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196-104
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS "L..1%W .V . III DEC - 6 2019 1. Operations Performed Abandon ❑ Plug Perforations 21 Stimulate ❑ Pull Tubing❑ O s11efI Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set WRP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 196-104 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6API Number: 50-029-20462-01-00 7 Property Designation (Lease Number): ADL 028281 8. Well Name and Number: PBU J -11A 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 12630 feet Plugs measured 11950 feet true vertical 9067 feet Junk measured 11844, 11950 feet Effective Depth: measured 10710 feet Packer measured 8699,8871,10469,10652 feet true vertical 8874 feet Packer true vertical 7490,7625,8719,8837 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" x 30" 32-112 32-112 Surface 2529 13-3/8" 32-2561 32-2555 5380 2670 Intermediate 9102 95/8" 31 -9133 31 -7826 6870 4760 Liner 2029 7" 8892- 10921 7642-8977 7240 5410 Liner 1949 4-1/2" 10683 - 12630 8857-9067 8430 7500 Perforation Depth: Measured depth: 10632 -12400 feet True vertical depth: 8825-9019 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6#, 13Cr80 / L-80 29-10673 29-8851 4-1/2" Baker 5-3 Perm Packer 8699 7490 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8871 7625 true vertical depth) 4-1/2" Baker Premier Packer 0469 8719 4-1/2" Baker SABL-3 Packer 10652 8837 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: 429 35036 4813 2000 1061 Subsequent to operation: 715 46149 82 1999 1022 14.Attachments: (requimdper2QMC25.070.25.071,525.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: NIA Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: Production Engineer Contact Email: Julle.WellmanQbp.com Authorized Signature: Date. 1 Contact Phone: +1 9075644657 Form 10-404 Revised04/2017�f �a//L ry.b..RoQD�t� gBDMS i1Ff n 6 emu Submit Onainal Oniv Daily Report of Well Operations PBU J -11A er.TiviTynnTF , ........., ***WELL S/I ON ARRIVAL*** (Profile modification) DRIFT TO DEVIATION AT 10,975' SLM W/ 2.74" x 20' DUMMY WHIPSTOCK, S-BLR (No sample or issues). UNABLE TO PASS 9,785' SLM (Sticky) W/ 2.50" (2.80" swell rings) x 10' DUMMY GUN, 3.69" (SC) DUMMY WRP. RAN READ 40 ARM CALIPER FROM 10,980' SLM TO SURFACE (Good data). DRIFT TO DEVIATION AT 10,941' SLM W/ K.JT, 2.50" x 10' DUMMY GUN (2.80" swell rings), 3.69" DUMMY WRP. HAD TO LIGHTLY WORK TOOLS THRU TIGHT SPOTS AT 9,826', 9,999', & 10,653' SLM. 11/7/2019 ***JOB IN PROGRESS, CONTINUED ON 11/8/19 WSR*** ***CONTINUED FROM 11/7/19 WSR*** (Profile modification) DRIFT TO 10,911' MD W/ 3.63" CENT, TEL, 3.00" S-BLR (No issues or sample). SET 3.69" WFD SPECIAL CLEARANCE WRP AT 10,699' SLM / 10,710' MD (MOE). 11/8/2019 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** TREE= CNV WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 69.01' REFELEV= BF. ELEV = 73N 392T KOP= 2350' Max Angle = 94agh 11136' Dahm MD = 10710' DalmTVD = 8800'SS 9-5/8^ HES ES CEMENTER --M 9-5/8" BKR ISOZONE ECP, D=8.620" 2031• 9-5/8' CSG, 47#, HYD SET—1) —=8 68-1 2052' /8' BOWED CSG PATCH. D = 8.770' 2052 -2056' 13-3/B' CSG, 72#, L-80 BTRS, ID = 12347' 2556' Minimum ID = 3.80" a@ 10601' 4-1/2" HES XN NIPPLE SAFETY HROMNOE�TUBING 'E J-1 IA ORIG WELLBORE NOT SHOWN BELOW 9-5/8" MILLOUT ••• 412"H6SX NP, D=3.813' GAS LFT MA MYTR S -b Sl p I1tl VVttN J RWLAJLt PKH5 1 $692' 1 19-5/8' X 41/2' BKR S-3 PKR, D = 3.875' 1 HES 412- TBG, 12.6#, 13CR-80 VAM TOP, $799' .0152 bpf, D = 3.958 412" TBG STUB (08111/09) 8805• X7"BKR ZXP L7Pw/f�KSLV,D=6.38" 6692' 95/8' X 7"BKR HMC LNR HGR, ID = 625" $906' 95/8' CSG, 47#, L-0 BTRS, D =8.66P 9133' I—I 10653' 10655' 1 8$15' 9-518' X 41/2" UNIQUE OVERSHOT 68'14• 412" F$ X NP, D = 3.813' . SPERRYSUN AWR ON 07/01/96 10669' ND ND DEV TYPE VLV LATCH FORT DATE 5 4 3 2 '1 3886 6280 7745 8581 '10532 3753 5608 6720 7397 8761 37 42 38 37 49 MMG NT4G NTNG MMG KBG-2 DMY DMY DMY DMY DMY W 0 RK 0 RK 0 RK 0 BK 0 0529/11 0529/11 08/11/09 08/11/09 0423/11 jj�ST 4 11170-11210 C -b Sl p I1tl VVttN J RWLAJLt PKH5 1 $692' 1 19-5/8' X 41/2' BKR S-3 PKR, D = 3.875' 1 HES 412- TBG, 12.6#, 13CR-80 VAM TOP, $799' .0152 bpf, D = 3.958 412" TBG STUB (08111/09) 8805• X7"BKR ZXP L7Pw/f�KSLV,D=6.38" 6692' 95/8' X 7"BKR HMC LNR HGR, ID = 625" $906' 95/8' CSG, 47#, L-0 BTRS, D =8.66P 9133' I—I 10653' 10655' 1 8$15' 9-518' X 41/2" UNIQUE OVERSHOT 68'14• 412" F$ X NP, D = 3.813' . SPERRYSUN AWR ON 07/01/96 10669' ANGLE AT TOP PERF: 51'@10632' 9-5/8' X 412" BKR S-3 FIQR, K)=3-88( Note: Referlo Production DB for tisbrical perf data SIZE SPF MLLOIfT WINDOW (J -11A) 9133' - 9144' OpriSqz 10463' 7' X 412" BKR PRNR PKR ID= 3.833" 412' TBG, 12.6#, 13CR-80 VAMACE, .0152 bpf, D = 3.958' I—I 10653' 10655' REF LOG: WA ACOUSTLOG ON 0623196 41/2' TBG, 12.6#, L-80 BTRS,10676' .0152 bpf, D = 3.958' 10532'--�1'CAMCO GLM (BEf1NT$J STRAq 10601' 4-12' HES XN NP MLLED TO 3.80' 10622;--1 - 0651' (3) 412' BLAST JOINTS 129 70653J�412" PERFORATION SUMMARY 10655' REF LOG: WA ACOUSTLOG ON 0623196 7- 7- LNR, 26#, L-80, .0383 bpf, D = 6276' j 0922• . SPERRYSUN AWR ON 07/01/96 10669' ANGLE AT TOP PERF: 51'@10632' 03/05/12 Note: Referlo Production DB for tisbrical perf data SIZE SPF INTERVAL OpriSqz OT SQZ 4-12' 5 10632-10640 O 07/0696 D-16 2-3/4' 4 11170-11210 C 07/06/96 GLV CA) 0423111 2-314' 4 11270-11550 C 07/06/96 2-3/4' 4 12100-12400 C 10/12/01 10532'--�1'CAMCO GLM (BEf1NT$J STRAq 10601' 4-12' HES XN NP MLLED TO 3.80' 10622;--1 - 0651' (3) 412' BLAST JOINTS 129 70653J�412" SE4L ASSY, D = 3.958" 10655' 7" X 4-12' BKR SABL.3 PKR, D = 7- 7- LNR, 26#, L-80, .0383 bpf, D = 6276' j 0922• 07/12160 10669' 41/2' HES XN NP MLLED TO 3.80 1 10676' 1 TNV LTPw/TEBACK SL' TNV DTH LNR HGP, D = 1 WRP (1110619) 412- LNR, 12.6#, L-80, .0152 bpf, D = 3.95W I 12630' DATE REV BY 11844' CTM -3-3/8" CBP, PUSHED DOVNV 1- 7- 7- LNR, 26#, L-80, .0383 bpf, D = 6276' j 0922• 07/12160 11950' CTM :1 412' Q DRLL CBP (10/12/1 03/05/12 PBTD1�� 07106196 12382' CTM SIDETRACK (J -11A) 412' CBP, PUSHED TO BTM 412- LNR, 12.6#, L-80, .0152 bpf, D = 3.95W I 12630' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/12160 N18E ORIGINAL COMPLETIO 03/05/12 118/PJC PERF CORRECTION (70196) 07106196 N28E SIDETRACK (J -11A) 11/05/13 TAO/JMD MILLED XN NIPPLES (1021/13) 05105102 046 RWO 0321119 JWUMD CORRECTED MIN ID 08/1209 D-16 RWO 11/12/19 GJB/JMD SETWFDWRP(1110619) 0427111 AH/PJC GLV CA) 0423111 12105/19 DD/JMD ADDED OKB, REF, BF ELEV 8 FD(ED CSG DEPTH 06/01111 MBM/PJCGLVC/0(0529H1) PRUDHOE BAY LINT WELL: J -11A PERMrr No: 1961040 API No: 50-029-20462-01-00 T11 N, R13E, 648' FNL 8 804' FEI BP Exploration (Alaska) iimommmmmumommmommimmmmmmmmmumimmmlmmmm V OF Tye w\��\ s7 THE STATE Alaska Oil and Gas ofA AsKA Conservation Commission •#x_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 ALAS' Fax. 907.276.7542 www.aogcc.alaska.gov Steven Cinelli SCO Production Engineer BP Exploration(Alaska), Inc. G P.O. Box 196612 I 1 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-11A Sundry Number: 315-474 Dear Mr. Cinelli: 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 by4:30 PM on the 23rd dayfollowingthe date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this /3"day of August, 2015 Encl. STATE OF ALASKA i.\,[j1::, n 4 ),`i l:.,, ALASKA OIL AND GAS CONSERVATION COMM, iN APPLICATION FOR SUNDRY APPROVALS O7'5 ell ) is 20AAC25.280 \n k...71 Lf 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other 7 v i r fly/20-1-7 It- 2. Operator Name. BP Exploration(Alaska),Inc 4. Current Well Class: • 5 Permit to Drill Number 196-104J • 3 Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20462-01-00- 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 0 No Q PBU J-11A• 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028281 • 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): 12630 • 9067 • 11950 9015 11950 11844/12382 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 0 0 Surface 2530 13-3/8"72#L-80 32-2561 32-2555 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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 See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13 Well Class after proposed work: BOP Sketch 0 Detailed Operations Program Q Exploratory 0 Stratigraphic 0 Development Q ' Service 0 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Cinelli,Steven Email Steven.Cinelli@bp com Printed Name ,Steven Title Production Engineer Signature i(T t Phone +1 907 564 5919 Date 10 1./ /✓ COMMISSION USE ONLY �j Conditions of approval:Notify Commission so that a representative may witness Sundry Number 31 5 4 iq Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No ® Subsequent Form Required: //, --- / (�4-- ` APPROVED BYTHE Approved by: a/42 eie__vrV.,....., COMMISSIONER COMMISSION Date:9_,5_,5 VTt_ 6/iv/i c RBDMSAUG 1 4 2015 URGN AL -OS ',- . c• ,s Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 2 gd 10— a O o 0 0C) 0 0 0 0 N cO (O c0 o O O O cflNNNvLOLOLC) LO O N 'Cr 'Cr Lo N N N N U N 0 0 0 0 0 0 0 0 0 I- CO N N N CO CO CO CO • O CO CO CO N V d' V CO d' CO CO CO N CO CO CO CO CO 'Cr CO N CO N N CO CO N N CO CO '� LO O O CO O O LO CO CO N N N N CO O) N CO CO I I I I I 1 1 1 1 1 H O CD N N CO 'Cr N N N- CO CO II) O) N CO CO CO CO O O CO CO N CO N N N CO N CO CO Sr CO N CO CO E LO N- OO (fl Cfl N N N O O N 0 0 V CU • Q coco N N CO CO O 0 0 CO CO CO O O CO cp N CO CD I N N CO CO CDCD a O O p O O C_ 02 O a oCD CO c U U , JJ CO F- J c cJ = O * Z c NCr) N -PT J ( co X N- N N O00 N U N M, Lo 0\�p Lo N N V 4 d7 O) N r- O CO CO N t O) 1U N C CO LI) CD CO 0 0 O) N CO N ) N N N N CO J W W W Q Q Q c „• 0 0 0 N U U W W W U a Z Z_ Z Z W W W W W m CO CD F- ZZDDD 0 u) Z Z Z F- a, N co co (0 — N CO N ,- 00001-0 Q O ,— (.O O c0 0 co 0 0 v p co O O O c) 0 c0 a) a) a) a) > H a O F- Lf) I- (O CO t N 0) O a L() O OM N O 0 O co O C) O O > p oo rn a) a) 0 > 2 r w cY a w z 0 . w o co w a H H J 1 W 0 ¢ Y U O(n O 0 0 <co co coY H g t 0 0 0 N 0 J Lij U.1 ▪ d' Ln CO O J tij Q Q W 4-0 1 z C d U U • ON N J Jc .- N _ _ _ p E y 2 Z 2 z < < a FH O t 2 00 0 11102 c z O z O Q 2 2 2 O c~n cnn c¢n (Jn (¢n CU r +++ r a Q I O 1- a t N 0 0 0 N Q co N- N- O CO • CO p O ,- - CV N casco L a) L G' co -1 I H 0OH d J a 2 z 2 O cn cn co cn cn a) CL 0 0 0 c .2 U CC CC U) U) is I— W W d W y U) W O m m a 0 0 a a) H a CO CD o o 0 D c Ocy)O O O O W z pN N N O 1 1 < W E N• CO CO CO CO 0 1 7 L J O N CCLil CC _ _ :7 U W W w W O. V L) Ln Q 0 _ J H J J J D 1 a. O m a D Y w J J Q O w w < < xi O Cn LL U 1 U) 1 cc 0 E cis z Q Q Q Q Q cn .— ,— .— ,— w 1 V) O Li N Y w CO 1 1 C.) -1001.11 Q Q CO CCI L.L. LL co co 1 cx ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15/ General Information Well Name: J-11A Well Type: Natural Flow Producer API Number: 50-029-20462-01 Well Activity Conventional 4 Classification: Activity Description: Profile Modification Cost Code/AFE: APBNRWOS Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Required? No Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Steve Cinelli Contact numbers: (907) 564-5919 (907) 240-071 Well Intervention Engineer: Jaime Bronga Contact numbers: No Data No Data Lead Engineer: Chris Stone Contact numbers: (907) 564-5518 (907)440-401 Date Created: July 15, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate lnj Rate Gas Injection GOR Gas Lift Rate FTP or Injectic Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 7/13/2015 549 6354 bwpd, 29,465 53,680 96 0 1,079 WC 92.05% Current Status: Operable Flowing Inclination>70°at Depth(ft) 10,935' MD Maximum Deviation (Angle and Recent H2S (date,ppm) 4/27/2011 10 ppm - Depth) 11,136' MD — Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 29° 10,947' MD Reservoir pressure(date, 1/1/2011 3,175 psi Minimum ID and Depth 3.80"(0 10601 psig) Reservoir Temp, F 208° F Shut-in Wellhead Pressure Known mech. integrity None problems(specifics) Last downhole operation(date, operation) 10/29/2015 Broach, Drift with SL Most recent TD tag(date,depth, toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, J-11A was drilled in 1996 to the J-Pad GDWFI block. The well was completed with blast joints and a Camco GLM background information, across a zone 4(43P oil lens).The well underwent a RWO in 2003 to replace the tubing. An IBP was set at 10,750' etc: to secure the well prior to the RWO. Following the RWO coil was required to do a FCO on top of the plug to remove debris from the workover,failed attempts were made to pull the plug,which finally resulted in coil pushing the plug down to 11.844'CTM. A flow sleeve was set in the well post-RWO to allow for commingled Zone 4 and Zone 2 production. It was SI in 2009 after the field pad operator reported bubbling in the cellar. This kicked-off further diagnostic work to determine the point source of the bubbling. Early June 2009,the surface casing was UT'd which proved there was no damage to the casing. Three days after the UT of the surface casing,a MIT-OA performed with nitrogen to 500 psi which failed. The failed MIT-OA with nitrogen and the detection of nitrogen confirms the presence of a surface casing leak. A RWO was performed in August 2009 to repair the surface casing leak, ultimately cementing the 9-5/8"x 13-3/8"annular space to surface. A WRP was set at 10,710'in May 2010 to isolate Zone 2 perforations and produce solely from Zone 4. The hopes were that this would provide water shut-off and make the well more competitive. The water shut-off worked,however after a couple of well tests,the GOR rose above MGOR and the well was no longer competitive and shut-in. The WRP was pulled August 2010 giving way to commingled Zone 4 and Zone 2 production. The result of the commingled production resulted in the water rate coming back to pre-WRP setting rates with oil and gas rates remaining similar as when the WRP was set. In April 2011,a DGLV was set in station#1 at 10,532'to isolate Zone 4 in reducing the gas volume produced through the well and returning production to Zone 2 at lower gas rates and a more competitive GOR but the oil rates and GOR stayed same.A caliper log was run in May 2011 and found a tubing hole®10,628'and it is believed that the zone 4 production is coming from the tubing hole©10,628'even though a DGLV was set in station#1.Caliper log report also found deposits in parts of the tubing from 10,597'-10,600'and 10,647'-10,648'.On 8/7/12 and 8/8/12,SL broached to removethese restrictions.After broaching,SL was unable to work past 10,632'with 20'x 3.70"dummy patch. During October 2012 SL returned and completed more drifts,but ultimately CT returned on 21-Oct-2013 to mill scale. After milling(27-Oct-131 SL was able to drift with a 20'x 3.7"dummy whipstock to 10,648'SLM,which should be sufficient to set this patch. Immediately thereafter work on the well ceased as OA repressurization issues resurfaced. On 14-May-2015 the OA was treated with Well-lock,and the well passed an MIT-OA to 500 PSI with N2. / The goal of this intervention is to set a patch over the hole in the blast joints at—10,628'MD to reducing the !, well's producing GOR. Well Intervention Details Suspected Well Problem: HGOR Specific Intervention or Well Objectives: 1 Set a patch over the hole in the blast joints at—10,628 2 Obtain jewelry log 3 Key risks,critical issues: Mitigation plan: 1 Unable to drift to patch location attempt to broach well;move patch uphole 2 Uncertainty regarding gas entry locations Set large patch 3 Depth control Read program&communicate with APE as necessary Summary Service Line Activity Step# 1 S D&T with dummy patch. Broach as necessary 2 E Set Baker 45 KB packer at 10,662' ELMD 3 S Set snap latch patch and upper Baker 45 KB packer Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): A) MIRU SL B) RIH with TEL and locate tubing TT(010,676' ELMD. Correct SLM depths. -Much of the previous D&T work was done without locating the TEL. On 16-Oct-2012 SL tagged the TEL and depth corrected (TT CO 10,663' SLM/10,676' ELMD). A 3.70 WRP then set down at 10,637 SLM. It's unclear if this depth was corrected. If it was then it SD at 10,650' ELMD. Depth control is very critical as the PE will have to used the depth from this SL work to decided if we need to bring CTU back to the well or not. Please ensure all depths are recorded in A WGRS as both SLM and ELMD so there is no ambiguity. B) RIH with 3.75" broach and drift to deviation. Broach as necessary to at least 10,670' ELMD. -On 29-Oct-2013 SL was on the well drifting and broaching. At that time it was clear that there is an obstruction at 10,643' SLM, . The last broach run was with a 3.79"broach while pumping crude at 0.5 1 S bpm. The broach passed the obstruction by jarring down, but was POOH with little resistance after passing the obstruction. However, SL did not tie-in to the TEL, and exact depths are unknown. C) RIH with bailer and attempt to get a solids sample from devation. -Obtain a large enough sample for lab analysis. Send the sample to the GPB lab for a full compositional and solubility analysis. Forward the results of the analysis to the J Pad APE. This well very likely has a scaling problem and understanding the nature of the scale will help with future scale removal and inhibition efforts. D) MU Baker 45 KB dummy patch and drift to deviation. Ensure that drift reaches 10,670' ELMD. -We have had trouble drifting this well in the past. However, we should make a good effort to drift and broach a dummy to 10,670' MD with SL. If SL can't reach 10,670 please contact the APE with the final drift depth before RDMO. El RDMO SL • A) MIRU cL B) MU GR/CCL toolstring and pull a jewelry log from deviation to 3,000' ELMD. -Tie-in log:3-5/8"Chemical Cut Record w/String Shot on 03-Apr-2002. The tubing was cut and removed above 10,592', so ensure that the tie-in is completed in the TT BELOW 10,592'. C) Set Baker 4.5" KB packer with seal element at 10,662' MD. -The SLB Chemical Cut Record from 3-Apr-2002 shows the jewelery over the patch interval. This log should be sufficient for tie-in. It DOES NOT show the hole in the blast joint, but the 28-May-2011 PDS 2 E caliper log shows the hole 41'above the tubing tail. I have marked the location of the hole on the tie-in log. The tie-in log matches the tubing tally. However,the tubing tally has a hand written note that the TT was cut at 10,645' MD. THIS IS INCORRECT. The chem cut log correctly calls out"Cut tubing at 10,592' above blast joint at 10,597". -Do not set the packer over a collar. Verify that the specified set depth is not in a collar prior to setting the packer. If so,adjust the final set depth as needed. C) RDMO EL A) MIRU SL B) RIH with lower snap latch assy and set into Baker KB at-10,662' MD 3 S C) RIH with upper snap latch assy and connect to lower assy. Set upper Baker KB packer at-10,612' MD. D) RDMO Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 550 MMSCFD: 20 BWPD: 6000 Expected Production Rates: FTP(psi): 1050 Choke setting: 96 Post job POP instructions: Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: 14) 0 Producer L'21-- Techlog NOTE(Dec.2000-STP) Minilog NOTE LWRP Set 5/7110) P'o,ecPBUGDWFI SOS 43P Well: J-11 A 7 416 al&a water 43P Author LauraJ. Larson Scate 1 3200 509627P 26%d&96%water 27P Da tf• 9/16(2013 734 .x.wit*to `44$4.0 NI*te$1411.17 MON . 4.44•544. 414 snit' moon Dais, s47441 NAOS, ,.aAAA1 Pr weir.4,8,41, *,. . r a Na31: ltraAJAIA1-14 OSS77 • 1 SPOISI 1440 a Ofl UT LAMMAS Hi Wild 1.4,Aar IOU , , 0 IIPLA - GR T- I AfIRAL i I Mur,ResisrIony 0 -19/4/Ft -Oa PE Comments - GR TVDSS PAO iie MOSS RE i DEP r ''‘ ERST,OR (cm) (FET) imiftivoss etsr RotEP 13200 13200 2 ‘9'... o API zoo t 9000 fv,00'01 oiimm 100 4 <, tial I ism es" - ' I / - ko..1111. 42 . . ;,,,-Ir;,,,,,_---- gm -- _ r 10100 - i -- . Set Patch.10,612'MD to 1 ' siso• III" over hole at 10,621'M I il ., . - nil . WRP set at 10,710* 4c. moo• 411 .tO7SO MO Set RR WIN SIP Sis0... ' WRP rwwwid item ,- Mit, Wel la 4/23/111 0.-- , 4 , $IM \ 1 CS' ' , I 192°4'IMO/-- — Amampasonsao ' On a 1 NA, ' - a ail ''' Il• --7- i111,0 ^ _ , liEM 17,.. * l. $1on -4. IMO. . r no 1 117S0 1 nil i iiCISP Set 9/96 ..:41 . , (Wiled&Rerun'01) -I2000.- .- — I • ....1 , I ,12.10. .. IIII ..._ _ ONO All ' . Si" 12S00- .-- 21, - I ONO , t , • • FILE COPY , . _ . Schlumberger Comoari; BP Exploration (Alaska), Inc. Well: J-11A Fielo: Prudhoe Bay Bo:o ..igh North Slope State: Alaska 6 ' 3 5/8" Chemical Cit Record wi String Shot To- -.1 1 03-APR-2002 kit L... 64FNi & 804 FFI Be/.. KB 73.4 ft Zs 45 8 gt cp ci5 ts 2 At Surface GL a45 ft 9 Okt Cr 71.9 ft 6 g .. a p--...-. < x , t , Lu Perm anert Datum MSL Elev. 0 ft 'c 6 :7) 1 -i Log Measured From FIX B 73.4 ft above Perm.Datum ,i. ii S a DnU'ng Measurec From. RKB _ Cif - API Serial No I_ Secbon Township Range 8 L 13 $ 3 50-029 20462.0' 9 I 1 N 131 Logging Date 3-Aps.2002 — _.....— _ . _ Fix)Number ____ *------ ---- — Depth Driller 10750 ft Schlumber9er Depth _ Bottom 1 w Interva; 10710 ft ......,— Top tog Irterva' 10440 ft Caszig FiUK3 Type Produced Fluids .... Sal,n_V FINAL -- Densdy .... _ _ 1-tud Level BiTrCASING1'USING STRING _ .._. Bit 92e From . _ ____ —__ ...., — . . __ To _Ca10.4robelkSize 4500 in WIght12.6 Ibrrtfit , — — -,-- Grade L-60 .....-,..... From Oft -c ft 10676 _ ...... CCL 0:1.J-on-Level 0.3 V RFO Yodla!Sals: 5'per 100 Graphics I Ie Created 03-Apr2002 11 00 OP System Version: 1000-306 MCM 1000-308 SAFE 1000 306 1000-306 Output DLIS Files PERF0_009LUP FN:8 PRODUCER 03-Apr-200211:00 thlumbeepr JEWELRY LOG LJAXI` I v hl Irv, Output DLIS Files PERF0 0081UP FN 7 PRODUCER 03 Apr 2002 10 52 10720,0 FT 10439.0 FT OP System Version: 1000.306 MCM 1000-308 SAFE IOCO.308 1000-306 PIP SUMMARY asst Every SO S i Collar Locator(CCL) Shifted Casing Collar Locator(SCCL) Tension(TENS, (--) 1 -10 (---) 10 4000 LBF) 0 • tats—t>• iimeneemin 21111 SHORT 1�i1 EN GLM#2 ���� $ 'HORT • II • l � i .,Gn j • - 111111111 -_'. . i, SNORT,r` r _` - - , PACKER Aa t' _..- i� AIL IL XMP �— , . . – ii , GLM*1 - .. I_ �.__ _ — t • _ • .._:t — .�� , { } ' 1 1 r I _.,.....-- , , .._ ii, _..• t - . . _ . toBooi 7 ■ BLAST J7/, ---4. ----- ' i Upper Patch assy set on SL at-10,612'MD mid-element r _ +. Approximate location of the hole in blast join., am''Mr identified on 28-May-2011 PDS caliper log . • 1 '4' _ 1 XN NIP Lower Packer set on Eline at 10,662'MD m' '- element t MVLEGI , 111111• Mi � ^-4. WLEG='"10,673'MD ' 1 I I �'�— ea MINIM WA� 10700 1 _4, ! 11,1 i-`,11 II t .II!" !Collar Locator(CC14 ShRMd Casing Collar Locator(SCCL) Tension(TENSA (----) 1 -10 (---) 10 4000 (LBF) 0 PIP SUMMARY rk Every 60 S Parameters snm�- n...rin • . Tubing Detail BP'+ _ 11* .400411 h M)4 Ow r BP', wi 0.184 Cat" 4 14 .47 ITC44 4 __ __ TAW rt., 11 le W1t!F4& 30113 011 VCR 23' 346117 18 0 00410 *701.40 FT 011 RACK '42'2 'TRW LSm fr••• 1 R411044.•'&1«•72o,4.s 387£, ` •' !t,'...* MI .... . ..R ... 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L,\ 1 's' (:)(101 iaq/o iz — TREE= CNV TY NOTES: WELL WELL = FMC J -11 A S'4 -1/2 CHROME TUBING ANGLE ACTUATRR= BAKER C ORIG WELLBORE AT OKB.ECFV 69.21' I 1 I NOT SHOWN BELOW 9-5/8"MLLOUT"' BF.ELEV_ 40.1' KOP= 2350' ' , 2009' ---4-1/2"HES X NP,D=3.813" Max Angle= 94"@ 11136' Letum MD= 10710' GAS LIFT MANDRELS x ST PA) ND DEV TYPE VLV LATCH PORT CATS Datum ND= 8800'SS 5 3886 3753 37 MMC DMY RK 0 05/29/11 9-5/8"HES ES CEM3YTER —{ 2009' 4 6280 5608 42 MMC DAY RIC 0 05/29/11 9-5/8"BKR I3OZONE ECP,D=8.620' H 2031' 3 7745 6720 38 MMC DMY RK 0 08/11/09 2 8581 7397 37 MMG DMY RIC 0 08/11/09 9-5/8"CSG,47#,Fr(D 563,D=8.681' —1 2052' '1 '10532 8761 49 KBG-2 DMY BK 0 04/23/11 9-5/8"BOWEN CSG PATCH,ID=8.770" — 2052'-2056' , *GLM#1 IS BEfVVEBV STRADDLE PKRS 13-3/8"CSG,72#,L-80 BTRS,D=12.347" -- 255E 8662' H4-1/2"HES X AP D=3.813" Minimum ID = 3.725" @ 10601' 75Z x,' 8692' H9-5/8'X 4-1/2"SKR S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE I I 8727' H4-1/2"FES X MD,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, — 8799' / 1 8815' _H9-5/8"X 4-1/2'UNIQUE OVERSHOT 0152 bpf,D=3.958 ' ,I—j 8844' H4-1/7 HES X NF D=3.813" 4-1/2"TBG STUB(08/11/09) —1 8805' ><-.1 8865' —{9-5/8"X 4-1/2"BKR S-3 FCR,D=3.880" 1 9-5/8"X 7"BKR ZXP LTP w/TEBK SLV,D=6.38" I I 8892' i 9-5/8"X 7"BKR HMC LIVHGR,D=625' -1 8906' j' MLLOUT W OW(J-11A) 9133'-9144' 9-5/8"CSG,47#,L-80 BTRS,D=8.681' —1 9094' r 10463' Hr X 4-1/2'BKR PRMf2 ESR D=3.833' 2g=r_....-1.---- 10532' —11"CAMCO GLM(BETVVEEN STRADDLE PKFtS) ' ' 10601' H4-112"HES XN NP MLLE)TO 3.80"(10/21/13) 4-1/2"TBG,12.6#,13CR-80 VAM ACE, — 10653' �' ill 10622'-10651' —{(3)4-1/2"BLAST JOINTS(29) .0152 bpf,D=3.958" ` 10653' —14-112"SEAL ASSY,D=3.958- 4-1/2" .9558"4 1/2"TBG,12.6#,L-80 SIRS, 10676' 10655' H r X 4-1/2"BKR SABL-3 PKR,D=3.875" .0152 bpf,D=3.958' S PERFORATION SUMMARY I ■ 1 10669' —j 4-112"E fes.,XN NP MLLE)TO 3.80"(10/21/13) REF LOG: WA ACOLSTLOG ON 06/23/96 *SPERRY-SUN AWR ON 07/01/9610676'10676' —14-1/2"WLEG,D=4.00" ANGLE AT TOP PERF: 51"@ 10632' 4 0_ 10683' H7"X 4-1/2"TNV LTP w/TACK SLV,0=3.890" I Note:Refer to Roduction DB for historical perf data _ SIZE SPF I4TERVAL Opn/Sqz SHOT SQZ 10695' —17"X 4-1/7'TNV DTH LNR HGR ID=3.918' 4-1/2" 5 10632-10640 O 07/06/96 L 2-3/4" 4 11170-11210 0 07/06/96 2-3/4" 4 11270- 11550 0 07/06/96 2-3/4" 4 12100-12400 C 10/12/01 1 R 11844'CTM —3-3/8"CBP,PUSHED DOWN HOLE(05/31/02) to 7"LW,26#,L-80,.0383 bpf,D=6.276" — 10922' 11950'CPA H4-1/2"EZ DRLL CEP(10/12/01) 12382'CTM H4-1/2"CEP,RJSI-f)TO BTM(05/14/01) PBTD — 12585' 4-1/2'UR,12.6#,L-80,.0152 bpf,D=3.958" —1 12630' DATE REV BY COMWEJTS DATE REV BY tX)tt 1TS PRUDHOEBAY UNIT 07/12/80 1418E ORIGINAL COMPLETION 04/27/11 AI-VPJC CLV 00(04/23/11) WELL J-11A 07/06/96 N28E SIDETRACK(J-11A) 06/01/11 WM'PJC GLV 00(05/29/11) PERMIT No: 1961040 05/05/02 D-16 RVVO 03/05/12 MBI PJC PBRF CORRECTION(7/6/96) AR No: 50-029-20462-01-00 08/12/09 D-16 RWO 11/05/13 TAO/JMD MLLE)XN IVJES(10/21/13) SEC 9,T11N,R13E,648'FNL&804'FEL 04/25/11 AM-VPJC CLV 00(04/23/11) 04/25/11 PJC DRAWING CORRECTIONS HP Exploration(Alaska) • Wallace, Chris D (DOA) ISI III& From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,June 17, 2015 8:52 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; 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; AK, OPS Well Pad RJ; Cinelli, Steven; AK, OPS GC2 Facility OTL; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Sayers, Jessica; Regg, James B (DOA); Pettus, Whitney Subject: OPERABLE: Producer J-11A (PTD #1961040) Well Lock Treatment Complete Attachments: image001.png; image002jpg; image003.png; Producer J-11A (PTD #1961040) TIO Plot.docx All, Producer J-11A(PTD#1961040) outer annulus was recently treated with Well-lock product to mitigate high OA pressure from an external source. The well was placed on production June 01, 2015 and monitored over the next two and a half weeks. The outer annulus pressure has been found to be manageable by bleeds. The well is reclassified as Operable and may remain in service. A copy of the TIO plot is included for reference. Please call with any questions or concerns. s tte JUN 2 6 2.015 Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator Gsobat V�. Organzmto WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, Well Integrity Coordinator Sent: Sunday, May 31, 20125 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Fie O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Oper tions Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; Cinelli, Steven; AK, OPS GC2 Facility OTL; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Sayers, Jessica; Regg, Jame B (DOA) (jim.reqg@alaska.gov) Subject: UNDER EVALUATION: Producer J-11A (PTD #1961040) Post OA Wellock treatm All, 1 Producer J-11A (PTD#1961040) TIO Plot June 17, 2015 -0-01 -0-M • Mk .+c,.s ann -aac,e a»x aaac sacro am sve sa n sash t.6 >:.. 71 F CE VED STATE OF ALASKA / ;KA OIL AND GAS CONSERVATION COMA JION i U N! 0 8 2015 • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull TubmL Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casin[ I .1 Change Approved Program E Plug for Redrill Ej'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other _Wellock Treatment_ Q 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 196-104-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-20462-01-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028281 PBU J-11A 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 12630 feet Plugs measured 11950 feet true vertical 9067 19 feet Junk measured 12382 feet Effective Depth measured 11844 feet Packer measured See Attachment feet true vertical 9016 76 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 32 29-112 29 32 29-112 29 0 0 Surface 2529 6 13-3/8"72#L-80 31 79-2561 39 31 79-2554 84 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10632-10640 feet 11170-11210 feet 11270-11550 feet 12100-12382 feet 12382-12400 feet True Vertical depth 8825 15-8830 16 feet 9000 47-9001 01 feet 9003 2-9006 32 feet 9012 96-9016 03 feet 9016 03-9018 52 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary- Intervals treated(measured) 31 79'-2561 39' SCON i ! a, ��t ;+,Ij ii i.' Treatment descriptions including volumes used and final pressure W� 5 5GALS WELLOCK 13 Representative Daily Average Production or Injection Data 1 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 401 17757 8034 0 857 Subsequent to operation 471 20534 8890 0 871 14 Attachments(required per 20 AAC 25 070 25 071,8 25 283) 15 Well Class after work Daily Report of Well Operations ❑ Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil U Gas U WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt 315-187 Contact Nita Summerhays _ Email Nita.Summerhays C!_bp corn Printed Name Nita mmerhays Title Data Manager Signature 1'�/?)�:/ i, - Phone 564-4035 Date 6/5/2015 1/7-7- 71/4//5" RBDMSJ JUN 1 1 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028281 T/I/O= SI/2100/0. Start Barriers list=VR plug (single isolation)able to T-bar in VR plug with written authorization. Add companion OA FMC valve tag#29. Torqued and PT'd to API specs. 5/13/2015 RDMO"""Job Complete***SEE LOG FOR DETAILS. Final T/I/O=S1/2100/0 T/I/O = SSV/0/15. Temp= SI. Wellock treatment for cemented OA. Heater in well house, Wellhead temp= 100°. Bled OAP to 0 psi and pulled bull plug from OA casing valve and ran pump hose to TOC. Pumped 5.5 gallons wellock to get returns, pumped additional 1 gallon for clean returns. Reinstalled bull plug and pressured OAP w/N2 to 2140 psi and monitored for 18 hours. N2 cap&Wellock tags hung on OA. See Log for details. 