Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2005 Northstar Oil Pool
Annual Reservoir Performance Report
Northstar Field
Northstar Oil Pool
January 2005 through December 2005
2
Table of Contents
A. Progress of Enhanced Recovery Project
B. Voidage Balance by Month of Produced Fluid and Injected Fluids
C. Summary and Analysis of reservoir pressure surveys within the pool
D. Results and Analysis of Production and Injection Log surveys, tracer surveys,
observation well surveys and any other special monitoring.
E. Review of pool production allocation factors and issues over the prior year
F. Review of Annual Plan of Operations and Development and Future
Development Plans
G. Status of wells shut-in for 365 days or more
Attachment 1: Map of well Locations
Attachment 2: Northstar Field 2005 Overview Statistical Summary, including
corrected Statistical Summaries for 2001 – 2004
Attachment 3: Corrected Voidage Balance by Month of Produced Fluid and
Injected Fluids – 2001 - 2004
Attachment 4: Northstar Field 2005 Reservoir Pressure Report, Form 10-412
3
A) Progress of Enhanced Recovery Project
During 2005, two additional production wells (NS05 and NS28) were brought on
line. The locations of these wells in addition to the other Northstar wells are
shown in Attachment 1. Production and injection statistics are summarized in
Attachment 2. Average oil production was 55,700 bopd and average gas
injection was 454.5 mmscfd.
During 2005, gas injection was just slightly less than reservoir voidage. At year
end, the reservoir had an overall voidage replacement ratio of 0.996.
4 B) Voidage Balance by Month of Produced Fluid and Injected Fluids – 2005 2005 MonthOil, MRBFree Gas, MRBWater, MRBTotal Voidage, MRBYearCum, MRBCum since start-up, MRBFormation Gas, MRBImport Gas, MRBTotal Injection, MRBYearCum, MRBCum since start-up, MRBNet Injection, MRBYearCum, MRBCum since start-up, MRBJan-20054,7314,8063739,5379,537212,8337,9148428,7568,756212,018-781-781-815Feb-20053,9854,5893538,57418,111221,4087,2121,2088,42117,177220,439-153-935-969Mar-20054,8326,88440111,71529,827233,12310,07969410,77327,950231,212-942-1,877-1,911Apr-20054,3054,6163648,92138,748242,0447,4581,6049,06237,012240,274141-1,736-1,770May-20054,7234,7564359,47848,226251,5227,8691,7519,62046,632249,894141-1,594-1,628Jun-20054,0524,6243958,67656,902260,1997,3031,3898,69255,324258,58616-1,579-1,613Jul-20054,2335,1354009,36866,271269,5677,9331,5349,46764,791268,05499-1,480-1,514Aug-20054,0035,2263929,22975,500278,7967,8731,4969,36974,160277,422139-1,340-1,374Sep-20053,2884,2723117,55983,059286,3556,4401,3727,81281,972285,234253-1,087-1,121Oct-20054,2705,82741810,09893,157296,4538,6431,36610,00991,981295,243-89-1,176-1,210Nov-20054,0416,46136610,502103,659306,9559,1141,52110,634102,615305,877132-1,044-1,078Dec-20053,8256,1703839,995113,654316,9508,6761,2579,934112,549315,811-61-1,105-1,1392005 Totals50,28863,3664,592113,65496,51416,035112,549-1,105Produced FluidsInjected FluidsNet Injection (Injection - Production) Produced water (MRB) was removed from the Total Voidage (MRB) calculation for years 2001 through 2005. Corrected Voidage Balance by Month of Produced and Injection Fluids charts for 2001 to 2004 are shown in Attachment 3.
5
C) Summary and Analysis of reservoir pressure surveys within the pool
Static bottom hole pressures collected in 2005 are summarized below.
