Rose Run Research Articles

Reservoir properties and CO2 storage capacity of the Rose Run Sandstone (Lower Ordovician, Knox Group) in the Central Appalachian Basin, northeast Kentucky

The Lower Ordovician Rose Run Sandstone is a potential CO2storage reservoir in the Central Appalachian Basin in northeast Kentucky where the Kentucky Geological Survey’s 1 Hanson Aggregates research well penetrated it at drill depths of 1,000–1,009.5 m. Average Rose Run porosity and permeability from core plugs are 9.1% and 44.6 mD, respectively.In situreservoir properties were determined by step-rate testing an 18.6-m interval bracketing the Rose Run. Pressure derivative analysis of wellbore falloff pressure suggests that the Rose Run shares properties of both dual-porosity and dual-permeability reservoirs, consistent with its mixed lithologies. The Rose Run pore pressure was 9.3 MPa/km, 1.1 MPa/km underpressured compared to the expected hydrostatic gradient of 10.4 MPa/km. Average porosity of the Rose Run, at the industry-standard 7% porosity cutoff for assessing CO2storage capacity, calculated from 27 wells in the surrounding region, was 11.6% and the average net reservoir thickness was 6.2 m. Geomechanical properties of the overlying Beekmantown Dolomite show that it would act as a reservoir confining interval during CO2injection. The estimated P50supercritical CO2storage volume is 77.2 kt/km2, yielding P50storage capacity of 165.7 Mt in the region. By itself, an average surface area of 12.9 km2would be required to store 1 Mt of supercritical CO2in the Rose Run, thus lacking the volume to act as a stand-alone CO2storage reservoir in this area. It could contribute to a stacked-reservoir storage project developed in the larger Knox section, however. CO2–brine relative permeability tests suggest that nearly half of any supercritical CO2injected into the Rose Run would be residually trapped, and another portion would be trapped by mineral precipitation. The Rose Run in the KGS 1 Hanson Aggregates well is very close to the subsurface CO2critical depth in the northeast Kentucky region and lacks an updip reservoir trap. How far and fast the mobile CO2migration might occur at this site remains for future research and reservoir modeling.

Geomechanical properties will constrain CO2 injection into the lower Ordovician Rose Run sandstone deep saline reservoir, Appalachian Basin, Kentucky, USA

The Kentucky Geological Survey (KGS) 1 Hanson Aggregates stratigraphic research well, Carter County, Kentucky, USA, was drilled to a total depth of 1474 m as a field-scale test of potential CO 2 storage reservoir properties in the Central Appalachian Basin. Geomechanical properties of the Rose Run sandstone (upper Ordovician Knox group) were tested for its suitability as a storage reservoir. A 9.8-m thick section of the Rose Run was penetrated at 1000 m drilled depth and a whole-diameter core and rotary sidewall cores were taken. Average porosity and permeability measured in core plugs were 9.1% and 44.6 mD, respectively. Maximum vertical stress gradient calculated in the wellbore was 26 MPa/km. Wellbore fractures in dolomites underlying and overlying the Rose Run follow the contemporary N53°E Appalachian Basin stress field. The Rose Run elastic geomechanical properties were calibrated to values measured in core plugs to evaluate its fracturing risk as a CO 2 storage reservoir. Mean Young's modulus and Poisson's ratio values of the Rose Run were 45 GPa and 0.23, respectively, whereas Young's modulus and Poisson's ratio values were 77.1 GPa and 0.28, respectively, in the overlying Beekmantown dolomite, suggesting the Rose Run may fracture if overpressured during CO 2 injection but be confined by the Beekmantown. Triaxial compressive strength measured in core plugs found the Rose Run and Beekmantown fractured at mean axial stresses of 156.5 MPa and 282.2 MPa, respectively, confirming the Beekmantown as suitable for confining CO 2 injected into the Rose Run. A step-rate test was conducted in a mechanically-isolated 18.6-m interval bracketing the Rose Run. Static Rose Run reservoir pressure was 9.3 MPa, and fracture gradient under injection was 13.6 MPa/km, suggesting step-rate testing before CO 2 injection, and subsequent pressure monitoring to ensure confinement. As the region around the KGS 1 Hanson Aggregates well is underpressured and adjacent to faulted Precambrian basement, further research is needed to evaluate its induced seismicity risk during CO 2 injection.

