ADNOC Onshore) | Almazrouei, Saeed Mohamed (ADNOC Onshore) | El Shahat, Ayman (ADNOC Onshore) | Bin Sumaida, Ali Sulaiman (ADNOC Onshore) | Al Mutawa, Ahmed Abdulla (ADNOC Onshore) | Yousfi, Fawad Zain (ADNOC Onshore) | Almteiri, Nama Ali (ADNOC Onshore) | Baslaib, Mohamed Ahmed (ADNOC Onshore) | Mantilla, Alfonso (ADNOC Upstream) | Ladmia, Abdelhak (ADNOC Upstream)
Summary United Arab Emirates (UAE) is seeking to become self-sufficient in gas supply by 2030. This has led the country to initiate several exploratory and appraisal projects to achieve this goal. This study covers one such pilot project targeting production from tight gas reservoirs in three wells through a coiled-tubing (CT) underbalanced drilling (UBD) project in ADNOC Onshore. CT pressure control equipment (PCE) was rigged up on top of production trees with wells already completed and cemented. A CT tower was used to accommodate the drilling bottomhole assembly (BHA) and eliminate risks related to its deployment. CT strings were designed to reach target intervals with sufficient weight on bit (WOB), suitable for sour environments, and able to withstand high pumping rates with mild circulating pressures. To address the hazards of H2S handling at the surface, a custom-fit closed-loop system was deployed. The recovered water was treated on the surface and reused for drilling to decrease the water consumption throughout the operations. The plan was to drill 3 3/4-in. horizontal laterals in all candidate wells. Each well was completed with a combination of a 4 1/2-in. and a 5 1/2-in. tubing and a 7-in. liner. Five laterals were drilled across the three candidate wells targeting carbonate reservoirs with each lateral having an average length of ~4,000 ft. The achieved rates of penetration varied significantly from 15 ft/min to 30 ft/min while drilling through the various formations. Over the course of the pilot project, several challenges had to be addressed, such as material accretion on the CT string during wiper trips, treatment of return fluids having high H2S content and rock cuttings, and ensuring the integrity of the CT pipe while operating in severe downhole environments. Solutions and lessons learned from each well were implemented subsequently in the campaign, such as the use of increased concentrations of H2S inhibitor to coat the CT string, the use of nitrified fluids based on changing well parameters to maintain underbalance, thorough pipe management through real-time CT inspection, and adding a fixed quantity of fresh water to the drilling system every day to avoid chemical reactions between the drilling fluid additives and hydrocarbons. The wells completed with this method exceeded production expectations by 35โ50% across the project while reconfirming the value of the technology. The use of CT for UBD is still considered a challenging intervention worldwide. Such cases in high H2S environments are rare. This study outlines best practices for a CT UBD and a setup that can be replicated in other locations to implement this methodology with high H2S and when rig sourcing is a concern.
Simulation-Assisted Diagnosis of GOR Evolution in Carbonate Reservoir, Offshore Abu Dhabi, Undergoing Miscible Gas Injection
Khan, M. N. (ADNOC Upstream) | Mogensen, K. (ADNOC Upstream) | Altaf, B. (ADNOC Upstream) | Menchaca, T. Felix (ADNOC Upstream) | Allouti, A. (ADNOC Upstream)
Abstract A major reservoir, Reservoir A, in an offshore carbonate field in Abu Dhabi underwent a thorough development-concept selection process. The subsurface evaluation recommended miscible gas injection-based development as the most optimal process, and the reservoir is undergoing the miscible gas injection operation. Over the course of production, โReservoir Aโ is experiencing a gradual GOR increase. The GOR evolution could be the result of different physical mechanisms, such as production below bubble point, gas coning, or miscible gas breakthrough. In the latter case, it is not clear whether reservoir dispersion has smeared out the miscible displacement front to a point where miscibility is lost. The key objective of this work was therefore to develop a diagnosis methodology using numerical simulation to interpret the GOR response. A 2D numerical, fine-gridded simulation with a producer-injector pair was set up to explore the following scenarios: (a) production below bubble point; (b) gas coning from the gas cap; (3) a perfect miscible displacement; (4) a perfect immiscible displacement; (5) a miscible displacement that turns immiscible due to dispersion; (6) a combination of the above. The key output parameters tracked included GOR and its derivative and the flowing bottom pressure at the producer. The different runs were then compared against each other and with the measured GOR response. A fit-for-purpose surveillance strategy was adopted to help assess the effectiveness of the overall development strategy. Recently, tracer test results confirmed the arrival of gas production down the horizontal wellbore. GOR evolution trends were captured using the inline multiphase flowmeters. The comparison of simulation-based type curves with the evolving GOR trend along with the other subsurface attributes shows an initial indication of the production of swelled oil, followed by the injection gas breakthrough. This paper showcases the effectiveness of the proposed technique and the initial results of the analysis.
