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200-010
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-07A PRUDHOE BAY UNIT R-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 R-07A 50-029-20523-01-00 200-010-0 W SPT 8102 2000100 2520 423 428 423 424 239 441 432 458 REQVAR P Adam Earl 3/12/2025 MIT-IA tested as per AIO 3.016 to 1.2X MAIP 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-07A Inspection Date: Tubing OA Packer Depth 197 2814 2796 2791IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250312125621 BBL Pumped:3.1 BBL Returned:3.1 Tuesday, April 22, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 99 999 99 9 9 AIO 3.016 to James B. Regg Digitally signed by James B. Regg Date: 2025.04.22 12:47:04 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-07A PRUDHOE BAY UNIT R-07A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 R-07A 50-029-20523-01-00 200-010-0 W SPT 8102 2000100 2460 570 574 574 572 60 148 143 151 REQVAR P Austin McLeod 3/5/2023 Two year MITIA to 1.2x MAIP (2050psi). AIO 3.016. 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-07A Inspection Date: Tubing OA Packer Depth 60 2705 2692 2690IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230305194554 BBL Pumped:3.1 BBL Returned:2.8 Monday, April 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 13:38:53 -08'00' MEMORANDUM TO: Jim Regg--Qq" 4-IzO(-?�g4 P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 31, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Nonh Slope, LLC R -07A PRUDHOE BAY UNIT R -07A Sre: Inspector Reviewed B Comm Well Name PRUDHOE BAY UNIT R -07A API Well Number 50-029-20523-01-00 Inspector Name: Lou Laubenstein Permit Number: 200-010-0 Inspection Date: 3/20/2021 Insp Num: mitLOL210322101459 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R -07A (Type Ini W ' TVD 8102 Tubing 575 577 574 573 ' PTD 2000100 (Type Test SPT' Test psi 2026 IA 199 2269 2262 2262 - � ' 2 - BBLBBL Pumped: z.z BBL Returned: z.l OA o o o Interval F REQVAR P/F I P Notes: MIT -IA every 2 -years to the maximum anticipated injection pressure per AA AIO 3.016 Wednesday, March 31, 2021 Page I of I MEMORANDUM TO: Jim Regg �F, �9 31 Zv J lei P.I. Supervisor GG FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 19, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. R -07A PRUDHOE BAY UNIT R -07A See: Inspector Reviewed By: P.I. SupryJAL Comm Well Name PRUDHOE BAY UNIT R -07A API Well Number 50-029-20523-01-00 Inspector Name: Guy Cook Permit Number: 200-010-0 Inspection Date: 3/15/2019 Insp Num: mi[GDCI90315155018 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-wA I Tubing 1100yp 1101 1102 - 1100 1099 l PTD 2000100 ' Type Test! —00 1 - SPT Test psi 2026 - IA 630 —� 2750 - 2747 - 2742 2739 " - -I- - - —o 0 o BBL Pumped: p 2.1 BBL Ret urned: z.z - OA 6 �4 _ Interval REQvAR P/F P Notes: AA A10 3.016 for IAxOA communication. Water inj only. Test to 1.2 max injection. Testing performed with a triplex pump, bleed trailer and currently calibrated gauges. Tuesday, March 19, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor I eFq 3)t('L J DATE: Thursday, March 7, 2019 SUBJECT: Mechanical Integrity Tests BE EXPLORATION (ALASKA) INC. R -07A FROM: Bob Noble PRUDHOE BAY UNIT R -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry >F-- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R -07A IInsp Num: mitRCN190304162619 Rel Insp Num: API Well Number 50-029-20523-01-00 Inspector Name: Bob Noble Permit Number: 200-010-0 Inspection Date: 3/3/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R -07A Typelnj � `A-1TVD 810'- Tubing iii [IIIIM 1120 1117 PTD z000loo (Type Test srT Test psi 2026 IA - 25s8 25542570 BBL Pumped: -REQvars .,'BBL Returned: 0 — OA a 9 erval— - Notes: 2nd test oft. AA 3.016 requires MIT- IA to 1.2 times max injection pressure (1615 psi x 1.2= 1938). Did not bleed off due to DHD ding diagnostics on the well. Thursday, March 7, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Thursday, March 7, 2019 TO: Jim ReggDATE: 3'/I Tests P.I. Supervisor I\� q SUBJECT: Mechanical Integrity Z BP EXPLORATION(ALASKA) INC. R -07A FROM: Bob Noble PRUDHOE BAY UNIT R -07A Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry ZW— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R -07A API Well Number 50-029-20523-01-00 Inspector Name: Bob Noble Permit Number: 200-010-0 Inspection Date: 3/3/2019 Insp NDm: mi[RCN 190304161853 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0-0 1, Type w TVD slot 'Tubing 1112 due ]III - i i u - PTD >_00010ioo "TYPe Test SPT Test psis 2026 IA IO2oz �� roo - — 2_09 BBL Pumped: z-7 �BBL Returned: _ OA 0 0 n Interval REQVAR IP/F I Notes: I test of 2.AA 3.016 requires MIT - IA to 1.2 times max injection pressure (1615 psi x 1.2 = 1938). Did not bleed down because they wanted to test it again. Thursday, March 7, 2019 Page I of I • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISbTON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations IBJ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved�tProgram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other SCi C/13 f Er 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 200-010 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service Er 6. API Number: 50-029-20523-01-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number PBU R-07A 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: hCetTotal Depth: measured 11278 feet Plugs measured See Attachment feet 0 true vertical 9095 feet Junk measured feet U I 0 7 ,70 0 7 Effective Depth: measured 10682 feet Packer 1 measured 8993 feet true vertical 8633 feet Packer true vertical 8103.78 feet Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20"x 30" 42-122 42-122 Surface 2650 13-3/8"72#L-80 41-2690 41-2690 4930 2670 Intermediate 9497 9-5/8"47#L-80 39-9536 39-8528 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10370-10430 feet 10750-10775 feet 11075-11100 feet 11100-11125 feet 11160-11230 feet True vertical depth: 8641-8632 feet feet 8656-8668 feet 8905-8928 feet 8928-8951 feet 8984-9050 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) No SSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: scA 6D NNEt'1 C C `�01 1d DE 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -3000 50 258 Subsequent to operation: -4445 200 1954 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG IBJ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-482 Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: Production Engineer Challenger Contact Email: Matthew.Bergene@bp.com Authorized Signature: /j "� rL `/-71Date: 7 4 ? Contact Phone: +1 9075644849 Form 10-404 Revised 04/2017 �qq( Vl� �l RBDMS 1/v AUG 1 1 2017 Submit Original Only Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, March 4, 2019 12:40 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, GWO Projects Well Integrity Subject: Produced Water Injector R-07 (PTD #2000100) inconclusive AOGCC MIT -IA Mr. Wallace, Produced Water Injector (PTD #2000100) is due for an AOGCC witnessed MIT -IA by 03/31/19. A witnessed MIT -IA was attempted yesterday, but was called inconclusive due to pressure increasing during the test, as shown in the table below. The well head pressures do not indicate pressure communication across strings. Also, looking at the wellhead temperature data, it appears the well head temperature dropped just prior to the test and was increasing back to stable conditions as the test began. The pressure increase appears to be from thermal effects and BP plans to keep the well online and re -test in the near future. R-07 W+IIn++C •wa 175 0 IND IF 1150 51+n+d wmY+Y +mpenl 00 to •5+m Please respond if in conflict with this plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 Tubing IA OA Pretest Pressure 1,120 90 vac Starting Pressure 1,116 2,500 vac 15 Minute Pressure 1,114 2,509 0 30 Minute Pressure 1,111 2,521 1 45 Minute Pressure 1,121 2,538 4 60 Minute Pressure 1,120 2,554 6 The well head pressures do not indicate pressure communication across strings. Also, looking at the wellhead temperature data, it appears the well head temperature dropped just prior to the test and was increasing back to stable conditions as the test began. The pressure increase appears to be from thermal effects and BP plans to keep the well online and re -test in the near future. R-07 W+IIn++C •wa 175 0 IND IF 1150 51+n+d wmY+Y +mpenl 00 to •5+m Please respond if in conflict with this plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED AUG 0 7 2017 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary ., G !+....�►'lr. August 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations covered by Sundry Application Approval # 316-482 for Well R- 07A, PTD # 200-010. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Plugs Attachment PBU R-07A SW Name Date MD Description R-07A 06/28/2017 10682 2-7/8"WFD CIBP R-07A 11/10/2003 11020 CIBP R-07A 11/05/2001 11140 CIBP • • . 0 _R 0 0 0 0O 0 C-O CO ONIV ) N C, N- N- co V i N- O COO N O 00 r r O m cf COV) 00 CO O NOO CO Nu N CO LO CO OLOr `- N CO O CO 00 O I I III I- V LO N N d) tt I's e- 'CT V CO CO 00 CO CO it m d0) CO 00 co CO O 00 ) CO CO CN LSI O O N 0) 0) 0) 0) Q Q0 N '- O � d N`CO O j "4- CI) co00O M Q • a 03OCCO 0 a� o � _ Jcoco C d C'r) NI* (0 J J N X h- TrN- 7 # N V• N � � NNNc- N4 J O N 0) N Ln O W Q G O- W ° W V 0 u_ c c a Z Z Z W W W m m ODI" ZZDD 0 U) Z J J I- I- • . . Packers and SSV's Attachment PBU R-07A SW Name Type MD TVD Depscription R-07A SSSV 2051.21 2051.17 4-1/2" MCX I-SSSV 7 ft4.14--- 'I `n R-07A PACKER 2583.37 2583.27 9-5/8" DV Packer R-07A TBG PACKER 8993.47 8103.78 7" Baker SAB Packer • 0 J o o U. " co OY Q g � °° ` 0 © � � ° U) c- E O 5 J ca N- oEc C O m Q u) ,.- u) f c0 73LO0 t O as EY Cu Nva y 02S -0 to O N C 7 c Q Z N N >> a3 U) Cu u_ N X13 •- m o RI o coW * `n Ca- m < m n. c Q a 0° W e Co -O a) 0 0 o O © 2 = E yft J • U) -0 Lo Q o 0 > Es) Lu ~ a J _1 d W N a) O 13 c o a 2 � 2 0 Lu w < N c N O ¢ N a) o O N W e _I c 3 o c m t O �J-- Q� co j 2 Z • o .- «- g a off (n (/) Z O E o ' C W > sz ca Ce o �oo � tncng Ill o O o � o 0 cn 0 � � > RS O Q ( o Q m d ga Ooh ;�, LO I- m — � a) Cu °) "coo ? ©a;1- O ccoiO3 �: = a '- o e ' ~ Mo- m ,- a) Q1,'0 Q J w- co 0 d ©a -•I �`d 0 n. C c CV Q Q•� (n E N . Q 1-1-. O O 0 Cl- O V ca •- - J N O EO N L O ato 5E NN`L. Z 1-- V W 0 W O -c 'y J LL L N U) To a~ ;7; 13 O Vct � O' J ° E > O cc U) QU) < tZ 2UN sZ Ki) fa 1- � E HWWu_ U) Wr- CN 0 U' f U' rn_ � 0 �(_ t p m � Z ¢ ? 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N m es a) N N .0 • TREE= 4-1/16-CIW 4110 ____. SAP NOTES:WELL ANGLE>70°(8)9775''''°"I-2S WELLHEAD= RC R.-0 7A REACNGS AVERAGE 125 ppm WHEN ON MI — WEL 1_ ACI'UATOR= BAKER C REQ'S AN SSSV WHEN ON Ml*0* 4-1/2"TAILPIPE OKB ELEV= 59 9' SACKED OUT OF PKR&LANDED IN TOP OF r LW- BF BE/= 21 57' 1 1 CM ro&THEN DRLD OUT BY CTD***MAX DOGLEG: iKOP= 380(7 26.3*@ 9840'** Mix Angle = 102°t 10135 / 2047' ]-17"INST Datum M39957' CI) '4111 ''- 204r -7*°T1SERSS.Sw/V4- " ,1)=1813' NV1/2DX:5P962"= Datum TVD= 8800'SS 20"CONDUCRTOR, #, ,ID= • —1 1 13-3/8'CSG,72#,1-80 SIRS,D=12.347" H 2690' 2581' —I9-518'DV PKR Minimum ID =2.441" @ 8884' 1 . TOP OF 2-7/8" LINER I , . 8879H5-1/2"BKR SCOOP ENTRY GUDE C/=3.63" TOP OF 2-7/8"LW H 8879' I 8879' —1 3-3/4'BKR DEPLOY SLV,I3=3.00" 7'TBG-1FC,29#,1-80 U4S,.0371 bpf,ID=6.184" H 8974" 8974' 1—9-5/8"X 7"BKR SAB PKR, Ci CI w/20'SEAL ASSY,ID=3.875" 9-5/8"X 7"LINR HGR 1-1 I—4-1/2"TAILPIPE BACKED OUT OF FKR 1 --k 1 II1 &LAMED ON TOP OF 7-LW. (CALLE)OUT BY CTD 02/23/00) • 1 ? —14-1/2-OT1S X NIP,D=3.813' 1 4-1/2"113G, 12 75,L-80, 0152 bpf,CI=3.958" —1NA 1-11-1 e R BEHIND . ? --14-1/2"OTIS XNIMP,ID=3.80" CT LNR (FELL 02J23/00) ? —14-1/2"WLEG,C)=3.958" 9-5/8"CSG,47#,1-80 BTRS,ID=1681" —I 1 7"MILLOUT WINDOW (R-07A)9583 -9590' 1 . 7"INFIPSTOCK(XX/XX/XX) H 9680' 7"LNR,29#,L-80 BTR ,0=6.184" —1 I FERFORA DON SUMMARY ‘ . ; 10682' 1-1.2-7/8"VVFD CUP(06/27/17) I REF LOG SPERRY MMIYGR ON 04/08/00 "riliT7ii; r,4 /7 ‘ 4 ,4-4 ,,r ANGLE AT TOP PERF.98°@ 10370' to*.4 -..--4.• 11020' --I 2-7/8"HES CP3P(11/10/03) Note_Refer to Production DB for historical perf data S2E1SPF' INTERVAL Cpn/Slz. SHOT SQZ iSt 2°' 1 6 , 10370-1043/) 0 06/27/17 1 11140' —.2-7/8'SKR CUP 2" 6 10750 - 10775 C 11/10103 IS (11/05/01) 2" 6 11075- 11125 C 11/05/01 2" ' 4 11160- 11230 C 11/05/01 PEITD ---1 11249' v . 2-7/8'LNR,6.16#,L-80 STL, .0058 bpf.ID=2.441' —1 11281' I DATE REV BY COMMENTS DATE REV BY COMVENTS PRUDHOE BAY 1W !01/18/81 VANGR 3 ORIGINAL COMPLETION 03/17/15 PJC LM/CSG/TBG UPDATES(TALI FS); WELL R-07A 104/09/00 ? CTD SIDETRACK 08/25/16 CRWMDI MINOR REVISIONS FERNITT No_ 2000100 08/14/12 108/14/12 WAIN lEti CEP @ 11020'CORRECTION 10/27/16 GJBIJINDI PULLED CHOKE(10/24/16) API No- 50-029-20523-01 1 03/12/14 MAU TREE C/O(03/02/14) 07/12/17 DLVV/JIVD SET CEIFIADIEERFS(06/27/17) SEC 32,T12N,R13E 592'FSL&752'AM. ,03/12/14 STFAMD SET CHOKE IN INSERT(03/06/14) 102/14/15,NLW/PJC FILL/RESET CHOKE ASSY 1 1 , I - BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,March 22,2017 TO: Jim Regg P.I.Supervisor ` SUBJECT: Mechanical Integrity Tests �'y�tt`I BP EXPLORATION(ALASKA)INC. R-07A FROM: Bob Noble PRUDHOE BAY UNIT R-07A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NtV61. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-07A API Well Number 50-029-20523-01-00 Inspector Name: Bob Noble Permit Number: 200-010-0 Inspection Date: 3/20/2017 Insp Num: mitRCN170321070808 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ! R-07A Type Inj w TVD 8102 Tubing 382 T 380 382 I 383 PTD 1 200010o Type Test SPT Test psi 2597 IA 59 1 2597 2595 2592 BBL Pumped: 3.2 BBL Returned: 3.1 OA 573 751 777 813 Interval REQVAR P/F P Notes: MIT-IA as per AIO 3.016,Every 2 years to 1,2 x max anticapated injection pressure(1000 psi)=1200 psi. 1,---* SCANNED AUG 3 0 2017, Wednesday,March 22,2017 Page 1 of 1 • OF TtJ ,1//7,"s THE STATE. Alaska Oil and Gas ofeLrSK ® Conservation Commission _ of I}£= 333 West Seventh Avenue GOVERNOR BILL WALKER^MAnchorage, Alaska 99501-3572 p ,1 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Rupert Lead EngineerSCA���d �!�. _ G L BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R-07A Permit to Drill Number: 200-010 Sundry Number: 316-482 Dear Mr. Rupert: 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 this (0 day of October, 2016. RBDMS LL OCT 1 0 2016 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! APPLICATION FOR SUNDRY APPROV ER 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ®. Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate I. Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 5e f C 113 P Er" 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-010 - 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service IBJ, 6. API Number: 50-029-20523-01-00. 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-07A . - r 9. Property Designation(Lease Number): 10. Field/Pools: j O~i 6y 1 6 `)F. ADL 0028282 • PRUDHOE BAY,PRUDHOE OIL • P 9 2016 i 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk 11281 . 9097 • 11020 8854 11020/11140 Casing Length I Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 42-122 42-122 Surface 2650 13-3/8"72#L-80 40-2690 40-2690 4930 2670 Intermediate 9497 9-5/8"47#L-80 39-9536 39-8528 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"MCX I-SSV 2051, 2050.90 12.Attachments: Proposal Summary ❑ Wellbore Schematic IRI 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service Ea- 14.Estimated Date for Commencing Operations: to/lc(G 15. Well Status after proposed work: V Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Rupert,C.Ryan be deviated from without prior written approval. Email Ryan.Rupert@BP.com Printed Name Rupert,C.Ryan Title Lead PE NWD&GC2 IPA.R-pad Engineer Signature /�7" ) Phone +1 907 564 4238 Date 4 1G,�� � COMMISSION USE ONLY / Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No L//: Spacing Exception Required? Yes 0 No FM Subsequent Form Required: l Q It 0 ��ll1 ///��� APPROVED BYTHE Approved by: / ' /� COMMISSIONER COMMISSION Date: /o._6 ,l/ fff / 1/71- 10/3/1(... }� ORIGINAL RBDMS OCT 102016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate •9rse/ ..7.s. g.2.7/-i6 Q. 00000 I8 O N N ct C N ti O O LC)N M O U N 00 , 000 o) M O CO ON CO CO CO CO O) O CO N. CO N Cn N O) N O M O O ID 0 CC) r- N CO 0) CO CO CO I I I I I I F in N O •4' CO O v- C7 O CO CO d OCflrch ,ltao N O M O O D O7 N CONCC) O O N d1 O O O) ✓ p 4 < 0) CO V 0 N O O ti t' N. O 0 I CO COCO CD O CO 6) C I- Q. O CD (=> CO I - J J J aa O Cb �# C N• M N *k (Or J J 'N X *k *k CV ✓ M ~ N rn � N4 — �)O CC) O) O co .q coo CO Nt "Sr Lo 0) 0) J N 0) N CO W - • o ' U Cu W UOI¢j_ eCacZZ Z W W W Om Om O D H Z Z J D UU) Z i F- H • • I I a, I I co m m N- CO rn a) CO N Ln o O 00 CO 00 W > I-- 0_a O H CO O 00 N .0 CD CO N- CO a CO 4 N- C i 0 N to O N CC) LU 0 CO 0) CS) 0) > O co co co co 0> F- W 0: 0 0 Q cn Z 0 UJ LU 0W H H 0 W a) gg Y 0 ° >> m O cn wY Y H r 2 cn cn 0 0 W W L N- O NLo cD LC) � ._I J J a d w III W O - - 0 0 0 W W W 0 J 0 0 E z z o 0 o a W a E ccQ II 2 0 0 0 W 2 1Y Z 0 Zz 0 < 2 2 0 <n o ccn ccn U¢) Q C a O H t CD LO O CD G L() N- CD CO Q a) N- CD v— v— D O = .- ,- r r r r co LL I. a) L — - Y I F- HH cn d -J d 2 2 2 0 (n co (n co co C, a a) a 0 U c IL_ U) U) U) is CL CL CL CL m QcoCO (0 a 0 t a) CL H O O O O Q D > o N N CV CV Z LL. 1 1 Q W 0000 OQ wWQ „L� LU C] N U , 0_ :9 W :7 U W W LL. W `- `- O m 0 Q Y W J J Q Cr W W Q Q m d m cn U LL LL (J) d W a) E co z Q Q Q Q N- NNN- - 0 0 0 0 m a a d O -1 0 0 w a CC CC CC CC Q Q m m LL LL cn cn a o: • 0 Packers and SSV's Attachment PBU R-07A SW Name Type MD TVD Depscription R-07A SSSV 2051.21 2051.17 4-1/2" MCX I-SSV R-07A TBG PACKER 2583.37 2583.27 9-5/8" DV Packer R-07A TBG PACKER 8993.47 8103.78 7" Baker SAB Packer ALASKA WELL ACTIOSTATEMENT OF REQUIREMENTS (V2.0,DBfD,EAZ,BPG 10/12/15) General Information Well Name: R-07A Well Type: WAG Injection Well API Number: 50-029-20523-01 Well Activity Conventional 4 Classification: Activity Description: Profile Modification Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Ryan Rupert Contact numbers: (907) 564-4238 (907)301-1736 Well Intervention Engineer: Josh Allely Contact numbers: (907) 564-5732 (907)350-7362 Lead Engineer: Dan Robertson Contact numbers: (907) 564-5546 (907) 529-5818 Date Created: September 1, 2016 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) 8/15/2016 3,322 0 811 Current Status: Operable Flowing Inclination>70°at Depth(ft) 9,775' MD Maximum Deviation (Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 103° 10,135' MD Datum depth,ft TVDss -8,800' TVDss Dogleg Severity(Angle and Depth) 30° 10,079' MD Reservoir pressure(date, psig) estimate 3,150 psi Minimum ID and Depth 2.441" i 2-18"liner Reservoir Temp,F 212° F Shut-in Wellhead Pressure Likely on a vac Known mech. integrity problems(specifics) none Last downhole operation (date, 2/14/2015 SL pulled choke from SSSV nipple at 2047' MD. B&F to 2000'. Set new operation) upsized choke in SSSV nipple. Most recent TD tag(date,depth, toolstring OD) 3/18/2014 SL found deviation at 9755' SLMD with a 2.25"centralizer Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, R-07A inj41/has injected into the current Z4 perfs for 13+y4II There was oil logged back uphole when background information, drilled in 2000,and it's now time to access that oil. The planned perfs will switch the stream lines,and • etc: also access oil above the 44N shale(currently perf'd under it). MI will be planned for these new perfs in the next 5 years as well for increased recovery. The injectivity of the current perfs seems very high for Z4, but a 2007 (PROF didn't see any smoking guns. They didn't however, check the liner lap, so SL will test it before the CT work to confirm its holding. The well currently has a 0.42"choke set in the SSSV nipple. We plan to POI the well with new perfs without a choke installed. If needed, a new one can be sized and installed based on the obtained injectivity. 2007- IPROF confirms injection going into Z4 perfs, and not past the plug. The liner lap wasn't logged. 11/10/2003: Plug set to isolate Z2B, Then Z4 perf'd. No PT on plug/lap 11/5/2001: Plug set to isolate Z2A,Then Z2B perf'd. No PT on plug/lap 4/9/2000: Rig cement job had only minimal losses and got 15.2 bbls of returns (2.6 bbls lost). That puts volumetric ToC at 9460' MD (assumed 20% washout). Rig logged their cement and saw cement in the liner lap(AOGCC reg at the time). Great cement up to 9614' MD, with none above 9110' MD. Passed a liner lap test to 2200 psi with 75 psi loss across 30 minutes. (Window at 9580' MD) • Well Intervention Details • Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2 For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Specific Intervention or Well Objectives: 1 Confirm liner lap still holding 2 Hydraulically isolate old perfs 3 Access new Z4 sweep point above shale 4 Opportunistic caliper(7"tubing,last one was 1999). Key risks,critical issues: Mitigation plan: 1 Depth control. Want to ensure we pert above the shale, Tie in log for plug set. Can tie into plug mechanically but with adequate fault standoff for perfs. Keeping max P's low. Won't exceed what recent injection has subjected well to(and has well behaved 2 7"tubing weaker than normal 4-1/2". Only have 1999 TIO's). Damage would have to be>580/0 penetration or caliper(was 27% max penetration back then) >31°/0 uniform to take us over 80%burst. Not an issues,as long as we honor max P's. If LLR down liner lap with LTTP set is>500 bpd(0.35 3 If liner lap fails against the LTTP bpm)at 1000 psi,call APE. Will likely want to waive off CT work,and set a 7" LTP instead. 4 Tubing movements,SBR floating TT See attached calcs. Fine as long as we honor our max Summary Service Line Activity Step# 1 S Pull choke from SSSV, drift to deviation, caliper, set LTTP, PT liner lap, pull LTTP 2 F SL assist. Liner lap PT 3 C Tie-in log, PT plug, Set 2-7/8"CIBP, adperf(60'), Steprate test Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): -Pull choke from SSSV nipple at 2047' MD. Note condition of choke, and no-go ID in AWGRS. Drift to deviation to mimic a 30' 2" perf gun 1 S -Run 40-arm caliper from TOL to surface -Set LTTP in existing deployment sleeve at 8879' MD, PT lap per FB template(call APE if fails. See above risk#3) - Pull LTTP regardless of PT result, RDMO Drift/tie in log for plug set. Want to tag existing plug, if possible. Required depth = 10,500' CTMD -Set 2-7/8"CIBP mid joint close to 10,680' MD -Tie in log 11/5/11 SLB GR/CCL/Temp - Prefer this depth, but if drift comes in shallow,anywhere mid-joint uphole is acceptable 3 C - PT plug to 1000 psi surface pressure for 10 mins. If fail rate is>0.35 bpm at 1000 psi, call APE. -60' adperf via mechanically tie-ing into new CIBP, per attached - Perform steprate test down CT x tubing annulus for 5 mins each at 0.5, 1, 1.5, 2, 3,4, 5 bpm. Honor a max pressure of 2000 psi throughout(consult SL caliper to ensure no deration is necessary below this max P). RDMO regardless. If injectivity low, will plan another intervention. Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: — FTP(psi): Choke setting: PI (bfpd/psi dp) Post job POP instructions: POI well at 5k PWI . • k ,i Tie-in for CIBP set a — Tie in for ii) so() 4 i ' _____.___ mu :_ r : a - UNININ- .■.1111► 1 -4 1111111111111 [ ......= -,_ -/ I i . „ _ _ 4 i .,7_ -I .- ,a I . _ .__ F4.: 4—DCCT. 10350 i . alik j VIIIIIMO __L- - — irme , I1A AI • r .rte _. i d I 1 -, a pl ' ''. t P - t, II i tf e •Iti i ' ,! rf MI 1111111 . S t 4 _- .. ii, 10700 EMI u► WM - - um MI w y t — a all t . : i r i . • i NSW- i p 1,- P - t •ig , : ... - {, t_ _..... _ _ . , ___________ . e - -i imumil 10750 a _ .. _ ..� _,,_. __ aun_mar all afT IP as +{ t -,......W6tiVYEW # * f Schlumberger .rug I 104 51) t o North:il. 14. gH9ca alla M uIMUNININUIS 'r-... a stela.r..rr .10.c. .w.. .K.. �_w w r A en... aw...n.an w.. —i _ _ It: a X T P>. 111 M a"armia s - is 10800 } -- j h pmt... • R-07A la. ill wir 8500 L 9600 85248536 -- 8558 4 4 r... 8568 - - -�- 8588 x .: --� . 9700 8588 • - 8598 m ' 8606 w 8614 �""". -. � 71 M!! �- 8620 8626 -9800 8632- - • 8636: 8640' 8644 lip ] -• , -9900 ----4 ' 1. 8644 8642 1000. 8630 T t 8638 8636 8634 8632 — — 1010. 8630 . �' J 8626 t 8622 8618 K. �a� `o-., c- 7ilomuld 8614 `„ ; 1020. 8610 - C 8606 i 1 8602 8598 ..mill' 1030• 8594 859 I 1 8586 '� 1 1 8582 `- / -1040. 8578 . _ ' I 1 f 8574 • i 8570 8568 11''- 8566 1.050• ` 55 8564 a S �.-. -1060. _ .., II 8564 8566 k 8570 •" 8574 I ` 7 . -1070. 8578 8584. E .8590 ""`— nr� 8596 y -- a �„.� #i.. ioo8612 -4 . -10801 86220 :: '""°aa. ' -,-.Ti. ti 8630 8650 - 8650 8660 8672 -1090.8684 It.8696 � , 8728 " n E r � -' ;.:�• 8720. ..� .. -- ' �'- 8734 ..r-' 8748 .� " =?5 - 3' 8762 _ r.^ -1100• 8776 ti 8790 8804 u1.. 8818 yaw 3° 8832 _ 8846 "1 -1110. 8860 ' =�7 8874 8888 8902 e_ _ — .�-. s. °„..rr ' 8916 - 't 8930 8944 I �.�_t �- - -1120. 8958 t 8972 8986 9000 a 9014 ti 9028 g 1130. 1 HILL= 4-1/16"CNV SA NOTES:WELL ANGLE>70°(a 9775'**"I-QS 4n-EAD= FMC 1110FtEA AVERAGE 125 ppm WI-EN ON MI*** AACT1 ATOR= BAKER C R�� A REQ N SSSV WHEN ON M1 4-1/2"TAILPIPE WELL 'OKB ELEV= 59.9' BACKS)OUT OF PKR&LANDED IN TOP OF r LNR- BF BEV= 21 57' 1 I CMT'D&TI-EN IX&'D OUT BY CTD'*'MAX DOGLEG: KOP= 3800' 26.3•@ 9840'**" Max Angie= 102`@ 10135' IIIIII Datum MD= 9957 ® ,, 2047" --�7"OTE SSSV NP,D=5.962" 'Datum TVD= 8800'SS C 2047' �—4-112"CHOKE SET IU 7"tNSEH I,D=.42" 20"CONDUCRTOR,.+#,, ,ID' _—...._- H T r � (02114/15) 133/8"CSG,72#,L-80 BTRS,D=12.347" H 2690' 2581' --9-5/8"DV FKR Minimum ID = ,42" @ 2047' 4-1/2" CHOKE IN 7" INSERT i 8879' H5-1/2"BKR SCOOP ONTRY GUIDE D=3.6371 TOP OF 2-718"LNR i— 8879' 8879' H 3-3/4"BKR DEPLOY SLV,D=3.00" T TBG-IPC,29#,L-80 1145,.0371 bpf,D=6.184" -{ 8974' CI 8974' -i 9-5/8"X 7"BKR SAB FKR, w/20'SEAL ASSY,D=3.875' ) 9-5/8"X 7"LPIF2 HGR — 8044' � .� ? LFPE BACKED OUT OF PKR — '6 _r\Null)ON TOP OF 7"LNR. • (DRLLED OUT BY C It)02/23/00) • ? —4-1/2'OTIS X NP,D=3.813" 4-1/2"TBG, 12.75,L-80,.0152 bpf,D=3.958" H NA BEHIND ? 4I-1/2"OTISXNNP,D=3.80" CT LNR (FELL 02(23/00) ? H4-1/2"WLEG,D=3.958" 9-5/8"CSG,47#,L-80 SIRS,C=8.681" —I 9534' 1--4 k 0 7'IUILLOUT WINDOW (R-07A)9583'-9590' 7"WHIPSTOCK(XX/XX/XX) 9580' eCI, 0 7"L142,29#,L-80 B I Hs,D=6.184" —I ~9583 \ `r 0 FERFORATDNSUMMARY 4 11020' J-12-718"FES CSP(11/10/03) REF LOG:SPERR1'i,M1 YGR ON 04/08/00 I, TiemArimaas 'll,4 ANGLE AT TOP PERF:63"@ 10750' Note:refer to Production DB for historical pert data 11140' —I 2-718"BKR CSP(11/05/01) SIZE SW INTERVAL Opn/Sqz SHOT SQZ % 2' 6 10750-10775 0 11/1W03 ` 2" 6 11075-11125 C 11/05/01 2" r 4 11160-11230 C 11/05/01 I PBTD H 11249' • 2-718"LNR,6.16{!,L-80 STL, 0058 bpf,C=2.441" H 11281' DATE REV BY COP. NTS DATE REV BY COMMENTS FRUC)-OE BAY UNIT 01!18181`/ANGR 3 ORIGINAL COMPLETION 03/17/15 PJC LNR/CSG/TBG UPDATES(TALLES) WELL. R-07A 04/09100 ? CTD SIDETRACK 08/25/16 CRWJM)MINOR REVISIONS FERwr No "2000100 08/14112 WABJ PJ(CIBP @ 11020'CORRECTION API No. 50-029-20523-01 03/12/14 DUIJM.) TREEC/O(03/02/14) SEC 32,T12N,R13E 592'FSL&752'FWL 03/12/14 SI I-/JM? SET CHOKE N INSERT(03/06/14) 02/14/15 M_W/PJC FULU RESET CHOKE ASSYBP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,February 18,2015 P.I.Supervisor kat?. ZII as SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC R-07A FROM: Chuck Scheve PRUDHOE BAY UNIT R-07A Petroleum Inspector Src: Inspector Reviewed By:n , J5 P.I.Suprva— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-07A API Well Number 50-029-20523-01-00 Inspector Name: Chuck Scheve Permit Number: 200-010-0 Inspection Date: 2/17/2015 Insp Num: mitCS150217143927 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-07A IType Inj TVD � 8102 I Tubing 960 960 • ! 950 955 PTD 2000100 Type Test SPT Test psi' 2026 IA 494 2594- 2592 -, 2590 • Interval L QvAR _ ,P/F P - OA I 297 501 - 503 - I 504 - Notes: 2 Year MIT per AIO 3 016 for slow IA x OA comunication. Wednesday,February 18,2015 Page 1 of I P-,1,- i —aA ?Az too Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Friday, May 24, 2013 12:55 PM 2C' � Z4 i3 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, D &C Well Integrity Coordinator; Daniel, Ryan; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L; AK, RES GPB West Wells Opt Engr Subject: RE: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat Notification Dear Mr. Regg, As of 5/24/13, well R -07A SVS has been returned to normal service. Please contact me with any questions. Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. SCANNED A ��� PBOC - 8103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 From: AK, OPS FF Well Ops Comp Rep Sent: Thursday, May 16, 2013 3:45 PM To: Regg, James B (DOA) Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Daniel, Ryan; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L Subject: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat Notification Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that well R- 07A (permit # 2000100) in now operating with its SVS defeated as of 5/16/13. