Day 1 Tue, February 01, 2022最新文献

{"title":"Driving Completion Execution Improvements Through Detailed Analysis of Acoustic Imaging and Stimulation Data","authors":"Mark Watson, M. Schinnour, D. Cramer, M. White","doi":"10.2118/209184-ms","DOIUrl":"https://doi.org/10.2118/209184-ms","url":null,"abstract":"\u0000 This study documents an ongoing analysis of frac plug integrity and inter-cluster treatment distribution using multiple datasets. It includes post-treatment acoustic imaging data from three Montney pads, in which the dimensions of 3538 perforations and casing wear patterns at 150 frac plug setting locations were determined. The analysis process features an iterative approach to improving execution performance during field appraisal – execute the design, measure performance, identify failures, and then implement an improved design. This approach identified execution performance issues that would have otherwise been undetected and provided insights that were used to inform manufacturers of necessary design improvements.\u0000 The fiber optic and acoustic imaging programs for Pad 1 indicated loss of frac plug isolation in 70% of stages. Acoustic imaging data gathered from Pad 2 indicated loss of frac plug isolation in 57.5% of stages. Additionally, the measured diameters of eroded perforations were smaller than the expected unstimulated diameter in 48% of measurements. This finding revealed a discrepancy in the perforation-charge manufacturer's published performance information which led to unintended treatment behavior.\u0000 Building on Pad 2 results, multiple vendors were engaged to provide engineered solutions to the issues identified through acoustic imaging campaigns for potential implementation on future wells. The findings from this exercise confirmed the underperformance of dissolvable frac plug technology and the importance of verifying perforation performance by conducting surface tests that are representative of field conditions. The outcome led to modified perforation charges and dissolvable frac plugs for trial on Pad 3.\u0000 Outputs from the analysis performed on Pad 3 revealed improved performance, with confinement issues identified in only 28% of the total stages. Initial unstimulated perforation diameters were within 3.59% of the pre-job surface validation tests. Improvements contributed to better treatment conformance relative to Pad 1 and Pad 2.","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130839126","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":"Reservoir and Completion Characterization Leads to Improved Well and Field Economics in South Texas Eagle Ford Field","authors":"S. Schubarth, Bruce Gates, Blain Spies, R. Lestz","doi":"10.2118/209182-ms","DOIUrl":"https://doi.org/10.2118/209182-ms","url":null,"abstract":"\u0000 The capital investment required when completing horizontal, unconventional reservoir wells is significant. This capital pays for materials and services which help to improve the productivity and recovery from the well. The goal of our work is to identify the primary drivers in this capital spending that effects productivity and recovery and then optimize the spending to get the most revenue for the least amount of dollars. We will show how through the characterization of reservoir properties and completion effectiveness that we can maximize the profitability of a well and field development without sacrificing recovery or productivity. A case history from beginning evaluation to final results will be presented. Improving oil recovery and economic performance.\u0000 Our process begins by estimating key reservoir parameters such as Net Pay, Porosity and Water Saturation. We include the description of reservoir fluid properties. We then analyze the producing history from existing wells and determine formation average permeability, the average effective length of the fractures created along with the number of fractures producing along the lateral. The solution for this becomes unique if we have sufficient producing history. However, engineering judgement can be used to narrow down the potential range of values when sufficient production data is not available. From the results of our production analyses, we can determine the effect of treatment size on resulting effective length of fractures and then using physical based analytical reservoir models we can predict the producing life for wells completed in a wide variety of completion designs. Economics scenarios are then calculated, and the outcome plotted to form a \"road map\" for the direction of change in completion design that will result in improved economics.\u0000 Comparative results are complete from five wells drilled 1000 feet apart. Four were completed using past designs and one with the recommended design to improve economics. The results indicate that the optimized design is performing much like predicted and should produce over 20% more oil over its life while total well cost was reduced. The productivity of all of the wells is very similar. The results seen here agree with other projects where this process has been implemented. We conclude that through accurate reservoir and completion characterization, capital spending can be targeted to enable profitability to be improved significantly.