Day 1 Mon, February 12, 2024最新文献

{"title":"Fluorinated Polyzwitterion Coatings for Stabilizing Colloids and Lowing Retention of Nanoparticles","authors":"S. S. Zhu, H. Chen","doi":"10.2523/iptc-23933-ms","DOIUrl":"https://doi.org/10.2523/iptc-23933-ms","url":null,"abstract":"\u0000 Nanoparticles (NP) injected in hydrocarbon reservoirs, as inter-well tracers or an enhanced oil recovery (EOR) method, has been of great interest in petroleum engineering. However, NP's retention in reservoir conditions of high salinity and high temperature is one of the challenges in these applications because high retention is economically unfavorable. We explored the concept of applying lightly fluorinated polyzwitterions as a coating on hydrophobic styrenic nanoparticles that had previously shown significant adsorption on rock surfaces. This is a less explored area of research that correlates the properties of polymer and NPs retention to the structure variation of polymers and polymer coatings. The fact that a small fraction of a functional comonomer on a common polymer backbone can significantly change the polymer and NPs retention provides a low-cost option of modifying the retention property of common oil field materials.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"26 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528344","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":"Field Development Plan Defined by Technology: Pressure Transient Analysis and Spectral Decomposition Integrated with Production Made the Difference","authors":"Z. Ardhi, M. Glukstad, A. Rafliansyah, M. A. Abdali, P. Govinda, R. Mohanty, H. Shabibi","doi":"10.2523/iptc-23919-ms","DOIUrl":"https://doi.org/10.2523/iptc-23919-ms","url":null,"abstract":"\u0000 Field XX in North Oman has been the focus of many penetrations targeting deep formations such as the Haima and Amin reservoirs since 1994. The Upper Gharif interval was penetrated by many wells, but it was never considered a pay zone of interest and was left behind casing. Petroleum Development of Oman (PDO)'s Exploration team considered the Upper Gharif (HSGH-G3) sand as a miss pay and carried out a very successful drilling campaign focused on these sands. Six out of nine wells encountered sands making clear that additional work was needed to understand the sand geometries and the trapping mechanism. Several wells were fracked and tested delivering self-flow production of over 500 m3/day. Not all the wells showed the same response. This work focused on two techniques to help define the extend, channel geometry, connectivity, and reservoir behavior: Wide Angle Spectral Decomposition (WASD) and Pressure Transient Analysis (PTA). Detailed seismic mapping on a Wide Azimuth re-processed volume by PDO's processing team, allowed the use of WASD and the definition of sand geometries, orientation, and dimensions. These were calibrated using the existing well penetrations. PTA analysis of two key wells was performed and the model and results were tested against the geometries observed in the Spectral images. The PTA work clearly showed radial flow and the presence of barriers. It confirmed observations of the dynamic behavior (permeability, skin and storage) and was also used to test different models pertinent to the presence of potential micro-fracture networks or cross flow. The next phase of appraisal and development will continue using the WASD images for well placement and calibration and refinement will ensue in case of surprises.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"457 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528193","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":"Comparing Product Performance Through Time of Silicone Based Defoamer and Polyalcohol Based Defoamer in Aqueous Fluid","authors":"M. A. Bu Khawwah, S. Alrammah","doi":"10.2523/iptc-23738-ms","DOIUrl":"https://doi.org/10.2523/iptc-23738-ms","url":null,"abstract":"\u0000 Foaming in water based mud is considered a major issue that drilling operations might encounter that causes several issues such as decreasing in mud weight and makes the assessment of the fluid volumes very difficult, and complicated while fluid mixing process at the correct rate and at the required density. During operation, lower gel strength reduces the degree of foaming encountered, but will often compromise the cutting support and removal properties of the mud. The addition of the defoaming and/or antifoaming agents such as polyalcohol based, and silicone-based products is used to eliminate the foam. Alcohol based defoamer composition is hydrocarbon chain and oil carrier fluid, and silicone-based defoamer composition is silica-based material with the organic solvent then coating the material with polydimethylsiloxane (PDMS). Two generic water based mud formulations were mixed where foam was guaranteed then, two different types of defoamers were added separately to eliminate the foaming. Antifoam timing and amount were observed during the addition. The process included examining the defoamer performance with brine contaminated formulations.\u0000 In this study, comparison of results between polyalcohol based and silicone based defoamers in two types of salts provided an evaluation of the behavior of defoamer through comparing antifoam timing and amount were studied by conducting performance tests within laboratory conditions.