Day 3 Wed, September 26, 2018最新文献

{"title":"A Tool to Manage Water Production in a Naturally Fractured Reservoir Using Flowing Pressure Data and Water Level Measurement","authors":"L. F. Rodríguez, Jennifer Arteaga","doi":"10.2118/191612-MS","DOIUrl":"https://doi.org/10.2118/191612-MS","url":null,"abstract":"\u0000 A key reservoir management guideline for a water driven, naturally fractured reservoirs is to minimize water production. Water breakthrough is undesirable as it drastically reduces oil production rate because of unfavorable mobility ratio and lower oil recovery due to poor sweep efficiency. This paper details a new analytical tool developed in DNO to (i) monitor water flooding, (ii) predict water breakthrough and (iii) mitigate post-breakthrough flooding, aiming to maximize dry oil production and to prevent fast escalation of water cut. The tool is based entirely on field measured parameters such as fluid properties, bottom hole pressures (DHG) and gradiometric surveys.\u0000 A proper reservoir management workflow includes a systematic and continual monitoring of water level depths in all, or some key wells, completed in the reservoir. To achieve such a goal, analytical well-specific models were developed. Full field models have serious limitations to handle the well scale, and coning critical rate correlations available in the literature are very simplistic. Well models are, on the other hand, well-specific, based exclusively on (i) bottom hole flowing pressure data, being collected on a quasi-real-time basis with pressure downhole gauges, and (ii) periodic water level depths measured in observation wells with gradiometric surveys, and (iii) fluid properties. First principles are applied to articulate the data and no assumption is made related to neither flow path geometry nor permeabilities. Well model, known as Water Towers model, are used primarily to track water level depths in each well and to predict and manage water breakthrough time. They have proved to be effective in fracture networks that are controlled by gravity.\u0000 The Water Towers consists of a set of simple equations that relate the variables listed above with the vertical velocity of water. They make use of measured water level depths to calibrate the dimensions of the well vertical column and to adjust the calculations for the convoluted effect of tortuosity of the flow path followed by water, local pressure decline, inflow from tributary fractures, and well interference. In addition to their primary use, they are effective to decide on the optimal rate of the wells and to investigate the existence of alternative water sources (different from the underlying aquifer). The Water Towers model is part of the toolbox developed by DNO to manage some of the assets it operates. It has been successful in forecasting water breakthrough in vertical and horizontal wells, in estimating the advance depth of water level in wellbores and in providing guidelines concerning the optimum rate of wells.\u0000 The reliability relies on the fact that their input is exclusively measured data. The more extensive the data set is, the more reliable the results are. These models are a relevant and reliable tool in proactive managing of naturally fractured reservoirs driven by an underlying aquifer and are of intere","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"82 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115748729","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":"Case Study: Apache's Approach to Societal Responsibility thru the Environmental Media Monitoring Program for the Alpine High Play","authors":"Navneet Behl, B. Bohm, M. Bruton, S. Fleming, S. Vance","doi":"10.2118/191589-MS","DOIUrl":"https://doi.org/10.2118/191589-MS","url":null,"abstract":"\u0000 A baseline environmental media monitoring program is presented. Analytical data sets collected by third party contractors at the request of Apache Corporation are presented. The analytical data presented documents the environmental condition of groundwater, surface water, soil, and ambient air, within an area with sensitive environments supporting multiple endangered and threaten species, recently being developed as oil and natural gas exploration and early development. The area of the study is a previously undeveloped portion of the prolific oil and gas development area of the Permian Basin. The baseline environmental media monitoring program occurred over an area of approximately 78 square miles in southern Reeves County, Texas. The analytical data provides interested stakeholders a starting data set for comparison to future environmental conditions, allowing parties to assess if there are changes in the environmental media and if those changes vary from natural seasonal variations.