Abstract Phase equilibrium calculations require experimental lab data to constrain component properties in an equation of state (EOS) model. In this work, we evaluated the miscibility behavior of four different injection gases for a reservoir onshore Abu Dhabi containing medium-light oil. The extensive experimental program included swelling and slimtube experiments using CO2 as well as three hydrocarbon gases, in addition to conventional black-oil experiments. Based on the large company PVT database, gas additions in the swelling experiment were carefully designed to reduce uncertainty on the transition point where the swollen fluid type changes from oil to gas. We developed several fully tuned EOS models by gradually lumping down while monitoring the match quality. Due to the richness of the injection gases, C2 (15 mol%), C3 (15 mol%), C4 (10 mol%) and CO2 were kept as separate components resulting in a 10-component final EOS description. The compositional data showed a distinct tail effect above C20, which we believe is a lab artifact. The plus fraction was therefore lumped back from C36 to C20 to characterize the composition from C20 up to C80. This step improved the match of the dead oil properties. While the swelling data were matched well, the slimtube recovery data yielded some uncertainty on the MMP estimate, especially for the CO2 test. We made use of the reported effluent gas composition to show that one of the points denoted as immiscible in the lab report is most likely miscible. We tested several EOS-based MMP algorithms and found them to give similar MMP estimates for the hydrocarbon gases whereas the CO2 MMP was predicted with a much larger spread. Our view is that for CO2 flooding, cell-based simulations capture the dynamic behavior of miscible displacement better than the key tie-line approach. The tuned EOS model reproduced the single-phase density very accurately, which is important for the saturation estimation in the transition zone. Several injection gases appear suitable for miscible flooding and further screening studies are now ongoing.
- North America > United States (0.94)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.72)
Acquiring Surface Seismic Without Surface Receivers: A 3D DAS-VSP Case Study Offshore Abu Dhabi
Mason, J. (ADNOC Upstream) | Cambois, G. (ADNOC Upstream) | Al Mesaabi, S. A. (ADNOC Upstream) | Cowell, J. (ADNOC Upstream) | Boukhanfra, F. (ADNOC Upstream) | Mahgoub, M. (ADNOC Upstream) | Al Neyadi, A. M. (ADNOC Upstream)
Abstract While shooting a dense ocean-bottom nodes (OBN) survey offshore Abu Dhabi, 3D Distributed Acoustic Sensing (DAS) Vertical Seismic Profiles (VSP) were recorded utilizing semi-permanent optical fibers present in wells across the field. The objective was not only to provide the benefits generally afforded by 3D VSPs, but to use the surface-related multiples and obtain a 3D image of the subsurface comparable to (if not better than) the OBN survey. The OBN survey recorded a high density shot carpet (25m ร 25m) into 4C nodes on a 25x150m grid using a wide azimuth, long offset geometry. It was shot over a producing field with four artificial islands used as drilling pads. Optical fibers clamped to the upper completion tubing are present in the majority of wells drilled from these islands. The team decided to use DAS interrogators to "eavesdrop" on the OBN seismic sources while the seismic sources operated in the vicinity of two of the artificial islands. VSPs provide local measures of attenuation, velocity, anisotropy, and multiple content that can aid surface seismic processing. Furthermore, a 3D VSP can provide an image of the subsurface that has higher resolution than surface seismic, but which does not extend too far from the well. A recent imaging technology for offshore 3D VSP uses seismic multiples to reconstruct the subsurface as if it were acquired by surface seismic. This imaging technology is very promising but suffers from weak signal-to-noise ratio, especially in ultra-shallow water. To mitigate this issue, the team used a total of 16 wells to reconstruct the subsurface in a 300km2 combined area around the two islands. The wells were chosen for the length of their usable fiber and their diverse trajectories.
