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204-113
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC N-01A PRUDHOE BAY UNIT N-01A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 N-01A 50-029-20079-01-00 204-113-0 W SPT 8504 2041130 3000 613 615 611 611 0 4 5 4 REQVAR P Bob Noble 6/8/2025 2 year MIT-IA to max pressure as per AIO 3C.003. 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 N-01A Inspection Date: Tubing OA Packer Depth 417 3301 3198 3178IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250617140740 BBL Pumped:6.5 BBL Returned:4.3 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC N-01A PRUDHOE BAY UNIT N-01A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 N-01A 50-029-20079-01-00 204-113-0 W SPT 8504 2041130 2900 782 784 784 785 0 0 0 0 REQVAR P Kam StJohn 6/21/2023 2 Year AOGCC MIT-IA per AA AIO 3C.003 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 N-01A Inspection Date: Tubing OA Packer Depth 507 3188 3117 3099IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621132157 BBL Pumped:8 BBL Returned:8 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 Þ 2 Year AOGCC MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 14:17:47 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 7, 2021 TO: Jim Regg P.I. Supervisor�C -71 Mechanical Integrity Tests Hilcorp North Slope, LLC N-01 A FROM: Adam Earl PRUDHOE BAY UNIT N-0 1A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J go— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-0 IA Insp Num: mitAGE210627183255 Rel Insp Num: API Well Number 50-029-20079-01-00 Inspector Name: Adam Earl Permit Number: 204-113-0 Inspection Date: 6/25/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ,Well N-01AType Inj G TVD �- 8503 Tubing 2391 2390 • 2388 2386 ' PTD 2041130 _ Type TestSPT jest psi 2126 IA 1087 3289 3244 3231 _ BBL Pumped: 10.7 '� BBL Returned: 4 OA 24_-__27 - 28 _ 28 - T Interval OTHER P/F P v Notes: Test was conducted for evaluation of suspected Tubing/IA communication. Operator noted a climb in IA psi last 10 days. Test passed JJ +, ff - V T& – ADT— (.10 + bpi pk,,>1J) Wednesday, July 7, 2021 Page 1 of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 2:49 PM To: Alaska NS - PB - Field Well Integrity; Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Oliver Sternicki Subject: RE: OPERABLE: WAG Injector N -01A (PTD #2041130) AA for continued WAG injection Attachments: AIO 3C.003.pdf Mr. Wallace, WAG injector N -01A (PTD #2041130) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #3C.003 Please respond with any questions. Aras Worthington Hilcorp Alaska LLC Well Integrity Engineer, PE Aras.worthington@hilcorp.com 907.564.4763 907.440.7692 mobile From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, June 21, 20214:06 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector N -01A (PTD #2041130) Suspected TxIA communication Mr. Wallace, WAG injector N -01A (PTD #2041130) has been found to have suspected slow TxIA pressure communication. The IA pressure was bled on 06/21/21 from 1030 psi to 660 psi mixed gas / liquid returns. The IA pressure increased —30 psi during a 30 minute monitoring period. The gas returns and subsequent re -pressurization indicate a failure or impairment of one or more well barriers. The well is now classified as UNDER EVALUATION and placed on a 28 day clock to be resolved. Plan Forward: 1. DHD: Verify re -pressurization rate, perform PPPOT-T 2. Fullbore: AOGCC MIT -IA 3. Engineering / Well Integrity: Consider AA or further corrective action as required. Please call with any questions or concerns. Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity<PBFieldWelllntegrity@hilcorp.com> Sent: Monday, June 21, 2021 4:06 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki Subject: UNDER EVALUATION: Injector N -01A (PTD #2041130) Suspected TxIA communication Mr. Wallace, WAG injector N -01A (PTD #2041130) has been found to have suspected slow TxIA pressure communication. The IA pressure was bled on 06/21/21 from 1030 psi to 660 psi mixed gas / liquid returns. The IA pressure increased —30 psi during a 30 minute monitoring period. The gas returns and subsequent re -pressurization indicate a failure or impairment of one or more well barriers. The well is now classified as UNDER EVALUATION and placed on a 28 day clock to be resolved. Plan Forward: 1. DHD: Verify re -pressurization rate, perform PPPOT-T 2. Fullbore: AOGCC MIT -IA 3. Engineering / Well Integrity: Consider AA or further corrective action as required. Please call with any questions or concerns. 