Computed tomography scans and data of cement that has been enhanced with graphene nanoparticles. Associated with the manuscript "Mechanical Strength and Microstructural Characteristics of Wellbore Cement enhanced by Graphene Nanoplatelets" by Cody Massion, Yunxing Lu, Mercy Achang, Andrew Bunger, Daniel Bour, Dustin Crandall, and Mileva Radonjic

Well completions are an integral part of providing safe, reliable and continuous access to underground resources such as oil, gas and geothermal resources. Completions are typically considered to be the final step of drilling engineering which includes processes such as setting casing, cementing, and perforating to reach the target formation. Completions provide the conduit from the resource to the surface. Although completions encompass a wide range of disciplines, several key factors ultimately determine the quality of the completion. One of those is cementing and centralizing casing within the wellbore. This white paper examines the current state of the art for centralizers in the context of well completions. The paper will include an introductory primer on well completions to provide the framework for the centralizer discussions. The types of centralizers currently available and how they are used will be discussed in addition to alternative centralizer techniques.

Data from high temperature dynamic sealing tests for various fracture widths, at various temperatures (degrees F), with 5 wt.% bentonite-based mud containing various material fiber contents, at 100 to 400 psi differential pressure. Data from pressure test and evaluation of the dynamic lost circulation materials (LCM) testing unit to reflect the condition of open and sealed fracture using fracture width of 1000 microns at 120 degrees F. Links to two papers based on the data - "Loss circulation prevention in geothermal drilling by shape memory polymer" which was published in Geothermics 89 (2021) 101943) as well as "Evaluating sealability of blended smart polymer and fiber additive for geothermal drilling with the effect of fracture opening size", published in the Journal of Petroleum Science and Engineering 206 (2021) 108998.

This submission includes the University of Alaska Fairbanks Monthly Research Performance Progress Reports. The goal of this project is to develop an improved cement for geothermal wells.

This submission includes the University of Alaska Fairbanks Monthly Research Performance Progress Reports. The goal of this project is to develop an improved cement for geothermal wells.

Directional Cooling-Induced Fracturing (DCIF) experiments were conducted on a short, cylindrical sample of Westerly granite (diameter = 4 inches, height ~ 2 inches). Liquid nitrogen was poured in a copper cup attached to the top of the sample, and the resulting acoustic emissions (AEs) and temperature changes on the surface of the sample were monitored. The obtained AEs were used to determine the microcracking source locations and amplitude, and the associated moment tensors. Included in this submission is an animation of the AEs, a graphic displaying the temperature changes, and the measured data.

This package includes data and footage from two rounds of downhole camera surveys performed at the Sanford Underground Research Facility (SURF) on the 4850 level. The exercise was performed once on 25 May 2018 and once on 21 December 2018. On May 25th, the first round was done during fluid injection at the 164-ft stimulation zone in the injection well (E1-I). On December 21st, the second round was carried out during fluid injection at the 142-ft stimulation zone. Prior to the injections, downhole instrumentation was removed from the production well (E1-P) to allow room for the downhole camera system. The water within E1-P was then lifted out by the application of air pressure and the downhole camera system was conveyed into the production well. Finally, the water was injected into E1-I and the camera was used to scan for jetting points, or fluid entry, in E1-P. There is a survey description in this package that further describes the procedure of the survey and the overall results. Additionally, there is a detailed analysis of the surveys in the form of a PowerPoint, which includes animations/visualizations from the camera footage, presents interpretations in detail, and provides some general conclusions. Three animations, along with the two video segments that show the jetting into E1-P, are also provided. The video footage was collected using a GeoVISION Dual-Scan Micro Video Camera, the specs of which are also included in this package as a resource.

