AndreaBozzo/ceres-open-data-index huggingface dataset:
EGOM Net Pay Tertiary

Net pay (usable sand thickness/seal thickness) (long/lat/Z) in the Tertiary section in the Eastern Gulf of Mexico. Generated by the Geological Survey of Alabama, with IHS Petra (v. 3.11.1.14) geologic interpretation software,  using highly connected features (least squares) and smoothing contours with grid flexing.

XYZ is long/lat/Z where long/lat is WGS 84 and Z is feet.

Resource includes:

-  TERT_NET_PAY_SAND.XYZ - Net pay sand (feet) for entire Tertiary section
-  UP_TERT_NET_PAY_SAND.XYZ -  Net pay sand (feet) for "upper Tertiary" Miocene through middle Eocene marker (Miocene undiff, Oligocene undiff, and Upper Eocene/Jackson Group (note Tmu is either the top of Miocene undiff and/or min depth 2500' BSL)
-  LOW_TERT_NET_PAY_SAND.XYZ -  Net pay sand (feet) for "lower Tertiary" middle Eocene marker through Selma Group (Lower Eocene/Claibrone Group, Wilcox Group, Midway Group, and Clayton Formation)
-  UP_TERT_NET_SEAL.XYZ - Net seal thickness for "upper Tertiary" Miocene through middle Eocene marker (Miocene undiff, Oligocene undiff, and Upper Eocene/Jackson Group (note Tmu is either the top of Miocene undiff and/or min depth 2500' BSL)

This material is based upon work supported by the U.S. Department of Energy National Energy Technology Laboratory (DE-FE0026086). Cost share and research support are provided by the Project Partners and an Advisory Committee.

Tags: CCUS, Eocene, Miocene, SOSRA, Tertiary
EGOM Tertiary RawCapacity

Raw CO2 storage capacity (long/lat/Z) in the Tertiary section in the Eastern Gulf of Mexico. Generated by the Geological Survey of Alabama, with IHS Petra (v. 3.11.1.14) geologic interpretation software,  using highly connected features (least squares) and smoothing contours with grid flexing; calculation is Net Pay * Porosity * CO2 density

Two grids for each interval were generated due to the paucity of data for the Destin Dome block region. Included in this resource are:

-  RawCap_TERT_MO-VK.XYZ - Entire Tertiary section (MO-VK blocks)
-  RawCap_TERT_DD.XYZ - Entire Tertiary section (DD block)
-  RawCap_LOW_TERT_MO-VK.XYZ - "lower Tertiary" middle Eocene marker through Selma Group (Lower Eocene/Claibrone Group, Wilcox Group, Midway Group, and Clayton Formation (MO-VK blocks)
-  RawCap_LOW_TERT_DD.XYZ - "lower Tertiary" middle Eocene marker through Selma Group (Lower Eocene/Claibrone Group, Wilcox Group, Midway Group, and Clayton Formation (DD block)
-  RawCap_UP_TERT_MO-VK.XYZ - "upper Tertiary" Miocene through middle Eocene marker (Miocene undiff, Oligocene undiff, and Upper Eocene/Jackson Group (note Tmu is either the top of Miocene undiff and/or min depth 2500' BSL) (MO-VK blocks)
-  RawCap_UP_TERT_DD.XYZ - "upper Tertiary" Miocene through middle Eocene marker (Miocene undiff, Oligocene undiff, and Upper Eocene/Jackson Group (note Tmu is either the top of Miocene undiff and/or min depth 2500' BSL) (DD block)

This material is based upon work supported by the U.S. Department of Energy National Energy Technology Laboratory (DE-FE0026086). Cost share and research support are provided by the Project Partners and an Advisory Committee.

Tags: CCUS, CO2 capacity, Eocene, Miocene, Tertiary, gulf of mexico
Formation Tops EGOM

Formation top picks in the post-Cretaceous section for offshore wells in the Eastern Gulf of Mexico (UWI/API, Fm Name, Source, MD, qual, remarks, well name, well number, well label, well name, lease, datum, td). Compiled from BOEM data and Geological Survey of Alabama/Alabama State Oil and Gas Board, with additional picks and refinements by Geological Survey of Alabama Energy Investigations Program staff. 

This material is based upon work supported by the U.S. Department of Energy National Energy Technology Laboratory (DE-FE0026086). Cost share and research support are provided by the Project Partners and an Advisory Committee.

