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197-250
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-05A PRUDHOE BAY UNIT R-05A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 R-05A 50-029-20380-01-00 197-250-0 W SPT 8124 1972500 2031 985 988 985 985 310 310 311 310 4YRTST P Adam Earl 6/19/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT R-05A Inspection Date: Tubing OA Packer Depth 84 2308 2261 2251IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622083049 BBL Pumped:3.2 BBL Returned:3 Wednesday, July 20, 2022 Page 1 of 1 STATE OF ALASKA - ' IEv O E ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS II IAI in Form 10-404 Revised 04/2017 4���r•&-rLt..y11\w17 RBDMS1L5^'JUN 12 2019 Submit Original Only 1. Operations Performed Abandon ❑ Plug Perforations 21 Fracture Stimulate ❑ Pull Tubing ❑ Operations squlr,(o m, �-a Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Pmglbkj Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ® Re-enter Susp Well ❑ Other: Liner Patch / Profile Mod 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number. 197-250 3, Address: P.O. Box 196612 Anchorage, 6. API Number 50-029-20380-01-00 AK 99519-6612 Stretigraphic ❑ Service0 7. Property Designation (Lease Number): ADL 028279 8. Well Name and Number PBU R -05A 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 12950 feet Plugs measured None feet true vertical 8799 feet Junk measured 12862 feet Effective Depth: measured 12882 feet Packer measured 8299 feet true vertical 8814 feet Packer true vertical 8122 feel Casing: Length: Size: MD: TVD. Burst. Collapse. Structural Conductor 80 20" 28-108 28-108 Surface 2626 13-3/8" 28-2654 28-2654 5380 2670 Intermediate 8855 9-5/8" 26-8881 26-8690 6870 4760 Liner 575 7" 8389-8964 8210-8771 8160 7020 Liner 4703 4-1/2" x 3-1/2" 8245-12948 8070 - 8799 8430/10160 7500 / 10530 Perforation Depth: Measured depth: 10560 - 12853 feet True vertical depth: 8924-8821 feet Tubing (size, grade, measured and true vertical depth) 7" 26# x 5-1/2" 17#, L-80 24-8396 24-8218 Packers and SSSV (type, measured and 5-1/2" TIW Packer 8299 8122 true vertical depth) No SSSV installed 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: 0 0 4758 50 450 Subsequent to operation: 0 0 2321 50 950 14. Attachments: inquired per28 nac 25 07025.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development ❑ Service m Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ WAG GINJ ❑ SUSP ❑ SPLUG ❑ Sundry Number or NIA if C.O. Exempt: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge- 318312 Authorized Name: Duong, Lea Contact Name: Duong, Lea Authorized Title: Senior Petroleum Engineer Contact Email: Lea.Duongatip.cem Dale: 6110111Contact Phone: +1 907 564 4840 Authorized Signature: Form 10-404 Revised 04/2017 4���r•&-rLt..y11\w17 RBDMS1L5^'JUN 12 2019 Submit Original Only ACTIVITYDATE ourvnv.nn #9 -1.75" Coil, 0.156" wt. bjective: Pull Patch, Set Lower Patch, Set Upper Patch. latch upper section of patch at 11281' CTMD. Pull free at CTU. Make up fishing BHA and RIH. RIH and over. POOH. 5/9/2019ntinued on WSR 5-10-19... #9 - 1.75" Coil, 0.156" wt. *"Cont. from WSR 5-9-19"' Objective: Pull Patch, Set Lower Patch, Set Upper Patch. H with fishing BHA #1. Retrieved Upper packer and additionaly spacer pipe. Able to trap in the master tool string. Make up Retrieval BHA and RIH. Chased wattempt ropped while attempting to recover with shortened 11274'. Latched up. Pooh. Upper packer and one spacer pipe recovered. ped upper packer down to ing 1/3 piece of element. MU & Rlh w/ Venturi. Unable to get past Entry guide. Pooh. Bullhead 70 bbls of MU & RIH w/ fishing BHA#2. RIH and did not appear to latch 3rd section of spacer pipe. 5/10/2019ntinued on WSR 5-11-19... #9 - 1.75" Coil, 0.156" wt. '**Cont. from WSR 5-10-19'** Objective: Pull Patch, Set Lower Patch, Set Upper Patch. of POOH and spacer pipe recovered. Make up tinue to attempt latch of 3rd spacer pipe section patch. Fshing BHA #3 and RIH. Latch up & pull lower anchor.Pooh and recover lower anchor. All intact. MU & RIH with 2.80" DJN. Tag bridge at 11704'. Able to jet thru and make it to TD at 12850'. Flag coil. Pooh. Change pack offs. Make up PDS 24 -arm extened reach caliper and RIH to 12820' CTMD. 5/11/2019 ...Continued on WSR 5-12-19... CTU #9 - 1.75" Coil, 0.156" wt. ***Cont. from WSR 5-11-19*'* Job Objective: Pull Patch, Set Lower Patch, Set Upper Patch. Log 24 arm extended reach caliper from 12820' to 8100', stopping to paint tie in flag at 11600'. POOH. Make Packer setting BHA with WFT Widepack LE packer, RIH. Confirm good data with 0' correction. up Unable to get thru Entry Guide. Pooh and reconfigure bha. Make up packer w/ muleshoe bottom. Same result, unable to get into liner. Pooh. Make up Packer setting BHA with WFT Widepack LE packer with centralizer, RIH enter liner, tie into flag. Set bottom packer at 11642' single knuckle, and heavily beveled mule shoe. and ME. POOH. ...Continued on WSR 5-13-19... '*"CAUTION: ENTRY GUIDE ON BOTTOM OF PACKER HAS MINIMAL TAPER FOR TOOLS TO BE /12/2019 PULLED THROUGH. ENSURE NO SQUARE EDGES ON TOOLS RUN THROUGH PATCH'*'* CTU #9 - 1.75" Coil, 0.156" wt. ***Cont. from WSR 5-12-19*" Job Objective: Pull Patch, Set Lower Patch, Set Upper Patch. POOH after setting lower packer for lower patch. Make up Lower Spacer Pipe BHA and RIH. Sting into lower [15/13/2019 packer and set spacer pipe. POOH. Make up upper packer bha and Rih. Sting into spacer pipe and set upper Make 2.4" GR/CCL carrier with 2.80" DJN and RIH. Tag top of packer. Lower patch set. Pooh. Trim pipe. up lower patch and log up to 8100', painting whitelorange tie-in flag at 11275'. ...Continued on WSR 5-14-19... CTU #9 - 1.75" Coil, 0.156" wt. *"Cont. from WSR 5-13-19'" Job Objective: Pull Patch, Set Lower Patch, Set Upper Patch. Continue GR/CCL log up to 8100', POOH. Confirm +8.5' coffection. Corrected lower patch set depth from 11596-1164,1%E4469 ment to element). Make up lower packer setting BHA and RIH. Tie into flag and set at 11341' mi -e ement. . Make up lower spacer pipe BHA and RIH. Sting into lower packer and set spacer pipe. Pooh. Make up upper spacer pipe BHA & RIH. Sting into lower spacer pipe and set upper spacer pipe. Pooh. Make up upper packer setting BHA with and RIH. Attempt to sting into upper spacer pipe. ...Continued on WSR 5-15-19... ""CAUTION: ENTRY GUIDE ON BOTTOM OF PACKER HAS MINIMAL TAPER FOR TOOLS TO BE 5/14/2019 PULLED THROUGH. ENSURE NO SQUARE EDGES ON TOOLS RUN THROUGH PATCH"" CTU #9 - 1.75" Coil, 0.156" wt. **'Cont. from WSR 5-14-19"* Job Objective: Pull Patch, Set Lower Patch, Set Upper Patch. section into upper spacer pipe and set upper patch packer with top at 11281'. Upper Latch upper packer patch now set from 11281-11342 (11285-11341 element to element). POOH. Only FP cap left on well as Pad Op to return to injection. RDMO CTU. 5/15/2019 '**Job Complete*** 6 X 7 CNV FLS .D= MCP/OY R= CU KERC = - _ _-- 54.05' = 45.40' =-- -. 19.43'3191'E n=8800, O 02/06/98 = 104' (id 12950'= 6 12739'n= O 8800'SS L3/8- CSG, 720, L-80 BUTT. D = 1 Ly,imum D = 1.750' 0 11281' 3-112" WFD PATCH S1/2 - FIE = 4.892' OF T LN = 8.681 - PERFORATION SUMIMRI' RB= LOG: MWDGWRESON 10102/98 ANGLE AT TOP PERF: 93' @ 10560' Nota: Defer to Production DB for hstarical pert data SIZE SPF NTH2VAL OpnlSqz SHOT SOZ 2-12' 6 10560 - 10581 O 02/06/98 2-12' 6 10842- 10863 O 02106198 CT LNR • 11000 - 11100 04/14/14 2-12' 6 11106-11127 O 02/06/98 2-12' 6 11297-11318 C 02/06/98 2-12' 6 11607-11628 C 02/06/98 2-12' 6 12228-12249 O 02/06/98 2-12' 6 12302-12323 O 02/06/98 2-12' 6 12408 - 12429 O 02/06/98 2-12' 6 12509- 12530 O 02/06/98 2-12' 6 12620-12641 O 02/06/98 2-12' 6 12706-12726 O 02/06/98 2-12' 6 12833-12853 0 02/06/98 -R17B INTERSEK;I u IN I na I- r va.AL r..+•..+•• -r SAFETY NOT6:1NEEL ANGLE> 70' @ 9230• "' H2S R -05A ���A�V��ONMI WHEN 1NAL COLLISION w/R-17 (SEE BB -OW) ape SSSV NIP ID = 5.962' ] TX5'BKR C2SS PKRlTI®KSLV,ID=4.375" � ]-F7- X 5-1 /2' XO ID = 4.892' (8GINR) 4.00- ] 7'X5 -1/2'X0, ID =2.938' 12' OTIS XA SLD SLV, ID = 4.562' BV C0MILNISSS/TLH PATCHSET/CLOSEPERF(1024/15) 518' X 5-12' TTN PF02 LATCH CB/JM D0VJMD MLLOUT EXT. D=4.75' BEHIND ADD® OKB. Rff. & BF EEEtI CT LNR 12' OPS X NIP, ID = 4.562' 12- 0115 XN NP MLL®, D=4.55' BEHIND=? 'SEAL ASSY w/XO,D CT LNR -5/8' X TLNR HGR D =? MILLOIJT NANOOW (RASA) 8964' - 8980' '-11342' 3-12' WFD PATCH w/ NO B4IRY GUDE D =1.75' (05/14/19) 11000' -11100' - COLLISION w/ R 17B (041041141 R-178 HAD AN BCP SET ABOVE COLLISION POINT 8. CMT PLUG TO PROVIDE ISOLATION BETWEEN WELLS 11596'-11641' 3-12' VUFD PATCH w/ NO ENTRY GD, D=1.75' (5/14/ 7- LNR 200, L-80 BUTT, I 9776- .0371 bpf, D=6.184' 3-1/2' LNR 9.34, L-80 STL, 0087 hof. D = 2.992' 12862•FISH- 9' SWS WEGHT / BAR W/ 1.75" SUCKER ROD BOX LOOKING UP PRUDHOE BAY UNIT WELL: R -05A pEF*AT No: 9972500 AH No: 50-029-20380-01 S� 32.712N, RI 3E. 707' FSL 8 1293' EWL BP Beploration (Alaska) BV C0MILNISSS/TLH PATCHSET/CLOSEPERF(1024/15) CB/JM D0VJMD rER;REV SET RBX GUDE(10/Ot/1814) JCF/JWD NESETWFDPATCWSET NL�I PACF:TONSJNJtM Pl1LLEDRBXGUDE(0522/19)OD/JMD ADD® OKB. Rff. & BF EEEtI 12862•FISH- 9' SWS WEGHT / BAR W/ 1.75" SUCKER ROD BOX LOOKING UP PRUDHOE BAY UNIT WELL: R -05A pEF*AT No: 9972500 AH No: 50-029-20380-01 S� 32.712N, RI 3E. 707' FSL 8 1293' EWL BP Beploration (Alaska) WELL LOG TRANSMITTAL 4905196087 To: Alaska Oil and Gas Conservation Comm. February 11, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: R -05A Run Date: 10/11/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 R -05A Digital Data (LAS), Digital Log file�E 1 CD Rom 50-029-20380-01 FEB 19 2019 A®GCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou, Date: Qy2Signed: 197250 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 12,2018 TO: Jim Regg P.I.Supervisor Ken(, 9/I51Ir; SUBJECT: Mechanical Integrity Tests l ( BP EXPLORATION(ALASKA)INC. R-05A FROM: Adam Earl PRUDHOE BAY UNIT R-05A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J � NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-05A API Well Number 50-029-20380-01-00 Inspector Name: Adam Earl Permit Number: 197-250-0 Inspection Date: 6/6/2018 Insp Num: mitAGE180606142001 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-05A Type Inj W ' TVD 8124 Tubing 765 767 770 776 - PTD 1972500 Type Test SPT Test psi 2031 IA 1 2501 2486 " 2489 BBL Pumped: 3.8 BBL Returned: 3.3 OA 660 - 657 - 660 662 Interval 4YRTST P/F P Notes: MIT-IA SCANNE0 JUN 2 2" u Pae1of1 Tuesday,June 12,2018 g STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate m Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Straddle Patch WI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 197-250 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20380-01-00 7. Property Designation(Lease Number): ADL 0028279 8. Well Name and Number: PBU R-05A 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 12950 feet Plugs measuredfeet RECEIVED true vertical 8799 feet Junk measured 12862 feet DEC 10 2015 Effective Depth: measured 12882 feet Packer measured 8298 feet true vertical 8814 feet Packer true vertical 8121.53 feet ADCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2634 13-3/8"72#L-80 26-2660 26-2659 4930 2670 Intermediate 8864 9-5/8"47#L-80 24-8888 24-8697 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet �� M„ to �l i(,' True vertical depth: See Attachment feet { Diialti ` ,''I .� Tubing(size,grade,measured and true vertical depth) See Attachment !s See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10560'-12853'. Treatment descriptions including volumes used and final pressure: 43 Bbls DAD Acid,12%HCL Acid,17 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1692 300 457 - Subsequent to operation: 1000 0 2002 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 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.O.Exempt: 315-443 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature /4 a tAl Phone +1 907 564 4424 Date 12/9/15 Form 10-404 Revised 5/2015 V Ti-- //10 ii L RBDMS DEC 15 20l1 Submit Original Only / 1---. .‘. • • a) - 000 0 _OO • IC-O O Oco N DD I� LO O O 4/ N p N f. to CO V g 0 0 0 0 0 0 0 O i M N- M (O O OD Nr r N N- m CO M -- M I,- CD ,CA N- C) N- LC) O O In CD CO O) 00 N- r- CO CO O I- r- O N N CO 00 00 00 OD OD • i I i I i i i H O CO LU I- CO NI- 00 r- N N- 01 N N O O N N O CO 00 00 OD G) OOOCO � OOO) O CO 00 4 O CO 41 00 r- CO 00 N N CA N M N CO 00a0 00 00 V C i i i i i I I i QI- up V LU O)) N CD a} IN N N N N M N N OD CO OD OD 1▪.2 O O O O O 00 00 co ' J J 00 00 = N 0 4* Up M J --I 4* U) X I- cq �# •03 O -0N N \O 00 - CV U N - N Ch In N CD ' M LU CAO M CQO N CD ON 00 CO 00 CO M N d N 00 - u) a0 J W OC 0 0 Q CW Lj • U Ua z z zWWWmm p D H z_ z_ z_ D D U (/) Z J J J H H • • 117 0 0 m 6 co co N T- Nr N CO 1.110 CO co O M 0 0 OO M O O) v- 0) Q N N M v- Cfl 6 M CO M U7 00 O O N 0) O N M N O 00 CO N o 0) 00 0) 0) 0) 0) 0) 0) 00 00 CO 00 ❑ 00 CO 00 00 CO CO CO CO 00 00 OD M N f1 0 1- a- 1.I) V N 0) 1.n N- 1.n CO — LO CO t O O 0) C) r) — O 0) 0) M LO M 0- .4 Ni O 0) ao 0) O N LC) 0 O N 0) O v- V co CV O 07 N 1.10 N w ❑ 0) CO 0) 0) 0) 0) 0) 0) co co 00 co > ❑ ao W 0000aoaoUO000aoaoao 0 > 2 w c CD ❑ w Z w w p w o F J w ggY U o 00 W Y Y g m _ J L"-" www w 00 CO N N- N V N N OM N C1)J J J ¢ ¢ (n cc 41 f2 LU OO — M CO N M V 1.f) CO N 00 ¢ ¢ ¢ W ❑_ !L Z C o 0 O - - - N N N N N N N U _10 w ❑ Z Z Z Jp pJ J J ,„ ¢ ¢ ¢ _ ❑ ❑ a U O U W Z O Z W W W 0_ (- ¢ J ¢ (.) Q 2 2 2 O Cl) cn Cl) u) cn 4-• L) 4.1 0. 0 F- = t O N CO N- N- 00 N 00 0) O 1.17 M Q CO O 0) O N O O O N O M O 0 CO 00 — N CO N M NT I1) CO N- 00 ... ❑ O O — — a- N CV N N N N N caa 0 L C) CI! (n = H O d J d 22 20 co m co co co w a 0 U �o▪ W W W H W W W W W W W W ai M M M W M M a M d M M M a 0 a) ro 0 a� I- 0 000000 = wmwmoowww o 0 rn m m o m m m m m m m rn c 0) 0) 0) N O O O 0) 0) 0) 0) 0) Z W ¢ W W N � N CCOO M CCOO N CSO CO CO CO CO CO CO ❑ d W U O W W W 0 N N N O N N N N N N N N Z 0_ ¢ a J J J J D J J 0 ¢ ¢ ❑_ N W U 1.¢L CO O N co co z < < < < < < < < < < < < z 1.n 1.0 Ln LU 1.n LU 1.0 1.0 1.0 1.17 1.0 1.0 65o 0 0 0 0 0 0 0 0 0 0 o m a a a 0 -10wCNl w a � � � � � tht � � � � � ¢ ¢ m W u. cn fn a CC • • Packers and SSV's Attachment PBU R-05A SW Name Type MD TVD Depscription R-05A PACKER 8244.46 8069.6 5" Baker C-2 SS Packer R-05A TBG PACKER 8297.69 8121.53 5-1/2"TIW Packer • • • I- 0 D E o C o o m cu %.-.. 1_ 3 5_ _ a) L U • 3 QOCO coo N a) .? 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U N m -� -aw • o c . c- - Q( a) mU Q O wv _0 aco ((i):5a) m N +:+ N Cl) CO p O U J UN aN O aj C CD • c N O '- CU QcUqO Q C in = U (}0 1 W Q E . c7 c Q c — o o � m 2 < c i • • co C (13 O E coE a) L Q- T 0- u 0 < 5 0o reo o o a a 0 a) co a) O O Oc U JJ O m Y -6 J 2 D o J U 2 V• o o O r U Q - E �c L L o ,C V U o Q N U o co CO O u) O d' O M r,, O O 00 CO OD Is- x- Ln Ifdt= 6 X 7 CM/ELS FLS NOTES:WELL ANGLE>70°@ 9230'"'H2S 1�= ""�'°" �` R 0 5A _. .. ._...._...... __._._...____._._o_._ry GS AVERAGE 125 ppm WHEN ON MI"'WELL AC,'TUATOR= BAKERC REQUIRES A SSSV WHEN ON MI"'04/04/14 0KB.ELE/- 54 COLLISION w/R-17(SEE BEI "' BF.ELEV__ 24.95' 1 KOP= 3191' Max Angle= 104`@ 12950' I 2013' —17"OTIS FIFE SSSV NP,D=5.962' Datum MD= 12739' Datum TVD= 8800'SS 2585' �9 5/8'DV FKR 133/8'CSG,72#,L-80 BUR,D=12.347' H 2663' , Minimum ID = 2.992" @ 8267' TOP OF 3-1/2" LINER 8245' —T X 5'BKR C2SS R(R/T1E6K SLV,D=4.375' 7'TBG,26#,L-80 U4S,.0383 bpf,D=6,276' — 8257 8252' —7'X 5-1/2"XO,D=4.892'(BEHIND CT LNR) 8267' —4-1/2'X3-112'xo, 8259' —7-X 5-12'XO,D=2.938' 8265' —5-112 OTIS XA SLD SLV,D=4.562' 1 o id 8300' —9-5/8"X 5-1/2'TIWPKR LATCH Z g &MLLOUT EXT,D=4.75" BEHIND CT LNR I I 8352' H 5-12'OTIS x NP,D=4.562' , 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892' -1---1-37--!-:-1-------- 875' \ I 8373' --15-12"OTIS XN NP PALLED,D=4.55" { 8391' H7"SEAL ASSY w/XO,D=? BEHIND TOP OF 7'LNR —I 8397' CT LNR 8397' —9-5/8'X 7'LNR HGR D=? 9-5/8'CSG,47#,L-80 BUTT,D=8.681' - 8890' TOP OF WHPSTOCK — 8966' TOP OF CN3MNBYT — 9013' II, MLLOUT WINDOW(R-05A) 8964'-8980" PERFORATION SLIMAARY R8 LOG:AMVDC,R/RES ON 10/02/98 11288'-11338'CTM H3-1/2"VVFD PATCH(10/24/15),D= 1.75" • ANGLE AT TOP PERF:93'@ 10560' ,� 11000'-11100'- COLLISION w 1 R 17B Note:Refer to Production DB for historical pert data �1�1�1�1�1�1�1' SIZE SPF MTERVAL Opn/Sgz SHOT SOZ 01111111 ` (04/04/14)R-17B HADAN ECP SET 11111111 4; S X111/111 LIABOVE COLLISION POINT& CMT PLUG 2-12' 6 10560- 10581 0 02/06/9811111111111111 , TO PRDVIDE ISOLATION BETWEEN WELLS 2-1/2" 6 10842- 10863 0 02/06/98 11111111 X11111111111111 • 11000-11100 • 04/14/14 4111111 2-1/2' 6 11106- 11127 0 02/06/98 •i1i1�1i1�9 e e S 2-1/2' 6 11297-11318 C 02/06/98 5, 12862' —FISH-9'SVVS WEIGHT 2-1/2" 6 11607-11628 0 02/06/98 , BAR VV/1.75' SUCKER 2-112' 6 1778- 12249 0 02/06/98 T LIN,29#,L-80 BUTT, — 9775' ROD BOX LOOKNNG UP 2-1/2' 6 12302- 12323 0 02/06/98 ,0371 bpf,ID=6.184' 2-1/2" 6 12408- 12429 0 02/06/98 el., ,wilkik2-1/2' 6 12509-12530 0 02/06/98 e�i�t 2-1/2" 6 12620- 12641 0 02/06/98 PBTD — 12887 \�t�i 2-1/2' 6 12706- 12726 0 02/06/98 �►! 12950' —1 TD 2-12' 6 12833- 12853 0 02/06/98 3-12'LNR,9.3#,L-80 STL, --I 12948' .0087 bpf,D=2.992' •R-17B INTERSECTS) IN THS INTERNAL(04104114) DATE REV BY COM%U'ITS DATE REV BY COMMtENTS PRU DHOE BAY UNIT 09111/79 ORIGINAL COMPLETION 04/15/14 PJC ACC/TONAL W13S CORRECTIONS WELL; R-05A r 11/89 RWO 03/09/15 PJC API NO CORRECTION PERMT No:'1972500 02/08/98 SIDETRACK COMPLETION 12/03/15 MSS(TLH PATCH SET/CLOSE FT3RF(10/24/15) AR No: 50-029-20380-01 03/12/02 RN/TP CORRECTIONS CTIONS SEC 32,112N,R13E,70T FSL 8 1293'EWA_ 05/21/12 RAJ/JAI t RI±CIO(05/17/12) 04/14/14 JUPJC COLLISION w/R-17B(4/4/14) BP Exploration(Alaska) • of Tif \v/j, THE STATE � Alaska Oil and Gas s of JA ftJ<j\ , Conservation Commission � t_ _ � - 333 West Seventh Avenue 2151,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 . Main: 907 279 1433 ALA`Itj. Fax: 907.276 7542 www.aogcc.alaska gov Cale Peru some t''i 5vPetroleum Engineer I q 7 f BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-05A Sundry Number: 315-443 Dear Mr. Peru: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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 P oerster Chair DATED this24 d y of July, 2015 Encl. STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COP 310N O 7 7 l S APPLICATION FOR SUNDRY APPRL..ALS JUL 2 1 2 10 20 AAC 25.280 � • 1. Type of Request: Abandon 0 Plug Perforations Ed - Fracture Stimulate 0 Pull Tubing 0 \O I� , hutdown 0 Suspend 0 Perforate 0 Other Stimulate ® Alter Casing 0 Change Approv�e/d Program!'❑, �` Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other HG/QCi ' StrMv.Ln /Vb-iIli paten 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 197-250• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612Stratigraphic 0 Service 0 6. API Number: 50-029-20380-01-00 . 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 ® PBU R-05A . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028279 ' PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12950 ' 8799 • 12882 8814 12862 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 27-107 26-106 0 0 Surface 2634 13-3/8"72#L-80 26-2660 26-2659 4930 2670 Intermediate 8864 9-5/8"47#L-80 24-8888 24-8697 6870 4760 Production Liner 4703 4.5"x 3.5" 8244-12948 8070-8799 8430/10160 7500/10530 Liner 586 7"29#L-80 8394-8980 8216-8787 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10560-12853 , 8924.01-8820.98 7"x 5.5" L-80/L-80 22'-8389' Packers and SSSV Type. 5"Baker C-2 SS Packer/5.5"TIW Packer Packers and SSSV MD(ft)and ND(ft): 8244/8298;8069.6/8121.53 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program ® Exploratory 0 Stratigraphic 0 Development 0 Service El 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 00 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 Peru,Cale Email Cale.Peru@bp.com Printed Name Peru,Cale Title Petroleum Engineer r Signature Phone 907.564.4522 Date 7/?! 1 /5 COMMISSION USE ONLY t Conditions of approval:Notify Commission so that a representative may witness Sundry Number. 316- 413 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes❑ No d Subsequent Form Required: 16 - 4- APPROVED BYTHE Approved by: " ' , _ COMMISSIONER COMMISSION Date: 7_ /�- TLL`a' Zz i� RBDM AUG - 2 2015 ORIGINAL 1, a/./> Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: R-05A Well Type: WAG Injection Well API Number: 50-029-20380-01 Well Activity Conventional 4 Classification: Activity Description: r Acidize toe perfs/patch theif zone Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Cale Peru Contact numbers: (907) 564-4522 (832)316-5774 Well Intervention Engineer: Michael Hibbert Contact numbers: (907)564-4351 (907) 903-5990 Lead Engineer: Dan Robertson Contact numbers: (907) 564-5546 (907) 529-5818 Date Created: July 9, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut (%) (Mscf/Day) (psi) 6/24/2015 3,000 700 Current Status: Operable Shut In Inclination>70°at Depth(ft) 9,230' MD Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 12,950' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 34° 9,485' MD Reservoir pressure(date, psig) analog 3,300 psi Minimum ID and Depth 2.992"at 8257' Reservoir Temp,F 200° F Shut-in Wellhead Pressure Unknown, probably near 0 Known mech. integrity problems(specifics) Coil: mill cement, SBG, (PROF, Caliper. Summary: RIH with Milling BHA: CTC(2.25"x1.37'), DBPV(2.13"x1.38'), G- force Jar(2.12x6.03'), 5/8"ball disco(2.13"x1.56'), 1/2"ball Circ sub (2.13"x1.01'), Mud Motor(2.13"x 8.16'), String Reamer(2.80"x1.09'), Parabolic mill (2.80"x .54'). Last downhole operation (date, 3/4/2015 Had little motor work, made it to coil lock up at 12,590'. operation) Ran iProf, made it to coil lock up at 12,515'. Caliper did identify a hole where the drill bit grazed the top of the liner at 11,081'. SL latest job 6/5/2014: drift to dev with 2.79"cent, 1.75"sample bailer. Dev out at 9271' SLM. Milling BHA: CTC(2.25"x1.37'), DBPV(2.13"x1.38'), G-force Most recent TD tag(date,depth, 3/4/2015 12,590' MD Jar(2.12x6.03'), 5/8"ball disco(2.13"x1.56'), 1/2"ball Circ toolstring OD) sub(2.13"x1.01'), Mud Motor(2.13"x 8.16'), String Reamer (2.80"x1.09'), Parabolic mill (2.80"x .54'). Surface Kit Fit-for-Service? YES If No,Why? Online less than 1 year ago. Comments,well history, R-05Ai was drilled in 1998, since that time most of its injected water has gone into 2 thief zones (11,106- background information, 11,127& 11,297-11,318') near the heal of the well.When drilled its highest resistivity was in the toe etc: portion of the well, North of the fault.The purpose of this job is to shut off the existing thief zone and establish injection in the perfs that have not previously seen water, especially the toe perfs. When drilling R17B, R05Ai was intersected at 11,107'.The P&A kit and cement combined with coil milling debris has shut off that set of perfs(11,106-11,127'). Well Intervention Details Suspected Well Problem: Conformance issue/thief zone. Specific Intervention or Well Objectives: 1 Establish toe only injection(shut off perfs above 12,000'). 