Enhanced Coalbed Methane Recovery

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1 Enhanced Coalbed Methane Recovery presented by: Scott Reeves Advanced Resources International Houston, TX SPE Distinguished Lecture Series 2002/2003 Season 1 Advanced Resources International

2 Outline Introduction ECBM Process Pilot Projects Economics Closing Remarks 2

3 Introduction Enhanced coalbed methane recovery (ECBM) involves gas injection into coal to improve methane recovery, analogous to EOR. Typical injection gases include nitrogen and carbon dioxide. Relatively new technology - limited field data to gauge effectiveness. Growing interest in carbon sequestration spurring considerable R&D into integrated ECBM recovery/carbon sequestration projects. 3

4 Integrated Power Generation, CO 2 Sequestration & ECBM Vision Power Plant CO 2 /N 2 CH 4 CH 4 CO 2 /N 2 CH 4 CH 4 CH 4 Deep, Unmineable Coal CH 4 CH 4 CH 4 CH 4 CO 2 /N 2 4

5 U.S. CO 2 -ECBM/Sequestration Potential CO 2 Sequestration Potential (Gt) ECBM Potential (Tcf) Basin Replacement of Primary Recovery Volume Injection for ECBM in Commercial Area Injection for CO 2 Sequestra-tion in Non- Commer-cial Area Total (Gt) % of Total Incremental Recovery in Commercial Area Incremental Recovery in Non- Commercial Area Total (Tcf) % of Total N. Appalachia % % C. Appalachia % % Black Warrior % % Illinois Cherokee/ Forest City % 1% % 1% Arkoma % % Gulf Coast % % San Juan % % Raton % % Piceance % % Uinta % % Greater Green River % % Hanna-Carbon % % Wind River % % Powder River % % Western Washington % % Alaska % % TOTALS % % 5

6 Outline Introduction ECBM Process Pilot Projects Economics Closing Remarks 6

7 Gas Storage in Coal (CBM 101) Dual-porosity system (matrix and cleats) Gas stored by adsorption on coal surfaces within matrix (mono-layer of gas molecules, density approaches that of liquid) 1 lb coal (15 in 3 ) contains 100,000 1,000,000 ft 2 of surface area Pore throats of angstrom Production by desorption, diffusion and Darcy flow (3 D s of CBM production) 7

8 Example Coal Sorption Isotherms CO 2 /CH 4 ratio = 2:1 N 2 /CH 4 ratio = 0.5/1 San Juan Basin coal Carbon Dioxide Absolute Adsorption (SCF/ton) CO 2 /N 2 ratio = 4:1 Methane Nitrogen Pressure (psia) 8

9 Variability of CO 2 /CH 4 Ratio CO2/CH4 Sorption Ratio vs Coal Rank CO2/CH4 Ratio Sub HV HVA MV LV y = x R 2 = Coal Rank, Vro (%) 100 psi 1000 psi 3000 psi 9

10 N 2 -ECBM Recovery Mechanism Inject N 2 into cleats. Due to lower adsorptivity, high percentage of N 2 remains free in cleats: Lowers CH 4 partial pressure Creates compositional disequilibrium between sorbed/free gas phases Methane stripped from coal matrix into cleat system. Methane/nitrogen produced at production well. Rapid N 2 breakthrough expected. 10

11 CO 2 -ECBM Recovery Mechanism Inject CO 2 into cleats. Due to high adsorptivity, CO 2 preferentially adsorbed into coal matrix. Methane displaced from sorption sites. Methane produced at production well. Efficient displacement process slow CO 2 breakthrough. 11

12 Modeling Sensitivity Study San Juan Basin setting (3000 ft, 40 ft coal, 10 md). Inject C0 2 and N 2 at rates of 10 Mcfd/ft, 25 Mcfd/ft and 50 Mcfd/ft. 15 year period. 4 Quarter 5-Spot Well Pattern 5 12

13 Gas Production Response N 2 Injection Gas Rate, Mscfd 1000 Incremental Recoveries: 10 Mcfd/ft 0.6 Bcf (21%) 25 Mcfd/ft 1.1 Bcf (39%) 50 Mcfd/ft 1.6 Bcf (57%) Nitrogen Content, % Days Base Case 25 Mcfd/ft 10 Mcfd/ft 50Mcfd/ft 13

