Day 2 Tue, June 12, 2018最新文献

{"title":"Offshore Safety: Collection and Recording of Relevant Drilling Data in the Italian Offshore by Means of Virtual Black Boxes","authors":"P. Macini, E. Mesini, Marco Ferrari, Graziano Pisconti, I. Antoncecchi, F Terlizzese","doi":"10.2118/190806-MS","DOIUrl":"https://doi.org/10.2118/190806-MS","url":null,"abstract":"\u0000 The paper illustrates systems and procedures recently adopted in Italy for the collection and recording of relevant drilling data, in the light of the requirements of Directive 2013/30/EU, elaborated and enforced following the 2010 Deepwater Horizon disaster. Thanks to the increased environmental consciousness of institutions, industry and people, worldwide environmental policies more and more require a rigorous protection of the environment.\u0000 The Directive 2013/30/EU on the safety of offshore oil and gas operations introduced strict requirements for the protection of both people and the environment, that are the targets which could be involved and seriously damaged by incidents occurring at offshore installations. Today, the Italian law requires Operators to set up an information and communication technology system that guarantees the integrity, availability and non-repudiation of drilling and drilling fluids parameters recorded in real time aboard drilling vessels and offshore platforms, while respecting the principles of confidentiality and responsibility of the data, under all conditions.\u0000 Oil companies operating in the Italian offshore implemented hardware and software systems that can be described as \"Virtual Black Boxes\". These are data management systems coupled to the Mud Logging Units of offshore drilling rigs, which allow the quasi-real time transmission of a subset of drilling parameters to a number of onshore data storage sites and their integral and safe recording on dedicated servers. The redundancy of information is ensured by managing multiple servers owned by the Operator and the mud logging Contractor. Normally, these servers are hosted at the Operators' headquarters and at Contractors' data storage centers. Data visualization is possible thanks to the use of special software, developed by Contractors and made available to Operators. Data acquisition, transmission and storage protocols are shared with the Italian competent Authority. These systems are already operative in the Italian offshore, even though studies are under way to enhance the intrinsic safety of the system and its possible implementation into a multi-criteria approach related to the overall safety performance of upstream operations.\u0000 The aim of this novel tool is to grant the competent Authority a reliable access to drilling data for the due analysis in case of accident, also in the light of taking the necessary legal actions. Virtual Black Boxes are designed, implemented and managed in order to ensure data safety and data security, also to prevent manipulation of the records, in compliance with the requirements of Directive 2013/30/EU and its Italian transposition.","PeriodicalId":339784,"journal":{"name":"Day 2 Tue, June 12, 2018","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123719925","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":"A Consistent Method to Build and Use a 3D Mechanical Earth Model","authors":"B. Cuesta, S. Vorobiev","doi":"10.2118/190799-MS","DOIUrl":"https://doi.org/10.2118/190799-MS","url":null,"abstract":"\u0000 The document presents a consistent method to build 3D Mechanical Earth Models (3D MEM). It is based on a rock physics study to derive field specific correlations between mechanical properties and interpreted petrophysical quantities. The 3D MEMs built using this methodology yield robustness and consistency when matching to the measured minimum stress. They also display good predictive capabilities making them valuable for operational design.\u0000 This method consists of conducting a preliminary rock physics study in order to obtain correlations between the mechanical properties (elastic moduli and strength), of the various formations that are considered, and basic interpreted quantities which are readily available in most 3D geological models (porosity or mineralogy). The correlations are used to build a 3D MEM which is consistent with both the 3D geological model and the 1D geomechanical interpretation. It is also possible to extend the correlations by linking raw log data to rock mechanical properties.\u0000 The model was tested against field case study to verify its predictiveness. Minimum stresses calculated by the 3D MEM matched well to the measured values obtained from mini-frac tests performed at various locations. Ultimately it permits to better forecast the material properties (in 3D) as well as the effective stress tensor (in 4D). The 3D MEMs were used to evaluate the risks for infill drilling, and for completion purposes. Performing this type of preliminary rock physics study has a number of benefits. Firstly, to help identify which logging suite should be run to characterize the geomechanical properties of a given formation, and secondly it can be used to derive correlations between raw log data and geomechanical properties. These correlations can be applied during operations for real time decision making purposes when there is not yet a petrophysical interpretation available.