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Monell Unit CO2 Flood Patrick Draw Field Sweetwater County, Wyoming
May 29th, 2008
Prepared by: Jason GainesSenior Reservoir Engineer
APC Forward Looking StatementThis presentation contains forwardThis presentation contains forward--looking statements within looking statements within the meaning of Section 27A of the Securities Act of 1933 and the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Anadarko Section 21E of the Securities Exchange Act of 1934. Anadarko believes that its expectations are based on reasonable believes that its expectations are based on reasonable assumptions. No assurance, however, can be given that such assumptions. No assurance, however, can be given that such expectations will prove to have been correct. A number of expectations will prove to have been correct. A number of factors could cause actual results to differ materially from thefactors could cause actual results to differ materially from the projections, anticipated results or other expectations projections, anticipated results or other expectations expressed in this presentation. Anadarko cannot guarantee expressed in this presentation. Anadarko cannot guarantee that it will successfully execute on its exploration, drilling athat it will successfully execute on its exploration, drilling and nd development plans. See development plans. See ““Risk FactorsRisk Factors”” in the companyin the company’’s 2007 s 2007 Annual Report on Form 10Annual Report on Form 10--K and other public filings and press K and other public filings and press releases. Anadarko undertakes no obligation to publicly releases. Anadarko undertakes no obligation to publicly update or revise any forwardupdate or revise any forward--looking statements.looking statements.
Fields– Monell– Salt Creek– Sussex
Pipelines– 33 mile, 8”– 125 mile, 16”
CO2 Supply– XOM Shute
Creek
Anadarko’s Wyoming EOR Assets
Salt Creek
Monell
Sussex
16”
8”
Land GrantGas FieldsOil FieldsThird Party CO2 PipelineAPC CO2 Pipeline
Monell Overview
18
6
7
1
10 11 12
13141516
234
9
30
31
25262728
33 34 35 36
WS
WS
WS
FEET
0 2,963
Active
Ph3
Future
18
6
7
1
10 11 12
13141516
234
9
30
31
25262728
33 34 35 36
WS
WS
WS
FEET
0 2,963
Active
Ph3
Future
General Facts & History– Discovered in 1959– ~115 MMBOOIP (prod 40 MMBO)– 2001: Initiated pilot– 2003: 33 mile PL & 1st CO2 injection– 2006: Ph2 start-up– 2007: NGL plant commissioned– 2008: 9-spot drlg program ( 9 wells )– 2009: Ph3 development– Planned sequestration of 85 Bcf CO2
Current Status– 3,000 BOPD– 48 MMCFD CO2 injection– 39 CO2 injectors– CO2 -EOR cumulative of 3 MMBO
Upper Cretacous Stratigraphy Lance Formation Fox Hills Sandstone Lewis Shale Almond Formation Ericson Sandstone Rock Springs Fm
Upp
er C
reta
ceou
s
Blair Fm
Mes
aver
de G
roup
West-East Cross Section
Fort UnionLanceLewis
Almond
NormalFault
SeaLevel
Patrick Draw Field Table Rock
Wasatchft
2000
mi0 1 2
Monell Unit – Upper Almond Reservoir
UA-5A Pay
UA-5B Pay
Lewis Shale
Lower Almond
MONELL UNIT
49
4500
4550
-90 10SPNORM
500 0CILD
0 100ILD
0 100SN
0 40MINV
0 40MNOR
Monell Unit Type Log