14 Gas Production Response CO 2 Injection Gas Rate, Mscfd 1000 Incremental Recoveries: 10 Mcfd/ft 0.1 Bcf (4%) 25 Mcfd/ft 0.4 Bcf (14%) 50 Mcfd/ft 0.8 Bcf (29%) No CO 2 breakthrough CO 2 /CH 4 ratio is 2:1 whereas N 2 /CH 4 ratio is 0.5/ Days Base Case 25 Mcfd/ft 10 Mcfd/ft 50Mcfd/ft 14

15 Outline Introduction ECBM Process Pilot Projects Economics Closing Remarks 15

16 Only Two Large-Scale Field Tests Exists Worldwide San Juan Basin, Upper Cretaceous Fruitland Coal Allison Unit Burlington Resources Carbon dioxide injection 16 producers 4 injectors 1 pressure observation well Tiffany Unit BP Nitrogen injection 34 producers 12 injectors 16

17 Field Sites, San Juan Basin LA PLATA CO. ARCHULETA Durango Florida River Plant Pagosa Springs N2 Pipeline Tiffany Unit San Juan Basin Outline COLORADO NEW MEXICO F A I R W A Y Allison Unit Dulce Aztec Farmington Bloomfield R 17

18 Allison Unit Base Map M POW#

19 Well Configurations Injector Producer 19

20 Allison Production History 2,000,000 1,800,000 1,600,000 1,400,000 4,000 3,500 3,000 1,200,000 2,500 1,000,000 2, ,000 1, , ,000 Gas Rate, Mcf/mo CO2 Injection Rate, Mcf/mo 1,000 Well Gas Rate, Mcf/d 200, Jan-89 Jul-89 Jan-90 Jul-90 Jan-91 Jul-91 Jan-92 Jul-92 Jan-93 Jul-93 Jan-94 Jul-94 Jan-95 Jul-95 Jan-96 Jul-96 Jan-97 Jul-97 Jan-98 Jul-98 Jan-99 Jul-99 Jan-00 Jul-00 Jan-01 Jul-01 Date 20 Rates, Mcf/mo Individual Well Gas Rate, Mcf/d 16 producers, 4 injectors, 1 POW Injectivity reduction Line pressures reduced, wells recavitated, wells reconfigured, onsite compression installed +/- 57 MMcfd +/- 3 1/2 Mcfd

21 Site Description Property Value Average Depth to Top Coal 3100 feet No. Coal Intervals 3 (Yellow, Blue, Purple) Average Total Net Thickness Permeability 43 feet 100 md Yellow 22 ft Blue 10 ft Purple 11 ft Initial Pressure 1650 psi Temperature 120 F 21

22 Progression of CO 2 Displacement (@ mid-2002) Face Cleat Butt Cleat N 22

23 Incremental Recovery Case Total Methane Recovery (Bcf) Incremental Recovery (Bcf) Total CO 2 Injection (Bcf) CO 2 Production (Bcf) CO 2 /CH 4 Ratio W/o CO 2 injection 100.5* n/a n/a n/a n/a W/CO 2 injection ** *6.3 Bcf/well ** 20 Mcfd/ft Small incremental recovery due to limited injection volumes. INJECTIVITY IS CRITICAL! Note: OGIP for model = 152 Bcf. 23

24 Tiffany Unit Base Map Previous Study Area Producer-to-Injector Conversions 24

25 Well Configurations Producer Well Multiple Injector Wells 25

26 Tiffany Production History 1,000, producers, 12 injectors 26 MMcfd +/- 5MMcfd 100,000 10,000 Injection initiated 1, Gas Rate, Mcf/mo N2 Injection Rate, Mcf/mo Suspension periods Max Inj Rate = 26 MMcfd Sep-83 Sep-84 Sep-85 Sep-86 Sep-87 Sep-88 Sep-89 Sep-90 Sep-91 Sep-92 Sep-93 Sep-94 Sep-95 Sep-96 Sep-97 Sep-98 Sep-99 Sep-00 Sep-01 Sep-02 Date 26 Gas Rates, Mcf/mo

27 Site Description Property Value Average Depth to Top Coal (A) 2970 feet No. Coal Intervals 7 total (A, A2, B, C, D, E, F) 4 main (B, C, D, E) Average Net Thickness Permeability 47 feet <5 md B 13 ft C 11 ft D 9 ft E 14 ft Initial Pressure 1600 psi Temperature 120 F 27

