Day 3 Wed, August 02, 2023最新文献

{"title":"Comparative Analysis of CO2 Storage Capacity on Saline Aquifers in the Niger Delta","authors":"Oluseyi Akinboade, B. Olusola","doi":"10.2118/217245-ms","DOIUrl":"https://doi.org/10.2118/217245-ms","url":null,"abstract":"\u0000 The recent clamour for net-zero gas emissions has increased the demand for further research in carbon capture, storage and utilization as a means to further reduce green gas emissions. Therefore, this paper has identified trapping index parameters to evaluate CO2 storage capacity in the Niger Delta of Nigeria. This was carried out by assessing two major trapping mechanisms that affect the efficiency of the carbon injection and storage within the saline aquifer.\u0000 In this work, we conducted a numerical simulation to compare the CO2 storage capacities of two reservoirs with saline aquifers. We considered some minor reservoirs not suitable for commercial development due to their minimal oil in place values and net pay thickness of less than 30 ft. These reservoirs are charged with aquifers which were simulated to study the storage capacity of CO2 at downhole conditions. The impact of the reservoir structure, permeability and pressure regimes are some of the parameters that were observed to affect CO2 storage capacity.\u0000 CO2 was continuously injected into the aquifers via injector wells at 80% of their fracture pressure. Crestal monitoring wells ensured the pressure distribution around the cap rock did not exceed fracture pressure limits. The results were compared and simulation-based inferences were made for each reservoir.\u0000 The results showed similar migration patterns for each reservoir however there was a significant difference in the residual trapping mechanism of both reservoirs. This impacted the overall CO2 storage capacity at the end of the simulation run. The results obtained from this work can be applied to other reservoirs in the Niger Delta where commercial development is not expected due to their hydrocarbon in-place volumes.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"17 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126822458","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Otakikpo Offshore Integrity Challenges and Solution","authors":"J. Akinyemi, Tamunotroko kala-otaji","doi":"10.2118/217129-ms","DOIUrl":"https://doi.org/10.2118/217129-ms","url":null,"abstract":"\u0000 The Otakikpo marginal field was carved out of OML 11 and is situated in the southern part of the license. Green Energy International Limited, the operator, successfully implemented the first phase of the field development between 2015 and 2017. This was followed up with a 2nd phase in 2022. The field currently produces circa 11000 bopd.\u0000 Due to its proximity to the shoreline, an amphibious production and evacuation methodology was implemented. This consists of batch production into onshore tanks, a subsequent evacuation into offshore shuttle tanker via an installed 6\", 6 Km offshore pipeline and final transportation to a 3rd party FSO facility. The end of the offshore leg is connected to a PLEM (Pipeline End Manifold) which acts as interface between marine pipeline and the submarine hose system. The mooring systems consists of 2 gravity anchors (5tons each ~ port and starboard); 200m steel anchor chains; 40m sling wire; 20m sling wire; and a 100m pick up rope.\u0000 However, the offshore environment experiences a significant adverse weather condition between March and December that peaks between June and November every year. Often, it could take professional divers up to 5 days to pick up rope from the seabed depending on weather condition. There were cases of incessant twisting, tension and curling as the hose is exposed to swinging by ocean swell and current leading to loss of operational integrity of the offshore system. Restoring the integrity of the system led to significant operational downtimes as high as 20 days per year; a situation that was not sustainable for a marginal field producer.\u0000 The GEIL engineering and operations team developed and implemented several vintages of design modifications over time to mitigate these concerns. The team realized that the most challenging part of resolving the hose swinging issue was finding a way to keep it fixed, in such a way that the hose end does not move under any weather condition(s). To achieve this, the team designed and installed a Crossbar + Buoy system. The Crossbar was installed on the seabed, while ensuring the height is above the water surface. A boat is used to unhook and hook up the cargo hose to the Crossbar before and after every shuttle loading respectively. This allows for a more efficient pick up and transfer of hose to tanker (10 mins) by professional divers while eliminating the challenges with hose twisting which usually results in hose curling around the PLEM and incessant shutdown from the EPF. Luckily for our operations, there was no spill recorded in these scenarios due the effective communication between EPF and the marine team, and timely shutdown of crude flow from the EPF.