2 3 Key risks,critical issues: Mitigation plan: Previous coil job passed restriction with 2.80"mill going 1 Liner damage at 11,107', may have problems getting past. down with little motor work. No issues noted coming back through. Reaching TD. Coil has locked up between 12,500-12,600' on multiple runs last job with no agitator.We need to get deeper 2 than that to treat the toe perfs with acid and potentially to do a Plan to use agitator for initial drift, possible FCO and acid. FCO. Bottom of perfs at 12,853' Review burst calcs. If it is necessary to apply more than 3 Burst 7"tbg if we lock up during final injectivity test. 2000 psi on 7"tbg,apply 1000 psi on IA first. 2015 caliper shows 7"max pen is 36%. Summary Service Line Activity Step# 1 S D&T at coil WSL descretion. 2 C Injectivity test. Drift with agitator/JSN, cngt FCO, spot SBG across toe perfs. Set treater packer, injectivity test, pump Dad acid, injectivity test. Set 2 run patch, injectivity test. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Drift and tag at coil WSL descretion. Recently drifted with coil, no GLM's, SL deviates out at 9270'. 1)drift to PBTD(12,850')with tempress, GR/CCL 2.75"JSN (same OD as treater packer that will be run later). Modeling and most recent coil job indicate lock up at 12,500'with no lube or agitator.We need to get to PBTD so plan to include tempress in initial drift. Injectivity test down backside on way down. Don't exceed 2000 psi. a)pump 360 bbl of 1c/0 KCL to fluid pack the well with water. 2 C b)pump at 1,3,5 bpm. Record pressure when it stabalizes. 2) FCO(fluff and stuff) if necessary. Desired clean out depth 12,853'. Minimum cleanout depth 12,726'. Jet with SBG (order 100 bbl©160F),take small bites,chase fill above theif zone top at 11,297'to ensure debris goes into formation, if it is necessary to exceed 2000 psi on the 7"tbg put 1000 psi on the IA first due to 7"tbg condition. Do not exceed 3000 psi 7"tbg pressure. 3)Jet remaining SBG across toe perfs(12,228 to 12,853'). Let soak for 3 hr. With nozzle at bottom of perfs (12,850')jet 50 bbl of 1% KCL chasing it up(ct/tbg annulus closed), POOH. Purpose:ensure SBG is displaced from toe before acid treatment, if we over displace down backside the water will probably just go into the theif zone and acid may contact SBG in toe during next step. 4) MU treater packer(2-1/8"FH 1 trip),tempress(at WSL descretion based on: previous runs/pump rates, lubricator space, ability to drop ball for treater packer)and JSN. Set treater packer at 12,000' (+or-100'). Pre acid injectivity test: Pump 1% KCL down coil at max rate, —2 bpm. Record pressure.Volume: —reel volume. 5) Pump 40 bbl's of Dad acid down coil. Recipe: 90% HCL to 10% Xylene, standard additives, see attached tab(L80, 220F). (no rubber in tempress, not an issue to pump acid through it if WSL elected to run tempress). Let soak 30 mins. 6) Post acid injectivity test: Pump 1% KCL down coil at max rate. Record pressure when it stabalizes. Don't exceed 3500 psi. 7) Once stable pressure/rate is obtained release treater packer, continue to over flush acid with a grand total(counting injectivity test)of 50 bbl of 1% KCL while POOH. 8) Drift for 3 run patch (OD 2.78", ID 1.812", longest segment 28'). Include GR/CCL,JSN. Flag pipe at 11,200'. POOH 9) MU lower packer. RIH to flag at 11,200' make depth correction. Set lower element at 11,338' by dropping ball. POOH. MU middle section. Latch into lower section. POOH. MU upper section. Set upper element at 11,288'. , 10) Perform injectivity test down backside while POOH. 1,3,5 bpm. Record stabalized pressures, don't exceed 2000 psi. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 3000 Expected Production Rates: FTP(psi): 750? Choke setting: 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: TREE= 6 X 7 C M/FLS SAFETY NOTE'SANELL ANGLE>70'fl 8238•"'MSWELLHEAD= Or R�,©5A . READINGS AVERAGE 126 ppm 18881 ON MI^'WELL ACTUATOR= BAKER REQUIRES A SSSV WREN ON 111"""04/04/14 OICB.E EV= 54' COLLISION w/R-17(S ea-ow) " BF.ELEV= 24.95 1 1 IMP= 3191' 1.1§x Angie= 104'822 12950'. ' { 2013• }-.{r o-i RPB SSSV Pig,D=5 967 J Gahm IVO= 12739 Detum TVD- 8800'SS Q — ; 2686 0-318•DV wcR 13-3r8"CSG,728,L-80 BUTT,o=12-34r 2683'�J Minimum ID— 2.992" a 8257' TOP OF 3-112"LINER , 824{6' H7'X S BKR(2SS PW2/ilf$K SUV,D"4..375 I `r TBG 280,1-80 L1t8,.0383 MA.D=8.278' — 6262' }---118262' —7'X 5.117•xo,ID=4.892'(BMW CT LNR) l 82ST —{4-1/2 X 3-112'XO.O=4,00' 8269' }—{7•X5-117 XO,ID=2938'{ i 1 { 8296' H5-1/2-OTISXASLDSLV.0=4.382- 8300' 1—9-5/8'X 5-117 TNVRCR LATCH 14 Iti BEHIND 8 MEXT.()T•D=4.75' CT LNR I fIss7 H5-1/7 OTR X NP D=4 38r { 1 '1117 TBG,178,1-80,0232 kpl,D=4.892' 8376 NTS H5-1?OTB XII NPI LLIDt D"4.55 } I —I 8391' rsFALAssYwBEHINDrxo,o=�� CT LNR 1I TOPOF r LNR 8317' . 1 8397 H9-518'x r LN4 MGR D=7 { 1 9-5/8•CSG,4 7#,L-80 BUTT,D=6-881• H 8890' I prof.a#1* TLIL H 4864' ' 1111. TOP CF CEMENT 9013' MLLOUT~OW(R-05A) 8904'-8980' R38FORATDN SUMLMRY REF LOG.kWIUO IIIM ON 10/02/98 L ANGLE AI TOP PERF 93-g 1056G �J� Y' _.�..��• . 11000'-11100'- COLLISION w/R-178 MAW Refer to Production CO for tYtbrleal part date •�+'4'4+0'4'4'4' ,'l �� (04104114)tt 178 MNDAN QP SET SIZE SPF 560-toL CprdSgz SI-OT SOZ •4'4�4'4�4�4,4'1 •, ABOVE COLUSIONPOINTIL CUT PLUG 2-1? 6 10580-10581 O 02S08f90 4/4140101 2-112' 8 10842-10883 0 02108198 01414010 ♦ TO PRC7V ISOLATION BETWEEN WELLS • • 11080-HU • 04/14/14 +014144414411101 • 2-i? 8 11106-11127 0 02/06198 P414141444144401 9994999/ • 12867 FISH-Er SINS WEIGHT 2-1? 6 11297-11318 0 02108198 2-1/T 6 11607-11628 0 02/06198 ,, BAR VN'1.75' 8LICILH4 2-1/T 8 12228-12249 0 02/06/98 — 1 RDD BOX LOOKING LP 2-1? 6 12302-12323 0 02/08/96 r LNR,298.L-80 BUTT. � 9775 I 2.1/7 8 12408 12429 0 027/06198 .0371 bp/,D=8.164' 2-112' 6 12509-12530 0 02/06/98 \rye 2-1/7 8 12620-12641 0 02/06/98 FF-13T5-1-1--12887vaA 2-1? 8 12706-12726 0 02/06/98 `w:: 113 2-1/2' 6 12833-12853 0 0210E998 12969 3-1/2•LNR 9.34.L-80 STL —1 12948' 1 '0-118 13S ® INTECTIN THIS INTERVAL(04/04/14) 0067 ltpt,0=2997. DATE REI/BY COMMENTS DATE REV BY COMMENTS FRUCHOE BAY(MT 09111171 ORIGINAL COMPLETION 04/14/14 JI/PJC COLLISION w/R-179(4/4/14) WELL: R-05A ' 11189 RWO 04/15/14 PJC ALUD)NALVOSS ODRRECDONS PERMTP '1972500 0210/191 SIDETRACK COMPLETION 04/17/14 VA04 PJC SET SSSV NSEtT(4/17/14) AR No. 50-029-20380-01 03/12/02 R1YTP CORRECTIONS 06/12/14 CJWJMD FUJ.DSSSV INSERT(06105/14) SEC 32,T12N,R13E.70T FSL&1293'QM_ 01/18/12 TM4/JMD(ADDED MRS SAFETY NOTE 03/09/15 PJC AR NO CORRECTION I 05/21/12 RVVY.84J TREE CYO(05/17/12) BP Er Moralfoa(Alaska) Injector g Techlog �► l�/l l 11110 Prosect.PBU WWF Well: R-05A Author. Laura J.Larion Scale: 1:4500 Date:5/18/2015 Ei.d.164 X 633111126 SPLA Ore$1164147 000090 Cowley USA Eledea1oawn 106 Y 517104T3 Conp4bn001 11666246661610 Ask$Prudhoe Say AM ChM 12666 Lova.*-1Y,106p1 SMus NW 1001/ Coal 000-NAMV APT ustuo_70.261671 Ow**Mx* Canopy IMPXA N.._ S aESTafi 1 - - 0 API 20402 PE Notes cc t; Rae*Of Penetration Tvcss MO RES_AMEO rBEST.ROP (FEET) (FEET) ex Int(eu.TVoss 8152.111011101 O O ow ` 1:1500 1:.4500 k' 0950 ft 3 #..# .4 OHMM }00 1311A zniii qK - $000 I w__ -1020 . •1035 %moo , l -15w0- . I -1030'- I !Z 10$ t10000• e61s 74 ews --44i4 -1111 • -ate MO y 10500-.,. arts /swot r..., abs • -ass , . rte_ abs -MKS ,:us.711400- 11_ y pS5 on* , ___ Shut off theif. 100%of water .470+ entering here. .inn . "SS" .11500 I aas 1000 woo -1010. am- -1010 , •1000 a,t - 0 - mom 410.' est 14r 02002 +61s r . -ales; mac . roe >` -alto; alma .17ss . ono , milm4 mL ---•-11715 .. Could not find a log with collars that was 4" per 100'. ::, .,,..„....,,.... ........,..„..............., .,......_,. .,,,. ,,.. F i .1.: :, „,,,,. ...„.„,......,,,:„,,,,,„„.7,,,,,,..„-„, L ,. ..,. . . . . ,. . , .....,. . . in . COMPANY: BP Exploration (Alaska)! ' c . 4 , WELL: 05A R- FINAL _ FIELD Prudhoe Prudhoe Bay BOROUGH: North SlopesTATE. Alaska SLIM ACCESS . , , . t '' I ' NEUTRON I:TENSITY' f 1 Schhxylberger ___ a_ • 141. i-1-; . < ,--- . R ,..... ' 707#461_c 8. •f „5,, G,L, , 9 . ,, I 41:'9JFF'' '' ';,, .,' ' , ' ,,..i .,9 :.g• ' , -&i 8 to _ a- • •,..• a F.. _ „ . i 0 , .. ,... ; 0- t'-- rt cn -4 00 Measured5,.. I , , a „,,,,",„"2; „:-„,„,i'. •• , 4,‘„,10,,,,,,„,;",,, ,-,-,-2 - „ , , „,,,, „,,,,,,,,,,,„„, ,L,",,f,.:"i . mo. : i, • 2 "6 8 t 8 ' 5c-4-129-.,...• ,• .1 m 2N. 13E 1 . 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FM:24 CUST 01-Feb-1998 10.51 12594.0 FT 8900.0 FT I i OP System Version: 8C0-609 MCM iSAIT A SPCWX-934 SSLT-AA SPCWX-934 SPCS-13 APCW-97Q2 SLDT-A APCW-9702 CNT S SPCWX-934 STGC-A APCW-9702 , - PIP SUMMARY - - Olt Time Mark Every .60 S SLOT Density Quality Factor(ORM° SLOT) _ 0 (----) -0.25 SLOT Pef(PEF SLOT) n 1 -I 10 SPCS C4Fer 1RCALSPCSJ SLOT Bulk Density RH013 SLOT) 10 1.65 (G C3) 2 65 ::-",;" ,1";;;:.,-, , - '''.•y(GR STGC) Neutron Porosity t1PHI1 0 , • . 1 s ---4. j1 pa • , '''.1; • -1.1: ' ' �200 ! ..�.__ k .._;:tin • • S 4 iE PPPi 7.. `T t '''''''"'‘,,, ' 1. Y j 113O( , l . _ 1. ( _ . __ , ___ , , ,... — I , -t , , ,yr,,,,gi-7,As,,, ,,.4. . ,„,„ „ ,,, , , , ..,, , . , _ , , ,.. , ..,,,,,„ 1.,,,,,,....,„„„,„ ,. , ,4.,. ,,„„ , 1 i c to , 1 a ;" A i } y r4 I i 11 , i#t $ U r i-- g - .. C f d ¢ • 11' r.::,`"i r§�° QQ , :' .:,,,e, ' ., .".----a---- .3"1"-.1,W"'.._H.,.- ' : 3tCi . SPC j t ({ .2 4'22 ' \ a 3 e 1 ri — - , t A ,. , : - !IC,: i ,-, 1, ' ' ,; 5 ''' ' '-' / . 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Not the standard scale cel cos�.,iutiT' INJECTIONPROFILE ..'t'Ad'*cllkir; " 1,. . %.S.4"c i�lVt T GR - '3?E55 TES- •C,FJ 06-Mar-2015 PaoAc wi,E IA NT iOsic SEE i*Yi* . _.-.-F AL Company BP EXPLORATION ALAB� . C. co Well R - 05A to cci Field PRUDHOE BAY c Borough State ALASKA Surface Ltafort L2 <mo p tl) co '- _-M w o to 706,83` FSL. & 1,293-01' FW... CL , 2 o co z4 ea ' , m tY t1 z Q SEC. 32 Tl�'VP: 12N _t�sE: 13E _ = r t cis Css Pyr-?anent C;..n< f L _ .._ __. � t3.0 . 4.� a. — s 2 .4.:et) u 1 ?iea d Flom RKB 54.f3 T.� Perm- C <; 'Pit' 4$ ° ii c ':-, amber 5{}-029-2038{ 3! ' t 2N , Cai "e 06 Mar-2015 One — — ... 12.8$2' P -_8171 NatT -.. __ ._.__.� 12 5� • 3''x' kit `. 4=r f, n,i<., n9�`"c''. ._..-._.......—_.__..,_water _.,.. g �.- PRINT 'f :: . ... _ - _ FINAL x ,✓ as✓y * rr-z t 1 / 5 3 i.rj/ri/ f s a <' _ /1//'4 i%Cyt ��/� j w ”`4,190,114-1 L / �;rs -v.c„ 10335' E.dt 1 �f ,.,..4,4'4 Af 4 +,F t' ,."1-71_,..., �fC.v, ...-04 M.'Y q »x r ,/, x i` To ' ,� L � "�r rr / ; r i' t/ "/',/ h/ immitommigAra ; /i f""'''7 ..-44., '' Fj�� '"' .„'/i'Jk r ,. -k,L'`,.:a. 'mkr 3 s r . „ `fir,','// P �* /i!;,: ze.%'/ .S yr4 v;" /"fir/ 'y,'� '`a f u ,y� ,,;.,f, 414.17'.4"-"'' ''. �tt`'.�:r"A".H- `s '. :.a ,. ' „,,,,,,-*v.--....,-.4, ,,„'' ? xrQc rtJ! j 'f 4A? ; - gjFM�yi/��” /H�/ . axaacrA, zax M '�y` yYY sy- g/ s' s+ �{ . t. #.,i -f^4° 4,7, y " r -,4, t.-4'„',,,,,,,-• i*/x . ` tvr 't ,4 } 1 / �r 4'"% i/ ,i i' „N 2/ /. r� r 7 y. .xy 4 > .w . . . , i . . , . L—Pressure (Mn 80) , - . . . , ilk 10800 . . , . . . ... 1 , 44—TeMperature(iiwn ao) io--Tempereture tdvawro.,*,,R) -- , 0- t • 11000 . ' ' 1 , ( . , . . . i ' —, „ . "...Alt 41.. 3(1, ---.1 . . 1 1 100 - ' ' 1 1 .... .. . , $74--Spitrotler(414vive4134) ,i 7 . , . . . . (- 1 ! . , . 1 . 112043 . . , . ; . „,— ! „. . , . ,..„ .. '&”' 1 I.! i I . • ..... 1 1 1500 . , . .._ -, . . ... ,. 1/000 , ....- ,, 1 ..,c_,. _.„ • .--1"4*--. 1 1 , - ”" i 117 , - , . + , •=tv ,,. 1 - , 1111 . , I ', • • _ ,, ! , ...... I ', 11'40) '.,, 7-.:: ;-,: „,..-,,.• :.l'..."'.,,,:,.....'. '. , i- . ' ' - ':-,' ' . , 1 _.... I '' , ...,.... i , 12000 ---.7c- alc..,..., . . - ic„__,Iri•-, ---1_,,, I .' I ..- . •-._.,,,S"''-. ''))4.4 — „ .i_-_ .. ' - f .• I . CO 1- cL LU LU LU LU LU LU 2r LU 2r Ui 2r W WW W W W W W W W W W `$ a 0. a a 0. 0. a 0. a a 0. 0 0 0 im (`,1 s 0 0 A M N I� co O 0 0 0 0) M r) O)p1 O)O .+N O 1p M M Or OO C10 ON a'N ON Na ON ON 0M Na ON 2'')u7 0-- -.nu-, 0 00 �a NNM O �O ) 0N.N 0('?r 0�a O�+ln 0 N 50 O ,. 0al00 0 00 O O .+,.: .-1,4* .-in,..7 N N N N Nr; Nr; N N N N N N 5 a �N �N :N -N ' ' : •v • �N a : - . $;o a 4 r O p M(.j 14,^ CO Z. CO c7 CO O+ M N1 O)O) O)g; N.y 50)O M(^1 00 V O ON O).,y ON Na ON ON 0M N,ze. ON MIl1 as 0�Ln 0�O3 N, N NM OOO 0NN 0^?M 0af I ^ n 0NN co� M • 0 00 0a N N N NNNNNNNNNN NN NNS3 a- a. N v N v N v N v N v N N N vN a Ovv vv vv N, I * 1 * * 1F * # * tt I * * * Ne O M I,*; —O m O M.. O) C) a 50 M rq O O M I� O O) O o 00 N O) 0 M 0 O) 0 0 N N 0 10 M M M O Lr1 CO 000 O 0 N N 0 N N 0 O N 0 N C 0 M N 0 V N 0 Lf1 M 0 40 Cr 0 N N0 CO Lr O Z CJ N'1 O O N ...i M N )O N N N M N ' N u7 N)O N n N m 7!+- N 0 N 0 N N —N N .-s N N N ..-4N .+ N N N .-sr.1 .-IN e-( N a,o "..y .'.y v.y .y `'.y v 4.4 .'.y v. .'..1 .4'.y .'.y ..'N O m co 0)) (co m V 00)) coNCO N 0 m N (0 N U) p0p 01 00 0 No N 527 ((H W co co 00 O) 000 0"0 00 0000 OND 000 N 00 00 co 00 00 00 00 co- OC co- m 00 CO co < N 0) 0) N (O 00'1 u0') O) . O F- co co U) M 00 NN- O) CO Is- < 00 fO 527 N- O) C) 3 N O N of m co. co co co co m co.. co co n '35 co CO CO00 COco CO-OCO CO- 00 oo N N N N N N N N N N N N I • M Is CO 00 O) M Cr) 0 CO (') CO CO N N .7 N N N) Q N 5A in 1 00 M (O N (5) er N CO h 00 .- r (Ni (N r 2 CO N O O O N N coO 0 ul 0 el (5) 5A 00 N CO N P) v. U) co_ N co. F O O N N N N N 2 Vm) (ml) ((1) Um] < < < < (1) (/) (l) N C v� V R N N N N V R >' RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM. ON JUL 16 2015 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ A Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 197-250 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development 0 99519-6612 • Stratigraphic ❑ Service 0 6. API Number: 50-029-20380-01-00 7. If perforating: 8. Wef'Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU R-05A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028279 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SU M Y Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective D VD(ft): Plugs(measured): Junk(measured): 12950 8799 12882 W14 12862 Casing Length Size MD TVD Burst Collapse Structural Conductor �� /\ Surface See Att ent 1) Intermediate Intermediate l ^/ Production r \ Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubi i : Tubing Grade: Tubing MD(ft): See Attachment See Attachment e Attac ent See Attachment See Attachment Packers and SSSV Type: See Attachment ckers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV installed \ No SSSV Installed 12.Attachments: Description Su ary pos:l G 13.Well Class after proposed work: BOP Sketch 0 Detailed Opera Progra i I Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14.Estimated Date for Commencing Operations: 8/1 5 15. Well Status after proposed work: Oil ❑ Gas ❑ WDSPL❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Op Shutdown ❑ GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Peru,Cale Email Cale.Peru@bp.com Printed Name Peru,Cale / Title Petroleum Engineer Signatureaoti Phone 907.564.4522 Date 07/16/2015 COMMISSION USE ONLY Conditions of approval:Notify Commissio so that a representative may witness Sundry Number: 15 - `I3 `I Plug Integrity ❑ BOP,/,:7/ est ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes 0 No ❑ Subsequent Form Required: $(. JUL 2 8 2015 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attach ents in Duplicate RBDMS VC JUL 2 3 2015 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.9,DBR,LHD,EAZ 01/15/15) General Information Well Name: R-05A Well Type: WAG Injection Wet API Number: 50-029-20380-01 Well Activity Conventional 4 Classification: Activity Description: Acidize toe perfs/patch theif zone Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, 75 bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Cale Peru Contact numbers: (907) 564-4522 (832)316-5774 Well Intervention Engineer: Michael Hibbert Contact numbers: (907)564-4351 (907)903-5990 Lead Engineer: Dan Robertson Contact numbers: (907)564-5546 (907) 529-5818 Date Created: July 9,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate In] Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 6/24/2015 3,000 700 Current Status: Operable Shut In Inclination>70°at Depth (ft) 9,230' MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and 104° 12,950' MD Depth) Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 34° 9,485' MD Reservoir pressure(date, analog 3,300 psi Minimum ID and Depth 2.992"at 8257' psig) Reservoir Temp,F 200°F Shut-in Wellhead Pressure Unknown, probably near 0 Known mech.integrity problems(specifics) Coil: mill cement, SBG, (PROF, Caliper. Summary: RIH with Milling BHA: CTC(2.25"x1.37'), DBPV(2.13"x1.38'), G- force Jar(2.12x6.03'), 5/8°ball disco(2.13"x1.56'), 1/2"ball Circ sub (2.13"x1.01'), Mud Motor(2.13'x 8.16'1, String Reamer(2.80°x1.09'), Parabolic mill(2.80"x.54'). Last downhole operation (date, 3/4/2015 Had little motor work,made it to coil lock up at 12,590'. operation) Ran iProf, made it to coil lock up at 12,515'. Caliper did identify a hole where the drill bit grazed the top of the liner at 11,081'. SL latest job 6/5/2014: drift to dev with 2.79"cent, 1.75"sample bailer. Dev out at 9271' SLM. Milling BHA: CTC(2.25"x1.37'), DBPV(2.13"x1.38'), G-force Most recent TD tag(date,depth, 3/4/2015 12,590' MD Jar(2.12x6.03'), 5/8"ball disco(2.13"x1.56'), 1/2"ball Circ toolstring OD) sub(2.13"x1.01'), Mud Motor(2.13"x 8.16'), String Reamer (2.80'x1.09'), Parabolic mill (2.80"x.54'). Surface Kit Fit-for-Service? YES If No,Why? Online less than 1 year ago. Comments,well history, R-05Ai was drilled in 1998,since that time most of its injected water has gone into 2 theif zones(11,106- background information, 11,127&11,297-11,318')near the heal of the well.When drilled its highest resistivity was in the toe etc: portion of the well, North of the fault. When drilling R17B, R05Ai was intersected at 11,107'.The P&A kit and cement combined with coil milling debris has shut off that set of perfs(11,106-11,127'). The purpose of this job is to shut off the remaining theif zone and to establish toe only(perfs past 12,000') injection. Well Intervention Details Suspected Well Problem: Conformance issue/thief zone. Specific Intervention or Well Objectives: 1 Establish toe only injection(shut off perfs above 12,000'). 2 3 Key risks,critical issues: Mitigation plan: Previous coil job passed restriction with 2.80"mill going 1 Liner damage at 11,107', may have problems getting past. down with little motor work. No issues noted coming back through. Reaching TD. Coil has locked up between 12,500-12,600' on multiple runs last job with no agitator.We need to get deeper 2 than that to treat the toe perfs with acid and potentially to do a Plan to use agitator for initial drift,possible FCO and acid. FCO. Bottom of perfs at 12,853' Review burst calcs. If it is necessary to apply more than 3 Burst 7'tbg if we lock up during final injectivity test. 2000 psi on 7'tbg,apply 1000 psi on IA first. 2015 caliper shows 7"max pen is 36%. Summary Service Line Activity Step# 1 S D&T at coil WSL descretion. 2 C Injectivity test. Drift with agitator/JSN,cngt FCO, spot SBG across toe perfs. Set treater packer, injectivity test, pump Dad acid, injectivity test. Set 2 run patch, injectivity test. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 S Drift and tag at coil WSL descretion. Recently drifted with coil, no GLM's, SL deviates out at-9270'. 1)drift to PBTD(-12,850')with tempress,GR/CCL 2.75'JSN (same OD as treater packer that will be run later). Modeling and most recent coil job indicate lock up at-12,500' with no lube or agitator.We need to get to PBTD so plan to include tempress in initial drift. Injectivity test down backside on way down. Don't exceed 2000 psi. a)pump 360 bbl of 19'0 KCL to fluid pack the well with water. 2 C b)pump at 1,3,5 bpm. Record pressure when it stabalizes. 2) FCO(fluff and stuff)if necessary. Desired clean out depth 12,853'. Minimum cleanout depth 12,726'. Jet with SBG (order 100 bbl @160F),take small bites,chase fill above theif zone top at 11,297'to ensure debris goes into formation, if it is necessary to exceed 2000 psi on the 7"tbg put 1000 psi on the IA first due to 7"tbg condition. Do not exceed 3000 psi 7"tbg pressure. 3)Jet remaining SBG across toe perfs(12,228 to 12,853'). Let soak for 3 hr. With nozzle at bottom of perfs(12,850')jet 50 bbl of 1% KCL chasing it up(ct/tbg annulus closed), POOH. Purpose: ensure SBG is displaced from toe before acid treatment, if we over displace down backside the water will probably just go into the theif zone and acid may contact SBG in toe during next step. 4)MU treater packer(2-1/8"FH 1 trip),tempress(at WSL descretion based on: previous runs/pump rates, lubricator space,ability to drop ball for treater packer)and JSN. Set treater packer at 12,000' (+or-100'). Pre acid injectivity test: Pump 1% KCL down coil at max rate, -2 bpm. Record pressure.Volume: -reel volume. 