4.001) 3.1301) 3.'600 3.400 3.2'00 3.01)0 2.800 2.600 2.400 2.200 2.000 1,800 1.600 1.40D 1.2D0 1.000 Soo 601) 400 200 We1I: M-01 03,••21,'21 04,x•21 x'21 Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 O5l22.t21 220 200 ISO 160 140 –, rn 120-9 100 So 60 40 20 From: AK, GWO Well Integrity Engineer <AKGWOWeI[Site Enginee@bp.com> Sent: Monday, October 1, 2018 2:39 PM 1 TIO Plot —O Tbg On Bleed Operably -f- Not Oper ♦ Under Eval -� MAN–IA —� MAN_QA MAN_OOA 1• MAN_OO[3A E3 Tem peratu re STATE OF ALASKA 110_ASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Milling Failure 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-113 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20079-01-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number: PBU N-01A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: RECEIVED PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 2 In5 7 Total Depth: measured 9750 feet Plugs measured feet OCT 7'J'f true vertical 8980 feet Junk measured feet ACGCC Effective Depth: measured 9662 feet Packer measured 8763 feet true vertical 8944 feet Packer true vertical 8504.36 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface 4239 13-3/8"68#K-55 31-4270 31-4265 3450 1950 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9355-9375 feet feet 9380-9394 feet 9394-9400 feet 9400-9417 feet 9417-9420 feet 9430-9455 feet True vertical depth: 8822-8830 feet feet 8832-8837 feet 8837-8840 feet 8840-8846 feet 8846-8848 feet 8852-8861 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-8821 24-8540 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED 1 •8 2O i Treatment descriptions including volumes used and final pressure: DECl 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 617 12605 924 2019 1237 Subsequent to operation: Shut-In 0 50 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic ❑ 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 0 WINJ 0 WAG 0 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: 317-024 Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: Production Engineer Challenger Contact Email: Matthew.Bergene@bp.com Authorized Signature: Date: Z54 Oct (?Contact Phone: +1 9075644849 Form 10-404 Revised 04/2017 " t-t— 1-2"7-//7- RBD�y4�^ NOV7 �Z/�/� L V — 2 20a/ Submit Original Only • by BP Exploration(Alaska)Inc. 900 East Benson Boulevard To: Alaska Oil and Gas Conservation Commission P.O.Box 196612 Anchorage,AK 99519-6612 333 West Seventh Avenue USA Anchorage,AK 99501-3572 Main 907 564 5111 RE: BP Exploration (Alaska), Inc. Reports of Sundry Well Operations Summary for wells N-01A and N-27 October 26, 2017 To Whom It May Concern: Please find attached the Reports of Sundry Well Operations for Channel Squeeze and Addition of Perforations for Wells N-01A (PTD # 204-113) and N-27 (PTD # 207-104). On August 31, 2017, the State received an additional request for Sundry Approval for each of the wells listed above. The purpose of this additional Sundry was to obtain current and valid Sundries for conversion to WAG injection. At that time, the wells were expected to be put on injection (P01) in September 2017 and after passing MITs a Report of Sundry Well Operations would have been submitted for both active Sundries; however, due to unforeseen facility work the wells have been unable to be POI. At this time, please find attached the Report of Sundry Well Operations for the well work portion only, referencing Sundries 317-024 and 317- 059 for N-01A and N-27 respectively. Additional Reports of Sundry Well Operations, referencing Sundries 317-422 and 317-423 for N-01A and N-27 respectively, will be submitted upon completion of a State witnessed Mechanical Integrity Test. Sincerely, Matthew C. Bergene Production Engineer Challenger BP Exploration (Alaska), Inc. P. 0. Box 196612 Anchorage, AK 995196612 Attachments: Form 10-404 for N-01A PTD#204-113 Form 10-404 for N-27 PTD#207-104 • • N v) U O N = N c 0 a) C 0) rn�'' a) ,C a) �.. O m (U C •C "p C _ • CO 3 U 4-, n O ti 7 N �C t L ,- 0) p)U c0 N E U C t a) > C N •c 7 _ _o U • N a) 0 - U E O C C a) -0 u) in U = •"d U V) O O V) V) a) U U _c o C 7 0 CO N c a) E o f Q7 N a) o_.