5/14/2015 """continued on 5/15/15 WSR""" FLUIDS PUMPED GALS 5.5 WELLOCK 5.5 TOTAL • CI) a 0 0 0 0 0 0 0 0 0 C\ N- N V Ln (O Ln Ln L() O V Ln N N- U N O o 0 0 0 0 0 0 0 i N- N N M CO M CO M 7 CO O CO N V 0) V Nr V- IM m CO CO CO r- O NY CO CO CO I- CO N O) CS) V N LO (U CO N N. co N- CO O N M LO CO c Cfl CS) N I� . Lf) CO - LO O O CO O) O LU Ln CO c0 N f- CO N f- CO CO H V M CO N- CV t- O N LU O) O) CO O) 0) V N V of COL1) V N L() CO V- LO NO i- co co m 0 0 CO O M LO CO N N f- CO N- CO N O M CO CO N M CO N U') ~ O CA CO LC) 0 O E N cm= N 00°° 0 0 CO 4-0 < N CN N COO CO00) N O) coCO co tooN N CO CO N 00 00 N = CO 00 O O omo00 c0 CO 0 c0 CO 00 0 0 CO = J z J c0 J J M M 4t = d co *k *k J (0 N # *k co N X r *k I� co CO •� fn Q 60 r N CO N N N aO N M -LO LO N N - N rn v � �r v v +� Ln O O) O N O CO N co 6) to N- C CO O CO O O O) LU N- O N d N N N O J W W W co 1- 0 0 0 y O W W W W U p cCrYcCccccW Z_ Z_ Z Z W W W W W m m m O H H H Z Z D D D D UZZZJH Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription J-11A PACKER 2037.89 2037.84 9-5/8" BOT External CSG PKR J-11A PACKER 8699.08 7490.51 4-1/2" Baker S-3 Perm Packer J-11A PACKER 8870.69 _ 7625.19 4-1/2" Baker S-3 Perm Packer J-11A PACKER 8898.3 7646.63 7" Baker ZXP Packer J-11A PACKER 10468.66 8719.03 4-1/2" Baker Premier Packer J-11A PACKER 10652.35 8837.88 4-1/2" Baker SABL-3 Packer J-11A PACKER 10693.38 8863.41 4-1/2"TIW Top Packer TREE r CAN ACTUATOD R J -11 A '"4 1/2 CHROME TUBING'EOR G WELLBORE = BAKER C OKB.E LEV= 69.21' I •' 11 I NOT SHOWN BELOW 9-5/8"MLLOUT"' BF.ELEV= 40.1' KOP= 2350' .0 • I 2009' H4-1/2"I IE..X NP,D=3.813" 'Max Angle= 94"@ 11136' / Datum MD= 10710' GAS UFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE Datum ND= 8800'SS 5 3886 3753 37 MC DMY RK 0 05/29/11 9-5/8'FES ES CEMENTER — 2009' 4 6280 5608 42 MAG DMY RK 0 05/29/11 9-5/8'BKR ISOZOPE ECP,D=8.620' H 2031' 11 3 7745 6720 38 MAG DMY RK 0 08/11/09 2 8581 7397 37 MAG DMY RK 0 08/11/09 [9-5/8"CSG,47#,HYD 563,D=8.681" —1 2052' 1 *10532 8761 49 KBG-2 DMY BK 0 04/23/11 9-5/8"BOWEN(SPATCH,ID=8.770" — 2052'-2056' 'GLM#1 S BE71M�J STRADDLE FKRS [, 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2556' t 8662' 1/2'HES X NP,D=3.813" Minimum ID =3.725" © 10601' ' . >< — 8692' —{9-5/8"x4-1r2"BKR S3 PKR,D=3.875" 4-1/2" HES XN NIPPLE I I 8727' —14-1/2"FES x NIP,D=3.813' 4-1/2"1BG,12.6#,13C R-80 V A M TOP, H 8799' -i 1 8815' —9-5/8"9-5/8'X 4-1/2"UNIQUE OVERSHOT .0152 bpf,D=3.958 4-1/2"TBG STUB(08/11/09) — 8805 _�4 1/7 FES X NP,D=3.813" l 8865' —9-58"X 4-1/2"BKR S-3 RKR,D=3.880" 9-5/8"X 7"BKR ZXP LTPw ITEBK SLV,ID=6.38" — 8892' 9-5/8"X 7'BKR HMC Ll..R HGR,D=6.25" H 8906' MLLCWT WIDOW(J-11A) 9133'-9144' 9-5/8"CSG,47#,L-80 BTRS,D=8.681" —I 9094' j--- Z Z10463' —7'X 41/2"BKR PRMR NCR,D=3.833" 10532' I"CAMCO GLM(BETWEEN STRADDLE P(RS) • 10601' —{4-1/2'I ICS XN NP MLLED TO 3.80"(10/21/13) 4-1/2"TBG,12.6#,13CR-80 VAM ACE, — 10653' I ' I] 10622'-1065 J—(3)412'BLAST/OMS(29') .0152 bpf,D=3.958" i , 10653' —41/2"SEAL ASSY,D=3.958' 4-1/2"TBG, 12.6#,L-80 BTRS, — 10676' 1 Q655' —7"X 41/2'BKR SABL-3 PKR D=3.875" .0152 bpf,D=3.958' g PERFORATION SIJMwAARY 10669' — 4-1/2"HES XN NP MILLED TO 3.80'(10/21/13) REF LOG: WA AC OIASTLOG ON 06/23/96 'SPERRY-SUN AWR ON 07/01/96 ' ' 10676' H412"WLEG,D=4.00" ANGLE AT TOP PERF: 51° ' 10637 i iff10683' —17"X 4-1/2"TMV LW w/TRACK SLV,D=3.890' Note:Refer to Production DB for historical perf data SEE SPF MERVAL Opn/Sqz SHOT S(O7 10695' —17"X 4-1/2"TIW DTH LNR HGR,ID=3.918" 4-12' 5 10632- 10640 0 07/06/96 k 2-3/4" 4 11170-11210 0 07/06/96 2-3/4" 4 11270-11550 0 07/06/96 2-3/4" 4 12100- 12400 C 10/12/01 — 11844'CTM -13-3/8"CEP,PUSHED DOWN HOLE(05/31/02) miam 7'LNR 26#,L-80,.0383 bpf,D=6.276' 10922' 11950'CTM H4-1/2-EZ DRLL CEP(10/12/01) 12382'CTM H 412"ClBP,PUSH To BTM(05/14/01) PBTD —I 12585' 4-12'LM,12.6#,L-80,.0152 bpf,D=3.958' —I 12630' DATE REV BY C)t#UTTS DATE REV BY COMbBJTS FRLCHOE BAY UNIT 07/12/80 N18E ORIGINAL COMPLETION 04/27/11 Ali/PJC GLV CO7 (04/23/11) WELL J-11A 07/06/96 N28E SIDETRACK(J-11A) 06/01/11 MEM PJC GLV C70(0529/11) PERMT No: 1961040 05/05/02 D-16 RWO 03/05/12 MB/PJC PERF CORRECTION(7/6/96) API No: 50-029-20462-01-00 08/12/09 D-16 RWO 11/05/13 TAO/JM) KILLED XN IWPLES(1021/13) SEC 9,T11N,R13E,648'FTL&804'FEL 0425/11 ANFYPJC GLV CJO(04/23/11) , 04/25/11 PJC DRAWING CORRECTDNS BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, May 31, 2015 4:25 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; 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; AK, OPS Well Pad RJ; Cinelli, Steven;AK, OPS GC2 Facility OTL; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Sayers,Jessica; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer J-11A (PTD #1961040) Post OA Wellock treatment Attachments: image001jpg; image002.png All, Producer J-11A (PTD#1961040) outer annulus was recently treated with Well-lock product due to high OA pressure from an external source. The well is reclassified as Under Evaluation to determine if the treatment was successful. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Bring well online 2. DHD: Monitor annuli for pressure trends Thank you, SCANNED JUN 0 9 2015 Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Monday, eJ_bruary 17, 2014 2:45 PM To: AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt n K,RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; Sinnok, Ralph; chris.wallace@alaska.gov; Regg, James B (DOA) (jim.reggOaska.gov) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer J-11A (PTD# 1961040) OA repressurization not manageable by bleeds 1 110 V OF Tk� • yw\�V/j_ss, THE STATE Alaska Oil and Gas -7ofALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Th Main: 907.279.1433 OFALAS*@. Fax• 907.276.7542 www.aogcc.alaska.gov Jessica Sayers ` Engineering Team Leader 1010 -(� BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-11A Sundry Number: 315-187 Dear Ms. Sayers: 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, Cathy '. Foerster Chair DATED this Zday of April, 2015 Encl. RECEIVED STATE OF ALASKA MAR 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Al GC( 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] o,�-�,��/t r7i k nnu r(r4k Operations Shutdown El Re-enter Susp.WOO Stimulate❑ Alter Casing❑ Other Well Lock'Teincdegy � - 2.Operator Name: 4.Current Well Class: 5 Permit to Dnll Number BP Exploration(Alaska),Inc. Exploratory ❑ Development E 196-104-0 • 3 Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20462-01-00 • 7 If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU J-11A Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number): 10.Field/Pool(s): ADL0028281• 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): 12630 • 9067 • 11950 9015 11950 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32.29-112 29 32.29-112.29 Surface 2530 13-3/8"72#L-80 31.79-2561.39 31.79-2554.84 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment 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: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Development 2 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations: 4/7/15 Oil 0 ' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Email Jessica.Sayers@BP.Com � Printed Name Jessica Sayers Title Well Intervetions Engineer Signature , Phon- 64-4281 Date Z0/15Prepared by Garry Catron 564-4424 / 4, COMMISSION USE ONLY Si Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 5-187 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No Lg Subsequent Form Required: /C —4 c 4_ APPROVED BY Approved by. 2(77V-4'‘ COMMISSIONER THE COMMISSION Date: 4. -Z_ t s- 7-1- 3/3i,✓! '/`'�J1 R I G n A I NA if-z-/ RBDMSAt APR - 6 2015 Form 10-403 Revised 10/2012 Approved application is vall�fdr 72 Molith_fr'omm the date of approval. Submit Form and Attachments in Duplicate �3/1./i,— - .‘i) 3• -,s— JUNK SUMMARY ADL0312828 SW_NAME MEAS_DEPTH MEAS_METHOD_CODE RUN DATE COMMENTS J-11A 11844 JUNK 5/31/2002 3-3/8" CIBP Pushed Downhole J-11A 12382 JUNK 5/14/2001 Milled CIBP 0 0 - 0000000000 moo CO CO CO CO CD J J z J J J co co J c- c- a) Q O O O O O O o O O (6 co co co f� V L CO O V t L N N- N- N- U 0 0 0 o O o 0 0 0 N- ti CO CO) CO CO CO CO CO CO N O) NI- Ca m CO CO CO N- CO CO CO CO a) co M CO V r` CO LO N- N CO N O N O) I` CO LC) CO 1O • O CO O O) O to LC) CO CO - N N N CO O) N N- CO CO H C2 O CO O N f— CO CV N— CO CO V LO N C) N- Q M CO O Co CO CO CO N 10 CO N N N- CO N- CO >+ ~ VC1 C a) Eco N CO M a— N CO M CO CO M O 0) M cos M CO O O N Q (NO) N o N co 0 U) O 2 CD J Cz D O CO O CV CO N- CO Q W ~ M CO C) C) CO CC) CV CO Cfl U N N CO CO O O O O O O p C2 CLO O CO CO 0O CO co U U CO J J Z COO J CO M N M „ J M N *k *k X *k (Ni co co N M - N N ON OO OO - (V - CV - N O) O) O) r r r O) O) O N Cn O CO N CO 0) IC) N- C CO O O CO O O) LC) N- CO N J N N- N N CO W W W cr 1— Q Q Q co Q Q Q •(7) 0W U U p ct Ltr 0ZZ_ Z W W W W W Cn CO m O H H i- _Z _Z DDD D U Z Z Z J J U) f I- F- Perforation Attachment ADL0028281 Well Date Perf Code MD Top MD Base TVD Top TVD Base J-11A 4/23/11 STC 10632 10640 8825 8830 J-11A 7/6/96 PER 11170 11210 9000 9001 J-11A 7/6/96 PER 11270 11550 9003 9006 J-11A 10/12/01 BPS 12100 12382 9013 9016 J-11A 10/12/01 BPS 12382 12400 9016 9019 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 Packers and SSV's Attachment ADL0028281 Well Facility Type MD Top Description TVD Top J-11A PACKER 2038 9-5/8" BOT External CSG PKR 2038 J-11A PACKER 8699 4-1/2" Baker S-3 Perm Packer 7491 J-11A PACKER 8871 4-1/2" Baker S-3 Perm Packer 7625 J-11A PACKER 8898 7" Baker ZXP Packer 7647 J-11A PACKER 10469 4-1/2" Baker Premier Packer 8719 J-11A PACKER 10544 4-1/2" Baker S-3 Perm Packer 8769 J-11A PACKER 10652 4-1/2" Baker SABL-3 Packer 8838 J-11A PACKER 10693 4-1/2" TIW Top Packer 8863 L4) ki To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: J-11 WeIlLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 03-17-14 CMIT-IA passed to 3000psi 07-03-13 OA Shell test @ 2000 psi, LLR 0.08 gpm Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1400 psi; Last H2S Reading: 05-24-2013 110 ppm Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 750-80° F throughout the entire job Relevant History: > 0908/12/09: RWO completed cement OA to surface > 01/05/10: MITOA Failed, LLR © 0.33 gpm @ 1000 psi > 06/07/11: MIT-OA Failed Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WeIlLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 TREE= GWI WELLHEACTUATOR,. FlACRC -I 1 A 5 4-1/2"CHROIII IliHIN6""ORRIG PIELL8ORE AGTIMTORn t3AKE3ZC OK&ELFV= 89 21' I r _ki NOT SHOWN BR OW 9 518"MITT OUT"" BEV EV= 40.1' X. KOP= 2350' )'9 I I •1 200W 4,1 111-K It NP,,I)=3813"' /Aix Angie- 94'0 11136' x' y Ditto m1.83= 10710' 1-C _ GAS LIFT MA S baton 8800'SS p' - - !ST' NO TVD DEV TYPE VLV LATCH PORT DATE 5 ' 3866 3753 37 /SIG DM( RK 0 05/29/11 4 51E'HELI s. MI N'I H t app♦!" ^ 4 6280 5608 42 IA.IG DMV FE 0 0512111 ELM'BIQS L`i(}ZOA[[4 d II "i 21131' 1a ' 3 7745 6720 38 41.43 DM( FE 0 0911/09 2 8581 7397 37 1/1.10 DMV 11K 0 08!11/09 19-578'CSG,47a,HYD 563,D-8 6+81'1-1/2057— "1 "10532 8781 49 KB13-2 DMF F3K 0 08/23111 19-5/W DLAMTtCSGPAnito-0.77R•j {2062•rn2068" ' , "01/4101iLSBEIWE3NSTTtACDLEMI5 13 n/e.enol ?PM,I-00 n-rr n n 1s 947•._.1 r 2S,'0' 8682" 1-FT/2"HES X ESP.D=].a13' Minimum ID=3.725'@ 10601' 1 -.--' _ 8692' H9-5/8-x 4-lir E40R S-3 PKR 0=3.875' 1 4-112" HES XN NIPPLE I I I 8727' --14-1rz`r1E5XPIP,D=3-613' 1.4 112'IHG,12.64.13C8-110 VA41 FOP, --1 8799" t 1- I 8815' -1_0-5/3'X 4-112'LINDLECNERSHOT 0152t I,D=3958 14-+n TBG STUB(08!/1109)Hr 8805' 1 8844' }—Ia 112 its x NP,D=3 813 �__�� `' l 8865 �9 51$ K4 1/2'OKRS3 FiSA I)_3 moll (stmt.7(7"E31(R 1X1 L IP w i 1 L tIK SL V,0 s 6.38' 91/518"x 7 BK1t rex LMit NGR,IU-6.29' -1 8906' 1—i 1 M&LOUT WM)OW(J-11A) 9133' 9144' 1 ��.••� l 4518 CSC,4741MRS,,L-80 RS,D-8.681' -I 9084' 10463' I-7'X 4-117 BKF:MAR PKR,D-3 833' Z 18632' H1'CPCO GLM 03E1INHEN STRADDLE PKRS)I I I 10801• -14-u2.1*S XN NIP NM U u»TO 3 SW(10/2V3.1)J 411Z'TBG,12B7713CR60VANACE - 10853 10622'-10651' -'.(314-1773AST X)MS(2S')1 01526pf,D=3058' �_- I 1 I 10653• H4-1/2'SEAL ASSY,0=3.968^ 1 1./2'/so,12BP,L SO MRS, )H 10676' .8152 bpf,D=3 958" 1\7N 1 ( 10655' I-17"x 4-1/7'FIKR SABI.3 ciat 1')=3.875' I FTX)NSLIMMARY r 10668 1-14-177 HIS XN r•1P P41 FR TO 1 BO"(10171/13) i FEY LOGc V6k A0OUSTLOG ON 06/23/96 •SF13E{Y-5114 AVNt ON 07101/96 -1 10676' I 14 1171$I(1,0. 4 00' ANGLE A T TOP F13if: 51" 10632' I 10683' 7'X 4-1t2"TAN LTPw/HACK SLY,0=3.390' NON..Pater to 19oduelon 0$for tustorlcal pert data S¢E SW 117733881/ C1pr115pz SHOT SOZ -4 10896• I--i7'x 4-1/2"1111/13111LNi FOR,D=3.916` 4-1x2" S 10634-10640 0 0706/96 2-314' 4 11170-11210 0 0706/96 2314' 4 11270-11550 0 0706/96 2-314' 4 12100-12400 C 10/12/01 I R11844'C7M-3318'CRP.R AND DOWN HOLE(05/31/02) T'cost 264-1-80..0383 040,0=6.276' 10-22" 11960'C7Mi-±41fT L2 DHLL CIOF'(1002,91(1 112382 CTM a-419•rte,Fusr—12TO B1U(05/141211 ( FB 1D H888• 1--- __... __ 14-177 L ,128#,L 00 01512 by D=3.968" H 12630" I WOE REU7 BY COMc647S EAE FEV BY 008/AB'1TS 1:18.O.0C BAY LAW 017/12(80 1118E ORIGINAL COMPLETION 04727/11 AHVOC_Q.V 00(04173/11) \'.6_L J-11A NNE SE SIDETRACK(]-11A) 061/01111 I7BM'PJCGLY00(05/29/11) PE4.41Ib: 1961040 05/05/02 0.15 RWO 01306/12 M3'PJC FUT'O3F61f1TI0N(7,1696) API It,: 50-029-20462-01-00 '08/12/99 D-16 RWO 11105713 TAG/Au MLLW XN NI 11,17:5(10/21/13) S1EC 0 71111 R13E.,648'FM_&801'NI 041?511 I At44PJC GLV CJO(04723/11) 0E25111 PJC TRAWIC GOF ECTO1- 8P Exploration(Alaska) 3 of 3 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts ~ Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy ~Vincent Nathan Lowell Date:-~' ' J ~1¢' Isl ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ OPERABLE: Producer J-11 A (PTD#61040) OA pressure stabilized 660 p~ Page 1 of 2 Regg, James B (DOA) ... ~_ _ w__ _ _ _ __ w... __m W.~ ~~ From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~~- 7~/S~j~ Sent: Tuesday, June 22, 2010 9:24 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Well Pad RJQ; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R Cc: Clingingsmith, Mike J (CH2M Hill); Janowski, Carrie; Stone, Christopher; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer J-11A (PTD# 1961040) OA pressure stabilized 660 psi All, Producer J-11A (PTD #1961040) has been monitored for OA repressurization since the IA pressure was bled on 06/12/10. The OA pressure has remained stabilized 660 psi for 7 days. The well has been reclassified as Operable. Please notify well integrity is the OAP becomes unmanageable. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Wednesday, June 02, 2010 8:19 PM ~- To: 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; 'Regg, James B (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; AK, OPS Well Pad RJQ; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; Quy, Tiffany; Wellman, Taylor T; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC) Subject: UNDER EVALUATION: Producer J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Producing well J-11A (PTD #1961040) has again been confirmed to have sustained OA casina Dressure. The wellhead pressures were tubing/IA/OA equal to 1040/1420/1060 on 5/31/2010. The well was worked over in Au ust 2009 to re air a SC leak b cementin the OA to surface. The well has been reclassified as Un er Evaluation and may continue to be online while further diagnostics are being conducted. Although OA gas samples confirm the source is external gas, not qas lift or produced gas, having the well on gas lift appears to continue having some Interaction with the sustalned casing pressure on the OA. The IA pressure will be bled down to assist with further diagnostics. Plan forward: 1. DHD: Bleed IA pressure below 1000 psi ~ 2. WIE: Monitor TIO pressures for 10 days and report back status to the AOGCC A TIO Plot and wellbore schematic have been included for reference. « File: Producing well J-11A (PTD #1961040) TIO Plot.doc» ~Jti(P = 5~~~~~ ~ ~~~ ~I06Q~-t~ = 1`~, 7~, ~~ off 1 ?, ~~ vF ~tf 7/15/2010 OPERABLE: Producer J-11A (PTD#61040) OA pressure stabilized 660 p~ Page 2 of 2 Please let us know if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/15/2010 PBU J-11A PTD #1961040 6/2/2010 TIO Pressures Plot Well: J-11 4,000 3,000 2,000 1,000 f Tbg ~- IA -~- OA OOA ~- DOOA On ~ t 03!06/10 03/13fl0 03/20110 03!27!10 04/03110 04110/10 Od/1?!10 Dd124110 05/01/10 D5/ORl10 05115!10 05/22'10 05129I1D r • TREE = 4-1 /8" GM/ ---- WELLHEAD = FMC ,,......~,.,......~ ,.. ACTUATOR = ,~~ ,~. w,w...~ OTIS KB. ELEV = 73.4' BF. ELEV = 40.1' KOP = 2350' Max Angle = 94 @ 11136' Datum MD = 10710' Datum TV D = 8800' SS J-11 A ~~lF~ t I ~' 2009' -~~-112" HES X NIP. ID = 3.813 ~ i GAS LIFT MANDRELS ~I 9-5r8" HES; ES Cementer, ID = 8,681'" 2{}{}$' 9-518" Baker IsaZane,EGP, 1D = 6.620 2031" 'T MD TVD DEV TYPE VLV LATCH PORT DATE 4 3886 3754 37 MMG DO1l~iE RK 16 08I22t09 3 6280 5608 42 MMG SO RK 20 08;'22109 2 7745 6721 38 MMG DMY RK 0 08/11?09 1 8581 7397 37 MMG DMY RK 0 08/11/09 9-518" CSG,47# HYD 563 {D = 8.681" 2052" ,: __ ~ `~,,, -._..._ . 9-5/8" Bowen CSG Patch. ID = 8,619' 2056' I I $662' 4-1,'2" HES X NIP„ ID = 3,813"~ L ~ $692® 9-5i8" X 4-1i2" BKR S-3 PKR, ID = 3.875" 13-318" GSG, 72#, L-80, ID = 12.347" 2556' $727' 4-112" HES X NIP, ID = 3.813" MILLOLII' WINDOW (J-11A) 9136' - 9144" °? TOP OF 7" BKR 71EBACK SLV $$92' 9-5/8" X 7" BKR ZXP PKR, ID = 6.38" 8$98' 9-5/8" X 7" BKR HMC HGR, ID = 6.38" $906' 9-5/8"' CSG, 47#, ID = 8.681 "' I-j 9094' $14' I---~ 9-5%8" x 4-112" UNIQUE OVERSHOT 8$44' x-14-112'" HES X NIP, ID = 3.813" 8865' ~-~ 9-518" X 4-112" BKR S-3 PKR, ID = 3.880" 10463' ~-i 7" X 4-112" BKR PRMR PKR, ID = 3.833" 10601' I-I4-112" HES XN NIP, ID = 3.725" 1(3} 4-112" BLAST JOINTS (29') ~ 4-112" TBG, 12.6#, 13-CR-80, ( 10653' .0152 bpf, ID = 3.958" 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674' TOP OF TNV TIEBACK SLV, ID = 3.890" 106$3' 7" X 4-1/2" TfW DTH LNR HGR; ID = 3.916" 10695' PERFORATION SUMMARY REF LOG: WA ACOUSTILOG ON 06/23/96 z SPERRY-SUN AWR ON 07/01!96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpniSgz DATE 4-112" 5 10632 - 10640 C 03/22!02 2-3/4" 4 " 11170 - 11210 C 03/22(02 2-3/4" 4 ` 11270 - 11550 C 03/22/02 2-3/4" 4 * 12100 - 12400 C 10/12/01 ~ 10653'.. ~-i4-112" SEAL ASSY, ID = 3.958" I 10655' 7" X 4-1/2" BKR SABL-3 PItR, ID = 3.875" _.,,,,,,---._..- 10669' 4-112" HES XN NIP, ID = 3.725" (NIP WASHED OUT 03(12/02) 1(}676' 4-112" WLEG, ID = 3.958" 14893' 7" X 4-112" TMJ LT PKR, ID = 3.916" 10710' 3.69" SPECIAL CLEARANCE WRP (05107/10) (05/31102} CTM 11950' 4-1i2" EZ DRILL CIBP, (10/12/01) CTM 7" LNR, 26#, L-80, ID = 6.276" I"I 10922' 4-1 /2" CIBP, PUSHED DH BY CT {05104!01) CTM (-) 1 PBTD (-~ 125$0' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 12630' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/12/80 ORIGINAL COMPLETION 09/09!09 DMS/TLH GLV CIO 07106196 SIDETRACK (J-11A) 05/31/10 GF/PJC SET WRP (05!07110) 05!05!02 D-16 RWO 08!12109 D16 RWO 08/21/09 PJC DRLG HO CORREGTIONS 08122(09 DMS/PJC PERF CORRECTIONS PRUDHOE BAY UNIT WELL: J-11A PERMIT No: 1961040 API No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Exploration (Alaska) OPERABLE: J-11A (PTD# 1961040 pressure stabilized • Page 1~ b~s'"w- Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ Q~~'IC Sent: Monday, April 05, 2010 10:27 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJO Cc: Janowski, Carrie Subject: OPERABLE: J-11A (PTD# 1961040)'~OA pressure stabilized AI I, Producer J-11A (PTD #1961040) has been monitored for OA repressurization since the IA pressure was bled on 03/17/10. The OA pressure has stabilized 760 si for nearl 14 da s. The well has been reclassified as Operable. Please notify well in egrl y Is a ecomes unmanageable. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, March 21, 2010 10:02 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Quy, Tiffany; Cooper, Katrina N; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Producer J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Producing well J-11A (PTD #1961040) has again been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 1120/1540/1300 on 3/16/2010. The well was worked over in August 2009 to repair a SC leak by cementing the OA to surface. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Although OA gas samples confirm the source is external gas, not gas lift or produced gas, having the well on gas lift appears to have some interaction with the sustained casing pressure on the OA. The IA pressure has been bled down to assist with further diagnostics. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source A TIO Plot and wellbore schematic have been included for reference. Please let us know if you have any questions. Thank you, Anna ~Dui6e, ~.~. (alt Torin Roschinger) 4/5/2010 UNDER EVALUATION: Producer J-~ (PTD# 1961040) Sustained OA Casi~Pressure Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ ~ -~(~~~,~ Sent. Sunday, March 21, 2010 10:02 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Quy, Tiffany; Cooper, Katrina N; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Producer J-11A (PTD# 1961040) Sustained OA Casing Pressure Attachments: J-11A TIO Plot.doc; J-11A.pdf r All, Producing well J-11A (PTD #1961040) has again been confirmed to have sustained OA casingpressure. The wellhead pressures were tubing/IA/OA equal to 1120/1540/1300 on 3/16/2010. The well was worked over in~ugust 2009 to repair a SC leak by cementin the OA to surface. The^ well has been reclassified as Under Evaluation and may continue to be online w i e urther diagnostics are being conducted. Although OA qas samples confirm the source is external gas, not gas lift or produced gas, having the well on gas lift appears to have some interaction with the sustained casing pressure on the OA. The IA pressure has been bled down to assist with further diagnostics. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source ~ A TIO Plot and wellbore schematic have been included for reference. «J-11A TIO Plot.doc» «J-11A.pdf» ,~- Please let us know if you have any questions. Thank you, Anna Dude, ~.~. (alt Torin Roschinger} Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 3/23/2010 PBU J-llA PTD 1961040 3/21/2010 TIO Pressures Plot Well: J-11 4,000 3,000 2,000 1 noo f Tbg -f- IA ~- OA OOA ~ OOOA On • • 12/25/09 01!02!10 01!09/10 01/16110 01/23/10 01/30/10 02'06/10 02/13110 02120/10 02/27!10 03105.10 03!13/10 03/20/10 TREE = 4-118" CMJ WELLHEAD = FMC ACTUATOR OTIS KB. ELEV = 73.4' BF. ELEV = 40.1' KOP -- 2350' Max Angle = 94 @ 11136' Datum MD = 10710' Datum TVD = 8800' SS ~~ ~~~~ J-11A p ~ ~ ~~.,. ~ ~~ ~.,~...----•-- 2009° 4-112'" HES X NlP, ID = 3.813 GAS LIFT MANDRELS ST MD 7VD DEV TYPE VLV LATCH PORT DATE 4 3886 3754 37 MMG DOPt1E RK 16 08!22109 3 6280 5608 42 MMG SO RK 20 08122109 2 7745 6721 38 MMG DMY RK 0 08111109 1 8581 7397 37 MMG DMY RK 0 08111109 s°p0~ 9-5/8" HES: ES Cerr~rter; ID = 8.681" 200$` ~ /4 9-518" Baker IsoZor~e,ECP, ID = 6.620' 2031' 9-518" CSG,47# HYD 563 1D = 8.681" 2052° 9-518" Bowen CSG Patch, ID = 8,619' 2056' 13-318" CSG, 72#, L-80, ID = 12.347" i--( 2556, MILLOUT WINDOW (J-11A) 9138'=9144" '~ TOP QF 7" BKR TIEBACK SLV 8$92' 9-518" X 7" BKR ZXP PKR, ID = 6.38" 8898'-- 9-5l8" X 7" BKR HMC HGR, ID = 6.38" $906' 9-518" CSG, 47#, ID = 8.681" 9094' 4-112" TBG, 12.6#, 13-CR-80, ~-~ 10653• .0152 bpf, ID = 3.958" 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674' TOP OF TNV TIEBACK SLV, ID = 3.890" 10683' 7" X 4-1/2" TM/ DTH LNR HGR, ID = 3.916" 10695' PERFORATION SUMMARY REF LOG: WA ACOUSTILOG ON 06/23/ 96 * SPERRY-SUN AWR ON 07/01/96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 10632 - 10640 O 03/22/02 2-3/4" 4 * 11170 - 11210 O 03/22/02 2-3/4" 4 * 11270 - 11550 O 03/22/02 2-3/4" 4 * 12100 - 12400 C 10/12!01 $662` 4-112" ]-3ES X NIP, ID = 3.813 $692° `~ 9-518'" X 4-112" BKR S-3 PKR. ID = 3.875" , $727' ' 4-1'2" HES X NIP, ID = 3,813"~ $814' 9-518" x 4-112" UNIQUE OVERSHOT $$4Q.' - i 4-112" HES X NIP, ID = 3.813' 8$65' 9-5i8" X 4-112" BKR S-3 PKR, ID = 3.880" 10463' ~'-~ 7" X 4-112" BKR PRMR PKR, ID = 3.833" 10601' -i4-112" HES XN NIP, ID = 3.725" D622' - 10651' (3) 4-112" BLASTJQIM 1~ .0655 ~ ' 10669' 10676' 10693' 4-1/2" SEAL ASSY, ID = 3.958" 7" X 4-112" BKR SABL-3 PKR, ID = 3.875"' 4-1/2" HES XN NIP, ID = 3.725" (NIP WASHED OUT 03/12/02) 4-112" WLEG, ID = 3.958" 7" X 4-1l2" TNV LT PKR, ID = 3.916" 3-3(8" IBP PUSHED DH (05131102) CTM 950' 4-1/2" EZ DRILL CIBP, 1 1 011 210 1) CTM 7" LNR, 26#, L-80, ID = 6,276" I-{ 10922' 4-1i2" GBP, PUSHED DH BY CT (05104101) CTM I PBTD 1 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 12630' DATE REV BY COMMENTS DATE REV BY COMMENTS 07!12180 ORIGINAL COMPLETION 09/09/09 DMSITCH GLV CIO 07/Ofi/9fi SIDETRACK()-11A) 05/05/02 D-1fi RWO 08/12/09 D16 RWO 08/21/09 PJC DRLG HO CORRECTIONS 08/22109 DMS(PJC PERF CORRECTIONS PRUDHOE BAY UNTi WELL: J-11A PERMTf No: 1961040 API Na: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Exploration (Alaska) OPERABLE: J-11A (PTD# 1.961040) pressure stabilized • Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~ (~~~OI ID Sent: Tuesday, March 09, 2010 4:50 PM To: Regg, James B (DOA) Subject: RE: OPERABLE: J-11A (PTD# 1961040) OA pressure stabilized No, just persistent OA bleeds. The OA returned agas/fluid mixture the first three times it was bled. After that, bled only gas back. ~~- Torin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 09, 2010 4:30 PM To: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: J-11A (PTD# 1961040) OA pressure stabilized anything done other than the planned OA pressure bleeds? any record of what was recovered during pressure bleed downs? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, March 09, 2010 3:36 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ; Hamilton, Gary N Cc: Janowski, Carrie Subject: OPERABLE: J-11A (PTD# 1961040) OA pressure stabilized All, The OA pressure has stabilized 680 psi on producer J-11A (PTD #1961040). The well has been reclassified as Operable. Please notify well integrity if the OA pressure becomes unmanageable. ~-- A TIO Plot has been included for reference. «J-11 TIO Plot 03-09-10.doc» Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 3/9/2010 OPERABLE: J-11A (PTD# 1961040) pressure stabilized . Page 2 of 3 From: NSU, ADW Well Integrity Engineer Sent: Monday, February 15, 2010 2:17 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ; Hamilton, Gary N Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure again. The wellhead pressures were tubing/IA/OA equal to 1140/1500/1040 on 02/13/10. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Attempt to bleed down the OA pressure A current TIO Plot and wellbore schematic have been included for reference. « File: J-11A TIO Plot.doc» Please let us know if you have any questions. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907j 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 06, 2010 6:06 AM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Williams, Carrie Subject: OPERABLE: J-ilA (PTD# 1961040) OA Pressure stable All, Well J-11A (PTD #1961040) appears to have a stabilized OA pressure ~ 600 psi after an open bleed was held for one week. OA gas samples taken on 12/31/09 indicate a different gas composition then the gas lift gas verifying the pressure is from an external source. The well has been reclassified as Operable and will be monitored closely for OA repressurization. Please call with. any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 3/9/2010 OPERABLE: J-1 lA (PTD# 1961040) pressure stabilized ~ Page 3 of 3 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 21, 2009 4:43 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Cooper, Katrina N; Reem, David C; Aivano, Michael J (ANC) Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 1160/940/1230 on 12/18/09. The well was worked over in August 2009 to repair a SC leak by cementing the OA to surface. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source - In progress 2. WIE: Evaluate gas samples from the IA and OA 3. DHD: MIT-OA to establish if there is infectivity into the cement in the OA A TIO Plot and wellbore schematic have been included for reference. Please let us know if you have any questions. Thank you, Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 3/9/2010 PBU J-11A PTD# 1961040 3/9/2010 TIO Pressures Plot Well: J-11 x,000 3,000 2,000 1.000 ~- Tbg -f- IA --~ OA OOA ---~- OOOA On 12112109 1 2!19109 12!20109 01 i'02110 01109110 01 r 16110 01123110 01130110 02106110 02/13110 02120!10 02127110 03!06110 UNDER EVALUATION: J-1 lA~D# 1961040) Sustained OA Casing P~sure Page 1 of 3 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, February 16, 2010 12:24 PM ~~~~ Z j~~~-~ To: Regg, James B (DOA) ~ ' Cc: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure Hi Jim, The spike in IA pressure on 1/25/10 was from a typo where the Operator entered the gas lift line pressure instead of the IA pressure. A tubing displacement treatment was recently conducted on the well for corrosion inhibition. The Operator used gas lift to kick-off the well after the treatment, hence the recent jump in IA pressure. ~r ~~.I~~ F~~ ~ ~~ 20i Thank you, Anna Dube From: Regg, James 6 (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, February 16, 2010 11:21 AM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: J-l1A (PTD# 1961040) Sustained OA Casing Pressure Known hydrates according to last email. IAxOA in notifications in 2006. What's up with the spike in IA pressure? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, February 15, 2010 2:17 PM To: Regg, James 6 (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ; Hamilton, Gary N Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure again. The wellhead pressures were tubing/IAlOA equal to 1140/1500/1040 on 02/13/10. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Attempt to bleed down the OA pressure 2/16/2010 UNDER EVALUATION: J-11A~D# 1961040) Sustained OA Casing P~sure Page 2 of 3 A current TIO Plot and wellbore schematic have been included for reference. «J-11A TIO Plot.doc» «J-11A.pdf» Please let us know if you have any questions. Thank you, Anna ~u6e, ~.~. {alt Toxin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907j 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, January 06, 2010 6:06 AM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Williams, Carrie Subject: OPERABLE: ]-11A (PTD# 1961040) OA Pressure stable All, Well J-11A (PTD #1961040) appears to have a stabilized OA pressure ~ 600 psi after an open bleed was held for one week. OA gas samples taken on 12/31/09 indicate a different gas composition then the gas lift gas verifying the pressure is from an external source. The well has been reclassified as Operable and will be monitored closely for OA repressurization. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 21, 2009 4:43 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Cooper, Katrina N; Reem, David C; Aivano, Michael J (ANC) Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure. The wellhead pressures 2/16/2010 UNDER EVALUATION: J-11A~D# 1961040) Sustained OA Casing P~sure Page 3 of 3 were tubing/IA/OA equal to 1160/940/1230 on 12/18/09. The well was worked over in August 2009 to repair a SC leak by cementing the OA to surface. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source - In progress 2. WIE: Evaluate gas samples from the IA and OA 3. DHD: MIT-OA to establish if there is infectivity into the cement in the OA A TIO Plot and wellbore schematic have been included for reference. Please let us know if you have any questions. Thank you, Anna ~u6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 658-5102 Pager: (907) 659-5100 x1154 2/16/2010 PBU J-11A PTD #1961040 2-15-2010 TIO Pressures Plot _ I 4,000 3,000 2,000 1,000 ~-- Tbg -F IA -~ OA OOA -~ OOOA On ...«.~.._.,T.~.__._.._~_~_.~,_____.__._.._.____.__..w___._,_.._~._._~._..._._~___~.a.d.___~~e~~~~_._.,_._~____._._~___ J • 11/21/09 11128/09 12/05/09 12/12/09 12119/09 12/26109 01102/10 01109!10 01/16110 01123/10 01130/10 02106110 02/13/10 TREE= 4-1/8" CIW W~LHrAD = FMC ACTUATOR = OTIS KB. ELEV = 73.4' BF, ELEV - 40.1' KOP = 2350' Max Angle = 94 @ 11136' Datum MD = 10710' J-11 A ~~, ~~A~T Datum TV D = 8800` SS ~ ~. 