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Collaborating Authors
Ojha, Aditya
Neutron Response Modeling to Track Lean Gas Plume in Recycled Gas Cap Reservoir in Concurrent Gas Cap-Oil Rim Development: A Step Forward
Reddy, Rathnakar (ADNOC Onshore (Corresponding author)) | Ojha, Aditya (ADNOC Onshore) | Nachiappan, Ramanathan (ADNOC Onshore) | Mengal, Salman (ADNOC Onshore) | Al Hosani, Mariam (ADNOC Onshore) | Al Bairaq, Ahmed (ADNOC Onshore) | Baslaib, Mohamed (ADNOC Onshore)
Summary Gas cap pressure maintenance while developing the associated oil rim is a critical aspect for optimum recovery. Preventing gas cap pressure dropping below dewpoint by injecting lean gas is essential for concurrent gas cap-oil rim development. Reservoir heterogeneity aggravates lean gas override causing preferential movement of lean gas plume. Thus, it is important to track lean gas plume while recycling and understanding the breakthrough potential of lean gas. This paper demonstrates a new workflow to track lean gas plume by estimating phase saturations with a case study from one of the giant oil and gas fields, Onshore, Abu Dhabi. Pulsed neutron capture (PNC) tools are used for reservoir monitoring and surveillance. However, sigma log evaluation is insufficient to derive individual hydrocarbon phase saturations to monitor lean gas plume. Neutron response modeling (NRM) is devised to differentiate between lean and rich gas. NRM is a probabilistic solver with input of mineral and fluid phase parameters into tool response functions in petrophysical evaluation. To distinguish with discrete neutron fluid response between lean and rich gas, pressure/volume/temperature (PVT) data are utilized to derive hydrogen index, capture cross section, thermal decay length, and neutron macro parameters, such as neutron slowing down length and migration length. Neutron response is investigated for lean and rich gas with sensitivity of invasion effects on neutron log by calibrating to core porosity. The response for each phase under thermal neutron and capture modes with corresponding raw neutron log statistics is reviewed in both openhole and casedhole environments in known lean/rich gas intervals. Thirty-five wells spread across gas cap and oil leg with quality neutron log data are modeled and individual phase saturations are estimated. The target reservoir is under development with over three decades of lean gas injection to support oil production. NRM results and phase saturations are validated with recent formation sampling, which enhanced the confidence in the overall workflow. Later, the results are verified to be in excellent agreement with lean gas injection and production history of the target reservoir. The identified movement of lean gas highlights nonuniform geology and gravity segregation of injected lean gas into upper members of the target reservoir. The results also emphasized the need for better injection support to lower members of the target reservoir where gas cap development is ongoing. The solution presented is unique, particularly for lean gas injection projects by utilizing PVT for NRM based on neutron transport mechanism in pore fluids. Existing workflows require a special nuclear modeling platform with computationally expensive processing on data sets acquired using advanced logging technology. In spite of these prerequisites, existing workflows are not able to distinguish lean gas over rich gas. This paper effectively demonstrates NRM workflow distinguishing lean gas plume from rich gas using neutron logs and reveals compelling reservoir management insights. The sensitivity studies and practicality of this workflow highlight the fundamental importance of neutron logs in mature fields.
- North America > United States (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.25)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Gas-injection methods (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
Novel Engineering Approach Utilizing Underbalanced Coil Tubing Drilling Solutions for Tight Sour Gas Carbonate.