= O a) U N N U U U O C c Y a) u) U .�-. U) -C C L j a) C o_ C C +---' T O > 7 41- 3 r3)-O cU N * �N �_ -0 co O O U U rn 2 a) C — c� CO C C N ++ - U L ) 'D - O — N > a) - 0 0 3 � O a) a) : O C O 3 a) > - m a) N a. L 0 d N C L > cOn = co 3 M _ N -C U -c cn Q N u) " O Y O 0 j O O a) 0 00 U Q- -C o CD0 ; ``) '.- Tr) c o -c < ccv E aa)) a) o o - Q w N •v- E co c D_'- C p m U ca - 3 .- -o Cl) 0)in N L • 0 CD c9 a) cn Cl) a c _0 Q 0 o a) j = -. a) � �") ` 0 co) co co c0i = oo cu C m U) E 0 Yin .m CU m e 0_ c z c m 00') u) :-.= o m �° _ - a) L o — L 2 U o C O N .-. 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CC C D Z Z Z Z c W W W W pp O Z Z O � H 0000) ZZJJ � • • Packers and SSV's Attachment PBU N-01A SW Name Type MD TVD Depscription N-01A PACKER 7184.1 7177.28 7" Baker ZXP Mech Top Packer N-01A TBG PACKER 8763.33 8504.36 4-1/2" Baker S-3 Perm Packer N-01A PACKER 8826.25 8543.97 5" Baker ZXP Top Packer TREE= " 4"CNV III INEI.I_FEAD= MCEVOY -1110„NOTES: "*OOOA HAS H-40 CSG.MAX ACTUATOR= BAKER C N _p 1 A MIT-000A1200 PSI*** KB.8_EV= 62.10' "*4-1/2"CHROME TBG"* BF.a.EV= 43.19' KOP= 3900' p — 1900' —113-3/8"DV PKR Max Angie= 68°(927T Datum MD= 948T Datum TVD= 8800'SS I I 2187' —14-1/2"FES X MP,D=3.813' O 2291' 1—}10-3/4"CM FCR 20"CSG, 133#/94#,K-55/11-40,D=19.124" — 2088' v' . 2426' —10-3/4'x 9-5/8'XO 0, 2426' TOP OF CEMENT(7"TEBACK LM) 10-3/4'CSG,55.5#,N-80,D=9.76" H 2426' I, GAS LFT MANDRELS 0� ST MD TVD DEV TYPE VLV LATCH PORT QATE I �� 5 3289 3288 3 KBG2 DMY BK 0 01/14/16 13-3/8"CSG,68#,K-55,D=12.415' —1 4200' } , • �� 4 5596 5589 0 KBG2 DMY BK 0 01/14/16 �i 3 7208 7201 2 KBG2 MY BK 0 12/21/12 1. 2 7935 7908 27 KBG2 DMY BK 0 08/04/04 Minimum ID = 3.725" @ 8807' I. 1 8589 8392 50 KBG2 DMY BK 0 01/14/16 4-1/2" HES XN NIPPLE tit I11 7171' —7'BKRTEBACKSEAL ASSY T w/CMT FORTS,D=6.19' 7"TIEBACK CSG 26#,L-80 BTC,13=6.276" —I 7181' 7171' —9-5/8"X 7'BKR ZXP LNR TOP FCR &I—PAC LNR MGR,D=6.261" MILLOUT WINDOW 7 31 6'-7332' 9-5/8"WHPSTOC K --I 7316' 9-5/8"EZSV(07/25/04) H 7336' 1- 8742' —14-1/2'FES X NP,D=3.813" TBG STL 3(07/03/04) H 7514' ` 8762' H7"x 4-1/2"BKR S-3 PKR,D=3.875" ■mm , 8786' J-14-1/2'FES X MP,D=3.813' ■ a n ,� N , 8807' —14-1/2'FES XN NP,D=3.725" 8 9-5/8'CSG 47#,N-80,D=8.681" H 9309' I • 8818' I--7"X 5"BKR ZXP LNR I TOP PKR&FMC LNR .�.�.t.�.�.f.�.f.E. ` INGR,13=3.958" 8819' —4-1/2"WLEG, PERFORATION SUMMARY „ — D=3.958" RE=LOG:S'AS-BRCS ON 10/09/70(N-01?) tv�4�4�4r .41. .j ` 8838' —5"X 4-1/2"XO, ANGLE AT TOP PERF:67°@ 9355 ` D=3.958' Note:Refer to Roduction OB for historical perf data 4-1/2"TBG,12.6#,13CR TCII, H 8819' SIZE SPF INTERVAL SHOT DATE SQZ .0152 bpf,13=3.958" ` 3-3/8' 6 9355-9375 0 07/25/08 1 2-7/8" 6 9380-9394 0 04/26/06 r LNR,26#,L-80 BTC,.0383 bpf,D=6.276' —1 8968' 2-7/8' 6 9380-9420 0 09/18/04 2-7/8" 6 9394-9417 0 02/18/06 2-7/8" 6 9430-9455 0 09/21/04 PBTD -{ 9662' `1 %%,` 0,0 • 4-1/2*TBG,12.6#,L-80 13T-M,.0152 bpf,D=3.958" —1 9748' DATE REV BY COMMENTS DATE REV BY COMMENTS ENTS PRUDHOE BAY UNIT 07/24/74 ORIGINAL COMPLETION 12/27/12 RKT/JMD GLV C/O-SET XXN PLUG(12121-2: VVELL: N•01A 08/10/87 RWO 01/28/13 WRAC TREE CO(01112/13) PERMIT No:"041130 08/07/04 HIES SIDETRACK(N-01A) 01/28/13 AMUMD RLL XXN PLUG&GLV C/O(01/24 AF No 50-029-20079-01 04/26/06 GJB/PJC PELF CORRECTION(2/18/06) 01/26/16 SWCYJMD GLV C/O(01/14/16) SEC 8,T11 N.R13E,1519'FSL&556'F W 04/26/06 GJB/PJC ADFBRF , 09/05/08 JLYPJC PERF(07/25/08) BP Exploration(Alaska) • ,§).-„ 1//77.:,, THE STATE Alaska Oil and as ��►`���� of Conservation Commission __ 333 West Seventh Avenue ii GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ® ;,{ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Bergene �0 17, Production Engineer ChallengerSataSE? BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-01A Permit to Drill Number: 204-113 Sundry Number: 317-422 Dear Mr. Bergene: 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, Hollis S. French Chair DATED this 1 Z day of September, 2017. RBDMS Suri 1 9 2017 I • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 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 Convert to Injector RI• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-113 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 3. 