Day 3 Wed, September 26, 2018最新文献

{"title":"How Different Density-Neutron LWD Tools Response can Affect the Formation Evaluation Approach","authors":"Federica Di Maggio, G. Duci, F. Pampuri","doi":"10.2118/191681-MS","DOIUrl":"https://doi.org/10.2118/191681-MS","url":null,"abstract":"\u0000 Log While Drilling (LWD) Density-Neutron allow to calculate, in real/near real time, a continuous porosity and shale volume curves. Sometimes log acquisitions from different tool types are available. In these cases, attention should be paid to the reading characteristics of the individual tools, to calibrate the petrophysical interpretation in a consistent way.\u0000 Generally, the LWD interpretation can be considered more critical than Wire Line Log WLL because the operation timing strongly limits an accurate QC of the data.\u0000 Different Nuclear tools involve different measurement system for density and different energy source as well as different neutron energy range for neutron. During the field development phase, the petrophysiscal analysis can deal with various type of Density and Neutron log, even in distinct phases of the same well, making the lithology recognition, the shale volume and the effective porosity evaluation more difficult and even misleading during the formation evaluation step.\u0000 The aim of this paper is to show through different case histories, how the various tool types can affect the formation evaluation model and a possible approach to mitigate the problem. The case study includes logs from different WLL and LWD tools, different well diameters, deviations and lithologies.\u0000 After a careful QC, the data sets have been processed in order to identify homogeneous intervals (from the lithology and the porosity point of view) in order to make the response comparison based only on the characteristic of the different tool types.\u0000 Once the conditions for a correct comparison have been fixed, the statistical distribution within the homogeneous intervals was quantitatively described using histograms and cross-plots.\u0000 The results of the analysis have proven the influence of lithology: silty-shale sequences show the most significant discrepancy between the tool responses, while the clean lithologies show less or negligible discrepancy.\u0000 If not properly considered, the different Density-Neutron (DN) tool responses inside a homogeneous interval can strongly affect the output of the petrophysical interpretation, mostly on shale volume and effective porosity with a dangerous fallout also in the reservoir modelling. In the presented case study, the observed discrepancy from different LWD Density tool can vary between 0-0.02 gr/cc while for Neutron tools between 0-5 p.u.\u0000 To quantify the impact of the mentioned discrepancies on the petrophysical interpretation, a deterministic interpretation model (calibrated against cores data) was used for shale volume and effective porosity calculation.\u0000 The comparison between DN shale volume derived from different tools and Gamma Ray (GR) has been defined as simple but strategic approach to understand the meaning of the DN response and therefore to define the proper shale point in the DN cross-plot for the petrophysical interpretation.\u0000 If DN logs are acquired with various tool types properly calibrated, the d","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"217 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":"124289685","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":"LEAN Mobile Production Facility to Unlock Marginal Oil Resources","authors":"Tanthai Poopaiboon, Phruettiphan Supalasate, Jiranoot Suebsook, S. Sakulkaew, Pawin Surattanasunya, A. Eksaengsri, P. Charoensawadpong","doi":"10.2118/191650-MS","DOIUrl":"https://doi.org/10.2118/191650-MS","url":null,"abstract":"\u0000 This paper propose a LEAN design and LEAN approach for project development of Mobile Production Facility (MPF). The Mobile Production Facility (MPF) is the well known facility developed in onshore oil and gas field for mature field which the field development plan has extended to remote areas which contain small marginal oil prospects. The LEAN design for Mobile Production Facility could improve the economics of onshore oil and gas projects development by reducing capital expenditure (CAPEX) and project development lead times and increasing flexibility for production planning through the mobilization design, and be a key factor in the economic exploitation of both marginal and mature fields. Insight gained through in-house design, international code & standard, and package design experts led to the development of the LEAN Mobile Production Facility proposed in this paper. Discussion include a characteristic of a reference oilfield, project background, application of Mobile Production Facility, the innovative design of package and equipment leading to lower CAPEX in detail, as well as the benefits and limitations of the LEAN Mobile Production Facility. Areas of future project development in support of LEAN Mobile Production Facility are identified, including the potential to unlock the further marginal reserves.