Engineering topics
Publications and source records attributed to Haeri, Foad.
Results of CT scanning experiments of several representative sealing rocks exposed to CO2 at elevated pressure conditions to determine if CO2 spontaneously imbibed into the low permeability rocks.
Abstract Carbon storage technology is primarily targeted in saline formations, which is a porous rock matrix filled with brine, sealed with a low permeability caprock. There are significant variations of CO 2 wetting properties, typically reported in the literature as contact angle of CO 2 and brine interacting with a rock material, suggesting that CO 2 could become wetting under geostorage conditions and negatively impact containment effectiveness. Here, we performed the first controlled laboratory measurements of CO 2 ‐brine contact angles on shale rocks from low permeability sealing formations with distinctive mineralogic properties—calcite‐rich, quartz‐rich, and dolomite‐rich. We targeted temperatures at 40° and 100°C, pressures at 8.3, 34.5, and 62.1 MPa, and salinity at 35,000 and 260,000 ppm. Results show no significant change in contact angle with mineralogy, temperature, pressure, salinity, and CO 2 bubble size. We conclude that caprocks will remain water‐wet at geologic CO 2 storage conditions and will not lose their capillary sealing capacity.
This presentation provides experimental results for H2 wetting, permeability and diffusion with reservoir caprock, reservoir rock, and wellbore cement.
Existing downhole geophysical sensors, like those used in LWD, offer an opportunity for early kick detection, but they are not currently used for detection or characterization. Downhole acoustic measurements also have the potential for providing reliable gas leak detection based on their high sensitivity to low concentrations of gas present in a gas-liquid mixture. This effort seeks to close a data knowledge gap through numerical simulation and use this data to aid in development of a low-cost, fast, and reliable early kick detection technology for preventing blowouts based on the acoustic signature.
This work provides an overview of the research conducted at NETL and the University of Pittsburgh related to improving the perfornace of CO2 huff-and-puff enhanced oil recovery (EOR) in fractured shale and fractured tight formations. CO2-soluble wettability-altering surfactants will be dissolved in high pressure CO2 during the "huff" stages in an attempt to shift the wettability of shale surfaces away from oil-wet toward CO2-wet. Such a change should promote additinal oil recovery during the depressurization of the formation that occurs during the "puff" stages. Surfactant soubility in CO2, CO2-oil IFT, CO2-rock-oil contact angle, and core-scale huff and puff oil recovery results are presented.