5) Pump 40 bbl's of Dad acid down coil. Recipe: 90% HCL to 10%Xylene, standard additives,see attached tab(L80,220F). (no rubber in tempress, not an issue to pump acid through it if WSL elected to run tempress). Let soak 30 mins. 6) Post acid injectivity test: Pump 1% KCL down coil at max rate. Record pressure when it stabalizes. Don't exceed 3500 psi. 7)Once stable pressure/rate is obtained release treater packer, continue to over flush acid with a grand total (counting injectivity test)of 50 bbl of 1910 KCL while POOH. 8) Drift for 3 run patch(OD 2.78", ID 1.812", longest segment 28'). Include GR/CCL,JSN. Flag pipe at 11,200'. POOH 9)MU lower packer. RIH to flag at 11,200' make depth correction. Set lower element at 11,338'by dropping ball. POOH. MU middle section. Latch into lower section. POOH. MU upper section. Set upper element at 11,288'. 10) Perform injectivity test down backside while POOH. 1,3,5 bpm. Record stabalized pressures, don't exceed 2000 psi. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 3000 Expected Production Rates: FTP(psi): 750? Choke setting: 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: -FEE= 6X7CNVFLSI SAFE i Y NO1 ES.WEL L ANGLE'70 iW 9230 "'H2S VELU D• SOY ACRNTDR= BA1032C R-05A READINGS AVERAGE 126 ppmINNENONMI'--WELL REQUIRES A SSSV WHEN ON MI^04/0414 OCR R FV= 54' i 1 COLLISION w/R-17(SEE 8ELOW1'-' BI- Fi FV 24.95 I KO.'- 3191' AA<Angle- 104'at 12950' -- 2013;---1-,-,'TY,T-. T,iV NP f1=5 962' (tun MD- 12739' ' 4111 1 11 teban ND- 8800'SS ----- --- _. - 2585' --,9:k8'W.a.. in 113 319-l5,.... :.n_..bJ bUI I IL 12.347 2663' Minimum ID- 2.992" a 8257' 1 TOP OF 3-1/2" LINER 5.--- -• 8245' j--Ir x s SKR c2ss PKAMEBK S(v.D=4 375' I r REG,268,L-80LMS,.0383bpt,D=6258- 8252• . 8257._" 7-X6./17 X0,D=4107(8t-n;M)r., ntt: - 8257' 1-f 4-1/2'X 3-IR'XO,13=4.00'1 `• 8259' 7'X 5-1?XQ D=tor] CI I • 8255—1-15-1/2"OTB XA SLDSLV,D=8.562' -L 8300' 9-5/8"X SS 1?OW PKR I-ATO] '4 8 MLLOUT EXT,D-4.75' BEHIND ' CTINR SI?TBG,17n,L-60.0232kpt,D=4692' H8376 1 83'3 '--4.5. 1,,OTt xN'.s s IT t 453 - 8391' ---')-7 '`-H'v tO n > BEHIND /TCP OF 7'LNR 1--+mm83a7' CT L-NR 8394• 1' 9-58'CSG 478,L-00 BUR,D=8.68r'x 6690'_j TCPa2'1rYFi 31U:A H *sow Ili TOPOF CEMENT-1 2013' i 1 La.LOUT wpoow(1806A) 8964'-8960 PERFORATION SUMMARY -- REF LOG.MMYDC RRES ON 1402/98 ANGLE AT TOP PSE.93'0 10580' 11611000-11100-COLLISION w/0.178 Mb'Refer to Reduction PB for NeMPIcal pert data 1 1 11 ,♦111111♦ 1111. (0404 14)R17B HADAN ECP SET SEE STS INTERVAL OpnlSpz SEDT SOZ 14411141 2-V2' 8 10500-10581 0 0281696 ,4•�1�1�/•1�111� •, ABOVE COLLISION PO641'&CUT PLUG e ll e e•11 TO PROVIDE WOLAT10N BETWEEN WELLS 2-112' 6 10642-10663 0 02/08/96 4.44•a 111 1111111 11000-11100 • 04/14/14 11111111 • 11111141 2-16 11108-11127 0 02806/96 •41�1�1�1�141�• ? 2-V2' 6 11297-11318 0 02/06/96 5 12862' FISH-9'SWS VMBCHT 2-Il? 6 11007 11628 0 02/06498 ,, BAR VW 1.75'SUCKER 2-1/2' 6 12228-12249 O 00/06/911 -- RW BOX LOPING U. 2-1/2* 6 12302-12323 O 07/08/96 r l►/R?98,l-60 61177, Y77S 2-112" 6 12408-12429 0 02/06/96 0371 bpf,D-8.104' 2-11? 6 12509-12530 0 02106/98 �`�\ 2-117' 6 12820-42641 O 02806/98 .------.-..�-.....- %h%\ 2-I? 6 12706-12728 0 02/061198 FETID 12867 =r„ __- _._ 2-112' 6 128333-12853 0 02/0698 1 12960' -4 TDj I 3-I?LNC 9.3/.L-80 SR- H 129W •0.178INTE INTERSECTED IN THIS NIE4VAL(04001/ 14) •0067 W.0=2992' DATE REV BY COMMENTS DATE REV BY CO04MEilIS PRUC.CE BAY L1P4T 08!11179 ORIGINAL COMPLETION _ 04/14/14 JL/PJC COLUMN w/(4176(414414) NELL: R-05A 11/89 RWO 04/15114 PJC ADGTDFNL WBS CORRBC115 PERMT No.'1972500 02106198 SIDETRACK COMPLETION 04117/14 VIM PK SET SSSV I SE E(4/17114) AR P . 50-029-20380 01 03112/02 RCP CORRECTIONS ---06/12/14 CJWJMD FLLLiD SSSV NSBET(06105/14) SEC 32,712N,R13E,/OT ESL 4 1293'6W,. OV18M21144.180 A00®9823 SAFETY NOTE 03/09/15 PJC AR NO CORRECTION 0521112 R)NJ1.6M4J TREE DO(05117/12) 6P BtploraBoa(Alaska) Injector Minilog A Techlog PrO11e1 PBU WWF Well: R-05A • Laura J.Larson Seale: 14500 (data 5!1812015 E*.IMn 11.1 wtux r .. tsllat.,:a«,a Asn Erw+lwr Azlin Ka +517101J.3 A�.al+or bay TOMOlpit 11160 Lab pn .111.101631 Stt,.,:x Kwk. AF Coo. 9rtYrn NNWNNWT (Auto*70Owe-.3166J1 O .. 6vzn Roza i a SEST.GR a 0 API 2..02 PE Notes cc 3 v Rate Of Penetration TVoss Mo o� r at Si.Hui' (FEET) (FEET) Indca.TVDSS o o , .. 1A500 1A500 1 t t•t E ♦ ___—,---____....;....--=1 6765 __� .—,,..,..._. ..._..,.._.. t....._ ISIS i... 6660 6695 r 5 6920 0935 0940 6940 69IS r $930 $925 - $915 6905 ss� s$95 aus ISw » f 111175 i _. 1165 SIMS i' - Sin abs1111I MO SKS 01 �. Shut off theif - 65 100%of water alp entering here. 1175 SUS Ilk - 0160 101s 0100 0105 1110 1115 1120 1125 1120 1110 _.. 1100 ' 11101: 1110 - a7o ONO 0110 - a40 11101111111111.1111.11 /12S III 0130 ens 1 L 70100 $765 Could not find a log with collars that was 4" per 100'. FILE c i 2 c* COMPANY: BP Exploration (Ala, ka , Inc. WELL: R-05A FIELD: Prudhoe Prudoe Bay BOROUGH North Slooe STATE: Alaska SUM ACCESS NEUTRON DENSITY 3., ScIALsriberger ry orte.,;,, �< Z L {i5., YS.. '4 -'44.,. may`"" .,"_ a,t, I Input DLIS Files DEFAULT SAIT 012 FN:21 FIELD 01-Feb-199807,7 12594.0 FT 8660.5 FT ! Output DLIS Files DEFAULT SAIT .015 FN:23 FIELD 01-Feb-1998 10:51 12594.0 FT 8900.0 FT COST SAIT.015 FN:24 CUST 01-Feb-1998 10:51 12594.0 FT 8900.0 FT rOP System Version: 8C0-609 MC M AIT-A SPCWX-934 SSLT-AA SPCWX-934 PCS-B APCW-9702 SLDT-A APCW-9702 NT-S SPCWX-934 STGC-A APCW9702 PIP SUMMARY ca T:rne Mark Every 60 S SLDT Density Quality Factor(ORHQ - ----- SLDT) 0 (---) -0.25 "''" PASOUT FP('-':, '--,FT SLDT Pef PEF SLOT) 't SPCS CaliperliCAL SPCSi__ SLOT Bulk Density(RHQB_SLOT) •� ——� (IN) 10 1.65 (G C3) 2 65 a Ra GSTGNeutron Porosity o;(GAPI)R_ C� 100 ity iN0 6 (V V) _—0 I J I , IIt— �� + I 1111nr x'- v .I t Om.- 4 — , - _4 a ... II, , „,, _ _ IMI. S nr 11200 L H1 • i ......: ri 4 MI I� li . il 1 130(1s a MM► Y i c. IIN , I ". r If i 11400 c) .imit- I ( t_... _ .. 1- . L in --- ..a , •� L. 111 } I r .. _ 11500 s , , HI 1I I 4 � � a mils 11800 1 6 � `"i PAF SLDT1 f � ` �. 1 N' H1 4 e ! "T." T 7711. * + -' n j "_" • I '• i L ft iH ' 1 i # _ _ .c c w+ wfi, — 1 A- .. x ....� 4 t r Yr / z • RC1. as PCS . x: , , 1 . { '' , C Q* 1O Sta.. . , r 1 ' v P I ¢ j% 'PEF_SIDT, .- -, NPHI } I ftOLI. S_DT,. H , ..a n„ e • .0 ms'•----- :} ... .. -..1_ - Y jt t ( I I I •t Gamma'Ray(G,R STGC) Neutron Poroso iNPHIL O (GAIN) 100 0.6 (V V) a SPCS CaliFstR�PCAL SVCS! Si..DT B,Ik.Density(RHO@ _ OP 0..... _- (0(N1 10 1.65 C3) 2.65 • SLOT Pat(PEF SLOT} st 0 (----) _.. . _10 SLOT Denary Quality Factor(ORHO "i, SLOT) 0 t----1 -0.25 PIP SUMMARY Cil Time Mark Every 60 S Parameters DLIS Name Description Value BHS Bose Note Status OPEN 1 �T Hole Temperature(used in eatcu(ationt} 225 OEGF BA Size $500 IN DF13 rating Fluid Oen &d0 LBG D Depth Offset 0.0 FT FVNA SLOT SLOT Firmware Version Number Mater FVNI SLOT SLOT Firmware Version Number-Minor 2 GCSE Gan♦rattzed Capper Selection r' t:AL1 SPCS GRO Geothermal Gradient - 0.01 OF F GTS£ Generatszad Temperature Selection LINEAR ESTIMATE MA TR Rock Matrix T MYNA SLOT ype SANDSTONE1.MYNA SLOT SLOT MMAXIS Version Humber-Motor 10 ,.� SLOT aytB Version Number-Minor 2 „ WNA SLOT Playback Processing ..,,..« ,n= Peen SLOT SLOT LOS Processing NORMAL g Votaress Number-Mafor Collar Check. Not the standard scale �• rbiAgFvps,..„ .r ,w Q� INJECTION PROFILE W 06 -Mar-2015 PnOAC I iv a. Oin‹,r.OSTlCSC MVI(,e _.., __ Li Company BP EXPLORATION (ALASKA;. INC. 03 Well R - 05A FIN L (13 Feld PRUDHOE BAY Borough NORTH SLOPE State ALASKA 0 r� 0 Surface Location ' '°` Q.. Q o cn m Extended , w o 706.83' FSL & 1293.01' FV,R. Reade a_ r p _co 24 mCazac SEC' 32 T1+VP: 12N RGE: 13E co cn Permanent Datum MSL Elevation 0 0' n i:8 54. E o ro Log Measured From RKB 54.0 FT. Above Perm. Datum o F 24.95' it: ID io it m Cn API Serial Number 50-029-20380-01 GL =Date 06"Mar 2015 Run Number One PBT D Driller 12.887 P B T D L ,.._ Not Tagged . Bottom Logged Interval 12.550' .1 Top_Loc Interval ..�_ 8,200 Open tSize N/A :- g ie Type Fluid Injected Water ___ [Max Recorded Temp.{degFJ_ 18' _ FINAL PRINT �Trr►e 6Nell Reach_ _-- 12 Q(i . Time Looe!an BO om 19 25 1 Fent Number _ SLB CTU#3 North __ Stupe _______ - 10335 ' Service Invoice No Recortted By _ __ Witrreissed B A McVey J.Stephens Borehole Record ..__ _ TubingRecord ' '' Run Number ;+ Bitr From To . ,Size_. LB I Ft Fres T 26.[90 ___, Suri ee_._ ...__L__ __..__ _.5117 1'-.00 8.257 8.3t '-a ., ..__ s _ ra ^g Record Size LB J Ft Top —. 13 3/8' _ _ 2,00 .- _ _ Space '9 518' 4700 Surtaoe — — 8..-1 -1 T' 29.00 5 8.391' 9 7 312`___,.. ..._.__ 930 __: .__, _ __ 8:,245` 1;�946 !4--Pressure (dwn 80) • 10900 1 j _ .4{--Temperature(dwn 80? )4--Temperature Wow,- I 11000 is*.,----- ...... i . j 1 1 100 r. ."- rS If-- 1, e 11200 , 1 :7'.7.--- k ; ii 11300 : .-'r__"'Zi i 11 1 A' i 11400 F, ...m.., i I 11600 z} 1 I 1. ' ci .:... .3 ! I 11800 i li 11900 1 • {{tt 12000 1 =.1E----CCL(up 80) ► 4 N oN F 4 Y B, . 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CO V — O O O O O O O • OM) coc0 N m CO ,O CO N- • O) N- O) O f- — M - OON- OCDCOCo ' COCOOCOr- 00 - N CD CD aD CD CD CO O) O - toTrN- N- CO CO M N C) O O N N O CO CO CO CO • • CO O CO CO - CD CO CO 00 LC') Cfl CO N N O) N N = N 00 00 00 CO CO V Q co N MNccNNMNN ) • N CO co CO CO CQ .Q 0 a coOma • M c‘i�# 4# CO # J J 4# M N It N- x � � J •O) � CO ,� N 0O &) N N N V M �• ti (V .c C▪ A 000000 � CoON C0N J N CO CO Z O • OU HV eti V O u_ O t c c Z Z Z Q W W W m m O Z Z Z D D UcndJJJHH Packers and SSV's Attachment ADL0028279 SW Name Type MD TVD Depscription R-05A PACKER 8241.76 8066.96 5" Baker C-2 SS W/Sleeve R-05A PACKER 8303.64 8127.34 �5-1/2"TIW Packer NEE= 6 X 7 CNV FLS TY NOTES:WELL ANGLE>70.41230'M H2S " "D= "'B/°'_' R-0 5A READINGS AVERAGE 126 ppm WHEN ON MI"'WELL ACTUATOR= BAKER C REQUIRES A SSSV WHBI ON MI"'04104/14 CMB.BEV= 54' COLLISION w/R-17(SEE BELOW)"" BF.BEV- 24.96' ) — ( KOP= 3191' Max Angle= 104'@ 12950' I I 2013' I--r OTS FPB SSSV NF',D=5.962" Datum MD-:-:—--- 12739' Datun1VD= 8800'SS 2685' -{9-5/8-DV PKR 13-3/8'CSG,72*,L-80 BUTT,0=12.347- H 26s3• Minimum ID = 2.992" @ 8257' ' TOP OF 3-1/2" LINER I 8246' Hr X 5'BKR C2SS PKRIT1ELK SLV,D=4.375' T TBG,26*,L-80 U4S,.0383 bpf,D=6276' H 8252' I--- I 8252' HT X 5-1/2"XO,D=4.897(BEHIND CT LNR) 8257' H4-1/2"X 3-12'XO,D=4.00" 8259' H7'X 5-12'XO,D=2.938' I 8266' H 5-12'OTIS XA SLD SLV,D=4.562' 0 II I 8300' 19-5/6'X 5-1/2"11W R(R LATCH Z Z a MI-LOUT EXT,D=4.75' BEHIND CT LNR I I I 8362' -j5-1/2"OTIS X NP,D=4.562' 5-1/2'TBG,17*,L-80, .0232 bpf,D=4.892" 8376• I 1 I 8373' —I5-12"OTIS XN NP MLLED,D=4-55' $3�' -�TSEALASSYw/XO,D=7 BEHIND TOP OF 7'LNR — 8397CT LNR 8397' _�9-5/8'X7"LNRHC�D=9 9-5/8'CSG,47*,L-80 BURT,13=8.681" H 8890' TOP OF WI-I:STOCK ---1 8966' , TOP OF C8i.0 T 9013' MLLOUT VVICOVV(R-06A) 8964'-8980' PERFORATION SLM ARY REF LOG:MMNDGRIRES ON 10102/96 ANGLE AT TOP PERF:93"0 10560' % Note:Refer to Production DB for historical peri data 111v11v11v11v11v1111000'-11100'- COLLISION w/R•17B 1 SIZE SFF PDE RVAL OpNSgz SHOT SOZ 01111111 , (04/04114)R-178 HAD AN ECP SET 2-12' 6 10560-10581, 0 02/06/98 1111111111111 S 1ABOVE COLLISION POINT& CMT PLUG 2-12' 6 10842-10863 0 02/06/98 •1.1.1.1#1#1#1# ,, TO PROVIDE ISOLATION BETWI33I WELLS 11000-11100 • 04/14/14 .11111111111111 % 2-1/2' 6 11106-11127- 0 02/06/98 •11111111111111 5 2-1/T 6 11297-11318 0 02/06/98 % 12862' FISH-9'SVYS WBGHT 2-1/2" 8 11607-11628 0 02/06/98 % BAR W/1.75' SUCKER 2-1/2" 6 12228-12249 0 02/06/98 ROD BOX IOOKFIG IP 2-12' 6 12302-12323 0 02/06/98 T LNR 291/,L 80 BUTT, 9775' • 2-12' 6 12408-12429 0 02/08/98 .0371 bpf,D=6.184" • 2-1/2" 6 12509-12530 0 02/06/96 viva wi,, 2-1/2" 6 12620-12641 0 02/06/96 I o`h� 2-1/T 6 12706-12726 0 02/06/98 PSTD -I 12882 �.� J 2-1/2' 6 12833-12853 0 02/06/98 j 12950' 1 3-12'LNR,9.3*,L-80 STL, H 12948' 'R-178 INTERSECTED IN THS INTERVAL(04/04/14) 0087 bpf,ID=2.992" DATE REI/BY COMMENTS DATE REV BY COI/ANTS PRUDHOE BAY UNIT 09/11/79 O(GQNALCOMPLETION .04/14/14 JL/PJC 'COLLISIONw/R-17B(4/4/14) VYaL R-05A 11189 MO '04/15/14 PJC ADDITIONAL ABS CORRECTIONS PE RAIT No:'1972500 02106/98 SIDETRACK COMPLETION 04/17/14 MP/PJC SET SSSV/BERT(4/17/14) AR Pb: 50-029-20380-01 03/12/02 ITP CORRECTIONS ,06/12/14 CIPYJMD PULLED SSSV INSERT(06/05/14) SEC 32,T12N,R13E,707'FSL&1293'EV& 01/18/12 TMWJMD ADDED ISS SAFETY NOTE 03/09/15 PJC AR ND COITION 05/21/12 RWYJ1C TREE CYO(05/17/12) BP Exploration(Alaska) Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday,July 17, 2015 9:37 AM To: 'cale.peru@BP.com' Cc: Loepp, Victoria T (DOA) Subject: Deficient Sundry Application Form for PBU R-05A (PTD #197-250) Cale, The intent of AOGCC's Sundry Application form is to provide a concise, single-page summary for each well. Repeated use of the phrase "See Attachment"to describe the present well condition of PBU R-05A is not sufficient. Please re- submit the Form 10-403 for R-05A with data in all pertinent boxes of the Present Well Condition Summary section of the form. Future applications containing the phrase "See Attachment" within well-data boxes will be considered deficient, and they will be returned to BP. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. For future Permit to Drill applications, please enter well data into all appropriate boxes on the 10-401 form. 1 STATE OF ALASKA , SKA OIL AND GAS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Li Mill Cement Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2 Operator 4.Well Class Before Work 5 Permit to Drill Number Name. BP Exploration(Alaska),Inc Developments Exploratory ❑ 197-250-0 3 Address P 0 Box 196612 Stratigraphic❑ Service ❑✓ 6 API Number Anchorage,AK 99519-6612 50-029-20380-01-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028279 PBU R-05A 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 12950 feet Plugs measured None feet RECEIVE D true vertical 8798 72 feet Junk measured 12862 feet APR 13 2015 Effective Depth measured 12882 feet Packer measured See Attachment feet true vertical 8814 49 feet true vertical See Attachment feet Ap G CC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 115 20"x 30" 29-144 29-144 0 0 Surface 2634.21 13-3/8"72#L-80 28 79-2663 28 79-2662 14 4930 2670 Intermediate None None None None None None Production 8862 9-5/8"47#L-80 28-8890 28-8698 82 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment S,,ttSee Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED MlAV 1 2 2W 15 True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 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 0 0 1950 0 380 Subsequent to operation 0 0 0 0 0 14 Attachments. 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑ Service Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work• Oil ❑ Gas ❑ WDSPLLI GSTOR ❑ WINJ ❑ WAG Q GINJ E SUSP ❑ SPLUCS 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: N/A Contact NitaSummerhays Email Nita.Summerha s• b..com / Printed Name N r Summerh� Title _ Petrotechnical Data Engineer �,vl /. Sign ,a Phone 564-4035 Date 4/13/2015 vr- 57/i //5" RBDMSJ\k APR 1 8 2015 Form 10-404 Revised 10/2012 fAhy Submit Original Only Daily Report of Well Operations ADL0028279 A SUMMARY Job Scope: Mill Cement, IPROF, Caliper MIRU, Perform 7 day BOP test on back deck w/no failures. 3/3/2015 ***Job in Progress*** CTU#3 1.75" CT (CTV=31.2) Job Scope: Mill Cement, SBG, IPROF, Caliper Dig out from blow, MU Milling BHA. Well is on injection at-3200 bpwd @ 685 psi whp. RIH w/2.80" D-331 DSM w/2.79" SR w/well on injection to set down at 10921'. Mill a stringer or hard fill, then RIH easily to stall at 11086'. Attempt to mill past w/two additional stalls and whp rising slowly 3/4/2015 In progress T/I/O-0/0/0 Temp= SI Assist CTU#3 (MILL/UNDERREAM) Pumped 5 bbls neat meth down FL to lateral valve for freeze protect. Coil in charge of well upon LRS 3/5/2015 departure. Tags hung on WV and lateral. Pad op notified FWHPS= 0/0/0 CTU#3 1.75" CT(CTV=31.2) Objective-mill probable cement in liner, IPROF and caliper after post-drilling intervention Mill past obstruction at 11086'. WHP continues to increase due to schmoo or cement fines plugging perfs and is up to 1230 psi. Wiper above top perf. SI injection. LRS FP FL from twin w/ R-32 w/McOH. RIH clean from 11087' to stall at 11287' (in perfs 11297-11318'). RIH reaming from 11300' at 2-15'/min and found minor wt loss areas, but no cement or stalls. Continue to RIH until lockup at 12,589 with no motor work. Called town and APE was good with POOH. POOH at 40 FPM back reaming liner. With CT above liner, drop circ ball and POOH pumping slick 1% KCL with SL. MU 2.5" nozzle and RIH to CT lockup at 12572. Jet liner and tubing with SBG while POOH. MU SLB IPROF toolstring. 3/5/2015 In progress T/I/0=930/500/160 Temp=INJ, FP FL for CTU. Pumped a total of 6.1 bbls MEOH 3/6/2015 for FP. FWHP's=200/500/160 DSO notified CTU on well & in control of all WHV's CTU#3 1.75" CT(CTV=31.2) Objective-mill probable cement in liner, IPROF and caliper after post-drilling intervention Thaw flowline between injection choke and wing valve. PO1 at 4300 bwpd / 1150 psi. RIH w/SLB Memory IPROF toolstring. Hit lock-up at 12515'. Make IPROF 40, 60, 80 FPM up/down passes from 12510' - 10500'. Perform 5 minute stop counts around suspected liner damage 11,110, 11,090, 11,025. POOH and LRS FP flowline to lateral valve. Pop off well and attempt to download data -tool turned off while RIH, no IPROF data recorded. MU PDS caliper and PLT. POI at 4600 bwpd / 750 psi. Log up/down passes at 40, 60 fpm from 12550' - 10500'. 3/6/2015 In Progress CTU #3 1.75" CT (CTV=31.2) Objective-mill probable cement in liner, IPROF and caliper after post-drilling intervention Log up/down pass at 80 fpm from 12550' - 10500'. Perform stop counts around suspected liner damage: 11,110', 11,090', 11,025'. Perform 24-arm caliper log from 12550' - 8200'. POH download data -data is good. Rig down move out; leave well on injection. 3/7/2015 ****Job Complete**** Daily Report of Well Operations ADL0028279 T/I/O= 0/180/140. Temp=Hot Inj. Freeze protect tbg and flowline for CTU. Pumped 5 bbls neat methanol down flowline to freeze protect. Pumped 3 bbls neat methanol through S-riser. Pumped 95 bbls 60/40 down tbg rig down (swab closed wing closed ssv closed master open annulus valves open to gauges operator notified to keep an 3/20/2015 eye on FL pressure) FWHP=0/0/150 FLUIDS PUMPED BBLS 19.1 METH 748.1% SLICK KCL W/SAFELUBE 214.60/40 METH 274 SCHMOO-B-GONE 1255.1 TOTAL CD N N CO 'Cr CO CO z V CO O CO O O CO CO O O O) _ N N co CO to co co co Lo Cb O cu (NI C) O N V CO N 0 OO CD V N ] ❑ CA Cb O) (A 0) O) O CA CO CO CO CO O ❑ C)O CO CO CO CO CO CO CO CO Cb 00 00 p p z W w O 0 H H J d w 0 0 0 O O w O Y Y H g H Ln V N O to N- LO CD •- LO CD J U U w L O O CA CO CO N O 0) 0) CO LO CO J J J d d w U) z 0_ CS V 4 0 0 OO ti 0) O N to Q Q Q W ❑ O Cb CA CA CT C�) CA CT CO 00 Cb oo z z z 0 J J J p J ❑ CO CO CO CO CO CO CO CO CO CO CO CO Q Q < = p p 0_ H 0_ O U U w m z p Z w w 0_ H H J Q 2 2 2 O (1) co v) v) cn a) Ca co lT) CO N- CO CO CA M CS) O N- CO CO CO CD N V N N M N Lo 0 to co CO co N co V to CO N- CO 0 0 0 N N N N N N N a) _ - J = H OH 0_ J 0_ (� 2 2 O cn cn co co co {�.+ Qcc) a N o H = L O N CO N- N- CO N CO C)) O Ln CO J a CO V O Cr) O N O O O N O CO O a) LU CO v- N CO N CO to CD N- CO 0 0 0 ,- N N N N N N N CD ttaa L a) 13 O O a a, 0 U W W W W W W W W W W W W m 0 d a. d d d d d d a. a d a 0 a, m 0. 0 w J 0 0 cwn H LU 0 0 cocouococococococococo co ❑ O O O (A (T (3) (A (A (3) CA O a p p O Q p CA CA CA CA C) CA CA O CT CA O O LU a d Z LU LU Z w m \D CO CO CO CO CO CO CO CO CO cD CO p W W W W WCC o_ 0 O 0 w w Q N N N N N N N N N N N N Q p 1212 _1 _Ip p rX d 0 m O o o J J O O w W < < m m W W U) Cn 0_ cc a) co co z < < < < < < < < < < < < z to LO LO LC) LC) LC) LC) LC) LO LO to LO Cn 00000000000 CD a0wam L.L. a J Ua w m m W u. cn c) o_ cL CA OO moo © O O CQ CO L() N O C` . CD O O O N- CO V' N O N V N In (O C.) O o 0 0 O O O O O N- COCO "Zr 3 O CO O N co OQ CO co V N- r- M LC) N N 1- V CO CO Cr) r N CO LO (N CO I- O Cf) CO "Cr N N- N I- (b O CO O O CO r"-- 0 �O O I� O CO O (0 O N 00 CO CO CO CO CO N CO 00 H CO CO C.() N- CO CO CO CO O LC) 0) N O C70 c0 O ~ V t` N (` CO N CO CO N f� O O O N ON O CO CO (b CO CO CO , CON- , 1U O O cO N (n N- O N- O O LO N N N f� CO N O NO C CO CO O CO CO N CO CO C.) N Co O0 0 ICrnCb0Ov ) (NJ N co (N co CON coON NN co co.c▪ o • J U � Q C� © c c 09 O 13) co O co O co = J O J CO J 00 J o • d CX CO CO M N N N J C c - co * O V _ (fl O CO (NJ u) a0 N U N N • -N- Lo 0C,) , O co N CCS) LU +• CO N CO co CD In c\I N co CO C O 0 as F_ F— w Co MoCtCLCtCCo > u_ ZZ UZwwwwOwcLmm O Z Z Z Z J D D j U J J J JCL (n U) Packers and SSV's Attachment ADL0028279 SW Name Type MD TVD Depscription R-05A PACKER 8245 8070.12 5" Baker ZXP Top Packer R-05A PACKER 8299.69 8123.48 5-1/2"TIW Packer I I TREE z 6 X 7 CNV FLS TY NOTE'S:WELL ANGLE>70°e 9230'"'It2S VYELU-EAD= MCEVCtY R-05A READINGS AVERAGE 125 ppm WHEN ON MI"'WELL ACTUATOR= BAKER C REQUIRES A SSSV WHEN ON MI'""'04/04/14 CKB ELEV 54' COLLISION w/R-17(SEE BELOW)•'• .__ __. . _ _....._ ___. BF.ELEV= 24.95' 1 KOP= 3191' Max Angle= 104 @ 12950' 2013' —17"OTIS RFB SSSV NP,D=5.962' Detum Ws= 12739' 41110 Datum 1VD 8800'SS 1 2585' -9.516'w PI(R 13-3/8"CSG,72#,L-80 BUTT,D=12.347' H 2663' , Minimum ID = 2.992" @ 8267' TOP OF 3-1/2" LINER 8245' -1r X 5'BKR C2SS R(WTIEBK Sly,D=4.375" r TBG,26#,L-80 LI4S,.0383 bpf,0=6.276" H 8252' I—♦ 8252 _�7'x 5-1/2'XO,D=4.892'(BEHIND CT LNR) 8257' —4-1/2'X 3-1f2"XO,0=4.00" 8259' Hr X 5-1/2'XO,I)=2.93r 8265' —15-1/2"OTIS XA SLD SLV,D=4.562" 8300' —9-5/8'X 5-12"11W FKR LATCH S S &IVLLOUT EXT,D=4.75" BEHIND CT LNR 1 1 " ' 8352' —15-12'OTIS X NP,0=4.562" 5-1/7 TBG,17#,L-80,.0232 bpf,D=4.892' 8375• 1 1 8373' H5-12'OTE XN NP PALLED,D=4.55" 8391' H--r SEAL ASSY w/XO,D=? BEHIND TOP OF 7"LNR — 839T CT LNR 8387' 9-5/8'X 7•LNR HGR D=? 