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Home My WebLink About2010 Northstar Oil Pool} by Emeka Emembolu Head of Base Management, Alaska Strategic Performance Unit March 28, 2011 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P 0. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 Dan Seamount RECEIVE Commissioner Alaska Oil and Gas Conservation Commission MAR 3 1 20fl 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 W-ke (Td & gas Cons. Gp9i iWn Annorago RE: Northstar Field, Northstar Oil Pool Annual Reservoir Performance Report Dear Mr. Seamount: 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, 2010 through December 31, 2010. The report is organized according to the outline provided in Rule 7 of the conservation order. Item f, Future development plans, and g, Review of Annual Plan of Operations and Development have been combined into a single item titled Review of Annual Plan of Operations and Development and Future Development plans. 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. Please contact John Garing (564-5167) or Mark Sauve (564-4660) if there are any questions. Sincerely, r r� Emeka Emembolu Phone:(907) 564-5536 Fax: (907) 564-4440 Email: Emeka.Emembolu@bp.com Web: www.bp.com cc: Jeff Walker, BOEMRE Kevin Banks, DNR Bob Gage, Murphy R. L. Skillern, BP File Annual Reservoir Performance Report Northstar Field Northstar Oil Pool January 2010 through December 2010 March, 2010 Table of Contents A. Progress of Enhanced Recovery Project and Reservoir Management Summary B. Voidage Balance by Month of Produced Fluids and Injected Fluids and Cumulative Status 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 2010 Overview Statistical Summary Attachment 3: Northstar Field 2010 Reservoir Pressure Report, Form 10-412 0' A) Progress of Enhanced Recovery Project and Reservoir Management Summary During 2010, no new wells were drilled or sidetracked in the Northstar Unit. The location of all the wells in the Northstar Unit is shown in Attachment 1. Production and injection statistics are summarized in Attachment 2. Average daily oil production from the Northstar field was 16,804 bopd and average daily gas injection was 503.8 mmscfpd. The reservoir voidage balance values reported do not include oil production from satellite well NS34A or Kuparuk zone production from well NS08. During 2010, gas injection was calculated to be 5,985 thousand -reservoir barrels (MRB) more than reservoir voidage. At year end, the reservoir overall cumulative voidage replacement ratio was 1.015. The average of reservoir pressure control for 2010 was 5,103 psia. CC' B) Voidage Balance by Month of Produced Fluid and Injected Fluids - 2010 2010 Month Jan -2010 Feb -2010 Mar -2010 Apr -2010 May -2010 Jun -2010 Jul -2010 Aug -2010 Sep -2010 Oct -2010 Nov -2010 Dec -2010 10 Totals Oil, MRB 1,454 1,326 1,341 1,001 1,104 1,108 849 403 1,070 1,113 945 1,124 Produced Fluids I Injected Fluids I Year Total Year Cum since Free Gas, Water, Voidage, Year start-up, MRB MRB MRB Cum, MRB MRB 10,981 472 12,435 12,435 798,266 9,920 458 11,246 