Tags: Cenozoic Tops, SOSRA, gulf of mexico, offshore wells
Enhanced Analytical Simulation Tool (EASiTool) for CO2 Storage Capacity Estimation

An analytical-based Enhanced Analytical Simulation Tool (EASiTool) has been developed for technical and non-technical users with minimum engineering knowledge. The purpose of EASiTool is to produce a fast, reliable estimate of storage capacity for any geological formation. EASiTool includes closed-form analytical solutions that can be used as a first step for screening of geological formations to determine which formation can best accommodate storage needs over given period of time.

Tags: analytical model, capacity estimation, co2 storage, saline aquifer
Bell Creek Near-Surface MVA - Water Sampling Locations

 The water shapefile contains water sampling locations that were part of PCOR Partnership near-surface monitoring, verification, and accounting (MVA) activities in the Bell Creek oil field. Sample locations were categorized based on the type of water being collected (e.g., surface water, livestock well, domestic well, etc.). Identifiers were project-specific.  

Tags: Bell Creek, MVA, PCOR, Phase III, sampling, water
shale pore

This data set meets the  FAIR data standards required for a  public domain repository or general repository.

1.	These data are freely available for exploratory analysis
2.	  If the PI makes a significant intellectual contribution to the research, or if the data are essential to the work, or if an important result or conclusion depends on the data, co−authorship would normally be expected. This should be discussed at an early stage in the work.
3.	Manuscripts using the data should be sent to the coauthors for review well before (e.g. 4 weeks) they are submitted for publication, to ensure that the quality and limitations of the data are accurately represented and the coauthors have adequate time to provide input.





Tags: shale
Geochemical Modelling of Acid Gas Injection with Reference to the Zama 08-33-115-6W6 Well

This report details the probable chemical interactions that will occur between the injected
acid gas and the host mineralogy. As well, results of physical and chemical modelling of
the gas flow are presented. Descriptions of the data required for this analysis and the tools
required to evaluate and process this data are given. The modelling consists of four steps.
Initially the mineralogical composition of the reservoir is determined. Secondly, analyses of
fluids recovered from the reservoir, or other similar local geological structures were
obtained and culled based on geochemical considerations. These results integrated to
simulate the gas uptake and solution changes associated with fluid/mineral reactions. These
results offer insights into the trapping reactions of the acid gas components with time,
which were used to define input parameters for the commercial reservoir simulator, GEM®
(Computer Modelling Group, Calgary). GEM was used to estimate the spread and
compositional changes to the gas composition in the reservoir as the acid gas plume spreads
following injection.

Tags: CO2, EOR, Keg River Formation, Zama, acid gas, field, oil
Zama Acid Gas EOR, CO2 Sequestration, and Monitoring Project

Since October 2005, the Zama oil field in northwestern Alberta, Canada, has been the site of acid gas (approximately 80% CO2 and 20 H2S) injection for the simultaneous purpose of enhanced oil recovery (EOR), H2S disposal, and sequestration of CO2. Beginning in December 2006 and continuing through the present, injection has taken place at a depth of 1494 meters into one of over 800 pinnacle reef structures that have been identified in the Zama Subbasin. To date, over 36,000 metric tons of acid gas has been injected, resulting in incremental oil production over 25,000 barrels. Cost-effective monitoring at EOR sites that utilize H2S-rich acid gas as the sweep mechanism has been the overall goal of the project. The primary issues that have been addressed include (1) cap rock leakage, (2) long-term prediction of injectate, and (3) generation of data sets that will support the development and monetization of carbon credits. To address these issues, activities have been conducted at multiple scales of investigation in an effort to fully understand the ultimate implications of injection. Geological, geomechanical, geochemical, and engineering work has been used to fully describe the injection zone and adjacent strata in an effort to prove the long-term storage potential of this site. Through these activities, confidence in the ability of the Zama oil field to provide long-term containment of injected gas has been achieved. Results obtained from these activities can be applied not only to additional pinnacles in the Alberta Basin but to similar structures throughout the world.