Comparative analysis of transport and storage options from a CO2 source perspective

This study evaluated integrated CCS costs from the perspective of a CO2 source. A source will have captured CO2 requiring suitable storage and affordable transportation between source and storage. Capture, transport, and storage are the links of the CCS value chain. For this study, capture costs were modeled for six hypothetical sources (various industrial and power-generation facilities) with annual CO2 capture rates ranging from 0.65 to 3.90 million tonnes (Mt). Seven storage reservoirs located in the Appalachian, Illinois and Gulf Coast Basins—and of various quality with respect to CO2 storage—were modeled: two within the Rose Run Formation, three within the Mount (Mt.) Simon Formation, one in the Lower Tuscaloosa Formation, and one in the Frio Formation. Storage costs were calculated with the FE/NETL CO2 Saline Storage Cost Model for the seven selected storage reservoirs under dome and regional dip structural settings. For transportation, a dedicated pipeline system and a trunkline pipeline system were modeled. Transportation costs from source to storage reservoirs were evaluated using the FE/NETL CO2 Transport Cost Model. A source may not always be able to find suitable proximal storage. Low CCS costs reflect a source’s mass of captured CO2 finding suitable storage within an affordable transportation distance. Economies of scale are present in each link of the CCS value chain. These economies of scale are limited with respect to storage or the distance captured CO2 can be transported to storage.

Modeling CO2plume migration based on calibration of injection and post-injection pressure response at the AEP Mountaineer Project

Supercritical CO2 injection was carried out at the AEP Mountaineer CO2 Capture and Geological Storage Project from October 2009 until May 2011. Approximately 27 000 MT and 10 000 MT were injected into the Copper Ridge dolomite formation and Rose Run sandstone formation, respectively. A 2-D radial-cylindrical model based on ‘average’ conditions in the study area was developed from integration of well-log data. STOMP-CO2 simulations were carried out to calibrate the observed pressure response using a trial-and-error procedure. This involved varying: (i) permeability near the injection well, (ii) permeability of the far-field region, and (iii) relative permeability model coefficients. Non-unique combinations of these parameters were found to produce similar pressure matches, but different estimates of plume migration. For the Ridge formation, excellent matches were obtained for the injection pressure/rate data at AEP-1 and observed pressures at MW-2, located ∼2200 feet away. Estimates of radial plume migration range between 925 and 975 ft. For the Rose Run formation, excellent matches were obtained for the injection pressure data at AEP-2 and observed pressure at MW-3, ∼125 feet away, although the match with MW-1, located ∼2200 feet away, was less satisfactory. Estimates of radial plume migration range between 460 and 510 ft. The modeling approach and results presented here represent a significant and unique case study of post-injection modeling at CO2 storage locations – a critical aspect for successful permit closure in accordance with the EPA requirements.

Which Reservoir for Low Cost Capture, Transportation, and Storage?

Abstract Quality and location of a carbon dioxide (CO 2 ) storage reservoir are critical for low cost carbon capture and storage (CCS). This analysis models the combination of capture, transportation, and storage costs to estimate a total cost of CCS. Cost of capture at the source is available for annual rates between 4.1 and 0.7 million tonnes of CO 2 . Cost of transportation is modeled for the distance between the source and the storage reservoir. Cost of CO 2 storage is modeled for four representative reservoirs, two Rose Run and two Mt Simon reservoirs, each reservoir in a dome or regional dip structural setting.