Well Date
Extrapolated Pressure at -11,100' TVDss
Datum, psia Data Source
NS13 7-Jan-05 5,155 Cidra Data
NS14 7-Jan-05 5,153 Cidra Data
NS24 19-Jan-05 5,177 Cidra Data
NS14 2-Feb-05 5,148 Cidra Data
NS13 14-Feb-05 5,157 Cidra Data
NS16 14-Feb-05 5,094 Cidra Data
NS21 14-Feb-05 5,117 Cidra Data
NS06 18-Feb-05 5,132 Cidra Data
NS24 26-Feb-05 5,159 Cidra Data
NS14 7-Mar-05 5,136 Cidra Data
NS24 26-Mar-05 5,084 SBHP
NS14 29-Mar-05 5,090 SBHP
NS05 11-Apr-05 5,076 Cidra Data
NS14 24-Apr-05 5,107 Cidra Data
NS24 29-Apr-05 5,109 Cidra Data
NS08 12-May-05 5,113 SBHP
NS19 17-May-05 5,101 PBU
NS05 21-Jun-05 5,140 Cidra Data
NS22 21-Jun-05 5,119 Cidra Data
NS24 21-Jun-05 5,107 Cidra Data
NS28 21-Jun-05 5,087 Cidra Data
NS05 24-Jul-05 5,099 Cidra Data
NS21 24-Jul-05 5,090 Cidra Data
NS22 24-Jul-05 5,121 Cidra Data
NS24 8-Aug-05 5,123 Cidra Data
NS05 6-Sep-05 5,112 Cidra Data
NS21 6-Sep-05 5,090 Cidra Data
NS13 21-Oct-05 5,102 Cidra Data
NS16 27-Oct-05 5,091 Cidra Data
NS21 2-Nov-05 5,092 Cidra Data
NS24 2-Nov-05 5,122 Cidra Data
NS24 27-Nov-05 5,124 Cidra Data
NS16 4-Dec-05 5,092 Cidra Data
NS28 6-Dec-05 5,116 Cidra Data
6
These pressures are graphically represented in the next figure that is a plot of
pressure by well versus time.
These data indicate pressures dropped slightly during 2005 due to less than
balanced voidage make-up.
A complete listing of data from these surveys is shown in Attachment 4 on the
AOGCC Reservoir Pressure Report form.
7 Northstar Well Pressure Data5,0605,0805,1005,1205,1405,1605,1805,2005,2205,2405,260Oct-01Jan-02Apr-02Jul-02Oct-02Jan-03Apr-03Jul-03Oct-03Jan-04Apr-04Jul-04Oct-04Jan-05Apr-05Jul-05Oct-05Jan-06psiaNS05NS06NS07NS08NS09NS09NS12NS13NS14NS15NS16NS17NS18NS19NS20NS21NS22NS23NS24NS25NS28
8 D) Results and Analysis of Production and Injection Log surveys, tracer surveys, observation well surveys and any other special monitoring. No injection profiles and seven production profiles were obtained in 2005. In addition to the production log in NS24, a borax log was run 03/27/05 identifying a channel. The following table summarized these as well as previous profile results. Well NameWell TypeDateTypeShublik D Ivishak Zone E Ivishak Zone D Ivishak Zone C3 Ivishak Zone C2 Ivishak Zone C1 Ivishak Zone BNS23Injector7/13/2003Memory S/T/P62913181618NS27Injector7/21/2004S/T/P512192638NS13Producer10/4/2004S/T/P/Grad/Ghost/DEFT12591910NS08Producer12/7/2004S/T/P/Gradio/Ghost553195NS09Producer12/11/2004S/T/P/Gradio5429170NS24Producer3/26/2005Memory S/T/P/Gradio43570NS14Producer3/29/2005S/T/P/Gradio/Ghost55432NS19Producer5/16/2005Memory S/T/P100NS14Producer6/26/2005Memory S/T/P/FCAP174538NS06Producer6/30/2005S/T/P/Gradio/Ghost494011NS28Producer8/20/2005Memory S/T/P/DEFT/Ghost100NS05Producer10/7/2005Memory S/T/P60400Percentage of flow to/from interval. Blank intervals are not perforated. A tracer study was initiated in 2004. Unique chemical tracers were injected into the six Northstar gas injection wells (NS17, NS23, NS25, NS27, NS29 and NS31) on April 12, 2004. Gas samples are taken from each producer once every two weeks. Results to date are shown in the following plots.
