Day 2 Tue, March 19, 2019最新文献

{"title":"Reservoir Fluid Geodynamics in Brazilian Presalt Carbonate Field","authors":"A. Bertolini, J. Monteiro, Jesus A. Cañas, S. Betancourt, O. Mullins, S. Colacelli, R. Polinski","doi":"10.2118/194841-MS","DOIUrl":"https://doi.org/10.2118/194841-MS","url":null,"abstract":"\u0000 The objective of this study is to characterize fluid distributions in a presalt field by using well data including downhole fluid analysis (DFA) from wireline formation testers (WFT), openhole logs, and a simplified structural/geological model of the field. From an understanding of the petroleum system context of the field, reservoir fluid geodynamics (RFG) scenarios are developed to link the observations in the existing datasets and suggest opportunities to optimize the field development plan (FDP).\u0000 DFA measurements of optical density (OD), fluorescence, inferred quantities of CO2 content, hydrocarbon composition, and gas/oil ratio of fluids sampled at discrete depth in six presalt wells are the basis of this study. DFA data at various depths captures fluid gradients for thermodynamic analysis of the reservoir fluids. OD linearly correlates with reservoir fluid asphaltene content. Gas-liquid equilibria are modeled with the Peng-Robinson equation of state (EOS) and solution-asphaltene equilibria with the Flory-Huggins-Zuo EOS based on the Yen-Mullins asphaltenes model. OD and other DFA measurements link the distribution of the gas, liquid, and solid fractions of hydrocarbon in the reservoir with reservoir architecture, hydrocarbon charging history, and postcharge RFG processes.\u0000 Asphaltene gradient modeling with DFA reduces uncertainty in reservoir connectivity. The CO2 content in some sections of the field fluids limits the solubility of asphaltene in the oil, and the small asphaltene fraction exists in a molecular dispersion state according to the Yen-Mullins model. Low values of OD and small asphaltene gradients seen in most of the upper zones reflect the small asphaltenes concentration in the crude oil. The CO2 concentration was modeled with the modified Peng-Robinson EOS in good agreement with measurements in upper reservoir zones. Matching pressure regimes and asphaltene gradients in Wells B and C indicate lateral connectivity. The hydrocarbon column in this part of the reservoir is in thermodynamic equilibrium. In Wells A, C, D, E, and F the OD of the oil indicates an asphaltene content increase by a factor of four at the base of the reservoir as compared with the crest of the reservoir. This tripled the viscosity in Wells C and D, as indicated by in-situ viscosity measurements. The accumulation of asphaltenes at the bottom of the reservoir is most likely driven by a change in solubility resulting from thermogenic CO2 diffusion into the oil column from the top down.\u0000 The challenge of the limited number of wells in the development phase of a presalt field for obtaining data to evaluate reservoir connectivity before the FDP is ably addressed by deploying the latest WFT technologies, including probes for efficient filtrate cleanup and fluid properties measurement. These measurements and methodology using a dissolved-asphaltene EOS enabled developing insightful RFG scenarios.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76068842","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":"Succession Planning; A Way Forward in Achieving Organizational Strategies","authors":"Eisa Hadi Al-Daihani, A. K. Nandi, Syed Mohammad Raza","doi":"10.2118/194773-MS","DOIUrl":"https://doi.org/10.2118/194773-MS","url":null,"abstract":"\u0000 The upstream oil and gas industry, facing with an aging workforce, need to implement the right approach to ensure that competent work force available to carry forward the needed tasks in achieving the company's strategic goals. As organization grows, we need to ensure that processes are in place to attract, retain and develop the employee's talent for succession planning and management. The paper present a strategic process that focuses on creating a sustainable value chain of high potential talent who have the requisite knowledge and skills to lead and manage new organizational requirements and address business challenges.\u0000 As good succession planning is critical for companies facing the \"big crew change,\" a systematic approach to implement fast track processes is proposed. It involves: i) Critical analysis of manpower (ageing/ specialization etc.), ii) Identification of specialized jobs / competencies, iii) Designing training & development roadmap for all jobs/ levels iv) Young Professional's, Mid- Career and Advance Career Competency Development Roadmaps v) Shadowing the personnel according to the jobs with target date and vi) Robust competency assessment process.\u0000 The significant impact of implementing above process will ensure the changed crew acquire the desired competencies within timeframe and will be able to take over the retired employee's position. Moreover, there will be no substantial setback to the organization in achieving the organizational strategies since technical capabilities is retained through systematic knowledge transfer process.\u0000 Implementing a proper succession plan process within the company is one of the significant initiatives to support the development of technical capabilities and leadership capacity to address the challenges like growth in production targets and handling maturing and more complex fields. The proper succession planning and management will also overcome the challenges of selecting the top performers and pooling the talent with equipped technologies.\u0000 The approach adopted will not only solve the problem of emerging big crew change but also help in achieving the company's strategic goals.