Integrated Approach for Effective Asphaltene Precipitation and Deposition Detection in Greenfield Wells
Lee, W. (Al Dhafra Petroleum, now with Korea National Oil Corporation) | Hamza, M. (Al Dhafra Petroleum) | Shim, J. (Al Dhafra Petroleum) | Mogensen, K. (ADNOC Upstream) | Grutters, M. (ADNOC Onshore)
Abstract This paper presents a comprehensive approach for assessing asphaltene precipitation and deposition in greenfield wells, which includes asphaltene risk evaluation using stock tank oil and bottomhole oil with and without miscible gas injection, the development of an asphaltene deposition simulation model employing PROSPER, and the interpretation of well operation results. A holistic solution for assessing asphaltene deposition in greenfields is proposed by combining laboratory analysis, simulation models, and field data. The methods involve screening techniques using dead oil, such as SARA plot, De Boer plot, CII index. These preliminary results were complemented with AOP tests using live oil and field intervention outcomes to confirm the risk. A throttle model was developed to estimate asphaltene deposition in wellhead throttle valves, validated using wellhead choke inspection and well test data. The comprehensive approach to managing asphaltene deposition in greenfield proved effective, as demonstrated by the results. The asphaltene risk assessment, well intervention activity interpretation, and simulation model successfully identified high asphaltene risk wells and targeted asphaltene treatment locations. Various screening methods determined different levels of asphaltene risk, with one method selected after comparison with AOP and field observations as the screening technique for new wells and reservoirs. Based on screening, asphaltene envelopes, and the deposition model, eight wells were chosen for asphaltene treatment. This paper offers unique insights by introducing a comprehensive approach for detecting asphaltene deposition in greenfield wells. The novel wellhead choke model, in particular, enables a simple prediction of asphaltene deposition using existing wellhead parameters and well test data. The findings have significant implications for greenfield management and can be applied to other oil-producing regions globally.
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 186 > Field A Field > Silurian Tanezzuft Formation (0.98)
- Africa > Middle East > Libya > Murzuq District > Murzuq Basin > Block NC 115 > Field A Field > Silurian Tanezzuft Formation (0.98)
First Application of Wave Equation Based-AVO Inversion on a Carbonate Reservoir in UAE
Ahmed, J. (ADNOC Onshore) | Mahmood, H. (ADNOC Onshore) | Al-Naqbi, S. (ADNOC Onshore) | Aljaberi, A. (ADNOC Upstream) | Doulgeris, P. (Delft Inversion) | Gonza;ez, H. (Delft Inversion) | Zhang, M. (Delft Inversion) | Denitez, P. (Delft Inversion)
Abstract Carbonate reservoirs, by definition, present additional challenges compared to clastic sections in seismic reservoir characterization. The lower porosities often hinder the robust detection of fluids using traditional inversion methods, and the whole rock less sensitive to AVO (Amplitude Versus Offset). Additionally, many carbonate reservoirs exhibit property contrasts that greatly surpass the 0.1 reflection coefficient, where linear convolutional models best approximate the seismic signal effectively. The WEB-AVO Reservoir Characterization technology addresses key uncertainties in onshore carbonate reservoirs arising from inherent heterogeneities and lateral porosity variations, first because of the nature of the derived properties, which are the inverses of the Bulk Modulus (Compressibility), inverse of the Shear Modulus (Shear Compliance) and the Bulk Density. These properties serve as direct parameters for reservoir properties of interest. Notably, Compressibility being approximately three times more sensitive to fluids than Acoustic Impedance (Gisolf, 2016). enabling fluid detection in lower porosity ranges when compared to Acoustic Impedance. In addition, the nature of WEB-AVO, being based on the full wave equation and not the linearization of Zoeppritz equations, allows it to inherently handle the scattering seismic often present in carbonate sections. This includes interbed multiples and mode conversions, which can be a major challenge, especially with the land data. The technology also accounts for transmission effects. This minimizes the need for significant preconditioning for the inversion, as the scheme has the full physics required for acquired seismic data, as opposed to having to modify the acquired seismic data to fit the linear inversion models. WEB-AVO was tested on onshore seismic data from the R Field, Abu Dhabi. WEB-IMI analysis was conducted to understand the scattering patterns in the subsurface and optimize the inversion window. The study aims at generating well-validated elastic properties that are directly related to reservoir properties spatially, using data that has not undergone gather preconditioning. These properties were later validated using the blind well test and its lateral predictability to capture the heterogeneity of the reservoir away from the wells. This technique removes the small-reflectivity and primaries-only limitations of linear and reflectivity-based inversion schemes. Additionally, it enables the determination of elastic parameters that are more directly connected to rock properties of interest, such as porosity. In this geological setting, the ability to work on gathers in the presence of multiples has a significant positive impact on both cost and turn-around time.