Reservoir HighlightsCretaceous Mesaverde Almond SS stratigraphic trap
Barrier island/tidal channel inlet/shoreface depositional system
Very fine to fine-grained lithic, illitic, kaolinitic, and quartzose sandstones
20% Porosity, 30md Permeability, 40% Swi
5 deg. dip, 25’ Net Pay, 5,000 Acres at 4,500’ depth
Fractures and faulting are minor
Oil zone confined up-dip by the depleted low pressure gas cap and down-dip by permeability pinchout
~115 MMSTB OOIP, 500 GOR, 43 deg. API sweet
20% Primary RF, 14% Waterflood RF
1,800 psi original reservoir pressure at 120 deg.F
CO2 Miscible with Oil (1450# MMP)
Monell Unit – Phase Development
Phase 1Phase 1
Phase 2Phase 2
Development HighlightsPhase 1 implemented adding first 28 patterns of development
“Water curtain” concept proven up as affective pressure barrier– Horizontal 1: MU 43-27H - 5,000’ lateral water injection well
– Horizontal 2: MU 44-27H - 6,800’ lateral water injection well
– Four vertical water injection wells to the north
Flood response seen within 3 months of initial injection
Phase 2 implementation added 12 patterns of development– Applied lessons learned from Phase 1 to Phase 2
• Drilling, Completions, Facilities
NGL plant installed and processing recycled CO2 to recover NGL’s
Monitor/idle wellbores converted to producers to test 9-spot concept
Drilling campaign under way to test 9-spot pattern performance
Future phase development planning currently under way
Operations HighlightsDrilling
– Currently drilling with coiled tubing drill rig
Completions– 50/50 lease crude and diesel frac fluid
Wellbores– Injectors: 5-1/2” casing; 2-3/8” IC tubing; Ni coated packer; inconell tubing hanger
– Producers:
• Pumping: 5-1/2” csg; 2-7/8” CS tubing; continuous sucker rod; 456 PU
• Flowing: 5-1/2” csg; 2-3/8” IC tubing; Ni coated packer; inconell tubing hanger;
H20 slip-stream line at wellhead
Flowlines– Injection/Production: Continuous HDPE
Headers– Latest design (A2) includes central injection/production manifolds in common facility
Operations Highlights
Operations Highlights
Operations Highlights
Operations Highlights
Operations Highlights
Operations Highlights
Operations Highlights
Operations Highlights
Monell Unit Performance
PATRICK DRAW FIELD, MONELL UNITCO2 FLOOD PROJECT PERFORMANCE
1
10
100
1000
10000
100000
Sep-
59
Sep-
61
Sep-
63
Sep-
65
Sep-
67
Sep-
69
Sep-
71
Sep-
73
Sep-
75
Sep-
77
Sep-
79
Sep-
81
Sep-
83
Sep-
85
Sep-
87
Sep-
89
Sep-
91
Sep-
93
Sep-
95
Sep-
97
Sep-
99
Sep-
01
Sep-
03
Sep-
05
Sep-
07
Sep-
09
Sep-
11
Sep-
13
Sep-
15
Sep-
17
BPD
, MC
FD
Oil Gas CO2 Inj
Monell Unit – Production History
Primary Secondary Tertiary CO2 Flood
1
10
100
1,000
10,000
100,000
Jan-01 Jan-02 Jan-03 Jan-04 Jan-05 Jan-06 Jan-07 Jan-08 Jan-09
BPD
, MC
FD
Oil Production History
CO2 Inj History
Monell Unit Performance
3,000 bopd3,000 bopd
48 MMcfdi48 MMcfdi
Pilot 2001-02
1st CO2 Inj Sept.03
Pilot 2001-02
1st CO2 Inj Sept.03
Monell 9-Spot Review
0
50
100
150
200
250
1 135 269 403 537 671 805 939 1073 1207 1341 1475 1609 1743
Normalized Time (days)
BOPD
#6Well#7 Well#14 Well#17 Well#18 Well#121Well#157WellType Well