9
NS05 Tracer Response
0
0.02
0.04
0.06
0.08
0.1
0.12
0.14
0.16
0.18
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb v/v)Tracer Response NS25
Tracer Response NS29
Tracer Response NS23
NS06 Tracer Response
0.00
0.05
0.10
0.15
0.20
0.25
0.30
0.35
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb v/v)Tracer Response NS25
Tracer Response NS27
10
NS07 Tracer Response
0
0.05
0.1
0.15
0.2
0.25
0.3
0.35
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb v/v)Tracer Response NS27
Tracer Response NS29
NS08 Tracer Response
0.00
0.20
0.40
0.60
0.80
1.00
1.20
0 50 100 150 200 250 300 350 400 450 500
Days After InjectionTracer Conc. (ppb)Tracer Response- NS29Tracer Response - NS23Tracer Response - NS 27
11
NS09 Tracer Response
0.00
0.05
0.10
0.15
0.20
0.25
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb)Tracer Response- NS29
Tracer Response - NS23
Tracer Response - NS 27
Tracer Response - NS25
NS12 Tracer Response
0.00
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb)Tracer Response - NS25
12
NS13 Tracer Response
0
0
0
1
1
1
1
1
2
2
2
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc. (ppb)Tracer Response - NS29
Tracer Response - NS23
Tracer Response - NS27
NS14 Tracer Response
0
0
0
0
0
1
1
1
1
1
1
0 50 100 150 200 250 300 350 400 450 500
Days After InjectionTracer Conc. (ppb v/v)Tracer Response - NS29
Tracer Response - NS23
13
N15 Tracer Reponses
0
0
0
0
0
1
1
0 100 200 300 400 500 600 700
Days After InjectionTracer Conc.(ppb v/v)Tracer Reponse - NS29
Tracer Response - NS17
NS16 Tracer Response
0.00
0.10
0.20
0.30
0.40
0.50
0.60
0.70
0.80
0.90
1.00
0 100 200 300 400 500 600 700
Days After injectionTracer Conc. (ppb)Tracer Response - NS29
14
NS18 Tracer Response
0
0.05
0.1
0.15
0.2
0.25
0.3
0 100 200 300 400 500 600 700
Days After injectionTracer Conc. (ppb v/v)Tracer Response - NS17
Tracer Response - NS29
NS19 Tracer Response
0
0.01
0.02
0.03
0.04
0.05
0.06
0.07
0.08
0.09
0.1
0 100 200 300 400 500 600 700
Days After injectionTracer Conc. (ppb v/v)Tracer Response - NS29
This point is believed to be in
error due to proximity of the
NS19 and the fact that NS19 is
still producing at solution GOR.
15
NS22 Tracer Response
0
0.02
0.04
0.06
0.08
0.1
0.12
0.14
0.16
0.18
0 100 200 300 400 500 600 700
Days After injectionTracer Conc. (ppb v/v)Tracer Response - NS31
NS 24 Tracer Responses
0
0
0
0
0
1
1
1
1
0 100 200 300 400 500 600 700
Days After injectionTracer Conc. (ppb v/v)Tracer Response - NS29
Tracer Response - NS23
16
NS28 Tracer Responses
0
0.1
0.2
0.3
0.4
0.5
0.6
0 100 200 300 400 500 600
Days AfterIinjectionTracer Conc.(ppb v/v)Tracer Response - NS29
17
E) Review of pool production allocation factors and issues over the prior
year
Theoretical production is calculated for each Northstar producing well on a daily
basis. A well’s theoretical production is calculated using average wellhead
flowing pressure and hours on production as follows:
ltheoreticaaof
n
whsi
whfproduced QQP
Phours =·-·124
Where:
hoursproduced = hours on line
Pwhf = average wellhead flowing pressure
Pwhsi = shut-in wellhead pressure
n = flow exponent
Qaof = absolute open flow of well with Pwhf = 0 psi
Qtheoretical = theoretical production
The input parameters (n, Qaof and Pwhsi ) for each well are determined from well
test data and systems analysis and are reviewed each time new test data
becomes available.
