PE1-2016 MAIN ARTICLE 101316106

Title Reservoir Modeling and Simulation of the Devonian Gas Shale of Eastern
Kentucky for Enhanced Gas Recovery and CO2 Storage
DOI SPE-126620-MS
Author(s) Karine Chrystel Schepers (Advanced Resources International) | Brandon C.
Nuttall | Anne Yvonne Oudinot (Advanced Resources
International) | Reinaldo Jose Gonzalez (Advanced Resources International)
Main 1. Hamilton-Smith, T., 1993, Gas exploration in the
Reference Devonian shales of Kentucky: Kentucky Geological
Reviewed Survey, ser. 11, Bulletin 4, 31 p.
2. Energy Information Administration (EIA), 2000, Annual
energy outlook 2001 with projections to 2020: U.S.
Department of Energy, Energy Information Administration
DOE/EIA-0383(2001), 262 p.,
www.eia.doe.gov/oiaf/aeo/pdf/0383(2001).pdf [visited 11-
Nov-2001].
3. Energy Information Administration (EIA), 2002, State Energy
Profiles, Kentucky: U.S.
Department of Energy, Energy Information Administration,
www.eia.doe.gov/cneaf/electricity/st_profiles/kentucky.pdf
[visited 4-Mar-2004].
4. Roen, J. B. and Walker, B. J.; “The Atlas of Major Appalachian
Gas Plays”, prepared for the U.S. Department of Energy,
Morgantown Energy Technology Center, Cooperative
Agreement DE-FC21-91-MC28176.
5. Schwerer, F. C., and Pavone, A. M.; “Effect of Pressure-
Dependent Permeability on Well-Test Analyses and Long-
Term Production of Methane From Coal Seams”, paper
SPE/DOE/GRI 12857 presented at Unconventional Gas
Recovery Symposium, Pittsburgh, PA, May 13-15, 1984.
6. Sawyer, W. K., Paul, G. W., and Schraufnagel, R. A.;
“Development and Application of a 3D Coalbed Simulator,”
CIM/SPE 90-119, presented at the 1990 CIM/SPE
International Technical Conference, Calgary, June 10-13,
1990.
7. Paul, G. W., Sawyer, W. K., and Dean, R. H., “Validation 3D
Coalbed Simulators”, SPE 20733, presented at SPE Annual
Technical Conference and Exhibition, Houston, TX,
September 23-26, 1990.
8. Nuttall, B.C., Drahovzal, J.A., Eble, C.F., and Bustin, R.M.,
2006, Analysis of the Devonian Black Shale in Kentucky for
Potential Carbon Dioxide Sequestration and Enhanced
Natural Gas Production, Final Report: Kentucky Geological
Survey, web page, url
PE1-2016 MAIN ARTICLE 101316106

http://www.uky.edu/KGS/emsweb/devsh/final_report.pdf,
accessed 1-Oct-2006.

Problems
• Reservoir heterogenety dan driving mechanism berasal dari gas shale
• Ingin meningkatkan produksi Field menggunakan injeksi CO2.
• Ingin menggunakan metode Huff-and-puff.
Assumptions and Limitations
• Permeabilitas rata-rata 2x10-2 mD
• Porositas rata-rata 15%
• Delapan sumur mencakup sekitar 5.300 hektar shale produktif
• Sebanyak 300ton injeksi CO2 telah disuntikan
Practical Applications
• Reservoir dibagi menjadi Upper Ohio dan Lower Huron.
• Untuk menangkap heterogenitas geologi, tingkat produksi gas untuk sumur-
sumur ini digunakan sebagai penghubung untuk mengkarakterisasi
permeabilitas fraktur menggunakan metode geostatistik.
• Skenario injeksi CO2 menggunakan metode huff-and-puff untuk mengevaluasi
potensi pemulihan gas dan kapasitas CO2.
Discussions
• Upaya history matching menghasilkan pemahaman yang lebih baik tentang
heterogenitas reservoir dan driving mechanism di Devon-gas shale. Nilai
permeabilitas rata-rata 2,10-2 mD untuk Huron Bawah dan porositas rata-rata 1,5%
ditemukan melalui optimisasi dan sesuai dengan nilai turunan inti.

• Injeksi CO2 kontinu secara penuh pada lapangan tampaknya berpotensi berhasil,
memungkinkan injeksi 300 ton selama satu setengah bulan dan menunjukkan
keuntungan yang signifikan dalam pemulihan. Selain itu, tergantung pada ketebalan
yang dipertimbangkan biasanya setengah dari total volume yang disuntikkan.