Monell Unit – 9-Spot Type Well
Oil Production
Monell Unit – 9-Spot Drilling - 2008
Monell Unit – Future Development
18
6
7
1
10 11 12
13141516
234
9
30
31
25262728
33 34 35 36
WS
WS
WS
FEET
0 2,963
Active
Ph3
Future
18
6
7
1
10 11 12
13141516
234
9
30
31
25262728
33 34 35 36
WS
WS
WS
FEET
0 2,963
Active
Ph3
Future
Ph1
Ph2
Monell Unit – Applied ToolsField/Pattern surveillance (OFM)
Dimensionless curves developed to help forecast performance– Allows pattern comparison and balancing
– Will help identify problem patterns
Bottom Hole Pressure Tool – Surface Injection Pressure– Calculates BHIP from SIP using phase envelope P & T segments
– Assures that we remain below fracture pressure at all times
CO2 Injection Schedule – Developed to aid in balancing patterns and CO2 utilization
– Automated system that can be controlled by volume and/or pressure
Production Allocation Tool– Ensure that production is allocated correctly from well test data
Reservoir Simulation – History Matching
RF_for_PI_II PATTERN: Phase 1&2 Patt_11-35PATTERN: Phase 1&2 Patt_13-25PATTERN: Phase 1&2 Patt_13-35PATTERN: Phase 1&2 Patt_15-25PATTERN: Phase 1&2 Patt_22-2PATTERN: Phase 1&2 Patt_22-25PATTERN: Phase 1&2 Patt_22-26PATTERN: Phase 1&2 Patt_22-3PATTERN: Phase 1&2 Patt_22-35PATTERN: Phase 1&2 Patt_22-36PATTERN: Phase 1&2 Patt_24-25PATTERN: Phase 1&2 Patt_24-26PATTERN: Phase 1&2 Patt_24-3PATTERN: Phase 1&2 Patt_24-35PATTERN: Phase 1&2 Patt_31-3PATTERN: Phase 1&2 Patt_31-35PATTERN: Phase 1&2 Patt_33-25PATTERN: Phase 1&2 Patt_33-26PATTERN: Phase 1&2 Patt_33-3PATTERN: Phase 1&2 Patt_33-34PATTERN: Phase 1&2 Patt_33-35PATTERN: Phase 1&2 Patt_35-25PATTERN: Phase 1&2 Patt_35-3PATTERN: Phase 1&2 Patt_35-35PATTERN: Phase 1&2 Patt_42-25PATTERN: Phase 1&2 Patt_42-26PATTERN: Phase 1&2 Patt_42-3PATTERN: Phase 1&2 Patt_42-34PATTERN: Phase 1&2 Patt_42-35PATTERN: Phase 1&2 Patt_44-25PATTERN: Phase 1&2 Patt_44-26PATTERN: Phase 1&2 Patt_44-3PATTERN: Phase 1&2 Patt_44-34PATTERN: Phase 1&2 Patt_44-35PATTERN: Phase 1&2 Patt_51-3PATTERN: Phase 1&2 Patt_53-25PATTERN: Phase 1&2 Patt_53-27PATTERN: Phase 1&2 Patt_53-3PATTERN: Phase 1&2 Patt_53-35
Monell Unit – Applied ToolsR
ecov
ery
Fact
or
Rec
over
y Fa
ctor
HCPVinjHCPVinj2003 04 05 06 07 08
10-4
10-3
10-2
10-1
100
101
102
103
104
105
Date
Patt_24-26Daily Oil Rate ( bbl/d ) Daily Gas Rate ( Mcf/d ) Daily Water Rate ( bbl/d ) Daily CO2 Volume ( Mcf ) PDB Daily Prd CO2 Volume ( Mcf/d ) RatioGORCO2d ( Mcf/bbl )
Anadarko Petroleum CompanyPATTERN: Patt_24-26
Monell Unit – Applied Tools
2003 04 05 06 07 080.1
0.5
1
5
10
50
100
500
1000
5000
10000
Date
MONELL UN 31-35 Daily Inj Water Volume ( bbl ) Daily CO2 Volume ( Mcf )
Anadarko Petroleum CorporationMONELL UN 31-35
Well Name:
Well Depth SIP SIT4,597 1,698 75
Tgrad0.00 F/ft
Depth Temp Davg Depth Pressure0 75 0 0 1,698
460 75 229.85 460 1,870919 75 689.55 919 2,044
1379 75 1149.25 1,379 2,2201839 75 1608.95 1,839 2,3992299 75 2068.65 2,299 2,5792758 75 2528.35 2,758 2,7613218 75 2988.05 3,218 2,9453678 75 3447.75 3,678 3,1304137 75 3907.45 4,137 3,3164597 75 4367.15 4,597 3,5035057 4826.85
0.76 psi/ft
Rate1,749 mcfd
Date Stamp02.04.08