\u0000 This paper aims to highlight the seasonal integrity challenges faced by the Otakikpo offshore evacuation system, its effect on operational excellence and the various stages of the elegant solutions developed and implemented.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125304883","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydrogen a Key Solution to Nigeria Energy Poverty: A Case Study of a Pilot Project","authors":"D. A. Okolocha, T. O. Oghale, A. Odili, D. Ogagarue","doi":"10.2118/217251-ms","DOIUrl":"https://doi.org/10.2118/217251-ms","url":null,"abstract":"\u0000 In this study, sustainable development is reviewed with particular focus on how Nigeria can efficiently utilize her renewable energy resources to provide cheap and affordable energy using Hydrogen as a fuel source to drive a Hydrogen economy. Hydrogen has the potential to become an important part of Nigeria's energy mix, as it is an abundant, clean, and safe fuel source. The paper first outlines the meaning of Hydrogen economy and it's important in the Nigeria energy mix. It also address the current energy situation in Nigeria, with a focus on the challenges faced by the country with regards to energy availability and affordability as well as the future of the conventional Petroleum base economy. It then provides an overview of hydrogen production and its associated technologies, with a focus on the potential of hydrogen as an alternative fuel source using water. The paper presents a proposed approach to achieve a balanced energy availability and affordability in Nigeria, with a focus on the development of hydrogen infrastructure. An experimental approach was used to demonstrate how hydrogen can be extracted from water into a storable fuel. The stored Hydrogen fuel was used to power a fabricated hydrogen fuel cell to generate energy for domestic cooking. The study highlights the importance of the experimental setup and the need for development in a commercial scale to meet the rising energy demand of the nation for a sustainable development. Finally, the paper outlines the potential benefits of hydrogen production for Nigeria, as well as the potential barriers to its successful implementation. The paper concludes by highlighting the need for further research and analysis to understand the feasibility of using hydrogen energy in Nigeria.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"338 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126599615","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Influence of Surface Modification on the Interfacial Tension Reduction and Wettability Alteration of Iron Oxide Nanoparticles Under Reservoir Conditions","authors":"F. Yakassai, M. Jaafar, M. Sidek, A. Agi, J. Gbonhinbor, N. Ridzuan, S. Mahat, E. Ngouangna, J. Oseh, M. Al-Ani","doi":"10.2118/217121-ms","DOIUrl":"https://doi.org/10.2118/217121-ms","url":null,"abstract":"\u0000 Iron oxide nanoparticles (IONPs) are at the forefront of advanced materials considered for enhanced oil recovery (EOR), due to their unique physicochemical properties. However, the major drawback is that IONPs quickly agglomerate to diminish their high surface energy, particularly in reservoir brine. Hence, losing their stability and beneficial characteristics which have a negative impact on oil recovery. In this study, these challenges have been circumvented by the functionalization of IONPs with 3-aminopropyltriethyloxysilane (APTES) and tetraethyl orthosilicate (TEOS). Herein, co-precipitation synthesis of bare IONPs and post-synthesis grafting of APTES (AIONPs) and TEOS (SIONPs) were carried out in the laboratory. Synthesis and functionalization were confirmed by examining the physical and chemical properties of the nanomaterials (NMs) using high-resolution transmission electron microscopy (HRTEM), energy dispersive X-ray analysis (EDX), X-ray diffraction (XRD), and Fourier-transform infrared spectroscopy (FTIR) analysis. The stability of the nanofluids (NFs) was examined using zetapotential and sedimentation analysis in the presence of reservoir brine (25,000ppm NaCl). The ability of the NFs to decrease interfacial tension (IFT) and alter the wettability of rock/fluid at reservoir conditions was examined using a K20 Easy Dyne Kruss tensiometer and Kruss drop shape analyzer, respectively. Based on the results, it was found that reservoir brine, decreased the electrostatic stability of IONFs, AIONFs, and SIONFs by 75.9%, 41.3%, and 68% respectively. The IFT reduction and wettability changes relative to the reference values of 25.53 ± 1.51 mN/m and 128 ± 3.4° at reservoir conditions were 11.6mN/m and 26° for IONFs, 7.7mN/m & 22.2° for AIONFs and 8.2mN/m& 15.5° for SIONFs. These findings contribute towards understanding the influence of functionalization on the oil recovery mechanism of IONPs under reservoir conditions.