Tags: CO2, EOR, MVA, PCOR, Phase II, Zama Field, acid gas, geology, geomechanics
Soils of the Fort Nelson Area of British Columbia

The soils of the Fort Nelson area (94J NE), in the plains region of northeastern British Columbia (Fig. 1), were surveyed during July and August 1967. A preliminary report of the soils along the Alaska Highway and the major navigable rivers
had been made by Leahey (5). The whole area lies within the Fort Nelson Lowland (4), which is a gently undulating plain dissected by three major rivers, the Muskwa, Prophet, and Fort Nelson. Access is afforded by the Alaska Highway, the roads to the Clarke Lake natural gas fields, and a number of short side roads. Most of the area, however, is inaccessible to a normal wheeled vehicle in summer because of the extensive sections of organic terrain and the steep-sided river valleys. A helicopter
was used for 4 days to map this portion. The soils of the alluvial terraces from Fort Nelson downstream to the Indian Village of Snake River were inspected by boat. Fig. 2 shows the portion mapped from the roads and the river and also that mapped, in much less detail, by helicopter traverse and air photo interpretation. The first part of the report describes the environment, including climate, vegetation, and physiography. The second part describes the soils and the land types in the context of physiographic regions called terrain systems. The third part includes interpretative sections for agriculture, forestry, wildlife, and recreation. The colors and symbols on the soil map show the distribution of the individual soils. The report and map ace complementary and both should be used to gain information about the soils.

Tags: Fort Nelson, PCOR, Phase II
Reservoir Condition Drainage and Imbibition Permeability Displacement Characteristics of Supercritical CO2

Hycal Energy
Research Laboratories Ltd. (Hycal) conducted a series of reservoir characterization and core
displacement tests on a sample of intergranular Sulphur Point formation core material taken from
well 08-13-116-06 W6M (1370.10 m interval) in the Zama field in northwestern Alberta. The
objective of the program was to determine the reservoir condition drainage (water saturation
decreasing) and imbibition (water saturation increasing) relative permeability displacement
characteristics for carbon dioxide and formation brine for the Sulphur Point carbonate formation.

Tags: CO2, PCOR, Phase II, Sulphur Point Formation, Zama, permeability, reservoir
Regional-Scale Geology and Hydrogeology of Acid-Gas Enhanced Oil Recovery in the Zama Oil Field in Northwestern Alberta, Canada

The Plains CO2 Reduction (PCOR) Partnership, covering nine U.S. states in the northern Plains and
the three Prairie provinces in Canada, is conducting a research program of assessing the technical and
economic feasibility of capturing and storing (sequestering) CO2 emissions from stationary sources
in the central interior of North America. The four-year Phase II program, currently run by the PCOR
Partnership, aims to demonstrate the efficacy of CO2 sequestration in a variety of subsurface and
terrestrial settings at four sites, among them being the acid-gas enhanced oil recovery (EOR) project run
by Apache Canada Ltd. in the Zama oil field in northwestern Alberta. Alberta Environment, Alberta
Energy and Utilities Board (EUB) and Natural Resources Canada (NRCan) are members of PCOR and
participate in the research program conducted at the Zama Acid-Gas EOR Project. This report represents
a contribution to the research program and presents the regional-scale geology and hydrogeology of the
Zama sub-basin that provide the context of site-scale project activities and findings.

Tags: EOR, PCOR, Phase II, Zama, acid gas, geology, hydrogeology
Rare-Earth-With-date-ID-All-samples-to-date-updated-for-posting-tjt-11-2019

NETL R&IC (Research and Innovation Center (formerly ORD - Office of Research and Development) has developed a data base with REE field sample inventory and analytical characterization results for coal and related by-product materials collected from different coal regions, in various stages of the process, and at various locations. The focus of this study is to characterize the bulk elemental concentration and mineralogy of rare earth elements in all coals and coal by-product material including: mineral matter associated with coal, fly ash, bottom ash, and post-processing/post-use materials among others.

Tags: NETL, REE, RIC
Reservoir Condition CO2-Brine Drainage and Imbibition Relative Permeability Displacement Characteristics in the Zama Area, Muskeg Anhydrite Formation (Caprock)

Report on Reservoir Condition CO2-Brine Drainage and Imbibition Relative Permeability Displacement Characteristics in the Zama Area, Muskeg Anhydrite Formation (Caprock)

Tags: CO2, Muskeg Anhydrite Formation, PCOR, Phase II, Zama Field, acid gas, brine, drainage, reservoir
Permeability and Relative Permeability Measurements at Reservoir Conditions for CO2-Water Systems in Ultra Low Permeability Confining Caprocks