9-5/8'CSG,47#,L-80 BUTT,D=8.681' —1 8890' TOP OF w-a siOCK — 8966' , TOP OF CEMENT — 9013' MLLOUT WINDOW(R-05A) 8964'-8980" PERFORATION SLMAARY REF LOG:AMOGR/IREJ;ON 10/02/98 ANGLE AT TOP PERF:93'©10560' S, Note:Refer to Production DB for historical pert data ,•1.1.1.1.1.1 .1 •111000'-11100'- COLLISION w!R-17B SIZE SNTERVAL Opn/Sgz SHOT SOZ 11111111 (04/04/14)R-17B HAD AN ECP SET FT X1111111 2-12' 6 10560-10581 0 02/06/98 1/1111/1111111 S ABOVE COLLISION POINT& CMT PLUG 2-1/2' 6 10842-10663 0 02/06/98 #11111111/11111 Si TO PROVIDE ISOLA110N BETWEEN WELLS • • 11000-11100 • 04/14/14 .11111111111111 % 2-12' 6 11106-11127 0 02/06/98 k.11111111111111 5 2-1/2" 6 11297-11318 0 02/06/98 5 12862' —FISH-9'SWS WIGHT 2-12' 6 11607-11628 0 02/08/98 ,, BAR W 1.75" SUCKER 2-12' 6 17778-12249 0 02/06/98 r LNR 29#,L-80 BUTT, 9775' ROO BOX LOOKNG LP 2-12" 6 12302-12323 0 02/06/98 2-1/2' 6 12408-12429 0 02/06/98 .0371 bpf,0=6.184" 2-12' 6 12509-12530 0 02/06/98 2-1/2" 6 12620-12641 0 02/06/98 '41.11.74 2-1/2" 6 12706-12726 0 02/06/98 PBTD 12882' \\ii 2-12' 6 12833-12853 0 02/06/98 H 12960' -i TD 3-12"LNR,9.3#,L-80 STL, —{ 12948' •R-170INTERSECTB) IN THS INTERVAL(04/04/14) 0087 bpf,D=2.992' DATEREV BY COMMB�fTS DATE RB/BY C)tJUITS PRUDHOE BAY UNIT 09111/79 ORIGINAL COMPLETION 04/14/14 JUPJC COLLISION w/R-17B(4/4/14) WELL: R-05A 11/89 FANO 04/15/14 PJC ADDTTIUNAL WBS CORRECTIONS PERMIT No:'1972500 02/06/98 SIDETRACK COMPLETION 04/17/14 WKPI PJC SET SSSV NSERT(4/17/14) AR No: 50-029-20380-01 03/12/02 RWTP CORRECTIONS TIONS 06/12/14 CJWJMD PUU_ED SSSV INSERT(06/05/14) SEC 32,T12N,R13E,707'FSL&1293'EVA_ 01/18/12 TMN/JM)ADDED ISS SAFETY NOTE 03/09/15 PJC AR NO CORRECTION 05/21/12 RWJ/JMD TREE C/O(05/17/12) BP Exploration(Alis ka) 147' 2,V.44"‘ WELLLOG DATA LOGGED /1/2015 TRANSMITTAL BENDER ilRECEIVED PRoAcrivE DiAgNosric SERVICES, INC. APR O92O15 AOGCC To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage,Alaska 99501 tA'' 0 `{ LU i (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1] LeakPointTM Survey 06-Mar-15 R-05A BL/ CD 50-029-20380-01 2] Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE tl@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFiles\Templates\Distributton\TransmntalSheets\BP_Transmit docx STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations Lf Perforate Li Other L Bright Water Performed: Alter Casing ❑ Pull Tubinc0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 197 -250 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0. 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20380 -01 -00 . 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028279 PBU R -05A • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL - 11. Present Well Condition Summary: Total Depth measured 12950 feet . Plugs measured None feet true vertical 8798 feet Junk measured 12862 feet Effective Depth measured 12882 feet Packer measured See Attachment feet true vertical 8814.49 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 114 20" x 30" 30 - 144 30 - 144 0 0 Surface 2632 13 -3/8" 72# L -80 29 - 2661 29 - 2660.14 4930 2670 Intermediate None None None None None None Production 9712 9 -5/8" 47# L -80 28 - 9740 28 - 8986.14 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED JUN 2 8 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 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: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorLI Development ❑ Service INI • Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG el . 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: N/A Contact Nita Summerhays Email Nita.Summer - 4 :%. P.co Printed Name Nita$umme. ays Title PDC PE Armansw -.. n 2MA - - y am /� Phone 564 -4035 Date 6/18/2013 iwa. ` -, trL-r - RBDMS JUN 26 20145 Form 10 -404 Revised 10/2012 Submit Oiriginal Only • • Daily Report of Well Operations ADL0028279 ** *Job condtinued from 5 -20 -13 WSR * ** Standy by for CTU to RDMO Road equiptment to location Spot equipment and start rig up. * ** WSR continued on 5/21/2013 5/22/13 * ** T /IIO = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/21/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 82 gal. EC9360A (surfactant). Average of 32.8 gph for 2.5 Hours. Pumped a total of 82 gal. since start of project. Pumped 211 gal. EC9398A (polymer) Average of 105.5 gph for 2 Hours. Pumped a total of 211 gal. since start of project. * *Establishing rates with proving pots ** 5/22/2013 * ** WSR continued on 5/23/13 * ** T /I /O = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/22/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 274 gal. EC9360A (surfactant). Average of 14.8 gph for 18.5 Hours. Pumped a total of 356 gal. since start of project. Pumped 1623 gal. EC9398A (polymer) Average of 90.2 gph for 18 Hours. Pumped a total of 1834 gal. since start of project. * *Establishing rates with proving pots ** 5/23/2013 * ** WSR continued on 5/24/13 * ** T /I /O = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/23/13 * ** Pumping brightwater chemicals down TBG while on water injection © 3500 bwpd. Pumped 475 gal. EC9360A (surfactant). Average of 19.8 gph for 24 Hours. Pumped a total of 831 gal. since start of project. Pumped 2091 gal. EC9398A (polymer) Average of 87.1 gph for 24 Hours. Pumped a total of 3925 gal. since start of project. * *Establishing rates with proving pots ** 5/24/2013 * ** WSR continued on 5/25/13 * ** • • 1 Daily Report of Well Operations ADL0028279 T /I /O = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) ***WSR continued from 5/24/13 * ** Pumping brightwater chemicals down TBG while on water injection © 3500 bwpd. Pumped 332 gal. EC9360A (surfactant). Average of 16.2 gph for 20.5 Hours. Pumped a total of 1163 gal. since start of project. Pumped 1829 gal. EC9398A (polymer) Average of 93.8 gph for 19.5 Hours. Pumped a total of 5754 gal. since start of project. * *Establishing rates with proving pots ** 5/25/2013 ***WSR continued on 5/26/13 * ** T /I /O = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) * ** WSR continued from 5/25/13 * ** Pumping brightwater chemicals down TBG while on water injection © 3500 bwpd. Pumped 422ga1. EC9360A (surfactant). Average of 17.6 gph for 24 Hours. Pumped a total of 1585 gal. since start of project. Pumped 2129 gal. EC9398A (polymer) Average of 88.7 gph for 24 Hours. Pumped a total of 7883 gal. since start of project. * *Establishing rates with proving pots ** 5/26/2013 ***WSR continued on 5/27/13 * ** T /I /O = 700/0/580 Temp = Hot (Brightwater Reservoir Sweep Mod) ***WSR continued from 5/26/13 * ** Pumping brightwater chemicals down TBG while on water injection @ 3500 bwpd. Pumped 188 gal. EC9360A (surfactant). Average of 18.8 gph for 10 Hours. Pumped a total of 1773 gal. since start of project. Avg for job = 17.82 gph Pumped 1005 gal. EC9398A (polymer) Average of 100.5 gph for 10 Hours. Pumped a total of 8,892 gal. since start of project. Avg. for job = 91.2 gph Rig down and de- mobilization of bright water sujpport equipment in progress Well on lnj. @ 3500 bwpd, SV = closed, WV, SSV, MV = open, IA and OA = OTG. FWHP's = 490/0/560 * ** WSR continued on 5/28/13 * ** 5/27/2013 Rig down and de- mobilization of bright water support equipment ***WSR continued from 5/28/2013 5/27/13 * ** 5/31/2013 Store chemicals for Bright Water 5/29 - 5/31 FLUIDS PUMPED GALS 1773 EC -9360A SURFACTANT 8888 EC -9398A POLYMER 10661 TOTAL • • Daily Report of Well Operations ADL0028279 Perforation Attachment ADL0028279 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base R -05A 2/6/1998 PER 10560 10581 8924.01 8922.44 R -05A 2/6/1998 PER 10842 10863 8894.05 8892.35 R -05A 2/6/1998 PER 11106 11127 8900.94 8903.03 R -05A 2/6/1998 PER 11297 11318 8919.32 8921.37 R -05A 2/6/1998 PER 11607 11628 8944.39 8946.08 R -05A 2/6/1998 PER 12228 12249 8938.15 8935.02 R -05A 2/6/1998 PER 12302 12323 8927.07 8923.81 • R -05A 2/6/1998 PER 12408 12429 8909.95 8906.34 R -05A 2/6/1998 PER 12509 12530 8891.96 8888.02 R -05A 2/6/1998 PER 12620 12641 8870.31 8865.96 R -05A 2/6/1998 PER 12705 12726 8852.55 8848.15 R -05A 2/6/1998 PER 12833 12853 8825.36 8820.98 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 • I • Casing / Tubing Attachment ADL0028279 Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 20" x 30" 30 - 144 30 - 144 LINER 635 7" 29# L -80 9227 - 9862 8963.18 - 8978.4 8160 7020 LINER 2148 3 -1/2" 9.3# L -80 9890 - 12038 8976.29 - 8966.39 10160 10530 PRODUCTION 9712 9 -5/8" 47# L -80 28 - 9740 28 - 8986.14 6870 4760 SURFACE 2632 13 -3/8" 72# L -80 29 - 2661 29 - 2660.14 4930 2670 TUBING 9058 7" 26# L -80 27 - 9085 27 - 8879.11 7240 5410 TUBING 136 5 -1/2" 17# L -80 9085 - 9221 8879.11 - 8960.97 7740 6280 • 1 • f IM • • Packers and SSV's Attachment ADL0028279 SW Name Type MD TVD Depscription R -05A PACKER 8245 8024.72 5" Baker ZXP Top Packer R -05A PACKER 8300 8078.39 5 -1/2" TIW Packer • TREE = 6X7CIWFLS V aLHEAD MCEVOY R 0 5 A Y NOTES: H28 READINGS AVERAGE 125 ppm T = WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR = BAKER C KB. ELEV = 45.4' Ml. WELL ANGLE> 70° (a 9230'. BF. ELEV = 24.95' KOP = 3191' I 2020' I-17" OTIS HRQ SSSV LAND NIP, ID = 5.962" I Max Angle -� 104° @ 12950' 0 i Datum NO = 12739' 2585' 9 -5/8" DV PKR Datum TV D = 8800 S S 1 13.3/8 " CSG, 72#, L -80, ID = 12.347" H 2863' I , r; X 8245' I-- 7'" X 5" BKR C2SS PKR/ TIEBK SLV, ID = 4.375" 8252' H5 -112" X 4-1/2" XO I 1 8257' H4-1/2" X 3-1/2" XO I r TBG, 26#, L-80, .0383 bpf, ID = 6.276" H 8259' I / 8259' H7" X 5-1/2" XO III m 8272' 5-1/2" OTIS XA SLDNG SLV, ID = 4.562" I Minimum ID = 2.992" @ 8267' Z4 E I 8300' I- 9-5/8" x 5 -1/2" TIW PKR LATCH TOP OF 3 -1/2" UN ER & MILLOUT EXT, ID = 4.75" I I 8359' H5 -112" OTIS X NIP, O = 4.562" I I I 8380' H5 -1/2' OTIS XN NIP MLLED, ID = 4.55" I 1 5 -1 /2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 8397' I — 1 8397' T Y SEAL ASS E . I _hi ELMD TT NOT LOGGED I 8964-/9 VJINOOW 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8890' I I I 8964' ' -8980' I TOP OF WHIPSTOCK H 8966' I 12862' FISH - 9' SWS WEIGHT BAR W/ 1.75" I TOP OF CEMENT H 9013' I .�.......... SUCKER ROD BOX LOOKING UP • 12950' TD o veAvAvAvAvAvAvA ffffffff i tttAt m� I 7" LNR, 29#, L -80, .0371 bpf, ID = 6.184" H 9775' I ����u �� =.�,„,_ PERFORATION SUMMARY I PBTD H 12882' REF LOG: MWDGR/RES ON 10/02/98 ANGLE AT TOP PERE: 93° 10560' Note: Refer to Production DB for historical pert data 3-1/2" LNR, 9.3#, L -80, .0087 bpf, ID = 2.992" 12948' SIZE j SPF I INTERVAL I Opn /Sqz I DATE See Page 2 for Perforation Data DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/11/79 ORIGINAL COMPLETION 01/18/12 TMWJMD ADDED H2S SAFETY NOTE WELL: R -05A 11/89 TBG SUMMARY 05/21/12 RWJ /JMD TREE C/O (05/17 /12) PERMT No: '1972500 02/08/98 SIDETRACK COMPLETION API No: 50- 029 - 20388 -01 03/12/02 RNITP CORRECTIONS SEC 32, T12N, R13E, 707 NSL & 1293" EWL 06/06/08 JM'TLH PKR DEPTH CORRECTIONS 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alas ka) TREE= 6 X 7 CM/FLS • • we_LHEAD = IVCEVOY R-05A ACTUATOR = BAKER C KB, ELEV = 45,4' BF. ELEV = 24.95' KOP = 3191' ei Max Angle = 104* @ 129r-Sor —, Datum MD . .=- - 12734 ,— . , Datum 'R/D- 8800' SS I PERFORATION SUMMARY REF LOG: MWDGR/RES ON 10/02/98 1.1.1 ANGLE AT TOP PERF: 93° @ 10560' Note: Refer to Production DB for historical perf data 2 SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 10560 - 10581 0 02106/98 2-1/2" 6 10842 - 10863 0 02/06/98 2-1/2" 6 11106 - 11127 0 02106/98 2-1/2" 6 11297 - 11318 0 02/06/98 2-1/2" 6 11607 - 11628 0 02/06/98 2-1/7 6 12228 - 12249 0 02106/98 2-1/7 6 12302 - 12323 0 02/06/98 1 2-1/2" 6 12408 - 12429 0 02/06/98 er 2-1/7 6 12509 - 12530 0 02/06/98 2-1/7 6 12620 - 12641 0 02/06198 2-1/7 6 12706 - 12726 0 02/06/98 2-1/7 6 12833 - 12853 0 02106/98 4 • 7044444 ■•••••••1 •••••••• ■•••••••4 Illi •••••••• '......a•AttV ■14111411 0••••••• ••••••••• •••••••• &wt. - 1....w. DATE REV BY COMMENTS DATE REV BY COMNENTS PRUDHOE BAY UNIT 09111179 ORIGINAL COMPLETION 01/18/12 TIVICMD ADDED H2S SAFETY NOTE WELL: R-05A r 11189 TOG SUMMARY 05/21/12 RWAINV:i TREE C/0 (05/17/12) PERMIT No: r 1972500 02/06/98 SIDETRACK COM PLETION AR No: 50-029-20388-01 03/12/02 RNITP CORRECTIONS SEC 32, T12N, R13E, 707 NSL & 1293' EWL 06/06/08 JWTLH PKR DEPTH CORRECTIONS 02/15/11 NE/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) n ,~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~~ ~ ~ ~~~~ ~~~~1~~s~.:~ .iUL ~-~ 2~'G~ July 10, 2009 ~~ Mr. Tom Maunder 1(~~' ~ ~ Alaska Oil and Gas Conservation Commission ~~~ ~ 333 West 7th Avenue ~~ Anchorage, Alaska 99501 - Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator ~ • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na ai R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13(20~9 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-OS 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206150000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6l12i2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 ~ BP Exploration (Alaska) (nc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 .:! 'i June 26, 2009 ~ a ~ ' ~ O~~ ~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, • ~~ k A~ Ys,. _ ~ ~ , ~ ~ ~f UL ~ ~ ~00~ ~~~~~~ ~p~ ~ ~~~ ~ansm ~~mr-~s~fa~ ~A~chora Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. ~ As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, `~: ~~~~~~~ ~;;~L +9 ~i_ 2~~C ; Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) / Date R-pad . 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 1.25 NA 6.6 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5l14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-186 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 025 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5l14/2009 R-31 A 2021500 1.5 NA 1.5 NA 8.5 5/11l2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Tuesday, August 01,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-05A PRUDHOE BAY UNIT R-05A 'ð- 60 \<\1/ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed Br:->_ P I S 'if--c/- .. uprv~, /;- Comm NON-CONFIDENTIAL Permit Number: 197-250-0 Inspector Name: Chuck Scheve Inspection Date: 7/31/2006 Well Name: PRUDHOE SAY UNIT R-05A Insp Num: mitCS060801061126 Rei Insp Num API Well Number 50-029-20380-01-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __. "M ... '__~__'-------'----' " ~,,_~._~___.___ Well i R-05A !Type Inj. I W ! TVD 8307 lA' 400 , 2300 ' 2280 , 2280 I ' +--------L___+..___-------L_~____-----'--__ P.T. ! 1972500 !TypeTest I SPT I Test psi .!07675 ! OA I 500 I 500 i~- i 500-----,- : Interval 4YRTST P/F p/ Tubing I 1350 I 1350 I 1350 1350 I Notes Preteat pressures were observed and found stable, Well demonstrated good mechanical integrity. --------L_._ -, ".~ "J~\i~f; ...,t.;,I"I¡; t, ",",,- ~J ..., Tuesday, August 01, 2006 Page 1 of 1 ¢' STATE OF ALASKA ," ALASI[,-, OIL AND GAS CONSERVATION COt,,,,,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon[-'] Suspend['"~ Operation ShutdownE~ Perforate~--~ Variancer-~ Annuar Disposalr'"] After Casin.q[~ RepairWellE~] Plu.q Perforations [-'l Stimulate[--I Time Extensionr-I Other[] Change Approved Programr-] Pull Tubing["] Perforate New Pool~] Re-enter Suspended Well~-'~ CONVERT-WAG IN,J 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [-'] Exploratoryr"~ 197-250 13. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic ['-] Service [] 50-029-20380-01-00 7. KB Elevation (ft): 9. Well Name and Number: 45.40 R-05A 8. Property Designation: 10. Field/Pool(s): ADL 028279 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12950 feet true vertical 8799 feet Plugs (measured) Tagged TD @ 12666' (08/31/1998) Effective Depth measured 12666 feet Junk (measured) Fish @ 12862' true vertical 8861 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 130' 130' 40K 540 Surface 2643' 13-3/8" 2663' 2662' 80K 2670 Intermediate 8870' 9-5/8" 8890' 8699' 80K 4760 Liner 567' 7" 8397'-8964' 8218'-8771' 80K 7020 Sidetrack Liner 4703' 3-1/2" 8245'-12948' 8070'-8799' 80K 10530 Perforation depth: Measured depth: Open Peris 10560'-10581', 10842'-10863', 11106'-11127', 11297'-11318', Open Peris 11607'-11628', 12228'-12249', 12302'-12323', 12408'-12429', Open Peris 12509'-12530', 12620'-12641 ', 12705'-12726', 12833'-12853' True vertical depth: Open Peris 8924'-8922', 8894'-8892', 8901 '-8903', 8919'-8921', 8944'-8946', Open Peris 8938'-8935', 8927'-8924', 8910'-8906', 8892'-8888', 8870'-8866', Open Peris 8852'-8848', 8825'-8821'. Tubing: ( size, grade, and measured depth) 7" 26# L-80 TBG @ 8259'; 7" x 5-1/2" XO @ 8259'; 5-1/2" 17# L-80 @ 8397'. Packers & SSSV (type & measured depth) 7" x 5" BKR C2SS Packer @ 8245'. 9-5/8" x 5-1/2" TIW PKR Latch @ 8307'. 7" Otis HRQ SSSV Landing Nipple @ 2020'. ~,~..--. ......... 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaqe Production or Iniection I~' Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure ,.: '.'~,..,Tubi~g~Pressure Prior to well operation: 0 0 Subsequent to operation: 4330 1457 14. Attachments: 15. Well Class after proposed work: Exploratory r--I Developmentr"] service~ Copies of Logs and OCT ~[ 4 2003 16. Well Status after proposed work: o, FI asl--I WA [] S NJI--I W NJI--I WDSPLEI Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWayne R. Schnorr , Title Techical Assistant Signature ~_~_,,~d,~,~,~~j~.,~,.,,,,..~ Phone 907/564-5174 Date Sept17, 2003 ..... Form 10-404 Revised 2/2003 ORIGINAL R-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/01/1998 FIRST WATER INJECTION 05/02/1998 FIRST HI IN.1ECTION EVENT SUMMARY 04/01/98 FIRST WATER INJECTION. 05/02/99 FIRST MI INJECTION. FLUIDS PUMPED BBLS 0 DIESEL FOR PFF OF SURFACE EQUIPMENT 0 CRUDE 0 TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor Chairman THRU: Tom Maunder ~"~ ) Superv so / _( FROM: Chuck Scheve Petroleum Inspector DATE: July 24, 2002 SUBJECT: Mechanical Integrity Tests BPX ,R Pad PBU Prudhoe Bay NON- CONFIDENTIAL ~ Well J P.T.D.} Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Well[ P.T.D.[ Notes: WellI P.T.D.I Notes: R-05A 197-250 Packer Depth Pretest Initial 15 Min. 30 Min, JType,nj.I $ IT.v:o. 18131 J T.b,.gI lO5O 11050 11050 11050 JlntervalJ 4 Type teStJ P J TestpsiJ 2033 JCasingJ 0 J 2340I 234O J 234o'J P/F J P 198-088 JTypetestJ P JTestpsiJ 2113 I Casingl 0 I 2250 J 2250 J 2250 .I P/F J P 183-128 ITypetestJ P ITestpsiJ i8oo J CasingJ 140 J 2180 J 2150 J 2140 J P/F J __P 197-230 JTypetestJ P ITestpsiJ 2096 J CasingJ 60 J 2280 J'2280 I 2280 J P/F J P TypetestJ I TestpsiJ I Casing J J J J J P/F J Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs R Pad and witnessed the 4-year MIT on wells R-05A, R-20A, R-22 and R-25A. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all 4 wells demonstrating good mechanical integrity. M.I.T.'s performed: 4 Attachments: Number of Failures: :0__ Total Time during tests: 4_ cc: 6CANNED AUG 1 2 2002 MIT report form 5/12/00 L.G. MIT PBU R Pad 7-24-02 CS.xls 7/3t/2002 · i97,250_0 MD 12950 PRUDHOE BAY UNIT R-05A 50- 029-20380-01 BP EXPLORATION TVD 08799 · cO~mPletion Date: ~z~/6/98 Completed Status: 1W1NJ Current: T Name Interval Sent Received T/C/D D 8409 OH D 9306 CH L CMT MAP CH 5 L DGR-MD OH L DGR-TVD OH L INJP CH 5 D ~1~ SPERRY GR . yPDS INJP ~L 9245-8200 bfia~l~A L 8990-12950 t,,,FfNAL 8771-8799 ~ 10450-12732 t.-P~AL 8900-12940 L,FI~AL 8900-12940 L~INAL 8900-12940 ~' SCHLUM SLIM/AIT/PEX/BHC L SLIM-AlT OH L SLIM-BHC/SL OH L SLIM-NDT OH R MWD SRVY OH T 8328 OH Daily Well Ops /l/ttT/]--~-- -- 2/ (/q ~ Was the w_elkeo~~o-" 3/25/98 3/25/98 9/1/99 9/1/99 3/13/98 3/13/98 3/25/98 3/25/98 3/25/98 3/25/98 9/1/99 9/1/99 3/13/98 3/13/98 3/13/98 3/13/98 3/13/98 3/13/98 4/15/98 4/17/98 3/13/98 3/13/98 Are Dry Ditch Samples Required? yes _(~__~ And Rec~~m~~ Analysis Description~Re~iV~ff.~~~ml~ ~g~ Comments: Thursday, February 03, 2000 Page 1 of 1 STATE OF ALASKA ALASKA- ,.,_ AND GAS CONSERVATION COIV,~. >SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [~Operation Shutdown [~]Stimulate [] Pull Tubing []Alter Casing [] Repair Well [] Other 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 707' NSL, 1293' EWL, SEC. 32, T12N, R13E, UM At top of productive interval 190' NSL, 2791' EWL, SEC. 32, T11N, R13E, UM At effective depth At total depth 1592' NSL, 281' EWL, SEC. 32, T12N, R13E, UM E~ Plugging [~ Perforate 6. Datum Elevation (DF or KB) KBE = 45.40' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-05Ai 9. Permit Number / Approval No. 97-250 10. APl Number 50-029-20380-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12950 feet true vertical 8799 feet Effective depth: measured 12881 feet true vertical 8815 feet Casing Length Structural Conductor 110' Surface 2630' Intermediate 8857' Production Liner 1378' Size Plugs (measured) Junk (measured) fill at 9503' (05/90) Cemented 20" x 30" 13-3/8" 9-5/8" 605 cu ft Arcticset concrete 4325 cu ft Permafrost 1195 cu ft Class 'G', 30 cu ft PF 'C' 7" 332 cu ft Class 'G' MD TVD 143' 143' 2663' 2663' 8890' 8699' 8397' - 9775' 8316' - 9568' Perforation depth: measured 8972' - 9034' (Sag River) 9104' - 9240' (Six Ivishak Intervals) true vertical subsea 8725' - 8786' (Sag River) 8855' - 8988' (Six Ivishak Intervals) Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attached Treatment description including volumes used and final pressure 14. ~rior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments 16. Status of well classifications as: -- __ Copies of Logs and Surveys run [] Oil [] Gas [] Suspended . i Daily Report of Well..Operatio,~s 17. I hereby pe~ifv/,t~at tl~ foreg,C~n.g ~s true ~apd,~ect to the best of my knowledge Service Water Injection Prepared By Name/Number: Submit In ~ Duplicate Form 10-404 Rev. 06/15/88 R-05A .... DESCRIPTION OF WORK COMPLETED Stimulation Operation 08/O5/99 A Stimulation Treatment was performed using the following fluids: SUMMARY Perform SBG tubing and flowline wash for upcoming CTU STP work. 08/05/99 Road to ARCO pick up 334 Bbls hot (160) deg water and 2807 gals. (67) Bbls of dispersant and mix giving us a total of 401 Bbls of solution. Rig up chemical pump truck and tanker at manifold building. Note R-05 is twinned with R-32. Shut in R-32 for treatment. Pressure test hardline to 3500 PSI. Good Test. Hold Safety meeting. Inj Pressure=1150 Inj Temp = 132 lAP = 00AP = 800. Begin pumping solution down flowline and tubing. Pump pressure = 1200 @ 3 BPM. Chemical pump truck pump loses a seal. Shut Down. Call HB&R to location. HB&R on location pressure test hardline. Good Test. Resume pumping solution. 