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116930433","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Offline Production Tree Installation: Key Decisions, Value Drivers and Lessons Learnt","authors":"C. Elendu, V. M. Bajomo, N. Enuneku, N. Nwamara","doi":"10.2118/217111-ms","DOIUrl":"https://doi.org/10.2118/217111-ms","url":null,"abstract":"\u0000 After successfully drilling and completing 40 wells with 5000 psi rated production trees in the swamp operation within a 5-year campaign the diverter deck on the Swamp Rig barge never posed a challenge until 6650 psi production tree had to be installed on two non-associated gas wells. The Field Development Plan (FDP) was approved in 2013 and it contained a 2-well (NAG-1A and NAG-2A) development plan for the target reservoirs with estimated recovery of 213 BCF of rich gas and 4.6 MMSTB of pool condensate at initial production rates of 35 MMSCFD and 1,380 BCPD each for both wells.\u0000 Gas production from these wells will bulk flow to the NAG separator located at the Production Flow Station where the pool condensate will be separated from it. The rich gas will subsequently be transported to the gas plant onshore bypass for supply to the domestic market through the ELPS.\u0000 NAG-1A and NAG-2A wells are part of the Non-Associated Gas (NAG) development and were completed as single string deviated gas producers with HRWP completions to meet target production rates and reserve recovery.\u0000 After successfully drilling and completing the NAG-1A well, it was later discovered that the diverter deck of the rig was going to impact the 6650 psi production tree while moving the rig onto the NAG-2A well slot on the same jacket.\u0000 This paper sets out to give an overview of the planning, risks assessment and execution for using a crane barge to successfully install two 6650 psi production trees on two NAG wells incidents free, after the drilling rig departed location due to the diverter deck limitation. Lessons learned and best practices were captured as well as the resultant cost savings from using the crane barge instead of the rig to install the production trees on the two NAG wells.\u0000 The total number of days to complete the offline XMT installation using a crane barge was 5 days for both wells while working daylight hours only. This resulted in a cost savings of 154,200 USD per well.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115252609","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Evaluation Studies of KCl and Amino Acid Mixtures for Clay Stabilization and Rheological Enhancement of Water-Based Fracturing Fluids","authors":"K. O. Duartey, A. K. Quainoo, C. Darko","doi":"10.2118/217118-ms","DOIUrl":"https://doi.org/10.2118/217118-ms","url":null,"abstract":"\u0000 Conventional stabilizers such as inorganic salts in water-based fluids are restricted for use in gas and oil shales drilling and hydraulic fracturing for drilling due to environmental, economic and performance concerns. For example, 2% use of KCl, a commonly used inorganic salt, contains an excess of 9500ppm chloride. This is considered high and toxic. Apart from environmental problems, KCl inhibiting solutions tend to negatively affect the rheology of the water-based fluids, posing a dilemma for industry operators. The clay and rheological stabilizing effects of KCl and amino acid mixes for hydraulic fracturing operations were investigated in this study. The stabilizing and rheological potentials of mixes of KCl and organic compounds have proven to be superior to the separate compounds in studies. The KCl was used in the study at safe quantities (1%) to prevent toxicity concerns. In this study, the inhibition potentials of KCl+ Arginine and KCl + Alanine solutions, mixed approximately at ecologically safe quantities, were tested at different bentonite wafers using M4600 Linear swell at 25°C and 1000psi in the work. Furthermore, rheological studies on bentonite-based suspensions were carried out using a high-precision Discovery Hybrid Rheometer (DHR-1). This was done to monitor the flow parameters of the inhibiting suspensions and their anti-swelling effects on the bentonite component of the prepared fracturing fluid. The effects of the mixtures were also compared to that of KCl, Arginine and Alanine inhibition solutions. Herschel-Bulkley's model was also used to determine the flow characteristics. After 24 hours of testing, the swelling findings reveal that KCl+ Arginine/KCl + Alanine treated fracturing fluids significantly affect the clay stabilization and rheological properties of the fracturing fluid. The study provides basic information on the inhibition potentials of KCl and natural amino acid mixtures in water-based fracturing fluids for clean clay stabilization.