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.34)
- Africa > Middle East > Libya > Wadi al Hayaa District (0.24)
- Geology > Geological Subdiscipline > Geomechanics (0.70)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.35)
- Africa > Middle East > Libya > Wadi al Hayat District > Murzuq Basin > Block NC 186 > I&R Fields > R Field > Mamouniyat Formation (0.99)
- Africa > Middle East > Libya > Wadi al Hayat District > Murzuq Basin > Block NC 115 > I&R Fields > R Field > Mamouniyat Formation (0.99)
Data Analytics Driven Subsurface Reservoir Sectorization Review of a Giant Abu Dhabi Onshore Field Carbonate Reservoir for Efficient Reservoir Management
Javid, Khalid (ADNOC Onshore) | Alshkeili, Sara (ADNOC Onshore) | Al-Hammadi, Fatema (ADNOC Onshore) | Benourkhou, Noureddine (ADNOC Onshore) | Al Sayari, Saleh Ali (ADNOC Onshore) | Kenawy, Maher (ADNOC Onshore) | Ryzhov, Sergey (ADNOC Upstream)
Abstract This paper discusses the approach used to sectorize mature giant carbonate reservoir located onshore Abu Dhabi for the purpose of reservoir management, offtake, and injection balancing. The reservoir is developed under line-drive WAG scheme in combination with peripheral water injection. Future development plan for the reservoir includes massive deployment of Maximum Reservoir Contact (MRC) horizontal wells and a gas-based EOR scheme. A practical data-driven approach, based on one of the ADNOC's Integrated Reservoir Management (IRM) workflows was selected for the purpose of sectorization. It starts from defining a number of possible sectorization schemes and goes through the review of: relevant geological data (faults and structural features, rock properties and facies distribution), well performance data (productivity/injectivity indices, WCT and GOR mapping, WOR/GOR vs. cum oil trends, well maturity indicators), reservoir performance indicators (fluid properties and reservoir pressure distribution, water, and gas front movement, streamline analysis and analysis of injection allocation factors). compliance to the future development plans. Through the review each of the preliminary sectorization schemes are scored for their compliance to IRM requirements and the scheme with the highest score is selected for the future implementation. Out of eight sectorization schemes proposed at the start, one single scheme compliant with most of the requirements of ADNOC IRM workflow was selected. This scheme honors major faults and lineaments, reflects observed variation in rock properties and pressure distribution and at the same time caters for the requirements of future development schemes. Selected sectorization scheme features five sectors, each having comparable number of wells, while number of wells "sharing" multiple sectors was reduced to the minimum. Being compliant to the distribution of reservoir pressure and to observed trends in well performance selected sectorization allows improved monitoring and management of voidage replacement, pressure maintenance and will cater for adequate surveillance planning and execution. Moving forward, selected sectorization scheme will be used for regular sector performance reviews aiming at identifying subsurface opportunities and areas of improvement and helping to drive efficient reservoir management decisions.