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"417 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76326549","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":"Role of Geomechanics and Integrated Reservoir Characterization in Production Enhancement from a Heterogeneous Carbonate Reservoir: A Success Story from Kuwait","authors":"G. S. Padhy, Tahani Al-Rashidi, T. M. Gezeeri, A. Shinde, S. Perumalla, Chong Zhou","doi":"10.2118/194920-MS","DOIUrl":"https://doi.org/10.2118/194920-MS","url":null,"abstract":"\u0000 The subject upper Cretaceous carbonate formation has been characterized as a heterogeneous reservoir with varying facies and petrophysical properties. Distribution of facies strongly varied not only with depth, but also laterally across the field. Upper part of the reservoir is dominated by natural fractures whereas lower part is predominantly argillaceous with mud enrichment. In addition, presence of laminations and vugs enhanced the heterogeneity of the reservoir. Very few wells were drilled and some of them were fractured. This paper demonstrates how geomechanical and integrated reservoir characterization has shown value in well placement strategy.\u0000 Built number of well-based geomechanical models with data from all wells in order to capture reservoir heterogeneity in models. These models quantified the distribution of rock mechanical properties and pore-pressure as well as present day principle stresses. In addition, these models were integrated with geological model as well as seismic data to generate a 3D geomechanical model. After a thorough rock typing and petrophysical classification, some patterns were recognized in terms of presence of natural fractures in certain layers. However, the production contribution of these natural fractures was unclear. Upon combining all available sensitive fracture indicators, a DFN model was built and calibrated. Finally, the 3D geomechanical model combined present day in-situ stress and pore pressure magnitudes, mechanical properties of all rock facies and natural fracture occurrences at field scale. A thorough well production analysis was also performed to validate the role of natural fractures during production.\u0000 After systematic integration of diverse sub-surface data sets in 3D geomechanical model, some natural fracture subsets were identified that are optimally oriented to become critically stressed at present day stress regime. Upon further analysis, a new parameter \"Index of Critically Stressed Fractures (iCSF)\" was created that captured the spatial distribution of networked fracture sets in 3D model that are geomechanically favorable for fluid flow. Number of geomechanical sweetspots were identified at field scale and correlated these areas with other data. It was also recommended to stimulate wells with certain practices.\u0000 Integration of geomechanical models with production analysis and natural fracture indicators delivered value in identifying geomechanical sweetspots that have potential to flow. Distribution of these sweet spots provided a strategy for well placement as well as stimulation. In addition, this paper also exhibits logical integration of findings from geosciences and engineering disciplines to make informed decisions on well planning in order to maximize the production from challenging reservoirs.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"23 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74052142","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":"Unleash Unconventional Resources with the Power of Light-Laser Technology","authors":"S. Batarseh, A. Harith, Haitham A. Othman, Hameed Al Badairy","doi":"10.2118/195094-MS","DOIUrl":"https://doi.org/10.2118/195094-MS","url":null,"abstract":"\u0000 The objective of this work is to establish a communication between the tight hydrocarbon-bearing formation and the wellbore by using high power laser technology. This paper presents different methods of utilizing the energy of the laser to enhance and improve the flow in unconventional reservoirs including tight formation, the successful results are used for field deployment strategy.\u0000 High power laser is an innovative alternative to several currently used downhole stimulation methods and technologies. The system consists of the laser source which is mounted on the surface on a coiled tubing unit, fiber optics cable to transmit the energy and the downhole tool. The advantages of utilizing high power laser technology for downhole applications are the ability to control and orient the laser energy precisely. Laser energy generates heat when in contact with the rock samples, the heat impacts the rock samples by dehydrating, collapsing and dissociating some minerals near the wellbore, as well as creating micro- and macro fractures in the formation. In addition, heat removes the blockage around the wellbore and the effect extends deeper into the tight formation for production.\u0000 Continues efforts over the past two decades have been proven that high power lasers provide controllable heat source while penetrating the formation, this mechanism enhances flow properties especially in tight formation. Low permeability in these formations restricts the flow and reduces production. Shale, Sandstones (including tight sandstones) and carbonate rocks have been treated with high power laser. Pre and post-treatment measurements are conducted for comparisons; the results from all rock types show improvement in permeability and flow. The results of advanced core characterizations, imaging and visualization are presented. The success of the lab experiments leads to the development of field deployment strategy to use high power laser for in-situ treatment in unconventional wells.