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178-100
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG _ h min 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.170 Devv �^YI ry ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero mer Service Stratigraphic Test ❑ 2. Operator Name: 6, Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 11/8/2019 178-100 - 3111 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 196612 Anchorage, AK 99519-6612 6/13/1979 50-029-20354-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 7/2/1979 PBU R-02 Surface: 4642' FNL, 4311' FEL, Sec. 32, T12N, R13E, UM • 9 Ref Elevations KB 54.97 17. Field/Pool(s): Top of Productive Interval: 3001' FNL, 1363' FEL, Sec, 31, T12N, R13E, UM GL 1972 • BF 19.61 PRUDHOE BAY, PRUDHOE OIL Total Depth: 2648' FNL, 1646 FEL, Sec. 31, T12N, R13E, UM 10. Plug Back Deplh(MD/TVD): 1B. Property Designation: 9370'/ 8656' ADL 028279 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/ D): 19. DNR Approval Number: Surface: x- 634620 y- 5977106 Zone - ASP 4 k 10303'/ 9474' 77-028 TPI: x- 632254 y- 5978705 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20Thickness of Permafrost MDfrVD: Total Depth: x- 631962 y- 5979052 Zone - ASP 4 None 2031'/ 2031' 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-dml/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A MD/ND: 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and Perforation record. Acronyms may be used. Attach a separate page if necessary DIL / SP, SHCS / GR, FDC / CNL / OR / Cal 23, CASING, LINER AND CEMENTING RECORD CASING Wr, PER GRADE SETTING DEPTH MD SETTING DEPTHTVD HOLE SIZE AMOUNT FT. CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" x 30" 38' 1 118' 38' 118' 36" 651 w ft Arctic Set 13-318" 72# L-80 37' 2628' 37' 2628' 17-1/2" 5348 cu ft Permafrost 9-5/8" 47# L-80 35' 9307' 35' 8600' 12-1/4" 1288 cu It Class'G', 130 cu It Pemlafmst C 7" 29# L-60 8815' 10302' 8175' 9473' 8-11/2" 430 cu ft Class'G' 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (MDrl VD) Size and Number, Date Perfd): 4-1/2" 12.64 8149'17612' x 5-1/2" 17# x 4-1/2" 12.6# L-80 8741'/ 8112' ,rte 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. fy/�- Was hydraulic fracturing used during completion? yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed I' T 20 f j information V RIFIE� DEPTHINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -^ 8372' Set Whipstock 27. PRODUCTION TEST Date First Production. Not on Production Method of Operation (Flowing, gas lift, etc)' N/A Data of Test: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Hours iestetl: Test Period —0. FlowTubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API room: Press 24 Hour Rate -y Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS�LF^'DEC 0 5 2019 r 28. CORE DATA Conventional Core(s) Yes ❑ No [Z Sidewall Cores Yes ❑ No 221 If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presenceof oil, gas or water (submit separate sheets with this form, if needed), Submit detailed descriptions, care chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9358' 8645' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9358' 8645' Shublik 9406' 8686' Sadlerochit-Zone 4 9505' 8747' CGL - Zone 3 9659' 8743' Base of CGL - Zon2 2 9746' 8727' Zone 1 10041' 8691' Base Sadlerochit - Kavik 10151' 8687' Formation at total depth: Kavik 10151' 8687' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contac[ Name: Sperry, Nathan Authorized Title: SIM QdallSt Contact Email: Nathan.Sperry@bosom Authorized Signature: Date:k) Contact Phone: 907-5644258 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a welt schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of tlaily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 512017 Submit ORIGINAL Only ***WELL SHUT IN UPON ARRIVAL*** (ELINE SBHPS AND SET WHIPSTOCK) INTIAL T/1/0=0/0/0 ARRIVE ON LOCATION TO SPOT EQUIPMENT ALL VALVES REMAINED IN INITIAL POSITIONS-SWAB, MASTER, WING=CLOSED 10/8/2019 ***IN PROGRESS, PAD OP NOTIFIED*** ***JOB CONTINUED FROM 08-OCT-2019*** (SLB ELINE SBHPS/WHIPSTOCK) RUN 1: PERFORM SBHPS PER PROGRAM. RUN 2: SET 4-1/2" X 7" BAKER DELTA WHIPSTOCK AT 9372' TOWS, 2 DEG ROHS (RA tags 8.65' from TOWS). LOG CORRELATED TO PDS COIL FLAG DATED 09-NOV-2016. 10/9/2019 ***JOB COMPLETE ON 09-OCT-2019*** CTU #9 w/ 1.75" Coil Objective: Mill XN & Window Travel to location. Begin rig up ...In progress... 10/25/2019 CTU #9 w/ 1.75" Coil. ***Continue from 10/25/19*** Objective: Mill XN & Window Complete BOP Test (witness waived by AOGCC). RIH w/ Baker left handed milling BHA w/ 3.80" mill. Tag XN nipple @ 8834', mill through in -2.5 hours. Dry drift up & down. POOH 10/26/2019 ...In progress... 10/26/2019 LRS Unit 76- Heat 3 Uprights of Slick KCL to 100* for CTU. RDMO. CTU #9 w/ 1.75" Coil. ***Continue from 10/26/19*** Objective: Mill XN & Window Finish POOH w/ left handed MHA. Gauge mill @ 3.81" go, 3.80" no go. MU & RIH w/ window milling MHA; 3.80" Diamond window mill & 3.80" Diamond string mill. Tag whipstock pinchpoint @ 9379'. Mill window & rathole to 9398' CTM. POOH. Freeze protect w/ 32 bbls 60/40 methanol down backside. 10/27/2019 ...In progress... CTU #9 w/ 1.75" Coil. ***Continue from 10/27/19*** Objective: Mill XN & Window Complete rig down 10/28/2019 ... Complete... T/I/O=TWC/0/0 **Job in Progress** Installed CDR kill line, Torqued to API specs. R/U lubricator, PT'd against TWC 300/low..5000/high.. pass. see "Field Charted Tests" Pulled 6" "J" TWC. R/D lubricator. Installed CDR Test spool with tapped blind on top. Torqued to API specs. PT'd through kill line against Top of Master, including test spool and blind, to flat line 10/30/2019 criteria... pass. PT'd top of second Master and bottom of Swab to flat line criteria... pass. Job . North America - ALASKA- BP Page r acerb. Operation Summary Report Common Well Name: R-02 AFE No Event Type: RE-ENTER- ONSHORE(RON) ,Start Date: 11/5/2019 End Date: 11/13/2019 H-S4DW0019G3-EX-D1-RN-(2,050,908.00) Project: PBU- Rig Name/No.. CDR-2 Spud Date/Time'. 6/13/1979 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000296 Active datum: KB @54.97usft (above Mean Sea Level) Date From -To Him Task Code NPT Total Depth' Phase Description of Operations 11/5/2019 07:00 - 16:00 9.00 RIGU P 9,377.00 PRE MOVE RIG FROM S-PAD TO R-PAD - RIG ON R-PAD AND CREW CHANGE 'I- HOLD PJSM WITH NABORS AND PEAK CREWS TO SPOT RIG AND PITS '- PAD TO SHORT FOR SOWS, RU STOMPER AND SPOT MAIN AND PIT SUBS T. RIG&PITS SPOTTED 16:00 - 00:00 8.00 _ RIGU P 9,377.00 PRE START MIRU OPS - ACCEPT RIG AT 16: 00 '- LOTO LOWER MASTER AND CYCLE UPPER MASTER & SWAB '- START MIRU CHECKLISTAND INSTALL REEL IRON AND MU THE PRESSURE BULK HEAD '- LEAK TIGHT TEST BOTH MASTER VALVES, SWAB AND WING VALVES TO 3500 PSI INSTALL MPD LINE 11/6/2019 00:00 - 12:00 12.00 RIGU P 9,377.00 PRE STAB 71/16"BOP - REMOVE LUBRICATOR '- INSTALL CTD FLOWBOX ',- REMOVE RIG TONGS AND ASSOCIATED ''. WORKOVER ITEMS FROM RIG FLOOR �I- SECURE TONG LINES IN DERRICK - CONNECTING CHOKE AND KILL LINES TO FLOWCROSS. I NOTE-HELD PRE SPUD MTG AND TABLE TOP ' H2S DRILL WITH MICAH BUSHS CREW WITH AAR. NU ROPE AND CONNECT KOOMEY HOSES - RU BOP TEST LUBRICATOR 12:00 - 00:00 12.00 RIGU P 9,37700 PRE - PULL COILTO INJECTOR I -GAVE PRE-SPUDAND TABLE TOP RIG EVAC DRILL WITH BEARD'S CREW -TEST GAS ALARMS - FUNCTION TEST BOP RAMS &ANNULAR '.- MEG TEST ELINE, BAD TEST, TROUBLESHOOT- FOUNDA BAD BHI CABLE - STAB ON AND FLUID PACK THE COILAND j CHECK TREE BOLTS - CUT 310'OF COIL FOR 2% SLACK -MAKE UP CTC. PULL TEST TO 50K -INSTALL STINGER AND NOZZLE. PUMP SLACK FORWARD - BHI INSTALL UQC. -FLUID PACK FOR BORE TEST 1117/2019 00:00 - 01:00 1.00 RIGU P 9,377.00 PRE FLUID PACKING. PERFORM SHELL TEST Printed 12/3/2019 3.30:42PM "All depths reported in Drillers Depths'" NorthAmerica- ALASKA -BP Page Operation Summary Report Common Well Name: R-02 AFE No Event Type. RE-ENTER- ONSHORE(RON) Start Date: 11/5/2019 End Dale: 11 /1312019 'H-S4DW0019G3-EX-Dl-RN-(2,050,908.00) Project: PBU Site: R Rig Name/No.: CDR-2 Spud Date/Time: 6/13/1979 12:00:OOAM 1 Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. -BPUOI: USA00000298 Active datum: KB @54.97usft (above Mean Sea Level) Date From-To His Task Cade NPT Total Depth - Phase Description of Operations (hr) (usft) 101:00 - 13:00 12.00 BOPSUR - P 91377.00 PRE INITIAL BOPE TEST WITNESSED WAIVED AOGCCL LOU LAUBENSTEIN ANNULAR 250 PSI / 3500 PSI RAMS AND CHOKE VALVES 250 PSI / 5000 PSI TESTED ON RAM LOCKS 7-1/16" 5K STACK ANNULAR, BLIND/ SHEAR, • 2-3/8" PIPE / SLIP, MUD X, 2-3/8"x3.5" VARIABLE, 2-3/8" PIPE 1,911P I �-TEST 1: IRV, PACKOFF, C9 BACKWARDS, C10 BACKWARDS 250 PSI LOW/ 4500 PSI HIGH PASS -TEST2: BLIND/SHEAR, 81, B4, R1, BL1A • �,, 250 PSI LOW/ 5000 PSI HIGH PASS -INSTALL MULTI- JOINT li -TET S 3. ANNULAR 2-3/8" 250 PSI LOW OW/ ) •3500 PSI HIGH PASS - TEST 4: UPPER 2-3/8" PIPE/ SLIP, TIW#2, B2, B3 250 PSI LOW/ 5000 PSI HIGH PASS - TEST 5: R2, C15, BL2, TIVJ#1 250 PSI LOW/ 5000 PSI HIGH LEAKAT CONNECTION TO • TEST CAP, SWAP OUT TEST CAP - TEST 5: R2, C15, BL2, TIW#1 250 PSI LOW / 5000 PSI HIGH TIW#1 FAIL, CLOSE TIW92 AND FINISH TEST PASS -TEST 6: C16, C11, BL1 250 PSI LOW / 5000 PSI HIGH PASS TEST 7:2-3/8" VBR'S W/LOCKS, C9, C7, C10, TV1, 250 PSI LOW/ 5000 PSI HIGH - PASS -TEST 8: LOWER 2-3/8"PIPE/SLIP W/ LOCKS, C5, C6, C8, TV2 250 PSI LOW/ 5000 PSI HIGH - PASS - TEST 9: CHOKEA, CHOKE C 1500 PSI -PASS -TEST 10: ACCUMULATOR DRAW DOWN TEST, REMOVE LOWER 2-3/8 SUB AND INSTALL SAVER SUB TO TEST VBR'S TO 3-1/2 - TEST 11: ANNULAR (3-1/2") TO 3500 PSI - . PASS - TEST 12: VARIABLE (3-1/2") W/LOCKS C1, C4 -PASS - TEST 13: C2, C3, TI W 41 250 PSI LOW/ 5000 'PSI HIGH -PASS - ND ANNULAR FLANGE TO REMOVE TEST PLUG AND RETEST- 1-HR r - TEST 14: T1250 PSI LOW/ 5000PSI HIGH - PASS - TEST 15: T2250 PSI LOW/ 5000 PSI HIGH - PASS BOP TEST COMPLETED IN 12-HRS TAKING 1-HR OFF TO REMOVE TEST PLUG 13:00 - 16:00 3.00 BOPSUR P 9,377.00 PRE CLEAR RIG FLOOR - RD TEST EQUIPMENT - RU DRILLING LUBRICATOR - INSTALL BHI FLOATS STAB ON AND PT THE LUBRICATOR, QTS AND BHI FLOATS 250 LOWAND 3500 HIGH —T- - GOOD PT, BLEED OFF Printed 12/3/2019 3:30:42PM '"All depths reported in Drillers Depths'" North America - ALASKA - BP Operation Summary Report Page 3 Common Well Name R-02 AFE No Event Type: RE-ENTER- ONSHORE(RON) Stan Date: 11/5/2019 End Date: 11/13/2019 H-S4DW0019G3-EX-DI-RN-(2,050,908.00) Project: l Site: R Rig Name/Ne/N o.. CDR -2 Spud Dat ,Ine: 6/13/1979 12:au uuAM ; Rig Release: Active datum: KB @54.97usft (above Mean Sea Level) Date From - To Him Task (hr) I a nn _ nn nn i u nn i vFl 1„ 11/8/2019'00:00 0430 4.50 �V4:UV - IV:UL JilI l, -02A ` 02 l 1000 - 11:45 Code j NPT Total Depth Phase Description of Operations _ (wt) P 9,377.00 PRE WELL KILL OPS HOLD A PJSM WITH CREW TO REVIEW BH KILL PROCEDURE AND VOLUMES - FLUID PACK STACK WITH METH, OPEN DRILL I P WELL TO A CLOSED CHOKE - LINE UP PUMPS TO MPL, PUMP 10 BBLS NEAT METH, 240 BBLS OF KCL - IAP = 0 PSI OAP = 0 PSI CAUGHT FLUID AT -20 BBLS AWAY, WHIP= j 1315 PSI AT 5.2 BPM �- 100 BBLS AWAY, PURGE LUBRICATOR IAP= 214 PSI OAP = 0 PSI -160 BBLSAWAY KCLAT THE PERFS WHP= 980 PSI AT 5.2 BPM IAP = 702 PSI OAP = 0 PSI - 240 BBLS AWAY REDUCE RATE TO I BPM i.,1 WHP= 930 PSI AT I.O. BPM IAP =960 PSI I CAP = 0 PSI - WHP STABLE AT 640 PSI AT 1.0 BPM SHUT DOWN PUMPAND MONITOR '.- WHP CONTINUALLY DROPPING SLOWLY. OPEN CHOKE AND BLEED REMAINDER OFF. - CIRCULATE ACROSS TOP TO CALCULATE '. LOSS RATE. 16-21 BPH LOSS RATE. - INSTALL MOUSE HOLES, MAKE UP BUILD BHA. ATTEMPT TO GET HIGH BEND MOTOR THROUGH UPPER SECTION OF TUBING -PULL BHA OUT. DISCUSS WITH ODE, DD - DECREASE BEND ON MOTOR FROM 2.92° AKO TO 2.83" AKO. -RUN BHA IN HOLE 9,377.00 PROD1 RIH WITH 4-1/4" DRILLING BHA#1 PRATE: 1.01 BPM IN, 0.97 BPM OUT, CIRC RESSURE: 216 PSI - MUD WEIGHT: 8.35 PPG IN, 8.41 PPG OUT - LOG DOWN FOR TIE-IN FROM 91 80'TO 9252 'MD (FORMATION) WITH -31' CORRECTION a,s1/.V9 PROD1 DRILL4-1/4" FREE SPIN: 2530 PSI, 2.60 BPM - RATE: 2.60 BPM IN, 2.46 BPM OUT, CIRC PRESSURE: 2530-2740 PSI - MUD WEIGHT: 8.77 PPG IN, 8.71 PPG OUT, j ECD: 9.71 PPG -ROP: 5-7'FT/HR, WOB: 2.2-3.35 KLBS 1.75 DRILL P 9,450.00 PROD1 WIPER TRIP PULLTO WINDOW PULLTHROUGH WINDOW, OPEN EDCAND PUH TO 9190' - LOG TIE IN, PUH TO 8600' AND LOG CCL TO LINER TOP PLACEMENT I- TAG AT SLIDING SLEEVE BUT POPPED THROUGH, TAG AT 8792 X -NIPPLE, ORIENT TO LOWSIDE AND TAG, ORIENT TO 90° R j- RM TO WINDOW, CLOSE EDC, TAGGING BELOW THE WINDO W AT 9392 & 9396' ROLL PUMP AT 0.75 BPM STILL TAGGING, ROLL PUMPAT 1.5 BPM, RAN PAST CLEAN, RIH TO CONTINUEDRILLING Printed 12/3/2019 3:30:42PM **All depths reported in Drillers Depths** I TREE = 6-3/8' CNV = MCEVO = BAKERC = _ 54.97' 01/ --6 RCRIJMD PULLED MP REDUCER 12/03/15 - 19.61'3300' _ gDahxnTVD= 10/14/19 MS/JMD SETWHIPSTOCKw/ RA TAGS (1010911 US/U1118 EPD/JMD SETXX PLUG w/F1LL EXT(04..i0M8 32• 8225' 04/07/19 JMD PULL/SETPLUG 9612' 8600'SS 20"X 30' COND, ID = 3UTT, D ;-2 1.347' SAFETY NOTES: H23 READINGS AVERAGE 125 ppm WHEN ON M I `•' WELL REQUIRES A SSSV WHEN ON Mf F -2 -2 -1v -1-4Z1/2- OTIS X NIP. ID = 3.813• �4-1r2.OTISXNIP,ID=3.813• I Minimum ID= 3.80"@8834' 8149' sse xa12 BKR 4-1/2" OTIS XN NIPPLE MILLED 8181' 4-12 ons x NP, ID 4-12' TB G, 12.6#, 13CR-85 VT, .0152 bpf, ID = 3.958• 8250' 5-02'TBGSNB(07/07/191 8751' 8� 264' -1 ssm 5-1/2' TBG -PC, 17#, L-80, .0232 bof. DDS ITOP OF 7' LNR I -U< 1Db, lz-i,L-aU,.UlbZ opt, D= 9-5/8' CS(3, 47#, L-80 BUTT, D = X 7' BKR DELTA WHPSTOCK w/ RA TAGS PERFORATION SUMMARY RE= LOG: SW6BHCS ON 07/02!79 ANGLEAT TOP PERF; 29• @ 9364' Note: Refer to Production DB for historical perf data SIZE I sPF I INTERVAL I Opn/Sgz I SHOT soz SE PAGE 2 FOR PERFORATION DETAILS BUTT, .0371 bpf, D = DATE REV BY COMMENTS DATE REV BY COMMENTS 07/08(/9 ORIGINAL COMPLETION 05/08/19 MS/JMD CUTTBG 8. TBG PUNCH 0426/19 04/18183 RWO 0724/19 Mu 111 RVVO BYINTERVENiIONS 01/ --6 RCRIJMD PULLED MP REDUCER 12/03/15 07/30/19 LG/JMD PULLED PXN PLUG 0728/19 1129/16 AUILH TBG PUNCH, CMTIA, MlLLCIBP(11/1 10/14/19 MS/JMD SETWHIPSTOCKw/ RA TAGS (1010911 US/U1118 EPD/JMD SETXX PLUG w/F1LL EXT(04..i0M8 10/!1/19 JTMIJMD MILLED XN NP 8 EXIT WINDOW 04/07/19 JMD PULL/SETPLUG X 4-12' XO, D OTIS X NP. D = = 3.856' 1-1/Z IbU IAL, U=3.958' ELMD TT LOGGED 12/15/89 ILLED 3.80' EXIT WINDOW w/ 10' RATHOLE 1027/19) FISH: MILLED BKR CJRP 111 n 1 Mel IFISH-3'BKRBP I PRUDHOE BAY UNIT WELL: R-02 PERMIT No: 91781000 API No: 50-029-20354-00 T12N, RI 3E, 637' FSL 8 968' BP Exploration (Alaska) PERFORATIONS Minimum ID = 3.725" @ 8834' 4-1/2" OTIS XN NIPPLE PBT -ORATION SU WRY Rff LOG: SV(6BHCS ON 07/02/79 ANGYEATTOP Pte: 29" @ 9364' Note: Refer to Production CB for hstor" pert data SEE SPF NI92VAL OprVSqz MOT SOZ 3-1/8' ? 9364-9404 S 05121/88 09/12189 33/8" 4 9364-9404 O 10/03/89 2-7/8" ? 9510-9520 S 0621184 10/1 O/85 2-7/8" ' 9510-9520 S 10/17/85 09/12189 33/8' 4 9510-9520 S 10/10/89 05128104 2-7/8" ? 9530- 9576 S 0621/84 10/10/85 2-7/8' ? 9530- 9576 S 10117/85 09/12/89 3318' r 4 9530- 9576 S 10/1089 0528tt4 3318" 4 9576-9580 S 10/1089 052854 33/8' 4 9590-9614 C 10/10/89 0528104 2-7/8" ? 9590-9636 S 0621/84 10/10/85 2-7/8" ? 9590-9636 S 10/17/85 09/12189 33/6" 4 9615-9636 S 12/15/89 07/14/94 2-7/8' ? 9882 - 9687 S 01/17/80 10/1085 33/8' ? 9670-9687 S 11/19/87 09/12/89 33/8' 4 9676 - 9687 S 12/1589 07/14/94 2-7/8" ? 9697-9730 S 01/1780 10/1085 33/8" 4 9700-9710 S 12/15/89 0711484 33/8" 4 9745-9788 S 10/10/89 07/1484 33/8' ? 9745-9789 S 1111918709/12M R-02 PRUDHOE BAY UNR WELL R-02 PERMITNo:1781000 API No: 50-029-20354-00 SEC 32, T12N, R13E, 637' FSL 8 968' FWL DATE REV BYT COMMENTS DATE REV BY COMMENTS 07/08/79 ORIGINAL COMPLETION 0508119 MS/JMD CUT TBG B TBG PUNCH 0426/19 04/18/83 RVVO 0724/19 AAO 111 RWO BYINTEFiVENTpNS 06/07/16 RCR/JMD PULLED MP REDUCER 12103/15 07/30/19 LG/JMD PULLED PXN PLUG 0728!19 1129/16 AOfrLH TBG PUNCH, CMTIA, MILL CIBP(1111 10114/19 MS/JMD SET WHIPSTOCK W/ RA TAGS (10/09/19 05/01/18 EPD/JMD SETXX PLUG w/FILL EXT 0450118 1061119 JTMUMD MILLED XN NIP 8 EXrr WINDOW BP Exploration (Mwka) 04/07/19 JMD PULUSETPLUG Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, November 23, 2019 8:20 AM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad RJ; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Duong, Lea; Infanti, Samuel; Nottingham, Derek; Peru, Cale; Stechauner, Bernhard; Wellman, Julie; Youngmun, Alex, Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; Smith, Travis T (CONOCOPHI LLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: UNDER EVALUATION: Injector R-02 (PTD# 1781000) Temporary flowback post rig workover and CTD sidetrack All, Injector R-02 (PTD# 1781000) was made not operable on 6/2/2018 for failing a drilling screen MIT -IA. The well was worked over with new production tubing on 07/19/2019 under AOGCC sundry #319-081 and later CTD sidetracked under PTD #219-112. The well passed a witnessed waived AOGCC MIT -IA to 3,799psi on 11/19/2019 verify that well barriers have successfully been restored. The well is now ready to be brought online for a temporary flowback via portable test separator and is reclassified as Under Evaluation. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO-titre tegrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, June 2, 201 AM To: AK, OPS EOC Specialists <AKOPSEO lists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Fie-Rh&&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOP56C2Well pad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcon rs1@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com , K, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPB WellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin <Austin.Draughon@bp.com>, 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integn THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean M. McLaughlin Engineering Team Lead — CTO BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU R-02 Permit to Drill Number: 178-100 Sundry Number: 319-366 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this g day of August, 2019. ROMSE(I-�AU6 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 13 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull TubingChange ❑ Chan g Approved Program 11 Plug for Rednll ® r Perforate New Pool ❑ Re-enter Susie Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 178-100 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ . Service ® 6_ API Number. 50-029-20354-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No m PBU R-02 ' 9. Property Designation (Lease Number): 10. Field/Pools: , ADL 0028279 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD:MPSP (psi): Plugs (MD): Junk (MD): 10303 9474 9405 8686 2484 9405.9620 9379,9925 Casing Length Size MD TVD Burst Collapse Stwctural Conductor 80 20" x 30" 38-118 38-118 Surface 2590 13-3/8" 37-2628 37-2628 5380 2670 Intermediate 9272 9-5/8" 35-9307 35-8600 6870 4760 Production Liner 1487 7" 8815- 10302 8175-9473 8160 1 7020 Perforation Depth MD (it): Perforation Depth TVD (ft): Tubing Size: 1 Tubing Grade: Tubing MD (ft): 9364-9404 4-1/2"12.6#x5-1/2"17# 13Cr85 / L-80 33-8878 Packers and SSSV Type: 4-1/2" Baker S-3 Production Packer Packers and SSSV MD (ft) and TVD (ft): 8148/7611 5-12" BOT 3-H Packer 8741 / 8112 12. Attachments: Proposal Summary Z Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ❑ Service 14. Estimated Date for Commencing Operations: September 1. 2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended R 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Sperry, Nathan be deviated from without prior written approval. Contact Email: Nathan.Sperryglibp.com Authorized Name: Mdaughlin, Sean M Contac Phone: 907-564-4258 Authorized Title: Engineering Team Lead - CTD Authorized Signature: / t Date: 91 (I L COMMISSION USE ONLY Conditions Conditions of approval: Notify Commission so that a representative may witness Sundry Number 31�1-3l.OlP Plug Integrity ❑ BOP Test 21 Mechanical Integrity Test ❑ Location Clearance ❑ Other: • (3t�)P'e -, +-0 2o,44(--:ZS-,)IZ&�j 0�P�R~���� Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: 11>-1404 APPROVED Approved by: COMMISSIONER COMMISSION COMMIS Date Form 10-003 Revised 04/2017 ORIGINAL RBDMS AUS 13 2019 Submit Form and Approved application is valid for 12 months from the date of approval Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission -6N1t014 Ar. From: Nathan Sperry �♦ .T p CTD Engineer ��`` Date: August 5, 2019 Re: R-02 Sundry Approval Request Sundry approval is requested to plug off the R-02 injection as part of the drilling and completing the proposed R -02A coiled tubing sidetrack. An AOR will be submitted with the PTD for R -02A. History of R-02: R-02 was originally drilled in 1979 and then it was worked over in 1983. It was perforated in Zone 4 in 1987. In 1988, Sag perfs were added and injection was in both the Sag and Ivishak. In April of 2004, the Ivishak perfs were squeezed off and injection has been Sag only since that time. Due to poor waterflood sweeping capability with the vertical wellbore, it has been proposed to Coil sidetrack in order to improve injection impact. Due to slow TxIA communication, the well is planned to be worked over (tubing swap) prior to sidetrack to allow for MI injection. Proposed plan for R -02A: The sidetrack R -02A will be a "2400' horizontal CST that will kick -out from the R-02 near - vertical Sag -only injector (used to be primarily Ivishak injector). The CST will be drilled to the east and will access a large acreage that has not been effectively swept before. Through making this injector horizontal and adjusting thelocation of injection, the well will be able to inject more water an MI an sweep a muchlarger area than the current well is able to. e sidetrack will be drilled on or around October 15`^, 2019. The rig will move in, test BE and killt e well. -'The window will be milled off a 4-1/2" x 7" delta whipstock set pre -rig. The well kicks -off in the Sag River and will be drilled in zone for the duration. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated. This Sundry covers Plugging the existing R-02 Production via the liner cement iob or liner too Packer. if the liner lap Pressure test fails (alternate plug placement per 20 AAC 25.1126)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin September 181, 2019) 11,, S Dummy GLM's.Drift for whipstock. 1 E`rE`5T 35ap ' 2. E Set whipstock. 3. C Mill XN. Mill window. 4. V Pre -CTD Tree work. -Z4 Y, -o A Rig Work (scheduled to begin October 151h, 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,484 psi). 2. Drill production build section: 4.25" OH, -590' (35 deg DLS planned). 3. Drill production lateral: 4.25" OH, `1816' (12 deg US planned). 4. Pump primary cement job: 43.8 bbls, 15.3 ppg Class G, TOC at TOL (-8812 MD)*. 5. Perforate "'1200' based on drilling logs. 6. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) -Vb Post -Rig Work: 1. V: Install second swab (to allow CTU to RDMO during flowback while well is still flowing if well is able to flow naturally). Tree work as necessary. Pull BPV/TWC as necessary. 2. F: MIT -IA (AOGCC Witness) 3. T: Flowback and Pre -produce down neighboring flowline for 5-7 days (to clean up perfs prior to injection) 4. CT: Test separator assist; N2 lift for 5-7 days (as well will not have GLMs and it is not certain that well will be able to naturally flow once kicked off) 5. S: Install 4.5" LTP (if fail lap). Set MCX 6. F: Pressure test LTP (if set) 7. V: Remove second swab Nathan Sperry CC: Well File CTD Engineer Joe Lastufka 564-4258 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL ('480 psi over -balance at 8,800' TVD). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "open hole" a BHA. Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. Fluids >1% hydrocarbons or flammables must go to Pad 3. Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "o firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: Maximum H2S reading on R-02: N/A (parent well is an injector). Maximum expected based on offset wells is 150 ppm. Reservoir Pressure: • The reservoir pressure on R-02 is expected to be 3,364 psi at 8800' TVDSS (7.35 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,484 psi. TREE= 6-3f8'CNV WELLHEAD= MCEVOY ACTUATOR= _ BAKERC OKB.ELEV= 54.97' BF. ELEV = 19.61' KOP = 3300' MaxAngle= 32- @ 8225' DalmMD= 9617 Dab" TVD= 8800'SS P X 30• COND. D = 12.347" Minimum ID = 3.725" -@8834' 4-1/2" OTIS XN NIPPLE 4-12• TBG,12.6#,13CRA6 VT, .0152 bpf, D = 3.958- ------------- 5-12• TBG STUB (07/07/191 - 8 a -'V2- I BG -PC, 17#, L-80, .0232 bpf, D= 4.892' I .0152 BUTT. D = PERFORATDN SIJMAMRY REF LOa SVSBHCS ON 07/02/79 ANGLE AT TOP P92F: 29' @ 9364' tote: Refer to Production DB for historical perf data I SIZE ISPF I MERVAL IOprWW I SHOT I SOZ SEE PAGE 2 FOR PERFORATION DETALS I PBTD L-80 BUTT, .0371 bpf, D = 6.184' 2211' 1--�4-12" OTIS X NP. ID 14-12'OTIS X MP, ID=3.813' •� 8149'—�9SR'X 4-12'BKR 53 PKR, ID =3.856" 8181' 4-12.0115 X MP, ID —=3-813- -d 3813• 9S/8"X 5-12 UUMQUE OVERSHOT 8368' - Sur CTM a 61 (11/11/16) 8669' 5-12" BKR L SLD SLV, D = 4.313• 8677' - 8678' CTM TBG Pl1NCH (11/10/16) 8717' TBG SEAL ASSY 8741'9 5/8" X 5-12' BOT 3H PIQ2, D = 4.75" 8741' 5-12" X 4-12' XO, D =T-95-8-7 879 4-12'OTISX NP.D=3813• tlt1/B" ��412-TBG TAL,D=3.958' 8878' ELMD TT LOGGED 12/15/89 E REV BY COMMENTS DATE REV BY COMMENTS 10710MORKi84AL COMPLE770N OSAB/19 MS/JMD CUiTBG&TBG PUNCH 0426/19183 RWO 0724M9 AAU 111 KWO BY INTERVENTIONS /16RCRIJMD PULLED MP REDUCER 1MW U71ri 19 LWJMD PULLED PXN PLUG 0728119 1129/18 AO/ILH TBG PUNCH, CMTIA, MLL CIBP 11/12H8) 05/01/18 EPD/JMD SETXX PLUG W/FILL EXT lJOHB 04/07/19 iTFUJMD4 PULUSET PLUG Kr,�e:a= alCi 11i� PRUDHOE BAY UNIT WELL: R-02 PERMIT No: 1781000 API No: 50-029-2035440 '., T72N, R13E, 637' FSL 8 968' BP Explo tion (Alaska) PERFORATIONS Minimum ID = 3.725" @ 8834- 4-112" OTIS XN NIPPLE PEFFORATION SU&N FfF LOG: SN6BFICS ON 07/02/79 ANGLEATTOP PEZF: 2W@93" We: Pefer to AWwtlon TB for listorical pert data S17E SPF INTERVAL Opr1/Sgz SHOT SOZ 3-1/8' ? 9364- 9404 S 0521/86 09/12/89 3-318' 4 9364-9404 O 10!03!89 TFUJMD PULL/SETPLUG 2-7/8' ? 9510 - 952(( S 062184 1010185 2-7/8" " 9510 - 9520 S 10/1785 09/1289 3-318" 4 9510 - 9520 S 10/10189 0528m 2-7/8" ? 9530-9576 S O621184 10/1085 2-718" ? 9530-9576 S 10/17/85 09/1289 338" 4 9530-9576 S 10MO890528,04 338" 4 9576-9580 S 10/10189 052804 3-3/8" 4 9690-9614 C 10(10/890528,04 2-7/0' ? 9590 - 9636 S 062184 1011085 2-7/8" ? 9590-9636 S 10/1785 09/1289 3-3/8' 4 9615-9636 S 1211518.9 07/14/94 2-7/8' ? 9662-9687 S 01/17/8010/10185 33/8' ? 9670-9687 S 11/19187 09/12/89 3318" 4 9676-9697 S 12/1589 07/14194 2-7/8' ? 9697-9730 S 01/1780 1011085 3318' 4 9700-9710 S 12/1589 07/14/94 3318" r4 9745-9788 S 10/108907/14/94 33/8" ? 9745-9789 S 1111918709/1289 R -o2 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/88/79 ORKMAL COMPLETION 05ABM9 MS/JMD CUTTBG B TBG PUNCH 0428/19 04113 88 RWO 0724/19 AAO111 RWOBYINTERVENTIONS OW7tl6 RCR/JMD PULLED MP REDUCER 12103115 07130/19 LG/JMD PULLED PXN PLUG 0728119 1128/16 _ AO/TLH TBG PUNCH, CMTIA, FALL CIBP(11/12/16 05/01/18 EPD/JMD SETXX PLUG w/FILL EXT 04/30/18 04107/19 TFUJMD PULL/SETPLUG SEC PRUDHOE BAY UMr WELL: R-02 PERMrr No: 1781000 API No: 50-029-20354-00 BP Exploration (Alaska) TREE _ 11 WELLHEAD= MCEVOY ACTUATOR= OKB. ELEV = 54.97' BF. ELEV = 19.61' KOP = 33W Max Anilei ' Datum MID = Datum TVD = 8800' SS 13-318" CSG, 72#, PROPOSED REV 2 20" X 30" COND, 118' D= Minimum ID = 3-725" @ 8833' 4-1/2" OTIS XN NIPPLE 4-12" TBG, 12.6#,�VT, .0152 bpf, D= 3.958"8250' s-1/2" TBG STUB (07/67/19) 8251' - 5-1/2" TBG, 17#, L-80, .0232 bpf, D = 4.892" -1 8741' 3-1/4" TOL/TOC 8812' TOP OF 7' LNR 8815' 4-12" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 8878' 9-5/8" CSG, 47#, L-80 BUTT, D -=8.681- 9307' 4-1/2" X 7" BKR TT WHIPSTOCK (_/_/_)9369' - 7" LNR, 29#, L-80 BUR, .0371 bpf, D= 6.184" -9369' FT32FORATDN SLIMM4RY REF LOG: ON ANGLEAT TOP PERF: _' @ _-- Note: Refer to Production DB for historical perf data 6.6#, L-80 TC11, .0079 bpf, D = PBTD bpf, ID = " Rm02A 2211' 14-12" OTIS X NIP, D = 3.813' !1' 1-1412' OTIS X NIP, D = 3.813' 97 95/8' X 4 -VT BKR S3 PKR, D = 3.856' 4-12" OTIS X NP, D = 3.813" V 9-5l8' X 5-12" UNDUE OVERSHOT - 8677' CTMCMT IA (11111/16) F-TE-1--/ZBKRLSLDSLV,ID=4.313" - 8678' CTM TBG PUNCH (11/10/16) TBG SEAL ASSY 9 5/8" X 5-1/2- BOT 3H PKR, ID = 4.75- 5-112- X 4-1/2- XO, 11) - 3,958- 4-1/2"OTIS XNP, D=3.813' -H3.70- DEPLOY SLV. D = 3.00" J--j4-V2- OTIS XN NIP MILLED TO 3 80" ( / / BEHIND 8878'4-12'TBGTAI-,D=3.958' CTLNR 8878' BMD TT LOGGED 12/15/89 13-1/4" X 2-7/8" XO. D = 2.377" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 07M8179 ORKUNAL COMPLETION 0478/83 RWO / CTD ST(R-02A) 0328/18 JMD BUILT PROPOSAL 05/01/78 28/JMD BULT PROPOSAL REV 1 08706/19 AA0111 RAO BY INTERVENTIONS (0724119) PRLDHOE BAY UNIT WELL: R -02A PERMIT No: API No: 50-029-20354-01 , T12N, R13E, 63T FSL & 968' FWL BP Exploration (Alaska) IiLiITanifoldL Choke M -------- --- --------- - — — - - - - — - - Mmwue�— Returns Tank Farm —.— ----- --- — — . . . . . . . . . . . C PUMP SLB CT PUMP 00 00 00 00 00 I I 01 e— — --- ----------- — tSource WaterTank Farm Well Bighole CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis -1.tft-------'—'—'— —'—'—'—'—' Top of 7" Otis 0.0 ft —._.—.—._._._._.—._._._._. Distances from top of riser -CDR2 Rig's Dnp Pan Excluding quick -test sub 7-1116" Sk Flange %7" Oris Boz Top of Annular 6.0 ft dril 7111 Top of Annular Element 6.7ft Annular ; Bottom Annular CL Blind/Shears 9.3 h CL 2-3/8" Pipe/Slips 10.1 h B1 Bx Ba Ba Line Kill Line �eeeeeeeeeeeexChoke Cr 2-3/8" x 3-1/2" VERs 12.6 ft CL 2-3/8" Pipe/Slips 13.4ft CL of Top Swab CL of Flow Cross CL of Master LDS LDS Ground Level 0 16.0 k Hose STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed h UG 0 C ?n, L J Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change AP her. iiPlug for Reddll ❑ Perforate New Pool El Repair Well 0 Re-enter Susp Well ❑ Other. """- -3 ` '-' ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Dnll Number: 178-100 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0 1 6. API Number: 50-029-20354-00-00 7. Property Designation (Lease Number). ADL 028279 8. Well Name and Number: PBU R-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10303 feet Plugs measured 9405, 9620 test true vertical 9474 feet Junk measured 9379, 9925 feet Effective Depth: measured 9405 feet Packer measured 8148, 8741 feet true vertical 8686 feet Packer true vertical 7611. 8112 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2590 13-3/8" 37-2628 37-2628 5380 2670 Intermediate 9272 9-5/8" 35-9307 35-8600 6870 4760 Production Liner 1487 7" 8815-10302 8175-9473 8160 7020 Perforation Depth: Measured depth. 9364-9404 feet True vertical depth: 8650-8685 feet Tubing (size, grade, measured and true vertical depth) 4-1/Z' 12.6# 13Cr85 / L-80 x 5-1/7 17# L-80 33-8878 33-8229 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Production Packer 8148 7611 true vertical depth) 5-1/2" BOT 3-H Packer 8741 8112 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In Subsequent to operation: No Test Available 14. Attachments: (.qulmd per 20 nnc 2507025,071, s 25210) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 15. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Date ❑ 1 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-081 Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: Special Contact Email: Trevof.HyattAbp.com Authorized Signature: Date: (& [to (i1 I - 1 Contact Phone: +1 907 564 4627 Form 10-404 Revised 04/2017 �'` 060�/ RSDMSk�AUG 0 71019 Submit Original Only Daily Report of Well Operations PBU R-02 T/I/O = SSV/0/0 TEMP = SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre Rig PPPOT-T: Stung into test void 150 psi on void bled to 0 psi through (SBS). Monitored for 15 min, no change in pressure. R/U Test equipment. Function all 16 LDS all but three functioned ok. One under wing on THA and two 180 from wing, all three have been flagged. torque all LDS to (550) ffnbs. Pump thought void out (SBS), good returns. Pressure test void to 5,000 psi for 30 min test. Lost 100 psi in 15 min, lost 30 psi in second 15 min (PASS). Bleed test void to 0 psi. Three hard LDS that may need to be replaced. PPPOT-IC: Stung into test void 0 plus on void, held open bleed for 5 min. Monitored for 10 min, no change in pressure. Function all LDS on IC flange. Torque all LDS to (550). Unable to pump though test void. Pressure test to 3,500 psi for 30 min test. Lost 50 psi in 15 min, lost 0 psi in second 15 min 4/15/2019 (PASS). Bled test void to 0 psi. T/I/O SSV/0/0 TEMP = SI, PPPOT-T eval LDS PPPOT-T: Stung into test void 0 psi on void. Monitored for 10 min no change in pressure. Assist (DHD) while R/U bleed hose. Bleed Tubing IA & OA to 0 psi. Held open bleed on (IA) throughout wellhead work. Held open bleed on THA throughout wellhead work. Remove and replace two LDS. Run Taps for lock down pin and gland nut. Unable to remove the third LDS. Put gland nut back on pin and torque to 500 fl/lbs. Test THA to 5,000 psi for 30 min test. Lost 100 psi in 15 in, lost 0 psi in 4/18/2019 second 15 min (PASS). Bleed test void to 0 psi. T/I/O = Vac/36/0. Temp = Sl. Hold open bleed (Assist Cameron). IA FL @ Near Surface. Bled IAP to BT from 36 psi to 0 psi in <1 min, (gas). Maintained open bleed for Cameron during lock down scew C/O. (See Cameron log for details). Final WHP's = Vac/0/0. 4/18/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:30 ***WELL S/I ON ARRIVAL*'* (SCMT/TBG Punch/RCT) INITIAL TWO = 0/0/0. MIRU & PT TO 3550 PSI. RUN 1: LOG SCMT FROM 8700' TO 7100'. IA TOC — 8355' MD. LAY DOWN FOR THE NIGHT. FINAL TWO = 0/0/0. 4/25/2019 ***JOB CONTINUED ON 26 -APR -2019*** ***JOB CONTINUED FROM 25 -APR -2019*** (SCMT/TBG PUNCH/RCT) INITIAL T/I/O = 0/0/0 PSI. R/U & PT. RUN 2: PUNCH TBG 8242'- 8247'W/ 1.56', 4 SPF, 0 DEG PHASE, SMALL CHARGE GUN (good txia pressure response). RUN 3: CUT TBG AT 8251'W/ SRT -SP -3375-100 POLLARD RCT. ALL LOGS CORRELEATED TO TB ALLY DATED 17 -APR -1983. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TWO = 60/0/0 PSI. 4/26/2019 ***JOB COMPLETE ON 26 -APR -2019*** T/1/0=10/10/5 (LRS Unit 42 - CMIT-TxIA Post Tbg Cut, Circ Out) CMIT TxIA PASSED To2929/2939 PSI. (3050 Max, 2500 Target) Pumped 10.4 bbls crude down tbg. to reach test pressure. Loss o psi st 15 min. Loss of 17/16 psi 2nd 15 min. Bled back 10 bbls. Pump the following down the tubing, up the IA to R -29's Flowline: 5 bbls 60/40 spear, 720 bbls Freshwater. 159 bbls Disel. U -Tube between TxIA for 1 hour SV,WV,SSV shut. MV, IA, OA Open. 4/28/2019 FWHP=370/370/0 (LRS Unit 70 - CMIT, Circ Out) Road to location, Walk Job Down. Experience truck issues. LRS 4/28/2019 Unit 42 to replace. T/1/0=0/0/0 Set 6" CIW "J" TWC #408 through tree. Removed existing production tree, installed Dryhole tree Temp #46 with blind and 90 jewelry on top. Torqued to 1191 ft. lbs. FWP's TWC/0/0 5/14/2019 **job in Progress** see log for details. Daily Report of Well Operations PBU R-02 T/I/O=TWCNACNAC. Pre All American Rig. PT TWC #408 to low 300psi and high 3500psi for 5min ea. Passed. PT 6" dry hole tree #46 to low 300psi and high 5000psi for 5min ea. Passed. RU 3" 5000 integral with block valve on I/A. PT to low 300psi and high 3500psi for 5min ea. Passed. RU 3" 5000 integral with block valve to O/A. PT to low 300psi and 3500psi for 5min ea. Passed. Verified VR plug on companion O/A. PT to low 300psi and high 3500psi for 5min ea. Passed. Job Complete 5/14/2019 See log. Final WHP's TWCNACNAC. TWO = TWCNacNac. Temp = SI. WHPs (Pre Rig). Dryhole tree installed. Cellar has - 8" of water and may need to be vac'd. 6/8/2019 SV, MV = C. IA, OA = OTG. 14:50 T/1/0 = TWCNACNAC. Temp = SI. WHPs (Pre RIG). No flowline, wellhouse or scaffolding. Dryhole tree installed. WHPs unchanged since 06/08/19. 6/20/2019 SV, MV = C. IA, OA = OTG. 21:00 DE-MOBE / RIG DOWN PULLING EQUIPMENT RIG DOWN CARRIER -RIG FLOOR - LOWER DERRICK REMOVE UPPER DOG/CHOKE HOUSE MOVE WATER -FUEL TANK 7/3/2019 ...Continue WSR on 7/4/2019... ...Continue WSR from 7/3/2019... Rig up - PJSM with Driver - Operators and Rig Crew on rigging up Set and level Sub base Rig up coflex choke line Set in BOP w/cradle - Dry hole tree - Tubing spool and adapter flange Set sub ramps and spot carrier Raise derick and scope out. Rlg up coflex and iron down stream of choke Hook up service lines 7/4/2019 ...Continue WSR from 7/4/2019... Finish rigging up Rig up and test TWC - Good test. Bleed OA to confirm zero. ONipple up BOPE - Change Pipe rams to 7" 7/5/2019 (LRS unit 70 tank heating for All American Rig) 7/5/2019 Heated tank 073 and 077 to 130`F for All American Rig. .-Continue WSR from 7/5/2019... Accept Rig @ 00:01 hrs 7/6/2019. Function Test BOPE. Rig up test equipment - Fill and Shell test choke and kill lines. Test BOP - Pipe Rams - Blind Rams - Annular - Choke - Kill - HCR's - Floor Safety and IBOP; Dart, Valves Per Sundry. Perform testing on down stream backside of choke valves. Pull TWC. Rig up and circulate the diesel out of the 7" tubing 7/6/2019 ...Continue WSR from 7/6/2019... Rig up and pump down tubing taking diesel to slop tank. Circulate 8.6 ppg surface to surface. Monitor well. Rig up landing joint and make up in tubing hanger. Back out LDS Pull 170K to pull tubing free. Change out Doyon's casing equipment (3 hrs) Attem[t to pull tubing - Trouble shoot clutch and transmison - Circulate - Pull out of the hole laying down tubing F/ 8,251'- T/ 7,670' Total 581' layed down. 7/7/2019 T/I/O=TWC/0/0. Pull TWC for All American Rig. Pulled 6" J TWC #408 @ 105" with one 5' ext. Job 7/7/2019 Complete. See log. Final WHP's 0/0/0. ...Continue WSR from 7/7/2019... Job Scope: Pull 7" TBG, set Baker 9 5/8" Storm PKR, Nipple down BOP's, Change out tbg spool Nipple up BOP's, change out ram insert from 7" pipe to 5 1/2" VBR's, Nipple down tbg spool. test AOGCC waived test. (Brian Bixby) continue pulling 51/2" TBG 7/8/2019 ...Job in progress.... ...Continue WSR from 7/8/2019... Job Scope: Change out tbg spool and test (good) NU BOPE & functiontest. Test Pipe rams and Annular with 4.5" and 5.5" test joints. Set wear bushing. Retrieve 9 7/9/2019 5/8" PKR ...Job in Progress ..... Daily Report of Well Operations PBU R-02 ...Continue WSR from 7/9/2019.. Pull BKR PKR and bring 5 1/2" TBH to surface. Rig having mechanical issues with draw works. Bad bearing in draw works - Start NPT @ 0500 hrs. Rig Crew 7/10/2019 assist the mechanic preparing for bearing and transmission replacement ...Job in progress... Continue WSR from 7/10/2019.. Rig Crew assist the mechanic preparing for bearing replacement on 7/11/2019 D/Works -Circulate S-S 508 bbis @ 3.2 BPM 75 PSI - Monitor well ...Job in progress... ...Continue WSR from 7/11/2019.. Monitoring Well with Trip Tank - Rig Crew assist the mechanic preparing for bearing replacement on D/Works. Bearing parts delayed @ Customs. Ship new set direct from U.S. Expect late tomorrow or Sunday morning. Repair hub @ machine shop. CBU to 7/12/2019 warm well. Final return temp 60f .....Job In Progress .. ... ..Continue WSR from 7/12/2019.. Monitoring Well with Trip Tank Rig crew change out / PTSM = Well and Rig Update - Cleaning and Housekeeping. Gave AOGCC notice of up coming BOP test at 5:43 pm 7/12/2019. Full circulation to warm well. Fire drill. Safety standown recent Incidents 7/13/2019 .....Job In Progress ..... ..Continue WSR from 7/13/2019.. Monitoring Well with Trip Tank / Rig crew change out / PTSM = BP Safety Standown recent Incidents Work with mechanic install new bearing - sprocket. Outer hub stress crack/repair. Man down and WC drill. Resume sprocket installation. Install drive chain - covers - test drawworks- all good - Resume Well Operations 20:00 hrs - PJSM with Rig and Doyon csg crews - UD 5.5" tbg. Total 38 jt 7/14/2019 UD ....Job in Progress ..... Continue WSR from 7/14/2019.. Monitoring Well with Trip Tank / Rig crew change out / PTSM = Laying down 5.5" tbg. Drifted tbg cut w/ 4-1/2" PX Plug. Inspect cut. Max OD 4.550" Min ID 4.668" (burrs) Cut very clean. Pics @ U:\Wells\Interventions WellWork\Well Pictures Info\R\R-02\RCT Cut 07-15-19. Pull wear bushing. Set 13-1/2 Cameron test plug. Drift Unique overshot over cut. Weekly BOPE test (waived by AOGCC). test Gas alarms. PJSM with Rig and Doyon Casing crew - R/U and run 4.5" TBG. per program. 