Characterizing the stimulation mode of a fracture is critical to assess the hydraulic efficiency and the seismic risk related to deep fluid manipulations. We have monitored the three-dimensional displacements of a fluid-driven fracture during water injections in a borehole at ~1.5 km depth in the crystalline rock of the Sanford Underground Research Facility (USA). The fracture initiates at 61% of the minimum horizontal stress by micro-shearing of the borehole on a foliation plane. As the fluid pressure increases further, borehole axial and radial displacements increase with injection time highlighting the opening and sliding of a new hydrofracture growing ~10 m away from the borehole, in accordance with the ambient normal stress regime and in alignment with the microseismicity. Our study reveals how fluid-driven fracture stimulation can be facilitated by a mixed-mode process controlled by the complex hydromechanical evolution of the growing fracture. The data presented in this submission refer to the SIMFIP measurements and analyses of the stimulation tests conducted on the 164 ft (50 m) notch of the Sanford Underground Research Facility (SURF), during the EGS-Collab test 1. In addition to the datafiles, there is the draft of a manuscript submitted to Geophysical Research Letters (GRL).

Evaluation of Deep Wellbore Integrity in the Zama Field

Evaluation of Zama Field Wellbore Integrity Part I is the evaluation of wellbore integrity Part II is the evaluation of leakage potential by well

This folder contains the GEOPHIRES codes and input files for running the base case scenarios for the six deep direct-use (DDU) projects. The six DDU projects took place during 2017-2020 and were funded by the U.S. Department of Energy Geothermal Technologies Office. They investigated the potential of geothermal deep direct-use at six locations across the country. The projects were conducted by Cornell University, West Virginia University (WVU), University of Illinois (U of IL), Sandia National Laboratory (SNL), Portland State University (PSU), and National Renewable Energy Laboratory (NREL). Four projects (Cornell, WVU, U of IL, SNL) investigated geothermal for direct heating of a local campus or community, the project by PSU considered seasonal subsurface storage of solar heating, and the NREL project investigated geothermal heating for turbine inlet cooling using absorption chillers. To allow comparison of techno-economic results across the six DDU projects, GEOPHIRES simulations were set up and conducted for each project. The GEOPHIRES code was modified for each project to simulate the local application and incorporate project-specific assumptions and results such as reservoir production temperature or financing conditions. The base case input file is included which simulates the base case conditions assumed by each project team. The levelized cost of heat (LCOH) is calculated and matches the base case LCOH reported by the project teams.

High-pressure and high-temperature (HPHT) lost circulation material (LCM) rheology test results, LCM particle size distributions (PSD) analysis, and HPHT LCM fluid loss test results. Three academic papers / reports derived from this research are also presented.

The data files below summarize the results from various experiments testing properties of high-temperature self-healing inorganic cement composites. These properties include cement-carbon steel bond strength, Young's modulus recovery, matrix recovery strength, and compressive strength and Yonug's modulus for cement composites modified with Pozzolanic Clay additives.

A presentation with notes showing an overview of the last 6 months of the project on high-temperature self-healing inorganic cement composites. General approach, test methods and results for the self-healing cement composites are presented. Data include strength recoveries for 9 cement composites in three curing environments (water, alkali carbonate, brine) at 300 degC, bond strength measurements for cement/carbon steel samples, thermal shock tests, performance of healing aids. The presentation was shown during the joint SPE/GRC workshop on March 22 in San Diego, California