- Geology > Geological Subdiscipline (0.55)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.49)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.56)
Underbalanced Coiled Tubing Drilling: Delivering Well Production Safely in High H2S and Tight Gas Reservoirs, UAE
Khan, Rao Shafin Ali (SLB (Corresponding author)) | Molero, Nestor (SLB) | Alam, Shah Sameer (SLB) | Mishael, Mohammad Basim (SLB) | Basha, Maged (SLB) | Zia, Arslan (SLB) | Zhylkaidarova, Sholpan (SLB) | Abd El-Meguid, Mohamed Osama (ADNOC Onshore) | Hasan Al Ali, Abdulrahman (ADNOC Onshore) | Saleh, Abdalla (ADNOC Onshore) | Almazrouei, Saeed Mohamed (ADNOC Onshore) | El Shahat, Ayman (ADNOC Onshore) | Bin Sumaida, Ali Sulaiman (ADNOC Onshore) | Abdulla Al Mutawa, Ahmed (ADNOC Onshore) | Zain Yousfi, Fawad (ADNOC Onshore) | Ali Almteiri, Nama (ADNOC Onshore) | Baslaib, Mohamed Ahmed (ADNOC Onshore) | Mantilla, Alfonso (ADNOC Upstream) | Ladmia, Abdelhak (ADNOC Upstream)
Summary United Arab Emirates (UAE) is seeking to become self-sufficient in gas supply by 2030. This has led the country to initiate several exploratory and appraisal projects to achieve this goal. This study covers one such pilot project targeting production from tight gas reservoirs in three wells through a coiled-tubing (CT) underbalanced drilling (UBD) project in ADNOC Onshore. CT pressure control equipment (PCE) was rigged up on top of production trees with wells already completed and cemented. A CT tower was used to accommodate the drilling bottomhole assembly (BHA) and eliminate risks related to its deployment. CT strings were designed to reach target intervals with sufficient weight on bit (WOB), suitable for sour environments, and able to withstand high pumping rates with mild circulating pressures. To address the hazards of H2S handling at the surface, a custom-fit closed-loop system was deployed. The recovered water was treated on the surface and reused for drilling to decrease the water consumption throughout the operations. The plan was to drill 3 3/4-in. horizontal laterals in all candidate wells. Each well was completed with a combination of a 4 1/2-in. and a 5 1/2-in. tubing and a 7-in. liner. Five laterals were drilled across the three candidate wells targeting carbonate reservoirs with each lateral having an average length of ~4,000 ft. The achieved rates of penetration varied significantly from 15 ft/min to 30 ft/min while drilling through the various formations. Over the course of the pilot project, several challenges had to be addressed, such as material accretion on the CT string during wiper trips, treatment of return fluids having high H2S content and rock cuttings, and ensuring the integrity of the CT pipe while operating in severe downhole environments. Solutions and lessons learned from each well were implemented subsequently in the campaign, such as the use of increased concentrations of H2S inhibitor to coat the CT string, the use of nitrified fluids based on changing well parameters to maintain underbalance, thorough pipe management through real-time CT inspection, and adding a fixed quantity of fresh water to the drilling system every day to avoid chemical reactions between the drilling fluid additives and hydrocarbons. The wells completed with this method exceeded production expectations by 35โ50% across the project while reconfirming the value of the technology. The use of CT for UBD is still considered a challenging intervention worldwide. Such cases in high H2S environments are rare. This study outlines best practices for a CT UBD and a setup that can be replicated in other locations to implement this methodology with high H2S and when rig sourcing is a concern.