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"249 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134344067","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":"Cloud-Based Solution for Advanced Real-Time Fracturing Evaluation","authors":"Sergey Parkhonyuk, Max Nikolaev, Andrey O. Fedorov, A. Konchenko, T. Vik","doi":"10.2118/191680-MS","DOIUrl":"https://doi.org/10.2118/191680-MS","url":null,"abstract":"\u0000 The ability to make real-time adjustments to hydraulic fracturing treatment design and pumping schedules leads to more-effective proppant placement and ensures every cluster delivers its full potential. There are numerous advanced methods to monitor and interpret the fracturing downhole events: microseismic analysis, distributed measurements with fiber optics, and high-frequency pressure monitoring. Advances in digital technologies allowed creating a cloud-based application combining downhole and surface data to enable real-time fracturing design adjustments from anywhere.\u0000 The application uses a public cloud solutions stack to synchronize surface and downhole measurements and visualize them on the Web. All computations are performed on virtual machines that create the visualization of downhole events in milliseconds. Interpretation of distributed temperature survey (DTS) and heterodyne distributed vibration sensing (hDVS) data has enabled reliable monitoring of diversion techniques, leak detection, and improvements in well integrity and provides support for any type of well intervention. The innovation in the use of the cloud-based application comes from the combination of a novel technique for processing and visualization of high-frequency pressure monitoring (HFPM). HFPM monitoring provides a cost-effective solution for completion efficiency.\u0000 The application is currently used for a novel wireline service that utilizes a fiber-optic cable for downhole temperature and acoustics measurements. Results have shown consistency and reliability in the interpretation of received data and confirmation of wellbore events, particularly in DTS and hDVS measurements. Field tests with HFPM have demonstrated that all processing and computations can be reasonably automated in a cloud to provide access to fracturing monitoring at anytime, from anywhere, and from any device. That provides excellent flexibility and means for further reducing the cost of well completions and maintenance, boosting the efficiency, and lowering cost per barrel. A technology stack of a secure public cloud makes an application cost effective and seamlessly scalable on demand. At the same time, the progress of the application does not stop with current possibilities. The innovation of cloud services, such as out-of-the-box machine learning libraries, is now available to for building applications on top of acquired data.\u0000 Cloud-based architecture is showing that any digital measurements can be effectively integrated, processed, and visualized in real time for decision making while the job is running. It creates a new service level for real-time fracturing monitoring that differentiates it from previous solutions.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114407289","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 Role of Chemicals Loss in Sandstone Formation in ASP Flooding Enhanced Oil Recovery","authors":"H. Zhong, Tingbao Yang, H. Yin, Chun-quan Fu, Jun Lu","doi":"10.2118/191545-MS","DOIUrl":"https://doi.org/10.2118/191545-MS","url":null,"abstract":"\u0000 Chemical combination flooding technique especially alkali/surfactant/polymer (ASP) flooding has proven to be an indispensable way to enhance oil recovery (EOR). The progress of this flooding technique in Daqing Oilfield (China) shows that it is promising to keep production from falling and help oil companies make profit in a low-oil-price era. However, the ASP chemicals chromatographic separation and loss in sandstone formation are still the weaknesses in the promotion of ASP flooding.\u0000 Laboratory investigations for characterizing the behavior and distinction of chemicals loss in sandstone reservoir with strong base (NaOH) and weak base (Na2CO3) ASP flooding were recently carried out. The experiments were designed to pointedly study the chromatographic separation, and consumption loss behaviors of alkali and surfactant in sandstone reservoirs with ASP flooding. Furthermore, the incremental oil recovery factor in heterogeneous sandstone reservoirs with strong base (NaOH) and weak base (Na2CO3) ASP flooding process was evaluated and compared. The loss rates of chemicals and the permeability damage degree in various experiments were determined respectively, the consumption loss mechanism and influencing factors were discussed, and the formulation composition and slug combination patterns were also optimized. Then, the role of ASP chemicals loss in sandstone formation during ASP combination flooding EOR process was worked out.\u0000 The results indicated that the chemicals loss behaviors could be weakened and the chemicals chromatographic separation phenomenon could be alleviated in weak base (Na2CO3) ASP flooding, and the average loss rate of alkali and surfactant could drop 9.61% and 15.67% respectively in heterogeneous sandstone reservoirs comparing to strong base (NaOH) ASP flooding. The profitable EOR effect could also be obtained with weak base (Na2CO3) ASP flooding, and the enhanced oil recovery could still reach 20% or more. Moreover, an approximately 15% reduction in permeability damage rate could be realized in the weak base (Na2CO3) ASP flooding instead of strong base (NaOH) system, and the reservoir flow assurance issues related to chemicals loss behaviors could be addressed. The optimal design of ASP formulation and slug combination pattern could technically and economically achieve high oil recovery in sandstone reservoirs with weak base (Na2CO3) ASP flooding.