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"53 6","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527606","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":"Early Warning Method to Detect Mud Motor Stallings Incidents in Drilling Operations Using Machine Learning","authors":"B. Zomarah, B. Alotaibi, M. Zahrani, A. Alsaihati","doi":"10.2523/iptc-24183-ms","DOIUrl":"https://doi.org/10.2523/iptc-24183-ms","url":null,"abstract":"\u0000 In recent years and with the increase of complex operations such as directional drilling, there has been an increase use of mud motors to drive performance and deliver more complex well design. The challenge is that motor failures increased due to the complexity of the operation which tends to have a significant impact on the well delivery and cost. Like any equipment failure, it is impacted by the conditions the tool has been through and it often provides prior warning signs that if missed will have significant non-productive time. One of the major motor failure signs is the motor uncontrolled stalling. The objective of this paper is to present an early warning method to detect and alert of mud motor stalling to the rig crew to react before it leads to other undesired conditions. Motor stall occurs when the mud motor stops working which will cause stalls with a high-pressure reading. Using daily drilling reports (DDRs) and real-time data surface parameters, subsurface data, a dataset of incidents was created by SMEs and it is fed into a machine learning model to detect early warning signs of stalling and provide the rig crew with detailed reports in real-time. After applying the proposed data-driven method, the stalling events can be accurately detected with +80% accuracy and a low false positive rate. To ensure proper mud motor monitoring; DDR, BHA, and relevant data such as motor specifications are considered. The result of such work is impacted by the data quality of real-time data such as uncalibrated channels, improper units, and significant noise in the data. This work extends the existing literature by using surface and subsurface data to accurately detect early warning signs of motor stalling. Our work presents a complete framework for how stalling events can be detected and reported in real-time.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"115 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527912","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":"Application of Remote Monitoring and Controlling Intelligent Separated Layer Water Injection Technology in BQ Oilfield, Dagang","authors":"Zu-chang Song, Yang Liu, Ji-jun Yang, Huaxing Zhou, Gang Feng, Liaoyuan Huo, Yingying Wang, Yong-tao Zhang, Xiaomei Cao, Baoyou Liu, Jie Zheng","doi":"10.2523/iptc-23977-ms","DOIUrl":"https://doi.org/10.2523/iptc-23977-ms","url":null,"abstract":"\u0000 The oil layers in Dagang Banqiao Oilfield are deeply buried, have many layers, and have large differences in water absorption between layers. The existing bridge-type concentric injection technology to control water distribution requires well test trucks and personnel to arrive at the well site to perform cable hoisting and instrument operations. Obtaining the injection parameters is short-term, and long-term monitoring cannot be achieved. During the operation, problems such as instrument obstruction and jamming often occur, resulting in a low operation success rate and difficulty in meeting the needs of the oil field for injection, control and water distribution. To solve the above problems, remote monitoring and remote control intelligent injection technology were proposed. This technology consists of a host computer client, a data center server, a monitoring remote control and a digital water distributor. The connection between the client and the data center server relies on the internal network of the oil field, and the remote wireless communication between the data center server and the monitoring remote control is carried out through VPDN. The monitoring remote control is installed on the injection wellhead water injection pipeline and consists of a pressure gauge, flow meter, chip, electronic control valve, communication module, etc. The digital water distributor integrates modules such as batteries, motors, chips, pressure sensors, and adjustable water nozzles, one for each water injection layer. Wave code wireless communication is used between the monitoring remote control and the digital water distributor. Wave code wireless communication uses injected water as the carrier. By changing the opening of the ground electronic control valve or the water nozzle of the digital water distributor in a short time, it establishes the water injection pressure fluctuation signal in the oil pipe. After coding and decoding processing, it realizes monitoring of remote control and digital water distribution. Two-way communication between controllers, that is, the monitoring remote controller sends control instructions to the digital water distributor, the monitoring remote controller receives instructions or the digital water distributor executes control instructions, and sends the collected dispensing parameter data to the monitoring remote controller.\u0000 Up to now, 36 wells have been applied on site, with a success rate of 100%, maximum well depth: 3827m, maximum oil layer temperature: 120°, and maximum validity period: 1482 days. This technology is not affected by well site environment, weather changes, time and other factors, and has significant advantages such as high measurement and adjustment efficiency, high measurement and adjustment success rate, and low management cost. The dispensing parameters can be monitored remotely from the PC client in the office for a long time, and the digital water distributor can be remotely controlled to inject wa","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"59 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528204","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":"Seeing Beyond the Obscure Fluid: How an Enhanced Production Logging Approach Helped to Improve the Workover Design","authors":"W. H. Mirza, M. T. Khan, R. Saud, I. B. Espinoza, U. Farooq","doi":"10.2523/iptc-23994-ms","DOIUrl":"https://doi.org/10.2523/iptc-23994-ms","url":null,"abstract":"\u0000 Typically, well workovers are performed based on production logging results. However, efforts to shut down water-producing layers may result in the opposite effect, such as increased water cut and decreased oil production. Hydrocarbon inflow behind the stagnant water at the bottom of the well that cannot be measured by typical production logging tool (PLT) sensors and may cause interpretation errors. As no alternative tools are available on the market, an enhanced evaluation approach is required to interpret the hydrocarbon inflow behind standing water column.