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Home My WebLink About2003 Northstar Oil PoolThomas B. Gray Northstar Delivery Manager BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Phone: (907) 564-5334 Fax: (907) 564-5200 Email graytbCbp,com Web' www,bp.com March 31,2004 John K. Norman Commissioner and Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Northstar Field, Northstar Oil Pool Annual Reservoir Performance Report Dear Mr. Norman BP Exploration (Alaska) Inc., as operator of the Northstar Unit, hereby submits the attached Annual Reservoir Performance Report in accordance with the requirements of Conservation Order 458A and 20 AAC 25.115. This report covers the period January 1 through December 31,2003. The repor1 is organized according to the outline provided in Rule 7 of the conservation order. Item f, Future develocment clans, and g, Review of Annual Plan of Ocerations and Develocment have been combined into a single item titled Review of Annual Plan of Ocerations and Develocment and Future Develocment clans. The final section addresses 20 AAC 25.115. BP reserves the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Sincerely, ~.s=Thomas B. Gray TBG/jdg Jeff Walker, MMS Mark Myers, DNR Bob Gage, Murphy R. L. Skillern, BP File cc: Annual Reservoir Performance Report Northstar Field Northstar Oil Pool January 2003 through December 2003 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 2003 Overview Statistical Summary 2 A) Progress of Enhanced Recovery Project During 2003, 7 additional production wells (NS24, NS18, NS22, NS06, NS12, NS19, and NS20) and 2 gas injection wells (NS17 and NS23) were brought on line. Average oil production was 62,926 bopd and average miscible gas injection was 277.5 mmscfd. Miscible injection gas consisted of produced formation gas containing NGLs and imported make-up gas from Prudhoe Bay. The location of these wells and other wells that have been added to date are shown in Attachment 1. Production and injection statistics are summarized in Attachment 2. During 2003, much of the voidage deficit was made up. Gas compressor problems that limited gas injection capacity in 2002 were minimized. Currently, the reservoir has an overall voidage replacement ratio of 0.99. History matched reservoir simulator model results have been provided to the AOGCC as part of the Submission of Proposed Interim Tract Participation Factors for the Northstar Participating Area. Additional drilling and laboratory work are ongoing and will be used to continue to refine the reservoir simulator model. 3 B) Voidage Balance by Month of Produced Fluid and Injected Fluids Produced Fluids Injected Fluids Net Injection (Injection - Production) Month Oil, MRB Free Gas, MRB Water, MRB Total Voidage, MRB 2003 Cum, MRB Cum since start-up, MRB Formation Gas, MRBImport Gas, MRBTotal Injection, MRB2003 Cum, MRB Cum since start-up, MRB Net Injection, MRB2003Cum, MRB Cum since start-up, MRB January-03 3,361 1,348 274,7364,73652,9133,5561,5445,1005,10050,450364364-2,464 February-03 4,4211,189595,66910,40558,5824,1051,1935,29710,39755,747-371-8-2,835 March-03 4,3411,777896,20616,61164,7884,6221,6666,28816,68562,0358274-2,753 April-03 3,008 1,117524,17720,78868,9653,0701,7474,81721,50266,852639714-2,114 May-03 4,589 1,370766,03526,82375,0004,3771,0405,41726,91972,269-61896-2,731 June-03 4,752 1,597716,42133,24381,4214,7291,6376,36633,28578,635-5441-2,786 July-03 4,233 1,516645,81439,05787,2344,2811,6615,94239,22784,577128170-2,658 August-03 4,2271,080705,37744,43492,6113,8551,7915,64644,87390,223270439-2,388 September-03 4,5820954,67649,11097,2872,9231,9794,90149,77495,124225664-2,163 October-03 5,1608901186,16755,278103,4554,2932,1226,41656,190101,540248913-1,915 November-03 4,2348611195,21560,492108,6693,6511,9045,55561,745107,0953401,253-1,574 December-03 