Effect of hydraulic fracturing on long-term storage of CO2 in stimulated saline aquifers

Stimulation techniques, primarily as hydraulic fracturing, can contribute to improve practical storage capacity of low-permeable saline aquifers by increasing injectivity. Since the shape of the CO2 plume in the injection period can affect its subsequent migration, impact of hydraulic fracturing on post-injection plume migration should be investigated to assess CO2 long-term trapping in stimulated saline aquifers. Compositional reservoir simulation results, based on a case study of Rose Run sandstone aquifer in Ohio River Valley, show the important role of methods for increasing near wellbore injectivity on CO2 plume dynamics. Significant tradeoff between enhancing injectivity and long-term trapping of carbon dioxide in hydraulically fractured saline aquifers in normal faulting regime is proven by analysis of parameters controlling CO2 storage in saline aquifers such as gravity number. In addition, we discuss effects of the aquifer stress regime, fracture properties, and injection of water on immobilization of CO2 by residual and solubility trapping inside the stimulated saline aquifers. Finally, we show that non-Darcy flow effects inside the fracture could reduce injectivity of the stimulated saline aquifer by causing additional pressure drop inside the fracture.

A coupled geomechanical reservoir simulation analysis of carbon dioxide storage in a saline aquifer in the Ohio River Valley

With almost 200 coal-burning power plants in the region, the Ohio River Valley is an important region to evaluate potential formations for carbon dioxide (CO2) storage. In this study, we consider whether injection-induced stress changes affect the viability of the Rose Run Sandstone, considered as a potential effective storage unit. Our study uses a coupled geomechanical and reservoir simulator that couples fluid flow to induced stress and strain in all the significant stratigraphic units from the surface to the crystalline basement. The pressure and stress variations were modeled during CO2 injection, focusing on injection from a single well. The model uses a constant pressure condition on the boundary of the system. Both reservoir and surface deformation were simulated, and the possibility of reaching shear failure in the reservoir was tested. Carbon dioxide injection in the Rose Run Sandstone aquifer is not likely to cause any significant surface deformation. To consider the potential of increasing injectivity, simulation of a static fracture with a half-length of 300 m (984.3 ft) was considered. As the modeling shows that, with constant injection rate, the fracture can propagate beyond the propped length, a dynamic fracture propagation was also studied. This was achieved by allowing the fracture to grow as a function of a propagation criteria based on effective stress. Because of the favorable stress state of the Rose Run Sandstone, the propagation is primarily in the lateral direction, and no upward fracture propagation through the cap rock has been observed in the model. Finally, we demonstrate that dynamic fracture propagation significantly increases the possible injection rates, and its modeling is useful for determining optimal injection rates.

Reactive transport modeling of CO2 and SO2 injection into deep saline formations and their effect on the hydraulic properties of host rocks

Abstract Injection of supercritical carbon dioxide (CO 2 ) into formations containing carbonate minerals may affect the porosity and permeability of the host rock and overlying caprock due to dissolution of the primary carbonate minerals and possible precipitation of secondary minerals. Simulations of pilot-scale CO 2 injection with co-sequestration of sulfur dioxide (SO 2 ) were conducted to assess the competing effects of dolomite dissolution and anhydrite precipitation on formation hydraulic properties. A geochemical model of two promising host formations in the midwestern United States (Rose Run and Copper Ridge) was developed for the purpose of assessing mineral dissolution and precipitation effects on injectivity and containment.

Assessing the economic feasibility of regional deep saline aquifer CO 2 injection and storage: A geomechanics-based workflow applied to the Rose Run sandstone in Eastern Ohio, USA