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 1 Polk r - 074 2 0100 Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Thursday, May 16, 2013 3:45 PM } I ( 7 /13 To: Regg, James B (DOA) Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Daniel, Ryan; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, , Jennifer L Subject: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat Notification Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that well R- 07A (permit # 2000100) in now operating with its SVS defeated as of 5/16/13. Per the wavier, BPXA has tagged L.-- d logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep SCANNED WY 2 0 2313 BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 1 RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMN JAN 2 2 2013 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U L( L( i Performed: Alter Casing ❑ Pull Tubing0 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 ❑ 200 -010 -0 3. Address: P.O. Box 196612 Stratigraphk Service el 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20523 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: s ADL0028282 - PBU R -07A 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 11281 feet Plugs measured See Attachment feet true vertical 9097 feet Junk measured None feet Effective Depth measured 11020 feet Packer measured See Attachment feet true vertical 8854.34 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 38 - 118 38 - 118 1490 470 Surface 2652 13 -3/8" 72# L -80 38 - 2690 38 - 2689.9 4930 2670 Intermediate None None None None None None Production 9497 9 -5/8" 47# L -80 37 - 9534 37 - 8525.69 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10750 - 10775 feet 11075 - 11100 feet 11100 - 11125 feet 11160 - 11230 feet True Vertical depth 8656.06 - 8667.77 feet 8904.69 - 8927.78 feet 8927.78 - 8950.92 feet 8983.62 - 9049.5 feet Tubing (size, grade, measured and true vertical depth) 7" 26# L -80 37 - 8990 37 - 8101.09 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: SCANNED MAR 1 8 2013 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 Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: f Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUC❑ 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 Nita Summerhays Email Nita.Summerh Printed Name Nita Summerhays Title Petrotechnical Data Technician ' dliMME _.,:;i.iivi n to Phone 564 -4035 Date 1/21/2013 RBD AN 2 8 2013 Form 10 -404 Revised 10/2012 14 /1)ubmit Original Only • • Daily Report of Well Operations ADL0028282 T /I /O = 200 /0 /0 Temp =hfot ( Brightwater Reservoir Sweep Mod) Rigged up and PT surface lines 12/17/2012 ** *Continued on WSR 12- 18- 2012 * ** T /I /O = 200/0/0 ** *Continued WSR from 12 -17- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 5000 bwpd. Pumped 548 gal. EC9360A (Surfactant) Average of 30.44 gph for 18 hrs. Pumped a total of 548 gal. since start of project. Pumped 2278 gal. EC9398A ( Polymer) Average of 126.5 gph for 18 hrs. Pumped a total of 2278 gal. since start of project 12/18/2012 ** *Continued on WSR 12/19/2012 * ** T /I /O = 236/20/0 ** *Continued WSR from 12 -18- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 961 gal. EC9360A (Surfactant) Average of 40.04 gph for 24 hrs. Pumped a total of 1509 gal. since start of project. Pumped 2980 gal. EC9398A ( Polymer) Average of 124.16 gph for 24 hrs. Pumped a total of 5258 gal. since start of project 12/19/2012 ** *Continued on WSR 12/20/2012 * ** TIO = 222/60/0 Continued from 12 -19 -2012 WSR Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 1121 gal. EC9360A (Surfactant) Average of 46.7 gph for 24 hrs. Pumped a total of 2630 gal. since start of project. Pumped 3147 gal. EC9378A ( Polymer) Average of 131.125 gph for 24 hrs. Pumped a total of 8405 gal. since start of project 12/20/2012 Continued on 12 -21 -12 WSR T /I /O = 247/60/40 ** *Continued WSR from 12 -20- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 5000 bwpd. Pumped 1086 gal. EC9360A (Surfactant) Average of 45.2 gph for 24 hrs. Pumped a total of 3716 gal. since start of project. Pumped 3189 gal. EC9398A ( Polymer) Average of 132.8 gph for 24 hrs. Pumped a total of 11594 gal. since start of project 12/21/2012 ** *Continued on WSR 12/22/2012 * ** • • Daily Report of Well Operations ADL0028282 T/I /O = 277/50/20 ** *Continued WSR from 12- 21- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 1030 gal. EC9360A (Surfactant) Average of 44.7 gph for 23 hrs. Pumped a total of 4746 gal. since start of project. Pumped 3218 gal. EC9398A ( Polymer) Average of 139.9 gph for 23 hrs. Pumped a total of 14812 gal. since start of project. 12/22/2012 ** *Continued on WSR 12 -23- 2012 * ** T /1 /0 = 266 /100 /40 'Continued-WSR from 12 -22- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 5000 bwpd. Pumped 414 gal. EC9360A (Surfactant) Average of 41.4 gph for 10 hrs. Pumped a total of 5160 gal. since start of project. Pumped an additional 533 gal surf. Pumped 855 gal. EC9398A ( Polymer) Average of 855 gph for 9 hrs. Pumped a total of 15667 gal. since start of project. 12/23/2012 Job Completed, Unit left on location due to phase conditions FLUIDS PUMPED GALS 5693 EC -9360A SURFACTANT 15667 EC -9398A POLYMER 21360 TOTAL Casing / Tubing Attachment ADL0028282 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 38 - 118 38 - 118 1490 470 LINER 2402 2 -7/8" 6.16# L -80 8879 - 11281 8014.17 - 9097.42 13450 13890 LINER 539 7" 29# L -80 9044 - 9583 8142.85 - 8565.78 8160 7020 PRODUCTION 9497 9 -5/8" 47# L -80 37 - 9534 37 - 8525.69 6870 4760 SSV 4 4 -1/2" MCX I -SSV 2047 - 2051 2046.96 - 2050.96 SURFACE 2652 13 -3/8" 72# L -80 38 - 2690 38 - 2689.9 4930 2670 TUBING 8953 7" 26# L -80 37 - 8990 37 - 8101.09 7240 5410 • • 1 1 1 1 • • Packers and SSV's Attachment ADL0028282 SW Name Type MD TVD Depscription R -07A PACKER 8990 8041.19 7" Baker SAB Packer R -07A PACKER 9044 8082.95 7" Top Packer • • R -07A 200 -010 -0 Plugs Attachement SW Name Date MD Description R -07A 11/11/2003 11020 CIBP R -07A 11/6/2001 11140 CIBP V TREE= 6' CM, • 1/VH D= FTC E NOTEk WELL ANGLE> 70° 9775' *** H2S -- ACTUATOR= = OTIS R -07A REA AVERAGE 125 ppm WHEN C44 MI *** WEI.L KB ELE1! _ 59 9 REQ'S AN SSSV WHEN ON Mt *** 4-1/2" TAILPIPE BF. BAY = - 21.57" BACKED OUT PIO2 3 LANDS} IN TOP OF T" LNR - KOP = 3800 I I CMTD & TttF31 DRL'D OUT BY CTD *** FMsx Angle = 102° 10135 Daft= MD= 9957" Datun1VD= 8800'SS I I 2047' H7" OTS SSSV NP, D= 5.96' 1 20° CONDl1CFTTOR, I 7 113 -3/8" CSG, 72#, L -80, D = 12.347" H 2690' I 8878' H5-1/z. BKR SCOOP ENTRY G&EE. D = 3.63" I I TOP OF 2 -7/8" LNR, D = 2.377" H 8885' I 8879' H 3-3/4' BKR DB'LOY SLV, ID= 3.00' I 17" TBG, 26 #, L-80, .0383 bpf, D = 6.278" H 8973' I I 8973' HTOP OF BKR PBR ASSY I L - I 8990' H9-5/8* X 7" BKR MB FKR, D = 3.875" Minimum ID = 2.377" @ 8885' TOP OF 2 -7/8" LINER 9-5/8" x r LNR HGR H 9044' I I I I NA I- I4 -1/2" OTIS X NP, D= 3.813" I BEHIND I I I NA H4 -112" OTC XN N6? D = 3.80" I CT LNR 1 4-1/2" TBG, 12.75, L-80, .0152 bpf, D = 3.958" H NA / \ I NA I--I4 112' MEG, D= 3.958" I 1 9-5/8" CSG, 47 #, L -80, D= 8.681' H 9534` I A • 7" A LLOUT VVI+DOW 9583' - 9590' I 7" AM-PSTOCK {XXDO U)0() I—I 958 —___. 17" LNR, 29#, L-80, D = 6.184' H -"9683 I ` PERFORATION SUMMARY n � ,� t 7 11020' H2 -7/8" I-ES COP (11/10/03) I 1'w / REF LOG: SPERRY MAd/GR ON 04/08/00 ;Y,�,y, ' ANGLE AT TOP FERF: 63° r, 10750' I Note: Refer to Production CB for historical perf data / I 11140' 1-12 -718' BKR COP {11 /05/01} SIZE SPF tITBRVAL Opn/Sgz DATE 2" 6 10750 - 10775 0 11/10/03 2" 6 11075 -11125 C 11/05/01 2" r 4 11160 - 11230 C 11/05/01 I PBTD H 11249' ' ; 12 -7/6' LNR, 6.16#, L-80, .0058 bpf, D = 2.377" H 11281' I DATE RB,/ BY COMVE TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01118/81 ORIGINAL COMPLETION 01/18/12 TM IJM) ADDED H2S SAFETY NOTE WELL: R. 07A 04/09100 CTD SIDETRACK 08/14/12 WAB/ PJC CDP ,s 11020' CDFFECTK)N PERIM' No: `2000100 12/31/01 CHtTP CORRECTIONS AR No: 50- 029 - 20523 -01 11/10/03 KEY/TLP ADD F$2F, COP SEC 32, T12N, R13E, 592' NSL & 753' EV& 06/17/04 PJRTLH FEW CORRELTIONS 02/15111 Mi/JM) ADDB)SSSV SAFETY NOTE ; BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg J C 1 DATE: Friday, March 11, 2011 P.I. Supervisor C' q 123/ !I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R -07A FROM: Bob Noble PRUDHOE BAY UNIT R -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J;�-- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT R - 07A API Well Number: 50 029 - 20523 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCNI10305152006 Permit Number: 200 - 010 - Inspection Date: 3/5/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R -07A ' Type Inj. W TVD 8102 ' IA 590 3000 ' 3000 3000 P.T.D 2000100 'ITypeTest SPT Test psi 3000 ' OA 230 400 470 500 Interval RE - p/F P Tubing 200 200 I L 200 200 Notes: 2 Year MITIA to 2500 psi AS 3,O I(p - AA fl€ -k- 1 .Z F're -S5 v `e *Oa APR 13 all Friday, March 11, 2011 Page 1 of 1 r L .~U~ ~ ~ ~9A~ Al~sk~ Qil ~ G~~ ~an~, Co~mossi~n ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 t:~;'`~~~'~~is~ J~.iL ~ '' ~~i~,~~1 ~~ tw> July 10, 2009 Mr. Tom Maunder Alaska Oi! and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Anchor~~~ ~, . '~ O~ - ~ ~Q ~ -~ ~ ~ ~ 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 LJ J BP Expioration (Alaska ) lnc. 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 # Initiai toQ of cement Vol. of cement um ed Fi~al top of cement Cement toQ off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 511i/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 . R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-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 50029206180000 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 5Q029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 f~-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5l17/2009 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 5i17J2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 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 6/11l2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18l2009 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 IVA 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) Ina ~ ~ Attn: Well Integrity Coordinator, PRB-20 ~`~ Post Office Box 196612 ' ` Anchorage, Alaska 99519-6612 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annutus. 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, Torin Roschinger ~y~~~~~~~~.? ~~ ~d-- #` -` ~Cu~ 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 Weli 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 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 A-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48,87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 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 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 19318i0 Q.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 i MEMORANDUM To: Jim Regg --~ ?~1~ ~da, P.I. Supervisor ~~~ `~I FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-07A PRUDHOE BA1' UNiT R-07A Src: Inspector 1vnN_f°nNTTnF.NTT A T . Reviewed By: P.I. Suprv ~- Comm Well Name: PRUDHOE BAY iJNIT R-07A API Well Number 50-029-20523-01-00 Inspector Name• Bob Noble Insp Num: mitRCN090322135238 permit Number: 200-010-0 - Inspection Date: 3/22/2009 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R-o7A Type Inj. W TVD 8102 / IA 0 3020 .i 3020 3020 P.T. 2000100 TypeTest sPT Test psi 3020 OA 340 320 35fl 380 Interval REQvAR P/F P Tubing 420 420 420 420 Notes: ~ ~ ~d~ (. Z Tuesday, March 24, 2009 Page 1 of 1 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOOCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 (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 : ProActive Diagnostic Services. Ine. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1 BL / EDE Disk R - 07 A Injection Profile w/WB 13-Jun-07 1) 2) 3) 4) 5) 6] 7) SCANNED JUL 1 0 2007 OTe- 6(D-al6 ~ lSé)0-"3 RECEIVED Signed: ePL--- JUL 0 3 2007 Print Name: tll/\c'Ót-\ u e n¡\r..tA 14 \-< e ,lI Date: Alaska Oil & Gas Coos. Commission Anchorage PROACTIVE DIAGNOS11C SERVICES, INc., 130 W.INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AI( 99518 PHONE: (907)245-8951 FAX: (907)245~952 E~L: PDSANCHORAGE@MEMORYLOG.COM WEeslTE: WWW.MEMORYLOG.COM D:\Master _ Copy- 00 ]DSANG-2OxxIZ_ WordIDistribulion\TmnsmittaC Sheets\TransmiC OriginaI.doc o SARAH P6iLlN, GOVERNOR t~~TT`~v~l A-~e~~~~ty ~~~jrn~r~~~+y~+~a~ 333 W 7th AVENUE, SUITE 100 ®17.-7~~~~gi®is ~®1-~e1•~9i~7~7~®li ANCHORAGE, ALASKA 9950?-3539 PHONE 1907) 279-7433 FAX (907) 275-7542 ADMINISTRATIVE APPROVAL AIO 3.016 iV1r. Steve Rossber ,Wells Mana er ~~`` SAN ~ 20~$ g g `~~ BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 RE:.PBU R-07A (PTD 2000100) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject water in the sub- ject well. The Commission hereby denies BPXA's request for administrative approval to inject gas in the subject well. PBU R-07A exhibits slow inner annulus by outer annulus communication. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU R-07A and is able to manage the annuli pressures with pressure bleeds. The Commission further fords that, based upon reported results of BPXA's diagnostic procedures, PBU R-07A exhibits two competent barriers to the release of well pressure. Accordingly, the Com- mission believes that well operation in water injection service will not threaten the envi- ronment or human safety. However, the Commission believes that PBU R-07A's condi- tion does not conform to the relatively more stringent standazds of well integrity neces- sary to ensure safe gas injection. AOGCC's administrative approval to inject water only in PBU R-07A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform aMIT - IA every 2 years to 1.2 times the maximum antici- pated well pressure; AIO 3.016 • • Apri16, 2007 Page 2 of 2 4. BPXA shall limit the well's outer annulus pressure to 1000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection; and 7. The MIT anniversary date is Mazch 20, 2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ska and dated April 6, 2007. Daniel T. Seamount, Jr. Commissioner J Cathy P oerster Commissioner .~.~~ ~~. 9'>. u.A".'",,, . . . .. ... ".. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm _Marker .doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator SuspendD Repair WellD Pull Tubing D Operation Shutdown D Plug PerforationsŒ] Perforate New Pool D 4. Current Well Class: Perforate ŒJ WaiverD Stimulate [i] Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0100 OtherD Name: BP Exploration (Alaska), Inc. 59.90 8. Property Designation: ADL-0028282 11. Present Well Condition Summary: Development D Stratigraphic D 9. Well Name and Number: R-07 A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool ExploratoryD Service ŒI 6. API Number 50-029-20523-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 11281 feet Plugs (measured) Junk (measured) 11020,11140 true vertical 9097.4 feet Effective Depth measured 11020 feet true vertical 8854.3 feet None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 118 38.0 118.0 1490 470 Liner 2402 2-7/8" 6.16# L-80 8879 - 11281 8014.2 - 9097.4 13450 13890 Liner 539 7" 29# L-80 9044 - 9583 8142.9 - 8565.8 8160 7020 Production 9497 9-5/8" 47# L-80 37 - 9534 37.0 - 8525.7 6870 4760 Surface 2652 13-3/8" 72# L-80 38 - 2690 38.0 - 2689.9 4930 2670 Perforation depth: Measured depth: 10750 - 10775 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 37 8990 F<ECEIVEi') FES 2 6 2004 Ala~~ka ml g\ Gas COilS. Comr:M~;s,~on ~ (It True vertical depth: 8656.06 - 8667.77 Packers & SSSV (type & measured depth): 4-1/2" MCX I-SSV 7" Baker SAB Packer 7" Liner Top Packer @ 2047 @ 8990 @ 9044 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 0 0 3678 60 616 0 0 7552 500 1611 Reoresentative Dailv Averaae Production or Iniection Data 13 14. Attachments: 15. Well Class after proposed work: : Exploratory D DevelopmentD Service Œ] Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and co.rrect to the best ofmykn9wledge. Contact Garry Catron Printed Name Garry Catron Signature Title Production Technical Assistant Phone 564-4657 Date 2/26/04 Form 10-404 Revised 1:~;~~;I,~~,~!;.',,~~'J ) MAR 1 6 2004 - RSÐMS Bfl FEB ,2," ?O.Q~ R-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/08/03 ***WELL INJECTING ON ARRIVAL*** PULL MCX ISSSV @ 2047 MD.( SERIAL # M-39B) DRIFT W/2.25 CENT, SAMPLE BAILER, 9855 SLM (STOPED DUE TO HIGH ANGLE) ***WELL & FLOWLINE WAS FREEZE PROTECTED.*** 11/09/03 CONTINUED FROM 11/08/03 WSR. PERFORM WEEKLY BOP TEST. MU 2.2111 BJSN. MAKE JET PASS ON TUBING AND LINER UP & DOWN WITH 1 % SLK KCL FROM SURFACE TO 111001 CTM. RIH WITH BAKER BHA 11/211 MT DBPV, HYDRAULIC DISCONNECT & PDS MEMORY GR/CCL. MAX OD OF TOOL STRING IS 2.2511. FLOWLINE FREEZE PROTECTED 11/8/03 WITH 50/50 METHANOL. TAG LINER TOP @ 88751. PUMP DOWN CT TO GET PAST LINER TOP. LOG GR/CCL FROM 111001-101001 W/ FLAGS @ 109601 & 107001, FP BACKSIDE W/ 40 BBLS METH/WTR. CONTINUED ON 11/10/03 WSR. 11/10/03 CONTINUED FROM 11/09/03 WSR. POOH. MAKE TIE-IN CORRECTION. MU/RIH W/ HES 2 7/811 CIBP, TIE INTO LOWER FLAG. SET 2 7/811 HES CIBP @ 110201 (MID ELEMENT). RIH W/ SWS 211 GUNS 6 SPF 60 DEG PHASING, MAKE TIE IN CORRECTION TO UPPER FLAG. PERFORATE INTERVAL 107501 - 107751, (25 FEET), ALL SHOTS FIRED. RIH WITH 2.1311 BDJSN TO PERFORM INJECTION TEST. CONTINUED ON 11/11/03 WSR, 11/11/03 PERFORM INJECTIVITY TEST DOWN BACKSIDE W/ 1% KCL @ 0.3 BPM/2944 WHP.TAG /DEPTH CORRECT TO CIBP, PERFORM 2 STAGE HCUHF ACID STIMULATION JOB. FIRST STAGE CONSISTED OF 10 BBLS 71/2 % HCL & 10 BBLS 9 % -1 % HCL-HF MUD ACID, SPOT ACID AND RECIPROCATE FROM 10,700 - 10,8201, PERFORM INJECTIVITY TEST AFTER FIRST STAGE ACID, 3.3 BPM/2800 PSI. SECOND STAGE ACID JOB CONSISTED OF 50 BBLS 71/2% HCL & 50 BBLS 9%-1% HCL-HF ACID, RECIPROCATE ACROSS SAME INTERVAL AS BEFORE.INJECTIVITY AFTER SECOND STAGE WAS 5.3BPM/2300 PSI. FREEZE PROTECTED TUBING TO 2300' WITH 90 BBLS 60/40 METHANOL. **** LEFT WELL SHUT IN ***** 11/12/03 ***CONTINUED FROM 11/11/03 WSR*** SET 41/211 MCX, 1,526 BEAN. SERIAL # M-12 (RQ-LOCK W/ NOGO RING, X-EQ DEVICE.) RAN 4 1/2" CHECK SET, CAME BACK SHEARED. NO CLOSURE TEST ( ZERO SURFACE PRESSURE) NOTIFY PAD OP, FLUIDS PUMPED BBLS 300 Methonal / Water 131 NH4CL 60 7.5% HCL (titration = 7.8% iron <22 ppm) 60 9/1 HCUHF (titration = 9.1 % HCUO.9% HF, iron <22 ppm) 858 1 % KCL xslick 1409 TOTAL Page 1 TREE = 6"CrN W8..LI-EAD = FMC A CTUA TOR = OTIS KB. ELEV = 59.9' BF. ELEV = 21.57' KOP= 3800' Max Angle = 102 @ 10135' Datum MD = 9957' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, [) = 12.347" TOP OF 2-7/8" LNR, ID = 2.377" 7" lBG, 26#, L-80, .0383 bpf, ID = 6.276" 8973' Minimum ID = 2.377" @ 8885' TOP OF 2-7/8" LINER R-07 A SAFETVNOTES: WB.LANGLE> 700@ 9775' & > 90° @ 9909'. 4-1/2" TAILPIPE BACKED OUT OFPKR AND LANDED IN TOP OF 1" LNR. ITWAS CMT'DAND THe! DRL'DOUT BVCTD. 1 9-5/8" X 7" LNR HGR I 4-112"lBG, 12.75, L-80,.0152 bpf,ID=3.958" 19-5/8" CSG, 47#, L-80, ID = 8.681" I NA PffiFORA TION SUMMARY REF LOG: SÆRRY rvwD'GR ON 04/08/00 ANGLEATTOPÆRF: 63 @ 10750' t\bte: Refer to Produetion DB for historical perf data SIZE SFf INTERVAL Opn/Sqz DATE 2" 6 10750 - 10775 0 11/10/03 2" 6 11075-11125 0 11/05/01 2" 4 11160 - 11230 C 11/05/01 17" LNR, 29#, L-80, ID = 6.184" 10478' <8 7" 011S SSSVN, ID = 5.962" 5-112" BKRSCOOPENTRY GUDE ID= 3.63" 3-3/4" BKR DER..OY SL V, ID = 3.00" -1TOPOF BKR PBR ASSY 1 9-5/8" X 7" BKR SAB A<R, ID = 3.875" -14-1/2" OTIS X NIP, ID = 3.813" (BHND LNR) I -14-1/2" 011S XN NIP, ID = 3.80" (BHND LNR) I NA -14-1/2" WLEG (BI-f\JD LNR) I 7" MLLOur WINDOW 9583' - 9590' -i TOP OF BKR WHIPSTOCK I -12-7/8" BKR CIBP - 11/05/01 I 11249' 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.377" DATE REV BY COMI\tENTS DATE REV BY COMMENTS 01/18/81 ORIGINAL COMPLEfION 04109/00 CTD SIDEfRACK 03/14/01 SIS-SL T CONVERTED TO CANV AS 03/15/01 SIS-MD FINAL 12/31/01 CH/TP CORRECll0NS 11/10/03 KEY /lLP A DO ÆRF, aBP PRUDHOE BAY UNIT WELL: R-07A PffiMT t\b: 2000100 API t\b: 50-029-20523-01 SEe 32, T12N, R13E, 592' NSL & 753' BNL BP Exploration (Alas ka) ( ( ~CC--ð 1-0 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7lhStreet Suite # 700 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 : Joey Burton / Jeni Thompson BP Exploration (Alaska)) Inc. ProActive Diagnostic Services) Inc. Petrotechnical Data Center LR2-1 P. O. Box 1369 900 E. Benson Blvd. Stafford) TX 77497 Anchorage) AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 Res. Eva!. CH 1 1 1 R-07A 11-10-03 Mech. CH 1 Jf),-~-::¡- Caliper Survey Signed: ~C")\.I\.' ^'\.~,~&-..~fl'iY'.. Date~ Print Name: ~J'\r\J 2 0 2004 Alaska Oil & Gas Cons. Commisston Anchorage PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box 1 }b9 STAffol{d IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~tA~~Eít' FEB ~J)2 200~ ~~'b\\\~ STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon BI Suspend BI Operation Shutdown BI Perforate[Y--] varianceE] Annuar DisposalE~ AIter Casin~l BI Repair Well [~ Plu~ Perforations ~[] Stimulate[~] Time Extension[~ OtherE] Chan~e Approved Pro,ram E~ Pull Tubin~ BI Perforate New Pool E] Re-enter Suspended WellE] 2. operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development E] Expl°rat°ryE] 200-0100 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicE] Service[~ 50-029-20523-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 59.90 R-07A// 8. Property Designation: 10. Field/Pool(s): ADL-028282 Prudhoe Bay Field / Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):l 1281 [Total Depth TVD (ft):9097.42 IEffective Depth MD (ft): IEffective Depth TVD (ft): IPlugs (measured): ]Junk (measured):11140 ' 8845.08 11140 Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110 20" 106.5# J-55 38 - 148 38.0 - 148.0 2400 770 Surface 2652 13-3/8" 72# L-80 38 - 2690 38.0 - 2689.9 4930 2670 Production 9496 9-5/8" 47# L-80 38 - 9534 38.0 - 8525.7 6870 4760 Liner 2402 2-7/8" 6.16# L-80 8879 - 11281 8014.2 - 9097.4 13450 13890 Liner 546 7" 29# L-80 9044 - 9590 8142.9 - 8571.4 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: I Tubing Grade: Tubing MD (ft): 11075' - 11125' 8904.7' -. 8950.9' 7" 26# L-80 38' - 8990' Packers and SSSV Type: Packers and SSSV MD (ft): 7" Baker SAB Packer / 7" Liner Top Packer 8990' MD / 9044' MD / 4-1/2" MCX I-SSV 2047' MD 12. Attachments: Description Summary of Proposal E] 13. Well Class after proposed work: Detailed Operations Program ~' BOP Sketch BI ExploratoryE] DevelopmentE] Service~] · , ,,trill-. 14.CommencingEStimated Dateoperation:fOr '"<~"~'ii/200 15. We:Iii i~tuSv, u after proposed work: GasE] Pluggedr~ Abandoned[-'1 ('"-~:1~'~ WAGE] GINJF'~ WINJD-] WDSPLD-1 16. Verbal Approval: Commission Representative: Perpared by Garry Catron 564-4657 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Katrina Cooper Printed Name Katrina Cooper Title Petroleum Engineer Signature ~ _~~,' Phone 564-4212 Date 10/31/03 Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity B BOP TestD Mechancial Integrity TestB Location ClearanceB Subsequent Form Required: i O "- q O"~ "*'-" Approved by: COMMISIONER THE COMMISSION Date: , Form 10-403 Revised 2/2003 NOV 0 5 ORIGINAL SUBMIT IN DUPLICATE bp To' Gary McBride/John Smart GPB Well Operations Team Leaders September 25, 2003 From: Paul Barrel Wells Engineer Trina Cooper R Pad Engineer Subject: R-07A CIBP, Perf~ and Mud Acid PBLWPR007 Est. Cost: $115M Est. IOR: 400 Please recomplete R-07A as per the attached program. 1. O 2. S 3. C Pump SBG treatment. Pull SSSV. Drift as deep as possible. Clean 7" tubing with a scale blast nozzle, CIBP, shoot 25' TCP perfs, mud acid, step rate test. Current Status: Max Deviation: Perf Deviation: Min. ID: Last tag: Last Downhole Ops: Last Profile Mod.: Latest H2S value: Injecting water at 4500 bwpd at 750 WHIP ,'"" 102° at 10,135' MD :, 19© - 102° (Horizontal with "S" tail) 2.377" in 2-7/8" liner top at 8885' MD 9770' SLM (10/29/01) due to angle Ran ISSSV (12/12/01) Set CIBP at 11,140', Perf 11,075-11,125 (11/4-6/01) NA (Injector) -/' R-07A was drilled in March 2000. For the first phase of injection a large MI bulb followed by water was injected into the 22P sandsqn zone 2 below a confining shale and response was seen in R-12. For the second phase of injection a large MI bulb followed by water was injected into the 24P-27P sands in zone 2 and response was seen in R-04 and R-12. It is now time for the third phase o/f injection We will set a CIBP to shut off zone 2 injection and then add zone 4 perfs'to turn the ~vell into a zone 4 MIST well that will support N-15, M-33, M-24A, and M-12A. × If there are any questions contact information is below. Name Title Work Home Cell Paul Bartel Wells Group Engineer 564-5402 696-1682 240-8036 Trina Cooper R Pad Engineer 564-4212 279-2667 230-4212 Dan Babcock Lead Waterflood PE 564-5735 746-0274 250-1466 cc w att: Well File Slope Distribution R-07A Clean 7" Tubing, CIBP, Adperfs, and Acid Stim Primary Goal The primary goal is to clean the 7" tubing, isolate the current perfs with a CIBP, /'shoot 25' of new perfs in Zone 4 above the CIBP (using 2" Power Jet guns at 6 spf), then perform a mud acid stim on coil. A step rate test will also be done to determine the injection parameters including the fracture pressure. Prep Work 1. Perform a standard SBG treatment on the well. with this program) Note: Well bore volume is 353 bbls. (Separate SBG recipe was sent . RU SL. Pull the SSSV. Drift as deep as possible. Note: OD of 2-7/8" CIBP to be run is 2.18". Last slickline drift was 10/29/01 when they drifted with a 2.28" swage to 9770' SLM before being stopped due to angle. Note: Minimum ID of the well is 2.377" at the 2-7/8 liner top at 8885' MD. Coil Work 1. The well will be put on MI injection immediately after pumping acid. Ensure that the well is ready to be placed on MI before starting this part of the job. , RU CTU with a scale blast nozzle and clean the 7" tubing taking returns down an adjacent flowline as per DS recommendations. Use filtered slick 150 °F 1% KCI. Beware of the potential for H2S in the returns. , RIH with drift and memory GR/CCL. Perform a jet pass to PBTD at max pump rate taking returns to the formation. Perform tie-in pass from TD to 10,500' CTM stopping at 11,020' CTM to flag pipe. POH and tie-in the memory log. Note: This log run will serve as the tie-in log for the CIBP and perfs. Note: Reference Log: SLB GR/CCLFFemp run 11/05/01 Note: OD of the CIBP to be run is 2.18" and minimum ID is 2.377" in the 2-7/8" liner top at 8885' MD. 2of4 . , MU CIBP to set in 2-7/8" liner. RIH to flag and correct depth as needed. RIH to position plug then drop ball to set CIBP at 11,020' ELM _+10'. PT plug to 1000 psi. POOH. MU TCP perf guns. Tag CIBP for depth control. RIH to position guns and per'[ from 10,750 to 10,775' MD. (Separate Excel perf worksheet was sent with this program) Note: Perf with 2" Power Jet guns at 6 SPF. Mud Acid Stimulation: 6. Trap 1000 psi on the inner annulus. RIH with nozzle and tag CIBP for depth control. Pull above the perfs. . o Perform an injectivity test with a maximum WHP of 3000 psi. If the perfs are taking fluids then skip to step 8. If the perfs are too tight then pump 10 bbls of 7-1/2% HC1 followed by 10 bbls of 9:1 mud acid as an attempt to establish injectivity. It may be necessary to take returns in order to stage acid to the nozzle. Make multiple passes across the perfs and pump the following at maximum rate down the CT with a recommended maximum WHP of 2000 psi. Make one pass to the CIBP while pumping the overflush. Don't POOH until the entire overflush has been pumped behind pipe(*): 25 bbls 50 bbls 50 bbls 100 bbls 3% NH4C1 with 10% U-66 and 0.2% Fl03 7.5% HC1 9% - 1% HC1-HF 3% NH4C1 with 10% U-66 and 0.2% Fl03 overflush (behind pipe) * Go to 3000 psi during the first half of the HCl stage if necessary to establish injection. Once mud acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the treating ~to th._e pro~m_~.uth.?r~ .......... ..~ ~ ...... 3 of 4 Treatment Design: -125 bbls 3% NH4C1 water with 10% U-66 and 0.2% Fl03 2100 gal 7.5% HC1 0.5% A261 0.5% A201 20 ppt L58 0.2% Fl03 0.5% W54 0.5% W35 2100 gal 9/1 HC1/HF 0.5% A261 0.5% A201 20 ppt L58 0.2% Fl03 0.5% W54 0.5% W35 Please note the acid_ ..~._... titrations and i.......(on.ppm on the WSR. 9. POOH ~::Step Rate. TeSt:: . .. · · · · ...'. . ... 10. Pump down the tubing at maximum rate or a maximum WHP of 3000 psi. Maintain the rate for 15 minutes, im~.Oi.at~ely' shut down and record the ISIP. 11. Wait 15 minutes. 12. Perform a step rate test at "min rate", 0.5, 0.75, 1, 1.5, 2, 3, 4, 5, and "max rate" BPM if possible with 1% KCI. Hold the first rate for 10 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step. (The pressure does not have to be completely stable). 13. Wait 15 minutes and repeat step #12. 14. If there is a break point on the SRT then pump any remaining 1% KC1 at this rate, recording the data in the WSR_every 10 bbls. 15. Freeze protect.. Bleed down the IA. RDMO. Leave the well shut-in. 16. The pad engineer will review the data and coordinate with the PCC regarding injection targets. Note that R-07Ai wil__~. ........ !...!:nit. i~ut on MI. 4 of 4 TREE = 6" CIW SAFETY NOTES: WELL ANGLE · 70° (~ 9775' & R 07A ~-~Ti;-UAT~-~ ................ ~i'§' m P~ AND LA~ IN T~ ~ T' LN~IT WAS KB. EL~ = 59.9' CMT'DA~ TH~ ~L'D ~T BY CTD. M~ An~le = i 02 i0135; 'Datum WD; moo; SS II (~~ 8878, ~ ~1/2" BKR SC~P E~RY GUDE ID = 3.63" ~inimum ID = 2.377" ~ 8885' lOP OF 2-718" Ll~fiR I~-s~'' m~, 4~, c-o0, ~= ~.~" H ~~TIO~ S~ARY ~ I ~ ~ 05~' - ~5~' R~ kOG: S~R~ MWD/GR O~ ~/08/00 ~oto: ~for to Pr~uction DB for histor~al po~ data 2" 4 ~0- ~230 G ~ ~/05/0~ ~ R~ BY GOMMfi~TS DATE 04/0~/00 G~ SID~GK ~ ~: 20~0~00 0~4/0~ SB-SLI GO~V~R~DIOGA~VAS A~ ~: S0-02~2052~0~ 0~5/0~ SIS-~ Fl~k S~32, T~2~,R~3E 5O2'~k&753'~k ~, ,, SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11075 - 11125 O 11/05/01 2" 4 11160 - 11230 C 11/05/01 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/18/81 ORIGINAL COMPLETION 04/09/00 CTD SIDETRACK 03/14/01 SIS-SLT CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 12/31/01 CH/TP CORRECTIONS DATA SUBMITTAL COMPLIANCE REPORT 8/29/2002 Permit to Drill No. 2000100 Well Name/No. PRUDHOE BAY UNIT R-07A Operator BP EXPLORATION (ALASKA) 1NC AP1 No. 50-029-20523-01-00 MD 11281 TVD 9097 Completion Date 4/9/2000 Completion Status WAGIN Current Status WAGIN U1C Y REQUIRED INFORMATION Mud Log N_~o Samples N_~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments Well Cores/Samples Information: Name Start Interval Dataset Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~,~ Chips Received? ~ Analysis Received? ~ Comments: Daily History Received? ~ N Formation Tops Receuived? b/N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Fill Clean Out/Acid Pull tubing _ Alter casing _ Repair well _ Other _X FCC 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 60 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 592' FSL, 753' FWL, Sec. 32, T12N, R13E, UM (asp's 634406, 5977057) R-07Ai At top of productive interval 9. Permit number / approval number 3158' FNL, 265' FWL, Sec. 06, T11 N, R13E (asp's n/a) 200-010 At effective depth 10.: APl number 2177' FSL, 334' FWL, Sec. 05, T11 N, R13E, UM (asp's 634066, 5973356) 50-029-20523-01 At total depth 11. Field / Pool 2186' FSL, 334' FWL, Sec. 05, T11 N, R13E, UM (asp's 634065, 5973365) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11281 feet Plugs (measured) true vertical 9097 feet Effective depth: measured 11253 feet Junk (measured) TD Tag @ 11253' (09/08/2000) true vertical 9071 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" x 30" 72 c.f. concrete 148' 148' Surface 2651' 13-3/8" 3720 c.f. Permafrost II 2690' 2690' Intermediate 9498' 9-5/8" 1300 c.f. 'G', 130 c.f. PF 9534' 8526' Liner 539' 7" 420 c.f. Class 'G' 9044' - 9583' 8143' - 8566' Sidetrack Liner 2402' 2-7/8" 101 c.f. Class 'G' 8879' - 11281' ,JUL 2 7 2001 Perforation depth: measured Open Perfs 11160' - 11230' Alaska 0il & Gas C0'ns. C0mmissir true vertical Open Perfs 8984' - 9050' Anchorage Tubing (size, grade, and measured depth) 7" 26#, L-80 TBG @ 8995' MD. 4-1/2" Tubing Tail backed-out of PKR & landed in top of 7". 4-1/2" tailpipe cemented in 7" liner and then drilled out. Packers & SSSV (type & measured depth) 9-5/8" x 7" Baker SAB PKR @ 8995'. 7" Otis RQ SSSV Landing Nipple @ 2047' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service _ Water & Gas Injector. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/~,~~-)?,~,.,~'""~ Title: Technical Assistant Date July 25, 2001 DeWayne R. Schnorr~,~~ Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT~ R-O7Ai DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/02/2000 ACID: FLUSH TBG W/SEA-WTR& FRZ-PRT (PRE-ACID STIM) 09/02/2000 ACID: DRIFT (PRE-ACID STIM) 09/06/2000 ACID: ACID TREATMENT 09/08/2000 ACID: FCO AND ACID JOB 04/30/2001 ACID: PULL ISSSV, DRIFT & TAG (PRE CIBP) EVENT SUMMARY 09/02/00 TBG WAS FLUSHED AND FREEZE PROTECTED AND TAGGED 09/02/00 DRIFT 2.25 CENT TO 9845 WLM,. STOP DUE TO DEVIATION OF WELL. 09/06/00 MIRU. RIH W/SIDE 2.0" JETTING NOZZLE. START HEATED KCL WATER DOWN COIL AND WASH LINER FROM 11110 DOWN TO 11198. PERFORMED INJECTIVITY TEST. INJECTIVITY TEST RESULTS: 0.50 BPM CTP = 1630 PSI, WHP - 1730 PSI. (NOTE THAT THE WHP IS FROM MECH GAUGE BECAUSE THE ELECTRONIC GAUGE WAS NOT ENTIRELY IN SINC.). 1.00 BPM CTP - 2400 PSI, WHP = 2400. (YES, THERE WERE BREAK BACKS DURING INJECTION TEST). 1.50 BPM CTP - 3050 PSI, WHP - 1300 PSI. 1.75 BPM CTP - 3900 PSI, WHP- 1450 PSI. WASHED LINER WITH 160 BBLS OF 160 DEGREE F KCL WATER. FINAL INJECTION WS 1.0 BPM @ 1820 PSI WHP. JETTED 22 BBLS NH4CL WITH FINAL INJECTION 0.4 BPM AT 500 PSI WHP (NOTE THAT INJECTION RATE DROPPED SIGNIFICANTLY AT MAX PRESSURE WHILE DAD ACID FILLED THE COIL). JETTED 92 BBLS DAD ACID WITH FINAL INJECTION 1.5 BPM @ 1690 PSI WHP. JETTED 48 BBLS MUD ACID, FINAL INJECTION WAS 1.5 BPM @ 740 PSI WHP. WHILE JETTING, IT APPEARS THAT THE COIL GOT INTO THE FILL AND PUSHED SOME OF IT ABOVE AND STUCK THE COIL, CONTINUED WITH NH4CL OVER FLUSH WHILE TRYING TO GET FREE. ONCE OVER FLUSH WAS COMPLETED, TRIED DUMPING WHP TO NEARBY WELL. THERE WAS NOT MUCH DIFFERENTIAL AND SO THIS DID WORK. PUMPED UP BACKSIDE TO 1000 PSI WITH I BBL AND THEN DUMPED TO NEARBY WELL. THAT DID NOT WORK EITHER, BUT SHOWED POTENTIAL. APPEARS THAT THERE IS SOMETHING PLUGGING ABOVE NOZZLE AND PERFS. CONTINUED TO PUMP UP BACKSIDE TO 1500 PSI AND DUMPED. AFTER MULTIPLE TRIES, WAS ABLE TO BRING WELL HEAD PRESSURE UP TO 500+ PSI, WHICH MEANT THAT THE BACKSIDE GUNK WAS FINALLY PUSHED DOWN AND INTO THE PERFS. DUMPED PRESSURE ONE MORE TIME, AND PULLED FREE. PULLED LIKE CRAZY TO GET OUT OF LINER, ONCE OUT OF LINER, PERFORMED INJECTION TEST AND IT WAS 1.0 BPM @ 1730 PSI WHP WHICH EQUIVALENT TO INITIAL INJECTION TEST. CONFIRMED WITH TOWN TO LEAVE WELL SHUT-IN AND DIAGNOSE DATA AND PROPOSE NEW PROGRAM. Page I O9/O8/OO CLEAN OUT 7" TO 8840 FT W/6.25" UNDERREAMER. PUMP 12 BBL BIOZAN PILL AND CHASE TO SURFACE. MU 2.25" MILL AND CLEAN OUT 2-718" LINER TO PBTD OF 11253 FT. CHASE OUT 30 BBL BIOZAN PILL TO SURFACE. RIH FOR ACID JOB 04/30/01 PULL 4.5 ISSSV. SN= M002. DRIFT TBG W/3.6 CENT & SAMPLE BAILER TO 8849' WLMD ( TOP OF 2-7/8 LINER). POOH W/NO-SAMPLE. RIH W/2.25 CENT. & SAMPLE BAILER TO 9726' WLMD (STOP DUE TO DEVIATION). POOH, NO- SAMPLE. GIVE WELL BACK TO OPERATOR Fluids Pumped 1 PRESSURE TEST LUBRICATOR W/DIESEL (1 TEST). 3O5 SEAWATER 80 METHANOL 30 2% KCL WATER + FRICTION REDUCER 160 2% KCL WATER 22 NH4CL (10% U-66, 0.2% F75N) 92 DAD (7.5% HCL/10% XYLENE) 48 MUD ACID (9% HCL/1% HF) 738 TOTAL Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _X ClaP/ADD PERFS/AClDIZE Pu, tubing _ Alter casing _ Repair well _ Other_X claP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 60 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4687' FNL, 4526' FEL, Sec. 32, T12N, R13E, UM (asp's 634406, 5977057) R-07A At top of productive interval 9. Permit number / approval number 3158' FNL, 4631' FEL, Sec. 06, T11N, R13E, UM (asp's 629102, 5973213) 200-010 At effective depth 10. APl number.~_ 3138' FNL, 4953' FEL, Sec. 05, T11 N, R13E, UM (asp's 634058, 5973319) 50-029-20523-01 At total depth 11. Field / Pool~'~ C'.~ ~,~ 3093' FNL, 4945' FEL, Sec. 05, T11 N, R13E, UM (asp's 634065, 5973365) Prudhoe Bay Oil Pool 12. Present well condition summary ~'~,.,.'~',.~ ~ ~'~ Totaldepth: measured 11281 feet Plugs (measured) Clap set @ 11140' (11/05/200'~P~ true vertical 9097 feet Effective depth: measured 11140 feet Junk (measured) true vertical 8965 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" x 30" 72 c.f. concrete 148' 148' Surface 2651' 13-3/8" 3720 c.f. Permafrost II 2690' 2690' Intermediate 9498' 9-5/8" 1300 c.f. 'G', 130 c.f. PF 9534' 8526' Liner 539' 7" 420 c.f. Class 'G' 9044'- 9583' 8143'- 8566' Sidetrack Liner 2402' 2-7/8" 101 c.f. Class 'G' 8879' - 11281' 8014' - 9098' Perforation depth: measured Open Perfs 11075' - 11125', Open Perfs below ClaP 11160' - 11230' true vertical Open Perfs 8905' - 8951', Open Perfs below ClaP 8984' - 9050' Tubing (size, grade, and measured depth) 7", 26#, L-80 TaG @ 8995'. 4-1/2" Tubing Tail backed-out of PKR & landed in top of 7". 4-1/2" tailpipe cemented in 7" liner and then drilled out. Packers & SSSV (type & measured depth) 9-5/8" x 7" Baker SAR PKR @ 8995'. 7" Otis RQ SSSV Landing Nipple @ 2047'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/27/2001 5820 1541 Subsequent to operation 11/18/2001 4982 939 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas _ Suspended __ Service Water & Gas Iniector .. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .~~ ~'~C~.,~~ [') Title: R Pad Petroleum Engineer Date November 21, 2001 BryanV-' .McLellan~,~t Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 10/29/2001 11/02/2001 11/03/2001 11/04/2001 11/05/2001 11/06/2001 10/29/01 11/02/01 11/03/01 11/04/01 R-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ACID: DRIFT TUBING. SCHMOO B GONE: SCHMOO-BE-GONE SCHMOO B GONE: SCHMOO-B-GONE ACID: MEM LOG/CIBP/PERF/ACID ACID: MEM LOG/CIBP/PERF/ACID ACID: MEM TEMP/CIBP/PERF/ACID EVENT SUMMARY 2.28" DRIFT TO 9770' WLM. SCHMOO-B-GONE. PRETRIP INSPECTION. LOAD AND MIX FRESH WATER AND CHEMICAL AT THE FRESH WATER PLANT. THEIR HEATER IS BROKEN SO WE WILL HEAT THE FLIUD WHILE WE PUMP IT. TRAVEL TO R-PAD. PJSM WITH THE PAD OPERATOR, TANKER OPERATOR, PUMP OPERATOR, AND SPILL CHAMPION. RIG UP TO PUMP FROM THE SKID TO THE WELL. PRESSURE TEST AT 3500 PSI. PUMP 343 BBLS. OF SBG. AND FREEZE PROTECT THE SURFACE EQUIPMENT WITH 10 BBLS. OF MEOH. RIG DOWN AND GO LOAD FLUSH WHILE THE WELL SOAKS FOR 3 HOURS. RETURN ON 11-03-01 TO FINISH THE TREATMENT. FLUSH AND F.P. BEHIND SBG ON 11-02-01. LOADED FLUSH DURING SOAK PERIOD AND RETURND TO PUMP FLUSH. RIGGED BACK UP AND P.T. @3500 PSI. PUMPED 343 BBLS OF SEA WATER AT 160' F. LONG LINE FOR HOT CH20 SO WE LOADED COLD AND HEATED IT WHILE PUMPING. FREEZE PROTECT SURFACE EQUIPMENT WITH 5 BBLS. OF MEOH. AND LET IT SOAK FOR 3 HOURS. RELEASE TANKER. FREEZE PROTECT THE TUBING AND FLOWLINE WITH 155 BBLS. OF 50% MEOH. LEAVE THE WELL SHUT IN AND FLAG / TAG THE INLET AND WING VALVES. CALL THE OPERATOR AND WELL SUPORT. RDMO MIRU DS CTU #3. MU WIRELESS CCL SUPPORT ELECTRONICS/HARDWARE. 11/05/01 11/06/01 MU MEMORY LOGGING TOOLS INCLUDING WIRELESS CCL TOOL. LOG STATIC TEMP DOWN FROM 9400' TO PBTD @ 11230' CTMD. FLAG PIPE AT 11,050'. TEST WIRELESS CCL TOOL WHILE POOH. DROP 1/2" BALL TO SHEAR PINS IN FIRING HEAD - CTP UP TO 4500 PSI - NO SHEAR, CAN'T CIRC - POOH. RIH W/BAKER 2-7/8" CIBP - SET AT 11,140'. RIH WITH GUN #1 - 25' (SWS 2" PJ 2006 HMX, 6 SPF, 60 DEG PHASING, 6.5 GM, 0.23 EH, 19.00" PEN). PERFORATE 11,100' TO 11,125'. POOH WITH GUN #1, ALL SHOTS FIRED. RIH WITH GUN #2 - 25' (SWS 2" PJ 2006 HMX, 6 SPF, 60 DEG PHASING, 6.5 GM, 0.23 EH, 19.00" PEN). PERFORATE 11,075' TO 11,100'. POOH. ALL SHOTS FIRED. RIH W/2.-1/8" Page I R-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/06/01 (CONTINUED) JSN. PERFORM BREAKDOWN - ESTABLISH INJ AT 2 BPM, 2000 PSI - ESTIMATE ISlP AT 2500 PSI. PUMP 100 BBLS 7.5% HCL AND 50 BBLS 1% HF - SEE GOOD PRESS RESPONSE AT PERFS. PERFORM STEP RATE TESTS. RD DS CTU #3. PUT WELL ON INJECTION. *** JOB COMPLETE **** FLUIDS PUMPED BBLS PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (2 TESTS) 10 METHANOL WATER 170 50% METHANOL WATER 242 60/40 METHANOL WATER 286 FRESH WATER 343 SEAWATER 273 2% KCL WATER 57 SCHMOO-BE-GONE 100 7.5% HCL ACID 50 9%/1% HCL - HF 175 NH4CL 1706 TOTAL ADD PERFS 11/05 & 06/2001 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2" PJ 2006 HMX, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. 11075'-11125' Page 2 11/14/01 Schh herg r Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1631 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 4-40 I (~)~/~ PSP LEAK DETECTION LOG 11/06/01 1 1 . . D.S. 5-02 ) "-}.q---~, PSP LEAK DETECTION LOG 11/03/01 1 1 D.S. 5-05B 1~/~'.<.') PSP LEAK DETECTION LOG 11/04/01 1 1 D.S. 18-28 } o~ ~_O-?~ PSP LEAK DETECTION LOG 11/05/01 1 1 R-07A ~-~---O) O TEMPERATURE SURVEY LOG 11/05/01 1 1 NK-07A ~---~1~0~.~ PRODUCTION PROFILE-GLS 10/31/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV I 6 2001 Alaska 0ii & Gas Cons. Commi~ion Ancl'~rage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Receive~ ~~/ I - WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' May 25, 2000 R-07A, AK-MW-00014 R-07A: 2" x.-5-" MDGamma Ray Logs' 50,029,20523-01 2" x 5" TVD Gamma Ray Logs' 5.0-029-20523-01 1 Blueline 1 Rolled. Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND. RETURNI!NG A COPY OF ~ TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Gal~ 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 RECEIVED e~.~,.~,, 9tv~t~ Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company rll=tlll I..I~G ~;EFIVICE~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 0O ' RE: MWD Formation Evaluation Logs R-07A, May 25, 2000 1 LDWG formatted Disc with verification listing. APl#: 50-029-20523-01 o AK-MW-00014 PLEASE ACKNOWLEDGE RECEIPT BY 'SIGNING AND RETURNING A COPY OF THE TRANSMI14r~LL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Tan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED OateMAY 25 2000 Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-Technical Data Cemer, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 563'1 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company 4/17/00 Schh berger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121380 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints !D-13 ~;~ q~oO 20131 CNTD 000313 1 1 1 N-12 '"~:~-qb? ~ \ 20069 CNTD 000202 1 I 1 R-07A 20159 SCMT 000408 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 99519-661 Date Delivered: APR ?-$ 000 Alaska Oit & Gas Co~s. ComnUssion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie /"xx I~I:LL LO~ TRA:NsM/~AL Il- ProActive Diagnostic Services, Inc. To: State of Alaska A~ 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' Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petrotechnical Date Center MB 3~3 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUELINE PJ37Ai 4~7~30 Open Hole I I 1 Res. Eval. CH I I 1 Mech. CH · 'Caliper Survey R E C E V E D ~ ~ ""~,°~ '~~ APR 1 5 2000 Signed' Date' Alaska 011 & Gas Cons. Commission Print Name: Anchorage ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdsprudhoe~NA800.net Website: x~x~¥.memorylog, con] MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~~ DATE: April 2, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor Crisp,~ FROM: John ~ d.