Abstract: Orientations of crustal stresses are inferred from stressinduced breakouts (well bore enlargements) in the eastern part of the Anadarko basin in central Oklahoma, the Marietta basin in south-central Oklahoma, and the Bravo dome area of the central Texas Panhandle. Inferred directions of maximum horizontal principal stress (SHmax) are east-northeast for the eastern Anadarko basin and northeast for the Marietta basin and the Bravo dome area. The relative magnitudes of the three principal stresses (S,, S2, S3) are known for the Bravo dome area from existing hydraulic-fracturing measurements, and a normal-faulting stress regime (Sv>SHmax >SHmIn) is implied. For the eastern Anadarko basin and the Marietta basin, the magnitudes of the principal stresses are not known. Possible left-lateral oblique slip on the Meers fault during the Quaternary implies that strike-slip (SHmax >Sv>SHmln) and reverse (SHmax >SHmln >Sv) faulting has occurred in south-central Oklahoma. Thus, the study region may be a transition zone between extensional stress in the Texas Panhandle and compressional stress in Oklahoma. Breakout data from the eastern Anadarko basin yield a single consistent SHmax orientation, whereas data from the Marietta basin and the Bravo dome area yield bimodalorthogonal distributions believed to consist of northwestoriented breakouts and northeast-oriented fracture-related wellbore enlargements. This northeast (orthogonal) trend in data from the Marietta basin and the Bravo Dome area is probably related to drilling-induced hydraulic fracturing of the wellbore or to preexisting natural fractures or joint sets intersecting the wellbore. On dipmeter log records, breakouts and fracture-related enlargements have similar elliptical cross sections. Orthogonally oriented breakout and fracturerelated wellbore enlargements are therefore differentiated by comparing their long-axis orientations with directions of known or inferred horizontal stress. The mean orientations of either the breakout or fracturerelated orthogonal trends in the Marietta basin and the Bravo dome area data sets are not as well constrained as the mean orientation of breakout data for the eastern Anadarko basin. Poorly constrained mean orientations give the appearance of data scatter or dispersion among wellbore enlargement orientations within the northwest and northeast bimodalorthogonal trends. Drill holes in the Marietta basin and Bravo dome area are located primarily between northwest-striking subparallel faults. Mean data orientations calculated for either orthogonal trend for individual well data sets appear to rotate counterclockwise across these two fault-bounded study areas. Stress trajectory rotation between suparallel faults within the Marietta basin and the Bravo dome study areas may account for the data scatter. Although breakouts and fracture-related enlargements formed in all parts of the thick sequences of sedimentary rocks logged, they are primarily in limestone, shale, and dolomitic rock, p

The Newberry Volcano EGS Demonstration in central Oregon, a 5 year project begun in 2010, tests recent technological advances designed to reduce the cost of power generated by EGS in a hot, dry well (NWG 55-29) drilled in 2008. First, the stimulation pumps used were designed to run for weeks and deliver large volumes of water at moderate well-head pressure. Second, to stimulate multiple zones, AltaRock developed thermo-degradable zonal isolation materials (TZIMs) to seal off fractures in a geothermal well to stimulate secondary and tertiary fracture zones. The TZIMs degrade within weeks, resulting in an optimized injection/ production profile of the entire well. Third, the project followed a project-specific Induced Seismicity Mitigation Plan (ISMP) to evaluate, monitor for, and mitigate felt induced seismicity. An initial stimulation was conducted in 2012 and continued for 7 weeks, with over 41,000 m3 of water injected. Further analysis indicated a shallow casing leak and an unstable formation in the open hole. The well was repaired with a shallow casing tieback and perforated liner in the open hole and re-stimulated in 2014. The second stimulation started September 23rd, 2014 and continued for 3 weeks with over 9,500 m3 of water injected. The well was treated with several batches of newly tested TZIM diverter materials and a newly designed Diverter Injection Vessel Assembly (DIVA), which was the main modification to the original injection system design used in 2012. A second round of stimulation that included two perforation shots and additional batches of TZIM was conducted on November 11th, 2014 for 9 days with an additional 4,000 m3 of water injected. The stimulations resulted in a 3-4 fold increase in injectivity, and PTS data indicates partial blocking and creation of flow zones near the bottom of the well. This submission includes all of the files and reports associated with the stimulation, pressure testing, and monitoring included in the scope of the project.

Operational performance requirements are needed to support development of specifications for downhole motor power sections to be used for drilling hard rock during geothermal wellbore construction. Theoretical torque specifications are derived based upon a widely-accepted rock-reduction model in the literature using representative properties for typical rock formations. The derived values correspond to optimum motor performance for rock reduction at minimum specific energy and form a set of minimum requirements on output torque and power for downhole motors. Actual values should be increased to account for factors such as increased hydrostatic pressure at depth, bit wear, heterogeneous rock, and non-ideal drilling conditions.