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"38 10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122727488","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Well Management: Top Tier Well Approach","authors":"Sulaiman Bakenne, Stephen Oboh, Ishomo Lucky, Iheanyi Ugwa","doi":"10.2118/217198-ms","DOIUrl":"https://doi.org/10.2118/217198-ms","url":null,"abstract":"\u0000 Effective well management and reliability are fundamental to ensuring high well production uptime with the attendant benefit of minimizing unscheduled volume loss. Well equipment reliability is impacted by the scope and frequency of preventive maintenance (PM) in place. The optimum PM frequency is one that maximizes incremental value with reduced equipment failures. While defining the PM program, due consideration must be given to the well risk (business and safety) which impacts consequence level of failures. In matured assets with high well counts, PM programs should be structured to maximize uptime of wells with significant volume contribution, critical gas producers to support gas lift systems and injectors while also minimizing process safety risk on all wells. These wells are referred to as top tier wells.\u0000 This paper defines criteria for selecting top tier wells. It also focuses on using a Prevent-Detect- Respond-Recover (PDRR) approach in defining a well equipment PM program that meets industry and local regulatory requirements to drive improved reliability of the top tier wells.\u0000 Prevent-Detect initiatives leverage Root-Cause-Failure-Analysis (RCFA) data to minimize the likelihood of equipment failure, and by extension, provide a focused surveillance system to ensure failures are detected before equipment are taken out of service. Whereas Respond-Recover initiatives provide a defined response plan to well equipment reliability issues through low complexity intervention actions and subsequent detailed repairs to correct detected failures with minimal downtime impact.\u0000 The benefit of a top tier approach to PM is to drive incremental business benefit for the asset through optimization of existing resources.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"62 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133537430","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Harnessing Value from Mature Offshore Asset: Successes from Recent Acid Stimulation Campaigns in Field X","authors":"A. Ganiyu, M. Burgess, Aghogho Eyeregba, Jules Vesters, Chukwu Festus, Olufemi Adebayo, Oyewole Anthony","doi":"10.2118/217189-ms","DOIUrl":"https://doi.org/10.2118/217189-ms","url":null,"abstract":"\u0000 Field X is a mature offshore field in the Niger Delta. In 2013, several wells in field X experienced significant production decline and a study conducted by cross-functional team identified fines migration as the primary cause of sandface impairment and acid stimulation was recommended as remediation for the damage. This technical work highlights the strategies and methodology adopted in implementing acid stimulation in field X.\u0000 The approach to candidate selection involved screening of historical well test data and pressure transient analyses (PTA) database for impaired/at-risk completions. Typical selection criteria are productivity index (PI) degradation (> 50%), pressure drop due to near wellbore skin (DP skin >500psi), violation of flux constraint, Interval Control Valve (ICV) integrity (dual completion) and water-cut evolution (<5.0%). The team also piloted diversion agents in the field to improve stimulation in wells with high water-cut. A novel method of using dynamic positioning marine vessel with Remotely Operated Vehicle (ROV) and customized dual conduit Coil Tubing (CT) have been deployed to bullhead acid into the formation.\u0000 In the last two campaigns executed in 2020 & 2021, this ingenious way of harnessing value from field X has resulted to combined incremental Initial Production (IP) gain of approximately 10,000 bopd and safeguarded completion of a critical oil producer (~11,000 bopd). The total project cost for the two campaigns was ~$25.4 million resulting in significant cost savings (>$51.6 million) compared to rig operations. The use of cross-functional team, robust candidate selection, continuous lookback and adoption of best practices were critical to successful execution. Some challenges being experienced in the field are lack of adequate injectivity, formation lock-up, increasing gas oil ratio (GOR) and increasing water-cut. The team plans to deploy diverters across additional high water-cut wells in future campaigns.