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"37 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":"122320662","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":"Estimating Clean Reservoir Fluid Bubblepoint and Other Properties in Real Time Using PCA Asymptote of Optical Sensor Data and Equation of State","authors":"P. Olapade, Bin Dai, C. M. Jones, Mehdi Alipour Kallehbasti","doi":"10.2118/191435-MS","DOIUrl":"https://doi.org/10.2118/191435-MS","url":null,"abstract":"\u0000 Mud filtrate invasion occurs in the immediate vicinity of the well as a result of the overbalance pressure of the mud column in the well. Oil-based muds (OBM), unlike water-based muds (WBM), are miscible with reservoir fluid, and OBM contamination alters the properties of the original formation fluid. The bubblepoint of contaminated fluid is usually lower than clean fluid. While fluid is pumped out of the formation, it becomes cleaner and the bubblepoint increases; the upper limit of the increase is the clean formation fluid. While increasing the pumping rate can shorten cleanup time, pumping below the bubblepoint can modify the fluid phase behavior and cause asphaltene content in the formation fluid to precipitate out and sensor data to become erratic and noisy. Therefore, it is important not to pump below the bubblepoint, knowing the clean fluid bubblepoint in real time provides a guideline for the field engineer. The purpose of fluid sampling is to collect a representative formation fluid—samples with an acceptably low contamination. The clean fluid bubblepoint provides a lower limit on pumping pressure, which helps ensure pumping does not go below the bubblepoint and the sample is in single phase.\u0000 This paper describes how clean fluid compositions are determined from the asymptote of the principal component analysis (PCA) reconstructed scores and then used as input for the equation of state (EOS) program to compute fluid properties such as bubblepoint and gas/oil ratio (GOR). The optical spectral data from the optical fluid analyzer is first despiked, and outliers from the despiked data are removed using the robust ordinary least squares regression (ROLSR) method and robust PCA (RPCA). After removing outliers, clean fluid spectra data are reconstructed using asymptotic PCA scores and PCA loadings. Using a neural network model, clean fluid compositions are determined from reconstructed fluid spectral data, and fluid compositions are used as input for the EOS program to determine fluid properties.\u0000 Results confirm that the clean fluid bubblepoint and GOR do not change significantly after a few tens of liters of fluid pumpout. Analysis of the first principal component (PC1) confirms that most of the variations occur during the first few tens of liters of pumpout, indicating the predicted clean fluid compositions and properties are somewhat stable. This approach can help determine the clean fluid properties, even while pumping before taking the sample, helping ensure a monophasic fluid sample. When pumpout accumulated volume reaches 40 to 50 L—within 15 to 20 min of pumping out contaminated fluid—clean fluid compositions and properties can be estimated and used to determine reservoir continuity. Additionally, knowing the clean reservoir GOR and API gravity can help determine the type of reservoir fluid in real time.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"54 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":"122002853","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":"Formation Evaluation, Economic and Environmental Assessment for the Slurry Injection for Biosolids Management in the City of Houston","authors":"Yashesh Panchal, I. Mohamad, O. Abou-Sayed, A. Abou-Sayed, M. Bruno","doi":"10.2118/191651-ms","DOIUrl":"https://doi.org/10.2118/191651-ms","url":null,"abstract":"\u0000 A strong economy, industrial base, and low cost of living have led to a significant rise in population in the Greater Houston Metropolitan area of Texas, and with it, an increase in production of sewage and biosolids wastes. In the Houston area, sewage is treated with a combination of anaerobic digestion and lime stabilization to create biosolids which are then pelletized into fertilizer, composted, landfilled, or land applied.\u0000 The Slurry Injection technique is an alternative treatment and disposal method, that can replace much of the capital costs associated with maintaining and expanding the wastewater treatment infrastructure in Houston at significantly lower capital cost. This technique utilizes the principles of Drill Cutting Injection which has been implemented in petroleum industry since mid 1980s for oil and gas waste management. A biosolids slurry injection facility of sufficient capacity to dispose of all the biosolids currently produced by the city of Houston could be installed for less than 1/10 of the nearly $526 million in capital currently budgeted by the city to expand the current system under the current rolling 5-year plan. A substantial reduction in greenhouse gases is achieved as well, by using the slurry injection technology as the Carbon Dioxide and Methane (which are prominenet greenhouse gases) produced by biosolids degradation is completely sequestered under deep geological formation and along with it the emissions produced during dewatering and transportation of biosolids is also eliminated.