9 6. API Number: 50-029-20079-01-00 ' 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Num What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 10 • PBU N-01A ' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: AUG 3 1 201? ADL 0028282 • PRUDHOE BAY,PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY AOG C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9750 ' 8980 - 9662 8944 Casing Length Size MD TVD Burst Collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface 4239 13-3/8"68#K-55 31-4270 31-4265 3450 1950 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24-8821 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service I3. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: JttwN..Lr ?--at7 Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG m ' 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 Name: Bergene,Matthew be deviated from without prior written approval. Contact Email: Matthew.Bergene@bp.com Authorized Name: Bergene,Matthew Contact Phone: +1 9075644849 Authorized Title: Production Engineer Challenger Authorized Signature: – V.12rz.�� Date: • 64. 5f 7 Yr COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number. 3 t-7- 4/2-2-- Plug —r– `f2-2Plug Integrity 0 BOP Test 0 Mechanical Integrity Test V Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes tr7 No Spacing Exception Required? Yes 0 No Ile Subsequent Form Required: / C' 4 C 4- APPROVED BYTHE Approved by: r i, L COMMISSIONER COMMISSION Date:'k `Z 111 VT-L. 61/di/i . \?'R G � N AL RBDMS u\.) SEP 1 9 2017 , ritt ' Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. 0 • bp BP Exploration(Alaska)Inc. 900 East Benson Boulevard P.O.Box 196612 Alaska Oil and Gas Conservation Commission Anchorage,AK 99519-6612 333 West Seventh Avenue USA Anchorage, AK 99501-3572 Main 907 564 5111 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval for Conversion to Injection Wells N-01A and N-27 August 30, 2017 To Whom it May Concern: fie(,f0vf; coACV• .1/ VA a,d, i���v� �c� G4/ if q107 Attached please find the Application for S dry Approvals to convert wells N-01A(PTD#204-113) and N- 27 (PTD # 207-204) to injectors. N-01A nd N-27 were the sub'ect of .reviousl approved sundries for conversion. numbered 315-330 and 315-332 respectively,,_Since the initial Sundries were approved on 06/19/2015, a significant amount of additional well work was required than expected to prepare the wells for injection. The well work is the subject of two additional sundries, 317-024 for N-01A and 317-059 for N-27. The well work that was required included a cement squeeze of the liners to remediate channels behind pipe within the Ivishak Formation. This work was recently completed and the wells are now ready to put on injection; however, since more than 12 months has passed since the initial Sundries for Conversion (315-330 and 315-332) were approved, it is requested that new, current sundries are approved. Sincerely, -4,61=t— 4r,..... ,,,_ Matthew C. ergene Production Engineer Challenger BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612. Attachments: Form 10-403 Application for Sundry Approval for N-01A Conversion to Injector Form 10-403 Application for Sundry Approval for N-27 Conversion to Injector Area of Review for N-01A and N-27 • • a) Q O 0 0 LU 0 0 0 0 0 coO o O N a O 0 LO LC) N- N 0 co) O O o 0 0 0 0 0 0 i N C) N LC) - LO ct CO CO 7 CO LU CO - N N NI- m N N CO N- CO CO CO O c- LO CO CO ct O 00 O O CO -- V CO C` •-- N N CO CO 00 I— O CO O) N O .- I- O) CO CO ct M ' CO N N '— LC) N N- CO C CD OO O N CO O) O) O O O I� 00 CO t N V O) f"- CO N N CO O) co C▪.) 