Codell Sandstone, a Review of the Northern DJ Basin Oil Resource Play, Laramie County, Wyoming and Weld County, Colorado

Sterling, Robert; Bottjer, Richard; Smith, Kevin H.

doi:10.15530/urtec-2016-2461775

Cited by 5 publications

(4 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The effective porosity calculated in the Codell was originally calculated to be 16.7%, seen in log track one (blue) of Figure 3.38 at 7,800 ft, however, this is artificially high due to the neutron porosity log reading a high value caused by the gas effect (Nelson et al 1999). This was reduced manually to 12%, seen in log track one of Figure 3.40; a porosity consistent with porosities published in literature (Higley and Cox 2007;Sonnenberg 2015;Sterling et al 2016).…”

Section: Gamma Ray Calibration and Synthetic Gamma Ray Generationsupporting

confidence: 85%

“…Figures 3.27 and 3.28, respectively. This is consistent with literature of reservoir pressure found in the DJ Basin where pressure gradients range from 0.45 psi/ft to 0.66 psi/ft in the Niobrara and Codell depending on depths(Sonnenberg 2016;Sterling et al 2016).…”

supporting

confidence: 93%

“…In 2010, the field produced an estimated 216.2 billion cubic feet (BCF) of gas and 18.6 million barrels of oil (MMBO) from approximately 18,000 active wells ranging in total vertical depth (TVD) from 6200 ft to 7800 ft. (Moritz and Barron 2012). Drilling activity within the DJ basin has continued to increase since 2010, production has increased from 192,000 BOEPD in 2010 to over 480,000 barrels of oil equivalent per day (BOEPD) in early 2016 (Sterling et al 2016). Figure 1.2 depicts the distribution of oil and gas wells, marked yellow and red respectively, in the DJ basin as well as associated fields labeled in white.…”

Section: Denver-julesburg Basin and Wattenberg Field Overviewmentioning

confidence: 99%

“…The porosity and the permeability in the Niobrara in the field are less than 10 percent and less than 0.1 md, respectively. The Codell sandstone, depicted in the stratigraphic column in Figure 1.6, is uncomformably overlain by the Niobrara formation and is an impermeable, bioturbated, very fine to fine grained marine shelf sandstone with a clay content from 15 to 25 percent including smectite, illite, chorite, and trace amounts of kaolinite (Sterling et al 2016). The Codell thins from a wedge-edge of 20 feet to 5 feet, from west to east, due to erosional truncation (Sonnenberg 2015).…”

Section: Stratigraphymentioning

confidence: 99%

See 3 more Smart Citations

Workflow Development and Sensitivity Investigation of Offset Well-to-Well Interference Through 3-D Fracture Modeling and Reservoir Simulation in the Denver-Julesburg Basin

Levon¹,

Miskimins²

2019

Proceedings of the 7th Unconventional Resources Technology Conference

View full text Add to dashboard Cite

The objective of this research was to construct a calibrated multi-well 3D fracture model to evaluate well-to-well interference, also known as well "bashing", in the Niobrara and Codell formations of the Denver-Julesburg (DJ) Basin. Hydraulic fracturing is a vital component to produce in unconventional resource plays economically. In the early stages of development in all unconventional resource plays, including the DJ Basin, single well pads were common for either exploratory drilling or lease retention. Initially many shale plays across the world were not fully developed and in order to capture the resources originally left behind, infill drilling is taking place to access additional resources to create a greater effective stimulated rock volume (SRV) and achieve better recovery. Unfortunately, many previously drilled, producing "parent" wells and newly drilled "child" wells are actually yielding a reduction in recovery rates in short and long-term cases due to interference. Research has shown that one of the main contributors to the variability in production is the presence of pressure depletion from production around the parent wells and the impacts it has on subsequent child well completions. As a means of examining well-to-well interference, the focal point of this study was a nine well pad consisting of six wells in the Niobrara and three wells in the Codell. This pad showed evidence of interference measured using bottom hole gauges installed in the two "parent" wells, one in each formation, during the stimulation of the child wells. Oil and water flowback tracers utilized during the treatment of the child wells also supported the presence of communication. A multi-well, multi-stage (total of 500 stages) 3D hydraulic fracture model was developed using offset vertical well logs and geologic interpretation of mud logs to define the variation in rock properties that best represent the reservoir in which these wells were drilled. vi TABLE OF CONTENTS

show abstract

Section: Gamma Ray Calibration and Synthetic Gamma Ray Generationsupporting

confidence: 85%

supporting

confidence: 93%

Section: Denver-julesburg Basin and Wattenberg Field Overviewmentioning

confidence: 99%

Section: Stratigraphymentioning

confidence: 99%

See 2 more Smart Citations

Workflow Development and Sensitivity Investigation of Offset Well-to-Well Interference Through 3-D Fracture Modeling and Reservoir Simulation in the Denver-Julesburg Basin

