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Home My WebLink About2013 Northstar Oil PoolA"1 EO Katrina Garner Head of Base Management, Alaska Strategic Performance Unit March 14, 2014 Cathy Foerster Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 P1A R 2 :5 c AOr,f Exporation (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RE: Northstar Field, Northstar Oil Pool Annual Reservoir Performance Report Dear Ms. Foerster: 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, 2013 through December 31, 2013. 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 Eko Apolianto (564-4569) or Mark Sauve (564-4660) if there are any questions. Sincerely, Katrina Garner Phone:(907) 564-4212 Fax: (907) 564-4440 Email: Katrina.Garner@bp.com Web: www.bp.com cc: Mark Fesmire, BSEE Kevin Banks, DNR Bob Gage, Murphy R. L. Skillern, BP File Annual Reservoir Performance Report Northstar Field Northstar Oil Pool January 2013 through December 2013 March, 2014 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 2013 Overview Statistical Summary Attachment 3: Northstar Field 2013 Reservoir Pressure Report, Form 10-412 2 A) Progress of Enhanced Recovery Project and Reservoir Management Summary During 2013, 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 9,286 bopd and average daily gas injection was 483.6 mmscfpd. The reservoir voidage balance values reported do not include oil production from satellite well NS34A or Kuparuk zone production from well NS08. During 2013, gas injection was calculated to be 4,638 thousand -reservoir barrels (MRB) more than reservoir voidage. At year end, the reservoir overall cumulative voidage replacement ratio was 1.021. The average of reservoir pressure control for 2013 was 5,109 psia. 3 B) Voidage Balance by Month of Produced Fluid and Injected Fluids - 2013 2013 Produced Fluids Month Oil, MRB Free Gas, MRB Water, MRB Total Voidage, MRB Year Cum, MRB Cum since start-up, MRB Jan -2013 439 7,583 365 8,022 4022 1,124,743 Feb -2013 419 6,339 305 6,759 14,781 1,131, 502 Mar -2013 617 10,086 330 10,702 25,483 1,142, 204 Apr -2013 543 9,700 310 10,243 35,726 1,152, 447 May -2013 497 8,195 352 8,692 44,417 1,161,139 Jun -2013 509 8,992 372 9,500 53,918 1,170, 639 Jul -2013 469 8,132 359 8,601 62,518 1,179, 240 Aug -2013 472 9,087 348 9,559 72,078 1,188, 799 Sep -2013 504 9,288 366 9,792 81,870 1,198, 592 Oct -2013 551 10,127 384 10,678 92,548 1,209,270 Nov -2013 596 10,469 355 11,065 103,614 1,220,335 Dec -2013 614 10,996 368 11,610 115,223 1,231,945 2013 Totals 6,231 108,993 4,214 115,223 4 rvec infection (Injection - Production) Net Year Injected Fluids Injection, Cum, Formation Import Total Year Cum since Gas, Gas, Injection, Cum, start-up, MRB MRB MRB MRB MRB 7,803 446 8,249 8,249 1,145, 768 6,555 391 6,946 15,195 1,152, 714 10,494 714 11,208 26,403 1,163, 922 10,058 609 10,667 37,070 1,174, 589 8,522 633 9,155 46,225 1,183, 744 9,319 587 9,906 56,131 1,193, 650 8,438 615 9,052 65,183 1,202,702 9,390 607 9,997 75,180 1,212,700 9,621 597 10,217 85,398 1,222,917 10,492 571 11,063 96,460 1,233,979 10,863 582 11,445 107,905 1,245,424 11,400 556 11,956 119,861 1,257,380 112,955 6,906 119,861 4 rvec infection (Injection - Production) Net Year since Injection, Cum, start-up, MRB