Abd EL Meguid, Mohamed Osama (ADNOC Onshore) | EL Shahat, Ayman (ADNOC Onshore) | Bin Sumaida, Ali Sulaiman (ADNOC Onshore) | Al Mutawa, Ahmed Abdulla (ADNOC Onshore) | Saleh, Abdalla Saleh (ADNOC Onshore) | Almazrouei, Saeed Mohamed (ADNOC Onshore) | Yousfi, Fawad Zain (ADNOC Onshore) | Baslaib, Mohamed Ahmed (ADNOC Onshore) | Al Ali, Abdulrahman Hasan (ADNOC Onshore) | Al Hosani, Mariam Ahmed (ADNOC Onshore) | Al Bairaq, Ahmed Mohamed (ADNOC Onshore) | Mohamed, Ihab Nabil (ADNOC Onshore) | Ojha, Aditya (ADNOC Onshore) | Alawadhi, Fatima Omar (ADNOC Onshore) | Solaiman, Tarek (ADNOC Onshore) | Almteiri, Nama (ADNOC Onshore) | Bernadi, Bondan (ADNOC Onshore) | Rangel, Pedro (Schlumberger) | Basha, Maged (Schlumberger) | Zhylkaidarova, Sholpan (Schlumberger) | Wahbi, Ali (Schlumberger) | Jumagaliyev, Yerlan (Schlumberger) | Rennox, John (Schlumberger)
Abstract Due to the declining reservoir pressures in some of its onshore gas carbonate fields, ADNOC decided upon an initial 3 well UBCTD, (Underbalanced Coil Tubing Drilling), campaign in its onshore Asab and Bab fields, with 2 wells to be drilled in Asab and 1 in Bab. Both target fields have high H2S concentrations up to 6% and ADNOC undertook the necessary candidate selection process, Basis of Design, and equipment selection to enable them to drill these wells using UBCTD techniques. Due to the high H2S content, it was required that a closed loop system design was implemented, which was the 1 successful one implemented in the Middle East. The project's given objectives were analyzed, and the planning was conducted considering the different aspects to achieve ADNOC's objectives and expectations. Several challenges were faced during the designing phase which had to be resolved prior the operations start-up. These challenges included extended drilling reach, closed loop returns handling system, handling high H2S levels at surface amongst others. One of the main design objectives, the drilling reach, was improved by optimizing the trajectories Dog Leg Severity, (DLS), and Bottom Hole Assembly, (BHA), configuration. Instead of a conventional mud motor, a turbine was used to give power to the bit and allowed having a lower Weight on Bit, (WOB), to drill the formation, thereby increasing the depth of the section. The trajectory was planned in a way to maximize the reservoir contact within the production layers and reduce footage in the non-productive zones between the producing formations, therefore maximizing the well productivity. Increasing the well production was key to the project economics and to prove the value brought by the UBCTD to ADNOC's hydrocarbons production. Several business disciplines collaborated closely under the IWC, (Integrated Well Construction), stewardship to provide practical solutions and design a system specifically tailored to achieve the objectives and overcome the various challenges associated with this project. The final solution was a closed loop system capable of:removing solids/drilled cuttings from the system. measuring flow rates of different fluid phases (gas, condensate & water). treating and removing H2S. exporting gas and condensate to ADNOC's production facility. whilst drilling the well in Underbalanced conditions. After the operations start-up on the 1 well, the returns handling system was modified to improve the efficiency and enhance the safety of the personnel and equipment. This paper will discuss the design and planning involved in the successful drilling of these three wells and the operational challenges and mitigations encountered while drilling.