The actual total production for a day is divided by the summation of the
theoretical production from each well to calculate a daily allocation factor. This
allocation factor is then multiplied by each well’s theoretical production to
calculate allocated production.
Allocation factors for 2005 had an average value of 1.0928 and a median of
1.0932.
18
F) Review of Annual Plan of Operations and Development and Future
Development Plans
Northstar concluded 2005 with six injection wells, seventeen producing wells and
two Class I disposal wells on line. During 2005, the NS05 and NS28 producers
were brought on line.
This drilling activity is summarized in the following table.
Northstar - Year End Wells
Year Count Producers Injectors Class I Disposal
1 NS07 NS27 NS10
2 NS08 NS29
3 NS09 NS31
4 NS13
5 NS14 2002 6 NS15
1 NS07 NS27 NS10
2 NS08 NS29
3 NS09 NS31
4 NS13 NS17
5 NS14 NS23
6 NS15
7 NS24
8 NS18
9 NS22
10 NS06
11 NS12
12 NS19 2003 13 NS20
1 NS07 NS27 NS10
2 NS08 NS29 NS32
3 NS09 NS31
4 NS13 NS17
5 NS14 NS23
6 NS15 NS25
7 NS24
8 NS18
9 NS22
10 NS06
11 NS12
12 NS19
13 NS20
14 NS16 2004 15 NS21
19
Northstar - Year End Wells
Year Count Producers Injectors Class I Disposal
1 NS05 NS17 NS10
2 NS06 NS23 NS32
3 NS07 NS25
4 NS08 NS27
5 NS09 NS29
6 NS12 NS31
7 NS13
8 NS14
9 NS15
10 NS16
11 NS18
12 NS19
13 NS20
14 NS21
15 NS22
16 NS24 2005 17 NS28
MMS wells in bold
Future Development Plans
We recognize the possibility that satellite hydrocarbon accumulations may exist
within expected drilling reach from the island. These targets will be the subject of
additional appraisal. Infill wells and or sidetracks to optimize recovery from the
Northstar pool are also possible.
As of March 2006, three additional infill development wells are planned and one
well is planned for a target outside the current Northstar Producing Area. Two of
the infill wells (NS14A & NS30) have been drilled to TD and are awaiting final
completion. Drilling is ongoing on a third well (NS34) and a fourth well (NS11) is
scheduled.
20
G) Status of Wells Shut-in for 365 days or More (20 AAC 25.115)
No Northstar wells were shut-in for 365 days or more during 2005.
21
Well Status 12/31/05
Bottomhole Locations
Abandoned
Disposal Well
Gas Injector
Not Complete
Oil Producer
Ivishak Boundary
Lease Boundary
Unit Boundary
Township / Range Boundary
Northstar Well Status for
AOGCC Annual Performance Report
E. M. Fueg
3/27/06
Projection Information
Alaska State Plane Zone 4
Clarke 1866, NAD 1927R13ER12E R14ER14ET14N
T13N
R13ER13ER12ER13ER13ER14ER13EADL312808
Y0181
ADL312799
Y0179
ADL312798
Y1645
ADL312809
NS13
NS16
NS26
NS15
NS14A
NS11
NS30
NS12
NS34
NS05
NS06
NS07
NS08
NS09
NS10
NS14
NS17
NS18
NS19
NS20
NS21
NS22
NS23
NS24
NS25
NS27
NS28
NS29
NS31
NS32
bp
LEGEND
T
R
A
N
S - ALA
S
K
A
PIP
ELIN
E
32
MILES
10
Attachment 1: MAP OF NORTHSTAR WELL LOCATIONS
22
Attachment 2
NORTHSTAR FIELD 2005 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