\u0000 The City of Los Angeles’ Terminal Island Waste Water Treatment Plant facility has deployed the slurry injection technology since 2010. It currently disposes of approximately 20% of biosolids of the city of Los Angeles.\u0000 This paper describes the economic and environmental aspects related to biosolids management and the formation evaluation carried out to inject the bioslurry in greater Houston. The study includes both the economics of the surface construction requirements as well as the science behind the subsurface strata evaluation for containment assurance. For the subsurface aspects, a geomechanical and stress analysis is performed on two different formations (the Frio and the Vicksburg). A significant confining layer is present above and below our targeted injection zones, which restrict and assure the injected waste remains contained. Also, hydraulic fracture simulation and analysis provides an assurance and the waste containment within the engineered subsurface strata/formation for permanent storage.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"154 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":"122045065","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":"Back to Basics: Revisiting Proppant and Fluid Selection for Unconventional Reservoirs Using a New 2D Slurry Transport Model","authors":"P. Pankaj, L. Belyakova, V. Isaev, I. Velikanov, D. Bannikov, L. Semin, A. Tikhonov","doi":"10.2118/191422-MS","DOIUrl":"https://doi.org/10.2118/191422-MS","url":null,"abstract":"It is often thought that in ultra-low-permeability unconventional reservoirs, proppant does not play a significant role in productivity because any proppant effectively results in a relatively infinite fracture conductivity. Although with over 75% of the treatment jobs pumped with slickwater in the shale reservoirs due to its cost benefit, it is also thought that slickwater has limited solids carrying capacity. Overflushing may compromise productivity by creating near-wellbore pinchouts. The study presented here aims to test some of these conventions through the use a new high-resolution slurry transport model in unconventional reservoirs. Hydraulic fracture propagation and solids transport are simulated across multiple wells and reservoir settings to measure the production performance of unconventional reservoirs. Wells completed in the Eagle Ford formation are studied using an integrated earth model built to capture the reservoir geology, petrophysics and geomechanics. A pseudo 3D model for fracture propagation has been coupled with a fine grid numerical simulation of proppant and fluid transport in hydraulic fracture. The transport model can distinguish and demarcate the corresponding bridging resolution. This allows capturing the effect of slurry with proppant bypassing bridged 2D elements. Multivariate analysis of over 50 cases with various combinations of hydraulic fracturing fluid with viscosity ranging from 1.5 cP (slickwater) to 362 cP (crosslinked gel) and various proppants ranging from 100 mesh to 20/40 proppants are evaluated using the 2D transport model to determine the impact on production. Additionally, various pumping schedules ranging from 750 lbm/ft to 3,000 lbm/ft are evaluated. Parametric sensitivity of the overflush fluid type and volume has been studied to measure the impact on proppant dislodgement in the near-wellbore area. Production performance for all the scenarios is studied through numerical simulation and an economic analysis workflow to evaluate the matrix for fracturing fluid and proppant selection.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"92 6 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":"128314146","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":"An Experimental Study for the Using of Nanoparticle/VES Stabilized CO2 Foam to Improve the Sweep Efficiency in EOR Applications","authors":"A. Ibrahim, H. Nasr-El-Din","doi":"10.2118/191534-MS","DOIUrl":"https://doi.org/10.2118/191534-MS","url":null,"abstract":"\u0000 CO2 foam has been used to improve the sweep efficiency for EOR as a replacement for polymers to avoid potential formation damage. Foams degrade at high temperatures (>212°F), in high-salinity environments, and in contact with crude oil. The present work evaluates nanoparticles and viscoelastic surfactants (VES) to improve foam stability when these foams are used as EOR fluid.\u0000 This study investigates the stability of alpha olefin sulfonate (AOS) foam for different foam solutions in the presence of nanoparticles and viscosifiers (VES). To achieve this objective, foam stability tests were conducted at different temperatures up to 150°F. Foam stability was studied in a high-pressure view chamber (HPVC) to find the optimal. Single and dual-coreflood experiments were conducted at 150°F to investigate the divergent ability for the foam solutions on heterogonous sandstone formations. Boise and Berea sandstone cores with permeability contrast of 10-15 were saturated initially with a dead crude oil. The CO2 foam was injected with 80% quality as tertiary recovery mode. The oil recovery and the pressure drop across the core were measured for the different foam solutions.