ASME 2022 Onshore Petroleum Technology Conference最新文献

OPTC2022 Front Matter OPTC2022前沿问题

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-fm1

引用次数: 0

Emergency Repair of a P-381 River Water Supply Line at a Refinery in Belle Chasse, LA 洛杉矶贝尔查斯炼油厂P-381河供水管道的紧急维修

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-92029

M. Larsen, Murat Engindeniz

{"title":"Emergency Repair of a P-381 River Water Supply Line at a Refinery in Belle Chasse, LA","authors":"M. Larsen, Murat Engindeniz","doi":"10.1115/optc2022-92029","DOIUrl":"https://doi.org/10.1115/optc2022-92029","url":null,"abstract":"\u0000 A refinery in Belle Chasse, LA had a leak on a 30 in. (0.76 m) cement mortar lined and coated river water supply line in a pipe rack 40 ft (12 m) in the air. The water supply line was a P-381 Pretensioned Pipe. An attempt to wrap the line externally with a bi-directional glass FRP system was completed by others during a turnaround but the wrap failed when put under pressure, which created an emergency for the Belle Chasse Refinery. The refinery was interested in other options and this failure was a top priority to repair in place or it would have delayed startup.\u0000 The P-381 water supply line had two locations that needed to be addressed. One location had spalled mortar in the coating exposing the steel cylinder and reinforced bar, the other location had a sizeable hole/breach in the pipe and the existing wrap was drooping down from the breach, the wrap had delaminated from the host pipe.\u0000 Attendees will learn more about this emergency repair, which had to be completed within seven (7) days including step by step construction procedures that were used for this repair: Carbon Fiber Reinforced Polymer (CFRP) technology including design considerations, design methodology and the QA/QC process.","PeriodicalId":210257,"journal":{"name":"ASME 2022 Onshore Petroleum Technology Conference","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131463945","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}

引用次数: 0

Reducing Carbon Intensity of Production & Improving Uptime by Use of an Electric Adaptive Gas Lift Compressor 使用电动自适应气举压缩机降低生产碳强度并提高正常运行时间

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-93990

Devvrat Rathore, J. Snow, P. Snow

{"title":"Reducing Carbon Intensity of Production & Improving Uptime by Use of an Electric Adaptive Gas Lift Compressor","authors":"Devvrat Rathore, J. Snow, P. Snow","doi":"10.1115/optc2022-93990","DOIUrl":"https://doi.org/10.1115/optc2022-93990","url":null,"abstract":"\u0000 This paper details the framework and operation of a wellsite facility that utilizes a wellsite gas lift compressor that implements “adaptive flow control” to minimize manual intervention and carbon intensity of oil and gas production. The adaptive operation of the compression package is detailed, along with the metrics quantifying the reduction in carbon intensity. The basis for the reduction in carbon intensity is achieved by reduction in scope-1 emissions, instrumentation exhaust, minimizing the intervention by operations teams, and operating in “adaptive” mode to minimize trips and maximize production.\u0000 Unconventional wells on gas lift are sensitive to surface compressors trips, and in most cases required to be shut in a few hours due to liquid loading. Given the remoteness of well facilities, there may not be enough time for a lease operator or compressor technician to arrive at the compressor before the well is shut-in. Tracking the data on the majority causes of failures, it is observed that about half of the compressor trips were caused due to fluctuation in process gas pressure — this can be suction side, discharge side or due to gas conditions causing sudden fluctuation between stages of compression. Additionally, these dynamic conditions of operation are protected by static equipment protection alarms. The adaptive compressor operates with the ability to adjust to fluctuating process conditions, including floating shutdown limits using real-time calculation of mechanical loads on key components to ensure the dynamic nature of the shutdown limits does not impact equipment integrity. In case of a trip, the compressor additionally goes through a series of tests and attempts to restart itself. First trials of this project have shown high uptime of the facility and gas lift compressor and provide a model for collaborative R&D towards achieving a producers goals.","PeriodicalId":210257,"journal":{"name":"ASME 2022 Onshore Petroleum Technology Conference","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124771555","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}

引用次数: 0

Tubular Lockup Prediction in Deviated Wells Using Markov Chains 利用马尔可夫链预测斜井管柱锁紧

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-91574

O. Ogundare, S. Fagbemi

{"title":"Tubular Lockup Prediction in Deviated Wells Using Markov Chains","authors":"O. Ogundare, S. Fagbemi","doi":"10.1115/optc2022-91574","DOIUrl":"https://doi.org/10.1115/optc2022-91574","url":null,"abstract":"\u0000 The effect of friction in well drilling operations is especially important in deviated wells and in cases where the impact of axial compressive loads on a drillstring decreases significantly with vertical depth and transversal displacement. The prevailing theories hope to determine the critical buckling loads analytically using the Paslay-Dawson equation with the hope of minimizing the event of tubular buckling in a principled way. In practice, there is very little that can be done to change the nature of a formation except to minimize the friction drag force by pumping friction reducers into the wellbore/borehole which consequently enhances the propagation of axial compressive forces. Determining the tubular lockup region accurately is possible with high fidelity and high-resolution friction profiling of the formation using models that determine critical buckling loads as a function of drag friction. Economically, it is important to determine ahead of time the friction factor or coefficient profile of a formation to establish if and where tubular lockup would occur, which consequently reduces drilling costs by pumping a friction reducer when it is needed and not before. The main idea of this paper is therefore to introduce a model that generates a high-resolution k-point friction profile for a formation using Markov chains. The model is then applied to predict the transition probabilities for friction drag in a reservoir with an accuracy of 86.8%.","PeriodicalId":210257,"journal":{"name":"ASME 2022 Onshore Petroleum Technology Conference","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134609562","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}