4,0628941025,05965,551113,7283,5702,1305,70067,445112,7956411,894-933 2003 Totals 50,970 13,639 94265,551 47,03120,41367,445 1,894 Note: MRB stands for thousand reservoir barrels 4 C) Summary and Analysis of reservoir pressure surveys within the pool Static bottom hole pressures collected in 2003 are summarized below. Well Date Extrapolated Pressure at -11,100' TVDss Datum, psia Data Source NS24 6-Jan-03 5,156 Cidra Data NS07 14-Jan-03 5,150 Cidra Data NS24 14-Jan-03 5,162 Cidra Data NS14 14-Jan-03 5,167 Cidra Data NS15 14-Jan-03 5,124 Cidra Data NS13 14-Jan-03 5,161 Cidra Data NS09 15-Jan-03 5,159 Cidra Data NS18 23-Jan-03 5,131 Cidra Data NS22 3-Feb-03 5,171 Cidra Data NS07 7-Mar-03 5,122 Cidra Data NS14 7-Mar-03 5,161 Cidra Data NS13 7-Mar-03 5,161 Cidra Data NS15 7-Mar-03 5,104 Cidra Data NS09 7-Mar-03 5,191 Cidra Data NS24 7-Mar-03 5,160 Cidra Data NS22 7-Mar-03 5,154 Cidra Data NS17 11-Mar-03 5,123 Static Survey NS07 23-Apr-03 5,163 Cidra Data NS15 23-Apr-03 5,149 Cidra Data NS13 24-Apr-03 5,179 Cidra Data NS06 24-Apr-03 5,192 Cidra Data NS22 24-Apr-03 5,171 Cidra Data NS24 24-Apr-03 5,177 Cidra Data NS14 24-Apr-03 5,198 Cidra Data NS19 7-May-03 5,146 Cidra Data NS12 18-May-03 5,148 Cidra Data NS23 26-Jun-03 5,146 Static Survey NS16 14-Jul-03 5,154 Cidra Data NS20 2-Aug-03 5,144 Static Survey NS13 12-Aug-03 5,171 Cidra Data NS14 12-Aug-03 5,215 Cidra Data NS22 19-Aug-03 5,165 Cidra Data NS24 18-Sep-03 5,178 Cidra Data NS13 5-Sep-03 5,179 Cidra Data 5 Well Date Extrapolated Pressure at -11,100' TVDss Datum, psia Data Source NS22 5-Sep-03 5,167 Cidra Data NS06 5-Sep-03 5,141 Cidra Data NS12 7-Sep-03 5,119 Cidra Data NS19 5-Sep-03 5,112 Cidra Data NS24 30-Sep-03 5,180 Cidra Data NS13 10-Nov-03 5,185 Cidra Data NS15 10-Nov-03 5,135 Cidra Data NS14 16-Nov-03 5,206 Cidra Data NS16 18-Nov-03 5,185 Cidra Data NS06 5-Dec-03 5,187 Cidra Data NS12 5-Dec-03 5,151 Cidra Data NS13 5-Dec-03 5,211 Cidra Data NS14 5-Dec-03 5,231 Cidra Data NS15 5-Dec-03 5,158 Cidra Data NS16 5-Dec-03 5,220 Cidra Data NS19 5-Dec-03 5,122 Cidra Data NS22 5-Dec-03 5,173 Cidra Data NS24 5-Dec-03 5,232 Cidra Data These pressures are graphically represented in the next figure that is a plot of pressure by well versus time. 6 Northstar Reservoir Pressure by Well50805100512051405160518052005220524010/31/2001 0:0011/30/2001 9:3612/30/2001 19:121/30/2002 4:483/1/2002 14:244/1/2002 0:005/1/2002 9:365/31/2002 19:127/1/2002 4:487/31/2002 14:248/31/2002 0:009/30/2002 9:3610/30/2002 19:1211/30/2002 4:4812/30/2002 14:241/30/2003 0:003/1/2003 9:363/31/2003 19:125/1/2003 4:485/31/2003 14:247/1/2003 0:007/31/2003 9:368/30/2003 19:129/30/2003 4:4810/30/2003 14:2411/30/2003 0:0012/30/2003 9:361/29/2004 19:12Cumulative Voidage Balance (MMSCF)NS06NS07NS08NS09NS12NS13NS14NS15NS16NS17NS18NS19NS20NS22NS23NS24NS27NS29NS31 7 8 These data indicate pressures have risen later in the year due to injection makeup and voidage replacement. The average of the pressures taken during the last survey in December of 2003 was 5187 psia. A complete listing of data from these surveys is shown in Attachment 2 on the AOGCC Reservoir Pressure Report form. D) Results and Analysis of Production and Injection Log surveys, surveys, observation well surveys and any other special monitoring tracer . ne injection survey was obtained in 2003. A spinner/temperature/pressure Well Name Type Date Type Comments O survey was run on the NS23 injector in July, 2003. NS23 Injector 7/13/03 STP Injection splits: 6% TSHD, 29% TZE, 13% TZD, 18% TZC3, 16% TZC2, 18% TZC1. There are plans to initiate a tracer study in 2004 and a more extensive production/injection survey campaign. Leak detection logs were run on NS27 and NS29 in an attempt to find the source of T x IA communication. Leaks were found in both wells at the packer. Attempts to patch the leaks were unsuccessful