3 BPM @ 1150 PSI. All solution away. Shut down and wait three hours for soak time. Pressure test lines to 3500 PSI. Good Test. Begin pumping flush pW down flowline and tubing. 1150 PSI @ 3 BPM. Pump 300 Bbls of PW to flush solution. Leave Well shut in for three hours per program. R- 32 put back on injection. Rig down HB&R and secure location. SI Inj Pressure = 850 lAP = 00AP = 720. Put R-05 back on injection. SBG tubing and flowline wash completed per program. Well to be kept on injection for a week following treatment program. Injection pressure not to exceed 1500 PSI. CTU will perform and injection profile and the Well will be shut in one day prior to Coil Logging work. Fluids Pumped BBLS. Description 67 SBG (schmoo-b-gone). 334 Hot PW ["0V '1 2_ 1999 3OO PW 701 Total Pumped ~ Oil & (~as Cons. Commission R-05A ..... DESCRIPTION OF WORK COMPLETED Stimulation Operation 09/27/99 A Acid Stimulation Treatment was performed using the following fluids: SUMMARY Miru Dowell CTU #2. Jet washed tubing down 1:1 with 345 bbls SBG down to 12749' (stacked out). Displaced SBG away with 325 bbls 2% KCl water. Jet washed perforated interval from 10500-12730' with 40 bbls 7.5%20% HCI/Xylene. Noted some positive effects with the acid. Let acid soak. Conducted a work stoppage meeting to discuss with all personnel on location the policies/practices involving the environmental handling of fluids on the slope (discuss questions/concerns). Made additional jet pass to displace acid away. PUH and pumped injection rate survey with coil pump. POH. RDMO.Pre-job injection rate data:3 bpm (4300 bwpd) at 1375 psi whp (3.1 bwpd/psi). [injection rate from SCADA].Post-job injection rate data:5 bpm (7200 bwpd) at 1346 psi whp (5.3 bwpd/psi). [injection rate with CTU]. Sent strip chad to APE. Fluids Pumped 625 Freshwater w/2% Kcl. 345 SBG (schmoo-b-gone). 40 7.5%/20% HCI/Xylene. 42 Mech. 1052 Total RECEIVED f:OV i 2 1999 Alaska Oil & Gas Cons. Commission Anchorage Vt/ELL TRAiV$/I'HTTAL, ProActive Diagnostic Services, Inc. To~ State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE ' Distribution- Final Print(s) 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 · Carl Jablonski/Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technicai Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT(S) Open Hole I I 1 Res. Eval. CH I I 1 o..b-,4,' ~-i ,2- ~ ~ ~ I Signed · Print Name: Date · -~.~.~ ~ .. ProActive Diagnostic Services, Inc., Pouch 340112, P~~ay, AK 99734 Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com Please Check When Transmittal Reports are Returned. Keep copy of this letter in the file for future use. C:gVly Documents~Excel_Word_Documents~Distribution_Forms~Bp_pb_form.cloc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~J Oil [~ Gas E~ Suspended []Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-250 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20380-01 4. bocation of well at surface i~i'~:-;-i~';iii,,';~i'~'~ ]~~ 9. Unit or Lease Name ¢''_~.'_'¢~.'.~i~ .~ """""""'" ~--!,~~~_P rudhoe Bay Un it 707' NSL, 1293' EWL, SEC. 32, T12N, R13E, UM~i 2, At top of productive interval ~ .- .~ ~_ 10. Well Number 190' NSL, 2791' EWL, SEC. 32, T11N, R13E, UM ~'~'~li~.!r:,: : R-05Ai At tot,al depth , ~ ~--~.:~.~--,~: ~ 11 Field and Pool 1592 NSL, 281 EWL, SEC. 32, T12N, R13E, UM ~ ........... ':'-'-- -';' ' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 45.40'I ADb 028279 12. Date Spudded1/17/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre 116' NO' °f COmpletiOns1/30/98 2/6/98 N/A MSL, One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12950 8799 FTI 12881 8815 FTI ~]Yes [~No (Nipple) 2020' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD .... ~MO.U. NT P._ULLED 20" X 30" Insulated Conductor Surface 110' 36" 805 cu ft Arctic Set E ~"=,,=~¢,r_~ ~*; ~' _ 13-3/8" 72# L-80 Surface 2663' 17-1/2" !4325 cu ft Permafrost 9-5/8" 47# L-80 Surface 8890' 12-1/4" i1195 cu ft Class 'G', 30 cu ft PF 'C' A. PR ~ 7 1998 7" 29# L-80 8397' 8964' 8-1/2" 332 cu ft Class 'G' 3-1/2" 9.3# L-80 8245' 12948' 4-1/2" 406 cuft Class 'G' 24'. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD ¢'~8~"~ ' Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 6 spf 7", 26#, L-80 8259' MD TVD MD -I-VD 5-1/2"; L-80 8259' to 8397' 8307' 10560' - 10581' 8923' - 8922' 12509' - 12530' 8892' - 8888 .............. 10842' - 10863' 8894' - 8892' 12620' - 12641' 8870' - 8866' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11106' - 11127' 8901' - 8903' 12705' - 12726' 8853' - 8848' DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED 11297' - 11318' 8919' - 8921' 12833' - 12853' 8825' - 8821' 11607' - 11628' 8945' - 8946' Freeze Protect with 84 Bbls of Diesel 12228' - 12249' 8938' - 8935' 12302' - 12323' 8927' - 8924' 12408' - 12429' 8910' - 8906' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 1, 1998J Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE I GAS-O~L RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 8964' 8771' Shublik A 9019' 8823' Shublik B 9074' 8870' Shublik C 9097' 8888' Sadlerochit 9123' 8907' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby ce(~fy that the ~~rue and correct to the best of my knowledge Signed janjr~s~.~ " Title Senior Drilling Engineer Date ~' R-05Ai 97-250 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. ~NSTRUCTIONS 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 Facility IDB R Pad Progress Report Well R-05A Rig Doyon 16 Page Date 1 11 February 98 Date/Time 14 Jan 98 15 Jan 98 16 Jan 98 17 Jan 98 18 Jan 98 19 Jan 98 02:00-06:00 06:00-06:30 06:30-07:00 07:00-09:30 09:30-10:00 10:00- I 1:00 I 1:00-11:30 11:30-13:00 13:00-18:30 18:30-19:00 19:00-20:45 20:45-21:30 21:30-02:00 02:00-04:00 04:00-04:45 04:45-06:00 06:00-06:30 06:30-14:30 14:30-16:30 16:30-18:00 18:00-18:30 18:30-23:00 23:00-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-11:00 11:00-18:00 18:00-18:30 18:30-19:30 19:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-11:30 11:30-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-02:30 02:30-06:00 Duration 4 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr I hr 1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1-3/4 hr 3/4 hr 4-1/2 hr 2 hr 3/4 hr 1-1/4 hr 1/2 hr 8 hr 2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 2 hr 1 hr 4 hr 1/2 hr 1 hr 2-1/2 hr 1 hr 7 hr 1/2 hr 1 hr 6-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 5 hr 2 hr 1/2 hr 4 hr 1/2 hr 9-1/2 hr 1 hr I hr 1/2 hr 5-1/2 hr 2 hr 3 hr 1/2 hr I hr 3 hr 4 hr 3-1/2 hr Activity Rig moved 90.00 % Held safety meeting Rig moved 100.00 % Fill pits with Seawater Held safety meeting Removed Hanger plug Installed Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Removed Tubing head spool Installed Tubing head spool Tested BOP stack Retrieved Hanger plug Installed Wear bushing Made up BHA no. 1 Held safety meeting R.I.H. to 8374.0 ft Circulated at 8374.0 ft Pulled out of hole to 5685.0 ft Held safety meeting Pulled out of hole to 103.0 ft Pulled BHA Made up BHA no. 1 R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 8375.0 ft Milled Landing nipple assembly at 8375.0 ft · ,., R.I.H. to 8964.0 ft ~-Milled Liner at 8964.0 ft Held safety meeting Circulated at 8980.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 2 R.I.H. to 800.0 ft Held safety meeting R.I.H. to 8180.0 ft Serviced Lines / Cables R.I.H. to 8980.0 ft Drilled to 9054.0 ft Held safety meeting Drilled to 9390.0 ft Circulated at 9390.0 ft Pulled out of hole to 8000.0 ft Held safety meeting Pulled out of hole to 184.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 2071.0 ft Held safety meeting Pulled out of hole to 184.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 6800.0 fl Facility DatefI'ime 20 Jan 98 21 Jan 98 22 Jan 98 23 Jan 98 PB R Pad 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-18:00 18:00-18:30 18:30-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-10:00 I0:00-10:30 10:30-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-01:00 01:00-02:00 02:00-03:15 03:15-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-02:00 02:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-11:00 11:00-11:30 11:30-16:00 16:00-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:00 Duration 1/2 hr I-1/2 hr 1/2 hr 1/2 hr 1 hr 8 hr 1/2 hr 5-I/2 hr 5 hr 1 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 5 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 5 hr 1 hr 1-1/4 hr 2-3/4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 9 hr 1/2 hr 1/2 hr 1-1/2 hr 5- l/2 hr I- 1/2 hr 1/2 hr 2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1 hr 4hr 112 hr 112 hr Progress Report Well R-05A Rig Doyon 16 Page Date Activity Held safety meeting R.I.H. to 8964.0 ft Set tool face R.I.H. to 9285.0 ft Washed to 9390.0 ft Drilled to 9566.0 ft Held safety meeting Drilled to 9661.0 ft Pulled out of hole to 185.0 ft Pulled BHA Held safety meeting Pulled BHA Made up BHA no. 5 Tested M.W.D. tool - Via string R.I.H. to 8964.0 ft Set tool face R.I.H. to 9210.0 ft Washed to 9661.0 ft Held safety meeting Drilled to 9684.0 ft Circulated at 9684.0 ft Pulled out of hole to 184.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 3000.0 ft Held safety meeting R.I.H. to 8915.0 ft Set tool face R.I.H. to 9684.0 ft Drilled to 9853.0 ft Held safety meeting Drilled to 9860.0 ft Circulated at 9860.0 ft Pulled out of hole to 184.0 ft Pulled BHA Retrieved Bore protector Tested BOP stack Held safety meeting Tested BOP stack Installed Bore protector Made up BHA no. 6 Took MWD survey at 274.0 ft R.I.H. to 8914.0 ft Set tool face R.I.H. to 9860.0 ft Drilled to 9864.0 ft Held safety meeting Circulated at 9860.0 ft Pulled out of hole to 68.0 ft Pulled BHA Made up BHA no. 7 R.I.H. to 6500.0 ft Held safety meeting R.I.H. to 9141.0 ft 2 11 February 98 Facility PB R Pad Progress Report Well R-05A Rig Doyon 16 Page Date 3 11 February 98 Date/Time 24 Jan 98 25 Jan 98 26 Jan 98 27 Jan 98 28 Jan 98 07:00-07:30 07:30-08:00 08:00-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-10:30 10:30-11:00 1 I:00-11:30 11:30-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-10:00 10:00-11:00 11:00-12:30 12:30-13:30 13:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-01:30 01:30-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-13:00 13:00-17:30 17:30-18:00 18:00-19:00 19:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-22:00 22:00-23:00 23:00-23:30 23:30-03:00 03:00-05:00 05:00-06:00 Duration 1/2 hr 1/2 hr 6-I/2 hr 1-1/2 hr 2 hr 1/2 hr 5-1/2 hr 1/2 hr l/2 hr 5 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 5-1/2 hr I hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 - 1/2 hr 1 hr 4 hr 1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 1 hr 2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr I- 1/2 hr 4-1/2 hr I/2 hr 1 hr 11 hr I/2 hr 11-1/2 hr 1/2 hr 3-1/2 hr I hr 1/2 hr 3-1/2 hr 2hr I hr Activity Washed to 9245.0 ft R.I.H. to 9864.0 ft Drilled to 9940.0 ft Circulated at 9940.0 ft Pulled out of hole to 7850.0 ft Held safety meeting Pulled out of hole to 75.0 ft Pulled BHA Made up BHA no. 8 R.I.H. to 4811.0 ft Held safety meeting R.I.H. to 8935.0 ft Set tool face R.I.H. to 9259.0 ft Washed to 9355.0 ft R.I.H. to 9940.0 ft Drilled to 10020.0 ft Held safety meeting Drilled to 10124.0 ft Circulated at 10124.0 ft Pulled out of hole to 75.0 ft Pulled BHA Held safety meeting Made up BHA no. 9 Tested M.W.D. tool - Via string R.I.H. to 3019.0 ft Tested M.W.D. tool - Via string Pulled out of hole to 68.0 ft Serviced M.W.D. tool R.I.H. to 8908.0 ft Set tool face R.I.H. to 10064.0 ft Reamed to 10124.0 ft Drilled to 10518.0 ft Worked toolstring at 10493.0 ft Circulated at 10518.0 ft Pulled out of hole to 8800.0 ft Held safety meeting Pulled out of hole to 184.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 8939.0 ft Set tool face R.I.H. to 10518.0 ft Drilled to 10965.0 ft Held safety meeting Drilled to 11669.0 ft Held safety meeting Drilled to 11792.0 ft Pulled out of hole to 10793.0 ft RAH. to 11792.0 ft Drilled to 11935.0 ft Pulled out of hole to 8561.0 ft Serviced Block line Progress Report Facility PB R Pad Well R-05A Rig Doyon 16 Page 4 Date 11 February 98 Date/Time 06:00-06:30 06:30-10:30 10:30-I 1:30 11:30-13:00 13:00-17:00 17:00-17:30 17:30-19:00 19:00-19:30 19:30-06:00 29 Jan 98 06:00-06:30 06:30-07:00 07:00-13:00 13:00-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:30 20:30-02:00 30 Jan 98 02:00-06:00 06:00-06:30 06:30-07:00 07:00-23:30 23:30-00:00 31 Jan 98 00:00-01:00 01:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-23:00 23:00-03:00 01 Feb 98 03:00-06:00 06:00-06:30 06:30-07:30 07:30-11:00 11:00-12:00 12:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-04:00 02 Feb 98 04:00-04:30 04:30-06:00 06:00-06:30 Duration 1/2 hr 4 hr I hr 1- I/2 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 1/2 hr 6 hr 1 hr I/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 5-1/2 hr 4 hr 1/2 hr 1/2 hr 16-1/2 hr 1/2 hr 1 hr 2 hr 2 hr 1 hr 1/2 hr 1-1/2 hr 7 hr 1-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 4 hr 3 hr I/2 hr I hr 3-1/2 hr 1 hr 2 hr 1 hr 3 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 7 hr 1/2 hr 1-I/2 hr 1/2 hr Activity Held safety meeting Pulled out of hole to 71.0 ft Pulled BHA Made up BHA no. 12 R.I.H. to 8940.0 ft Set tool face R.I.H. to 11893.0 ft Reamed to 11935.0 ft Drilled to 12117.0 ft Held safety meeting Circulated at 12117.0 ft Pulled out of hole to 74.0 ft Pulled BHA Retrieved Bore protector Tested BOP stack Held safety meeting Tested BOP stack Installed Bore protector Made up BHA no. 13 R.I.H. to 8940.0 ft R.I.H. to 9850.0 ft Held safety meeting R.I.H. to 12117.0 ft Drilled to 12950.0 ft Circulated at 12950.0 ft Pulled out of hole to 12020.0 ft Pulled out of hole to 8990.0 ft R.I.H. to 12950.0 ft Circulated at 12950.0 ft Held safety meeting Circulated at 12950.0 ft Pulled out of hole to 184.0 ft Pulled BHA Rigged up sub-surface equipment - Formation logs Held safety meeting Ran logs on tubulars Installed Logging/braided cable equipment Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Retrieved Cable head Pulled out of hole to 5532.0 ft Laid down 902.0 ft of 3-1/2in OD drill pipe Laid down 3472.0 ft of 2-7/8in OD drill pipe Held safety meeting Laid down 1157.0 ft of 2-7/8in OD drill pipe Retrieved Formation logs Installed Bore protector Rigged up Tubing handling equipment Ran Liner to 4689.0 ft (3-1/2in OD) Rigged up Tubing handling equipment Installed Downhole equipment Held safety meeting Progress Report Facility PB R Pad Well R-05A Rig Doyon 16 Page 5 Date 11 February 98 Date/Time 03 Feb 98 04 Feb 98 05 Feb 98 06 Feb 98 06:30-10:30 10:30-11:30 11:30-12:00 12:00-15:30 15:30-16:00 16:00-18:00 18:00-21:00 21:00-22:00 22:00-22:30 22:30-23:00 23:00-03:00 03:00-06:00 06:00-06:30 06:30-07:00 07:00-10:00 10:00-16:00 16:00-16:30 16:30-21:30 21:30-22:30 22:30-23:30 23:30-00:30 00:30-02:30 02:30-04:00 04:00-06:00 06:00-09:00 09:00-13:00 13:00-00:30 00:30-01:00 01:00-02:30 02:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-07:00 07:00-15:00 15:00-17:00 17:00-22:30 22:30-23:00 23:00-23:30 23:30-00:30 00:30-04:30 04:30-06:00 06:00-07:00 07:00-10:00 10:00-11:00 11:00-12:30 12:30-14:00 Duration 4 hr Iht 1/2 hr 3-1/2 hr 1/2 hr 2 hr 3 hr 1 hr 1/2 hr 1/2 hr 4 hr 3 hr 1/2 hr 1/2 hr 3 hr 6 hr 1/2 hr 5 hr 1 hr 1 hr 1 hr 2 hr 1-1/2 hr 2 hr 3 hr 4 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 8 hr 2 hr 5-1/2 hr 1/2 hr 1/2 hr 1 hr 4 hr I-1/2 hr 1 hr 3 hr I hr 1-1/2 hr 1-1/2 hr Activity Installed Downhole equipment Installed Locator seal assembly Circulated at 4701.0 ft Ran Drillpipe in stands to 8960.0 ft Circulated at 8960.0 ft Ran Drillpipe in stands to 12948.0 fl Circulated at 12948.0 ft Mixed and pumped slurry - 72.400 bbl Displaced slurry - 70.900 bbl Functioned Setting tools Circulated at 12876.0 ft Fill pits with Seawater Held safety meeting Fill pits with Seawater Pulled Drillpipe in stands to 4589.0 ft Laid down 4589.0 ft of Tubing Rigged up Wireline units Conducted electric cable operations Rigged down Wireline units Tested Liner Serviced Block line Space out tubulars Space out tubulars Rigged up sub-surface equipment - Gun assembly Rigged up sub-surface equipment - Gun assembly Ran Tubing to 4697.0 ft (2-1/16in OD) Ran Drillpipe in stands to 12862.0 ft Circulated at 12854.0 ft Serviced High pressure lines Tested High pressure lines Functioned Retrievable packer Circulated at 10580.0 ft Perforated Functioned Retrievable packer Laid down 8175.0 ft of 3-1/2in OD drill pipe Laid down 2384.0 ft of Tubing Rigged down sub-surface equipment - Gun assembly Rigged down Kelly Removed Bore protector Installed Accessories Rigged down BOP stack Installed Xmas tree Installed Adapter spool Installed Xmas tree Removed Hanger plug Freeze protect well - 84.000 bbl of Diesel Installed Hanger plug SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE ! SHARED SERVICES DRILLING PBU / R-0SA 500292038801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 013198 MWD SURVEY JOB NUMBER: AKMW80085 KELLY BUSHING ELEV. = 45.40 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 8891.35 8700.14 8654.74 12 18 S 55.41 E .00 8964.00 8771.17 8725.77 11 56 S 51.76 E 1.17 9006.73 8812.08 8766.68 21 16 S 40.27 E 23.07 9038.23 8840.43 8795.03 30 9 S 36.55 E 28.64 9069.86 8867.01 8821.61 35 28 S 34.24 E 17.25 445.67S 1440.27E -1487.55 454.71S 1452.54E -1502.57 463.39S 1461.05E -1514.06 474.13S 1469.47E -1526.39 488.11S 1479.38E -1541.50 9101.11 8891.46 8846.06 41 28 S 32.50 E 19.54 9132.28 8913.61 8868.21 47 54 S 33.26 E 20.67 9165.98 8934.65 8889.25 54 46 S 34.21 E 20.50 9198.23 8951.41 8906.01 62 34 S 37.22 E 25.49 9229.95 8964.21 8918.81 69 46 S 38.76 E 23.13 504.35S 1490.05E -1558.31 522.74S t501.95E -1577.18 544.61S t516.56E -1600.03 566.94S 1532.65E -1624.40 589.78S 1550.51E -1650.59 9261.86 8973.07 8927.67 77 57 S 39.74 E 25.80 9293.79 8976.89 8931.49 88 16 S 39.42 E 32.34 9325.64 8977.13 8931.73 90 51 S 36.09 E 13.23 9356.91 8976.78 8931.38 90 25 S 30.87 E 16.75 9388.69 8976.87 8931.47 89 13 S 23.77 E 22.66 613.50S 1569.89E -1678.53 637.90S 1590.06E -1707.48 663.07S 1609.56E -1736.18 689.14S 1626.80E -1763.26 717.36S 1641.38E -1788.91 9420.68 8977.74 8932.34 87 40 S 14.08 E 30.67 9452.73 8979.33 8933.93 86 39 S 5.90 E 25.69 9484.85 8980.98 8935.58 87 28 S 4.89 W 33.65 9516.64 8982.09 8936.69 88 31 S 13.52 W 27.33 9548.85 8982.42 8937.02 90 18 S 23.73 W 32.18 747.57S 1651.74E -1811.69 779.07S 1657.29E -1830.74 811.10S 1657.57E -1845.31 842.43S 1652.49E -1854.78 872.91S 1642.22E -1859.22 9580.39 8982.41 8937.01 89 43 S 31.36 W 24.26 9610.54 8982.54 8937.14 89 47 S 39.19 W 25.97 9644.60 8983.28 8937.88 87 43 S 46.77 W 23.06 9676.72 8984.73 8939.33 87 4 S 53.38 W 20.66 9708.93 8985.90 8940.50 88 46 S 61.33 W 25.22 900.85S 1627.64E -1858.67 925.45S 1610.24E -1854.11 950.34S 1587.05E -1844.49 970.92S 1562.45E -1831.70 988.27S 1535.37E -1815.23 9740.93 8986.13 8940.73 90 24 S 68.13 W 21.85 1001.92S 1506.45E -1795.47 9773.00 8985.30 8939.90 92 34 S 76.34 W 26.48 1011.70S 1475.95E -1772.55 9805.24 8983.31 8937.91 94 29 S 85.71 W 29.61 1016.71S 1444.20E -1746.40 9836.49 8980.67 8935.27 95 10 N 84.93 W 29.92 1016.50S 1413.10E -1718.49 9868.88 8977.81 8932.41 94 56 N 75.30 W 29.62 1010.97S 1381.35E -1687.62 9894.67 8976.04 8930.64 92 53 N 67.05 W 32.90 1002.67S 1357.02E -1662.14 9926.76 8974.90 8929.50 91 10 N 57.59 W 29.94 987.79S 1328.66E -1630.12 9958.87 8974.22 8928.82 91 15 N 50.33 W 22.61 968.92S 1302.72E -1598.47 9991.06 8972.62 8927.22 94 25 N 49.45 W 10.22 948.21S 1278.13E -1567.22 10021.75 8969.97 8924.57 95 28 N 50.46 W 4.74 928.54S 1254.73E -1537.49 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA. -PAGE 2 SHARED SERVICES DRILLING PBU / R-05A 500292038801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 013198 MWD SURVEY JOB NUMBER: AKMW80085 KELLY BUSHING ELEV. = 45.40 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. 