7/15/2019 ....Job in Progress ..... Continue WSR from 7/15/2019.. PTSM = Run 4.5" Vamtop tbg per plan. Ran a total of 80 jts @ 06:00 3,470' with no problems - Monitoring returns on trip tank Kick drill. Work pipe to get over stub saw upper set of pin shear w/ 35k down. Sheared both sets when pipe dropped. Tag/No-go @ 8250. Repeat tag several times and stack 30k down to ensure all the way down. Space out 5' above no-go @ 8245'. Overshot has 13.5' swallow. 8.5' over stub and 5' above no-go. Spaceout/land Tbg 7/16/2019 run in LDS's - Rig up and test TWC - Flush BOP and Choke manifold - Continue WSR from 7/16/2019.. PTSM = Nipple down BOPE - Remove choke and kill NCR's and lines - Take off koomey lines and roll up R/D hard line from choke. 3 hours to move the stack from wellhead to BOP stand. Bridge cranes would not travel. Move stack w/ tuggers and loader. NU THA / dry hole tree. Valve shop torque both. Test and chart hanger void to 4500 psi 15 mins. Lost xx psi (Pass) 5-minute 4500 psi visual leak tight test of the tree. Rig released F/ R-02 @ 18:00 hrs 7-17- 7/17/2019 19 Rig down and move to Peak yard for transmission replacement. T/1/0=TWC/150/0. RU 6" ASV #13. Torqued to API spec. PT to low 300psi and high 5000psi for 5 min ea. Passed. Pulled 6" J TWC #424 @130". PT tree cap to 500psi for 5min. Passed. Job 7/18/2019 Complete. See log. Final WHP's 0/150/0. T/1/0=0/0/0 Temp=Sl (LRS Unit 76 - Circ Out, Set Packer Post Pulling Unit) Pump the following down the IA, taking returns up the Tubing, to surface tanks. 5 bbl 50/50 spear, 150 bbls 2% KCI ***55 bbls before catching pressure*** 310 bbis Inhibited 2% KCL and 172 bbsl 90* Diesel U-Tube Diesel FP into IA. Well went on vac during U-Tube. CMIT-TxIA Failed. Pumped 9.3 bbis to pressure TxIA to 2972/2912. Conducted 30 min pressure test. 1st min lossof 1055/1053 psi. 2nd 15 min loss of 818/811 psi. Established LLR of 0.16 BPM @ 2000 psi. SSV/SV Shut MV,IA,OA Open 7/19/2019 FWHP=0/0/50 Daily Report of Well Operations PBU R-02 T/1/0= -12/-12/-6 (LRS Unit 76 - Assist Slickline: Leak Detect Log, LDL) Pumped 101 bbls of DSL down IA and maintained 2300-2500 psi to assist SL with LDL. Bled TBG/IAP together to 0 psi. Bled 7/26/2019 back - 9 bbls. SB for data results ***Continued on 07/28/19'** '**WELL S/I ON ARRIVAL*** (RWO capital) TAG 4-1/2" HES RHC -M W/ 2-1/2" x 10' DUMMY GUN, 3.70" CENT AT 8,166' SLM / 8,181' MD. RAN READ ARCHER LDL FROM 8,165' SLM TO SURFACE (Data sent to Houston for analysis). 7/26/2019 ***JOB IN PROGRESS, CONTINUED ON 7/27/19 WSR*** 'Continued from 07/26/19*** (LRS unit 76 - Assist SL w/ LDL) Good data results. PDS/SL determined leak is below packer on IA. Pump the following down the IA, taking returns up the Tubing, to surface tanks for circ -out: 5 bbl 50/50 spear, 150 bbls 2% KCI 310 bbls Inhibited 2% KCL and 172 bbsl 100* Diesel freeze protect U -tubed IA over to TBG for freeze protect. MIT -T **Pass** Pumped TBG up to 4219 psi with 4.5 bbls of DSL max applied 4250, TBG lost 154 psi in 1 st 15 min, 2nd 15 min TBG lost 60 for a total of 214 psi lost in 30 mins. bled TP to 500 psi bled back 3.1 bbls MIT -IA **Pass** Pumped IA up to 3473 psi with 7.3 bbls of DSL max applied 3500, IA lost 62 psi in 1st 15 ,2nd 15 mins IA lost 28 for a total of 90 psi lost in 30 mins. bled IAP to 300 psi bled back 7.3 bbls Hung tags. SLB SL left in control of well IA,OA = OTG 7/27/2019 Final WHP's = 500/300/40 ***CONTINUED FROM 7/26/19 WSR*"* (RWO capital) LEAK DETERMINED TO BE BELOW BAKER S3 PACKER & 4-1/2" RHC -M BODY AT 8,181' MD. LRS PUMPED CIRC OUT AT 3 BPM PER PROGRAM & U -TUBED DIESEL FREEZE PROTECT. DEPLOY BALL & ROD. LRS SLOWLY PRESSURED UP TBG TO SET BKR PACKER. LRS PERFORMED SUCCESSFUL MIT -T TO 4005 PSI (Tbg bled to 1500 psi per program). LRS PERFORMED SUCCESSFUL MIT -IA TO 3382 PSI. PULL B&R FROM 4-1/2" HES RHC -M BODY AT 8,166' SLM / 8,181' MD. PULL 4-1/2" HES RHC -M BODY FROM X -NIPPLE AT 8,166' SLM / 8,181' MD. UNABLE TO PASS 8,789' SLM W/ 3.50" BELL GUIDE, 2-1/2" JUS (-25' high of prong). BAIL 1 GALLON OF PLASTIC / RUBBER CHUNKS FROM 8,787' TO 8,789' SLM. 7/27/2019 *'*JOB IN PROGRESS, CONTINUED ON 7/28/19 WSR*** ***CONTINUED FROM 7/27/19 WSR*" (RWO capital) BAIL -12 GALLONS OF RUBBER / IPC MIX OFF OF EQUALIZING PRONG AT 8,834' MD PULL EQUALIZING PRONG FROM 4-1/2" PXN PLUG BODY AT 8,815' SLM. PULL 4-1/2" PXN PLUG BODY (Rig trash in body) FROM 8,823' SLM / 8,834' MD. TAG HARD BOTTOM AT 9,387' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK (No issues). 7/28/2019 'WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS'*' MCEVOY ^ Zrc r rvM i ea: n<b Kt UINbb A V u UL i m ppm = BAKERO =O` I WHEN ON MI"' WELL REQUIRES A SSSV WHEN ON MI NITIAL KB. ELE 54.9T DATE 71 3F. ELEV = 19.38' 05/08/19 2211'4-12" OTIS X NIP, D = 3.813" COP = 3300' 0724/19 AAO 111 RWOBYINTERVENTIONS ,lax Angle = 32° 8225' -CONDUCTOR ? 07/30/19 LG/JMD PULLED PXN PLUG 0728119 )atumM)= 9612' 05/01/18 EPDUMD SET XX PLUG W/FLL EXT 04/30/18 )atum ND = 8800' SS 04/07/19 ffWJMD, PULUSET PLUG 13-3/8' CSG, 72#, L-80 BUTT, ID = 12.347"]--[2628' 8121' 4-12" OTIS X NIP, D = 3.813' 8149' 95/8"X4-12"BKR S3PKR,D=3.856" Minimum ID=3.725"@8834' 4-1/2" OTIS XN NIPPLE 8181' 4-12" OTIS X NIP, D = 3.813" 4-12' TBG, 12.6#,13CR-85 VT, .0152 bpf, ID = 3.958" $250' 5-12' TBG STUB (_1/19) DEPTH? 8264' 9-5/8" X 5-12" UNIQUE OVERSHOT 835W - 867T CTM cMi w (11/11/16) 8659' 5-1/2" BKR L SLD SLV, D = 4.313" 5-1/2" TBG -PC, 17#, L-80, .0232 bpf, ID = 4.892" 8741' 8677' - 8678' CTM TBG PUNCH (11110/16) 8717' TBG SEAL ASSY 8741' 9 5/8" X 5-1/2" BOT 3H PKR, D = 4.75" 8741' S-1/2" X 4-1/2" XO, D = 3.958" 8792' 4-1/2" OTIS X NP, D = 3.813' TOP OF 7" LNR 8815' 8834' 4-1 /2" OT XNXN NP, D = 3.725" 4-12' TBG, 12.6#, L-80, .0152 bpf, D = 3.958" $$78' 8878' 4-1/2" TBG TAIL, V= 3.958" 9-5/8" CSG, 47#, L-80 BUTT, K)=8.681" 9307' 8878' ELMD TT LOGGED 12/15/89 9379'CTM FISH: MILLED BKR CIBP(11/11/16) 9405' ESTMATEDTOC (TAGGED 05/26/04) PERFORATION SUMMARY REF LOG: SWS-BHCS ON 07/02/79 ANGLE AT TOP PERF: 29'@ 9364' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT S& SEE PAGE FOR PERFORATION DETAILS 7" LNR 29#, L-80 DATE REV BY COMMENTS DATE I REV BY COMMENTS 07/0&79 ORIGINAL COMPLETION 05/08/19 MS/JMD CUTTBG & TBG PUNCH (0426/19) 04118/83 RWO 0724/19 AAO 111 RWOBYINTERVENTIONS 06/07116 RCR/JMD PULLED NP REDUCER It2/03/15 07/30/19 LG/JMD PULLED PXN PLUG 0728119 1129116 AO/TLH TBG PUNCH, CMT w, MILL CIBP(11/12/16) 05/01/18 EPDUMD SET XX PLUG W/FLL EXT 04/30/18 04/07/19 ffWJMD, PULUSET PLUG TOP OF CEMENT PRUDHOE BAY UNIT WELL: R-02 PERMIT No: 1781000 API No: 50-029-20354-00 I, T1 2N, R1 3E, 63T FSL & 968' BP Exploration (Alaska) PERFORATIONS Minimum ID = 3.7250'@ 8834' 4-1/2" OTIS XN NIPPLE PERFORATION SUfv`IMARY REF LOG: SVvSBHCS ON 07/02/79 ANGLE AT TOP FERF: 29" @ 9364' Note: Refer to Production D13 for historical pert data SIZE SPF INTERVAL Opn1Sqz SHOT SOZ 31/8" ? 9364-9404 S 05/21/88 09/12/89 33/8" 4 9364-9404 O 10/03/89 2-7/8" ? 9510-9520 S 06/21/64 10/10/85 2-7/8" " 9510-9520 S 10/17/85 09/12/89 33/8" 4 9510-9520 S 10/10/89 05/28/04 2-7/8" ? 9530-9576 S 06/21/84 10/10/85 2a/8" ? 9530-9576 S 10/17/65 09/12/69 33/8" 4 9530-9576 S 10/10/89 05/26/04 33/8" 4 9576-9580 S 10/10/89 05/28/04 33/8" 4 9590-9614 C 10/10/89 05/28/04 2-7/8" ? 9590-9636 S 06/21/84 10/10/85 2-7/8" ? 9590-9636 S 10/17/85 09/12/89 33/8" r 4 9615-9636 S 12I1589 07/14/94 2-7/8" ? 9662-9687 S 01/17/8010/10/85 33/8" ? 9670-9687 S 11/19/87 09/12/89 33/8" 4 9676-9687 S 12/15/89 07/14/94 2-7/8" ? 9697-9730 S 01/17/8010110/85 33/8" 4 9700-9710 S 12/15/89 07/14/94 33/8" 4 9745-9788 S 10/10/89 07/14/94 33/8" ? 9745-9789 S 11/19/8709/12/89 R-02 DATE COMMENTS DATE REV BY COMMENTS 07/08!/9ORIGINAL COMPLETION 05/08/19 MS/JMD CUT TBG 8 TBG PUNCH (0426/19) 04MI8B3RWO 0724/19 AA0111 RWOBYNTERVENTIONS 06/07/16 PULLED NP REDUCER 12/03/15 MEPDIJMD 07/30/19 LG/JMD PULLED PXN PLUG 0728/19 1129/16TBG PUNCH, CMT IA, MILL CBP(11/12116) 05/01/18 SET XX PLUG w/FLL EXT 04/30/1804/07/19PULL/SETPLUG 11 PRUDHOE BAY UNIT WELL: R-02 PERMIT No: 1781000 API No: 50-029-20354-00 SP Exploration (Alaska) Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: '+t 4/ AOGCC -+ " ATTN: Natural Resources Technician 11 Alaska Oil&Gas Conservation Commision r, 333 W. 7th Ave, Suite 100 ., Anchorage, AK 99501 TRANSMITTAL DATE TRANSMITTTAL# 17 81 00 ESERVICE ORDER SERVICE COLOR LL NAME API # p FIELD NAME 50-029-23385-00 4: 0, DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs Print Name( ) Signature return via courier or sign/scan and email a copy Date Schlumberger and BP Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, ynvelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin CTD & RWO SDE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-02 Permit to Drill Number: 178-100 Sundry Number: 319-081 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, vl-e� Daniel T. Seamount, Jr. Commissioner �p DATED this Z/ day of February, 2019. g 16 2019 RBDM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 . PE UEE nVFi,.a n:. 1. Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 11 Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory 11 Development ❑ p ry 5. Permit to Drill Number 178-100 - Address: P.O. Box 196612 Anchorage, AK 3. 9 6. API Number: 50-029-2035400-00 99519-6812 Stretigrephic ❑ Service IZ. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU R-02 9. Property Designation (Lease Number): I 10. Field/Pools: ADL 028279 - PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD' Effedive Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10303 9474 8792 8155 2780 8792.9405.9620 9379,9925 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 38-118 38-118 Surface 2590 13-3/8" 37-2628 37-2628 5380 2670 Intermediate 1 9272 9-5/8" 35-9307 35-8600 6870 4760 Production Liner 1487 7" 8815-10302 8175-9473 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:Tubing Grade: Tubing MD (ft): 9364- 8650-8685 T' 26# x 5-1/2" 17# x 4-1/2" 12.6# L-80 33-8878 Packers and SSSV Type: 41/2" BOT 3H Perm Packer Packers and SSSV MD (ft) and TVD (ft): 8741 / 8112 No SSSV installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13, Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ StraBgraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: May 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning, Zachary H be deviated from without prior written approval. Contact Email: Zachary.BrowningQbp.com Authorized Name: Mdaughlin, Sean M Contact Phone: +1 907 564 5220 Authorized Title: CTD 8 RWO SDE 'Z Authorized Signature: Date: / 2Z 7 COMMISSION USE ONLY Sundry Number: �t^ Conditions of approval: Notify Commission sothatas representative may witness !".11 1 BOP Test Gr Mechanical Integrity Test CCd� Location Clearance ❑ Plug Integrity ❑ r Other of %/E57" To 3Sco� S/ 161019 Post Initial Injection MIT Req'd? Yes ❑ No ❑J pBDMSg RI Spacing Exception Required? Yes ❑ No W Subsequent Form Required: �Q — SI APPROVED BYTHE Approved by COMMISSIONER COMMISSION Date. 7 Q0, ,,� ID11 ' Form 10-403 Revised 04/2017 ORIGINAL Approved application is valid for 12 months from the date of approval. Submit Form and ttachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Zach Browning RWO/CTD Engineer = b Date: February 21, 2019 ��to Re: R-02 Sundry Approval Well Type: Injector Current Status: The well is currently shut-in, listed as non-operable (TxIA communication). Request: Sundry approval is requested for plans to restore tubing integrity. History and current status: R-02 was originally drilled in 1979. In 1983 it was recompleted with a 7" X 5.5" tapered tubing string. In 1984 it was converted to an Ivishak injector. Sag perfs were added in 1988 and it was a Sag and Ivishak comingled injector. The well was frac'd in the Sag in Oct 1989. In 2004, Ivishak perfs were isolated (Bridge plug set - sand plug, and cement cap with top @ 9421') and it was converted to a Sag only injector. In NOV-2017 an IA cement job was done to mitigate TxIA communication at the sliding sleeve above the packer. R-02 is currently a vertical Sag only produced water injector. It was intended to be a WAG injector, but it showed slow TxIA communication while on produced water injection (with an IA build up rate of -76 psi/day). Proposed plan: The All American Oilfield 111 pulling unit will swap the tubing to restore tubing integrity. MASP=2780 psi. AAO 111 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines • One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to make R-02 Operable for MI injection via replacing the current tubing with 4.5", 13Cr tubing with gas tight threads. Pre -Ria Prep Work: 1. V: PPPOT-T, PPPOT-IC. Cycle LDS. 2. F: CMIT- TxIA to 3500 psi, OA Integrity test to 1200 psi. 3. E: Set PX plug in tubing tail. Cut Tubing at -8300' MD 4. F: CMIT-TxIA. Circulate out well. 5. O: Purge control lines. 6. V: Install BPV. 7. O: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed for the pulling unit. Proposed RWO Procedure: ) /j _ n ' , 1. 1IRU. ND tree. NU and test BOPE. 2 -4p A#--� oyer 2. FuII 7" x 5-171 u ing. 3. Contingency -Change out tubing spool and IC packoff. 4. Run new 4-1/2" 13Cr Completion with production packer set at -8200' MD and overshot. 5. Freeze protect well. Set TWC. ND BOPE. NU and test tree. RDMO. Post ria Work: 1. F: Circ inhibited SW, Drop B&R, Set and test a. State wtn iess of MIT T and IA test to 2. S: Pull B&R, RHC sleeve. Fish PX plug. Set I 3. V: Tree work as necessary. Install S -Riser MIT -T & MIT -IA to 3350 si i prior to in6ection. joerr SGC, Zach Browning CC: Well File RWO/CTD Engineer Joe Lastufka 564-5220 _= 6-319* CW L-EAD= M�VOYMVOY UATOR= BA1032C R-02 ND DEV AL 103. BLE 54.9T VLV LATCH 3F7 = 19.38' DATE 8 -... _ 3300' 3145 8 ? Angle 32" @8225' �'234P7 EW RA nn MD 9612' #. 07113184 7 xn13-3/8' CSG, 72#, L-80 BURT, D 2628' T 3. 26#. L-80..0383 bpf, D=6.276' 2980' 4933 O Minimum ID = 3.726" @ 8833- 4-1/2" OTIS XN NIPPLE 15-i2 TBG -FC, 17#, L-80,.0232 bpf, D = 4.89Z- 2599' 9-5/8• w Raz 9�9R0' 7" X 5-12' XO. F= I' CAMOO SSSV LANDING NP, D = r-4 C 1 Fr LW NI -M S ST M) ND DEV TYPE VLV LATCH FORT DATE 8 3147 3145 8 6T15 EW RA 0 07113184 7 5096 4933 28 OTIS DMY RA 0 07/13/84 6 6572 6233 29 OTIS DMY RA 0 07/13184 5 7637 7159 31 OTIS DMY RA 0 07/13/84 4 8225 7662 32 OTIS DMY RA 0 04/18/83 3 8362 7777 32 OTIS 'DMY RA 0 04/18/83 28460 7860 32 OTLS 'DMY RA 0 3/8 07/14 1 8593 7973 32 OliS 'DAAY RA 0 07113/84 'DMY VLVS CEMENTED 11/1 111b 8368' -867T CTM cMT a (1 v1 v1s) T--8659' �5-1/2-BKRLSLDSLV,U=4.313" 8677' - 8678' CTM -TBG Plx'r.H (11/10/16) 871 T TBG SEAL ASSY 8741' 95/8' X 5-112' BOT 3H PKR D = 4.75' 8741' 5112' X 4-112' XO, D = 3.958' 8792' WI/YOTISX NP, D=3.813' 8792' 4-1/2' XX FLU* -/FILL TXT (04130118; A—�4-1/2" OT6 XN NP, D = 3.725' 4-12" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 1--i:9307"j /V CSG, 47#, L-80 BUTT. D = 8.681" 9-5 9379'CTM Rsltnw-L®BICRCBP(ttn PERFORATION Sl1AMARY RET= LOG: SWSBH S ON 07/02/79 ANGLE AT TOP PERF: 29` @ 9364' Fbte: Refer to Roduction DB for historical pert data. SEE PAGE 2 FOR PERFORATDN DETAILS FISH-3'BKRBP I PBTD L-80 BUTT. .0371 bpf, D=6.184" DATE I REV BY COMMENTS DATE REV BY COMMENTS PRLUHOE BAY UFlT WELL: R-02 PWIVIT W: r17811000 API No: 50-029-20354-00 SEC 32, T12N R13E, 637' FSL 8 968' FWL 07108179 ORIGINAL COMPLETION 06/07116 RCW PLLLED NP REDl10EIR(12103115) 04118183 RWO 11129116 AO/TLH TBG PUNCK CMT W, ALL CBRI1112J 11126/01 RWTP nDNS 05/01/18 EPLYJAU SEF XX PLUG w /FLL EXT (04!30/18 07124/15 PJC BF ELEV LVDATE (BELL 2012) 07129/15 PJC PERFWIRRECTONS �Exploration (Alaska) 12107/15 DLFYJ PULLED FISH8 FLl1G(12/D4/15) PERFORATIONS FEF FORAATION SLO"Rf FIEF LOG SVYS4*iCS ON 07IO2f79 ANGLEAT TOP PERF: 29'@ 9364' Flote: Fifer to Prodmton OB for hmlb al perf data SIZE SPF WERVAL OpnlSrg SHOT SOF 3-1/8' ? 9364 - 9404 S 0521188 MUM 3.3/8' 4 9364-9404 O 1010389 2-78' 1 9510-9520 S 062184 10110/85 2-78' ' 9510-9520 S 10/17185 09/1289 3-38' 4 9510 - 9520 S 10110M 052&04 2-7/8' ? 9530-9576 S 062184 10/10/85 2-718' ? 9530-9576 S 10117/85 09/1289 3-316' 4 9530 - 9576 s 10/10189 0528104 3-3/8" 4 9576-9590 S 10110M 0528104 3-38' 4 9590-9614 c 10/10189 0528104 2-7/8' 7 9590-9636 S 0621/8410/1085 2-78' ? 9590-9636 S 10117/85 0911289 3-38' 4 9615-9636 S 12115M 07114194 2-78' ? 9662-9687 S 01/171801011085 3-38' ? 9670-9687 S 11119187 0911289 3-38' 4 9676-%87 S 12/15189 07/1484 2-78' ? 9897-9730 S 01/17/80 10/10M 338' 4 9700-9710 S 1211589 07/14/94 3-38' 4 9745 - 9788 S 10110M 07/14194 3-W ? 9745-9789 S 11/1987 09112M U R-02 PRUDHOE BAY UN! W9 -L R-02 PF3Mf W:'1781000 ARM: 54029-20354-00 SEC 32, T42µ R13E, 63T FSL 8 969 FWL BP Pxploratim (Alaska) TREE= 6-3/8° CfWV 0 A SAFETY NOTES: H2S READINGS AVERAGE 125 ppm ELLHEAD= MCEVOY PProposed,R=02 _ L WHEN ON MI — WELL REQUIRES A SSSV WHEN ON MI'"" rx Angle= az to oeca mm -- Z= 9812' —#, —. rtum N=D8BO SSSS D=_" 13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347" 2628' 4-112" TBG, 12.6#, 13Cr85 VamTop —� Minimum ID = 3.725" @ 8833' 4-1/2" OTIS XN NIPPLE = 8.681" PHiFORATK N SUMMARY REF LOG: SWS-BRCS ON 07102/79 ANGLE AT TOP PERF: 29" @ 9364' Note: Refer to production DB for historical pert data SIZE I SPF I Opn/Sgz SHOT SQZ SEF PAGE 2 FOR PERFORATION DETAILS PBTD 10225' 2200' 4-112" FES X NIP, ID = 3.813" 2599' 9-5/8" DV R(R — 4-i12' HES X NIP, 10 = 3 813' �� 4-112" x 9-518" HES'TNT RCR , D = 3.88" 41/2"HESX NP,D=3.813" 4-i12" UMI Overshot J -j5-1/2" BKRL SLU 5LV, N=4.41 - 8678' CTM TEG PUNCH (11/10/161 TBG SEAL ASSY F9518" X 5-1/2" BOT 3H PKR, ID = 1•5-1/2" X 4-1/2" XO, ID= 3.958" 4-1/2" OT1S X NIP, D = 3.813' y 4-1/2" XX RUG W/FLL EXT (O4L 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2' TBG TAL, D = 3.958' 'g• '� E1MD TT LOGGED 12/15/89 CTIU FRH MILLED BKR CBP(11/11/ PRUDHOE BAY UNIT WE -L: R-02 PERmrr No: 9781000 AFI No: 50-029-20354-00 SEC 32, T1 2N. R1 3F- 63T FSL 8 968' FWL BP Exploration (Alaska) 1 2 3 4 — 41.211 ° ° ° ° A A T-815/16" SHENKAI SL 13-5M ANNULAR 6-103/6' SHENKAI SL 13-5M DOUBLE RAM B B 61.511 9' 17/6 -T 4'_611811 3'-25/8" F-1/2" C C 1'-93/4 0 °jO ° 0 0 °10' + o 4" ° 111/2, o 0 ° GIO ° ZMINPEN 51.31/2' CLOSING / OPENNING VOLUME (GAL) ITEMS CLOSING VOL OPENNING VOL 300 ANNULAR 23.59 17.41 RAM 4.39 3.91 p D HCR 0.40 0.40 THECONTENTSOFTMSDRAWING ARETHEPROPERTTOFNESTERN PROJECT TITS 6OP 13-5M BOP STACK N ORMATION IN THIS REPROYSERVICEs wRP.ANY N OF THIS �AERO°WG"� A-000.15-002 SCAIE WEIGHT REV DRANANG IS R FO REFERENCE ONLY DRAWNULTIO MYNNG WTHOUT THE ExPREss PERMISSION OF WESTERNI^'^L^ _._. DR/WN DATE O TY 28/Feb2018 N.T.S. AND ISNOT FOR 0 INITIALflEIFhSE CONSTRUCTION. TY MJP DIR.1ar201E ENERGY SERWCES CORPIS BY MPD DATE STRICTLY PgOHISITE°. APPROVfO DATE SIZE SHEET MJP D1/Med2D18 A 1 OF 1 REV DESCRIPTKK! 2 3 4 1 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,June 2, 2018 11:35 AM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad RJ;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Draughon, Austin;Wallac , Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Project Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Informatio ; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternic i, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector R-02 (PTD# 1781000) Failed drilling screen MIT-IA Attachments: R-02.pdf All, Injector R-02 (PTD#1781000)operates under AOGCC Administrative Approval 36.007 for slow TxIA communication. n 6/2/2108 DHD performed a failing drilling screen MIT-IA indicating a deterioration of the mechanical condition of the well, and a lack of two competent barriers. At this time the well is reclassified as Not Operable and will remain shut in and secured with a tubing tail plug. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCANNED JUN o 62018 Cell: 907-341-9068 WC) 1 Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday,January 21, 2017 7:03 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Schultz, Kirsten L; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J; Regg,James B (DOA);AKIMS App User Subject: UNDER EVALUATION:Injector R-02 (PTD #1781000) Possible Tubing x Inner Annulus Communication Attachments: Injector R-02 (PTD #1781000) TIO Plot 2017-01-21.docx All, Injector R-02 (PTD# 1781000), currently on Produced Water Injection, has begun to exhibit possible indications of tubing x IA communication.The well passed an AOGCC-witnessed MIT-IA on 12/20/16.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Downhole Diagnostics: Bleed IA pressure—Completed 01/14/17 2. Downhole Diagnostics: Monitor wellhead pressures—In progress 3. Wellhead: Positive Pressure Packoff Test—Tubing 4. Well Integrity Engineer: Additional diagnostics as needed A TIO and Injection plot is attached. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey scale MAR 0 0 2017 Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 From: A , .• - Integrity Sent: Tuesday, November 22, 20 . . To: AK, GWO SUPT Well Integrity; AK, OPS GC . • K, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS EOC Specialists; Cismoski, Doug •, !.niel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; 'chris.wallace@alas..=•v' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, G e letions Well Integrity; AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Schultz, Kirsten L; Hibbert, Michael; Janowski, Carr , ontgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, J; 'Regg, James B (DOA) Injector R-02(PTD#1781000) TIO Plot 2017/01/21 MN1:5,02 •'b 2OOP xc 0000 .p 1611n6 105tK t1A✓lt I Ir'K 111y16 11'3116 123016 0I2.7 Oi'r,i' Or 2:.. Injection Plot NO:R@ I 010 r 900 � 110 1W 1� 1.100 Ii 7_7 tN0 _l�1r ;. -PW Ia0°{ -M ace S,0 10'2011 102110 1122012 1211 . ,,. 11.00'+6 I]n61t 12121% t11076 OtgVt> 01.7.11 O1.161' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 21,2016 P.I.Supervisor ''.1- �C; (Z1 z /,, SUBJECT: Mechanical Integrity Tests (;1 BP EXPLORATION(ALASKA)INC. R-02 FROM: Chuck Scheve PRUDHOE BAY UNIT R-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-02 API Well Number 50-029-20354-00-00 Inspector Name: Chuck Scheve Permit Number: 178-100-0 Inspection Date: 12/20/2016 Insp Num: mitCS161220151415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-02 . Type Inj W TVD 8099 -. Tubing 797 799 . 798 799 PTD 1781000 Type Test SPT Test psi! 2025 IA 393 2298 - 2241 - 2227 - I Interval l°THER P/F P OA 121 301 294 - 291 • Notes: Test performed post IA squeeze to repair leaking sliding sleeve at 8659 MD. SCANNED APR 0 5 2 ?.. Wednesday,December 21,2016 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change ApprovedProgram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well IvT Re-enter Susp Well ElOther:Packel`n, queezet I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 178-100 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20354-00-00 7. Property Designation(Lease Number): ADL 0028279 8. Well Name and Number: PBU R-02 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10303 feet Plugs measured 9405 feet DEC 19 2015 true vertical 9474 feet Junk measured 9379/9925 feet Effective Depth: measured 9405 feet Packer measured 8741 feet O 3CC true vertical 8686 feet Packer true vertical 8112 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 37-117 37-117 Surface 2595 13-3/8"72#L-80 35-2631 35-2631 4930 2670 Intermediate 9288 9-5/8"47#L-80 34-9322 34-8614 6870 4760 Production Liner 1487 7"29#L-80 8815-10302 8175-9473 8160 7020 Perforation Depth: Measured depth: See Attachment feet SCANNED AIN 1 4 2‘017 True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"BOT 3H Perm Packer 8741 8112 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8358'-8677'in IA. Treatment descriptions including volumes used and final pressure: 19.2 Bbl 15.8 ppg Cement,232 Bbls 60/40 Methanol/Water,11 Bbls Fresh Water,80 Bbls PowerVis,811 1%Slick KCL,608 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1047 760 1999 Subsequent to operation: Shut-In 0 0 14.Attachments:(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG I3 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-384 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature /-V it/‘w.-1______L -__ Phone +1 907 5644424 DECate 12/15/16 Form 10-404 Revised 5/2015 'Oh✓ATL �/J RBDMS 2 / ®MS V' t� �O I� Submit Original Only • i (v CA la m N- N co r- Cn r- co N r- co V r- cr N N N co 00 0) r- (O N- M CO (` CO O 00 LO O O) N- CDN r- r- t Ln CO (O cn N- O lf) 00 OO M 07 Ch V 07 V r- Lr) N m 00 CO C) C`') (O N- N- CO v- N N M V V L() N- N o (fl r- CO OD 00 CO 00 00 CA C)) CA CA CA CA CA CA O O CO CO 00 CO 00 CO 00 CO 00 CO CO 00 CO 00 00op CO CA CA I- Q 0 Nr L1) N c- LC) c- N r- 00 r- r- L co N N- N- co CO C0 O CO N) OCD N 2O 5 cd u c O OO M01 N ci Ni Ch c v- p 0 CO CO N- CO CO CO co CO CO O) cn a) a) O) C) > CO 00 CO CO CO CO CO CO CO CO Cb C O C o M co 0) 0 I- LU CC 0 0 W z W p fV I- I- O d g g < U O > v C7 CO O N Ln r- CO O U1 (O N- CA 0 0 O CD CO O O Q Q W W W 00 r- c- I- (` (` 00 CD O r- r M 00 00 < < < W CL 0_ (n 1 O N (- N coC 0 V' LO Li) CO CO CO CO co CO CO CD CO N- N- N- N- N- N- _0 _0 _0 J W W O J O 0 CA O)(� CA CD CA O) CA cn CA CD C)) CA CD CA CA CD CA CD CD CDCI) Z Z Z 0 p p Q Q < 0 0 d a _ U 22 U U w Z p Z V N N c) v¢) v¢) - o < 0 H C w ct 0 C) CO O N LC) r- N O L11 (O N- 0) O C) r- U C) MM O- CO r- C`') I,- CA r- r- N CO N- N- N- 0) O) O T- r- Nr co W co in Ln CO Q1 CO CO co CO (D CO CO CO CO N- N- N- N- ti a U) cs) a) CA Cn CA O) O) a) o) o) a) a) CA (s) a) a) O) a) Cu cn _ I- I- a J 0 2 O u) cn (n (n Cn C, a 0 U c .° LL co 00 u) cn (n (n 000) 0) 00 n u) u) 0) n (n U) maaaaaao_ aaaaaaaaaaaa Qommmmmmmmmmmmmmmmmm 0 t d 0 Cu H 0 CO O CD C7 C) O O O O O O C) CD O C) O O O O p 6) O CD 0 0 CD 0 0 0 0 0 0 CD 0 0 O O O C) 1.1-1 J Z oN- N N N N N N N N N N N N N N N N N N Z LL. 1 1 < _U W 0 LU N N LL 07 00 00 00 00 00 00 00 00 00 00 00 00 00 CO CO 00 00 CO W 11 0 JJ N N N N N N N N N N N N N N N N N N Z a J U JLJ pW W W W Q r ) ) ) ) C U LU C U LU LU L() LU L) C 0 L L) 141 U1 LU < 0 _ J - H -J J D J_ 0 d' 0_ 0 m 0 D Y W J J 3 Q 0 W 0 E (a z N N N N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 CO CD O O O O O O O O O Ll_ C1 wW O N J !r LL • • ca. oo00o0 N- O N - 00 O O O N LO CO I- U y 0 0 0 0 0 0 i M I" (O cr 'Cr CO 3 O CO v- N N- CONr O) O CO N- f- CO O N CO O V CA N N CO O) N CO CO CI H LO I� LO N CO O M M M M O Co N CO G� r NNO CO CO N M co M CO O CO O O ti CO N d) C) N CO CO V Q O LC) - CO I� LO N CO CO • Cy CO CO CO CO0O M N CO rei W a ~ O CO o 0 co0 • d CO N *k J J 4t N N X N *k *k Ns N O 0\0 00 N N N Lni� r � C�V y LnCoNot- C)O O) oo co LU Lc, C. 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(n ~ _ CN OII O m O • a a 0 as C C N U N N U i� v CO> > °° o . a) a C a,D (A u) co �_ o O o O N c0 rn n O , N 00 CO M s C° TREE= 6-3/8"CNVIII WELLHEAD= MCEVOY R-02 SA NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C WHEN ON MI"'" WELL REQUIRES A SSSV WHEN ON MI""' NT1AL KB.ELE 54.92 BF.ELEV= 19.38' r KOP= 3300' / Max Angle= 32°@8225. CONDUCTOR — ? Datum MD= 9612' —#, , Datum IND= 8800'SS D= / 29$0' —17"X 5-1/2"XO,F=4.892" 13-3/8"CSG,72#,L-80,D=12.347' H 2628' r'�� 2992' H5-1/2"CAMCO SSSV LANDING NP,0=4.562" 7"TBG,26#,L-80,.0383 bpf,D=6.276" --I 2980' I © GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE I '7 8 3147 3145 8 OTS DMY RA 0 07/13/84 7 5096 4933 28 OTS DMY RA 0 07/13/84 Minimum ID = 3.726" @ 8833' 6 6572 6233 29 OTIS DMY RA 0 07/13/84 5 7637 7159 31 OTS DMI' RA 0 07/13/84 4-1/2" OTIS XN NIPPLE 4 8225 7662 32 OTIS DMY RA 0 04/18/83 3 8362 7777 32 OTS 'DMY RA 0 04/18/83 2 8460 7860 32 OTS 'DMY RA 0 07/13/84 1 8593 7973 32 OTS *DMY RA 0 07/13/84 'DMY VLVS CEMENTED 11/11/16 8358'-8677'CTM — CMT IA(11/11/16) Y.. I I 8659' L5-1/2"BKRLSLDSLV,D=4.313" 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892' —I 8741' f'__ ..I 867T-8678'CTM TBG PUNCH(11/10/16) 8717' —{TBG SEAL ASSY :x".411; FA.C. 8741' —I9 5/8"X 5-1/2"BOT 3H PKR D=4.75' ----------1 8741' H5-1/2"X 4-1/2"XO,D=3.958" 8792' --I4-1/2"OTIS X NP,D=3-813' TOP OF 7"LI2 --I 8815' J 8833' H4-1/2'OTIS XN NIP,D=3.725' 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" —I 8876' 8876' —14-1/2"TBG TAL,D=3.958' 8878' —I ELM)TT LOGO 12/15/89 9-5/8"CSG,47#,L-80,D=8.681" —I 930THi I 9379'CTM —IFISII MLLEDBKRCBP(11/11/16) r 9405' -ESTIMATED TOC (TAGGED 05/28/04) 9580' HSAND PLUG(05/28/04 P62FORATION SUMMARY * 9620' EST.TOP OF CEMENT(07/14/94) - REF LOG:SWS-BHCS ON 07/02/79 ',f,^T '+' —� ANGLE AT TOP FERF:29"@ 9364' is Note:Refer to Production DB for historical perf data •5• SIZE SPF INTERVAL VAL Opn/Sqz SHOT SOZ 9653' MARKER JOINT .i 7 .4 SEE PAGE 2 FOR PERFORATION DETALS 1 1 l 1 9925' H RSH-3"BKR BP FBTD — 10225' 7"LNR,29#,L-80,.0371 bpf,D=6.184' --I 10302' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MT 07/08/79 ORIGINAL COMPLETION 07/24/15 PJC BF E.EV UPDATE(BELL 2012) WELL: R-02 04/18/83 RWO 07/29/15 PJC PERF CORRECTIONS PERMIT No:'1781000 11/26/01 RN/TP CORRECTIONS 12/07/15 DLFVJMD PULED ASH&RUG(12/04/15) AFI No: 50-029-20354-00 11/05/13 JMIMYJMD FULL SLV/SET R.UG(10/18-19/13) 06/07/16 RCR/JMJ RULED NP REDUCER(12/03/15) SEC 32,T12N,R13E,637'FSL&968'FWL 08/01/14 Jk JM3 SET ISO SLV/SLP STOP(12/25/13) 11/29/16 AO/TLH TBG PUNCH,CMT IA,MILL CBP(11/12/16) 07/09/15 SWC/JM:RLL ISO/SUPSTOP&2 ASH 1 BP Exploration(Alaska) i i R-02 PERFORATIONS i Li fol ILI fr1 FERFORATION SUI/MARY REF LOG:SWS-BRCS ON 07/02/79 ANGLE AT TOP PERF:29°Q0/ 9364' 3 Note:Refer to A oduction DB for historical perf data SIZE SPF INTERVAL Cpn/Sgz SHOT SOZ 3-1/8" ? 9364-9404 S 05/21/88 09/12/89 3-3/8"r 4 9364-9404 0 10/03/89 2-7/8" ? 9510-9520 S 06/21/84 10/10/85 2-7/8" " 9510-9520 S 10/17/85 09/12/89 4 3-3/8"r 4 9510-9520 S 10/10/89 05/28/04 2-7/8" ? 9530-9576 S 06/21/84 10/10/85 2-78" ? 9530-9576 S 10/17/85 09/12/89 111, 3-3/8"r 4 9530-9576 S 10110/89 05/28/04 ► }. . 3-3/8"r 4 9576-9580 S 10/10/89 05/28/04 3-3/8"r 4 9590-9614 C 10110/89 05/28/04 • F, 2-718" ? 9590-9636 S 06/21/84 10/10/85 2-7/8" ? 9590-9636 S 10/17/85 09/12/89 3-3/8"r 4 9615-9636 S 12/15/89 07/14/94 2-7/8" ? 9662-9687 S 01/17/80 10/10/85 ..•, 3-3/8" ? 9670-9687 S 11/19/87 09/12/89 3-3/8"r 4 9676-9687 S 12/15/89 07/14/94 2-7/8" ? 9697-9730 S 01/17/80 10/10/85 # 3-3/8"r 4 9700-9710 S 12/15/89 07/14/94 41171' 04tIgriliNit. 3-3/8"r 4 9745-9788 S 10/10/89 07/14/94 3-3/8" ? 9745-9789 S 11/19/87 09/12/89 DATE REV BY COMMENTS DATE REV BY COMvENTS F t DHOE BAY UNIT 07/08/79 ORIGINAL COMPLETION 07/24/15 PJC BF ELEV UPDATE(BELL 2012) WELL: R-02 04/18/83 RINO 07/29/15 PJC PERF CORRECTIONS PERMIT No:'1781000 11/26/01 RAYTP CORRECTIONS 12/07/15 DLWJMD PULLED FISH&PLUG(12/04/15) AR No: 50-029-20354-00 11/05/13 JMM'JM?PULL SLV/SET PLUG(10/18-19/13) 06/07/16 RCR/JM)PULLED NP REDUCE (12/03/15) SEC 32,T12N,R13E,637'FSL&968'FWL 08/01/14 MAW SET ISO SLV/SLP STOP(12/25/13) 11/29/16 AOfRH TBG PUNCH,CMT IA,MLL aBP(11/12/16) 07/09/15 SWC/JM:PULL ISOISLPSTOP&2 FISH I BP Exploration(Alaska) • S • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, November 22, 2016 5:57 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Rupert, C. Ryan; Schultz, Kirsten L; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J; Regg, James B (DOA);AK, GWO Well Integrity Well Information; Bergene, Matthew;AKIMS App User Subject: OPERABLE:Injector R-02 (PTD#1781000)Two Barriers Restored Post-Cement Squeeze All, Produced Water Injector R-02 (PTD#1781000)was Not Operable and shut in for tubing x inner annulus communication (TxIA)through the sliding sleeve just above the packer. Coiled Tubing repaired the TxIA communication through the sliding sleeve with a cement squeeze on 11/11. A subsequent MIT-T and a CMIT-TxIA passed on 11/18 verifying two competent barriers to formation. This well is now reclassified as Operable. Please mind fluid packed annuli when putting on injection. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W:907.659.5102 �CA�NE� 2 2 2 C: 907.943.0296 NO NOVV016 H: x2376 1 y of Tye • • y*.e\����y/,�sv THE STATE Alaska Oil and Gas .��..►��;, Of T T Q Conservation Commission A -__ _ =_ 41w .:4..„,,,,..__,____,.:__:_ •I i.kx_ 333 West Seventh Avenue " 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O 4.1' Fax: 907.276.7542 www.aogcc.alaska.gov Josh Allely Well Intervention Engineer scale SEP.2 9 ZO15 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-02 Permit to Drill Number: 178-100 Sundry Number: 316-410 Dear Mr. Allely: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, li-11 Cathy . Foerster Chair DATED this 7fday of September,2016. • RBDMS fit/SEP - 8 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROLS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well I1" Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Packer Squeeze ll ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 178-100 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20354-00-00 7. If perforating: • What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and N Will planned perforations require a spacing exception? Yes 0 No WI PBU R-02 9. Property Designation(Lease Number): 110. Field/Pools: A U G 0 4 2 ADL 0028279 ' PRUDHOE BAY,PRUDHOE OIL ' I�r 5 717 fc 11. PRESENT WELL CONDITION SUMMARY UGC (psi): Plugs Total Depth MD(ft): Total Depth TVD(ft): I Effective Depth MD: I Effective Depth ND: MPSP AUGG SS..t1 I (MD): Junk(MD): 10303 • 9474 8833 8190 8833 9925 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 36-116 36-116 Surface 2593 13-3/8"72#L-80 35-2628 35-2628 4930 2670 Intermediate 9275 9-5/8"47#L-80 32-9307 32-8600 6870 Production 4760 Liner 1487 7"29#L-80 8815-10302 8175-9473 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): I Tubing Size: I Tubing Grade: I Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"BOT 3H Perm Packer See Attachment Packers and SSSV MD(ft)and TVD(ft): 8741, 8111.97 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic a 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service EZI 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ ® ' WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 OpShutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Allely,Josh be deviated from without prior written approval. Email Josh.Allely@bp.com Printed Name Allely,Josh Title Well Intervention Engineer Signature /� G Phone +1 907 564 5732 Date 1(3 / G 6 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: J� 3`�-e-— ``0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Location Clearance ❑ Other: 1 h 1%A. Post Initial Injection MIT Req'd? Yes a No ❑ /f Spacing Exception Required? Yes 0 No V Subsequent Form Required: ` b —4-04. Approved by:/�j` SLS ` /, / APPROVEDBYTHE u ,✓ COMMISSIONER COMMISSION Date:Q.-7_,// 1/71- 111-114, S. ORIGINAL RBDMS u'' SEP - 8 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate III/1 • m Lc01 0 CD M CD Ns CO O aOD O CDN O N CV 01 0 oopa30101CONON- aC ' Noi NC)'tcti '- N o00000300Ns 03 03 030030000000ODCOOD03003000000CDO0) 0. 0 ct N 0 (N �. r LI) V 0 N '— CO T- N- N N N t co ti r' ti Cr) CO _ OOOOMOO) r` CO4 .- o.m LO N0 (h COON - N N vi .4 cc0) 000 W 0003 00O0Da0Oapa000a00apccaCD 0Oopapa000a0000) Q I- g ce 0 a a w LU W ° a W R 3 5 Y 0 O m 0 o W N N w Tr OCDONU) T- COOc CONsCD00 '- 0000 J J J Q Q W W W = O. 0NN- OT- � NC') f�- N- N- COO) O - - M 00 O0 a a Z m 0 cc LO CD CO CO cO CO CO CO CO CO N- N N- Ns Ps Ns _0 _0 _0 J W W U --I C9 0) 0) 0) 0 C)) 0) O) 0) C)) 0 0 0) 0 0 0 C)) C)) 0) ()) Z Z Z J J 0 J m Q Q Q = O 0 w 0 0 0 W 0 0 w W W Cl- I- I- Z Q Z � 2 220 c~nccoococo O ICE C w cl' OOCDONcT- N0ccCONsO) 00s- cc0 O M f3- CO r- Ch N Cr) r- '- N CO N- ti N- 0) 0) O r 0 W G MccU) cC) COcOCOCOCOCOCOCOUPNsN- rs Ns N- L a 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) — 01 Ne I FV- 1O d J a 2 2 2 0 0 0 0 coo a.. m 0 C.) c w CO GO CO CA CO Cn OD Cn co co Cn co u) Cn Cn CA co co C/) Eaaaaaaaaaaaaaaaaaaa Q mmmmmmmmmmmmmmmmmmm 0 m a I- m• N N N N CV N N N N N N N N N N N N N N 0 C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W O 0 N N N N N N N N N N N N N N N N N N N Z U- Q W R N N N N N N N N N N N N N N N N N N N U N LL a. N N N N N N N N N N N N N N N N N CV N I) W 0 O w w O Ill 0 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) < 0 J I- J J J d CO0w -I J Q Q W W < Q LL U) cL cL LL U) a R' m E 16 Z N N N N N N CV N N N N N N N N N CV N N 00000000000000000I00 LL d CO 0 U- N IL m m -100W o OceCCCLXCLCCC4CL_CLXWCCrCLCCCLYCCCLEt Q 0- 0- 0- W c • a) 12. 0 (r=) 00000000 O ti N ER p C' - LO co r. C.) 4g cco � coo � vcCO 0) 00 A- N I� v m v cO0ol - r- 0o CC' OOOch CD CD N O I,- co .- N CO (ONI- Oc- N N 00 O N 00 CO i LON � NCO A- CO MCO V- COOT- co N CO CD CO CO (. NO r 00 00 r O 0 00 co s coC) �O N co CO CO C 2 N COitt ��O// CO M 00 coCNS) NCO =Li co N CO co a co = o � oo . d CO N *k J J O x �# �# cNi U y N M � N = N y O L s �orn � 0cotou Q) = co in N • N O) r- N `- W C c 0 W •y UV W 00u_ X ZZZ Z c W W m m m Oml— ZDDD • ALASKA WELL ACT•V1TV STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: R-02 Well Type: Water Injection Well API Number: 50-029-20354-00 Well Activity Conventional 4 _ Classification: Activity Description: IA squeeze to mitigate TxIA Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE SAG RIVER 12 Month Avg IOR, bopd: Job Type: Packer SQZ Estimated Cost, $K: AWGRS Job Scope: CEMENT SQUEEZE (OA/IA DWNSQZ) Other regulatory - requirements? Sundry (injector) Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Ryan Rupert Contact numbers: (907) 564-4238 (907)301-1736 Well Intervention Engineer: Josh Allely Contact numbers: (907) 564-5732 (907) 350-7362 Lead Engineer: Javier F. Contact numbers: No Data No Data Date Created: May 25, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate In) Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Choke Setting Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut (To) (Mscf/Day) (psi) 2010 1000 bpd 1500 psi injection P Current Status: Not Operable Shut In Inclination>70°at Depth (ft) n/a Recent H2S (date,ppm) NA 0 Maximum Deviation (Angle and ppm Depth) 330 8,350' MD Datum depth,ft TVDss -8,800' TVDss Dogleg Severity(Angle and Depth) 4' 8,675' MD Reservoir pressure(date, psig) - 12/3/2015 2,670 psi Minimum ID and Depth 3.725" 8,833' MD Reservoir Temp,F 174° F Shut-in Wellhead Pressure should be low Known mech. integrity problems(specifics) TxIA communication at/around 5-1/2"SS. See WI write-up in this program Last downhole operation (date, Pulled nipple reducer, caliper, and set/pulled 5-1/2" EvoTrieve at 8609' operation) 12/4/2015 SLMD Padded MIT-T above Most recent TD tag (date,depth, toolstring OD) 12/3/2015 9364 SLMD 20' x 3.70"dummy WS Surface Kit Fit-for-Service? YES If No,Why? WTI/CIC walkdown completed Dec-2015, and all was in working condition Comments,well history, R-02 has been an LTSI injector since 2010 due to TxIA communication the well is still currently non- background information, operable. See the integrity write-up in the workbook for more details. etc: The well was screenedin late 2015 for an IA squeeze to fix TxIA communication and then execute a Sag , l.J I SIaSK. I ne t, I sioetracK Jon was progressea, OUT aenieo oy partners at a time wnen no injectors were being approved. The plan is to re-issue the R-02A injector CST and the R-30A producer CST packages to partners in 2016. the IA squeeze will be needed to drill the R-02A CST. Regardless if the CST happens or not,the R-02 current vertical bore has value in it's current location,and the above 10R/value is based on reestablishing parent bore injection only. Current value with future MI in this location totals --250mbo. • Well Intervention Details • Please contact the SOR author if: 1.There is a change in work scope to the approved SON 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: TxIA communication Specific Intervention or Well Objectives: 1 Resolve TxIA communication. Passing MIT-IA with 2500 psi differential. 