0 03 i i i i i Q Q r O C) O) 0 N O c- N- O) N- O '— CO N (N — CO N C Z N- CO I-▪ CCI O O LO LO LO coi 00 0 LUL C) Z ) 00 Y � Y °O *k00 _= a) *k = *k 0(0 J t1') J (.O *k N N CO % C7 CO *k Ln *k (V CO co a M - O CO r nj O DO N N _ O N N N C- O) CO V N CO a) N- O OC) N N- (3") N- V N- N CO W W Q Q Q p)OOO CI— I— I— w 00 '00000 U O O 0 L ct Z Z Z Z f W W W W pp O O O 0 H Z Z 0 • oc.) zJJI— • • • d Co ca CO M in O M t O V l'-- CO co Q O N.: o) (D ` y co co co .,:r V C0 a0 co ❑ CO o0 00 cc ❑ 00 00 co co OD 00 > I— o. O I— L!7 00 Ln 0) co •- Z N 6) �t N-- LC) 0. N I` 6) CO 0 d N co co co •ct in W ❑ 00 00 co cc 00 CO > ❑ CO CO CO CO CO CO 0 > 2 I- W CL 0 0 0 WZ W W0 W 0 a) < < J 0 w Y 0 O mW O W Y Y Z Ln O I"- O Ln co Q Q w Wcr w G0 - 0 C a)_ f— 0) O c- N LO Q Q Q W CL 0_ Z ❑ 6) O) O) 6) 6) CA Z Z Z O J J J 0 3 CO = 0 0 a W W Eca 2 O O O W i2 1Y Z 00 Z W W w a H H < J < V Q 2 O co co co co co as r Q C a Z 12 C 'i Ln O v O N- O a Lr) 00 6) O '— M O m co 0) el rn rn a) CO 0- L a) O 2 cc wY = 0 O wcc t 2 2 2 O co co can u) can w a 0 0 C LL LL LL LL t w m d d 0_ d CL W a. 0 0) a) a 0 W J W a> a coH w w al CO CO 00 CO CO 'Cr ❑ 0 0 0 0 0 0 0 0 0 O c C) 0 CD 0 0 0 W J J Z Lu O N N N N N N Z W d d < W W LU LU LU c O CC W N N L. Lf) Lf) L() LO LC) 00 O N N N N N Z CL 0 0 0 W W W W a i i ti t i a? 0 0 < O J J ❑ 0 0_ O CO 0 CC Cl J J 00 W W Q Q CO m L_ LL co co CL CC a) E e6 Z Q Q Q Q Q Q N O O O O O O CO d d O) O J 0 0 w d ZZZZZZ < < m m L_ LC cn u) o_ tY • • Packers and SSV's Attachment PBU N-01A SW Name Type MD TVD Depscription N-01A PACKER 7184.1 7177.28 7" Baker ZXP Mech Top Packer N-01A TBG PACKER 8763.33 8504.36 4-1/2" Baker S-3 Perm Packer N-01A PACKER 8826.25 8543.97 5" Baker ZXP Top Packer .I HEE= 4"CM/ • WE_LFEAD= MCEVOY N O A SAFETY NOTES: ***000A HAS H-40 CSG.MAX ACTUATOR= BAKER C MIT-000A 1200 Psr KB.HEV= 62.1(Y ***4-1/2"CHROME TBG"** BE.HEV= 43.19' KOP= 3900' C Max Angle= 68°@ 927T — 1900' —{13-318'DV PKR altUM MD= 9487 Datum TVD= 8800'SS I 218T' —14-1/2"HES X NP,ID=3.813" D 2291' —10-3/4"DV PKR 20"CSG,133#/94#,1455/H-40,D=19.124" — 2088' v42426' -110-3/4"x 9-5/8"XO All 10-314"CSG,55.5#,N-80,D=9.76" — 2426' '4 2426' --I TOP OF CEMENT(7"TIEBACK LNR) �, GAS LFT MANDRELS t, Ilp $ ST MD TVD DEV TYPE VLV LATCH PORT DATE 1, 1 5 3289 3288 3 KBG2 DMT' BK 0 01/14/16 13-3/8"CSG,68#,K-55,D=12.415" — 4200' 1411 r4 $ 4 5596 5589 0 KBG2 DMT' BK 0 01/14/16 t, 1 3 7208 7201 2 KBG2 DMY BK 0 12/21/12 .4 i 2 7935 7908 27 KBG2 DMY BK 0 08/04/04 Minimum ID = 3.725" @ 8807' .4 1 8589 8392 50 KBG2 DMY BK 0 01/14/16 1 4-1/2" HES XN NIPPLE f, •� 7171' —7'BKRTEBACKSEALASSY IT 1 w/CMT PORTS,ID=6.19" 7"TEBACK CSG 26#,L-80 BTC,ID=6.276" — 7181' 7171' —9-5/8"X 7"BKR ZXP LNR TOP PKR &HMC LNR HNGR,D=6.261" 9-5/8"W-IPSTOCK —j 7316' MILLOUT WINDOW 7316'-7332' la 9-5/8"EZSV(07/25/04) H 7335' 40,, 74ati 8742' --I4-1/2"HES X NP,D=3.813" TBG STUB(07/03/04) H 7514' f ` 8762' H7"x 4-1/2"BKR S-3 PKR,ID=3.875" .:'•, 1 8786' —j 4-1/2"HES X NP,D=3.813" i � ` 8807' --I4-1/2"HES XN NP,D=3.725" 9 5/8"CSG,47#,N-80 D=8.681' H 9309' I 8818' —7"X 5"BKR ZXP LNR TOP PKR&HMC LNR Atteeeititi% 4k FNGR�R,ID=3.958" 8819' —4-1/2"WLEG, PERFORATION SUMMARY �r `^ D=3.958" REF LOG:SW5 BRCS ON 10/09n0(N-01?) 6.6.4.4.6.6.6.6.6.6 —5"X 4-1/2"XO, ANGLE AT TOP PERF:67°@ 9355' ` D=3.958" Note:Refer to Production OB for historical perf data 4-1/2"TBG,12.6#,13CR TCII, —I 8819' SCE SFF NTERVAL SHOT DATE SQZ .0152 bpf,D=3.958" Vv� ~io ` 3-3/8" 6 9355-9375 0 07/25/08 ` F a 2-7/8" 6 9380 9394 0 04/26/06 7"LNR,26#,L-80 BTC,.0383 bpf,D=6.276" H 8968' ` °a 0 2 M Q 2-7/8" 6 9380-9420 0 09/18/04 2-7/8" 6 9394-9417 0 02/18/06 2-7/8" 6 9430-9455 0 09/21/04 PBTD -H 9662' `;01.` 4-1/2"TBG,12.6#,L-80 ET-M,.0152 bpf,D=3.958" —I 9748' DATE REV BY COMMENTS DATE REV BY COM E TTS PRIDHOE BAY UNIT 07/24/74 ORIGINAL COMPLETION 12/27/12 RKT/JMD GLV CIO-SET XXN PLUG(12/21-Z WELL: N-01A 08/10/87 RWO 01/28/13 TRP/JMD TREE C/O(01/12/13) PERMTNo:' 041130 08/07/04 MES SIDETRACK(N-01A) 01/28/13 AMJMD PULL XXN PLUG&GLV C/O(01/24 API No: 50-029-20079-01 04/26/06 GJB/PJC FERE CORRECTION(2118/06) 01/26/16 SWC/JMD GLV C/O(01/14/16) SEC 8,T11 N,R13E 1519'FSL&556'FW.. 04/26/06 GJB/PJC ADFERF 09/05/08 JEYPJC PERF(07/25/08) BP Exploration(Alaska) • • Area of Review PBU Wells N-01A (API No: 50-029-20079-01) N-27 (API No: 50-029-233656-00) This Area of Review is required prior to the conversion of N-01A, N-07A and N-27 from producers to WAG injectors. This AOR discusses wells