Carbon dioxide has been successfully used in more than 80 enhanced oil recovery (EOR) operations in North America, and the number of such operations may increase significantly around the world if CO2 becomes available at reasonable costs. On the other hand, geological storage in deep saline aquifers and hydrocarbon reservoirs of large amounts of CO2, captured from large stationary sources is one method that is under consideration for reducing greenhouse gas emissions into the atmosphere on a worldwide basis. In both cases of CO2-EOR and CO2 capture and geological storage (CCGS), the containment of CO2 within the injection unit and leakage avoidance are essential. Effective CO2 containment is achieved by the overlying tight caprock that is initially highly saturated with formation brine, which prevents CO2 migration into uphole intervals and potentially into shallow freshwater aquifers and ultimately to the atmosphere. The confining properties of the caprock are due to its very low permeability and to relative permeability and capillary pressure effects that prevent the penetration of CO2 into, and significant flow through the caprock. Essential to the assessment of CO2-EOR and CCGS operations, including numerical simulation, is knowledge about the caprock permeability to brine and CO2. This paper presents results of detailed measurements at full reservoir conditions for permeability to water, primary drainage and secondary imbibition permeability, relative permeability and trapped saturation of supercritical, dense-phase CO2 and brine for three different, regionally-extensive low permeability formations in the Alberta basin, Canada. These formations include Devonian and Cretaceous shales and a Devonian anhydrite whose measured relative permeabilities were found to be in the nano to pico Darcy range. The methodology used in the test program and the results can be extended to the evaluation of other sealing caprocks for other prospective CO2-EOR or CCGS operations around the world. 

(PDF) Permeability and Relative Permeability Measurements at Reservoir Conditions for CO2-Water Systems in Ultra Low Permeability Confining Caprocks. Available from: https://www.researchgate.net/publication/254526441_Permeability_and_Relative_Permeability_Measurements_at_Reservoir_Conditions_for_CO2-Water_Systems_in_Ultra_Low_Permeability_Confining_Caprocks [accessed Sep 25 2018].

Tags: CO2, caprock, permeability
Investigation of Poroelastic Effects on In-Situ Stresses and Concomitant Effects on Seal Integrity: Comparison of Analytical and Numerical Models

The primary objective of this project is to apply a number of geomechanical modelling tools to a
specific poroelastic problem (fluid withdrawal and subsequent injection into a pinnacle reef), and
to assess the strengths and weaknesses of these modelling tools. A secondary objective is to use
the modelling results to assess: (i) the critical pore pressures at which the reservoir’s seal could
be compromised, for the specific pinnacle reef problem being analysed; and (ii) the locations and
types of rock failure processes that would negatively impact the seal’s integrity if these critical
pressures were exceeded.

Tags: PCOR, Phase II, Zama, pinnacle reef, pore pressure, poroelastic
Fort Nelson Cap Rock Petrographic Analysis - July 2011

The EERC, through the Plains CO2 Reduction (PCOR) Partnership is working with Spectra Energy Transmission to investigate the feasibility of a carbon capture and storage project to mitigate carbon dioxide emissions produced by SET's Fort Nelson Gas Plant. This report summarizes the Fort Nelson cap rock petrographic analysis from July 2011.

Tags: Fort Nelson, PCOR, Phase II, cap rock, petrographic analysis
Experimental Study of CO2 and H2S Partitioning in a Brine-Saturated Porous Medium

The goal of work reported here was to assess the potential for early detection of acid gas
in case of leakage into overlying aquifers at Zama. Breakthroughs of acid gas at
producing wells at other acid gas disposal sites in Alberta indicated that CO2 will arrive
first at a producing well, ahead of H2S, although the two gases are injected together.
From a monitoring point of view, the implication is that the earlier arrival of CO2, even if
not accompanied by H2S, should signal leakage of acid gas from the storage reservoir.
Accordingly, an experimental program was set up under contract at Hycal Energy
Research Laboratories Ltd. in Calgary to test the hypothesis that the partitioning of the
two gases and different arrival time at the producing well are due to different solubility of
the two gases in water.

Tags: CCS, CO2, PCOR, Phase II, Zama, acid gas, detection
HFTS-1 Phase 1  Environmental Monitoring

This folder contains results of air and water monitoring before, during,  and after hydraulic fracturing.  Nearby water wells were used to collect water and assess quality before, during and after hydraulic fracturing.  Air sampling stations were deployed up-wind and down-wind of the test site to collect air samples and determine air quality.  Folder contains data and results.