2 Retain 3.70" pass-through to PBTD 3 Need to be able to set a CTD WS below TSGR(9361' MD) in the future. 4 Key risks,critical issues: Mitigation plan: Take care to create no more differential from IA--> 1 IA may have original completion fluid in some/all of IA than necessary. Circ IA to water or lighter fluid pre- (9.6#brine) squeeze. Watch TxIA collapse forces(especially up high in the 7"durring cementing,AND post-rig MIT-IA 2 Packer rating may be low keep pre squeeze CMIT-TxIA to 2500 psi. Don't bring ToC unnecessarily high. 3 One IC seal currently failed Passed MIT-OA's,and CMIT-TxIA's,so 1 seal is holding. Don't bother fixing now. After fluff/ stuff obtain baseline injectivity data down 4 Hasn't injected in 5 years the backside at 1600 psi WHIP. If<0.25 bpm (360 bpd), call APE. Will likely troubleshoot injectivity before executing IA squeeze. CT fluff/stuff before IA squeeze. Ensure logged PBTD Need future capability to a CTD WS below TSGR(9361' afterwards is 9375'MD or deeper. Under ream,if not. 5 MD) This should save enough rathole for milled composite plug/retainer,while still preserving a CTD KOP below 9361' MD. Summary Ste # Service Line Activity p 1 C Fluff-n-Stuff. GR/CCL. Set Composite. Tubing punch. Packer squeeze. Mill out plug. 2 S Set TTP for MIT's, pull TTP 3 F Load tubing, CMIT-TxlA, MIT-T Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 2 S Secure well in tubing tail for MIT's (tubing tail will be below composite used for squeeze, so shouldn't have cement debris across nipples} 0 • 3 % o o 0 o R o o m e ® 2 \ Co,- -t) \ 2 0 = \ ƒ t n e = 5 n % / / O a) & » a) \ / / k c _ # ) 2 R $ ma _- = q _R "0 ( 3ƒ / „ ® S E / 6 g k m C@ § 2 f % U . e 0 k \ e Cl) / \ @ 7. / Q EL co ° & _ CL us H 3 I « 0 2 k = \ < a) 2 k = \ \ a 7 \ ƒ � � @ / f k > ^ 0 % / k = ® » � \ � Qm � � / � � ® e < E ? / / / / \ / o \ co k / k / a) co a f H e > R _ S 141 f a), m 7 E C o \ I I q / L� \ \ E \ 2 o C 0 k k / C ° \ / a) ® 0 t c ) E \ \ 0 5 w / 0_ % / k O 2 a 7 % 0_ re / < \ \ (.0 \ o / \ 0 ® ) I- \ C 2 0- _5 O 0 % LI_ � \ k " _ ! m 2 0 2 ) o > ƒ _ o $ ± $ / u o 0 2 \ as k 0 = k k § / $ t < d ƒ f C 2 o I— ® \ _ u o -E. E . ) \ CO -3 2 ƒ Ca R e Oct 7 o 2 I- ,- - ()cr in c w • 0 Fullbore Pumping Design Template I 1/0/1900 I 0 ppm I H2S(date/ppm) 3500 Max Pumping Pressure(psi) Crude Main Fluid T 260 Main Fluid Volume(bbls) Crude Freeze Protect Type n/a Freeze Protect Volume(bbls) likely 3000'or lower Recent Tbg Fluid Level(ft) n/a Recent IA Fluid Level(ft) n/a Recent OA Fluid Level(ft) 250 Expected Tbg Fill Up Volume(bbls) 10 Expected IA Fill Up Volume(bbls) n/a Expected OA Fill Up Volume(bbls) 270 I Wellbore Volume to Perfs(bbls) 2500 Anticipated Bottom Hole Pressure (psi) Yes I Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse 7"Tubing Burst(psi) 7 4923 3938.4 7"Tubing Collapse(psi) 7 3389 2711.2 5-1/2"Tbg Burst(psi) 5.5 5107 4085.6 5-1/2"Tbg Collapse(psi) 5.5 4150 3320 9-5/8"Csg Burst(psi) 9.625 6870 5496 Select Input Depth Integrity Issues? I Select Select I IYes-derate I Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition ISelect I Production Packer within Pressure Limits? I 'Rated Packer dp Max Anticipated dp at Packer ISelect I Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) III • 1m hr i$ g' D m LLm 3 p 11!;_l LL g J U V Q W oz y w c$ m>j U mQ_ '-11 Q U m (..111 pO -1 P^ d W q>1 lil- IIiv : LL WJWJ K m V h# j d ` 6 111 lam 3 G = LL O Z b o w II O Z> m 3 q oo uw e W LL"'' 3° � - 2 1 18 z a a41- 01, Msli"I ' 41- 004NNm5 nm:miN IM j v i 31MmFmv'NmNiAMmmlm'"P `" o 1 �%oe�Smm�o�'om`��o =�^ W h v�$$$$$$$ $8 n$1 1 EA$E$E$oEoE o j G 0Y$ $O O O YY$��Q�Q`�j �TQQ�Tjj Om$(O(OO$O O�44i ttOO aa O O 111M00000P IIIIII(O�N�pp O C X P 0$BNp Ip M D m0 F V m N M m to P m m N N N N N N R N N N N N N N N N N N m 1 v ta o �<,E . a o m oof m((NVV ottNVV$ao(NV m 8$$0$8S8i I$ $ry O a1 - mNNNNryryNN NNNNNOON -T-Tm — o II E c e a a` .. 3 _ C li >, a Ie ISWmBS $$88P888� o j C O N O L Oa m m m Q Q m N N M t0(V lV(V IV N tV(V lV(V m m m8moN O O a 6 Ce 1B. 1 C '6.? a Q 3�� �E u m m I Nei c�$^mg mm�v e$m mm m m��my�N�mN`�$ $�i°�ti o c >;� LL o o d'o o$$o o$o 0 0$$o 0 0 0 2S o 0 0 0$$o no Q ' �= 33 ITI 00000 0 'c o o 'o o "o 0o c o 3 yN y LLO�mW OmO N�NO�O O O O� Om V ob. lV fV (V fV N N tV N lV N (V a v AIIIIIEIIIEIII$IE111og1o1$$E1 a �oEEEiggkass�ss� omoma � ` Ne m n _ o m N N N N N N N m chi Y Q y W 3aN m 8 gWd �r d LL s.7-i§ 1-8`-`�$6SP�MEEovorv� 8.23 sq e� I --.......08 a=0 m_=-vin=o C a $omo$0000 vg e ao0 y_4 ry E N mm$moon � N NREINIFNMO R!! aO�,m_ O a G'y 3 8 $m W N lV N m t7 N m t�ri N M N an m m c� M m to m m m n m o5nt wacii11418°d a li,?? Y qE!* n§U�X$a��c`�''` F21.Rv"'imn$ Re • • DATA ENTRY AREA: MUST ENTER DEPTHS, FLUID DENSITIES AND SURFACE Depth of Fluid Tubing Conditions IA Conditions Interface Etc. I Fluid Fluid (Needs Entry) Density Pressure Density Pressure Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Psi) C Enter Tbg = 3500 Enter IA= 0 2850 7.4 1095 6.8 1006 7100 7.4 1633 6.8 1501 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DATA ENTRY AREA: ENTER FLUID INTERFACE DEPTHS AND FLUID 0 DENSITIES FOR ALL INTERFACES. ENTER SURFACE PRESSURES. 0 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE. ENTRY POINTS 0 ARE DESIGNATED BY RED LETTERING. 0 0 0 Pressure @ Pkr= 6228 Pkr= 2507 Max Differential at Packer= -3721 Differential Pressure across Tbg Calc Differential Pressure I Calculated Threshold -5000 -4000 -3000 -2000 -1000 0 I I 1000 I 2000 I 3000 I 4000 L 15. 5000 6 6000 7000 8000 - noun • • - 7"\26# - 5 1/2"\17# • 0 TBG COLLAPSE REFERENCE DATA User Input Tbg Size Class Pressure Derated 5 1/2"117# L or N-80 -5107 -5107 80%= -4085.6 7"126# L or N-80 -4923 -4923 80%= -3938.4 FLUID GRADIENT REFERENCE DATA TYPE DENSITY GRADIENT (#/GAL) (PSI/FT) 15° CRUDE 8.05 0.4182 28° CRUDE 7.40 0.3841 30° CRUDE 7.31 0.3793 40° CRUDE 6.88 0.3572 DIESEL 6.80 0.3531 100% METH 6.64 0.3446 1 50/50 M/W 7.49 0.3888 60/40 M/W 7.32 0.3800 FRESH WATER 8.34 0.4329 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Post-Job Brine Water 9.60 0.4985 MIT-T Brine Water 10.00 0.5193 Brine Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 Prod Gas @ 1000 0.49 0.0254 Your Choice = 2 0.1039 EXAMPLE CASE 111 Diesel IA Fluid Interface @ 2000' TVD. .77/ .,.. j� ` • 4 e/ Gas .; Brine 10.6#/gal 1 ---------:'"/".0/;;/''''2) '‘,:•\\::\;, .ti•. : Tbg Fluid Interface @ 8000' / TVD �•.•.•.i::.•.•:.• • Packer Depth @ 8200' TVD. ►�:::::: :: Crude S 0 TREE- 63AVIcY 3/8-OW I SAFETY sons tin RFAOINGS AVERAGE 125 ppm !ACTT*TOR 1 354.1.1.110130- R-0 2 ,: .ON.. 14413.4.- RMPIFAES A SSW M )M .".IDI 04 at- SA 61.16 C 1241341, 88 ELY 54 9r 2 I [1 19 38 3303 r was ArKie,, Sr 22 9729 .c4:1"3Crc 'f ? l 1 (0 Mir j 3 / { ,2992":-7, ES--iii.cA taco,=EN LA Notaio NIP 0-4 Ser 1 r 1134 28*,I 40 0381 bpf,CI..4 776Pr 1-4 ilio rr 0 1,4,10004a S 7s-frik, n;:ifir-- 747,, it WV .1.101••••••••. ri 73147 31451 8 'OTOS MN M 1, 0 074736741 L $ : 7 5C64933, 2$ OTIS OAP M i 0 07713134 [Minimum ID = 2.313" (g 8833' , 6 65/7]6733 29 ORS Ea21 RA 1 0 071094 5 16371 7150 31 !OM OW M a 0 07113194 24/8- NWPLE REDUCER 1 , 4 Am it62, 32 CMS (Z* RA I 0 0411$843 3 .8362,rrY1 32 !OM OW R'. i 0 -04/11E3 2 !6460 81%0 32 :OTIS CUT R 0 ortmeA 1 85E13 7973 30 ons thy R ', 0 07/13094 u&.. I---;5-1/2-sxRLstaskv,vr431r 1 MI c s.ta-Ti&G.17* 1.-ao, 0232 bor 0.4e2 111.Mal t..._ . 971r lEIG SEAL ASSY aar! -----------. 974r Hil Sir X 5-1/7.1301 3H4(/4 li)*,--4 IV° J 974f` j--1s lir X 4-ter X4 in-3 034' '-'132-‘211-4.11772;cyRs x Irapor r t3 -i. gel, 4 1114 44.41 9833" 1...F.UV OTIS XN RP Or 3 425'i H 4 1/.2*786, 12 68,L-80. 0152 bpi,0-3 956* 9816. .--N-*-!:--13993!"--1-- r---tVP IEDUCEN Es=s•2 -------,--- afar Ht.trr Toro TAAL WM H WO Ti..00CED 12/1SINJ a x spas=r3 474 t. 40,0-4681.-j--, 930r ,........... — -- -- , _ _ _ 84W -atESTMATEE)TOC (TAGGED 062904) I 4, 40 _ : -- s—Va—loy, -i SAND MUG 405,74004 PERFOFik MN SURMA RV . .a. - ! 94120' ja-iFIT TOP OF CEMENT(07714194) TET LOC SWS,BRCS ON 010209 it . ANGEL At-CIF'PERF 29s 49364 Pant Paratt kr Ptoduatraft Di)to no Mama*part dado tfr.,....., .... ? ........_. Wteettigt JOINT' STU ga pautvst. Oprt,Sqz SEEM ! SQL it,,,‘rXcir%I.*, Ir*',1r47. .......- ME MOE 2 R3RruiroRATIoN0ETAtaS 4rli 11._% 4., v,...........-vo, %,...,- 9926'j-insm-r SKR OP vi a****4_,•,. ,,,%44111..,,u, 49,00"aVril rciSTT -F10226* "tat r r:ar.,`•., iRi.7%ft,29a„-no, awl b 1 p,.v-.,A 1..&4- - 1-0"3-lif _ 1 L____...... — . _. OA TT I REV en mons T—Dkx- -iv;SF! COMMENTS' ! PREEPOT"BA Y UNIT a 07•0011711! ouiruosti c OM PI,MON )(Trawl 5 Pir, lac TLEV(STATE(13(1 L 2012) , WEI a PM 061943 RWO 07‘29115 PJC KW'CORRECITONS 1U41lb /81(03 , . _ 'I 1/26017'raw), caRpsi ,,„ cnoRs .:124137/15 114 Riat mai&FEW A(124104i151_r. Plii its 50023-20354.00 Iii I 1101VIAASaFEU 'St W,SET PIM(it:*,11.1.*1.34 '' SEC 32.112N RI 3E.,63r F$T X 961)i-ert 011(01,14 LAM SET ISO SI.Via P STOP 02126131: a0710911-511CF MEL ISOSLIPSTOPS 2 FISH FP Exploration(Alas kai 4_ • • Wellhead Integrity OOA OA 11/12/15: PPPOT-IC failed after plastic packing,and reenergizing LDS and gland nuts 2/19/15: PPPOT-IC failed IA 11/23/12: Plastic packed secondary seal,then passed a PPPOT-IC to 3500 psi with losses of 150 followed by 0 psi 11/11/12: PPPOT-IC failed 2/19/15: PPPOT-T passed to 5000 psi with losses of 200 followed by 50 psi Tubing 11/11/12: PPPOT-T passed to 5000 psi with losses of 200 followed by 50 psi Braidenhead No negative comments Comments Casing/Tubing Integrity OOA OA 12/5/15: MIT-OA to 1200 psi passed on the first attempt with losses of 52 followed by 3 psi(0/0/1200) 12/5/15: IA LLR at 0.35 bpm at 2500 psi 12/4/15: SI sets 5-1/2"EvoTrieve at 8609'MD and got a passing MIT-T to 2500 psi with losses of 69 followed by 20 psi(3300/0/0) 6/21/15: CMIT-TxIA passed to 2500 psi with losses of 24/25 followed by 19/17(2500/2500/0)Had TTP set. 12/25/13: SL set new/different iso sleeve. Couldn't catch pressure on IA. 10/18/13: CMIT-TxIA initially failed, but then passed after pulling/resetting TTP. Losses were 11/11,and 8/7. MIT-IA failed. 9/21/13: MIT-IA fails with>1700 psi loss 9/6/13: pulled old and set new iso sleeve. Passed an MIT-T to 2500 psi with losses of 9 followed by 39 psi. TTP pulled 11/4/12; MIT-T with iso sleeve in place passed against a TTP with losses of 26 followed by 19 psi. A IA subsequent MIT-IA attempt failed with a LLR=7.3 gpm. Appears to be a one-way leak from IA to T. 10/19/12: SL set another isolation sleeve, and failed an MIT-IA(tracking). Then they set a LTTP in the top of the iso sleeve,and attempted an MIT-T,which also failed(tracking) 9/23/12: CMIT-TxIA to 2500 passed on the second attempt with losses of 14 followed by 10 psi (2500/2500/0). Well was secured in the TT. 9/23/12: MIT-IA fails again(tracking tubing P) even though a 5-1/2"isolation sleeve was in place. SL then pulled. 12/17/11: SL opened and closed the sleeve, but MIT-IA's still failed with losses of 250 psi in 10 minutes. (300/2500/0) 9/11/11: Acoustic LDL finds leak at or just above the 5-1/2"sliding sleeve(pumping on IA) 8/23/11: LLR on IA at 2.6 gpm at 2500 psi while pumping down the IA,taking returns to tubing 8/21/11: MIT-IA to 2500 psi failed with final losses of 370 followed by 300 psi(1050/2500/0) 9/12/09: MIT-IA passed to 2500psi on the first attempt with losses of 140 followed by 30 psi (2100/2500/450) 12/4/15; Caliper showed tubing to be in ok conditions with max penetrations all<34%. Overall wall loss was Tubing all<17% 12/3/15: Nipple reducer pulled from TT. SL d&t to 9364'SLMD with a 20'x 3.70"dmy WS. • • Wel!work Procedure Request To: Well Services Operations Team Lead Date: 06/28/2016 Wireline Operations Team Lead VER1 AFE: APBINJEC From: Josh Allely -Well Intervention Engineer Ryan Rupert— Pad Engineer IOR: 90 Est. Cost: 300K Subject: R-02 FCO/ Packer Squeeze Please perform the following steps 1. C Fluff-n-Stuff. GR/CCL. Set CBP. Tubing punch. Packer squeeze. Mill out plug. Current Status: Minimum ID: 3.725" at 8833' MD. 4-1/2" XN Nipple. Max Deviation: 32deg at 8500' MD Top Perf Deviation: 29deg at 9364' MD Last TD Tag: 09/22/12: SL tagged TD with 3.70"WS drift at 9364' SLMD. Last Downhole Op: 12/05/15: SL pulled 5-1/2" Evotrieve. Last SBHPS: 12/03/15: 2670 psi and 170deg F at 8800 TVDSS. Latest H2S: NA Injector AnnComm Status: Not Operable. TxIA communication. Program Contacts Contact Phone -Work Phone -Mobile/Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Pad Engineer Ryan Rupert 907-564-4238 907-301-1736 Page 11 of 8 • • > 12/04/15: Caliper 7"tbg 52 jts 0-20% &25 jts 20-32%, 5-1/2" &4-1/2" tbg 112 jts 0-20% & 66 jts 20-34%, Set Evo-Trieve @ 8609' SLM, Barrier Test Passed to 3000 psi > 12/05/15: MIT-IA Failed, LLR=0.35 bpm @ 2500 psi, MIT-OA Passed to 1200 psi Coiled Tube; ` Fluff-n-Stuff/ Packer Squeeze. 1. Perform Fluff-n-Stuff down to a hard bottom. 2. Injectivity test. 3. Memory GR/CCL for TD determination and flag for CBP. 4. Set Composite Bridge Plug 5. Tubing punch. CMIT-TxIA. 6. Circulate IA to diesel. 7. Packer Squeeze. 8. Mill CBP and push to bottom. Page 1 2 of 8 • • Objective The objective of this procedure is to 1) ensure there is sufficient depth for a future CTD sidetrack; minimum objective is 9375' ELMD and 2) fix the TxIA communication at the sliding sleeve via a packer squeeze. Notes • R-02 is in an injector with low BHP (2670 psi at 8800' TVDSS). • Best estimate of PBTD (cement cap) is 9405' ELMD. This depth was determined from a SL tag, corrected to the tubing tail, performed immediately after the cement cap operation. There appears to be about 10-15' of fill/schmoo on top of the cement cap. • TxIA communication is a small leak at the sliding sleeve (0.35 bpm at 2500 psi). This leak should not affect the clean out, but be prepared to bleed IA as necessary. • If well locks up during fluff-n-stuff, it may be necessary to take returns the long way. Be prepared to clean out well the long way if well plugs off during the fluff-n-stuff. • An IA line will need to be rigged up for the packer squeeze portion of the job. Also recommend running a line downstream of the choke to an adjacent wells' flowline (R-30 or R-29) to help manage returns during the circ out. • Planned TOC in the IA is 8340' MD. This will account for any cement that leaks back in the tubing after the clean out. Cement Design: BHST- 174 deg F. SBHP - -3600 psi. BHCT- 174 deg F Cement: Class G cement. Batch mixed. Density: 15.8 ppg Thickening time: 4 to 6 hrs. (1 hr surface time + 1 hr pump time + 1 hr clean out + 1 hr contingency) API Fluid Loss: 50-80 (25-40 cc/30 min) Free Water: 0 Compressive Strength: Minimum of 2000 psi Requested Volume: 20.0 bbls pumpable. (14.0 to be placed in the IA) Planned Procedure FCO- Fluff-n-Stuff 1. MU JSN. 2. RIH and dry tag TD with nozzle. 3. PUH above the perfs to 9300' MD. With choke closed, begin pumping slick 1% KCI down the CT at max rate. If well is on a vac, pump enough fluid to ensure well is at steady state prior to performing the fluff-n-stuff. This will ensure all fluid is entering the perfs. 4. Proceed with fluff 'n' stuff clean out down to a hard bottom. • If perfs lock up and WHP climbs above 2000 psi, open choke and proceed with a FCO the long way. 5. After tagging a hard bottom, make several reciprocations over perforations: 9300'-TD. 6. PUH to 9000' MD and perform an injectivity test down the CT to get the final post fluff-n-stuff injectivity. Pump at max rate with slick 1% KCI down the CT keeping backside pressure below 1600 psi for 20 minutes. If rate is less than 0.25 bpm at 1600 psi backside pressure, then contact pad Page 13 of 8 • • engineer for further guidance. The tentative plan will be to perform a Schmoo-B-Gone treatment, but that will depend on the pressures observed during the fluff-n-stuff clean out. TD Determination/Drift for Composite Bridge Plug 7. MU and RIH with a memory GR/CCL log and 3.70" nozzle (nozzle is intended as a drift for CBP). 8. Tag TD. PUH 30' and flag pipe. This flag will be used to help ensure the correct depth is reached when cleaning out cement if underreaming is necessary. 9. Log from TD to 8500' MD. Flag pipe at -8600' MD. Flag will be used to set the composite bridge plug. 10. Tie-in log to Western Atlas PPROF (17-APR-1995) and determine corrected depth of tag. 11. If tag depth is shallower than 9375' ELMD, make preparations to underream. The objective will be to underream down to 9400' ELMD. Set Composite Bridge Plug 12. MU and RIH with a 4-1/2" composite bridge plug. 13. Set composite bridge plug at 8770' MD. This corresponds to the middle of the first full joint below the packer. 14. POOH pumping diesel down the backside to keep the hole full. 15. At surface, perform a CMIT-TxIA to 2500 psi (starting pressure). 16. If test is a failure, contact town for further guidance. Tubing Punch 17. RIH with 1' of 4 spf standard tubing punch for 5-1/2" tubing. Ensure BHA has sealed knuckle and swivel as well as bow spring decentralizer. This has been the standard tubing punch BHA; contact town if there are any discrepancies between this BHA and the service provider recommended BHA. 18. Well is now a closed system and it will be necessary to take returns up the CTxTBG while RIH. 19. Perform a tubing punch at -8677' MD. This corresponds to 2' below the bottom collar of the pup joint below the sliding sleeve. Depth control can either be from the flag or by tagging the CBP. 20. POOH. Circ Well 21. Pump the following down the IA taking returns up the tubing and down an adjacent wells flowline (or out to tanks if necessary). Pump at max rate but do not place more than 2000 psi differential between tubing and IA when pumping. This should not be an issue unless the tubing punch was unsuccessful. • 290 bbls of 1% KCI (for IA flush and tubing load) • 345 bbls of diesel (annular volume plus 15 bbls) • CMIT TxIA to 2500 psi (IA will be at a slightly higher pressure due to difference in hydrostatics. Packer Squeeze 22. MU and RIH with a -2.0" BDN cementing assembly. Page 14 of 8 • • 23. Tag composite bridge plug. 24. PUH until weight indicator breaks over plus 1-2' and prep for pumping cement. 25. Pump the following down the CT taking returns to up the CTxTBG annulus to tanks. • 5 bbl freshwater spacer. • 20 bbls of 15.8 ppg cement. • CT volume to displace cement to nozzle. 26. As cement reaches nozzle, ensure nozzle is -1-2' from the CBP. Allow 1-2 bbls of cement to get above the nozzle and lay in cement 1:1 to -7910' MD. .u. 27. Position nozzle at cement top just as last barrel of cement reaches nozzle. Pull up hole to safety -300' above WCTOC. 28. While at safety, circulate 14.0 bbls of cement into the IA. 29. After placing the 14.0 bbls, shut in IA and take returns from the CTxTBG annulus for the remainder of the job. 30. Swap to powervis (1.25 ppb mixed in fresh water) to contaminate cement. Pump 5 bbls, drop ball, and continue pumping powervis. Cleanout cement down to the CBP and lay in powervis from the CBP up to 8340 MD (10.0 bbls). This will help contaminate any cement that leaks back into the tubing. • Maintain -200 psi on the choke for the entire clean out. 31. Chase OOH at 80% with slick 1% KCI, washing the nipples and GLMs. Wash BOP stack. Mill Composite Bridge Plug 32. At surface, make up a LH motor/ mill assembly (to ensure tubing tail does not get backed off when milling the composite plug) with a 3.70 junk mill suitable for cement/CBP (must be 3.70" OD, a 3.80" will not make it past the XN nipple). 33. Wait on cement to build at least 500 psi compressive strength based on field blend testing results. Do not RIH until 500 psi compressive strength is reached. 34. RIH and tag TOC /CBP. Perform a mini-MIT-IA to 500 psi above starting pressure to ensure no TXIA communication. Hold test for 10 minutes (does not need to be a 30 min test). Due not exceed 500 psi due to collapse concerns. If TxIA communication is observed, POOH and contact intervention engineer for plan forward. 35. Mill cement and composite bridge plug and push to TD. If significant milling is observed in the 5-1/2", perform a bottoms up with a large gel sweep prior to milling through the CBP to ensure hole is clean as the well will likely go on a vac once the plug has been mill through. 36. POOH and freeze protect to 2500' MD. Page 15 of 8 0 • Current Schematic: DEE= 6-3x6'Ch1/ W T ACEYOY R--02 SAFElY Ig AVERAGE WHIN HWELL REQUIRES A SSSVYFB1 ON MI ••AGTUATOR= BAKER M1AL Imo.LIE 9.1 BF.E3 EV= 19 KOP= 330()' Mu ANN= 32`0 8225' __-comucTOR. --I ? Ca4un AO= 9812' _$. Daum TVD= 880/SS D=4 ' f2967 I-17'x sl/2'x0,F.-4.897 1133/8"CSG,729,L-80,6.12.34r H 2 2r IT TBG,281,L-80,.038;1 /� 2' -15-1?CALICO SSSV LANDING Alf,D=4.562' I bpr,D=627er H 2980' V GAS LIT 11NNI3iELS ST AO IVO'C7EV TYPE VLV LATCH PORT DATE 8 3147 3145 8 OTS MAY RA 0 07/1184 7 5096 4933 28 OTIS EXIT RA 0 07/13/84 Minimum ID = 3.725"@ 8833' 6 6572 8233 29 OTIS DIN RA 0 07/13/84 4-1/2"OTIS XN NIPPLE 5 7637 7159 31 OTE MN RA 0 07/13/84 — , 4 5225 7662 32 OTE DAV RA 0 04/18/83 Voch 3 8362-7777 32 OT6 ORA 0 04/18/83 PI' Am'2 5480 7860 32 OTE OMI RA 1 0 07/13/84 7,110 1 8593 7973 32 OTS CAW RA I 0 07/13/64 III -Pc 86SW H5-1/2'SKRLSLD SLV,D=4.313' 5-1/2'TOG,17$,L-80, 0232 bpf,6=4892' 8741'. i ' ..Teal- �'V - vn L: 871T 11913 SEAL ASSY I J 664 6741' 9 51S X 51/2 BOT 3M PKR D=4.75 -------I 8741' -45-1/2'X 4-1/2'X0,D=3.9511- I 8792 I-I4-1/2 OTIS X AV,D=3.813" I ITOPOFT LAR-f 88W 3 11833' I.-Lt-1/2-OTIS XN NP;D=3.725'I II 4112'TOG,12.6$.L-36..0152 ON,D=3.956' H 8878' r" u76' 4-1F2'TBG TAIL,D=3.65r I 9-5/8-03G,474 L-80,C=8-681- H 930T ' I - [3AO TTLQGO 12/15!69 I 9405' J-IESTRNTED TOC (TAGGED 05128/04) I 9680'_I--LSAIVO PLLG(05/2804_I POTION SL.Yw1ARY TOP OF CJ F LOG:SVYSE9CS ON 07102/79 �+� ��' I I ESTB�6 fr(07/14/94) ANGLE AT TOP REEF 29'a 9364' s/.is IIIII4 Nee:Etter to Production DB for historical perf data �O'I•"dr e.� sizE{sPF "riawAL 1 apNsqz_L_ T I ''29•A°/X'' WSW w�facez�otr�r SEE RAGE 2 FOR FITFORAT1ON OErAAS �!I r. 00.141 I I ( I ` `I`I`I`. 101.1..-116.14 1 9626' Faro-rpm BP J ►.11101�1� PBTD 10226' ►1."101.1%1V I LNC 291,L-80, 0371 bpf,0=6.184' --1-7-103-6i; 6114‘1‘1L.- DATE REV BY OX1,9434TS DATE REV By COMMENTS FRUDHOEBAY ENT 07M1V79ORICENAL COMPLEOON 07/24/15 PJC BFELEVUPDATE(B(i.2012) , WELL: R-03 04/1863 RYYO 07129115 PJC PERE OOF2REL'TlOf4$ P[3iMT Ab:'1781000 11/26!01 (SliP CORRECTIONS 12/07/15 OLJ-VJAID FILLED.18)F15714 FLOG(12/04/15) AR P: 50-029-20354-00 11/05/13 JMiIJAO RLL SLV/SET PLUG(10/18-19/13) 06/07/16 FY:t7/JAO RLLED NP PEE4X t31(12/03/15) SEC 32,T12N,R13E 637'FSL 4 968'FWL 0101/14 JAM'JAO SET 810 SLV/SLP STOP(12/25/13) 07)09/15 SWC7JA[;RILL 6O/SLPSTOP4 2 P8111 BP Btpbratlon(AEaskal Page 16 of 8 • • FILE UOPT waU PRODUCTION LOGGING SERVICES mosinutss AURAS (Injection Profile) Atlas Wireline Services Na.!LFCOMPANY BP EXPLORATION (ALASKA) INC. WELL R - 02 4P1 NO. FIELD PRUDHOE BAY 50 -029-20354-00 COUNTY NORTH SLOPE STATE ALASKA LOCATION: OTHER SERVICES SURFACE: 63T' F GL & 958' FR. SEC 32 T-1.1P IN ROE 3C PERMANENT DATUM M.S L ELEVATION I FT, ELEVATIONS • LOG MEASURED FROII R. .8 54f FT. ABOVE PERMANENT DATUM 01 53.0 DRILL PIERS FROM R.K.8. GL 20.0 • DATF 17-APR-95 - --- -- RUN ONE SERVICE ORDER 1695T5 DEPTH-DRILLER 9612' CEMENT CAP DEPTH-LOGGER 9601' TAGGED TD BOTTOM LOGGED INTERVAL -.-96117 TOP LOGGED INTERVAL 9270' TYPE FLUID IN HOLE SEAWATER SAL I N I TY PPM CL. N.A. DENS!TY LB/GAL. N.A. LEVEL FULL 'MAX. REC. TEMP. DEG. F 95 OPR. RIG TIME CRANE TRUCK EQUIP. NO. / LOCATION HL-649 I NORTH SLOPE RECORDED BY K. BRUNNER W I TNESSED 8Y _D. ROMBERG BOREHOLE RECORD CASING RECORD NUMBER BIT FROM TO SIZE WEIGHT FROM TD 9 5/8" 47 LB 6 9307' 29 L8 NI 5' 15302' 26 LB II 29 51/2" I/ LB 2980' 8816' Pagel 7 of 8 • • TLI-- } 11"' . W ILA f 1 Y , • 4 _. - _ _, 7 i ; m , � i } „7-- , , ,. . 4 NOM ran NM !!IIIIIMMunismins ins i111 1111111111= gm MIMI 111151111.11111•1111111MINipm......, II an pall1111111111111111 AMR 11111111111111111•11111111111111111111111111111111111111111 ' wani. It . , aammumam ili - Ti'- ' y I __ ; I,: ' MEM ' • ,moi +- r S MI i ,__ ' _:__ _ '___I _ al '1. 41111111 ..., iii ON I! 1iIall MU 11111110111111 liMIMMINNE■MUS mum MI Page I8of8 • "LCo1-1� Gyrodata Incorporated gYi'O/d9ta ?3000 Northwest Lake Dr. Houston,Texas 77095 T: (281) 213-6300 • F: (281) 213-6301 RECEIVED Precision Wellbore Placement FEB 0 3 _,fs) DATA LOGGED OGCC 2. S/2 10r J"'� M. K.BENDER RECEIVED FEB 03 LQ16 SCANNED JUN 2 8 2,016 AOGCC SURVEY REPORT BP Exploration R-Pad #R-02 Wellhead Prudhoe Bay, North Slope Borough, AK AK0715GCM150 8 July 2015 RIGHT PLACE FIRST TIME S((`\ www.gyrodata.com — '1 • S Gyrodata Incorporated gyro/data ',.3000 Northwest Lake Dr. Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 February 2, 2016 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: R-Pad, Well #R-02 Prudhoe Bay, Alaska Enclosed, please find one (1) copy, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. 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O O Cr) cnL cn _o L = N O _.___T.__._ .r ..-._ 7 1 1 .� .- -I____ ___1_ _.__ ____...___o • O Hr_i • N .Ne c0O -0o Q - O � O C o .� UJ 74"tu O 1 C I X'• _ i:+ t l I i t l I i I I I 11 I l 1 1 1 1 1 I O wco a o o j Ln o Ln o in o Lno 0o J d' I rrj M Ni Ni .-4 ,-i O O (1400i/6ap) All GA9S s. isoa Survey QC - RGS-C•pecification Sheet • gyro/data SURVEY QUALITY CONTROL- SPECIFICA s lON DA I A PRE-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 11265 271.25 312.31 0.00007914 1.02 11264 225.95 255.73 0.00006393 2.88 11263 225.95 254.87 0.00006372 2.76 11262 44.85 225.78 0.00005641 5.46 11261 44.85 223.09 0.00005574 5.14 11260 359.96 1.86 0.00000046 2.87 11259 359.96 -3.94 -0.00000097 1.45 11258 330.04 -90.67 -0.00002253 2.63 11257 330.04 -81.90 -0.00002035 1.54 11256 300.11 69.08 0.00001739 1.87 11255 300.11 68.00 0.00001712 1.18 11254 270.82 307.06 0.00007780 3.77 11253 270.82 311.04 0.00007881 2.87 11252 241.32 336.90 0.00008481 2.90 11251 241.32 353.67 0.00008903 1.64 11250 210.39 176.69 0.00004388 2.88 11249 210.39 189.69 0.00004711 1.69 11248 181.06 48.36 0.00001194 0.62 11247 181.06 44.72 0.00001104 1.40 11246 149.64 -48.76 -0.00001212 0.60 11245 149.64 -52.62 -0.00001308 1.13 11244 120.11 83.13 0.00002093 4.63 11243 120.11 84.44 0.00002126 3.35 11242 j 90.36 316.47 0.00008019 2.80 11241 90.36 317.93 0.00008056 4.26 11240 59.73 325.32 0.00008184 6.19 11239 59.73 333.54 0.00008390 6.07 11238 29.53 166.89 0.00004143 6.77 11237 29.53 181.80 0.00004513 6.42 11236 359.33 30.13 0.00000744 2.30 11235 359.33 39.83 0.00000983 0.34 11234 j 270.48 363.66 0.00009216 2.69 11233 270.48 368.27 0.00009332 1.91 11232 225.39 330.82 0.00008270 -0.78 11231 225.39 321.18 0.00008029 -0.74 11230 45.36 301.42 0.00007534 4.91 ' 11229 w 45.36 311.66 0.00007791 3.26 11228 359.82 72.99 0.00001802 2.63 11227 359.82 82.24 0.00002030 2.70 11226 330.62 -16.39 -0.00000407 2.39 11225 330.62 -12.58 -0.00000313 1.47 11224 299.53 141.24 0.00003557 1.66 11223 299.53 144.35 0.00003636 0.74 11222 270.72 395.39 0.00010020 0.71 11221 270.72 401.19 0.00010167 0.03 11220 240.36 421.42 0.00010606 0.13 11219 240.36 422.30 0.00010628 1.07 11218 210.13 252.13 0.00006261 1.91 11217 210.13 256.28 0.00006364 1.04 11216 180.08 100.08 0.00002470 1.65 11215 180.08 104.35 0.00002576 2.71 11214 150.61 2.93 0.00000073 1.07 11213 150.61 7.14 0.00000177 0.24 11212 120.32 176.22 0.00004437 0.17 11211 120.31 182.08 0.00004585 -0.45 11210 90.95 441.58 0.00011192 3.60 11209 90.95 450.04 0.00011407 2.20 11208 60.39 445.09 0.00011202 2.62 11207 60.39 445.63 0.00011216 2.07 11206 29.84 253.47 0.00006294 3.36 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 6 AK0715GCM150 Survey QC - RGS-C•pecification Sheet • gYrOata 11205 29.84 255.30 0.00006339 0.94 11204 0.22 71.07 0.00001754 8.55 11203 0.22 70.10 0.00001730 4.84 MBO = 0.23 Gravity Error= 195.92 Scale Factor Uncertainty = 0.00004923 Rate Error= 2.42 POST-30B CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 11330 270.30 283.56 0.00007185 -0.43 11329 270.30 286.18 0.00007251 0.19 11328 224.82 240.80 0.00006017 -3.74 11327 224.83 218.89 0.00005469 -0.73 11326 45.91 258.79 0.00006470 16.58 11325 45.91 244.65 0.00006116 12.40 11324 0.48 2.93 0.00000072 -1.57 11323 0.48 5.77 0.00000142 -0.46 11322 330.36 -81.57 -0.00002027 -2.15 11321 330.36 -80.45 -0.00001999 0.11 11320 301.23 50.73 0.00001277 -0.72 11319 301.23 55.00 0.00001384 -0.79 11318 270.23 341.41 0.00008651 0.49 11317 270.23 341.00 0.00008641 0.46 11316 240.45 404.11 0.00010170 -0.06 11315 240.45 407.74 0.00010261 1.02 11314 209.76 248.32 0.00006166 7.17 11313 209.76 241.34 0.00005992 1.24 11312 178.96 17.48 0.00000431 3.89 11311 ' 178.96 18.41 0.00000454 3.85 11310 148.49 -65.53 -0.00001629 0.68 11309 148.49 -60.29 -0.00001499 2.78 11308 119.75 81.93 0.00002063 3.19 11307 119.75 82.70 0.00002082 3.05 11306 89.12 333.34 0.00008446 4.85 11305 89.12 337.38 0.00008549 4.94 11304 59.62 337.25 0.00008483 3.69 11303 59.62 333.44 0.00008388 2.27 11302 28.74 178.40 0.00004427 3.32 11301 28.74 180.42 0.00004477 3.25 11300 359.85 40.21 0.00000992 2.89 11299 359.86 63.04 0.00001556 1.58 11298 269.97 384.65 0.00009748 -1.63 11297 269.97 388.50 0.00009845 -2.22 11296 224.85 286.71 0.00007165 0.82 11295 224.85 287.06 0.00007174 2.36 11294 44.43 303.04 0.00007572 3.26 11293 44.43 311.51 0.00007783 3.12 11292 0.85 75.60 0.00001866 0.67 11291 0.85 90.09 0.00002223 0.99 11290 329.56 -15.22 -0.00000378 3.58 11289 329.56 -8.28 -0.00000206 3.23 11288 298.42 188.49 0.00004750 2.41 11287 298.42 198.20 0.00004994 1.37 11286 270.45 487.31 0.00012352 4.35 11285 270.45 496.20 0.00012578 3.62 11284 240.39 466.52 0.00011742 5.11 11283 240.39 485.20 0.00012213 8.44 11282 211.42 280.74 0.00006976 6.65 11281 211.42 283.86 0.00007053 5.18 11280 182.73 125.75 0.00003104 0.90 11279 182.73 133.13 0.00003286 -0.41 11278 151.00 26.37 0.00000655 3.02 11277 151.00 40.59 0.00001009 1.79 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 2 of 6 AK0715GCM150 Survey QC - RGS-Cpecification Sheet • grUgata 11276 120.56 297.21 0.00007485 5.31 11275 120.56 296.55 0.00007468 3.49 11274 90.92 644.19 0.00016334 6.98 11273 90.92 656.64 0.00016650 7.52 11272 61.64 674.83 0.00017001 8.16 11271 61.64 709.42 0.00017873 4.18 11270 28.99 385.27 0.00009566 10.08 11269 28.99 383.88 0.00009532 8.73 11268 359.71 239.49 0.00005913 7.57 11267 359.71 243.24 0.00006005 7.63 MBO = 0.20 Gravity Error= 237.41 Scale Factor Uncertainty = 0.00005965 Rate Error = 3.12 INITIALISAI Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs (ERMeas-ERTheo) 132 10.23 304.47 0.0263 133 10.23 304.21 0.0337 134 10.23 304.14 0.0553 135 10.23 304.54 0.0261 136 10.23 304.56 0.0171 13 10.23 304.48 0.0256 Average 10.23 304.40 0.0307 Tolerance on Average* 0.0819 Standard Deviation 0.00 0.18 0.0132 Tolerance on St. Dev.** 0.10 0.2° 0.0378 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance = TBA * Tolerance on Average'of earth horizontal rate difference is given by (1/Cosi)*J[(CosA*SinI*0.1)z+0.0821 0/hr ** Tolerance on Standaid Deviation of earth horizontal rate difference tolerance is given by (1/Cosl)*J[(CosA*SinI*0.1)2+(0.082/(n-1))] °/hr 'TFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 820.74 4100.07 26.38 302.96 0.000 -0.001 -0.002 -0.003 2 1273.98 5400.54 28.17 301.83 -0.011 0.011 -0.012 0.008 3 1361.38 6950.17 29.21 301.01 -0.009 0.007 -0.012 0.003 4 1386.25 8450.01 32.91 308.07 0.041 -0.046 0.014 -0.020 5 717.85 8725.16 32.37 309.60 -0.002 -0.001 -0.003 -0.002 6 539.36 8449.93 32.90 307.89 0.000 -0.001 -0.001 -0.001 7 1445.51 7099.95 29.36 299.65 -0.065 0.059 -0.025 0.016 8 805.92 6500.17 28.59 298.35 0.001 -0.002 -0.001 -0.002 9 928.21 5699.92 28.20 300.25 0.010 -0.011 -0.001 -0.008 10 1017.81 4800.25 28.44 299.10 -0.066 0.066 -0.030 0.024 Average -0.010 0.008 -0.007 0.002 Standard Deviation 0.033 0.033 0.013 0.013 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 6 AK0715GCM150 Survey QC - RGS-C•pecification •Sheet • g a INCLINA i1ON AND AZIMUTH INRUN AND uU i"RUIN COMPARISON Depth I Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * I Difference 100.00 0.42 0.41 0.00 80.95 55.74 25.21 200.00 0.42 0.20 0.22 328.52 113.64 -145.13 300.00 0.41 0.30 0.10 343.43 85.12 -101.69 400.00 0.37 0.36 0.01 319.73 313.47 6.26 500.00 0.52 0.65 -0.13 49.03 74.46 -25.43 600.00 0.91 0.95 -0.04 47.12 46.64 0.48 700.00 0.49 0.63 -0.14 59.02 22.69 36.33 800.00 0.49 0.58 -0.09 62.55 17.01 45.53 900.00 0.71 0.77 -0.06 27.58 47.82 -20.23 1000.00 0.57 0.84 -0.27 57.83 49.90 7.93 1100.00 0.35 0.44 -0.10 69.29 0.84 68.46 1200.00 0.31 0.21 0.09 57.81 21.85 35.97 1300.00 0.59 0.60 -0.00 3.91 8.43 -4.52 1400.00 0.75 0.73 0.02 18.94 55.03 -36.09 1500.00 0.90 0.82 0.07 23.58 51.95 -28.37 1600.00 0.91 0.82 0.09 71.35 75.77 -4.42 1700.00 0.72 0.75 -0.03 52.17 50.08 2.09 1800.00 0.47 0.45 0.02 87.07 97.32 -10.25 1900.00 0.59 0.66 -0.07 143.58 98.05 45.53 2000.00 0.59 0.61 -0.01 69.02 127.95 -58.92 2100.00 0.97 0.84 0.13 78.31 100.79 -22.48 2200.00 0.81 0.83 -0.02 58.29 56.56 1.73 2300.00 0.55 0.64 -0.08 356.18 16.68 -20.49 2400.00 0.49 0.74 -0.25 356.95 343.46 13.49 2500.00 0.44 0.74 -0.30 11.75 2.16 9.59 2600.00 0.27 0.37 -0.10 105.49 263.08 -157.59 2700.00 1.40 2.07 -0.67 192.57 218.34 -25.77 2800.00 2.53 3.12 -0.59 279.40 285.52 -6.12 2900.00 4.51 4.48 0.03 301.51 302.08 -0.57 3000.00 5.63 5.73 -0.10 301.03 301.22 -0.18 3100.00 6.83 7.19 -0.36 302.49 302.56 -0.07 3200.00 8.62 8.65 -0.03 304.23 305.11 -0.88 3300.00 10.23 10.27 -0.03 304.48 304.06 0.43 3400.00 12.20 12.17 0.03 303.46 303.56 -0.10 3500.00 14.39 14.38 0.01 303.18 303.84 -0.65 3600.00 16.75 16.63 0.12 302.69 303.49 -0.80 3700.00 19.35 19.11 0.24 302.47 303.62 -1.15 3800.00 20.87 20.54 0.33 302.39 303.71 -1.31 3900.00 22.12 21.82 0.30 302.80 304.29 -1.49 4000.00 23.78 23.77 0.01 302.83 303.86 -1.03 4100.00 26.37 26.45 -0.08 302.95 303.36 -0.41 4200.00 27.38 27.14 0.25 302.92 303.47 -0.56 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 6 AK0715GCM150 Survey QC - RGS-specification •Sheet • gyro/data 4300.00 27.44 27.36 0.09 302.74 303.37 -0.64 4400.00 27.42 27.28 0.15 302.98 303.63 -0.65 4500.00 27.29 27.20 0.08 302.63 303.36 -0.72 4600.00 27.48 27.38 0.10 302.32 302.95 -0.63 4700.00 27.86 27.78 0.08 302.50 302.77 -0.27 4800.00 28.07 28.05 0.02 302.71 302.54 0.18 4900.00 28.41 28.32 0.08 303.33 303.10 0.22 5000.00 28.30 28.27 0.03 302.61 302.46 0.15 5100.00 28.13 28.01 0.12 302.42 302.35 0.06 5200.00 28.01 27.99 0.02 302.32 302.37 -0.05 5300.00 28.17 28.08 0.09 302.22 302.39 -0.17 5400.00 28.12 28.03 0.09 301.89 302.26 -0.37 5500.00 28.09 27.99 0.10 301.95 302.37 -0.42 5600.0028.12 27.92 0.21 301.90 302.45 -0.55 5700.00 1 28.05 28.07 -0.02 302.04 302.36 -0.32 5800.00 28.01 27.98 0.03 301.43 301.52 -0.09 5900.00 27.96 27.96 -0.00 301.28 301.28 0.00 6000.00 27.88 27.88 0.00 301.09 300.97 0.13 6100.00 28.02 28.01 0.02 300.90 300.57 0.33 6200.00 I 28.29 28.24 0.05 300.50 300.01 0.48 6300.00 28.35 28.33 0.02 300.20 299.61 0.60 6400.00 28.48 28.46 0.02 300.17 299.54 0.62 6500.00 j 28.60 28.56 0.04 300.41 299.58 0.83 6600.00 28.41 28.31 0.10 300.54 299.37 1.18 6700.00 28.88 28.81 0.06 300.22 299.32 0.90 6800.00 29.14 29.11 0.03 300.36 299.34 1.02 6900.00 29.23 29.17 0.06 300.91 299.91 1.01 7000.00 29.28 29.32 -0.04 300.92 300.13 0.79 7100.00 29.14 29.07 0.07 301.40 300.42 0.98 7200.00 28.76 28.69 0.08 301.87 301.02 0.85 7300.00 27.93 27.85 0.08 302.13 301.37 0.76 7400.00 27.76 27.67 0.09 303.50 302.97 0.52 7500.00 28.22 28.16 0.06 303.86 303.54 0.33 7600.00 28.50 28.45 0.05 304.38 304.43 -0.06 7700.00 28.89 28.89 0.00 305.30 305.77 -0.47 7800.00 29.68 29.61 0.07 305.03 305.81 -0.77 7900.00 30.97 30.92 0.06 305.10 306.11 -1.02 8000.00 31.64 31.61 0.03 306.30 307.96 -1.66 8100.00 32.14 32.14 -0.00 305.90 307.28 -1.38 8200.00 32.44 32.47 -0.03 306.02 307.21 -1.19 8300.00 32.49 32.45 0.05 306.65 307.67 -1.02 8400.00 32.16 32.27 -0.12 307.44 308.25 -0.81 8500.00 32.32 32.41 -0.09 307.06 307.71 -0.65 8600.00 32.15 32.13 0.01 309.32 308.83 0.48 SURV-Q167(OPS SUR-MA-003) 19'"Nov 03/Rev 15 Page 5 of 6 AK0715GCM150 Survey QC - RGS-C•pecification Sheet • gYr4data 8700.00 31.80 31.81 -0.01 309.86 309.81 0.04 Average 0.0060 -0.1578 Standard Deviation 0.1495 0.7469 Tolerance for both the Average and the Standard Casing 0.30 Casing 0.50 Deviation Drillpipe 0.30 Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 6 AK0715GCM150 • . Survey QC - RGS-ADAnalysis Sheet gy SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I I Grid Correction 0.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details TIE ON DAT/ Depth 0.00 Inclination , 0.00 Azimuth 0.00 I TVD 10.00 Northings 0.00 Eastings 0.00 Latitude 70.3454 Az. Ref: Grid Corrected Y/N? Description Grid/True 'ALIBRATION Tool Number I F0211 Calibration Date 01 Oct 2014 %NG TEMPERATURE Calibration range From 40.06 To 119.98 Gyro operating range From 63.76 To 86.47 Spec'- Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000056 0.000049 0.000060 0.000060 0.000010 Cal/Post- 0.00015 Mass Unbalance 0.15 0.23 0.20 0.20 0.03 Pre/Post-0.4°/hr NITIALISATION Depth (Approx) 3300.03 No of stns 6 Spec'- Min No. -6 Azimuth I Mean 304.40 Std deviation 0.18 Spec'-Azi SD 0.2° Inclination Mean 10.23 Std deviation 0.00 Spec'- Inc SD 0.1° Earth Horizontal;Rate Mean (Abs(meas-theor)) 0.03 Std deviation 0.01 Spec'- See Q167 DRIFT TLs. Residual x gyro bias Mean 0.008 Std dev' 0.033 Spec's - Mean and SD- 0.333°/hr Residual y gyro bias Mean 0.002 Std dev' 0.013 Spec's - Mean and SD- 0.333°/hr TOOLFACE RATE Maximum toolface rate 30.59 I Spec'-400°/sec IN/OUT COMPARISON (All" N!A N! IF INC' X15°) Inclination Difference Mean 0.01 Std dev' 0.15 Spec's- Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean -0.16 Std dev' 0.75 Spec's- Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.77 Spec- 5.0/1000 Vertical Divergence/1000 0.25 Spec'- 2.0/1000 1 CON I KO Wireline Company Schlumberger Line type 7/32 Encoder SF Schlumberger Max Depth (TD) 8724 CCL Corrected _ No Zero Depth (Rig up) l l'I ,, /`3'AMSL Rezero Depth -4 Given pup joint depth NA Measured PJ NA Strech cor. At TD divided by TD/1000 .3678 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .4597 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 SURV-Q165(OPS SUR-MA-010)22^d Jan 2004/Revision 20 Page 1 of 1 AK0715GCM150 • gyro Survey QC RGS-CT Acceptance Sheet /data FIELD AND SURVEY INFORMAT1 Operator BP Exploration (Alaska) Inc. Field/ Platform Wellhead / Schlumberger WLS Well Number N.Slope Borough R-02 Survey section From 0.00 ft. to 8724.00 ft. Date 08 Jul 2015 Gyrodata Job No AK0715GCM150 Gyrodata Surveyors Joshua Ca macho Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13`"Nov 03/Revision 12 Page 1 of 1 AK0715GCM150 r MiiMiMIMMMMMMMMMMMMIMIIIIIIMIIIIMIIIIgrMMIMIMIIMIMMM OF Tye e.`"\ �y/,mss, THE STATE Alaska Oil and Gas mw '\ OfAT T i\ SIKi\ Conservation Commission '=—, l 11 rift _:_ _ 333 West Seventh Avenue -�� Anchorage, Alaska 99501-3572 �*a � GOVERNOR BILL WALKER 9 Main: 907.279 1433 ALAS Y' Fax. 907.276 7542 www.aogcc.alaska.gov Josh Allelyr1 g - a� Well Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-02 JULsa�kE© 6 av:; Sundry Number: 315-384 Dear Mr. Allely: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, lat /))04... szt,,_ Cathy . Foerster Chair ape- I DATED this ...7(.1 day of June, 2015 Encl. RECEIVED WED AN 18 2611,, STATE OF ALASKA 61.N61 I S ALASKA OIL AND GAS CONSERVATION COMMISSION ACT C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate El Alter Casing ❑ Change Approved Program❑ Plug for Redrill CIPerforate New Pool CIRepair Well CI• Re-enter Susp Well CIOther acker Squeeze ❑ • ' 2 Operator Name. 