within 1/4 mile of each well's entry point into the Sag River formation. Current Status: N-01A is currently an operable producer. The last well test on 09/08/2015 indicated 607 bopd, 61%watercut, and 20,722 scf/bbl GOR. N-27 is currently an operable producer. The last well test on 10/09/2015 was 584 bopd, 29%watercut, and 36,729 scf/bbl GOR. Both of these wells were initially scheduled to be converted to WAG injectors in 4Q 2015 as part of the N-pad UZI (Updip Zone 4 Injection) Project, prior to that work beginning sundries for conversion were approved on 06/19/2015 (315-330 and 315-332). The UZI Project targets remaining oil where the gas cap has expanded into zone 4, and the gravity drainage process is less efficient. The UZI Project achieves improved recovery through pattern injection of water and/or MI. The area of UZI potential is generally identified as immediately upstructure of the existing WF/EOR area. The planned facility work to install MI and water injection headers was completed slightly behind schedule, and one of the three conversion wells, N-07A, was put on injection July 10, 2016. Due to conformance issues with N-01A and N-27, the wells were not ready to be put on injection until recently. Since more than 12 months lapsed between the initial sundry approvals and the completion of the well work, these wells have not been put on injection until a new sundry for conversion is approved. N-01 A N-01A Completion: N-01 A is a conventional (max angle is 68°) well that was sidetracked in September 2004 in zone 4. It was sidetracked with future UZI injection potential in Z4 as part of that justification. The well was pre-produced between 09/2004 and 09/2015, while waiting for approval and construction of the UZI project. The well has been SI and disconnected • from the production system since 09/29/2015. N-01A is completed with 4-1/2", L-80 tubing and production liner (wellbore schematic Figure 1). The original well was drilled in 1970 and it was sidetracked in 2004. A CBL shows that the cement behind the original 9-5/8" casing was poor. However during the sidetrack in 2004, a new 7" liner was installed from 8,968'MD to 7181' MD' with a 7" scab liner cemented in place from 7181' to 2426'MD. The liner was cemented with 35 bbls of • 15.8 ppg Class G cement. The estimated TOC is 7,884'MD. There are no cement bond logs for this section of pipe, but no abnormalities occurred with this cement job. 4-1/2" tubing was installed from surface to TD @ 9748'MD. It was cemented with 27 bbls of 15.8 ppg Class G cement. No abnormalities occurred with this cement job although—15 bbls were circulated back to surface. After the initial sundry for conversion was approved in 2015 (315-330), a caliper was run on January 13, 2016, indicating that there was corrosion across the L-80 production liner. On February 24, 2016, a borax/RPM log was run. The log indicated channeling across / the proposed perforation interval. A remedial cement squeeze (sundry 317-024) was attempted on June 22, 2017. As part of the approved program, coil tubing attempted to first mill a restriction at 9185' MD, milling was unsuccessful and no more progress was made past 9202' MD, at this point the squeeze was cancelled and the coil tubing unit rigged down off the well. On 15 July, 2017, slickline drifted the well with a variety of tool strings, and confirmed that we do not have access to the wellbore below 9202' MD. There is a potential hole in the liner at 9185' MD, this depth is located in the 46P,just below the Shublik Shale, within the Ivishak formation. It is planned to operate N-01A as a WAG injector, we believe it to be suitable based on the most recent integrity tests, which are: 01/14/2016: MIT-IA Passed to 4000 psi 12/22/2012: MIT-T to 2,500 psi passed (plug @ 8,807'MD) 01/29/2004: MIT-OA to 2,500 psi - passed N-01A Area of Review The wells within 'A mile of N-01 A are listed in the table below (Map showing wells within 0.25 mi radius from N-01A figure 3). The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Three individual wells (including • the N-01 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-01A 50-029-20079-01 ---- TOC calc to be above