The paper was presented at the 46th Workshop on Geothermal Reservoir Engineering, Stanford University, Stanford, California, February 15-17, 2021. In this study, the effectiveness of different additives was evaluated in maintaining drilling fluid rheology at HPHT(high pressure and high temperature) conditions. The additives considered in this investigation are bentonite, xanthan gum (XC), low-viscosity and regular polyanionic cellulose (PAC-L and PAC-R), hydroxyethyl cellulose (HEC), other synthetic polymers and clay such as THERMA-VIS. Fluid samples were prepared in various concentrations and left to hydrate for 20-24 hrs. The rheological analysis was performed under HPHT conditions using a rheometer. Different parameters were considered in the screening, such as temperature, concentration, shear rate, and aging time.

Polymer-cement experiments were conducted in order to assess the chemical and thermal properties of various polymer-cement composites. This file set includes the following polymer-cement analyses: Polymer-Cement Composite Synthesis Polymer-Cement Interactions by Atomistic Simulations Polymer-Cements Compressive Strength & Fracture Toughness Polymer-Cements Fourier Transform Infrared Spectroscopy (FTIR) Analysis Polymer-Cements Resistance to Thermal Shock-CO2 and H2SO4 Attack Polymer-Cements Rheology Analysis Polymer-Cements Self-Repairing Permeability Analysis Polymer-Cements Scanning Electron Microscopy with Energy Dispersive X-Ray Spectroscopy (SEM-EDX) Compositional Analysis Polymer-Cements Thermogravimetric Analysis (TGA) and Total Organic and Inorganic Carbon Analysis (TOC and TIC) Polymer-Cements X-Ray Diffraction (XRD) Analysis

The site characterization data used to develop the conceptual geologic model for the Snake River Plain site in Idaho, as part of phase 1 of the Frontier Observatory for Research in Geothermal Energy (FORGE) initiative. This collection includes data on seismic events, groundwater, geomechanical models, gravity surveys, magnetics, resistivity, magnetotellurics (MT), rock physics, stress, the geologic setting, and supporting documentation, including several papers. Also included are 3D models (Petrel and Jewelsuite) of the proposed site. Data for wells INEL-1, WO-2, and USGS-142 have been included as links to separate data collections. These data have been assembled by the Snake River Geothermal Consortium (SRGC), a team of collaborators that includes members from national laboratories, universities, industry, and federal agencies, lead by the Idaho National Laboratory (INL). Other contributors include the National Renewable Energy Laboratory (NREL), Lawrence Livermore National Laboratory (LLNL), the Center for Advanced Energy Studies (CEAS), the University of Idaho, Idaho State University, Boise State University, University of Wyoming, University of Oklahoma, Energy and Geoscience Institute-University of Utah, US Geothermal, Baker Hughes Campbell Scientific Inc., Chena Power, US Geological Survey (USGS), Idaho Department of Water Resources, Idaho Geological Survey, and Mink GeoHydro.

Rheology data obtained from flow loop tests, performed using different lost circulation materials (LCM) to study their effect on fluid rheology and wellbore hydraulics. The sealing performance of different LCM was tested using different fracture sizes. Five academic papers / reports derived from this research are also presented.

Borehole W1 is a NQ core hole drilled at our test site in Socorro. The rock is rhyolite. Borehole W1 which was used to test gas-gas explosive mixtures is 55 feet deep with casing (pinkish in the drawing) set to 35 feet. The model is a representation of the borehole and the holes we cored around the central borehole after the test. The brown colored core holes showed dye when we filled W1 with water and slightly pressurized it. This indicates there was some path between W1 and the colored core hole. The core holes are shown to their TD in the drawing. The green plane is a fracture plane which we believe is the result of the explosions of the gas mixture in W1. Data resource is a 2D .pdf Solid Works Drawing of borehole W1.

This submission contains documents that describe the USU Camas-1 test well, drilled in Camas Prairie, Idaho, in Fall 2018 and Fall 2019. The purpose of this well is to validate exploration methodologies of the Snake River Plain (SRP) Play Fairway Analysis (PFA) project.

This link leads to a webpage with spreadsheets containing seismic borehole sensor locations and well trajectories for wells 56-32, 58-32, 78-32, 78B-32. Each of the files at the provided link include meta data on relevant information.