23,681 809,513 10,908 421 12,249 35,930 821,762 8,086 386 9,087 45,017 830,849 8,452 461 9,556 54,573 840,405 8,618 433 9,726 64,299 850,131 7,182 379 8,030 72,330 858,161 3,404 159 3,807 76,137 861,968 9,505 465 10,575 86,712 872,544 10,310 481 11,423 98,135 883,966 8,194 421 9,139 107,274 893,106 10,611 446 11,735 119,009 904,840 106,172 4,985 119,009 I Injected Fluids I 12 Net injection (Injection - Production) Net Year Cum since Year Cum since Formation Import Total Injection, Cum, start-up, Gas, MRB Gas, MRB MRB MRB MRB 11,941 744 12,685 12,685 806,400 10,796 714 11,510 24,195 817,910 11,791 820 12,611 36,806 830,522 8,744 1,148 9,892 46,698 840,414 9,182 1,701 10,883 57,581 851,296 9,352 1,619 10,971 68,551 862,267 7,742 491 8,234 76,785 870,500 3,669 262 3,931 80,716 874,431 10,204 628 10,832 91,548 885,264 11,046 694 11,740 103,288 897,003 8,819 571 9,390 112,678 906,394 11,355 960 12,315 124,994 918,709 114,642 10,352 124,994 12 Net injection (Injection - Production) Net Year Cum since Injection, Cum, start-up, MRB MRB MR 250 250 8,134 263 514 8,398 362 876 8,760 805 1,681 9,565 1,326 3,007 10,891 1,244 4,252 12,136 204 4,455 12,339 124 4,579 12,463 257 4,836 12,720 317 5,153 13,037 251 5,404 13,288 581 5,985 13,869 C) Summary and Analysis of reservoir pressure surveys within the pool Static bottom hole pressures collected in 2010 are summarized below. Well Date Extrapolated Pressure at -11,100' TVDss Datum, psia Data Source NS08 2/10/10 5108 OTHER NS08 2/22/10 5111 OTHER i NS08 3/21/10 5113 OTHER NS08 5/16/10 5125 OTHER +NS08 9010 5126 OTHER NS08 102/10 5124 OTHER NS08" 12/4/10 4451" OTHER NS09 1127/10 5093 SBHP NS13 5/21/10 5121 OTHER NS13 9/12/10 5124 OTHER ' NS13 12/17/10 5120 OTHER NS14A 2/6110 5096 OTHER NS14A 3114/10 5094 OTHER NS14A 6/30/10 5080 OTHER i NS14A 82/10 5043 OTHER NS16A 1128/10 5115 SBHP NS18 1128110 5117 SBHP NS19 1129/10 5060 SBHP NS21 528/10 5108 OTHER NS21 920/10 5104 OTHER `NS21 10/5/10 5089 OTHER NS24 9/30/10 5125 SBHP j NS28 3/17/10 5096 OTHER I NS28 62/10 5103 OTHER NS28 9/30/10 5095 OTHER 'NS28 12/31/10 5087 OTHER j NS34A 2111/10 4958 OTHER j NS34A 6/3/10 5000 OTHER I NS34A 823/10 5016 OTHER NS34A 12/3/10 4957 JOTHER • Datum for Kuparuk Reservior is 9000' TVDSS These pressures are graphically represented in the next figure that is a plot of pressure by well versus time. These data show a slight decease of reservoir pressures during 2010. The average Northstar field reservoir pressure for 2010 is 5,103 psia, down some 9 psi from the 2009 average. Please note that well NS -34A is a satellite well to the main field and the reservoir pressure reported from NS08 in December is from the Kuparuk Reservoir. A complete listing of data from these surveys is shown in Attachment 3 on the AOGCC Reservoir Pressure Report form. 5 Northstar Well Pressure Data --NS06 0 NS07 —X NS08 —SIE--NS09 —0 NS12NS13 —NS14 -- —NS15 - NS16 NS17 NS18 NS19 NS20 NS21 - NS22 5250 - Q U) 5200 NS23 NS24--*—NS25 --- NS27 NS29 NS31 --- NS05—M—NS28—l—NS11 -- —NS30 0 0 T 5150 E D ca 3 5100 -I d i , a i 0 N 5050 4) c 5000 r N N N N M M M M d d d �t In Ln to L[) (U (D (p (0 r -r- r CO O MM O O O O O O O O - O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O Q75 U Q-5 U Q 5 t Q75 U � Q 7 (..) Q 7 U c Q 5 U Q 7 (�j Q75 U Q U Q - O Q O Q O Q -O-)Q O-)Q)O Q O-�Q O Q - O-`�QO i D) Results and Analysis of Production and Injection log surveys, tracer surveys, observation well surveys and any other special monitoring. Two production profiles and zero injection profiles were obtained in 2010. The following table summarized these as well as previous profile results. Did not log across entire perforation interval; therfore, unknown contibutions from open zones below logged interval are indicated by -. Gas tracer status: The gas tracer program, initiated in 2004, was concluded in 2008 and no further updates are required for this reporting period. 7 Percenta e of flow from/to interval. Blank intervals are not erforated. Well Name Well Type Date Log Type Ivishak Shublik D Zone E Ivishak Zone D Ivishak Zone C3 Ivishak Zone C2 Ivishak Zone C1 Ivishak Zone B NS23 Injector 7/13/2003 Memory S/T/P 6 29 13 18 16 18 NS27 Injector 7/21/2004 S/T/P 5 12 19 26 38 NS13 Producer 10/4/2004 S/T/P/G radio/G host 12 59 19 10 NS08 Producer 12/7/2004 S/T/P/Gradio/Ghost/DEFT 55 31 9 5 NS09 Producer 12/11/2004 S/T/P/Gradio 1 54 29 17 0 NS24 Producer 3/26/2005 1 Memory S/T/P/Gradio 43 57 0 NS24 Producer 3/27/2005 RST/Borax-PNL NS14 Producer 3/29/2005 S/T/P/Gradio/Ghost 55 43 2 NS19 Producer 5/16/2005 Memory S/T/P 100 NS14 Producer 6/26/2005 Memory S/T/P/FCAP 17 45 38 NS06 Producer 6/30/2005 S/T/P/Gradio/Ghost 49 40 11 NS28 Producer 8/20/2005 Memory S/T/P/DEFT/Ghost 100 NS05 Producer 10/7/2005 Memory S/T/P 60 40 0 NS16 Producer 5/5/2006 S/T/P/Gradio/Ghost 43 42 15 NS11 Producer 12/20/2006 Memory S/T/P/DEFT/Ghost 82 18 NS09 Producer 12/22/2006 S/T/P/Gradio 65 30 5 NS08 Producer 4/10/2007 Memory S/T/P 20 0 27 53 NS24 Producer 4/11/2007 Memory S/T/P 50 50 NS19 Producer 4/24/2007 S/T/P/Gradio/GhosVDEFT 98 2 NS13` Producer 7/14/2007 Memory S/T/P/Gradio 0 100 - - NS15` Producer 5/10/2008 Memory S/T/P/Gradio 87 13 NS09 Producer 8/29/2008 Baker Gas/Fluid View NS24 Producer 8/30/2008 Baker Gas/Fluid View NS16A Producer 9/12/2008 S/T/P/Gradio/GhosVDEFT 100 0 NS16A Producer 9/16/2008 S/T/P/Gradio/GhosVDEFT 100 0 NS16A Producer 10/21/2008 S/T/P/Gradio/GhosVDEFT 100 0 NS24 Producer 12/3/2008 S/F/P/Gradio/Ghost 100 0 NS24 Producer 12/5/2008 S/T/P/Gradio/Ghost 0 100 0 NS16A Producer 2/12/2009 S/T/P/Gradio/Ghost/DEFt 100 0 NS05 Producer 2/14/2009 S/r/P/Gradio/Ghost/DEFT 73 27 NS19 Producer 4/19/2009 S/F/P/Gradio/GhosVDEFT 96 4 NS16A Producer 4/20/2009 S/-F/P/Gradio/GhosVDEFT 90 10 NS33A Producer 11/12/2009 Neutron WF log and Memory S/T/P 100 NS05 Producer 11/16/2009 Memory S/T/P/Gradio/Ghost/DEFT 70 30 NS30 Producer 11/19/2009 Memory S/T/P/Gradio/Ghost/ DEFT 50 5o NS11 Producer 11/21/2009 Memory S/T/P/Gradio/DEFT 80 20 NS21 Producer 12/13/2009 Memory S/T/P/Gradio/GhosVDEFT 100 NS20 Producer 12/15/2009 Memory S/T/P/Gradio/GhosVDEFT 50 50 NS22 Producer 12/16/2009 Memory S/T/P/Gradio/GhosVDEFT 60 40 NS34A Producer 12/21/2009 Memory S/T/P/Gradio/GhosVDEFT 1 100 NS06 Producer 5/4/2010 S/T/P/Gradio/GhosVDEFT 1 65 1 30 5 NS06 Producer 10/19/2010 S/T/P/Gradio/GhosVDEFT I 1 0 1 70 1 30 Did not log across entire perforation interval; therfore, unknown contibutions from open zones below logged interval are indicated by -. Gas tracer status: The gas tracer program, initiated in 2004, was concluded in 2008 and no further updates are required for this reporting period. 