10053.64 8966.75 8921.35 10087.05 8963.01 8917.61 10118.47 8959.40 8914.00 10149.21 8955.70 8910.30 10181.06 8951.58 8906.18 96 7 96 43 96 30 97 18 97 33 N 50.05 W 2.38 908.25S 1230.33E N 50.47 W 2.19 887.03S 1204.80E N 51.33 W 2.80 867.34S 1180.58E N 51.69 W 2.82 848.35S 1156.70E N 51.72 W .79 828.78S 1131.91E -1506.60 -1474.28 -1443.81 -1413.96 -1383.03 10246.03 8944.45 8899.04 10342.43 8936.92 8891.52 10439.04 8930.87 8885.47 10532.68 8925.69 8880.29 10628.81 8917.93 8872.53 95 4 93 53 93 17 93 3 96 12 N 51.47 W 3.84 788.67S 1081.32E N 53.68 W 2.59 730.28S 1005.01E N 52.98 W .95 672.70S 927.68E N 53.43 W .54 616.70S 852.81E N 51.38 W 3.91 558.26S 776.90E -1319.85 -1225.49 -1130.57 -1038.56 -944.53 10723.41 8907.35 8861.95 10819.47 8896.36 8850.96 10851.64 8893.22 8847.82 10884.96 8891.05 8845.65 10916.98 8889.96 8844.56 96 37 96 30 94 41 92 48 91 4 N 50.83 W .73 499.23S 703.74E N 51.45 W .65 439.36S 629.43E N 52.48 W 6.49 419.64S 604.22E N 52.54 W 5.68 399.4tS 577.84E N 52.79 W 5.46 380.00S 552.40E -852.69 -759.46 -728.09 -695.44 -664.01 10949.16 8889.81 8844.41 10981.41 8890.66 8845.26 11013.43 8892.70 8847.30 11044.91 8895.36 8849.96 11140.90 8904.47 8859.07 89 28 87 30 85 11 85 6 84 0 N 53.12 W 5.05 360.61S 526.71E N 53.39 W 6.20 341.33S 500.88E N 53.40 W 7.21 322.28S 475.24E N 53.00 W 1.29 303.49S 450.12E N 54.57 W 2.00 247.04S 373.04E -632.37 -600.65 -569.19 -538.32 -444.13 11237.22 8913.79 8868.39 84 54 11332.82 8922.85 8877.45 84 13 11428.73 8931.67 8886.27 85 13 11524.71 8938.62 8893.22 86 27 11620.81 8945.50 8900.10 85 19 N 53.23 W 1.67 190.56S 295.58E N 55.64 W 2.61 135.22S 218.19E N 54.23 W 1.80 80.36S 140.03E N 54.40 W 1.29 24.52S 62.28E N 53.65 W 1.41 31.78N 15.29W -349.60 -255.62 -161.18 -66.67 27.89 11716.64 8953.49 8908.09 11781.07 8958.79 8913.38 11844.69 8963.77 8918.37 11876.76 8966.24 8920.84 11908.08 8968.38 8922.98 85 5 85 28 85 32 85 36 86 33 N 52.84 W .88 88.92N 91.80W N 51.19 W 2.62 128.44N 142.40W N 50.37 W 1.29 168.54N 191.54W N 51.32 W 2.96 188.73N 216.33W N 49.16 W 7.51 208.71N 240.35W 121.87 184.81 246.69 277.89 308.30 11940.81 89?0.09 8924.69 11973.68 8970.58 8925.18 12006.04 8969.15 8923.75 12035.87 8966.60 8921.20 12069.10 8962.48 8917.08 87 26 90 51 94 11 95 37 98 38 N 49.02 W 2.78 230.12N 265.05W N 49.38 W 10.43 251.59N 289.92W N 48.53 W 10.62 272.81N 314.30W N 48.15 W 4.96 292.57N 336.50W N 48.48 W 9.14 314.49N 361.13W 339.97 371.82 403.12 431.81 463.64 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA · PAGE 3 SHARED SERVICES DRILLING PBU / R-05A 500292038801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 013198 MWD SURVEY JOB NUMBER: AKMW80085 KELLY BUSHING ELEV. = 45.40 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12163.35 8948.05 8902.65 98 58 N 49.16 W .79 12259.71 8933.43 8888.03 98 28 N 48.89 W .58 12355.83 8918.60 8873.20 99 16 N 48.66 W .87 12451.26 8902.44 8857.04 /~ 12 N 47.67 W 1.41 12547.47 8884.71 8839.31 /~ 2 N 48.23 W 1.03 12643.41 8865.46 8820.06 /~Z 5 N 48.39 W 1.12 12739.14 8845.41 8800.01 I~ 5 N 50.11 W 1.76 12834.53 8825.04 8779.64 34 N 49.10 W 1.15 12901.19 8810.12 8764.72 ' ~ 17 N 49.07 W 1.08 12950.00 8798.73 8753.33 ~O~ 41 N 49.07 W .84 375.82N 431.23W 553.76 438.27N 503.13W 646.00 500.86N 574.56W 737.88 563.58N 644.63W 828.60 626.92N 714.85W 919.72 689.43N 785.03W 1010.45 750.52N 855.93W 1101.19 810.91N 926.90W 1191.67 853.46N 976.00W 1254.61 884.55N 1011.86W 1300.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1343.98 FEET AT NORTH 48 DEG. 50 MIN. WEST AT MD = 12950 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 296.56 DEG. TIE-IN SURVEY AT 8,891.35' MD WINDOW POINT AT 8,964.00' MD PROJECTED SURVEY AT 12,950.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA · PAGE 4 SHARED SERVICES DRILLING PBU / R-05A 500292038801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 013198 JOB NUMBER: AKMW80085 KELLY BUSHING ELEV. = 45.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8891.35 8700.14 8654.74 9891.35 8976.22 8930.82 10891.35 8890.73 8845.33 11891.35 8967.36 8921.96 12891.35 8812.38 8766.98 445.67 S 1440.27 E 1003.94 S 1360.09 E 395.52 S 572.77 E 197.82 N 227.69 W 847.19 N 968.76 W 191.21 915.13 723.92 2000.62 1085.48 2923.99 923.38 4078.97 1154.97 12950.00 8798.73 8753.33 884.55 N 1011.86 W 4151.27 72.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA -PAGE 5 SHARED SERVICES DRILLING PBU / R-05A 500292038801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 013198 JOB NUMBER: AKMW80085 KELLY BUSHING ELEV. = 45.40 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8891.35 8700.14 8654.74 8937.66 8745.40 8700.00 8971.35 8778.34 8732.94 445.67 S 1440.27 E 451.34 S 1448.26 E 455.75 S 1453.79 E 191.21 192.26 1.05 193.01 .75 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. .Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs R-05A. AX-MW-80085 March 25, 1998 R-05A: 2" x 5" ~MD Gamma Rav Logs: 50-029-20388-01 2"x 5" TVD Gamma Ray Logs: 50-029-20388-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACltED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. .Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company WELL LOG TRANSMITTAL To: State of Alaska March 25, 1998 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ?'/-- ~"--(~ MWD Formation Evaluation Logs R-05A, AK-NFvV-80085 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Wav. #G, .Anchorage, .AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20388-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 3/1 3/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11914 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape R-05A ~ '~ ~,~.~ 98119 SLIM ACCESS AIT/PEX/BHC 980201 1 R-05A 98119 SLIM ACCESS AlT 980201 1 1 R-05A 9811 9 SLIM ACCESS NEUTRON DENSITY 980201 I 1 R-O5A 9811 9 SLIM ACCESS BHC 980201 1 1 R-O5A 98119 CEMENT MAP LOG 980203 1 1 R-25A ~ ~.~,..~_~c':[ 98047 SLIM ACCESS AIT/PEX/BHC 980108 1 R-25A 98047 SLIM ACCESS AlT 980108 I 1 R-25A 98047 SLIM ACCESS NEUTRON DENSITY 9801 08 I 1 R-25A 98047 SLIM ACCESS BHC l..,~,½r.c~ ~t, ~,~.. 980108 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~ ~.-'~ ~'~'~";,',"" '%,,/_~,.L~.,~ .... ~ UUk BP EXPLORATION BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 TELECOPY TO: SATELLITE UNIT Name: ~Z//-//~ , ~tJo~/').~Z/_.. Company: Location: .~ft/c.~. . Fax # FROM: NOTES: ,,,'r-F 2'-t.rt you /Y--,,F i/,o PAGES TO FOLLOW. II SECURITY CLASSIFICATION (Do not include cover sheet) ~a q' ~0 ~ A~W.. PRIVATE · SECRET _ i CONFIDENTIAL, SATELLITE FAX MACHINE FAX# CONFIRM# 1998 0 22-141 50 SHEETS 22-142 100 SHEETS 22-T4~ 21)0 SHEETS I ' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johann, DATE: ChairmanJ~ January 22, 1998 THRU' Blair Wondzell, ~/,~.,~(,~8 FILE NO: P. I. Supervisor aiikavfe.doc FROM: Chuck Scheve, ~ ) SUBJECT: Petroleum Inspector BOPE Test Doyon 16 PBU R-05Ai PTD # 97-250 Tuesday November 25, 1997: I traveled to BPXs R-05AI Well being drilled by Doyon Rig 16 and witnessed the weekly BOPE test. As the attached AOGCC BOPE test report shows/the test lasted 4.5 hours with one failure. Valve #8 on the choke manifold failed to pressure test. This Valve was rebuilt and tested by toolpusher Scott Helm after I departed location. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to the rig. Summary: Doyon 16, Attachment: I witnessed the weekly BOPE on Doyon rig 16. 1122/98, test time 4.5 hours, one failure aiikavfe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: 1/22,/98 Doyon Rig No. ~' PTD # 97-250 Rig Ph.# 659-4610 SSD Rep.: Micheal Jackson R-05AI Rig Rep.: Scott Heim Set @ Location: Sec. 32 T. 12N R. 13E Meddian Umiat Weekly X Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes FLOOR SAFETY VALVES: Well Sign OK Upper Kelly / IBOP Drl. Rig OK Lower Kelly / IBOP Hazard Sec. OK · Ball Type · Inside BOP Quan, 1 1 Pressure P/F 250/5,000 P 250/5,000 P 250/5,000 P P 250/5,000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F I 250/2500 P I 250/5,000 P 1 250/5,000 P 250/5,000 P P CHOKE MANIFOLD: No. Valves 13 No. Flanges Manual Chokes 1 Hydraulic Chokes I 250/5,000 250/5,000 P 250/5,000 P N/A ; N/A Test Pressure P/F 250/5,000 F/P 26 250/5,000 Functioned Funclfoned P P P 1 2 1 ACCUMULATOR SYSTEM: N/A System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 sec. Trip Tank OK OK System Pressure Attained 1 minutes 55 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 ~ 2000 PSI Meth Gas Detector OK OK ° Psig. H2S Gas Detector OK OK , 2900 1700 Number of Failures: I ,Test Time: 4.5 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Valve ~8 on choke manifold failed to pressure test, it was rebuilt and tested OK Distribution: orig-Weli File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev. 12/94) aiikavfe TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 30, 1997 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit R-05Ai BP Exploration (Alaska) Inc. Permit No. 97-250 Sur. Loc. 707'NSL. 1293'EWL, Sec. 32. T12N. R13E, UM Btmnhole Loc. 1522'NSL, 206'EWL, Sec. 32, T12N, R13E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by lax,,' from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of the Commission mav witness the tests. Notice max' be given bv nspector on the North Slope pager at 659-3607. David W. J~nston ~ ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section xv/o encl. Department of Environmental Conservation w/o encl. , STATE OF ALASKA ALAS,~:-, OIL AND GAS CONSERVATION C--OMMISSION PERMIT TO DRILL 20 AAC 25.005 Revised: 12/22/97 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 46.9 Prudhoe Bay Field / Prudhoe 3. Address !6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 4. Location of well at surface i7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 707' NSL, 1293' EWL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 5023' NSL, 2586' EWL, SEC. 05, T11N, R13E, UM R-05Ai At total depth 9. Approximate spud date Amount $200,000.00 1522' NSL, 206' EWL, SEC. 32, T12N, R13E, UM 01/07/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028282, 1522'I No Close Approach 2560 12988' MD / 8755' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8970' MD Maximum Hole Angle 102° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-1/2" 3-1/2" 9.8# L-80 ST-L 4788' 8200' 7968' 12988' 8755' 334 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen OperationS.Present well condition summary0 R J GJ NA L Total depth: measured 9780 feet Plugs (measured) true vertical 9573 feet Effective depth: measured 9503 feet Junk (measured) fill at 9503' (05/90) true vertical 9301 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" x 30" 605 cuft Arcticset concrete 143' 143' Surface 2630' 13-3/8" 4325 cu ft Permafrost 2663' 2663' Intermediate 8857' 9-5/8" 1195 cuft Class 'G', 30 cuft PF 'C' 8890' 8699' Production Liner 1378' 7" 332 cuft Class 'G' 8397' - 9775' 8316' - 9568' RECEIVED Perforation depth: measured 8972'- 9034' (Sag River) ~P~-C 2 ~199; 9104' - 9240' (Six Ivishak Intervals) true vertical subsea 8725' - 8786' (Sag River) 8855' - 8988' (Six Ivishak Inteil~a CJJJ & Gas Cons. CommisBi~ r, i20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] ~E~verCtJtet~ ~J~ch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number:___ . _,__ .l/D/~otlz, 564-4922 . Chris Brown, 564-5582 Prepared By Name/Number: Terrie Hubble, 564-4628 21.1 hereby certify that tl~ f¢going/~,/~r~an/~/gorrect to the best of my knowledge Signed _~=;~.~,.///,,e~~' ~ --~ Title Senior Drilling Engineer, Acting Date Commission Use Only Permit Number APl Number ~'~,2' "~ ~.<~.) 50-029-20380-01 l'~/'~q~3 for other requirements Conditions of Approval' Samples Required []Yes []No Mud Log Required ' -- []Yes ~No Hydrogen Sulfide Measures ]~Yes [] No Directional Survey Required ~J~Yes [--INo Required Working Pressure for BOPE •2M; •3M' *J~5M; 1-110M; ~15M Other: 0i-iginat SigFleo dh W. J0hnst0r, by order of David Commissioner the commission Date Approved By :orm 10-401 Rev. 12-01-85 Submit~ ; I Well Name: ]R-05ai I Sidetrack Plan Summary Type of Redrill (producer or injector): I hnjector [ Surface Location: 707' FSL, 1293' FWL, S32, T12N, R13E, UM Target Location: 5023:' FSL, 2586' FWL, S5, T1 iN, R13E, UM Bottom Hole Location: 1522' FSL, 206' FWL, S32, T12N, R12E, UM [AFE Number: [ 4P0985 I Estimated Start Date: IMD: 112,988 [ I 1/14/98 ~ Doyon 16 [ Operating days to complete: ] 28 I~= 18755 ] ~ ~6.9 I Well Design (conventional~ slimhole, etc.): I Through tubing horizontal sidetrack IObjective: I Sidetrack the R-05i well to the proposed Sag/Zone 4 target accessing new I injection zones Mud Pro~ram Whipstock Mud Properties: Solids Free 6 % Quikdriln Density Funnel LSR LSRV API FL ph (PPG) Viscosity YP 8.6-8.9 45-65 10-18 >35,000 NC 8.5-9.0 Production Mud Properties: Solids Free 6 % Quikdriln Density Viscosity LSR LSRV API FL pH (PPG) YP 8.6-8.9 45-65 10-18 >35,000 NC 8.5-9.0 Directional I KOP: l-+8,970'MD (estimated) [ Maximum Hole Angle: I +102° Close Approach Well: none R-05ai Sidetrack D~illing Permit Page 2/5 Formation Markers Formation Tops MD TVD (SS) 8970' 8730' Window kick off point TSag 8968' 8728' TShublik 9014' 8770' Tsad 9098' 8853' TD 12988' 8755' End of target polygon - 3-1/2" liner point HOT 8992' Not reached Casing/Tubing Program Hole Size Csg Wt/Ft Grade Conn Length Top Btm MDflW-Dss MD/TVDss 4.5" 3.5" 9.8 L80 ST-L 4788' 8200'/7968' 12988'/8755' 8.681" 7"/ 26/ L80/ IJ4S/ 8220'/ 32'/-15.1'/ 8252'/8029'/ 5-1/2" 17 L80 BTC 138' 8252'? 8390'/8164' NOTE: As this is a TTRD well, the 7"/5-1/2" tubing described above is already in place, and will not be disturbed during the sidetrack. Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 3.5" None 334 / 15.8 / 1.15 Class G: 40% excess; TOC at liner top; Pump time = 4+ hrs; Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as listed. Logging Program I Logs: 4.5" Hole Cased Hole: MWD GR. Platform express across reservoir interval (available in 4-1/2") CBL across liner Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. R-05ai Sidetrack Dr~ling Permit Page 3/5 Hazards This is a TTRD well, and since the annular volume of the well is small, a close watch must be kept on trip volumes, and tripping speeds to avoid surging and swabbing of the well. The main production target for this well is the Sag River, although the Ivishak will be penetrated briefly. For this reason, known hazards for the Ivishak are also listed below. Sag River The Sag River can sometimes have very low reservoir pressure in this area (as low as 6.1ppg or 2700-2900psi). Despite this, the pad data sheet indicates that only one well (R-36i) has experienced major lost circulation in this production interval, most other drilling wells experiencing only minor losses. The area does have some faults which, if present, are likely to be conductive, and this well does cross to 10-20' faults while in the target polygon, hence losses should be expected. Productive zone LCM will be employed to combat this. On the R-36i well, returns were also not obtained while cementing the casing in place. Losses should be cured before attempting to run casing. Risk of differential sticking is expected based on offset wells, but should be mitigated by the use of Quikdriln drilling fluid which is solids free. Ivishak Differential sticking has occurred frequently in the Ivishak at 9183' TVD. Once the sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using LSND mud; since the TTRD wells will employ solids free Quikdriln, this should mitigate the risk of sticking. High torque has been reported on several wells in the production hole, hence some open hole lubrication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole location of these wells are all in the same area. Wells from all three pads have experienced problems with bridges, tight hole, differential sticking, and packing off while in the production interval. This has caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area - be alert while driling this interval and employ frequent reaming if any sign of unstable hole is seen. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. R-05ai Sidetrack DHlling Permit Page 4/5 Operational Summary Pre-Rig Work: . . o . NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead manufacturer to initiate repairs. If repairs are not possible, the TTRD sidetrack may be halted, and an alternative sidetrack method used. This well is an injector, the Sag is frac'ed., and the remaining perforations will be thermally fractured. This means that the perforations will likely drink most or all of a standard cement plug. For this reason, it is recommended that a 20ppb aggregate cement plug is pumped until some squeeze pressure is obtained. If tubing and annulus have not recently (_<1 month) been tested RFLI wireline and retrieve SSSV. Set tubing plug in XN nipple. Perform MIT on tubing and annulus to 4,000psi. Test 9-5/8" packoff to 5,000psi. Retrieve tubing plug and POOH. Notify Operations Engineer immediately upon results of the annulus and packoff tests. RIH and retrieve XXN plug in tubing at 9,174'. Drift tubing to plug back TD at 9,509' (elm) with drift to ensure access to lower perforations. Drift tubing to XN nipple at 9,174' with drift to ensure whipstock (3.635" OD) pass through of minimum 3.8" OD. R/U CT unit and RIH to XN nipple at 9,174' (elm) with cementing BHA. Jet liner across the proposed cement interval in order to remove any debris (consider using "schmoo-be- gone"). Spot a balanced cement plug w/20ppb aggregate (crushed brick) from base of the well to -8,700' (open perforations from 8,972' to 9,240'), displacing with diesel against a closed choke until' 1,000psi squeeze pressure is seen. Run back in hole to _+9,013', circulating out excess cement with contaminant to obtain the required TOC at _+9,013'. POOH. Let the plug set up, then tag with slickline. NOTE: If necessary to prevent loss of cement, circulate well to a diesel cushion sufficient to remove hydrostatic overbalance from the cement column. Pick up underreamer sized for 7" 29# casing, and underream interval from 8,900' to 9,013' to ensure good casing for whipstock to set in. Tag TOC as required for AOGCC representative and POOH. NOTE: The under-reamer will be working across a perforated interval and hence care must be taken not to damage or lose any parts of the under-reamer arms R/U electric line. Set Baker through tubing whipstock oriented highside with top of whipstock at 8,967' set for a kickoff to exit the casing at 8,970' (the base of the whipstock should be at approximately 8,985'). This will put the top of the whipstock 3' MD below the base of the Kingak formation which is known to be troublesome. Please have a Baker representative on site when setting the whipstock. R/D electric line. R-05ai Sidetrack Dx-riling Permit Page 5/5 If cement plugback or whipstock setting problems are encountered, please contact SSD Ops Drilling Engineer immediately for possible alternative procedures. 6. M/U 4.55" OD milling assembly and RIH. Mill out XN nipple at 8,380' to 4.55". RIH, tag whipstock/liner and mill out/dress window to 4.55". Do not mill out more formation than is needed to bury the window dressing mill. 7. Circulate kill weight fluid and freeze protect with diesel (estimated BHP at 8800'TVDSS is 3,500psi - 7.6ppg EMW) to depth of +2,200'. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Rig Work: Prior to rig move, test 9-5/8" packoff to 5,000psi, and function lock down screws (FMC wellhead representative to do this). If any problems with the 9-5/8" packoff are observed, contact the wellhead manufacturer to initiate repairs. If repairs are not possible, the TTRD sidetrack may be halted, and an alternative sidetrack method used. 2. MIRU. Pull BPV and set/test TWCV. ND tree, NU BOP's and test same. Pull TWCV. RIH with 4.5" drilling assembly (circulate out freeze protection) and tag TD of new hole. Displace well to Quikdriln drilling fluid, and drill 4.5" hole section to TD of 12988' as per directional plan. 4. RIH with DPC logs and make logging run across open hole section from window to TD. , M/U and run 4,788' of 3-1/2" solid L80 ST-L liner to hang off depth in 7" tubing of +8,200'. Cement liner in place with inner string cementing assembly, and set liner hanger/packer. Circulate out excess cement, and displace well to clean seawater. POOH. RIH with DPC CBL log and make logging pass over the liner to determine condition of cement job. POOH. 7. RIH with DPC perforating guns and perforate 50' of liner. 8. RIH with DP and circulate freeze protection to _+2,200'MD. 9. Set and test TWCV, ND BOP, NU tree. Pull TWCV and set/test BPV. RDMO. TREE: McEVOY 6'-5m i~.omnlefion KE /= 54.05 WELLHEAD: McEVOYR-~, Ii Proposed-- r"' '' BF .... V :21.40 ACTUATOR OTIS '--. j ~ L sssv LANDING I ~----- NIPPLE I 2020 ( OTIS )( 5.962" ID) 13-3/8', 72 #/ff ..... I ,i ~ ~ 5-1/2' X 3'1/2' Hner hanger/packer I I j ~ 7'x5 1/2' , , I~ ~ SLIDING SLEEVE . . !~ ~! .... o~,s x~, ~' I~ ~ 9-5/8'x 5-1/2' TIW , , 5-1/2",17~/~L~80,~~ ~ -- P,~ P;cker (4.75' ID, ~ 5-1/2 X' NIPPLE 35 8,96~ (~ck off at 8,970') ~ ~~~.,. at 12,988' Cement plug top ~ 9,013' Squeezed ~ ~ MarkorUoint . po~orations 8,072-~,0~' I 9,1~-9,124' I ~ -- (OTIS)(4.~ ID) 9,126-9,132' I ~ ~1/~ ~N NIPPLE I 0174' -- (OTIS) (3.725" I D) ~", ~ ~/., L-~O, I o~s DATE nEV. BY COMME~S 12-04-89 H. Farrell RWO PRUDHOE BAY UNIT 12-15-89 Jack Ha~ Revised / Corrections 5/1/90 M. Marlin Add-Peals WELL: R-05ai 7/~94 HUGHES Add XN ELMD & Revise ~-24-a7 O. Brown ~ Sidetrack BP/ARCO PBU DRILLING I : ... , : : .. ~t:. :- ..... -'..'?ii' K' --.V = 54.05 TREE: McEVOY 6'-5mRio' WELL,~O:McEVOY .05ai Pre-__.., Status B;.~.._.~v=21.4o ~I ~ J~ iSSSV LANDING NIPPLE I I 2020 Freeze I ' '.~.;~ ~ ~ ~ ( OTIS )( 5.962 "ID) I , protection l2200 I [] 13-3/8', 72 #/ft, I 2585 I L-80, BTRS II ii~ii~, ._ i~.~.. KOP @ 2851' Max Angle @16° 7', 26~, L-80, IJ4S 'l'bg ~.~-.~.' ~.. ~ ~.~! J~ 7'x5 1/2' I T~NG ~D: ~.27~' ~,~~ _______CROSSOVER ~ 8259,I CAPACITY: 0.O383 BBUFT ................ ~ ~ OTiS XA 5 1/2' 8272 ( 4.562 ' MIN. ID) I I 5-1/2", 17 #/ft, L-80, i i ~ ~ 9-5/8"x 5-1/2" TIW ~.~.. 03 ~ ~.' ~ 5-112" "X" NIPPLE ~ ii! ~il ~ ----(OT~S)(~.982" ID) ~ ~i~ = 5-1/2" 'XN"NIPPLE O Ii!~l'O ~(4.5",D-millodout)I I TopofBakor i~.~-~."~11~.~ ~7"SealAssombly I~0°~ I 7" Liner Hanger Whipstock top set at ~ ~ Milled window kicked 8,967" (kick off at 8,970')I off at 8,970' Cement plug top 9,013' Marker JointI9080I Squeezed podorations 8,972-9,034' WD PACKER I9167 I 9,i04-9,i 12' (OTIS )(4.00 ID) 9,i9P-9,i24' 9,126.9,132' 4'1/2" "XN NIPPLE I 9174'I 9,174-9,184' (OTIS) (3.725" I D) 9,188-9,194' 9,236-9,240' 4-1/2" WLEG I 9175' I PBTD 19509 BTRS D^TE REV. BY COMMENTS 12-04-89 ~. Farre~ RWO PFIUDHOE B~¥ UNIT 12-15-89 Jack Hartz Revised / Corrections WELL: R-05ai APl NO: 50-029-20388-01 5/1/9o M. Marlin Add-Perfs SEC 32; TN 12N; RGE 13E 7/3/94 HUGHES Add XN ELMD & Revise 11-24-97 C.Brown 'l-rRD Sidetrack BP/ARCO PBU DRILLING -. R 05i -nt Status TREE: McEVOY 6"-5m ~,,. BF. ELEV = 21.40 WELLHEAD: McEVOY ACTUATOR OTIS · .. 13-3/8', 72 #/ft, j · L-80, BTRS [] ~ 9 5/8" DV PACKER 2585 12585 J {~ · SSSV LANDING NIPPLE 12020 ( OTIS )( 5.962" ID) lMKOP:2851 AX ANGLE:lB DEG .7", 26 #/ft, L-80,1J4S TUBING 7'x51/2' 18259 TUBING ID: 6.276 ' X ~/ CROSSOVER CAPACITY:BBL/FT .0382 '--''~' Ill· · SLIDING SLEEVE _ _ OTISXA51/2' 8272 ~ ( 4.562 ' MIN. ID) ~~ -- TUB,NG SEALASSY. 