MRB MRB 227 227 21,024 187 414 21,212 506 920 21,718 424 1,344 22,142 463 1,807 22,605 406 2,213 23,011 452 2,665 23,462 438 3,103 23,900 425 3,528 24,325 384 3,912 24,710 379 4,292 25,089 346 4,638 25,435 4,638 C) Summary and Analysis of reservoir pressure surveys within the pool Static bottom hole pressures collected in 2013 are summarized below. Well Extroplated Pressure at -11,100' TVDss Date Datum, psia Data Source NS06 2/5/13 5088 SBHP NS08 1/6/13 4214* Other NS08 2/17/13 4206* Other NS08 4/18/13 4188* Other NS08 6/8/13 4161* Other NS08 7/13/13 4133* Other NS08 8/11/13 4141* Other NS08 11/19/13 4151* Other NS08 12/19/13 4134* Other NS09 3/4/13 5068 SBHP NS13 3/10/13 5110 SBHP NS14A 8/23/13 5133 SBHP NS18 8/23/13 5106 SBHP NS24 8/19/13 5127 SBHP NS28 3/31/13 5125 Other NS28 6/30/13 5121 Other NS28 7/15/13 5123 Other NS28 8/20/13 5121 SBHP NS28 9/12/13 5122 Other NS28 12/31/13 5105 Other NS33A 8/21/13 5062 SBHP NS34A 8/22/13 4995 SBHP * Datum for Kuparuk reservoir is 9000' TVDSS These pressures are graphically represented in the next figure that is a plot of Ivishak pressure by well versus time. These data show a slight increase of reservoir pressure during 2013. The average Northstar field reservoir pressure for 2013 is 5109 psia, up some 5 psi from the 2012 average. Please note that well NS -34A is a satellite well to the main field and the reservoir pressures reported from NS08 during 2013 are from the Kuparuk Reservoir. A complete listing of data from these surveys is shown in Attachment 3 on the AOGCC Reservoir Pressure Report form. Northstar Ivishak Well Pressure Data -�NS06 NS07 - -NSOS —+—NS09 --o—NS 12 Pis 13 NS14 —NS15 NS16 NS17 NS1S NS19 NS20 —NS21 NS22 NS23 NS24 --+ -NS25 - NS27 —+--NS29 --= NS31 +--NSOS NS28 --s---NS11 —NS30 tNS33A 5250 co a 5200 0 0 0 5150 0 m 5100 m CL` 0 m m 5050 oc 5000 ----------------------------------- CU CL CL �Co OCL OCL OOCL OCL O 0. OOOd d d d OO,¢Od d Q d -,dma¢d -, 9 1; ----------------------------------- CU CL CL �Co OCL OCL OOCL OCL O 0. OOOd d d d OO,¢Od d Q d -,dma¢d -, 9 D) Results and Analysis of Production and Injection log surveys, tracer surveys, observation well surveys and any other special monitoring. Two new production/injection profiles were obtained in 2013. 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 Percentage of flow from/to interval. Blank intervals are not perforated. 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/Gradio/Ghost 12 59 19 10 NS08 Producer 12/7/2004 S/T/P/Gradio/Ghost/DEFT 1 55 31 9 5 NS09 Producer 12/11/2004 S/T/P/Gradio 54 29 17 0 NS24 Producer 3/26/2005 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/G rad io/G host 43 42 15 NS11 Producer 12/20/2006 Memory S/T/P/DE FT/G host 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/Ghost/DEFT 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/Ghost/DEFT 100 0 NS16A Producer 9/16/2008 S/T/P/Gradio/Ghost/DEFT 100 0 NS16A Producer 10/21/2008 S/T/P/Gradio/Ghost/ DEFT 100 0 NS24 Producer 12/3/2008 S/T/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/T/P/Gradio/Ghost/DEFT 73 27 NS19 Producer 4/19/2009 S/T/P/Gradio/Ghost/DEFT 96 4 NS16A Producer 4/20/2009 S/T/P/Gradio/Ghost/DEFT 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 50 NS11 Producer 