Levon¹,

Miskimins²

2019

Proceedings of the 7th Unconventional Resources Technology Conference

View full text Add to dashboard Cite

show abstract

Integration of Dual-Porosity Modeling with 4D Seismic and Microseismic Technology in Niobrara and Codell Formations, DJ Basin

Ning

Kazemi

Davis

2018

SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

This paper presents construction and validation of a reservoir model for the Niobrara and Codell Formations in Wattenberg Field of the Denver-Julesburg Basin. Characterization of Niobrara-Codell system is challenging because of the geologic complexity resulting from the presence of numerous faults. Because of extensive reservoir stimulation via multi-stage hydraulic fracturing, a dual-porosity model was adopted to represent the various reservoir complexities using data from geology, geophysics, petrophysics, well completion and production. After successful history matching two-and-half years of reservoir performance, the localized presence of high intensity macrofractures and resulting evolution of gas saturation was correlated with the time-lapse seismic and microseismic interpretations. The agreement between the evolved free gas saturation in the fracture system and the seismic anomalies and microseismic events pointed to the viability of the dual-porosity modeling as a tool for forecasting and future reservoir development, such as re-stimulation, infill drilling, and enhanced oil recovery strategies.

show abstract

Critical Diagenetic Features Controlling Intergranular Flow Paths and Matrix Permeability in the Codell Sandstone, Northeastern Colorado

Medina

Budd

2020

MT GEOL

View full text Add to dashboard Cite

The Codell Sandstone is a hydrocarbon-bearing, tight sand (permeability <0.1 mD) that is an active target for unconventional hydrocarbon production in the Denver-Julesburg Basin. In northeastern Colorado, the intergranular microporous drainage network within this clay-rich sandstone is poorly understood, with a strong diagenetic control suggested by the lack of correlation between permeability and depositional facies. Core samples from the Wattenberg Field and Redtail areas in Weld County were used to identify which diagenetic processes were most important in developing a connected pore network. Thirteen diagenetic features were defined using thin-section petrography and electron microprobe mineralogical phase mapping, and skeletonized flow paths were delineated by epifluorescence imaging. Quartz overgrowths, mechanical compaction, and clay cements (illite, chlorite, and kaolinite) are better developed in the laminated facies than the burrowed facies. Authigenic calcite and pyrite, and dissolution of framework grains are equally developed in both types of facies. Cumulative 2D flow-path lengths positively co-vary with permeability, indicating that the skeletonized paths capture the features that control permeability. The longest flow paths in high permeability (≥0.09 mD) samples follow micropores created along the periphery of framework grains where the discontinuous quartz overgrowths abut clays. Micropores within intergranular clay masses (detrital, pore-filling cements, and authigenic replacements) associate with shorter flow paths that dominate in low permeability (≤ 0.01 mD) samples and feed the longer paths in high permeability samples. While compaction and all types of cements had a negative impact on the original pore network, the development of long contacts between quartz overgrowths and mechanically juxtaposed grains eventually became beneficial to the drainage system. The increased surface area along those contacts increased the continuity of the flow paths developed along grain surfaces. All observations indicate that the minute quartz overgrowths, and the high authigenic rugosity they created along grain boundaries, were a key diagenetic event in creating the most efficient drainage networks that now facilitate the movement of hydrocarbons at the core-plug scale.

show abstract

Codell Sandstone, a Review of the Northern DJ Basin Oil Resource Play, Laramie County, Wyoming and Weld County, Colorado

Cited by 5 publications

References 0 publications

Workflow Development and Sensitivity Investigation of Offset Well-to-Well Interference Through 3-D Fracture Modeling and Reservoir Simulation in the Denver-Julesburg Basin

Workflow Development and Sensitivity Investigation of Offset Well-to-Well Interference Through 3-D Fracture Modeling and Reservoir Simulation in the Denver-Julesburg Basin

Integration of Dual-Porosity Modeling with 4D Seismic and Microseismic Technology in Niobrara and Codell Formations, DJ Basin

Critical Diagenetic Features Controlling Intergranular Flow Paths and Matrix Permeability in the Codell Sandstone, Northeastern Colorado

Contact Info

Product

Resources

About