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Alaska > North Slope Basin > Lisburne Field (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Asab Field > Thamama Group Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.89)
Lessons Learnt from First Time Coiled Tubing Underbalanced Drilling Implementation in Adnoc Group of Companies
Abd EL Meguid, Mohamed Osama (ADNOC Onshore) | EL Shahat, Ayman (ADNOC Onshore) | Bin Sumaida, Ali Sulaiman (ADNOC Onshore) | Al Mutawa, Ahmed Abdulla (ADNOC Onshore) | Saleh, Abdalla Saleh (ADNOC Onshore) | Almazrouei, Saeed Mohamed (ADNOC Onshore) | Mantilla, Alfonso (ADNOC Upstream) | Yousfi, Fawad Zain (ADNOC Onshore) | Baslaib, Mohamed Ahmed (ADNOC Onshore) | Al Ali, Abdulrahman Hasan (ADNOC Onshore) | Al Hosani, Mariam Ahmed (ADNOC Onshore) | Al Bairaq, Ahmed Mohamed (ADNOC Onshore) | Mohamed, Ihab Nabil (ADNOC Onshore) | Ojha, Aditya (ADNOC Onshore) | Alawadhi, Fatima Omar (ADNOC Onshore) | Solaiman, Tarek (ADNOC Onshore) | Almteiri, Nama (ADNOC Onshore) | Bernadi, Bondan (ADNOC Onshore) | Rangel, Pedro (Schlumberger) | Basha, Maged (Schlumberger) | Cui, Shuai (Schlumberger) | Jumagaliyev, Yerlan (Schlumberger) | Rennox, John (Schlumberger)
Abstract ADNOC Onshore initiated a pilot implementation of Under Balanced Coiled Tubing Drilling technologies for Gas Reservoirs with this being the first time in the ADNOC Group of Companies. Detailed planning was carried out for this project implementation and the onward optimization for the 3 well based on lessons learnt was carried out. This 3 well pilot Underbalanced Coiled Tubing Drilling, UBCTD, pilot campaign involves the sidetracking from a pre-drilled 6" hole and then drilling 3-ยพ" laterals with the laterals drilled in a carbonate gas reservoir utilizing UBCTD technology and methods with these being applied to eliminate formation damage, enhance production, and improve drilling performance.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > UAE Government (0.83)
- Asia > Middle East > UAE > Abu Dhabi > Rub' al Khali Basin > Asab Field > Thamama Group Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.99)
- Asia > Middle East > UAE > Thamama Group > Shu'aiba Formation (0.89)
- Asia > Middle East > Saudi Arabia > Thamama Group > Kharaib Formation (0.89)
- Well Drilling > Pressure Management > Underbalanced drilling (1.00)
- Well Drilling > Drilling Operations (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
Modeling a Novel Approach to Delay the Water Breakthrough in Gas Cap Wells Using Smart Completions: Case Study Onshore Abu Dhabi Field
Ojha, Aditya (ADNOC Onshore) | Al Hosani, Mariam Ahmed (ADNOC Onshore) | Al Bairaq, Ahmed Mohamed (ADNOC Onshore) | Mengal, Salman Akram (ADNOC Onshore) | Mohamed, Ihab Nabil (ADNOC Onshore) | Abdullayev, Azer (Halliburton) | Roopal, Allen (Halliburton)
Abstract This paper presents modeling a novel approach to determine the impact of implementing smart completions on water injectors located near the periphery of the gas cap and on gas producing wells situated in the gas cap of a giant Middle East onshore field. The objective of the study is to thoroughly investigate different smart completion designs which can effectively delay water breakthrough on the gas cap wells. The study investigates the impact of adding smart well completion designs like ICD and AICD valves in delaying water breakthrough. The first phase involves adding smart completions to only water injectors. Sensitivity runs on several downhole completion design scenarios are conducted using a commercial near wellbore simulator and the optimal downhole completion design is implemented on a dynamic model and its impact is examined using a reservoir simulator. In the second phase, this approach is applied only for gas producers, and in the third phase the smart completions are simultaneously applied to both water injectors and gas producers. The detailed study has revealed that the uncertainties and time involved in selecting optimal ICD design and placements could be reduced considerably by using an optimized workflow. The workflow uses a carefully designed process of using the outcomes from near wellbore simulators and incorporating the results in the actual full field dynamic models to assess the field level impacts. When compared to the bare foot design, ICD and AICD valves showed better performance in delaying water breakthrough from the gas wells. This paper provides a detailed study on the impact of different smart completions on delaying water breakthrough in gas production wells. The study also investigates how a uniform injection or production profile can be produced using different smart completions. Uniform injection and production profiles limit water fingering in the reservoir, and thereby delay water breakthrough caused by the flow of water through high permeability channels.