Typical top-down regional assessments of CO 2 storage feasibility are sufficient for determining the maximum volumetric capacity of deep saline aquifers. However, they do not reflect the regional economic feasibility of storage. This is controlled, in part, by the number and type of injection wells that are necessary to achieve regional CO 2 storage goals. In contrast, the geomechanics-based assessment workflow that we present in this paper follows a bottom-up approach for evaluating regional deep saline aquifer CO 2 storage feasibility. The CO 2 storage capacity of an aquifer is a function of its porous volume as well as its CO 2 injectivity. For a saline aquifer to be considered feasible in this assessment it must be able to store a specified amount of CO 2 at a reasonable cost per ton of CO 2. The proposed assessment workflow has seven steps that include (1) defining the storage project and goals, (2) characterizing the geology and developing a geomechanical model of the aquifer, (3) constructing 3D aquifer models, (4) simulating CO 2 injection, (5,6) evaluating CO 2 injection and storage feasibility (with and without injection well stimulation), and (7) determining whether it is economically feasible to proceed with the storage project. The workflow was applied to a case study of the Rose Run sandstone aquifer in the Eastern Ohio River Valley, USA. We found that it is feasible in this region to inject 113 Mt CO 2/year for 30 years at an associated well cost of less than US $1.31/t CO 2, but only if injectivity enhancement techniques such as hydraulic fracturing and injection induced micro-seismicity are implemented.

Geomechanical aspects of CO2 sequestration in a deep saline reservoir in the Ohio River Valley region

The Ohio River Valley CO2 Storage Project is an ongoing characterization of deep saline formations being considered as potential sites for geological CO2 sequestration. We completed a geomechanical analysis of the Rose Run Sandstone, a potential injection zone, and its adjacent formations at the American Electric Power's 1.3-GW Mountaineer Power Plant in New Haven, West Virginia. The results of this analysis were then applied to three investigations used to evaluate the feasibility of anthropogenic CO2 sequestration in the potential injection zone. First, we incorporated the results of the geomechanical analysis with a geostatistical aquifer model in CO2 injection-flow simulations to test the effects of introducing a hydraulic fracture to increase injectivity. We observed a nearly fourfold increase of injection rate caused by the introduction of a hydraulic fracture in the injection zone. The flow simulations predict that a single vertical well with a hydraulic fracture could inject a maximum of 300–400 kt of CO2/yr. In the second investigation, we determined that horizontal injection wells at the Mountaineer site are feasible because the high rock strength ensures that such wells would be stable in the local stress state. The third investigation used the geomechanical analysis results to evaluate the potential for injection-induced seismicity. If preexisting, but undetected, nearly vertical faults striking north-northeast or east-northeast are present, the increased pore pressure from CO2 injection would raise their reactivation potential. Geomechanical analysis of potential CO2 sequestration sites provides critical information required to evaluate its sequestration potential and associated risks.

Computer simulation of CO 2 trapped through mineral precipitation in the Rose Run Sandstone, Ohio

Equilibrium, path-of-reaction and kinetic modeling of CO 2–brine–mineral reactions in the Rose Run Sandstone, one of Ohio’s deep saline aquifers, was conducted in order to investigate the factors that are likely to influence the capacity of this formation to trap injected CO 2 as solid carbonate mineral phases. Equilibrium modeling was applied to investigate the impact of temperature, pressure, mineralogy, brine composition, and CO 2 fugacity on mineral dissolution and precipitation, the amount of CO 2 sequestered, and the form of sequestration. Path of reaction and kinetic modeling were used to evaluate intermediate products and reaction progress as a function of time, as well as to investigate the impact of brine-to-rock ratio. The results of equilibrium modeling demonstrate that dissolution of albite, K-feldspar, and glauconite, and the precipitation of dawsonite and siderite are potentially very important for mineral trapping of CO 2. According to the path of reaction and kinetic modelling, the stability of carbonate rocks is controlled by the brine-to-rock ratio, the pH of the system, the fugacity of CO 2, and the kinetic rate of dissolution. In kinetic modeling, with a brine-to-rock ratio of 1:25, reactive surface area of 10 cm 2/g, 10 MPa f CO 2 , and 12% porosity (1.5–2 g of CO 2 per kg of reacted rock), significant quantities (10–40 g) of carbonate minerals were precipitated from both the sandstone and mixed rock assemblages. The Rose Run Sandstone has the potential to store CO 2 over millennia as a negatively buoyant aqueous solution and, ultimately, as immobile carbonate minerals.