28 Progression of N 2 Displacement (@ mid-2002) Face Cleat Butt Cleat N 28

29 Current Field Results (through mid-2002) Case Total Methane Recovery (Bcf) Incremental Recovery (Bcf) Total N 2 Injection (Bcf) N 2 Production (Bcf) N 2 /CH 4 Ratio W/o N 2 injection *35.3 n/a n/a n/a n/a W/N 2 injection ** *1.0 Bcf/well ** 46 Mcfd/ft At N 2 /CH 4 ratio of 0.75:1 and reproduced volume of 25%, ultimate incremental recovery estimated to be +/- 14 Bcf or 40% improvement over primary. Note: OGIP for model = 438 Bcf. 29

30 Summary of Field Results Field results are in general agreement with theoretical understanding; reservoir models can reasonably replicate/predict field behavior. Low-incremental recovery with CO 2 injection at Allison due to low injection volumes. CO 2 injectivity key success driver; strong evidence that coal permeability (and injectivity) reduced with CO 2 injection. Incremental recoveries with N 2 injection at Tiffany currently; estimated to provide 40% improvement over primary. 30

31 Outline Introduction ECBM Process Pilot Projects Economics Closing Remarks 31

32 Hypothetical Field Setting (US onshore) Example CBM Basin Well Injection Pattern (4 Sections) Sec. 6 Sec. 5 Sec.7 Sec. 8 Conventional Recovery 48 Bcf (2.5 Bcf/well) Incremental Recovery 16 Bcf (1 Bcf/well) 32

33 Economics of CO 2 ECBM US $/Mcf Hub Gas Price $3.00 Less: Basin Differential ($0.30) BTU Adjustment (@ 5%) ($0.15) Wellhead Netback $2.55 Less: Royalty/Prod. Taxes (20%) ($0.51) O&M/Gas Processing ($0.50) Gross Margin $1.54 Capital Costs (1) ($0.25) CO 2 Costs (@ ratio of 3.0 to 1) (2) ($0.90) Net Margin $0.39 (1) Capital Costs = $500,000 *4 (inj wells) = $2,000,000/16 Bcfg = $0.13/Mcfg * 2 = $0.25/Mcfg (2) CO 2 Costs = $0.30/Mcf * 3.0 = $0.90/Mcf (CO 2 ) 33

34 Economics of N 2 ECBM US $/Mcf Hub Gas Price $3.00 Less: Basin Differential ($0.30) BTU Adjustment (@5%) ($0.15) Wellhead Netback $2.55 Less: Royalty/Prod. Taxes (20%) ($0.51) O&M/Gas Processing ($1.00) (double over CO 2 case) Gross Margin $1.04 Capital Costs (1) ($0.25) N 2 Costs (@ ratio of 0.5 to 1) (2) ($0.30) Net Margin $0.49 (1) Capital Costs = $500,000 * 4 (inj. wells) = $2,000,000/16 Bcfg = $0.13/Mcfg * 2 = $0.25/Mcfg (2) N 2 Costs = $0.60/Mcf * 0.5 = $0.30/Mcf (N 2 ) 34

35 ECBM Economic Considerations N 2 ECBM appears favorable, but early breakthrough requires costly post-production gas processing. CO 2 - ECBM also appears favorable, but maintaining injectivity a key success driver. More experience required to validate & optimize economic performance. CO 2 /N 2 mixture may be optimum. High N 2 concentrations early for rapid methane recovery Increasing CO 2 concentrations later for efficient methane displacement. 35

36 Outline Introduction ECBM Process Pilot Projects Economics Closing Remarks 36

37 Closing Remarks ECBM recovery appears to hold considerable promise; on the verge of commerciality with a bright future. CO 2 sequestration economic drivers (carbon credits) will substantially improve financial performance and accelerate commercial adoption. In U.S., CO 2 -ECBM/sequestration potential is substantial; recently assessed at 90 Gt CO 2 and 150 Tcf of incremental gas recovery. 37

38 Closing Remarks More work is needed to economically optimize the process. N 2 /CO 2 mixtures CO 2 injectivity Spacing, patterns, rates, etc. Reservoir settings (coal rank) Reservoir response is generally consistent with theoretical understanding of CO 2 /N 2 processes. Reasonable predictions of reservoir response possible. Informed investment decisions. Acknowledgements: U.S. Department of Energy Burlington Resources BP America For more information: 38