\u0000 The novelty of the method introduced lies in the systematic and coherent integration of data to build a consistent geomechanical model (3D or 1D), that exhibits a robust predictive capability and shows the value of 3D MEM for the design of drilling and completion operations.","PeriodicalId":339784,"journal":{"name":"Day 2 Tue, June 12, 2018","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134422373","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":"Effect of Small/Medium Scale Reservoir Heterogeneity on the Effectiveness of Water, Gas and Water Alternating Gas WAG Injection","authors":"Gary Hoare, C. Coll","doi":"10.2118/190855-MS","DOIUrl":"https://doi.org/10.2118/190855-MS","url":null,"abstract":"\u0000 Water-alternating-gas (WAG) injection is a technique employed in EOR (Enhanced Oil recovery). WAG injection can be immiscible or immiscible with water and gas being injected into the hydrocarbon liquids reservoir to promote greater recovery. WAG injection is effective as gas typically has greater microscopic sweep efficiency whilst water has better macroscopic sweep efficiency. It is important to be able to characterise and quantify how much the degree and type of small/medium scale heterogeneity during WAG flooding could affect the recovery factor from a reservoir, such that during project evaluation teams are able to properly evaluate the ranges on uncertainty on recovery factors and the economic benefit of the project as well as risks associated with WAG implementation.\u0000 The Hutton field is located in the North Viking Graben area of the North Sea and the lithology of the reservoir section is made up of Brent group sandstones which are highly heterogeneous in the horizontal and vertical directions at a small scale (i.e. pore scale and plug scale) and at a medium scale (the vertical layering of different formations).\u0000 The effect of reservoir heterogeneity on WAG efficiency has been evaluated using dynamic reservoir simulation models of the Hutton field. Input parameters were based on an available model of the Hutton Field. A fine grid geological model (grid size 5ft × 5ft × ~2ft) has been created of a small section of the Hutton reservoir. A variety of field development schemes were evaluated including depletion, water injection, gas injection and immiscible WAG production scenarios. Geological models were created for three scales of heterogeneity (small scale and medium scale heterogeneity models, and a homogeneous model) based on interpretation of log data from a set of three control wells. Compositional simulation models were used to model the dynamic behaviour. Two phase relative permeability (oil / water and gas / oil) data was used, as three phase relative permeability data for Hutton was not available. There is no hysteresis data available for the Hutton field, therefore separate test runs were carried out to evaluate how hysteresis might affect recovery factor during WAG injection using two and three phase relative permeability data and parameters for use in the Killough correlation for hysteresis.\u0000 Immiscible WAG injection is beneficial in reservoirs with small and medium scale heterogeneity and gives ~5% improvement in recovery factor when compared to water injection. However, when hysteresis is included, the recovery factor may be higher than this by another ~10%. WAG injection may provide inferior recovery factors to water injection in homogeneous reservoirs. However, simulations indicated that some limited gas injection into a homogeneous reservoir may prove beneficial for accessing attic oil. It is recommended that laboratory testing of core samples (core flood experiments) be carried out prior to a WAG injection specifically wit","PeriodicalId":339784,"journal":{"name":"Day 2 Tue, June 12, 2018","volume":"112 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124127648","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":"Integrated Dynamic Modelling of the Sea Lion Field","authors":"Aldo Lopez Marmolejo, R. Newbould, L. Lawton, J. Godlewski","doi":"10.2118/190805-MS","DOIUrl":"https://doi.org/10.2118/190805-MS","url":null,"abstract":"\u0000 The Sea Lion Field is an Early Cretaceous turbidite fan complex, located in the North Falkland Basin, 220 km north of the Falkland Islands. The reservoirs are dominated by amalgamated high density turbidites (Bouma Ta and liquefied sediment gravity flows), but also contain low density turbidites, linked debrites and interdigitated lacustrine mudstones. An integrated dynamic modelling workflow which incorporates the latest understanding of the Sea Lion Field sedimentology and reservoir heterogeneities is presented.\u0000 The workflow focuses on capturing and retaining reservoir heterogeneity throughout the reservoir modelling process. Coarse-scale heterogeneity is captured during the construction of the full-field geological (static) model and conserved in the dynamic model by using the same grid dimensions. Sedimentological features (fine-scale heterogeneity) below the grid resolution are captured in separate, 3D core-scale models. Through a process of kv/kh and relative permeability upscaling, the core-scale models are used to inform effective permeability in the full-field model.