\u0000 Utilizing state-of-the-art high power lasers technology in downhole provides innovative and safe stimulation methods. Reliability, accuracy, and precision in controlling the power, orientation and the shape of the beam are some of the properties of the technology that made it attractive for downhole applications. Different tools have been developed for different applications that can fit any slim holes.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"4 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80902950","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":"Is Steamflooding a Form of Low Salinity Waterflooding?","authors":"Hasan N. Al-Saedi, W. Al-Bazzaz, R. Flori","doi":"10.2118/194820-MS","DOIUrl":"https://doi.org/10.2118/194820-MS","url":null,"abstract":"\u0000 Previously, Al-Saedi and Flori et al. 2018d proposed a novel steam-low salinity EOR technique called low salinity-alternating-steam flooding (LSASF) into a reservoir core with a high reservoir temperature. Naturally, if a reservoir's temperature is very low, then oil is heavy. Using thermal EOR techniques in such a low-temperature reservoir resulted in considerable heat loss. In this study, we investigate the steam lifespan from the injector to the producer in order to check if the injected steam is still active throughout the flooding process or if it will condense because of the heat loss. The Bartlesville Sandstone Reservoir, as with other heavy oil reservoirs, is a low temperature (23°C) shallow reservoir containing heavy oil (600 cP). We believe that steam injected into various cores from the Bartlesville Sandstone Reservoir will condense due to the low reservoir temperature. The question is whether or not this condensed steam behave similarly to low salinity (LS) waterflooding.\u0000 First, the steam was injected into the oil-free core to determice when the steam condensed and what temperature it condensed at by using a multi-port model to check if the injected steam turned into water.\u0000 Several Bartlesville Sandstone Reservoir cores were initially flooded with formation water (FW), and then were flooded with different scenarios of steam and LS water. The temperatures of the inlet, the core, and the outlet were recorded. The effluent was collected from different ports out of the cores and different producer positions in order to follow up the steam position inside the core.\u0000 Core contact angle measurements were conducted throughout the flooded cores to determine the wettability alteration between steam and condensed steam (LS water) with the rock.\u0000 This study shows that when steam turned into LS water, the sandstone core wettability was altered towards being more water-wet. The condensed steam is considered to be hot LS water, which can reduce oil viscosity and alter the wettability at the same time.\u0000 These results were for short length cores. If these results are upscaled up to the oil reservoir scale, then the steam will still be turned into LS cold water (LSCW) as will be illustrated in the analytical model (We are still working on the analytical model). The LSCW will work as a wettability modifier only without reducing the oil viscosity. LSCW is not favorable for use in heavy oil reservoirs because the sweep efficiency is very low due to density differences unless the LS water chemistry is manipulated; however, contact angle measurements showed that the LSCW altered the sandstone wettability towards the neutral wet condition.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87466077","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":"The Synthesis and Application of a New Plugging Inhibitor PAS-5 in Water-Based Drilling Fluid","authors":"Liou Zhiyong, L. Qiang, Gang Yang, Zhang Fengyan, T. Ma","doi":"10.2118/194785-MS","DOIUrl":"https://doi.org/10.2118/194785-MS","url":null,"abstract":"\u0000 Wellbore instability caused by the dispersion of the clay is one of the most important challenges in drilling operation of fractured formations. The synthesis of new plugging inhibitors and the research of drilling fluid systems are key steps to keep the wellbore stabilization. In this paper, the limitations of conventional drilling fluid inhibitors are discussed and a new plugging inhibitor PAS-5 is synthesized by using amine inhibitor, polyethylene glycol and asbestos fiber as the main monomers. The detailed synthesis step of the plugging inhibitor PAS-5 is illustrated and its action mechanism is explained by scanning electron microscopy. In order to express the good effect of the PAS-5, a new evaluation system is used to indicate its plugging performance. At the same time, the plugging inhibitor PAS-5 was used on-site drilling operation in the Ordos Basin. The results of research show that the synthesis process of PAS-5 is simple and the effect of plugging inhibition is obvious. Compared with conventional treatment agents? PAS-5 outperforms sulfonated asphalt FT-1 and emulsified asphalt RHJ-3 in terms of plugging inhibition performance, with a plugging rate of 90.5% and roller recovery rate of 93.7%. It also has better temperature resistance, there is almost no change in viscosity and filtrate loss when the temperature rises from room temperature to 80°C. The field application results indicated that PAS-5 meets the requirements of drilling, that the reaming time of the trips of the wells is shortened considerably, that the ROP is improved, and that the hole enlargement rate is less than 6%. During the drilling process, PAS-5 can inhibit formation hydration and seal small cracks, thus maintaining the stability of the borehole. This study synthesized a novel plugging inhibitor PAS-5 and an evaluation system was adopted to reveal its plugging performance, and achieved good application effect in on-site drilling operations.