39 Enhanced Coalbed Methane Recovery presented by: Scott Reeves Advanced Resources International Houston, TX SPE Distinguished Lecture Series 2002/2003 Season 39 Advanced Resources International

40 Well #132 Performance CH 4 Recovery w/o CO 2 injection = 6.1 Bcf CH 4 Recovery w/ CO 2 injection = 6.9 Bcf CH 4 Incremental Recovery = 0.8 Bcf 3000 CH4 Rate, Mscf Days CO2 Injection No CO2 Injection 40

41 Nitrogen Content of Produced Gas Average = 12.3 % 10 No. Wells < > 50 Last N2 Concentration (%) 41

42 Matrix Shrinkage/Swelling Source: An Investigation of the Effect of Gas Desorption on Coal Permeability, paper 8923, 1989 Coalbed Methane Symposium. 42

43 Relevant Formulas* Pressure-Dependence Shrinkage/Swelling φ = φ i + φ i C p (P-P i ) + (1 - φ i ) C m dp i dc i (C-C i ) k = n φ n = +/- 3 φi *Used in COMET2. Alternative formulation presented by Palmer & Mansoori; SPE 36737,

44 Permeability Changes with Net Stress, Gas Concentration, and Sorptive Capacity Matrix Shrinkage Pressure Dependence 250 Permeability, md Sorption Capacity Methane Carbon Dioxide Pressure, psi 44

45 Typical Injection Profile, Allison Unit Well # Pressure CO2, Mcf/mo Jan-89 Jul-89 Jan-90 Jul-90 Jan-91 Jul-91 Jan-92 Jul-92 Jan-93 Jul-93 Jan-94 Jul-94 Jan-95 Jul-95 Jan-96 Jul-96 Jan-97 Jul-97 Jan-98 Jul-98 Jan-99 Jul-99 Jan-00 Jul-00 Rate BHP, psi Date 45

46 Permeability History for Injector 250 Start Permeability, md Continued Injection Depletion Displace w/ CO Pressure, psi 46

47 CO 2 Sorption Behavior (Pc=1073psi, Tc=88ºF) Source: SPE 29194: Adsorption of Pure Methane, Nitrogen and Carbon Dioxide and their Binary Mixtures on Wet Fruitland Coal,

48 Pure Gas Gibbs Adsorption on Tiffany Coals at 130 F Gibbs Adsorption (SCF/ton) N abs = N Gibbs 1- ρ gas ρ ads N2 on Mixed Coal CH4 on Well #1 CH4 on Well #10 CH4 on Mixed Coal CO2 on Mixed Coal Pressure (psia) 48

49 CO 2 Absolute Adsorption on Tiffany Mixed Coal Sample Using Different Adsorbed-Phase Densities Aboslute Adsorption (SCF/ton) Adsorbed Phase Density(g/cc) Saturated liquid density at triple point ZGR estimate Graphical estimate Pressure (psia) 49

50 Multi-Component Sorption Behavior Extended Langmuir Theory V Li p i, i = 1, 2, 3,, n. C i (p i ) = n p p Li 1 + Σ j=1 p L Other Langmuir Models: Equations of State: Simplified Local Density Models: Loading Ratio Correlation (LRC), Real Adsorbed Solution (RAS), Ideal Adsorbed Solution (IAS) Van der Walls (VDW), Eyring, Zhou-Gasem-Robinson (EOS-S, PGR) Flat Surface (PR-SLD), Slit (PR-SLD) 50

51 Accuracy of Model Predictions for Pure Gas Adsorption Quality of Fit, % AAD, for Specified Model Component Langmuir LRC (n = 0.9) ZGR-EOS Experimental Error Methane Nitrogen Carbon Dioxide

52 Accuracy of Model Predictions for Binary/Ternary Gas Adsorption (based on pure-gas adsorption data) LRC Mixture, Langmuir (n=0.9) ZGR-EOS Experimental Error (Feed Mole %) % AAD % AAD % AAD % AAD CH 4 N 2 : CH 4 (50%) N 2 (50%) Total CH 4 CO 2 : CH 4 (40%) CO 2 (60%) Total N 2 CO 2 : N 2 (20%) CO 2 (80%) Total N 2 CH 4 -CO 2 : N 2 (10%) CH 4 (40%) CO 2 (50%) Total

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