2005 (12/31/05) Full year (1) As of 12/05 (2)
Producers 17 16
Injectors 8 7
NOTES:
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2005
PRODUCTION/INJECTION STATISTICS
Production 2005
Cumulative: Start-
Up through
12/31/05
Oil (BBL) 22,421,483 89,636,187
Gas (MCF) 142,131,405 367,677,560
Water (BBL) 4,361,019 8,231,854
Injection
W ater (BBL) into NS10 & NS32Disposal W ell 4,634,231 9,894,642
Gas (MCF) 165,712,093 466,574,682
Balance
Cum Production (MRB) 113,654 316,950
Cum Injection (MRB) 112,549 315,811
Over/Under (MRB) -1,105 -1,139
DAILY AVERAGE RATE DATA 2005
Production
Oil, BOPD 61,429
Gas, MCF/D 11,948
W ater, BW PD 389,401
Injection
W ater, BW PD 12,697
Gas, MCFPD 454,006
AVER AGE RESERVOIR PRESSURE
Average of surveys obtained in 2005, psia 5,115
23
Changes to the Voidage calculation for years 2001 – 2005 have also changed
the Overview Statistical Summaries filed with past Annual Reports. Updated
Corrected Statistical Summaries for 2001-2004 follow.
NORTHSTAR FIELD 2004 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
2004 (12/31/04)
Producers 15
Injectors 6
NOTES:
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2004
PRODUCTION/INJECTION STATISTICS
Production 2004
Cumulative: Start-Up
through 12/31/04
Oil (BBL) 25,078,477 67,214,704
Gas (MCF) 104,382,882 225,546,155
Water (BBL) 2,817,059 3,870,835
Injection 3,029,981 5,260,411
Water (BBL) into NS10 & NS32Disposal Well 131,501,283 300,862,589
Gas (MCF)
Balance 89,970 203,296
Cum Production (MRB) 89,310 203,262
Cum Injection (MRB) -660 -34
Over/Under (MRB)
DAILY AVERAGE RATE DAT A 2004 (366 days)
Production
Oil, BOPD 68,520
Water, BW PD 7,697
Gas, MCF/D 285,199
Injection
Water, BW PD 8,279
Gas, MCFPD 359,293
AVERAGE RESERVOIR PRESSURE
Average of surveys obtained in 2004, psia 5,178
24
NORTHSTAR FIELD 2003 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
2003 (12/31/03)
Producers 13
Injectors 5
NOTES:
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2003
PRODUCTION/INJECTION STATISTICS
Production 2003
Cumulative: Start-Up
through 12/31/03
Oil (BBL) 22,968,022 42,136,227
Gas (MCF) 70,861,557 121,163,273
Water (BBL) 894,229 1,053,776
Injection
W ater (BBL) into NS10 & NS32Disposal Well 1,193,004 2,230,430
Gas (MCF) 101,268,254 169,361,306
Balance
Cum Production (MRB) 65,512 113,327
Cum Injection (MRB) 68,697 113,953
Over/Under (MRB) 3,185 626
DAILY AVERAGE RATE DAT A 2003
Production
Oil, BOPD 62,926
W ater, BW PD 2,450
Gas, MCF/D 194,141
Injection
W ater, BW PD 3,269
Gas, MCFPD 277,447
AVERAGE RESERVOIR PRESSURE
Average of surveys obtained in 2003, psia 5,164
25
NORTHSTAR FIELD 2002 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
2002 (12/31/01)
Producers 6
Injectors 3
NOTES:
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2002
PRODUCTION/INJECTION STATISTICS
Production 2002
Cumulative: Start-Up
through 12/31/02
Oil (BBL) 17,902,653 19,168,205