Monell Unit 31-35
Bottom Hole Pressure
3,503
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
5,000
0 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000Monell Unit 31-35
Monell Unit 31-35
Well Name:
Well Depth SIP SIT4,597 750 75
Tgrad0.00 F/ft
Depth Temp Davg Depth Pressure0 75 0 0 750
460 75 229.85 460 780919 75 689.55 919 813
1379 75 1149.25 1,379 8501839 75 1608.95 1,839 9502299 75 2068.65 2,299 1,1022758 75 2528.35 2,758 1,2623218 75 2988.05 3,218 1,4253678 75 3447.75 3,678 1,5934137 75 3907.45 4,137 1,7634597 75 4367.15 4,597 1,9335057 4826.85
0.42 psi/ft
Rate
Date Stamp
Monell Unit 31-35
Bottom Hole Pressure
1,933
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
4,500
5,000
0 500 1,000 1,500 2,000 2,500Monell Unit 31-35
Monell Unit 31-35
Monell Unit – CO2 In ActionPATRICK DRAW FIELD, MONELL UNIT
CO2 FLOOD PROJECT PERFORMANCE
1
10
100
1000
10000
100000
Sep-
59
Sep-
61
Sep-
63
Sep-
65
Sep-
67
Sep-
69
Sep-
71
Sep-
73
Sep-
75
Sep-
77
Sep-
79
Sep-
81
Sep-
83
Sep-
85
Sep-
87
Sep-
89
Sep-
91
Sep-
93
Sep-
95
Sep-
97
Sep-
99
Sep-
01
Sep-
03
Sep-
05
Sep-
07
Sep-
09
Sep-
11
Sep-
13
Sep-
15
Sep-
17
BPD
, MC
FD
Oil Gas CO2 Inj
Primary Secondary Tertiary CO2 Flood
Salt Creek OverviewGeneral Facts & History– Discovered in late 1800’s– ~1.7 Bbbl OOIP (0.7 Bbbl cum prod)– 9 productive intervals & 4,400 total wells– 2003: Completed pilot, Ph1 & 125 mile PL– 2004: 1st CO2 injection– 2005: Ph2 start-up– 2007: Ph3-4 start-up– 2008: 2Q Ph5 start-up– Flowing producers – identical inj/prod set-up– Planned sequestration of 660 Bcf CO2
Current Status– 7,000 BOPD from CO2 ( 8,500 BOPD total )– 320 MMCFD CO2 injection– 153 CO2 WAG injectors ( 20-acre 5-spots )– CO2 -EOR cumulative of 5.5 MMBO
161718
19 20 21
282930
456
7 8 9
1
10 11 12
131415
2
22 23 24
252627
3
161718
19 20 21
282930
31 32 33
78 910 11 12
131415
22 23 24
252627
34 35 36
SALT CREEKLIGHT OIL UNIT
SALT CREEKSOUTH UNIT
Town ofMidwestTown ofMidwest
Ph1-2
Ph3-4
Ph5
Ph6
Ph7
Scale = 1 mile
Future Development
161718
19 20 21
282930
456
7 8 9
1
10 11 12
131415
2
22 23 24
252627
3
161718
19 20 21
282930
31 32 33
78 910 11 12
131415
22 23 24
252627
34 35 36
SALT CREEKLIGHT OIL UNIT
SALT CREEKSOUTH UNIT
Town ofMidwestTown ofMidwest
Ph1-2
Ph3-4
Ph5
Ph6
Ph7
Scale = 1 mile
Future Development
Phase 1-4 CO2 Flood Performance
Salt Creek Phases 1-4 CO2 Flood Performance
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
Jan-04 Jul-04 Jan-05 Jul-05 Jan-06 Jul-06 Jan-07 Jul-07 Jan-08
Gro
ss O
il P
rodu
ctio
n (B
OP
D)
0
40
80
120
160
200
240
280
320
360
Tota
l CO
2 In
ject
ion
(MM
CFD
)
Oil Production
CO2 Injection
Anadarko’s Rockies EORCurrent ActivityMonell Unit 3,000 BOPD 50% Developed (based on area)
Improved sweep via 9-spot pilotFive years of continuous injection without major breakthrough
Salt Creek 7,000 BOPD 20% Developed (based on area)Unique CO2 flood pushing technological envelopePhase development allows flexibility to apply lessons learned
Future Development1) Significant undeveloped resources at Monell and Salt Creek2) Linch Fields ~ 15 miles north of Salt Creek3) Apply lessons learned to future developments
Discussion?