18397' 8307 ~ 9-5/8" PACKER :><3 ( T~w )(4.75'~D) I I NOTE: 7' SEALASSY IS ' 'I ' , I! 5 1/2' 'X" NIPPLE ABOVE LINER iI ( OTIS ) ( 4.562" ID) 8359 '""" ~' ~ 51/2 ' 'XN' NIPPLE I 8397 I 7' SEAL ASSEMBLY [' "] ( OTIS)(4.445), 8380 L-80, BTRS MARKER JOINT I9°s° PERFORATION SUMMARY REF. LOG: BHCS 9-6-79 SIZE SPF INTERVAL OI~EN/SQ~D 5' 4 8972-9034 Open 3 3/8 4 9104-9112 Open 27/84 9112-9122 Sqz ~ WD PACKER 19167 333/83/8 44 9126-91329122'9124 OpenOpen (OTIS) (4.00 JEL Set Depth 2 7/8 4 9132-9164 Sqz ID) 5 4 9174-9184 Open ! ~ 41/2 ' "XN" NIPPLE I I 33/8 4 9188-9194 Open i (OTIS) (3.725'1D) 1~74 I 2 7/8 4 9194'9208 Sqz 33/84 9218-9222 Sqz 41/2' WLEG !9176 33/8 4 9230-9234 Sqz I ( OTIS ) ( 3.958 'ID) 5 4 9236-9240 Open 41/2" XXN-Plug W/3/4" Note: No Keys Set- 6/15/90 PBTD 19509 I' 7'.29,/ft, L-80, I 9775 BTRS DATE REV. BY COMMENTS PRUDHOE BAY UNIT 34-32-12-13 12-04-89 H. Farrell RWO WELL:RSi 12-15-89 Jack Hartz Revised / Corrections APl NO: 50-029- 20388 5/1/90 M. Marlin Add-Perfs SEC 32; TN 12N; RGB 13E 7/3/94 HUGHES Add XN ELMD & Revise BP = p~uruu~x-'-"-'"ont/~ ~a)'~'as"-' Shared Services Drilling Prudhoe Bay Unit Sperry-Sun Drilling Services Proposal Report for R-OSAi . R-OSAt Wp2 Measured Sub-Sea Vertical Local C~r~inates Global Coordinates Dogleg Vertical Depth Ind, Azim. Del~h ~ Northlngs Eastings Northings Eastlngs Rste Section Comment {fi) (,) (n) (fi) (ft) fit) 8~70.00 11.915 128.561 8731.64 8777.64 9<x~.o<) 14,589 134,52:4 8760.64 8806.24 9~10,0~ 15,506 13S. 05'/ 8770.49 8~16,89 9100,00 37.,q90 138,145 ~)0.36 8895.75 9200.00 62.9S5 13&836 8913.47 8958.87 ~.00 87..9.81 139.262 ~.q38.34 8983.74 IT'J07.91 89,659 ';36'.~ 8.q3&48 8983.68 9311.21 ~.959 139.293 ' 8,938.4.0 8983.69 9400.00 89.6~ 161,491 8.938.60 456.49 S 1453.52 E 5976751.76 N 636404,4~ E -1503,78 480~07S 145~63E 597874727N 636409.66E 10.060 -1510.41 461.91 S 1460,46E 5976745,46N 636411,54E 10,060 -1512E7 49159 S 1437.54E 5976716,27 N 636439.25 E 25,000 -1550.45 648.9~ S 1638~£ 597~59,82 N 636400.93E 26,000 ,16,?,1.42 699.19 S 1630.24 E 5976311.30 N 6,.t65~.16 E 26.000 -1860.25 970.56 $ 156133 E 5976238.70 N 636621.55 E 25.000 -1830.53 g~00.00 89 .,~W3 261.462 8939,77 8985;17 1006,135 1468.72 E 5976201.47 N 636429,~E 25.000 -17,63..59 10(]00.00 91.078 306.986 ~:~39.83 8985.23 10,t~9.00 96.417 306.919 ~;~34.02 8979.42 10100.00 96.4.17 306,919 8:932,79 8978.1g 10200,00 96.417 306.919 i~21.61 6967.01 10300.00 96,417 306.919 8910,43 9955.63 I0400.00 96.417 306.919 6,~9.25 6944.65 I0500,00 0~.417 ,.'X)6.919 8888.06 8933.48 10600,~ 96.417 306.919 86r76.00 6922.30 10'/00.00 96.417 306.019 6865.72 6611.12 10~00,~ 99.417 306,919 6654.55 6899.65 10876.60 66.417 306.919 8645.98 6891,~ 10900.00 95.014 . 306.920 8943.65 6889.05 109~.,~ ~0.000 306,924 6840,00 8385.40 11000,00 89.014 306.886 8840.14 8885.54 11091.00 83.558 306,676 8846.03 8891.43 99923 S 1369.75E 5976206,60 N 636330.52E 26.000 -f671.96 962.505 1296.88 E 5676242.00 N 636257.00 E 25.000 ,1590.36 TsuT~ R. OSN T1, Geok)gk:al 951.69 $ 128253 E 5976262.66 N 636242.48 E 6.0(X) -1572.72 896,32 S 121159 E ~3 N 636170,56 E 6,000 -14~5.40 691,76 S t202J15 E 5676311,04 N 638t61.71 E 0.000 -1474.64 832.07 S 1123,40 E 5971~3~.29 N 636081.20 E 0.{XX) -1376.89 772,37 S 1043,~ E 5976427,55 N 638000.69 E 0,1X]O -1279.14 ~12,6~ $ 964~1 E 5976486.~ N 63~18 E 0.000 -1181.36 652.69 S 685.06 E 5976644.05 N 635839.67 E 0,000 -I083.63 693.3OS 606.61 E 59766~30N 635759.16 E 0.000 -gSS.8a 53,.I.61 8 726.16 E 6676660,65 N 635678.65 E 0.000 .868,12 473.91 8 646.72 E ,5976718.61 N 635598.1,4. E O.000 -790.37 426.19 S 685.86 E 5976763.43 N 63.5.536.47 E 0.000 -715.46 41426 S 567.24 E 5976777.08 N 635517.61 E 6.000 ..692.59 364.075 500.~E 5976826.00N 635450.00E 6.000 -610.49 TargetR-05NT2, Geo~ 354.20 $ 487.38 E 5976835.63N ~5436.68 E 6.000 -694,32 299.65 S 414,68 E 5676888.67 N 635363.01 E 6.000 -504,9~ Alaska State Plane Zone 4 PBU_WOA R Pad t20ecerm~r, 19~7. ~:59 ' !- ~ Sperry-Sun Drilling Services Proposal Report for R-O5Ai . R-OSAi Wp2 Shared Services Drilling Prudhoe Bay Unit Measured Sub. Sea Vertical Local Coordinates GIobaICoordirmtes Dogleg Vertical Deplh Incl. Azlm. Depth Depth Northtngs Eastings Nodhlngs Eastlngs Rate Section Comment (ft) (fi) {fl) (fi) (fl) (fl) (ft) ~'/~efl) Ct) Il00.00 83.558 308.876 8847.04 8892.44 f200,00 83.558 306.678 8115&26 8903,66 1:3(X),00 83.558 306.676 8880.48 8914,88 14~.00 83,558 306.676 8880,70 8926A0 1500.00 83.558 306,676 8891.92 8937.32 11600.00 83.,~58 306.676 8903.14 8946,54 11700,(X} 83,558 306.676 8914,36 8959.76 118l;X).0~ 83.558 306.676; 8<32538 8970.98 11874.82 83.558 306,676 8933.97 8679,37 11900.00 86.069 306,679 8936.47 8981.87 11982.18 90,000 306,890 8940.00 8985.40 12000,00 91,06~ 308.887 8939.83 89852'3 12100,00 97.0~7 306.5,38 89~2.74 8~'/8.14 1217~,30 101,764 306,436 891i).94 8965.34 12200,00 f01.7~ 306.436 89t6,51 6960.91 123(X),00 101264 306,4,36 8~95.12 694052 12400,0~ I01,764 30&436 8874.74 8920.14 12500,~ t012~ 3(6.436 1~54~ 88,~.7S 12{~0,0~ 101284 306.436 ~,3.96 8879.~ 12700.0~ 101264 306.436 881357 8&58.~ 12600.00 101.764 306.436 8793.19 8838,58 12900.00 101.764 306.436 8772:76 8818.19 1298726 101.764 3~.438 875~.~ 8800.40 294.51 S 235.158 175~S 116.45 S 5'/.10 S 40751 E 5976893.88 N 635355.74 E 0.000 -496.16 327.81 E 5976951,79 N ~4.99 E 0.000 -396,36 248,11 E 59'77006.66 N 63,5194.24 E 168,42 E 5977067.60 N 636113,49 E 0,0~ -202.71 88,72 E 5977125,51 N 63,60~2.~ E 0.000 -104,86 2,25 N 9,02 E 5977183A1 N 634951.98 E 0.0~) -7.06 61.60 N 70.67 W 5,977241.32 N 63487! 23 E 0.000 90.76 120.~6 N 150.37 W 5,97729923 N 834790.48 E O.{XiO 188.58 165.36 N 210,00 W 5977342.,56 N 634730.0~ E 0,000 261.78 180.33 N 238.09 W 5977"357,16 Iq 634709.70 E $,000 28~,44 229~ N 295.92 W 5977405.00 N 634643.00 E 6.000 367,26 Target: R-05N % Geologlca 240,01 N 31021 W 5977415,38 N 634626.52 E 6,000 384,78 299.46 N 390.25 W 597/~ N 634547.43 E 6.0(X} 482.96 34638 N 4,r~2.33 W 597/51&18 N ILq4484.62 E 6.000 666.03 357.99 N 46'9,42 W 5977530.48 N r~167.21 E 0,{:~ 5'71i.m 416.14N 548. tgW 5977587,2:0 N 634387.41 E 0.0~ 676.40 47428 N 826.95 W 5gT/843,92 N 834307.62 E 0.000 772.Ei 5,32.43 N 705,71 W 5977700.64 N 634227.82 E 0.1X]0 8~30 590.57 N 784.47 W :5977757.,35 N 634148.02 E 0.000 :965,75 648,72 N t~323W 5977814.07 N 634068.23 E 0.000 1062.20 706.86 N 642.00 W 5977870.79 N 633968,~E 0,000 1158,66 Alaska State Plane Zone 4 PBU_WOA R Pad '7 Shared Services Drilling Prudhoe Bay Unit Sperry-Sun Drilling Services Proposal Report for R-OSAi - R-OSAi Wp2 Alaska State Plane Zone 4 PBU_WOA R Pad All data is in feet unless othe~se stated, Directions and coordinates are relative to True North. Vertical deplhs are relative to Well. Northings and Eastings are retative to Well. The Dogleg Severity is in Degrees per l O Oft. Vertical Section is from Well and cak~lated along an Azimuth of 296,560° (True), Based upon Minimum Curczture type calculations, at a Measured Depth of 12987.26ft., The Bottom Hole Displaceme~ is 1361.040, in the Direction of 306.824" {True). Sl e -Sun iL/Q ,..,.-,.= ,~E. v,=E. Shared ~mi~ Dfilli~ Dr uest Scale: linch = 7~ -14~ -7~ Eastings ~ 7~ 14~ I I , I I P~I D.~ for R~S~ Wp2 1400 - -- 1 4~ v~ . : W~l ~ ~,~: T~ N~ V~ ~ ~: K~ TO ~ V~~: ~.49 S,l~.~ E u~ ~ ~ v~ ~ ~ v~ ~ ~ D 8970.~ 11.915 1~.~61 8~.~ 455.49 S 1453.52 E - 1~3.~ 9~.91 a9.9~ 139.~3 ~83.~ 627.~ S 1~.39 E - 1717.~ ~.~ 931l~1 89.9~ 139.~3 8983.~ 63~S ~a~O~ ~.~ ZO*.~ S*SS.~ ~ZSOS ~:~.aa E .~S~Z~ ~n.~ 700 7~ 1~9~ ~.417 ~.919 89~.42 89~32S 1211.59 E - 1415.~ 6.~ 1~76.~ 96.417 3~.919 ~91.38 4~19~ 585.~ E -71~.49 0.~ II~].~ 83.558 3~.676 8a91.43 2~.85 S 414.6a E -~.~ 6.~ ' 11874.~2 a3.558 3~.676 8979.37 165.36 N llO.~ W 261.~ O.~ i I=l?a.30 IOt.7~ 3~.4~ 8~.M ~5.38 N 452.33 W 559.~ 6.~ ~ ~ ~ ~ 8985.40 ~D o SURFACE LOCA~ON RE~RENCE PlOT DATE: ~ i Z H~on~l ~dl~s: 59~181.~ N, ~3.~ E Created By: 0 0 RKB Beva~: 2S~0E R~ (ES~ 19.~ ff Well (CB~ 45.4~ R~-AMSL Checked By: Coo~lnate Syetem: N~7 Na~ S~ ~, Z~ 4, US ~ PRELIMINARY . oo i 9~2 50 S 1~6 88 E I I I I 82ffi.~ -1400 -700 0 700 1400 Scale: linch = 700ff Eastings Reference is True No~h ---~o ~Summa~~ ~250 - ~ posal Tar 85~. f Target Name: TVDss: TVD~b: Wel~ead OffseB: Glob~ Coordinates: / R-05~ TI 8940.~ 8985.~ 962.50 S, 1296.88 E 5976242.~ N, 636257.~ E ~ ~ R-05Ai T2 8840.~ 8885.~ 364.07 S, 5~.53 E 5976826.~ N, 635450.~ E ~~ [ R-05~ T3 8940.~ 8985.~ 229.36 N, 295.92 W 5977405.~ N, 634643.~ E ~ 88~.~ R-05AI T4 8775.~ 88~.~ 815.75 N, 1089.49 W 5977977.~ N, 633839.~ E / o 8750 - ~ ~ ~oo 2 7/8" Liner 12987.26 MD, 8800.40 TVD ~ 91 10500 00 - ,0800 ....... 00 , ...... 11400 00 ....... ~ ~15.75'05AI 1~1 11100 00 / r ~o.~ ~n ,~ow.w - ~ ..... ~ '~-~-- 11700 O0 ~ ~ ~ ~ ~00.40~ N, 1089.49 W O II c 9250 ~ I I I I I I I I Scale: I inch = 500E -1500 -1000 -500 0 500 1000 1500 2000 Ve~ical ,Section Section Azimuth: 296.560° (lrue No~h) H ~306~8 ~/r~o:,~71 oo~o6~s VENDOR ALASF, AST 14 O0 DATE INVOICE / CREDIT MEMO ) DESCRIPTION GROSS DISCOUNT NET 1i1897 C½11i897K ' 100. O0 100. O0 PYMT ;OMMENTS: accompany permit to d~ill app 1 ication HANDLINQ INST: s/h te~ie hubble, x46~8 .,1. HE A'ri'ACHED CHECK IS IH PAYMENT FOR ITEMS DESCRIBED ABOVE. · WELL PERMIT CHECKLIST COMPANY FIELD & POOL (~ ~0_/)~ C) INIT CLASS GEOL AREA PROGRAM: exp [] der [] redrll~ serv~wellbore seg [' ann. disposal para req I'i UNIT# //~'~¢2 ON/OFF SHORE ADMINISTRATION 1 1 APPR DATE 1 ,, -7' 1. Permit fee attached ...................... Y N ~ 2. Lease number appropriate ................... Y (~,) 3. Unique well name and number .................. Y 4. Well located in a defined pool ................. Y N 5. Well located proper distance from drilling unit boundary .... Y N 6. Well located proper distance from other wells .......... Y N 7. Sufficient acreage available in drilling unit ............ Y N,~ 8. If deviated, is wellbore plat included ............. Y 9. Operator only affected party ................. Y 0. Operator has appropriate bond in force ............ Y N 1. Permit can be issued without conservation order ........ Y N 2. Permit can be issued without administrative approval ...... Y N 3. Can permit be approved before 15-day wait ........... Y N ENGINEERING APPR D_AT/E ,,.? 14. Conductor string provided ................... Y 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 tie-in long string to surf csg ........ /Y_.., N 18. CMT will cover all known productive horizons .......... ~,,._, N 19. Casing designs adequate for C, T, B & permafrost ...... 20. Adequate tankage or reserve pit ................. ~"NN 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... Y N 24. Drilling fluid program schematic & equip list adequate ..... (~) N 25. BOPEs, do they meet regulation ............ (~ N 26. BOPE press rating appropriate; test to ,~"-'~ ' 'ps:~gl~ N 27. Choke manifold complies w/APl RP-53 (May ~-4) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... ,, , 32. Seismic analysis of shallow gas zones ............. N 33. Seabed condition survey (if off-shore) ........... .~.~ Y N A~PR DATE 34. Contact name/phone for we,ekly,progress repods . . . ~,¢'... Y N ~,', /,"-~,,,~,~.:,..,./..;.:~. lexp,oratory only] ,,¢ ,, ~.,,, - . ... / GEOLOGY: ENGINEERING: COMMISSION' BEW4¢~,~. ¢¢I"Z¢', DWJ'~e--~_ ]DH ~ RNC~ % CO Comments/Instructions: HOW/lit · A \FC)RMS ~ ~ ,.I-h,I r~,v I,.'~ 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... . ............................ . COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : R-OSA FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUNiBER : 500292038001 REFERENCE NO : 98119 LIS Tape 9~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/03/12 ORIGIN : FLIC REEL NAME : 98119 CONTINUATION # : PREVIOUS REEL : COI~4ENT · B.P. EXPLORATION, R-O5A, PRUDHOE BAY, API #50-029-20380-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/03/12 ORIGIN · FLIC TAPE NAME : 98119 CONTINUATION # : 1 PREVIOUS TAPE : CO~k4ENT · B.P. EXPLORATION, R-OSA, PRUDHOE BAY, API #50-029-20380-01 TAPE HEADER PRUDHOE BAY 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: RUN 1 98119 KIRKBY M. JACKSON TOWNSHIP: RANGE: FNL : FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1 ST STRING 2ND STRING R-OSA 500292038001 BP EXPLORATION ~ALASKA) SCHLUBIBERGER WELL SERVICES 12-MAR-98 RUN 2 RUN 3 .......... 32 12N 13E 1293 707 45.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.500 5.500 8980.0 LIS Tape~erification Listing Schlumberger Alaska Computing Center 12 -MAR-19 9 8"~: 5 3 3RD STRING PRODUCTION STRING REMARKS: This file contains the LDWG edit for BP Exploration well R-OSA. The well was logged with the SLim Access Platform Express/AIT/BHC. There was a main up pass and a repeat down pass. Logging problems resulted in a gap in the main pass between 12618 - 12544 ft. Depthshifting waived as per Steve Jones. The AIT/GR is the primary depth control for the well. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE PEX AIT BHC $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8980.0 12867.0 9000.0 12916.0 8980.0 12896.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE PEX PEX $ REMARKS: .......... EQUIVALENT UNSHIFTEDDEPTH .......... PEX AIT BHC RUN NO. PASS NO. MERGE TOP MERGE BASE 1 1 12618.0 12867.0 1 2 8980.0 12544.0 This file contains the clipped data for the Slim Access Array Induction Tool (AIT), Platform Express Litho Dentity (SDN), Compensated Neutron (CNT), and Borehole LIS Tape V~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~53 PAGE: TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 0.5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 THIS FILE CONTAINS THE RAW DATA FROM LOWER SECTION OF MAIN PASS. DATA ACQUIRED AT .5' SAMPLE RATES $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 3 1 1 4 68 0000000000 SP AIT MV 1209217 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape 9~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~{53 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) GR AIT GAPI 1209217 O0 000 O0 0 3 1 1 4 68 DTRP BHC US/F 1209217 O0 000 O0 0 3 1 1 4 68 DTCO BHC US/F 1209217 O0 000 O0 0 3 1 1 4 68 DT BHC US/F 1209217 O0 000 O0 0 3 1 1 4 68 DRHO LDT G/C3 1209217 O0 000 O0 0 3 1 1 4 68 PEF LDT 1209217 O0 000 O0 0 3 1 1 4 68 RHOB LDT G/C3 1209217 O0 000 O0 0 3 1 1 4 68 DPHI LDT PU 1209217 O0 000 O0 0 3 1 1 4 68 CALI LDT IN 1209217 O0 000 O0 0 3 1 1 4 68 RTNR CNT 1209217 O0 000 O0 0 3 1 1 4 68 RCNT CNT CPS 1209217 O0 000 O0 0 3 1 1 4 68 RCFT CNT CPS 1209217 O0 000 O0 0 3 1 1 4 68 CNTC CNT CPS 1209217 O0 000 O0 0 3 1 1 4 68 CFTC CNT CPS 1209217 O0 000 O0 0 3 1 1 4 68 TNRA CNT 1209217 O0 000 O0 0 3 1 1 4 68 NPHI CNT PU-S 1209217 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12936.000 SP.AIT -85.875 GR.AIT 17.318 DTRP.BHC DTCO.BHC 73.917 DT. BHC 72.891 DRHO.LDT 0.170 PEF. LDT RHOB.LDT 2.935 DPHI.LDT -17.294 CALI.LDT 4.503 RTArR.CNT RCNT. CNT 8500.000 RCFT. CNT 3000.000 CNTC. CNT 9694.631 CFTC. CNT TNRA.CNT 2.896 NPHI. CNT 15.773 DEPT. 12617.500 SP.AIT -51.313 GR.AIT 32.270 DTRP.BHC DTCO.BHC 99.251 DT. BHC 112.480 DRHO.LDT 0.090 PEF.LDT RHOB.LDT 2.267 DPHI.LDT 23.188 CALI.LDT 4.674 RTArR.CNT RCNT. CNT 5500.000 RCFT. CNT 1473.684 CNTC. CNT 6486.485 CFTC. CNT TNRA.CNT 3.906 NPHI.CNT 23.091 73.917 11.582 2.833 3098.773 99.251 2.804 3.732 1522.204 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SOW2VARY VENDOR TOOL CODE FILE HEADER FILE NUMBER 4 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 2 0.5000 START DEPTH PEX BHC $ LOG HEADER DATA DATE LOGGED: STOP DEPTH .......... 12594.0 8980.0 12594.0 8980.0 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (F~: TDLOGGER(FT): TOP 'LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNT SLIM ACCESS CNT LDT SLIM ACCESS LDT BHC SLIM ACCESS BHC AIT SLIM ACCESS AIT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 1-FEB-98 8C0-609 500 31-JAN-98 600 1-FEB-98 12950.0 12940.0 8900.0 12940.0 1800.O TOOL NUMBER ........... CNT-S SLDT-A SSLT-AA SAIT-A 4.500 8980.0 8980.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998 PAGE: 11 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 206.0 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 200 MUD CAKE AT (BHT): 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 THIS FILE CONTAINS THE RAW DATA FROM UPPER SECTION OF MAIN PASS. DATA ACQUIRED AT .5' SAMPLE RATES $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape verification Listing Schlumberger Alaska Computing Center 12 -MAR- 1998 i~i<~ 53 PAGE: 12 TYPE REPR CODE VALUE 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 4 1 i 4 68 0000000000 SP AIT MV 1209217 O0 000 O0 0 4 1 i 4 68 0000000000 GR AIT GAPI 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 DTRP BHC US/F 1209217 O0 000 O0 0 4 1 i 4 68 0000000000 DTCO BHC US/F 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 DT BHC US/F 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LDT G/C3 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDT 1209217 O0 000 O0 0 4 1 i 4 68 0000000000 RHOB LDT G/C3 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 CALI LDT IN 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNT CPS 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNT CPS 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNT CPS 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNT CPS 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNT 1209217 O0 000 O0 0 4 1 i 4 68 0000000000 NPHI CNT PU-S 1209217 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12594.000 SP.AIT -51.375 GR.AIT 17.043 DTRP.BHC DTCO.BHC 96.205 DT. BHC 94.082 DRHO.LDT 0.217 PEF.LDT RHOB.LDT 2.502 CALI.LDT 5.720 RCNT. CNT 6500.000 RCFT. CNT CNTC. CNT 7413.541 CFTC. CNT 1807.618 TNRA. CNT 3.797 NPHI.CNT DEPT. 8980.000 SP.AIT -42.438 GR.AIT 184.506 DTRP.BHC DTCO.BHC 59.641 DT. BHC 53.770 DRHO.LDT 0.454 PEF. LDT RHOB.LDT 2.281 CALI.LDT 4.446 RCNT. CNT 3966.667 RCFT. CNT CNTC. CNT 4423.877 CFTC. C iTT 887.669 TNRA. CNT 4.655 NPHI. CNT 96.205 2.836 1750.000 21.218 59.641 3.679 859.375 29.227 ** END OF DATA ** LIS Tape '~e~ification Listing Schlumberger Alaska Computing Center 12 -MAR-1998 ~'~-~? 53 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUFff~a~gY FILE HEADER FILE NUM~ER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... PEX 12936.0 12618.0 BHC 12936.0 12618.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERV$~L (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNT SLIM ACCESS CNT 1-FEB-98 8C0-609 500 31-JAN-98 600 1-FEB-98 12950.0 12940.0 8900.0 12940.0 1800.O TOOL NUFiBER ........... CNT-S LIS Tape V~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998"~-:53 PAGE: 14 LDT SLIM ACCESS LDT BHC SLIM ACCESS BHC AIT SLIM ACCESS AIT $ SLDT-A SSLT-AA SAIT-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.500 8980.0 8980.0 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 206.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 200 MUD CAKE AT (BHT) : 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTOArE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG '. DOYON 16 THIS FILE CONTAINS THE RAW DATA FROM LOWER SECTION OF MAIN PASS. DATA ACQUIRED AT .25' SAMPLE RATES $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998~.53 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 5 1 1 4 68 0000000000 AFiO AIT 0H~4~1209217 O0 000 O0 0 5 1 1 4 68 0000000000 AF20 AIT OHF~q1209217 O0 000 O0 0 5 1 1 4 68 0000000000 AF30 AIT OH~k41209217 O0 000 O0 0 5 1 1 4 68 0000000000 AF60 AIT OHFK41209217 O0 000 O0 0 5 1 1 4 68 0000000000 AF90 AIT 0H~41209217 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12936.000 AFiO.AIT 243.966 AF60.AIT 338.538 AF90.AIT 87.745 DEPT. 12617.250 AFiO.AIT 3.938 AF60.AIT 8.181 AFgO.AIT 8.431 AF20.AIT 243.297 AF30.AIT AF20.AIT 8.515 AF30.AIT 271. 231 8. 442 ** END OF DATA ** LIS Tape V~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998'~-~:53 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUFmL~Y VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 12594.0 8980.0 BHC 12594.0 8980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNT SLIM ACCESS CNT 1-FEB-98 8C0-609 500 31-JAN-98 600 1-FEB-98 12950.0 12940.0 8900.0 12940.0 1800.0 TOOL ~]MBER ........... LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 17 LDT SLIM ACCESS LDT BHC SLIM ACCESS BHC AIT SLIM ACCESS AIT $ SLDT-A SSLT-AA SAIT-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (?T) : LOGGERS CASING DEPTH (FT): 4.500 8980.0 8980.0 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TE~IPERATURE (DEGF) : 206.0 RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.200 MUD CAKE AT (BHT): 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 THIS FILE CONTAINS THE RAW DATA FROM UPPER SECTION OF MAIN PASS. DATA ACQUIRED AT .25' SAMPLE RATES $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998 11:53 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUI4~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUA~ SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 6 1 1 4 68 0000000000 AFiO AIT 0HI~41209217 O0 000 O0 0 6 1 1 4 68 0000000000 AF20 AIT OH~M 1209217 O0 000 O0 0 6 1 1 4 68 0000000000 AF30 AIT O HF~q1209217 O0 000 O0 0 6 1 1 4 68 0000000000 AF60 AIT OH~M1209217 O0 000 O0 0 6 1 1 4 68 0000000000 AF90 AIT oIq~4M1209217 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12594.000 AFiO.AIT 2.480 AF20.AIT AF60.AIT 7.561 AF90.AIT 7.789 DEPT. 8980.000 AFIO.AIT 12.675 AF20.AIT AF60.AIT 1.083 AF90.AIT 9.599 9. 604 AF30.AIT 0.193 AF30.AIT 8. 505 0.196 ** END OF DATA ** LIS Tape ~e~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~:53 PAGE: 19 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~4~L~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12850.0 9438.0 PEX LOG HEADER DATA DATE LOGGED: 1-FEB-98 SOFTWARE VERSION: 8C0- 609 TIME CIRCULATION ENDED: 500 31-JAN-98 TIME LOGGER ON BOTTOM: 600 1-FEB-98 TD DRILLER (FT) : 12950.0 TD LOGGER (FT) : 12940.0 TOP LOG INTERVAL (FT) : 8900.0 BOTTOM LOG INTERVAL (FT) : 12940.