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 178-100 • 3 Address: Stratigraphic ❑ Service CI • 6.API Number. P O.Box 196612,Anchorage,AK 99519-6612 50-029-20354-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU R-02 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number) 10.Field/Pool(s) ADL0028279 ' PRUDHOE BAY, PRUDHOE OIL • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured) Junk(measured): 10303 • 9462 • 8833 8178 8833 9925 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 35.75-115 75 35.75-115.75 Surface 2593 13-3/8"72#L-80 35 25-2627.76 35.25-2627.63 4930 2670 Intermediate 9275 9-5/8"47#L-80 32-9307 32-8588.02 6870 4760 Production None None None None None None Liner 1487 7"29#L-80 8815.3-10302 8162.61-9460.76 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade. Tubing MD(ft). See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"BOT 3H Perm Packer Packers and SSSV MD(ft)and ND(ft): 8741.15,8099 31 No SSSV Installed No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service [ • 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations. OIL ❑ WINJ El• WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Allely Email Josh.Allely@BP.Com Printed Name Josh Allely Title Well Intervetions Engineer Signature ! ....-'t A--- Phone 564-5732 Date 6/f']/ Z D/ S Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 `-3 - 3RD Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: _ fa.fe I,v1 -iv2t5s rd. �1 /T-/A- r-gvlr«/ after S-Ft /,3rC/ �`vi <c,ti a- Spacing Exception Required? Yes ❑ No d Subsequent Form Required. /0— 4 v .+ APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date. G-3D__/S V7-1_ 6 ORU3INAL6. L-2-. ,I Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Submit Form app Attachments in Duplicate RBDMS-3 ` JUL - 1 2015 Perforation Attachment 178-100 Well Date Perf Code MD Top MD Base TVD Top TVD Base R-02 9/22/12 BPS 9364 9404 8638 8673 R-02 9/22/12 BPS 9510 9520 8766 8775 R-02 9/22/12 BPS 9530 9576 8783 8824 R-02 9/22/12 BPS 9576 9580 8824 8827 R-02 9/22/12 BPS 9590 9612 8836 8855 R-02 9/22/12 BPS 9612 9615 8855 8858 R-02 9/22/12 BPS 9615 9621 8858 8863 R-02 9/22/12 BPS 9621 9636 8863 8876 R-02 9/22/12 BPS 9662 9670 8899 8906 R-02 9/22/12 BPS 9670 9675 8906 8911 R-02 9/22/12 BPS 9675 9676 8911 8912 R-02 9/22/12 BPS 9676 9687 8912 8921 R-02 9/22/12 BPS 9697 9699 8930 8932 R-02 9/22/12 BPS 9699 9700 8932 8933 R-02 9/22/12 BPS 9700 9710 8933 8941 R-02 9/22/12 BPS 9710 9711 8941 8942 R-02 9/22/12 BPS 9711 9730 8942 8959 R-02 9/22/12 BPS 9745 9780 8972 9003 R-02 9/22/12 BPS 9780 9788 9003 9010 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF OO O O O O co co co co co co L J J J J J J a) Q O O O O co co O N I"- - O CO N- O CO •ct LC) N p *Cr f- N Ln I- CO U 0 0 0 0 0 0 D CO O N I"- CD CO V CO h- a) Cn S CO CO N CO 1- O 1.0V CO O) N O `- CO O N N CO CO C1 O CO I� (9 N CO LO N 0) CO a CO CO CO CO 0 CA CO CO N L EO co CO (` NO CO CO Cb O co C) N CO Io M N- o co .IO 0 ‘- 0) co N CO CO O) N- C •— C2 O l() op v- I— CO N Lo N CO CO U 0 CO CO CO CO CO CO (b N O CO (D CO CO O O CO J CO CO J J a) CO 4$ J N J Cfl 4$ N X V % ti O a0 N E0 N _ CV IO N- i LO I- CO O I- 0/ O CO O Ln M Lc-)C co N LoO - N- J N N LO W OQ cl- 0 W W U a cU (-) 000 Z Z Z Z W W 00 00 00 O ;- Z D > > D `= U) I- I- 11 = 6"MDEVOY SAFETY NOTES: S ACTUAT D R= MC OTt R-02 — 2 WHEN ON I.WELL REQUIRES A SSSSSV WHEN ON GE 125 ppm ACTUATOR= OT1S NT1AL KB.ELE 55' MI. BF.ELEI/= 21.09' KOP= 3300' Max Angle= 32°@ 8500' Iii Datum MD= 9612' Cetum1VD= 8800'SS 2980' —j7"X 5-1/2"X0 13-3/8"CSG,72#,L-80,D=12.347'H 2628' 2992' H5-1/2"CAMCO SSSV LANDING NP,D=4.562" 7"TBG,26#,L-80, .0383 bpf,D=6.276' 2980' 0 GAS LFT MANDRELS Ell. MD ND TYPE VLV LATCH PORT DATE TOP OF 5-1/2"TBG —{ 2980' 8 3147 3145 8 OTIS DMY RA 0 07/13/84 7 5096 4933 28 OTIS DMY RA 0 07/13/84 Minimum ID = 2.313" 8833' 6 6572 6233 29 OTIS DMY RA 0 07/13/84 5 7637 7159 31 OTIS OMY RA 0 07/13/84 2-7/8" NIPPLE REDUCER 4 8225 7662 32 OTIS DMY RA 0 04/18/83 3 8362 7777 32 0115 DMY RA 0 04/18/83 2 8460 7860 32 0115 OMY RA 0 07/13/84 1 8593 7973 32 011S DMY RA 0 07/13/84 y(o24 8659' —{5-1/2"SLPSTOP(12/25/13) / .R. 8659' H5-1/2"BKR LSLD SLV,D=4.313" 8659' -45-1/2"ISOLATION SLV,ID=2-94" el 8717' —{TBG SEAL ASSY �� ►_ 8741' —9 5/8"X 5-1/2"BOT 3H PKR,D=4.75" I 5-1/2"TBG, 17#,L-80, .0232 bpf,D=4.892" — 8741' i 8741' H5-1/2"X 4-1/2"XO 8797 H4-1/2"OTIS X NP,D=3.813" TOP OF 7"LNR — 8815' _ 8833' H4-1/2"OTIS XN NP,ID=3.725" 8833' —12-7/8"NPR D=2.313" 4-1/2"TBG, 12.64,L-80,.0152 bpf,D=3.958" H 8876' • 16118833' —2-7/8"XX PLUG(10/18/13) 8876' H4-1/2"TBG TAF,D=3.958" 9-5/8"CSG,474,L-80,D=8.681' —I 9307' , ilk 8878' —I ELM)TT LOGGED 12/15/89 PERFORATION SUMMARY '!l!r!�!�!V!ril 9405' —� TOP OF CHNBYf REF LOG:SUNS-BRCS ON 07/02/79 ANGLE AT TOP FEW:29'@ 9364' 9620' --I TOP OF CB 4 '1T Note:Refer to Production DB for historical perf data .....4••••64e 44 SCE SPF INTERVAL Opn/Sqz SHOT SQZ 111111♦11♦♦1♦♦i 3-3/8" 4 9364-9404 0 10/03/89 •••••••4••• 3-3/8" 4 9510-9520 S 05/28104 ♦�♦�/•/�1�1�♦�i* 9653' — MARKER JOINT 3-3/8" 4 9530-9580 S 05/28/04 1♦♦♦♦♦1♦1♦♦♦♦♦Ir 3-3/8" 4 9590-9615 S 05/28/04 ♦/1.111/11111♦, 3-3/8" 1 9615-9636 S 07/14/94 1♦1♦1♦♦♦1♦1♦1♦r 111111111111♦I04 3-3/8" 1/2 9676-9687 S 07/14/94 11111111 3-3/8" 1/2 9700-9710 S 07/14/94 ♦♦♦♦1♦♦1♦♦♦♦♦Ij 3-3/8" 4 9745-9788 S 07/14/94 / • 9925' -3 FISH-3"BKR BP • ♦ ig PBTD 10225' V•We1 1/1/••1/•/1111• 7"LNR,29#,L-80,.0371 bpf,D=6.184" —{ 10302' 111.141*♦...•+ BATE REV BY COMvtEPITS DATE REV BY COMMENTS PRUDHOE BAY LNT 07/08/79 ORIGINAL COMPLET101 09/12/13 RKT/JMD PULL XX PLUG/SET ISO SLV(9/6/13) WELL R-02 04/18/83 RWO 11/05/13 JMWJMD PULL ISO SLV/SET XX PLUG(10/18-19/1 PERMT No: 1781000 11/26/01 RN/TP CORRECTIONS 08/01/14 JMWJM) SET ISO SLV/SLP STOP(12/25/13) AR No: 50-029-20354-00 05/17/04 KSB/KAK CORRECTIONS SEC 32,T12N,R13E,637'FSL&968'FNNL 07/08/04 PJP/KAK CORRECTIONS 10/01/12 .MSS/JMD SET NP RED&XX PLUG(9/22/12) BP Exploration(Alaska) Wellwork Procedure Request To: Well Services Operations Team Lead Date: 06/15/2015 Wireline Operations Team Lead VER1 AFE: From: Josh Allely -Well Intervention Engineer Kirsty Schultz— NWD Engineer Est. Cost: Subject: R-02 Pre CTD Screening Please perform the following steps 1. S Pull Plug. Set Plug. MIT-T. Pull Plug. Whipstock Drift. Caliper. 2. F A/SL: CMIT-TxIA . MIT-T. 3. F LLR on IA. MIT-OA. 4. E SBHPS. Gyro. 5. C Fluff n Stuff. Set Composite Bridge Plug. Packer Squeeze. WOC. Mill Composite Plugs. Mill XN Nipple. Work is pending results of previous steps. 6. S Drift for Whipstock. Objective: R-02 is a water injector that has TxIA communication at the sliding sleeve. All efforts to patch the tubing have thus far failed. The objective of this procedure is to fix the communication by placing a cement packer in the IA from 8624' MD to 8741' MD. Current Status: Minimum ID: 2.313" at 8833' MD. 4-1/2" x 2-7/8" Nipple Reducer Max Deviation: 32deg at 8500' MD Top Perf Deviation: 23deg at 9364' MD Last TD Tag: 09/22/12: SL tagged TD with 3.62" centralizer and TEL at 9388' ELMD. Last Downhole Op: 12/25/13: SL set slip stop on isolation sleeve. Last SBHPS: 09/22/12: 2959 psi and 146deg F at 8800 TVDSS. Latest H2S: NA Injector AnnComm Status: Not Operable. TxIA communication. Program Contacts Contact Phone -Work Phone- Mobile/Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 NWD Engineer Kirsty Schultz 907-564-5105 907-350-4310 Page I 1 of 3 Notes > 10/18/13: Set XX Plug @ 8833' MD > 10/19/13: MIT-T Failed, MIT-IA Failed, CMIT-TxIA Passed to 3000 psi > 12/25/13: Set isolations sleeve across sliding sleeve, Could not pressure up down IA, tubing tracked > 02/19/15: PPPOT-T Passed to 5000 psi, PPPOT-IC Failed Slickline Pull Plug. Set Plug. MIT-T. Pull Plug. Whipstock Drift. Caliper. 1. Pull slip stop at 8659' MD (5-1/2" G profile). 2. Pull isolation sleeve at 8659' MD (4-1/2" G profile). 3. CMIT-TxIA to 2500 psi with diesel. 4. Pull 2-7/8" XX plug from nipple reducer at 8833' MD. 5. Pull 4-1/2" x 2-7/8" nipple reducer at 8833' MD. 6. Set 5-1/2" HES Evotrieve or BKR RBP (assuming they can turn it down < 4.562") above sliding sleeve at 8649' MD. • Tag Baker Sliding Sleeve (4.313" ID) and PUH 34'. See attached log for reference. • MIT-T to 3000 psi. LDL if fails. 7. Pull plug. 8. Drift with a 20' x 3.70" OD whipstock drift to TD (run with TEL and obtain corrected TD tag). 9. Run a 40 arm caliper from TD to surface. Fullbore LLR on IA. MIT-OA 10. Perform a LLR on the IA at 2500 psi or 2 bpm with diesel for 20 minutes. 11. Perform MIT-OA to 1200 psi with crude. E-Line SBHPS. Gyro. 12. Perform a SBHPS: • See attached SBHPS form for depth. • Obtain a static temperature profile from TD to 8400' MD. • Tag TD to verify depth. 13.A tubing punch may be required based on results of LLR on IA. Contact town for guidance. 14. Run a gyro survey from surface to TD in PDC mode. • Obtain a new base flange (or other wellhead component) elevation from Bell and Associates. Page 12 of 3 • Correct tool zero to RKB of 54.97'. Coiled Tubing FCO. Packer Squeeze. WOC. Mill Composite Plug. Mill XN Nipple. 15. The objective of this procedure is to place a cement plug in the packer to fix the TxIA communication. Plan is as follows. • Perform a FCO to a hard bottom. • Run GR/CCL to verify TD and obtain flag for setting composite bridge plug. • Set 4-1/2" composite bridge plug at 8750' MD. • Packer squeeze with planned TOC at 8625' MD. • Wait on cement. • MIT-IA to 4000 psi while holding 2000 psi on the tubing. • Mill composite plug and push to bottom with a 3.70 mill. • Mill the XN nipple to 3.80" with a LH motor/ mill assembly. • Detailed procedure to be provided once SL work has been completed to ensure objectives of packer squeeze can be completed. Slickline Drift for Whipstock 16. Drift and tag PBTD with a 20' x 3.70" OD whipstock drift. Page 1 3 of 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Li Plug Perforations H Perforate U Other E Pull Iso Sleeve Performed: Alter Casing ❑ Pull TubingEl Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmert❑ Stratigraphic❑ Exploratory ❑ Service Q 178-100-0 3. Address: P.O. Box 196612 6. RPI Number: Anchorage, AK 99519-6612 50-029-20354-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028279 PBU R-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10303 feet Plugs measured 8833 feet true vertical 9461.65 feet Junk measured 9925 feet Effective Depth measured 8833 feet Packer measured 8741 feet true vertical 8177.74 feet true vertical 8099.19 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 34-114 34-114 1490 470 Surface 2595 13-3/8" 72# L-80 33-2628 33-2627.87 4930 2670 Intermediate None None None None None None Production 9275 9-5/8" 47# L-80 32-9307 32-8588.02 6870 4760 Liner 1487 7" 29# L-80 8815-10302 8162.36 - 9460.76 8160 7020 Perforation depth Measured depth See Attachment feet E D E i Y E D True Vertical depth See Attachment feet DEC 15 2014 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment /� /� v DGD^ Packers and SSSV (type, measured and true vertical depth) 4-1/2" BOT 3H Perm Packer 8741 8099.19 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): �G+ 1 S°`10 JhllV i R N t q 2075 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 315 Subsequent to operation: 0 0 0 0 400 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Q Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil H Gas 0 WDSPLLJ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUC[-] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C. 0. Exempt: 313-317 Contact Nita Summerhays Email Nita. SUmmerhaVsC&ft.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer Signature 1 ' Phone 564-4035 Date 12/15/2014 i2/z9/I4 Form 10-404 Revised 10/2012 Submit Original Only L Daily Report of Well Operations ADL0028279 U { DRIFTED TBG W/ 4.495" CENT & S.BAILER, TAGGED I BAILER EMPTY, L/D UNIT FOR THE NIGHT 3 ***CONT ON WSR 7-6-13*** PULLED 5 1/2" ISO SLEEVE FROM 8630' SLM, RDMO 7/6/2013 ***WELL S/I ON DEPARTURE*** "'WELL 6/1 ON ARRIVAL` ,.. RIG UP SWCP 4520 DRIFT TBG W/ 4/50" G. RING TO BKR L SSD AT ,8633' CURRENTLY RI'H W/ ISO SLV FOR BKR SSD,' *"CONT WSR ON 9/6/13 -- UU1141 VVJt( rMUIVI W01113 ...__ SET 5-1/2" ISO. SLV. FOR BKR L SSD(4-1/2" G -FN, MAX OD= 4.40" NOGO, 67" OAL, 2.94" ID) AT 8633' SLM/8659' MD (PICTURE IN WELL FILE) PERFORM MIT -T TO 2500# ..... PASS. PULL 2-7/8" XX PLUG FROM 8819' SLM/ 8833' MD. 9/6/2013 ***WELL S/I ON DEPARTURE, PAD -OP NOTIFIED*** >ET 2-718" XX -PLUG IN NIPPLE REDUCER @ 88 2UN 4 1/2" GS (dogless). TAP ON ISOLATION SLV RS PERFORMED FAILING 2500 psi CMIT-T (see °I ALL & RESET 2-7/8" XX -PLUG IN NIPPLE RED, arse acs o€ pct inside) Zj 1N4 it (dogless). TAP ON 1SQgT r �`Fr �OB ON 10119I13**** UMI i - i xIH to 6000 psi. uoaa tuDing wan o DDIs mein, znU DAIS alesel. rumpea Z0.13 bbls diesel to attempt to psi up tbg Pumped 2 bbls meth 7.5 bbls diesel, 12.2 bbls meth to attempt tp psi up IA SSL to pull & rest plug. Pumped 20 bbls diesel down IA ***wsr 10/18/2013 continued to 10-19-13*** ailed MIT -T to 3000 Failed CMIT-TxIA to 2500 PASSED. (Rei, post ISO sleeve repair) Pumped 35 bbls diesel down IA to atter rbls diesel down tbg to attemp MIT -T, IA tracked. Rolled into Ch AA lost 11/11 psi in 1st 15 min and 8/7 psi in 2nd 15 min for; 10 min test. Final WHP's 2450/2470 0 SSL on well at depart ****CONT. JOB FROM 10/18/13**** (patch tubing / liner) LRS PERFORMED PASSING 2500 psi CMIT IA x T (see Irs log) RAN 4 1/2" GS (dogless). TAP ON ISOLATION SLEEVE@ 8630' SLM / 8659' MD ATTEMPT MIT -IA W/ TRIPLEX FAILED (tbg x is communication) DRIFTED W/ 4.50" G. RING TO ISOLATION SLEEVE PULLED 5-1/2" ISOLATION SLEEVE FROM SSD @ 8659' MD 10/19/2013 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** 365 DIESEL 17 METH 382 TOTAL FLUIDS PUMPED AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028279 MLK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base R-02 9/22/2012 BPS 9364 9404 8637.99 8672.99 R-02 9/22/2012 BPS 9510 9520 8765.85 8774.62 R-02 9/22/2012 BPS 9530 9576 8783.4 8823.77 R-02 9/22/2012 BPS 9576 9580 8823.77 8827.28 R-02 9/22/2012 BPS 9590 9612 8836.05 8855.36 R-02 9/22/2012 BPS 9612 9615 8855.36 8858 R-02 9/22/2012 BPS 9615 9621 8858 8863.26 R-02 9/22/2012 BPS 9621 9636 8863.26 8876.43 R-02 9/22/2012 BPS 9662 9670 8899.25 8906.27 R-02 9/22/2012 BPS 9670 9675 8906.27 8910.66 R-02 9/22/2012 BPS 9675 9676 8910.66 8911.53 R-02 9/22/2012 BPS 9676 9687 8911.53 8921.19 R-02 9/22/2012 BPS 9697 9699 8929.96 8931.72 R-02 9/22/2012 BPS 9699 9700 8931.72 8932.59 R-02 9/22/2012 BPS 9700 9710 8932.59 8941.37 R-02 9/22/2012 BPS 9710 9711 8941.37 8942.25 R-02 9/22/2012 BPS 9711 9730 8942.25 8958.92 R-02 9/22/2012 BPS 1 9745 9780 1 8972.07 9002.77 R-02 9/22/2012 BPS 1 9780 9788 1 9002.77 9009.78 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028279 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 34 - 114 34 - 114 1490 470 LINER 1487 7" 29# L-80 8815 - 10302 8162.36 - 9460.76 8160 7020 PRODUCTION 9275 9-5/8" 47# L-80 32 - 9307 32 - 8588.02 6870 4760 SLEEVE 2 5-1/2" Baker Sliding Sleeve 8659 - 8661 8029.25 - 8030.95 SURFACE 2595 13-3/8" 72# L-80 33 - 2628 33 - 2627.87 4930 2670 TUBING 2949 7" 26# L-80 31 - 2980 31 - 2979.26 7240 5410 TUBING 5761 5-1/2" 17# L-80 2980 - 8741 2979.26 - 8099.19 7740 6280 TUBING 135 4-1/2" 12.6# L-80 8741 - 8876 8099.19 - 8214.56 8430 7500 ol w , 7FF P7 D /-79-/00 3/33/,7 Ferguson, Victoria L (DOA) To: Derrick, Laurie R Subject: RE: Well R-02, permit to drill: 178-100-0, Sundry: 313-317 Laurie, This email will suffice to modify the 10-403. You have approval to proceed with the work as outlined. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferouson dalaska.aov From: Derrick, Laurie R [mailto:Laurie. Derrick@bp.com] Sent: Tuesday, July 30, 2013 2:54 PM To: Ferguson, Victoria L (DOA) Cc: Peru, Cale Subject: Well R-02, permit to drill: 178-100-0, Sundry: 313-317 Victoria — "C�..:1►13J We would like to revise the 10-403 (Sundry number: 313-317) for well R-02. The sundry was requested to pull an isolation sleeve, which was acting as a mechanical patch across the sliding sleeve profile at 8659'md. The Isolation sleeve did not seal appropriately and did not fix the leak. We submitted the sundry to pull the isolation sleeve and redress the seal elements so that we could re -run the sleeve to repair the tubing leak. We have pulled the sleeve and re -dressed it and are ready to run it back into the well, but we realized our program was lacking a step in the WIRELINE Action section to re -run the isolation sleeve. We would like to revise the sundry to include a step to set the redressed isolation sleeve. I have attached the original sundry document and the proposed revised program. Please let me know if it is possible to revise the sundry to include the step to set the redressed isolation sleeve. «1020353725. pdf>> <<R-02 2013 -July -30 Revised Iso SLv.pdf>> Thanks, Laurie Wireline Work Request Alaska Wells Group R-02 Well: R-02 AFE: APBINJEC 1-12S: N/A Date: 07/30/13 Engineer: Cale Peru 10-403? Y IOR 150 WBL Cat. IOR 10-404? Y AWGRS Job Scope: PATCH TUBING / LINER Problem Description R-02 is a Sag water injector, shut in due to TAA in Aug 2011. A LDL showed that Baker SSD is leaking. An isolation sleeve was set in Oct 2012. MIT -IA failed, tbg tracked IA. Plan now is to pull iso sleeve then at a later date redress it with more packing, re -run, do MIT -T then . CMIT to restore integrity. Initial Problem Review > Well status: PW I, Not Operable > Min ID: 2.313" @ 8833' MD (2 7/8" Nipple reducer) > Max angle: 32 degrees at 8500' MD > Last TD tag: 8659' MD Oct 19 2012 (top of sld slv didn't try to go deeper) > Last DH Ops: Set iso sleeve (Oct 19, 2012) > MIT-IA:To 2500 psi, Failed (Nov 4, 2012) tbg tracking. > Caliper Log: from 9,364' SLM to surface (8/17/11) > FL: IA @ surface (Nov 23, 2012) Remedial Plan - WIRELINE ACTION Ob': Pull isolating sleeve 1. S: RU SL & Drift to top of sid slv @ 8659' 2. S: Pull isolation sleeve, diagram attached in JMS, pictures in "wellpicture" folder. Leave XX plug in the well. RD SL. 3. S: RU SL. Drift to Bkr Slv at 8659'. Set redressed isolation sleeve in profile. FB assist SL - MIT -T to 2500 -psi. If MIT -T passes, plull XX plug at 8833'md. 7� THE STATE 01AL SKA GOVERNOR SEAN PARNELI, 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 SCANNED NO V 0 4 2013 Fax: 907.276.7542 Cale Peru Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 737 —1 b 0 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-02 Sundry Number: 313-317 Dear Mr. Peru: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, kl--� Daniel T. Seamount, Jr. Commissioner DATED this2 day of June, 2013. Encl. • * STATE OF ALASKAl �f� ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well❑ Stimulate ❑ Alter Casing ❑ Other: Pull Isolation Sleeve Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service • 178-100-0 3. Address: 6. API Number. P.O. Box 196612, Anchorage, AK 99519-6612 50-029-20354-00-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 341 D PBU R-02 Will planned perforations require a spacing exception? Yes ❑ No Li 9. Property Designation (Lease Number): I 10. Field/Pool(s): ADL0028279 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10303 - 9462 • 8822 8168 None 9925 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 34-114 34-114 Surface 2595 13-3/8" 72# L-80 33-2628 33 - 2627.87 4930 2670 Intermediate None None None None None None Production 9275 9-5/8" 47# L-80 32-9307 32-8588.02 6870 4760 Liner 1487 7 29# L-80 8815-10302 8162.36 - 9460.76 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2" BOT 3H Packer Packers and SSSV MD (ft) and TVD (ft): 8741, TVD Top No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/1/13 Oil ❑ Gas ❑ WINJ Q GINJ ❑ WDSPL ❑ Suspended ❑ WAG ElAbandoned 1:1Commission 16. Verbal Approval: Date: Representative: GSTOR ElSPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cale Peru Email Printed Name Cale PeruTitle PE Signature Phone Date � 564A522 6/18/2013 COMMISSION USE ONLY Conditions Notify Commission that Sundry Number. of approval: so a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS JUL -1201 Other: Spacing Exception Required? Yes ❑ No Lin Subsequent Form Required: fb �b q' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 1/ 02 10Appro �f �a i months from the date of approval. 6/l3 t'tV� L Sub it in uplicatp��X'I Wireline Work Request R-02 Alaska Wells Group Well: R-02 AFE: APBINJEC H2S: N/A Date: 06/05/13 Engineer: Cale Peru 10-403? N IOR 150 WBL Cat. IOR _ 10-404? N AWGRS Job Scope: PATCH TUBING / LINER Problem Description R-02 is a Sag water injector, shut in due to TAA in Aug 2011. A LDL showed that Baker SSD is leakinn . An isolation sleeve was set in Oct 2012. MIT -IA failed, tbg tracked IA. Plan now is to pull iso sleeve then at a later date redress it with more packing, re -run, do MIT -T then . CMIT to restore inter. Initial Problem Review I> Well status: PWI, Not Operable > Min ID: 2.313" @ 8833' MD (2 7/8" Nipple reducer) _ > Max angle: 32 degrees at 8500' MD _L Tr% t- f]C%Pf%I RAf% /1-1 wn 0"%f% 0% /A -- _r _IJ - J: -j VL a.... ad...........\— — �aaL I v LCK . vv.►u rviv v�.L i iJ w i c kwN v1 � %A 0 V uru" L u Y av !d uNI > Last DH Ops: Set iso sleeve (Oct 19, 2012) _ > MIT-IA:T_o 2500 psi, Failed (Nov 4, 2012) tbg tracking. > Caliper Log: from 9,364' SLM to surface (8/17/11) > FL: IA @ surface (Nov 23, 2012) Remedial Plan - WIRELINE ACTION Obj: Pull isolating sleeve 1. S: RU SL & Drift to top of sld siv @ 8659' 2. S: Pull isolation sleeve, diagram attached in JMS, pictures in "well picture" folder. Leave XX plug in the well. 3. S: RD SL TREE= 6" MCEVOY VUIiLHEAD = MCEV_OY ACTUATOR OTES KB. ELEV = 54.9T BF. ELEV = 21.09' KOP = 3300' Max Angle = Datum MD = 32" @_8500' 9612 Datum TVD =� 8800'SS 0 13-3/8" CSG, 72#, L-80, D = 12.347 262W 7" TBG, 26#, L-80_0383 bpf, D = 6.276" 2980' TOP OF 5-1/2" TBG 2980' Minimum ID = 2.313" @ 8833' 2-7/8" NIPPLE REDUCER 5-1/2" TBG, 17#, L-80, .0232 bpf, D = 4.892" 1-1 8741' OF 7" LNR 1—I 8815' 11 4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 1—) 8876' 9-5/8" CSG, 47#, L-80, D = 8.681" 1--� 9307' PERF0RATION SUMMARY REF LOG: SWS-BHCS ON 07/02/79 ANGLE AT TOP PE RR 29" @ 9364' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 9364-9404 O 10/03/89 3-3/8" 4 9510-9520 S 05/28/04 3-318" 4 9530-9580 S 05/28/04 3-3/8" 4 9590-9615 S 05128/04 3-318" 1 9615-9636 S 07/14/94 3-318" 1/2 9676-9687 S 07/14/94 3-318" 112 9700-9710 S 07/14/94 3-318" 4 9745-9788 S 07/14/94 PBTD 10225' 7" LNR, 29#, L-80_0371 bpf, ID = 6.184" 1030T R-02 ( SAFETY NOTES: WHEN ON MI. WELL REQUIRES A SSSV WHEN ON 2980' —E X 5-1/2" XO 2992' 5-1/2" CAMCO SSSV LANDING NP, 1)=4.562" 4 I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 3147 3044 7 OTIS DMY RA 0 07/13/84 7 5096 4881 28 OTIS DMY RA 0 07/13/84 6 6572 6202 29 OTIS DMY RA 0 07/13/84 5 7637 7104 31 OTIS DMY RA 0 07/13/84 4 8225 7585 32 OTIS DMY RA 0 04118/83 3 8362 7754 32 OTIS DMY RA 0 04/18/83 2 8460 7839 32 OTIS DMY RA 0 07/13/84 1 8593 7924 32 OTIS DMY RA 0 07/13/84 8659' —j 5-1/2" BKR, L SLD SLV, D = 4.313" 8659' 5-1/2" ISOLATION SLV, D = 2.91" 871 T —{TBG SEAL ASSY 8741' 9 5/8" X 5-1/2" BOT 3H PKR, ID = 4,75- 4-1/2- .75" 9620' 1—I TOP OF CEMENT 9653' H MARKE RJOINT 9925' H FISH - 3" BKR IBP 4-1/2" 0TIS XN NP, ID = 3.725" 8$33' 2-7/8" NP RE3)LK;ER D = 2.313" 8833' 2-718" XX PLUG (09122112} 8876' 10/01/12 MSS/JMD SET NP RED 8 XX PLUG (9122112) 8878' EiMD TT LOGG®12/15/89 05/17/04 KSB/KAK CORRECTIONS 10120/12 PJC GLV CORRECTION TOP OF CEMENT �9M5' 1 9620' 1—I TOP OF CEMENT 9653' H MARKE RJOINT 9925' H FISH - 3" BKR IBP PRUDHOE BAY LW WELL: R702 PERWrr No: 11781000 AR No: 50-029-2035400 SEC 32, T12K R13E, 637' FSL 8 968'FW[- DATE REV BY COMMENTS DATE REV BY COMMENTS 07/08179 ORIGINAL COMPLETION 01/18112 TMPYJMD ADDED H2S SAFETY NOTE 04/18/83 RWO 10/01/12 MSS/JMD SET NP RED 8 XX PLUG (9122112) 11/26/01 RWTP CORRECTIONS 10/19/12 RKT/ PJC SET ISOLATION SLV (10119/12) 05/17/04 KSB/KAK CORRECTIONS 10120/12 PJC GLV CORRECTION 07/0a/041 PJP/KAK CORRE=NS BP Exploration (Alaska) 021151111 M31JMD JADDED SSSV SAFETY NOTE Cl • AB ABANDONED Perforation Attachment MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED ADL0028279 BRIDGE PLUG PULLED MLK Well Date Perf Code MD Top MD Base TVD Top TVD Base R-02 9/22/12 BPS 9364 9404 8638 8673 R-02 9/22/12 BPS 9510 9520 8766 8775 R-02 9/22/12 BPS 9530 9576 8783 8824 R-02 9/22/12 BPS 9576 9580 8824 8827 R-02 9/22/12 BPS 9590 9612 8836 8855 R-02 9/22/12 BPS 9612 9615 8855 8858 R-02 9/22/12 BPS 9615 9621 8858 8863 R-02 9/22/12 BPS 9621 9636 8863 8876 R-02 9/22/12 BPS 9662 9670 8899 8906 R-02 9/22/12 BPS 9670 9675 8906 8911 R-02 9/22/12 BPS 9675 9676 8911 8912 R-02 9/22/12 BPS 9676 9687 8912 8921 R-02 9/22/12 BPS 9697 9699 8930 8932 R-02 9/22/12 BPS 9699 9700 8932 8933 R-02 9/22/12 BPS 9700 9710 8933 8941 R-02 9/22/12 BPS 9710 9711 8941 8942 R-02 9/22/12 BPS 9711 9730 8942 8959 R-02 9/22/12 BPS 9745 9780 1 8972 1 9003 R-02 9/22/12 BPS 9780 9788 1 9003 1 9010 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 0 11 Casing Summary ADL0028279 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H-40 34 114 34 114 1490 470 H-40 LINER 1487 7" 29# L-80 8815 10302 8162 9461 8160 7020 L-80 PRODUCTION 9275 9-5/8" 47# L-80 32 9307 32 8588 6870 4760 L-80 SURFACE 2595 13-3/8" 72# L-80 33 2628 1 33 2628 4930 2670 L-80 TUBING 2949 7" 26# L-80 31 2980 31 2979 7240 5410 L-80 TUBING 135 4-1/2" 12.6# L-80 8741 8876 1 8099 8215 8430 7500 L-80 TUBING 5761 5-1/2" 17# L-80 2980 8741 2979 8099 7740 6280 L-80 0 11 • • r ff A11 [E [F [I\ 113 [i\k\SEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Walaa Badawy ', ") I " Production Engineer BP Exploration (Alaska), Inc. g _ / P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, R -02 Sundry Number: 312 -348 Dear Walaa Badawy: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Fo rster Chair, Commissioner DATED this 12th day of September, 2012. Encl. • • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION SET 1 0 20d? APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska UHF Et G:?. ,s: ; •_ :Tr A 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 5 • C1a1ge,,Appt{ yed Program 0 Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 178 -100-0 • 3. Address: Stratigraphic ❑ Service El • 6. API Number. P.O. Box 196612, Anchorage, AK 99519 -6612 50-029-20354-00-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 111 PBU R -02 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0028279 . PRUDHOE BAY, PRUDHOE OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10303 9462 9405 8674 None 9925 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 34 - 114 34 - 114 Surface 2595 13 -3/8" 72# L -80 33 - 2628 33 - 2627.87 4930 2670 Intermediate None None None None None None Production 9275 9 -5/8" 47# L -80 32 - 9307 32 - 8588.02 6870 4760 Liner 1487 7" 29# L -80 8815 - 10302 8162.36 - 9460.76 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5 -1/2" BOT 31i Packer Packers and SSSV MD (ft) and TVD (ft): 8741, 8099.19 No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development ❑ Service [] 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El , Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Walaa Badawy Title Production Engineer Signature Phone 564 -5473 Date of /0 / /2- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _3/2 -a ys Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: 44 l T l re- v/ d'' (e p y--/ 6 l/ 7 l vt. J re h . �` t l � � I I - 0 6 7 C G , -1– 41 l 7` L 4 - Subsequent Form Required: /0 — .gd4- APPROVED BY Approved by: C / X."' (1-1r'--___ COMMISSIONER THE COMMISSION Date: 9- ! / Z -/ 2- vi F ORIGINAL 4 4r' �2 in Duplicate �` �� /fz 1 • • Perforation Attachment ADL0028279 Well Date Perf Code MD Top MD Base TVD Top TVD Base R -02 10/3/89 RPF 9364 9404 8638 8673 R -02 5/28/04 BPS 9510 9520 8766 8775 R -02 5/28/04 _ BPS 9530 9576 8783 8824 R -02 5/28/04 BPS 9576 9580 8824 8827 R -02 5/28/04 BPS 9590 9612 8836 8855 R -02 5/28/04 BPS 9612 9615 8855 8858 R -02 5/28/04 BPS 9615 9621 8858 8863 R -02 5/28/04 BPS 9621 9636 8863 8876 R -02 5/28/04 BPS 9662 9670 8899 8906 R -02 5/28/04 BPS 9670 9675 8906 8911 R -02 5/28/04 BPS _ 9675 9676 8911 8912 R -02 5/28/04 BPS 9676 9687 8912 8921 R -02 5/28/04 BPS 9697 9699 8930 8932 R -02 5/28/04 BPS 9699 9700 8932 8933 R -02 5/28/04 BPS 9700 9710 8933 8941 R -02 5/28/04 BPS 9710 9711 8941 8942 R -02 5/28/04 BPS 9711 9730 8942 8959 R -02 5/28/04 BPS 9745 9780 8972 9003 R -02 5/28/04 BPS 9780 9788 9003 9010 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE . BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED . RPF REPERF Casing Summary . ADL0028279 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H-40 34 114 34 114 1490 470 H -40 LINER 1487 7" 29# L -80 8815 10302 8162 9461 8160 7020 L -80 PRODUCTION 9275 9 -5/8" 47# L -80 32 9307 32 8588 6870 4760 L -80 SURFACE 2595 13 -3/8" 72# L -80 33 2628 33 2628 4930 2670 L -80 TUBING 2949 7" 26# L -80 31 2980 31 2979 7240 5410 L -80 TUBING 135 4 -1/2" 12.6# L -80 8741 8876 8099 8215 8430 7500 L -80 • TUBING 5761 5 -1/2" 17# L -80 2980 8741 2979 8099 7740 6280 L -80 • • • • by To: Wireline Operations Team Lead Date: Aug 27, 2012 From: Walaa Badawy M/R -Pad Engineer Subject: R -02 Sliding Sleeve Repair Job Sequence 1. S Drift to TD & Obtain SBHP 2. S Set Nip. Reducer © 8833' MD OTIS XN Nip 3. S B &F SSD @ 8659' MD 4. S Set Isolating sleeve (8659' - 8664' MD) 5. F Load IA & Perform MIT -IA TO 2500 psi 6. S Set WF ER packer using HES DPU 7. F AOGCC MIT -IA to POI Current Status: PWI, Not Operable Minimum ID: 3.725" ©8833' MD (4 1/2" Otis XN Nipple) Max Deviation: 32° at 8500' MD Last Drift: 09/09/11: 9388' ELM on (Possibly Schmoo covering part of perf) Last Downhole Op: 12/17/11: Troubleshooting SSD &LDL MIT -IA 08/21/11: To 2500 psi, Failed Caliper Log 08/17/11: from 9,364' SLM to surface, good to fair conditions SBHP /SBHT 09/10/11: 3,879 psi and 133 °F © 8800' TVDss IA FL 08/23/11: near surface Latest H N/A Program Contacts Contact Phone — Work Phone — Cell /Home Pad Engineer Walaa Badawy 564 -5473 350 -0784 (c) Lead Pad Engineer Laurie Derrick 564 -5952 (720) 308 -3386 Panes 1 of & • • Program Objectives The objective of the program is to set a_ n iso_latin sleevet_ o repair the leaking SSD and put the well back on injection. Well History R -02 was originally drilled in 1979 then it was worked over in 1983. In 1987 it was perforated in Zone 4. Sag perfs were added in 1988 to start injection in both the Sag and Ivishak. In April of • 2004, the Ivishak perfs were squeezed off to turn the well to Sag only injector. In Aug 2011, the well was shut due to the increase of IA pressure. To confirm integrity; MIT -IA to 2500 psi was performed. The test failed and LRS were able to establish an IA LLR of 2.6 gpm @2500 psi. A caliper log was run in Aug 2011, and both tubing and liner were in good to fair conditions. In Sep. 2011, a Techwel LDL showed a clear leak at SSD. In Dec. 2011 SL shifted , Baker SSD to confirm close but MIT -IA failed and LRS couldn't estab h LLR. = Procedure Steps SS Yt, 21 A. Slick line 1. RUSL &Drift to TD 2. Run SBHP as per attached program 3. Set a nipple reducer in XN Nip @8833' MD Min. ID of isolating sleeve in 3.00 ", XN Nip profile is 3.725 ". This will allow us to set TTP if it is required for future operations. 4. Rig up Full Bore & carry out PJSM 5. Pump diesel as per attached pumping schedule to B &F SSD 6. RIH to set isolation sleeve ? ‘01%-"-(-- �. Sl �s� 7. Load IA with Diesel 8. Perform MIT -IA to 2500 psi 9. If MIT -IA passed, move to the next step. If MIT -IA failed; try to establish LLR. CaII Pad Eng to discuss further action. Consider setting TTP & perform MIT -T to 2500 psi to confirm tbg integrity. Depending on outcome, a LDL might be required. 10. RIH with HES DPU to set WF ER packer above sleeve 11. RD SL B. Put on Injection Coordinate with WIC to perform the AOGCC MIT -IA prior to POI. Contact Pad Engineer for injection target. Pana7of4 • • Isolating Sleeve schematic _ PanPi nf4 .. _.... _... _.._.. _.. 40 ..... ........... _.. _..... ...... .......... m„ J • 6" 1ACE1/0Y WELLHEAD = MCEVOY sAfeTY NOTES M28 REA 191.38 MIRAGE 1 Z1 ppm ACTUATLit* OTIS R.02 WHEN ON Mt. WELL REOUIRIM A SSSV WHEN ON K5. ELev = 54 gt IS BF ELEV = 21 KOP- 3300 . A r g a - 32 0 5 0 D L am 1.40 812 y �pry Daum TVD = 8800 SS 1 1 33,+9' cm 721, 1,'8O Ej= 123471—f 2628' ® I- ? t 1J2 xol I r TBG, L 0383 blur, 0 * /6.276' H z98o' 21/192" H9- 1 /r CA NCO sssv LI0. NIP C = 4. sarj TOP OF S.1rr TBG 2980' GAS LIFT' MANDRELS 9T NCI TVt '0EV TY PE VLV LATCH t4DRT DATE IYSnimum ID >< 3.726" 128833' a 3147 3044 7 1)71S IN RA 07713494 4 -112 " OTIS XN NIPPLE 7 5096 4881 28 OTIS DV RA 07113164 5 6572 5202 29 0715 C>4( RA 07013614 5 7637 7104 31 OTIS Ctil R1A 07113184 4 6225 7595 32 0115 Cu RA 04119163 3 6362 7754 32 OTIS Cu RA 04/18/83 2 0460 7830 W OTIS Cr1 PA 07113194 �� �� 1 9690 7'924 32 016 Cu RA 07113'84 4 9669` 1--15.1 152° 81ffi L SLIDING &L1F, I@ c 4.3A 3" Ill WHAM TBD SEAL ASSY ill # a 0.--4 8741' 9 • X 5.112' DOT 3H PKR, 0 " 4 7V" t 5-1/2' MG, 1 70 , L -20, 0232 bpi, ID = 48 T 8741' All 8741' 5.1/1"X4- 1F1"XQ 8792' 4.12" OTISX08►, Da 3-$13' TOP OF T LN2 IIMEIII 111 1 I 6513' H4-1/2- 13115 XN Nt', 0 • 3.725' 4 - 1/7'TBG, 1260, 140, 015250f, ID 2 3 '915$' 4- I??'T8oTAX., 0_33 I 6576' Filmy TT LOOGED 12F15 1 19.518" CS13, 479, L-80, 0 = 8.681' H 9307' I I 94E36' T�!P OF aneNT t11�Pa1`I0N $61V41MFO' ms's +a'4 * +� RCP LOG; 814C8 ON 0710209 ANGLIA!' TOP PERF 291' G 9364' Nate: Rear to R 118 for hatarical parf data ' # I 9 I ( Top QF SZE SPF NTERVAL 0pah3gz DATE Ii 4 4 4 44 It# #44 #4 3-318' 4 9364.9404 0 1003189 ****14 4 4 3-3/8` 4 9610 - 9620 S 062210934 `i 1.4.4 m 9853` _ MARKE}'4 ,K F.44444.* 3-31 4 MIO - 959C! S 05129104 14 t# 1# i 4' 3 4 9590 - 9815 S 05264:4 W 444+04.4 04. 44 3 1 MI5 - 9&35 8 07114/94 h l f t t t # # t 4 4 t 1 4 + 4 3 12 9976 - 9007 8 07114/94 h # + ' 3.3(11` 1/2 419 -9710 S 07114 04.11440 !1.1144441 1 441• 41# 3 -318` 4 9745 9798 S 07(14194 ' i ( 991$" �F`16H - 3' f+ I h TIN I H 102251' I r � it' #11/1' 4 t t # �/ # t + t 4 4 . 1 r L NR, 291, L-ao 0371 bpr, is • 6 164` I—( 1 p; h.•,t t,4,t t l t DATE 1 REV BY COMMENTS I 647E I REV BY CO344134 FRLDHOF BAY iter 0790897! ONG@U.L COMPLET1SN4 t111S8ts2 ITMWJ?ND ACXED 1-128 SAFETY NOlt 0K.L'6 limn 04/18983 1690 No:'1781m o 11126141 RNTP CORRECTIONS API No 53-029-29054.00 85(17104 KS9+1CAK. CORRECTIONS SEC32, TUN 9213E 07 a PROW CORRECTIONS D2015011 10161.04i ACOOD SSW SAFETY NOTE 19P EXp oralian (M s k41 PanP 4 of 4 \y9 7-S CCD • \-7y-too WELL LOG TRANSMITTAL PROAcrivE D SERVICES, INC. To: AOGCC ECF \/E® Christine Mahnken 333 W. 7th Ave NOV 1 ;* .) 11 Suite 100 Anchorage, Alaska 99501 Alaska On of uns ;,elms. r;®IrmissiOn (907) 793 -1225 An:3rcte RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MT() The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 11- Sep -11 R -02 BL/ CD 50- 029 - 20354 -00 2] Signed: ) Date: \.Al29'1'' Print Name: N Az.111•. 11 .%) PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E-MAIL : PDSANCHORAGEaMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:lArchives\ Distribution \TransmittalSheets\BP TransmitdocX 3Q2011 Not Operable Injector Report • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIl lntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 302011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip Tom, Jim, Phoebe and Guy, . '"�. . as Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000))dentified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 NOT OPERARABLE: Injector R -02 (PTD .81000) Failed MIT -IA Page 1 of / Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, August 21, 2011 7:59 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Chan, Paul (PRA) Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Reynolds, Charles (ALASKA) Subject: NOT OPERARABLE: Injector R -02 (PTD #1781000) Failed MIT -IA All, Injector R -02 (PTD #1781000) failed an MIT -IA to 2500 psi on 08/21/2011. The failing test proves a lack of two competent barriers and the well is reclassified as Not Operable. The well is currently shut in and should remain shut in until repaired. The plan forward: 1. APE: Evaluate for LDL Thank you. Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: D &C Well Integrity Coordinator Sent: Saturda , ly 30, 2011 1:43 PM To: 'Maunder, Thoma DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pa. ; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lea., • . RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Sayed, Mohamed Cc: AK, D &C Well Integrity Coordinator; King, Whi - • Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector R -02 (PTD #1 : 10) IA Repressurization After UIC Bleed All, Injector R -02 (PTD #1781000) exhibited IA repressurization after a blee. or UIC compliance. The IA was bled on 07/28/2011 1100 psi to 550 psi. The monitor on 7/29/2011 indicated the IA h_: ' creased to 1090 psi. The well is reclassified as Under Evaluation. 11/29/2011 Monthly Injection Report for GPB,MA, Northstar, Milne Point & Endicor August... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator ( AKDCWetllntegrityCoordinator ©bp.com] Sent: Saturday, September 03, 2011 4:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for August 2011 Attachments: AOGCC Inj Report 09- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the August 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 09- 11.zip» Notes on wells: Added to Report: , 4 'i'wi;<i sG�p: 8 2O'E None Taken off Report: 09 -36C (PTD #1951140): Reclassified as Not Operable and added to Quarterly Not Operable Report after LDL identified patch leaking. f ------- R -02 (PTD #1781000): Reclassified as Not Operable and added to Quarterly Not Operable Report after MIT -IA failed. L -119 (PTD #202060): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. L -210 (PTD #2031990): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. W -03 (PTD #1971390): Monitored for IA repressurization reported February, 2011. No repressurization noted. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/6/2011 Monthly Injection Report for GPB,•MA, Northstar, Milne Point & Endiclior July 20... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, August 04, 2011 8:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for July 2011 Attachments: AOGCC Inj Report 08- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the July 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 08- 11.zip» a rg Ai`L �.`'` i.t Notes on wells: Added to Report: 09 -36C (PTD #1951140): Under Evaluation for IA repressurization. AGI -08 (PTD #1930330): Exhibited IA repressurization. Repressurization mitigated after SSSV change out. To be left on Monthly Injection Report for monitoring for 2 months. NS -27 (PTD #2010270): Under Evaluation for IA repressurization. -02 (PTD #1781000): Under Evaluation for IA repressurization after a UIC bleed Taken off Report: U -10 (PTD #1851970): Successful AOGCC witnessed MIT -IA after tubing patch repair Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/8/2011 Well R -02 Injection Plot TIO Plot Well: R -02 °o Pressure vs. Rate o PTD: 1781000 a °o ri M Tbg IA Under Evaluation for IA OA repressurization after a UIC o bleed 0 o J 1 � b � n 0 'ull a ♦ a 0 _ • a = J� • o l V u • 90 days • Last Month • ♦Last �i\--- o• , , , r• o ,n 111/ 0 1,000 2,000 3,000 4,000 5,000 6,000 2/19/11 5/12/11 8/2/11 10/23/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 08/01/11 0 0 08/01/11 0 1,040 0 07/31/11 0 0 07/30/11 0 1,100 0 07/30/11 0 0 07/29/11 0 1,100 0 07/29/11 0 0 07/28/11 0 1,160 0 07/28/11 5,118 0 07/27/11 0 1,260 0 07/27/11 0 0 07/26/11 0 1,260 0 07/26/11 0 0 07/25/11 0 1,260 0 07/25/11 0 0 07/24/11 0 1,260 0 07/24/11 0 0 07/23/11 0 1,260 0 07/23/11 0 0 07/22/11 0 1,360 0 • 07/22/11 0 0 07/21/11 0 1,360 0 07/21/11 0 0 07/20/11 0 1,360 0 07/20/11 0 0 07/18/11 0 1,200 0 07/19/11 0 0 07/17/11 0 1,200 0 07/18/11 0 0 07/16/11 0 1,200 0 07/17/11 0 0 07/15/11 0 1,200 0 07/16/11 0 0 07/14/11 0 1,200 0 07/15/11 0 0 07/13/11 300 700 0 07/14/11 5 14 07/12/11 2,000 760 150 07/13/11 0 184 07/11/11 2,000 760 150 07/12/11 315 749 07/10/11 2,080 820 200 07/11/11 1,101 1,999 07/09/11 2,080 850 200 07/10/11 1,145 2,002 07/08/11 2,080 850 125 07/09/11 959 1,957 07/06/11 1,440 520 0 07/08/11 1,447 2,022 07/05/11 2,100 740 160 07/07/11 1,604 1,913 07/04/11 2,100 740 160 07/06/11 139 1,316 07/03/11 1,700 500 0 07/05/11 584 1,544 07/02/11 1,700 500 0 07/04/11 1,421 2,063 07/01/11 2,060 720 220 07/03/11 1,576 2,044 06/30/11 2,060 720 220 07/02/11 378 1,638 06/29/11 2,060 720 180 UNDER EVALUATION: Injector 142 (PTD #1781000) IA Repressurization After UIC ... Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Saturday, July 30, 2011 1:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Sayed, Mohamed Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector R -02 (PTD #1781000) IA Repressurization After UIC Bleed Attachments: Injector R -02 (PTD #1781000) TIO and Injection Plot.doc; R -02 (PTD #1781000) welibore schematic. pdf All, Injector R -02 (PTD #1781000) exhibited IA repressurization after a bleed for UIC compliance. The IA was bled on 07/28/2011 1100 psi to 550 psi. The monitor on 7/29/2011 indicated the IA had increased to 1090 psi. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: MIT -IA to 2500 psi 2. WIE: Evaluate for Leak Detect Log depending on MIT -IA results A TIO and Injection plot and welibore schematic have been included for reference. «Injector R -02 (PTD #1781000) TIO and Injection Plot.doc» «R -02 (PTD #1781000) welibore schematic. pdf» Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/10/2011 • S Injector R -02 (PTD #1781000) TIO Plot 07 -30 -2011 Well: R -02 000 t Tbg -MI- IA 2 000 - - on Dan -.-- 0004 On 1000 11111111 661111.111111111111111111111116........11110. Amman. _ __ 04/30211 05/07 /11 05/14 /11 05/21 /11 05/28/11 05/04/11 06/11/11 06/18/11 0625/11 07/02/11 07/09/11 07/1 6/11 07/23/11 07/30/11 Injector R -02 (PTD #1781000) Injection Plot Well: R -02 2,200 - 5,200 - 5,000 - 4,800 2,000 - - 4,00 - 4,400 1,800 - I 1 - 4200 - 4,000 1,600 - 3,800 - 3,600 - 3,400 1,400 - - 3200 m . - 3,000 - WHIP a. 1,200 - - 2,800 0 -- SW - 2,600 2,600 MI - 2 n 1.000 - GI - 2200 0 - Other 800 - 2,000 On - 1.800 - - 1,600 600 Y - 1,400 - 200 1, 400 - 1,000 - 800 zoo _ - soa - 400 - 200 05/07/11 05/21/11 06/04/11 06'13:11 07/02/11 07/16 11 07/30/11 AOGCC MITIAs for NK-15 (#1~320), NK-18 (#1931170), P-03A (#19~280), R-02 (... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, October 05, 2009 10:21 PM ~~~ Z~~~~5~~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Fleckenstein, Robert J(DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer Subject: AOGCC MITIAs for NK-15 (#1970320), NK-18 (#1931170), P-03A (#1972280), R-02 (#1781000), U-05A (#2090700), W-35 (#1880330), 14-21A (#2051070), NK-65A (#2050630) Attachments: MIT PBU NK-15 NK-18 09-17-09.x1s; MIT PBU P-03A 09-12-09.x1s; MIT PBU R-02 09-12- 09.xis; M!T PBU U-05A 09-12-09.x1s; MIT PBU W-35 09-12-09.x1s; MIT PBU 14-21A 09-21- 09.x1s; MIT PBU NK-65A 09-21-09.x1s Jim, Tom, and Bob, Please find the attached MITIA forms for the following wells: NK-15 (#1970320) NK-18 (#1931170) P-03A (#1972280) ~~ R-02 (#1781000) U-05A (#2090700) W-35 (#1880330) 14-21 A (#2051070) NK-65A (#2050630) ~ ~~~~,F~ ~ ,~ ,~ _ ~~ ~,~v`„~ ~ ;:~2:~~ «MIT PBU NK-15 NK-18 09-17-09.x1s» «MIT PBU P-03A 09-12-09.x1s» «MIT PBU R-02 09-12-09.xis» «MIT PBU U-05A 09-12-09.x1s» «MIT PBU W-35 09-12-09.x1s» «MiT PBU 14-21A 09-21-09.x1s» «MIT PBU NK-65A 09-21-09.x1s» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. ~alt Torin Roschinger) 1Ne11 lntegrety Coardinator GP~ Wells Group Phone: {907) 659-5102 Pager: {907) 859-51Q0 x1154 10/15/2009 • ~ STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_MaundercLDadmin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / R pad DATE: 09/12/09 OPERATOR REP: Torin Roschinger AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well R-02 T e In'. W TVD 8,099' Tubin 2360 2120 2120 2080 Interval 4 P.T.D. 1781000 T e test P Test psi ~ 2025 Casing ~ 440 2500 2360 2310 ~ P/F P Notes: AOGCC MITIA to 2500 psi OA 300 440 460 480 Well Ty e Inj. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubin Intervai P.T.D. Ty e test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Ty e test Test psi Casin P/F Notes: OA Well Ty e Inj. TVD Tubing Interval P.T.D. Type test Test si Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test i INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 2009-0912_MIT_PBU_R-02.x1s • . STATE OF ALASltA ALASKA OIL AND GAS CONSERVATION C011~MISSION Mechanical Integrity Test Email to: Winton_Aubert~admin.state.ak.us; Bob F~cker~ein~admirt_sSate.ak.~rs; JF~ Regg min.state.ak.us; Tom_Maunder~admin.staie.ak.us OPERATOR: BP E~loration (Alaska}, Inc_ FIELD ! UNIT ( PAD: Prudhce Bay / PBU 1 R pad DATE: Q3/i2/09 OPERATOR REP: Torin Roschinger AOGCC REP: Padces i3ep1~ Pse4est 4r9~a5 't5 i~lhs~. 3p tJ~ir. Well R-02 Type Inj. W ND 8,~9' Tubirg 238D 2120 2120 208d Interval 4 P.T.D. 178100(} Type test P Test psi Zd25 Casi~ 440 250d 2360 2310 P/F P Notes: AOGCC MITIA to 2500 psi OA 3Ud 440 460 480 Well T tnj. TVD '~ubi~ Interval P.T.D. Type test Test ~si Casar~ P/F Notes: ~ Well Type Inj. TVD Tubir~} Interval P.T.D. T test Test psi Gase~og P!F Notes: OA Well Type Inj. lVD T~rbir~ Interval P.T.D. Type test Test psi Casang P!F Notes: OA Well Type Inj. TVD Tubirtg Interval P.T.D. Type test Test psi Casi P~F Notes: OA ~ ~~ i~ ~ ~i TYPE INJ Codes 7YPE T£ST Cades INTERVAL Cades D= Drilling Waste M= Annulus Monimring 1= Initial Test G= Gas P= Shatrdard Pressure Tesk 4= Four Year Cycle I= Industrial Wastewater R= Intemal Radioadive Tracer Survey V= Required by Variance N= Not Injecting A=TemperaWre Anomaly5urvey T=Test during Workwer W= Water D= DitFeren4al Tempetal~aeTest O= Other (describe in notes) ~.,`~ ~ F ~; LG~ ~ ~yg,,~i gel~~ _ ~ u `:~ ~:YY~+`~ °~ C ~w.b.> 1 , - MIT Report Form BFL 9/1/O5 Mff PBII R-OZ ~-12-09.~c1s • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 • `~ ' ~~~ ~ ~~1 ~- ~~ ~ bp ~~~~~~~~ ,~UL. A ~ ~00~ A~a~k~ Q~! $~ Gas ~ons. ~A~mis~io~ Anchorage Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. y. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~~ ~~;;~ ~ :~ 2~Q~ ~~~'~~~: Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~~ ~ ~ ~~~~ `F ' ~~`~~~~~' ~lVL '~ 4-' ~~G~ ~t ~ July 10, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7ih Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, `~a~ ~$ ~ ~~~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ seafant date ft bbls ft na al R-02 50029203540000 1781000 1.25 IVA 125 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-08 50029205480000 1810010 0.25 NA 025 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6(22l2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11l2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5h 8/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5l18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6l11 /2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5114I2009 R-31A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5l12l2009 # ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~ ~ Date R-pad 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 125 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA i 6.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6l11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11 /2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 325 NA 3.25 NA 22.1 5/12/2009 H-09 (PTD# 1800640), M-14 (P~# 1801090), R-02 (PTD# 1781000), R-(PTD# 19812... Page 1 of 1 Regg, James B (DOA) ~ 17g ~--1 From: Regg, James B (DOA) ~~~ ~/~~~D~ Sent: Tuesday, June 16, 2009 11:24 AM To: 'Roschinger, Torin T.'; Maunder, Thomas E (DOA); Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Schwartz, Guy DOA s onsored Subject: RE: H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000) R-06 (PTD#1981270) 4- Year Compliance Testing Postponing MITs until completion of GC2 turnaround and wells H-09, M-14, R-02, and R-06 are put back on injection (and stabilized) is acceptable. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 .z~~.~'L~t~~ ~ ~ ~ ~ k `` ~ ~ ~ ~ ~# Anchorage, AK 99501 907-793-1236 From: Roschinger, Torin T. [mailto:Torin.Roschinger@bp.com] Sent: Monday, June 15, 2009 3:47 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000), R-06 (PTD#1981270) 4-Year Compliance Testing Jim, The following water injectors H-09 (PTD#1800640), M-14 (PTD#1801090), R-02 (PTD#1781000), and R-06 (PTD#1981270) are due for their 4-year regulatory compliance testing this month. However, because the GC2 turn-around will continue until July 7th the injectors will remain shut-in. Preferably, we would like to wart until GC2 is operating and the injectors are back online and stabilized rather than testing them shut-in. Please let us know if postponing the 4-year tests until after GC2 turn-around is acceptable. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 6/16/2009 MEMORANDUM ) State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg. 'Rtf-tit? ì /26/0-;- P.I. SupervIsor ( ( DATE: Wednesday, June 22,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA IrON (ALASKA) INC R-02 PRUDHOE BAY UNIT R-02 t 7 PJ'~/O\Ð FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: I P.I. Suprv....1BJ2- 7 Ujoç Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT R-02 Insp Num: rnitJCr050622043652 Rei Insp Num: API Well Number: 50-029-20354-00-00 Permit Number: 178-100-0 Inspector Name: John Crisp Inspection Date: 6/19/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R-02 Type Inj. w TVD 8099 IA 540 2500 2360 2350 P.T. 1781000 TypeTest SPI Test psi 2024.75 OA 10 10 10 10 Interval 4YRISI P/F P Tubing 1200 1200 1200 1200 Notes: 13.5 BBL's pumped to attain test pressure. No problems witnessed. SCANNEI) AUG 0 9 2005 Wednesday, June 22,2005 Page I of I STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Repair Well 0 PluQ Perforations IX] Pull TubingO Perforate New Pool 0 Operation Shutdown 0 Perforate 0 4. Current Well Class: Stimulate D OtherO WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 178-1000 Name: BP Exploration (Alaska), Inc. Development 0 ExPloratoryD Service ŒI 6. API Number 50-029-20354-00-00 Total Depth measured 10303 feet true vertical 9461.7 feet Effective Depth measured 9448 feet true vertical 8711.5 feet 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.00 8. Property Designation: ADL-0028279 11. Present Well Condition Summary: Casing Conductor Liner Production Surface Length 80 1487 9271 2591 Perforation depth: Measured depth: 9364 - 9404 Stratigraphic 0 9. Well Name and Number: R-02 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Plugs (measured) None Junk (measured) 9925 Size 20" 91.5# H-40 7" 29# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 38 118 38.0 118.0 1490 470 8815 - 10302 8162.4 - 9460.8 8160 7020 36 - 9307 36.0 - 8588.0 6870 4760 37 - 2628 37.0 - 2627.9 4930 2670 True vertical depth: 8637.99 - 8672.99 Tubing ( size. grade. and measured depth): 7" 26# L-80 5-1/2" 17# L-80 4-1/2" 12.6# L-80 @ 34 @ 2980 @ 8741 2980 8741 8876 Packers & SSSV (type & measured depth): 5-1/2" Baker 3-H BOT Packer @ 8741 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Oil-Bbl 0 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure 850 1380 0 0 -450 -1176 250 250 0 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil 0 GasD DevelopmentD Service ŒJ WAG D GINJD WINJ[! WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-032 Daily Report of Well Operations! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Garry Catron Garry Catron ki j~- Signature Form 10-404 Revised 4/2004 Title Production Technical Assistant CIVk-~ Phone 564-4657 Date 8/6/04 ORIGINAL RtDASBfl AUG 1 J 1~~' R-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY OS/27/04 Sand plug set @ 9580'-9788' OS/28/04 Sand plug set @ 9405'-9580'. Lay in cement cap. 06/04/04 ***** WELL SHUT IN PRIOR TO ARRIVAL ***** ( POST SANDBACK) DRIFT TO TO W/2.80 CENT & TEL. LOC TT @ 8845'SLM, ELM = 8878. CF = 33'. TAG TO @ 9372'SLM OR 9405' CORRECTED. TOP SET OF PERFS, 40' OPEN. SBHPS W/DUAL PETREDAT GAUGES. PETREDAT HAS ALL STATIC DATA *****LEFT WELL SHUT IN ***** BBLS 290 96 184 29 18 1 618 FLUIDS PUMPED 1 % KCL Diesel 50/50 Methonal Fresh Water Carbolite Slurry and Gel Class G Cement TOTAL Page 1 ~8' lREE= 6" MCEVOY WELLH~D = MCEVOY ACTIJA TOR = OllS KB. ELEV = 54.97' BF. 8..EV = 21.09' KOP = 3300' Wax Angle = 32 "@ 8500' I):¡tum MD = 9612' I):¡lumlVD= 8800'SS 113-3/8" CSG, 72#, L-80. ID = 12.347H I7"TBG, 26#, L-80. .0383 bpf, D = 6.276" H ITOPOF 5-1/2" TBG H 2628' 2980' 2980' Minimum ID = 3.725" @ 8833' 4-112" OTIS XN NIPPLE 15-1/2" TBG, 17#, L-80. .0232 bpf, ID = 4.892" l-i 8741' ITOPOF7" LNR 1--1 8815' 4-1/2"TBG. 12.6#. L-80, .0152 bpf. ID= 3.958" 1-1 8876' 19-5/8" CSG. 47#. L-80, ID = 8.681" l-i 9307' ÆRFORA 1l0N SUMMA. RY REF LOG: SWS-BHCS ON 07102/79 ANGLEA TTOPPffiF: 29 @ 9364' Note: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 3-3/8" 4 9364 - 9404 0 10103/89 3-3/8" 4 9510 - 9520 S OS/28/04 3-3/8" 4 9530 - 9580 S 05/28/04 3-3/8" 4 9590 - 9615 S 05/28/04 3-3/8" 1 9615 - 9636 S 07/14/94 3-3/8" 1/2 9676 - 9687 S 07/14/94 3-3/8" 1/2 9700 - 9710 S 07/14/94 3-3/8" 4 9745 - 9788 S 07/14/94 1 PBTD I~ 10225' 1 1 7" LNR. 29#, L-80, .0371 bp[, D = 6.184" 1-1 10302' I DA TE REV BY COMMENTS 07/08/79 ORIGINAL COMPLETION 0~1W83 RWO 11/26/01 RN/TP CORRECllONS 05/17/04 KSB/KAK CORRECllONS 07108/04 PJP/KAK CORRECllONS DATE REV BY R-02 L I I [ ~ - I .. j ë -~ COMMENTS I SAFETY NOTES ~ 1 1 2980' H 7" X 5-1/'2:' XO 1 2992' 1~5-1/2" CAMCO SSSV LANDING NIP, ID = 4.562" 1 ST MD 8 3147 7 5096 6 6572 5 7637 4 8225 3 8362 2 8460 1 8593 GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH 3044 7 OTIS OJ RA 4881 28 OTIS OJ RA 6202 29 OTIS OJ RA 71 04 31 OTIS OJ RA 7585 32 OTIS OJ RA 7754 32 OTIS OJ RA 7839 32 OTIS OJ RA 7924 32 OTIS OJ RA PORT Dð. TE 07/13/84 0711 3184 07113184 07113/84 04/18/83 04/18183 07113/84 07113/84 8659' 1-15-1/2" BKR L SLIDING SLV. 10 = 4.313" I 8717 I-ITBG S~LASSY 1 8741' 1~9 5/8" X 5-1/2" BOT 3H A<R. ID = 4.75" 1 8741' 1-i5-1/2" X 4-1/2" XO 1 8792' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 8833' 1-14-112" OTIS XN NP, ID = 3.725" I 1-i4-1/2" TBG TAIL, ID = 3.958" 1 l-i ELMDTTLOGGED 12/15/891 8876' 8878' 9405' l-i TOP OF CEMENT 1 9620' 1-1 TOPOFCEMENT 1 9653' 1-1 MARKER JOINT 1 9925' l-i FISH - 3" BKR IBP 1 PRUDHOE BAY UNIT WELL: R-02 PffiMIT r-.b: 1781000 API r-.b: 50-029-20354-00 SEe 32, T12N, R13E BP Exploration (Alas ka) \¡-..itA-- L' '-t-l </..-i../ (,1 c..t STATE OF ALASKA 2/4-(Cf-- ALASKA OIL AND GAS CONSERVATION COMMISSIO~QJ:; tc E APPLICATION FOR SUNDRY APPROv~' EIV '0 20 AAC 25.280 FEB 0 3 2004 1. Type of Request: D Suspend D Operation Shutdown D PerforateD Alaska OW&~dS:ton~rßummtggioA11 D Abandon Alter Casin~ D Repair Well D Plu~ Perforations 00 StimulateD Time Extens~nEHorage OtherD Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 178-1000/' BP Exploration (Alaska), Inc. Development D Exploratory D StratigraphicD Service Œ1 9. Well Name and Number: R-02 /' 10. Field/Pool(s): Prudhoe Ba Field / Prudhoe Oil Pool / PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9461.7 10225 9337.9 Size MD TVD 6. API Number / 50-029-20354-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.00 KB 8. Property Designation: ADL-0028279 3. Address: 11. Total Depth MD (ft): 10303 Casing Length Plugs (md): None Burst Junk (md): 9925 Collapse Conductor Liner Production Surface Perforation Depth MD (ft): 9364 - 9404 9510 - 9520 9530 - 9576 9576 - 9580 9590 - 9612 9612 - 9615 9615 - 9621 Packers and SSSV Type: 5-1/2" Baker 3-H BOT Packer 80 1487 9271 2591 to bottom to bottom 20" 91.5# H-40 38 118 38.0 118.0 1490 470 7" 29# L-80 8815 10302 8162.4 9460.8 8160 7020 9-5/8" 47# L-80 36 9307 36.0 8588.0 6870 4760 13-3/8" 72# L-80 37 2628 37.0 2627.9 4930 2670 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8638 8673.0 4.5 " 12.6 # L-80 8741 8876 8766 8774.6 5.5 " 17 # L-80 2980 8741 8783 8823.8 7 " 26 # L-80 34 2980 8824 8827.3 8836 8855.4 8855 8858.0 8858 8863.3 Packers and SSSV MD (ft): 8741 12. Attachments: Description Summary of Proposal D Detailed Operations Program ŒI BOP Sketch D 13. Well Class after proposed work: Exploratory D DevelopmentD Service ŒJ 14. Estimated Date for Commencin 0 eration: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasO WAG D GINJD PluggedO AbandonedD WINJŒ WDSPLD Prepared by Garry Catron 564-4657. February 15, 2004 Contact Katrina Cooper Other: Title Phone Commission Use Onl Petroleum Engineer 564-4212 1/28/04 Printed Name Signature Conditions of approval: Notify Commission s Plug Integrity ~ Sundry Number: -50 "1- CJ,3.:::J- Mechanciallntegrity Test D Location Clearance D Approved by: BY ORDER OF THE COMMISSION Date: Form 10-403 ~N~~~:3 FEB 1 32004 fEB 0 \i) 1- SUBMIT IN DUPLICATE bp ... ,~t.'ífI. -.....~ ~.~ ~4Þ.:- --:....- "'k~ F~" . I'.~I\" ". To: Doug Cismoski/J ohn Smart GPB Well Operations Team Leaders January 23, 2004 From: Paul Bartel Trina Cooper Wells Engineer R Pad Engineer Est. Cost: $~ Est. lOR: 400 Subject: R-02 Sandback and Cement Cap PBL WPROO2 Please recomplete R-02 as per the attached program. 1. 0 Pump SSG treatment. 2. S Pull SSSV. Drift as deep as possible. 3. C Sand back and Cap with 1 bbl cement to -9433'. 4. S Tag and POP. Current Status: Max Deviation: Min.ID: Last tag: Last Downhole Ops: Latest H2S value: wac 24 hrs. /' Injecting water at 3500 bwpd at 500 WHIP / 32° at 8500' M D 3.725" in 4-1/2" XN nipple at 8833' MD 9607' MD (4/17/95) C/O ISSSV (12/12/01) NA (Injector) R-02 is currently a Sag and Ivishak injector. Historically little to no injection has gone into the Sag. The Ivishak injection is no longer needed; however, Sag injection is /' needed to support the new Sag well R-31 A. This program is requested to convert this well to a Sag only injector. If there are any questions contact information is below. Name Title Work Home Cell Paul Bartel Wells Group EnQineer 564-5402 696-1682 240-8036 Trina Cooper R Pad Engineer 564-4212 279-2667 230-4212 Dan Babcock Lead Waterflood PE 564-5735 746-0274 250-1466 cc watt: Well File Slope Distribution R-02 SandbacklCement Cap Program Prepared By: Paul Bartel Phone#: 564-5402(w), 696-1682(h), 240-8036 (c) JOB PLANNING DETAILS: Perfs: 9364' -9404' , 9510-9520', 9530' -9580', 9590' -9615', 9615' -9636', plus more intervals below cement, Current Top of Cement at 9620' Perf Deviation: 29° Gas Lift Design: Dummies TD Tag History: 9607' with Atlas full bore STP tool (4/17/95). Displacement bbls: 268 bbls (tubing = 250, liner to top perf = 18) Static: Current estimate = 3200 psi. Old static = 3703 psi, 148°F (7/13/90) PREP 'YORK: 1. Pump SBG Treatment as per SOP. Freeze protect the flowline 2. RU SL and drift with TEL to PBTD. CT OPERATIONS: 3. RU CT. MU (pigs ear) shear nozzle (2.62" aD, 7/8" aluminum ball, 6 brass pins for a 2500 psi shear setting). 4. Perform a surface test with the shear nozzle. Load an open cell foam pig followed by the ball. Displace to the nozzle, slowing a few barrels prior to seating the ball. Note the displacement volume and final shear pressure. Recover the ball and redress the nozzle. 5. RIH and tag PBTD for depth control. Beware of a soft bottom. Make multiple passes across the perfs at max pump rate as an attempt to clean the liner. Take returns to the perfs. 6. Sand back with 20/40 carbolite to 9460' +/- 20'. The theoretical volume based on a PBTD of 9600' (bulk density = 13.3 ppg) is -2900#. Carbolite is recommended due to improved settling at higher hole angles. Note that the frac gradient in this mature injector is -0.5 psi/ft (-450 psi WHP) Multiple batches are recommended for accurate sand placement. Take returns while laying in the sand to minimize losses to the formation. Pump at a rate sufficient to prevent free-fall. Allow sufficient settling time between stages. SI the choke to tag. Please note the actual volume of carbolite used in the WSR summary. 2of3 7. Cap with 1.0 bbl of cement to -9433' +/- 10' (Class G with 4 hour thickening time @ 2000P BHT.). Use the foam pigs/shear nozzle procedure to insure precise measurement and placement: /' . Place the nozzle 5' above the sand top. Close in the reel and flood the surface lines to the reel valve with good quality cement. Open the reel valve. Place an open cell foam pig then pump 1.0 bbl of cement using the micro motion meter and displacement tank strapping to measure the volume accurately. Place a second foam pig and ball to shear the nozzle behind the cement. Close the reel valve and flood the surface lines back to water. Open the reel valve and displace the cement and ball to the nozzle. Slow to 1 BPM @ 4 bbls prior to the ball hitting the nozzle. When the ball seats, slowly pull to 10' above the calculated top of the cement. Wait 10 minutes for any cement to settle. Shear the nozzle. . . . . . . . . . 8. POOH, taking care not to underbalance the well. RDMO. 9. WOC 24 hours and tag the plug with slickline. / 10. Return to injection. 3 of 3 1REE = 6" MCEVOY WELLH~D = MCEV OY ACTUA TOR = OllS KB. ELEV = 54.97' BF. B..EV = 21.09' KOP= 3300' rv'ax Angle = 32 @ 8500' Datum tv{) = 9612' Datum lV D = 8800' SS R-02 I SAFETY NOlES 13-3/8" CSG, 72#, L-80, ID = 12.347 TOP OF 5-1/2" TBG Minimum ID = 3.725" @ 8833' 4-112" OTIS XN NIPPLE 15-1/2" TBG, 17#, L-80, .0232 bpf, ID= 4.892" 1-1 8741' ITOPOF 7" LNR l-i 8815' 4-1/2"TBG, 12.6#, L-80, .0152bpf,ID= 3.958" -1 8876' 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9307' PERFORA 1l0N Sllv1tv1A RY REF LOG: SW8-BHCS ON 07/02f79 ANGLEA TTOP PERF: 29 @ 9364' Note: Refer to Production œ for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 9364-9404 0 10/03/89 3-3/8" 4 9510-9520 0 10/11/89 3-3/8" 4 9530-9580 0 10/11/89 3-3/8" 4 9590-9615 0 10/11/89 3-3/8" 1 9615-9636 0 12/14/89 3-3/8" 1/2 9676-9687 0 12/14/89 3-3/8" 1/2 9700-9710 0 12/14/89 3-3/8" 4 9745-9788 0 10/11/89 17" LNR, 29#, L-80, .0371 bpf, D = 6.184" I 10302' e GAS LIFT MANDRELS TV D ŒV TYPE V LV LATCH 3044 7 OTIS [N RA 4881 28 OTIS [N RA 6202 29 OTIS [N RA 7104 31 OTIS [N RA 7585 32 OTIS [N RA 7754 32 OTIS [N RA 7839 32 OTIS [N RA 7924 32 OTIS [N RA PORT Dl\ lE 07113/84 07113/84 07/13/84 07113/84 04118/83 04/18/83 07113/84 07/13/84 ST MD 8 3147 7 5096 6 6572 5 7637 4 8225 3 8362 2 8460 1 8593 5-1/2" BKR L SLIDING SLV, ID = 4.313" 95/8" X 5-1/2" BOT 3H R<R,ID = 4.75" -15-1/2" X 4-1/2" XO 1 -i4-1/2" OTIS X NIP, ID = 3.813" 1 -14-1/2" OTIS XN NP, ID = 3.725" I 4-1/2" TBG TAIL,ID = 3.958" l-i ELMDTTLOGGED 12/15/891 9620' TOP OF CEMENT -1 FISH - 3" BKR IBP 1 Dl\lE REV BY COMrvENTS DATE REV BY COMMENTS 07/08/79 ORlGINl\L COMR..ETlON 04/18/83 RWO SIS-SL T CONVERlED TO CANV AS 03/14/01 SIS-tv{) FINl\L 11/26/01 RN/W CORRECllONS PRUDI-OE BAY UNIT WELL: R-02 PERMT f\b: 178-1000 API f\b: 50-029-20354-00 SEe 32, T12N, R13E 8P Exploration (Alaska) LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF ECC No. Run # 1 607.04 Run # 1 2311.03 Run # 1 5831.04 Run # 1 5938.05 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Flease sign and ~eturn Petrotechnical Data Cente~ BP Exploration (Alaska) Ina 900 East Benson Boulevard ~e6et~ed ~Z' - ' --' PR:' 1995 ....... AnchoraBe ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 15 June 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL R-02 D=17 (14-23-11-13) J-06 (04-11-13) # DESCRIPTION /1 PLS INJPROF.FINAL BL 1 PLS INJPROF.RF SEPIA /~1 PLS PP/GE FINAL BL 1 PLS PP/GE RF SEPIA /1 PLS FINAL BL 1 PLS FINAL RF SEPIA ECC No. / Run # 1 607.03 Run # 1 Run # 1 6036.01 Run # 1 Run # 1 6031.03 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date STATE OF ALASKA &~ .KA OIL AND GAS CONSERVATION COMMI~_...,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate.__ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection weft At effective depth 2494' NSL, 5678' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, SEC. 31, T12N, R13E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 54.97 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-02i (33-31-12-13) PBU 9. Permit number/approval number 78-100 / 10. APl number 50- 029-20354 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10303 feet 9461 feet 9920 feet 9125 feet Plugs (measured) Junk (measured) intl. bridge plug fish on bottom at 9920' CTM (07/90) Length Size Cemented Measured depth True vertical depth .. BKB 110 20X30 651 c.f. 144 144 2594 13 3/8 5348 c. f. 2628 2628 9273 9 5/8 1418 c.f. 9307 8587 measured .. 1487 7 9364'-9404' (Sag R) true vertical 430 c.f. 8815-10302 8162-9460 9510'-9520',9530'-9580',9590'-9636',9676-9687', 9700'-9710', 9745'-9788' (Ivishak) Sqzd. off: 9662'-9676', 9697'-9730' subsea 8583'-8634' (Sag R) 8710'-8955' (six Ivishak intervals) Tubing (size, grade, and measured depth) 7" x 5 1/2" tapered string to 8741' with 4 1/2" tailpipe to 8876' Packers and SSSV (type and measured depth) 9 5/8" BO Tpacker at 8741'; 5 1/2" injection valve~j ~ ~ ~ i ~at 2992' ~.~ .~ 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure Anchorago 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 13718 Tubing Pressure 0 1572 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended__ Service water injection well 17. I hereby~ .~.' cf~rtify that,,,~the fo~ng is /~/~/" ~'true and correct to the best of my knowledge. Signed /{ ~~ ~. Title Senior Technical Assistant I Form 10-40'~, Ro~/06/15/88 SUBMIT IN DI~PLI(~ATE 01/05/92 WELL R-02i(33-31-12-13) ACID Stimulation Operation Performed a HCL using the following fluids below: Summary: Run in hole w/coil to 9807' displace hole w/240 bbl slick produced water-spot acid across perf. Pull coil above perf. Close well head valve put acid away 2.0 bpm w/3800 psi down coil 250 psi max on wellhead while pumping acid away used 72 bbl 15% hcl w/10% xylene flushed w/slick produced water-freeze. FLUIDS PUMPED; 35 BBLS METHANOL 274 BBLS SLICK PRODUCED WATER 72 BBLS ACID fjh 5/20/93 BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/20/92 T% 83191 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. PITS 12/31/91 ~1 INJ 01/02/92 ~1 LEA/{ DET 01/04/92 ~1 LEAK DET 01/01/92 ~1 LEAK DET 01/01/92 ~1 INJ 01/07/92 ~1 PROD-F 01/01/92 #1 GAS ENTRY LOG 12/31/91 5 " 8970.00- 9500.00 CAMCO 5 " 9300.00- 9850.00 CAMCO 5 " 9410.00- 9914.00 CAMCO 5 " 11700.00-12600.00 CAMCO 2/5" 8450.00- 9850.00 CAMCO 5 " 10580.00-10835.00 CAMCO 5 " 10200.00-10520.00 CAMCO 5 " 9700.00-10065.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED JAN 2 9 1992 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA AI_~,.,,~, OIL AND GAS CONSERVATION COMMISSI(..N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate X Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection well At effective depth 2494' NSL, 5678' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, SEC. 31, T12N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5. Type of Well: Development~ Exploratory Stratigraphic s.rvic 6. Datum elevation (DF or KB) KBE-- 54.97 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-02 (33-31-12-13) PBU 9. Permit number/approval number 78-100/9-745 10. APl number 50- 029-20354 11. Field/Pool Prudhoe Oil Pool 10303feet Plugs (measured) 9461feet 9920feet 9125f eet Junk (measured) intl. bridge plug fish on bottom at 9920' CTM (07/90) Length Size Cemented Measured depth True vertical depth - - BKB 110 20X30 651 c.f. 144 144 2594 13 3/8 5348 c.f. 2628 2628 9273 9 5/8 1418 c.f. 9307 8587 Tubing (size, grade, and measured depth) .. 1487 7 430 c.f. 8815-10302 8162-9460 measured 9364'-9404' (Sag R) 9510'-9520',9530'-9580',9590'-9636',9676-9687', 9700'-9710', 9745'-9788' (Ivishak) Sqzd. off: 9662'-9676', 9697'-9730' true vertical subsea 8583'-8634' (Sag R) 8710'-8955' (six Ivishak intervals) 7" x 5 1/2" tapered string to 8741' with 4 1/2" tailpipe to 8876' a ' ~ Packers and SSSV (type and measured depth) 95/8" BOTpackerat 8741';51/2" injection valve ~C ~ IV ~ 0 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure Oil 8: ~s Go~'~s. Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 2170O 470O Tubing Pressure 1380 1366 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service water injection well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ Title Supervisor Waterflood/Miscible Flood Form 10-404 Rev 06/15/88 ~' Date ::21/~7!(~ ! SUBMIT IN DUPLICATE WELL R-021 ~'33-31-12-13} PBU PROFILE MODIFICATION/ SAG FRAC OPERATIONS 9/12/89 9/24-10/1 10/3/89 Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. Performed perforation acid wash and cement squeeze. Resqueezed well three times. Rigged up Dresser Atlas and perforated the following Sag River Intervals using 3 3/8" carder guns at 4 spf: Reperf: 9364'- 9404' MD BKB 10/4/89 1 0/5/89 10/6-8 1 0/1 0/89 12/15/89 Set inflatable bridge plug at 9495' in preparation for Sag R. frac. Performed hydraulic fracture of Sag River perfs. Attempted to retrieve bridge plug; knocked downhole to 9925' CTM. Returned well to injection and tested. Rigged up Schlumberger and perforated the following Ivishak intervals using 3 3/8" carrier guns at 4 spf: Reperf: Reperf: Add perf: Reperf: Reperf: 9510' -9520' MD BKB 9530' -9576' MD BKB 9576' -9580' MD BKB 9590' -9615' MD BKB 9745' -9788' MD BKB Returned well to injection and tested. Reperforated the following Intervals using Schlumberger 3 3/8" carrier guns: 9615' - 9636' MD BKB @ 1 spf 9676'- 9687' MD BKB @ .5 spf 9700' - 9710' MD BKB @ .5 spf Returned to injection and tested. jam 1/18/90 TO: THRU: M E MO ~onnle ~C. $ Commissioner Sta' e of Alaska GAS CONSERVATION COMMISSION DATE: FILE NO: TELEPHONE NO: SUBJECT: December 20, 1990 jT.HH.i220.3 Wellhouse explosion & fire BPX PBU Pad k-2 Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum Inspector Tuesda~ Dec. 13, 1990: I found out there was a wei!house explosion at Bp~x'PBU pad-~i2' on 12/7/90. i checked on the wellhouse and took pictures with Lonnie Smith's acknowledgement (attached). The supervisor in field production would not tell me any details, his name was Me ll Pye. Saturda~ Dec. 15, ~990; i went to security and found out who to ta. ik to at the BOC. B~ Cardon, sa£ety supervisor ior BPX PBF. He gave me a copy of the loss control investigation report and a safety bulletin leaflet which is attached to the report. in su~r~_nary: I spent approximately a iull day to tinally get the information the commission wanted. I was told by Mr. Cardon that he had discussed the accident and the state regulations with Lonnie Smith. Attachment. 02-00lA (Rev. 6/89) 20/IUMEMO1.PM3 BP Exploration (Alaska) Inc. STATIC ELECTRICITY A FIELD OPERATOR, WHO WAS SWITCHING WELL R-2 FROM M.I. TO WATER INJECTION, WAS INJURED WHEN A STATIC DISCHARGE GENERATED BY HIS MOVEMENT IGNITED GAS THAT HAD BEEN BLED OFF IN THE WELLHOUSE. THIS IS A MIRROR OF TWO SIMILAR INCIDENTS THAT HAPPENED LAST YEAR AT ABOUT THIS SAME TIME. GAS THAT HAD ACCUMULATED IN ENCLOSED AREAS WAS IGNITED BY STATIC GENERATED FROM PERSONNEL MOVEMENT. AK 2607-1 (2/89) THIS IS A REMINDER TO USE METERS TO MONITOR FOR GAS ACCUMULATION, CAREFULLY PLAN AND IMPLEMENT ADEQUATE VENTILATION, AND VENT GAS AWAY FROM YOUR IMMEDIATE WORK SPACE. 90-08/12-9-90 LOWCONTROL INVESTIGATION REE11MiT PERSONAL IN,, NJURED'S NAME AGE SEX �RY P L 8rA SOCIAL SECURITY NUMBER OBJECT/EQUIPMENT/SUBSTANCE INFLICTING INJURY fflas 1. OCCUPATION (- 3�) PERSON WITH MOST CONTROL OVER OBJECT/EOUIPME T/SUBSTANCE V r0 4 ra ✓ PROPERTY DAMAGE NATURE OF DAM AGE ✓ r n1 PROPERTY DAMAGE 1, PROCESS SYSTEM (�� ) OBJECT/EQUIPMENT/SUBSTANCE INFLICTING INJURY W e D v e. Pcu /l?.T. Gal ESTIMATED COST ACTUAL COST PERSON WITH MOST CONTROL OVER OBJECT/EQUIPMENT/SUBSTANCE ❑ ANCHORAGE ❑ DRILLING 2. CO'yMPnANY ( 21 ) ( (O ) 3. DEPPAR1T�M" DATE OF OCCURENCE TIME (2400) ❑ CONSTRUCTION OPERATIONS 1J i QENT rleCla Pted. 1 04:00 DATE OF REPORT 4. LOCATION/FACILITY (b/61 S. INJURY/OCCURRENCE ( ) 6. AGENT ( I lL- 7- 90 R-2- /I%r 0; a es EXPERIENCE/EQUIPMENT AGE ]. TYPE ( (p ) B. BODY PART/EQUIPMENT PART L,u ) ,CLASSIFIC!(-(ION {'�., ) , �r ; ,,d. l t✓t!! U-0 3 ^, , Ili - tC�v/7/Oa��� sio� GS 10. SUBSTANDARD ACTION A (/ y ) U c. SAiC AISpX./ 11. SUBSTANDARD CONDITION A ( ) 12. BASIC CAUSES A ( l S) tN ADA44A't ace4swwm sp4cMwa/P B(/5)a/-,W- B( ) B( ) C( ) C( ) C( ) PROBABILITY OF OCCURRENCE LOSSLRVERITY POTENTIAL ❑ FREQUENT (30 DAYS OR LESS) wp�- OR (LOST TIME INJURY AND/OR ABOVE $5000) ❑.,OCCASIONAL (30 DAYS TO 6 MONTHS) ®/SERIOUS (RECORDABLE INJURY ANDIOR $501 TO $5000) III SELDOM (1 YEAR OR MORE) ❑ MINOR (FIRST AID TREATMENT AND/OR LESS THAN $500) DESCRIPTION OF EVENT: ❑CHECK IF ATTACHED SUBMITTED Paul 13ee6C was e{rN iun R 2. Wren. MA-x +o PWT Pressure. Awi cooll heaA WJ s 2300 Psis 'prom fn T ka was "a-fl AAn -Por CC = %o iA/Crea-ce. Pre s re a" S fir PUr y ftmom -k overcome_ well heal Pr scut¢ lie, one.+ cl n. sn Rlft F± 1*0 ehook /,, wa< ;"Jai reach' 4t wcil head Vef, L..16w Ae Q,,J 4-kAf• i+ had Al -P Ae sf:// i.v tl k /i.ve. be C/os !i/a/ve A,.v6 Alas lea" Ale//4i�eeSe, eyf&, he fbue4eaA errf cia0r` he ere AW Q_ tOer.0 eF Slizr/iQ elecDkle iv erh1 • i LI YL1 f� Paf,;Aui/ p9d V L4 AlaS 00 e ! r e e OT SPECIFIC TAMSK B�E.INGPERFO MED ///✓. _ ON fI ea REMEDIAL ACTION PLAN: ❑CHECK IF ATTACHED SUBMITTED ITEM DATE TO COMPLETE RESPONSIBILITY l.s.fpf,mjm = Pow, versln.es Aatbw -2S'/F /2 -7-4Q 15�f1er dies zN d ILL/ cln s ^of F &jell h0vs¢ vio_ bleed Fie$P I 3i-Ita% c%esA,'% Riau.. rfirhd atla kind is disdlwmQ. 4CIJ Du Ora4r- I ODer-11;'t5 4R�iu6trl «w6xAL IN r s nue�s P /a - 9- 91l oloadw r7o,t/S A.vo it �das�i�szA) 5 i vsrr rdr7s- sJ' 6l6 /c/ %rlu6s Ti�ltie t/ 3-1- 9 / /JpEsPR7'/O /J LliVTiY COALS /AJG GX 6. SIGN ORES OF INVEST TORS j' 1nL REVIEW/APPROVAL q �)Q 1 IMME SU €R I. DATE NAME DEPARTMENT HEAD S �REPRESENTATIVE%v DATE NAME SAFETY MANAGER �?'"`*• DATE NAME SENIOR MANAGER ,.,,,..•,,, FOR NUMBERED BLOCKS REFER TO CODE SHEET IN DOP A-1-S FOR MOST ACCURATE DESCRIPTION(S) AND ENTER CORRESPONDING NUMBER(S) IN PARENTHESIS. AK 2583 5 (1/90) 1y BP E~PLORATION BP Exploration (Alaska! Inc. 900 East Benson Bouievarcl PO. Box 196612 Anct~orage. Alast<a 99519-6612 (907) 561-5111 To: Distribution Date: 01/22/g0 Transmittal: 80808 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material questions, please contact BP Well Records C-02 TEMP~i 01/03/90 #1 C-05 TEMP~ ~ 01/03/90 #1 F-22 RR~OD-F~ 01/05/90 G-17 PROD// 01/04/90 #1 M-Il ~R~ 01/04/90 #1 Q-05 TEMP~ 01/08/90-- #I R-02 INJ ~ _ 01/01/g0 #1 S-15 CCL&~. 01/02/90 #1 W-11 S~L~ZER~ 01/04/90 #1 Z-02 PRODJ 01/05/90 #1 listed below. If you at (907) 564-4445. 9800-10194 Camco 11500-11843 Camco 9550-9840 Camco 11000-11299 Camco 8100-9203 Camco 10100-10421 Camco 9250-9913 Camco 10250-11650 Camco 12500-13562 Camco 96aD-9800 Camco have 5" 5" 5" 5" 5" 5" 5" 5" any Distribution: .ARCO CHEVRON EXXON GEOSCIE~CES MOBIL PHILLIPS RES~RVOTR_ ~ ALA~K~ -A-RL"~IVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 12/26/89 Transmittal: 80712 From: Information Control Well Records LR2-1 Subject: Enclosed is your questions, please BP CASED HOLE FINAL ,LOGS copy of the' materia,,1:. !~iisted below. If contact BP well R'~cori~s':ht (907) 564-4445. : R-02i COMP U-~7 CALIPER ,, 12/15/89 #1 8630-9887 12/16/89 #1 9520-9756 you Sch Sch have 5~ any Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR BP EXPLORATION BP Exploration (Alaska) Inc. 900 Eas~ Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 11/03/89 Transmittal: 80554 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-16 PROD-F/TEMP 10/19/89 81 9100-9345 Camco R-02 INJ-F 10/22/89 81 9250-9908 Camco 5' R-07 INJ-F 10/22/89 81 9600-10374 Camco 5" X-09 TEMP 10/20/89 ~1 1990-12260 Camco 2'/5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 10/18/89 Transmittal: 80495 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-16 Perf 10/12/89 #1 9000-9353 Sch 5" R-02i Perf 10/10/89 81 9400-9899 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR ARCHIVES Alaska Oil & Gas Cons. Anchorage BP EXPLORATION To: Distribution BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: 10/12/89 Transmittal: 80479 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. F-21A PFC 10/06/89 ~1 11330-11614 Atlas 5" E-08 CCL 10/10/89 91 9810-10150 Atlas 5" R-02 CCL. 10/03/89 ~1 8613-9514 Atlas 5' Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR ........... <'s SE oF ARCHIVES BP EXPLORATION BP Exolo~tion (Alaska) Inc. 900 East ,,~enson_ Boulevard RO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 10/11/89 Transmittal: 80476 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907)~564-4445. C-12 PROD-F 09/28/89 ~1 1150~-11960 Camco F-16 PROD-F 10/01/89 91 91T~-9539 Camco 5' R-02 ' PITS/FM/TEMP 09/30/89 91 9190-9920 Camco 5' S-04 INJ 09/27/89 ~t 10290-11079 Camco W-26 PROD-F 09/26/89 ~I 11500-11810 Camco 5~ X-01 POST FRAC TEMP 09/27/89 ~1 8700-8994 Camco 5' Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS STATE OF ALASKA> ARC~IVES e CO lss/O : x BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 10/05/89 Transmittal: 80453 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGs Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. R-02 INJ 09/22/89 91 9200-9900 Camco 5" R-07 INJ/TEMP 09/20/89 ~1 9650-10399 Camco S-02~ GAS LIFT 09/21/89 #1 100-11127 Camco 5" U-1O_ INJ 09/23/89 ~1 9650-10060 Camco 5" W-09 PROD-F 09/22/89 ~1 14200-15306 Camco X-04 GAS LIFT 08/23/89 91 2500-10053 Camco 1"/5" X-ll INJ 09/20/89 91 9050-9450 Camco 5" X-i~ INJ 09/20/89 #1 9050-9450 Camco 5" X-19 GAS LIFT 09/21/89 #1 100-10027 Camco Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR ARCHIVES & Gas Cons. Commissioi} Anchorage BP EXPLORATION August 21, 1989 ORIGINAL BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, Manager Production Engineering JAM: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED AUG 2 1989 _A/aska 0ii & Gas Cons. C0mmiss[01/ Anchorago STATE OF ALASKA '-- ..ASKA OIL AND GAS CONSERVATION OOMk ,1ON 0 R APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing ~ Repair well ~ Plugging .__ Time extension ~ Stimulate X Change approved program Pull tubing __ Variance Perforate~ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection weft At effective depth 2567' NSL, 1628' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, SEC. 31, T12N, R13E, UPM 12. Present well condition summary Total depth: measured 10303 feet true vertical 9461 feet Effective depth: measured 10116 feet true vertical 9296 feet 5. Type of Well: Development x Exploratory __ Stratigraphic ~ Service Plugs (measured) Datum elevation (DF or KB) KBE = 54.97 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number R-02 (33-31-12-13) PBU 9. Permit number 78-100 10. APl number 50- 029-20354 11. Field/Pool Prudhoe Oil Pool Junk (measured) fill at 10116'MD (05/88) Casing Length Size Structural -- Conductor 110 20X30 S u rf ace 2594 13 3/8 Intermediate 9273 9 5/8 Production -- Liner 1487 7 Perforation depth: measured 9364'-9404' (Sag R) Cemented Measured depth True vertical depth BKB 651 c.f. 144 144 5348 c.f. 2628 2628 1418 c.f. 9307 8587 430 c.f. 8815-10302 8162-9460 9510'-9520',9530'-9576',9590'-9636',9670'-9687',9745'-9788' ( Ivish ak) true vertical subsea 8583'-8618' (SagR) 8710'-8955' (five Ivishak intervals) Tubing (size, grade, and measured depth) 7" x 5 1/2" tapered string to 8741' with 4 1/2" tailpipe to 8876' Sqzd. off: 9662'-9670' 9697'-9730' RECEIVEDI Alaska Oil & Gas Cons. C0mml Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8741'; 5 1/2" injection valve at 2992' /~cti0rag{l~' ' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch × 14. Estimated date for commencing operation August/September 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Suspended Service water injection well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed//~ ~,~, ~ Title Mana~terProduction En~linoerin~l FOR COMMISSION USE ONLY Cond of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subl~~[[al~l~lCEj)JiB~l 10- LONNIE C. SMITH Approved by order of the Commission Dater'S' ~0~ ! J Approval No. 9 "" ~?