Novel Approach for Machine Learning Assisted Carbonates Reservoirs Saturation Heigh Modeling and Automated Pore Network Characterization
Gerges, Nader (ADNOC Upstream) | Cortez, Luisa Ana Barillas (SLB) | Madhavan, Midhun (SLB) | Kuruba, Sushmitha (SLB) | Almarzooqi, Lulwa (SLB) | Makarychev, Gennady (SLB) | Maarouf, Alaa (SLB) | Darous, Christophe (SLB) | Mustapha, Hussein (SLB) | Kloucha, Chakib Kada (ADNOC)
ABSTRACT Key datasets for permeability modeling, rock-typing, reservoir characterization, and saturation height modeling (SHM) include capillary pressure (Pc) measurements and conventional core analysis (CCA). The Pc data quality control and modeling is time-consuming and sensitive to the intricate pore network in carbonate rocks. In this study, we automate the Pc-based pore network characterization and use machine learning (ML) for capillary pressure modeling in an effort to improve the workflow efficiency and lessen interpretation bias. Additionally, a framework for advanced analytics was developed to enable interactive quality control and user visualization. We developed and tested the proposed algorithms on real data from a large carbonate oil field in the Middle East. There are around 500 MICP samples of good to exceptional quality. The parent-plug porosity and permeability are also available for all samples. The suggested methodology considerably enhances the Pc-based pore network characterization workflow. We can automatically identify low-quality data and outlier samples using sophisticated data science outliersโ identification methods. These outlier samples are removed, eliminating data-quality-artifacts in the interpretation. The automated pore network characterization method makes it simple to understand the porosity modality and partition. The petrophysical grouping at MICP level is built honoring this characterization. We provide a thorough comparison of the outcomes of standard approaches to petrophysical rock type with the outcomes attained utilizing the suggested pore network characterization methodology. Although the focus of this study is to improve the petrophysical grouping component of the rock-typing, further integration with geology and diagenetic overprints is required to improve the overall workflow. Additionally, we use ML methods to compute the final saturation height functions and automatically create the optimum analytical model as a function of Pc. Compared to the currently available conventional methodologies in commercial petrophysical software, this unique workflow enables more complex mathematical modeling. The overall results provide an enhanced mathematical solution that minimizes the relative error to the input Pc data. The equations are automatically constrained by the reservoir physical behavior. The suggested methodology provides a considerable increase in terms of efficiency as well as in the accuracy of the saturation modeling characterization of carbonate reservoirs. This greatly improve the saturation modelling workflows and 3D volumetric calculations using advanced ML techniques.
Integrated Logistics Cost Optimization Through Automated Forecasted Drilling Operations Report
Hussain, M. (ADNOC Onshore) | AlRashdi, A. (ADNOC Onshore) | El-Mahdy, M. (ADNOC Onshore) | El-Kasrawi, A. (ADNOC Onshore) | Ibrahim, A. (ADNOC Onshore) | Mizukami, A. (ADNOC Upstream) | Zherelyev, A. (Halliburton) | Varga, S. (Halliburton)
Abstract Oil and gas companies continuously invest on digital transformation, to economically improve logistics workflow and enhance service providers interaction. A unique digital solution has been designed to automate business processes and reduce unexpected deviations from drilling operation execution process; to avoid unplanned costs and delays affecting overall drilling performance. The manuscript will focus on drilling process modifications and performance impact resulted from implementing drilling forecasting approach for materials and services. Company and Software Provider jointly developed and implemented drilling forecast Report on top of existing reporting system to support drilling operations execution as per short- and long-term plans set earlier. Overall workflow and interconnection logic of steps were defined based on current Company's Standard Operating Procedures detailing Drilling Operation Policies and Instructions. Which ensured the software solution to be fully compliant with Company requirement. The developed automated Report passed a series of comprehensive tests in real conditions and after proven success; was decided to be implemented in Production environment to be efficiently utilized. Following the specific logic of Company's drilling operations execution, the automated forecast report improved planning procedures and automated the information exchange between Company and respective Service Providers to support smooth logistics of materials and personnel that required to be delivered to rig sites or removed from it. Implementation of first phase required strong dedication of drilling engineers, the developed report was designed to eventually lighten the current workload and release additional man-hours in future to analyze and optimize existing procedures. As a digital solution, the report was designed to gather required information from different data sources and automatically compare it with current drilling operations status; to evaluate current phase and predict accordingly the next 10 days of forecast for drilling operations, materials to be prepared and personnel to be located. Which helped to assure materials and field engineers availability on rig site on time. Assuring cost saving and avoiding unplanned logistics costs due to potential deviation and optimized overall Company's financial burden. The forecast report is being developed to be auto generated and shared on daily basis for all rigs to be available for all suppliers on daily basis. Automated forecast Report implanted on top of existing database is enriching current reporting system. Utilizing a digital and automated approach for forecasting daily operation and planning tool for services and materials ahead of time would improve drilling performance efficiency, eliminate any unwanted delays and complement Company's digital strategy.