9-518" HE.S; ES Cementer; iD = 8.681" 200$° 9-518" Baker 1saZone,ECP, ID = 6.620 2031" 9-518" CSt;,47# HYD 563 1D = 8.681" 206.2' 9-518" Bowen CSG Patch, ID = 8.619' 2056" 13-318" CSG, 72#, L-80, ID = 12.347" ~- j 2556' MILLOUT WINDOW (J-11A) 913fi' - 9144' ? TOP OF 7" BKR TIEBACK SLV 8892'_ 9-5(8" X 7" BKR ZXP PKR, ID = 6.38" $$98' _ 9-5/8" X 7" BKR HMC HGR, ID = 6.38" $906' 9-5/8" CSG, 47#, ID = 8.681" 9094' {1 1 2009' I-(4-112" HES X NIP, ID = 3.8(3" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 3886 3754 37 MMG DOPIAE RK 16 08122/09 3 6280 5608 42 MMG SO RK 20 08122109 2 7745 6721 38 MMG DMY RK 0 08/11109 1 8581 7397 37 MMG DMY RK 0 08111109 ~ f $662' 4-1 2' HES X NIP, ID = 3.813 $692' 9-518" X 4-112" BKR S-3 PKR. ID = 3.875" $727° 4-112"' HES X NIP, ID = 3.813„ " " ' x 4-112 UNIQUE OVERSHOT ~ 9-518 $$14 $$44' 4-1/2" HES X NIP, ID = 3.813 8$65' 9-5i8" X 4-1i2" BKR S-3 PKR, ID = 3.880" 10463' I-{ 7" X 4-112" BKR PRMR PKR, ID = 3.833" 10601' ~-14-1/2" HES XN NIP, ID = 3.725" 1!2" 4-1/2" TBG, 12.6#, 13-CR-80, l-j 10653' ~ .0152 bpf, ID = 3,958" I 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674-' -~ TOP OF TNV TIEBACK SLV, ID = 3.890" 106$3 ~i 7" X 4-1/2" TNV DTH LNR HGR, ID = 3.916" I-1 10695' PERFORATION SUMMARY REF LOG: WA ACOUSTILOG ON 06/23/96 * SPERRY-SUN RWR ON 07/01/96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 10632 - 10640 O 03/22/02 2-3/4" 4 * 11170 - 11210 O 03/22/02 2-314" 4 * 11270 - 11550 O 03/22/02 2-314" 4 * 12100 - 12400 C 10/12/01 I 10669' I 10676' 10693' 4-112" SEAL ASSY, ID = 3.958" 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 4-112" HES XN NIP, ID = 3.725" (NIP WASHED OUT" 03/12/02) 4-1/2" WLEG, ID = 3.958'-1 7" X 4-112" TNV LT PKR, ID = 3.916" 3-318" IBP PUSHED DH (05131102) CTM 11950' 4-112" EZ DRILL CIBP, (10112101) CTM 7" LNR, 26#, L-80, ID = 6.276" I-~ 10922' 4-1/2" CIBP, PUSH® DH BY CT (05104/01) CTM ( 123$2' PBTD --C 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 12630' DATE REV BY COMMENTS DATE REV BY COMMENTS 07112!80 ORIGINAL COMPLEI'tON 09109/09 DMSITCH GLV CiO 07/06/96 SIDETRACK (J-11A) 05/05/02 D-16 RWO 08/12/09 D16 RWO 08121!09 PJC DRLG HO CORRECTIONS 08/22/09 DMS/PJC PERF CORRECTIONS PRUDHOE BAY UNIT WELL: J-11A PERMIT No: 1961040 API No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Exploration (Alaska) OPERABLE: J-11A (PTD# 1961) OA Pressure stable Regg, James B (DOA) • Page 1 of 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, January 06, 2010 1:05 PM ~~,~ ~ ~ ~~ /~~ To: Regg, James B (DOA) / 1 Subject: RE: OPERABLE: J-11A (PTD# 1961040) OA Pressure stable Jim, No, this is not MI. The J-11 gas sample showed 94% methane found in the OA signifying hydrates. Toxin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, January 06, 2010 9:22 AM To: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: J-11A (PTD# 1961040) OA Pressure stable Is the gas MI? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 - _;, JAN ~ ~ 2010 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, January 06, 2010 6:06 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJQ Cc: Williams, Carrie Subject: OPERABLE: J-l1A (PTD# 1961040) OA Pressure stable All, Well J-11A (PTD #1961040) appears to have a stabilized OA pressure ~ 600 psi after an open bleed was held for one week. OA pas samples taken on 12/31/09 indicate a different gas composition then the pas lift qas verifying the. ClrPCC~ pro ~~ frnw, ~n cY4arnal SO rce. The well has been reclassified as Operable and will be monitored closely r for OA repressurization. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 1 /6/2010 OPERABLE: J-11A (PTD# 1961) OA Pressure stable ~ Page 2 of 2 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 21, 2009 4:43 AM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2,OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng.; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad R]Q Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Cooper, Katrina N; Reem, David C; Aivano, Michael J (ANC) Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 1160/940/1230 on 12/18/09. The well was worked over in August 2009 to repair a SC leak by cementing the OA to surface. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source - In progress 2. WIE: Evaluate gas samples from the IA and OA 3. DHD: MIT-OA to establish if there is infectivity into the cement in the OA A TIO Plot and wellbore schematic have been included for reference. Please let us know if you have any questions. Thank you, Anna Dude, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /6/2010 UNDER EVALUATION: J-11A~D# 1961040) Sustained OA Casing P~sure Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, December 21, 2009 4:43 AM ~ r To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Stone, Christopher; GPB, Well Pad RJO Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Cooper, Katrina N; Reem, David C; Aivano, Michael J (ANC) Subject: UNDER EVALUATION: J-11A (PTD# 1961040) Sustained OA Casing Pressure Attachments: J-11A TIO plot.doc; J-11A.pdf All, Well J-11A (PTD #1961040) has been confirmed to have sustained OA casing pressure. The wellhead pressures were tubing/IA/OA equal to 1160/94%1230 on 12/18/09. The we was worked overin 7~ugust 2009 to repair a SC leak by cementing the OA to surface. The well has been reclassified as Under Evaluation and may continue to be online while further diagnostics are being conducted. Plan forward: 1. DHD: Hold an open OA bleed for 2-4 days to attempt to bleed down source - In progress 2. WIE: Evaluate gas samples from the IA and OA 3. DHD: MIT-OA to establish if there is infectivity into the cement in the OA ~~ ~-- '~ ,~z ~F A TIO Plot and wellbore schematic have been included for reference. ~ ~ ~~ Leo ~~ «J-11A TIO plot.doc» «J-11A.pdf» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Weil Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 P=S~~' S C ~ -= 1 Z 3v~~:~ ~. ~a~~~=zz~~, 12/21 /2009 PBU J-11A PTD #1961040 12-21-09 TI/l Drecc~~rec~ 03!26!09 10!03!09 10/10!09 10!17/09 10!24!09 10!31/09 11!07,'09 11!14/09 11/28!09 12J05.~09 J TREE = 4-118" CNV WELLHEAD = ACTUATOR= FMC OTlS KB. ELEV = BF. ELEV..- 73.4' 40.1' KOP= 2350' Max Angle = DatumMD= 94 {c~ 11136' 10710' Datum TV D = 8800' 5S ~L ~A~~ 9-5i8" i fES, ID = 8.681" ~ 260$° ~ r_5!8„ Baker i~~;oZone,~~:i', ID = 6.620 2031"~~ 9-518" C~'a.47# HYD 563 ID = 8.681" 2052` 9-5 ~ CBG Patch; ID = 8.619' 2056 13-318" CSG, 72#, L-80, ID = 12.347" ~-j 2556 MILLOUT WINDOW {J-11A) 9136' - 9144' ? TOP OF 7" BKR TIEBACK SLV $892' 9-518" X 7" BKR ZXP PKR, ID = 6.38" 8$9$~ 9-518" X 7" BKR HMC HGR; ID = 6.38" $906' 9-518" CSG, 47#, ID = 8.681 "' 9094' 7" LNR, 26#, L-80, ID = 6.276" 10653" -{4-1/2" SEAL ASSY, ID = 3.958" -- 10655 7" X 4-112" BKR SABL-3 PKR, ID = 3.875" 4-1/2" TBG, 12.6#, 13-CR-80, 10653 .0152 bpf, ID = 3.958" 4-1l2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674 TOP OF TfW TIEBACK SLV, ID = 3.890" 10683 7" X 4-112" TNV DTH LNR HGR, ID = 3.916° 10695 PERFORATION SUMMARY REF LOG: WA ACOUSTILOG ON 06!23/96 SPERRY-SUN AWR ON 07101!96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" 5 10632 - 10640 O 03/22/02 2-3/4" 4 ` 11170 - 11210 O 03/22/02 2-3/4" 4 ' 11270 - 11550 O 03/22/02 2-314" 4 " 12100 - 12400 C 10/12101 $662` 4-172" HES X NIP, ID = 3.813„ $602' 9-5/8" X 4-112" BKR S-3 PKR. ID = 3.875„ $72T - $$14" $$44' ~4-1/2" HES X NiP, 1D = 3.813„ 9-518" x 4-1?2" UNIQUEOVERSHOT 4-1/2" HES X NIP, ID = 3.813" $$65' 9-5/8" X 4-112" BKR S-3 PKR, ID = 3.880" 10463 7" X 4-1/2" BKR PRMR PKR, ID = 3.833" ~ 0801' 4-1/2'° HES XN NIP, ID = 3.725" 7622" - 1Q65'1'~ (3) 4-1/2" BLAST JOINTS (29') 10669 4-112" HES XN NIP, ID = 3.725" (NIP WASHED OUT 03112102) 10676 4-1 /2" WLEG, ID = 3.958" 10693' 7" X 4-1/2" TIW LT PKR, ID = 3.916" 4-1i2" CIBP, PUSHED DH BY CT {05/04101) CTM I-~ 12 PBTD 3-318" IBP PUSHED DH (05!31!02) CTM 1950' 4-112" EZ DRILL CIBP, (10/ 12101) CTM 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/12180 ORIGINAL COMPLETION 09/09/09 DMS/TLH GLV C/O 07106(96 SIDETRACK {J-11A) 05/05102 T}-16 RWO 08112109 D16 RWO 08/21/09 PJC DRLG HO CORRECTIONS 08/22/09 DMSIPJC PERF CORRECTIONS PRUDHOE BAY UNIT WELL: J-11A PERMIT Na 1961040 API No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Exploration {Alaska) J-11 A ~,,.,._.._..-~---- Q9` 4-1?2" !-iES X NIP, ED = 3.813„ 1 ~ ----" i GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3886 3754 37 MMG DOME RK 16 08/22109 3 6280 5608 42 MMG SO RK 20 08!22?09 2 7745 6721 38 MMG DMY RK 0 08111I09 1 8581 7397 37 MMG DMY RK 0 08%11109 SchlumUerger t~ N0. 5353 Alaska Data & Consulting Services n /' ~~~ ~` ~` Company: State of Alaska 2525 Gambell Sireet, Suite 400 ~~- ` Alaska Oil & Gas Cons Comm Mchorage, AK 99503-2838 ~ v ~~ Attn: Christine Mahnken n77N: eeth 333 West 7th Ave, Suite Y00 Mchorage, AK 99501 Well Job M Log Descriptio~ Date BL Color CD osn ~ios , ~ , ., k ....' ~ \Y t''~. ~ S:i[ ~s~`IS ~ i V-02 W-26A M-32 82WY-00018 BiJJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ' MEM PRODUCTION PROFIIE ~ - PRODUCTION PROFILE ' L- 07/27/09 07/2W09 p7/p5/pg 1 7 ~ ~ ~ ~ ~ P2-29 L2-it L2-06 AVTU-00052 ANHV-00106 B69K•00007 INJECTION PROFILE ' '1 -- LDL ~ CROSS FLOW CHECK 08/02/09 OS/02/09 07/31/09 1 1 1 ~ ~ ~ P2-28 L-Y13 V-227 AYTU•00051 82WV-00019 N(60.00037 INJECTION PROFILE C, -~ MEMINJECTIONPROPI E' - MEM INJECTION PROPILE " 08/Oi/09 07/29/09 07/2B/09 1 1 1 ~. ~ ~ L-220 07-22 04-02A B7 JJ-00035 AZCM-00036 AYS4-00091 MEM INJECTION PflOPILE ~ PRODUCTION PROFILE - ~ USIT 07/30f09 08/09/09 08/11/09 1 1 7 ~ ~ 1 J-11A L1•09 X-28 AWLB-00029 AYS4-00089 AXBD-00026 USIT PRODU TIONPROFILE '_Q(} MEM INJECTION PROFILE lJ 08/05/09 OB/08/09 05/17/09 1 1 1 1 1 1 L2-O6 3-29/J-32 06-04A B3Sa-00020 AP3~-00055 BSJN-00009 PRODUCTION PROFILE IBP SET RECORD W/CflOS GLOW ! RST 08/14/09 08/08/09 08/23/09 1 7 1~ 7 ~ ~ 15-096 62NJ-00013 MCNL - 07/15/09 1 7 03-328 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 ~ G-14B AWJI•00043 MCNL - W/2M09 1 ~ L2-13A AWJI-00036 MCNL 06/Y7/09 ~ 18•028 AWJI-00045 MCNI q- $~ 08/17/09 1 ~ P1-OS AWLB-00032 RST 08/09/09 1 ~ B•16A B2WY-00020 MCNL ' - ~~ 08/03/09 f ~ J•20B AXBD-00020 MCNL (flEVISED) - .~ ,'L ' D4/12/09 ~ PLFASP ecKNnwi cnnc ccr c~or wv cin_uu~ r_ ww~n ocr~~ou..~n n.~~ ......., ....... ~,.. BP Exploration (Alaska) Inc. Pe~rotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Dala & ConsWting Services 2525 Gambell Strest, Sude 400 Anchorage, AK 99503-2838 ~ ~ ~q~ t.' j~~~ . ~ ti~ ,.. .,~.. - • ~ w~~^~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Thursday, September 10, 2009 12:42 PM To: 'Baca, Hank' Cc: Hobbs, Greg S (ANC) Subject: RE: J-11A (196-104) Page 1 of 1 ~ Hank, Thanks for the clarification; that answers my qusstions. 1 wasn't clear that the spear was run through the hanging BOP, but that would be the way to do it. It is prudent to conduct the low pressure test you performed on this well. Granted, there are multiple barriers to give isolation to the reservoir but it is appropriate to verify that the broken flange has been properly made up and is leak tite given ail the fluids that wi11 be circulated during the 9-518" replacement. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Thursday, September 10, 2009 10:36 AM To: Maunder, Thomas E (DOA) Subject: RE: J-11A (196-104) Hi Tom. The BOPs and tubing spool were lifted up and swung back ta facilitate removing the snap ring and packoffs. The BOPs were then centered over the well without bofting them back up. The spear was engaged, the casing lifted and the old siips removed. The BOPs were then set down and bol#ed up. The annular preventer was closed around the 9.625" casing and the well pressured up undemeath it to a few hundred psi to just to make sure it didn't ieak. No test plug emplflyed. With the 9.625" casing cut and no packof#s the 13-3/8" shoe sees that pressure, therefore the minima! pressure applied. Its really just a quick check_on our part that could be skipped. Lst me know if you have further questions. Hank Baca Drilling Engineer ~~ . 907-564-5444 otfice ~~~ , ~ ~ °~-°' s ?._ . ~. . 907-748-0997 ceii From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) 5ent: Wednesday, September 09, 2009 3:58 PM To: Baca, Hank Cc: Reem, David C SubjeCt: J-11A (196-104) Hank, I am reviewing the operations report for the recently compieted workover on this we11. On August 8, the BOP stack and tubing spool are removed from the well and pulled out of the way. The 9-5/8" casing is engaged with a spear and the slips removed. It is then stated that the stack and tubing spool are reinstalled that then "test BOP break to ensure no leaks". How was tMis accomplished? Although it isn't stated, I presume that the spear needed to be disengaged and the casing set back down to allow the stack/spoal combination to be reinstalled. Was a test plug employed? Was the well pressured up? Thanks in advance. Tom Maunder, PE AOGCC 9/10/2009 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REP T OF SUNDRY WELL OPE~IONS ~~~r~~ . ~~ ,~ `g ~ f ,,i z , ~" >. ~ , r ~ - ~ 1. Operations Performed: ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 196-104 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20462-01-00- 7. KB Elevation (ft): 73 40 9~ ~Nell Name and Number: . _ PBU J-11A- 8. Property Designation: 10. Field / Pool(s): _ ADL 028281 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12630 ~ feet true vertical 9067 ~ feet Plugs (measured) >>8aa~, 11950~, izsa2~ Effective depth: measured 11844 feet Junk (measured) N/A true vertical 9017 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2556' 13-3/8" 2556' 2550' 4930 2670 Intermediate Production 9094' 9-5/8" 9094' 7796' 6870 4760 Liner 2366' 7" 8892'-11258' 7642' - 9003' 7240 5410 Liner 1947' 4-1/2" 10683' - 12630' 8857' - 9067' 8430 7500 :~.. ~~~~ q'i `7(7~;r: .. ' `~ . . °F f ez'; _ J Perforation Depth MD (ft): 10632' - 11550' Perforation Depth TVD (ft): 8825' - 9006' 4-1/2", 12.6# 13Cr-80 / L-80 10676' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" BKR S-3 Packers, 7" x 4-1/2" BKR PRMR 8662' & 8865', 10463' Packer and a 7" x 4-1/2" BKR SABL-3 Packer & 10655' 12. Stimulation or cement squeeze summary: Intervals treated (measured}: Treatment description including volumes used and final p ressure: Cut and pull tub+ng from 8790'. Cut and pull 9-5/8" casing from 2053'. Run 9-5/8", 47#, L-80 tieback to surFace. Cement w/ 147 bbls Class 'G' w/ Gas-Blok 825 cu ft/ 712 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 363 15972 6099 1360 420 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram _~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Hank Baca, 564-5444 309-254 Printed Name Sondra Stewman Title Drilling Technologist ~ - ? Prepared By NamelNumber: D (~ ~' Sign ture ~- --- ) Phone 564-5743 ate Sondra Stewman, 564-4750 Form 10-404 Revised 04l2006 Submit Original Only ~:~~.~~-k ~~~~ ~ ; ~ ~ ~~ 2009 ~ ~~ .~'G~ ~/~~G~ TREE = 4-1 /8" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 73.4' BF. ELEV.- 40.1' KOP = 2350' Max Angle = 94 @ 11136' Datum MD = 10710' Datum ND = 8800' SS • DRLC GtRAFT 9-518'° HES; ~S CzrrsellL2C, lD =$.68 9" 2{~Q$' 9-5/8'° ~a3cer 1soZone,EGP; [D = ~a.~20 2031' 9-5(8" C5G,47~ HYQ 563 ED =$.6$1" 2052' 9-5l8" B~~u en CSG Patch; ID = 8.G1 S' 2056' ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ( 2556~ MILLOUT WINDOW (J-11A) 9~]36' - 91A4° ? TOP OF 7" BKR TIEBACK SLV $$92' 9-5/8" X 7" BKR ZXP PKR, ID = 6.38" 8898~ 9-5/8" X 7" BKR HMC HGR, ID = 6.38" 8906~ 9-5/8" CSG, 47#, ID = 8.681" 9094' I 4-1/2" TBG, 12.6#, 13-CR-80, I 10653' .0152 bpf, ID = 3.958" 4-1/2" TfP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674~ TOP OF TIW TIEBACK SLV, ID = 3.890" 10683~ 7" X 4-1/2" TIW DTH LNR HGR, ID = 3.916" 10695~ PERFORATION SUMMARY REF LOG: WA ACOUSTILOG ON 06/23/96 * SPERRY-SUN AWR ON 07/01/96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to aoduction DB for historica! perf data SIZE SPF INTFRVAL Opn/Sqz DATE 4-1/2" 5 10632 - 10640 O 03/22/02 2-3/4" 4 ' 11170 - 11210 O 03/22/02 2-3/4" 4 ` 11270 - 11550 O 03t22/02 2-3/4" 4 ' 12100 - 12400 C 10/12/01 SAFETY E: 9-5/8" SDTRK WINDOW, 9094' - -11 A 9144' (~ION MILL). PRE-SDTRK WELLBORE J P&ANOT SHOWN BELOW 9-5/8" MILLOUT WINDOW. "*" RIG MILLED THRU 7" LNR @ 10992 (06/25/96) 1~., ~~ -~.... 20~9' 4-1;'2° HES X NIP, EC` = 3.813"~ GAS LIFTMANDRELS ~~ S~" MD 7'JD DC~J 7YF'E brLV LATGH POF~7 C~;=~TE 4 3~86 375~ 37 ~,1MG Q(viY C~CR fl t3£~;`;1:'~i~3 3 6280 5~i~8 =~2 Mi~1C'.-~. Dtv1Y RK C~ 0&'r` a 11C~9 2 774~ 6721 38 f~1MG DIvIY RK 0 0~3r'19?03 1 8581 7397 37 ~r91~9G D(~1Y RtG ~ C~8i~11C~:) $6~~' 4-1;'2" HES X NIP„ ED = 3.E313~~ $692' 9-518" X 4-1,'2" BKR S-3 PKR, iC~ = ~.~7~„ 8'~~7' 8$14' $$44' 4-'f i2° HES X NIP, iL} = 3~~37 3„ 9-5(8° x 4-1,`2°` UNIQUE{)VER~N~T 4-1 /2" HES X NIP, ID = 3.813"~ 8865~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.88Q" 10463~ 7" X 4-1/2" BKR PRMR PKR, ID = 3.833" 10601 ~ 4-1/2" HES XN NIP, ID = 3.725" ~ 10653' ~~ 10655' ' 10669' 10676' 10693' ( ~Z~ 7" LNR, 26#, L-80, ID = 6.276" -~' 4-1/2" SEAL ASSY, ID = 3.958" 0 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 4-1/2" HES XN NIP, ID - 3.725" (NIP WASHED OUT 03(12/02) 4-1/2" WLEG, ID = 3.958" 7" X 4-1/2" TNV LT PKR, ID = 3.916" 11844~ 3-3/8" IBP PIJSHED DH (05131/02) CTM ~ 11950~ 4-1/2" EZj RILL CIBP, ~ (10/12/01 CTM 4-1/2" CIBP, PUSHF~ DH BY CT (05/04/01) CTM ~ 12382~ ~TD 12580' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12630~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/12/80 ORIGINAL COMPLEfION 07/06/96 SIDETRACK(J-11A) 05105/02 D-16 RWO 08/12/09 D16 RWO 08l21/09 PJC DRLG HO CORRECTIONS 08/22/09 DMS/PJC PERF CORRECTIONS PF2UDHOE BAY UN(f WELL: J-11A PERMIT No: r1961040 API No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Euploration (Alaska) • • J-11 A Well History 05/29/09 T/I/O = 970/1480/520. Temp = 130 deg. Bleed OAP to 0 psi (eval bubbling in cellar). AL line SI @ casing valve. ALP = 2020 psi. OA FL @ 402'. Cellar has 25" of fluid, conductor submersed in cellar fluid. Rapid bubblina in cellar aqnears to be risin~ from entire circumfPrPnr.P ~f, conductor_LEL= Over Ranc~e, 02 = 19.6%, CO = 6 ppm, H2S = 0 ppm. Bled OAP from 520 psi to 180 psi in 45 min into BT (gas), fluid to surface. Small bubbles of crude beqan to rise to surface in cellar. LEL = 40 %, 02 = 20.9%, CO = 0 ppm, H2S = 0 ppm. Bled IAP from 1480 psi to 280 psi in 1 hour 5 min into OT. Durinq IA bleed OAP increased to 240 psi. Steadv bubblin~. from 4 o'clock to 7 o'clock position in cellar. Final WHPs = 970/280/240. WV, SSV, MV = open. SV = closed. IA, OA = OTG. 05/30/09 T/I/O = 970/280/260. Temp = 130 deg. Bleed IAP, OAP. Vac out cellar, MIT-OA w/N2 to 500 psi. SC leak depth determination (eval bubblinp in cellar). AL line SI @ casing valve. ALP = 2020 psi. OA FL @ 450'. Cellar was vacuumed out last evening, cellar now has 17" of fluid, 35" old conductor is 1.5" above fluid level. Flutes exposed w/2" of fluid, bubblina @ 6 o'clock position. LEL = Over Range, 02 = 20.6%, CO = 6%, H2S = 0 ppm. Bled IAP, OAP to 20 psi in 5 hours 10 min. SI IA, OA bleed, OA has fluid to surface. Increased OAP from 20 psi to 50 psi with two N2 bottles. LEL = 0%, 02 = 20.9%, CO = 0%, H2S = 0 ppm. Re shot OA FL. OA FL decreased to 552' (32 bbl) (OA may have had foam/wet gas to surface). Bled IAP to 0 psi in 2 hours, OAP to 0+ in 2 hours. Final WHPs = 970/0/0+. WV, SSV, MV = open. SV = closed. IA, OA = OTG. 05/31/09 T/I/O = 1030/0/0+. Temp = 105 deg. Load OA w/diesel, MIT-OA w/N2 to 500 psi (eval bubblin in cellar). TP increased 60 psi, IAP unchanged, 0AP unchanged overnight. OA FL decreased 108' overnight to 660' (38.5 bbl). Cellar water in flowed 13" overnight. Cleaned SH for UT. Job postponed for OA load. Final WHPs = 1030/0/0+. WV, SSV, MV = open. SV = closed. IA, OA = OTG. 06/02/09 T/I/O = 1090/0+/20. Temp = 102 deg. Install Katch Kan. MIT-OA w/N2 to 500 psi (eval bubbling in cellar). AL line SI @ casing valve. ALP = 2020 psi. TP increased 60 psi, IAP increased to 0+, OAP increased 20 psi since 5/31/09. IA FL inconclusive. OA FL ~ 660' (38.5 bbl). Conductor exposed, no visible or audible signs of Ieaking.,Unable to install Katch Kan due to ffuid level in cellar. Assisted Acuren w/UT. Final WHPs = 1090/0+/20. WV, SSV, MV = closed. SV = closed. IA, OA = OTG. 06/04/09 T/I/0=1020/0+/40. Temp=105*. Supersuck gravel from cellar (eval SC leak). TP decreased 70 psi, IAP unchanged & OAP increased 20 psi since 06/02/09. Flute @ the 6 o'clock position is rapidly bubbling, no LELs were detected. OA FL C~ 648' (38 bbis). IA FL @ 5828' sta#4 S/O (312 bbls). Removed 3' of water from cellar. Confirmed there are no circ-ports & installed Katch- Kan around 20" insulated conductor. Job in progress. Final WHPs=1020/0+/40. SV=Closed. WV, MV, SSV=Open. IA & OA=OTG. NOVP. 06/05/09 T/I/0=1020/0+/40. Temp=105~. Assist FB load OA; MIT-OA w/N2 FAILED. OA FL @ 648'. LRS fluid packed OA with 33 bbls of crude. Pressured OAP up to 400 psi with N2. Detected N2 in conductor C the 6 o'clock position. Bled OAP to 0 psi. Post OA FL @ 30'. Final WHP's=1020/0+/0+. SV=closed.W V,SSV,MV=open.lA,0A=0TG. NOVP. 06/06/09 T/I/O = 1200/0+/10. Temp = 102*. Monitor conductor (post MIT-OA w/N2). AL is SI @ casing valve, ALP C~ 1360. 20" conductor has water C~ 6 o'clock & 12 o'clock positions, 1" deep (top of flutes are dry). 6 o'clock position has bubbling w/ small sheen of crude. LEL's = 17 %, 02 = 20.9, CO = 0%, H2S = 0%. 06/07/09 TIO=SSV/vac/0+. SI Monitor WHPs (SC Leak). AL SI C~ casing valve, ALP= 0+ psi. 20" conductor has dirt and gravel filled 2-3" below top of flutes (top of futes are dry). 1/2" of water between conductor and insulation ring. Katch kan installed. SV,WV,SSV=C. MV=O. IA,OA=OTG. NOVP Page 1 of 3 ~ ~ J-11A Well History 06/15/09 T/I/0=200/0/0 Assist Slickline, MIT T PASSED to 3000psi (Secure Well) Pumped down the IA with 3 bbls neat meth & 350 bbls crude to load. Pumped down Tbg with 160 bbls crude to load. Slickline set TTP. Pumped 3 bbls crude down Tbg to reach test pressure for MITT. Tbg lost 40 psi in the 1 st 15 mins and 20 psi in the 2nd 15 mins for a total pressure loss of 60 psi in 30 min test. FWHP's=0/20/0. OA & IA=OTG. Slickline in control of well at LRS departure. Performed simulated flowline rupture table top drill. 06/15/09 BRUSHED X-NIP C~3 8844' MD, W/ 3.805 G-RING & BRUSH. LRS LOADED IA & TBG...SEE LRS WSR FOR DETAILS. SET 4-1/2" PX PLUG BODY ~ 8840' SLM. SET P-PRONG @ 8837' SLM. LRS MIT-T PASSED. 07/26/09 PULLED 4-1/2" PX TTP FROM 8735'SLM (8844' MD), RIH W/ 3.70" CENT & S.BLR. SAT DOWN IN XN-NIPPLE C«~ 10594' SLM. WORKED 3.70" CENT THRU XN NIPPLE & MADE SEVERAL PASSES UNTIL CLEAR CONT RIH W/ 3.70" CENT TO DEVIATION C~ 10950' SLM. POOH W/ NO SAMPLE. 07/26/09 INITIAL T/I/0=400/0/0. RIH WITH BAKER OIL TOOLS QUICKDRILL COMPOSITIE PLUG. 3.595" MAX OD. OVERALL TOOL LENGTH = 24.8'. GET BAKER QUIGK DRILL PLUG AT 8910' MID ELEMENT, TIED INTO TUBING SUMMARY DATED 5/4/2002. RIG UP LRS TO MIT-T. STANBY FOR VAC TRUCK AND DHD OPERATOR 07/27/09 I/I/U = bUU/U/U Hssist t-une with MI I I Upl11g I'H55tU t0 :ibUU psl. / MI I IH F'HSStU/ Ult'C-UUi. r11'St attempt to 3500 psi. Pumped 19 bbls crude to MIT Tbg. Tbg lost 120 psi in the first 15 min and 40 psi in the second 15 min for a total loss of 160 psi in the 30 min test. Left pressure on Tbg. RD off of Tbg and RU to IA. Pumped into IA with 12 bbls of crude to reach test pressure. !A lost 200 psi in first 15 min and 40 psi in the second 15 min for a total loss of 240 psi in the 30 min test. Bled down TxIAP. Tbg failed to bleed off below 530 psi. Re-MIT Tbq to 3000 psi with 25.5 bbls crud~ Tbg lost 160 psi in first 15 min and 50 psi in the second 15 min for a total loss of 210 psi in the 30 minute. Attempted to bleed Tbg pressure down. Started getting gas back at 650 psi, started bleeding to Flowline of J-24. Bled to 140 psi. Re MIT Tbg PASSED first attempt to 3000 psi. Pumped into the Tbg with 10.6 bbls of crude to reach test pressure. MIT Tbg lost 140 psi in the firstl5 min and 35 psi in the second 15 min for a total loss of 175 psi in the 30 min test. Bled Tbg to 150 psi. Start CIRC out. T/I/(~-9(lN~/n Pumnarl i(l hhls math 1 R(1 hhlG Raawatar rlnwn Thn iin IA anrl tn .I-9d flnwlina 07/27/09 T/I/0=550/vac/0. Temp=Sl. Eval SC leak (FB call-in}. A/L is connected, Sf C~3 casing valve. iA FL & OA FL C«~ 60'. Monitor Cellar while FB CMIT-TxIA, MIT-OA. No increase in OAP or fluid movement in conductor or cellar at this time. Final WHPs 540/100/0. FB has control of valves. 07/27/09 T/I/0=650/0/0. Temp=Sl. Assist with secure (SC leak). IA has poorboy connected to production of J-24. TBG FL near surface. Bleed TP to production of J-24 from 560 psi to 160 psi in 45 min. Monitor 1 hr, TP increased 70 psi. Assist FB with secure. 07/27/09 LRS MIT-T TO 3500 PSI = PASSED, MIT-IA TO 3500 PSI = PASSED. BLEED IA TO ZERO. BLED TBG TO 500 PSI BUT THEN TBG PRESS CAME UP TO 530 PSI AND WOULD NOT COME DOWN. MIT-T AGAIN TO 3000 PSI = PASSED. BLED TBG DOWN AGAIN THIS TIME TO 160 PSI. CUT 4.5" TUBING AT 8801' WITH 3.65" POWERCUTTER. TOOL CAME BACK WITH 3 THIN PIECES OF RUBBER STUCK IN CENTRALIZERS. WELL TURNED OVER TO LRS FOR CIRC OUT (ON NEW PERMIT). DSO NOTIFIED OF FINAL VALVE POSITIONS: MV=O, SSV=C, WV=C, GV=C, AL=C, IA/OA=OTG, SV=C. 07/28/09 Circ Out Tubing and IA with Sea Water. Pumped down Tbg a total of 900 bbls Sea Water taking returns up IA to J-24 flowline. Freeze protect Tbg and IA with 140 bbls diesel and U-tube to place freeze protect. RD off of Tbg and onto IA. Pumped 10 bbls diesel to freeze protect hardline jumper. W ill come back a later date to finish CMIT. Notified Pad Operator of well status, hung tags and verified Valve positions on both wells. J-11; Swab- shut, SSV-shut, Wing-shut, Master-open, Hardline-shut, IA and OA valves open to gauges. J-24; Swab- shut, W ing-shut, SSV-shut, Master-open, IA and OA valves open to gauges. FW HP's= 200/240/0 Page 2 of 3 ~ • J-11 A Well History 07/28/09 T/I/O = 120/100/10 CMIT TxIA PASSED to 1000 psi. (RWO Prep) Pumped into the IA with 2.0 bbls of diesel to reach test pressure. CMIT TxIA loss 20 psi in the first 15 min and 10 psi in the second 15 min for a total loss of 30 psi in the 30 min test. Bled TxIAP down. Freeze protected J-24 FL w/ 3 bbls meth, 50 bbls Diesel. Final WHP's = 0/0/0 SV,WV,SSV shut, MV,IA,OA Open 07/30/09 T/IA/OA= SSV/0/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void, 2000 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "ET style" alf were in good working condition. PPPOT-IC RU 2 HP BT onto IC test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment, cycled LDS out 1.0" ran in torqued "ET style" all were in good working condition 08/19/09 T/I/0=250/500/0. Pulled 4- 1/16" CIW BPV # 251. Post Ri PULLED RHC BALL AND ROD FROM 8,705' SLM (8,727' MD) RIH W/ KJ, 4-1/2" OM-1, 7" EXT, 1-5/8" JDS PULL RK-DGLV FROM STA #3 AT 6,268' SLM (6,279' MD) PULL RK-DGLV FORM STA #4 AT 08/21/09 3,875' SLM (3,886' MD) RIH W/KJ, 4/2" OM-1, RK-1 RUNNING TOOL SET RK-LGLV 1500 PSI DOME, 16/64" PORT IN STA #4 AT 3,875' SLM (3,886' MD) SET RK-S/O 20/64" PORT IN STA #3 AT 3,875' SLM (3,886' MD) 08/22/09 PULLED 4-1/2" RHC PLUG BODY FROM 8,713' SLM (8,727' MD) DRIFTED TO DEVIATION AT 10,960'SLM W/ 3.5" CENT, 2.5" S.BAILER (EMPTY) Page 3 of 3 • • __ BP EXPLQRATIaN Page 1 Qf 11 Ope'rations Surnrnary Report Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Qate Fram - TQ Hours Task Gode NPT Phase Description of Operations 8/2/2009 08:00 - 10:30 2.50 MOB P PRE Bridal up and prepare rig to move to J-11A 10:30 - 11:00 0.50 MOB P PRE Lay Derrick Over 11:00 - 13:30 2.50 MOB P PRE PJSM on Moving Rig -Install Front and Rear Boosters Wheels 13:30 - 21:00 7.50 MOB P PRE Move Rig from DS 14-12 to J Pad Well A -9.7 Mile Move 21:00 - 22:30 1.50 MOB P PRE Spot Rig on J Pad -Remove Booster Wheels -Remove Goose Neck 22:30 - 23:00 0.50 MOB P PRE Raise Derrick 23:00 - 00:00 1.00 MOB P PRE Finish Rigging up Rig -Rig up Circulating Lines -Spot Equipment -Ready Floor 8/3/2009 00:00 - 01:30 1.50 MOB P PRE Spot and shim Rig 01:30 - 03:00 1.50 MOB P PRE Spot Slop Tank , Gen Trailer, Enviro-Shack, Flow Back Tank, -Take on heated seawater to Pits -Spot Pump Trailer ****Accept Riq at 03:00 Hrs."" 03:00 - 04:30 1.50 WHSUR P DECOMP PJSM with DSM and Rig Crew on removing BPV -Ri U Lubricator and test to 500 si, ood test wn L bricator. 04:30 - 09:30 5.00 KILL P DECOMP PJSM on displacing diesel freeze protect with Ch2MHill truck drivers and Doyon Rig Crew. Reverse circulate -40-Bbls of diesel out of tubing at 3-BPM and 300-psi to the flowback tank. Realign valves and circulate the long way, taking -150-Bbls of diesel to the flowback tank. Continue circulation of another 460-Bbls, taking returns to the Pits. The returns are very clean and 8.4-ppg heavy, seawater. Wells Support personnel had circulated the well with 900-Bbls of seawater, taking returns to the flowline on 7-27-2009. 09:30 - 10:30 1.00 WHSUR P DECOMP P/U and install H-t e TWC and test from above to 3500- si and below to 1000- si for solid tests. Start rig camp move at 0930-hours. 10:30 - 11:30 1.00 WHSUR P DECOMP R/D circulating lines, drain tree. N/D tree. Make crew change. Finish N/D tree. 11:30 - 13:00 1.50 BOPSU P DECOMP PJSM with rig crew and WSL to discuss N/U the BOP stack. N/U BOP stack. Hold surprise Man-Down drill in the Pipe /Shed. 13:00 - 13:30 0.50 BOPSU P DECOMP Man-Down drill and after action review in the Pipe Shed with crew and WSL. 13:30 - 16:00 2.50 BOPSU P DECOMP Continue N/U BOP. 16:00 - 20:00 4.00 BOPSU P DECOMP Test BOPE to 250-psi low, 3500-psi high, using 2-7/8" and 4-1/2" test joints in the VBRs. Use only the 2-7/8" test joint in the Hydril. Swap out the 3-1/2" x 6" VBRs to 2-7/8" x 5" VBRs. The first test with the 2-7/8" x 5" VBRs failed. The sealing elements need to be repiaced. Toolpusher found a set in Kuparuk Tool Services and sent the camp SPO to get them at 1700-hours. Continue with remainder of the BOP test schedule. Test witness by BP WSL Mike Rooney & David Newlon, Doyon Drilling TP Sam Dye and Jerry Hansen. AOGCC Jeff Jones waived witness of test at 10:00 hrs Printed: 8/17/2009 10:16:52 AM ~ ~ BP EXPLQRATION Page 2 of 11 ' Qperations Sumrnary R~port Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: ' Date From - To Hours Task Code NPT Phase Description of Operations 8/3/2009 16:00 - 20:00 4.00 BOPSU P DECOMP 8-3-2009. 