~ SUBJECT: Petroleum In§pector BOP Test Nordic 1 P_BU_B_Pad Well 07A April 2, 2000: I traveled to BP's PBU R Pad to witness the initial BOP test on Nordic / Dowell CTU Redrill of well 07A. Initial test of lower pipe rams was delayed due to leaking Swab, Master & Wing valves on the tree the BOP's were N/U on. After BP's tree service crew serviced the tree & grease locked the appropriate valves to be able to test BOP's the test went fairly well. The only failure witnessed was the Combination pipe & slip rams. We finished all tests possible before Comb. Pipe slip rams were repaired. I requested Nordic chart ram test & contact me after test was completed. The AOGCC test report is attached for reference. SUMMARY: I witnessed the initial BOP test on Nordic / Dowell Rig 1 sidetracking well R-07A in the PBU for BPX. Tested BOP's on Nordic / Dowell Rig 1, test time 6 hrs. one failure witnessed. ' Attachments: Nordic Rig 1 4-2-00jc cc; NON-CONFIDENTIAL BOP Nordic 1 4-2-00jc STATE OF ALASKA OIL AND GAS CONSERVATION COMM,,.,JION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nordic / Dowell Rig No. I PTD # BPX Rep.: PBU R-O7A Rig Rep.: 7" Set @ 10478' Location: Sec. X Weekly Other 200010 DATE: 4/2/00 Rig Ph.# 659-4434 John McMullen Zane Montague 32 T. 12N R. 13E Meridian UM DATA BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln, Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 1 350M000 F/P 1 350~000 P 1 350/2500 P 1 slip rams 1 350M000 P 1 350~000 P 1 350/4000 P 2 350M000 P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Meth Gas Detector Not Tested Not Tested H2S Gas Detector Not tested Not Tested CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan, Pressure P/F 13 350/4000 P 32 350/4000 P 1 Yes Functioned Functioned Yes ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3,000 2,000 minutes 37 2 minutes 9 X Remote: 3 Btls. @ 2050psi. Ave. Psig. sec. sec. X MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK Permit to drill: Yes Standing Order Posted Yes Well Sign Drl. Rig Hazard Sec. Yes OK Yes TEST RESULTS Number of Failures: 1 ,Test Time: 6.0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within 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 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 Distribution: orig-Well File c - Oper./Rig c - Database c ~ Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES x NO 24 HOUR NOTICE GIVEN YE~; x NO Waived By: Witnessed By: John Crisp Form Revised 2/20197 L.G. BOP Nordic 1 4-2-00jcl A/3100 R-07ai Tailpipe '"" Subject: R-07ai Tailpipe Date: Thu, 23 Mar 2000 01:24:05 -0000 From: "Stagg, Ted O (ORBIS)" <StaggTO~BP.com> To: "'Blair Wondzell'" <blair_wondzell~admin.state.ak.us> ego - Re: R-07ai Tubing Tailpipe Problem R-07ai has an approved Sundry Notice (300-031) and Permit to Drill (200-010) for a coil tubing sidetrack. A whipstock has been set in the 7" liner and all existing perfs have been squeezed to 1500 psi with cement. Window milling was in progress with service coil when it was determined that the 4 1/2" tubing tailpipe had backed off from the production packer and landed in the top of the 7" liner. The back off appears to have occurred at the mill out extension immediately below the production packer. Since this mill out extension and cross over are too large to enter the 7" liner, the approx. 100 ft long tailpipe assembly is currently hanging at the top of the 7" liner. A memory Gamma Ray / CCL log was run and provides confirmation of the location of the tailpipe. The planned solution for this problem is to stabilize the 4 1/2" tailpipe by cementing it in place. The cement will then be milled out of the tailpipe and the sidetracking of R-07ai will continue as planned. The original completion plan for R-07ai called for the 2 7/8" liner top to be placed within the 4 1/2" tailpipe. With the failure of the tailpipe, the 2 7/8" liner top will placed in the 7" tubing, above the production packer, at a depth of approx. 8880 ft. Please contact Ted Stagg at 564-4694 if further information needed. 1 of 1 3/23/00 10:06 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-010 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20523-01 4. Location of well at surface i' ~i~:~i~"Ti"i"i.!?~?''? '~ ~i 9. Unit or Lease Name 592' NSL, 753' EWL, SEC. 32, T12N, R13E, UM i i: ',"~: ! 'i~--/~~l Prudhoe Bay Unit At top of productive interval ! ~..~ ~ , 3158'SNL'265'EWL'SEC'06'T11N'R13E'UM [ %i~i~ii~L?i ' 10. WellNumber At total depth ~. R-07A 3092' SNL, 334' EWL, SEC. 05, T11N, R13E, UM ~-.~; ......... :.%?;'-~'2~ ~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 59.90' AMSL ADL 028282 12. Date Spudded 4,3,2000 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband' 4,6,2000 4,9,2000 I15' Water depth' if OffshOre N/A MSL II 16' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11281 9097 FTI 11250 9068 FTI [] Yes [] NoI (Nipple) 2047' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ROP, Memory DIL, Memory CNL, Slim Cement Mapping Tool 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 39' 2690' 17-1/2" 3720 cuft Permafrost II 9-5/8" 47# L-80 36' 9534' 12-1/4" 1300 cu ft Class 'G'~ 130 cu ft PF 7" 29# L-80 9044' 9583' 8-1/2" 420 cu ft Class 'G' 2-7/8" 6.16# L-80 8879' 11281' 3-3/4" 101 cu ft Class 'G' 24. Perforations open to Production (MD+'I'VD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 7", 26#, L-80 8974' 8995' MD TVD MD TVD 4-1/2. Tailpipe (Crnt'd in top of 7' Liner) 9044' - 9148' 11160' - 11230' 8984' - 9050' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2050' Freeze Protect with 40 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 19, 2000 Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL 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. Sul~q.j~,~7,e~,~c~p%.~~ ~,~ ~ } ~o~ ~,# ~ ~,) 0 RIG INA L Nasi,:a ()il & Gets Coi~!:~. Anchorage 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 recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Shublik 9620' 8595' Top of Sadlerochit / Zone 4B 9738' 8669' 23 10870' 8727' ~ '~ ............................ ~'~' ~' ...... 22C 10973' 8812' {.' ,-~ ~ ~ 6 200~ Zone 2A / 23N / 22N 11150' 8974' ~' ' O~~ & G~ CO~. COfi"i~'~Or~ ~1. List of A~aehments: Summa~ of ~ail~ ~rilling ~epo~s, 8u~e~s 32. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~~~ Title TechnicalAssistantlll Date ~-~.~ R-07A 200-010 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: R-07A Accept: 04/01/00 Field: Prudhoe Bay Spud: 04/03/00 AP I: 50-029-20523-01 Re lease: 04/09/00 Permit: 200-010 CTD Unit: Nordic #1 PRE-RIG WORK 02/15/00 RIH w/Baker whipstock for 7", 29# (No RA tag). Tied into SWS CBL 1/14/81, set whipstock top at 9580, 4 deg. left of high side. RIH and tagged whipstock at same; pooh. Lwsi. 02/20/00 After digging out equipment, performed BOP test. Rih with BP tapered squeeze nozzle and tagged whipstock tray, corrected -8 feet from 9591 ctmd to 9583. Performed injectivity test while waiting for cementers to line out cement. Pumped 5 bbls fw, 5 bbl neat gel cement, followed by 15 bbls with aggregate (note that we were unexpectedly shorted 5 bbls cement due to pump cavitation), 5 bbls neat gel cement, and 5 bbls fw spacer. Bullheaded cement with nozzle 20 feet above whipstock, and with 2 bbls behind pipe, open chokes and laid in cement 1:1 up to WCTOC holding 680 psi. Pulled to safety and hesitated squeezed for 2 hours while trying to work squeeze up to 1500. Broke back several times but was finally able to get bbl/bbl returns. Estimated 12 bbls cement behind pipe. Dropped ball and chased with biozan contaminate to whipstock tray at 9583. Observed cement top at 9532 (13 bbls cement behind pipe). Chased out of hole at 80% and ardently washing the jewelry. Freeze protected coil and well. Sdfn. 02/21/00 Opened up well and the squeezed held tight. RIH w/3.80" window mill and string reamer. Milled XN and then started window at 9583. Milled at 1 to 2 feet per hour. Initial WOB was 1600 and worked up to 3500. Milled down to 9588 with little or no problem. Pumped one flo pro sweep. At 9588, could not make footage, could not punch through, and could not get motor to stall. Picked up and had stalls in several unrelated places. PU and had to mill up XN again. RIH and painted flag and pooh freeze protecting coil. The mill was severely worn around the edges; about 4/1000" or more undergauge; very little work on mill face. String reamer was gauge and in good condition. Sdfn. O2/22/OO Cut 215' of coil, picked up new but similar bha and rih. Tagged up 9384' Motored thru easily. Tagged up 9579' got hung up. Got free. POH to troubleshoot cause of problems w/Slickline. Freeze protected wellbore. Mill and Strg. Reamer had no marks on them.. 02/23/00 RIH w/T.E.L, and 3.50 L.I.B., tools sat down at 9021' and 9024' WLM, able to get through, tag tbg tail at 9025' WLM, made several passes through tailpipe, tools sat down in the same place every time, continue in, sat down at 9454', tap down, tools fell, sat down at 9473', tap down, tools fell, sat down at 9550', tap down several times, OOH, L.I.B. inconclusive. RIH w/PDS GR, CCL, stop at 8800' WLM for I minute, log in at 40 FPM, sat down at 9026', able to work through, stop at 9200'. Log out at 40 FPM 9200 > 8800', good data. R-07A, Coil Tubing Drilling Page 2 Summary: Investigated tbg tail, T.E.L. and 3.50 L.I.B. Ran 3.5" LIB to 9550' WLM. Impression of part of a ring with cement. Ran PDS GR, CCL, good data. Returned well to Pad Ops. PDS CCL shows the tubing tail has fallen off the packer. The crossover is still on the tubing tail that fell down hole but it is not conclusive if the mill out extension came off and fell downhole also. The tailpipe that came off the packer fell to top of the 7" liner where the x-over and maybe the millout extension hung up on the liner top. 03/29/00 RU DS CTU #2. RIH and tag whipstock. Correct depth to 9583' (pinch point). Circulate 250 bbls of seawater to cool down. Pump 26 bbls. of 13.8 ppg Class 'G' cement wi 8% bentonite and 2.5 ppb fiber. Lay cement from whipstock through tailpipe. Applied 1000 psig squeeze pressure, held jug tight - no cement to formation. Contaminated cement, using Biozan, to a depth of 9075' or approximately 30' into the top of the tailpipe. Jetted while POH chasing returns to surface. Freeze protected the tubing to 2000' with methanol. RD DS CTU #2. COIL TUBING DRILLING 04/02/00 1 Move rig from F-Pad to R-07i. Accept rig 22:00 hrs 4-1-00. NU BOPE. Service tree valves. Pressure test BOPE (John Crisp wi AOGCC witness). Repair leaking combi's. O4/03/0O 2 96O5' Finish BOP test. Install new packoff, pump pig. MU cement milling BHA. RIH. Mill cement from 9066' (inside backed-off tailpipe) to whipstock. POOH. MU window milling BHA (used HCC DP0261 and string reamer). RIH and mill window 9583' - 9589' corrected depth. Drill formation to 9605'. Dress window. 04/04/00 3 10094' Finish dressing window. Dry tag clean. Displace well to FIo-Pro mud. POOH. LD milling BHA. MU drilling BHA (1.5 deg short radius motor; M-09 bit). RIH. Tied-in with GR to BHCS/GR log [-24 ft CTD]. Drilled build section from 9605 - 9705 ft. Short trip to window. Drilled build section from 9705 - 9855 ft. Short trip to window. Drilled build section from 9855 - 10015 ft. Landed well at 9905 ft at 8646 ft TVDSS. Short trip to window. Hole in good condition. Drilled inverted section from 10015 - 10090 ft. POOH for less bend motor. Tied-in with BHCS/GR at 9391 ft. [ +4 ft CTD]. Flagged CT. POOH. 04/05/00 4 10899' POOH with BHA #3. M/U MWD BHA #4 with 1.4 deg motor and DS49 Bit #2. RIH with BHA #4. Correct depth at flag. RIH to TD and drill Inverted hole from 10,094 - 10,290 ft. Short trip to window. Hole in good condition. RIH and drill inverted hole from 10,290 - 10,440 ft. Full returns past second fault. Short trip to window. Hole in good condition. RIH, orient for 120R and drill inverted hole from 10,440-10,470'. Orient for 160R and drill from 10,470 - 10,600 ft. Swap to new FIoPro, 600 bbls. Apex of well at 10,580 ft at 8562.5' TVDSS. Short trip to window. Tied-in with BHCS/GR, Added 7 ft to CTD. Drilled slant hole from 10,600 - 10,750 ft. Short trip to window. Hole in good condition. Drilled from 10,750 - 10,899 ft. Full returns. Top of Zone 3 seen at 10,880 ft. R-07A, Coil Tubing Drilling Page 3 , ?:,q¥ 1 6 200e', 04/06/00 5 11132' Anctmra~'~ Drilled Z3 to 10900'. Short trip to window - hole condition good. Drill ahead with multiple stalls and ROP 10-20 fph. Saw slight ROP improvement below 10960' which may be near base Z3. Drilled to 10969 ft. Slow ROP. Pull for new bit. Flagged CT at 8700 ft EOP. POOH. Safety Drill at surface. L/O BHA #4. Cut off 300 ft of CT for fatigue life maintenance. M/U MWD BHA #5 and RIH. Shallow test Sperry tools. RIH to TD. Orient 'FF. Drilled from 10969 - 11132 ft. Short trip to window. 04/07/00 6 11281' Short trip to window. Got bit stuck at 10555' - poss fault #3. Work free OK. Cont POH - tight spots 10235-10170'. Log shows shale interval. POH to window. RIH. Work tight spots 10150-10250' - OK. Cont RIH. Work previous bad spot at 10555'. RIH and tag bottom. Having trouble getting started drilling - frequent stalls & poor weight transfer. Drilling improved below 11145' - ROP 60-90 fph. TD well at 11263' MD, 9020' TVDSS. POH above window for tie in and depth correction. Correct to original Sonic GR (+17'CTD). RIH to bottom - no problems. Corrected Well TD - 11278' MD. 9034.7' TVDSS. POH for logs. Make MAD pass 10975-10950'. Flag CT at 8900' EOP. POH to run memory induction and neutron logs in tandem. L/O BHA #5. Safety Meeting. M/U memory logging BHA #6. RIH with DIL / GR and CNL / GR memory logging tools. Correct CTD depth to flag at 8900'. Log down from 9230 ft to TD at 30 FPM. Tagged TD at 11,276 ft. Log up to 9230 ft. POOH. Safety Meeting. Lay out SWS and PDS logging tools. P/U Baker fishing tools. Safety Meeting. M/U Baker fishing BHA #7 to fish 7" SSSV insert. RIH with Baker fishing BHA. Memory logs obtained good data. Corrected TD from logs, correlated to BHCS/GR log is 11,281 ft BKB. 04/08/00 7 11281' RIH with GS spear, jars, 2 DC, accel. Tag up at 2038' and set down 2 klbs to latch fish. Jar up at 15-20 klbs over up weight. Jarred fish free after 27 hits. POH. LD fish and spear. LD fishing assembly. RU for liner. PJSM prior to running liner. DS, Nordic, BPX personnel present. Run 2 7/8" STL liner. Perform well control drill, stabbing safety valve into liner. Fill pipe at 45 jts in. Cont running liner - 79 its total. MU CTLRT and deployment sleeve in string. MU Baker coil conn& pull test 30k press test 4000 psi. Pump dart thru CT to verify volume - 56.6 bbl act vs 58.4 bbl calc. RIH with 2 7/8" STL liner on CT. Correct depth at flag. RIH and tag TD at 11271 ft CTD. Reciprocate twice. Liner at TD at 11,281 ft BKB. Displace 5/8" steel ball and disconnect from liner. Displace well to 2 % KCL water at 2.9 BPM. Circulate extra water to clean 7" wellbore better. R/U DS cementing equipment. Safety Meeting. Batch cement. Pressure test lines. Stage 18 bbls, 15.8 PPG, "G" cement with Latex. Insert dart and displace with rig pumps. Shear liner wiper plug and bump plug. Sting out and circulate at tip of liner. Full returns. POOH. Lay out Baker CTLRT. RIH with nozzle on CSH workstring. RIH with CT. Stop and 8800 ft and wait on cement. 