• Skenario Huff-and-Puff tampaknya tidak menjadi pilihan yang baik untuk reservoir ini,
tidak menghasilkan pemulihan gas yang baik karena CO2 yang diproduksi dengan
sangat cepat selama periode puff. Bahkan mencoba periode perendaman yang lebih
lama tampaknya tidak akan meningkatkan pemulihan.
Recommendations and Extensions
Simulasi ini efisien meskipun kompleksitas masalah aliran flow kurang diperjelas, namun
beberapa data dapat diambil dengan baik sehingga dapat ditemukan kesimpulan secara
actual. Walaupun percobaan metode ini diterapkan secara langsung pada sumur sehingga
dapat diketahui langsung perbedaannya dengan simulasi.
PE1-2016 MAIN ARTICLE 101316106

Title GAS EXPLORATION IN THE DEVONIAN SHALES OF KENTUCKY

DOI 0075-5559
Author(s) Terence Hamilton-Smith
Main 1. Abdullin, R. A., 1981, Nature of filtration properties of rocks of the
Reference Bazhenov Formation of Salym Field of west Siberia: Petroleum
Reviewed Geology, v. 18, no. 11, p. 512–515.
2. Ault, C. H., 1990, Directions and characteristics of joint-ing in the
New Albany Shale (Devonian-Mississip-pian) of southeastern
Indiana, in Lazar, D. J., ed., Proceedings, 1989 Eastern Oil Shale
Symposium: University of Kentucky Institute for Mining and Min-
erals Research, IMMR89/201, p. 239–252.
3. Avila, John, 1976, Devonian shale as source of gas, in Natural gas
from unconventional sources: Washing-ton, D.C., National
Research Council, p. 73–85.
4. Barker, Colin, 1972, Aquathermal pressuring—Role of
temperature in development of abnormal pressure zones:
American Association of Petroleum Geolo-gists Bulletin, v. 56, no.
10, p. 2068–2071.
5. Barker, Colin, 1990, Calculated volume and pressure changes
during the thermal cracking of oil to gas in reservoirs: American
Association of Petroleum Ge-ologists Bulletin, v. 74, no. 8, p.
1254–1261.

Problems
• Most of the natural gas reserves of Kentucky are contained in fractured reservoirs
in the Devonian shales

Assumptions and Limitations

• The Devonian shale sequence of Kentucky consists of dark-gray or brown to black
shale interbedded with subordinate amounts of green-gray shale.
• 86 percent had total organic carbon contents above 1 percent, with a maximum
of 15.6 per-cent. Organic matter in the green-gray shales.
Practical Applications
• Geological and geophysical method

Discussions
• Shale Gas Resources
• Hydrocarbon Generation and Migration
• Fractured Devonian Shale Reservoirs
Recommendations and Extensions
The discussion about this article is still limited to geological and geophysical methods.
PE1-2016 MAIN ARTICLE 101316106

Title Effect of Pressure-Dependent

Permeability on Well-Test Analyses
and Long-Term Production of
Methane From Coal Seams
DOI SPE 12857
Author(s) F.e. Schwerer and A.M. Pavone
Main 1. Warren J. E. and Root P. J.: "The Behavior of Naturally
Reference Fractured Reservoirs," Society of Petroleum Engineers
Reviewed Journal, September, 245-255 (1963) •
2. Price H. S. and Abdalla A. A.: "Mathematical Model Simulating
Flow of Methane and Water in Coal Mine Systems," Project
Report, Contract No. 50110752, U.S. Bureau of Mines (197Z).
3. Price H.S., McCulloch R. C., Edwards J. C., and Kissel F. N.: "A
Computer Model Study of the Methane Migration in Coal Beds,"
<..;anadian Mining and Metallurgy tlulletin, September, 103-llz
(1973)
4. Kissel F. N. and Edwards J. C.: Two-Phase Flow in Coalbeds,
Report of Investigation, RI8066, U. S. Bureau of Mines (1975).
5. King G. R., Ertekin T., and ~chwerer F. C.: "Numerical Simulation
of the Transient Behavior of Coal Seam Degasification Wells,"
Proceedings of 1983 Reservoir Simulation Symposium, Society of
Petroleum Engineers (1983).

Problems
• Laboratory measurements have shown that the permeability of coal samples
varies significantly for ranges of pressure encountered during the testing of
coalbed methane wells.
Assumptions and Limitations
• The base case corresponding to a constant (pressure-independent)
Practical Applications
• Numerical
• Two-phase coalbed methane simulator
Discussions
A numerical simulator for two-phase flow of methane and water through a coal
seam with time-dependent desorption was used to study the effects of pressure-
dependent permeabilities. It was found that apparent permeabilities deduced from
conventional analyses of Single-phase, constant-rate or constant-pressure production or
injection tests were signifi-cantly different from the value of the absolute permeability at
initial coal seam conditions. The magnitude of the difference between the apparent.
Recommendations and Extensions
Use 2 different methods so don't focus on one calculation.
PE1-2016 MAIN ARTICLE 101316106

Title DEVELOPMENT AND APPLICATION OF A 3D COALBED

SIMULATOR

DOI CIMISPE 90-119

Author(s) W.K. Sawyer, G.W.Paul, A.A. Schraufnagel
Main 1. Price H. S. and Abdalla A. A.: "Mathematical Model Simulating
Reference Flow of Methane and Water in Coal Mine Systems," Project
Reviewed Report, Contract No. 50110752, U.S. Bureau of Mines (197Z).
2. Ault, C. H., 1990, Directions and characteristics of joint-ing in the
New Albany Shale (Devonian-Mississip-pian) of southeastern
Indiana, in Lazar, D. J., ed., Proceedings, 1989 Eastern Oil Shale
Symposium: University of Kentucky Institute for Mining and Min-
erals Research, IMMR89/201, p. 239–252.
3. Paul, G. W., Sawyer, W. K., and Dean, R. H., “Validation 3D
Coalbed Simulators”, SPE 20733, presented at SPE Annual
Technical Conference and Exhibition, Houston, TX,
September 23-26, 1990.