\u0000 The results are beneficial to well understand the chemical combination flooding mechanism and can contribute to the existing knowledge in the chemicals super additive effects during EOR process, and it is also significant to further improve the oil displacement efficiency and reduce the injection cost in heterogeneous sandstone reservoirs with weak base (Na2CO3) ASP flooding process.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116437434","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":"Osmosis and Clay Swelling Effects in Gas Shale Formations under Stress","authors":"Vena F. Eveline, I. Akkutlu","doi":"10.2118/191599-MS","DOIUrl":"https://doi.org/10.2118/191599-MS","url":null,"abstract":"\u0000 Water-shale interactions are traditionally perceived as complex phenomena due to reactive nature of shale with water. However, the current trends in shale gas industry requires an advanced-level of understanding of these interactions and their impact on gas production. In this paper we investigate the invasion of fracturing water into the formation and the subsequent water-shale interactions. Objective of this work is to study osmosis and clay swelling effects of the invasion on the formation permeability.\u0000 For this purpose, a new geomechanically-coupled reservoir flow simulator is developed, which accounts for water imbibition, osmosis and clay swelling effects on the formation permeability under stress. The simulation model considers the formation has a multi-scale pores consisting of microcracks, clay pores and organic pores. Water imbibition occurs in the water-wet inorganic part of the matrix in the microcracks. Osmosis and clay swelling effects develop in the clay pores acting as semi-permeable membrane to the imbibed water and changing the local stress in the formation. The simulation model includes aqueous and gaseous phases with three components: water, gas and salt.\u0000 The simulation results show that the formation permeability is dynamically affected during the shut-in period by a combination of mechanisms including imbibition, capillarity, diffusion/osmosis, and total stress. Notably, a permeability impairment zone, rather a fracture skin, develops near the fracture. The permeability alteration is due to osmosis-related clay swelling and changing stresses in the formation. The magnitude of the permeability alteration is controlled mainly by the salt concentration difference between the fracturing fluid and the clay-bound water, the clay-membrane efficiency, the clay cation exchange capacity (CEC), the clay porosity, the stress and the duration of the shut-in time. We develop a fracture skin factor that can be used with the single-phase (gas) shale reservoir flow simulators that are typically run in the absence of water invasion at the scale of the stimulated reservoir volume (SRV) and in multidimensional geometries.\u0000 Currently there is a clear need in the unconventional industry to better-understand and control the hydraulic fracturing fluid-shale interactions. This work is an important milestone considering the complexity of the problem and suggesting that the water chemistry and the formation lithology plays a significant role after the fracturing operations.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"97 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127170396","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 Method for Calculating More Accurate Stratigraphic Positioning of Horizontal Wells Using Continuous Inclination and Azimuthal Gamma Ray Images Even While Sliding","authors":"Susana Gutierrez Carrilero, Anne Holmes, David Hinz, Jiaxin Wang, Jeff Crawford, E. Stockhausen, Haijing Wang","doi":"10.2118/191740-MS","DOIUrl":"https://doi.org/10.2118/191740-MS","url":null,"abstract":"\u0000 Geosteering long lateral wells in narrow target windows demands accurate stratigraphic positioning, true vertical depth (TVD) positioning, and apparent dip determinations. Using positive displacement motors with alternating slide and rotate drilling modes to control the well trajectory, along with standard 90-ft surveys and single-detector azimuthal gamma ray (GR) tools, have proven to be inadequate. To overcome these issues, a new method has been developed that combines continuous measurements and uses a four-detector azimuthal GR tool.\u0000 The bottomhole assembly (BHA) used here is equipped with two inclinometer packages and a four-detector azimuthal GR logging-while-drilling (LWD) tool. A high-resolution survey is calculated using a combination of the two continuous inclination survey data sets for the deeper portion of the well and the stationary survey data from the shallow (low inclination) portion of the well, which provides a more accurate well path that better reflects the TVD positioning of the wellbore. The four-detector azimuthal GR tool is used to generate high-quality wellbore images, both while sliding and rotating. This enables more accurate structural dip angles to be determined from the continuous GR images. It also leads to better stratigraphic and structural positioning of the wellbore and a better understanding of changes in stratigraphy across the length the lateral section. Combining more accurate surveys with complete GR images and more accurate dip picking enables a better determination of the stratigraphic position of the wellbore and its path through stratigraphic layers. The wellbore can be divided into various up- and down-drilled sections that can be compared side-by-side using true vertical thickness (TVT) methods to show lateral continuity of the beds.