~',~--- Approved Copy Returned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STATE SUN DRY NOTICE Well R-021 Well R-021 needs a cement squeeze with coiled tubing to shut off a water channel. The program involves squeezing all perforations followed by a Fracture Stimulation of the Sag. River and reperforation, A summary of the planned procedure is as follows: 1. MIRU coiled tubing unit. 2. Acid wash the perforations, 3. Liquid pack the well and cool the reservoir. 4. Cement squeeze all perforations up to 3500 psi differential. 5, Reverse out cement after holding squeeze for 30 to 40 minutes. 6, Leave well with WHP sufficient to maintain 500 to 1000 psi positive differential at perforations for WOC period. 7. Pressure test well 8, Resqueeze well if it fails the pressure test. 9. Perforate the Sag R. @ 9364'-9428' (BHCS 7/2/79) 10, Fracture stimulate the Sag R. 11. Perforate the Ivashak at: 9510'-9520' 9530'-9580' 9590-9615' 9615'-9636' 9676'-9687' 9700'-9710' 9745'-9788' Ref BHCS 7/2/79 10. Put well on injection. PRH.8/17/89 Coflcd Tubfn~ t3iorv-Out-Prcvcntkrs Coiled Tubing P a c k-O f? 7 Blind Rams ~ · _~ '[ Cutter Rams '(-"~2" Chk:ksan (KIll Line) (---- .I ~ Sffps ~ .j _-~-~r_ ' J=~ Pipe Rams urnp-ln Sub (Clrcula te/R e turns W ell Head Swab Valve TO: HOUSTON ARCO CHEVRON E~XON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES INOEXED , STANDARD AL ASKA PRODUCTION 11-29-88 Date: 79592 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge recelpt by signing a copy of thls let-let and returning It to this offlce: J-19 Static Gradient 10-30-88 Camco R-02 Static Gradient 11-14-88 Camco U-09 Static Gradient 11-11-88 Camco U-06 Static Gradient 11-18-88 Camco S-01 Static Gradient 11-09-88 Camco S-07 Static Gradient 11-10-88 Camco A-10 Static Gradient 11-17-88 Camco U-02 Static Gradient~ 11-18-88 Camco H-12 Static Gradient 11-16-88 Camco H-23 Flowing Gradient 11-19-88 Camco N-07 Static Gradient 11-11-88 Camco S-il Static Gradient 11-12-88 Camco Replace J-09 with J-19 * Transmittal #79547 Dated 11-15-88 Static Gradient J-09 wrong Number Please Destroy. .~ u~,, of ,he o*'~a;,'.ol S,om:lo*d OI founded m Cle.elond. C)~;o. ,n 1870 Shirley R. McCurry I NFORI~b~T I ON CONTROL Wol I Records LR2-1 Slanda~'d Alaska Production Company, 900 Eo$! B,en,,,on ~oulevord p.O. ~. 19~12 (~73 564-511 I INDEXED HOUSTON TO: ARCO CHEVRON E~ON TEXACO MOBIL STANDARD ALASKA PRODUCTION Date: 11-29-88 TI: 79590 PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it to this office: '~t-23 .R-02 'M-15 Gas Lift Survey 11-19-88 #1 100-9157 Camco 2" Temp 11-14-88 #1 sUrface-2500 Camco 5" Leak Det. Prod-F 11-19-88 #1 100-9526 Camco 2"/5" Received , Commissio~ !~i~1~!% ~o![c oiii~rry Production Compe 900 Eos! flenson Bc 3rd P.O- Box 196612 Anchoroge, Aloska 99.519-66 (907) 564-5 I DALLAS ARCO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION D~te: 06/27/88 TI: 79013 The following material Is being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning it to thls office: R-2 CCL/Perf 05/21/88 #1 8650-9500 GO 5" Gas Cons. commission Date A unil Of the or,g;nol $,ondo,d C),l ComponF Founded ,n Clevelond. Oh,o. in 1810. Jennifer Dietz I NFORMAT I ON CONTROL Wel I Records LR2-1 Slanda~d Ala~.ka ~. P~odu¢l;on Company 900 East Benson Boulevov~ P.O. Boa 196612 Anchorage. Alaska 99519-66 1~7) ~64-~1 II DALLAS INDEXED =,, ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date: 06/03/88 TO: MO B IL TI: 78905 PHILLIPS GEOSCIENCES ARCHIVES .'t REFERENCE:'. SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith.. Please acknowledge receipt by signing a copy of this letter and returning It to this office: :. A-25 Production Profile 05/22/88 #1 12300-12682 Camco B-25 " " 05/13/88 #1 8950-10563 " C-30 Flowmeter/Temp 05/11/88 #1 9300-9700 Camco C-31 Flowmeter/Temp ~05/12/88 #1 11450-11659 Camco C-34 Flowmeter/Temp 05/12/88 #1 9360-9605 Camco D-16 Flowmeter/Temp 05/24/88 #1 9650-10000 Camco G-2 Spinner/Temp 05/18/88 #1 9900-10225 Camco M-10 Leak Detection 05/21/88 #1 Surf-6150 Camco R-2 Spinner (Fullbore) 05/24/88 #1 9400-9641 Sch R-5 Leak Detection 05/21/88 #1 10-8600 Camco R-21 PITS 05/19/88 #1 5500-10514 Camco 5II Ii 5" 5II 5'I 511 5I1 2II 2II 5" Alask0~- ' .... r. nmmission & Gas uu-o .... - ,~ 'An~ho;a~le · J A un;t o! the o,;9;nol .~tondotd ~1 Com~ny ~ lounded i~ Cleeelond ~,o ~n 1870 Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 .% Standard Alaska I Production Company~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 June 1, 1988 Attention: Mr. C. V. Chatterton Well 'R-2 ' (33-31-12-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Operations, for the above-named well. subsequent report of perforating the well. Report of Sundry Well This contains our Yours very truly, r Waterflood & Miscible Flood BJP:JAM~ Enclosures (4) CC: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 R-2 Well File RECEIVED JUN 0 6 1988 Oil A Gas Cons. Commissim'~ ~chorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter casing [] Other [] " 2. Name of Operator Standard Alaska Production Company Address P. O. Box 196612, Alaska 99519-6612 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection well At effective depth 2607' NSI., 1658' WEL, SEC. 31, T12N, RI3E, UPM At total depth 2638' NS/_, 1681' WEL, SEC. 31, T12N, R13E, UPM · Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 S u rface 2594 Intermediate 9273 Production -- Liner 1487 Perforation depth: 5. Datum elevation (DF or KB) KBE = 54.97 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number R-02 (33-31-12-13) PBU 8. Approval number 8-118 9. APl number 5 0 - 029-20354 0. Pool Prudhoe Oil Pool 10303 feet 9461 feet 10121 feet 9389 feet Size Plugs (measured) Junk (measured) Cemented 20X30 651 c.f. 13 3/8 5348 c.f. 9 5/8 1418 c.f. Measured depth 144 2628 9307 7 430 c.f. 8815-10302 measu red 9364'-9404' (Sag R) ~ 9510'-9520',9530'-9576;9590'-9636',9670'-9687,,9745'.9788' (Ivishak) true vertical subsea 8583,-8618,(sa~/ R) 871o'-8955' (five Ivishak intervals) Tubing (size, grade and measured depth) 7"x 5 1/2"tapered string to 8741'with 4 1/2"tailpipe to 8876' True Vertical depth BKB 144 2628 8587 8162-9460 Sqzd. off: 9662;9670' 9697;9730' Packers and SSSV (type and measured depth) 2. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure · Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -- - 24300 -- -- - 17000 -- Tubing Pressure 620 1600 4. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 5, I hereby certify that the foregoing is true and correct to the best of my knowledge orm 10-404 Rev. 12-1-85 ~ Date Submit' in Duplicate Well R-2i (33-31-12-13) PBU Additional Perforating Operations The following Sag River interval was perforated May 21, 1988 using Gearhart 3 1/8" HSC guns at 4 spf: 9364' - 9404' MD BKB (8583' - 8618' TVDss) Depths are referenced to BHCS, 07/02/79. A lubricator was installed and tested to 3500 psi for all well work. The well was returned to water injection immediately following perforatin~ operations. 5/16/88 0800Z Stonclo~d P~oductlon C:'<'npa n y 900 [o~t P.O Bo. 196612 Ancho,oge. 19071 564-51 I I I NDE XED DALLAS ARCO CHEVRON E,~LXON TEXACO Date: 04/27/88 lO: MOBIL TI: 78759 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD AL AS~2/:, PPODUC REFERENCE: SAPC CASED HOLE FINAL LOGS The following material ls being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-16 ~ A-23 ~ B-12 Injection Profile 04/15/88 #1 9400-9850 Camco 5" " " 04/13/88 H1 10550-10850 Camco 5" Production Profile 04/10-11/88 #1 11200-11600 Camco 5" GR/CCL 04/15/88 #1 8650-9025 Sch 5" Spinner 07/18/83 #1 9090-9147 Camco 5" GR 04/13/88 H1 9600-10228 Camco 5" CBT 04/21/88 H1 8995-10156 Sch 5" Spinner/Temp/Tracer 04/17/88 #1 9400-9900 Sch 5" Production Log 04/18/88 H1 9000-9500 Sch 5" Injection Profile 04/15/88 #1 11200-11850 Camco 5" ~ ?' . Maska Oil & Gas Cons. Comm!ssion - AnchOmn?, Victoria Aldridge INgoat, t~l iON CONIRO{. Wol I Records LR2-I Standard Alaska Production Compar 900 East Benson BoA rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION April 26, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 R-2 Well File 3.~ A. Bra~ ' Manager Production Engineering A unit of the original Stondard Oil Company Founded in Cle,,elond Ohio in 1870 Operation performed: Operation shutdown [] Stimulate [] Plugging [] Alter casing [] Other [] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Perforate [] Pull tubing [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection well At effective depth 2607' NSL, 1658' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, SEC. 31, T12N, R13E, UPM 1. Present well condition summary Total depth: measured Effective depth: 10303 feet true vertical 9461 feet measured 10121 feet true vertical 9389 feet Length Size .- 110 20X30 2594 13 3/8 9273 9 5/8 .. 1487 measured Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) KBE = 54.97 AMSL feet 8. Unit or Property name Prudhoe Bay Unit ?. Well number R-02 (33-31-12-13) PBU 8. Approval number 8-259 9. APl number 5 0 - 029-20354 O. Pool Prudhoe Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Cemented Measured depth True Vertical depth BKB 651 c.f. 144 144 5348 c.f. 2628 2628 1418 cof. 9307 8587 7 430 c.f. 9510'-9520', 9530'-9576', 9590'-9636 9670'-9687; 9745'-9788' true vertical subsea 8710'8955' (five intervals) Tubing (size, grade and measured depth) 8815-10302 8162-9460 Squeezed off: 9662'-9670' 9697'-9730' 7" x 5 1/2" tapered string to 8741' with 4 1/2' tailpipe to 8876' Packers and SSSV (type and measured depth) 9 5/8' BO Tpacker at 8741 '; no SSS V in B VN at 2992' 2. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure , Prior to well operation Subsequent to operation Represer~ta, tiye Daily Ay~re, ge Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure .... 242OO -- 24300 Tubing Pressure 699 59O 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 5. I hereby certify that the foregoing is true and correct to the best of my knowledge · Form 10-404 Rev. 12~1-05 - ~/r Submit in Duplicate Well R-2 (33-31-12-13) PBU STIMULATION OPERATIONS A selective mud acid stimulation was perfozmed April 15, 1988, on the following perforated interval in water injection well R-2. 9745' - 9788' MD BKB An inflatable packer was set at 9737' MD to isolate the interval from the upper intervals. The packer was pulled following the treatment. Treatment fluids consisted of the following pumped via coiled tubing: 46.5 bbls. 15% HC1 93 bbls. 12% HC1 - 3% HF 94 bbls. 3% NH4C1 brine The treatment fluids were displaced to the perforations with 32 bbls. seawater overflush. The well was returned to injection and tested. jm 4/19/88 Stondo,d Alod~o P,odu(lion Compon- 900 [o',t B,.',,son Bo,d PO Bo, 196612 [907t S64 5 I I I INDEXED DAI.IAS ARCO CHEVRON E~XON TEXACO MOBIL PHILL~IPS GEOSC IENCES STANDARD AL ASP'*, PRODUC ~ I(]N Dote: 04/08/88 TO: TI: 78719 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is belng submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning it to this office: ~A-11 '~'~A-27 ""~A-34A A-34A ~B-2 ~C-4 ~C-9 "~G-7 ~H-25 K-la ~H-28 ~R-2 ~R-11 R-23 ~X-4 X-28 Injection Profile 04/03/88 #1 9700-10124 Sch 5" Tubing Puncher Record 03/31/88 #1 8390-8570 Sch 5" PITS/FM 03/24/88 //1 8800-9260 Camco TEMP 03/31/88 #1 8750-9260 " 5" Completion Record 04/01/88 #1 8500-9236 Sch 5" Completion Record 03/25/88 #1 10295-10527 Sch 5" Production Profile 03/29/88 #1 10250-10690 Camco 5" CNL/GR 03/26/88 #4 9050-9731 Sch 5" Production Profile 04/02/88 #1 11000-11335 Camco 5" Temp 03/12/88 #1 10100-10742 " 5" Production Profile 03/31/88 #1 9800-10050 " 5" M-28 03/15/88 #1 8700-8940 " 5" Injection Profile 03/26/88 #1 9550-9840 " 5" Injection Profile 04/01/88 #1 9550-9840 " 5" Injection Profile 03/15/88 #1 9400-9830 " 5" PITS 03/14/88 #1 10229-10705 " 5" Production 04/02/88 #1 11500-11751 Sch 5" PITS 03/25/88 #1 9600-10050 Camco 5" Completion Record 04/04/88 #1 8900-9595 Sch 5" 11 Received Dote A ,~.~ ol ,he o.9.,-,ol 5'o,.clo,d Oil COmpony Fouodcd .n Cle-elond Oh.o. 0. 1870 Alaska Oil & Gas Cons. Commlsslo. Anchorage Victoria Aldridge INFORHAT ION CONTRO{_ Wel I Records LR2-1 Standard Alaska -~'~'~ Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 561-5111 STANDARD ALASKA PRODUCTION April 5, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM~ Enclosures (9) J. L. Haas (MB12-1) R-2 Well File MJ~naA~e rBr~rgogduc t ion E~ngineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other I-i 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 ¢. Location of well at surface 638' NSL, 969' EWL, SEC. 32, T12N, R13E, UPM At top of productive interval N/A - water injection well At effective depth 2607' NSL, 1658' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, SEC. 31, T12N, R13E, UPM 5. Datum elevation (DF or KB) KBE = 54.97 AMSL feet 6. Unit or Property name Prudhoe Bay Unit '. Well number R-02 (33-31-12-13) PBU 8. Permit number 78-100 9. APl number 5 0 - 029.20354 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 S u rface 2594 Intermediate 9273 Production -- Liner 1487 Perforation depth: measured 10303 feet 9461 feet 10121 feet 9389 feet Size 20X30 13 3/8 9 5/8 Plugs (measured) Junk (measured) Cemented 651 c.f. 5348 c.f. 1418 c.f. 7 430 c.f. 9510'-9520', 9530'-9576', 9590'-9636 9670'-9687', 9745'-9788' Measured depth 144 2628 9307 True Vertical depth BKB 144 2628 8587 8815-10302 8162-9460 Squeezed off: 9662'-9670' 9697'-9730' true vertical subsea 8710'-8955' (five intervals) Tubing (size, grade and measured depth) 7"x 5 1/2" tapered string to 8741' with 4 1/2" tailpipe to 8876' Packers and SSSV (type and measured depth) 9 5/8" BO Tpacker at 8741 '; no SSS V in B VN at ~j~a 12. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 3. Estimated date for commencing operation April 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~e/r,r,r~fy that the foregoing is true and correct to the best of my knowledge Signed~h tJ,,"4~,~ ~ Title Manager Production Engineering7 I ~" ~/ - ~ Commission Use Only Conditions of approval Notify commission so representative may witness IApproval No. [] Plug integrity [] BOP Test [] Location clearance I · ~pr~r'oved Copy Retu rne~/) ~iGINAL SIGNED BY .~/~ ~-~'~ by order of Approved by LONNIE C. SMITH Commissioner the commission Form 10-403 Rev 12-1-85 Date Submit in triplicate Well R-2 (33-31-12-13) PBU STIMULATION PROPOSAL A selective mud acid stimulation is proposed for the following perforated interval in water injection well R-2. 9745' - 9788' MD BKB An inflatable packer will be set between 9730' and 9745' MD to isolate the interval to be treated from the upper intervals. The packer will be pulled following the treatment. Treatment fluids will be pumped as follows via coiled tubing: 2142 gal. 15% HC1 4284 gal. 12% HC1 - 3% HF 4284 gal. 3% NH4C1 brine The well will be returned to injection and tested. jm 3/31/88 ~^leA qe~s ~ peeH lie M (eUl'l II!)!) ~O-)lOed .. bulqnl pellOO s~:~)3u~)/t~)~:d-3no-/nOl~! l~u!qnl p~)l!O3 Standard Alaska Production Company 900 East Benson Bouleva~ P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 561-5111 STANDARD ALASKA PRODUCTION February 25, 1988 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2 (33-31 12-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (9) J. L. Haas (MB12-1) R-2 Well File A unit of the originat Standard Oil Company Founded in Cleveland, Ohio, in 1870. Yours very truly, B. J. Pol~cky, S~ervisor Waterflood & Miscible Flood RECEiVEO F £ a 2 9 1988 , Jaska Oil & Gas Cons. Comm~ior Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY .APPROVALS 1. Type of Request: Abandon r-i Suspend I-I Operation Shutdown I-! Re-enter suspended well I-I Alter casing r-! Time extension n Change approved program I-I Plugging I-I Slimulate r'l Pull lubing I-I Amend order I-1 Perforale [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address .~. P. O. Box 196612~ Anchorage, Alaska 99519-6612 4.' Location of well at surface 638'NSL, 969'EW1., SEC. 32, T12N, R13E, UPM At top of productive interval N/A , water injection well At effective depth 2607' NSL, 1658' WEL, SEC. 31, T12N, R13E, UPM At total depth 2638' NSI_, 1681' WEL, SEC. 31, T12N, R13E, UPM 1. Present well condition summary Total depth: measured 10303 feet Plugs (measured) true vertical 9461 feet Effective depth: measured 10121 feet true vertical 9389 feet Casing Length Size Structural -- Conductor 110 20X30 S u rface 2594 13 3/8 Intermediate 9273 9 5/8 Production -- Liner 1487 7 430 c.f. Perforation depth: measured 9510'-9520', 9530'-9576', 9590'-9636 9670-9687', 9745'-9788' true vertical subsea 8710'-8955' (five intervals) Junk (measured) 5. Datum elevation (DF or KB) KBE,,54.97 AMSL feet Tubing (size, grade and measured depth) 6. Unit or Property name Prudhoe Bay Unit 7. Well number R-2 (33-31-12-13) PBU 8. Permit number 78-100 APl number 0 - 029-20354 10. Pool ; Prudhoe Oil Pool Cemented Measured depth True Vertical depth BKB 651 cof. 144 144 5348 c.f. 2628 2628 1418 c.f. 9307 8587 8815-10302 8162-9460 Squeezed off: 9662'-9670' 9697'-9730' REEEI 7" x 5 1/2" tapered string to 8741' with 4 1/2" tailpipe to 8876' FEB 2 9 1988 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8741~ no SSSVin BVN at ~ 0il & ~as Anchorage 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation February 1988 4. If proposal was verbally approved ~,~baa¢/!~ ~.~ approver ~s ~ II,in.,:' ~_~_~ ~.;/~.:;'~._,~_ ~,,.._~'~' Date approved Name of 15. I hereby certif, f~l~ that th~ for~o,o,o~g i~ true and correct to the best of my kh~3Wl~cr~6ge Commission Use Only Conditions of approval [] Plug integrity [] BOP Test Approved Copy Returned Approved by LONNIE C. SMITH Form 10-403 Rev 12-1-85 Notify commission so representative[] Locationmay witneSSclearance IApproval No. ~ '-' ~ ./? by order of Commissioner the commission Date Submit in triplicate Well R-2 (33-31-12-13) PBU ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following Sag River interval for water injection during February 1988 at 4 spf: 9364' - 9404' MD BKB (8583' - 8618' TVDss) Depths are referenced to BHCS, 07/02/79 A lubricator will be installed and tested to 3500 psi for all well work. Following perforating operations, the well will be returned to production and tested. RECEIV O FE ~ 2 ~ 1~88 , ,,~aska Oil & Gas Cons. Anchorage 0833Z j~ 02/08/88 d bi I OAIzlEIS_:::! bi ziSVBM9~ 08 bl~Slbl dlAlnd CI'-IO_..,II NVI/~ / 'qSV::ltJ9 3^-1¥^ 3NI-1MO~ 3N1-1 EISVEII~9 :::! N IqMO"i..,I dlAlnd ::18 NJ.N~0'I::I "IV:::IS 3SVqk:19 aNVH-*-{ zl..zlO~lOYd 'N3M08 -I:::lOHOVd ~' S::!8 FIJ., MO'I.--I INDEXED DALLAS ARCO CHEVRON STANDARD ALASKA PRODUCTION E,'C(ON TEXACO Date: O1/06/88 TO: HOBIL TI: 78391 PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning It to this office: ~ B-13 ~ C-9 ~ F-24 "~ G-23 ~ SC-lA · K-13 R-23 CCL/Perf. 11 CCL/Perf. 11 C~L/CR 12 Spinner/TEMP/Hydro on coil tub Plug setting & Tubing Puncher Record CCL/Perf. 11/29/87 Completion Record 12/29/87 X-Y CALIPER 11/26/87 CCL/Perf. 11/19/87 Squeeze Perf. Record 12/23/87 12/30/87 #1 3450-3734 #1 9600-9832 GO #1 10765-11972 Sch #1 10400-11710 GO #1 9500-9900 GO #1 11192-12138 SCH /19/87 #1 10590-10750 GO 5" /21/87 #1 9500-9800 GO 5" /28/87 #1 11830-12216 SCH 5" ing 11/21-22/87 #1 9750-10515 GO Sch _) 5" 5" 5" Rece i red Date AN 1 E' ]?.'~;! '--/ Gas Cons. Commission Anchorage ~ un,, ot ,he o,,g,not S,ondo,d C).l (O.nDOnf founded ,n (]le.¢lond C~.o ,. 18.10 Victoria Aldridge I NFORi%~T ION CONTROL Wel I Records LR2-1 Standard Alaska ~'~-' Production Compare. 900 East Benson Boulevu,u P.O. Box 196612 Anchorage, Alaska 9951 9-6612 (907) 561-5111 December 8, 1987 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. BJP: JAM ~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 R-2 Well File Yours very truly, Waterflood & Miscible Flood A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870 STATE OF ALASKA ALAb.,, OIL AND GAS CONSERVATION COM, .SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging E~ Perforate ~ Pull tubing Alter Casing [Z] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 54.97 AMSL Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 638' NSL, 969' EWL, Sec. At top of productive interval N/A - water injector At effective depth 2607' NSL, 1658' WEL, Sec. At total depth 2638' NSL, 1681' WEL, Sec. 32, T12N, R13E, UPM 31, T12N, R13E, UPM 31, T12N, R13E, UPM 7. Well number R-2 (33-31-12-13) PBU 8. Approval number N/A 9. APl number 50--029-20354 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 10303 feet Plugs (measured) 9461 feet BKB Effective depth: measured true vertical 10121 feet Junk (measured) 9389 feet Bt<~3 Casing Length Size Cemented Structural -- Conductor 110' 20"x30" 651 c.f. Surface 2594' 13 3/8" 5348 c.f. Intermediate 9273' 9 5/8" 1418 c.f. Production -- Liner 1487' 7" 430 c.f. Perforation depth: measured 9510' - 9788' (six intervals) true vertical (ss) 8710' - 8955' Measured depth True Vertical depth BKB 144 ' 144 ' 2628' 2628' 9307' 8587' 8815 ' -10302' 8162 ' -9460' Tubing (size, grade and measured depth) ;'[!r.lska 0ii&,Gas Cons. Commissjo~ 7" x 5 1/2" L-80 tapered string to 8741' with 4 1/2" tailpipe to 8876~Ch0~§e Packers and SSSV (type and measured depth) 9 5/8" BOT 3H packer at 8741'; no SSSV 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure .... 185OO -- 17000 Tubing Pressure 995 485 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run I1 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-g5 Title Supvr. Waterflood/Miscible Flood Date / ,//~//~,,,~. Submit in Du'plicate Well R-2 (33-31-12-13) PBU REPERF/ADDITIONAL PERFORATING OPERATIONS The fOllowing perforating was performed November 19, 1987 using Gearhart 3 3/8" HSC Tru-Jet carrier guns at 4 spf: Reperf: 9670' -9687' MD BKB (8851' -8866' TVDss) Add perf: 9745' - 9788' MD BKB (8917' - 8955' TVDss) A lubricator was installed and tested to 3500 psi for all well work. The well was returned to water injection immediately following perforating ope rations. jm 12/3/87 Standard Alasl~o ~-"~ .... Productlon Company 900 Eo~! Be,~on Boule,,o._ PO ~ 19~1~ Anchorage. Alaska 99~ 19-66 ~907t 564.5 I I I DALLAS ARCO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS 'STATE OF ALASKA GEOSCIENCES I NDEXEO STANDARD ALASKA PRODUCTION Date: 12/02/87. TI: 78337 REFERENCE: SAPC CASED HOLE FINAL LOGS The following materiel Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-4 A-13 C-4 E-5 E-7 E-27 E-28 H-19 J-17 M-13 R-2 R-23 CNL/GR 11/20/87 #12 10350-10995 Sch 5" CNL/GR 11/19/87 #1 9095-9795 Sch 5" Perf Record 11/24/87 #3 8900-10683 Sch 5" CNL/GR 11/22/87 #5 9400-10000 Sch 5" Prod. Profile 11/19/87 '#1 9150-9440 Camco 5" CBT 11/21/87 #1 8500-9692 Sch 5" CNL/GR 11/25/87 #1 9600-10572 Sch 5" Perf. Record-For Squeeze 11/26/87 #1 10100-11623 Sch 5" CNL/GR 11/23/87 #1 10000-10907 Sch 5" Miscible Gas Injection Profile 11/18/87 #1 9390-9626 Sch 5" Injection Profile 11/21/87 #1 9400-9830 Camco 5" PITS/Spinner 11/20/87 #1 11500-12050 Camco 5" Victoria Aldridge I NFORHAT I ON CONTROL Wel I Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION Date:. 02/24/87 TI: 77739 REFERENOE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-16 A-17 B-12 B-12 B-19 B-19 E-7 G-23 J-6 M-2 R-2 R-6 S-14 S-20 T-7 Injection Profile Injection Profile DFT Cont. Flow & CCL Cont. Flow Completion Record CCL/Perf. GR/CCL Packer Setting 01/27/87 01/30/87 01/28/87 0~/28/87 01/26/87 02/15/87 02/01/87 02/02/87 02/13/87 Cont. Flow/Injection Profile 01/28/87 Cont. Flow 02/06/87 gl Injection Profile 02/9-10/87 gl Cont. Flow 02/03/87 gl Production Pr'ofile 02/01/87 #2 Injection Profile 01/29/87 gl gl 9900-11000 Camco 5" gl 10000-10300 Camco 5" #3 8850-9300 GO 5" #3 8850-9300 GO 5" #1 9350-9700 GO 5" gl 9200-9718 Sch 5" #1 9100-9432 · GO 5" #2 8100-9203 Camco 5" gl 10030-11350 Sch 5" #1 9700-10010 GO 5" 9390-9640 GO 5" 9900-10200 Camco 5" 10150-10900 GO 5" 9150-9750 Camco 5" 9200-9550 Camco 5" Rece i ved A un~l ol the o~,nol ~,to,~elofd C~l Compony Founded m Cie-elond. Ohm. m 1870 r:l.~ Aldr'l d~e I NFORHAT I ON CONTROL Records LR2-1 Standard Alaska P~oduction Company ~.. 900 Eost Benson Boulev, P.O. Box 196612 Anchorage, Alaska 99519-66 J907) 564.511 ! INDEXED , , , DALLAS ARCO CHEVRON EXXON TEXACO Date: 02/23/87 lO: MOBIL TI: 77736 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: B-7 CCL/Perf. 01/23/87 #1 11550-11950 GO 5" B-12 DFT 01/23/87 #1 8500-9340 GO 5" B-12 CONT. FLOW 01/23/87- #1 8850-9250 GO 5" B-12 DFT 01/26/87 #1 8850-9350 GO 5" B-i2 Cont. Flow 01/26/87 #2 8850-9270 GO 5" B-19 Cont. Flow 01/24/87 #! 9350-9700 GO 5" B-19 Temp. 01/24/87 #1 9350-9700 GO 5" B-19 Temp. 01/26/87 #1 9350-9700 GO 5" F-14 Cont. Flow 01/14/87 #1 9100-10200 GO 5" R-2 Cont. Flow 01/22/87 #1 9400-9670 GO 5" Rece i ved Date A unit ot the otig;nol Slondo,d O;I Co,wpony founded in Clevelond. Oh;o. m 1870 Victoria Aldridge INFORHATION CONTROL Well Records LR2-1 Standard Alaska Production Coml~ 900 East Benson B~ /ard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 9, 1987 STANDARD ALASKA PRODUCTIOt ,, ,' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well R-2i (33-31-12-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 R-2 Well File ~ J. A. Bragg Supervisor Production Operations Alaska 0il & Gss Cons. C0mm;ssio~ Anchorage A unit of the or~g;nol Standard O'1 Company Founded in Cleveland Ohio in 1870 STATE OF ALASKA ALAS~ DIL AND GAS CONSERVATION COMI~ ~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging .~. Perforate ,_~ Pull tubing Alter Casing.r-. Other ~ 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 7. 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM At top of productive interval N/A- water injection well At effective depth 2399' NSL, 1495' WEL, Sec. 31, T12N, R13E, UPM At total depth 2638' NSL, 1681' WEL, Sec. 31, T12N, R13E, UPM Datum elevation (DF or KB) KBE = 54.97 Feet Unit or Property name Prudhoe Bay Unit Well number R-2 (33-31-12-13) PBU 8. Approval number N/A 9. APl number 50-- 029-20354 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 10303 feet Plugs (measured) 9461 feet BKB Effective depth: measured true vertical 9673 feet Junk (measured) 8909 feet Fill @ 9673' Casing Length Structural -- Conductor 89 ' Surface 2607 ' Intermediate 9286 ' Production -- Liner Perforation depth: Size Cemented Measured depth True Vertical depth BKB 20"x30" 651 c.f. 110' 110' 13 3/8" 5348 c.f. 2628' 2628' 9 5/8" 1418 c.f. 9307' 8587' 1487' 7" 430 c.f. measured 9510' - 9636' (three intervals) true vertical (subsea) 8710' - 8821' 881 5' -10302 ' 8162 '-9460 ' Tubing (size, grade and measured depth) 5 1/2" L-80 to 8741' with 4 !/2" tailpipe to 8876' Packers and SSSV (type and measured depth) 9 5/8" B0T 3H packer at 8741 '; no SSSV 12. Stimulation or cement squeeze summary See attachment Intervals treated (measured) Treatment description including volumes used and final pressure f-EB i i 1987 Alaska Oil & Gas Co~s. Commission Anchorage 13. Prior to well operation Subsequent t° operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure .... 3330 -- .... 6770 -- Tubing Pressure 9OO 89O 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~? 15. I hereby certify that 'the foregoing is true and correct to the best of my knowledge Signed '~~~~ ~ '-~' ~ TitleSupervisor Production Operations Date ,2/(,/~'~z Form 10-404 Rev. 12-1-85 Submit in Duplicate Well R-2i (33-31-12-13) PBU STIMULATION OPERATIONS A bullheaded three-stage mud acid stimulation was performed January 28, 1987, on the fo~lbowing Zone 4 perforated intervals in water injection well R-2. 9510' - 9520' MD BKB 9530' - 9576' MD BKB 9590' - 9636' MD BKB Total volumes of the treatment were as follows: 2500 gal. 15% HCl 5000 gal. 12% HCl - 3% HF 2500 gal. 15% HCl 900 gal. gelled 3% NH4Cl w/900# benzoic acid flakes The final stage was followed by 1500 gal. 100% methanol; the perforations were flushed with 273 bbls. seawater. Following the treatment, the well was put back on injection and tested. Ala¢.'a Oil & Gas .... ~.,~,ns. jm 1/29/87 $1andard Alaska Preduction Cempan¥ 900 East I~en$on Boulevard P.O. Box 196612 Anchorage. Alaska (907! 564-5! I I INDEXED DALLAS ARCO CHEVRON ExxON TEXACO Date: 01/19/87 TO: MOBIL TI: 77666 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning It to this office: ~B-9 ~ G-11 G-19 H-9 H-9 ~H-9 ''"- M-25 ~ R-2 '~- S-12A ~:Y-8 Temp. 11/16/86 #1 CCL/Perf. 12/06/86 #1 CCL 12/01/86 #t CCL/Perf. 12/30/86 #1 CCL/Perf. 12/13/86 #1 Temp. 12/18/86 #1 Cont. Flow. 12/18/86 #1 Prod. Profile 01/03/87 #1 Injection prOfile 01/04/87 #1 CCL/Perf. 12/08/86 #1 TemP. 12/07/86 #1 Cont. ~low 12/07/86 #1' 10-3200 GO 5" 9830-11095 GO 5" 9800-10210 GO 5" 10550-11503 GO 5" 8750-10100 GO 5" 9400-10300 GO 5" 9400-10050 GO 5" 10650-11020 Camco 5" 9300-10000 Camco 5" 8700-10215 GO 5" 11433-11900 GO 5" 11500-11850 'GO 5" Rece i ved Date A un;t of the o~g~nol .Slando~d 0~1Compc~ny ' v~' a A r ge Anchorage I NFORHAT I ON CONTROL Wel I Records LR2-1 ALAS ..ND GAS CONSERVATION COMMI~£ON C. V~ C~atterton December 16, Cha',~.~'n ~_. D.BDF.89 1986 Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector Mech Integrity Test SAPC PBU Pads S, M, U, R, N, T, Y, H, F, X Prudhoe Oil Pool Wednesday, November 19~ 1986: The tests began at 7:00 a.m. and were concluded for the day at 4:30 p.m. with 10 wells being tested. Thursday, November 20, 1986: The tests began at 7:00 a.m. and were concluded for the day at 7:00 p.m. with 14"wells being tested. Friday, November 21,198.6: The tests began at 6:30 a.m. and were concluded for the day at 4:30 p.m. with lO.wells being tested. Saturday, November 22, 1986: The tests began at 6:30 a.m. and were concluded at 1:00 p.m.; and were resumed at 6:00 p.m. and concluded for the day at 9:00 p.m. ~,,~,~'~ 0~:'~., As the attached mechanical integrity tes_t ~ports show, '3~we't~l~s were tested, all of which met thejAOGCO regulations. In summary, I witnessed the mechanical integrity tests on Standard Alaska Production Company's injections wells listed on the attached test forms. Attachments AIASKA OIL AND GAS CONSERVATION CCP~ISSION F~-CHANICAL INTEGRITY TEST I PP~'I'~ST START 15 MIN 3 0 MIN *P *I TYPE OF PKR CASING TlR] REQ TBG TIb~. TIME TIME W~. *S --- ANNL~US TVD SIZE/WT/GRADE~ SIZE TEST CSG TBG TBG TBG CC~MENTS ~! *N ~LUID MD PRESS PRESS CSG CSG CSG : PRESS PRESS PRESS · _ ':', N.c I , ' ..... ..2.. ~ ~ ,.F,~'.,~ q s% Z-,~,o 5'2'.,,,,, ~, · , · ,. , r ..~ ,, -'tWD .., ! ~ ~i~I,,-rw v" /oo.~_~ so c °N " , '0/(' . , ~s Bo: . ~ _,. ~ . *TUBING ~~ ~: ~ ~: ~~: ~C ~S SI ,' P = P~~ ~ D~ , ~ ~ - ~~ I - ~~ D~z.~ ~ : 20 ~C 25.030(a) N - ~ ~ ~ 20 ~C 25.412(c) ':.. L ._ ~ . 20 ~C ~.252(d) ':.,;. ~.~.o6 ':: .' INDEXED DALLAS ARCO CHEVRON EX_XON TEXACO Date: 10/09/86 TO: MOBIL It: 77393 PHILLIPS ~' :'"STATE '0'F' ALASKA ~ zI .. ~ , ~ -fi~,-.::.~.~-~,., ~ GEOSCIENCES STANDARD ALASK/'~, F~P.©[.xl. JC TION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is belng submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: - CET 03/02/86 CET 03/18/86 CET 03~20/86 CET 03/19/86 CCL/Perf. 09/17/86 CCL/Perf~ 09/27/86 CBT 03/08/86 CCL/Psrf. 09/21/86 GCT 06/12/86 CCL/Perf. 09/22/86 EPL 03/15/86 CBT 03/07/86 CBT 06/24/86 CCL/Perf. 09/23/86 GCT 04/18/86 #2 1100,h-11986 Sch 5" H1 9C30-9786 Sch 5" H1 9100-9875 Sch 5" HI 10200-11180 Sch 5" Hi 9700-10250 GO 5" H1 9700-9940 GO 5" HI 8700-9648 Sch 5" Hi 7900-9217 GO 5" Hi 32-6711 Sch 5' Hi 9402-10657 GO 5" H3 9350-9850 Sch 5" #1 8960-9629 Sch 5" Hi 8600-9780 Sch 5" H1-4 10500-10950 GO 5" #1 0-10510 Sch 5" Rece J red ' c c '~ I NFOR"'~T I ON CONTROL Date ...,.'.] :']] ~., {'7 ' ......... '- ' Wel I Records LR2-1 Founded ,,~ Cl~'velo,~d C~'-o ,,~ IH7() SOHIO ALASKA PETROLEUM COMPANY DALLAS ARCO CHEVRON EXXON ro DAL/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS 31 ! ! "C" STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL POUCH 6-612 ANCHORAG£. ALASKA 99502 Da te: Tf/: 04/18/86 77007 STATE OF AK BPAE GEOSCIENCES REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge rece,ot by signing a CODy of this letter and returning it to this office:-- DAL/STATE/UNIT/GEOS.: ~D-24 ~"~D-25 ~-H-24 H-26 ~S-14 ×-15 GCT Survey 01/08/86 #1 Sch - GCT Survey 01/30/86 #1 40-10850 Sch 5" GCT Survey 02/06/86 ~1~ 0-10089 Sch 5" GCT Survey 12/14/85 #1 50-9408 $ch 5" EPL 10/15/85 #2 9400-10000 Sch 5" EPL 12/21/85 #2 10100-11075 Sch 5" EPL 12/08/85 #I 9600-9920 Sch 5" EPL 12/03/85 #i 9500-9900 Sch 5" R£CE~VED SOHIO ALASKA PETROLEUM COMPANY January 10, 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed~ in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to perforate the well. PFB:JAM~ Enclosures (3) Yours very truly, P. F. Barth Supervisor, Reservoir/ Production Surveillance Unit STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 78-100 3. Address 8. APl Number P. O. BOX 196612, ANCHORAGE, 'ALASKA 99519-6612 50-029-20354 OTHER 4. Location of Well At surface: 638' NSL, 969' EWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL 12. 32, T12N, R13E, UPM I 6. Lease Designation and Serial No. ADL 28279 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing I--I Perforations [] Altering Casing [] Stimulate [] Abandon I-'J Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work., for Abandonment see 20 AAC 25.105-170). The following additional water injection interval will be perforated during January 1986 at 1 spf: 9745' -9788' BKB (Ref. BHCS/GR, 7/2/79) r:, C :IV D AIr~ska 0ii & Cas C0t~s, Cuml~ .......... ~4. I hereby certify that the foregoing is true and corr~t to the best of my knowledge. Signed TitleSU_pervisor Resez-voir/2roauction Date The space below for Commission use P. F. Barth Surveillance Unit I Conditions of Approval, if any: Approved by By Order of COMMISSIQNER the Commission Form 10-403 Submit "Intentions" in Triplicate ..... ~n,-4 "q~,h~an,~ant IZ~nnrt¢" in J~llr~JJ¢'.qtp SOHIO ALASKA PF. TROL~UM COMPANY $ FO ARCO CltEVRON EXXON \ . to: SFO/UNIT/STATE: TEXACO (-.Marathon) MOBIL PHILLIPS STATE OF AK BPAE 31 I I "C" S'I'nEET ANCHORAGE. ALASKA rELEPf<ON£ (9011 265.0000 ANCHORAGE. ALASKA 99502 12-19-85 Oate: Tf: 76640 SOHIO CASED HOLE FINAL LOGS c~y of this letter a~ returning it to this office:-- SFO/Unit/State: ~ D-7 ~= ~'GC3'C '' ~ JX-2 -' ~,~M-6 '- -,.R_2~ ~R-2 ~ ' '~, R-20" ~'U-2-- MX-5 ' Packer Record DFT CH-CNL Temp Log EPL Temp Log Inj. ProfilA ' EPL CFS Temp Log .-- . cm-c II-2!-85 #I - 9796-i0330 Sch 11-02-85 #1 surf-2830 GO 5" 11-26-85 #1 9100-9955 Sch 5" 12-08-85 #I surf-4500 Camco 2" 10-10-85 #1 9300-9951 Sch 5" I1-17-85 #1 9400-10000 GO 5" II-17-85 #1 9400-9800 GO 5" 10-24-85 #3 11300-11900 Sch 5" 10-28-85 #I 9620-10220 GO 5" 11-30-85 #1 9950-10748 Sch 5" ,, // " ~"'="£ Te~chnical Documentation ,s Records Management A. SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 December 16, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Wel]('"R-2'~?/- (33-31-12-13) PBU Ge ntl eme n: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM4~%x . A.B. ragg v v upervisor Production Operations Enclosures (3) cc: Drilling Well Files (MB12-1) Well Records (LR2-1) R-2 Well File ~"~:','~t ,..~ .,.~ ~j Anu,,o~ag. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 78-100 3. Address 8. APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50-029-20354 OTHER 4. Location of Well At surface: 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool Prudhoe Bay I 6. Lease Designation and Serial No. Prudhoe Oil Pool ADL 28279 ; Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A bullheaded three-stage mud acid stimulation of the following Zone 4 perforations is pro- posed for R-2 water injection well. 9510' - 9520' BKB 9530' - 9576' BKB 9590' - 9636' BKB Each stage of the treatment will consist of: 1700 gal. 15% HC1 3400 gal. 12% HC1-3% HF 850 gal. 15% HC1 800 gal. gelled 3% NH4C1 w/800 lbs. benzoic acid flakes The final stage will be followed by 2000 gal. methanol and 3000 gal. perforations will be flushed with seawater. This work is scheduled to commence .in January, 1986. Alaska 0il & tSas (.;~,~. bu~iu~'~issiori Anchorage ,14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The ~lS~e below for Commissiorl/u~ Co dr~/ions of APproval, if any: J. A. Bragg TitleSupervisor Production Operation§ate !£'/~-~5~ Approved by ..__~ COMMISSIONER By Order of the Commission Date / '-_~._ ' /; '(~ ~'~ Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON TO SFO/UNIT/STATE: TEXACO (-Marathon) MOBIL PHILLIPS BPAE 3111 "C" ANCI"iOHAG[. ALASKA TELEPHONE (9071 265.0000 MAIL: POUCH 6.6 12 ANCHORAGE, ALASKA 99502 Date: 10/31/85 T#- 76532 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: .// j_6'~' ~'--J-6 ~ t,-.K- 7 Temp. Temp. Fluid ID Spinner Cont. Flow Survey Temp. . 10/01/85 #1 10250-10540 Camco 10/05/85 #1 11000-11430 Camco 10/05/85 #1 11000-11430 Camco 10/05/85 #1 11000-11430 Camco 10/03/85 #1 9900-10180 GO 5" 10/03-04/85 #1 9000-10110 Camco 1! 5" 5" 5" 5" R£C£~v£o I NOV u 5 Alas~ 0i~ & Gas, Con~-. Commission An~,homg~ Technical Documen tati6n Records Management SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON ?EXACO TO: SFO/UNIT/STATE: (-Mara t hun) MOBIL PHILLIPS STATE OF AK BPAE 3111 "C" STREET ANCHORAGE. ALASKA T£LfPHONE (9071 265.0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: T#- 10-24 -85 76514 REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: '-~ F-5 ~ 9-11-85 CFS/Spinner K-4-~ 9-27 -8 5 Spinner ~ R-2v/ 9/23-24/85 Spinner Inj. Pro. '~ ~ R-2 ~/ 9-24-85 Temp Inj. Pro. ' S~'~;~ ~ 9-14,851~. ' ' '- CCL/Perf~' X-1i// 9-19-85 Inj. Profile ~ "" Y-4 J 9-09-85 CFS 11000-11340 #1 GO 5" 8450-8930 ~1 Camco 5" 9350-9850 #1 Camco 5" 9000-10110 ~1 Camco 5" 8890-9760 #1 GO 5"- 9150-9450 # 1 Camco 9950-10300 #1 GO 5" RECE{VED DAT~ 19 Cathy Perkins LR 2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.Q. BOX 6612 ANCHORAGE, ALASKA 99502-0612 October 30, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Gentlemen' Mr, C' V~ Chatterton Well R-2 (33-31-12-13) PBU Enclosed in duplicate is Forr~ Wells' for the above named well Wel 1 R-2, 1 O-q.03' RSA/L~/H/d§/1026N Enclosure CC' S. R. Bundy T. N. Tyler Well Records Drilling Well File #17 P. E. Well File #17 Sundry Notices and Reports on This gives notice of completed work on Very truly yours, SOHIO ALASKA PETROLEUM COMPANY R. S. Allan Division Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:E] OTHER [] 2. Name of Operator SOHIO ALASKA PETROLEUM COMPANY. 3. Address P. O. Box 196612, Anchorage:, Alaska 99519-6612 4. Location of Well At Surface: 638' NSL, 969': EWL, Sec. 32, T12N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) _¥BE = 54.97' AHST, I 6. Lease Designation and Serial No. ADT, 28279 7. Permit No. 78-100 8. APl Number 50- 029-20354 9. Unit or Lease Name Prudhm~ Bay Ti_ri_it 10. Well Number R-~ (33-31-12-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following work was performed on Well R-2, using a Coiled Tubing Unit (CTU). 1. Cement squeezed existing perforated intervals to shut off water channel. 2. Reperforated the following intervals at 4 s.p.f.: 9510'-9520'MD 9530'-9576'MD 9590'-9636'MD Intervals 9662'-9687'MD and 9697'-9730'MD were left squeezed. 3. Put well back on water injection. 