injection zone behind 7" N-01 50-029-20079-00 1010 7/24/1974 CBL indicated fair cement quality above the Sag. The cement was poor quality in most places- however there was a good section (50') of cement existing (between 8,660- 8,710), combined with production history that had no evidence of barium scaling (which would be indicative of communication with the Cretaceous). These factors indicate zonal . isolation. N-14B- 50-029-20594-70 1230 Only plugback is in AOR & it was cemented. PB1 However the TOC for the 7" liner of the parent well is calc to be above injection zone N-17 50-029-20898-00 1280 TOC calc to be above injection zone behind 9- 5/8" • Well Name Csg Hole Volume of Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-01A 7" 8-1/2" 35 bbls of 15.8 ppg Class G 8,968 8,957 N-01 9-5/8" 12-1/4" 9,309 8,613 82 bbls of Class G cement 310 bbls Class G gel N-14B-PB1 7" 8-1/2" PB: 8 bbls of 17 ppg class G 9,405 9,524 7" Liner: 59 bbls of premium Class G 15.7 ppg N-17 9-5/8" 12-1/4" 206 bbls 15.8 ppg Class G 8,720 8,758 23 bbls 15.7 ppg Arctic Set I NOTE: All calculated TOC's assume 30% washout of hole. N-27 N-27 Completion: N-27 is a conventional (max angle is 26°) well that was rotary drilled and completed in November 2007 in zones 3 & 4. It was drilled with future UZI injection potential in Z4 as part of that justification. The well was pre-produced between 12/2007 and 10/2015, while waiting for approval and construction of the UZI project. The well has been SI and disconnected from the production system since 10/31/2015. N-27 is completed with 4-1/2", 13-Cr tubing and 4-1/2", L-80 liner (wellbore schematic Figure 2). When the well was drilled and completed in 2007, a 4-1/2" L-80 liner was run from 8,795 to 9,503'MD and cemented with 24 bbls of Class G cement. The 7" casing was run from 26' to 8,967'MD and cemented with 132 bbls of 12 ppg Lite Crete and 38 bbls of 15.8 ppg Class G. A CBL was run on September 12, 2007 in the 7" casing and it indicated an adequate cement bond with the TOC at 6,350'MD. A subsequent CBL run on November 28, 2007 showed a good to poor cement bond in the production liner. After the initial sundry was approved in 2015 (315-332), a caliper was run on January 12, 2016, indicating that there was corrosion across the L-80 liner. On June 28, 2016, a borax/RPM log was run. The log indicated channeling across the proposed perforation interval. A remedial cement squeeze (sundry 317-057) was performed on June 28, 2017. On 14 July, 2017, a subsequent borax log indicated that we had successfully fixed the channeling, and now have the desired conformance in upper zone 4. It is planned to operate N-27 as a WAG injector, we believe it to be suitable based on the most recent integrity tests, which are: • 06/23/2017: MIT-T Passed to 2590 psi 01/14/2016: MIT-IA Passed to 4000 psi 07/09/2011: MIT-OA to 1200 psi passed N-27 Area of Review The wells within 1/4 mile of N-27 are listed in the table below (Map showing wells within 0.25 mi radius from N-27 figure 3). The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-27 50-029-23365-00 9/12/2007 CBL indicated TOC @ 6,350'MD with an adequate bond N-16 50-029-20886-00 710 TOC calc to be above injection zone behind 9- 5/8". N-30 50-029-23523-00 1200 TOC calc to be above injection zone behind 7" Well Name Csg Hole Vol Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-27 7" 8-1/2" 132 bbls of Litecrete & 38 bbls of 8,967 8,964 Class G N-16 9-5/8" 12-1/4" 296 bbls Class G with gel 13.2 ppg 9,686 9,688 102 bbls Class G 15.8 ppg 23 bbls Arcticset 15.7 ppg N-30 7" 8-1/2" 47.3 bbls 15.8ppg Class G 9,151 9,150 NOTE: All calculated TOC's assume 30% washout of hole. Plan Forward: 1) Obtain Sundry for conversion of both wells to WAG injection. 2) Place N-01A on water injection in September 2017 3) Place N-27 on water injection in September 2017 4) AOGCC witnessed MIT-IA to 2500 psi on each well after injection has stabilized. • • TRIS= 4•OJy VYaLttEAD" M1XVOY SAFETY MOTES:'••OOOAHAS tN0ISGMAX ACTUATOR- RAKERG N—U 1 A tMT-0000.1200 PSI"' KB HEV= 62 10 ».4-1/2"CHROME TRW. BE aE'" 4115' KOP. 39017lb — w I Io' H13.318-0V P1(R I Max Anglo= 68'5p 57777 pease MO: 948/' eamMDD= 8806'85 I [ 2187 a�r7Fpszin i0 3.6137 I p —.I2281' 10.3/4'CA1 BOi (10`CSG 1338/SIM.K 56114 40,0•10121' .