Lithologic and Geomechanical Control on CO2 Huff-n-Puff Enhanced Oil Recovery Processes Using Integrated Modeling Framework in Wolfcamp

Phan, Tien N.; Cronk, Bradley; Almasoodi, Mouin; Reza, Zulfiquar

doi:10.15530/urtec-2018-2901346

Cited by 2 publications

(4 citation statements)

References 0 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…For example, many simulation studies agree that EOR should not be started until primary production is complete, 201,232,238,239 closer fracture spacing can improve recovery, 18,182,199,202,227 and numerous short cycles can recover more oil than one long cycle. 61,182,183,197,204,210,229,230 Often, conclusions from simulation studies are supported by observations in laboratory-scale experiments. For example, several simulation reports state that injection pressures at or above the MMP for a given gas can improve oil recovery, 60,132,197,198,206,207 that a rich natural gas can improve oil recovery over methane alone, 18,137,198,202,205,214 and that increasing the surface area of the rock exposed to EOR fluid can increase recovery.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 97%

“…To improve the incremental oil recovery by 1%, injection of about 3% hydrocarbon pore volume of CO 2 would be required. Another study focused on CO 2 huff-n-puff in the Wolfcamp formation (Table , entry 52) . An integrated modeling framework using complex fracture geometry and heterogeneous fracture conductivity was used.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

“…For example, several reports suggest that CO 2 and other EOR fluids are more miscible with oil when confined in nanopores. ,, Insights can also be extended to the field scale using simulations. For example, many simulation studies agree that EOR should not be started until primary production is complete, ,,, closer fracture spacing can improve recovery, ,,,, and numerous short cycles can recover more oil than one long cycle. ,,,,,,, Often, conclusions from simulation studies are supported by observations in laboratory-scale experiments. For example, several simulation reports state that injection pressures at or above the MMP for a given gas can improve oil recovery, ,,,,, that a rich natural gas can improve oil recovery over methane alone, ,,,,, and that increasing the surface area of the rock exposed to EOR fluid can increase recovery. ,,, In many cases, however, simulation studies reach conflicting conclusions.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

“…Another study focused on CO 2 huff-n-puff in the Wolfcamp formation (Table 5, entry 52). 230 An integrated modeling framework using complex fracture geometry and heterogeneous fracture conductivity was used. They recommended 30 days of injection and 90 days of soaking for optimal oil recovery.…”

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

See 3 more Smart Citations

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

et al. 2020

View full text Add to dashboard Cite

Primary oil recovery from fractured unconventional formations, such as shale or tight sands, is typically less than 10%. The development of an economically viable enhanced oil recovery (EOR) technique applicable to unconventional liquid reservoirs (ULRs) would lead to tremendous increases in domestic oil production. Although injection techniques such as waterflooding and CO2 EOR have proven profitable in conventional formations for decades, EOR in ULRs presents a far more difficult challenge. The extremely low permeability and mixed wettability of unconventional formations are the foremost obstacles to success. Because of the challenges associated with water-based EOR techniques (a.k.a., chemical EOR) in shale, several nonaqueous injection fluids have been considered, including CO2, natural gas, and (to a lesser degree) nitrogen. All these fluids have significantly lower viscosities than water, allowing them to more easily penetrate shale nanopores. Unlike water, they also each possess some degree of miscibility with oil, which enables the gas to extract oil through a combination of mechanisms. Based on laboratory-scale experimentation, CO2 and rich natural gas (methane-rich natural gas containing high concentrations of ethane, propane, and butane) are the most promising EOR fluids. The interpretation of results from field tests in the Bakken and Eagle Ford formations have been complicated by interference of frac-hits or well-bashing caused by hydraulic fracturing at nearby wells. In this review we cover mechanisms, laboratory experiments, numerical simulations, and field tests involving high-pressure CO2, natural gas, ethane, nitrogen, and water.

show abstract

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 97%

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

Section: Simulation Studies Related To Gas-based Eor In Ulrsmentioning

confidence: 99%

See 2 more Smart Citations

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

et al. 2020

View full text Add to dashboard Cite

show abstract

A Superior Shale Oil EOR Method for the Permian Basin

Downey¹,

Venepalli²,

Erdle³

et al. 2021

SPE Annual Technical Conference and Exhibition

View full text Add to dashboard Cite

The Permian Basin of west Texas is the largest and most prolific shale oil producing basin in the United States. Oil production from horizontal shale oil wells in the Permian Basin has grown from 5,000 BOPD in February, 2009 to 3.5 Million BOPD as of October, 2020, with 29,000 horizontal shale oil wells in production. The primary target for this horizontal shale oil development is the Wolfcamp shale. Oil production from these wells is characterized by high initial rates and steep declines. A few producers have begun testing EOR processes, specifically natural gas cyclic injection, or "Huff and Puff", with little information provided to date. Our objective is to introduce a novel EOR process that can greatly increase the production and recovery of oil from shale oil reservoirs, while reducing the cost per barrel of recovered oil. A superior shale oil EOR method is proposed that utilizes a triplex pump to inject a solvent liquid into the shale oil reservoir, and an efficient method to recover the injectant at the surface, for storage and reinjection. The process is designed and integrated during operation using compositional reservoir simulation in order to optimize oil recovery. Compositional simulation modeling of a Wolfcamp D horizontal producing oil well was conducted to obtain a history match on oil, gas, and water production. The matched model was then utilized to evaluate the shale oil EOR method under a variety of operating conditions. The modeling indicates that for this particular well, incremental oil production of 500% over primary EUR may be achieved in the first five years of EOR operation, and more than 700% over primary EUR after 10 years. The method, which is patented, has numerous advantages over cyclic gas injection, such as much greater oil recovery, much better economics/lower cost per barrel, lower risk of interwell communication, use of far less horsepower and fuel, shorter injection time, longer production time, smaller injection volumes, scalability, faster implementation, precludes the need for artificial lift, elimination of the need to buy and sell injectant during each cycle, ability to optimize each cycle by integration with compositional reservoir simulation modeling, and lower emissions. This superior shale oil EOR method has been modeled in the five major US shale oil plays, indicating large incremental oil recovery potential. The method is now being field tested to confirm reservoir simulation modeling projections. If implemented early in the life of a shale oil well, its application can slow the production decline rate, recover far more oil earlier and at lower cost, and extend the life of the well by several years, while precluding the need for artificial lift.

show abstract

Lithologic and Geomechanical Control on CO2 Huff-n-Puff Enhanced Oil Recovery Processes Using Integrated Modeling Framework in Wolfcamp

Cited by 2 publications

References 0 publications

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Superior Shale Oil EOR Method for the Permian Basin

Contact Info

Product

Resources

About

Lithologic and Geomechanical Control on CO2 Huff-n-Puff Enhanced Oil Recovery Processes Using Integrated Modeling Framework in Wolfcamp

Cited by 2 publications

References 0 publications

A Literature Review of CO2, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO2, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Superior Shale Oil EOR Method for the Permian Basin

Contact Info

Product

Resources

About

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs

A Literature Review of CO₂, Natural Gas, and Water-Based Fluids for Enhanced Oil Recovery in Unconventional Reservoirs