20:00 - 21:00 1.00 BOPSU P DECOMP PJSM on changing rams; hazard recognition performed to identify specific lifting procedures for rams. Chan e Rams to 3 1/2" x 6" VBR 21:00 - 22:00 1.00 BOPSU P DECOMP Test 3 1/2" x 6" VBR rams to 250-psi low, 3500-psi high with 4" Test Joint, -Test Annular to 250 low and 3500 psi high with 4" Test Joint -Test 3 1/2" x 6" VBR rams to 250-psi low, 3500-psi high with 4 1/2" Test Joint -Perform accumulator test -Rig down test equipment 22:00 - 23:00 1.00 WHSUR P DECOMP Pull Two Way Check Valve -Rig up Dutch System Riser -Pick DSM Lubricator and Test to 500 psi, good test -Pull TWC 23:00 - 00:00 1.00 PULL P DECOMP Make Up Landing Joint and NSTC Crossover to Tubing Hanger -Back Out Landing Screws 8/4/2009 00:00 - 00:30 0.50 PULL P DECOMP Pull Hanper Free with 135,000, same as calculated weight + 00:30 - 01:30 I 1.001 PULL I P 01:30 - 09:30 I 8.001 PULL I P 09:30 - 12:30 I 3.001 FISH I P 12:30 - 20:30 8.00 FISH P 20:30 - 21:30 1.00 FISH P 21:30 - 22:30 1.00 FISH P 22:30 - 00:00 1.50 FISH P 8/5/2009 00:00 - 02:00 2.00 FISH P 02:00 - 05:00 3.00 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 07:00 1.00 EVAL P -Pull to floor without issues. DECOMP CBU at 10 bpm / 390 psi -PUW 140k -Take SPR's -Monitor Well, Static 8.4 ppg Seawater In/ Out DECOMP Lay Down Hanger, Crossover and Landing Joint La Down 4 1/2" 12.6# Vam Ace Com I tio -- 185 VD at 0730-hours. All joints appear to be in very good shape with no signs of external corrosion nor in the threads of pins or boxes. Cutoff Joint is 9.02' long with a 5-1/16" flare. DECOMP P/U and M/U Dress-off BHA:8-1/2" x 4-1/2" Dress-off shoe, Triple conn drive sub with carbide cutters, 9-5/8" Scraper, Bumper Sub, 6-ea 6-1/4" DCs, and Pump-out Sub. DECOMP RIH with Dress-off BHA -Picking up DP 1 x 1 DECOMP Slip and Cut Drilling Line Service Rig Draw Works, Crown and Top Drive DECOMP Break Circulation and establish Parameters -PUW 185k / SOW 145k / RtWt 160k -6 BPM / 570 psi -60 RPM / 4k Ft-Lbs Torque Taq stum~ at 8790'md. Dress 6" of stub with 3-5k WOB No Issues sliding over stump DECOMP Pump High Vis Sweep and Circulate hole clean -12 BPM / 2150 psi DECOMP Monitor Well , Static 8.4+ Seawater In / Out Detail Inspection of the Top Drive -Found several bolts loose on rotating head bull gear -Re-tighten and safety wire bolts to spec's DECOMP POH, standing back 4" DP in derrick. DECOMP Lay Down Dress off BHA. -Good wear indication on dress off mills. DECOMP PJSM with SWS Wireline Crew and Doyon Rig Crew on RU Printed: 8/17/2009 10:16:52 AM ~ ~ BP EXPLORAT[4N' pag~ 3 af ~ ~ Operations Summary Report Legal Well Name: J-11 A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: ~ ~ ~ ~ ~ ~ i 8/5/2009 06:00 - 07:00 1.00 EVAL P 07:00 - 09:30 2.50 EVAL P 09:30 - 10:00 0.50 EVAL P 10:00 - 10:30 0.50 EVAL P 10:30 - 12:00 1.50 DHB P 12:00 - 13:00 1.00 DHB P 13:00 - 13:30 0.50 DHB P 13:30 - 14:30 1.00 DHB P 14:30 - 16:30 2.00 DHB P 16:30 - 17:00 0.50 DHB P 17:00 - 17:30 0.50 DHB P 17:30 - 18:00 0.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 19:30 0.50 FISH P 19:30 - 22:30 I 3.001 FISH I N 22:30 - 00:00 I 1.50I FISH I P 8/6/2009 I00:00 - 02:00 I 2.00 I FISH I P wr i rudoe u~a~i iNsiviu ui vNGi a~~~i ra DECOMP and Running USIT Log DECOMP Schlumberaer E-line run USIT loa to locate TOC in 13-3/8" x 9-5/8" Annulus. DECOMP Hold PJSM and RD Schlumberger E-line. DECOMP Send USIT log to town for review. Hold Tabletop Stripping drill with Moses' crew. DECOMP Perform housekeeping throughout rig while waiting for HES to arrive with 9-5/8" RBP. DECOMP RIH with 9-5/8" 47# RBP to 2150'. DECOMP Set 9-5/8" RBP er HES re at 2150' (top of RBP). PU and RIH to confirm set. DECOMP Stand back 1-std. RU to test RBP. Test RBP to 1000-psi for 10-charted minutes. Gland nut leakin . Ti hten land nut and resume testin . Good test. DECOMP RU sand hopper and dump 2200-Ibs (44-sks) of 20/40-mesh sand. Allow sand to fall for 30-minutes. DECOMP Pump 1-DP volume to clear DP of sand. RIH and tag top of sand at 2110". DECOMP POH w- ith RBP unning tool, standing back 4" DP in derrick. -LD Running Tool and Clear Floor DECOMP MU Baker Multi-strin cutter XO, 8 1/2" Stab, XO DECOMP RIH DECOMP Break Circ. and establish Parameters -PUW 75k / SOW 75k -4.4 bpm / 290 psi -60 rpm / 2k ft-Ibs torque Locate Collar at 2043' md, set knives ~ 2052' md WAIT DECOMP Wait on Heated 9.8 ppg Brine -CH2MHill Trucks had to wait on Heated Seawater Plant -Test Surface Lines to 2000 psi -Safety Meeting with Crew on Dropped Objects -PJSM With CH2MHill Truck Drivers, LRS,MI Mud Man and DDI Rig Crew / TP on displacing "Dead Crude " From OA DECOMP Cut 9 5/8" Casin and Displace Dead Crude from OA -Make Casing cut, 70 rpm 3-15k Ft-Lbs, 7 bpm - 870 psi -After cut through, string stalled and OA Showed 200 psi increase, -Pull up to free pipe, 75k overpull to pull free cutters and string from cut. Displace OA; Switch to LRS and Pump 22 bbls of 90 degree heated diesel at 3 bpm - 500 psi, Shut Down Pumping and Shut Annular, Continue pumping Heated diesel, Dead Crude returns from OA, Zero sign of Arctic Pack, Finish pumping Diesel at 3 bpm 550 psi for a total of 50 barrels. DECOMP Displace Dead Crude from OA -Chase heated diesel with 120 bbls of 9.8 ppg heated brine(90 F) -ICP ~ 5 bpm / 560 psi, 35 bbls away 4.5 bpm / 1385 psi, 75 bbls away 3.7 bpm / 1600 psi, 100 bbls away 3.0 / 1700 psi, 120 bbls away 2.7 bpm / 1680 psi, shut down pumping -Pump 44 bbl Safe Surf-O Sweep 4.7 bpm / 547 psi "lost apx. 1000 psi from the time we stop pumping to resuming pumping, Dead Crude / Diesel still returning. Printed: 8/17/2009 10:16:52 AM ~ ~ I BP EXPLORAT[C?N' Page 4 of 1 ~' Qperations Summary R~port Legal Well Name: J-11 A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: ' Date' From - To HQUrs Task Cod~ NPT Phase De~eription of Operations 8/6/2009 00:00 - 02:00 2.00 FISH P DECOMP -Displace safe 5urf-O sweep with 150 bbls of heated 9.8 Brine, 13 bbls into sweep displacement, dirty brine back to surface; 8 bpm / 1290 -1520 psi -Displace 9.8 Heated brine out of Drill string and OA with Seawater; 7.5 bpm 1300 - 1450 psi -Shut Down, Bleed off and confirm zero pressure on OA and DP, Open Bag, -Circulate one hole volume at 10 bpm / 1470 psi -Monitor well, Static 8.4+ In / Out -Suck out residual oil/ diesel from stack -Pump 20 bbls dry job Monitor Well for 5 minutes, Static -Gravel in flutes became stained with crude during circulation, although no fluid came from the flutes. -Recycle 290 bbls of Diesel / Crude to GC2 02:00 - 02:30 0.50 FISH P DECOMP Rig Down Hoses and Ready floor for Trip out of hole -Move 2 stands of 6 1/4" collars to Off Drillers side 02:30 - 03:30 1.00 FISH P DECOMP POH 03:30 - 04:00 0.50 FISH P DECOMP Lay down Multi-String casing cutter 04:00 - 07:00 3.00 BOPSU P DECOMP Pull Wear Bushing -Blow down lines and drain stack. Remove riser. -Nipple Down BOP Stack (with tubing spool attached) and Pull back out of the wa . 07:00 - 09:30 2.50 WHSUR P DECOMP FMC rep remove snap ring below upper packoff. -Remove upper packoff from tubing spool. -Remove lower packoff from on top of slips. 09:30 - 10:30 1.00 WHSUR P DECOMP PU 1-jt of DP and MU to Spear dressed to catch 9-5/8" 47# Csg. -Torque all connections. -MU BTC XO to TIW valve 10:30 - 11:00 0.50 WHSUR P DECOMP RIH and s ear casin . -PU to 132K-Ibs and casin ulls free. Continue to PU with PU wt = 129K-Ibs. -FMC rep recover E-slips in cellar. 11:00 - 12:30 1.50 BOPSU P DECOMP NU BOP stack and tubing spool. -Use Sweeney wrench to properly torque all nuts. -RU power tongs for LD 9-5/8" casing. 12:30 - 13:00 0.50 BOPSU P DECOMP Fill stack and lines. -Test BOP break to ensure no leaks. Good test. 13:00 - 13:30 0.50 CLEAN P DECOMP Circulate surface to surface at 10-BPM with 50-psi. -Fluid density - 8.5-ppg. 13:30 - 14:30 1.00 CLEAN P DECOMP Attempt to break out and LD single jt of DP, but well is out of balance. -Bring pump on at 6.5-BPM with 50-psi and circulate while mixing dry job. -Mix and pump 20-bbl dry job. -Blow down Top Drive. 14:30 - 15:00 0.50 CLEAN P TIEB1 Break out and LD single jt of DP. -Break out first jt of 9-5/8" casing and LD with spear inside. (Break out torque = 37K-ftlbs) -RU handling equipment for 9-5/8" casing. 15:00 - 18:00 3.00 CLEAN P TIEB1 LD 9-5/8" 47# L80 NSCC casing through pipe shed. -First jt below wellhead cut jt is a pup (9.98'). Printed: 8/17/2009 10:76:52 AM • ~ __. _ BP EXPLORATION Pa~e 5 afi 1 ~ Operafions Summary Repor# Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: ' Date From - To Hours Task Code NPT Phase ` Description of Operations 8/6/2009 15:00 - 18:00 3.00 CLEAN P TIEB1 -LD a total of 51-jts, 1-pup jt, 1-welihead cut jt and 1-downhole cut jt. -Downhole cut joint length = 9.6". Casing split above cut and one side of cut folded over. -Average break-out torque = 30K-ftibs. 18:00 - 18:30 0.50 CLEAN P TIEB1 Rig Down Casing Equipment 18:30 - 19:00 0.50 CLEAN P TIE61 Break Down 9 5/8 Casing Spear and Lay Down 19:00 - 20:00 1.00 FISH P TIEB1 MU Dress Off BHA -9.625 Shoe, 11.75 Extension, WO Boot Basket, XO, 13.375 Scraper, Bit Sub, Bumper Sub, Float Sub, XO, - 6 x 6 1/4" SDC's, XO 20:00 - 20:30 0.50 FISH P TIEBi RIH 20:30 - 00:00 3.50 FISH P TIE61 Dress 9 5/8 Stub -Establish Milling Parameters, 70 rpm - 2.5k ft-Ibs off, 6 bpm - 110 psi, -PUW 85k / SOW 85k / RtWt 85k Ta at 7 feet hi h at 2045' md attem t several different parametrs and rpm without success qetting past 2047' Ream Down finall ast and ta ed to of Stub at 2052', Proceeded to dress off to and worked i ed i e back to 2040 and then back down, unable to qet past 2045 - 2047'.. 8/7/2009 00:00 - 01:30 1.50 FISH P TIE61 Milled through area several times and was able to slide past 2045 - 2047 without issues, tag Top of Stub and Dress off 6.5 feet and milled 1 foot to clean up cut, Dress off the top of the stub with inner dress off mill from 2052' to 2053'. Work over stub several times without issues. 01:30 - 02:30 1.00 FISH P TIEB1 Pump High Vis sweep followed by a Safe Surf-O Sweep -No Significant metal cuttings on sweeps return -Monitor Well - Static 8.4+ Seawater In / Out 02:30 - 03:30 1.00 FISH P TIEBi POH and Set Back BHA DC's 03:30 - 04:00 0.50 FISH P TIE61 Lay down BHA and Inspect dress off shoe and top mill~shoe was split and dama ed 1/3 of the circumference xtensive bird nesting drag up hole. -Recover -2-gallons of bird's nested metal cuttings from Boot Basket. -Abundance of bird's nested metal cuttings visible in BOP stack. 04:00 - 06:30 2.50 BOPSU P TIEB1 MU BOP stack washer. Flush BOP stack with Hi Vis sweep. -Function rams / annular. -Re eat flushin stack. 06:30 - 07:30 1.00 FISH P TIEB1 Clean & Clear rig floor. Inspect Top Drive. 07:30 - 09:00 1.50 FISH P TIEB1 Bring Overshot BHA to rig floor and discuss options with town. Wait on information from internal dress off mill. Good indication of dress off but lar e sheet of 13-3/8" ?? casin inside wash i e. Decide to run sealing overshot to ensure that casing patch will seal on 9-5/8" stump. 09:00 - 09:30 0.50 FISH P TIE61 Hold PJSM on overshot run. MU sealing overshot BHA. 09:30 - 10:30 1.00 FISH P TIE81 RtH with Overshot with ackoff on 4" DP from derrick fo 1998'. -Obtain parameters: PU, SO & Rot Wt = 85K-Ibs. Rotate at 20-rpm with 1 K-ftlbs free torque. -Bring pump on at 3-BPM with 40-psi. -Wash down without issue and tag stump at 2053'. Printed: S/17/2009 10:16:52 AM • • BP' EXPLQRATfON Page 5 of 11 Qperations Summary Report Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Date Fram - To Hours Task Code NPT Phase [?escription of ~perations 8/7/2009 09:30 - 10:30 1.00 FISH P TIEB1 ~onfirm catch bv overnullina 40K-Ibs. 10:30 - 11:30 1.00 FISH P 11:30 - 12:00 I 0.50I FISH I P 12:00 - 12:30 0.50 FISH P 12:30 - 14:00 1.50 FISH P 14:00 - 15:00 ~ 1.00 ~ CASE ~ P 15:00 - 20:00 I 5.00 I CASE I P 20:00 - 21:00 I 1.001 CASE I P 21:00 - 22:00 ~ 1.00 ~ CASE ~ P 22:00 - 23:00 ~ 1.00 ~ CEMT ~ P TIEB1 RU to test 9-5/8" casing and test casing. TIEB1 TIEB1 TIE61 TIEB1 TIE61 TIEB1 -Stape pressures up to 500-psi, then 1000-psi and finall 1500-psi. Consistent 150-psi bleed-off in -3-minutes indicates packoff leaking. -Discuss situation with RWO engineering team and decide to LD overshot and run 9-5/8" tieback. Release overshot grapple and pick up off of stump. -Pump 20-bbl Hi Vis sweep around at 12-BPM with 470-psi. Small amount of inetal shavings seen on magnets at shakers. Break out and blow down Top Drive. -POH, standing back 4" DP in derrick. Break out and LD Overshot BHA. -Clean "ring" mark in overshot from sitting down on stump. -Clear rig floor of all un-necessary tools. RU to run 9-5/8" 47# L80 Hydril 563 casing tieback. -RU and function test power tongs. -RU handling equipment. -Clean drip pan of "bird's nested" metal shavings -WSL, Baker Completion and Fishing reps and HES rep all inspect tieback components. -Hold PJSM with all individuals involved on running tieback and power tong safety. r~.._ n rinn .~,. ~ nn ~ i..~_:i ron n__:__ a:,.~...,.i....:i~ n_....,.. -Use torque turn services to MU all Hydril 563 connections to optimum torque of 15,800-ftibs of torque. -Use Jet Lube Seal Guard thread compound on all connections. -Bakerlok all connections below packer. -Install 1-free floating straight bladed centralizer per jt of casing, except final joint through wellhead. -Set 30,000# Down to assure full engagement of Overshot slips and seals -PUW 85k / SOW 85k Bfock Wt. 45k TIEB1 RU Cementer and Test Lines to to 3500 psi. Good Test -Set ECP• Pressure up to 1000 psi for 10 minutes, Pressure up to 1200 and hold for 1 min, Pressure up to 1400 psi and hold for 1 min, Pressure up to 1600 psi and hold for 1 min, pressure up to to 1700 psi and ECP valve opn , bled down to 1380 psi, hold for 5 min, pressure back up 1700 psi - 0.3 bbls to bring back to 1700 psi, pressure up to 2000 psi and hold for 10 minutes, Good Test Bleed o to zero. -Open Cementer; Pressure up to 2650 psi and HES Cementer shifted o ened, Circulate at 6 bpm to confirm cementer is open TIEB1 Circulate warm brine 80 de ree brine in & out -6 bpm / 240 psi Printed: 8/17/2009 10:16:52 AM • • BP EXPLQRATtON Page 7 of ~ 1 Qperations Summary Report Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name; DOYON 16 Rig Number: ~ ~ ~ ~ ~ ~ ~: ...,.,.,.- . ~.,~.~ ..,, ....,...„ ..,.,.,,. ....,,.... ... . . ,..,.,,.. .....,....r....... ~,_. 8/7/2009 22:00 - 23:00 1.00 CEMT P TIE61 PJSM with DDI Rig Crew & TP, CH2MHill Truck Drivers, Schlumberger Cementers, HES Cementer hand and BP WSL on cementing 9 5/8 Tieback String 23:00 - 00:00 1.00 CEMT P TIE61 Cement Tieback Strin -Switch to cementers, pump 5 bbis of fresh water, shut down, PT lines to 4500 psi, Batch Cement and~ump 147 bbls of Class "G" Cement at 5-6 bpm - 220 psi -Cement yield = 1.16-bbls/sk 8/8/2009 00:00 - 01:00 1.00 CEMT P TIEB1 Cement Tieback -At midnight 140 bbls away, 5.5 bpm 220 psi, Finish Pumping cement at 00:03 hrs, Shut Down Kick Plug out with 5 bbls of Water (positive indication of plug leaving), Chase Plug with Rig Pumps at 8 bpm, Caught cement at 50 bbls away, displace at 6 bpm (950 psi) till 110 bbls away, Cement back to surface at 124 bbis dis laced, 5 bpm (1120 psi) till 130 bbls away, Slowed pump rate to 2.5 bpm (1265 psi) the last 10 barrel, choke back backside with 450 si Cementer shifted close C~ 1890 psi additional 625 si over bum ressure , Continue to pressure up to 2500 psi for 5 minutes, good test , zero bleed off *" CIP at 00:30 hrs"*" "*23 bbls of cement back to surface"`* Bleed off pressure, check for flow, O.K. Rig down Cement Equipment 01:00 - 01:30 0.50 CEMT P TIEBi Flush Cement Lines, BOP Stack and Lines running to Flowback tank with Citric Pill 01:30 - 02:00 0.50 BOPSU P TIE61 Nipple Down BOP's -Suck out stack and landing joint 02:00 - 05:00 3.00 WHSUR P TIE61 Set Emer enc Sli s on 9 5/8" casing with 100,000 Ibs on slips -Cut Casing with Wachs' cutter and Lay Down an ing ~om -Set Spool on and Install New Packoff -Test Pack off to 3800 psi for 30 minutes 05:00 - 07:00 2.00 BOPSU P CLEAN Ni le U BOP's and Change Rams -Install 2-7/8" x 5" VBRs. -Open blind rams and clean cavities. 07:00 - 07:30 0.50 BOPSU P CLEAN RU to test VBRs & break. -Set test lu . 07:30 - i 0:30 3.00 BOPSU P CLEAN Test Blind Ram door seal, 2-7/8" x 5" VBRs. Also test annular with 2-7/8" test jt. -Test to 250-psi low and 3500-psi high, using 2-7/8" and 4-1/2" test jts for VBRs. -Hold and chart each test for 5-minutes. -AOGCC rep Jeff Jones waived witness of test on 8/7/09. 10:30 - 11:00 0.50 BOPSU P CLEAN Blow down and RD test equipment. 11:00 - 12:30 1.50 CLEAN P CLEAN Hold Doyon 16 Safety Stand UP to celebrate Doyon 16's safety and operational success. Motorman monitor rig while all crews meet, eat and discuss their safe, good work. 12:30 - 13:00 0.50 WHSUR CLEAN Install wear ring and RILDSs. 13:00 - 14:00 1.00 CLEAN P CLEAN MU 9-5/8" Drill out BHA. -BHA consists of 8-1/2' it, ea oot Baskets, Bumper Sub, and 2-stds of 6-1/4" DCs. -Total length = 208.82'. Printed: S/17/2009 10:16:52 AM ~ • i BP EXPLQRATIQN Page ~ of 11 '' Operations Summary Report Legal We-I Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description caf Operations 8/8/2009 14:00 - 14:30 0.50 CLEAN P CLEAN RIH on 4" DP from derrick to 1918' 14:30 - 19:00 4.50 CLEAN P CLEAN MU to Top Drive and obtain parameters. -PU wt, SO wt & Rot wt = 85K-Ibs. -Pump on at 6-BPM with 120-psi. Rotate at 60-RPM with 2K-ftlbs free torque. -Wash down, seeing stringers at 2002'. -PU, begin rotation and Continue ahead, running 5K-Ibs WOB. Ta cement at 2008' and then lug at 2009'. -Good cement and light rubber returns across shakers. -RIH to 2114' -Dry drill on junk for 10 min 19:00 - 19:30 0.50 CLEAN P CLEAN -Pump two 20-bbl Hi Vis sweep. 10 bpm - 540 psi -Sand and metal cutting return with sweeps Monitor Hole, Static Seawater In / Out 19:30 - 20:30 1.00 CLEAN P CLEAN POH 20:30 - 21:30 1.00 CLEAN P CLEAN Lay Down BHA -Clean out boot baskets and recover 7 gals of inetal shaving and drillout junk 21:30 - 22:00 0.50 CLEAN P CLEAN MU RCJB BHA 22:00 - 23:00 1.00 CLEAN P CLEAN RIH to 2025' 23:00 - 00:00 1.00 CLEAN P CLEAN Wash down from 2025' - 2122' -PtJW 85k / SOW 85k -8 bpm / 490 psi, Drop Ball, 8.6 bpm / 2060 psi -Pump 20 bbl High Vis Sweep, Sand with a few metal cutting returned with sweep 8/9/2009 00:00 - 01:00 1.00 CLEAN P CLEAN POH with RCJB 01:00 - 01:30 0.50 CLEAN P CLEAN ay own 6 1/4" Drill Collars 01:30 - 02:30 1.00 CLEAN P CLEAN Clean out RCJB and Boot Baskets -1 gallon ot larger pieces and 2 gallons of inetal cuttings recovered 02:30 - 03:30 1.00 CLEAN P CLEAN MU Run #2 on RCJB BHA and RIH 03:30 - 05:30 2.00 CLEAN P CLEAN Wash Down from 2130 to 2140 -PUW 85k / SOW 85k -8.8 BPM 330 PSI -Pump 20 bbls High Vis Sweep 05:30 - 06:30 1.00 CLEAN P CLEAN POH with RCJB. -LD RCJB and clean out. Recover 2" x 3" piece of rubber from RCJB and minimal sand from boot baskets. 06:30 - 07:00 0.50 CLEAN P CLEAN Clean and clear rig floor. 07:00 - 08:00 1.00 CLEAN P CIEAN RU and ressure test 9-5/8" casin tieback / atch down to top of RBP at 2150' to 3500- si for 30-charted minutes. -Good test. -RD test equipment. 08:00 - 09:00 1.00 DHB P TIEB1 MU HES RBP retrieval tool. -RIH to 2090'. PU wt = 70K-Ibs, SO wt = 75K-Ibs. -Bring pump on at 8-BPM with 240-psi and wash down. -Engage RBP at 2150'. Set down 20K-Ibs and PU 10K-Ibs over to confirm latch. 09:00 - 09:30 0.50 CLEAN P CLEAN Pump 20-bbl Hi Vis sweep at 8-BPM with 240-psi. -Sand and small pieces of rubberjust ahead of and throughout sweep. -Release RBP with 20K-Ibs overpull. 09:30 - 10:00 0.50 DHB P TIE61 CBU at 8-BPM with 240-psi. Printed: 8/17/2009 10:16:52 AM • i BP EXPLORATION Page 9 t~f 1 ~ Operations Summary Repart Legal Well Name: J-11A Common Weli Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hcaurs Task Cod~ NPT Phase Description of C~peratic~ns 8/9/2009 09:30 - 10:00 0.50 DHB P TIEB1 -Monitor well. Static. -Blow down top drive. 10:00 - 11:30 1.50 DHB P TIEBi POH, standing back 4" DP in derrick. -LD HES RBP and RBP retrieval tool. 11:30 - 12:00 0.50 CLEAN P CLEAN Close blind rams and test 9-5/8" casing from surface down to 12:00 - 14:00 I 2.00 I CLEAN I P 14:00 - 19:30 I 5.501 BOPSUFI P 19:30 - 20:00 0.50 WHSUR P , 20:00 - 00:00 4.00 WHSUR P I8/10/2009 00:00 - 02:00 2.00 CLEAN P 02:00 - 03:30 1.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 06:00 I 2.00 I CLEAN I P 06:00 - 09:30 I 3.501 CLEAN I P 09:30 - 10:30 I 1.00 I CLEAN I P 10:30 - 14:00 I 3.501 CLEAN I P -Test to 3500- si for 30-charted minutes. -Good test. CLEAN Pull Wear ring. -Clean & Clear rig floor. -Install test plug. -RU for weekly BOP test and function rams. CLEAN Perform weekly BOPE test. - es o -psi ow, -psi igh. -Hold and chart all tests for 5-minutes. -Test 2-7/8" VBRs with 4-1/2" and 2-7/8" test jts. Test Annular with 2-7/8" test jt. -Test 4" and 2-7/8" TIW and dart valves. -AOGCC rep Chuck Scheve waived witness of test on 8/8/09. -All tests witnessed by BP WSL (Abbie Barker) and Doyon Toolpusher (Sam Dye). CLEAN Pull Test Plug and Install Wear Bushing CLEAN MU 3 5/8" mill with Shear Guide, 3 1/8" DC Jars, Bumper Sub and 2 7/8" HT Pac DP CLEAN Continue RIH picking 2 7/8" HT Pac DP -Break Circ at 1263' to assure DP Clear 3 bpm / 840 psi CLEAN Slip and Cut Drilling Line CLEAN Service Rig -Serviced Draw Works, Crown and TDS -Inspect TDS CLEAN RlH with QuikDrill Mill out BHA on 4" DP from derrick. -Break circ at 5803' and 8644' to ensure DP is still clear. -Obtain parameters at 8770' - PU wt = 157K-Ibs, SO wt = 127K-Ibs, Rot wt = 140K-Ibs. Rotate at 10-RPM with 2.5K-ftlbs free torque. CLEAN Circulate full wellbore volume at 5.5-BPM with 2650-psi. -Pump clean 8.5-ppg SW and dump all dirty returns to ensure downhole fluid is as clean as possible. -Continue to circulate while waiting on load of SW to arrive prior to drilling out plug. CLEAN RIH and ta tubin stum at 8790'. -Set down 7K-Ibs and see shear pin guide shear out. -Continue in hole and tag QuickDrill plugat 8908'. Mill plug with 2-3K-Ibs WOB, pumping at 3-BPM / 970-psi and rotating at 60-RPM w+th 41(-ftlbs torque. -Lose returns just prior to plug letting go. -Attem t to re ain circulation b fillin backside at 6-BPM. Pump 100-bbls and unable to get returns. CLEAN Continue to RIH with 4" DP from derrick, maintaining continuous hole fill of 150-BPH. -Hanq up at 11368' and work free. Stand back 3-stds of DP to Printed: 8/17/2009 10:16:52 AM • ! BP' EXPLORATI~N Page ~ a of 11 Operations Summary Repart Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operati~ns 8/10/2009 10:30 - 14:00 3.50 CLEAN P CLEAN -MU to To Drive and wash and ream ahead through tight spot without issue. -Continue RIH and han u a ain at 11,530'. Work through several times. -Wash and ream down to final de th of 11,575'. Running 1-2K-Ibs WOB, pumping at 3.6-BPM / 1060-psi and rotating at 60-RPM with 7K-ftlbs of torque. -Confirm depth okay with asset and RWO engineer. 14:00 - 00:00 10.00 CLEAN P CLEAN POH from 11,575' to 11,105' in order to get above erfs, s an mg ac in derrick. -Hold PJSM with rig crew on LD DP through pipe shed. -Continue to POH, laying down DP through shed. -Maintain continuous hole fill of 120-BPH. 8/11/2009 00:00 - 00:30 0.50 CLEAN P CLEAN Service Rig -Service Draw Works, TDS -Inspect Top Drive 00:30 - 03:30 3.00 CLEAN P CLEAN Lay Down 2 7/8" Drill Pipe -Hold PJSM with rig crew on LD 2 7/8" DP through pipe shed. -Maintain continuous hole fill of 120-BPH. 03:30 - 04:30 1.00 RUNCO RUNCMP LD BHA -Clear Floor -LD Bakers XO & Tools 04:30 - 06:30 2.00 RUNCO RUNCMP PJSM on rigging up to run 4 1/2" Chrome Completion -RU Double Stack Tongs -Change Bales. -RU Compensator. -Hold PJSM with all involved on running 4-1/2" 12.6# 13cr80 Vam Top tbg. Highlight tong safety and assign people to positions. 06:30 - 12:00 5.50 RUNCO P RUNCMP Run 4-1/2" 12.6# 13cr80 Vam Top tubing with 9-5/8" x 4-1/2" Uni ue Overshot to 4026' -Torque turn all connections to optimum torque of 4440-ftibs. -Use Jet Lube Seal Guard on all connections. BakerLok all connections below packer. -Tailpipe assembly RIH at 0730-hrs. -Maintain continuous hole fill of 120-BPH. 12:00 - 16:00 4.00 RUNCO RUNCMP Continue running 4-1/2" 12.6# 13cr80 Vam Top tubing per running tally from 4026' to no-go on tubing stub C~3 8816' observed shear ins with overshot assin tubin stub at 3' & 11'. Tubin stub to at 8805'. Up wt = 152k dn wt = 117k. -Maintain continuous hole fill of 120-BPH. 16:00 - 17:30 1.50 RUNCO P RUNCMP Lay down jts # 202-200. Pickup required space out pups. Make up tubing hanger and landing joint. 17:30 - 18:30 1.00 RUNCO P RUNCMP Land tubing, guide shoe set C~3 8815'. RILDS. 18:30 - 21:30 3.00 RUNCO RUNCMP R/U circulating lines to reverse circulated clean inhibited seawater. PJSM covering seawater displacment. Test lines to 3,500 psi. Circulate in 290 bbls of 50 deg seawater treated with corrosion inhibitor C~3 3 bpm 10 psi followed by 210 bbls 120 deg seawater treated with corrosion inhibitor ~ 3 bpm, 10 psi. No returns during displacement. 21:30 - 00:00 2.50 RUNCO P RUNCMP Drop 1 7/8" ball_and rod, fill tubinq with 18 bbls seawater, fluid Printed: 8/17/2009 10:16:52 AM ~ ! BP EXPLORATIUN Page 11 ofi 11 Operations Summary R~port Legal Well Name: J-11A Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 7/29/2009 End: 8/12/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 8/12/2009 Rig Name: DOYON 16 Rig Number: Date ' Frorn - To Hours Task Code NPT Phase Description of Operations 8/11/2009 21:30 - 00:00 2.50 RUNCO RUNCMP and test tubin hold ressure for 30 min record on chart. Bled 8/12/2009 00:00 - 01:30 1.50 WHSUR P 01:30 - 02:00 0.50 WHSUR P 02:00 - 03:00 1.00 BOPSU P 03:00 - 06:00 3.00 WHSUR P 06:00 - 07:30 1.50 WHSUR P 07:30 - 08:30 1.00 WHSUR P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:00 0.50 WHSUR P 10:00 - 11:00 1.00 WHSUR P tubing pressure to 1600 psi. Fill IA with 43 bbis seawater, fluid level at 800' Pressure u on IA to 3500 si to test acker hold ressure for 30 min. record on chart. Bled tubin to shear DCR shear valve, pump 5 bbls through both ways. ~ 3 bpm, 240 psi Losses for ast 24 hrs. = 1503 bbis. RUNCMP La down landin 'oint. D rod in TWC. Test from above to 3500 qsi. test from below to 1.000 qsi. Record tests on chart. . RUNCMP Blow down circulating lines and drain stack. RUNCMP Ni le down BOP. 2 barriers for ND are 1) Ball & Rod on seat w/ KWF above and 2) Tested TWC. RUNCMP Nipple up Tubing head adapter and tree. Pressure test tubing head seals to 5000-psi for 30-minutes and tree to 5000-psi for 5-minutes. Good Tests. RUNCMP PJSM on pumping diesel freeze protection with LRS. RU LRS an pressure test ines to 3500-psi. everse in 150-bbls of RUNCMP PU DSM lubricator and ressure test to 500- si. Good test. Lubricate in BPV. LD Lubricator. RUNCMP LRS ressure test BPV to 1000- si for 10-charted minutes. Good test. Blow down lines and RD LRS. RUNCMP RD secondary IA valve. Install all gauges and valves on tree. Secure well. Empry Slop tank. Release Rig at 1100-hrs. Printed: 8/17/2009 10:16:52 AM ~ ~ ~ ' ~~ ~ ~ ~~ ~~~ ~ ~~~ ~ ~ ~~~ ~~ . ~~ '~ ~~ ~'~ ~ ~' ~`'~~ ~"`' ~ ~. a a ~ c~°~ j . ~; A~ ~ ~~~~ ~ r .~ SEAN PARNELL GOVERNOR ~ ~~ ~ ~, ~~ ~ "" ~~~' ~ @~~ ~~ ~,~` ~k~~ ~~ ~~ ~ ~ ~ ~~' ~:.~,~ ~ :s 0 - ,: ~~ y ~+ ~r~~~+ ~ ~-7~~ ~IL ~D Vr~-7 ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQA7`I011T COM1rIISSIOI~T ;~ ANCHORAGE, ALASKA 99501-3539 y~ PHONE (907) 279-1433 p FAX (907)276-7542 Mr. David Reem Engineering Team Leader BP Exploration (Alaska), , F P.O. Box 196612 . 4~' a~ `~ ~~~' ,; a~~~-;r, .;~ „ ~~~. Anchorage, AK 99519-6612 i b' ` Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-11A ~~ Sundry Number: 309-254 ~ Dear Mr. Reem: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleur:z field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this3o~J day of July, 2009 Encl. . ~ ~' °~ r~ ~ STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COM~SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 aLL , ._... ___ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensian•~ 7`C~4~ 4 i r' p ~ Alter Casing - -~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program -~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 196-104 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-Z0462-01-00 ~ 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: PBU J-11A - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): , ADL 028281 , 73.40 °' Prudhoe Bay Field / Prudhoe Bay Oil Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12630 - 9067 ~ 8844 7604 eaaa', ~ ~ saa~, i ~ sso~ N/A in n th i M TVD B r II ruc r I on r 11 ' 2" 11 ' 1' SurFace 2556' 13-3/8" 2556' 2 4 2 7 Interm diate Pr in 4' -/" 4' 77 ' 67 470 Liner 2366' 7" 8892'-11258' 7642' - 9 03' 7240 5410 Lin r 1947' 4-1/2" 10 8'- 12630' 8857' - 067' 8430 7500 PerForation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 10632' - 12400' 8825' - 9019' 4-1/2", 12.6# 13Cr-80 / L-80 10676' Packers and SSSV Type: 9-5/8" x 4-1/2" BKR S-3 Packer, 7" x 4-1/2" BKR PRMR Packers and SSSV MD (ft): 8865', 10463' Packer and a 7" x 4-1 /2" BKR SABL-3 Packer & 10655' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Expioratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 1, 2009 ,~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 56a-5a44 Printed Name id Reem Title Engineering Team Leader Prepared By Name/Number Signature Phone 564-5743 Date ~/z~ d Sondra Stewman, 564-4750 Commisaion Use Onl Sundry Number: _ ~ Conditions of approval: N fy Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 35D0 P~'„ ~p~ ~S~ Subsequent Form Required: ~Q _ ~~~ ~ APPROVED BY 3 G ~ ~ ~ A roved B: COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2f106 Q ~ ~ ~ + ~l~ ~ ~. . ~ ~~~ ~~~~. t~ € ?~os ~~~~~~ ~F-~~ ~ vt 8-~ _~ ~.~ !~, `~ ~ ? ~ t~ ~ Submit In Duplicate ~ ~~~~~ ~,~ 71z~/~ `~t~ ~ ~p GP~~ J-11A Rig Workover (Repair IA x OA communication) ~ Zq~o1 ?~ ~ ~ Scope of Work: Pull 4.5" 13Cr-80 completion. Run USIT log to find TOC, cut and pull 9.625" casing as deep as possible. Tie back 9.625" casing, and cement to surface with new packoffs and slips. Run 4.5" 13Cr-80 completion. Engineer: Hank Baca MASP: 2140 psi Well Type: Producer Estimated Start Date: August 1 st, 2009 Pre-Riq Work Request: S 1 Pull PX plug @ 8,844'. Drift the 4-1/2" tubing to 10,674' for composite brige plug. Pull dumm valve on GLM Station #3 at 7,530' MD. E 2 Set com osite brid e lu at ~8,910' MD Reference tubin tall dated 5/4/2002 . F 3 CMIT-T x IA to 3,500 si. MIT-OA to 2,000 psi. E 4 Power Jet cut 4-'/" 13CR tubing at ~8,801'MD, ~10' below the collar at 8,791' MD Reference tubin tall dated 5/4/2002 . F 5 Circulate well with clean seawater and freeze rotect to 2000'. F 6 CMIT T x IA to 1,000 psi for 10 minutes. 6 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time . PPPOT-T & IC. W 8 Set a BPV in the tubin han er. 9 Rhino liner cellar Pronosed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. BOP stack consists of annular, blind/shear, and 2-7/8" x 5" variable rams. Circulate out freeze protection and circulate seawater. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. RU wireline and run USIT from cut to surface. 5. Run 9-5/8" RBP and set ~100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump -50 ft of sand on RBP. 6. Mechanically cut 9-5/$" casing in 15~ full joint above top of cement. Pull casing & LD. Note: VBR's will not be changed to 9 5/$" pipe rams as the well has 2 tested barriers (RBP 8~ packer/comp. BP) to the reservoir. 7. Dress-off 9 5/$" stub in preparation of casing overshot. 8. Run condition B 9 5/$", 47#, L-80 casing and land on new emergency slips with new primary pack-off. 9. Cement 9-5/8" casing to surface. 10. Drill out 9.625" shoe track. 11. Cleanout above 9-%" RBP w/ RCJB. PT 9.625" tieback to 3500 psi for 30 minutes. Pull 9 5/e' RBP. 12. Drill up 4.5" composite bridge plug @ 8910' & chase below bottom perf (10,640') 13. Run 4-%2" 13Cr-80 stacked packer completion 14. Displace the IA to packer fluid and set the packer. 15. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 16. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. U i ,~- 6 ~~, WELLHEAD = FMC J 11 A 'ACTUATOR= OTIS ~ ' KB. ~EV - . 