Tags: Environmental Monitoring, Water Well, air Monitoring, water Monitoring
SECARB Project Overview Book

In 2003, the United States Department of Energy (DOE) issued awards initiating seven Regional Carbon Sequestration Partnerships (RCSP) spanning the United States and portions of Canada. Managed by DOE’s National Energy Technology Laboratory (NETL), the RCSPs currently represent more than 400 state agencies, universities, and private companies, spanning 43 states, three Native American Organizations, and four Canadian provinces. The Southern States Energy Board (SSEB) received an award on October 1, 2003, which established the Board’s overall management and administration of the Southeast Regional Carbon Sequestration Partnership, or SECARB. The geographical region currently includes 13 states and a network of more than 100 stakeholders. The Nation’s leading scientists, university researchers, national laboratories, industrial representatives, environmental organizations, and many others have taken a proactive approach at identifying and characterizing the most promising options for technology deployment and carbon dioxide (CO2) utilization and storage (CCUS) for the Southeast. The results obtained during these injections will be important to the future commercialization of CCUS technologies and the continued use of fossil fuels as a significant energy source in a manner that is environmentally responsible.

Each of the six SECARB project locations has been locally coordinated by its own field team. The field teams assume responsibility for the technical scope of work, local education and outreach, permitting, monitoring, verification, and accounting (MVA), and maintaining the validation test’s schedule and budget. Each team contributes new information to the continued characterization of the region. In addition, a task is dedicated to integrating field data and filling gaps in regional characterization data sets. Data and tools developed in the Continued Characterization task are incorporated into a relational database and geographic information system (GIS).

All field tests, the continued characterization project, and the cross-cutting functions are designed to support the DOE roadmap by validating technologies and identifying locations throughout the region that could support full-scale CCUS deployment opportunities. Detailed fact sheets for the SECARB projects are available on the SECARB website at www.secarbon.org (see “Projects” tab).


Tags: RCSP, SECARB, southeast regional carbon sequestration partnership
Bell Creek 2014 Monitoring Survey Clipped Down to 2015 Monitoring Survey

 Seismic monitoring survey at Bell Creek 2014 clipped down to the 2015 monitoring survey. 

The raster layers represent a map of the RMS amplitude slice between the horizons Springen Ranch and the Skull Creek (Muddy Formation) enclosing the Bell Creek sand reservoir at the Bell Creek oil field. This gridded dataset was interpolated within ArcGIS based upon seismic amplitude values measured across the study area. 

Monitor2014 contains 3 rasters:
-ClpMon2014 is the monitoring survey.
-Clp2014ovr15 is the 2014 monitor survey clipped down to where it overlaps the 2015 monitor survey.
-ClpDiff1412 is the RMS amplitude difference between the monitor 2014 and baseline 2012 survey.

Additional information regarding this data and interpretations can be found in the following document:
Salako, O., Livers., A.J., Burnison, S.A., Hamling, J.A., Wildgust, N., Gorecki, C.D., Glazewski, K.A., and Heebink, L.V., 2017, Analysis of Expanded Seismic Campaign: Plains CO2 Reduction (PCOR) Partnership Phase III draft Task 9 Deliverable D104 for U.S. Department of Energy National Energy Technology Laboratory Cooperative Agreement No. DE-FC26-05NT42592, Grand Forks, North Dakota, Energy & Environmental Research Center, June.


Tags: Bell Creek, GIS, PCOR, Phase III, seismic
Bell Creek 2015 Monitoring Seismic Survey - RMS amplitude difference between the monitor 2015 and baseline 2012 surveys

 2015 Monitoring Seismic Survey at Bell Creek

The raster layers represent a map of the RMS amplitude slice between the horizons Springen Ranch and the Skull Creek (Muddy Formation) enclosing the Bell Creek sand reservoir at the Bell Creek oil field. This gridded dataset was interpolated within ArcGIS based upon seismic amplitude values measured across the study area. 

Additional information regarding this data and interpretations can be found in the following document:
Salako, O., Livers., A.J., Burnison, S.A., Hamling, J.A., Wildgust, N., Gorecki, C.D., Glazewski, K.A., and Heebink, L.V., 2017, Analysis of Expanded Seismic Campaign: Plains CO2 Reduction (PCOR) Partnership Phase III draft Task 9 Deliverable D104 for U.S. Department of Energy National Energy Technology Laboratory Cooperative Agreement No. DE-FC26-05NT42592, Grand Forks, North Dakota, Energy & Environmental Research Center, June.

Monitor2015 contains 4 rasters:
Clp2015ovr12 is the 2015 monitor survey clipped down to where it overlaps the 2012 baseline survey.
Clp2015ovr14 is the 2015 monitor survey clipped down to where it overlaps the 2014 monitor survey.
Clpdiff1512 is the RMS amplitude difference between the monitor 2015 and baseline 2012 survey.
Clpdiff1514 is the RMS amplitude difference between the monitor 2015 and monitor 2014 survey.


Tags: Bell Creek, PCOR, Phase III, amplitude, seismic