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"47 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83548403","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":"Managing Challenges for Digital Transformation Initiative in a National Drilling Contractor - A Case Study from Algeria","authors":"A. Arnaout, Sara Bakhti, G. Thonhauser","doi":"10.2118/195060-MS","DOIUrl":"https://doi.org/10.2118/195060-MS","url":null,"abstract":"\u0000 Digital transformation is a process of applying all digital technologies and tools on current workflows to be able to deliver high quality information at the right time. The digital transformation of drilling will provide an unprecedented stream of high-quality information that has never been accomplished in the industry, through the utilization of automated real-time drilling downhole tools, data analytics and predictive analysis. Thus, it creates value, improves efficiency, further reduces costs and boosts performance significantly.\u0000 Despite the advantages of digital transformation, the oil and gas industry (especially drilling contractors) has been slow to seize the opportunity. There are many challenges that need to be overcome to realize its full potential for the drilling contractors. A coherent road map to build a successful digital transformation strategy will be addressed in this paper. (that is not only focused on assets, but also focused on how to create new revenue streams.)\u0000 A setup of a real-time digitalization tool based on automated rig activities detection technology is established in a national drilling contractor in Algeria and a measurement and monitoring process was started. Data aggregation is the first step towards implementing a digital transformation process.\u0000 However, the main task was standardizing and aggregating cross-vendor data streams. Breaking the data silos was required to move data smoothly from rig site to our digital records for a fast setup\u0000 Another issue is quality of data. Constant quality control checks of the received data ensured that the maximum value can be accomplished, which will consequently support in improving the awareness and decision process for the contractor based on this detailed information and following systematic procedures.\u0000 Also, company culture is extremely important to fostering the successful execution of a digital strategy. An approach of sharing relevant information between all members of the drilling crews on daily basis and using what is so-called \"Hawthorne Effect\", defines a continuous improvement process.\u0000 The digitalisation of drilling process has the ability to sustain a constant flow of information with the potential to transform operations and create additional profits from existing capacity. Clearing the bottlenecks in the data integration and analysis stages was vital for a successful digital transformation process.\u0000 This process enables real time reporting of drilling performance. This empowers the contractor to track the improvement and efficiency over time and find a performance gap to establish a feedback link to correct the deviations. The second benefit of applying such process is to by doing increase the utilization of the existing equipment and evaluating the best performance that crews can achieve with such equipment.\u0000 The eventual goal is establishing and improving the global process and workflow of monitoring the operating units for the multi-level operating","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"252 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91429873","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":"Unlocking Tight Carbonate Reservoir Potential: Geological Characterization to Execution","authors":"A. I. Latief, S. Syofyan, Tengku Mohd Fauzi Tengku Ab Hamid, M. A. A. Amoudi, Tariq Ali Al Shabibi","doi":"10.2118/194712-MS","DOIUrl":"https://doi.org/10.2118/194712-MS","url":null,"abstract":"\u0000 The reservoir in discussion is a tight carbonate reservoir with low productivity and relatively under-developed albeit the huge in-place volumes. The expectation is that a detail reservoir characterization will provide insight on factors affecting reservoir productivity, spatial distribution of productive portion of the reservoir and offering solution to overcome reservoir tightness.\u0000 The case study discusses on how a comprehensive multi-discipline review unravels and presents a robust reservoir heterogeneity framework. A geological review that includes both depositional and diagenetic process is performed to understand distinct components/factors responsible for reservoir heterogeneity. Simultaneously, petrophysical assessment was performed to quantitatively define rock grouping based on porosity-permeability, capillary pressure and pore throat distribution in the log and core domain.\u0000 The multi-discipline observations were then reconciled to establish relationship between the process origin and the resultant product of specific group/range of reservoir petrophysical properties. The multitude of pore throat characters and its petrophysical properties were linked to the underlying geological processes. The established heterogeneity framework provides clarity on spatial distribution of the reservoir sweet-spot, factors controlling low productivity and the required mitigation.\u0000 The study provides a complete journey of unlocking tight reservoir potential. It illustrates the geological studies influence toward innovative completion technology selection, design, and execution to overcome reservoir challenge. The study is supported by recent drilling and test results, hence offering insight for adoption and lesson learned.