and each well had the tubing replaced this fall. A vertical pulse test was conducted on the NS06 producer. Using the downhole Cidra pressure gauge and a memory pressure gauge hung below an IBP set between 2 sets of perforations, the well was brought online and shut in repeatedly. The data from both pressure gauges was analyzed to determine the vertical permeability. This data confirms that there are no vertical barriers to permeability in the vicinity of the NS06 well. 9 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 asis. A well’s theoretical production is calculated using average wellhead ure our oduc fo b flowing press and h s on pr tion as llows: ltheoreticaaof n whfproduced QQP Phours =×       −× 124 whsi  Where: head pressure = flow exponent he actual total production for a day is divided by the summation of the eoretical 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 2003 had an average value of 1.036 and a median of 1.032. hoursproduced = hours on line Pwhf = average wellhead flowing pressure Pwhsi = shut-in well n 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. T th 10 Review of AF) nnual Plan of Operations and Development and Future Development Plans 9 08, NS09, NS12, NS13, S14, NS15, NS18, NS19, NS20, NS22, and NS24) and one Class I disposal ell (NS10) online. During 2003, NS17 and NS23 injectors and NS18, NS22, NS06, NS12, NS19, and NS20 producers were brought on line. In addition to the wells that were completed and brought on line in 2003, one well was drilled, completed, and perforated but not brought on line because of an ice lug in the tubing (NS16), one Class 1 disposal well was drilled but not d (NS32), one well was drilled into the intermediate formation (NS25), d one well (NS21) had the surface hole drilled in 2002 but no further drilling g and completing the NS25 injector, the NS21 S32 Class 1 disposal well. his drilling activity is summarized in the following table. Northstar concluded 2003 with five injection wells (NS17, NS23, NS27, NS2 and NS31), thirteen producing wells (NS06, NS07, NS N w p complete an yet. The plan for 2004 is to finish drillin producer, and the N T 11 Northstar - Year End Wells Count ProduceYear rs 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 2003 8 NS18 9 NS22 10 NS06 11 NS12 12 NS19 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 (Planned) 15 NS21 MMS wells in bold 12 De We also recognize the y exist within e ected d ach from the island. These targets will be the subject of additional appraisal. Future velopment Plans possibility that satellite hydrocarbon accumulations ma rilling rexp 13 G) Status of Wells Shut-in for 365 days or More (20 AAC 25.115) here were no wells shut-in for all of 2003. T 14 Attachment 1: MAP OF NORTHSTAR WELL LOCATIONS 15 Ivishak Boundary Lease Boundary Unit Boundary Township / Range Boundary Northstar Well Status for AOGCC Annual Performance Report E. M. Fueg 1/26/04 Projection Information Alaska State Plane Zone 4 Clarke 1866, NAD 1927R13ER12E R14ER14ET14N T13N R13ER13ER12ER13ER13ER14E ADL312799 Y0179 ADL312798 ADL312808 Y0181 ADL312809 ADL355001 NS08 NS24 NS21 NS29 NS13NS16 NS31 NS32 NS22 NS23 NS20 NS18 NS14 NS15 NS27NS07 NS25 NS10 NS12 NS09 NS06 NS19 NS17 bp LEGEND T R A N S - A L A S K A PIP E LIN E 32 MILES 10 Well Status 12/31/03 Bottomhole Locations A D GI NC OP Y1645 Attachment 2: 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 PRODUCTION/INJECTION STATISTICS Production 2003 Cumulative: Start-Up through 12/31/03 Oil (BBL) ,968,022 42,136,898 Gas (MCF) 70,861,557 121,163,273 Water (BBL) 894,229 1,053,776 Injection Water (BBL) into NS10 Disposal Well 1,193,004 2,230,430 Gas (MCF) 101,268,254 169,361,306 Balance Cum Production (MRB) 65,551 113,728 Cum Injection (MRB) 67,445 112,795 Over/Under (MRB) 1,894 -933 AVERAGE RATE DATA 2003 22 Production Oil, BOPD 