73.4' BF. ELEV = 40.1' KOP = 2350' Max Angle = 94 @ 11136' Datum MD = 10710' ~tum ND = 8800' SS 13-3/S" CSG, 72#, L-80, ID = 12.347" ~~ 2551 Minimum ID = 3.725" @ 10669' 4-1/2" HES XN NIPPLE L TOP OF 7" BKR TIEBACK SLV 9-5/8" X 7" BKR ZXP PKR, ID = 6.38" 9-5/8" X 7" BKR HMC HGR ID = 6.38" 9-5/8" CSG, 47#, ID = 8.681 " S TES: ***W ELl ANGLE > 70° @ 10950' 8~ > 90° @ 80'. POSSIB~E DAMAGE TO 4-1/2" XN NIP @ 10669'. SEETElIX OF11/30/00. 4-1/2" CHROME TUBINCs**" 2219~ 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3665 3575 35 MMG DOME RK 16 O6/04/02 4 5828 5270 41 MMG SO RK 20 O6/04/02 3 7530 6553 39 MMG DMY RK 0 06/04/02 2 8773 7549 38 MMG DMY RK 0 06/04/02 *1 "10532 8761 49 KBG-2 BKFS BK 0 06/04/02 "CiLM iFl IS litl WttN S I KAUULt F'KK5 $$44' 4-1/2" HES X NIP, ID = 3.813" $$44' 4-1/2" PX PLUG (O6/15/09) 8865~ 9-5/8" X 4-1/2" BKR S-3 PKR ID = 3.880" 9-5/8" SDTRK WINDOW, 9094' - 9144' (SECTION MILL). PRE-SOTRK WELLBORE P&A NOT SHOWN B~OW 9-5l8" MILLOUT WINDOW 10463' ~" X 4-1/2" BKR PRMR PKR, ID = 3.833" 10601' 4-1/2" HES XN NIP, ID = 3.725" 10622' (3) 4-1l2" BLAST JOINTS (29') 10653~ 4-1/2" SEAL ASSY, ID = 3.958" 4-1/2" TBG, 12.6#, 13-CR-80, 10653~ .0152 bpf, ID = 3.958" 10655' 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 10669~ 4-1/2" HES XN NIP, ID = 3.725" 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674~ (NIP WASHm OUT 03/12/02) TOP OF TNV TIEBACK SLV, ID = 3.890" 106$$~ 1Q676' 4-1/2" WLEG, ID = 4.00" ~ " " " 7" X 4-1/2" TNV DTH LNR HGR ID = 3.916" 10695~ 10693 7 X 4-1/2 TNV LT PKR, ID = 3.916 PERFORATION SUMMARY R~ LOG: WA ACOUSTILOG ON 06/23/96 ' SPERRY-SUN AWR ON 07/01/96 A NGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 10632 - 10640 C 03/22/02 2-3l4" 4 * 11170 - 11210 C 03/22/02 2-3/4" 4 ' 11270 - 11550 C 03/22/02 2-3/4" 4 * 12100 - 12400 C 10/12/01 ~~ 1 ~z5so~ r 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 12630' DATE REV BY COMMENTS DATE REV BY CAAMAHVTS 07/12I80 ORIGINAL COMPLETION 07/06/96 RIG SIDETRACK 05/05/02 JDM/KK RWO 10/20/01 CFUKAK CORRECTIONS 04/02/07 LWB/TLH GLV GO (06/04/02) 06/28/09 TFA/TLH PLUG SET (06/15/09) PRUDHOE BAY UNIT W~L: J-11A PERMff No: 1961040 AR No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL & 804' FEL BP Exploration (Alaska) 11844' 3-3/8" IBP PUSHED DH (05/31/02) CTM 11950~ 4-1/2" EZ DRILL CIBP, (10/12/01) CTM 7" LNR 26#, L-80, ID = 6.276" ~~ 1 ~ 4-1/2" C16P, PUSH~ DH BY CT (05/04/01) CTM ~ TREF = • 6" CNV 4VEl"LHEAD = FMC AETUATOR = OTIS KB. ELEV = 73.4' BF. E1EV = 40.1' KOP = 2350' Max Angle = 94 @ 11136' Datum MD = 10710' Datum ND = 8800' SS J-1'I~ Proposed r 2,000' - 4-1/2" HES X NIP,ID-3.813" 2,370' - 9-5/8", 47#, L-80 Hyd-563 2,350` - 9-5/8" ECP 2,375' - 9-5/8" CSG Patch 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2556~ Gas Lift Mandnels ST MD TVD Size 4 - x 1-1 3 6269' 5600' 4-1 /2" x 1-1 /2" 2 7719' 6700' 4-1 /2" x 1-1 /2" 1 8648' 7450' 4-1i2" x 1-1/2" I TOP OF 7" BKR TIEBACK SLV ~ 8892~ 9-5/8" X 7" BKR ZXP PKR, ID = 6.38" $$9$' 9-5/8" X 7" BKR HMC HGR ID = 6.38" 8906~ s-5is" csG, a~#, io = 8.sai~~ 9094' 8,950' 4-1/2" HES X NIP, ID=3.813" 8,910' 41/2" x 9-5/8° BKR S-3 PKR, 9CR 8,880' 41/2" HES X NIP, ID=3.813" 8,850' 4-1/2" HES X NIP, ID=3.875° 8,791' 4-1/2" x 9-5/8" Unique Overshot, 9CR $$44' 4-1/2" HES X NIP, ID = 3.813" 8865' 9-5/8" X 4-1/2" BKR S-3 PKR ID = 3.880" 9-5/8" SDTRK WINDOW, 9094' - 9144' I (SECTION MILL). PR~SDTRK WEILBORE P8~A NOT SHOWN B~OW 9-5/8" MILLOUT WINDOW. ~ 10463~ ~ 7" X 4-1/2" BKR PRMR PKR ID = 3.833" 10601 ~ 1~~ 4-1/2" HES XN NIP, ID = 3.725" (3) 4-1/2" BLAST JOIMS (29'1 'IUb53~ I~4-~/L"JtALAJJY,IU=:S.y523 10655~ ~~ 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" 4-1/2" TBG, 12.6#, 13-CR-80, 10653~ 10669~ 4-1/2" HES XN NIP, ID = 3.725" .0152 bpf, IO = 3.958" (NIP WASHm OUT 03/12/02) 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" 10674' 10676~ 4-1/2" WLEG, ID = 4.00" TOP OF TNV TI~ACK SLV, ID = 3.890" 10683' 10693~ 7" X 4-1/2" TNV LT PKR, ID = 3.916" 7" X 4-1/2" TNV DTH LNR HGR, ID = 3.916" 10695~ PERFORATION SUMMARY R~ LOG: WA ACOUSTILOG ON O6/23/96 ' SPERRY-SUN AWR ON 07/01/96 ANGLE AT TOP PERF: 51 @ 10632' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 10632 - 10640 C 03/22/02 2-3/4" 4 ' 11170 - 11210 C 03/22/02 2-3/4" 4 ' 11270 - 11550 C 03/22/02 2-3/4" 4 ' 12100 - 12400 C 10/12/01 (05/31/02) CTM ~ g~' 4-1/2" Q DRILL CIBP, (10/12/01) CTM 7" LNR, 26#, L-80, ID = 6.276" ~-i 10922~ 4-1/2" CIBP, PUSHED DH BY CT (05/04/01) CTM ~ 12382~ PBTD -~ ~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/12180 ORIGINAL COM PLETION 07/06/96 RIG SIDETRACK OS/05/02 JDMIKK RWO 10/20/01 CWKAK CORRECTIONS 04/02/07 LWB/TLH GLV GO (06/04/02) 06/28/09 TFA/TLH PLUG SET (06/15/09) PRUDHOE BAY UNff WELL: J-11A PERMff No: 1961040 API No: 50-029-20462-01 SEC 9, T11 N, R13E, 650' FNL 8~ 804' FEL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Camille O. Taylor Chair THRU' Tom Maunder ~~..~ P.I. Supervisor' FROM' Lou Grimaidi Petroleum Inspector DATE' April 18, 2002 SUBJECT: Blowout Preventer Test Doyon 16 BPX, J pad J-11A PTD # 196-104 Prudhoe Bay Field/Unit NON- CONFIDENTIAL Operator Rep.' Abbot/Haines Contractor Rep.' WillinghamtBillings Op. phone: 659-4608 Rig phone' 659-4610 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 25013500 Annular: 250/3500 Choke: 250/3500 TEST DATA MISC. INSPECTIONS' Location Gen.' Housekeeping' PTD On Location Standing Order: FLOOR VALVES' P/F P/F Quantity P/F P Sign: P Upper Kelly 1 P Rig cond: P Lower Kelly 1 N/A Hazard: N/A' Ball Type 1 P Inside BOP I BOP STACK: Quantity Size P/F Annular Preventer 1 13 5~8" F CHOKE MANIFOLD: Pipe Rams 1 3 1/2"x6" P Quantity P/F , , Lower Pipe Rams 1 4 1/2"x7" P No. Valves 14 P Blind Rams ' 1 1:~ 518" i~'' Man. Chokes I 'P .... Choke Ln. Valves 1 3 1/8" P Hyd. Chokes 1 P ' HCR Valves 2 3 118" P Kill Line Valves 1 3 1t8" P Check Valve 0 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P ACCUMULATOR SYSTEM: System Pressure After Closure 200 psi Attained Full Pressure 1:57 Blind Covers (AIl'"Stati°ns): N2 Bottles (avg)' 6/2000 Time/Psi PIF 3000 P 1450 P · 33 P P Test's. Details The rig was ready to test when I arrived. Due to problems with the tubing hanger not accepting a back pressure valve, a tubing plug was set in the SSSV and I allowed for the Blind's and Bottom pipe rams to be tested after the hanger and four joints of tubing were pulled. The remaining tubing was hung off of a storm packer. The teSt (both..parts) went well with one failUre observed, this being the annular preventer. This was cycled and retested but still failed. The element was changed and retested "OK". The rig was in good shape, the location was clean and orderly. This is normal for this rig. Total Test Time: 6 hours Number of failures: cc' Attatchments: None BOP Test (for inspectors) BFL 1 1/02/01 BOP Doyon 16 4-17-02 LG.xls 1. Operations performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r-i operation Shutdown i"i Stimulate I-I Plugging l-I Perforate I~ Pull Tubing r'l Alter Casing I~ Repair Well l'-I Other 2. Name of Operator BP Exploration (Alaska) Inc. '3. Address P.O. Box 196612, Anchorage, Alaska "4. Location of well at surface 650' SNL, 804' WEL, SEC. 09, T11N, R13E, UM At top of productive interval 296' NSL, 4900' WEL, SEC. 04, Tll N, R13E, UM At effective depth 285' NSL, 3655' WEL, SEC. 04, T11N, R13E, UM At total depth 115' SNL, 2989' WEL, SEC. 09, T11N, R13E, UM 12. Present well condition summary Total depth' measured 99519-6612 Effective depth: Casing Structural true vertical measured true vertical Conductor Surface Intermediate Production Liner Liner 12630 feet 9067 feet 11844 feet 9017 feet Length 110' 2556' 9094' 2366' 1947' 5. Type of well: I~ Development I'"! Exploratory r-'! Stratigraphic r"! service Plugs (measured) Junk (measured) Size 20" 13-3/8, 9-5/8" 7" 4-1/2" 6. Datum Elevation (DF or KB) KBE = 73.40' 7, Unit or Property Name Prudhoe Bay Unit 8. Well Number J-I1A 9. Permit Number'/ ' Apl~'rovai No. 196-104 1'0. APl Number ' 50-029-20462-01 , , , 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 3-3/8" IBP pushed down to 11844' (05/02); Set EZSV ClBP at 11950' (10/01); CIBP pushed down to 12382' (05/01) Cemented MD TVD 8.5 cu yds Concrete 4790 cu ft Arcticset II 1086 cu ft Class 'G', 83 cuft AS I 505 cu ft Class 'G' 267 cu ft Class 'G' 110' 110' 2556' 2550' 9094' 7796' 8892' - 11258' 7642' - 9003' 10683' - 12630' 8857' - 9067' Perforation depth: measured 10632' - 10640', 11170' - 11210', 11270' - 11550' Open Perfs Below CIBP: 12100' - 12400' true vertical 8825'- 8830', 9001'- 9001', 9003'- 9006' Open Perf Below CIBP: 9013'- 9019" Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 10653' RECEIV'Eb Packers and SSSV (type and measured depth) 7" x 4-1/2" TIW 'LT' packer at 10693'; 7"x 4-1/2" Baker 'SABL-3' packer at 10655'; 7"x 4-1/2" Baker'PRMR' packer at 10463'; 9-5/8" x 4-1/2" Baker 'S-3' packer at 8865'; 4-1/2" HES 'X' Nipple at 2219' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation: Subsequent to operation' 15. Attachments I'1 Copies of Logs and Surveys run !~ Daily Report of Well Operations !~ Oil r"! Gas I-] Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ Title Technical Assistant .Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 16. Status of well classifications as: Form 10-404 Rev. 06/15~88 , , , Casing Pressure Tu in sure , .-.-, 5 .... Date O~,~" 1 ~ "0 ~ Prepared By Name/Number: Terri; hubbte, 564-4628 ' Submit in Duplicate~ Well: J-1 lA RWO Rig Accept: 04/16/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-20462-01 Rig Release: 05/04/02 Permit: 196-104 Drilling Rig: Doyon 16 PRE-RIG WORK 03/22/02 RIH W/3 3/8" IBP, DID NOT TAG TD, TIED INTO P-PROF LOG, SET (IBP) PLUG @ 10750' (COE) TOP OF PLUG IS @ 10743.5'. SET 50' LOWER THAN REQUESTED SETTING DEPTH OF 10700' DUE TO INDICATION OF RATTY LOOKING PIPE AT THE 10700' AREA ON CCL LOG. POOH, RDMO. 03/25/02 DRIFTED TUBING WITH A 3.78" SWAGE AND DUMPED TWO 10' 3.5" BAILERS FULL OF SLUGGIT ON TOP OF IBP AT 10727' AMS-SLM. 03/31/02 PUMPED (160K LSRV) FLO-PRO TO PLUG PERFS. INITIAL PRESSURE W/FLO-PRO ON PERFS 900 PSI, INJECTED 35 BBLS FLO PRO. PRESSURE INCREASED TO 1300 PSI AND HELD ON SHUT DOWN. 04/03/02 STRING SHOT & CHEM CUT 4.5" TUBING AT 10592' (8' ABOVE BLAST JOINT). STUCK CUTTER AT 830', ATTEMPT TO FREE TOOL BY PRESSURING UP ON TBG (SHUT DOWN WHEN IA AT 3000 PSi & TBG AT 2300 PSI). BLED WELL BACK, UNABLE TO FREE TOOL. DECISION MADE TO PULL OUT OF WEAK POINT. NOTE: *** FISH IN HOLE - CHEM CUTTER' OAL 37' WITH I 3/8" FISH NECK, ESTIMATE TOP OF FISH AT 810'. O4/O5/O2 FISH E-LINE CHEMICAL CUTTER FROM 794' SLM. CHEM CUTTER HAD FIRED. WELL LEFT SHUT-IN. 04/07/02 CHEMICAL CUT TUBING AT 10539 FT MD (ABOVE UPPER PACKER AT 10545 FT). RAN 3 5/8" CHEMICAL CUTTER WITH 3 3/8" ANCHOR BODY. GOOD INDICATIONS THAT CUTTER FIRED. POH. INSPECTED CHEMICAL CUTTER - FOUND A SILVER DOLLAR SIZED HOLE IN THE LOWER CHEMICAL TUBE. THE HOLE WAS ABOUT 2 FEET UPHOLE OF WHERE THE CHEMICAL EXISTS THE CUTTER HEAD. THE CUTTER HEAD ALSO HAD SIGNS OF NORMAL CHEMICAL EXPULSION OVER 1/2 OF THE RADIUS. ALL SURFACE INDICATIONS SUGGEST THE TUBING WAS NOT COMPLETELY CUT. WILL RETURN TO MAKE SECOND ATTEMPT TO CUT WITH JET CUTTER 4/8/02. 04/08/02 TIE IN AND JET CUT TUBING AT 10542 FT MD - 3' ABOVE PACKER, 3 FEET BELOW ATTEMPTED CHEMICAL CUT. GOOD INDICATIONS OF SUCCESSFUL CUT. POOH. BOTTOM 2' OF ALUMINUM CUTTER GONE. RDMO. 04/10/02 CIRC-OUT TUBING AND INNER ANNULUS WITH 1500 BBLS OF WATER. PUMP 175 BBLS OF DIESEL DOWN THE INNER ANNULUS AND U-TUBE FOR FREEZE PROTECT. 04/14/02 FUNCTION TEST SSV. SSV WOULD NOT CLOSE. BAGGED SSV W/HEATER. THAWED OUT. RIH W/3.80" DRIFT TO SSSV NP. SET 4 1/2 HXO BBE SSSV 3 SETS OF PKG. CONTROL OPS AT 2132' SLM SN# BB-453. RIH W/4 1/2 CK. SET LOOKS GOOD, DO CLOSURE TEST ( LEAVE SSSV CLOSED ) RDMO. .. , Legal Welt Name' J-1 lA Common Well Name: J-11A Spud Date' Event Name: WORKOVER Start: 4/15/2002 End: 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ~ i ~§te i ~~ ~ ~0 H~!i~ ~i i~a~k ~NP~ ~h~.Se ~: : i~ ~' riPtion of Operations ..... 4/16/2002 00:00 - 02:00 2.00 MOB P PRE CONTINUE MOVING RIG F/H PAD TO J PAD. 02:00 - 09:00 7.00 MOB P PRE LAY PIT LINER, SET MATS, WELD PAD EYE ON DERRICK BOARD, (ACTION ITEM), PJSM & RAISE DERRICK. RIG UP FLOOR. MOVE RIG OVER WELL, CENTER & LEVEL UP. SET SLOP TANK & RAMPS. RIG ACCEPTED @ 09:00, 04-16-2002. 09:00 - 12:00 3.00 KILL P DECOMP CONDUCT DERRICK INSPECTION, OK. O/A 400 PSI, I/A 200 PSI, TUBING SHOWS NO PRESSURE, (SSSV CLOSED). N/U SECONDARY ANNULUS VALVE. R/U CIRC LINES, HARDLINE TO ADJACENT WELL & R/U CAMCO TO CONTROL LINE TO OPEN SSSV. 12:00 - 15:00 3.00 KILL P DECOMP R/U TEST/DISPLACEMENT MANIFOLD, TEST HARDLINE & DISPLACEMENT MANIFOLD / 2000 PSI, OK. 15:00- 17:30 2.50 KILL P DECOMP PRESSURE UP CONTROL LINE, OPEN SSSV. PUMP 55 BBLS SEAWATER DOWN I/A TAKING DIESEL RETURNS UP TUBING & TO FLOWLINE. PUMP 250 BBLS SEAWATER DOWN TUBING, DISPLACING ALL DIESEL FROM WELLBORE. MONITOR WELL & RID LINES. 17:30- 18:00 0.50 KILL P DECOMP BLEED PRESSURE OFF CONTROL LINE & PUMP DOWN I/A, 500 PSI, TEST SSSV W/TUBING OPEN, CHARTED, OK. 18:00 - 19:00 1.00 BOPSUR P DECOMP ATTEMPT TO SET TEST PLUG, UNABLE TO GET THROUGH SURFACE SAFETY VALVE, SUSPEND FURTHER EFFORT. 19:00- 21:00 2.00 BOPSUF P DECOMP N/D TREE & ADAPTER FLANGE. INSPECT THREADS ON HANGER, GOOD SHAPE. SUSPECT PROFILE IN HANGER MACHINED IMPROPERLY, REASON FOR INABILITY TO SET BPV. WILL SEND IN FOR FURTHER INSPECTION. 21:00 - 00:00 3.00 BOPSUF; P DECOMP N/U 13 5/8" x 5M BOPE. 4/17/2002 00:00 - 03:00 3.00 BOPSUF P DECOMP PJSM. N/U RISER, FLOWLINE & P/U KELLY. 03:00- 05:30 2.50 BOPSUF; :~ DECOMP CONDUCT INITIAL TEST ON BOP COMPONENTS. WITNESSED BY LOU GRIMALDI. ANNULAR PREVENTOR FAILED. UNABLE TO TEST LOWER PIPE RAMS & BLIND RAMS AT THIS TIME. 05:30 - 19:00 13.50 BOPSUR N RREP DECOMP REPLACE ELEMENT IN ANNULAR PREVENTOR. TROUBLE REMOVING CAP ON PREVENTOR. 19:00 - 20:00 1.00 BOPSUR P DECOMP N/U FLOW NIPPLE & FLOW LINE. 20:00 - 21:00 1.00 BOPSUF P DECOMP PRESSURE TEST ANNULAR, 250 / 2500 PSI, 5 MIN EACH, OK. TEST FLOOR VALVES, 250 / 3500 PSI, 5 MIN EACH, OK. TESTS CHARTED. 21:00 - 00:00 3.00 PULL P DECOMP PJSM. PULL HANGER TO FLOOR. 127K UP WT. PULLED INITIALLY TO 157K, TUBING CAME FREE. CIRCULATE ONE COMPLETE HOLE VOLUME @ 8 BPM / 2150 PSI. LID TUBING HANGER & CIRC HEAD. OBSERVE WELL. 4/18/2002 00:00 - 00:30 0.50 PULL :' DECOMP SLIGHT FLOW UP TUBING. MIX & PUMP DRY JOB. 00:30- 03:30 3.00 PULL P DECOMP R/U SLICKLINE. RIH & RETRIEVE HX© @ 2160', SHEARED OFF 1st RUN, (PINNED LIGHT), SUCCESSFUL ON 2nd RUN. RID WIRELINE. 03:30 - 04:00 0.50 PULL P DECOMP PJSM. POOH & LID (4) ,ITS 4 1/2" TBG & C-LINE. CUT & SECURE C-LINE TO TUBING. 04:00 -06:30 2.50 PULL P DECOMP M/U RTTS & RIH ON (2) JTS DP, SET @ 57' & STING OUT. POOH W/DP. CLOSE BLIND RAMS. O/A BLED DOWN TO 100 PSI & FLUID PACKED. TEST PACKOFF & 9 5/8" Printed: 5/6/2002 11:43:57 AM ............ Legal Well Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4115~2002 End: 5~4~2002 Contractor Name: DOYON Rig Release: 5~4~2002 Rig Name: DOYON 16 Rig Number: .::-:!:::~.:.~--:D, ate?.--: 'From-i:~:~:TO:' ::Hours~::~ :- Task'?:: ::COde ::-':'NPT .' Pha:se -:: :~-:-. Description of Operations 4/18/2002 04:00 - 06:30 2.50 PULL P DECOMP CASING ABOVE RTTS @ 3000 PSi / 30 MINUTES, GOOD TEST, CHARTED. BLEED PRESSURE. 06:30 - 09:00 2.50 BOPSUF; P DECOMP SET TEST PLUG, TEST BLIND RAMS & LOWER PIPE RAMS, 250 / 3000 PSI, OK. PERFORM DRAWDOWN TEST ON ACCUMULATOR, OK. AOGCC STATE REP LOU GRIMALDI WITNESSED. PULL TEST PLUG, SET WEAR BUSHING. 09:00- 10:00 1.00 PULL P DECOMP RETRIEVE & LID RTTS. 10:00 - 12:00 2.00 PULL P DECOMP CIRCULATE BTMS UP, NO GAS, PUMP DRY JOB. 12:00- 12:30 0.50 PULL P DECOMP SERVICE RIG. 12:30- 13:30 1.00 PULL N RREP DECOMP REPAIR POWER TONGS. 13:30 - 00:00 t0.50 PULL P DECOMP POOH & LID 4 1/2" COMPLETION STRING & C-LINES. RID SPOOLING UNIT & CONTINUE LAYING DOWN TUBING. 4/19/2002 00:00 - 03:00 3.00 PULL P DECOMP PJSM. CONTINUE TO POOH & LID TUBING. 251 JTS TOTAL, 5 GLMS, PUP JTS, X-NIPPLE & (4') OF CUT JT BELOW X-NIPPLE. CHEMICAL CUT LOOKS GOOD, NO APPARENT INDICATION OF INCOMPLETE CUT. INITIALLY BELIEVED TO BE INCOMPLETE CUT, A JET CUT WAS SUBSEQUENTLY MADE (3') BELOW CHEM CUT, SO WILL HAVE TO FISH PRIOR TO MILLING. 03:00- 04:00 1.00 PULL P DECOMP SLIP & CUT 57.5' OF DRILLING LINE. 04:00 - 06:00 2.00 PULL P DECOMP M/U FISHING BHA & P/U DCs. 06:00- 11:30 5.50 PULL P DECOMP P/U 3 1/2" DP & RIH. 11:30 - 12:00 0.50 PULL P DECOMP SERVICE RIG. 12:00 - t6:30 4.50 PULL P DECOMP CONTINUE TO P/U 3 112" DP & RIH W/FISHING BHA. 16:30- 17:30 1.00 PULL P DECOMP P/U KELLY, TORQUE CONNECTIONS & PT KELLY VALVES @ 250~3500 PSI, OK. BLOW DOWN & STD BACK KELLY. 17:30- 20:00 2.50 PULL P DECOMP CONTINUE IN HOLE, 321 JTS DP TOTAL. P/U KELLY, 165K UP WT, 124K DOWN, 140K ROTATING WEIGHT. 160 AMPS TORQUE @ 30 RPM. 20:00- 21:00 1.00 PULL P DECOMP ROTATE SLOWLY DOWN, TAG FISH 37' IN ON KELLY, RELEASE TORQUE, SET DOWN 10K & ENGAGE FISH. OVERPULL TO 200K, (35K OVER), SET OF JARS (3) TIMES W/OUT FREEING FISH. JAR (5) TIMES @ 225K & 5 TIMES @ 250K, FREED UP. PULL TO 10,503'. 21:00- 22:00 1.00 PULL P DECOMP CBU @ 7.8 BPM, 2180 PSI. MONITOR WELL, STABLE. 22:00 - 00:00 2.00 PULL P DECOMP POOH W/3 1/2" DP & FISHING BHA. 4/20/2002 00:00 - 02:30 2.50 PULL P DECOMP PJSM. POOH, LID OVERSHOT & FISH. (2.3' RECOVERED). CUT WAS 50% INCOMPLETE. 02:30 - 03:00 0.50 PULL P DECOMP PJSM. M/U PACKER MILL & BHA. 03:00 - 07:00 4.00 PULL P DECOMP RIH W/PACKER MILLING BHA. 07:00 - 12:30 5.50 PULL P DECOMP P/U KELLY. 158K UP WT, 123K DOWN, 139K ROTATING WT. 60 RPM, 110-190 AMPS TORQUE, (LOW GEAR), TAG TUBING STUB @ 10,539'. MILL STUB & PACKER TO 10,544', PUMP 20 BBL HI VIS SWEEP & MILL TO 10,546'. PUMP 2nd 20 BBL HI VIS SWEEP. 12:30- 14:00 1.50 PULL P DECOMP CIRCULATE SWEEP OUT, NO SIGN OF PACKER RUBBER. 14:00 - 17:30 3.50 PULL P DECOMP POOH W/PACKER MILLING ASSEMBLY. 17:30 - 18:30 1.00 PULL ~ DECOMP LID MILL & PICK UP SPEAR & ACCELERATORS. 18:30 - 22:00 3.50 PULL ~ DECOMP RIH W/FISHING ASSEMBLY, 321 JTS DP. KELLY UP. 180 K UP WT, 112K DOWN, 650 PSI @ 3.5 BPM. 22:00- 00:00 2.00 PULL P DECOMP TAG FISH & ENGAGE @ 10,546'. JAR A FEW TIMES @ 215K, NOT FREE, WORK UP TO 270K JAR LICKS, (90K Printed: 5t6t2002 11:43:57 AM i? ::--,::i i ii'.i O:peratio_fiSi summa_ : Report: . , Legal Well Name' J-J 1A Common Well Name: J-11A Spud Date' Event Name: WORKOVER Start: 4115/2002 End: 514/2002 Contractor Name: DOYON Rig Release' 5/4/2002 Rig Name: DOYON 16 Rig Number: Date :': F~0m:,To HoU¢s- Task COde NP~ -Ph~ase · ' ~.' .. Description of Operations 4/20/2002 22:00 - 00:00 2.00 PULL P DECOMP OVER UP WT). NO PROGRESS. 4/21/2002 00:00 - 01:30 1.50 PULL P DECOMP CONTINUE TO JAR ON PACKER, JARRING @ 270K, (90K OVER UP WT). NO SIGN OF MOVEMENT, CALL NO JOY. PUMPING @ 3.5 BPM / 650 PSI THROUGHOUT JARRING OPERATION. 01:30- 02:30 1.00 PULL P DECOMP PJSM, RELEASE SPEAR, PUMP DRY ,lOB. 02:30 - 06:00 3.50 PULL P DECOMP POOH F1 PACKER MILLING BHA. 06:00 - 07:00 1.00 PULL P DECOMP CIO BHA. LID FISHING BHA, P/U MILLING BHA. 07:00 - 10:30 3.50 PULL P DECOMP RIH W/3 1/2" DP, 107 STDS. KELLY UP. 180K UP WT, 113K DOWN WT, 138K ROTATING WEIGHT. 10:30- 13:30 3.00 PULL P DECOMP TAG UP ON FISH @ 10,546', MILL F/10,546'-10, 551', THRU PACKER & MILLED APPROXIMATELY 3' OF 4 1/2" PUP JT BELOW PACKER. 13:30- 15:00 1.50 PULL P DECOMP REVERSE CIRCULATE (4) DP VOLUMES @ 5BPM, 1160 PSI. 15:00- 17:00 2.00 PULL P DECOMP PUMP 40 BBLS H! VIS SWEEP AROUND. 17:00 - 21:00 4.00 PULL P DECOMP POOH W/MILLING ASSEMBLY 21:00- 21:30 0.50 PULL P DECOMP L/D MILL, CLEAN OUT JUNK SUBS. RECOVERED 7-8 GAL OF METAL. 21:30 - 22:30 1.00 PULL P DECOMP SERVICE RIG, SLIP & CUT 60' OF DRILLING LINE. 22:30- 23:30 1.00 PULL P DECOMP M/U FISHING BHA, (OVERSHOT). 23:30 - 00:00 0.50 PULL P DECOMP RIH W/FISHING BHA ON 3 1/2" DP. 4/22/2002 00:00 - 02:30 2.50 PULL P DECOMP RIH W/OVERSHOT ON 3 1/2" DP. 02:30 - 05:00 2.50 PULL P DECOMP KELLY UP ON JT #321. 183K UP WT, 113K DOWN, 138K ROTATING WT. 3.5 BPM @ 410 PSI SPP PRIOR TO ENGAGING FISH. TAG FISH @ 10,551', ROATE OVER & ENGAGE. PUMP PRESSURE INCREASE W/INDICATION OF A FLOW RESTRICTION. JAR FOR (1) HOUR @ 275K, (90K OVER UP WT). NO MOVEMENT. SLACK OFF TO 10-15K OVER ROT WT & ROTATE 12-14 TURNS TO THE RIGHT, KEEPING SURFACE TORQUE BELOW 13,000 FT/LBS. 7100 FT/LBS - FREESPIN TORQUE. WORK TURNS DOWN, ATTEMPTING TO RELEASE FROM 'KBH' ANCHOR. LOSS OF PUMP PRESSURE & OVERPULL, MAY HAVE RELEASED ANCHOR. 05:00 - 07:00 2.00 PULL P DECOMP P/U TO 10,515', PUMP HINIS SWEEP AROUND, 6 BPM / 1200 PSI. 07:00 - 08:30 1.50 PULL P DECOMP RUN BACK IN HOLE TO VERIFY FISH ON OR NOT. RE-ENGAGE FISH, JAR @ 275K, PULL 325K MAX, NO MOVEMENT, RELEASE OVERSHOT. PULL TO 10,515'. 08:30- 10:30 2.00 PULL P DECOMP CBU, PUMP DRY JOB, BLOW DOWN & STAND BACK KELLY. 10:30 - 14:00 3.50 PULL P DECOMP POOH W/FISHING ASSEMBLY. 14:00- 15:30 1.50 PULL :~ DECOMP L/D BHA. CLEAR RIG FLOOR. 15:30 - 20:30 5.00 PULL N DPRB DECOMP PJSM. RIG UP SCHLUMBERGER E-LINE & RIH W/CCL & 3.375" CHEMICAL CUTTER TO 10,54t' E-LINE MEASUREMENT. UNABLE TO GET INTO 4 1/2" TUBING STUB IN 7" CASING. POOH & RID E-LINE. 20:30 - 22:00 1.50 PULL N DPRB DECOMP DISCUSS W/TOWN. OPT TO PICK UP 4 1/2" WORK STRING & OVERSHOT & LATCH TUBING, THEN RUN E-LINE CUTTER. LOAD PIPE SHED W/4 1/2" BUTTRESS TUBING. BAKER MAKING X-OVER FOR OVERSHOT THAT WILL ALLOW CUTTER TO PASS. Printed: 5/6t2002 11:43:57 AM : , ..... Legal Well Name: J-1 lA Common Well Name' J-11A Spud Date: Event Name: WORKOVER Start: 4/1512002 End: 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: 4/22/2002 22:00 - 00:00 2.00 PULL N DPRB DEOOMP W/WAITING ON X-OVER & LOADING PIPE, R/U SLICKLINE TO VERIFY 4 1/2" TUBING CLEAR, (SLICKLINE FEELS THEY CAN GET IN TUBING STUB). RIH W/3.625" OENTRALIZER WI 1' ,SAMPLE BAILER. TAG UP @ 10,557', WORK THERE & POOH. 4/23/2002 00:00 - 06:30 6.50 PULL N DPRB DEOOMP HELD PJSM, RIH w/3.625" SWEDGE ON SLICKLINE, TAGGED UP AT 10,557', (SLM), POOH. R / U LIB AND RIH ON SLICKLINE TO 10,557'. POOH w/TUBING STUB IMPRESSION. R / U 3" BAILER AND RIH ON SLICKLINE, TAGGED UP AT 10,557', GOULD NOT GET DEEPER. POOH. NO RECOVERY IN BAILER. R / D 8LICKLINE. 06:30 - 07:30 1.00 PULL N DPRB DEOOMP HELD PJSM. M I U OVERSHOT w/4-1/2" GRAPPLES. 07:30 - 20:30 13.00 PULL N DPRB DEOOMP RIH w/OVERSHOT ON 4-1/2", 12.6 #, BTO TUBING. PIOKED UP AND DRIFTED 260 JT8 OF 4-1/2" TUBING WORK ,STRING TO 10,507'. WASHED DOWN AND TAGGED TOP OF FISH @ 10,561'. BROKE CIRCULATION, PUMP RATE 3 BPM, 8PP 350 PSI. WASHED DOWN TO 10,562'. PUMP PRESSURE INCREASED TO 500 PSI, INDICATING OVERSHOT ON FISH. 20:30 - 00:00 3.50 PULL N DPRB DECOMP HELD PJSM. R / U SLICKLINE & RIH WITH 3.5" OD BAILER. 4/24/2002 00:00 - 07:00 7.00 PULL N DPRB DECOMP RIH w/3-1/2" BAILER ON SLICKLINE, TAGGED UP AT 10,551', COULD NOT WORK THROUGH 10,551'. POOH wi 3-1/2" BAILER. R / U 1-3/4" BAILER AND RtH ON SLICKLINE. TAGGED UP AT 10,551', WORKED BAILER THROUGH TO 10,670'. POOH w/1-3/4" BAILER. BAILER 3/4 FULL OF FINE METAL CUTTINGS AND PARAFFIN. R / U 3-1/2" BAILER AND RIH ON SLICKLINE TO 10,670'. POOH w/3-1/2" BAILER. R / D HOWCO SLICKLINE. 07:00 - 07:30 0.50 PULL N DPRB DECOMP SERVICED RIG. 07:30 - 11:00 3.50 PULL N DPRB DECOMP HELD PJSM. R / U SCHLUMBERGER EQUIPMENT AND STRINGSHOT w/COLLAR LOCATOR. 11:00 - 13:00 2.00 PULL N DPRB DECOMP RIH w/SCHLUMBERGER STRINGSHOT TO t0,670'. RAN CORRELATION LOG AND GOT ON DEPTH. FIRED STRINGSHOT. 13:00 - 13:30 0.50 PULL N DPRB DECOMP POOH w/SCHLUMBERGER STRINGSHOT. BOTTOM HALF OF STRINGSHOT DID NOT FIRE. 13:30 - 14:30 1.00 PULL N DPRB DECOMP HELD PJSM. R / U CHEMICAL CUTTER TO E-LINE. 14:30 - 19:00 4.50 PULL N DPRB DECOMP RIH w/3-1/8" CHEMICAL CUTTER ON E-LINE TO 10,670'. PULLED CORRELATION AND GOT ON DEPTH. LATCHED UP ELEVATORS TO TUBING AND ENGAGED FISH w/ OVERSHOT. PULLED UP ON FISH w/25,000# OVERPULL, FIRED CHEMICAL CUTTER, LOST OVERPULL. SPOOLED UP E-LINE 500' AS PRECAUTION. PULLED UP ON TUBING 10' TO CONFIRM FISH FREE. POOH w/E-LINE. R / D SCHLUMBERGER. 19:00 - 21:00 2.00 PULL N DPRB DECOMP ATTEMPTED TO CIRCULATE, TUBING PLUGGED. P ! U 35'. ESTABLISHED CIRCULATION. WASHED BACK DOWN TO TOP OF FISH @ 10,645'. PUMPED AND CIRCULATED HIGH VIS, PUMP RATE 8 BPM, SPP 980 PSI. FLOW CHECKED WELL, WELL STATIC. PUMPED SLUG. 21:00- 00:00 3.00 PULL N DPRB DECOMP HELD PJSM. POOH L / D 4 1/2" WORK STRING. 4/25/2002 00:00-01:30 1.50 PULL N DPRB DECOMP INCORREP~~OL, E,,F.I~LL DUE TO SLUG PUMPED. Printed: 5/6t2002 11:43:57 AM . BP E×PLORATiON '' . Page5of 2 :. _, i i -rati°ns summa : RePort '. ' Legal Well Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4/15~2002 End: 5~4~2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ..:..':Date~.i"~'~'~:~':'i:From'~:~To-':HOu~s'~.. Task?'Oode~'iNPT--'i.'~ .PhaSe. "' ". ' . Description of Operations 4/25/2002 00:00 - 01:30 1.50 PULL N DPRB DECQMP ~WELL, WELL STATIC. 01:30 - 07:30 6.00 PULL N DPRB DECOMP POOH, L / D 4-1/2" BTC WORK STRING. 07:30 - 08:30 1.00 PULL P DECOMP BROKE OUT AND L / D FISH. RECOVERED 6' MILLED PUP JT, X NIPPLE, PUP JT, GLM, 3 PUP JTS, BLAST JT, PUP .IT, CHEM CUT JT. TOTAL RECOVERY 95.47'. 08:30 - 11:00 2.50 BOPSUF P DECQMP HELD PJSM. M / U PULLING TOOL, PULLED WEAR BUSHING. M / U TEST PLUG AND JT. TESTED BOPE. TESTED UPPER AND LOWER PIPE RAMS, BLIND RAMS, ANNULAR PREVENTER, VALVES, HCR, KILL LINE, CHOKE LINE, KELLY AND STANDPIPE MANIFOLD. CHOKE MANIFOLD AND LINES WERE TESTED WHILE POOH. TEST PRESSURES 3,500 PSI HIGH / 250 PSI LOW. ALL TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. JOHN SPAULDING w/ AOGCC WAIVED WITNESSING TEST. 11:00 - 11:30 0.50 BOPSUR P DECOMP M / U RUNNING TOOL, RAN AND SET WEAR BUSHING. 11:30 - 12:00 0.50 PULL P DECOMP R / U TO P / U AND RUN BHA. 12:00 - 12:30 0.50 PULL P DECOMP HELD PJSM. M / U FISHING BHA, OVERSHOT w/CUT LIP GUIDE & 4-1/2" GRAPPLE - TOP SUB - BUMPER JARS - OIL JARS - 9 x 4 3/4" DC's. TOTAL LENGTH 301.02' 12:30 - 16:00 3.50 PULL P DECOMP RAN wi FISHING BHA ON 3-1/2" DP TO 10,633'. 16:00 - 17:00 1.00 PULL P DECOMP M / U KELLY, BROKE CIRCULATION, PUMP RATE 3 BPM, SPP 340 PSI. CHECKED PARAMETERS, STRING WEIGHT UP 155,000#, STRING WEIGHT DOWN 130,000#, STRING WEIGHT ROTATING 140,000#, TORQUE 6,100 ft /lbs. LOWERED DRILL STRING OVER FISH, OBSERVED PUMP PRESSURE INCREASE TO 980 PSI. SHUT DOWN PUMPS AND ENGAGED FISH. PULLED UP TO 35,000# OVERPULL. ROTATED DRILL STRING 24 TURNS TO THE RIGHT, LOST TORQUE AND OVERPULL. PULLED UP 15' TO ENSURE FISH FREE. LOWERED STRING AND FISH AND TAGGED UP 1' HIGHER. 17:00- 19:00 2.00 PULL P DECOMP PUMPED AND CIRCULATED AROUND 20 BBL HI-VIS SWEEP, PUMP RATE 7.5 BPM, SPP 1,900 PSI. FLOW CHECK. PUMP SLUG. BLOW DOWN KELLY. 19:00 - 22:00 3.00 PULL P DECOMP PJSM. POOH S / B DP. L / D OVERSHOT ASSEMBLY & FISH (K-ANCHOR, X/O, 3' STUB 4 1/2" TUBING PUP JT, TOTAL LENGTH - 6.90'.). 22:00 - 22:30 0.50 PULL P DECOMP PJSM. R / U 2 7/8" HANDLING TOOLS. 22:30 - 23:30 1.00 PULL P DECOMP P I U BHA #8: 3.56" JUNK MILL, 3 JTS 2 7/8" PAC DP, X/O, 3 - 4.75" BOOT BASKETS, X/O, X/O, 7" CASING SCRAPER, X/O, BUMPER SUB, OIL JARS, 9 -4.75" DC's. TOTAL LENGTH 411.90'. 23:30 - 00:00 0.50 PULL ~ DECOMP RIG SERVICE. 4/26/2002 00:00 - 04:00 4.00 CLEAN ~ DECOMP HELD PJSM. RIH w/CLEAN OUT BHA ON 3-1/2" DP TO 10,617'. 04:00 - 06:30 2.50 CLEAN P DECOMP M / U KELLY, ESTABLISHED PARAMETERS, PUMP RATE 6.75 BPM, SPP 1,640 PSi, RPM 50, TORQUE OFF BOTTOM 5,500 ft / lbs, STRING WEIGHT UP 153,000#, STRING WEIGHT DOWN 125,000#, STRING WEIGHT ROTATING 138,000#. WASHED AND MILLED FROM 10,672' - 10,738', WOM 1,000#- 3,000#, RPM 50, TORQUE ON BOTTOM 7,100 ft / lbs, PUMP RATE 7 BPM, SPP 1,700 PSI. WASHED Printed: 5~6~2002 11:43:57 AM ........ Legal Well Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4/15/2002 End: 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ~..:~i .:..~::.:-.-:i..:.':::.::~: .... ::~-~-::...--:.~::.:.: ~i~;- '. ~:~..:~... -~-::.::~-. ~--.: -:":::: ..... -:~;.~ ~:.~:::~ ::,~-:,--:. :.. ::..~.: ~:i~.. --:. '" ' Description of Operations 4/26/2002 04:00 - 06:30 2.50 CLEAN P DECOMP DOWN WITHOUT ROTATING LAST 5' FROM 10,733' - 10738'. TAGGED TOP OF FISHING NECK OF IBP @ 10,738'. 06:30 - 08:30 2.00 CLEAN P DECOMP PUMPED AND CIRCULATED AROUND 40 BBL HI-VIS SWEEP. PUMP RATE 8 BPM, SPP 2,300 PSI. CIRCULATED BACK SLUGGITS FROM TOP OF IBP. SHUT DOWN PUMPS, FLOW CHECKED WELL, WELL STATIC. BLEW DOWN AND SET BACK KELLY. 08:30 - 12:30 4.00 CLEAN P DECOMP POOH w/3-1/2" DP FROM 10,738' - 411'. 12:30 - 13:30 1.00 CLEAN P DECOMP POOH, BROKE OUT AND L / D BHA. NOTE: LEFT 1.25" SQUARE PIECE OF MILL IN HOLE. 13:30- 14:00 0.50 CLEAN P DECOMP CLEANED AND CLEARED RIG FLOOR. CLEANED OUT BOOT BASKETS. 14:00- 14:30 0.50 CLEAN P DECOMP HELD PJSM. M / U 7" CHAMP PACKER. 14:30 - 18:30 4.00 EVAL P DECOMP RIH w/7" PACKER ON 3-1/2" DP TO 10,600'. 18:30- 20:00 1.50 EVAL P DECOMP SET CHAMP PACKER @ 10,600'. TESTED CASING TO 3,000 PSI f/30 MIN. WEEPED UP DP. LOST 240 PS! IN 30 MIN. PULLED 1 JT DP. SET PACKER. TESTED CASING TO 3,000 PSI. 200 PSI PRESSURE LOSS IN 15 MIN. STILL WEEPED UP DP. 20:00 - 22:00 2.00 EVAL P DECOMP POOH TO 9,633'. TESTED CASING TO 3,000 PSI f/30 MINUTES. DP WEEPED f/15 MIN THEN STOPPED. GOOD TEST f/30 MINUTES. 22:00 - 23:30 1.50 EVAL P DECOMP RIH TO 10,584'. SET PACKER. ATTEMPTED TEST. DP HAD SUBSTANTIAL WEEPING (WORSE THAN PRIOR). t OPENED BY-PASS AND CIRC f/5 MIN. CLOSED BY-PASS. PACKER 2' DEEPER w/SAME WEIGHT. UNSET PACKER, SUBSTANTIAL DRAG. PACKER APPEARS TO HAVE MALFUNCTIONED. PREPARE TQ POOH. 23:30 - 00:00 0.50 EVAL P DECOMP SLIPPED AND CUT 60' OF DRILL LINE. 4/27/2002 00:00 - 00:30 0.50 EVAL P DECOMP HELD PJSM. FINISHED CUTTING AND SLIPPING DRILLING LINE. 00:30 - 04:30 4.00 EVAL N DFAL DECOMP POOH w/PACKER FROM 10,535', 25,000# - 30,000# DRAG. PACKER HUNG UP AT 9,464'. WORKED PACKER FREE AND POOH. 04:30 - 05:00 0.50 EVAL N DFAL DECOMP BROKE OUT AND L / D PACKER. PACKER MISSING BOTTOM RUBBER. 05:00 - 05:30 0.50 EVAL N DFAL DECOMP M / U NEW 7" RTTS PACKER. 05:30 - 10:30 5.00 EVAL N DFAL DECOMP RIH w/RTTS PACKER ON 3-1/2" DP TO 10,580'. 10:30 - 14:30 4.00 EVAL N DFAL DECOMP CHECKED PARAMETERS, STRING WEIGHT UP 140,000#, STRING WEIGHT DOWN 115,000#. SET PACKER AT 10,580', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PS! IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. POOH TO 10,530'. SET PACKER AT 10,530', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. POOH TO 10,485'. SET PACKER AT 10,485', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. POOH TO 10,010'. SET PACKER Printed: 5/6t2002 11:43:57 AM i. · .. ::-oper ti6ns sum.ma Report. Legal Welt Name' J- 1 lA Common Well Name: J-11A Spud Date' Event Name: WORKOVER Start: 4115/2002 End' 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ' ~ate' .F~om.~o .H0~'~S .~ask C~de NPT ph%e Description of Operations 4/27/2002 t0:30 - 14:30 4.00 EVAL N DFAL DECOMP AT 10,010', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. POOH TO 9,633'. 14:30- 15:30 1.00 EVAL N RREP DECOMP RIG REPAIR, REPAIRED MUD LINE VALVE. 15'30 - 16:30 1.00 EVAL N DFAL DECOMP SET PACKER AT 9,633', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN t5 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. POOH TO 9,000'. SET PACKER AT 9,000', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. 16:30 - 20:00 3.50 EVAL N DFAL DECOMP POOH w/3-1/2" DP. ONE PACKER RUBBER TORN. 20:00 - 21'00 1.00 EVAL N DFAL DECOMP M / U BHA #11' JUNK MILL, 7" CSG SCRAPER, 3 JUNK BASKETS, BIT SUB, 3 1/2" DP (1717'), DBL PIN SUB, 9 5/8" CSG SCRAPER, 2 JUNK BASKETS, BIT SUB. TOTAL LENGTH = 1,753.62'. 