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.51)
- Asia > Middle East > Kuwait > Jahra Governorate (0.40)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Bab Field > Thamama Group Formation (0.99)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Abu Dhabi Field (0.99)
Maximizing Recovery from a Depleted Oil Rim Carbonate Reservoir Through an Integrated FDP Approach: Case Study Onshore Field Abu Dhabi, UAE
Fathalla, Magdy Farouk (ADNOC Onshore) | Al Hosani, Mariam Ahmed (ADNOC Onshore) | Mohamed, Ihab Nabil (ADNOC Onshore) | Al Bairaq, Ahmed Mohamed (ADNOC Onshore) | Ojha, Aditya (ADNOC Onshore) | Mengal, Salman Akram (ADNOC Onshore) | Pramudyo, Yuni Budi (ADNOC Onshore) | Nachiappan, Ramanathan (ADNOC Onshore) | Bankole, Ibukun Olatunbosun (ADNOC Onshore)
Abstract This paper examines risk and rewards of co-development of giant reservoir has gas cap concurrently produce with oil rim. The study focus mainly on the subsurface aspects of developing the oil rim with gas cap and impact recoveries on both the oil rim and gas cap. The primary objective of the project was to propose options to develop oil rims and gas cap reservoir aiming to maximize the recovery while ensuring that the gas and condensate production to the network are not jeopardized and the existing facility constraints are accounted. Below are the specific project objectives for each of the reservoirs: To evaluate the heterogeneities of the reservoir using available surveillance information data. To evaluate the reservoir physics and define the depleted oil rims current Gas oil contact and Water Oil Contact using the available surveillance information and plan mitigate reservoir management plan. To propose strategies in co-development plan with increase in oil rim recovery without impact on gas cap recovery. To propose the optimum Artificial methods to extended wells life by minimize the drawn down and reduce bottom head pressure. To propose methods to reduce the well head pressure to reduce back pressure on the wells. The methodology adopted in this study is based on the existing full field compositional reservoir simulation model for proposing different strategical co-development scenario: Auto gas lift Pilot implementation phase. Reactivate using Auto gas lift all the in-active wells. Propose the optimum wells drilling and completion design, like MRC, ERD and using ICV to control water and gas breakthrough. Proposing different field oil production plateau Propose different water injection scheme The study preliminary findings that extended reach drilling (ERD) wells were proposed, The ability to control gas and water breakthrough along the production section will be handled very well by deploying the advanced flow control valves, reactivation of existing Oil rim wells with Artificial lift increases Oil Rim recovery factor, and optimize offtake of gas cap and oil rim is crucial for increase the recovery factories of oil Rim and gas cap.
- Asia > Middle East > Saudi Arabia > Thamama Group > Habshan Formation (0.99)
- Asia > Middle East > Saudi Arabia > Thamama Group > Kharaib Formation (0.94)
- Asia > Middle East > Oman > Ad Dhahirah Governorate > Arabian Basin > Rub' al-Khali Basin > Block 6 > Lekhwair Field > Thamama Group > Thamama Group > Shuaiba Formation (0.94)
- (3 more...)
Abstract An important aspect of reservoir management process is monitoring and revising plans and an essential component of reservoir management strategy is integration of technologies (Satter et al. 1994). In revisions of reservoir management plans, very rarely do operators incorporate any other data than the data from newly drilled wells and the field production in between the revisions. Any inference in the inter-well space is an interpolation between the well data, as surface seismic is limited by its resolution, as the calibration data is available only at well level. For an effective reservoir management, especially in the decline phase of the field, a logical integration of technologies to capture maximum heterogeneity in the interwell space can be very advantageous. Crosswell technologies, that provide high resolution data between a set of wells, but if used individually, are essentially limited to a very small part of the field having multiple wells. Therefore, in order to monitor and revise reservoir management plans, it is important that such technologies are integrated with full-field solutions. This paper describes a methodology that aims to better manage reservoir by logically integration the 3D reservoir model- a full-field solution- and crosswell electromagnetics/crosswell seismic- an interwell solution.