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"17 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86967364","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":"Turning an Offshore Analog Field into Digital Using Artificial Intelligence","authors":"R. Espinoza, J. Thatcher, M. Eldred","doi":"10.2118/195027-MS","DOIUrl":"https://doi.org/10.2118/195027-MS","url":null,"abstract":"\u0000 Replacing all analogue sensors in the oil field is very costly and normally only a fraction of them is done. Currently, there is no cost-effective method to efficiently, reliably and accurately capture analogue meter readings in a digital format. Operators are then left with only two options: either replace them with digital (high capex) or continue with manual gathering (high opex). This paper shows how computer vision and artificial intelligence was used for the first time to capture analogue field gauges data with dramatic reduction of cost and increase reliability.\u0000 This unique solution was implemented in the Cheleken Oil field, Caspian Sea, Turkmenistan. In the offshore platforms, only low-cost cameras were necessary, and gauges were identified using QR codes. During the field trial, operators were only required to take pictures of the gauges at a given interval of time and upload the photos to the application. After an innovative process of calibration, the acquired images were processed using artificial intelligence and deep learning computer vision.\u0000 Routine manually gathered data was compared with data collected using this solution with the following observations made: Date/time: Operators usually round time. The solution described records time on the captured pictures automatically.Value: Manually gathered data is subject to reading, typing and transcription errors. This solution has no error (provided a good calibration is done).Data Modification: Data gathered automatically with this solution has no human intervention. Therefore, is not subject to alteration, copying or duplication.Data collection with pictures was completed in 1/10th of the time that manual processes take.The business benefits from quicker operator rounds with improved accuracy in meter reading data, and time stamps. The administrative burden for operators of filling in extensive spreadsheets which are prone to error was reduced, this allowed them to collect more meter readings or be reassigned by management to more important scopes of work that bring greater value to the business. Once more it was proved that \"a picture is worth a thousand words \".\u0000 This solution offers an excellent opportunity for digitizing the marginal section of the field and provides a unique way to turn all analogue data into digital with a very low cost of implementation, on an infinitely scalable platform that is vendor agnostic and simple to manage.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"06 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86080409","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":"Safaniya Lagoon Corporate Stewardship Biodiversity Sanctuary","authors":"Moayad Jumaan, Ali Alsinan","doi":"10.2118/194806-MS","DOIUrl":"https://doi.org/10.2118/194806-MS","url":null,"abstract":"\u0000 Among the many goals of environmental management in Saudi Aramco, protection of special environmental areas is recognized as high priority to both the company and the Kingdom of Saudi Arabia. In line with this objective, Safaniya Onshore Producing Department (SONPD) designated Safaniya area sea water lagoon as Corporate Stewardship Biodiversity Area. The area is estimated to be 6 km2 peninsula, which is located in the north east of the Safaniya Producing Plant, where undisturbed native flora combines with a pristine shallow sea water lagoon, and provide a safe place for land wildlife (foxes, rodents, reptiles), marine wildlife (turtles, shrimps, fish, mollusks) and birds (flamingos, seagulls, etc.). Establishment of the Safaniya Lagoon started with surveying Safaniya and Tanajib Area, in collaboration with Saudi Aramco Environmental Protection Department (EPD) to select the most suitable region for biodiversity development. An establishment procedure was followed to secure the area with fences to limit the accessibility and prevent improper usage. A signboard was installed to identify the area as a sanctuary, forbidding entrance or any type of land use. Site development included mangrove plantation, already existing trash clean-up, and observation any type of waste dumped in the area, to ensure no contamination or danger to the habitat in the lagoon. The department successfully cooperated with Saudi Aramco EPD to plant more than 9,000 mangrove seedlings at the first two years of development. SONPD in collaboration with Society of Advocates and Volunteers for the Environment (S.A.V.E) invited employees with their respected family members to participate in a biodiversity beach clean-up campaign. The campaign helped collect more than 300 kg of waste, consisting of plastic bottles, old ropes, wood, and other waste materials. SONPD, along with its partners and programs, has now established the Safaniya Lagoon ecological and biological diversity sanctuary as a permanent refuge, with in-place protection and future mangrove planting events planned, the area is expected to expand in biodiversity with native flora and fauna, and expand a natural breeding and hatchery. During the winter season, migratory birds — such as flamingos and Amur Falcons, with flyways that pass over Safaniya Lagoon — are seeking warm weather and abundant food supplies. Creation of biodiversity is just the beginning of further area development. The next phase of sanctuary enhancement will be reutilization of tertiary treated wastewater for trees, which will form a wind barrier for mangroves.","PeriodicalId":10908,"journal":{"name":"Day 2 Tue, March 19, 2019","volume":"9 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88848973","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}