7 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: n hoursproduced Pwhf _ X 1 — X Qaof — Qtheoretical 24 PWhsi Where: hoursptoduced = hours on line P,hf = average wellhead flowing pressure PWhS; = 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 PWhS;) 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. Northstar field allocation factors for 2010 averaged 1.18 for oil, 1.04 for water and 0.99 for gas. 0 F) Review of Annual Plan of Operations and Development and Future Development Plans Northstar concluded 2010 with six gas injection wells, twenty-one producing wells and two Class I disposal wells available for production. histoncai wen count Tor Tne -. Count Producers Iasi two ears are sum .Wells Year Injectors Class I Disposal 1 NS05 NS17 NS10 2 NSO6 NS23 NS32 3 NS07 NS25 4 5 NS08 NS27 NS09 NS29 6 NS11 NS31 7 NS12 8 NS13 0) 9 10 NS14A NS15 - 11 NS16 --^- CV 12 NS18 �— -- 13 NS19 14 NS20 15 NS21 16 NS22 ! 17 NS24 18 NS28 19 20 NS30 NS33A NS34A 21 1 NS05 NS17 -- --- ---- ----- NS23 NS10 2 3 4 5 6 NS06 NS32 NS07 NS25 NS08 NS27 NS09 NS29 NS11 NS31 7 NS12 8 9 NS13 NS14A O p 10 11 NS15 NS16 CV 12 NS16 13 NS19 NS20 14 _ 15 NS21 _ ^ 16 17 NS22 NS24 _ NS28 _---18 19 NS30 20 NS33A 21 NS34A BQEMRE wells in bold manzed in the following table. Future Development Plans The possibility that satellite hydrocarbon accumulations may exist within expected drilling reach from the island is recognized. These and locations within the main Northstar Ivishak formation will be the subject of additional future appraisal. As of March 2011, no drilling activities are ongoing at Northstar. The Nabors 33 drilling rig was de -mobilized from Northstar Island during the 2010 barging season. 10 G) Status of Wells Shut-in for 365 days or More (20 AAC 25.115) Producer NS15 was the only well at Northstar shut-in for all of 2010. Northstar show WellS 2090 1. Reasons for Well Shut -In A. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems B. High water, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical Problem E. Other (Specify under comments) 2. Current Mechanical Condition Briefly describe the current mechanical condition including the condition of installed tubing and casing strings. 3. Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2 Remedial well work planned 3. Long term Shut-in well/ No immediate plans 4. Suspended well 5. P&A planned 6. Other (Specify under comments) 11 Date Shut- Reason for Well Current Mechanical Condition of Future Utility Plans & Sw Name In Shut4n' Wolf Possibilities3 Comments D. Mechanical Secured with down hole mechanical 3. Long term Shut-irdNo N515 Mar -09 Problem plug and BPV immediate plans 1. Reasons for Well Shut -In A. High GOR, curently uncompetitive to produce due to facility constraints, no known mechanical problems B. High water, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical Problem E. Other (Specify under comments) 2. Current Mechanical Condition Briefly describe the current mechanical condition including the condition of installed tubing and casing strings. 3. Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2 Remedial well work planned 3. Long term Shut-in well/ No immediate plans 4. Suspended well 5. P&A planned 6. Other (Specify under comments) 11 N Legend Well Status as of 12/31/2009 0 Disposal Well ` Gas Ir4ector Oil Producer Unit Boundary 0 Lease Tract Botrtdary IvistlakBoundary by Nor thStsr 0 Well Stafm Balsemap C Annual PerfoPirl0nm Report Auhor DougWison HalzortalScale: 1"=6,0001[ Date. IOMarcn, 2010 NS2S NS NS2\\ NS32 NS15 NS08 1 I N514A � �. NS 13 NS �NS12 NS 11.1 �'. ;tNS27 NS09 NS'0 _f lS'10 NS06._ • NS19 t �NS11 uNS25 1:72000 1 inch = 6000 feet 4000 0 4000 6000 12000 it 1 0 1 2 3 ml Projection Information: Alaska Stale Plane Zone 4 Clarke 1866, NAD 1927 Attachment 2 NORTHSTAR FIELD 2010 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS As of 12/312010 Full year (1) As of 12110 (2) Producers 20 17 Injectors 8 7 (1) Well count data reflects ONLY those wells which contributed to produetionAnjection during the respective year (2) Active wells as of December 2010 PRODUCTIOWINJECTION STATISTICS Injection 16,804 Cumulative Start - (Water (BBL) into NS10 & NS32Disposal Well 5,844,769 Up through Production 2010 12/31/10 Oil (66L) 6,133,516 147,948,777 Gas (MCF) 170,452,817 1,175,148,074 Nater (BBL) 5,582,576 34,269,034 Injection 16,804 Gas, MCF/D (Water (BBL) into NS10 & NS32Disposal Well 5,844,769 37,867,069 Gas (MCF) 183,874,486 1,353,795,572 Balance (excludes satellite well NS -34A and NS08 Kup oil Production Gas, MCFPD 503,766 ;Cum Production (MRB) 119,009 904,827 Cum Injection (MRB) 124,994 918,704 Over/Under (MRB) 5,985 13,877 DAILY AVERAGE RATE DATA 2010 Production Oil, BOPO 16,804 Gas, MCF/D 466,994 Water, BWPD 15,295 (Injection (Water, BWPD 16,013 Gas, MCFPD 503,766 AVERAGE RESERVOIR PRESSURE Average of surveys obtained in 2010 13 5103 psia Attachment 3: Reservoir Pressure Report 14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. BP ExplorettaVAMaka Ina- 2. Address: P.O. Box 1!111112, Anchw% a, Make !!513-41112 3. Lint or Lease Nene: Northater 1krN 4. Field and Poot 5. Datum Reference: Northatr FieldNora"Aw Oil Pool -11,1 W 6, 01 Gravity 42 7. Gas Gravity: 41.79 S. Wel Name and Number. 9. API Number 10. Type SOXXXXXXXXXXXX See NO DASHES instruction 11. AOGCC 12. Zone Pod Code 13. Perforated 14. Final Test 15. Slut -in 16. Press. intervals Date Time Hours Surv. Type Top - Bottom (see TVDSS instructions for codes) 17. B.H. 18. Depth Temp. Toot TVDSS 19. Final Observed Pressure at Tod Depth 20. Datum 21, Pressure 22. Pressure at TVDSS (nplt) Gradient. psiM. Datum (cd) NS08 50029230680000 0 590100 Nishak 11068-1109 2/10/10 96 Other 200 8834 4619 11100 0.109 5108 NS08 50029230660000 