\u0000 The methods presented in this work can be applied to every unconventional play to optimize completion capital spending, reducing the capital needed to develop a field by hundreds of millions of dollars, where applicable. This work has been performed in other areas with similar results.","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"46 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127772520","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":"Lessons Learned from the Large-Scale CO2 Stimulation of 11 Unconventional Wells in the Williston Basin: A Practical Review of Operations, Logistics, Production Uplift, and CO2 Storage","authors":"L. Ribeiro, Ashley Thoma, J. Bryant, D. Sundararajan, Wesley Zurovec","doi":"10.2118/209159-ms","DOIUrl":"https://doi.org/10.2118/209159-ms","url":null,"abstract":"\u0000 The paper introduces the results of the first CO2 fracturing campaign conducted in the Williston Basin. From 2015 to 2019, 11 horizontal multi-stage wells were safely stimulated using a CO2-hybrid design to improve production and store CO2 underground. The fracturing design consisted of the injection of a super-critical CO2 pre-pad (with a target injected volume of 5,000 tons per well) followed by a traditional slickwater or hybrid proppant slurry. The CO2 was captured from point-source plants that would have released the CO2 to the atmosphere otherwise.\u0000 The performance of the CO2 fracturing design is compared to the performance of nearby hybrid and slickwater designs. The paper provides a range of potential production uplift for both 12-month production and EUR. The paper also provides the range of CO2 concentrations produced back to the surface and an estimate of CO2 storage potential based on extensive compositional monitoring.\u0000 The paper shares practical guidelines and recommendations to facilitate the understanding and logistics of CO2 operations during injection and production. The field study highlights critical considerations related to fracturing design, logistics, operational handling of CO2, reservoir uplift, and permanent CO2 storage potential. The analysis provides new insight to the storage potential for CO2 fracturing, EOR, and/or carbon capture and storage (CCS) applications in the Williston Basin, and by extension to other ultra-tight formations.","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"7 5","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121013295","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":"Hydraulic Fracture Geometry, Morphology, and Parent-Child Interactions: Bakken Case Study","authors":"Michael G. McKimmy, Stephanie Hari-Roy, C. Cipolla, Jennifer Wolters, Haffener Jackson, Haustveit Kyle","doi":"10.2118/209162-ms","DOIUrl":"https://doi.org/10.2118/209162-ms","url":null,"abstract":"\u0000 Until recently, microseismic has been the primary diagnostic for estimating \"bulk\" or stage-level fracture geometry, including asymmetry due to parent-child interactions, for modern multi-cluster plug-and-perf completions. However, microseismic cannot provide details on individual fractures or cluster-level measurements. With the continued advances in fiber optic technologies, we can now measure cluster level fracture behavior at the wellbore and in the far-field. Characterizing the relationship between wellbore and far-field fracture geometry, referred to as fracture morphology, is important when simultaneously optimizing completion design and well spacing. Microseismic and fiber optics are very robust, but expensive, technologies and this limits the frequency of their application. Recently developed low-cost pressure-based technologies enable high-volume data acquisition but may not provide the same level of detail compared to microseismic and fiber optic measurements. This paper presents a case history that details the application of deployable fiber optics to characterize fracture geometry and morphology using microseismic and strain data. The paper also presents results from Sealed Wellbore Pressure Monitoring (SWPM) (Haustveit et al. 2020), comparing the lower-cost SWPM technology to the higher-cost deployable fiber.\u0000 Wireline-fiber was deployed in the inner two wells, one Middle Bakken (MB) and one Three Forks (TF), of a four-well pad. Surface pressures were recorded on all wells on the pad and nearby parent wells. The outer two wells, one MB and one TF, were completed first, using zipper operations. Fiber-based microseismic and strain measurements were used to characterize fracture geometry and morphology, and parent-child interactions. Pressure measurements on the two inner wells were used for SWPM, providing estimates of completion effectiveness and fracture geometry using Volume to First Response (VFR) measurements.\u0000 The microseismic data showed asymmetric growth from the eastern well to the parent well pad, with fractures covering the entire parent well pad. More symmetric fracture growth was measured for the western well, as the parent well pad was farther away. The microseismic data provided fracture geometry measurements consistent with previous measurements in the same area using a geophone array. The SWPM results compared favorably to the fiber measurements using the high confidence data. However, there were data acquisition complexities with both technologies that will be detailed in the paper.