Day 2 Tue, March 21, 2023最新文献

{"title":"Sustained Anulus Pressure in NoC Wells. Prevention and Remediation Using Polymeric Isolating Materials","authors":"Sofia Rivelli Lavallen, Luciana Martina García Eiler, M. Mucci, Lucas Martin Arribillaga Jofre, José Gimutky, W. Morris","doi":"10.2118/212580-ms","DOIUrl":"https://doi.org/10.2118/212580-ms","url":null,"abstract":"\u0000 Sustained Annulus Pressure (SAP) is a common issue that affects shale plays wells worldwide. The cement sheath barrier deteriorates due to extremely high hoop stresses generated in the cement annulus during fracture treatments. These stresses are approximately one order of magnitude higher than the cement maximum tensile stress.\u0000 Once cement sheath fails, gas or oil migrates from high-pressured subsurface formations through vertical cracks along the annulus. Pressure at the wellhead can reach values above the installation maximum rate which persistently rebuilds after bleed-down operations.\u0000 The presence of SAP means that well integrity has been compromised generating serious safety and environmental risks for operators.\u0000 After conducting several finite element simulation studies, that demonstrated the failure hypothesis, a research project was conducted to design an isolating material that would withstand service conditions generated during well termination and its overall life cycle. A polymeric sealing ma terial with high deformation capacity, consequently low Young's modulus, high toughness and bonding properties was developed.\u0000 The material was tested following API recommended practices and ASTM standards. A procedure to prevent SAP in new wells was proposed. Five well of different Vaca Muerta shale fields were isolated combining a cement slurry batch with the polymeric system pumped in tandem. Also, a repair procedure for wells showing SAP was proposed and successfully tested using a similar polymeric sys tem. This procedure consisted of injecting a 14.8 ppg formulation in the annulus in a pump and relief (P&R) manner. The pilot test is currently under evaluation. Wells isolated with the polymeric system have not presented SAP after more than six months, nor have the two remediation jobs conducted so far. Annular pressure of new and repaired wells is being monitored to determine treatment effectiveness.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129257126","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 State-Of-The-Art Methodology in Live Measuring of Stimulated Reservoir Volume (SRV)","authors":"Ahmed Assem, A. Ibrahim, M. Sinkey, T. Johnston, Shabnam Marouf","doi":"10.2118/212405-ms","DOIUrl":"https://doi.org/10.2118/212405-ms","url":null,"abstract":"\u0000 Shale well performance depends mainly on stimulated reservoir volume (SRV) which is generated from the hydraulic fracture job. The hydraulic fracture requires a mixture of fluid and proppant per feet to increase well recovery factor. Production rate of shale wells is related to the stimulated rock volume during the fracture treatments. Horizontal well spacing and depletion also play a significant role in optimizing SRV for each well.\u0000 This paper presents a method of improving and measuring SRV during a frac job by using neural network technology to guide frac operation in achieving the maximum SRV per injected fluid volume. Also, this technique can detect well-to-well interference, in case of a parent/child completion, and optimize frac hits. The guided system makes frac time more efficient and generates an efficient SRV with high connectivity to wellbore. The generated SRV per each stage is integrated with leak-off SRV to confirm the SRV volume and conductivity of each fracture system.\u0000 Actual field cases from oil and gas shale frac data are presented with live measurements of SRV for each stage followed by leak-off connected stimulated surface volume. The new method demonstrates that this concept can be used to improve completion design, well spacing, and placement strategies\u0000 The paper proposes a technology that will help shale producers optimize and measure SRV during frac operation without paying for or installing extra equipment after the pressure gauge.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"04 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128461772","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":"Vaca Muerta: Naturally Fractured and Oil-Wet Shale Characteristics Revealed by Water Saturation (Sw) Modeling Using Archie's Equation and Pickett Plot","authors":"Rahimah Abd Karim, R. Aguilera, C. Bernhardt, J. Bouhier","doi":"10.2118/212425-ms","DOIUrl":"https://doi.org/10.2118/212425-ms","url":null,"abstract":"\u0000 Sw modeling in Vaca Muerta using ‘resistivity-based’ methods has been recognized as challenging due to the complex mineralogical and depositional settings of Vaca Muerta. Consequently, ‘resistivity-free’ methods are commonly preferable. In this study, Sw modeling using Archie's equation (1942) and Pickett plots (1966, 1973) have been used with the inclusion of thin bed heterogeneity. Despite the complexity, the analysis reveals the variability of both naturally fractured and oil-wet shale characteristics of Vaca Muerta.