引用次数: 1

ROP Optimization of Lateral Wells in SW Oklahoma: Artificial Neural Network Approach 俄克拉荷马州西南部水平井ROP优化:人工神经网络方法

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-91464

Haden P. Kolmer, Clark M. Cunningham, M. Al-Dushaishi

{"title":"ROP Optimization of Lateral Wells in SW Oklahoma: Artificial Neural Network Approach","authors":"Haden P. Kolmer, Clark M. Cunningham, M. Al-Dushaishi","doi":"10.1115/optc2022-91464","DOIUrl":"https://doi.org/10.1115/optc2022-91464","url":null,"abstract":"\u0000 Rate of Penetration (ROP) optimization has played a key role in the economic return and value of both onshore and offshore wells by decreasing drilling time thereby increasing the net present value (NPV) of the localized field. In this study, an Artificial Neural Network (ANN) model is developed to accurately model the ROP of a well in SW Oklahoma to optimize the drilling process.\u0000 A parametric study was conducted to showcase the effect of operational parameters on the ROP-ANN model and to minimize error and increase accuracy. The number of neurons and hidden layers within the model are optimized based on the lowest Mean Square Error (MSE) and highest R2. A comparative study was comprised of one well in Southern Oklahoma targeting the Caney Shale. The well is about 10,000″ vertical with a 2-mile lateral with a maximum inclination of 78° and Dogleg Severity (DLS) of 12°/100ft. UCS was incorporated into the model to geomechanically differentiate between shale, sandstone, and limestone.\u0000 The input drilling data is weighed against ROP showcasing the impact of each parameter on ROP. From this and further proven in the results, RPM, WOB, and UCS greatly effect ROP per foot based on the sensitivity analysis but steadily decline as the critical value is achieved.\u0000 The major advantage of this study is developing an accurate ANN model for onshore North American shale plays in understanding the lithological impact of UCS and high lateral deviation on ROP which can be used in pre-planning to optimize the drilling processes.","PeriodicalId":210257,"journal":{"name":"ASME 2022 Onshore Petroleum Technology Conference","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116169879","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}

引用次数: 0

Field Development Optimization of Haynesville Shale Wells Haynesville页岩井开发优化

ASME 2022 Onshore Petroleum Technology Conference Pub Date : 2022-09-20 DOI: 10.1115/optc2022-96604

S. Morsy, M. McClure, G. Fowler, D. Ratcliff

{"title":"Field Development Optimization of Haynesville Shale Wells","authors":"S. Morsy, M. McClure, G. Fowler, D. Ratcliff","doi":"10.1115/optc2022-96604","DOIUrl":"https://doi.org/10.1115/optc2022-96604","url":null,"abstract":"\u0000 Field development relies on understanding geological changes across a shale asset, adopting a successful landing zone strategy, and optimizing completion designs specific to each landing zone. Different areas may require different landing zone strategies or completion designs as a function of lithological and geological changes across the asset. Depletion effects also impact optimal landing and completion designs among pads. Therefore, a comprehensive field development plan is needed to address uncertainties and challenges that are associated with shale well development.\u0000 In this study, a simulation model is calibrated against field data, and then used for field development optimization. The plan first screens a wide range of development scenarios that include different landing strategies, frac zippering order, fluid intensity, proppant loading, cluster spacing, stage length, well spacing, and depletion levels. The screening is helpful to narrow the list of the key effective parameters to optimize. Tornado charts reveal relative importance of all tested parameters. The results reveal that, within the constraints of this particular study, stage length has largest impact on estimated ultimate recovery (EUR). Well spacing, landing, and fluid loading have a moderate effect. Proppant loading has the least impact. The majority of EUR uplift is associated with higher fluid intensity, shorter stage length, and wider well spacing. Optimal stage length is shown to change as a function of landing depth and is related to geology, geomechanics, and stress shadowing.\u0000 All tested scenarios provide different EURs, with different economic outcomes. Opportunity charts are used to identify the most economic field development scenarios. The best opportunities provide similar or higher EUR as of the current base design, but at a lower cost and/or higher rate of return. The best economical cases were recommended for field trials.","PeriodicalId":210257,"journal":{"name":"ASME 2022 Onshore Petroleum Technology Conference","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-09-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124310932","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}

引用次数: 0