Problems
• Coalbed methane reservoirs is a more complex.
• Data intensive process for conventional gas reservoirs.
Assumptions and Limitations
• Fully3-D data
• Multiple well model
• Based on the non-equilibrium
• Pseudo steady-state formulation discussed by King
Practical Applications
• Theory of flowing through coalbeds.
• Model development
• History matching
Discussions
The effects of both internal stress-induced and matrix shrinkage permeability
changes on gas production were simulated.

Recommendations and Extensions

Equation used is a general formula that is limited to certain conditions.
PE1-2016 MAIN ARTICLE 101316106

Title Validation of 3D Coalbed Simulators

DOI SPE 20733

Author(s) G.W. Paul, W.K. Sawyer, R.H. Dean

Main 1. Odeh, A.S.: "Comparisons of Solutions to a Three-Dimensional
Reference Black-Oil Reservoir Simulation Problem," JPT (Jan. 1981) 13-25.
Reviewed
2. King, G.A., Ertekin, T., and Schwerer, F.C.: "Numerical Simulation of
the Transient Behavior of Coal-Seam Degasification Wells," SPERE
(April 1986) 165-183.

3. Sawyer, WK, Paul, G.W., and Schraufnagel, R.A.: "Development and

Application of a 3D Coalbed Simulator" paper CIM/SPE 90-119
presented at the 1990 CIM/SPE International Technical Conference,
Calgary, June 10-13.

4. Dean, R.H. and Lo, LL.: "Simulations of Naturally Fractured

Reservoirs," SPERE (May 1988) 638-648.

5. Fleming, G.C.: "Modeling the Performance of Fractured Wells in

Pattern Floods Using Orthogonal, Curvilinear Coordinates," paper
SPE 16973 presented at the 1987 SPE Annual Technical Conference
and Exhibition, Dallas, Sept. 27-30.

Problems
• The two no-flow barriers were not present and the layers were allowed to
communicate with vertical permeabilities.
• The sandstone layer was also removed, leaving two coal layers in
communication.
Assumptions and Limitations
• ICF used COMETPC 3-0, a three-dimensional (3D), two-phase, single or dual
porosity simulator for modeling gas and water production from coal seams,
devonian shales, and conventional reservoirs.
Practical Applications
• The matrix equations are solved in 3D by a combined direct (04) - slice SOR method

Discussions
Simulators developed by ICF Resources Inc. and ARCO Oil and Gas Company were
compared for three related coal seam gas problems. Results from the two models were
in close agreement. The problems and associated results presented here can serve as
benchmarks for verification of other coalbed simulators
Recommendations and Extensions

The equation used is not precise.

PE1-2016 MAIN ARTICLE 101316106

Title ANALYSIS OF DEVONIAN BLACK SHALES IN KENTUCKY FOR POTENTIAL

CARBON DIOXIDE SEQUESTRATION AND ENHANCED NATURAL GAS
PRODUCTION
DOI SPE 22255

Author(s) Brandon C. Nuttall, Cortland Eble, R. Mark Busting and James A

Drahovzal'

Main 1. lEA Coal Research. 1999. CO2 reduction—Prospects for coal.

Reference London, lEA Coal Research, 84 p.
Reviewed 2. Boswell, R., 1996. Play Uds: Upper Devonian black shales, in Roen,
J.B. and B.J. Walker, eds. Atlas of major Appalachian gas plays.
West Virginia Geologic and Economic Survey, Publication V-25, p.
93-99.
3. Ting, F.T.C., 1978. Petrographic Techniques in Coal Analysis, in Karr,
C, Jr. (ed). Analytical Methods for Coal and Coal Products. Academic
Press, vol. 1, pp. 3-26.

Problems
• Occurring organic matter (kerogen) is a microporous material that possesses a
very high surface area and hence sorption capacity for gas. The question is: can
Devonian gas shales adsorb sufficient amounts of CO2, that they might be
significant targets for CO2 sequestration
Assumptions and Limitations
• As key wells and available samples are identified, wells in deep (at least 1,000
feet) and thick (at least 50 feet) areas will be included. Two Illinois Basin wells
have also been sampled. Battelle has contributed drill cuttings through the
Devonian shale from their deep AEP CO2.
Practical Applications
• Lab test
Discussions
Twenty-six samples have been collected from seven wells, including three cuttings
samples and 10 sidewall cores from the Columbia Natural Resources No. 24752 Elkhorn
Coal Corporation well in Knott County. In addition to the sidewall cores, electron capture
spectroscopy and lithodensity logs has been acquired for the well. Data for completed
analyses
Recommendations and Extensions

This calculation uses the lab test method.