11/21/2009 Memory S/T/P/Gradio/DEFT 80 20 NS21 Producer 12/13/2009 Memory S/T/P/Gradio/Ghost/DEFT 100 NS20 Producer 12/15/2009 Memory S/T/P/Gradio/Ghost/DEFT 50 50 NS22 Producer 12/16/2009 Memory S/T/P/Gradio/Ghost/ DEFT 60 40 NS34A Producer 12/21/2009 Memory S/T/P/Gradio/Ghost/DEFT 100 NS06 Producer 5/4/2010 SIT/P/Gradio/Ghost/DEFT 1 65 30 5 NS06 Producer 10/19/2010 S/T/P/Gradio/Ghost/DEFT 0 70 30 NS11 Producer 5/5/2013 S/T/P/Gradio/Ghost/DEFT 89 11 NS30 Producer 5/13/2013 S/T/P/Gradio/Ghost/DEFT 91 9 * 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 Qtheoretacal 24 Pwhsi Where: hoursproduced = hours on line PWhf = 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 2013 averaged 1.23 for oil, 0.98 for water and 1.01 for gas. �:3 F) Review of Annual Plan of Operations and Development and Future Development Plans Northstar concluded 2013 with six gas injection wells, twenty-one producing wells and two Class I disposal wells available for utilization. Historical well count for the last two years are summa irized in the following table. ;%• - • rr- 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 NS11 NS31 7 NS12 8 NS13 9 NS14A N 10 NS15 O 11 NS16 N 12 NS18 13 NS19 14 NS20 15 NS21 16 NS22 17 NS24 18 NS28 19 NS30 20 NS33A 21 NS34A 1 NS05 NS17 NS10 2 NS06 NS23 NS32 3 NS07 NS25 4 NS08 NS27 5 NS09 NS29 6 NS11 NS31 7 NS12 8 NS13 9 NS14A co 10 NS15 O 11 NS16 N 12 NS18 13 NS19 14 NS20 15 NS21 16 NS22 17 NS24 18 NS28 19 NS30 20 NS33A 21 NS34A BSEE wells in bold 9 irized 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 2014 no drilling activities are ongoing at Northstar. The Nabors 33 drilling rig was de -mobilized from Northstar Island during the 2010 summer barging season. D ti 4 v s 10 J N Legend Weil Status as of 12131(2009 0 Disposal Well Gas Injector Oil Producer UrdtBounday Lease Tract Boundary Ivishac Bounclat y by NorthStar 0 Well Status Basemap A0GCC Annual Performance Report Adtror. DaigWtison Horizma Scale, 1-6,000 ft Die. 10 March, 2010 •NS18 IVS29 NS13 M? � • NS12,.' w •NS07 NS27'�� NS10 l NS05 �! •NS19 !NS11 1:72000 1 inch = 6000 feet 4000 0 4000 0000 12000 ti 1 0 1 2 3 ml Projection Information: Alaska State Plane Zone4 Clarke 1866, NAD1927 NS09 ONS25 E Attachment 2: NORTHSTAR FIELD 2013 OVERVIEW STATISTICAL SUMMARY WELL STATISTICS As of 12131/2013 Full year (1) As of Dec -13 (2) Producers 18 18 Injectors 8 7 NOTES: (1) Well count data reflects ONLY those wells w hich contributed to production/injection during the respective year (2) Active w ells as of December 2013 PRODUCTION/INJECTION STATISTICS Cumulative Start - Up through Production 2013 12/31/13 Oil (BBL) 3,389,396 159,620,059 Gas (MCF) 175,955,964 1,672,921,759 Water (BBL) 5,138,085 50,009,285 Injection Water (BBL) into NS10 & NS32 Disposal Well 5,402,889 54,413,756 Gas (MCF) 176, 514, 885 1,853,295,094 Balance (excludes satellite well NS -34A and NS08 Kup oil Production) Cum Production (MRB) 115,223 1,232,035 Cum Injection (MRB) 119,861 1,257,375 Over/Under (MRB) 4,638 25,339 DAILY AVERAGE RATE DATA 2013 Production Oil, BOPD 9,286 Gas, MCF/D 482,071 Water, BWPD 14,077 Injection Water, BWPD 14,802 Gas, MCFPD 483,602 AVERAGE RESERVOIR PRESSURE Average of surveys obtained in 2013 5109 psia 13 Attachment 3: Reservoir Pressure Renort 