04/09/00 8 11281' Wait on cement - UCA sample at 1100 psi. RIH to 7000' EOP and correct depth (-24'). Tag latch collar and correct depth to 11249'. Replace 2" Io torq valve on reel manifold prior to pumping lithium hypochlorite. Test valve and high pressure piping to 4500 psi - OK. Hold pre-job safety meeting with all personnel involved in pumping bleach pill to discuss hazards, procedures and proper PPE. Pump 22 bbl bleach into CT direct from vac truck. Displace bleach to nozzle and lay in 2 7/8" liner at 1:1 while pulling at 80 fpm. POH with C'F. Stand back injector. POH with CSH workstring. LD 16 stands. RUE line. Hold PJSM. RIH with SCMT to max depth of 9848' WLM. Log up to 8870' - cement quality in OH section good and areas of good cement in liner lap. POH with SCMT & RD Schlumberger. Pressure test wellbore to 2200 psi for 30 min. 75 psi pressure drop - acceptable test. Slip and cut drilling line. Safety R-07A, Coil Tubing Drilling Page 4 Meeting. M/U SWS 2", Power Jet perforating guns. RIH with 40 Stds of CSH workstring. RIH with CT. Tag PBTD of 11,249 ft and correct CTD. Safety Meeting. Pump 10 BBL bleach pill and 3 BBL KCL water. Insert 5/8" steel ball and displace. Position bottom perforating charge at 11,230 ft BKB. Ball on seat at 56 BBLS. Firing head shifted at 2900 psi. POOH with guns. Lay out CSH workstring in singles. Safety Meeting. Lay out Perforating guns. All shots fired. PERFORATED INTERVAL: 11,160 - 11,230 FT BKB. M/U nozzle. 04/10/00 9 11281' RIH with nozzle and freeze protect tubing to 2050' with MEOH at 2:1 (last 200' at 1:1). Blow down CT with nitrogen prior to reel swap. Clean pits. Spool CT back on to reel and clamp end. ND BOP stack. Suck out green tank. Back rig off well & install tree cap. Rig released from R-07A at 14:30 hrs on 04/09/00. Total time on well was 7 days 16-1/2 hours. Well is freeze protected to 2050 ft. Changed out reels on R pad. Derrick down rig move to H-36A. North Slope Alaska Alaska State Plane 4 PBU_ WOA R Pad R-O7A Surveyed: 6 April, 2000 SURVEY REPORT 14 April, 2000 Your Ref: API-500292052301 Surface Coordinates: 5977057.07 N, 634405.15 E (70° 20' 42.9271" N, Kelly Bushing: 59.90ft above Mean Sea Level 148° 54' 32.4544" W) L-;,qy 1 6 200¢ DRILLINI~ SERVIEEB SurveyRef:svy9763 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for R-O7A Your Ref: API-500292052301 Surveyed: 6 April, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (it) 9500.00 34.582 212.713 8437.79 8497.69 9580.00 35.890 216.437 8503.14 8563.04 9611.48 40,160 212.557 8527.93 8587.83 9642.98 45.000 208.667 8551.12 8611.02 9676.10 50.100 204.587 8573.47 8633.37 9706.48 55.550 200.017 8591.83 8651.73 9740.38 61.700 197.027 8609.48 8669.38 9769.73 68.200 196.157 8621.90 8681.80 9805.73 75.230 198.257 8633.18 8693.08 9839.73 80.510 190.877 8640.34 8700.24 9872.73 85.600 187,537 8644.33 8704.23 9908.95 90.530 180.337 8645.55 8705.45 9940.48 92.810 176,287 8644.63 8704.53 9970.50 94.900 169.497 8642.61 8702.51 10003.70 95.890 162.927 8639.49 8699.39 10040.13 95.620 153,437 8635.82 8695.72 10072.82 96.300 143.597 8632.42 8692.32 10103.70 99.930 139.547 8628.06 8687.96 10135.22 102.130 136.387 8622.03 8681.93 10165.37 101.160 133.047 8615.94 8675.84 10194.17 100.900 128.657 8610.43 8670.33 10227.47 100.720 124.787 8604.18 8664.08 10256.82 99.580 121.797 8599.01 8658.91 10285.17 99.760 117.577 8594.24 8654.14 10313.57 99.880 112.697 8589.40 8649.30 Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100ft) 2960.47 S 1137.39W 5974076.68 N 633321.03 E 2998.44 S 1163.59W 5974038.24 N 633295.51 E 3014.43 S 1174.54W 5974022.06 N 633284.85 E 3032.78 S 1185.36W 5974003.52 N 633274.37 E 3054.63 S 1196.27W 5973981.49 N 633263.85 E 3077.02 S 1205.42W 5973958.93 N 633255.10 E 3104.45 S 1214.58W 5973931.34 N 633246.43 E 3129.92 S 1222.16W 5973905.74 N 633239.31 E 3162.55 S 1232.28W 5973872.94 N 633229.78 E 3194.69 S 1240.61W 5973840.65 N 633222.02 E 3227.01 S 1245.84W 5973808.24 N 633217.37 E 3263.09 S 1248.32W 5973772.12 N 633215.54 E 3294.58 S 1247,40W 5973740.65 N 633217.03 E 3324.29 S 1243.70W 5973711.02 N 633221.26 E 3356.37 S 1235.82W 5973679.08 N 633229.71 E 3389.98 S 1222.37W 5973645.72 N 633243.77 E 3417.67 S 1205.41W 5973618.33 N 633261.22 E 3441.61S 1186.42W 5973594.74 N 633280.63 E 3464.59 S 1165.71W 5973572.13 N 633301.75 E 3485.36 S 1144.73W 5973551.74 N 633323.10 E 3503.85 S 1123.36W 5973533.64 N 633344.80 E 3523.40 S 1097.14W 5973514.56 N 633371.36 E 3539.26 S 1073.00W 5973499.14 N 633395.79 E 3553.10 S 1048.72W 5973485.74 N 633420.31 E 3564.98 S 1023.40W 5973474.31 N 633445.84 E 3.143 15.539 17.484 17.875 21.568 19.639 22.308 20.297 26.289 18.406 24.078 14.735 23.615 19.926 25.929 30.010 17.513 12.064 11.317 14.989 11.428 10.754 14.687 16.936 Alaska State Plane 4 PBU_WOA R Pad Vertical Section (ft) Comment 1239.37 1246.91 1250.15 1255.12 1262.45 1271.44 1283.91 1296.16 1311.55 1327.90 1346.60 1369.88 1392.44 1415.74 1443.69 1476.73 1508.16 1538,46 1569.32 1598,84 1627.06 1659.49 1687.87 1714.95 1741.42 Tie-on Survey Window Point MWD Magnetic Continued... 14 April, 2000 - 8:57 - 2 - DrillQuest 1.05,05 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for R-O7A Your Ref: API-500292052301 Surveyed: 6 April, 2000 Vertical Depth (ft) 10342.95 98.960 109.137 8584.59 8644.49 10375.67 98.350 103.337 8579.66 8639,56 10406.67 98.520 98.947 8575.11 8635,01 10436.57 98.260 94.727 8570.75 8630,65 10465.57 96.590 98.597 8567.00 8626.90 10500.37 92.460 100.527 8564.25 8624.15 10534.67 91.230 104.217 8563.15 8623.05 10562.97 91.930 107.737 8562.37 8622.27 10594.75 88.860 109.847 8562.15 8622.05 10627.75 84.550 110.727 8564.04 8623.94 10661.10 79.540 111.077 8568.66 8628.56 10693.10 74.180 112.657 8575.93 8635.83 10722,80 69.520 113,187 8585.18 8645.08 10756,25 63.110 114.767 8598.61 8658.51 10789,75 57.390 115,297 8615.23 8675.13 10819.35 52.290 115.467 8632.27 8692.17 10853.47 45.730 116.477 8654.64 8714.54 10883.80 40.960 117.047 8676.69 8736.59 10914.30 35.150 117.947 8700.69 8760.59 10945.30 29.440 117.757 8726.89 8786.79 10986.10 25.050 96.657 8763.24 8823.14 11022.20 23.730 83.827 8796.14 8856.04 11058.10 24.080 73.277 8828.97 8888.87 11087.50 22.500 57.457 8856.00 8915.90 11123.20 22.240 44.807 8889.03 8948.93 Local Coordinates Northings Eastings (f~) (ft) 3575.32 S 996.33W 3584.36 S 965.28W 3590.29 S 935.21W 3593.81S 905.84W 3597.14 S 877.29W 3602.91S 843.09W 3610.25 S 809.61W 3618.04 S 782.42W 3628.27 S 752.34W 3639.69 S 721.44W 3651.47 S 690.60W 3663.07 S 661.68W 3674.06 S 635.70W 3686.49 S 607.72W 3698.79 S 581.38W 3709.15 S 559.52W 3720.42 S 536.37W 3729.78 S 517.79W 3738.45 S 501.12W 3746.19 S 486.48W 3751.88 S 468.98W 3751.98 S 454.15W 3749.09 S 439.95W 3744.34 S 429.45W 3735.87 S 418.93W Alaska State Plane 4 PBU_WOA R Pad Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/100ft) (ft) 5973464.46 N 633473.09 E 12,357 1768.07 5973455.97 N 633504.29 E 17.623 1796.67 5973450.59 N 633534.47 E 14.019 1822.42 5973447.60 N 633563.89 E 13:990 1845.98 5973444.77 N 633592.50 E 14.431 1868.84 5973439.62 N 633626.80 E 13.092 1897.43 5973432.88 N 633660.41E 11.334 1926.61 5973425.59 N 633687.74 E 12.677 1951.58 5973415.89 N 633717.99 E 11.721 1980.32 5973405.03 N 633749.09 E 13.329 2010.47 5973393.80 N 633780.14 E 15.058 2040.84 5973382.73 N 633809.25 E 17.426 2069.69 5973372.21 N 633835.43 E 15.782 2096.01 5973360.28 N 633863.63 E 19.644 2124.77 5973348.45 N 633890.19 E 17.130 2152.25 5973338.48 N 633912.23 E 17.236 2175.18 5973327,63 N 633935.57 E 19.355 2199.65 5973318.60 N 633954.32 E 15.780 2219.52 5973310.23 N 633971.15 E 19.135 2237.53 5973302.76 N 633985.92 E 18.422 2253.44 5973297.39 N 634003.52 E 25.844 2269.97 5973297.55 N 634018.35 E 15.095 2280.71 5973300.69 N 634032.50 E 11.934 2288.91 5973305.63 N 634042.91 E 21.877 2293.16 5973314.29 N 634053.28 E 13.482 2294.84 Comment Continued... 14 April, 2000 - 8:57 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for R-O7A Your Ref: API-500292052301 Surveyed: 6 April, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 11154.05 20.130 31.267 8917.82 8977.72 3727.18 S 412.05W 11183.92 19.640 17.907 8945.92 9005.82 3718.00 S 407.84W 11212.45 19.900 7.697 8972.78 9032.68 3708.63 S 405.72W 11238.17 20.040 355.587 8996.96 9056.86 3699.89 S 405.47W 11278.00 20.040 355.587 9034.38 9094.28 3686.28 S 406.52W 5973323.10 N 634060.00 E 5973332.35 N 634064.04 E 5973341.76 N 634066.00 E 5973350.50 N 634066.09 E 5973364.09 N 634064.80 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.051° (02-Apr-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 134.020° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11278.00ft., The Bottom Hole Displacement is 3708.63ft., in the Direction of 186.293° (True). Dogleg Rate (°/lOOff) 17.226 15.270 12.125. 16.063 0.000 Alaska State Plane 4 PBU_WOA R Pad Vertical Section (ft) Comment 2293.75 2290.40 2285.41 2279.52 2269.31 Projected Survey Continued... 14 April, 2000 - 8:57 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for R-O7A Your Ref: API-500292052301 Surveyed: 6 April, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA R Pad Comments Measured Depth (ft) 9500.00 9580.00 11278.00 Station Coordinates TVD Northings Eastings (tt) (ft) (ft) 8497.69 2960.47 S 1137.39 W 8563.04 2998.44 S 1163.59 W 9094.28 3686.28 S 406.52 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 9580.00 8563.04 To Measured Vertical Depth Depth (ft) (ft) 9580.00 8563.04 11278.00 9094.28 Survey Tool Description AK-1 BP_HG MWD Magnetic 14 April, 2000 - 8:57 - 5 - DrillQuest 1.05.05 ALASi~A OIL AND GAS CONSERVATION COPlMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Pxe~ Prudhoe Bay Unit R-07A BP Exploration (Alaska) Inc. Permit No: 200-010 Sur. Loc. 592'NSL, 753'EWL, Sec. 32, T12N, R13E, UM Btmhole Loc. 3076'SNL, 293'EWL, Sec. 05, T11N, RI3E, UM Dear Mr. Stagg: 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 law 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 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THE__~/OMMISSION DATED this ~ C~ ~'~ day of February, 2000 dlf/Enclosurcs cc: Dcpanmcnt of Fish & Gmnc. Habitat Section xv/o encl. Department of Environmental Conservation vv/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [] Development E~ Exploratory [] Stratigraphic [~ Service 4. Location of well at surface 592' NSL, 753' EWL, SEC. 32, T12N, R13E, UM At top of productive interval 2401' SNL, 423' WEL, SEC. 06, T11 N, R13E, UM At effective depth 2832' SNL, 729' WEL, SEC. 06, T11N, R13E, UM At total depth 2893' SNL, 770' WEL, SEC. 06, T11 N, R13E, UM . Datum Elevation (DF or KB) KBE = 59.90' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-07 9. Permit Number 180-125 10. APl Number 50- 029-20523 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10490 feet true vertical 9246 feet Effective depth: measured 10382 feet true vertical 9168 feet Casing Length Size Structural Conductor 110' 20" x 30" Surface 2651' 13-3/8" Intermediate 9498' 9-5/8" Production Liner 1434' 7" Plugs (measured) Junk (measured) Fill at 10382' MD (10/89) Cemented MD TVD 8 cy yds Concrete 110' 110' 3720 cuft Permafrost II 2690' 2690' 1300 cuft Class 'G', 130 cuft PF 9534' 8523' 420 cu ft Class 'G' 9044' - 10478' 8140' - 9238' Perforation depth: measured true vertical 9720'- 10270' (Nine Intervals) 8673'- 9086' (Nine Intervals) Tubing (size, grade, and measured depth) 7", 26#, L-80 to 8974' with 4-1/2" tailpipe to 9099' Packers and SSSV (type and measured depth) RECEIVED ~,laska 0il & Gas Ooi~s. 60m~issio~ Anchorage 7" Baker Inflatable 'Choke' packer at 9981'; 9-5/8" Baker 'SAB' packer at 8995'; 7" Otis 'RQ' SSSV Landing Nipple at 2047' 13. Attachments [~ Description summary of proposal E~ Detailed operations program [] BOP sketch 14. Estimated date for commencing operation February 21, 2000 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Date approved Ted Stagg, 564-4694 15. Status of well classifications as: [] Oil [~ Gas [] Suspended Service Water Injection Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fo~ and correct to the best of my knowledge Signed ~~ Ted Stagg Title CT Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Date Approved by order of the Commission Commissioner Date Submit In Triplicate ~ STATE OF ALASKA ALASI~ .)ILAND GAS CONSERVATION CCI ~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil .~..Re-Entry [] DeepenI ....... [] 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. KBE = 59.90' AMSL 3. Address '6. Property Designation ~ Prudhoe Bay Field / Prudhoe P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028282 ~i~"~Zx~ 2..7,~.ay Pool 4. Location of well at surface 7. Unit or Property Name ¢~--11. Type Bond (See 20 AAC 25.025) 592' NSL, 753' EWL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2401' SNL, 423' WEL, SEC. 06, T11N, R13E, UM 9. R-07A At total depth , Approximate spud date Amount $200,000.00 3076' SNL, 293' EWL, SEC. 05, T11N, R13E, UM 02/23/00 12. Distance to nearest property line 113. Distance to neare'S'i' well i'"4. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028279, 3076' MDI .. No Close Approach 2560 11313' MD / 9032' TVDss 16. To be completed for ~ieviated wells 1'~'i Anticipated press'are {see 20 AAC 25.035 (e) (2)) Kick Off Depth 9590' MD Maximum Hole Angle 102° Maximum surface 2263 psig, Attotal depth (TVD) 8800' / 3319 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity. of Cement ........ ' Hol~' Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2263' 9050' 8084' 11313' 9032' 109 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 104909246 feetfeet Plugs(measured) ORIGINAL Effective depth: measured 10382 feet Junk (measured) Fill at 10382' MD (10/89) true vertical 9168 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cy yds Concrete 110' 110' Surface 2651' 13-3/8" 3720 cuft Permafrost II 2690' 2690' Intermediate 9498' 9-5/8" 1300 cuft Class 'G', 130 cuft PF 9534' 8523' Production Liner 1434' 7" 420 cu ft Class 'G'R EC E ~ V ~' - 10478' 8140' - 9238' Perforation depth: measured 9720'- 10270' (Nine Intervals) FEB 02 2000 true vertical 8673' - 9086' (Nine Intervals) A~aS~l, 0il & Gas Cons. Commission ......... Anchorage ........ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 !21. I hereby certify that the fore~oj~g~ is true and correct to the best of my knowledge Signed Ted Stagg ~/~.~ Title CT Drilling Engineer Date Commission Use Only Permit Nu~~;~ I APl Number Approval Date I See cover letter ' /(~ 50-029-20523-01 C-~ -"/~) ~) 0 for other requirements Conditions of Approval: Samples Required [] Yes .~['ltlo Mud Log Required [] Yes J~No Hydrogen Sulfide Measures J~Yes []No Directional Survey Required ,J~es [] No Required Working Pressure fof BOPE I-'I2K; I-'I3K; ~i~K; [-15K; 1-110K; D15K Other: by order of Approved By ORIGINAL SIGNED'BY Commissioner the commission Dat~.~ Form 10-401 Rev. 12-01-85 Robert N. (;hristenson Submit In Triplicate BPX R-O7ai Sidetrack Summary of Operations: N-08 is being sidetracked to improve injection conformance. Zone 4B is the targeted injection interval with initial MI injection into Zone 2. This sidetrack will be conducted in two phases. Phase 1: Set Whipstock, squeeze perfs, Mill Window: Planned for week of Feb. 21, 2000. · A Mechanical Integrity Test was successfully performed On 1/30/00. · A new gyro survey was run on 1/28/00. · The whipstock drift was run on 1/22/00. · A Kinley caliper was run on 4/30/99. · E-Line will be used to set the mechanical whipstock at 9,580'. · Service coil will cement squeeze existing perfs & mill the window. Phase 2: Drill & Complete sidetrack: Planned for Feb. 28, 2000. Directional drilling coiled tubing equipment will be rigged up to drill and complete the directional hole as per attached plan to planned TD of 11,313' MD (9,032' TVDss). Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,050' MD and cemented with approx. 19.5 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Open hole will be logged with Memory Induction log. · A Cement Evaluation Log is planned for the upper portion of the 2 7/8" liner. r.E 02 2000 Alaska Oil & Gas Cons. Commissio~ Anchorage Hazards Three small faults will be crossed with this sidetrack but all faults are small and the risk of lost circulation is considered Iow to moderate. Reservoir Pressure Res. pressure is 3319 @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2263 psi. R-07 Vertical Section Path Distance (Feet) 0 500 1,ooo 1,500 I I Angle @ K.©.= 37 deg MD:9590 2,000 2,500 3,000 ] ] I =. ........... 8,548 102 deg. · "8;655 ................ J Zone 3 J Zone 2 Tot Drld:1723 ft 11313TD Marker Depths ~ri~l Wellbore TSGR I 8,4941ft TVD TSHU TSAD I 8,653~ 8,531 Jrt TVD 8,609Jft TVD 8,653tft TVD JKick Off J 8,509 ft TVD 9,590 ft MD IDeprtr @KO 3,241 ft J MD KO Pt 9,590J MD New Hole 1723J I Total MD M 11,31 3J TVD TD 9,032J DL$ de~l/100 Tool Face Len~lth Curve 1 6 - 15 Curve 2 22 -30 100 Curve 3 22 -30 135 'Curve 4 14 -50 189 Curve 5 14 -90 444 Curve 6 14 - 150 204 Curve 7 16 - 180 599 1,723 Drawn: 2/1/2000 11:02 Plan Name: Case 107 -2,000 - 1,500 R-07 I -1,000 -500 X distance from Sfc Loc 500 0 1,[ -500 -1,000 -1,500 -2,000 -2,500 -3,000 -3,500 -4,000 -4,500 IWellName R-07 J CLOSURE Distance 3,695 ft Az 186 de~l NEW HOLE E/W (X) N/S (Y) Kick Off - 1,128 -3,022 TD -380 -3,676 State Plane 634,025 5,973,381 Surface Loc 634,405 5,977,057 DLS deq/100 Tool Face Len~lth Curve 1 6 - 15 ~2 Curve 2 22 -30 100 Curve 3 22 -30 135 Curve 4 14' -50 189 Curve 5 14 -90 444 Curve 6 14 - 150 204 Curve 7 16 - 180 599 1,723 Drawn: 2/1/2000 11:02 Plan Name: Case 107 TREE: 6" CIW 'WELLHEAD: FMC 41' ACTUATOR: OTIS 13-3/8", 72#/ft, I 2690' L-80, BTRS R-07a Proposed Completion KB. ELEV = 59.90' BF. ELEV = 21.57' FOC-- SSSV LANDING NIPPLE OTIS RQ )(5.962" ID) I 2047' ] KOP: 3500' MAX ANGLE: 44° @ 10,300' 7", 26#/ft, L-80, IJ4S TUBING (IPC) TUBING ID: 6.276" CAPACITY: .0382 BBL/FT TOP OF 7" LINER 9-5/8", 47#/ft, 1 9534'1 L-80, BTRS ITop of Whipstock approx. Cement downsqueezed past whipstock PERFORATION SUMMARY REF LOG: SWS - BHCS - 1-8-81 SIZE SPF INTERVAL OFEN/SQZ'D 3 3/8" 4 9720- 9776' OPEN/10-2-89 3 1/8" 4 9785- 9804' SQZD/8-29-89 3 3/8" 4 9804- 9845' OPEN/10-2-89 3 3/8" 4 9849. 9866' " 3 3/8" 4 9874 - 9890' " " 3 3/8" 1 9910- 9970' OPEN/9-9-89 3 1/8" 4 9990 - 10,020' SQZD/8-29-89 3 3/8" 2 10,030- 10,120' OPEN/9-9-89 3 3/8" 2 10,160- 10,175' ,, ,, 3 3/8" 2 10,198- 10,212' ,, ,, 10,222 - 10,270' 3 3/8" 2 .... PBTD 7", 29#/ft, L-80, BTRS 0430' I 0478' I BAKER PBR ASSY. I 8937' I 9 5/8" BAKER PACKER (SAB)(3.875"1D) I8995'1 cs 4 1/2 ....X" NIPPLE I (OTIS) (3.813" ID) 9035' 4 1/2 ....XN" NIPPLE I (OTIS) (3.725" ID) 9067' 4 1/2" TBG TAILI 9099' (BAKER SOS ) (ELMD) I 9076' 2 7/8" liner cemented to 200 ft above window '~~ BAKER INFL "CHOKE" PACKER SET 1-15-92 AT 9981'. ] ] ~ FISH: BAKER IBP SET 10-27-88 @ 9975', MVD DH TO 10,375' CTM. - FISH: 12' PRONG FROM BAKER IBP w/1 1/2" FN. LOST ON 10-6-88 AT 10,435' BLM. u.I 2 3/8" CT ~ I 10,000 psi Pack-Off ! R-07ai CT Drilling & Completion BOP 12" 36" 7 1/16" Annular 7 1/16" 5000 psi 22.5" 18" 38" ~ Blind/Shear ~ Pipe/Slip ~" --- 2 3~8" -~- ~, s,,.s~=.. ~ ~/~,, I~ 71116" , Pipe ~ ~ 2 3~8" SWAB OR MASTER VALVE I I DATE CHECK NO, VENDO~ ALA~KAO I LA OD DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DIscoUNT NET 120(~99 CK120999Q 100. O0 100. O0 HANDLING INST' S/H TERRI HUBBLE X4628 THE ATIrACHED CHECK IS I. PAYME~ FOR ~MS DE~RIBED ABOVE. ~ l!l~ ~ 1 OO. 00 1 OO. CO BP EXPLORATION (ALASKA), INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To Th e ORDER O~ FIRST NATIONAL BANK.OF ASHLAND No. H t 59954: AN:AFFILIATE OF NATIONAL CITY BANK CONSOLIDATED COMMERCIAL ACCOUNT CLEVELAND, OHIO :: 56-38g ~2 O0159954 ONE HUNDRED & 00/100~~~~~~~~~~ US DOLLAR ALASKA OIL AND OAS CONSERVAT I ON COMMI SS I ON 3001 PORCUPINE DRIVE DATE AMOUNT [ 12/:1.0/99 L $1oo. OD J NOT VALID AFTER 120 DAYS : ANCHORAGE AK 99501 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION COMPANY ~_/~,~' WELL NAME(;? Z~7"~'PROGRAM: exp dev redrll /' se~ / wellbore seg ann. disposal para req ~ ~~~ INIT C~SS ~~~ GEOL AR~ ~~ UNIT~ ~//~-~ ON/OFF SHORE 1. Permit fee a,ached .............. . ...... ; ... (~,. , -- ~ .. ~ / ' ' 2. Lease number appropriate.~. ~ .~:~. ~./~-~t ,~ .~L~c ~5~-2~, ~ A/~R DATE 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included~ ............ 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided .............. ..... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ....... · . 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 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 .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to H,I;:5(:~,,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y DATE 31. Data presented on potential overpressure zones ..... Y N 32. ' ' ' ~'~n ~,, N 34. ss reports [explora ly] N ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLC)~S~ ENGINEERING: UIC/Annular COMMISSION: JDH ~ __'~. RNC Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09~27~99) Well Histo.ry 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 APPENDIXl .. No Special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon May 22 14:31:01 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/05/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD (FT FROM MSL 0) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 1 AK-MW-00014 B. JAHN J. MCMULLEN, OPEN HOLE BIT SIZE 3.750 3.750 3.750 R- 07A 500292052301 BP Exploration (Alaska) , Inc. Sperry Sun 22 -~Y- 00 MWD RUN 2 MWD RUN 3 AK-MW- 00014 A/<-MW- 00014 B. JAHN B. JAHN W.L. W.L. 32 12N 13E 592 753 59.90 .00 .00 CASING (IN) SIZE (IN) 7.000 RECEIVED MAY 2 § 2000 Alaska Oil & Gas Cons. Commie=ion Anchorage DRILLERS DEPTH (FT) 9580.0 ' REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 04/07/00 (PDS GR) WITH A KBE OF 59.9' AMSL. KICKOFF POINT FOR THIS WELLBORE IS AT 9580' MD, 8503' SSTVD (TOP OF WHIPSTOCK). 4. MWD RUNS 1 - 3 REPRESENT WELL R-07A WITH API # 50-029-20523-01. THIS WELL REACHED A TOTAL DEPTH OF 11278MD, 9035' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/22 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 9575.5 11245.5 ROP 9605.5 11275.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9575.5 9579.0 9615 5 9619 9623 9626 9632 9639 9641 9647 9649 9651 9663 9666 9668 9672 9675.0 9677.5 9679.0 GR 9576.5 9580 0 9616 0 9620 0 9624 0 9627 5 9633 5 9640 0 9641 5 9646 0 9648 5 9652 0 9664 5 9667 5 9670 5 9673 5 9676 0 9678 5 9680 5 EQUIVALENT UNSHIFTED DEPTH 9681.0 9685 0 9687 0 9690 5 9692 0 9697 0 9701 0 9703 0 9709 5 9716 5 9721 0 9724 5 9727 5 9732.0 9733 5 9741 0 9752 5 9761 5 9763 5 9772 0 9822 0 9827 0 9838 0 9866 0 9869 0 9875 0 9879 0 9886 0 9914 5 9920 5 9923 5 9926 0 9930 0 9976.5 10025.5 10041.5 10054.0 10071.5 10077.5 10085.5 10090.5 10093 0 10132 5 10144 5 10149 0 10156 0 10157 5 10176 5 10320 0 10337 0 10342 5 10356 0 10369 0 10379 0 10385 5 10437 0 10442 5 10445 0 10447 5 10461 0 10481 0 10508 0 10513 0 10541 5 10544 5 10549 5 10554 0 10613 5 9682.5 9685.0 9687.5 9691.0 9693.0 9698.0 9702.0 9703.5 9710.5 9717.5 9721.5 9725.0 9727.5 9732.5 9733.5 9742.0 9753.5 9761.0 9764.0 9773 0 9823 5 9828 0 9838 5 9867 0 9871 0 9876 0 9880 5 9887.5 9917 0 9922 0 9926 5 9929 0 9932 5 9978 5 10026 5 10043.5 10055.0 10071.5 10078.0 10086.0 10091.5 10093.5 10134.0 10145.5 10154.0 10156.0 10158.0 10177.5 10321 0 10338 0 10340 5 10354 5 10367 0 10378 0 10386 0 10437 0 10441 5 10444 0 10447 0 10461 5 10481 0 10509 0 10513 5 10542 0 10545 0 10550 0 10555 0 10614 5 10616 5 10665 5 10671 5 10674 0 10679 0 10698 5 10699 5 10713 0 10721 5 10730 0 10738.0 10743 0 10747 0 10749 5 10756 0 10761 0 10767 0 10773 0 10777 0 10780 5 10793 0 10805 5 10815 5 10823 5 10826 0 10828 0 10829 0 10838 0 10839.5 10853.0 10855.0 10856.5 10865.0 10875.0 10881.5 10884.0 10888.0 10899.5 10903.0 10912.5 10929 5 10931 0 10932 5 10936 0 10938 5 10939 5 10942.0 10972.0 10985 5 11002 0 11027 0 11038 5 11041 0 11047 5 11053 0 11065 0 11068 5 11072 0 11081 0 11087 5 11097 0 11102 0 11104 0 11108 0 11119.0 11126.0 11129.0 11131.0 10617.0 10665.5 10671.0 10673.0 10678.5 10699.0 10701.0 10715.0 10722.0 10726.5 10737.0 10741.0 10744.0 10747.0 10753.0 10757.5 10764.0 10769.5 10773.0 10778.5 10791.5 10803.5 10813.5 10823 0 10825 0 10826 0 10827 5 10835 5 10837 5 10851 0 10852 0 10853 5 10862 0 10870 5 10876 5 10879 0 10883 5 10894 5 10898 5 10908.0 10924 5 10926 0 10927 5 10932 0 10933 5 10935 0 10937 0 10964 5 10981 0 10997 0 11023 5 11034 5 11038 0 11044 5 11051 0 11063 5 11066 5 11070 5 11081 0 11086 5 11097 0 11102 0 11104 0 11109 0 11118 0 11124 0 11126 5 11128.0 11134 11137 11139 11146 11148 11150 11151 11156 11158 11165 11173 11179 11202 11205 11214 11216 11220 11228 11239 11242 11244 11275 $ 0 5 5 5 5 5 5 5 .5 5 5 0 0 0 0 .0 .5 .5 .0 .0 .0 .5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 11130 5 11133 5 11136 5 11145 0 11146 0 11147 5 11148 5 11153 5 11156 0 11163 5 11171 5 11177 5 11201 5 11204.5 11214.5 11216 5 11221 0 11230 0 11240 5 11243 5 11246 5 11278 0 BIT RUN NO MERGE TOP MERGE BASE 1 9576.5 10095.0 2 10095.5 10968.0 3 10968.5 11278.0 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9575.5 11275.5 10425.5 3401 ROP MWD FT/H 1.13 2160 99.8876 3341 GR MWD API 17.57 979.47 50.4896 3341 First Reading 9575.5 9605.5 9575.5 Last Reading 11275.5 11275.5 11245.5 First Reading For Entire File .......... 9575.5 Last Reading For Entire File ........... 11275.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 D~te of Generation ....... 00/05/22 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 ....... 00/05/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEA/DER FILE NUMBER: 2 R3kW 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 GR 9576.5 ROP 9606.0 $ 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 10065.5 10095.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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: 04-APR-00 Insite 7.75 Memory 10095.0 35.9 95.9 TOOL NUMBER 003 3.750 Flo-Pro 8.70 60.0 9.5 24000 4.6 .000 .000 .000 .000 .0 129.0 .0 .0 ~EUTRON 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9576.5 10095 9835.75 1038 ROP MWD010 FT/H 5.31 189.47 84.4884 979 GR MWD010 API 21.98 979.47 91.4794 979 First Reading 9576.5 9606 9576.5 Last Reading 10095 10095 10065.5 First Reading For Entire File .......... 9576.5 Last Reading For Entire File ........... 10095 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/22 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT~ RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10066.0 ROP 10095.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 05-APR-00 Insite 7.75 Memory 10968.0 29.4 102.1 TOOL NUMBER 002 3.750 Flo-Pro 8.75 80.0 9.2 24500 7.8 .000 .000 .000 .000 STOP DEPTH 10937.5 10968.0 .0 141.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10066 10968 10517 1805 ROP MWD020 FT/H 2.68 2160 104.669 1746 GR MWD020 API 17.57 162.33 32.2911 1744 First Reading 10066 10095.5 10066 Last Reading 10968 10968 10937.5 First Reading For Entire File .......... 10066 Last Reading For Entire File ............ 10968 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/22 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 ....... 00/05/22 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW 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 10938.0 11248.0 ROP 10968.5 11278.0 $ LOG HEADER DATA DATE LOGGED: 06-APR-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11278.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 20.0 MAXIMUM ANGLE: 25.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ 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 TOOL NUMBER 3.750 Flo-Pro 8.70 80.0 9.3 25500 6.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 141.7 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10938 11278 11108 681 ROP MWD030 FT/H 1.13 1715.6 115.623 620 GR MWD030 API 18.51 164.83 34.5475 621 First Reading 10938 10968.5 10938 Last Reading 11278 11278 11248 First Reading For Entire File .......... 10938 Last Reading For Entire File ........... 11278 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/22 Maximum Physical Record..65535 File Next Type ................ LO File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/22 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 00/05/22 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