\u0000 Adding silica nanoparticles (0.1 wt%) of size 140 nm and viscoelastic cocamidopropyl betaine surfactant (cocobetaine VES) (0.4 wt%) to the AOS (0.5 wt%) solution improves foam stability. In contact with crude oil, unstable oil-in-water microemulsion generated inside the foam lamella that decreased foam stability. A weak foam was formed for AOS solution, but the foam stability increased by adding nanoparticles and VES. From the single coreflood experiments, the oil recovery from the conventional water flooding 47% of the original oil-in-place. AOS was not able to enhance the oil recovery. No more oil was recovered by AOS foam, however, extra oil was recovered in the presence of nanoparticles (19 %) and VES (26%). The dual-coreflood experiments revealed low sweep efficiency during the water flooding as a secondary recovery. Adding nanoparticles and VES to the AOS foam system increased the sweep efficiency and increased the oil recovery from the low permeability cores.\u0000 Nanoparticles and VES were able to improve the foam stability for AOS solution. Adding nanoparticles is highly recommended for EOR applications, particularly at high temperatures.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"28 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":"128560862","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":"Large Scale Field Development Optimization Using High Performance Parallel Simulation and Cloud Computing Technology","authors":"Shusei Tanaka, Zhenzhen Wang, K. Dehghani, Jincong He, Baskar Velusamy, X. Wen","doi":"10.2118/191728-MS","DOIUrl":"https://doi.org/10.2118/191728-MS","url":null,"abstract":"\u0000 Field development optimization for oil and gas reservoirs is typically challenging due to large number of control parameters, model complexity, as well as subsurface uncertainties. In this study, we propose a joint field development and well control optimization workflow using robust parameterization technique and demonstrate its application through a offshore oil field development.\u0000 Traditionally, using simulation models for optimization of field development plan was considered time and cost prohibitive when incorporating models to cover range of uncertainties in reservoir properties. Consequently, the problem was simplified by reducing the number of control parameters through multi-disciplinary workflows. In this paper, we aim to optimize field development strategy by simultaneously controlling topside facility, number of wells, their trajectories, drilling sequence, and completion strategy etc., considering subsurface uncertainties and constraints. To achieve this, we used our next generation reservoir simulator and commercial cloud computing to explore the possibility of achieving an optimized development scenario within reasonable time and cost constraints.\u0000 We have applied the proposed workflow to the Olympus field case, which is an optimization benchmarking problem set up by Netherland Organization for Applied Scientific Research (TNO) using a synthetic North-sea type reservoir. Our objective is to improve the net present value (NPV) after 20 years of operation by controlling the number and location of platforms, number of injectors and producers as well as their trajectories and drilling sequence. The large number of control parameters and subsurface uncertainties make the optimization process challenging. Three optimization techniques, genetic algorithm (GA), particle swarm optimization (PSO) and ensemble-based optimization (EnOpt) were tested and their performances were compared. Best results in terms of NPV improvement was obtained by using the mixed-integer Genetic Algorithm method. More than ten thousand simulation runs were required by the method to reach to optimal development of well location, trajectory, drilling sequence etc. This was made possible by utilizing a high performance parallel simulator and cloud computing. The estimated cost of the commercial cloud service is almost negligible compared with the improvement in the economic value of the optimized asset development plan. The developed workflow and parameterization technique are flexible in well trajectory configuration and completion design allowing application to primary depletion as well as waterflooding.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"6 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":"130297201","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":"Extended Reach U-Shape Re-Entry Drilling in Shallow Depleted Fractured Reservoirs in Congo Offshore Oldest Oilfield","authors":"Chembou Mike Tony, V. Bruno, Crevoisier de Loïs, Akue Michel, Rodet Vincent, Ghia Gabriele, Mouamba Achille, Lazzem Ali","doi":"10.2118/191436-MS","DOIUrl":"https://doi.org/10.2118/191436-MS","url":null,"abstract":"\u0000 Congo has been an oil producing country since the 70's, it is in this context of aging oilfield and low oil price environment that a redevelopment project was launched to give a second life to a shallow, depleted, mature, offshore oilfield with viscous oil (22° API) in a cost-effective manner.\u0000 The solution selected was to drill \"U-shape\" side tracks (inclination at TD 115deg) from the original boreholes on an existing platform (60m WD). The objective was to create a second drainage area of up to 500m, ~200m away from the original producing zone. Five re-entries U-shape wells were delivered with measured to vertical depth ratios up to 2.5 in shallow heavily depleted reservoirs (270m TVD). The team selected innovative and low cost techniques to overcome many challenges, from high DLS in unconsolidated formations using simple mud motor BHA, to running 4-1/2\" liner up to 115deg inclination and implementing a thixotropic mixed metal oxide mud system to mitigate losses.