14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: SP ExplorationlAlaska Inc. 2, Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 3. Unit or Lease time: Northstar Unit 4. Feld and Pool: Northstar Field/Northstar 5. Datum Reference: Oil Pool -11,100 6.01 Gravity: 7. Gas 42 Gravity: 0.79 8. Well Name and Nurrber: 9. AIR Number 10. Type 50� See NODASHES Instructions 11. AOGCC 12. Zone Pool Code 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test 15. Shut -In 16. Press. Date Time, Hours Surv. Type (see instructions for codes) 17. B.H. 18. Depth Temp. Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum 21. Pressure 22. Pressure at TVDSS (input) Gradient, psyfl. Datum (cagpsig NS06 50029223088000 0 590100 Ivishak 10900-11099 2/5/131 2064 SBHP 252 11000 5078 11100 0.1025 5088 NS08 50029230680000 0 590100 Kuparuk 8924-8961 1/6/13 24 Other 197 8834 4128 9000 0.26 4214 NS08 50029230680000 0 590100 Kuparuk 8924-8961 2/17/13 24 Other 197 8834 4120 9000 0.26 4206 NS08 50029230680000 0 590100 Kuparuk 8924-8961 4/18/13 48 Other 197 8834 4102 9000 0.26 4188 NS08 50029230680000 0 590100 Kuparuk 8924-8961 6/8/13 24 Other 197 8834 40751 9000 0.26 4161 NS08 50029230680000 0 590100 Kuparuk 8924-8961 7113/131 24 Other 197 8834 4047 9000 0.26 4133 NS08 1 50029230680000 0 590100 Kuparuk 8924-8961 8/11/13 48 Other 1971 8834 4055 9000 0.26 4141 NS08 50029230680000 O 590100 Kuparuk 8924-8961 11/19/13 48 Other 191 8834 4065 9000 0.261 4151 NS08 50029230680001 O 590101 Kuparuk 8924-8962 12/19/13 48 Other 191 88341 4048 9000 0.26 4134 NS09 50029223052000 0 590100 Ivishak 10938-11092 3/4/13 10608 SBHP 251 11000 5058 11100 0.103 5068 NS13 50029223017000 0 590100 IHshak 10924-11094 3/10/13 9888 SBHP 253 11000 5100 11100 0.103 5110 NS14A 50029230260100 0 590100 Nishak 13190-14140 8/23/13 48 SBHP 253 11000 5122 11100 0.11 5133 NS18 50029231020000 0 590100 Ivishak 16775-16850 8/23/13 28 SBHP 250 11000 5096 11100 0.101 5106 NS24 50029231110000 0 590100 Ivishak 12428-12490 8/19/13 2424 SBHP 252 110001 5116 11100 0.11 5127 NS28 50029232480000 O 1 590100 IHshak 11052-11095 3/311131 17323 Other 1 242 10480 4998 11100 0.10 5125 NS28 50029232480000 0 590100 hAshak 11052-11095 6/30/13 19507 Other 242 10480 4994 11100 0.10 5121 NS28 50029232480000 0 590100 Ivishak 11052-11095 7/15/13 19603 Other 242 10480 4996 11100 0.10 5123 NS28 50029232480000 0 590100 Withak 11052-11095 8/20/13 20443 SBHP 242 10900 5101 11100 0.101 5121 NS28 50029232480000 0 590100 Ivishak 11052-11095 9/12/13 21235 Other 2421 10480 4995 11100 0.10 5122 NS28 50029232480000 0 590100 IHshak 11052-11095 1 12/31/131 1806 Other 242 10480 4978 11100 0.10 5105 NS33A 1 5002923325010010 1 590100 IHshak 25785-25837 8/21/13 22176 SBHP 248 11000 5041 11100 0.21 5062 NS34A 1 5002923301010010 1 590100 Ivishak 18962-19012 8/22/13 48 SBHP 253 11000 49541 11100 0.41 4995 Comments: Surveys indicated as "Other' were obtained from Cidra guages. 23. All tests reported herein w ere Trade in accordance w Ah the applicable rules, regulations and instructions I hereby certify that the foregoing is true and correct to the best of ow ledge. Signature Printed Name Mark Sauve of the Alaska Oland Gas Conservation comrissicn. Tale Date Northstar Lead Production Engineer January 3, 2014 14