Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah

John Yilin Wang, D. A. McVay, W. B. Ayers

Research output: Chapter in Book/Report/Conference proceedingConference contribution

1 Citation (Scopus)

Abstract

Monument Butte field produces oil from low-permeability, lacustrine fluvial-deltaic sandstones of the Green River formation. Reservoir sands are heterogeneous, lenticular, and have limited aerial extent and vertical communication, resulting in poor inter-well connectivity. Cumulative recovery to date (primary and secondary) is about 2% of the estimated 2 billion barrels of original oil in place (OOIP). Current water flooding successfully maintains reservoir pressure, but it provides very poor sweep efficiency. The objectives of this study were to assess secondary and tertiary recovery methods and to recommend a reservoir management approach that would increase oil recovery efficiency. To accomplish these objectives, we conducted detailed compositional simulation studies in a pilot area of the field. The reservoir model was calibrated using manual and assisted history matching methods. To reduce simulation time, we grouped fluid components into 10 pseudo-components. The 3-parameter, Peng-Robinson equation of state (EOS) was used to match PVT experimental data. Primary-then-water-flood and water-flood-only strategies were simulated using different water-flood timings. Infill drilling potential was evaluated by simulating downspacing from the original 40-ac to 20-ac well spacing. Immiscible and miscible flooding with CO 2, water alternating with gas (WAG), N 2, and CH 4 were simulated with reservoir pressures below and above minimum miscibility pressure (MMP). Simulation results indicate that water flooding should be started within 6 months of production. A water-flood-only strategy provides more oil recovery than a primary-then-water-flood strategy. Infill drilling may effectively produce unswept oil and double oil recovery. Immiscible gas injection suffers early gas breakthrough and is not an effective way to increase ultimate oil recovery. CO 2 injection is much more efficient than N 2 and CH 4 injection, because it has a lower MMP (2500 psia) and later gas breakthrough. Water-alternating-CO 2 injection is superior to continuous CO 2 injection in oil recovery, because it makes the gas-oil mobility ratio more favorable, controls early CO 2 breakthrough and maintains reservoir pressure. The study results can be used to optimize oil production from other parts of the large Monument Butte field.

Original languageEnglish (US)
Title of host publicationSociety of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008
Pages470-488
Number of pages19
StatePublished - Dec 1 2008
EventSPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008 - Pittsburgh, PA, United States
Duration: Oct 11 2008Oct 15 2008

Other

OtherSPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008
CountryUnited States
CityPittsburgh, PA
Period10/11/0810/15/08

Fingerprint

Secondary recovery
Enhanced recovery
monument
Oils
Carbon Monoxide
Water
oil
simulation
Recovery
Infill drilling
water
gas
flooding
Gases
infill
Solubility
drilling
Well spacing
Reservoir management
recovery method

All Science Journal Classification (ASJC) codes

  • Geochemistry and Petrology
  • Geotechnical Engineering and Engineering Geology

Cite this

Wang, J. Y., McVay, D. A., & Ayers, W. B. (2008). Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah. In Society of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008 (pp. 470-488)
Wang, John Yilin ; McVay, D. A. ; Ayers, W. B. / Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah. Society of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008. 2008. pp. 470-488
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abstract = "Monument Butte field produces oil from low-permeability, lacustrine fluvial-deltaic sandstones of the Green River formation. Reservoir sands are heterogeneous, lenticular, and have limited aerial extent and vertical communication, resulting in poor inter-well connectivity. Cumulative recovery to date (primary and secondary) is about 2{\%} of the estimated 2 billion barrels of original oil in place (OOIP). Current water flooding successfully maintains reservoir pressure, but it provides very poor sweep efficiency. The objectives of this study were to assess secondary and tertiary recovery methods and to recommend a reservoir management approach that would increase oil recovery efficiency. To accomplish these objectives, we conducted detailed compositional simulation studies in a pilot area of the field. The reservoir model was calibrated using manual and assisted history matching methods. To reduce simulation time, we grouped fluid components into 10 pseudo-components. The 3-parameter, Peng-Robinson equation of state (EOS) was used to match PVT experimental data. Primary-then-water-flood and water-flood-only strategies were simulated using different water-flood timings. Infill drilling potential was evaluated by simulating downspacing from the original 40-ac to 20-ac well spacing. Immiscible and miscible flooding with CO 2, water alternating with gas (WAG), N 2, and CH 4 were simulated with reservoir pressures below and above minimum miscibility pressure (MMP). Simulation results indicate that water flooding should be started within 6 months of production. A water-flood-only strategy provides more oil recovery than a primary-then-water-flood strategy. Infill drilling may effectively produce unswept oil and double oil recovery. Immiscible gas injection suffers early gas breakthrough and is not an effective way to increase ultimate oil recovery. CO 2 injection is much more efficient than N 2 and CH 4 injection, because it has a lower MMP (2500 psia) and later gas breakthrough. Water-alternating-CO 2 injection is superior to continuous CO 2 injection in oil recovery, because it makes the gas-oil mobility ratio more favorable, controls early CO 2 breakthrough and maintains reservoir pressure. The study results can be used to optimize oil production from other parts of the large Monument Butte field.",
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Wang, JY, McVay, DA & Ayers, WB 2008, Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah. in Society of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008. pp. 470-488, SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008, Pittsburgh, PA, United States, 10/11/08.

Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah. / Wang, John Yilin; McVay, D. A.; Ayers, W. B.

Society of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008. 2008. p. 470-488.

Research output: Chapter in Book/Report/Conference proceedingConference contribution

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N2 - Monument Butte field produces oil from low-permeability, lacustrine fluvial-deltaic sandstones of the Green River formation. Reservoir sands are heterogeneous, lenticular, and have limited aerial extent and vertical communication, resulting in poor inter-well connectivity. Cumulative recovery to date (primary and secondary) is about 2% of the estimated 2 billion barrels of original oil in place (OOIP). Current water flooding successfully maintains reservoir pressure, but it provides very poor sweep efficiency. The objectives of this study were to assess secondary and tertiary recovery methods and to recommend a reservoir management approach that would increase oil recovery efficiency. To accomplish these objectives, we conducted detailed compositional simulation studies in a pilot area of the field. The reservoir model was calibrated using manual and assisted history matching methods. To reduce simulation time, we grouped fluid components into 10 pseudo-components. The 3-parameter, Peng-Robinson equation of state (EOS) was used to match PVT experimental data. Primary-then-water-flood and water-flood-only strategies were simulated using different water-flood timings. Infill drilling potential was evaluated by simulating downspacing from the original 40-ac to 20-ac well spacing. Immiscible and miscible flooding with CO 2, water alternating with gas (WAG), N 2, and CH 4 were simulated with reservoir pressures below and above minimum miscibility pressure (MMP). Simulation results indicate that water flooding should be started within 6 months of production. A water-flood-only strategy provides more oil recovery than a primary-then-water-flood strategy. Infill drilling may effectively produce unswept oil and double oil recovery. Immiscible gas injection suffers early gas breakthrough and is not an effective way to increase ultimate oil recovery. CO 2 injection is much more efficient than N 2 and CH 4 injection, because it has a lower MMP (2500 psia) and later gas breakthrough. Water-alternating-CO 2 injection is superior to continuous CO 2 injection in oil recovery, because it makes the gas-oil mobility ratio more favorable, controls early CO 2 breakthrough and maintains reservoir pressure. The study results can be used to optimize oil production from other parts of the large Monument Butte field.

AB - Monument Butte field produces oil from low-permeability, lacustrine fluvial-deltaic sandstones of the Green River formation. Reservoir sands are heterogeneous, lenticular, and have limited aerial extent and vertical communication, resulting in poor inter-well connectivity. Cumulative recovery to date (primary and secondary) is about 2% of the estimated 2 billion barrels of original oil in place (OOIP). Current water flooding successfully maintains reservoir pressure, but it provides very poor sweep efficiency. The objectives of this study were to assess secondary and tertiary recovery methods and to recommend a reservoir management approach that would increase oil recovery efficiency. To accomplish these objectives, we conducted detailed compositional simulation studies in a pilot area of the field. The reservoir model was calibrated using manual and assisted history matching methods. To reduce simulation time, we grouped fluid components into 10 pseudo-components. The 3-parameter, Peng-Robinson equation of state (EOS) was used to match PVT experimental data. Primary-then-water-flood and water-flood-only strategies were simulated using different water-flood timings. Infill drilling potential was evaluated by simulating downspacing from the original 40-ac to 20-ac well spacing. Immiscible and miscible flooding with CO 2, water alternating with gas (WAG), N 2, and CH 4 were simulated with reservoir pressures below and above minimum miscibility pressure (MMP). Simulation results indicate that water flooding should be started within 6 months of production. A water-flood-only strategy provides more oil recovery than a primary-then-water-flood strategy. Infill drilling may effectively produce unswept oil and double oil recovery. Immiscible gas injection suffers early gas breakthrough and is not an effective way to increase ultimate oil recovery. CO 2 injection is much more efficient than N 2 and CH 4 injection, because it has a lower MMP (2500 psia) and later gas breakthrough. Water-alternating-CO 2 injection is superior to continuous CO 2 injection in oil recovery, because it makes the gas-oil mobility ratio more favorable, controls early CO 2 breakthrough and maintains reservoir pressure. The study results can be used to optimize oil production from other parts of the large Monument Butte field.

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Wang JY, McVay DA, Ayers WB. Compositional simulation and optimization of secondary and tertiary recovery strategies in monument butte field, utah. In Society of Petroleum Engineers - SPE Eastern Regional/AAPG Eastern Section Joint Meeting 2008. 2008. p. 470-488