\u0000 Fiber strain measurements provided detailed information on fracture morphology, showing significant decreases in the number of far-field hydraulics as distance increases from the completion well. The advancements in Low Frequency Distributed Acoustic Sensing (Ugueto et al. 2019) provides the ability to monitor hydraulic fractures approaching, passing above/under, and intersecting the monitoring location. Both fiber and SWPM showed much","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129616500","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":"Completions and Stimulation Experimental Design, Execution, Analysis & Application for the Permian Delaware Basin Hydraulic Fracture Test Site 2","authors":"P. Huckabee, G. Ugueto, K. Haustveit, M. Wojtaszek, S. Mondal, C. Ledet, Talib Daredia, A. Reynolds","doi":"10.2118/209172-ms","DOIUrl":"https://doi.org/10.2118/209172-ms","url":null,"abstract":"\u0000 Comprehensive and integrated diagnostics associated with the NETL-GTI Hydraulic Fracture Test Site 2 (HFTS2) in the Permian Delaware Basin enabled a unique opportunity to evaluate stimulation distribution effectiveness (SDE) in the wellbore, near-well and far-field regions (WBR, NWR, FFR) for upper Wolfcamp completions. This paper will summarize the experimental design, execution and analysis for HFTS2 well completions. Results and observations are translated into applications and opportunities for Wolfcamp completions and resource development optimization.\u0000 A Completions Sub-Committee was created to allow for broad industry input to design the scope of trials to be considered for execution in the HFTS2 wells. Primary objectives were to evaluate Stimulation Distribution Effectiveness (SDE) and test eXtended Stage Lengths (XLS) for stimulation value opportunities. Trials included: 1) HFTS2 operator base-plan completions; 2) more Aggressive Limited Entry (ALE) practices; 3) tapered number of perforations per cluster; and 4) XLS up to ∼ 330’ stage lengths, with ALE practices. Diagnostics included multiple wells with Optic Fiber and Step-Down Tests to evaluate stimulation domain characteristics in the WBR, NWR and FFR regions.\u0000 The combination of multiple wells with permanent optic fiber installed, and controlled sequencing the stimulation treatment placement operations, enabled good understanding of the frac domains created in the WBR, NWR and FFR. Evaluation of the base-design completions demonstrated good SDE for most applications, from the optic fiber distributed sensing. EXtreme-Limited-Entry (XLE) applications were determined to not be necessary for SDE in the Permian Wolfcamp. Tapered perforation designs were not necessary for good SDE. Risks to SDE were clearly observed with injectivity loss due to mechanical problems with the pumping operations. Risks to SDE were also observed when stage isolation was not effective. Extended Stage Lengths (XLS), up to ∼ 330’ stage lengths with 10 perforation clusters, were generally effective with ALE practices. Acquiring and maintaining injection rate was critical for the higher cluster count stages. The FFR stimulation domain dimensions were generally consistent with the WBR dimension distributions. Significant non-uniformity was observed in the FFR at a cluster dimension resolution. There was good correlation with domain dimensions in the FFR when there was lack of stage isolation the treatment well. Staggered landing depths of the wells, and an instrumented vertical monitor well, enabled assessment of vertical fracture geometry characteristics.\u0000 Application of integrated diagnostics for completion and stimulation design evaluation enabled assessment of multiple designs in just a few wells. Optic Fiber Distributed Acoustic, Temperature and Cross-Well Strain Sensing (DAS, DTS & DSS), in combination with selective Step-Down Tests, enabled evaluation of stimulation domain characteristics in the WBR, NWR an","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"12 4","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133205444","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of Disposable Fiber Technology to Evaluate Far-Field Communication and Fracture Performance in the Marcellus Shale","authors":"M. Mantell, A. Mercer, J. B. Jackson, D. Murphy, J. Conaway, S. Machovoe, J. Stokes, M. Elliott","doi":"10.2118/209148-ms","DOIUrl":"https://doi.org/10.2118/209148-ms","url":null,"abstract":"\u0000 The use of fiber-optic-sensing technology for the evaluation of completion efficiency, primary cement sheath integrity, and offset well interference has become more prevalent in recent years. In addition, the use of a fiber-optic cable for microseismic monitoring as opposed to traditional wireline-conveyed geophones was recently introduced. Various fiber deployment methods have been developed over the years to allow operators to make rapid decisions in real-time based on distributed acoustic sensing (DAS), distributed temperature sensing (DTS), and microseismic data, all provided by a small fiber- optic cable deployed in the well and monitored at surface via sophisticated interrogation equipment.\u0000 Historically, fiber-optic cables were deployed in a permanent configuration, strapped to the production casing, in a manner similar to a standard control line, and deployed with the casing prior to cementing. Permanent fiber has become simpler and cost effective over time and provides valuable near wellbore information - and there are continuous developments to keep reducing that cost and complexity. Some operator focus has been less on the monitoring of the completion efficiency metrics and more on understanding the cross well interference data provided from fiber. As a result, operators have looked to other, temporary-type deployment options for fiber.