Injection and trapping of carbon dioxide in deep saline aquifers

Abstract Carbon dioxide (CO 2 ) collected from the waste streams of point sources can be injected into deep geologic formations in order to limit the emission of greenhouse gases to the atmosphere. Deep saline aquifers provide the largest potential subsurface storage capacity for injected CO 2 . Once injected, free CO 2 can be retained in deep aquifers for long time periods by slow-moving, downward-directed formation waters. Over time, the injected CO 2 will dissolve in the formation waters and, through reactions with formation minerals, may be converted to carbonate minerals, resulting in permanent sequestration. Factors that influence the mass of CO 2 that can be injected and stored in free or aqueous form, and as mineral phases, are reviewed and applied to estimate storage capacity of the Rose Run Sandstone, a saline aquifer beneath eastern Ohio, USA. It is estimated that 30 years of CO 2 emissions from five of Ohio’s largest coal-fired power plants can be injected into the Rose Run Sandstone and, over time, converted to aqueous and, ultimately, mineral phases.

Cambrian-Ordovician Knox production in Ohio: Three case studies of structural-stratigraphic traps

The Knox Dolomite (Cambrian-Ordovician) in Ohio consists of a mixed carbonate-siliciclastic sequence deposited in a tidal-flat to shallow-marine environment along a broad continental shelf. Knox hydrocarbon production occurs in porous sandstone and dolomite reservoirs in the Copper Ridge dolomite, Rose Run sandstone, and Beekmantown dolomite. In Ohio, historical Knox exploration and development have been focused on paleogeomorphic traps within the prolific Morrow Consolidated field, and more recently, within and adjacent to the Rose Run subcrop. Although these paleogeomorphic traps have yielded significant Knox production, structural and stratigraphic traps are being largely ignored. Three Knox-producing pools demonstrate structural and stratigraphic traps: the Birmingham-Erie pool in southeastern Erie and southwestern Lorain counties, the South Canaan pool in northern Wayne County, and the East Randolph pool in south-central Portage County. Enhanced porosity and permeability from fractures, as evident in the East Randolph pool, are also an underexplored mechanism for Knox hydrocarbon accumulation. An estimated 800 bcf of gas from undiscovered Knox resources makes the Knox one of the most attractive plays in the Appalachian basin.

Abstract: Geologic Assessment of Core Data from the Stahl #1 and Correlation with the Rose Run of Ohio

Abstract: Geologic Assessment of Core Data from the Stahl #1 and Correlation with the Rose Run of Ohio

Reflection Configuration and Paleotopography of Rose Run Sandstone Remnants in Ohio : ABSTRACT

ABSTRACT A Rose Run sandstone remnant is easily identified with moderate quality seismic data, but more can be learned about the prospect and prospect area by examining the reflection configuration of the anomaly or anomalies. Rose Run seismic anomalies in the Rose Run subcrop fairway typically exhibit a low-angle dip slope (backside) and an escarpment face (frontside); whereas, Rose Run remnants (outliers) west of the subcrop fairway typically exhibit a symmetrical, even-sided reflection configuration. By examination of reflection configuration and form, geologic features such as escarpments, valleys and channels are identified from seismic profiles. Knox unconformity erosional patterns mimic regional NW-SE and NE-SW joint patterns and support geologic settings interpreted from seismic profiles. By combining details from seismic reflection configuration and the regional geologic setting interpreted from seismic mapping, the results provide a powerful tool to guide seismic and leasing programs.

Geology and Log Responses of the Rose Run Sandstone in Randolph Township, Portage County, Ohio: ABSTRACT

Approximately 75 wells have penetrated the Cambrian Rose Run sandstone in Randolph Township, Portage County, Ohio, about half of which should produce well beyond economic payout. Only one deep test (to the Rose Run or deeper) was drilled in this Township prior to 1990. Two separate and distinct Rose Run producing fields exist in the Township; the western field is predominately gas-productive and the east is predominantly oil-productive. Both fields are on the north side of the Akron-Suffield Fault Zone, which is part of a regional cross-strike structural discontinuity extending from the Pittsburgh, Pennsylvania area northwestward to Lake Erie. This feature exhibits control over Berea, Oriskany, Newburg, Clinton, and Rose Run production.