This dataset contains all well logs from Utah FORGE well 16A(78)-32. This includes the mud log, Sanvean Technologies logs, and Schlumberger logs. Please see the file descriptions below for information about each log.

This test was conducted at the Chevron Cymric oilfield in the California central valley near Bakersfield. A reflected seismic signal was observed in all three components (x, y, z) of the 3-component Episensor geophone, as well as all phones on the single component array. The arrival time of the reflected seismic signal matches calculations based on a reasonable velocity model (~650 m/s). The seismic data has three channels that are from the 3-C Broadband Episensor, then from 4th -- 12th channels has no data. Channel 13 -- 25 are surface single change vertical geophones. The source of this seismic survey is weight drop. More info could be found from the data header and the attached PPT file.

The objective of this field test is to validate several technologies for non-invasive well integrity assessment using existing wells with a known completion. The tests were made at the Cymric oil field, which is a steam flood operation. The wells therefore undergo similar downhole conditions as geothermal wells. The Cymric field is mainly a cyclic steam operation where wells are 1000-15-00 ft in depth and the reservoir occupies the bottom 400ft. The maximum temperatures can exceed 500 degrees F and the well spacing is very close, often less than 50m. The field plan consisted of applying the Time Domain Reflectometry (TDR) method to the wells. The input voltages were set as 70 V shows the TDR responses at frequencies of 450 kHz, 2500 kHz, and 4500 kHz. There is a summary report will full information about the field tests.

The Plains CO2 Reduction (PCOR) Partnership performed a wellbore integrity assessment to evaluate the relative leakage potential of 826 wells penetrating the basal Cambrian system in the United States, drilled between 1921 and 2010. The basal Cambrian system is a deep saline reservoir that has been identified by the U.S. Department of Energy as a potential carbon dioxide (CO2) storage site. The ability of the basal Cambrian system to retain injected CO2 over an extended period of time is, in part, dependent on the integrity of wellbores that penetrate the target reservoir. Wellbore integrity is the ability of a well to maintain hydraulic isolation of geologic formations and prevent the vertical migration of fluids (Zhang and Bachu, 2011; Crow and others, 2010). This study’s evaluation of wellbore integrity involves analyzing wellbore characteristics (i.e., cement types, cement additives, completion techniques, well depths, and well casing) to derive a relative leakage potential score using methods similar to Bachu and others (2012). Wells were assigned a classification of minimal, lower, moderate, or higher based on their relative leakage potential. This study provides a screening-level evaluation to compare and rank wells for further detailed evaluation. Site-specific risk analysis within these target areas would trigger a more detailed assessment of those wells identified for further investigation. Potentially leaking or high-risk wells could be addressed using established remediation programs employing current well mitigation technologies or appropriate monitoring during CO2 injection. The results of this regional screening-level evaluation determined that 15% of the wells assessed were classified as moderate or higher potential for deep well leakage, and 6.0% of the wells were classified moderate or higher for shallow well leakage. Of the wells assessed, 3.4% exhibited moderate or higher potential for both shallow and deep leakage. The majority of the moderate- or higher-potential wells are located in western North Dakota and eastern Montana in areas of intensive oil and gas exploration and production. The practice of producing oil and gas from these wells has increased the relative well leakage potential (based on the available data and methods utilized). The ranking of the relative leakage potential provides a mechanism to screen wells for detailed evaluation in areas targeted for CO2 injection.

Schlumberger's gyro survey for well 36-16 in the project study area.

Temperature logs, pressure logs, directional survey, well history, well bore schematic, and other reports for well 48-11TCH at West Flank FORGE

Wireline logs available for 36-10 well in project area.

Wireline logs available for 36-15 well in project area.

Wireline logs available for 36-15C well in project area.

Wireline logs available for well 36-16 in the project area.

National Energy Technology Laboratory’s (NETL) GEO Water Energy Link Library, geoWELL, is a map-based application that provides quick access to the primary on-line sources of subsurface geologic and wellbore (oil, gas, and underground injection) information for appropriate U.S. state, tribal and federal agencies.