4. The above work was completed on October 17, 1985. hereby certify that the foregoing is true and correct to the best of my knowledge. ~e space below for Commission use Title District Drilling Engineer Date Conditions of APproval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 R~v 7-1-R0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate INDEXED ~o: S FO/UNI T / S TATE: SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON TEXACO · (-Marathon) MOBIL PHILLIPS : .STATE BPAE (Transmittal Only) 3111 "C"STR£ET ANCHORAGE, ALASKA TELEPHONE(907) 265-0000 MAIL:POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 10-11-85 T#: 76490 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- K-4 R-2 9-27-85 Flowing Gradient Camco 9-28-85 BHPD 9-23-85 Flowing Gradient Camco 9-24-85 BHPD RECEIVED DATE Cathy Perkins LR 2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 September 20, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr' C.V Chatterton Well R-2 (33-31-12-13) PBU Gentlemen' Enclosed in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above named well. proposed work on Well R-2. This gives notice of intention for Yours very truly, SOHIO ALASKA PETROLEUM COMPANY RSA:~:kkm 0920~5: 0864N · 1 Enclosures CC' T. N. Tyler, (MB9-2) S. R. Bundy, (MB12-4) Well Records (LR2-1) Drilling_Well File #17 P. E. Well File R. S. Allan District Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL )~D OTHER [] 2. Name of Operator SOHIO Alaska Petroleum Company 3. Address P. O. Box 196612, Anchorage, Alaska 9951 9-6612 4. Location of Well At Surface' 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE : 54'97' AMSL I 6 . Lease Designation and Serial No. ADL 28279 7. Permit No. 78-1 O0 8. APl Number 50-029-20354 9. Unit or Lease Name Prudhne_ Ray Ii,it 10. Well Number R-2 (33-31 -12-1 3)PBU 11. Field and Pool Prudhoe Ba.y Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to squeeze the existing perforations in Well R-2 using a coiled tubing unit (CTU). After the squeeze the well will be cleaned out and re-perforated. The following summarizes the proposed work' · ® Lay in heavy mud from PBTD to 9755'MD. Pump in low fluid loss Class "G" cement and squeeze off interval s. Contaminate cement i n wel 1 bore. Reverse out contaminated cement after 12 hours. Re-perforate the following Zone 4 intervals at 4 s.p.f.; 9530--9576'MD, 9590'--9636'MD). all perforated (951 0'--9520 '~ID, Zone 3 perforations (9662'--9687'MD and 9697'--9730'MD) will be re-perforating at a later date and. covered under separate notice. This work is scheduled to commence September 30, 1985. evaluated for I 1~} I hereby certify that the foregoing is true and correct to the best of my knowledge. t'~S~i ned , . Title District Drilling Engineer I T~ie space below for Commission use Date Conditions of APproval, if any: Approved by. ~pproved Co,~y ~eturne~J ~.%o-~r 5 By Order of COMMISSIONER the Commission Form 10-403 Rev_ 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY AtEO CItEVRON 'to SFO/UNIT/STATE' (-[1a r a thon) EXXON TE;(.ACO PItILLI?S STATE OF AK BPAE 31 I 1 "C" STltffl ANCIt()IIA(][, AtA.%KA Ii I [t'ttON[ 1907l ?65 ()0()O MAIl. POUC'tt 6 tD I 2 AN(;ttOflAG~. ALASKA !t9.502 Date' 7/0!J8_~ .... TI/· 76277 REFERENCE gSED HOLE FINAL LOGS material is being submitted herewith. Please acknowledge receipt by signing a lelter and returning it Io this otlice:- SFO/UNIT/STATE: K-7 CH-CNL 5/22/85 #1 9650-10193 GO 5" N-8 EPL 2/1/85 #1 9500-9960 Sch 5" R-2 EPL-Inj. Profile 1/25/85 #1 9900-10140 Sch 5" R-24 EPL 5/14/85 #1 9056-9346 Sch 5" ttl ( I ivt I) IIA!t Alaska 0il & Gas Cons. Commission Tec:hnical [)ocument:at:ior~ Anchoraq,e, ~ecorc]~; Ma nagem(~nt INDEXED SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON TEXACO TO~ SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS :sTATE',-.`. BPAE (Transmittal Only) 3111 '°C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 6-27 -85 76273 REFERENCE: INAL DATA - ,PRESSURE SURVEY DATA he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- API# M-2 101. 1-29-85 M-13 522 1-24-85 R-2 354 1-26-85 R-20 641 1-16-85 PFO/Injec. Profile PFO/Injec. Profile PFO/ Injec. Profile PFO/Injec. Profile RECEIVED DATE ...... ,.-,~,,,., Oil & C-as ^~ · ~'~"::~J' t;;'::::"~25!~g4'~t, hy PErkins LR 2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 October 10, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Gentlemen: Mr. C. V. Chatterton Wells M-i, M-2, M-3, M-12, M-13, M-14, R-2, R-5, R-7, R-20 S-6, S-9, S-11, S-14, PBU Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-~ wells. - These contain our subsequents to converting the wells from oil wells into water injection wells. Yours very truly, Enclosures cc: J. D. Hartz Well File #17 O/iA: Bragg ~ trict: Petroleum Engini~er (Acting) RECEIVED OCT 1 ':2 1984 Alaska 0il & Gas Cons. Commission Anchorage ........ STATE Of ALASKA ALASKAC AND GAS CONSERVATION CO, /IISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ OTHER [] 2. Name of Operator 7. Permit No. ~./, Sohio AlaSka Petroleum Company 78-100 3. Ad~e.s~. BOX 6612, Anchorage, Alaska 99502 8'~u-~%~54 50- 4. Location of Well At Surface: 638' NSL, 969' ~4L, Sec. 32, T12N, R1.3E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL I 6. Lease Designation and Serial No. ADL 28279 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] . Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was ~onverted from a Prudhoe Bay Production well into a produced water injection well for 1984 P.W.I. water flow evaluation on September 28, 1984. Water was injected through the following perforations at 4 s.p.f. 9510'-9520' BKB 9530'-9576' BKB 9590'-9636' BIfB 9662'-9687' BKB 9697'-9730' BKB hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ /~~~ Title District Petroleum Enqineer The space b~f;r Commiss,o;1 us;' (/'~ Conditions/of/Approval, if any: Date BV Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev_ 7-1 -(tO Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 25, 1984 Alaska Oil & Gas Conservation Cor~ission 3001 Porcupine Drive Anchoragef Alaska 99501 Attention: Mr. C. V. Chatterton Gentl~nen: Well R-2 (33-31-12-13) PBU Enclosed, in triplicate, is Form 10-403~ Sundry Notices ~d Reports on Wells, for the above-n~ned well. This contains our proposal to convert it from an oil well into a water injection well. GJP/JI2t/pjw Enclosures cc: J. D. Hartz Geology Well File #17 i~~Engineer .... STATE OF ALASKA -- ALASKA _ AND GAS CONSERVATION CC i¢IISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED W E L L ;I~;] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-6,]-2, Anchorage, Alaska 99502 4. Location of Well At Surface: 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL 6. Lease Designation and Serial No. ADL 28279 7. Permit No. 78-100 8. APl Number 50_029-20354 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other EX Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). With reference to the previous Sundry Notices dated: November 16, 1979; January 30, 1980; May 17, 1984; and July 20, 1984, for the perforation of the 7" liner, it is intended to convert this Prudhoe Bay Production well into a produced water injection well for 1984 P.W.I. water flow evaluation. Water Will be injected through perforations ( 4 SPF) at 9510'-9520' BKB 9530'-9576' BKB 9590'-9636' BKB 9662''9687' BKB 9697'-9730' BKB RECEIVED Subsequent Work Reported o,~ Form No./~C'/'/O. 3Dated/___~/~~ 14. I he if¥ t is true and correct to the Best of my knowledge. Signed ~~%__.] ~¢ Title Dis~ict Pe~ole~ ~g~r Bate The sp~ below for ~ission use JUL,0'" ,204 Alaska 0il & Gas Cons. Commission Conditions of APproval, if any' Approved by SIGNED LOflfllE C. SMITH COMMISSIONER Approved Cop?' Returned . By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 19, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton · Gentlemen: Well R-2 (33-31-12-13) PBU Enclosed, in duplicate, are the following forms for the above-named well. 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. GJP/¢/pjw Enclosures J.D. Hartz Well File #17 cc: District Petroleum Engineer RECEIVED JUL24L984 ~,laska Oil & Gas Cons. Commission Anchorage -' STATE OF ALASKA ,~ ALASKA ,L AND GAS CONSERVATION C~MISSION ~~/~ ' WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator~ 7. Permit Number 78-100 Sohio Alaska Petroleum ~y 3. Address 8. APl Number :Pouch 6-612, Anchorage, Alaska 99502 5o- 029-20354 4. Location of well at surface 9. Unit or Lease Name 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM Prudhoe Bay Unit At Top Producing Interval top Sag R. SST. 10. Well Number 2397' :~SL, 1490' WEL, Sec. 31, T12N, R13E, UPM R-2 (33-31-12-13) PBU At Total Depth 1 1. Field and Pool 2638' NSL, 1681' WEL, Sec. 31, T12N, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 54.97' AMSLI ADL 28279 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 6-13-79 7-2-79 1-17-80I feet MSLI 2 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost /0303'MD 9461'TVD 10225'MD 9392'TVD YES [~ NO []I 2992 feetMD 2031' 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, FDC/CNL/GR/Cal 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SiZE CEMENTING RECORD AMOUNT PULLED 30" x 20"::nsulated Conducto:: Surface 110' 36" 651 cu. ft. Arcticset 13 3/8" 72~ L-80 Surface 2628' 17 1/2" 5348 cu.f%. Permafro.,~t 9 5/8" 47~ L-80 Surface 9307' 12 1/4" 1288 cu. ft. Class G; 130 cu. ft. Permafrost: C 7" 29~ L-80 8815' 10302' 8 1/2" 430 cu. ft. Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) MD TVDss SIZE DEPTH SET (MD) PACKER SET (MD) Prudhoe Oil pool Top: 9510' 8710' 7"/5 1/2" 8877' 8741' Bottom: 9730' 8903' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9510'-9520' BKB (8710''8719' TVDss) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 9530'-9576' BKB (8728'-8768' TVDss) 9590'-9636' BKB (8781'-8821' TVDss) 9662'-9687' ]3.-KB (8844'-8866' TVDss) 9697'-9730' BKB f8874'-8903' TVDss) 27. PRODUCTION TEST Date FirSt Production Method of Operation (Flowing, gas lift, etc.) 1-17-80 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I1~ Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUL 2 4,191~4 Alaska Oil & Gas Cons. Commission Anchoran~, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - f : \, j 29. 30. GEOLOGIC MARKERS FO'RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST 9361' 8580' Shublik 9407 ' 8620 ' Ivishak 950 8 ' 8709 ' 31. LIST OF ATTACH~XlTS - 32. I herebycerllify/that t~yrue and correct to the best of my knowledge ~'~ ~/ District Petroleum Engineer 7/2l /~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". STATE OF ALASKA ~-'~' ALASKA ,~IL AND GAS CONSERVATION C~.,,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 78-100 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20354 OTHER [] 4. Location of Well , At Surface: 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 54.97' AMSL I ADL 28279 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ]~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ' The following additional intervals were perforated June'21, 1984, using Schlumborger 2 7/8" Hypordom~ guns at 4 spf. · A lubricator was installed m-~d tested to 3500 psi on all well work. 9510'-9520' BE}3' (Ref. BHCS/GR, 7-2-79) 9530 '-9576' BKB ( " ) 9590'-9636' BKB ( " ) An SSSV was set and tested in the ball valve nipple at 2992'. RECEIVED JUL 2 4 1984 Alaska Oil & Gas Cons. Commission s~ ~n~ District Petroleum Engineer / A ~ --'" ,.~j 'r'~space below for~gJommission use ~./~4,~ Title Co~ditions of Approval, if any: Anchorage Date 7/2 O/ ' By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ,,~,, ALASKA' _AND GAS CONSERVATION CC..VIISSION MONTHLY REPORT OF DRILLINO AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] I ~ . 2. Name of operator 7. Permit No. Sohio Alaska Petroleum ~y 78-100 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20354 4. Location of Well at surface 638' NSL, 969' EWL, Sec. 32, Ti2N, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL I6. Lease Designation and Serial No. ADL 28279 For the Month of ,'h~]v , 19 F~4 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. R-2 (33-31-12-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool PBU 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data R c iV D JUL 2 ]984 See Attached Alaska 0il & Gas Cons. Commission 17. I hereby i at the for ng is true and correct to the best of my knowledge. ~ ~ ~ , hJ District Petroleum Engineer 7~ / NOTE--~Report on thi~Jorm is required~for each calendar month, regardless of the status of operations, and must be f~fed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate PERFORATING DATA - Well R-2 (33-31-12-13) PBU June 21, 1984: Rigged up Schlumberger and perforated the . following additional intervals using 2 7/8" Hyperdome guns at 4 spf: 9510 '-9520' BKB (Ref. BHCS/GR, 7/2/79) 9530'-9576' BKB ( " ) 9590'-9636' BKB ( " ) Put well on production. RECEIVED JUL 2 z~ l~l~ Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM .COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 May 16, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells M-l, M-14, R-2, R-7 PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate additional intervals in these wells. GJP/~J~/pjw EnClosures cc: J. D. Hartz Well File #17 Yours very truly, ~sga'~~ ~ ~neer ~ ~istrict Petrole g' RECEIVED Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ~' '_ AND GAS CONSERVATION CC~,IMISSION SUNDRY NUTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] It 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 4. Location of Well At Surface: 638' NSL, 969' EWL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) KBE = 54.97' AMSL 12. 99502 32, T12N, R13E, UPM 7. Permit No. ~.,,.; 78-100 8. APl Number 50- 029-20354 ~ 9. Unit or lease Name Prudhoe Ba_v Unit ~ 10. Well Number R-2 (33-31-12-13) PBU 1 1. Field and Pool 6. Lease Designation'and Serial No. Prudhoe Oil Pool ADL 28279 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed Work, for Abandonment see 20 AAC 25.105-170). The following additional intervals will be perforated May/June, 1984, using Schlumberger 2-7/8" Hyperdome guns at 4 s.p.f A lubricator will be installed and tested to 3500 psi for all well work. 9510 '-9520' BKB (Ref. BHCS/GR, 7-2-79) 9530'-9576' BKB ( " ) 9590'-9636' BKB ( " ) An SSSVwillbe set and tested in the ball valve nipple at 2992. Subsequent Work Beported on Form No/~-t,l?//)-~ Dated RECEIVED MAY 1 81984 Alaska Oil & Gas Cons. Commission Anchorage I1\~. I hereby certify that the foregoing is true and correct to the best of my knowledge. gned Title District Petroleum Engineer / Zhe spa//elow for Commission use / Condit~l~fs of Approval, if any: Approved Copy Returned ItT [0tqllE I~. SlillTll B¥Orderof Approved by COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON GETTY To SFO/UNIT/STATE: ( -Mar a tho n) MOB I L PHILLIPS ,. STATE OF AK BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) :~) 1 1 (: '.-;THI[ T ANC't't~)t'IA(;I . Al A,%KA II l[-t')l"l()N[ t~}(')?l 2(~[) ()()0(.) MAlt [-'OLJ(:H 6 612 ANCHORAGE, ALASKA 99502 Date' 5/26/83 CC#: 74486 REFERENCE: ____I'0 CA____SED HO___LE FINAL LOGS copy of this letter and returning it to this office:- SFO/UNIT/STATE: E-12 TDT-M 4/3/83 #1 8680-9415 Sch 5" J-1 TDT-M 5/19/83 #3 8350-9133 Sch 5" N-6 TDT-M 5/18/83 #3 10250-11049 Sch 5" R-2 Completion Record 4/8/83 #1 8580-8820 Sch 5" X-19 Completion Record 3/30/83 #1 8680-9994 Sch 5" (4/82) RECEIVED DATE Victoria Aldridge Development Geology Well Records TPI-5 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 April 26, 1983 Alaska Oil & Gas Conservation C~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: 'WRT'~'.R-2'(33'31-12-13)'PBU Enclosed, in duplicate, is FOrm 10-403, Sundry Notice and Reports on Wells-, for the' above-named well. This gives Subsequent Report of pulling tubing in well. Very truly yours, enCS cc: Well File #17 R. H. Reiley District Drilling Engineer STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well At surface: 638' NSL, 969' AS'~, 8OC. 32, T12N, R13E, I_IPM 7. Permit No. 78-100 8. APl Number 50- 029-20354 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) PBU 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 55' A~SL I ADL 28279 Prudhoe Oil Pool 12. Check Appropriate 8ox To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 7" tubing and packer w~re pulled from Well R-2. A new 7"/5 1/2" tapered tubing string was run complete with production packer, sliding sleeve, 5 1/2" tubing and gas lift mandrels to 3000' and 7" tubing from 3000' to surface. This w~rk was cc~oleted April 19, 1983. 14. I hereby certify that the foregoing i~true and correct to the best of my knowledge. [.~ I/ % . }t J District Drilling Engineer Signed~,,-~ ~)~,,,~~ /'~-~~ Title The space below for Commission use HJ Reiley Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company sFO/UNIT/STATE: 'INAL CASED HOLE: f M ~- arathon) RESSURE SURVEYS: TO: SFO/UNIT/STATE ,.. SOHIO-BP ALASKA PRODUCTION DIVISION C:~:~ BPAE I~ 1 C-7 EPL 3/3/80 #1 E-2 EPL 3/7/80 #1 E-13 Temp. Log 3/4/80 #1 J-1 Spinner 3/7/80 #1 ~ DDNLL 3/3/80 #1 R-5 TDT-M 3/14/80 #1 R-6 TDT-M 3/13/80 #1 R-6 EPL 3/11/80 #1 X-4 Mudlog 12/25/79-1/23/80 X-5 Temp. Log 3/5/80 #1 NW#1 Spectralog 2/20/80 #1 . . 3111 "C"S]REET ANCHORAGE, ALASKA 'tELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~/18/80 SOHIO DATA ~'~:he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- A-2 Spinner 3/8/80 D-1 Bottom-Hole Pressure Data Form& Survey E-3 ,, ,, ,, E-4 ,, ,, " " ,, II #110A !! 2"/s', (1 5" 5 !' 5" .~" Log) !! 3/10/80 (Otis) 3/z?/80 (Go) 3/16/80 (Otis) 2/11/80 (Go) Well Records RECEIVED , · ,.. . / DATE&_ SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 March 31, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Re: Well R-2 (33-31-12-13) PBU Gentlemen: Enclosed in triplicate is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This gives notice of intention to repair the well. Sincerely, R. H. Reiley District Drilling Engineer RHR: JAS: jbc 0022t enclosure cc: Well file ~17 STATE OF ALASKA .... ALASKA (J~L AND GAS CONSERVATION COw, MISSION SUNDRY NOTICES AND REPORTS ON WELLS St 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroluem Company 78-100 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20354 4. Location of Well At Surface: 638' NSL, 969' EWL, Sec 32, T12N, R13E UPM. 5. Elevation in feet (indicate KB, DF, etc.) KBD 55' AMSL 6. Lease Designation and Serial No. ADL 2 82 79 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number R-2 (33-31-12-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair. Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is intended to pull the present 7" completion and run a tapered 7"/5 1/2" completion with gas lift mandrels. (7" will be from surface to 3000' TVD). This work is scheduled for April, 1983. ~o~ ~o. ~ ' 14. I hereby certify that the foregoing is true and correct to the best of ~y knowledge. The space below for Commission use R.H. Reiley ~ ¢~ - - ' Conditions of Approval, if any: Approved Car., Returned By Order of COMMISSIONER the Commission Date Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 'SFO ARCO CHEVRON EXXON GETTY To: SFO/UNIT/STATE: (-Marathon) MOBIL · ' PHILLIPS sTATE BPAE (Transmittal Only) .._ CENTRAL FILES (CC#'s - Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE: ALASKA 99502 Date: 12/8'/82 Trans.#: 2913 CC~: 55913 REFERENCE: ' 'SOHIO FINAL DATA- PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of, this letter and returning it to this office:-- B-13 '~ E-10~' · E_18_~ E-20 '- G-17 -' R-2--~ R-17~ R-19"- Pressure Survey & BHPD .... II II I1 II II II II Il 11 Il" II II II II II 11 · 11 Otis 10/12/82 GO 10/28/82 CAMCO 10/27-29/82 GO 10/12/82 Otis 11/9/82 CAMCO 10/22/82 Otis 11/7/82 GO 11/18/82 4/82) RECEIVED DATE Victoria Aldridge Development Geology Well Records TP1-5 SOHIO ALASKA PETROLEUM COMPANY SYO ARCO CHEVRON EXXON GETTY TO: SFO/UNIT/STATE: (-Mar a tho n) MOBIL , . PHILLIPS '~' STATE OF'AK ! BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) 3111 "C" STREET ANCHORAGE, ALASKA IELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 11/17/82 Trans.#: 2855 CC#: 55855 REFERENCE: ' - I0 CASED HOLE FINAL LOGS T~e f~ll~w~gng %ter~al 7s being submitted herewith. Please acknowledge receipt bY signing a copy of this letter and returning it to this office:-- A-15 E-18 H-6 R-2 DDNLL/GR 8/16/82 #1 1055-11538 Dres 5" Spinner 10/27-28/82 10800-11170 Camco 5" Temperature Survey 11/1/82 #1 9600-10005 Camco 5" Temperature Survey 11/5/82 #1 9300-10200 Camco 5" (4/82) RECEIVEO DATE ........... Victoria Aldridge Development Geology _ ~9 TP1-5 ~Ias~a o~ & Gas coas. co~~ Records ~ohofag~ SOH I 0 CONF I DENT IAL SOHIO ALASKA PETROLEUM COMPANY · ARCO _~-- .- :._- TO: 'SFO/UNIT/STATE Logs Indexedn/a / 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Da%e: 9/9/81 REFERENCE: SOHIO FINAL DATA'- · following material is bein~'~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and return!ng it.to this office:.-- SFO/ARCO/EXXON/PHILLIP S / STAT'E~ Magnetic LIS Tape Printouts not sent with tape. R-2 X-12 Magnetic Tape LiSting for Dresser Tape ~/ECC6951.00 " " " " " " f/ECC ? DDNLL 7/24/81 DDNLL "EcE'V~/t"~/C~'~"v~ -U/ask, ~,, :' ~- ~-v~"' r DATE aul, ~aS ~on~ ~ ~velopment Geology a~ehor~ °o~/8~/on Well Records ' SOHIO CONk DENT I AL SOHIO ALASKA PETROLEUM COMPANY C.h~vro~ TO: SFO/UNIT/STATE: Mobil ...... - (-Marathon) l:~llil~ ......... - 31 1 1 "C" STBEET ANCHOftAGE, ALASKA '[EL[PHONE (907) 26b-0000 MAIL: POUCH 6 612 ANCHORAGE, ALASKA 99502 Dahe: 8/21/81 # 1000'E REFERENCE: A//~0HIO FINAL DaTA CASED HOLE FINAL DATA ~/'~l~e following material is being ~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-4' ~_6~,/ B-8 D_3~/ D_12y' D-13 D-15 L. F-4 ~' F-10 F-11 F-13/ H-ii M-4 R-2 J/' X-ll CNL (Sch) 6/25/81 H4 5" TDT-M (Sch) 7/2/81 H2 5" TDT-M (Sch) 7/22/81 H2 5" TDT-M (Sch) 7/28/81 H1 5" CNL (Sch) 5/29/81 H1 5" DDNLL (Dres) 5/25/81 H1 5" DDNLL (Dres) 6/13/81 H1 5" DDNLL (Dres) 7/12/81 H1 5" DDNLL (Dres) 7/27/81 H1 5" CNL (Sch) 6/27/81 H2 5" CNL (replaces final log (Sch) 5/21/81(correct date) #7 5" incorrectly dated 5/2/81) DDNLL (Dres) 6/24/81 H1 5" DDNLL (Dres) 6/23/81 Hi 5" DDNLL (Dres) 6/25/81 H1 5" DDNLL (Dres) 7'/13/81 H1 5" TDT-M (Sch) 6/29/81 H2 5" DDNLL (Dres) 5/8/81 Hi 5" DDNLL ~ (Dres) 7/15/81 Hi 5" DATE 19 ~pment Geology Records SOHIO ALASKA PETROLEUM COMPANY SOH IO COHFIDEI'tTIAL 31 11 "C" STREET ANCHORAGE, ALASKA TELEPt;ONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ARCO -to: EXXON Date: 7/30/81 #_972 PHILLIPS SFO /' REFERENCE: //.SOHIO MAGNETIC LIS TAPES ././~he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- *M.~4 Magnetic LIS Tape & Listing (Sch) #62001 7/17/81 #1 (Dresser) .Magnetic LIS T~'pe~ ECC 6951 7/24/81 DDNLL 9250' -,n~ , -~20 ('..." ~ / .~' ../' ' ,/~ ~'~~ ': iV::,: Carol Krieter DATE 19 .__ Development Geology ?~L~'~'~:"~'~'~ '~'~' ~'~'~'~'~ ~' Well Records t[Q 4-5 /',p(": ,:~ SOHIO ALASKA PETROLEUM COMPANY SOH IO COHFIDENTIAL 3111 "C" STF~EET . ANCHORAGE, ALASKA IELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ARCO TO: EXXON Date: 7/30/81 PHILLIPS SFO REFERENCE: /~OHIO MAGNETIC .LIS TAPES ~-he followin§ material is bein§ submitted herewith. Pie@se acknowled§e receiot by signing a gop¥ of this letter and returnin§ it to this office:- *M.~4 Magnetic LIS Tape & Listing (Sch) #62001 7/17/81 #1 Magnetic LIS TJpe (Dr esser) ECC 6951 7/24/81 DDNLL 9250'-10220' DATE Carol Krieter Development Geology Well Records HQ 4-5 SOH I 0 CONF I DENT IAL SOHIO ALASKA PETROLEUM COMPANY CJ~v~:m ,- z _- il Logs Indexed I L. uIvww '--i ANCHORAGE, ALASK I 'S- AT TEC MAIL: POUCH 6-61 4.5~ J-~O~FER]---- Date: 7/L/81 A-1 B-9 B-9 B-9 B-16 D-4 E-2. E-2 F-3 F-6 F-8 F-14 G-2 G-3 H-8 J-5 J-6 M-8 N-1 Y-7 X-12 MPC (11) 33-11-12 REFERENCE: SOHIO FINAL DATA CASED HOLE The following material is being' submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- CCL/Perf CCL/Perf 'COL/Peri S p inner CCL/Perf CNL - CNL CNL CNL CNL CNL DDNLL CNL CNL S p inn er CNL CNL CBL/VDL TDT-M EPL CNL CBL DDNLL CBL/VDL (Sch) 4/14/81' II-- (Sob) 4/26/81 ¥/3 (seh) 4/22/8i (Camco) 5/14/81 ,~t-- (sch) 4/2o/81 (Sch) 5/2/81 ¥/5 (Sch) 4/28/81 (Sch) 4/28/8i ¥t8 (Sch) 5/1/81 ,//6 (Sch) 5/8/81 ¥t3 (Sch) 4/29/81 (Dres) 4/23/81 (Sch) 4/30/81 t/5 (Sch) 5/1/8i (Camco) 5/25/81 !/-- (Sch) li/23/80 (Sch) 5/8/81 ¥/2 (Sch) 5/6/8i !ti ('Sch) 4/23/81 fib (Sch) 4/].7/8i Iii (Sch) 5/7/8i //2 (Go) 6/19/81 (Pres) 4/21/81 (Sch) 4/21/81 Iii 1! 5'~ 5~ 5~ 5~ 5~ 5~ 5'~ 5~ 5~ 5~ 5~ 5~ 5~ 5~ 5~ 5TM 5~ 5~ 5~ 5~ 5~ 5~ 5~ DATE~-/~''~ / ' ,JUL U 6 iL):'iil 19 Alaska 0il & Sas Cons. :'-'~rzhoragc Carol Krieter~ Development Geology Well Records · SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" S'fREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION TO: ARCO EXXON PHILLIPS SFO STATE / R E ~-~ ~ ~--ii~. . SOHIO /'~GNETIC ~IS TAPES MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 2/10/Sl #~_3 .. /./The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- F-5 Magnetic LIS Tape & Listing #2 12/9/80 #61247 ,, ,, ,, ,, R-2 Tape & Listing is mislabeled as R-Z dated 1/8/81, It should be corrected to R-2 dated 3/3/80, Re;Magnetic LIS tapes sent on 1/29/81~ N-7 should have read N-m, Well Records RECEIVED DATE 19 Alaska Oil & Gas Cons. Colnmissi(]n . -,. s~-'i ~OL~ ,.O~ ~ TELEPHONE (907)2fl~0'fl0~ ~O[/ __.I ~ FILE: .......... ] TO: SFO/UNIT/STATE Mobil -- ___._. 9/16/80 #357 REFERENCE: SOHIO FINAL DATA ',~.~h~e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- STATE/UNIT/SFO (-Marathon) R-2 Spinner Survey 8/23/80 #1 5" Carol Krieter Well Records DATE coMA'Y- COMM':/c''"' SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: SFO/UNIT /STATE 9/3~80 #333 Phillips ........ BPAE , , , REFERENCE: SFO/UNIT/STATE: (-Marathon) Sohio Data ~..,/,~'The following material is being submitted herewith. Please acknowled¢ receipt by signing a copy of this letter and returning it to this office:- 'd~C-5 _~ Bottom-Hole Pressure Data Form & Survey 7/28/80 " " " " " " 8/~l/8O ~- " " " " " " 8/17/80 " " " " " " 8/~z/8o LX z " " " " " " 8/8/8o (Dressc (Go) (So) (Otis) (.Sch) {.-~'. 6.~ Carol Kridter Well Records DATE 19 SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: STATE OF ALASKA "C" STREET RAGE, ALASKA )NE (907) 265-0000 ,: POUCH 6-612 ~GE, ALASKA 99502 5/29/80 tt173 REFERENCE: Retransmittal of Gyroscopic Surveys previously obscured by stamp. ollowing material is being submitted herewith. Please acknowledge receipt by signing a of this letter and returning it to this office:- C-9 0yroscopic Survey C-12 " " D-10 " " G-5 " M. 6 Il !1 R-2' '~ " " X-1 " " TW"B" " " TW"C" Gyroscopic Survey 7/18/79 1/6/80 1/16/80 4/25/80 8/16/79 7/14/79 11/9/79 7/14/79 5/1/79 Carol Kr ie tx~r Well Records 19 .'--t ~ :~ · SOHIO PETROLEUM OOMPANY .... -":-s- ~,~'r'~;f~ ............. D,v,s,on of Soh,o Natural Resources Company [ 1 .... :_.: ~'-_~iNCHORAGE. ALASKA .. · l'Z,]-'-'i O~0L-t-~'~EPHONE (9O?)265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION ~---F'-6' ~_~O[-~/...1' ' /%l~l'~f) , - ' '." :-~'~' I o ~--, -.~ ANCHORAGE. ALASKA 99502 ...... _± ..... [STATTEC / c.~- , ' ' 1~ S~A~'~c--1 ~.,,:,~o,, _ , ' ' l~ ........ --1 SFO/UNIT/STATE iFILF:-" _._ 4~]/18/80 #1Z0A REFERENCE: A-2 SFO/UNIT/STATE: C-7 FINAL CASED HOLE: E-2 (-Marathon) F-13 R-6 R-6 X-4 X-5 PRESSURE SURVEYS :~D-i~, ~ JE-3~ ~'~ , .,_ / E-4J SFO ~ ease acknowledge SOHIO DATA ,~T~he following material is ~ing submi~ed herewith. PI copy of this le~er and returning it to this office:- Spinner 3/8 /80 EPL 3/3/80 EPA 3/7/80 Temp. Log 3/4/80 Spinner 3/7/80 DDNLL 3/3/80 TDT-M 3/14/80 TDT-M 3/13/80 EPA 3/11/80 Mudlog 12/25/79-1/23/80 Temp. Log 3/5/80 Spectralog 2/20/80 receipt by signing a 5" 5" 2",/5"(1 Log) 5" 5" 5" 5" 5" 5" 5" 5" Bottom-Hole Pressure Data Form& Il Il Il Il Il II II II II II I1 I1 !I II II Survey 3/10/80(Otis) " 3/17/80(Go) " 3/16/80 (Otis) " 2/11/80 (Go) Carol rze er Well Records RECEIVED DATE SOHIO ALASKA PETROLEUM COMPANY February 1, 1980 Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 ANCHORAGE, ALASKA !' TELEPHONE 1907)265-('~'0j' 3''r:,,~'';~ I _ CONFER: ~ FILF: Attn: Mr. H. H. Hamilton Well R-2 (33-31-12-13) Enclosed, in duplicate, is Form P-7, Conl01etion Report, for the above-named well together with the Well History. This well has been perforated and is now on production. P~PJ: ja Enclosures cc: Well File #17 Yours very truly, SOHIO ALASKAPETROIAJ3MCCMPANY P. R. Judd District Drilling Engineer Yorn~ P 7 .... ~ SUBMIT IN STATE OF ALASKA (s~.e other In- st ructions on reverse side/ §. AP1 N~CAL CODE OI/ AND GAS CONSERVATION COMMITTEE 50-029--..20354 W£LL cOMPL£IION OR REfOMPL£11ON REPORT AND LOG* w ELL w ELL DR ¥ Other b. TYPE OF COMPLETION: WELL OVER EN BACK nESVR. Other 2. ~,~,~ oF oP~.,,~o~ Prudhoe Bay Unit Sohio Alaska Petroleum Company s. W~.L ~O. S. AOD~SS OF O~^~o. R--2 (33-31-'12-'13) Pouch 6-612, Anchorage, AK 99502 ~0. Fm,.~ ~ ~OOL, O~ W~C'~ 4. LOC^T~ON OF W£LL (Rel;ort locatio~ ¢~earlg and in a¢¢orda;loe wi~h ar~;I ~tat¢ reqttirer~ts)* ~t ~,~. 638' NSL, 969' EWL, Sec. 32~ T12N, R13E, UPM At top prod. Interval reported below 2397' NSL, 1490' WEL, Sec. 31, T12N~ R13E, UPM At total depth 2638' NSL, 1681' WEL, Sec. 31, T12N, R13E, UPM ~. P~i~o. 78-.] n~ .. 6/13/79 | 7/2/79 | 1/17/80 ! I<BE =: 5~.97~ AMSL. ~ 21.09' AMSL 'kc~r^L DEPTH, 5TD & ~VD[19. PLUG I~P~CK MD & TVI~. IF 1VfULT~PLE COIV~PL., 21. INTERVALS DRILLED BY ~ ! I-~OW~Y* ROTARY TOOLS ' 'l ' CABLE TOOLS 10303'MD 9461'T~ 10225'MD 9392'T~D None Total [ Top: 9662' MDoo./.~ 'TVD l! SURVEY MADE Prudhoe Oil Pool: Bottcm: 9730' MD 8958' TVD ! Yes 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIA.N, A/~LOTTEE OR TRIBE NAME ?rudhoe Bay,Prudhoe OilPool 11. SEC., T., lq,., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN DIL/SP, BHCS/GR, .FDC/CNL/GR/Cal 25. CA~SI1NI G SIZE 30"x20" 13 3/8" 9 5/8". 7" CASING RECORD (Report all strings set in well) In'~ulated qonduct{r .... li0'[ 36~ [651 cu. ft. Arcticset 72~ ! L-80[ ~.628'[ 17%"[ 5348 cu.ft, permafros, t 29~47~ '[[ L-80[_ . .~307'[ !2¼"[8½.,[ 1288 cu.ft. ClassG; 13'0culf~.Perma~ost C L-80~' 8815-16302 '| 430 cu. ft. Class G 26. LINER I~ECOI{/~ ] 27. TUBING 1RIDC, OP~.D 7" ~70' ; 9.8. PERFORATIONS OPEN TO PRODUC~O (In%ervaI, size and number) ';.9. ACID, SHOT, F?~CTURIE, CEaVIENT SQUEEZE, ETC. 9662'-9687' Bl~3 0.5"@ 4 s.p.f. (Ref.~ICS/GR 7/2/79) q6q7'-q71~' " " " " " 30, PRODUCTION DATE FIRST PIIODUCTION 1/17/80 DAT~ OF T~T, FLOW, TUBING PT{ESS. 31. DISPOSITION OF DEi-~TI-I INT]~IRVAL (MD) AMOUNT AND KIND OF MAT~PJ~AL USED PtlODUCTION ME'iHO'D (Flowh~g, gas lifL pumping--size and type of pump) Flowing CItO;<E SiZE [PROD'N FO,R OIL--BBL. G.%S---IVJ~CF. GAS (Sold, used for 7'uel, vented, etc.) 32.LIST OF ATTACHMENTS Well History WELL .STATUS (Producing or [ ~nut-xn), Producing 33. I hereby certify that tJ~e~oing and attached Information 1. complete and correct as determined from allVavatlable records / / EFW ml~m~m'- ~--- T,TL~.Oistrict Drilling Engineer DXTE '~/¢/¢~ : P. R. OU(~ - - , *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct ,.,,.ell completion report end log on all types of lanJs and leases tr'~ Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shovvn/ for depth measure- ments g~ven ,ncther spaces on this for~x~ and ~r~ a~y Items 20, and 22:: If ti~ls well is completect for separ,~tc [)r;'c]wc'~ior~ lro,', r'~orC th,~rh one ~t~,rval zone (multiple completior~), so stste ~m ~ten~ 20 8nd top(s), bottom(s) and n~me (s) (if anW) for only the tnter~.~ ra~orted ~r~ ~te,~ 30 St~b~:t a sep.~rate repor' (page) on this form, adequately identified, for each add~tior~l ir~tetvat to be seperately produceJ, show- ing the a~itional dora pertinent to such interval. Item26: "S~cks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing ~nd the location of the cementing tool. Item 28: Submit a separate completion re~rt on this form for each ~nterval to be separately produc~. (~e instruction for items 20 and 22 above). 34. SUMMARY (3F PORMA'PION TE2S'I'.~ INt'I,LII)IN(; INTIqRVAL TF~qTED PltE~qtJRE DATA ~C()VERIF~ OF OIL GAS. 35 G~GIC MARK~ WATER AND MUD NAM~ MEAS D~{ ~U~ . , B~ ~S~ Sag ~ver SST 9361' 8580 Sh~lik 9407 ' 8620 Ivish~ 9508' 8709 .,, ....... ,t .... WEI.I. R-2 (33-31-12-13) HISTORY June, 1979 Spud well at 1830 hours, June /3, 1979. Drilled 17 1/2" hole to 2670'· Ran 66 jts. 13 ~3/8" 72~ L-80 Buttress casing to 2628'. ~ted with 5348 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2586', tested casing to 3000 psi. Drilled out to 2680', ran leak-off test. Directionally drilled 12 1/4" hole to 9310'. Ran 238 jts. 9 5/8" 47~ L-80 Buttress casing to 9307'. C~ted in two stages: First stage with 1288 cu. ft. Class G cement; second stage through DV packer at 2599' with 130 cu. ft. Permafrost cement preceded by Arctic Pack. Cleaned out to 9264', tested casing to 3000 psi. Drilled out to 9317', ran leak-off test to 0.7 psi/ft., gradient. Directionally drilled 8 1/-2" hole to 10152'. July, 1979 Directionally drilled 8 1/2" hole to 10303'. Ran open hole logs. Ran 38 jts. 7" 29~ L-80 Buttress casing to 10302'. C~-~nted with 430 cu.ft. Class G cement. Cleaned out to 10225', tested casing to 3000 psi. Changed well over to NaC1. Ran CBL log. Ran 222 jts. 7" 26# L-80 AB-IJ-4S tubing to 8870'. Landed tubing vrith ball valve ni ple at 2002' Installed and tested tree. DisPlaced tubing to diesel. Set production packer at 8765', tested tubing to 3500 psi. Released rig at 0600 hours, July 8, 1979. December, 1979 Pressure tested tubing and inner annulus. January, 1980 Rigged up S~htumberger and perforated the following intervals using- 2 7/8" _c~ns @ 4 s.p.f.: 9662-9687 Ft, BKB (Ref. BHCS/~R, 7-2-79) 9697-9730 Ft. BKB (" " ") Closed in v~ll in preparation for static pressure survey. Ran static pressure/temperature survey at 8800 ~ft. TVDss. Set and tested insert sleeve, and SSSV in ball valve nipple ca. 200Q ft. Well on production. SOHIO ALASKA PETROLEUM COMPANY January. 30, 1980 i COM : ..... ~ ~..=.,,.~ .. 31~'1 "C" STREE~ ~ ...... : .... 5 ANCHORAGE, ALAS~ RES ENG TELEPHO.E (907, 2~~ ~-E~'~"~-- MAIL: POUCH ~61~"'3 r~bj~-- - ANCHORAGE ALASKA~02 · ~ ~-z~ .......... i I STAT THC I TAT TE% I ~, CONFER: J State of Alaska Depar~t of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine DriVe Anchorage, Alaska 99509 Attn: Mr. H. Hamilton Re: Well R-2 (33-31-12-13) Gentlemen: Enclosed please find, in duplicate, Form 10-403, Sundry Notices and Reports on Wells; and Form 10-404, ~bnthly Report of Drilling and Workover Operations, for the above-referenced well. Very truly yours, SOHIO ALASKA PETRO~ COMPANY J Plisga District Field Engineer Enclosures cc: S. Bundy A. E. Leske Drilling File .A,qOilora.g~ Form 10-,403 ,REV. 1-1(%73 Submit "1 ntentions" in Trlpli~ate & "Subse~luent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L i--~ GAS I'"] WELL V.~i' WELL OTHER 2. NAME OF OPERATOR Sohio Alaska Petroleum Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, AK 99502 4. LOCATION OF WELL At surface 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54.97' ~L 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit West 9. WELL NO. R-2 (33-31-12-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAIRING WELL FRACTURE TREATMENT~_~ ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent der&lis, and give pertinent dates, including estimated date of starting any proposed work. The following intervals were perforated during January, 1980, using Schlumberger 2 7/8" guns @ 4 s.p.f.: 9662-9687 Ft. BKB (Ref. BHCS/GR, 7-2-79) 9697-9730 Ft. BKB (" " ") A SSSV was run and tested in the ball valve nipple, and the well put on production. 16. SIGNED/74'~~ ~ ~ TITLE District Field Enqineer (This space for State~ffice use) DATE . [ APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Form No. 10-404 R~EV. 3-1-70 SUBMIT IN DUPLICATE STAT E O F A LAS KA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-.20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 0iL GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Alaska Petroleum Company Prudhoe Bay Unit West 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, AK 99502 R-2 (33-31-12-13) 4. LOCATION OF WELL 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 10. FIELD AND POOL, OR WILl)CAT Prudhoe Bay, Prudthoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. December 23, 1979: Pressure tested tubing and inner annulus. January 17, 1980: Rigged up Schlumberger and perforated the following intervals using 2 7/8" guns @ 4 s.p.f.: ., 9662-9687 Ft. BKB (Ref. BHCS/GR, 7-2-79) 9697-9730 Ft. BIG3 (" " ") January 26, 1980: Closed in well in preparation for static pressure survey. January 28, 1980: Ran static pressure/temperature survey at 8800 ft. TVD ss. January 29, 1980: Set and tested insert sleeve and SSSV in ball valve nipple ca. 2000 ft. Well on production. 14. , hereby certi/~a~.h~ forego_i~tr, ue _and correct SIGNED JF~--~I~~ ~-'I~~ TITLE District Field Enoineer DATE.. t 30 O NOTE-Report on thisMf/orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Division of Sohi~ Naturul Resources Company SOHIO--BP ALASKA PROgUCTION DIVISION November 15, 1979 · } (- ' ANCHORAGE, ALASKA TELE?HONE (907) 265~0000 · MAIL: POUCH 6-6i2 ANCHORA¢;E, ALASKA 99502 State of Alaska Department of Natural Reseurces Divisien of Oil & Gas Conservatien 3001 Porcupine Drive Anchorage, Alaska 99509 Attn: Mr. H. Hamilton Re: Wells R-1 (44-31-12-13)~R-2}33-31-12-13) Gentlemen: ; and R-3 (41-31-12-13) Please find attached, in triplicate, Form 10-403, Sundry Notices and Reports.on Wells, containing ourproposal to perforate Wells R-i~ R-2, and R-3 for production. Perforating of Well R-2 would result in a violation of the Prudhoe Bay. Field Rules, Rule 2 of Conservation Order No. 130, which states, "...nor shall any pay opened to the well bore...be closer than 2.000 feet to any pay'in ~e same pool opened to well bore of another well." At the deepest (closest) perforations, the well is 1968 feet fr~n a similar point in Well M-4 (23-31-12-13) as per the gyroscopic surveys of each well. As shown on the Application for Permit to Drill R-2 compared to the Completion Report for Well M-4, the two wells were in- tended to be greater than 2000 feet apart; however, during the course of directional drilling Well R-2, circumstances arose causing the proposed subsurface target to be missed. We would like to apply for an exception to the footage spacing re- quirements of Rule 2 of Conservation Order No. 130 to permit ~e perforation of Well R-2 approximately 1970 feet from Well M-4 in order to utilize an existing well bore. GIP:MJS:mlh cc: Mike Smith A. E. Leske Drilling File CC% 16,834 V~t:y yours, ~tIO/P~t~ROi~M CO~?ANY /.,., _~'~G. J. Plisga Form 10-403 REV. 1-10-73 Submit "1 ntentic, vs" in Triplicate & "Subsequent P,:~orts" in Duplicate STATE ~. ALASKA OIL AND GAS cONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-"" for ~uch proposals.) 1. OIL~ ~ GAS ['~ WEI'LD WELL OTHER 2. NAME OF OPERATOR Sohio Pe~.~'ole~ Co./ A D~v~s~o~ o~ Sohio Nat~al Reso~ces, Inc. 3. ADDRESS OF OPERATOR Pouch 6-612, A~chorage, Ag: 99502 4. LOCATION OF WELL At surface 638' NSL, 969' ~v-~, Sec. 32, T12N, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, e.tc.) KBE = 54 97' AMSL · Check Appropriate Box To Indicate Nature of Notice, Re .5..-~Pl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADT, 28279 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit West 9. WELL NO. ~R-2 (33-31-12-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPOR-~ OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion onWell Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~etalls, and give pertinent dates, including estimated date of . starting any Proposed work. The following intervals will be perforated during November/December, 1979, using Schlumberger 2 7/8" guns @ 4 s.p.f: 9662 - 9687 ft. BKB (Ref. BHCS/GR 7-2-79) 9697 - 9730 ft. BKB (" " ") A SSSVwili be set & tested in the ball valve nipple ca. 2000 ft. .. 16. I hereby certify that the foregoing Is true and correct S I OANE D .___--_..--i--~.~.2-9' ..... . TITLE E._~.. G. o. ~±~sqa ' ~ .(This space for State offl.q~use) ~,~ { ) APPROVED BY - · TITLE District Field Engineer See Instructions On Reverse Side WEI,I, R-2 (33-31-12-13) WEI.L HISTORY June, 1979 Spud well at 1830 hours, June 13, 1979. Drill,ed 17 1/2" hole to 2670'. Ran 66 j%s. 13 3/8" 728 L-80 Buttress casing %o 2628'. Cemented with 5348 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2586', tested cas'.