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131058930","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":"Improved Reservoir History Matching and Production Optimization with Tracer Data","authors":"Hsieh Chen, M. Poitzsch","doi":"10.2118/191523-MS","DOIUrl":"https://doi.org/10.2118/191523-MS","url":null,"abstract":"\u0000 Interwell tracers have been shown to provide invaluable information about reservoir dynamics, well connectivity, and fluid flow allocations. However, tracer tests are often applied sporadically because their immediate returns of investments are not readily apparent to a resource-holder. Here, we rigorously demonstrate that tracer data can indeed improve reservoir history matching, and, more importantly, improve future production, using reservoir simulations on benchmark problems. Sensitivity studies and the limitations of tracer data are also provided.\u0000 The numerical experiments were divided in two sections. First, production data with or without tracer data from reference fields were collected for the first water flooding periods for history matching. Second, the history matched models from the first section were used for production optimization for the next water flooding periods. The ensemble smoother with multiple data assimilation (ES-MDA) was used for the history matching processes for the first part of the numerical experiments, and the modified robust ensemble-based optimization (EnOpt) was adopted to maximize the net present value (NPV) for the second part of the numerical experiments.\u0000 The three-dimensional channelized \"Egg Model\" was chosen as the initial benchmark problem. From the first part of the numerical experiments, using the same hyper-parameters, it was observed that history matching including tracer data resulted in a better match of the field production rates with smaller standard deviations. In addition, history matching including tracer data resulted in more distinct geological features when observing the history matched permeability maps. From the second part of the numerical experiments, we observed that the geological models history matched including tracer data resulted in better production optimization with higher NPV produced. In the specific case of the Egg Model, +4.3% increase of the NPV was observed.\u0000 To understand the sensitivity and the limitations of the tracer data, the same numerical experiments were performed on a library of reservoir models with different fracture patterns. After the history matching and production optimization simulations, we observed that including tracer data gave positive NPV increases ranging from +0.3% to +9.4% from 5 of the 7 test cases. It was observed that tracers were more effective for the non-homogeneously flooded reservoirs.\u0000 To the best of our knowledge, this paper is the first study that quantifies the benefits of tracers in the context of the improved production, measured in NPV. In a broader perspective, we believe this is the best way to test any new history matching algorithms or reservoir surveillance methods. In this work, we show that tracers can result in positive NPV in most situations, and oil producers using large-scale water flooding operations would benefit from performing more tracer tests in their operations.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126702735","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 Kick Detection Using Adaptive Analytics with Downhole Accelerometer Data","authors":"Robello Samuel","doi":"10.2118/191645-MS","DOIUrl":"https://doi.org/10.2118/191645-MS","url":null,"abstract":"\u0000 High frequency downhole vibration data includes more hidden information than low frequency surface data. This paper discusses monitoring high frequency acceleration data for early kick detection because the accelerator sensor values’ trend is monitored rather than processed.\u0000 When gas, fluid, or oil kick occurs, fluid influx reduces fluid viscosity in the annulus, causing degradation of the damping factor. The sensor installed on the drillpipe detects the velocity/acceleration modification, resulting in the damping factor modification and includes an analytical model to calculate the effect of the damping ratio on the acceleration calculations. Fluid influx and migration in the wellbore strongly affects the damping factor.\u0000 This paper discusses a method of deconvoluting sensor values that use a combination of minimum entropy deconvolution and the Teager-Kaiser energy operator to remove the noise, unwanted sensor values, and the likelihood of false predictions. The trend of the final intrinsic mode functions (IMFs) at each depth is continuously monitored to predict formation influx, if any. A novel concept of monitoring incremental IMF and IMF energy at each depth is introduced, revealing a wealth of information and simplifying the process of monitoring and analyzing the vast amount of available data. The methodology developed extracts essential information from high frequency vibration data to make real-time data monitoring straightforward, reliable, and fast.