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNT SLIM ACCESS CNT LDT SLIM ACCESS LDT BHC SLIM ACCESS BHC AIT SLIM ACCESS AIT TOOL NUMBER ........... SLDT-A SSLT-AA SAIT-A LIS Tape ~'erification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~'..53 PAGE: 20 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. LOGGERS CASING DEPTH (FT): 4.500 8980.0 8980.0 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 206.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.200 MUD CAKE AT (BHT) : 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. $ REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 THIS FILE CONTAINS THE RAW DATA FOR THE REPEAT (DOWN) PASS ACQUIRED AT 0.5' SAMPLE RATES. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape ~e~rification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~1~:'53 PAGE 21 TYPE REPR CODE VALUE 3 73 60 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 7 1 i 4 68 0000000000 SP AIT MV 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 GR AIT GAPI 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 DT BHC US~F1209217 O0 000 O0 0 7 1 1 4 68 0000000000 DTCO BHC US/F 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 DRHO LDT G/C3 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 PEF LDT 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 RHOB LDT G/C3 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 CALI LDT IN 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT CNT CPS 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT CNT CPS 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC CNT CPS 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC CNT CPS 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA CNT 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI CNT PU-S 1209217 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12936.000 SP.AIT -999.250 GR.AIT -999.250 DT. BHC DTCO.BHC 73.917 DRHO.LDT -999.250 PEF. LDT -999.250 RHOB.LDT CALI.LDT -999.250 RCNT. CNT -999.250 RCFT. CNT -999.250 CNTC. CNT CFTC. CNT -999.250 TNRA.CNT -999.250 NPHI.CNT -999.250 DEPT. 9438.000 SP.AIT 56.750 GR.AIT 15.747 DT. BHC DTCO.BHC -999.250 DRHO.LDT 0.057 PEF. LDT 2.131 RHOB.LDT CALI.LDT 2.837 RCNT. CNT 7000.000 RCFT. CNT 2250.000 CNTC. CNT CFTC. CNT 2324.080 TNRA.CNT 3.180 NPHI. CNT 20.437 -999.250 -999.250 -999.250 77. 815 2. 367 7983. 813 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE 22 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: O. 2500 FILE SO?~fARY VENDOR TOOL CODE START DEPTH AIT 12850.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) '. TOOL STRING (TOP TO BOTTOM) STOP DEPTH .......... 9438.0 1-FEB-98 8C0-609 500 31-JAN-98 600 1-FEB-98 12950.0 12940.0 8900.0 12940.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 23 VENDOR TOOL CODE TOOL TYPE CNT SLIM ACCESS CNT LDT SLIM ACCESS LDT BHC SLIM ACCESS BHC AIT SLIM ACCESS AIT $ TOOL NUMBER CNT-S SLDT-A SSLT-AA SAIT-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.500 8980.0 8980.0 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 206.0 RESISTIVITY (OPHir) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.200 MUD CAKE AT (BHT) : 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL TURNER ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 THIS FILE CONTAINS THE RAW DATA FOR THE REPEAT (DOWN) PASS ACQUIRED AT 0.25' SAMPLE RATES. $ LIS FORMAT DATA LIS Tape V~ification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~ 53 PAGE: 24 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API A_PI API FILE NUM~ NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 8 1 1 4 68 0000000000 AFIO AIT OP24Pl1209217 O0 000 O0 0 8 1 1 4 68 0000000000 AF20 AIT OH~k41209217 O0 000 O0 0 8 1 1 4 68 0000000000 AF30 AIT 0H~941209217 O0 000 O0 0 8 1 1 4 68 0000000000 AF60 AIT 0H~1209217 O0 000 O0 0 8 1 1 4 68 0000000000 AFgO AIT 0HF241209217 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 12850.500 AFiO.AIT 4.207 AF20.AIT AF60.AIT 11.259 AF90.AIT 9.818 DEPT. 9438.250 AFiO.AIT 5.662 AF20.AIT AF60.AIT 13.117 AF90.AIT 13.700 6.865 AF30.AIT 7.442 AF30.AIT 9.989 12.407 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~gfzARY VENDOR TOOL CODE START DEPTH PEX 8980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNT LDT BHC AIT $ STOP DEPTH 8900.0 1-FEB-98 8C0-609 500 31-JAN-98 600 1-FEB-98 12950.0 12940.0 8900.0 12940.0 1800.0 TOOL NUM~ER ........... SLIM ACCESS CNT CNT-S SLIM ACCESS LDT SLDT-A SLIM ACCESS BHC SSLT-AA SLIM ACCESS AIT SAIT-A LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998 ~= {53 PAGE: 26 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 4.500 8980.0 8980.0 BOREHOLE CONDITIONS MUD TYPE: BARADRILN MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.9 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 206.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 141 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 180 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 0.200 MUD CAKE AT (BHT) : 66.0 70.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: *** RUN NUMBER 1 *** THIS LOG WAS RUN DRILL PIPE CONVEYED THREE STANDOFFS ON THE SAIT, THREE STANDOFFS ON SONIC ONE TOOL ~R ON DENSITY, BOWSRPING USED FOR ECCENTRAL. PASSES PRESENTED: DOWN LOG TO FROM 9438 TO TD MAIN PASS UP FIRST ATTEMPT TO 12,617 FT. MAIN PASS (AFTER COMPRESSION, COULDN'T GET DOWN) FROM 12,5 RIG: DOYON 16 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998 11:53 PAGE: 27 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NOW~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 GR AIT GAPI 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 RCNTCNT CPS 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT CNT CPS 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC CNT CPS 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC CNT CPS 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA CNT 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI CNT PU-S 1209217 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 8980.000 GR.AIT CNTC. CNT 4423.877 CFTC. CNT DEPT. 8900.000 GR.AIT CNTC. CNT 1688.470 CFTC.CNT 184.506 RCNT. CNT 3966.667 RCFT. CNT 887.669 TNRA. CNT 4.655 NPHI.CNT 60.306 RCNT. CNT 1531.250 RCFT. CNT 206.585 TNRA. CNT 7.585 NPHI.CNT 859.375 29.227 200.000 53.078 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/03/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-MAR-1998"~.-53 PAGE: 28 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/03/12 ORIGIN : FLIC TAPE NAME : 98119 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : B.P. EXPLORATION, R-O5A, PRUDHOE BAY, API #50-029-20380-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/03/12 ORIGIN : FLIC REEL NAM~ : 98119 CONTINUATION # : PREVIOUS REEL : COPffqENT · B.P. EXPLORATION, R-OSA, PRUDHOE BAY, API #50-029-20380-01 Sperry-Sun Drilling Services LIS Scan Utility Thu Mar 19 12:28:42 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-80085 E. CRIBBS M. JOHNSON R-05A 500292038801 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 19-MAR-98 MWD RUN 3 AK-MW-80085 E. CRIBBS M. JOHNSON MWD RUN 4 AK-MW-80085 E. CRIBBS M. JOHNSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-80085 E. CRIBBS M. JACKSON MWD RUN 6 AK-MW-80085 E. CRIBBS M. JACKSON MWD RUN 7 AK-MW- 80085 E. CRIBBS M. JACKSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK-MW- 80085 E. CRIBBS M. JACKSON MWD RUN 11 AK-MW-80085 E. CRIBBS M. JACKSON MWD RUN 12 AK-MW-80085 E. CRIBBS M. JACKSON MWD RUN 13 MWD RUN 14 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 AK-MW-80085 T. FLYNN M. JACKSON AK-MW-80085 T. FLYNN M. JACKSON 32 12N 13E 707 1293 45.40 44.20 19.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 7.000 8964.0 PRODUCTION STRING 4.750 12950.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRC) IS DOWNHOLE RECORDED. 3. MWD RUNS 1,3,4,5,6,7,8,11,12,13, AND 14 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR). 4. MWD RUNS 2,9, AND 10 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12950'MD, 8799'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service narae ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record 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 START DEPTH STOP DEPTH GR 8938.0 12908.0 ROP 8957.5 12961.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 8938.0 8981 8987 8998 9006 9013 9018 9020 9022 9025 9030 9034 9036 9039 9041 9043 9045 9049 9052 9056 9058 9060 9064 9068 9071 9077 9084 9087 9090 9092 9093 9096 9098 9105 9113 9115 9116 9119 9123 9127 9130 9132 9151 9153 9156 9159 9162 9178 9180 9182 9185 9186 9264 9267 9273 9283 9289 .5 .5 .5 .0 .0 .5 .5 .0 .5 .0 .0 .0 .5 .5 0 0 0 5 5 0 .0 .0 .0 .0 .5 .5 .5 .5 .0 .5 .5 .5 .0 .0 .0 5 0 0 5 0 0 5 0 5 0 5 0 0 0 0 5 5 5 0 0 0 GR 8932.0 8975.5 8983.5 8991.0 9001.5 9008.0 9012.5 9014.5 9016.5 9021.5 9025.0 9029.0 9031.0 9033.0 9035.5 9039.0 9040.5 9043.5 9047.0 9049.5 9052 0 9055 0 9057 5 9063 0 9066 0 9076 0 9078 5 9081.0 9087.5 9090.5 9092.5 9095.5 9099.0 9102.5 9106.5 9109.0 9110.5 9112.0 9114.5 9121 5 9125 0 9126 5 9144 0 9146 0 9147 0 9154 0 9156 0 9170 5 9173 5 9175 5 9177 5 9179 0 9257 0 9260 5 9264 5 9275 5 9281 5 9292 9294 9296 9298 9303 9308 5 9314 0 9316 5 9325 0 9330 0 9333 0 9337 5 9375 0 9377.5 9385.5 9392.5 9398.0 9444.0 9447.5 9451.0 9455.0 9460.5 9503.0 9506.5 9510.0 9625.5 9630 0 9632 5 9636 5 9768 0 9772 0 9776 0 9780 5 9791 0 9846.0 9848.0 9851.5 10051.5 10054.5 10063.0 10071.5 10081.5 10086.5 10091.5 10094.5 10100 0 10138 0 10142 0 10152 0 10167 0 10169 5 10173 0 10187 0 10192 0 10194 5 10200 0 10204 5 10208 0 10214 5 10234 0 10251 0 9285.5 9292.5 9293.0 9295.5 9299.0 9303.0 9306.0 9309.5 9315.0 9320.5 9324.0 9328.0 9369.5 9371.5 9381.0 9386.5 9391.0 9434.5 9440.0 9444.5 9448.0 9454.5 9497.0 9500.0 9503.5 9619.0 9621.5 9626 5 9631 0 9761 5 9765 5 9768 0 9775 0 9785.0 9839.0 9841.5 9844.0 10045.0 10048.0 10055.5 10063.0 10073.5 10079.5 10084 0 10087 0 10093 5 10130 0 10133 5 10143 0 10158 5 10161 0 10164 0 10180 0 10185 5 10187 5 10192 5 10196 0 10200 0 10208 0 10228 0 10244 0 10381 10387 10417 10429 10470 10474 10477 10482 10486 10489 10494 10499 10507 10510 10544 10550 10552 10555 10562 10689 10693 10698 10717 10725 10729 10736 10740 10744 10748 10755 10896 10900 10903 10907 10909 10913 10917 10919 10921 10924 11050 11053 11057 11164 11169 11171 11174 11180 11186 11189 11193 11196 11203 11209 11214 11249 11251 11273 11277 11280 11287 5 5 0 0 0 0 0 0 0 0 5 5 0 0 5 0 5 5 5 5 5 0 .0 .5 5 5 0 0 5 5 5 0 0 0 5 5 .0 .5 .0 .0 .5 .5 0 5 0 5 5 0 0 0 0 0 0 5 5 5 0 5 0 5 5 10374.5 10380.0 10410.0 10420.5 10464.5 10466.5 10468.5 10473.0 10477.0 10479.5 10487.0 10491.5 10497.0 10499.0 10538.5 10541.5 10543.0 10546.0 10553.0 10677.0 10682.5 10688.0 10705.0 10712.5 10717.0 10723.5 10728.5 10731.5 10735.5 10745.0 10886.0 10892.0 10895.0 10897.0 10903.0 10905.5 10909.0 10910.5 10911.5 10914.0 11041.0 11045.5 11049.5 11155.5 11159.5 11162.0 11164 5 11171 5 11175 5 11178 5 11183 0 11186 0 11195 0 11200 0 11203 5 11238 5 11241 0 11262 5 11267 0 11270 5 11278 0 11291 11296 11318 11329 11339 11343 11351 11375 11379 11386 11449 11455 11460 11572 11582 11586 11589 11592 11594 11601 11625 11659 11662 11676 11738 11741 11751 11755 11765 11780 11782 11786 11796 11798 11806 11811 11826 11830 11834 11837 11892 11900 11909 11915 11923 11938 11942 11947 11953 12044 12054 12061 12077 12078 12082 12195 12205 12211 12214 12218 12222 .0 .0 .5 .0 .0 0 5 0 0 5 0 0 5 .5 .0 .0 .5 .5 .0 .0 0 5 0 5 5 0 5 5 0 .0 .5 .0 .0 .5 .5 .5 0 5 0 5 5 5 0 0 0 5 5 .0 0 0 5 0 0 5 5 0 0 0 5 5 0 11280 11286 11307 11319 11328 11332 11340 11363 11369 11374 11440 11444 11450 11563 11571 11574 11578 11582 11584 11591 11614 11648 11650 11665 11728 11731 11739 11743 11751 11766 11771 11776 11784 11787 11796 11800 11814 11819 11822 11826 11883 11891 11900 11905 11913 11932 11936 11941 11945 12036 12043 12048 12064 12067 12070 12184 12193 12199 12203 12207 12212 .0 .0 .0 .5 .0 .0 .5 .5 .0 .5 .5 .5 .0 .0 .0 .5 .5 .0 .0 .5 .5 .0 .5 .0 .5 .5 .5 .0 .0 0 0 0 5 5 5 0 5 0 .5 .5 .0 .5 .5 .5 .0 0 0 0 5 0 5 5 5 5 5 5 5 5 0 5 5 .._., 12229 12268 12274 12280 12286 12297 12352 12367 12376 12382 12387 12393 12667 12671 12681 12740 12746 12754 12789 12791 12822 12825 12832 12834 12840 12843 12908 $ MERGED PBU MWD MWD MWD $ REMARKS: .5 .5 .0 .0 .0 .0 .5 .5 .5 0 5 5 5 5 0 0 .0 .0 .5 .5 .5 5 5 5 0 0 0 12218 12258 12262 12269 12275 12285 12345 12358 12365 12370 12377 12381 12653 12659 12667 12728 12732 12739 12774 12776 12806 12812 12817 12821 12825 12830 12895 .5 .0 .5 0 5 5 5 0 DATA SOURCE TOOL CODE 0 0 0 5 5 0 5 0 .5 .0 .5 .5 .5 .0 .5 .0 .5 .5 .5 BIT RUN NO MERGE TOP MERGE BASE 1 8990.0 9390.0 3 9390.0 9661.0 4 9661.0 9684.0 5 9684.0 9860.0 6 9860.0 9864.0 7 9864.0 9940.0 8 9940.0 10124.0 11 10124.0 10518.0 12 10518.0 11935.0 13 11935.0 12117.0 14 12117.0 12950.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 8938 12961 10949.5 8047 GR 18.8573 206.811 41.0728 7911 ROP 4.931 6018.75 102.197 8008 First Last Reading Reading 8938 12961 8938 12908 8957.5 12961 First Reading For Entire File .......... 8938 Last Reading For Entire File ........... 12961 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name..~ ........ STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8932 . 0 9336 . 0 ROP 8951 . 5 9389 . 0 $ LOG HEADER DATA DATE LOGGED: 18-JAN- 98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9390.0 8990.0 9390.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12.0 91.0 TOOL NUMBER SOLAR GM 77113 4.500 4.5 QUIKDRIL-N 8.60 42.0 7.8 31000 9.2 .000 .000 .000 .000 35.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8932 9389 9160.5 915 8932 GR 24.2305 206.811 81.8923 809 8932 Last Reading 9389 9336 ROP 15.1382 972.796 117.171 876 8951.5 9389 First Reading For Entire File .......... 8932 Last Reading For Entire File ........... 9389 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9336.0 9606.0 ROP 9391.5 9660.5 $ LOG HEADER DATA DATE LOGGED: 19-JAN-98 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: 86.7 MAXIMUM ANGLE: 90.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 77113 $ ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9661.0 9390.0 9661.0 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.500 4.5 QUIKDRIL-N 8.60 51.0 8.5 31000 6.2 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 37.5 First Name Min Max Mean Nsam Reading DEPT 9336 9660.5 9498.25 650 9336 GR 18.8573 99.681 30.2473 541 9336 ROP 5.7375 181.204 33.0188 539 9391.5 Last Reading 9660.5 9606 9660.5 First Reading For Entire File .......... 9336 Last Reading For Entire File ........... 9660.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9608.0 ROP 9662.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): STOP DEPTH 9630.0 9684.0 20-JAN-98 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9684.0 9661.0 9684.0 89.8 89.8 TOOL NUMBER SOLAR GM 77113 4.500 4.5 QUIKDRIL-N 8.60 54.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.4 29000 6.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 37.2 First Name Min Max Mean Nsam Reading DEPT 9608 9684 9646 153 9608 GR 26.3082 63.3941 37.907 45 9608 ROP 20.1104 141.686 69.5679 45 9662 Last Reading 9684 9630 9684 First Reading For Entire File .......... 9608 Last Reading For Entire File ........... 9684 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9630 . 5 9806 . 5 ROP 9685 . 5 9860 . 5 $ LOG HEADER DATA DATE LOGGED: 21-JAN- 98 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: 87.1 MAXIMUM ANGLE: 94.5 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9860.0 9684.0 9860.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER SOLAR GM 77113 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4.500 4.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHFIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: QUIKDRIL-N 8.60 510.0 9.0 30000 5.0 .000 .000 .000 .000 37.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. ~Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9630.5 9860.5 9745.5 461 9630.5 GR 19.6053 39.1624 25.4314 353 9630.5 ROP 8.0443 81.7033 27.1446 351 9685.5 Last Reading 9860.5 9806.5 9860.5 First Reading For Entire File .......... 9630.5 Last Reading For Entire File ........... 9860.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO rJ Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9807.0 ROP 9862.0 $ 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 9809.0 9864.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 22-JAN-98 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9864.0 9860.0 9864.0 94.5 94.5 TOOL NUMBER SOLAR GM 77113 4.500 4.5 QUIKDRIL-N 8.60 51.0 9.0 30000 5.0 .000 .000 .000 .000 35.0 .3 $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9807 9864 9835.5 115 9807 GR 22.966 28.2897 25.4113 5 9807 ROP 15.1758 32.2056 22.2938 5 9862 Last Reading 9864 9809 9864 First Reading For Entire File .......... 9807 Last Reading For Entire File ........... 9864 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ............ STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9811.0 ROP 9865.0 $ 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 9886.5 9940.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 23 - JAN- 98 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 9940.0 9864.0 9940.0 93.0 95.2 TOOL NUMBER SOLAR GM 77113 4.500 4.5 QUI~RIL-N 8.60 48.0 8.9 30000 5.0 .000 .000 .000 .000 35.0 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9811 9940 9875.5 259 9811 GR 21.1667 37.0133 25.6009 152 9811 ROP 6.9685 31.1524 15.7935 151 9865 Last Reading 9940 9886.5 9940 First Reading For Entire File .......... 9811 Last Reading For Entire File ........... 9940 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9886 . 5 10069 . 5 ROP 9941 . 5 10124 . 0 $ LOG HEADER DATA DATE LOGGED: 24-JAN- 98 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 DGR DUAL GAMMA RAY $ 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 10124.0 9940.0 10124.0 91.2 96.1 TOOL NUMBER SOLAR GM 77113 4.500 4.5 QUIKDRIL-N 8.60 48.0 8.9 5.0 .000 .000 .000 .000 39.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 9886.5 10124 10005.2 476 GR 19.8085 42.6226 25.9002 367 ROP 4.931 86.7457 32.4056 366 First Last Reading Reading 9886.5 10124 9886.5 10069.5 9941.5 10124 First Reading For Entire File .......... 9886.5 Last Reading For Entire File ........... 10124 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19. Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10068 . 0 10467 . 5 ROP 10122 . 0 10520 . 5 $ LOG HEADER DATA DATE LOGGED: 26-JAN-98 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 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 10518.0 10124.0 10518.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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 (OHM/~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 93.8 97.5 TOOL NUMBER SOLAR GM 74165 4.500 4.5 QUIKDRIL-N 8.70 53.0 8.8 4.1 .000 .000 .000 .000 42.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10068 10520.5 10294.2 906 10068 GR 21.3937 90.575 35.1663 800 10068 ROP 9.8137 6018.75 170.047 798 10122 Last Reading 10520.5 10467.5 10520.5 First Reading For Entire File .......... 10068 Last Reading For Entire File ........... 10520.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10467 . 0 11881.5 ROP 10521 . 5 11935 . 0 LOG HEADER DATA DATE LOGGED: 27-JAN- 98 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: 84.0 MAXIMUM ANGLE: 96.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 74165 $ BOREHOLE AND CASING DATA ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 11935.0 10518.0 11935.0 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): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.500 4.5 QUIKDRIL-N 8.70 41.0 8.7 31000 5.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 53.9 First Name Min Max Mean Nsam Reading DEPT 10467 11935 11201 2937 10467 GR 19.9883 126.239 38.3412 2830 10467 ROP 10.4079 301.758 115.873 2828 10521.5 Last Reading 11935 11881.5 11935 First Reading For Entire File .......... 10467 Last Reading For Entire File ........... 11935 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11881.5 ROP 11936.5 $ 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: MAXIMLrMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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) : STOP DEPTH 12063.0 12117.5 29-JAN-98 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 12117.0 11935.0 12117.0 86.6 98.6 ToOL NUMBER SOLAR GM 77113 4.500 4.5 QUIKDRIL-N 8.70 41.0 8.7 31000 FLUID LOSS (C3): RESISTIVITY (OH/~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 5.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 51.7 First Name Min Max Mean Nsam Reading DEPT 11881.5 12117.5 11999.5 473 11881.5 GR 25.7632 74.1201 36.7454 364 11881.5 ROP 6.9371 191.326 40.7231 363 11936.5 Last Reading 12117.5 12063 12117.5 First Reading For Entire File .......... 11881.5 Last Reading For Entire File ........... 12117.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12065 . 5 12895.5 ROP 12119 . 5 12950.0 $ LOG HEADER DATA DATE LOGGED: 31-JAN- 98 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: 98.0 MAXIMUM ANGLE: 103.0 ISC 5.07 / ISC 5.07 DM .09 / GM 1.21 MEMORY 12950.0 12117.0 12950.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER SOLAR GM 77113 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.500 4.5 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: QUIKDRIL-N 8.70 49.0 8.9 32000 5.0 .000 .000 .000 .000 56.1 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 R0P MWD 14 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12065.5 12950 12507.8 1770 12065.5 GR 19.0215 196.484 42.2038 1631 12065.5 ROP 7.1136 283.347 116.814~ 1662 12119.5 Last Reading 12950 12895.5 12950 First Reading For Entire File .......... 12065.5 Last Reading For Entire File ........... 12950 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Reel Trailer Service name ............. LISTPE Date ..................... 98/03/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Physical EOF End Of LIS File