\u0000 Characterizing producing intervals in heterogeneous reservoirs with various saturation levels and low pay is difficult with only open-hole (OH) logs. A standard PLT approach based on spinners and density readings may not identify the oil and gas entry across stagnant water in vertical wells. Therefore, an enhanced procedure for PLT was developed. The flow behind the static or moving water column was first identified using a combination of pressure derivative (dP/dZ), temperature (dT/dZ), and density data. The zones with high dP/dZ fluctuations were used for potential hydrocarbon inflow. Secondly, the weighted average of the density trend was used to break down the potential hydrocarbon entry behind the water. The dT/dZ variation was input into the HC exact production. The OH results used for PLT correlation improved the final interpretation.\u0000 Two cases with multiple historical PLT were evaluated for this study. In Case 1 (Well x02), PLT was carried out three times over a four-year period, and the water cut increased following production based on the standard interpretation. Different workovers were attempted to shut off water inflows, both successful workover that led to a 27% increase in oil production and a 68% decrease in water production was possible after the improved interpretation of three-phase flow from the enhanced PLT approach. In Case-2 (Well x06), the new technique confirmed a masking behavior of water to the wellbore fluid flow, and the interval above was selected to guarantee the evaluation from the lower part. The study shows that the new approach to interpretation successfully quantified zonal contributions, helping to enhance the workover strategy and mitigate the increase in water cut level of up to 30%.\u0000 The improved PL interpretation workflow demonstrates that traditional PLT interpretation cannot be directly applied to reservoirs with three-phase flow and the objective of reducing water cut. The enhanced technique has good potential for successful interpretation and helped to reduce water production.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"84 ","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140528197","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":"Changing The Status Quo: First Application of Utilizing Novel Tracer Technology for Monitoring Hydraulic Fracture Stage Contribution","authors":"W. Arshad, I. Brohi, S. Pooniwala","doi":"10.2523/iptc-23916-ms","DOIUrl":"https://doi.org/10.2523/iptc-23916-ms","url":null,"abstract":"\u0000 The ultimate goal of drilling and stimulating long horizontals wells is maximizing production with minimal economic investment to ensure a good return on investment. The costs associated with fracturing and stimulation are a significant portion of a well's completion cost. Considering that the number of stages and stage volumes have an almost linear relation with well completion costs, on a field scale optimizing the number of stages and fracturing treatments can have massive impact in budget optimizations.\u0000 Conventionally stage contribution in the field is estimated by running a PLT post fracturing. In long horizontals accessibility to TD could pose a challenge. Running a PLT also requires a wellbore cleared of isolation frac plugs or ball seats based on the completion type. In sub-hydrostatic pressured reservoirs, the debris created from the milling of plugs can be detrimental to the ultimate well performance. The results from PLTs’ provide a snapshot of well performance at a single point of time and not the dynamic response of the well over time.\u0000 In order to overcome the challenges of conventional PLTs’ for fracture stage contribution monitoring, various technologies were evaluated. It was decided to implement chemical tracers as an alternative monitoring technology due to the ease of deployment and some well monitoring benefits. The chemical tracer technology provides an intervention-less method to qualitatively measure stage by stage production which can be used to enable building a production profile for each stimulated stage. As the results can be observed with a quick turn-around time, production trends can be easily monitored over time by implementing a structured well surveillance plan.\u0000 Chemical tracers are applicable to Open Hole Multi-Stage Fracturing (OH-MSF) completions using ball operated frac sleeves and openhole packers and the \"Perf & Plug\" method of multi-stage fracturing in cemented completions. The examples presented in this paper include a 5-stage OH-MSF and 11-stage P&P stimulation scenarios.\u0000 Post-fracturing flowback in conjunction with chemical tracers provide interesting insights into the well clean-up operations and stage contributions from the heel to the toe of the well. Quite a few succinct conclusions can be made on the behavior of reservoirs and some unusual observations which highlight the persisting weaknesses in understanding complex reservoirs. The lessons learnt from some of the observations may help optimize the future hydraulic fracturing and post fracturing well clean-up strategy in the field.\u0000 This paper discusses the workflow of selecting the appropriate tracer technology, setting success criteria, and the field implementation of the technology.","PeriodicalId":519056,"journal":{"name":"Day 1 Mon, February 12, 2024","volume":"23 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-02-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140527632","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}