0 590100 Ivishak 11068-1109 2/22/101 96 Other 200 88341 4821 11100 0.109 5111 NS08 50029230680000 0 590100 Ivishak 11068-1109 3721/10 48 Other 207 8834 4823 11100 0.109 5113 NS14A 50029230260100 0 590100 Ivishak 11088-11091 2r6/10 240 Other 245 10555 5035 11100 0.112 50% NS14A 50029230260100 O 590100 Mshak 11088-11091 3/14/10 312 Other 246 10555 5033 11100 0.112 5094 NSM 50029232480000 0 590100 Ivishak 11052-1107 3/17/10 5352 Other 243 10480 5019 11100 0.124 5096 NS34A 50029233010100 0 590100 Mshak- 11048-1106 2/11/10 72 Other 233 8908 4037 11100 0.42 4958 NS06 50029230680000 0 590100 Mshak 11068-1109 5/16/10 480 Other 200 8834 4835 11100 0.109 5125 NS14A 50029230260100 0 590100 Nishak 11088-11091 6/30/10 236 Other 244 10555 5019 11100 0.1121 5080 NS28 50029232480000 0 590100 Ivishak 11052-1107 672/10 784 Other 242 10480 5026 11100 0.124 5103 NS34A 50029233010100 0 590100 Nishak 11048-1106 6/3/10 170 Other 212 8908 4079 11100 0.42 5000 NS13 50029230170000_0 590100 Mshak 11055-1109 5/21/10 510 Other 233 10390 4989 11100 0.127 5121 NS21 50029231260000 0 590100 Ivishak 10915-11031 5/28/10 77 Other 2451 10576 5024 11100 0.112 5108 NS08 50029230680000 0 590100 Ivishak 11068-1109 9/6/10 312 Other 197 8834 4836 11100 0.1091 5126 NS14A 50029230260100 0 590100 Ivishak 11088-11091 82/10 236 Other 243 10555 4982 11100 0.112 5043 NS2B 50029232480000 0 590100 Mshak- 11052-1107 9/30/10 6312 Other 242 10460 5018 11100 0.124 5095 NS34A 50029233010100 0 590100 Ivishak 11048-1106 823/10 744 Other 210 89081 4095 11100 0.42 5016 NS13 50029230170000 0 590100 Ivishak 11055-1109 9/12/10 456 Other 1 237 10390 4992 11100 0.127 5124 NS21 50029231260000 0 590100 Nishak 10915.11031 920/10 648 Other 243 10576 5019 11100 0. 1121 5104 NSOB 50029230680000 0 590100 Nishak If1068-1109 102/10 16 Other 197 8834 4834 11100 0.109 5124 NS09 50029230520000 0 590100 Ivishak 10938-1108 1127/10 120 SBHP 253 11000 5081 11100 0.12 5093 NS13 50029230170000 0 1 590100 Mshak 11055-1109 12/17/10 360 Other 2371 10390 49881 11100 0.127 5120 NS16A 50029230960100 0 590100 Nishak 11029-1109 1128/10 48 SBHP 242 10900 5091 11100 0.12 5115 NS1B 50029231020000 0 590100 Ivishak 10975-1104 1128/10 48 SBHP 251 11000 5107 11100 0,101 5117 NS19 50029231220000 0 590100 Mshak 10953-1103 11 f2911 01 48 SBHP 256 11000 5048 11100 0.12 5060 NS21 50029231260000 0 590100 Nishak 10915.11031 10/5/10 14 Other 1 246 105761 5004 11100 0.112 5089 NS24 50029231110000 0 590100 Ivishak 10985-11047 9731/10 2376 SBHP 252 11000 5115 11100 0.10 5125 NS28 50029232480000 0 590100 Mshak 11052-1107 12/31/10 8496 Other 242 10480 5010 11100 0.124 5087 NS34A 5002923301010010 1 590100 Ivishak 11048-1106 12/3/10 30 Other 231 8908 4036 111001 0.42 4957 NS08 50029230680000 0 I 590100 Ku aruk 8924-8961 12/4/10 1464 Other 1971 8834 4365 9000 0.26 4451 23. AN tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oi and Gas Conservation Commission. I hereby certify that the foregoing is tnue and correct to the best of my lmoMedge. Signature Tire Printed Name Mark Sauve Date BPXA Northstar Lead Production Engineer March 15, 2010 14