Gas (MCF) 47,615,650 50,301,716
Water (BBL) 152,461 159,547
Injection
Water (BBL) into NS10 & NS32Disposal Well 935,119 1,037,426
Gas (MCF) 64,396,277 68,093,052
Balance
Cum Production (MRB) 45,311 47,814
Cum Injection (MRB) 43,087 45,255
Over/Under (MRB) -2,224 -2,559
DAILY AVERAGE RATE DAT A 2002
Production
Oil, BOPD 49,048
Water, BW PD 418
Gas, MCF/D 130,454
Injection
Water, BW PD 2,562
Gas, MCFPD 176,428
AVER AGE RESERVOIR PRESSURE
Average of surveys obtained in 2002, psia 5,115
26
NORTHSTAR FIELD 2001 OVERVIEW STATISTICAL SUMMARY
WELL STATISTICS
2002 (12/31/01)
Producers 2
Injectors 2
NOTES:
(1) Well count data reflects ONLY those wells which contributed to production/injection during the respective year
(2) Active wells as of December 2001
PRODUCTION/INJECTION STATISTICS
Production 2001
Cumulative: Start-Up through
12/31/01
Oil (BBL) 1,265,552 89,636,187
Gas (MCF) 2,686,066 367,677,560
Water (BBL) 7,086 8,231,854
Injection
Water (BBL) into NS10 & NS32Disposal Well 102,307 102,307
Gas (MCF) 3,696,775 3,696,775
Balance
Cum Production (MRB) 2,503 2,503
Cum Injection (MRB) 2,168 2,168
Over/Under (MRB) -335 -335
DAILY AVERAGE RATE DAT A 2001
Production
Oil, BOPD 3,458
W ater, BW PD 19
Gas, MCF/D 7,339
Injection
W ater, BW PD 0
Gas, MCFPD 10,100
Updated 3/15/05 – clp
27 Attachment 3 Voidage Balance by Month of Produced Fluid and Injected Fluids Produced water (MRB) was removed from the Total Voidage (MRB) calculation for years 2001 through 2005. Corrected Voidage Balance by Month of Produced and Injection Fluids charts for 2001 to 2004 are shown below. 2004 MonthOil, MRBFree Gas, MRBWater, MRBTotal Voidage, MRBYearCum, MRBCum since start-up, MRBFormation Gas, MRBImport Gas, MRBTotal Injection, MRBYearCum, MRBCum since start-up, MRBNet Injection, MRBYearCum, MRBCum since start-up, MRBJan-20045,4691,3151846,7836,783120,1104,9322,0396,9716,971120,923187187813Feb-20042,556651913,2069,990123,3162,3391,5063,84510,816124,7686398261,452Mar-20045,0491,7041836,75216,742130,0695,0401,9627,00217,818131,7702501,0761,702Apr-20044,2631,7051725,96922,711136,0374,5221,2845,80623,624137,576-1639131,539May-20045,2373,2942018,53131,242144,5686,7551,4308,18531,809145,761-3465671,193Jun-20044,9063,1752528,08139,323152,6496,4148787,29239,101153,053-789-222404Jul-20044,8533,8022788,65647,978161,3057,0059017,90647,007160,960-749-971-345Aug-20043,4492,0332115,48353,461166,7874,2871,3025,58952,596166,548106-865-239Sep-20045,1333,6273248,76062,221175,5477,0171,8448,86261,458175,410102-763-137Oct-20045,1713,5483748,71970,940184,2676,9621,7568,71970,176184,129-1-764-138Nov-20044,9624,1683309,13080,071193,3977,4501,9169,36679,542193,494235-52997Dec-20045,1684,7313689,89989,970203,2968,1471,6219,76889,310203,262-131-660-342004 Totals56,21733,7532,96689,97070,87018,44089,310-660Produced FluidsInjected FluidsNet Injection (Injection - Production) Note: MRB stands for thousand reservoir barrels.