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"58 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126049283","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":"Mechanistic Modeling of Foam Flow Through Porous Media in the Presence of Oil: Review of Foam-Oil Interactions and an Improved Bubble Population-Balance Model","authors":"Kun Ma, K. Mateen, G. Ren, Haishan Luo, G. Bourdarot, D. Morel","doi":"10.2118/191564-MS","DOIUrl":"https://doi.org/10.2118/191564-MS","url":null,"abstract":"\u0000 Modeling foam flow through porous media in the presence of oil is essential for various foam-assisted enhanced oil recovery (EOR) processes. We performed an in-depth literature review of foam-oil interactions and related foam modeling techniques, and demonstrated the feasibility of an improved bubble population-balance model in this paper.\u0000 We reviewed both theoretical and experimental aspects of foam-oil interactions and identified the key parameters that control the stability of foam lamellae with oil in porous media. Upon reviewing existing modeling methods for foam flow in the presence of oil, we proposed a unified population-balance model that can simulate foam flow both with and without oil in standard finite-difference reservoir simulators. Steady-state foam apparent viscosity as a function of foam quality was used to evaluate the model performance and sensitivity at various oil saturations and fluid velocities.\u0000 Our literature review suggests that, among various potential foam-oil interaction mechanisms, the pseudo-emulsion-film (gas/aqueous/oil asymmetric film) stability has a major impact on the foam-film stability when oil is present. Based on the pseudo-emulsion-film mechanism, we therefore developed a new foam-coalescence function in the population-balance model using the gas-water capillary pressure (Pcgw) in oil-free cases and the pseudo-emulsion capillary pressure (Pcpf) when oil was present. The respective critical values Pcgw * and Pcpf * can be estimated through disjoining pressure measurements. A smooth transition, from no foam destabilization at zero or substantially low oil saturations to no foam beyond a critical oil saturation, was considered for this purpose. The new model was able to handle the extent of the detrimental effect of oil on foam with one adjustable parameter k-2.\u0000 This work consolidated various findings of foam-oil interactions based on pseudo-emulsion films in the past through a comprehensive literature survey. We have developed a unified model to simulate foam flow in porous media with and without oil using the mechanistic population-balance approach for the first time. This model can therefore be used in foam EOR simulations both in the oil-bearing zones as well as zones with no oil or residual oil present.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116773912","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":"Improved Collaboration and Transparency of Oil & Gas Capital Projects Using a Digital Project Delivery System","authors":"J. Stroh, Harit Naik, Edmund Memi","doi":"10.2118/191550-ms","DOIUrl":"https://doi.org/10.2118/191550-ms","url":null,"abstract":"\u0000 The adoption of a digital project delivery methods utilized by the manufacturing industry can be applied to oil and gas capital projects. Benefits include: greater collaboration and transparency between an EPC and owner-operator, the use of near real-time data to facilitate and drive better project decision-making, and the ability to save resources through increased efficiencies. To better understand poor performance on capital projects, different methods must be looked at. A case study using implementation of a digital project delivery approach through Project Lifecycle Management (PLM) is compared to a legacy project delivery using disconnected tools. This new approach to project delivery shows how adapting PLM software brings together engineering data with planning information, digital action workflows, collaborative review sessions, and visualization of status using a 3D model into a new way of delivering oil and gas capital projects more efficiently. The project schedule is merged with the master deliverables register and data coding to create live project dashboards and end-to-end schedule visibility. Going beyond the technological aspects, the behavioral and organizational challenges of project execution are examined, highlighting the limitations of legacy approaches and the project benefits gains using the digital project delivery approach.\u0000 By leveraging the interconnectedness of data, the real-time insights that can be derived, and with the right project team support model, all of these factors come together to show how application of digital project delivery systems enables better project management visibility and capital project performance.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125115607","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}