\u0000 The project has been successful both from a budget and production standpoint.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"1 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":"130530179","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":"Peoples in Voluntary Isolation, Hydrocarbon Exploration and Recommended Practices – 10 Years After","authors":"F. L. Benalcazar, M. Thurber","doi":"10.2118/191584-MS","DOIUrl":"https://doi.org/10.2118/191584-MS","url":null,"abstract":"\u0000 \u0000 \u0000 A case study about the interaction and management of PVIs with E&P activities in the upper Amazon basin of Ecuador was presented in an SPE paper at Rio de Janeiro Conference in 2010. We outlined the history of PVIs within the context of E&P activities in remote tropical rainforest, and the actions taken by stakeholders to understand and protect these vulnerable groups. This paper will provide an evaluation of the strategies that have worked or failed in protecting the PVIs during the past 10 years since the publication of our original paper.\u0000 \u0000 \u0000 \u0000 This paper will draw on our own personal experience in the Ecuadorian Amazon, as well as interviews and publications on the PVIs since 2010. We will update the timeline of events and link those to specific policies that have been implemented by the government of Ecuador, operators in the oil company concessions, and other stakeholders. Interviews will be conducted with key decision-makers in the government, community relations professionals in the oil industry, academics and non-profit organizations (NGOs); to map out the evolving story of the PVIs and their prospects for the future. Information will be geo-referenced in a GIS system to better understand location of encounters with PVI, and how those may relate to E&P and other activities.\u0000 \u0000 \u0000 \u0000 The PVIs continue survive in a NoGoZone (Area Intangible) that is surrounded and superimposed by oil company concessions. There has been increased E&P activity in the buffer zone of the NoGoZone during the past 10 years - including seismic exploration and drilling, road building, and construction of production facilities, which has resulted in additional conflicts, including violent clashes between oil workers, settlers and PVIs, resulting in injury and death. The government of Ecuador, as well as oil companies, have implemented some effective measures to prevent conflict, but with mixed success. Although there is some improvement in management of PVIs since 2010, the issue is generally left unattended by petroleum companies until there is a violent clash.\u0000 \u0000 \u0000 \u0000 Proposals for specific solutions and more proactive stakeholder involvement and coordination will be presented, that need to be led by the oil companies and the government of Ecuador. It is hoped that this paper will generate more specific protective actions in Ecuador and in-depth discussions with SPE on how this complex issue should be managed worldwide by the O&G industry.\u0000","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"24 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":"123887167","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":"Review of Professional Engineering in Petroleum Engineering","authors":"L. Kinney, C. Norwood","doi":"10.2118/191431-MS","DOIUrl":"https://doi.org/10.2118/191431-MS","url":null,"abstract":"Many individuals who practice in the field of oil and gas production, transportation, and refining perform engineering tasks and activities but do not become licensed as Professional Engineers for a variety of reasons, such as statutory exemptions, corporate policies, or lack of understanding of the value of professional practice in an area with a high potential impact on health and safety. This paper uses information from state boards of licensure, national organizations related to petroleum engineering, and case studies to address these misunderstandings related to licensure. The value of licensure as a Professional Engineer in the area of petroleum engineering is summarized, including statutory requirements and exemptions to practice in various U.S. states. The licensure process for Professional Engineers is explained, including education, experience, and examination requirements. Professional practice and ethical standards are discussed. While some jurisdictions do not specifically require licensure to practice in the area petroleum engineering, there are a number of advantages for individual practitioners to become licensed as a Professional Engineer. Examples are provided to explain how professional engineering licensure can protect the health, safety, and welfare of the public, as well as benefit the individual practitioner and industry as a whole.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"74 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":"114837166","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}