Improved Reservoir Characterization of the Rose Run Sandstone on the East Randolph Field, Portage County, Ohio: ABSTRACT

ABSTRACT The East Randolph Rose Run field is located in Randolph Township, Portage County, Ohio. The field was discovered in 1992 as a down dip extension of the Randolph Gas field discovered by Belden & Blake Corporation a year earlier. Since its discovery, over 40 wells have been drilled in the East Randolph field that have produced an estimated 600,000 barrels of oil and 1.5 billion cubic feet of gas. Characterization of the productive upper Rose Run sandstone members is underway to determine the technical and economic feasibility of water flooding, gas pressure maintenance, or the possibility of infill drilling for oil in the East Randolph field. Core data and log data for each sandstone member was analyzed and mapped to determine their relationship with estimated ultimate recovery of oil and gas. The upper Rose Run sandstone can be divided into four distinct sandstone units characterized by bedding, mineralogy and log character. Each of the four sandstone units usually represents a fining-upward cycle of sandstone, sandy dolomite and dolomite. The uppermost unit (#1) consists of tightly cemented sandstone with quartz overgrowths, low permeability and low porosity, while the lowermost sandstone unit (#3B) is usually the most permeable (1.5 - 12.9 md) and porous (2.6 - 11.2 percent). This variation in porosity and permeability is predominantly controlled by grain size, amount and type of intergranular cement, and extent of secondary dissolution porosity. Most of the East Randolph field's oil production can be attributed to the reservoir development of the Rose Run #3A and #3B units. Gas production appears to be present in all four units, but seems to be best when good reservoir development is found in the #1 and #2 sandstone intervals. Volumetric calculations using new geologic models increase estimates of the amount of original oil-in-place at over 10 million stock tank barrels, more than double the initial estimates. The new geologic model will be used as input for reservoir simulation to optimize future locations of infill wells, and determine waterflood and/or pressure maintenance feasibility.

Seismic Detection of the Rose Run in Southcentral Ohio: ABSTRACT

Seismic Detection of the Rose Run in Southcentral Ohio: ABSTRACT

Natural Gas Plays of the Knox Group in the Appalachian Basin: A Significant Element of the U.S. Department of Energy Atlas of Major Appalachian Gas Plays

Oil and gas have been produced from the Knox Group in the Appalachian basin since the early 1990s. However, only since the 1960s have significant volumes of hydrocarbons been produced. Porosity development along the Knox unconformity is the dominant geologic control for hydrocarbon migration and entrapment. Other important controls include stratigraphy, diagenesis, paleokarst, structure, and fractures. Cumulative production is ultimately, controlled by the reservoir conditions characteristic to each play. The two most significant Knox plays in terms of total cumulative gas production are (1) the Lower Ordovician-Upper Cambrian eroded shelf sandstones known as the Rose Run sandstone in Kentucky, Ohio, and Pennsylvania, and the Theresa sandstone in New York, and (2) the Lower Ordovician-Upper Cambrian paleokarstic carbonates known as the Beekmantown dolomite in Kentucky, Ohio, and Tennessee, and the Copper Ridge (Trempealeau) dolomite in Ohio. Minor volumes of gas have been produced from fracture and paleokarstic carbonate plays in the Know dolomite of Kentucky, Tennessee, and Virginia, and from localized sandstones of the Copper Ridge (Trempealeau) in Ohio. Some individual wells in Ohio have produced more than 1 billion ft[sup 3] of gas from the Beekmantown, Rose Run, or Copper Ridge (Trempealeau). Cumulative gas production from all the Knox playsmore » in the Appalachian basin has been in excess of 60 billion ft[sup 3] of gas. The Knox Group plays are currently the most active exploration targets in the basin.« less

Porosity Trends of the Lower Ordovician Rose Run Sandstone in Holmes, Tuscarawas, and Coshocton Counties, Ohio

Porosity Trends of the Lower Ordovician Rose Run Sandstone in Holmes, Tuscarawas, and Coshocton Counties, Ohio