21:00 - 00:00 3.00 EVAL N DFAL DECOMP TIH W/DP. 7,666' @ RPT TIME. 4128/2002 00:00 - 01:00 1.00 CLEAN N DFAL DECOMP HELD PJSM. RIH w/CLEAN OUT BHA ON 3-1/2" DP TO 10,590'. 01'00- 03:00 2.00 CLEAN N DFAL DECOMP M / U KELLY, BROKE CIRCULATION. PUMPED AND CIRCULATED AROUND 40 BBL HI-VIS SWEEP. PUMP RATE 8 BPM, SPP 2,250 PSI. WORKED 7" SCRAPER FROM 10,625' TO 10,530'. RECIPROCATED AND SLOWLY ROTATED DRILL STRING. 03:00 - 03:30 0.50 CLEAN N DFAL DECOMP BLEW DOWN AND SET BACK KELLY. 03:30 - 06:30 3.00 CLEAN N DFAL DECOMP POOH w/3-1/2" DP. 06:30 - 08:00 1.50 CLEAN N DFAL DECOMP POOH, BROKE OUT AND L / D CLEAN OUT BHA. CLEANED OUT JUNK BASKETS. RECOVERED SCALE IN 9-5/8" BASKETS, NO JUNK RECOVERED IN 7" BASKETS. 08:00 - 08:30 0.50 EVAL N DFAL DECOMP HELD PJSM. M / U NEW 7" RTTS PACKER. 08:30 - 12:30 4.00 EVAL N DFAL DECOMP RIH w/RTTS PACKER ON 3-1/2" DP TO 9,136'. CHECKED MAKE UP ON ALL CONNECTIONS. 12:30- 14:30 2.00 EvAL N DFAL DECOMP CHECKED PARAMETERS, STRING WEIGHT UP 120,000#, STRING WEIGHT DOWN 107,000#. SET PACKER AT 9,125', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 150 PSI IN 15 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. RIH TO 9,600'. SET PACKER AT 9,600', CLOSED PIPE RAMS AND TESTED CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE, LOST 350 PS! IN 30 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. 14:30 - 17:30 3.00 EVAL N DFAL DECOMP POOH w/3-1/2" DP & RTTS. PACKER RUBBER TORN. 17:30 - 00:00 6.50 EVAL N DFAL DECOMP PJSM. R / U SLICK LINE. RIH W/8.50" GAUGE RING AND JUNK BASKET. TAGGED UP @ 2,417'- 2,419'. WORKED THRU WITH SLIGHT DRAG. CONTINUED RIH TO TOP OF 7" LINER @ 8,892'. POOH. TIH W/6.1" GAUGE RING AND JUNK BASKET. TAG TOP OF 7" LINER. CONTINUE TIH TO 10,600'. HOLE SLICK. POOH. 4/29/2002 00:00 - 01:30 1.50 EVAL N DPRB DECOMP POOH w/GAUGE RING ON SLICKLINE. R / D SLICKLINE. ri e · 5/ I :43:57 AM !:!:-: ;i.: :!i_ !!_ operations Su. ma RePort Legal Well Name: J-1 lA Common Well Name: J-1 IA Spud Date: Event Name: WORKOVER Start: 4/15/2002 End: 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: --.::-:;Date -:~- -~ .~From-..~' TO:.: HOurs:..:. :Task-;-.~:' Clode::~:-',N'PT..~.phase:..' · Description of Operations .... 4/29/2002 01:30 - 02:00 0.50 CLEAN N DPRB DECOMP HELD PJSM. M / U BI-IA #12: 6-1/8" POLISH MILL - 3 JTS - 3 1/2" DP (95') - XO - XO - 8-1/2" POLISH MILL - XO --XO, TOTAL LENGTH 110.27'. 02:00 - 03:00 1.00 CLEAN N DPRB DECOMP RIH w/POLISH MILL ASSEMBLY ON 3-1/2" DP TO 2,400'. 03:00-03:30 0.50 CLEAN N DPRB DECOMP M/U KELLY, BROKE CIRCULATION, PUMP RATE 7 BPM, SPP 1,000 PSI. WASHED AND REAMED POLISH MILL FROM 2,385'- 2,430', f/15 MINUTES. SHUT DOWN PUMPS, BLEW DOWN AND SET BACK KELLY. 03:30- 05:30 2.00 CLEAN N DPRB DECOMP RIH w/MILL ASSEMBLY ON 3-1/2" DP TO 8,884'. 05:30-07:00 1.50 CLEAN N DPRB DECOMP M/U KELLY, BROKE CIRCULATION, PUMP RATE 7 BPM, SPP 1,140 PSI. PARAMETERS - STRING WEIGHT UP 126,000#, STRING WEIGHT DOWN 113,000#, STRING WEIGHT ROTATING 117,000#. WASHED AND REAMED POLISH MILL FROM 8,884'- 8,993'. 07:00- 09:00 2.00 CLEAN N DPRB DECOMP PUMPED AND CIRCULATED AROUND 20 BBL HI-VIS SWEEP. PUMP RATE 7 BPM, SPP 1,150 PSI. 09:00- 11:30 2.50 CLEAN N DPRB DECOMP POOH w/3-1/2" DP. 11:30 - 12:00 0.50 CLEAN N DPRB DECOMP POOH, BROKE OUT AND L / D BHA. 12:00 - 13:00 1.00 EVAL N DPRB DECOMP HELD PJSM. R / U HOWCO SLICKLINE TO RUN PDS MIT (CASING INSPECTION) LOG. 13:00 - 17:00 4.00 EVAL N DPRB DECOMP RIH w/PDS MIT LOG ON SLlCKLINE. LOGGED OUT FROM 9,650' TO 7,880'. 17:00- 18:00 1.00 EVAL N DPRB DECOMP DOWNLOAD AND INTERPRET PDS MIT LOG DATA. 18:00 - 18:30 0.50 EVAL N DPRB DECOMP R / D SLICKLINE. 18:30 - 19:00 0.50 EVAL N DPRB DECOMP M / U 7" RTTS. 19:00 - 23:00 4.00 EVAL N DPRB DECOMP RIH SLOWLY w/RTTS ON 3 1/2" DP. RAN THROUGH LINER TOP @ 8,891' EXTREMELY SLOW TO 8,963'. NO DRAG. 23:00 - 23:30 0.50 EVAL N DPRB DECOMP SET RTTS @ 8,963'. TESTED CASING TO 3,000 PSI. FLUID WEEPING UP DP, LOST 50 PSI/5 MIN. PULLED UP HOLE ONE JT TO 8,940'. SET RTTS. TESTED CASING TO 3,000 PSI. FLUID WEEPING UP DP, LOST 50 PSI/5 MIN. UNSET RTT$. 23:30 - 00:00 0.50 EVAL N DPRB DECOMP POOH. 4/30/2002 00:00 - 03:00 3.00 EVAL N DPRB DECOMP HELD PJSM. POOH w/3-1/2" DP. 03:00 - 03:30 0.50 EVAL N DPRB DECOMP BROKE OUT AND L I D 7" RTTS PACKER. 03:30 - 04:00 0.50 EVAL N DPRB DECOMP M / U 9-5/8" RTTS. 04:00 - 04:30 0.50 EVAL N DPRB DECOMP RIH w/RTTS ON 3-1/2" DP TO 2,304'. 04:30 - 05:00 0.50 EVAL N DPRB DECOMP SET PACKER AT 2,304', CLOSED PIPE RAMS, ATTEMPTED TO TEST CASING TO 3,000 PSI. LOST 125 PSI IN 30 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. 05:00- 05:30 0.50 EVAL N DPRB DECOMP RIH wi RTTS TO 2,483'. 05:30- 06:00 0.50 EVAL N DPRB DECOMP SET PACKER AT 2,483', CLOSED PIPE RAMS. ATTEMPTED TO TEST CASING TO 3,000 PSI. LOST 125 PSI IN 30 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. 06:00 - 07:00 1.00 EVAL N DPRB DECOMP RIH w/RTTS TO 4,583'. 07:00 - 08:00 1.00 EVAL N DPRB DECOMP SET PACKER AT 4,583', CLOSED PIPE RAMS. ATTEMPTED TO TEST CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE. LOST 50 PSI EVERY 5 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. Printed: 5t612002 11:43:57 AM i' i i 'i:ii i'-! !'i ilPe" r iti nsi'.': 'Siiu! m'm-a RePort , Legal Well Name' J-11A Common Well Name: J-1 lA Spud Date: Event Name: WORKOVER Start: 4/15/2002 End: 5/4t2002 Contractor Name: DOYON Rig Release' 5~4/2002 Rig Name: DOYON 16 Rig Number: ". Date' :i'~.~:~om"~!~'TO'''Hours' Task" C6d.' .NpT. ' Phase ' ' ... Description of Operations 4/30/2002 08:00- 09:00 1.00 EVAL N DPRB DECOMP RIH w/RTTS TO 6,678'. 09:00 - 10:30 1.50 EVAL N DPRB DECOMP SET PACKER AT 6,678', CLOSED PIPE RAMS. ATTEMPTED TO TEST CASING TO 3,000 PSI. FLUID WEEPING OUT OF DRILL PIPE. LOST 50 PSI EVERY 5 MINUTES. BLED OFF PRESSURE, OPENED PIPE RAMS AND RELEASED PACKER. 10:30 - 11:00 0.50 EVAL N DPRB DECOMP POOH w/RTTS TO 6,590'. 11:00- 12:00 1.00 EVAL N DPRB DECOMP HELD PJSM. SLIPPED AND CUT DRILLING LINE. 12:00 - 14:00 2.00 EVAL N DPRB DECOMP HELD PJSM. POOH w/3-1/2" DP. 14:00 - 14:30 0.50 EVAL N DPRB DECOMP BROKE OUT AND L / D 9-5/8" RTTS PACKER. RUBBERS SCARRED UP. 14:30 - 15:00 0.50 EVAL N DPRB DECOMP HELD PJSM. M / U 7" RBP. TOTAL LENGTH = 7.45' 15:00 - 18:00 3.00 EVAL N DPRB DECOMP RIH w/7" RBP ON 3-1/2" DP TO 5,251'. RAN IN HOLE SLOW DUE TO VERY HIGH WINDS. 18:00 - 00:00 6.00 EVAL N DPRB DECOMP SHUT DOWN @ 5,251' DUE TO HIGH WINDS. BLOCKS CATCHING ON GIRDERS AND DERRICK MAN CANNOT CLIMB TO MONKEY BOARD. PHASE I! CONDITIONS ON SPINE ROAD AND PHASE Iii ALL OTHER AREAS. 5/1/2002 00:00 - 02:30 2.50 EVAL N DPRB DECOMP WAIT ON WEATHER. VERY HIGH WINDS. PHASE 2 . CONDITION ON SPINE RD, PHASE 3 ON PADS. 02:30 - 06:00 3.50 EVAL N DPRB DECOMP CONTINUED TO RIH SLOWLY w/7" RBP TO 9,633'. 06:00 - 09:00 3.00 EVAL N DPRB DECOMP SET RBP AT 9,633'. ATTEMPTED TO TEST CASING TO 3,000 PSI. TEST HELD FOR 15 MIN AND STARTED LEAKING OFF, LOST 200 PSI IN 15 MIN. RELEASED PRESSURE. ATTEMPTED TO RETEST CASING TO 3,000 PSi, LOST 250 PSI IN 12 MINUTES. RELEASED PRESSURE, OPENED RAMS. LATCHED AND RELEASED RBP. RIH ON STAND TO 9,729'. SET RBP. ATTEMPTED TO TEST CASING TO 3,000 PSI. ISOLATED ENTIRE SURFACE SYSTEM. LOST 700 PSI IN 20 MIN. BLED OFF PRESSURE, OPENED RAMS. 09:00- 10:00 1.00 EVAL N DPRB DECOMP LATCHED AND RELEASED RPB. POOH TO 9,068'. 10:00 - t1:00 1.00 EVAL N DPRB DECOMP SET RBP @ 9,068'. ATTEMPTED TO TEST CASING TO 3,000 PSI. ISOLATED ENTIRE SURFACE SYSTEM. LOST 600 PSI IN 20 MIN. BLED OFF PRESSURE, OPENED RAMS. 11:00 - 15:00 4.00 EVAL N DPRB DECOMP LATCHED AND RELEASED RBP. POOH w/3-1/2" DP SLOWLY, DUE TO HIGH WINDS. RBP MISSING BOTTOM RUBBER. 15:00- 15:30 0.50 EVAL N DPRB DECOMP CHANGED OUT TUBE ON BELL NIPPLE. 15:30 - 19:30 4.00 EVAL N DPRB DECOMP M/U 9 5/8" RBP. RIH TO 8,879'. BROKE CIRCULATION. 19:30 - 21:00 1.50 EVAL N DPRB DECOMP SET RBP @ 8,879'. TEST 9 5/8" CASING TO 3,000 PSI f/30 MINUTESl. OK. 21:00 - 00:00 3.00 EVAL N DPRB DECOMP LATCHED AND RELEASED RPB. POOH W/9 5/8" RBP. 5/2/2002 00:00 - 01:00 1.00 EVAL N DPRB DECOMP POOH w/3-1/2" DP. BROKE OUT AND L / D 9-5/8" RBP. 01:00 - 01:30 0.50 CLEAN N DPRB DECOMP HELD PJSM. M / U CLEAN OUT BHA, JUNK MILL - BIT SUB - 1 JT 2-7/8" PAC DP - XO - STRING MILL- DOUBLE PIN SUB - JUNK BASKET - JUNK BASKET- BIT SUB. TOTAL LENGTH 55.79' 01:30-05:30 4.00 CLEAN N DPRB DECOMP RIH w/ CLEAN OuT BHA ON 3-1/2" DP TO10,600'. 05:30 - 06:30 1.00 CLEAN N DPRB DECOMP M / U KELLY. BROKE CIRCULATION, PUMP RATE 7.5 BPM, SPP 2,300 PSI. STRING WEIGHT UP 151,000#, STRING WEIGHT DOWN 132,000#, STRING WEIGHT ROTATING 143,000#. WASHED AND REAMED FROM 10,600' TO , Printed: 5~6~2002 11:43:57 AM ;: ; i -; BP EXPLORATION . Page 10 of 12 ;; i:i:i. !': ;i' ;::;!.!.i !!'i?!i i; i-i - operlati°nsi;su:m Report ........... Legal Well Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4/15/2002 End: 5/4/2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ::-~ :Date!i:.:.:i.' 'i'::Fromi;':TO:' i-i:.HOU.~s;~-::.;:iTask Code':NPT :.::.i.!PhaSe' '. :i'. - '- Description of Operations 5/2/2002. 05:30- 06:30 1.00 CLEAN N DPRB DECOMP 10,690'. 06:30- 09:00 2.50 CLEAN N DPRB DECOMP PUMPED AND CIRCULATED AROUND 40 BBL HI-VIS SWEEP. PUMP RATE 7.5 BPM, SPP 2,300 PSI. BLEW DOWN AND SET BACK KELLY. 09:00- 17:30 8.50 CLEAN P DECOMP HELD P JaM. POOH, L / D 3-1/2" DP. 17:30 - 18:00 0.50 CLEAN P DECOMP HELD P JaM. P / U KELLY. BROKE CONNECTIONS AND RACKED BACK. 18:00- 19:00 1.00 CLEAN P DECOMP HELD PJSM. SLIPPED AND CUT 115' OF DRILL LINE. 19:00 - 21:30 2.50 CLEAN P DECOMP CONTINUED POOH L / D 3 1/2" DP & BHA. 21:30 - 23:30 2.00 CLEAN P DECOMP HELD P JaM. M / U PULLING TOOL, PULLED WEAR BUSHING. M / U TEST PLUG AND JT. TESTED BOPE. TESTED UPPER AND LOWER PIPE RAMS, BLIND RAMS, ANNULAR PREVENTER, VALVES, HCR, KILL LINE, CHOKE LINE, KELLY AND STANDPIPE MANIFOLD. CHOKE MANIFOLD AND LINES WERE TESTED WHILE POOH. TEST PRESSURES 3,500 PSI HIGH / 250 PSI LOW. ALL TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. TOM MAUNDER w/ AOGCC WAIVED WITNESSING TEST. TESTED KOOMEY UNIT, OK. 23:30 - 00:00 0.50 CLEAN P DECOMP R / U TO RUN 4 1/2" COMPLETION. 5/3/2002 00:00 - 01:00 1.00 RUNCOI~I~ COMP R / U EQUIPMENT AND POWER TONGS TO RUN 4-1/2" COMPLETION. HELD P JaM w/DRILL CREW, BAKER, CASING CREW AND GATORHAWK CREW. 01:00 - 02:00 1.00 RUNCOi~ COMP M / U 4-1/2" SEAL / BLAST ,,IT ASSEMBLY, X NIPPLE ASSEMBLY, GLM ASSEMBLY AND PREMIER PACKER ASSEMBLY. M / U TORQUE 3,650 ft / lbs. 02:00 - 23:30 21.50 RUNCOI~ COMP M / U AND RAN 246 JTS 4-1/2" 12.6# 13Cr VAM-ACE TUBING AND JEWELRY. M / U TORQUE 3,650 ft /lbs. HYDROTESTED EACH CONNECTION TO 4,000 PSt w/ GATORHAWK. 23:30 - 00:00 0.50 RUNCOI~ COMP M / U TIW ON JT 247 TO TAG TOP OF 7"x 4 1/2" SABL PKR P / U JT RIH TAG PKR TOP @ 10,651' TUBING MEASURMENT. 5/4/2002 00:00 - 01:00 1.00 RUNCOI~ ~ COMP HELD P JaM. R / U TIW VALVE AND HOSE TO CIRCULATE. 01:00 - 04:30 3.50 RUNCOI~I~ COMP PUMPED 510 BBLS 140 DEG SEAWATER w/CORROSION INHIBITOR DOWN ANNULUS. PUMP RATE 3 BPM, 400 PSI. 04:30 - 05:30 1.00 RUNCOr~ COMP SPACED OUT 4-1/2" TUBING STRING. M / U SPACE OUT PUP, TUBING HANGER AND LANDING JOINT. 05:30 - 06:00 0.50 RUNCOr~ COMP LANDED TUBING HANGER IN WELLHEAD AND RILDS. DROPPED BALL / ROD ASSEMBLY. COMPLETION EQUIPMENT SET AT THE FOLLOWING DEPTHS: ITEM LENGTH DEPTH SEAL ASMBLY 1.71' 10,652.00' 10,611.93' 20.96' XN NIPPLE ASMBLY 10,590.97' , Printed: 5t6t2002 11:43:57 AM , ,, Legal Well Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4/15t2002 End: 5~4~2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: :~-:?:--: Date ' .-~:: :: -- FrOm ~:~.:T0: HoUrs Task · C.O:de~ NPT.: .i~:PhaSe:~:'' ;'- .~ ~ . ' :Description of Operations 5/4/2002 05:30 - 06:00 0.50 RUNCOI~ COMP 1JT 4.5" 12.6# 13Cr VAM TBG 41.97' 10,549.00' #1 GLM NIPPLE ASMBLY 26.68' 10,522.32' 1JT 4-1/2" 12.6¢ 13Cr VAM TBG 41.96' 10,480.36' 7"x 4-1/2" PREMIER PKR ASMBLY 27.66' 10,452.70' 37JTS 4.5" 12.6# 13Cr VAM TBG 1,552.78' 8,899.92' 4.5" 12.6# 13Cr VAM PUP JT 19.94' 8,879.98' 9-5/8" x 4-1/2" S-3 PKR ASMBLY 25.25' 8,854.73' X NIPPLE ASMBLY 20.94' 8,833.79' 1JT 4.5" 12.6# 13Cr VAM TBG 41.96' 8,791.83' #2 GLM ASMBLY 28.76' 8,763.07' 29JTS 4.5" 12.6# 13Cr VAM TBG 1,214.61' 7,548.46' #3 GLM ASMBLY 29.10' 7,519.36' 40JTS 4.5" 12.6# 13Cr VAM TBG 1,672.51' 5,846.85' #4 GLM ASMBLY 28.39' 5,818.46' 51JTS 4.5" 12.6# 13Cr VAM TBG 2,134.46' 3,684.00' #5 GLM ASMBLY w/RP SHR 28.91' 3,655.09' 34JTS 4.5" 12.6# 13Cr VAM TBG 1,424.79' 2,230.30' X NIPPLE ASMBLY 20.92' 2,209.38' 51JTS 4.5" 12.6# 13Cr VAM TBG 2,131.47' 77.91' 4.5" 12.6# 13Cr VAM PUP JT 9.87' 68.04' 1JT 4.5" 12.6# 13Cr VAM TBG 41.99' 26.05' TUBING HANGER 2.80' 23.20' 06:30 - 08:30 2.00 RUNCOI~ COMP HELD PJSM. R / U CIRCULATING HEAD,TIW AND HOSE. PRESSURED UP ON TUBING TO 2,500 PSI TO SET PACKER. PRESSURE TESTED TUBING TO 4,000 PSI f/30 MINUTES, OK. LEFT 2,000 PSI ON TUBING, PRESSURE TESTED IA TO 3,000 PSI f/30 MINUTES, OK. BLED DQWN TUBING PRESSURE AND SHEARED RP VALVE. BLED DOWN ALL PRESSURES, R / D HOSE, TIW AND CIRCULATING HEAD. BROKE OUT AND L / D LANDING JOINT. Printed: 5t6/2002 11:43:57 AM :i .i i i .- Operati°nssumma 'Rep°rt - . , ...... Legal Welt Name: J-1 lA Common Well Name: J-11A Spud Date: Event Name: WORKOVER Start: 4/15/2002 End: 5/4t2002 Contractor Name: DOYON Rig Release: 5/4/2002 Rig Name: DOYON 16 Rig Number: ~-:.~::."Date~i~'::~:~:~::From':?.To~i.~:: RoU~§ Task: Code N'P¥ Phase .. i Description of Operations 5/4/2002 06:30 - 08:30 2.00 RUNCOI~ COMP SET TWC AND TESTED TO 1,000 PSI, OK. 08:30 - 09:00 0.50 RUNCOr~ COMP CLEARED FLOOR OF ALL TUBING EQUIPMENT. 09:00- 12:00 3.00 BOPSUF; P COMP HELD PJSM. N ! D DOPE. 12:00 - 13:30 1.50 WHSUR P COMP HELD PJSM. N / U ADAPTER FLANGE AND 5M TREE. 13:30 - 14:00 0.50 WHSUR P COMP HELD PJSM. R / U AND TESTED TREE TO 5,000 PSi, OK. 14:00 - 15:00 1.00 WHSUR P COMP HELD PJSM. R / U DSM. PULLED TWC. R / D DSM. 15:00 - 15:30 0.50 WHSUR P COMP HELD PJSM. R / U H B & R. TESTED LINES TO 3,000 PSI, OK. 15:30- 18:00 2.50 WHSUR P COMP PUMPED 140 BBLS DIESEL DOWN IA, PUMP RATE 3 BPM, 600 PSI. U-TUBED DIESEL BETWEEN TUBING & IA. FREEZE PROTECTED IA & TBG TO 2,000'. 18:00- 18:30 0.50 WHSUR P COMP SET BPV. REMOVED 2ND ANNULUS VALVE, INSTALLED TREE CAP & GAUGES. INSTALL BLIND FLANGE ON ANNULUS VALVE. 18:30 - 20:00 1.50 WHSUR P COMP SECURED WELL, BLEW DOWN MUD LINES, PREP FOR MOVE, MOVED OFF WELL & INSPECTED DERRICK. RELEASED RIG @ 20:00 HRS, 05 / 04 / 2002. Printed: 5t6t2002 11:43:57 AM Well: J-1 lA RWO Rig Accept: 04/16/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-20462-01 Rig Release: 05/04/02 Permit: 196-104 Drilling Rig: Doyon 16 POST RIG WORK 05/14/02 INSTALL GENERIC GL DESIGN, PULL BALL & ROD - RHC, A-r'TEMPT PULL IBP. HAVING TROUBLE GETTING INTO THE OLD 4 1/2" TBG SECTION AT 10,683, IBP SET AT 10,743'. 05/15/02 ATTEMPT TO PULL IBP, UNABLE TO GET PAST 10624' SLM. 05/19/02 RUN PUMP BAILER 3.50" X 10' LONG BAIL 6' OF FILL, TAGGED AT 10631' SLM, WORK TO 10647' SLM, IBP SET AT 10743'. 05/21/02 MIRU RIH W/VENTURI BASKET / JARS OAL=21.35'. POOH W/VENTURI FULL OF LCM, BITS OF RUBBER, A THIN PIECE OF METAL, NO CHUNK OF MILL. 05/22/02 RIH W/VENTURI BASKET (3RD RUN)- GOT BACK PIECES OF PKR ELEMENT. RIH W/VENT BSKT (4TH RUN) - PKR RUBBER & METAL PIECES. CUT 75' PIPE, RIH W/VENT BSKT (5TH RUN) - RETRIEVED MORE PKR RUBBER / FINE FILL W/METAL SHAVINGS & 1 PIECE OF IRON APPROX. 1" X 3/4" X 3/8". (POSSIBLY PART OF BROKEN MILL LEFT IN HOLE) RE-RUN VENTURI BASKET. 05/23/02 RIH W/VENTURI BASKET. S/D @ 10740' CTM. SLIGHT OVER PULL OF - 2 - 3 K. UNABLE TO GO ANY DEEPER. POOH. RETRIEVED MORE FILL / PKR RUBBER / SLIP PIECE'S. VENT RUN #9 - TAG TD AT 10738' CTM, RETRIEVED SMALL AMOUNT OF STEEL SHAVINGS. WHILE PRESSURE TESTING FOR FINAL RUN, HAD LEAK IN THE COIL. LEAK WAS SIGNIFICANT - CALLED FOR N2 TRUCK TO BLOW DOWN REEL. RDMO. 05/24/02 PUMPED DOWN IA, TAKING RETURNS FROM TUBING TO TIGER TANK. PUMPED 10 BBLS NEAT MEOH, 25 BBLS DIESEL, 225 BBLS CRUDE. BAIL ABOVE IBP. RETRIEVE METALIC SLUDGE AND METAL CHUNKS 05/25/02 PUMP BAILING SLUDGE AND DEBRIS. 05/26/02 CONTINUE BAILING JUNK OFF IBP. 05/27/02 LIB IMPRESSION OF IBP FN. ATTEMPT TO PULL IBP. 05/28/02 ATTEMPT TO PULL IBP. ABLE TO LATCH W/RS. UNABLE TO LATCH W/EQUALIZING BELL GUIDE. IBP STILL IN HOLE. J-1 lA, POST RIG WORKOVEi Page 2 O5/30/O2 MIRU DS CTU #3. WELL SI ON ARRIVAL, RIH W/3.5" HYD JDC OVERSHOT & JARS. LATCH PLUG AT 10750' CTM - WORK JARS, BREAK FREE. WAIT 1 HOUR FOR BAG TO DEFLATE. JAR UP & DOWN. IBP NOT MOVING UP. ABLE TO WORK DOWN TO .-. 10810' CTM. PULLED BIND & PUMP DOWN COIL. UNABLE TO PUMP DOWNHOLE. HIT 1 UP & 1 DOWN LICK. IBP FREE. POOH. 05/31/02 OOH W/O IBP. INSPECT TOOLS & RIH. S/D AT 11180', 11310', 11398, 11408' & 11410'. UNABLE TO WORK PAST 11410' CTM. UNCERTAIN IF LATCHING IBP - TOOLS PUH FREELY, POOH. RIH W/3.625" GRAPPLE OVERSHOT & U/D JARS. TAG IBP AT 11420'- COULD NOT LATCH, BUT ABLE TO PUSH DOWN HOLE TO 11844' CTM (BELOW PERFS). WELL FREEZE PROTECTED. 06/03/02 SET CATCHER SUB AND WILL BE SETTING FLOW SLEEVE IN GLM# 1. 06/04/02 PULLED DGLV FROM ST# 1 @ 10529' WLM. SET FLOW THROUGH SLEEVE IN ST # 1 AND PULLED C-SUB, RDMO. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Set GImP Pull tubing _ Alter casing _ Repair well _ Other. X Set CIBP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 73 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 647' FNL, 803' FEL, Sec. 09, T11 N, R13E, UM (asp's 643546, 5970706) J-1 lA At top of productive interval 9. Permit number / approval number 296' FSL, 379' FWL, Sec. 04, T11 N, R13E, UM (asp's 639430, 5971573) 196-104 At effective depth 10. APl number 245' FSL, 1722' FWL, Sec. 04, T11 N, R13E, UM (asp's 640774, 5971547) 50-029-20462-01 At total depth 11. Field / Pool 115' FNL, 2991' FWL, Sec. 09, T11 N, R13E, UM (asp's 641350, 5971197) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12630 feet Plugs (measured) EZ Drill CIPB @ 11950' (10/12/2001) true vertical 9067 feet Effective depth: measured 11950 feet Junk (measured) true vertical 9015 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 76 c.f. concrete 142' 142' Surface 2524' 13-3/8" 4790 c.f. Arcticset II 2556' 2550' Production 9062' 9-5/8" 1086 c.f. 'G', 83 c.f. AS I 9094' 7796' Liner 2366' 7" 505 c.f. Class 'G' 8892' - 11258' 7642' - 8977' Sidetrack Liner 1947' 4-1/2" 267 c.f. Class 'G' 10683' - 12630' 8857' - 9067' Perforation depth: measured Open Perfs 10632' - 10640', 11170' - 11210', 11270' - 11550' Open Perfs Below GImP 12100'- 12400'. ,_. true vertical Open Perfs 8825' - 8830', 9001' - 9001', 9003' - 9006' Open Perfs Below CIBP 9013' ~ 9019'. 4-1/2", 12.6#, L-80 TBG to 10546'. 4-1/2" Straddle Pack from 10546' - 10655'. [~l ~ °""~' Tubing (size, grade, and measured depth) 4-1/2" Tubing Tail @ 10676'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker SABL-3 Packers @ 10546' & 10655'. 4--1/2" HES HXO SSSVN @ 2160'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/10/2001 1026 28760 1439 1166 Subsequent to operation 10/15/2001 1286 12534 3083 1038 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09/17/2001 10/11/2001 10/12/2001 J-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS MECH SET BRIDGE PLUGS: DRIFT INTO LINER TOP (PRE CIBP) MECH SET BRIDGE PLUGS: SET CIBP MECH SET BRIDGE PLUGS: SET CIBP EVENT SUMMARY 09/17/01 DRIFT TO 10800' SLM W/3.625 CENT (LINER TOP @ 10683' MD). NOTIFY PAD OPER - WELL LEFT SI, 10/11/01 MIRU CTU #8, DRIFT COIL, WEEKLY BOP TEST, MU 3.65" JSN (8.54' OAL). KILL WELL W/111 BBLS FILTERED 2% SKCL, RIH. DRIFT TO 12100'. POH. MU HALIBURTON EZ SV CIBP ON WEATHERFORD BHA (12.12' OAL). KILL WELL DOWN BACKSIDE W/2 % KCL. 10/12/01 KILL WELL DOWN BACKSIDE. RIH W/EZ SV CIBP. SET CIBP @ 11950'. TAG CIBP, STACK 7K#. APPEARS TO BE GOOD SET. POH. TOOLS LOOKED GOOD. RIG DOWN. FLUIDS PUMPED BBLS I SURFACE PRESSURE TEST OF LUBICATOR 82 60/40 METHANOL WATER 189 2% SLICK KCL WATER 272 TOTAL Page 1 STATE OF ALASKA ALASK~ ulL AND GAS CONSERVATION COiv~MlSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] 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 647' FNL, 803' FEL, SEC. 09, T11N, R13E, UM At top of productive interval 399' FSL, 4521' FEL, SEC. 04, TllN, R13E, UM At effective depth 17' FSL, 2088' FWL, SEC. 04, TllN, R13E. UM At total depth 115' FNL, 2291' FWL, SEC. 09, T11N, R13E, UM 5. Type [~] well: Development [] Exploratory [] Stratigraphic []Service Mill CIBP (asp's 643546, 5970706) (asp's n/a) (asp's 641144, 5971326) (asp's 641350, 5971197) 6. Datum Elevation (DF or KB) KBE = 73.40' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number J-11A 9. Permit Number / Approval No. 196-104 10. APl Number 50- 029~20462-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12630 feet 9067 feet 12382 feet 9016 feet Length Structural Conductor 110' Surface 2483' Intermediate 9021' Production Liner 2030' Sidetrack Liner 1947' Size Plugs (measured) Junk (measured) Window milled in 9-5/8" Junked CIBP pushed to Cemented 20" x 30" 13-3/8" 9-5/8" 76.5 c.f. concrete 4790 c.f. Arcticset II 1086 c.f. Class 'G', 83 c.f. Arcticset I ST Liner 7" 505 c.f. Class 'G' 4-1/2" 267 c.f. Class 'G' (9094' - 9144') for sidetrack. 12382' CTM (05/04/2001) MD 152' 2556' 9094' 8892'-10922' 10683'-12630' TVD 152' 2550' 7796 7642'-8977' 8857'-9067' Perforation depth: measured Open Perfs 10632' - 10640', 11170' - 11210', 11270' - 11550', 12100' - 12382' Open Perfs Below Junked CIBP 12382'- 12400' true vertical Open Perfs 8825' - 8830', 9001' - 9001', 9003' - 9006', 9013' - 9016' Open Perfs Below Junked CIBP 9016' - 9019' Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 tubing to 10655'. 4-1/2" 12.6# L-80 tubing tail @ 10676'. Packers and SSSV (type and measured depth) 7" Baker 'S-3' Packer @ 10546'. 7" Baker 'SABL-3" Packer @ 10655'. 4-1/2" HES HXO SSSVLN (ID 3.813") @ 2160'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is_true and correct to the best of my knowledge Signed DeWayne SchnfCr ~ (~ v,-~ Title Technical Assistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 ' Date DeWayne Schnorr 564-5174 Submit In Duplicate~,.4.~ ON OR BEFORE c:LOi~VI~FILM-DOC J-11A Description of Work Completed NRWO OPERATIONS O5/O 1/2OO 1 05/02/2001 05/03/2001 05/04/2001 05/11/2001 MECH SET BRIDGE PLUGS: MILL CIBP AT 12000' MECH SET BRIDGE PLUGS: MILL CIBP AT 12000' MECH SET BRIDGE PLUGS: MILL CIBP AT 12000' MECH SET BRIDGE PLUGS: MILL CIBP AT 12000' ANN-COMM: LOAD AND MITOA SUMMARY 05/01/01 MIRU, MAKE UP BAKER MOTOR AND 3.7" FLAT BOTTOM MILL, 05/02/01 RIH WITH BAKER MILL AND MOTOR, TAG CIIBP AT 11,951 '; MILL ON CIBP FOR 4 HOURS WITH LITTLE MOTOR WORK; POOH; MU NEW MOTOR AND MILL; PUSH CIBP TO 12316', STUCK MOTOR - FREED MOTOR AND PUH TO 11403' MOTOR STUCK AGAIN, PUMP 180 BBL CRUDE IN CASE OF DIFFERENTIAL STICKING, NO HELP, DISCONNECT- POOH TO PICK UP JARS AND GS FISHING SPEAR. 05/03/01 DROP DISCONNECT BALL, PUMP DOWN WITH 60/40 METH, MAKE UP GS FISHING TOOL AND RIH, JARS NOT WORKING; POOH; RIH WITH ACCEL. JARS, WT. BAR, O J, GS. BEAT DOWN SEVERAL TIMES; PUMP DOWN BACK SIDE WITH WATER WHILE BEATING DOWN. POOH WITH FISH 05/04/01 (CONTINUATION)_LAY DOWN RECOVERED FISH AND BHA. MU & RIH W/3.7" MILL TO PUSH CIBP TO BOTTOM, PUSH PLUG TO 12365', MOTOR STALLED AND STUCK, UNSTUCK TWICE, POOH TO MAKE VENTURI JB, RAN VENTURI, HOOVER FROM 10,800' DOWN TO PLUG AT 12,382'; POOH; OOH W/3 CHUNKS OF PLUG; RIH WITH OIL JARS, MOTOR AND MILL; SLIGHT STALL AT 12,369'; HUNG UP, HAD TO LET JARS GO OFF TO COME FREE; POOH; CIBP LEFT AT 12,382' CTM. 05/11/01 MITOA PASSED Fluids Pumped BBLS. Description 870 SLICK KCL 1400 2% SLICK KCL 57O 2% KCL 17 METHANOL 112 METHANOL WATER 200 60/40 METHANOL 75 BIOZAN 360 CRUDE 54 DEAD CRUDE DOWN CA 3658 TOTAL PERMIT 96-104 96 -104 96-104 96 -104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96-104 96 -104 DATA DIFL/GR/SP ZDL/CN/GR CN/GR DAC BHP SSVD GR- CCL GR/CCL/PERF 7345 7463 7464 CNP / GR- TVD RES / GR- TVD CNP/GR-MD RES / GR- MD RES/GR-MD CNP/GR-MD CNP/GR-TVD RES / GR- TVD AOGCC Individual Geological Materials T DATA PLUS Well Inventory ~/~EPIA ~5~SEPIA ~SEPIA ~'/SEPIA L~SEPIA SEPIA 10200-11243 10200-11188 10200-11152 10200-11202 10200-11182 10200-11243 ~10550-10799 L 10550-10565 J~/DIFL/DAC/ZDL/CN/GR ~ 1-6,9-12 SPERRY RES/GR/CNP ~SPERRY RES/GR/CNP ~"/7732-9008 J~7732-9008 ~c.L/9010-11577 ~.,L'/"9010_11577 /9OlO-11258 PB1 ~9010-11258 PB1 ~L/7732-9085 PB1 ~f~7732-9085 PB1 Page: 1 Date: 07/07/98 RUN RECVD 1 07/12/96 1 07/12/96 1 07/12/96 1 07/12/96 1 07/12/96 1 07/12/96 1 07/19/96 1 07/19/96 1 07/26/96 09/20/96 1-6 09/20/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 FINAL 09/26/96 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 2 Date: 07/07/98 RUN RECVD 10-407 R~COMPLETION DATE 7 / Q /g~/ DAILY WELL OPS R G//X/~ / TO ?/ ? / q Are dry ditch samples required? yes r~And received? Was the well cored? yes ~ Analysis & description received? Are well tests required? yes ~ Received? Well is in compliance Initial COMMENTS WELL LOG TRANSNHTTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 September 25, 1996 RE: MWD Formation Evaluation Logs - J-1 lA & J-1 lA PB 1, AK-MM-960632 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' J'nm Cralvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 J-11A: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20462-01 2" x 5" MD Neutron and Gamma Ray Logs: 50-029-20462-01 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-20462-01 2" x 5" TVD Neutron and Gamma Ray Logs: 50-029-20462-01 Blueline S F'P 2 ¢ 't996 Rev Folded SepiaAl~kaC~ &Gas C~r~.Co~ Blue~e Rev Folded Sepia ~ ~ Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia ,I-11APB1: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20462-70 2" x 5" MD Neutron and Cramrna Ray Logs: 50-029-20462-70 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-20462-70 2" x 5" TVD Neutron and Gamma Ray Logs: 50-029-20462-70 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. ' .~_. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - J- 11A & J- 11A PB 1 September 20, 1996 AK-MM-960632 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~ Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 J-11A: 1LDWGformatted LIS tape withverific~ion hsting. API#: 50-029-20462-01 J-11A PBI: 1 LDWG formatted LIS tape with verification listing. API#: 50-029-20462-70 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A I~r~r Inch [~tri~.~ Ir'lc._ .... ' STATE OF ALASKA ALASKf....~L AND GAS CONSERVATION CO,v,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-104 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20462-01 4. Location of well atsurface ~- 0~Ji~ ,-~.~,,lu ~ ~~~' 9. Unit or Lease Name 650' SNL, 804' WEL, SEC. 9, T11N, R13E ~ . ~3~ i~.~~,i Prudhoe Bay Unit At top of productive interval ~ ~~~., i~: 10. Well Number 399' NSL, 4521' WEL, SEC. 4, T11N, R13E ~ ¥[~ ~ . J-11A At total depth ~-~- .... ~ 11. Field and Pool 117' SNL, 2990' WEL, SEC. 9, T11N, R13E ~ ....... Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 73.40'I ADL 028281 12. Date Spudded06/17/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' water depth' if °fish°re 116' N°' °f c°mpleti°ns06/30/96 07/06/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)~19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosl 12630 9067 FT~ 12580 9055 FT~ []Yes i--INo I 2160' MD/ 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, CDL, CNL, GR, DFIR, RES, DIFL, AC, CN, ZDL, LWD, RLL, DEN, 4-Phase RES 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulated Conductor Surface 110' 36" 8-1/2 cu yds concrete 13-3/8" 72# L-80 Surface 2556' 17-1/2" 4790 cu ft Arcticset II 9-5/8" 47# L-80 - Surface 9094' 12-1/4" 1086 cu ft Class 'G', 83 cu ft Arcticset I 7" 26# L-80 8892' 11258' 8-1/2" 505 cu ft Class'G' 4-1/2" 12.6# L-80 10683' 12630' 6" 267 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2" Gun Diameter, 5 spf 4-1/2", L-80, 12.6# 10676' 10546' & 10655' MD TVD MD TVD 11170' - 11210' 9001' - 9001' 10632' - 10640' 8825' - 8830' 11270' - 11550' 9003' - 9006' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12100' - 12400' 9013' - 9019' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/150 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 26, 1996 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 0ALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAvn-Y-API (CORR) Press. ~4-HOuR RATE 28. CORE DATA Brief descriptiOn of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core :; .~ "~-,~ ;~,, '~ ..-. · · -' ;:. ~-;.- .-. t.'. ,.-,.. '::..;: ".. ., , .-. ".,.., , ,.."~'-: (~ ..,,,) h, i ,- ¢.... -:,.~ .. _.,.~' ',t. '-~'~' ?'. '.;'~' Form 10-407 Rev. 07-01-80 "? Submit In Duplicate 29. Geologic Marker. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 10292' 8601' Shublik 10350' 8640' Top of Sadlerochit 10477' 8725' Top of Zone 2B 10963' 8990' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby cedify that th,~ foreigoing is~ ~ue and correct to the best of my knowledge DanStor~ Title Senior Drilling Engineer Date Prepared By Name/Number: Terrie Hubble, 564-4628 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: J-11A Rig Name: Nabors 28E AFE: 4P0826 Accept Date: 06/12/96 Spud Date: 06/1 7/96 Release Date: 07/06/96 Jun 12 1996 (1) Skid rig. Rig moved 100 %. Skid rig. Rigged down Drillfloor / Derrick. Jun 13 1996 (2) Rigged down Drillfloor / Derrick. Rigged up Drillfloor / Derrick. Installed Accessories. Retrieved Hanger plug. Circulated at 9385 ft. Held safety meeting. Circulated at 9385 ft. Installed Hanger plug. Pulled Adapter spool. Rigged up Additional services. Rigged up All functions. Installed BOP test plug assembly. Tested All functions. Retrieved Hanger plug. Rigged up Tubing handling equipment. Retrieved Tubing hanger. Laid down 100 ft of Tubing. Jun 14 1996 (3) Laid down 9400 ft of Tubing. Serviced Drillfloor / Derrick. Tested Kelly cocks. Installed Bore protector. Singled in drill pipe to 9300 ft. Functioned downhole tools at 9300 ft. Circulated at 9300 ft. Pulled out of hole to 30 ft. Pulled BHA. Jun 15 1996 (4) Made up BHA no. 2. R.I.H. to 4924 ft. Set Bridge plug at 35 ft with 0 psi. Removed Bore protector. Rigged down BOP stack. Removed Casing spool. Installed Casing spool. Tested Wellhead connector. Packer worked at 35 ft. R.I.H. to 9094 ft. Milled Casing at 9133 ft. Jun 16 1996 (5) Circulated at 9133 ft. Pulled out of hole to 30 ft. Pulled BHA. Made up BHA no. 3. Serviced Drillfloor / Derrick. R.I.H. to 9105 ft. Reamed to 9113 ft. Milled Casing at 9144 ft. Circulated at 9139 ft. Pulled out of hole to 30 ft. Pulled BHA. Made up BHA no. 4. R.I.H. to 7000 ft. Serviced Block line. R.I.H. to 9094 ft. Operations Summary for: J- Jun 17 1996 (6) Washed to 9130 f. Milled Casing at 9144 ft. Circulated at 9144 ft. Pulled out of hole to 30 ft. Pulled BHA. Serviced Drillfloor/Derrick. Made up BHA no. 5. R.I.H. to 9245 ft. Circulated at 9245 ft. Mixed and pumped slurry - 30 bbl. Pulled out of hole to 8145 ft. Circulated at 8145 ft. Pulled out of hole to 30 ft. R.I.H. to 1200 ft. Laid down 1200 ft of 5 in OD drill pipe. Serviced Flowline. Removed Bore protector. Tested All functions. Installed Bore protector. Made up BHA no. 6. R.I.H. to 4500 ft. Jun 18 1996 (7) R.I.H. to 8881 ft. Drilled cement to 9095 ft. Drilled to 9641 ft. Jun 19 1996 (8) Drilled to 10054 ft. Circulated at 10054 ft. Pulled out of hole to 9090 ft. R.I.H. to 10054 ft. Drilled to 10178 ft. Circulated at 10178 ft. Pulled out of hole to 120 ft. Pulled BHA. Held safety meeting. Made up BHA no. 7. R.I.H. to 6500 ft. Jun 20 1996 (9) R.I.H. to 10013 ft. Washed to 10178 ft. Drilled to 10646 ft. Circulated at 10646 ft. Pulled out of hole to 120 ft. Pulled BHA. Made up BHA no. 8. R.I.H. to 8900 ft. Serviced Block line. Jun 21 1996 (10) Serviced Block line. R.I.H. to 10646 ft. Circulated at 10646 ft. Drilled to 10775 ft. Circulated at 10775 ft. Pulled out of hole to 120 ft. Held safety meeting. Pulled BHA. Removed Bore protector. Installed Bore protector. Made up BHA no. 9. R.I.H. to 10653 ft. Reamed to 10775 ft. Drilled to 10808 ft. Jun 22 1996 (11) Drilled to 10811 ft. Circulated at 10811 ft. Pulled out of hole to 120 ft. Pulled BHA. Made up BHA no. 10. R.I.H. to 10697 ft. Reamed to 10811 ft. Drilled to 10962 ft. Circulated at 10962 ft. Pulled out of hole to 120 ft. Held safety meeting. Pulled BHA. Made up BHA no. 11 . Jun 23 1996 (12) Made up BHA no. 11 . R.I.H. to 10870 ft. Reamed to 10962 ft. Drilled to 10258 ft. Circulated at 10258 ft. Pulled out of hole to 9090 ft. R.I.H. to 10258 ft. Circulated at 10258 ft. Pulled out of hole to 120 ft. Pulled BHA. Serviced Drillfloor / Derrick. Rigged up sub-surface equipment - Formation logs. Ran electric logs. Page 2 Operations Summary for: J- Jun 24 1996 (13) Ran electric logs. Conduct braided cable operations - 7/32 size cable. Ran electric logs. Rigged down Logging/braided cable equipment. Pulled Drillpipe in stands to 9094 ft. Serviced Block line. Pulled Drillpipe in stands to 160 ft. Rigged down sub- surface equipment- Formation logs. Retrieved Bore protector. Tested All functions. Installed Bore protector. Rigged up Casing handling equipment. Ran Casing to 318 ft (3.5 in OD). Held safety meeting. Ran Casing to 2365 ft (7 in OD). Ran Casing on landing string to 6000 ft. Jun 25 1996 (14) Ran Casing on landing string to 11258 ft. Circulated at 11258 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry- 90 bbl. Displaced slurry - 228 bbl. Set Liner hanger at 8905 ft with 1100 psi. Reverse circulated at 8892 ft. Laid down 5000 ft of 5 in OD drill pipe. Pulled out of hole to 30 ft. Pulled BHA. Made up BHA no. 13. Singled in drill pipe to 3800 ft. R.I.H. to 10685 ft. Drilled cement to 10840 ft. Circulated at 10840 ft. Tested Casing - Via annulus and string. Held drill (Kick (well kill)). Drilled cement to 10922 ft. Milled Subs at 10922 ft. Jun 26 1996 (1) Milled Float collar at 10933 ft. Circulated at 10933 ft. Held drill (Spill). Pulled out of hole to 150 ft. Pulled BHA. Made up BHA no. 2. R.I.H. to 5200 ft. Jun 27 1996 (2) R.I.H. to 10933 ft. Drilled to 10999 ft. Circulated at 10999 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 3. R.I.H. to 10955 ft. Logged hole with LWD: Formation evaluation (FE) from 10955 ft to 10999 ft. Drilled to 11067 ft. Circulated at 11067 ft. Pulled out of hole to 1000 ft. Jun 28 1996 (3) Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 4 . R.I.H. to 11067 ft. Drilled to 11555 ft. Jun 29 1996 (4) Drilled to 11555 ft. Circulated at 11555 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 10922 ft. Serviced Block line. R.I.H. to 11576 ft. Drilled to 11900 ft. Jun 30 1996 (5) Drilled to 12087 ft. Circulated at 12087 ft. Pulled out of hole to 200 ft. Pulled BHA. Tested BOP stack. Made up BHA no. 6. R.I.H. to 7500 ft. Page 3 Operations Summary for: J- Jul I 1996 (6) R.I.H. to 11870 ft. Reamed to 12087 ft. Drilled to 12630 ft. Circulated at 12630 ft. Pulled out of hole to 10922 ft. R.I.H. to 12630 ft. Circulated at 12630 ft. Pulled out of hole to 7000 ft. Jul 2 1996 (7) Pulled out of hole to 200 ft. Pulled BHA. Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 1948 ft (4.5 in OD). Ran Drillpipe on landing string to 12630 ft. Circulated at 12630 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 47 bbl. Displaced slurry - 191 bbl. Reverse circulated at 10688 ft. Circulated at 10688 ft. Pulled Drillpipe in stands to 9000 ft. Jul 3 1996 (8) Pulled Drillpipe in stands to 0 ft. Rigged up Drillstring handling equipment. Made up BHA no. 7 . R.I.H. to 12481 ft. Drilled cement to 12580 ft. Circulated at 12580 ft. Tested Casing - Via annulus and string. Serviced Block line. Pulled out of hole to 1000 ft. Pulled BHA. Jul 4 1996 (9) Pulled BHA. Held safety meeting. Rigged up sub-surface equipment - Gun assembly. Ran Drillpipe in stands to 10390 ft. Perforated from 11170 ft to 12400 ft. Reverse circulated at 10399 ft. Packer worked at 10399 ft. Pulled out of hole to 9500 ft. Serviced Drillstring handling equipment. Laid down 9500 ft of Drillpipe. Jul 5 1996 (10) Laid down 1900 ft of Drillpipe. Ran electric logs. Perforated. Retrieved Wear bushing. Rigged up Tubing handling equipment. Ran Tubing to 10678 ft (4.5 in OD). Space out tubulars. Jul 6 1996 (11) Reverse circulated at 10675 ft. Set packer at 10546 ft with 4000 psi. Tested Permanent packer. Tested Tubing. Installed BOP test plug assembly. Conducted slickline operations on Slickline equipment- Retrival run. Jul 7 1996 (12) Conducted slickline operations on Slickline equipment - Setting run. Rigged down BOP stack. Installed Adapter spool. Installed Xmas tree. Freeze protect well - 150 bbl of Diesel. Serviced Fluid system. Rigged down Drillfloor / Derrick. -..--.. ;...... :. ":i.'" · '~ .... . -,. r?~ r-.. '"." :; 'i ~ ', -.) ",,' ,-, A .-~:",. Paqe~ 4 ,.,,.,.. ,-. ':'-",: ": :.\ \ O,':~ ,' .... i- ," '" SPF' Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE · SHARED SERVICES DRILLING PBU/J-11APB1 500292085370 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 062296 MWD SURVEY JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9004.39 7728.19 7654.79 9094.00 7795.96 7722.56 9099.00 7799.71 7726.31 9138.20 7829.66 7756.26 9169.98 7854.47 7781.07 40 20 41 22 41 26 38 55 38 28 N 86.00 W .00 94.55N 3807.19W N 86.18 W 1.16 98.55N 3865.68W N 86.19 W 1.25 98.77N 3868.98W N 80.10 W 11.89 101.75N 3894.07W N 74.92 W 10.29 106.04N 3913.46W 3630.35 3686.95 3690.15 3714.84 3734.56 9202.04 7879.60 7806.21 9231.44 7902.71 7829.31 9263.75 7928.14 7854.74 9295.27 7952.80 7879.40 9324.82 7975.39 7901.99 38 19 38 6 38 3 39 3 41 13 N 69.50 W 10.51 l12.11N 3932.40W N 63.50 W 12.64 119.36N 3949.06W N 61.60 W 3.63 128.54N 3966.75W N 56.60 W 10.38 138.63N 3983.59W N 52.20 W 12.06 149.73N 3999.06W 3754.45 3772.57 3792.28 3811.49 3829.73 9356.32 7998.7'8 7925.38 9387.55 8021.75 7948.35 9419.14 8045.19 7971.79 9452.01 8069.79 7996.39 9483.19 8093.10 8019.70 9515.01 8116.41 8043.01 9547.48 8139.42 8066.02 9579.02 8160.83 8087.43 9611.31 8181.75 8108.35 9644.14 8202.19 8128.79 9675.39 8221.19 8147.79 9707.42 8240.52 8167.12 9738.98 8259.49 8186.09 9769.81 8277.91 8204.51 9802.41 8297.32 8223.92 9834.83 8316.56 8243.16 9864.21 8333.94 8260.54 9894.12 8351.62 8278.22 9926.12 8370.58 8297.18 9957.94 8389.51 8316.11 42 55 42 25 41 46 41 17 41 56 43 52 45 55 48 32 50 42 52 17 52 48 52 57 53 9 53 25 53 30 53 41 53 46 53 43 53 36 53 22 N 47.30 W 11.73 163.37N 4015.15W N 42.80 W 9.89 178.31N 4030.12W N 38.60 W 9.15 194.36N 4043.93W N 35.20 W 7.01 211.78N 4057.02W N 31.80 W 7.53 229.04N 4068.44W N 27.80 W 10.49 247.84N 4079.19W N 24.10 W 10.22 268.44N 4089.20W N 21.80 W 9.91 289.76N 4098.22W N 19.80 W 8.16 312.76N 4106.94W N 18.50 W 5.75 337.03N 4115.37W N 17.60 W 2.83 360.61N 4123.05W N 17.40 W .68 384.97N 4130.73W N 16.70 W 1.87 409.09N 4138.13W N 16.20 W 1.59 432.79N 4145.13W N 16.20 W .24 457.95N 4152.44W N 15.40 W 2.06 483.05N 4159.54W N 14.60 W 2.22 505.93N 4165.67W N 14.10 W 1.36 529.30N 4171.65W N 12.50 W 4.04 554.39N 4177.58W N 12.20 W 1.07 579.37N 4183.05W 3849.38 3868.41 3886.69 3904.74 3921.16 3937.44 3953.62 3969.09 3984.83 4000.70 4015.65 4030.85 4045.70 4060.03 4075.14 4090.03 4103.28 4116.55 4130.33 4143.64 9990.37 8408.89 8335.49 10020.90 8427.23 8353.83 10052.44 8446.44 8373.04 10084.55 8466.42 8393.02 10111.45 8483.38 8409.98 53 13 52 58 51 58 51 2 50 49 N 11.10 W 2.76 604.84N 4188.30W N 8.40 W 7.12 628.89N 4192.44W N 4.70 W 9.82 653.73N 4195.29W N 1.70 W 7.88 678.82N 4196.70W N .60 W 3.28 699.70N 4197.12W 4156.89 4168.64 4179.43 4188.93 4196.13 SPE' '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/J-11APB1 500292085370 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 062296 MWD SURVEY JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10148.92 8507.18 8433.78 50 18 N 1.70 E 4.93 728.63N 4196.84W 4205.29 10176.93 8525.17 8451.77 49 45 N 4.32 E 7.43 750.06N 4195.72W 4211.21 10208.79 8545.97 8472.57 48 46 N 8.90 E 11.33 774.03N 4192.95W 4216.40 10240.16 8566.73 8493.33 48 20 N 13.30 E 10.60 797.10N 4188.43W 4219.64 10272.86 8588.54 8515.14 48 2 N 19.20 E 13.48 820.48N 4181.61W 4220.81 10304.28 '8609.55 8536.15 48 5 N 23.60 E 10.42 842.23N 4173.09W 4219.84 10336.33 8630.87 8557.47 48 31 N 27.90 E 10.11 863.78N 4162.69W 4217.03 10367.66 8651.64 8578.24 48 27 N 32.70 E 11.47 884.02N 4150.86W 4212.44 10431.77 8694.33 8620.93 48 10 N 42.00 E 10.84 922.01N 4121.88W 4197.41 10463.69 8715.67 8642.27 47 56 N 46,.90 E 11.44 938.95N 4105.27W 4187.22 10495.50 8736.95 8663.54 48 8 N 51.00 E 9.60 954.47N 4087.44W 4175.42 10527.46 8758.13 8684.73 48 50 N 55.60 E 11.00 968.77N 4068.25W 4161.94 10559.46 8779.01 8705.61 49 43 N 59.70 E 10.08 981.73N 4047.77W 4146.79 10591.44 8799.52 8726.12 50 30 N 63.30 E 8.98 993.44N 4026.21W 4130.22 10609.40 8810.91 8737.51 50 47 N 65.70 E 10.45 999.41N 4013.67W 4120.32 10624.48 8820.41 8747.00 51 9 N 67.40 E 9.08 1004.07N 4002.93W 4111.67 10656.66 8840.54 8767.14 51 24 N 71.60 E 10.21 1012.86N 3979.42W 4092.31 10687.87 8859.97 8786.57 51 38 N 76.60 E 12.56 1019.55N 3955.94W 4072.29 10718.79 8878.75 8805.35 53 32 N 80.00 E 10.70 1024.52N 3931.89W 4051.17 10756.91 8900.53 8827.13 56 45 N 81.90 E 9.36 1029.43N 3901.00W 4023.56 10793.41 8920.07 8846.67 58 30 N 82.60 E 5.03 1033.58N 3870.46W 3996.04 10822.97 8934.90 8861.50 61 17 N 84.40 E 10.84 1036.47N 3845.05W 3972.96 10854.31 8949.38 8875.98 63 39 N 84.98 E 7.68 1039.04N 3817.38W 3947.64 10887.60 8963.55 8890.15 65 55 N 84.66 E 6.90 1041.76N 3787.39W 3920.17 10921.60 8976.76 8903.36 68 20 N 82.90 E 8.54 1045.16N 3756.25W 3891.84 10949.52 8986.47 8913.07 70 59 N 81.80 E 10.18 1048.65N 3730.31W 3868.44 10979.67 8996.16 8922.76 71 29 N 81.30 E 2.28 1052.84N 3702.07W 3843.11 11011.54 9006.29 8932.89 71 27 N 80.90 E 1.19 1057.52N 3672.22W 3816.41 11043.53 9016.48 8943.08 71 23 N 82.20 E 3.86 1061.97N 3642.22W 3789.50 11075.75 9026.77 8953.37 71 21 N 81.90 E .89 1066.20N 3611.99W 3762.29 11107.67 9036.99 8963.59 71 18 N 80.90 E 2.97 1070.72N 3582.09W 3735.49 11139.97 9047.37 8973.97 71 11 N 80.90 E .31 1075.56N 3551.89W 3708.52 11172.26 9057.78 8984.38 71 11 N 81.00 E .29 1080.36N 3521.70W 3681.54 11237.00 9078.64 9005.24 71 11 N 81.10 E .15 1089.90N 3461.16W 3627.41 11258.00 9085.41 9012.01 71 11 N 81.10 E .09 1092.97N 3441.52W 3609.84 THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM HORIZONTAL DISPLACEMENT = 3610.91 FEET AT NORTH 72 DEG. 22 MIN. WEST AT MD = 11258 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 289.01 DEG. TIE-IN SURVEY AT 9,004.39' MD ARE BASED ON THE USE OF CURVATURE METHOD. ~ ~- .". ~3~ ., .~%"¥~., ,., ,,, ... ~ ~. . ~,.~-,. ,~!NDOW POINT AT 9,094.00' MP PROJECTED SURVEY AT 11,258.00' MD SPE' '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/J-11APB1 500292085370 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 062296 JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9004.39 7728.19 7654.79 10004.39 8417.29 8343.89 11004.39 9004.02 8930.62 11258.00 9085.41 9012.01 94.55 N 3807.19 W 1276.20 615.86 N 4190.46 W 1587.10 310.90 1056.45 N 3678.91 W 2000.37 413.27 1092.97 N 3441.52 W 2172.59 172.22 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE*' "'-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/J-11APB1 500292085370 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 062296 JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 9004.39 7728.19 7654.79 94.55 N 3807.19 W 1276 9063.94 7773.40 7700.00 97.22 N 3845.86 W 1290 9194.13 7873.40 7800,00 110.54 N 3927.75 W 1320 9322.20 7973.40 7900.00 148.72 N 3997.69 W 1348 .20 .54 .73 .80 14.34 30.19 28.07 9456.81 8073.40 8000.00 214.37 N 4058.84 W 1383 9598.31 8173.40 8100.00 303.42 N 4103.47 W 1424 9762.24 8273.40 8200.00 426.96 N 4143.43 W 1488 9930.87 8373.40 8300.00 558.12 N 4178.40 W 1557 10095.-63 8473.40 8400,00 687.42 N 4196.90 W 1622 .41 .91 .84 .47 .23 34.61 41.50 63.93 68.63 64.76 10250.17 8573.40 8500.00 804.31 N 4186.50 W 1676 10400.38 8673.40 8600,00 903.98 N 4136.78 W 1726 10550.83 8773.40 8700,00 978.31 N 4053.36 W 1777 10709.90 8873.40 8800.00 1023.17 N 3938.86 W 1836 10912.76 8973.40 8900.00 1044.22 N 3764.37 W 1939 .77 .98 .43 .50 .36 54.54 50.21 50.46 59.07 102.86 11220.74 9073.40 9000.00 1087.52 N, 3476.37 W 2147.34 11244.39 9081.02 9007.62 1090.98 N 3454.25 W 2163.37 207.98 16.03 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPE:~ "-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/J-11A 500292085301 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 070196 MWD SURVEY JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10921.60 8976.85 8903.45 10935.00 8981.58 8908.18 10947.00 8985.38 8911.98 10962.31 8989.38 8915.97 10974.81 8992.16 8918.76 68 20 70 17 72 48 76 55 77 19 N 82.90 E .00 1045.01N 3756.14W 3891. N 83.42 E 15.00 1046.50N 3743.69W 3880. N 83.88 E 21.31 1047.76N 3732.38W 3870. N 84.46 E 27.10 1049.26N 3717.69W 3856. N 84.93 E 4.92 1050.39N 3705.55W 3845. 68 40 12 71 60 10992.75 8995.85 8922.45 11003.56 8997.77 8924.37 11037.88 9002.30 8928.90 11059.03 9003.95 8930.55 11072.22 9004.46 8931.06 78 57 80 33 84 15 86 48 88 44 N 85.58 E 9.75 1051.84N 3688.06W 3829. N 85.96 E 15.20 1052.62N 3677.45W 3819. N 87.17 E 11.33 1054.66N 3643.50W 3788. N 87.91 E 12.51 1055.57N 3622.43W 3768. N 88.36 E 15.10 1055.99N 3609.26W 3756. 53 76 32 70 39 11101.96 9003.90 8930.50 11135.83 9001.82 8928.42 11167.02 9000.56 8927.16 11198.99 9000.74 8927.34 11230.95 9001.74 8928.34 11264.52 9003.03 8929.63 11294.67 9003.94 8930.54 11325.94 9003.67 8930.27 11358.02 9002.36 8928.96 11389.90 9001.06 8927.66 93 24 93 38 90 59 88 23 88 0 87 35 88 56 92 3 92 37 92 1 S 89.50 E 17.24 1056.29N 3579.54W 3728. N 87.87 E 7.78 1056.77N 3545.74W 3696. S 88.80 E 13.64 1057.02N 3514.58W 3667. S 86.69 E 10.47 1055.77N 3482.64W 3636. S 87.51 E 2.84 1054.15N 3450.74W 3605. S 88.64 E 3.57 1053.02N 3417.22W 3573. S 86.00 E 9.83 1051.61N 3387.11W 3544. S 85.09 E 10.36 1049.18N 3355.94W 3514. S 82.77 E 7.43 1045.80N 3324.08W 3483. S 80.92 E 6.09 1041.28N 3292.55W 3452. 38 58 21 60 91 85 93 67 44 16 11422.96 9000.04 8926.64 11453.88 8999.85 8926.45 11486.53 9001.23 8927.83 11516.89 9003.58 8930.18 11549.89 9006.36 8932.96 91 30 89 11 85 56. 85 9 85 10 S 80.05 E 3.06 1035.82N 3259.96W 3419. S 79.72 E 7.55 1030.39N 3229.53W 3389. S 78.94 E 10.24 1024.35N 3197.48W 3356. S 78.64 E 2.78 1018.46N 3167.79W 3326. S 79.14 E 1.51 1012.13N 3135.52W 3294. 57 03 76 77 20 11580.80 9009.08 8935.68 11613.34 9011.32 8937.92 11646.19 9012.73 8939.33 11676.56 9013.96 8940.56 11708.54 9014.90 8941.50 84 43 87 22 87 41 87 39 88 58 S 77.96 E 4.07 1006.02N 3105.35W 3263. S 76.49 E 9.31 998.84N 3073.69W 3231. S 75.10 E 4.33 990.78N 3041.88W 3198. S 76.71 E 5.30 983.40N 3012.45W 3168. S 75.87 E 4.89 975.82N 2981.40W 3136. 68 41 71 48 65 11740.89 9015.43 8942.03 11772.83 9016.04 8942.64 11804.19 9016.63 8943.22 11834.23 9016.83 8943.43 11865.22 9016.61 8943.21 89 8 88 40 89 11 90 1 90 46 S 73.79 E 6.45 967.36N 2950.18W 3104. S 72.72 E 3.66 958.16N 2919.60W 3072. S 69.93 E 9.05 948.12N 2889.90W 3041. S 67.82 E 7.55 937.29N 2861.89W 3011. S 68.56 E 3.38 925.78N 2833.12W 2980. 38 48 13 11 16 SPE: -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/J-11A 500292085301 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 070196 MWD SURVEY JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11896.00 9016.18 8942.78 90 49 S 70.09 E 4.97 914.92N 2804.33W 11927.07 9015.53 8942.13 91 34 S 65.77 E 14.10 903.25N 2775.55W 11961.42 9014.73 8941.33 91 6 S 64.46 E 4.04 888.80N 2744.40W 11991.91 9014.51 8941.11 89 41 S 60.36 E 14.23 874.68N 2717.38W 12023.57 9014.75 8941.35 89 26 S 57.14 E 10.20 858.26N 2690.32W 2949.40 2918.39 2884.23 2854.09 2823.16 12054.50 9014.78 8941.38 90 25 S 58.19 E 4.64 841.72N 2664.19W 12086.35 9013.77 8940.37 93 12 S 57.45 E 9.03 824.76N 2637.25W 12118.53 9011.95 8938.55 93 16 S 57.49 E .22 807.49N 2610.16W 12150.97 9010.21 8936.81 92 53 S 57.74 E 1.40 790.14N 2582.80W 12183.08 9009.08 8935.68 91 8 S 57.26 E 5.65 772.90N 2555.74W 2793.06 2762.07 2730.83 2699.32 2668.11 12214.50 9008.67 8935.27 90 22 S 57.07 E 2.52 755.86N 2529.34W 12248.90 9008.59 8935.19 89 52 S 57.47 E 1.84 737.26N 2500.41W 12277.93 9008.79 8935.39 89 19 S 57.65 E 2.03 721.69N 2475.91W 12308.98 9009.40 8936.00 88 27 S 57.71 E 2.78 705.09N 2449.67W 12343.01 9011.46 8938.05 84 35 S 57.05 E 11.51 686.79N 2421.07W 2637.61 2604.19 2575.95 2545.74 2512.74 12375.26 9015.16 8941.76 82 11 S 56.55 E 7.60 669.25N 2394.27W 12406.74 9019.50 8946.10 81 56 S 56.31 E 1.09 652.01N 2368.29W 12438.84 9024.23 8950.83 81 5 S 56.92 E 3.25 634.54N 2341.78W 12470.30 9029.98 8956.58 77 50 S 57.09 E 10.38 617.70N 2315.84W 12501.40 9036.76 8963.36 76 59 S 56.48 E 3.34 601.07N 2290.45W 2481.69 2451.51 2420.75 2390.74 2361.32 12534.10 9044.31 8970.91 76 18 S 56.50 E 2.11 583.51N 2263.92W 12567.97 9052.38 8978.98 76 8 S 57.32 E 2.40 565.55N 2236.36W 12630.00 9067.24 8993.84 76 8 S 57.32 E .00 533.03N 2185.67W 2330.52 2298.61 2240.10 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2249.73 FEET AT NORTH 76 DEG. 17 MIN. WEST AT MD = 12630 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 289.01 DEG. TIE-IN SURVEY AT 10,921.60' MD PROJECTED SURVEY AT 12,630.00' MD SPE:' '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/J-11A 500292085301 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 070196 JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10921.60 8976.85 8903.45 11921.60 9015.67 8942.27 12630.00 9067.24 8993.84 1045.01 N 3756.14 W 1944.75 905.46 N 2780.55 W 2905.93 961.18 533.03 N 2185.67 W 3562.76 656.84 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEI -SUN DRILLING SERVICES ANCHOR3tGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/J-11A 500292085301 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/96 DATE OF SURVEY: 070196 JOB NUMBER: AK-MM-960632 KELLY BUSHING ELEV. = 73.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10921.60 8976.85 8903.45 12630.00 9067.24 8993.84 1045.01 N 3756.14 W 1944.75 533.03 N 2185.67 W 3562.76 1618.01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE A/qCHOP~AGE AK, 99501. .Date: RE: 19 July 1996 Transmittal of Data ECC #: 6716.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Ro~ey D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 ~chorage, AK 99518 Received by . Date: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL $ DESCRIPTION 1 CCL FINAL BL+RF / Run # 1 1 PLS FINAL BL+RF/ Run # 1 1 PLS FINAL BL+RF j Run # 1 1 PLS FINAL BL+RF u,~ Run # 1 1 PLS FINAL BL+RF Run # 1 1 PLS FINAL BL+RF Run # 1 1 PLS FINAL BL+RF~-~ Run # 1 1 GR/CCL FINAL BL+RF u-- Run # 1 1 PFC/PERF FINAL BL+RF /Run # 1 q¥-,ttt B-02A qb"lt{ B-02A 1 CCL FINAL BL+RF ~ 1 SBT/GR FINAL BL+RF Run # 1 Run # 1 ECC NO. 4298 04 5642 03 5792 02 5829 02 5829 03 5938 06 6685 02 6720 00 6721.00 6721.01 Received by: Please si~n and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 . _ Date: RECEIVED dUt 1 9 199 HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOP~AGE AK, 99501. Date: RE: 28 June 1996 Transmittal of Data ECC #: 6716.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: J- 11APH PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: DIFL FINAL BL+RF / Run # 1 ZDL/CN FINAL BL+RF c/ Run # 1 CN FINAL BL+RF ~-~ Run # 1 DAC FINAL BL+RF ~ Run # 1 BH PRO FINAL BL+RF ~/ Run # 1 SSVD FINAL BL+RF c/ Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 563-7803 Received by: JUL 12 Date: TONY KNOWLES, GOVERNOR ~S~ OIL A~NIt GAS ~@~~A~ION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 4, 1996 Dan Stolz, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit J-1 lA BP Exploration (Alaska), Inc. 96-104 650'SNL, 804'WEL, Sec 09, T11 N, R13E, UM 112'NSL, 2983'WEL, Sec 09, T11N, R13E, UM Dear Mr. Stolz: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-36O7. Si r\ Chairma~ BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o enci Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIv~f3SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen I [] Service [] Development Gas [] Single Zone [] Multiple Zone 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE -- 74.09' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028281 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 650' SNL, 804' WEL, SEC. 9, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4853' SNL, 4346' WEL, SEC. 4, T11N, R13E J-11A At total depth 9. Approximate spud date Amount $200,000.00 112' SNL, 2983' WEL, SEC. 9, T11N, R13E 06/14/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028282 2297'I No Close Approach 2560 12679' MD / 9024' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 9100' Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 2170' 8850' 7476' 11020' 8981' i31 sx Class 'G', 301 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 1809' 10870' 8855' 12679' 9024' 214 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate RE£EIVED Production Liner MAY 2 9 1996 Alask~ 0il & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tim Burns, 564-4315 Prepared By Name/Number Terrie Hubble, 564-4628 21. I hereby certify that,~pe~'ffregoing i~~/¢Trrect to the best of my knowledge Signed Dan Stoltz ,-:~'(k,'-~'~~_.~ Title Senior Drilling Engineer Date ~'-/2 Commission Use Only Permit Number t APl Number Approval .Date See cover etter ~"~'-~O/./z't 50-C~,. ~- .~4:~ d/Z~/'.,~, - 4::~// I (~,/~,/r~,., J for other requirements Conditions of Approval: Samples Required I-I ,~es~ No Mud Log Required -I-1 Yes ,,~No Hydrogen Sulfide Measures [] No Directional Survey Required ./~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; I~ 5M; [] 10M; [] 15M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In ~riplicate I Well Name: I J-11A Redrill Summary Type of Well (producer or injector): I Producer Surface Location: 650' FNL 804' FEL Sec 9, T11N, R13E Pilot Hole Bottom Hole Location: Not applicable Sadlerochit Zone 2 Lateral Start of Horizontal Location: 4,853' FNL 4,346' FEL Sec 4, T11 N, R13E End of Horizontal Location: 112' FNL 2,983' FEL Sec 9, T11N, R13E Start of Horizontal Location: End of Horizontal Location: Not applicable Sag River Lateral Not applicable I AFE Number: I 4P0826 I I Rig: ] Nabors 28-E Estimated Start Date: I June 14, 1996 I I Operating days to complete: I 22 MD: 112,679' I ITVD: 19,024' I IRT-GL I KBE: I33.8' _73.9' Well Design (conventional, slimhole, etc.) I Horizontal Sidetrack (after Pilot Hole) Formation Markers: Formation Tops MD TVD (SS) Ugnu N/A 3990' Above KOP HRZ N/A 6925' Above KOP Put River N/A N/A Above KOP Kingak (TJD) 9100' 7726' KOP in Kinc.:jak - Jurassic D Marker Sag River 10309' 8560' Shublik 10370' 8600' Top Sadlerochit 10481' 8670' Zone 3 10852' 8850' Zone 2/2C 11013' 8905' 7" casing point (11,020' MD, @ 90° in Zone 2) TD of Well 12679' 8950' 4-1/2' liner point Casinq/Tubinq Proqram: · ~ y Y Hole Size Csg/ Wt/Ft Grade Conn Lengb5 Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC-MOD 2170' 8850'/7476' 1102078981' Lower Lateral 6" I 4-1/2" 12.6# L-80 BTC-MOD 1809' 10870'~8855' 12679'/9024' Upper Lateral N/A I N/A N/A N/A N/A N/A N/A N/A I Production Tubing I 4-1/2" 12.6# L-80 BTC-MOD 10470' 30'/30' 10500'/8760' RECEIVED MAY 2 9 1996 Alaska 011 & Gas Cons. Commission Anchorage Cementing Program: Lead Cement Tail Cement Casin~/Liner Sx / Wt / Yield Sx / Wt / Yield Comments Premium Tail to 1,000 above Sag; 7" 31 / 11.0 / 3.24 301 / 15.7 / 1.14 Tail FW=0; 30% excess; Lead TOC at liner top; Pump time = 4+ hrs; 4-1/2" None 214 / 15.7 / 1.17 Class G: 30% excess; TOC at liner top; Pump time = 4+ hrs; Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. I Logs: 12-1/4" Hole 8-1/2" Hole Logging Program: 6" Hole Cased Hole: Not applicable MWD GR/Directional to top of Zone 3; MWD GR/CNL/Directional from Zone 3 to Zone 2 (horizontal); DPC logs are contigency only if MWD logs are inconclusive; MWD GR/Directional/Resistivity None planned Mud Program: Intermediate Mud Properties: 1 8-1/2" hole section: LSND Density Yield 10 sec 10 min pH Fluid (PPG) PV Point ~lel gel Loss Initial 9.8 10-12 8-12 4-8 8-12 9.0-9.5 <8 Final 9.8 16-20 8-12 LSYP 12-16 16-20 9.0-9.5 HTHP-<15.0 Hazards/Concerns Cretaceous (Kingak) MW to be at least 9.8 ppg. Utilize hi vis sweeps to assist hole cleaning Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could require lubricant use. Reduce APl fluid loss to <6 cc before drilling Kingak Section. Differential sticking due to higher MW. Production Mud Properties: 1 6" hole section: Baroid Sheardril Depth Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss Initial 8.8-9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6 Final 8.8-9.0 50-60 30-40 15-20 18-24 8.5-9.0 <6 Hazards/Concerns Lost Circulation due to overbalance in Sadlerochit. Differential sticking with overbalance situation. Perform report daily checks on KCI concentrations in Xanvis KCI system. Potential high torque could require lubricant use. RECEIVED MAY 2.9 1995 Alaska 011 & (~as Cons. Commission Anchorage Directional: I KOP: I 9,100' MD/Sidetrack from 9-5/8" casing) Maximum Hole Angle: I 90° Tan~lent Angle I N/A Close Approach Well: None Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal No annular injection permits will be submitted for the J-Pad sidetrack program. RECEIVED MAY ;~ 9 1~9~ Alaska 011 & ~.~ Oon~. Commi~mon Anchorage Operational J-11A Horizontal Sidetrack Summary I . . . , . , , , , 10. 11. P&A well. Test cement to 1,500 psi. 'Tag cement minimum of 100' above top perforation @ 10,560' MD. Cut the 5-1/2" tubing @ _+9,400' MD. MIRU Nabors 28-E drilling rig. Pull 5-1/2" tubing. Test 9-5/8" casing to 3,500 psi for 10 minutes. RIH and set EZSV at _+9,300' MD (205' below proposed 9-5/8" section). PU section mill, TIH and spot _+18 bbl (+_205') of 18.0 ppg milling fluid from EZSV (9,300' MD) to 9,145' MD. Space out and mill section from 9,095' MD to 9,145' MD. POOH. TIH with open-ended drillpipe. Mix and spot a 17.0 ppg cement kick-off plug (per recommended practices) from 9,245' to 8,895' MD. POOH a minimum of 12 stands. Perform a hesitation squeeze. Do not exceed a final squeeze pressure of 2,000 PSI and do not displace cement any closer than 100' above section top. NOTE' Final cement volume should insure slurry placement 100' below milled section, 50' across milled section and 200' inside casing above milled section. PU directional BHA and TIH. Tag TOC. MINIMUM WOC TIME IS 12 HOURS. Dress off cement plug to 9,100' MD (5' below top of section), kick-off and directionally drill to TD of Pilot Hole at +_11,454' MD (9,130' TVD). Final inclination is planned for 70° along an azimuth of 80°. POOH. Plug back pilot hole upon evaluation of MWD logs. NOTE- If pilot hole logs are inconclusive, DPC logs will be run. TIH with bit and BHA to dress cement plug below the gas/oil contact and the base of Zone 3. RU and run 7" liner from _+11,020' MD and tie back into 9-5/8" casing at _8,850 MD. POOH and LD liner running tools. RE£E VED ~AY t 9 1996 Alaska 011 & Gas Co~s, commission Anchorage J-11A Sidetrack Operations Summary Page 2/2 12. 13. 14. 15. 16. 17. 18. PU directional BHA and drill 6" horizontal hole to _+12,679' MD (final inclination at _+90°) at an azimuth of 133°. Planned lateral interval is _+1,502'. POOH. NOTE: Inclination, azimuth and overall lateral length may be shortened by onsite geologist. MW in this interval will be_+9.0 ppg. ' - Run and run a 4-1/2", L-80 solid liner to TD and cement in place. Top of liner will be at _+10,870' MD. NOTE: A wiper trip may be made prior to running production liner. RIH with DPC perforating guns and perforate 4-1/2" production liner using MWD logs to select optimum perf interval. POOH. RU and run 4-1/2", L-80, production tubing with 7"x 4-1/2" permanent production packer at_+10,500' MD (___55° inclination). Set two way check and test to 1,000 psi. ND BOPE. NU tree and test to 5,000 psi. Freeze protect well and release rig. Drilling Hazards KOP will occur in the Kingak shales. MW should be at minimum 9.8 ppg to maintain hole stability. Shublik B interval may be fractured resulting in lost circulation. 7" liner will set across these intervals. Sadlerochit interval has an estimated pore pressure of +7.4 ppg EMW. Lost circulation may occur due to overbalance conditions. Small (20') faults are expected in the the build interval of Zone 2C. Lost circulation is possible but not likely. No faulting is anticipated in the horizontal interval. There are no known drilling close approaches. No other known drilling hazards are expected. M~¥ '~ 9 ~996 Naska 0il & ~s Cons. Commissio~ Anchorage BPX - Shared Services Drilling Alaska State Plane: Zone4 PBU ' WOA: J-Pad ~-llA fi-JlA Wpl9 (NCW) II01{IZONTA~ ViE.W (TRUB SC~ lO0 ~t./ m. ~UR~Y ~F: WE~ HALLIBURTON )0 45~0 44b0 43~0 4E~0 4lb0 4~ 3~30 3e~ 37~0 36~ 3~0 34~00 33~ 3R~0 3t~ 30~ 2~ E~0 27~ R6~ ES~0 24~0~ ~0 EE~ Et~ ~0 19~ Il 4700 460~ 4400 4300 ~0 ;00 ~0 400 300 ~00 0 J-il E00 WELL PLAN PROFILE SUMMARY START MDENO MDPLANNED ACTIVITY I Ioio I I i?? Plalll4 TII-I& [(0 lihl kill alit! ~llrI¢l[lll · [).}il I IOO'slll lit?? 12i?t Jlld DIrIcUIlll · 3.11' 1100'llll fei(kiel hi. of II,ll' la AIL I~ 13~.11' lIi?t TD .uke4 r CA~INO PDINT D~T~ ND I~ ~J TVD N/S [/1/ DD I~ tt0R0 70,00' 00,00'999R 1064 N 3697 IT~et NGs-~ TVp NS IV Grid X Gi~d y J-aL O0~'4338 N~el V~13~ ~971R~ J-~ ~4 ~ N ~ V 640853 597L010 ~)3 ~ 5~3 N~ V ~40 5971E~ ~]S ~4 164~ N ~i0 V640~ 597~85 ~]G ~ 9~ N ~9 V 640~0 59715~ J-J P~y~ ~14 338 N2161 V 6413~ 5971~ ~J4 ~4 1~9 H~7 V ~97~ ~97L7~ ~tot ~4 1073 H ~36 V~ ~97&7tO Lead 89t9 l~gt N ~ V ~6 ~97L~ I CRITIC~. POINT DATA j N0 lr~ Az J,TYD £/~ { STAAT DF' e~ez~ 36.B v IST~T ~ lit77 I~ ~' ~10 1077 N 3343 V { ~vK I I J PLOT INFORMATION DRAWING NAME / FILE NAME J-11AwplgNCW Composite I Jl 1 anvho.akd SURFACE LOCATION PROPOSED BHL Alaska ~tale Plane 0 Aa-BuiltTV'D ~ 12678.98 Ne~h~g: Elite: 0 Al-Bilked Plan RTE Ft.: O E,Um.ted g181.07 De,laned ey : ~ ~ A?F',:OVED WEI I. DESIGN SC,U.,~ 100 ~ / LQ. TVD REF: WELL,'-[EAD YgR~ SgCTION PEr: V~LLHEAD 66001 9700] BgO01 9900t ~ll~a' ! 11'377 9300~ 9400] VF, RTICAL ~'"'Z30N PLA.N~: 269.01' / ~ 't ':i:, /, STATE OF ALASKA ALASKA Ot~ AND GAS CONSERVATION COMIv,. ~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend ~ Plugging E~ Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance i~ Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 650' SNL, 804' WEL, SEC. 09, T11N, R13E At top of productive interval 452' SNL, 120' WEL, SEC. 08, T11N, R13E At effective depth 359' SNL, 414' WEL, SEC. 08, T11N, R13E At total depth 353' SNL, 431' WEL, SEC. 08, T11N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11045 feet 9416 feet 10999 feet 9374 feet 5. Type of well: ,~ Development ~ Exploratory .~, Stratigraphic L._J ,~ Service Datum Elevation (DF or KB) KBE = 69.01' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number J-11 9. Permit Number 80-35 10. APl Number 50-029-20462 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Plugs (measured) Junk (measured) OF I61NAL Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD 110' 20"x30" 2528' 13-3/8" 10002' 9-5/8" Perforation depth: measUred true vertical 1527' Tubing (size, grade, and measured depth) 7" 401 cu ft ~' '~ 10520'- 10552', 10562'- 105~(~?.', 105i~193' - 10613' subsea 8872'- 8955' (three intervals) 7", L-80 to 9467' with 4-1/2" tailpipe to 9562' TVD Packers and SSSV (type and measured depth) 8.5 cu yds ,,..