Abstract Until recently, reservoir characterization methods in the industry were limited to use of seismic technologies in exploration of oil and gas and had a very constrained role in production and development. In the past, using characterization for development fields was considered a very perilous task. Technological advancements and the risk-averse mindset have significantly expanded the application of reservoir characterization. Today, reservoir characterization is the basis of any development plans made for a commercial field. Development of 3D reservoir modeling techniques to generate field development plans (FDPs) marked a step-change in reservoir characterization methods. Introduction of geostatistics and numerical simulation made it possible to build precise models to generate realistic field development scenarios. This is the state-of-the-art seismic-to-simulation method of reservoir characterization used in FDPs today. However, the struggle to estimate reservoir properties spatially away from the well continues. Surface seismic data provide excellent areal coverage but do not provide the vertical resolution required for a fine-scale reservoir model. Geostatistical methods reduce the uncertainty in spatial distribution of petrophysical properties from pseudo-point supports (wells) but are not calibrated spatially between the wells. Correspondingly, the fluid saturation distribution and the parameters used in dynamically calculating the same during numerical simulation are not calibrated in the interwell space. This paper details necessary data acquisitions and methods of calibration of 3D reservoir model to reduce uncertainty in the interwell space. The data acquisition methods have been available for some time, but have rarely been electronically incorporated in the 3D reservoir model and have been largely used to analytically guide the modeling and its inferences. A logical way of interpreting the results of acquisitions and calibrating the 3D reservoir model cell-by-cell is detailed in this paper.
- Asia (1.00)
- North America > United States > Texas (0.28)
- Geophysics > Seismic Surveying > Seismic Modeling (0.67)
- Geophysics > Electromagnetic Surveying > Borehole Electromagnetic Surveying > Cross-Well Electromagnetic Surveying (0.52)
- Geophysics > Seismic Surveying > Seismic Interpretation > Seismic Reservoir Characterization > Amplitude vs Offset (AVO) (0.47)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
Abstract Optimal exploitation of hydrocarbon reservoirs has always been a challenge due to uncertainties posed by subsurface heterogeneities that are often not factored into field development plans. Secondary and tertiary recovery mechanisms, such as waterflooding and enhanced oil recovery (EOR), are used to enhance the oilfield recovery beyond primary recovery. However, as the field development transitions to secondary/tertiary mechanisms, the challenges in monitoring these mechanisms further increase the uncertainty in field development. If these uncertainties are not reduced or incorporated properly, the field development may easily become uneconomic. This work presents a workflow that addresses the limitation of regular waterflood surveillance while characterizing the reservoir for optimal exploitation. The current technologies for waterflood surveillance are limited either to local surveillance methods, such as tracers, crosswell seismic and crosswell electromagnetics (EM), or to uncalibrated global realizations, such as full-field streamline simulation, with no validation between the wells (It is to be noted that a full-field reservoir simulation calibrated with production-injection data in defined time-interval is stated as a global-surveillance method in this paper). This workflow devises integration of an effective local waterflood monitoring method, crosswell EM, and a global waterflood modeling method, streamline simulation. The process of validating the parameters of a geological model and a dynamic model with time-lapse crosswell EM data significantly reduces reservoir characterization uncertainty and helps in the preparation of a precise dynamic model.