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"429 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132769180","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integration of Artificial Intelligence with Economical Analysis on the Development of Natural Gas in Nigeria; Focusing on Mitigating Gas Pipeline Leakages","authors":"C. Ezechi, E. Okoroafor","doi":"10.2118/217163-ms","DOIUrl":"https://doi.org/10.2118/217163-ms","url":null,"abstract":"\u0000 With Nigeria's massive proven natural Gas reserves and potential to provide a sustainable and economically viable system, a significant challenge has been the need for development strategies that enhance safety, growth, and investments in the gas sector. To tackle these challenges, the data generated in oil and gas, which is a valuable tool, has to be harnessed for stakeholders to implement life-changing solutions. The Nigerian economy has faced a significant drawback in the gas transportation and storage sector. The challenge in gas transportation can be seen in gas pipeline leakages which have resulted in the loss of lives, properties, and the country's revenue. Thus, early leak detection gas of pipelines remains critical for economic and safety reasons. This paper uses artificial intelligence to build models that utilize the available gas flow data to detect potential gas leakages across the pipeline. Machine learning algorithms which include Recurrent Neural Networks, and K-nearest neighbourhood are built and trained with operational data to derive the optimal learning model. Also, each model's performance metrics were evaluated to measure the model's accuracy and precision. Furthermore, an economic model is then developed to show the monetary benefits of implementing AI solutions to gas leakages. Thus, we provide a stepwise comparative analysis of the gas revenue, gas leakage detection cost, and the cost of providing an answer from an AI-based architecture to a non-AI-based one. The results showed that recurrent neural network outperforms the K-nearest neighbors in leak detection in pipelines as a result of the framework of neural network that allows the algorithm to learn without human supervision a and sift through the data set and label the data point. However, all the machine learning models possess high reliability. The accuracy and reliability of these models upon economic analysis proved to be a cost-effective solution lowering cost and increasing revenue. These models can be employed by companies and engineers to tackle the problem of pipeline leakage detection.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122224258","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Oil & Gas Production Capacity Digitalization – A Strategic Approach to Production Deferment Management","authors":"A. K. Adebajo, E. Duruzor, B. Oyakhire, B. Onasanya, C. Nwangwu, E. Michael, D. O. Akpedeye, O. O. Afere, D. I. Ayalogu","doi":"10.2118/217224-ms","DOIUrl":"https://doi.org/10.2118/217224-ms","url":null,"abstract":"\u0000 Deferred production is a common occurrence in the E&P industry particularly for mature assets, usually accounting for significant volumes to an assets total production. As a result, E&P companies are continually pursuing innovative ideas and leveraging the latest technologies to support earlyidentification of underperforming wells to minimize production loss and maximize asset recovery.\u0000 This paper focuses on Oando Energy Resources (OER) in-house development and operationalization of a Production Capacity Digitalization solution. A continuous business process improvement initiative geared towards enhancing the management of the company's portfolio of shut-in wells and reporteddeferred volumes. The digital solution is designed to guide senior management towards strategic planning and achieving cost-effective production restoration by integrating time, budgetary and economic factors in a single platform for shut-in volumes classification.\u0000 The digital platform integrates multi-disciplinary asset data, deferment management processes withorganizational structure and leverages petroleum engineering workflows (validation, diagnosis & analysis) for systemic understanding and collaboration of stakeholders, to make informed decisions on volumes restoration efforts, ensure the technical team is chasing the \"right\" volumes forrestoration and focus on high priority assets with critical production capacity.\u0000 This paper describes the production capacity workflow, implementation, development strategy, valueproposition and benefits of the solution to OER on her quest for improved business performance management and operations excellence in order to maximize value for all stakeholders.","PeriodicalId":407977,"journal":{"name":"Day 3 Wed, August 02, 2023","volume":"98 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116332534","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}