28 2003 MonthOil, MRBFree Gas, MRBWater, MRBTotal Voidage, MRBYearCum, MRBCum since start-up, MRBFormation Gas, MRBImport Gas, MRBTotal Injection, MRBYearCum, MRBCum since start-up, MRBNet Injection, MRBYearCum, MRBCum since start-up, MRBJan-20033,3861,394274,7804,78052,5943,6311,5655,1955,19550,451416416-2,143Feb-20034,4531,237595,69010,47058,2844,1911,2155,40610,60155,856-285131-2,428Mar-20034,3731,837896,21016,67964,4944,7191,6816,40017,00162,256190321-2,238Apr-20033,0301,156524,18620,86668,6803,1341,7494,88421,88467,1406971,019-1,540May-20034,6221,422766,04526,91174,7254,4691,0395,50827,39272,647-537481-2,078Jun-20034,7871,656716,44333,35481,1684,8281,6656,49433,88679,14151532-2,027Jul-20034,2641,570645,83439,18887,0024,3711,6656,03639,92285,177202734-1,825Aug-20034,2581,125705,38344,57192,3853,9361,8135,74845,67190,9263661,100-1,459Sep-20034,6150954,61549,18697,0002,9842,0165,00050,67195,9263851,485-1,074Oct-20035,1989361186,13355,320103,1344,3842,1646,54757,218102,4734141,899-660Nov-20034,2669011195,16760,486108,3013,7281,9385,66662,884108,1394992,398-161Dec-20034,0929341025,02665,512113,3273,6452,1685,81368,697113,9537873,1856262003 Totals51,34514,16894265,51248,02020,67768,6973,185Net Injection (Injection - Production)Injected FluidsProduced Fluids Note: MRB stands for thousand reservoir barrels.
29 2002 MonthOil, MRBFree Gas, MRBWater, MRBTotal Voidage, MRBYearCum, MRBCum since start-up, MRBFormation Gas, MRBImport Gas, MRBTotal Injection, MRBYearCum, MRBCum since start-up, MRBNet Injection, MRBYearCum, MRBCum since start-up, MRBJan-20022,405042,4052,4054,9091,5156792,1942,1944,362-211-211-546Feb-20022,198022,1984,6037,1071,1095861,6953,8896,057-504-715-1,050Mar-20023,378023,3787,98210,4851,9771,4223,3997,2889,45620-694-1,029Apr-20022,376002,37610,35712,8611,5551,2912,84610,13412,302471-224-559May-20022,3558912,44412,80215,3051,5426282,17012,30414,473-274-498-833Jun-20023,97232744,30017,10119,6052,9737053,67815,98218,151-622-1,119-1,454Jul-20023,853714104,56721,66824,1723,3171,1674,48420,46722,635-83-1,202-1,537Aug-20024,0131,043185,05626,72429,2283,7471,0714,81825,28427,453-238-1,440-1,775Sep-20022,949476153,42530,14932,6532,4449763,42028,70430,873-5-1,445-1,780Oct-20024,0401,042365,08235,23137,7343,7919194,71033,41535,583-372-1,817-2,152Nov-20023,6491,192304,84140,07242,5753,6728684,54037,95540,123-301-2,117-2,452Dec-20023,7291,510375,23945,31147,8144,0351,0975,13243,08745,255-107-2,224-2,5592002 Totals38,9196,39216145,31131,67611,41143,087-2,224Produced FluidsInjected FluidsNet Injection (Injection - Production) Note: MRB stands for thousand reservoir barrels.
30 2001 MonthOil, MRBFree Gas, MRBWater, MRBTotal Voidage, MRBYearCum, MRBCum since start-up, MRBFormation Gas, MRBImport Gas, MRBTotal Injection, MRBYearCum, MRBCum since start-up, MRBNet Injection, MRBYearCum, MRBCum since start-up, MRBJan-200100000000000000Feb-200100000000000000Mar-200100000000000000Apr-200100000000000000May-200100000000000000Jun-200100000000000000Jul-200100000000000000Aug-200100000000000000Sep-200100000000000000Oct-20011001111-45-44-44-44-45-45-45Nov-200169801698699699390200589545545-109-154-154Dec-20011,804061,8042,5032,5031,1504741,6232,1682,168-181-335-3352001 Totals2,503072,5031,5406292,168-335.0Produced FluidsInjected FluidsNet Injection (Injection - Production) Note: MRB stands for thousand reservoir barrels.