\u0000 Several published studies have used Archie's equation to model Sw in Vaca Muerta, but often assumed that the porosity exponent, m is equal to the water saturation exponent, n. In this study, a new approach is presented using Archie's equation, but this time with the m and n being determined from Pickett plots for each stratigraphic unit. Although this method is simple, no such application has been published for the studied area. This technique is very powerful as it helps to relate the vertical variation of m and n to the complex pore system and wettability characteristics in Vaca Muerta.\u0000 The Sw analysis using Archie's equation and Pickett plots shows vertical variability in m and n values in each stratigraphic unit of a vertical well. The decreasing m and increasing n values with depth are corroborated by the increasing natural fractures intensity and oil wettability towards the Lower Vaca Muerta (LVM), as indicated by the cuttings descriptions, micro-resistivity images and a published Scanning Electron Microscopy (SEM) study. Better reservoir quality lies in the deeper section, especially the LVM with lower Sw, higher Total Organic Carbon (TOC) and porosity. The organic rich unit also has a higher intensity of thin bed heterogeneity, which comprises bedding parallel calcite-filled microfractures (beef), ash beds and calcite nodules. This emphasizes the criticality of including them in petrophysical evaluation. The most pronounced effect of thin bed heterogeneity is on the resistivity log. Despite the complexity, the modelled Sw matches well the Sw determined from retort and Dean Stark measurements. This shows that resistivity and porosity-based techniques, such as Archie's equation and Pickett plots are applicable in the complex Vaca Muerta shale.\u0000 Through analysis of Sw modeling using Archie's equation and Pickett plot, the variability of naturally fractured and oil-wet shale characteristics are revealed in each stratigraphic unit of a vertical well in Vaca Muerta. Despite its complexity, the analysis also includes, for the first time, thin bed heterogeneity. These challenges do not hinder the application of the above resistivity and porosity-based techniques which are proven to be powerful tools for characterizing the complex Vaca Muerta shale.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121457409","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":"Oil Production and CCUS Potential in La Luna Shale in Colombia","authors":"Claudia Marcela Herrera Tellez, A. Fragoso, R. Aguilera","doi":"10.2118/212408-ms","DOIUrl":"https://doi.org/10.2118/212408-ms","url":null,"abstract":"\u0000 La Luna Shale in Colombia is the main source rock in the Middle Magdalena Valley (MMV) and the Catatumbo Basins. La Luna shale is a high-quality source rock and its potential has been investigated by several authors. This paper presents geological, geochemical, and petrophysical description of La Luna shale with the dual objective of (1) utilizing CO2 for improving oil recovery through Huff-n-Puff (HnP) gas injection, and (2) storing CO2 safely and without leaks.\u0000 The overall approach includes verifying that geologic fluid containment exists in the shale reservoir. The present work shows that this is indeed the case in La Luna shale. Geologic containment is valuable as it permits maximizing oil recovery from La Luna shale and safe storage of CO2 with negligible possibilities of fluid leakage, thus providing a valuable contribution to solve problems related to climate change. Consequently, the procedure described in this paper conforms well to CCUS: Carbon capture, utilization and storage of CO2.\u0000 The Eagle Ford shale in Texas is a good analog of La Luna shale. In both reservoirs, sedimentation and development of the source rock start at about the same time in the late Cretaceous, about 93 million years ago. It is not surprising then that in both Eagle Ford and La Luna shales, oil, condensate and natural gas are in the same location where they were generated, gas is at the bottom, condensate in the middle and crude oil at the top of the structure. Thus, the hydrocarbon fluids have been upside down or inverted position through millions of years. This constitutes geologic containment.\u0000 The paper describes the following activities once geologic containment is established: (1) drill a pilot horizontal well (HW), (2) stimulate the HW with multi-stage hydraulic fractures and investigate the environmental impact (if the pilot is successful, drill another pilot(s)), (3) produce oil by primary means for a maximum of 2-3 years, (4) implement HnP CO2 injection, (5) store the CO2 in the shale reservoir once the HnP reaches economic limit. Regular pressure monitoring throughout the life of the HnP project guarantees the lack of leaks, a major concern when CO2 is stored in other types of depleted reservoirs or aquifers.\u0000 The novelty of the paper is demonstrating geologic containment in La Luna shale in both the MMV and Catatumbo Basins of Colombia. This provides the basis for implementing CCUS. The geological, geochemical and petrophysical description allow to construct a simulation model to investigate primary recovery as well as EOR by HnP CO2 injection. CO2 can be stored safely, without leaks, in the shale reservoir once the HnP project reaches economic limit.","PeriodicalId":357695,"journal":{"name":"Day 2 Tue, March 21, 2023","volume":"96 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134129300","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}