~ng %o 3000 psi. Drilled out to 2680', ran leak-off %est. Directional!y drilled 12 1/4" hole to 9310'. 'Ran 238' jts. 9 5/8" 47~ L-80 Buttress casing to 9307'. Ce/nented in two stages: First s~ge with 1288 cu. ft. Class G cement; second stage thrOugh DV packer at 259.9' with 130 cu.ft. Permafrost c~nent preceded by'Arctic Pack. Cle ,aned out to 9264' tested casing %o 30'00 psi. Drilled out %O 9317' ran leak-off %est %o 0.7 ps±/ft., gradient. Directional!y drilled 8 1/2" hole to 10152'. July, 1979 Directionally drilled 8 1/2" hole to !03Q3'. Ran open hole logs. Ran 38 jts. 7" 29~ L-80 Buttress casing %o 10302'. Cemented with 430 cu.ft. Class G cement. Cleaned' °9~co-t0225'~ tested casing to 3000 psi. Changed well over to NaCi.t.I_tl~n~CBL ~_~, Ran 222 its. 7" 26~ L-80 AB-IJ-4S tubing to 8870'. Land~cl~{~g with ball valve nipple ah 2002'. Installed' and tested'tree. Displaced tubing to die~ei. Set production packer at 8765','tested tubing to'3500 psi° Released rig at 0600 hours, JulY 8, 1979. Fc~rm 1 0-403 ,REV. 1-1~0~7 3 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proDosals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 5. APl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIAN, ALLOTTEE OR TRIBE NAME ~ NAMEOFOPERATOR Sohio Petroleum Co., A Division of Sohio Natural Resources, Inc. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, AK 99502 4. LOCATION OF WELL At surface 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 54.97' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit West 9. WELL NO. R-2 (33-31-12-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ~ec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 3o~, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS [Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF i~ REPAI RING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals will be perforated during November/December, 1979, using Schlumberger 2 7/8" guns @ 4 s.p.f: 9662 - 9687 ft. BKB (Ref. BHCS/GR 7-2-79) 9697 - 9730 ft. BKB (" " ") A SSSVwill be set & tested in the ball valve nipple ca. 2000 ft. 16. I hereby certify ~~s true and correct SI~.NED 1%//~lf i (T~i~:pace for State AP".OVEDaV ~ ~ T~TLE CONDITIONS OF~PPROVAL, IF BY ORDER OF ~ Instructions On Reveme Side TITLE District Field Engineer DATE. II/l~h~ DATE SOHIO PETROLEUM COMPANY Division .of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: S]',:J.{ O? AL,~..,;<A e~.¢'i Porcupine Drive f%~ohorage, Alaska 90501 31il "C"STREET At'JCldO RAG E, ALASKA TELEPttONE (907)265-0000 MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 Unit/P&P/S~ate Sep~er 6, 1979 REFERENCE; Well Data Transmission The following material is being submitted herewith. Please.acknowledge receipt by signing a copy of this letter and returning it to this office:- logs for hhe 'follc~cing Sohio oparated vzell,~':- C-6 EPL RLln 1 G-1 EPL Run 2 F-7 177I~M Rim 3 t{-5 TlYf-M RLm 1 A-1 TEf2-M Run 1 J-7 ~-M ~ 1 C-8 ~M ~ 1 ~6 ~L ~ 1 C-10 ~at~e ~ 1 R-1 " ~ 1 M-6 " ~ 2 ¢~ " ~ 2 B-1 ~M ~ 1 N-1 ~f-M ~ 1 A-8 ~M ~ 1 M-3 ~-M ~ 1 A-6 ~~ ~ 1 ~6 ~~ ~ 1 C-6 Transient P~essure & Spinner/Data Packet. II II II II II 8/4/79 8/1/79 19 Co].ette Tracy Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTIQN DIVISION TO: '3001 porcupine Drive Anchorage, Alaska 99501 } L"ut'n~v'v~ ! 3111 "C" S FRI~E~, ~ ~; ~,~':,.' ANCHORAGE AL~A KA ' TELEPHONE (9( 7)-~6~0D0¢~ - ~ MA L: P UCH-~61.~..~'-~ ' rqLF: ' ~ REFERENCE: Well Da%a Transmission The following material is being submitted herewith. Pleas~ acknowledge receipt by signing a copy of this letter and returning it to this office:-~..- Magnetic tapes for the following wells: G-6 #55507 .T.e~Well B / ..... R-2...~ ~55634 Run 1 7/9/79 OH #55510 Run 3 7/23/79 Run 1 7/2/79 OH OH Colette Tracy Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION July 25, 1979 Alaska Oil & Gas Conservation Cc~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Well R-2 (33-31-12-13) Enclosed, in duplicate, is Form P-7, Completion Report for the akove-namedwell together with the Well History, Well Logs, and Directional Survey, MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 This well has been suspended pending perforating operations. PRJ: ja Enclosures cc: Well File ~17 Colette Tracy Yours very truly, SOHIO PETRO~ COMPANY P. R. Judd District Drilling Engineer Form P--7 SUBMIT IN DUP STATE OF ALASKA (see o' ,er m- structlbns on reverse side) OIL AND GAS CONSERVATION COMMITTEE 5. APl NUMERICAL CODE 50-029-20354 6, WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS I'--'l 7. WELL[~ WELLI__J DRY J-~ Other b. TYPE OF COMPLETION: LEASE DESIGNATION AND SERIAL NO. ADL 28279 IF INDIAN, ALLOTTEE OR TRIBE NAME NEW [] WORK~ DEEP-(--'I PLUG I---1 DIFF. WELL OVER ~ EN I I BACK I I RESER. ~ Other 2. NAME OF OPERATOR Sohio Petroleum Ccmpany, Div. of Sohio Natural Resources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface 638' NSL, 969' EWL, Sec. 32, T12N, R13E, 'UPM At top prod. i,terval reported below top Sag R. SST. 2287' NSL, 1396' WEL, Sec. 31, T12N, R13E, UPM At total depth 2638' N~L, 16Sl' WS~L, Sec. 31, T12N, R13E, UPM 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. (R-2/ (33-31-12-13) 16.~F-IEI~D AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe Oil Pool 11 · SEC., T., R., M., (BO/TOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 7 8-100 6/13/79 7/2/79 7/8/79 KBE = 54.97' AMSL '""". 21 09' AMSL 18. TOTAL DEPTH, MD&TVD I19. PLUGBACK MD&TVD]20.1F MULTIPLECOMPL., I CABLE TOOLS ] DEPTH , HOW MANY* 21. ROTARY TOOLS INTERVALS DRILLED BY 10303'MD 9461'TVDI 10225'MD 9392'TVD] None I Total 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL SURVEY MADE None Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/GR, FDC/CNL/GR/Cal 25. CASING RECORD (Report all strings set in well) CASING SIZE 30"x20" 13 3/8" 9 5/8" 7" WEIGHT, LB/FT, / GRADE I DEPTH SET (MD) Insulated C~nduct~r 110' i ~,-8o ! 2628' 47~ IL-80 ! 9307' 299 IL-80 18815-10302' LINER RECORD HOLE SIZE ] 36" 651 17½" 15348 12¼" 11288 8½" 1430 CEMENTING RECORD cu.ft. Arcticset cu.ft, permafrost cu.ft. Class G;130 cu.ft. Class G AMOUNT PULLED ft. Permafrost C 27. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 8870' 8765' 29. ACID, SHOT, FRACIURE, CEMENT SQUEEZE, ETC. SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) None DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30. DATE FIRST PRODUCTION PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, DumPing--size and type of pump) WELL STATUS (Producing or shut-In) DATE OF TEST. I HOURS TESTED ICHOK E SIZE ITEsTPR OD'N, PERIoDFOR~ I PI L--DB L. 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) I GAS--MCF. I WATER-DB L. JGAS-OIL RATIO lOlL GRAVITY-APl (CORR.) I I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Well Histoz¥, W~.I~L Loqs, Directional Data 33. I hereby certify that t~e~~ at~tach~mation Is co~nplete and correct as determined from all available records. , SIGNEDpo t~. ~ TITLE District Drillinq Engineer *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item' 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH TRuE VERT. DEPTI BKB Subsea Sag River SST. 9361' 8580' Shublik 9407 ' 8620 ' Ivishak 9508 ' 8709 ' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. , , d. A. Fouch~ President July 18, 1979 Mr. Gary Plisga Sohio-BP, Alaska 3111 C. Street Anchorage, AK 99503' Re: Our Boss Gyroscopic Survey Job No. Boss-16424 Well R-2 Prudhoe Bay Field North Slope, Alaska Date of Survey: July 14, 1979 Dear Mr; Plisga: Please find enclosed the "Original" and sixteen (16) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this Opportunity to be of service. KB/kc Enclosures Yours very truly, SpERRY-SUN, INC. Ken Broussard District Manager Anchorage PPU3HDE BAY AL/~SKA coMPuTATION DATE dULY 17, !979 t,~ E/~ S U R E D DEr'TN VERIICAL DEPTH VERTICAL INCLINATION DI REC'TION SEVERITY DEPTH DEG MIN DEGREES DEG/1 O0 E Y~OSCOPI C '~"UR'V'Lr~ dOB NUMBER BOSS-IGC-24 KELLY BUSHIN6 ELEV, ~PAGE I ' 1979 5q.97 FT. RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECTION '0 100 200 306 AD0 500 6 '0 7 o. o: 900 8~.97 8a5.00 0 1000 99~.97 ~]qS.OO 0 300.00 2~5-03 0 5 z~O0.OO 3A5.03 0 : 11 500.00 4"+5.03 0 37 N 27.10 E N 76,69 E N 59. 9 E .15 3q- N 32..29 E .09 31 N 31.60 E .05 :i"37. N .04 .59 N .53 E -.07 · 91 N 1.16 E -,37 -,72 -. ~ 7 ~+o11 E 4.62 E -.76 llO0 1099.96 1200 1199.96 llq~. 1300 1299.95 1. a, 00 !.3.99.95 1344' 1500 lqgg.9q 1600 1599.93 1700 1699.92 1800 1799,91 1900 1899.91 2000 1999.91 15flq.9 16~4.95' 174.4.94 I 8'~. 9q 19~4.9q 2100 2099.90 20z~fl.93 2200 2199,89 21qq.92 0 22. N' 27.39 E ,16 5.54 N ·: ":' ' '' ~::'~: ' ~" 9 0'.... ...~ :35 ..:.::3:7:,2 E 3 "'' 2e N 9 E ' O'q' ;::]:::8:'10N o ~5 ~j ,i~;5o E .l~ 9.05 N 5.01 E · 5 ~ E [,:;:]:'o: E:: ..: 6.76 0 49 N 62.29 E 0 ~ 1 N 70.69 E 5~ N 8q .19 E 51 N 63.90 E · 25 9.85 N .17 10.38 N · 18 ' N N '26 1.0'.70 N .2'9 10'85N .32 11,2 6 N 7.57 E 8.67 E 9.87 E 10 '91 ' ll.7q 'E 12,63 E i'3 .'96' "E' 15 .~2 E -.66 --Gl -.57 -°52 -.59 -.98 -1.62 -2.94 -3.6~ -4.60 .... -5.52 2300 2'+00 ~_500 2299.88 22q~a,. 91 2,'599'87 , 23qz~.90 ~99-~ .2,~,~', · ~ o 2599.87 25~'90 2700 2699.8a 26~.87 ~ G 29 N 9.60 E .70 12.01 N '~ii~'O :i:36 ' N:: :9:"20 'WI' ,': "21 .12'95'N- ""~0.: :'7 29 :.: N: 19:,10'W: 1:3.87 N 0 : 8 S 22.79 W · 1~.16 N 1 53 S 35'29 W "i'"-'75 2750 2.800 ...... 2~50 27~+9.~1 269z~.8~ I 51 N 8~.60 W 3.76 2799.77 27~+.80 2 5q N 68.10 W 2.q~7 12.66 '28fl9,68: :.i 279%'71 3: N 59-:10 W:'. ': :.:14'O0 16.17 E 16 o15 E 15.93 E 15 .?z~ E 12.70 N 12.11 N N N 14.74 E 13 .q6 E 11 .qB E 8 '8~+ E -5.67 -q.03 -3.45 -1.5:.9 SOh]'O ER AL F,-~ PcUDHDE BAY ALASKA ~FASURED VERTICAL VERTICAL DFPTH DEPTH DEPTH JULY 17, 197':) INCLINATION DIRECTION SEVERITY DEG MIN DEGREES DEG/IOO dOB NUMBER BOSS-16424 KELLY BUSHING ELEV. : 54.97 FT. RE gTANGULAI~ .... '--Q'~'~C~E NORTH/SOUTH EAST/WEST SECTION 5~00 t ~000 ,? ~100 6200 6300 6qOO ~500 6600 s7o o $800 6452.41 6377.44 6900 6519.6fl 6464.71 7C00 6606.86 6551 705O BODO .01 5gsa.o,+ 28 ~ 60~1.91 ~026.~,+ 28 s2 ~500 P. 500 B6OO R7CO oRO0 9ODD 9100 9200 :SOO 970& W N 59.50 W .10 N 59.20 W .19 N. 59. 0 W .26 N 58.29 ~ .38 N '58.89 W .30 N 52. OW N 51.70 W N 51.20 W 50.9y 1197,79, ..46 'W: 1244,63 i-2~l--JG'3 735.69 N 1122.10 W 1338.82 760.00 N 1163.11 W 1386.20 3.84 : N t2 1481 · 58 .. , . :::':8 87,~7..:u z s2~. ~7 , ,.. 7809.21 ~ I 27 N 49'59 W' -ql ~f~m~.o~ ~0~'0'~.~~ ~ ~.~,_,,~ ~ .2'7'' 62~q.65 8~20 ,67 8265, 70 866~.93 8613.96 '~ N 4D.89 W 2.68 A756.51 87D1.5~ 28 -~(J N ~0.89 W .39 BA44,26 R789.29 2R 3~, N ~0.20 W 8932.01 8877.04 28 34 N-qO~ '0' W .10 858.19 N 1328.97 W 1577.74 883.58 N 1370.66 W 1626.31 909.11 N 1412.~9 W 1675.07 .29 .22 · 29 1524.89 · N'SOJ. 79 ,31:: : :'-1358'~6 :5o..,.. 76' i 3 ~ 2.28' :: 1433'46': W 1699,51 1226.32"N .:' 18'70,35 W 2231.62 1258','79' N 191'2','22' W LF2f14,'60 ..... 1291.69 N 195~.10 W 2337.85 N 1995.76 W 2391.10 N ~2037,'22 W N 2078.10 ~ 2~97.~3 1426.17 N 2118.06 W 2549.73 .... i'~60',2'?" N .... 215i ;50" W ...... 2~-D[;75 .... 149~.30 N 2196.o, 4 W 2653.34 1527.92 N 2234.78 W 2704.19 1561.q0 N '' 2272.23 W 2756.~ 1594.9q N 2308.77 W 2803.63 1628.23 N 23~.23 W 2851.9~ 1699,62 N 2q09,11 W 29~6.77 1736,06 N 2qq0.29 W 2993.62 1 772.7~ N' '2~ 71,~7 R-2 PRUnHOE AL/~SKA BP:AUASKA'i:F'ROOuCTz:ON~'DIVIS_ ..__ __ _ . _ _ _ _ ION ':;" COMPUTATION DATE P, AY dULY 17, 1979 ME'~.SURED D~-PTH VERTICAL VERTICAL INCLINATION DIRECTION DEPTH DEPTH. DEG M I I",I DEGREES )'PAGE 2 SEV ER I TY DEG/IO0 SURVEY dULY 14, '1979 BOSS GyR'O~'CO'Pi'c SURVEY ,JOB NUMBER BOSS-16424 KELLY BUSHING ELEV. : :TOTAL ' . RECTANGULAR CooRDINATES NORTH/SOUTH EAST/WEST 54,97 FT, VERTICAL SECTION 2900 ~_~50 3000 3100 "200 .5300 3098.53 3197.58 3296,19 .l~O0 350'0 :5600 3043.56 7 5 N 55,10 W 31A2.61 8 38 N 54.29 W 3241,22 10 21 N 55,50 W 3700 3gO0 4000 41 O.O' ~200 430D 3682.65 3776,44 3869,37 422~.60 qqO0 4500 4318.27 4406.98 1.56 1,56 1.72 27,20 N 10,65 W 35.12 N 21,81 W q.q.60 N 35,33 W 5'03 9.25 1.3.91 24-89 38,57 55,07 7~'65 3627.68 19 32 N 57,20 W 2.60 100,30 N 3721.47 21 2 N 57,50 W 1.50 119,00 N 3814.~0 22 16 N. 56.50 W 1,29 139,11 N 417~+,63 27 32 56.79 W .20 234,15 N 4263.30 27 32 ~.'i'D, 56,79 W 0.00 259,47 N 4352.01 27 2_5 °~,~l i'?.20 U .21 28q,60 N 120,00 W 156,20 149,20 W 190,78 180,15 W 227,59 21'~,88: W 266,70 325.21 W 400.63 363.90 W q46.76 402.60 W q92.80 q B 0 0 ~700 q~OO 5Oa 510 520 530 540 .'350 560 570 q672.22 ,461:7'25 0 4760,26 4705,29 0 4848,21 4793,24 O ~936,27 48~.1,30 5112,52 5200,58 5288.68 5376.~2 5464.99 4969-45 '::5'057.55 5145.61 5 2'~ S't 7i ..... 5321.~5 5~10,02 ........ N Y.20 N ~8 1,~~ 57.29 W .22 438.12 N 2~ ':" ~63'57 N N . 28....:'~. N 57'79 U ' · '.~ 5. Z.A,.34 N 2~ z~ N 57.~ ~ .z~ 5a~.52 N ~e ~ N 5~.1o ~ .o~ 5~.s5 N 28 7 N 58.10 W .06 5F, 9.~8 N qql-A9 W 538,9~ ~+BO, 77 W 585,57 520-35 W 632,58 560.08 W 679,90 599.97 W 727.37 639.82 W 77q.62 679'611 .W 821,71 719.50 W 868,86 759,5~ Id 916,09 799,60 W 963.24 839,65 %; 1010.2({ 879,70 W 1057,27 91'9,78' W 1104:17 ......... SOH!O BP:~:LASKA PR PRU~HOE BAY ALAS~'A MEASURED VERTICAL DEPTH DEPTH COMPUTATION DATE dULY 17, 1979 VERTICAL. INCLINATION DIRECTI ON SEVERITY DEPTH OEG MIN DEGREES DEG/lOO ~AGE A E~ ING~COMPA'N~: ~ ~ ' BOSS GYROSCOPIC SURVEY ,JOB NUMBER BOSS-16424 KELLY BUSHING ELEV. : 54.97 FTo RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECTION I O O 0 0 1':'~.: 10100 9282,26 1.0200 9370,22 1021q 9,382.56 10 IZONT L.:,D~ 9227,29 2R 41 N 37',79 W .$0 9315.25 28 7 N 36.20 W ,95 9327.59 28 10 N 36,10 W .55 15~.o ,' :: ze I. 2 4 1923.03 N 2592.55 3227.79 1961.01 N 2621.18 W 3273.5:' 1.96,6.35 N 2625.0~ W 3279.B5 320.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD, ,, :: - . ... . SOH!O BP AL _ .. - : R-2 COMI ~TION DA PPUDHOE BAY JULY 17~ 1979 ALASKA ~AGE 5 JOB NUMBER BOSS-1Gq2q KELLY BUSHING ELEV- = 5q.97 FT. TRUE SUB-SEA TOTAL N~EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL D E PT H DEP IH..:,' :? :i~:~ :~::ORRE,C T: i::: :il ~::. :~,: :.:: ' o. ~"o ...~ ::.i::.. .... ]OOO 999.97 P_000 1999.91 3000 ~ 2999.14 ~ ooo sOoo' 7000 6606.86 RO00 746q.98 9000 P, 320.67 I DO00 TH~ CALCULAT!ON~ 945.00 4.86 N 4.62 E .03 .03 194A.9A 10.70 N 12,63 E .09 o06 2944,17 20.99 N 1.59 W ,86 6551,89 909.11 N 1412, q9 W 393.1q 122oBA 7415.01 1194,40 N 1828.76 W 530.02 136,87 8265.70 1527.92 N ' 2234,78 W 679,33 14,9.31 OCEDURES ARE BASED ON THE USE OF DIMENs IDNAL RADIUS OF'~'~UR~V~I~U~"'M~THOD. SOHIO BP AL ASKA PiRoDI')CTI:ON DI'V'i:$ION:. UUL¥ 14, !979 .. R-;,2 COMPUTATION DATE PRUDHDE BAY dULY 17,~ 1979 'dOB NUMBER BOSS-16424 ALASKA KELLY BUSHING ELEV, = 54,97 FT, MEASURE DE P TH~ ) 5 15 35 TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL 5A.97 0.00 °02 N ..01 E oD0 o00 154.97 100.09 .32 N ,17 E .DO .00 25A,97 200,00 ,42 N ,30 E ,00 ,00 · ' 4 ' '"" ' ' '"' ~' ' ' '" ' ' ' .... '" ' ' "'" ' "" "" ........ '~" ........ '" .... ' ' ' .... ~ ..... ..... ........... "" ' . 9 10 11 5q 654,97 6,90,00 2,21 N 2°74 E ,02 ,01 54 75A,97 7DO,OD 2,94 N 3,29 E ,02 ,00 54 854,97 8OO,'O0 3.66 N · 3.86 E ,03 ,00 55 '95~"97::: ~..~.: 4-5:0. N . . . . 55 1 z 5 A', 97 1.00'~ :.:::~.:. 5.87' ~ 6.70 N 5.82 E 7.68 N 6.q5 E .05 1255 125q ¢~ · 97 1200.00 1355 1354,9 1300,00 ~,00 ,01 ,01 14 1555 1,~55 1755 175~.97 o01 ,01__ TRUE SUB=SEA MEASURED VERTICAL VERTICAL DFPT 1955 1954,97 1900, O0 2055 205A.97 2600.00 2155 2154,97 2100,00 .225 235 5 24'54 2555 2655 2755 ~_855 2955 3056 · 3156 3~58 3359 3~,62 3565 3670 255q,97 265q,97 275fl.97 285~ 2500,00 2600,00 2700,00 97 3100.00 97 3200,00 7 3300.00 7 ~';0 0' 0 0.: Y'SUN. U )PAGE 7 COMPUTATION DATE dULY 179 1979 EVEN IO'O'FEET OF" :SUB'SE"A EY" ,JU L.Yi I ~ '~ 1979 dOE NUMBER BOSS-1G~2q KELLY BUSHING ELEV, : 5~,97 FT. TOTAL RECTANGULAR COORDINATES 10,6~ N 12.16 E. 10.78 N 13,26 E 10.98 N 14.81 E MD -TVD .O9 VERTICAL o 0 0 ' ,00 .01 ii.' · 15.79 El .13 o00 15,55 E .1~+ .00 13,29 E ,19 ,05 .58 1 · 29,15 W 3,13 : ~-90 PDUDHDE BAY ~L. AFKA '::': ::': :::: NTER : ANcHORA" ' ' "i 14 ' 19 79 -, COHPUTATION DATE dULY 17, 1979 dOB NUMBER B0SS-16424 KELLY BUSHING ELEV, = 5A,97 FT, TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL D ED T H :' .:: :?:i:?::::. ::CO 3BB4 3~354,97 3800,00 135,85 N 175,22 W 29,66 3993 3c~54.97 3?DO,DO 159,10 N 210,52 A103 405z+,97 4000,00 18A,95 N 249,94 W 48,61 4554 4A54..97 4667 455A,97 4780 4GSA.97 5575 5802 4893 .: 5007 5121. , , ,,,~, ,.,.,~,4, 5234 5054 5348 515A 54~1 5254 5354 5454 5554 z+q. OO,OO 298,12 N 423,57 W 99,11 4500,00 326,62 N 467,76 W 112,10 4-600.0D 355,61 N. 512,59 W 125,46 · ~7.,,,:. ........ ........... ;, ,.,, ,, .5~ · 97 5000,00 472,36 N 693,41 W 179.6~ 501,24 N 7::58,77 g 195,23 529.92 N 784,30 g 206,79 558,36 N 586,65 N 61~ ,72 N 7.4~ 8,57 10,57 12,69 12,98 ,2~ -.!i. 247 · 03 3,53 · 97 ~00.00 ..~ ~oo.oo . ~ 7 ~'[~o~ .... ' 13.45 13.54 13.56 1 ;3 · 45.: 13 '~ ::i 13o3'/ ' ~OH]'O BP ALASKA 'PRoDUCT! PRUgHO£ BAY ALASKA JULY 17e 1979 dOB NUMBER BOSS-IGC24 KELLY BUSHING ELEV, = 54.97 FT. TRUE SUB-SE A MEASURED VERTICAL VERTICAL H 5915 6028 5754.97 5'700.00 6162 5854.97 5800.00 E, 255 5°54.97 5900. O0 DEPT 6569 64B5 6597 6711 6825 6940 7055 7170 72.85 7400 7516 76~2 7748 7A65 7982 TOTAL RECTANGULAR COORDINATES. MD -TVD VERTICAL :::.C:OR R E CT.! ON .. 670.19 N 1011,63 W 273,68 13,32 697,68 N 1057,46 W 287,06 13,38 72fl.gB N 1103, 90 W 300,65 13,59 8.56.15 U 1292, 02 W 356,44 14,14 864.66 N 1339, 76 W 270,86 14,42 ~93,99 N ' 1387,51 W 3P, 5o49 14,63 1048,83 N 1628.29 W 461,68 1082.47 N I676,54 W ~77,69 , : 1:188 635q.97 6300.00 6454.97 6400,00 655/4.97 6500.00 66 675 ~ 854.. 97 7054,97 7000,00 715~.,~7 7100,00 7254,! 7.35 7454'.97 15,7~ 16.01 16.88' SOHI 9 BP A L A S K A P R 0 iD u CT I ON · D I V i i~i 0 NI "ii;: · iSURVE¥ dU[:Y:14v 1979 .., JULY 17, 1979 DRUDHDE FiAY _A_kAS___KA · . , ,JOB NUMBER BOSS-16424 KELLY BUSHING ELEV. : 54,97 FT. TRUE SUB-SEA MEASURED VERTICAL VERTICAL D EP ? H. 8217 7654,97 7600,00 R335 775A,97 7700,00 845~ 785A.97 7800.00 ~806 :' .;'8154,97 g:iO 8923 g254,97 820~,00 9039 8554.97 8300,00 ~155 ~z~5A.97 ~400.00 9269 '.~. ~: TOTAL, RECTANGULAR COORDINATES MD-TVD VERTICAL 1264,60 N 1919.65 W 562,77 17.94 1~03,57 N 1969.14. W 5~0,96 18.19 1342,9A N 2018.16 W 599,08 18,12 1502.~1 N 2205.60 W 668,72 1.6.76 1541.21 N 2249.90 W 68.4.B0 16,09 1579,91 N · 2292,53 1,d 700,19 15,39 9612 885~.97._ 8800.00 9726 8954.97 '~ 8900.00 1782.$5 N 2479.24 ~ 9840 9054,97 m]~.9900.00 1~24,76 N 251A. 13 W 771,20 13.96 7P. 5.28 ~H!O PRUDqOE BAY TRUE SUB-SEA ~EASURED VERTICAL VERTICAL D.. F P T ~ :, 1 0303. 9461.01 940G.0~ T~E CALCULATION PROCEDURES USE A THE NEAR.! JULY 17~ 1979 TOTAL RECTANGULAR COORDINATES MD-TVD 2000.31 N 26~-9. Sq. LINEAR INTERPOLATION BETWEEN dOB NUMBER BOSS-1642~ KELLY BUSHING ELEV, = 5~.,97 FT. VERTZCAL ,. LOCATED IN .THE APPENDIX WFL IPR LOG CALIPER SURVEY VOLAN ~CURVE DATA [~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER UI OTHER: SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION TO: State of Alaska Alaska Oil & Gas 3001 Porcupine Anchorage, AK 99504 Attn: Mr. H. Hamilton REFERENCE: Well Data Transmission The following material is being submitted herewith. Ple~a~se~cknowledge receipt by signing a copy of this letter and returning it to this office:- MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 August 2 19-~ ' '-C. 0M.~M '_I COrM -i ~-fs 2 EN~ 3 4 ENG ~J' 1 GEOL J 3 GEOL I STAT TEC J STAT TE'C~ .... Fi[F: ,., R-2 2 copies Boss Gyroscopic Survey #16424 1 sepia and 1 print for the following Sohio operated well: R-2 BHCS Run 1 5" & 2" DIL Run 1 5" & 2" CNL/FDC Run 1 5" & 2" FDC Run 1 5" & 2" CPL Run 1 5" RECEIVF g 1979 Colette Tracy Well Records RECEI DATE SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION July 25, 1979 3111 "C" STP EF,~ TELEPHONE (907) 26~00C0 MAIL: POUCH 6-6 ANCHORAGE, ALASK~9~ ~ CONFER'i ~ FILF: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well R-2 (33-31-12-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and kbrkover Operations, for the above- named well for the month of July, 1979. PRJ: ja Enclosures cc: Well File $17 Yours very truly, SOHIO PETROLEUM ~ANY District Drilling Engineer Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE CONFIOENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Sohio Petroleum Ccmpany, Div. Sohio Natural Resources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqe, Alaska 99502 4. LOCATION OF WELL At surface: 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM 5. APl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR EEASE NAME Prudhoe Bay Unit 9. WELL NO. R-2 (33-31-12-13) 10. FIELD AND POOL, OR WILIX.'AT Prudhoe Ray:P~x~hc~_ O~l Pool 11. SEC. T. R. M. (BOTTOM HOLE ' OBJECTIVE) Sec. 31r T12N, R13Er UPM 12. PERMIT NO. 78-100 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. July, 1979 Directionally drilled 8 1/2" hole to 10303'. Ran open hole logs. Ran 38 jts. 7" 29~ L-80 Buttress casing to 10302'. C~nented with 430 cu. ft. Class G cement. Cleaned out to 10225', tested casing to 3000 psi. Cb2~nged well over to NaC1. Ran CBL log. Ran 222 jts. 7" 26~ L-80 AB-IJ-4S tubing to 8870'. Landed tubing with ball valve nipple at 2002'. Installed and tested tree. Displaced' tubing to diesel. Set production packer at 8765', tested tubing to 3500 psi. Released rig at 0600 hours, July 8, 1979. 14. I hereby certify t~ true and correct .TiTLE District Drilling Engirlee]~ATE' 7//~'/7~ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form No. 10-404 REV. 3-1-70 SUBMIT 1N D[~PLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS CONFIDENTIAL $. APl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 WELL WELL OTItER 2. NAME OF OPERATOR Sohio Petroleum Cc~.pany, Div. of Sohio Natural Resources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 4. LOCATION OF WELL 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit At surface: 9. WELL NO. 99502 R-2 (32-31-12-13) 10. FIELD AND POOL, OR WILl)CAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM ltOLE OBJECTIVE) 638' NSL, 969' EWL, Sec. 32, T12N, R13E, UPM Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. June, 1979 Spud well at 1830 hours, June 13, 1979. Drilled 17 1/2" hole to 2670'. Ran 66 jts. 13 3/8" 72# L-80 Buttress casing to 2628'. Cemented with 5348 cu.ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2586', tested casing to 3000 psi. Drilled out to 2680', ran leak-off test. Directionallydrilled 12 1/4" hole to 9310'. Ran 238 jts. 9 5/8" 47# L-80 Buttress casing to 9307'. Cemented in tw~ stages: First stage with 1288 cu.ft. Class G c~t; second stage through DVpacker at 2599' with 130 cu.ft. Pe//nafrost cement preceded by Arctic Pack. Cleaned out to 9264', tested casing to 3000 psi. Drilled out to 9317', ran leak-off test to 0.7 psi/ft. Directionally drilled 8 1/2" hole to 10152'. 14. I hereby certify that the forego?g is true a~nd correct SIGNED NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION July 9, 1979 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil and Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well R-2 (32-31-12-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of June, 1979. Very truly yours, SOHIO PETROLEL~ CK~ANY PR J: ja Enclosures cc: Well File ~17 f/ P. R. Judd District Drilling Engineer Alaska Oil and Gas Conservation Commission ttoyle H. Hamilton ~~' June 20, 1979 Chairman of the Commissio~~ Lonnie C. Smith ~ Commiss ion .... Bobby Foster Petroleum Inspector Witness BOPE test on SOt!IO's R-2 Sec. 31,~.T12N, R13, UPM, Permit ~i78-100 Saturday, June 16,...19.7.9 - I departed Anchorage at 9:15 AM via SOHIO .charter flight #1 for DeadhorSe. I arrived at A.A.D.CO. Rig #1 at 11:30 AM where I stood by for BOPE test to begin. ~u~nday, June 17, 1979 - The BOPE test began at 12:30 PM with the testing of the BOPE stack consisting of one annular preventer, two se~s of 5" pipe rams and one set of blind rams. The kill line consisted of one' manual 3" valve, one Check valve and one HCR valve. The choke line consisted of one manual 4" valve and one t{CR valve. T1~e choke manifold consisted of eleven manual valves, two adjustable chokes and one hydraulically operated Cameron choke. The ball type floor safety valve was tested while testing the upper and lower Kelly valves. Ail of the above BOPE was tested to 5000 psig, with the exception of the annular preventer which was tested to 2500 psig. The acctumulator unit ~ms tested by turning off the power to the unit and closing two sets of pipe' rams, the annular preventer and opening the ~ICR valve. The full charge / unit pressure of 3000 psig dropped to 1675 psig and stabilized. The power was then turned on and a 250 psig increase in pressure was attained in 31 seconds and full charge pressure of 3000 psig was attained in three minutes. The N~ bottle backup system pressures were 2300, 2500, 2500, 2300, 2800, 2800, ~800 and 2800 psig. The BOPE tests were concluded at 4:00 PM. I boarded Wien flight 20 at 9:45 PM and arrived in Anchorage at 12:00 AM. In summary I witnessed the satisfactory BOPE test on SOHIO's R-2 well. Drlg. Permi t~lo. Operator A~w""~.~ka Oil and Gas Conservation Co ,tee ~ ~ Field Inspection Report ' Well/Platfm ~Sec3~ T~-_~ RI~ ,~ Represented _ Name & Number. Satisfactory Type/Inspection . Satis factory Type Inspection Yes No Item (~Location,General Yes No Item (~BOPE Tests ('~' ( ) 1. Well Sign I~( ) 15. ~_~Casing set @ (~[ ( ) 2. General Housekeeping ( ) 16 Test fluid-(~rbr~ )mud ( ) oil ( ) 3. Reserve Pit-(~pen( )filled (~ ( ) 17. Master Hyd. Control Sys.-~ psi9 ( ) 4. Rig (~. ( ) 18. N? btls. , , , psi.q ( ) SafetX Valve Tests (~-~ ( ) 19 R~mote Control~-- ( ) ( ) 5. Surface-No. Wells (4 ( ) 20. Drilling spool-~ "outlets ( ) ( ) 6. Subsurface-No. Wells__~ (r~ ( ) 21. Kill Line-(~Check valve ( ) Well Test Data (-~[_ ( ) 22. Choke Flowline (~' HCR valve ( ) ( ) 7. Well Nos. , , , (~ ( ) 23. Choke Manifold No. valvs ~/_~_flo~_~ ( ) ( ) 8. Hrs. obser , ~, (~ ( ) 24 Chokes-(~emote~( )Pos.(~Adj~- ( ) ( ) 9. BS&W , ,~','-- (&~ ( ) 25 Test Plug-(~-)~W~lhd( )csg( )none ( ) ( )' 10. Gr. Bbls. , , , (~ ( ) 26. Annular Preventer~l,~opsio ( ) Final Ab-~andonment -- (-~/ ( ) 27. Blind Rams,,~psi§ ( ) ( ) 11. P&A Marker (~J~ ( ) 28. Pipe Rams~'~ psig ( ) ( ) 12. Water well-( )capped( )plugged (~)~ ( ) 29. Kelly & Kelly-cocV~-~ psig ( ) ( ) 13. Clean-up (~)~ ( ) 30. Lower Kelly valve,~ psig ( ) ( ) 14. Pad leveled (~)~ ( ) 31 Safety Floor valves-(C~BV (~rt Total inspection o.~va~ion time hrs/days Total number ieaks and/or eouip, failures Remarks Notify in days or when ready Inspected b~.?~~ Date C. BP ALASKA IN BOP EQUIPMENT TEST REPO WELL TEST FLUID ACCUMULATOR VOLUME /(~0 ,-' TEST TYPE: F'IWEEKLY i~]"FLANGE UP O CA_~IO SET ' II LAST CASING' /5'~, AT ~,.3;1 PRESSURE ~ PERFORMANCE TESTS: IBOP STACK-- LIST ALL ITEMS TOP TO BOTTOM, MANUFACTURER AND TYPEt SIZE OF RAMS, ETC. ACCUMULATOR · .u..s ccu.u. o, T ST 'r sT . c os,. c.os,. BLIND RAM PIPE RAM ~~.~ CHOKE MANI~ KELLY COCK ~ m ~000 ~'~:~ "~'~,,~, CASIN~ TESTED: ~'~- .,~ F~ TO ~0 0 PS ~'~ ,F ~ .L PS, ArmOR CLOSING ALL BO /*)'~.-~'~'%/ ~' YIN. RECHARGE TIME. STAND PI PE CHOKE L~.'~E KILL LINE E¢ )UIPMENT .CHECKLIST YES ,NO. CIRCULATING HEAD ON'FLOOR~':~'" INSIDE BOP oN FLOOR & SUBS ~/ '. KELLY VALVES ON. FLOOR & SUBS SPARE KELLY VALVE PVT' SYSTEM oPERATiNG ' ' ' ',,~," FLOW, SENSOR ':OPERATING STROKE 'COUNTER OPERATING TRIP TANK . LOCKING SCREWS ON BOP & ALL VALVES OPERATE EASILY. · . · ., REMOTE STATION. OPERATING BOP HANDWH. EELS INSTALLED GAS SNIFFER OPERATING · . BARITE O'N HAND ~.:~C, '" SACKS GEL ON HA ND SACKS WATER ON HAND ~'~:"~) BBL SURFACE MUD VOLUME '/~ ~ ~ ~ BBL HYDRAULIC OIL ON HAND ,,ft' DRUMS NITROGEN BACKUP SYS ~ NC. OF BOTTLES HOOKED UP, AT~/~g~''~ PSI NITROGEN PRESSURE. ~' '~ '~'~ 4? 2: ~:":::'-' L,Y - MALFUNCTIONS 6 COMMENTS (ITEMIZE ALL LEAKS, MALFUNCTIONS, MISSING EOUIPMENT~ ETC., AND ACTION TAKEN~) BP SUPERVISOR: BE COMPLETED AND PUT ON FILE FOR EACH BOP TEST. June 5, t979 Re: Flow Diverter System waived for PBU Well ~R-2 and all subsequent wells from Pad R. Mr. P. R. Judd District Drilling Engineer Sohio Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Judd: As requested by ~ur letter of May 31, 1979, the flow diverter system re~F~ired by CO 145, Rule 4(b) is hereby waived for Prudhoe Bay Unit, Pad R-2 well and all subsequent wells drilled from Pad R. Very truly yours, Lonnie C. ~mith Commiss ioner by order of the Commission SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION May 31, 1979 31 11 "C" STREET ANCHORAGE, ALASKi MAIL: POUCH 6-612j -' j State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska 99501 RE: Prudhoe Bay Unit R-2, Sohio Petroleum Company Dear Sirs: In accordance with the Prudhoe Bay field rules and Sohio's policy for drilling the first well on a new pad and/or new area, a 20" Hydril and Diverter System was used when drilling the surface hole on well R-1. We did not experience any surface gas during the drilling of the 17 1/2" hole on R-1 and therefore believe it not necessary to continue the use of the 20" Hydril and Diverter System on R pad wells. PRJ:DMS:ch CC~9672 cc: Well file - R pad D.M. Skelton Very. truly yours, P. R. Judd District Drilling Engineer SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION May 9, 1979 Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well R-2 (32-31-12-13) Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This report contains-our proposal to change the completion of this well. Very truly yours, PR J: ja SOHIO PETROLEUM CC~4PANY District Drilling Fzagine..er .. Enclosures cc: Well File #17 F~>gm 10-403 REV. ~-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL ~ GAS r'~ WELL !--! WELLL_-.I OTHER 2. NAME OF OPERATOR Sohio Petroleum Cc~pan¥, Div: of' Sohio Natural Resources Pouch 6-612, gncl~raqe, /d. aska 99502 4. LOCATION OF WELL At surface 968' EWL, 639' NSL, Sec. 32, T12N, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 60' AMSL est. 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20354 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME }. Prudhoe Bay Unit 9. WELL NO. R-2 (32-31-12-13) 10. FIELD AND POOL, OR WILDCAT l:~"udl'K~ Bay,~ Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N, R13E, UPM 12. PERMIT NO. 78-100 )orr, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT ~ MULTIPLE COMPLETE ~ FRACTURE TREATMENT ~ ALTERING CASING SHOOT OR ACIDIZE ~ ABANDON* g--~ SHOOTING OR AClDIZING La ABANDONMENT* REPAIR WELL ! _ ~ CHANGE PLANS ~ (Other) (Other) [_ I '(NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly State all pertinent details, and give pertinent dates, including estimated date of ~tarting any proposed work. We propose to change the cc~pletion of the above-named well as follows: Directionally drill 12 1/4" hole to 8568' TVD. Run 9 5/8" 47~. L-80 Buttress casing to 8568' TVD. Cement first stage with 1410 cu. ft. Class G cement. Cement second stage through DV packer at +_2600' with 164 cu. ft. Permafrost cement. 9 5/8" x 13 3/8" annulus will be Arctic Packed. o Directionally drill 8 1/2" hole to 9433'TVD~ Run 7" 29~ L-80 Buttress casing fr~m T.D. to 500' inside 9 5/8" casing. Cement with 280 cu.ft. Class G cement with 18% salt. 3~ Run 7" 26~ L-80 AB-IJ-4S tubing with a production packer assembly at 8082'TVD. A subsurface safety valve will be placed at +-2000'TVD. Displace tubing to diesel. .... .i6. ,herebycertif~~g 'S,~NED ~ ~~ T,TLEDiS~iCt ~ill~q Engineer DATE ...... · , (This sp~e for State~ ~ APPROVED bY CONDITIONS OF APPROVAL, IF ANY: TITLE . DATE See Instructions On Reverse Side ~e~urned Conservation December 29, 1978 Re: Prudhoe Bay Unit Well P~2 (32-31-12-13) Sohio Petroleum Company Permit Number 78-100 Sohio Petroleum Company Attn: P.R. Judd Pouch 6-612 An~torage, Alaska 99502 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a locatiom in Section 31, Township 12 N, Range 13 E, UPM. Well samples, core chips, and' a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experi- m~ental logs, velocity surveys and dipmeter surveys. Mmny rivers in AlasP~ and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promul- gated thereunder (Title 5, Alaska Administrative Code). Prior to com- mencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Con- servation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska State Department of Labor is being notified of the issuance of this pe~:~it to drill. SOHIO Petroleum Company 2 December 29, 1978 To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours aft~er the well is spudded. We would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment please give this office ade- quate advance notification so that we may have a witness present. Very truly yours, Chai~an Alaska Oil and Gas Conme~ation Committee Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Dept. of Labor, Supervisor, Labor Law Compliance I)ivision encl. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION December 29, 1978 STFIEE~ .....i · 3111 State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anc~Prage, Alaska 99501 Attn: Mr. Hoyle H- Hamilton Director Gentlemen: Enclosed, in triplicate, are the survey plats for the following wells: Term Well B Term Well C PRJ: PJM: Ja Enclosures Very truly yours, SOHIo PETROIAJjM COMPANY District Drilling Engineer cc: Well Files 40 04 OI O2 0:~ 04 Oi 02 20 30 4862' 31 4884' i i 4~ 10 (Proposed) 753' .......... Z-t.~ -_ ~ '~ . 32 R-ID ii i i i 40 !0 L. AT. = 70°20'44.95'' LONG.= i48° 54'04 I 5" X= 635,370 Y =5,977,280 T i2. N. 03 04 Ol u. ii 4906' PORTION OF TI2N, R13E, UM SCALE I"= I/2 MILE CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct, Date Surveyor ADDED (PROPOSED) BOTTOM HOLES R-I,R*2&R-3 8800' SUB SEA REVISED WELL HEAD NUMBERS ..... .i ~1111 i iiiBiili!i iiii1~111 i iiiiiiii · i i i iiiiHiii ii iii i iii I[111 I III ii i I i 12- 28- 78 C.J.R. 10-31-77 C.J.R. · mi ii .,! 350' SUMP /$) 3/- ~-/.~) PAD DETAIL SCALE I" = 400' PAD "R" Located in SW I/4 PROTRACTED SEC. 32,T. I? N..,.R. 1~5.E.,UMIAT..__MERI.D!AN, AK. B.P. Surveyed for ALASKA INC. II i I Surveyed by LINDSEY 8~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights' Boulevard Box 4-081 Anchorage Alask~ I I I I I [I ii SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION December 28, 1978 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: Well R-2 (32-31-12-13) Enclosed are the following documents: le , Application for Permit to Drill, in triplicate Proposed Drilling Program Outline 3~ Our check for $100.00 to cover the permit filing fee. The surveyor's plat of well location will follow at a later date. Very- truly, yours,, SOHIO PETROLEUM COMPANY District Drilling Engineer PRJ: j a Enclosures cc: Well File #17 Form 10-401~ REV. 1-1-71 la. TYPE OF WORK SUBMIT IN TRIPLICATE (Other instructions on STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE reverse side) PERMIT TO DRILL OR DEEPEN DRILL [-~ b. TYPE OF WELL OIL~ GAS WELL ~ WELL I OTHER DEEPEN [-] SINGLE MULTIPLE ZONE ~] ZONE [--] 2. NAME OF OPERATOR Sohio Petroleum Company, Div. of Sohio 3. ADDRESS OF OPERATOR POuch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 968' EWL, 639' NSL, Sec. 32, At proposed prod. zone 0 8800' ss TVD 1180' WEL, 2630' SNL, Sec. 31, Natural Resources Co. T12N, R13E, UPM T12N, R13E, UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 10 miles NW of Deadhorse API ~50,029-20354 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 28279 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. R-2 (32-31-12-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay,Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31~ T12N~ R13E~ UPM 12. 14. BOND INFORMATION: TWE Blanket Surety and/or No. American Insurance Co. 3348616 Amount $100,000.00 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 2650' N of ADL 28282 DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2360'-E of Well M-4 16. No. OF ACRES IN LEASE 2459 19. PROPOSED DEPTH 10189'MD 9412' TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Est. KBE = 60' AMSL 23. PROPOSED CASING AND CEMENTING PROGRAM 17. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START March 20, 1979 SIZE OF HOLE sIZE OF CASING WEIGHT PER FOOT GRADE ~ SE~ING DEPTHTV~ Quantity or cement 36" 20"x30" insulated Conductor 110' 110' 600 cu.ft. Arcticset 17 1/2" 13 3/8" 72# L-80 2670' 2670' 3500 cu.ft. Arcticset 12 1/4" 9 5/8" 47# L-80 8028' 7500'1)1412 cu.ft. Class G 9 5/8" 47# Soo-95 10189' 9412'2) 360 cu.ft. Arcticset See attached proposed drilling program. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certi 7' --~--- DATE / TITLE Dis t. SIGNED, Drilling Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [ MUD LOG [] YES ["~ NO ] [] YES DIRECTIONAL SURVEY REQUIRED [~YES [] NO CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: NO A.P.I. NUMERICAl_, CODE ' 50-029-20354 PERMIT NO. APPOVED BY 78-!:Yh n APPROVAL DATE ~vv *See Instruction On Reverse Side 12/29/78 DATE 1.9/gQ/"70 PROPOSED DRILLING PROGRAM Dry bucket 36" hole to 80' below ground level and cement 30" x 20" insulated conductor to surface using Arcticset cement. Drill t7 1/2" hole 'to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3500 cu.ft. Arcticset cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind r~s, and annular preventer from 13 3/8" casing point to T.D. Directionally drill 12 1/4" hole to 9412'± TVD. Run 9 5/8" 47# Soo-95 and L-80 Buttress casing to 9412' TVD and cement first stage ~zith 1412 cu.ft. cement. Cement second stage through D.V. collar at 2300'~ with 130 cu.ft. Arcticset cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" ~annulus being displaced to Arctic Pack through a F.O. cementer placed at 2050'. Run 7" 26# L-80 Atlas Bradford IJ-4S tubing with a production packer assembly at 8491'~ TVD. A subsurface safety valve with dual control lines will be placed at 2000'~. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. · · 1. !s tho lT'~:jt fco a,.,~.~ hud .., , . . . ,~/~ ---. _. , a .......... . i-:',,to': ko:';d 4 .' .... t,'._,..h, C':-<' ?..LiL'C Z'~ ~I2 ~02~CC2 . ]s rv-?..~.,-4s'.?yz:::.ffv~_,-- ciFE,iTOVa], ncod.'.i:d o' ........ ; .... ; . . ] 3 ................. i'S ('c..:'K~.:.::' r,,- c;t,-~,,r, ~'"O"J ¢7.'.'C' ~,., ~- ]'.q c:':c:u,-:}; c:.:.:-'..?': ; [- ~,,--.'-'. I.o c:Jrcu]:~hr.: '(;:'](:(.::w]t~' ] n ' ......... ] .... ct.. ,.]::: :-:t]v£a¢:c: . ~ .................................. ~. ......................................... . " ~'.'; Il ,.',. :'.'.,. hi. l:J,'.'~ i;: .~:'.:'...'"~:c,'~ :!:',d J~!c.]:"'.:','";.-'t.:? -or l,rcx!uchJ.on .q t: Y i n('! :; . .~__[_ ') C,:i.'::'. ~ · . :-; I '! ('. '.::'".;:i: (',>'.',. :- ,.: ~::.: '...'..; i>~.'(-~:]:i'.':t~.'.:~: ]ic:q'J ..... '" . . ;~dditlonal" ..... ; :'S 5 , Revj sod 4/],;.' ". :;' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. Company Sohio Petroleum LIBRARY TAPE CURVE ~PECIFICATIONS Field Prudhoe Bay County,State North Slope, Alaska Date 178-8~ Curve Name (Abbrevialed) Standard Curve Name Logs Used Scale FILE 1 CC1 Correlation Curve Pass 1 NLLC 5-~0 SHO1 Sigma Short Pass 1 NLLG 60-0 GTA1 Gate 1 Pass 1 NLLG 0-10 GTB1 Gate 2 Pass 1 NLLG 0-1.67 '' 'RATi Ratio P'ass LON1 Sigma Long Pass 1 NLLG 60~0 CC2 Correlation Curve Pass 2 .NLLG 5~0 .., SH02 Sigma Short Pass 2 NLLG 60~0 GTA2 Gate 1 Pass 2 NLLG 0-10 GTB2 Gate 2 Pass 2 NLLG 0-1.67 RAT2 Ratio Pass 2 NLLG 20-0 LON2 Sigma Long Pass 2 NLLG 60-0 CC3 Correlation Curve Pass 3 NLLG 5-0 . , SHO3 Sigma Short Pass 3 NLLG 60-0 , , GTA3 Gate 1 Pass 3 NLLG 0-10 --. GTB3 Gate 2 Pass 3 NLLG 0-1.67 .. , FILE 2 RAT3 Ratio Pass 3 NLLG 20-0 LON3 Sigma Long Pass 3 NLLG ,~(~-0 % L I ~RARY TAPE CURVE ~SPE C I F I CAT IONS Company Sohio Petroleum Well R-~ Field Prudhoe Bay County,State North Slope, Alaska Date 1-8-81 Curve Name (Abbreviated) Standard Curve Name CC4 SHO4 GTA4 FILE 2 . . 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