62,926 Gas, MCF/D 194,141 Water, BWPD 2,450 Injection Water, BWPD 3,269 Gas, MCFPD 277,447 AVERAGE RESERVOIR PRESSURE Average of surveys obtained in 2003, psia 5,164 16 Page 1 of 26. Oil Gravity:428. Well Name and Number:9. API Number 50-XXX-XXXXX-XX-XX10. Oil (O) or Gas (G)11. AOGCC Pool Code12. Final Test Date13. Shut-In Time, Hours14. Press. Surv. Type (see instructions for codes)15. B.H. Temp.16. Depth Tool TVDss17. Final Observed Pressure at Tool Depth18. Datum TVDss (input)19. Pressure Gradient, psi/ft.20. Pressure at Datum (cal)NS24 50-029-23111-00-00 O 590100 01/06/03 Initial Survey OTHER 250 10427 4863 0.413 5141NS07 50-029-23081-00-00 O 590100 01/14/03 154 OTHER 253 10526 5005 0.227 5135NS24 50-029-23111-00-00 O 590100 01/14/03 158 OTHER 250 10427 4995 0.227 5147NS14 50-029-23026-00-00 O 590100 01/14/03 163 OTHER 245 10458 5007 0.227 5152NS15 50-029-23073-00-00 O 590100 01/14/03 163 OTHER 250 10580 4991 0.227 5109NS13 50-029-23017-00-00 O 590100 01/14/03 166 OTHER 247 10388 4985 0.227 5146NS09 50-029-23052-00-00 O 590100 01/15/03 167 OTHER 250 10451 4997 0.227 5144NS18 50-029-23102-00-00 O 590100 01/23/03 Initial Survey OTHER 253 10540 4891 0.402 5116NS22 50-029-23128-00-00 O 590100 02/03/03 Initial Survey OTHER 251 10590 5040 0.227 5156NS07 50-029-23081-00-00 O 590100 03/07/03 17 OTHER 253 10526 4977 0.227 5107NS14 50-029-23026-00-00 O 590100 03/07/03 19 OTHER 245 10458 5001 0.227 5146NS13 50-029-23017-00-00 O 590100 03/07/03 21 OTHER 247 10388 4985 0.227 5146NS15 50-029-23073-00-00 O 590100 03/07/03 21 OTHER 250 10580 4971 0.227 5089NS09 50-029-23052-00-00 O 590100 03/07/03 22 OTHER 250 10451 5029 0.227 5176NS24 50-029-23111-00-00 O 590100 03/07/03 22 OTHER 250 10427 4992 0.227 5145NS22 50-029-23128-00-00 O 590100 03/07/03 24 OTHER 251 10590 5023 0.227 5139NS17 50-029-23113-00-00 GI 590100 03/11/03 Initial Survey SBHP 252 11100 5108 0.000 5108NS07 50-029-23081-00-00 O 590100 04/23/03 217 OTHER 255 10526 5018 0.227 5148NS15 50-029-23073-00-00 O 590100 04/23/03 168 OTHER 253 10580 5016 0.227 5134NS13 50-029-23017-00-00 O 590100 04/24/03 218 OTHER 250 10388 5002 0.227 5164NS06 50-029-23088-00-00 O 590100 04/24/03 171 OTHER 240 10487 5038 0.227 5177NS22 50-029-23128-00-00 O 590100 04/24/03 231 OTHER 241 10590 5040 0.227 5156NS24 50-029-23111-00-00 O 590100 04/24/03 258 OTHER 239 10427 5009 0.227 5162NS14 50-029-23026-00-00 O 590100 04/24/03 232 OTHER 242 10458 5038 0.227 5183NS19 50-029-23122-00-00 O 590100 05/07/03 Initial Survey OTHER 252 10665 4961 0.391 5131NS12 50-029-23091-00-00 O 590100 05/18/03 Initial Survey OTHER 238 10594 4925 0.411 5133NS23 50-029-23146-00-00 O 590100 06/26/03 Initial Survey SBHP 255 11100 5131 0.406 5131NS16 50-029-23096-00-00 O 590100 07/14/03 Initial Survey OTHER 241 10526 4898 0.420 5139NS20 50-029-23118-00-00 O 590100 08/02/03 Initial Survey SBHP 252 11052 5118 0.227 5129Northstar Unit Northstar Field/Northstar Oil Pool -11,100 0.79BP Exploration (Alaska) Inc. P.O. Box 196612, Anchorage, Alaska 99519-66123. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 7. Gas Gravity:STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONRESERVOIR PRESSURE REPORT1. Operator:2. Address:Form 10-412 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 61- U50: ~o ~a.. ~w 00: 6w <{f=0: ~<{~ ~fi:(1)~LU (1)<{00 LLZW 000:LU° a..1-00 <{<{0:~ (9 - 00 ~> ~o: Ow <{(1) ~W ~o:~ <{ (\I"6(\IQ)0)~(1. "'(/) ~ -0 -0 ~ N o eQ)0. () (\I.-ID'i'01~01011 jl Gilal l~ ~I ~I- (\1 .- ID ID 01 .- )( o m O n: u .= -;-~(/)~ ~ c .2 ro '0 -0.>< w 0. m 0> E co z 0) (I) co 0) -J 5 - .2 => O o Q. -0 c: "' -0 ""di iL '3" :i;..~(!)ato:i;..~(!)(/)cIS(!)£ Qj () c: e 0) "Q5 a: E ~ 10 o Lri O o 11. '6 :0 '(;j.c 1:: 0 z-"C -0; ir :0 '(;j .c 1:: 0 z ~~ N"'0.,..n - "c ~ 10 0.c t: O7 1- c ~ , ~ -o E :I: 00 - (1) .E ~i= l :i ci. 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