~-'~ 139' 139' 4790cu ff ~.~/ 2557' 2557' 1168 cuff 10031' 8517' 9518'- 11045' 8115'- 9416' MAY 2 9 1996 Alaska 0tt & ~at C0r~, ~ti~ 9-5/8" Guiberson Polar packer at 9467'; 4-1/2" SSSV and insert at 2046' 13. Attachments ~ Description summary of proposal ~ Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation May 29, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: ~ Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Tim Bums, 564-4315 Prepared By Name/Number 17. I hereby certify that/41~'c)regoing~orrect to the best of my knowledge Signed Dan Sloltz/ ~ ~~_.,~_/?,~. _ _.~;;~!;;~ Title Senior Drilling Engineer Terrie Hubble, 564-4628 Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness I Approval No. Plug integrity c,,"'" BOP Test ~ Location clearance __ Mechanical Integrity Test Subsequent form required 10- /.Cc) 7' Approved Copy Returrted Original Signed By Approved by order of the Commission David W. J0hnst0R Commissioner Form10-403 Rev. 06/15/88 Submit In "l'r~i~ate ~ · WELL PERMIT CHECKLIST COMPANY FIELD &'POOL INIT CLASS ADMINISTRATION ENGINEERING APPR EO ^RE^ PROGRAM: exp [] dev"~ reddl~serv [] wellbore seg [] ann. disposal para req i-I UNIT# //~'-~-0 ON/OFF SHORE 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number ................ N 4. Well located in a defined pool ................. N 5. Well located proper distance from drlg unit boundary .... IN 6. Well located proper distance from other wells ........ N 7. Sufficient acreage available in ddlling unit .......... N 8. If deviated, is wellbore plat included ............. ~N 9. Operator only affected party .................. N O. Operator has appropriate bond in force ............ N 1. Permit can be issued without conservation order ..... .' N 2. Permit can be issued without administralJve approval... N 3. Can permit be approved before 15-day wait ......... N REMARKS 14. Conductor string provided ................... (~ N"'/ , ,.,~,, _ 15. Surface casing protects all known USDWs .......... Y N 16. CMT vol adequate to circulate on conductor & surf csg .... Y N 17. CMT vol adequate to lie-in long string to surf csg ...... ./~ N 18. CMT will cover all known productive horizons ......... ~ N 19. Casing designs adequate for C, T, B & permafrost ...... ~ N 20. Adequate tankage or reserve pit ............. . . . (..y.) N 21. If a re-drill, has a 10-4.03 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ............ ~ N 23. If diver[er required, is it adequate ................ 24. Drilling fluid program schemalJc & equip list adequate .... 25. BOPEs adequate ........................ N BOPE press rating adequate; test to __,~'"'C~'l~ ____psig.~ N 26. 27. Choke manifold complies w/APl RP-53 (May 84) ....... ,-,,*'Y'--N 28. Work will occur without operation shutdown .......... .~ N 29. Is presence of H2S gas probable ............... dY./,..~N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... __Y./NfL.,/, /'7, 32. Seismic analysis of shallow gas zones ............ ./2¢ N 33. Seabed condition survey (if off-shore) ........... //. Y N 34. Contact name/phone for weekly pro.qress reports .... X'. · . Y N [~xproratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ JDH ~ JDN TAB "~,"~ Comments/Instructions: HOW/~jb- A:~FORMS~cheklist rev 4/96 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 APPENDIX. No special effort has been made to chronologically organize this category of information. ~Tap~ Subfile 2 is type: L1S TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMSANY: TAPE CREATION DATE: JOB DATA JOB NLTMB]ER: LOGGING ]ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM- 960632 P. ROBERTS K. WHITE J-11A 500292046201 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 19-SEP-96 MWD RUN 2 P. ROBERTS K. WHITE MWD RUN 3 P. ROBERTS K. WHITE JOB NUMBiER: LOGGING [ENGINEER: OPERATOR WITNESS: MWD RUN 4 P. ROBERTS K. WHITE MWD RUN 5 P. ROBERTS K. WHITE MWD RUN 6 P. ROBERTS K. WHITE JOB NUMB[ER: LOGGING [ENGINEER: OPERATOR WITNESS: MWD RUN 9 E. CRIBBS C. DIXON MWD RUN 10 E. CRIBBS C. DIXON MWD RUN 11 E. CRIBBS C. DIXON MWD RUN 12 JOB NUMBiER: LOGGING iENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUI~.D LEVEL: WELL CASING RECORD E. CRIBBS C. DIXON 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9 liN 13E 650 804 73.40 71.90 38.45 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 9094.0 8.500 11258.0 6.000 12630.0 MWD - GR/EWR4/CNP. ALL DEPTHS ARE MEASURED BIT DEPTHS. RUN 1 WAS DIRECTIONAL GAMMA RAY (GEIGER MUELLER TYPE). GAMMA RAY SENSOR LOGGING CASING FROM 9000' TO 9094' PRIOR TO EXITING CASING WINDOW, 9094' TO 9144'. RUNS 2-6 WERE FEWD P4 (DIR/REALTIME GAMMA RAY, CN POROSI~if, RESISTIVITY). RUN 7 WAS DMWD (DIRECTIONAL ONLY) AND WAS USED TO MILL WINDOW IN CASING. RUN 8 WAS DMWD (DIRECTIONAL ONLY) AND WAS USED TO BUILD ANGLE OUT OF MILL. RUN 9 WAS SP4 (REALTIME 4-PHASE RESISTIVITY), DRILLED TO 11066' DUE TO UNINTENTIONAL SIDETRACK. RUN 10 WAS SP4 (REALTIME 4-PHASE RESISTIVITY), DRILLED TO 11577' IN NEWLY SIDETRACKED HOLE. RUN 11 WAS SP4 (REALTIME 4-PHASE RESISTIVITY), DRILLED TO 12087'. RUN 12 WAS SP4 (REALTIME 4-PHASE RESISTIVITY), DRILLED TO TD AT 12630'. WELL J-11A KICKED-OFF FROM WELL J-11A PB1 AT 10922', PART WAY THROUGH RUN 5. WELL J-11A IS DRILLED TO TD AT 12630'. WELL J-11A IS NOT DEPTH SHIFTED, PER PHONE CONVERSATION BETWEEN DUANE VAAGEN (SPERRY-SUN) AND GREG BERNASKI (BP) ON 20-AUG-96. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8961.0 12582.0 10087.0 12589.0 10098.0 10922.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 3 MWD 4 MWD 5 MWD 9 MWD 10 MWD 11 MWD 12 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 9144.0 10178.0 10178.0 10646.0 10646.0 10775.0 10775.0 10811.0 10811.0 10922.0 10922.0 11066.0 11066.0 11577.0 11577.0 12987.0 12087.0 12630.0 MERGED MAIN PASS. RUN 5 ROP DATA IS USED TO 10922'. RUN 6 GR, EWR4 AND CNP DATA IS USED TO 10922'. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 320 4 90 120 46 4 90 120 46 4 90 890 01 4 90 334 30 4 90 334 31 4 90 180 01 4 90 810 01 4O Tape File Start Depth = 12630.000000 Tape File End Depth = 8961.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 80730 datums Tape Subfile: 2 442 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes 0 0' : (MI) .~,~O~NIf,T,$ ~IO0.T, 000 ' 00' : (MI) MOILOZ~HOD ZqOH :XLISN~ XI~lfI4 :XIHilzDq ~OOi NOHIQ~N . 0' 0'09I 0' 000 ' 000 ' 000 ' 000 ' 005I E'6 0'8/. 08'6 QNS~I 0'5606 00S'8 : (L.~) HLdZ~I ~NISIfD S : (MI) ZZIS LI~{ Z~IOH NZdO tfi~f(I D/qISlfO (IN~f Z~IOHZHO~t 9D~DL£S0d ~ZSNDN ~OOL 8'0S £'05 0 0'8LIOI 0'5516 0'8£IOI 05'IA 5d / 95'SA HID 5S'5 ~ZA DSI / g£'I ~A DS~ 96-N/lP-6I 0 ' 0£IOI H£dZG dO,T,S ZdXJ, ~IOOJ] ZGOD qOO.T, HOClNZA (~40iiO~t O,l, dO,l,) D~II%tLS ~IOOJ. 'SSITg sq~xedss uT unx qTq qo~s xo~ wq~p xsp~sq BoI pu~ ssA~no :HZ~WI1N Z~IZ ~ZGIfZH Z~IZ SIq :sdAq sT £ sIT~qns sd~i CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 10185.000000 Tape File End Depth = 8961.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7348 datums Tape Subfile: 3 93 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10105.0 10608.0 EWR4 10089.0 10593.0 CNP 10098.0 10600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ 20-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 10646.0 10178.0 10646.0 0 48.1 51.2 TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 44.0 8.6 1000 4.1 .750 .520 .820 1.050 68.0 161.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 50 Tape File Start Depth = 10650.000000 Tape File End Depth = 10080.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 93282 datums Tape Subfile: 4 117 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10602.0 10731.0 EWR4 10586.0 10715.0 CNP 10594.0 10723.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 20-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 Vl.40 REAL-TIME 10775.0 10646.0 10775.0 0 51.0 56.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 48.0 9.8 1100 4.1 .750 .330 .820 1.050 68.0 161.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. $ CN WN FN COUN STAT BP EXPLORATION (ALASKA) J- llA PRUDHOE BAY NORTH SLOPE ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 18 Tape File Start Depth = 10780.000000 Tape File End Depth = 10580.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11760 datums Tape Subfile: 5 85 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes 000' ZN0£SQNIfS :(MI) NOI£DZHHOD ZqOH :XIISN~ XIHitfI4 :XI~LIfM %OOi NO~J~fl~N 0'89 0'89 0'58I 0'89 0S0'I 0ES ' 06E ' 0S£ ' 9'5 006 6'8 0'85 06'6 0'5606 00S'8 : (In) HIdZQ DNISVD S,~Z~I~Q : (NI) ~ZIS iI~ ~OH NZdO VI~Q ONIS~D ~NIf ~OH~O~ 9~ON~DE£S0d 9d~N'~OE£S0d ZdAi ~OOi ~OD ~OOi ~O~N~A (NOiiO~ Oi ~Oi) ONI~IS ~OOi S'8S S'8S 0 0'IISOI 0'S££0I 0'IISOI 05'IA 58 / 95'SA ~S'5 ~ZA DSI / E£'I ~ZA 96-Ni10- IE Z%BfMi.~OS : (IZ©OO~I ZI~fG SIq :~cL{q sT 9 SIT~qns sd~i ssjXq 8IOI :q~Bu~I p~os~ mnm~x~M s~jXq 59 :q~6u~I p~oo~ mnmTu~M '''sp~oo~ 8A 9 :sI~qns smn~ep ~£6S6 89 :~poD d~H 00000S'0 = 5uTo~dS T~A~ ~IT~ 000000'00£0I = qqd~ pu~ eIT~ 000000'0ESOI = qqd@G q~eqS eIT~ II 0~ I I I I I I I I I I I0 018 06 P I0 08I 06 P I£ P££ 06 P 0£ P££ 06 P I0 068 06 P 9P 0gI 06 P 9~ 0gI 06 ~ 9~ 0gI 06 P 9~ 0gI 06 P I0 0I£ 06 ~ pon SlD clA£ clAi qqBus% szys A~D A~D sqIu~ ssIdm~S spoo IOOi sm~N :s~nD 0i (V9 #.~dX,l.) 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MOgLflZM 0'P£ 0'P£ 0 ' ~£I 0'PA 00~'I 098' 0L£' 018' 000I 0'0I O'IS 08'6 LH O' P606 00S'8 : (In) HidZ~ OMIS~D S,gZ~Ig~ :(MI) ZZIS iI~ Z~OH MZdO ~i~ DMIS~D QNIf Z~OHZgO~ 9dO_N-~D~£S0d 9dDN-%IDE£S0d 0'IL 0 'I9 0 0'E960I 0'IISOI 0'E960I 0~'IA ~d / 9~'SA MID P~'P gZA DSI / ~£'I gZA DS~ 96-NflP- EE P 'SISZg 'D~OgLDZ~Z PgMM (NOLLOM OL dOL) DMIgLS ~OOL 0'EE60I · SSlTg s2~z~dss uI unz ~Tq qo~s ~o~ ~wp zsp~sq BoI pu~ SSA~nO gZ~fZH Z~I~ SIq :~dX~ s! £ sII~qns sd~L s~Aq s~Aq ~9 :q~Bu~I p~oo~ mnmyx~M :q~Bu@I p~oo~ mnmiuiM · ''sp~oo~ ~t t :aIT~qns adeL smnq~p £~LEI 89 :~poD d~H :A~wmmns BuTPOm~p spom UOTq~qu~ss~d~x 00000S'0 = BUTO~dS I~A@% sITZ sdPi 000000'S~LOI = q~d~ puz ~IT~ ~de~ 000000'0£60I = q~dsG ~m~S ~IY~ ~d~L ~ SZLX~ ~EOI (0 #ZdXi) G%IODZ%t ~.T,~fG ~ I I0 018 06 9 ~ HHd~ I 89 GMN dOH I poM sIO clKi clKL qq6ua% azTs sqTu~ s@Idm~s apoD IOOL :S~A~nD I (~9 ~ZdAi) G~ODZ~ i~O~ . ~S~ : ZdO~IS HZ.HO~I : X~f~ ZOHgflHd : %flI -i2 : (~tS~itf) NOIL~Oq~XZ d~{ : NflOD NM ND : S~{~4Z%{ Tape Subfile 8 is type: LIS FILE HEADER FILE NI3MBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10885 . 0' 10922 . 0 10867.0 10922 . 0 10877.0 10922.0 EWR4 CNP $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ 22-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 11258.0 10962.0 11258.0 0 71.1 71.5 TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 51.0 10.0 1000 4.2 .810 .340 .860 1.400 74.0 187.0 74.0 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 6. ONLY GR, EWR4 AND CNP DATA USED FROM RUN 6, TO 10922'. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: Tape File Start Depth = 10922.000000 Tape File End Depth = 10860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 97185 datums Tape Subfile: 8 75 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10913.0 EWR4 10920.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11022.0 11030.0 27-JUN-96 ISC VER 4.54 CIM V5.03 / DEP V2.17f REAL-TIME 11066.0 10999.0 11066.0 0 72.3 79.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0497SP4 P0497SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 10922.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MI/D AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SHEARDRILL 9.20 53.0 8.7 25000 4.6 .150 .000 .130 .190 68.0 179.2 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 ss~Xq 866 :q~BusI p~oo~ mnmyxmM ss~Xq ~9 :q~BusI p~oo~ mnmyuiM smn~p ESSST 89 :~poD :Xm~mmns 5u!poosp spoo uo!~e~usssxd~ O0000S'O = buIoeds I~A~5 SlI~ 000000'0060I = q~d~ puZ ~I7~ 000000'S40TI = q~d~ 3~e~S ~I7~ 866 (0 #Z6/£) ~HODZH ~i~ ~ 8~ I I T I T I I I0 018 06 P I0 0ST 06 P 9P 0ET 06 P 9P 0ET 06 P 9P 0~I 06 P RP OgI 06 P I0 0T£ 06 P poM sIO clKi clKi q~Bua% ~zys s~Iu~ ssIdm~S apoo IOOl smeM :ssA~nD t ~ :QI q~dsp sde£ (P9 #ZdXi) GHODZH £~zCM:O~ ~ ZdO~IS H,T, HON : AllOt ZOHCIfl%Id : tfII -f' : (lOISlfTf) MOI,T,lf%IOqdXZ d~ : NIIOO MM 0 0' 000 ' 00' :(MI) MOI£D~HHOD ~50H :A~ISM~ XI~k~4 O'Ot O'Ot E'SLI 0'0£ 08I ' 0ET ' 000 ' 0£I ' 0'P 000PE 0'0~ 0I'6 qqI~{~HtfZHS 0'EE60I 000'9 : (LM) HidZ~ ©MIS~O : (MI) ZZIS LIM Z%OH MZdO ~£~ DMIS~D ~N-~ Z~OHZHO~ PcISL6 P0cI PdSL6P0cI ~ZSW/1M qOOJ, P ' SISZ~ '~40%{LDZ~IZ (MOLLO~t O,l, dOi) ~MI%tLS 9'£6 0 0'LLSII 0'990II 0'LLSII ZNIL-~I~fZM ~LI'gA ~ZG / £0'SA PS'P MZA DSI 96-NnD-SE 0'IPSII 0'££5II · ssIIg a~wx~dss uI unx ~.q qoes xo~ ~p x~p~sq 6oi pue s~Axn0 (L~4 Mk~ 6 : %tZ ~WIZN ~ZfSfZH Z~I,~ SIq :~cL{~ sT 0I SITgqns ~d~i ss~Xq 866 :q~SusI p~oDs~ mnm~x~N ss~Xq E9 :q~Su~I p~o3~z mnm~uTN '''sp~ooo~ SOT smn~p P£0£0I 89 :spoD dsm :A~mmns 5u!poo~p ~poo uoi~e~u~s~d~ SI~ 00000~'0 = BUlOedS IeAe~ ell~ 000000'0£60I = 000000'SSSII = 0P :sp~o~e~ eqe~ ieqol I0 018 06 ~ I0 08I 06 ~ 9~ 0El 06 ~ 9~ 0El 06 ~ 9~ 0El 06 ~ 9~ 0ET 06 ~ I0 0I£ 06 ~ IdW IdW IdW s~luo s~Idmes epoD IOOi emeM :s~A~nD £ ~ :GI qjdep ~fXS~r~i~ : HdO~S H£MOM : '0I Nn%t G~,I N_qOD NM ND 0 0' :(~) ~.~nb~g,~ : (.LXTI) ~OC[M'~,T,~ "IO0,T, 000 ' 00' 0'69 0'69 8'S8I 0'00I 0£I ' 0£I ' 890 ' 00I ' 0'5 00SS~ 0'0S 0E'6 ~ffIIgGI~fZHS 0'EE60I 000'9 : (NI) ZZIS iI~ Z~OH NZdO ~SL6~0~ ~SL6~0d gZ~MflN ~OOi 9'I6 0 0'LS0~I 0'L£SII 0'LSOEI ~£I'gA a~G / £0'SA NIO ~S'~ gZA DSI 96-NflD- 6~ ~ 'SISZ~ '©~OgiOZqZ ~MZ ZdXi TOOL ZGOD %00L gOf[6IZA (MOLLO~ Oi dOi) DNI~LS ~OOL 0 ' £50EI 0'S£0EI · ssII~ s~dss uI un~ ~Tq qo~s ~o~ ~p ~sp~sq BoI pu~ S~A~nO ~MI4 Mlf~ OI :gZ~MEIN Z~I~ HZfSfZH Z~I~ SI% :sclKq sT II SIT~qns sdwL s~Aq 866 ss~Aq E9 :q~6u~I pzoos~ mnm!x~M :q~6usI p~oo~ mnmIu!M II :~I7~qns ~d~i smn~mp I09~E 89 :spoD d~ :A~mmns Buipoosp ~poo uoI~u~ss~d~ SI% 00000~'0 = Bu!oPds ISASq sIY~ sdPi 000000'S~II = q~d~ pu~ ~T7~ ~d~ 000000'060ET = q~d~ ~S ~T~ ~d~ ££ 866 (0 #~4Xi) ~OD~ ~i~ ~ I0 018 06 ~ I0 08I 06 ~ 9~ 0EI 06 5 9~ 0EI 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ I0 0I£ 06 ~ pox SlD cI~i cL{i q~Bu~% sz!s s~IuD s@Tdm~s ~poD TOOl sm~N :ssA~nD L (~9 #,~dAi) ~%{OD,~ £~a-~O~ · lQ{ Slf-I~ : ,~dO~IS H£%{O~I : A~f~ ,~OH~fl%Id : ~flI -~ : (tf~StfI~) NOI£~OqdX,q d~ : i~IS NiIOD NM ND Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11935.0 EWR4 11941.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12582.0 12589.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MI/D AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 01-JUL-96 ISC VER 4.54 CIM V5.03 / DEP V2.17f REAL-TIME 12630.0 12087.0 12630.0 0 76.1 93.3 TOOL NUMBER P0497SP4 P0497SP4 6.000 10922.0 SHEARDRILL 9.20 49.0 8.6 25000 0.0 .110 .060 .150 .220 102.0 193.0 72.0 72.0 .00 .000 .0 0 ss~Xq 866 :q~Bu~I p~oD~ mnm~x~ ss~Xq E9 :q~Bu~I p~o~ mnm~uT~ · '-sp~oo~ III ET :~I~qns smn~p £~8II 89 :spoD d~ 00000~'0 = Bu~o~ds I@~s~ sI~ 000000'0£6II = q~d~ pu~ ~IT~ 000000'0£9EI = q~d~G ~x~S @I~ 9P 866 (0 #MdXi) ~HOD~H ~ ~ 8~ I0 018 06 ~ I0 08I 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 5 I0 0I£ 06 ~ pon sIO dXi clKi q~Sus~ ~zys Id~ Id~ Id~ Id~ s~!u~ s@Idm~s spoD IOOi ~m~M :s~AxnD £ YZ S~i~f : ZdO~IS HLMON : X~fM ZOHg/lMd : %fII -_~ : (%[~{S~ltf) NOI£~{O~dXZ d~ : NiiOD NM ND Tape Subfile 13 is type: LIS 96/ 9/19 01 **** REEL TRAILER **** 96/ 9/19 01 Tape Subfile: 13 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 19 SEP 96 1:36p Elapsed execution time = 3.41 seconds. SYSTEM RETURN CODE = 0 0'SSEII 00S'8 0'9606 SL8'6 (ia) Hi6a~ (X~) MZ~S (~) MZ~S i~S SM,~q~IIM~ ONIS~fD .~qOH N.~60 06'I/. ".~:,,(;f2 ::')i! .~.:!-; o~. £/_.. f~08 059 6 MiIHM '~ SIMM~OM '6 9 N/1M (/M/4 ZLIHM ZLIHM MLIHM ZLIHM 'H SLMM~OM ' 6 96-6ZS-6I DNI (~rZS~ml~f) NOIL~f~O%6XM 6E 0£Eg~0E6E00~ ZLIHM ' M SIMMS0%{ · d E£9096 :MMMNI©NM ONIODO% FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR .5000 START DEPTH 8961.0 RP 10087.0 NPHI 10098.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 11231.0 11215.0 11223.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 9144.0 10178.0 10178.0 10646.0 10646.0 10775.0 10775.0 10811.0 10811.0 10962.0 10962.0 11258.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples' Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM NPHI MWD 68 1 PU-S NCNT MWD 68 1 CPS 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 ~ 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 200 4 90 334 31 4 90 180 01 4 90 810 01 4O Tape File Start Depth = 11259.000000 Tape File End Depth = 8961.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 50568 datums Tape Subfile: 2 293 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes ~ Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8961.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMIIMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ STOP DEPTH 10130.0 19-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 10178.0 9144.0 10178.0 0 40.3 50.8 TOOL NUMBER P0537CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 78.0 9.2 1400 4.5 .000 .000 .000 .000 .0 160.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT BP EXPLORATION (ALASKA) J-11A PB1 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 10185.000000 Tape File End Depth = 8961.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7348 datums Tape Subfile: 3 93 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Ta~e Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10105.0 10608.0 EWR4 10089.0 10593.0 CNP 10098.0 10600.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 20-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 10646.0 10178.0 10646.0 0 48.1 51.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 44.0 8.6 1000 4.1 .75O .520 .820 1.050 68.0 161.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 TOOL ~STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 '1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 50 Tape File Start Depth = 10650.000000 Tape File End Depth = 10080.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63120 datums Tape Subfile: 4 117 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NI/MBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10602 . 0 10731.0 EWR4 10586.0 10715.0 CNP 10594.0 10723.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 20-JUN-96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 10775.0 10646.0 10775.0 0 51.0 56.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MI/D DENSITY (LB/G): MUD VISCOSITY (S) : MI/D PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 48.0 9.8 1100 4.1 .750 .330 .820 1.050 68.0 161.0 68.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 S~Xq 8IOI :q~Su~I p~o~ mnm~x~M ss~Xq E9 :q~Su~I p~oo~ mnm~u~M · ''sp~oD~ ~8 ~ :sI~qns smn~ep 09£II 89 :~po~ 00000S'0 = 6UTOedS IOAS~ ~IT~ 000000'08SOI = q~d0~ puz ~IT~ 000000'08£0I = q2d~ 2~e2S ~IT~ 8I 0~ I0 018 06 ~ I0 08I 06 ~ I£ ~££ 06 ~ 0£ ~££ 06 ~ I0 068 06 ~ 9~ 0EI 06 ~ 9~ 0EI 06 ~ 95 0EI 06 5 9~ 0EI 06 ~ I0 0I£ 06 ~ poM SlO cIAL clAL q~6us~ szTs s~uD ssIdmmS spoD IooL smmN :S~A~nD 0I ~ :GI q2dsp ~dwL (~9 #ZdAL) ~HODZ~ Lk~4HO~ ~ k~/StfI~ : ZdO~IS H£HO~I : X~f~ ZOHG/1Hd : I~d ~fII-P : (k~Sk~f~) NOI,~,k~6Oq6XZ d~ : L~LS N/iOD NM : (MI) ~.~OfIN-tf,LS ~I00£ ~ · 000' S9'~ :(MI) NOIIOZHHOD ZqOH :X£ISNZG XIHi~fM :MIM£~fM 0'89 0'89 0 ' PSI 0'89 0S0'I 0ES' 06E' 0S£' 9'P 006 6'8 0'8~ 06'6 0'~606 00S'8 : (J.~) HIdZG ~NIS~fD S : (MI) ZZIS J,I~{ Z~IOH ~fJ,~fG DNIS~fD fhkKf Zq~OH,~%IO~5 9dDN~DE£S0d 9d~N~DE£S0d 9dON%{DE£S0d ~ZSWflN qO0£ NO~J~IZN ~ZIVSNZdMOD END ~ 'SISZE 'O~O~IDZ~Z ~MZ ZdXi ~OOi Z~OD ~00~ ~OfKXIZA (~OiiO~ O~ dOi) ONI~IS ~OOi S'8S S'8S 0 0'IISOI 0'SLLOI 0'IISOI Z~IL-~i~fZ~ 0P'IA ~ / 9~'~A HID P~'P ~ZA DSI / E£'I ~ZA DS~ 96 -NIIP- I E 0'09£0I 0'ESLOI 0'89LOI Hid~ dOIS · s@I!~ s~exwdss uI unx ~7q qo~@ xo~ e~p xspesq BoI pu~ S@A~nO GM~ S : HZ~MD_N Z~II,~ %~ZC~fZH Z~II,~ SIq :sd~ s~ 9 sI~qns ~dwi ~TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLOP~ATION (ALASKA) : J-11A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MW-D 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 11 Tape File Start Depth = 10820.000000 Tape File End Depth = 10700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 65772 datums Tape Subfile: 6 78 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 7 is type: LIS EWR4 CNP $ LOG HEADER DATA DATE LOGGED: SOFTWARE FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10748 . 0 10907.0 10731.0 10891.0 10740 . 0 10899 . 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON DGR DUAL GAMMA RAY $ 22 - JUN- 96 MSC VER 1.32 / ISC VER 4.54 CIM V5.46 / P4 V1.40 REAL-TIME 10962.0 10811.0 10962.0 0 61.0 71.0 TOOL NUMBER P0532CRNGP6 P0532CRNGP6 P0532CRNGP6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 9094.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND HT 9.80 51.0 10.0 1000 4.2 .810 .370 .860 1.400 74.0 172.0 74.0 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 10 ROP MWD 68 1 FPHR 4 4 90 310 01 4 90 120 46 1 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 22 Tape File Start Depth = 10970.000000 Tape File End Depth = 10725.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17162 datums Tape Subfile: 7 89 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes 000 ' S9'E : (MI) NOI£DZ~HOO Z~OH :XIHL~ qOOi NO~iflZN 0'5£ 0'5£ 0'LSI 005'I 098' 05£' 018' 000I 0'0I 0'IS 08'6 0 ' 5606 00~'8 : (Id) HidZ~ ~NIS~D S,~Z~I~ : (NI) ZZIS iI~ Z~OH NZdO ~i~ DNIS~D ~Nlf ZqOHZ~O~ NO~JJ1ZN (IZI~SNZd~OD dND 5 'SISZ~ 'OlfI40~IDZ~Z 5~MZ ZdXi ~OOi Z~OD ~OOi ~OfL~IZA (HOiiO~ Oi dOi) ©NI~IS ~OOi S'IL I'IL 0 0'8SEII 0'E960I 0'8SEII 05'~A 5d / 95'~A HID 5~'5 ~ZA OSI / ~£'~ ~SA DSH 96-NflD- EE SI% :sctJ~ s! 8 ~II~qns @dPi TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 6. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : J-11A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 NPHI MWD 68 1 PU-S 4 7 NCNT MWD 68 1 CPS 4 8 FCNT MWD 68 1 CPS 4 9 FET MWD 68 1 HR 4 .10 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 35 Tape File Start Depth = 11259.000000 Tape File End Depth = 10860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 74562 datums Tape Subfile: 8 102 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes T~pe Subfile 9 is type: LIS 96/ 9/18 01 **** REEL TRAILER **** 96/ 9/19 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 19 SEP 96 l:16p Elapsed execution time = 2.31 seconds. SYSTEM RETURN CODE = 0 ::::::::::::::::::::::::::::::: Tap? Subfile. 2 is type: .~-~"S TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6716.00 R. ECK R. GEESAMAN REMARKS: J-11A PH 500292046280 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 18-JUL-96 OPEN HOLE RUN 2 RUN 3 9 liN 13E 650 804 73.40 71.90 38.45 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 9094.0 8.500 11258.0 DIFL/DAC/ZDL/CN/GR. CIRCULATION STOPPED AT 1900 HRS, 22-JUN-96. LOGS WERE DRILL PIPE CONVEYED. TD WAS NOT TAGGED. PUSHED UP TO 7000 LB AT 10740 FT TO GET TO BOTTOM. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. ~ FIL~E HE~DER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DAS depth shifted and clipped curves; .5000 START DEPTH 10200.0 10200.0 DIL 10200.0 SDN 10200.0 2446 10200.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH)~ STOP DEPTH 11157.0 11202.0 11240.0 11188.0 11164.0 BASELINE DEPTH LL8 10206.5 10208.5 10222.0 10230.0 10230.5 10232.5 10234.5 10235.0 10239.5 10251.0 10258.5 10272.5 10272.5 10281.5 10286.5 10288.5 10289.0 10297.0 10296.5 10297.5 10330.5 10343.0 10344.0 10346.5 10350.5 10352.0 10351.5 10354.5 10355.0 10354.5 10360.0 10364.0 10370.0 10370.0 10372.0 10372.0 10379.5 10380.0 10382.0 10391.0 10394.0 10395.5 10400.0 10400.0 10400.5 10402.5 all EQUIVALENT UNSHIFTED DEPTH ILD DT RHOB 10205.5 10208.0 10221.5 10221.0 10230.0 10230.0 10232.0 10234.0 10235.0 10239.5 10251.0 10250.5 10258.5 10272.5 10272.5 10272.0 10281.5 10281.0 10286.5 10289.5 10289.0 10296 . 5 10297 . 0 10297 . 0 10330.0 10342.5 10343.0 10345.5 10351.5 10354.0 10354.5 10360.0 10364.0 10370.0 10369.5 10372.0 10371.5 10371.5 10379.5 10380.0 10381.5 10393.5 10395.0 10400.0 10400.5 10400.5 runs merged; NPHI 10230.5 10288.5 10297.0 10343.0 10350.5 10372.0 10390.5 10394.0 10402.5 no case 10404.5 10406.0 10406.5 10408.5 10409.0 10410.5 10413.0 10413.5 10415.5 10423.0 10426.5 10428.5 10429.0 10432.5 10436.5 10440.0 10440.5 10443.5 10445.0 10445.5 10448.5 10450.0 10453.5 ]_0461.5 10462.0 10465.0 10467.5 10468.5 10470.0 10472.5 10473.0 10475.5 10476.0 10481.0 10485.5 10489.5 10490.0 10509.5 10518.5 10523.5 10524.5 10529.0 10539.0 10546.5 10561.5 10562.0 10567.5 10580.5 10581.0 10591.0 10591.5 10608.0 10608.5 10612.5 10619.5 10620.0 10628.0 10643.5 10644.0 10646.0 104~5.5 10408.5 10414.0 10429.5 10443.5 10453.5 10525.0 10539.0 10608.5 10644.0 10405.5 10408.5 10412.5 10429.0 10436.5 10440.0 10443.5 10453.5 10461.5 10472.0 10525.0 10539.0 10608.5 10644.0 10406.0 10408.0 10410.0 10415.0 10422.5 10433.0 10440.0 10443.0 10445.0 10453.0 10460.0 10465.5 10468.5 10475.5 10490.0 10509.5 10539.0 10547.0 10562.0 10581.5 10591.5 10608.0 10620.0 10643.5 10407.0 10409.0 10411.0 10426.5 10432.5 10439.5 10442.5 10444.5 10448.5 10453.0 10467.5 10470.5 10473.0 10475.0 10481.0 10485.0 10524.5 10529.0 10538.5 10545.5 10560.5 10567.5 10579.5 10590.5 10608.0 10619.0 10627.5 10644.0 10404.5 10422.5 10433.5 10439.5 10443.0 10449.5 10465.0 10470.0 10475.5 10489.5 10519.0 10523.5 10539.5 10581.5 10591.0 10612.5 10646.0 S'6680I S'8S80I S'O~80I O'ILLOI S'£~LOI S'6~90I O' £EIII S'90III S'ILOII S'LSOII O'I£OII S'900II S'6660I S'8960I 0'8160I S ' 9060I q'6680I O'OL80I 0'8980I S'£S80I S'£980I S 'I~80I 0'6E80I S'6180I S'II80I S'£6LOI S'88LOI O'OgLOI 0 ' ~LLOI S'89LOI S'E9LOI O'09LOI 0'99LOI O'IgLOI S'8£LOI O'L£LOI 0'9£LOI S'8[LOI 0'E690I S'9890I 0'E890I S'~S90I S'6~90I S'8160I S'I980I 0 'I~80I S'II80I 0'£6£0I S'68LOI S'98AOI 0'I9£0I S'ISLOI S'9£LOI 0'0890I S'6~90I S'£~80I S'9ESOI O'IISOI S'£6LOI 0'£8£0I S'~8£0I O'08LOI O'~LLOI O'[LLOI S'I9LOI O'S[LOI O'IELOI S'S690I 0'I890I S'SS90I S'OS90I 0'0~80I 0'II80I S'I9LOI O'SELOI 0'I890I S'SS90I S'o~qoI S'EEIII S'90III S'ELOII 0'SSOII S'IEOII S'900II O'O00II S'6960I S'8160I O'S060I S'6680I 0'0£80I 0'8980I 0'I980I S'8S80I O'~S80I 0'~80I 0'£~80I ~'0980I 0'0~80I 0'8E80I 0'£E80I S'6180I ~'IISOI O'IISOI S'OISOI S'£6LOI 0'£6LOI 0'68LOI S'88LOI 0'£8LOI S'98LOI 0'~SAOI S'08LOI 0'~££0I S'ELLOI O'ILLOI S'O£LOI 0'69LOI S'£9£0I O'I9LOI S'09LOI S'ISLOI O'~SLOI S'£~LOi S'O~LOI S'8CLOI O'L£LOI S'9[LOI S'8[LOI O'IELOI 0'S690I 0'E690I S'9890I ~'E890I S'0890I S'SS90I O'SS90I O'OS90I §-6~90I· I 66 966 L~ P P I 66 966 69 ~ P I 66 566 6~ ~ 9 I 66 566 6~ ~ P I 66 966 6~ ~ P I 66 S66 80 P P I 66 S66 80 ~ P I 66 ~66 80 P P I 66 ~66 80 ~ P I 66 ~66 80 P P I 66 566 80 ~ P I 66 ~66 80 P ~ I 66 ~66 6~ ~ P I 66 ~66 6~ ~ P I 9I 0£~ 6~ P P I I0 0I£ 6S ~ ~ po~ SlO dXA dYkL q~Buaq az!s A~D ~O 6o~ s~Iug ssIdm~S spoo IOOi ~m~M :ssA~no 8I ( ~9 #MdA3.) G~ODM%t J.k~ar~0.4 ~ ~S~ : MdO%S HIMON : A~ MOHG/iMd : Hd ~II-~ : (kr)tSk~i~f) NOIi¥~O~dXH d~ : J ao'£Hoz zz/ J/10'gHD£~Ng6/ J~O'IHDik~N66/ NnOD NM ND 0'99III 0'88III 0'0PglI 0'g0gII 0'LSIII O'OOgOI S I O'OOgOI S I O'OOgOI S I O'OOgOI S I 0'00~0I S I dO~ HO~HN 'ON SS~d 'ON 0 · 6c:3~ -,- · 17 FUCT 2446 68 1 CPS 18 NUCT 2446 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 183 994 BYTES * 72 47 995 99 47 995 99 Tape File Start Depth = 11250.000000 Tape File End Depth = 10062.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 45164 datums Tape Subfile: 2 449 records... Minimum record length: Maximum record length: 62 bytes 994 bytes ~Tap~ Su~file 3 is type: _~S TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 5 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10200.0 11159.0 DAC 10200.0 11203.0 DIFL 10200.0 11242.0 ZDL 10200.0 11188.0 2446 10200.0 11166.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOI~TOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 23-JUN-96 ECLIPS 2.2 1900 22-JUN-96 1111 23-JUN-96 11258.0 11245.0 10200.0 11243.0 1200.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV TTRM COMR KNJT GR CN ZDL KNJT KNJT DAC SLAM KNJT DIFL $ SWIVEL SUB TEMPERATURE COMMON REMOTE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG SLAM ADAPTER KNUCKLE JOINT DUAL INDUCTION TOOL NUMBER 3944XA 3981XA 3510XA 3923XA 1329XA 2446XA 2228EA/MA 3923XA 3923XA 1667EA/1680MA 3516XA 3921NA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT) : 8.500 9094.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): LSND 9.80 pox slO clXi clKi q~6u~ az!s A~D A~D Id~ Id~ IdV s~!u~ soldm~s opoo Iool amen :ssn-~no gE :Gl q~dap ( ~9 #.gdAJ,) G-MOD,gM ,L~O.~ ~ O· 0'I£ 0' 0'££ 0'90g 0'~£ 000' S9'~ MNOISGN~S 000 ' 006 ' 000 ' 0~0'I 08£ ' 080'I 0'90Z O'OI %D{S~ : .gdO~IS H.L%tON : i~fM .gOHGll%{d : Hd ~fII-D : (~Sk~f) NOIJ.~O~IdX.g dM : NiIOD NM ND ' SS~fd NI~fN : S)IMYN,q%t : (NI) ,~MOGN~,I,S qOOJ, :(MI) NOIiOMMMOD M~OH :A~ISN~G XI~4 : (~MPLL ~0 ~~H~IdH) ~A~ qO0~ qOOi NOEJ~flMN sa~Xq 8IOI :q~BuaI p~oma~ mnm!x~ sa~Xq E9 :q~BuaI p~oma~ mnm!ui~ smn~p 0g£60I 89 :~poD :Xm~mmns 5uypoo~p ~poo uoi~u~s~d~ 0000~E'0 = 5u~D~ds I~A~ ~I~ 000000'E900I = q~d~G pu~ ~IY~ 000000'0SEII = q~d~G ~S ~I!~ 0£ ~££ L~ ~ IO 06~ L~ £E9 :sp~ooa~ e~G I~Ol ~ SdD I 89 95~E NSS 5 SdD I 89 9~E NSq O'OI O'IS 08'6 :HcI CLrl~ : (S) X,LISODSIA CIDJ4 : (0/8~I) A.T, ISN.~CI C[FIN SNOI.T, ICINOD .~IOH,WMO~ O. 0 ' ~606 00S'8 : (.T,,4) H,T,d,~G ONISIfD S : (,T,,4) H,T,d,~G ONISlfD S : (NI) ,~ZIS ,T.I~ .~IOH tf,T,lfG DNISIfD C[NIf Z~IOH.qMO~ 0'00EI 0'£~EII 0'00EOI 0'S~EII 0'SSEII 96-ND_D-£E LIOI 96-NIq/P-EE 006I E'E 96-NflD-£E ~I.gI(I .T._ON)I ~Fu~I S ,T.£N)I ~IGZ ND lid .T._r'N)I %54O0 krg,T..T, AIMS ~'99III 0'68111 0'£PEII 0'P0EII 0'09111 HdAA ~OOi ~GOD %00~ HOGNE[A (NOiZO~ 0£ dOZ) ONIMIS %001 : (MHdM) GZMdS : (ig) T~AMMINI ~0~ :(IM) ~I%fAMZJAII DO~ dO~ :NO.L~.0~ NO M~ODO~ : NOIS%tMA ~fL~f(/ MZ(/~fZH DO~I 0'0060I 9PPg 0'6160I ~GZ 0'L£60I ~ZIG 0'LP60I D~G 0'8£80I MD TOOL ~OgI~ZA OOSE' I I A~S Z~I~ :MZ~WI1NONI~S ~OOi :MM~IN Ni1M a~P~Pd~s u7 un~ puw 'Builds IOO~ 'ss~d qo~ ~o~ ~Pp ~p~aq 6oI pu~ S~A~nD S~SS~d i~dZM ~%OH N~O Ming SI~ :sdX~ s! ~ sII~qns SdD I 89 ~-~d I 89 9P~E ND 0~ S-~d I 89 9PP~ ~DND 6I s-nd NI t 89 ~Qz qlfD ti M/NE I 89 ~QZ Ma 9I NNHO I 89 q~I~ GqIH 6 NNHO I 89 ~I~ NqIH 8 NNHO I 89 q~IG DOtH t pox sIO dAi dAi q~Bus~ sz!s n-~D A~D 6o% s~IuR ssIdmws spoD IOOl :ssn-~nD gE :Gl q~dap ad~L ~Nk~ H~d H~ ~LNO ( ~9 #.~aAJ.) (IHOD,gH .I.WNHO.~ ~ e 0'IL 0' 0'CL O'SOg 0'E£ S'I 000' S9'E MNOISG/kRfS 000' 006' 000' 0~0'I 08£' 080'1 O'SOE krH~ : MdOqS HIHON : A~9 MOHG/1Hd : Hd ~II-D : (k~~) NOIZk~HOq~XM dM : N/1OD N~ NM ND : (gI) ~fO(IN~IS TOOl : (XI) NOIJ.D,g%rHOD .g~IOH : AJ. I SN,gQ X I H.Lk~N : XIH3AfN :(~fAr~.~PLL gO qWN~.~HJ. Id~) ~dA.I. ~IO0.I. ~IO0.I. NOHJaqHN 22 SSN 2446 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 142 1018 BYTES * ~ 47 334 88 30 Tape File Start Depth = 11250.000000 Tape File End Depth = 10862.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 80884 datums Tape Subfile: 4 225 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 5 is typ_e: LIS 96/ 7/18 O1 **** REEL TRAILER **** 96/ 7/19 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 19 JLY 96 9:08a Elapsed execution time = 2.91 seconds. SYSTEM RETURN CODE = 0