\u0000 Two typical temporary deployments are via coiled-tubing and an armored fiber-optic cable. For the first method, a fiber-optic cable is fed into a coiled-tubing reel and then deployed downhole to monitor the strain when the well is impacted or closely impacted by a hydraulic fracture from an adjacent well. An armored fiber-optic cable deployment is similar to electric wireline in that it is installed in the well during pump down or with a wireline tractor.\u0000 Both these options are viable and readily available; however, they include supplementary expenses in terms of equipment required to convey the fiber into the well. In addition, the surface footprint required during the conveyance and monitoring phases of the operation is substantial with crane(s), a coiled-tubing unit or wireline unit, and associated on-location equipment required during the job. Figure 1 depicts a wireline-conveyed fiber operation in conjunction with fracturing operations. Additional equipment in the form of a wireline truck and extra crane are highlighted in yellow. In contrast, a wellsite where disposable fiber is being deployed is shown in Figure 2. Once the fiber is landed, the pump units are removed and only a trailer and crew pickup remain on-site.\u0000 Figure 1 Typical fracturing operation, wireline-conveyed fiber\u0000 Figure 2 Typical offset well monitoring wellsite, disposable fiber\u0000 This paper will discuss a new, low-cost option now available to conduct cross well monitoring and microseismic evaluation of offset completions using a disposable optical fiber that requires minimal equipment to deploy into the wellbore, reduces surf","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127471306","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":"Evaluating Effects of Completion Design on Fracturing Stimulation Efficiency Based on DAS and DTS Interpretation","authors":"Shohei Sakaida, Iuliia Pakhotina, D. Zhu, A. Hill","doi":"10.2118/209167-ms","DOIUrl":"https://doi.org/10.2118/209167-ms","url":null,"abstract":"\u0000 Fiber optic measurements including Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) have been established as common tools to monitor the downhole condition during hydraulic fracturing treatment as well as during production. Several authors presented a methodology of quantitative interpretation for DAS and DTS data to estimate injected/produced fluid volume distribution among perforation clusters. The quantitative interpretation allows us to not only diagnose the stimulation efficiency but also optimize the completion design for subsequent fracturing jobs. This study investigates how completion parameters are correlated with fracturing stimulation performance based on the field application of DAS and DTS interpretation methodology. The field data from MIP-3H provided by the Marcellus Shale Energy and Environmental Laboratory is analyzed in this work.\u0000 As previously presented, a DAS/DTS integrated interpretation method estimates fracture half-length distribution for each stage. In this approach, fractures are assumed to be created in a swarm pattern from each perforation cluster. We do not assign fractures only at the perforation cluster locations but assume that multiple fractures are initiated along a stage interval with much smaller spacing than cluster spacing. This fracture swarm model is supported by several field observations. Once the DAS interpretation estimates the injected fluid volume for each perforation cluster, by considering the fluid volume distribution as an input parameter for the DTS interpretation, the temperature inversion provides the half-length of each fracture. This interpretation approach allows us to estimate uniformity of the fracture half-length distribution. To statistically describe the fracture uniformity, a uniformity index is defined. The estimated uniformity index is compared with inflow rate for each stage to investigate how the uniformity of fracture distribution contributes to well performance. The inflow profile is estimated by interpreting the DTS data during production. The comparison shows that the stages with uniform fracture half-length distribution are more productive. This result implies that the stages more uniformly stimulated become more productive.\u0000 By observing the relationship between the uniformity index and several completion parameters such as injection rate, total volume of injected fluid, proppant concentration and so on, we can investigate what parameter is more influential to the fracture stimulation efficiency. The statistical analysis illustrates that the uniformity of the fracture half-length distribution and high productivity are correlated with high injection rate. Based on this study, the injection rate would be one of the primary design parameters to maximize the fracturing stimulation performance in this field case. As demonstrated in this study, the evaluation of fracturing stimulation design based on the interpretation of DAS and DTS data would be an","PeriodicalId":262088,"journal":{"name":"Day 1 Tue, February 01, 2022","volume":"121 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-01-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116833377","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}