\u0000 Detailed interpretation of the available core data enables a statistical evaluation, which underpins the construction of core-scale models for the individual rock types. The resulting 3D core-scale models are representative of the reservoir and the development concept in terms of reservoir dip, lithology, petrophysical and fluid properties and well spacing. Matching the coarse model behaviour to the core-scale model forecast is an inverse problem with multiple possible solutions; therefore, assisted history matching is a valuable tool for quickly obtaining, comparing and ranking possible upscaled relative permeability functions and kv/kh ratios. The upscaled relative permeability functions output from the assisted history matching workflow correct for numerical dispersion and reproduce the waterflood behaviour observed in the core-scale model, thus capturing the influence of small-scale heterogeneities.\u0000 This integrated dynamic modelling workflow allows for the direct use of detailed geological models characterising the main heterogeneities impacting flow behaviour, while retaining the ability to investigate and capture small-scale heterogeneities below the resolution of the full-field static model, thus avoiding the cumbersome process of upscaling geological properties. Assisted history matching and optimization have been integrated into the workflow, providing a robust method to produce upscaled relative permeability functions that replicate the expected waterflood behaviour.","PeriodicalId":339784,"journal":{"name":"Day 2 Tue, June 12, 2018","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127614568","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":"Optimizing Laboratory cEOR Flooding Evaluations to Assess Initial Oil Saturation and Mobility Ratio","authors":"Hendrik Foedisch, H. Abdullah, R. Hincapie, L. Ganzer","doi":"10.2118/190769-MS","DOIUrl":"https://doi.org/10.2118/190769-MS","url":null,"abstract":"\u0000 We evaluate the polymer, surfactant and alkaline flooding performance in porous media by using an in-house innovative experimental setup. This, to reach an optimum experimental evaluation in an attempt to avoid repeated experimental failures reported in the literature. The workflow presented help us to understand the recorded data with high reliability and accuracy. Moreover, allow working at high temperatures and high salinities in order to mimic reservoir conditions.\u0000 The evaluation undertaken in this paper comprises four main steps: 1) Fluids preparation and optimization, beginning with an extensive rheological evaluation to define the optimum concentration/composition of the fluids. 2) Calibration of pressure sensors and pumps, and detailed determination of the system's dead volume. 3) Routine core analysis was performed, which included measuring porosity, permeability and pore volume. 4) Spontaneous imbibition experiments, secondary and tertiary mode cEOR flooding experiments. The core flooding experiments were performed at a constant flow rate of 0.15ml/min (equivalent to the field conditions of 1ft/day), then followed by a bump rate after Sor is reached.\u0000 The constructed setup proved to be beneficial on reducing the experimental failures by showing data reproducibility and precision. Small diameter tubings of 1/16″ minimized the dead volumes and core face differential pressure measurement allowed high accuracy at any injection rate. At elevated temperatures (50°C) polymer flooding in secondary mode showed 2% higher recovery compared to tertiary mode. Similar difference was observed at the ambient temperature. For the conditions evaluated in this work, HPAM polymer showed higher recoveries than those of Bio-polymer at higher temperatures. However, lower recoveries from HPAM were observed at lower temperatures. In terms of surfactant flooding experiments the observed performance is significantly better in secondary compared to tertiary mode, as well as facing significant production of emulsion from suboptimal surfactant solutions. Thoroughly examining these differences in recoveries, two key factors were considered to be of critical interest: initial oil saturation and mobility ratio. Moreover, CT scan imaging allowed assessing capillary end effects during oil saturation. A detailed comparison between dry and saturated core images was performed to insure no capillary end effects existed. Finally, a developed mathematical simulation model permitted to quality check the work and create a benchmark for further evaluations.\u0000 The workflow presented in this paper helps to close the gaps often discussed in the literature with regards to flooding experimental failures at core plug scale. Thus, it can help fellow researchers to optimize their workflow and enhance the final results to aid in fluid evaluation and assessing the optimum cEOR process.","PeriodicalId":339784,"journal":{"name":"Day 2 Tue, June 12, 2018","volume":"65 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126082808","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}