- North America > United States (0.46)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
A Novel Holistic Workflow for Field Development Planning in Green Field Environment: A Case Study
Alkhatib, Mohamad (Al Dhafra Petroleum Company) | Al Ali, Abdulla Ali (Al Dhafra Petroleum Company) | Mukhtar, Muhammad (Al Dhafra Petroleum Company) | Park, Sangseok (Al Dhafra Petroleum Company) | Ghorayeb, Kassem (American University of Beriut) | Nasiri, Amir (Schlumberger) | Shah, Abdur Rahman (Schlumberger) | Ojha, Aditya (Schlumberger)
Abstract A novel workflow was developed to select the optimal field development plan (FDP) accounting for the associated uncertainties in a green onshore oil field with a limited number of wells and no production data. The FDP was then revisited in view of the performance of wells drilled during the execution phase and updated as needed based on the acquired data . Comprehensive uncertainty analysis was performed resulting in multiple subsurface realizations. A broad set of development scenarios and options were screened under uncertainty. The viable scenarios were then economically evaluated, resulting in an optimal FDP that is robust to uncertainty and the least risk prone from an economical point of view. The used workflow was specifically suitable to test many development concepts and explore various options including horizontal well orientation, well pattern concept, pattern acreage and spacing, length of the horizontal sections, and landing of the horizontal sections. Following an extensive techno-economic analysis of all possible combinations (900 in total), the most robust development concept was selected and analyzed considering the viable development strategies pertaining to plateau rate, drilling schedule, phasing, water injection timing and artificial lift timings. A phased development approach was adopted enabling acquiring necessary data to mitigate the remaining uncertainty and avoid costly consequences of significant over- or under-capacity. Data acquired in one development phase were assessed and used to update the following planned phases, if necessary. The study demonstrated that the field development could accommodate a delay in either water injection or artificial lift implementation. Although it was not recommended at this stage to delay either of them, it is noteworthy that the long lead time that may be incurred in the implementation of artificial lift or the risk of lower injectivity would not impact the field performance or ultimate recovery if contained to a few years during initial production. These results further reinforced the robustness of the proposed development plan. Large subsurface uncertainty combined with an extensive set of possible development scenarios and options required cutting-edge uncertainty analysis and screening workflows to select the optimal FDP. These unique workflows can be readily used in similar green fields to help arrive at the final FDP.
- North America > United States (1.00)
- Asia > Middle East > Qatar (0.30)
- Asia > Middle East > Saudi Arabia (0.29)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
- (5 more...)
High-Speed Robust Simulation Delivers Fast, Detailed Results for a Complex Offshore Field
Thapliyal, Anil (Oil and Natural Gas Corporation Ltd.) | Kundu, Sudeb (Oil and Natural Gas Corporation Ltd.) | Dimri, Sunil Kumar (Oil and Natural Gas Corporation Ltd.) | Dutt, Ankit (Schlumberger) | Mishra, Shubham (Schlumberger) | Aggarwal, Akshay (Schlumberger) | Agarwal, Ankit (Schlumberger) | Ojha, Aditya (Schlumberger) | Bradley, David (Schlumberger) | Giddins, Marie Ann (Schlumberger)
Abstract For planning the operations of Oil and Natural Gas Corporation Limited (ONGC) in the complex Heera field, it was estimated that over one hundred simulation runs would be needed to complete the history match of the field and almost the same number of simulations would be needed for production forecasting. Heera is a large field, with multiple faults and seven stacked carbonate formations. There are significant variations in petrophysical properties, and variable degrees of communication between reservoir zones. The simulation models include 479 wells with commingled production or injection. Well trajectories are complex and include multilateral and horizontal configurations. Field development options include use of simultaneous water alternating gas (SWAG) for enhanced oil recovery. Combining all these features, it would be difficult to run all the necessary sensitivity cases within the required project timeline, using a conventional reservoir simulator. Therefore, it was decided to test the applicability of a new generation simulation tool to address the challenges of the study. To ensure that the change of simulator would not impact the integrity of the model, rigorous quality checks were performed on the input data. After successful evaluation, the new software was used for the reservoir engineering study. The decision to apply the new simulator significantly reduced the elapsed time, with some realizations over 20 times faster compared to the original base case. As a result of this speed-up, numerous runs could be carried out to refine the history match. Multiple sensitivities could be used to help understand and reduce the uncertainties in a more comprehensive manner. Moreover, the prediction cases could be optimized to identify the best recovery strategy. This study has demonstrated the value of reducing simulation run times, to complete the project with greater efficiency and more confidence in the results. In future studies, high performance software tools can also enable use of fine resolution models, to capture detailed heterogeneities and optimize areal and vertical sweep.
- Geology > Rock Type > Sedimentary Rock (0.69)
- Geology > Geological Subdiscipline (0.48)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > India Government (0.55)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Heera-Panna Block (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Heera Field (0.99)
- Asia > India > Maharashtra > Arabian Sea > Bombay Offshore Basin > Bassein Field (0.93)
- (2 more...)