�. . Iain• H10.3/4-r 4.11/gr xcl I 1 ► j10-o - :" Geo, -H sue- j---- �i ►4 w2426' ITOPOF CS(7'WRACK L142) j Ii ► GAS LIFT M M ORELS f+ 1111IS QST MD TVD DEV TYPE 1/IV LATCH PORT POE / 5 3299 3288 3 KBG2 DMH BK 0 01114/16 . ►4 4 5596 5589 0 10362 DMH BK 0 01/14/16 13-3/8'M 860,K-50,D=12 415- H saw ►+ 3 7208 7201 2 1(802 DAV 8K 0 12121H2 •i 1 111 !I 2 7935 7908 27 10302 MAY BK 0 08104 04 Minimum ID a 3.725"@ 8807' 1i 0 4 1 8569 8392 50 KBG2 MAY BK 0 01/14/18 4112"HES XN NIPPLE i1 ►1 i 7171' —rBKRTEMAo(sEALASSY 1 w/OAT 10N15,10=6.15' I r TIEBACK CSG 266,1-80 BTC,D=6.276- ! 7181' 7171' 9.5)8"x r MR ZXP UV TOP Nal &MAC LNR MGR,13=6.261" �5 51"8'YviP TOCI( H 7316 MLLOUT WINDOW 7311'-7332" 1 (ARIA•F7RV 01/75/10 H 7536' 4 ITT1(/s7U8(07IWtW) 7614' _!� .874I2' —4-,/2'rES XNa,D=3-8/3'1 N8762' 7'x4-1/41 BKR S-3 PKR D=3.81t75' I 8788 4-117 FES X PA DA 3.813- 1 A 1.1-...• ` 8807 4-112'1£S XN ANS,D=3.725- 9-518"CSG,4741,1.80.D=8 881'... 9309/ 9811' 1 rxtr6104txPLNR TOP AOR a MBC 1NR i'w4.e.4t'f + Fit'aM D=3 955. 1 8/11 4 4 11 4 PERFORATION SLMNMRY \ ID=3.958' REF LOG:WS-MOS ON 10'09/70(1401?) 11'1 V 1 i 4*4.44.614.4 \ 8838' —9x4-1/2-x0, ANGLEAT TOP PIEF.67'47/9355' ` D=3.958' Nate:Refer to Production DB for Ilgtariest pelf data 4-12'711G,1181,*OCR TC11, —I- 8819' 1 SIZE SW H1FRVAL SHOT DA1E SQZ 0152 bid,D=3958' 3.338' 6 9355-9375 0 07/25/08 28 R, 11. TI;,0383 = 2-715 8 9380-9391 0 04128106 r L► 1-80 Btip'.D-8.276'. 891g' 2-118" 6 9386-9420 0 09(18/04 2-715 6 9394-9417 0 02/18)08 2-7'8' 6 9430-9455 0 0021.04 1143-70 I Nor /Alb' 4-12'TTIG,12.88,1-60 BT-M,.0152 tut,D•3.968' 8718' • DATE REV BY COMI.B4TS 11ATE REV BYQ B-9.44M& PRUDHOE BAY GMT 07124174 ORIGINAL COMPLETION 12127/12 RKDAID Gt.V 00-SET/009 PLUG(12/21-Z WELL N-01A 08/10187 RVVO 01/28/13 TW/JMD TREE 00(01/12/13) j 1.66/11 I "2001130 08107/04 N? 'SIDETRACK(NMUM),01A) 01/28/13 MUM) RLL)004 RUG&GLV 00(0124 Al!Mx 50429.20079.01 04/26/06'GJB/PJC PERF 'TION(2118/06) 01/26/16 SWO.MD GLV 00101/14/16) SEC8,T11N,R13E 1517 FSL&556'FAL 04/26106 GE AI>PH8 0i - 9/05/081JB /R .DPJC 1x37'(07125,08) J BP Ettpbration Wu Figure 1 —N-01A Wellbore Schematic • • TREE= 4-11(CNV FMC SAFETY NOTES:••4412'CHROME TBG••WELL WELLHEAD= 11'F N-2 7 TWINNED TO N-06 ROW LAP' IIBREV= 71.6 131 E1.EV= 45.6' 1 KOP= 5007 ! - Angle= 28" 21W 881"—1-19-SIr TAM PORT COLLAR D:8.TS'I 1ALYDatum MD= 91672201' - 4 1**HES X NP,D•3.813' Callum TVD= 8800'S3 © 1 � 120"CONDUCTOR 91-54,H-40 D=19.124' 108-__ I9-s/r CSG,474,L-80 ETC-M,D=8.er H 3222'__I-A 11, GAS LFT MkPERE S _ ST MD TVD 10EV I TY9 VLV LATCH FORT LATE 4 3811 3631 15 1(8(32 MY BK 0 01/14/16 3 6100 5827 16 K3G2 OW BK 0 0/14116 r CSG 2641.L-80 TG X0 TOL-80 BTCM J--{ 4714' - x 2 7637 7301 17 IBG2 CM( BK 0 08/16/11 1 6629 8254 14 KBG2 (MI' Bk 0 00W16 1 0707' H4-12'FES X NP,13=3.813' I Min ID(N-27)=3.70"tg 9014'-9200'CTM MILLED CEMENT RETAINER&CEMENTx728' 3'x4 12'BKRS-3 FII,D-3.87-51 a I $761' 1----11i12"MIS XNP,D=3.813' I 8792 H4-1n HES XN NF D"3.725' I $796 r X 5'SKR C-2 ZXP LTR 0,-4.440 ITOPOF r LNii $196' - 6604 I-141(1 WLEG,D=3.958"I 4-1 f2"ma 12.011.Walla VAN 1 P. 8804' 0152 bpf.D=3-958' .-_-___-,._1--1BLMO TT LOGGED (D4Tq 6813" Hr X 5"BKR FLET-LOCI(NOR D=4.440 I 882J-5'X 4-1/2'X0.D=3-940'I IT CSG,261,L-80 131CµD=6.276' H Kier 1-40 Ik 9014'-9200'CTM]—MELLO HES CEMENT RETAILER 8 C®MENT.D I=3.70'(0678117) 1 -- , 9033' H4-1/7 MARKf3i,10M PaLFORATON SUMMARY ;+ + REF LOQ SLB MtM GR ON 08/30/07 I g►' , ANGL.EATTOP PE31F-12"@9073 Nole.} ter to Ftoduction DB tot testorcal pert data !i • SIZE SPP INTERVAL Oprt/Sgz DATE ,, 2.778" 6 9073-9078 S 06126)17 i, ', 2-716" 6 9073-9078 0 07/14/17 + 2-778" 6 9086-9091 S 06126/17 `+ 2-778" 6 9006-9091 0 07/14/17 )'4 2.776" 6 9109-9114 S 06/26117 ,' 3-318" 6 9144-9164 S 06(26/17 ,' 2-7/8' 6 9144-9164 O 07114(17 :4 . " 2-718" 6 9172-9192 S 06(28/17 5 _ 2-7/8" 6 9172-9192 0 07713/17 I/, ----- - 9197' .1—R5-4 4 112"ARP PULLING TOOL 8 3 69"ARP 2-7/8" 6 9214-9219 S 06126117 t+V*� •1 - - {01,23/16)(DEPTH1 (DEPTHCORRECTED 01013/17) )+444.444 MVO P91D 1417' 11 4 ..4 118814 1.4118 8 14-1(1 TAG,1281,L-80 BTM, -0152 bpf,ID=3.958'H 9643' 4'+11.+ DATE FEV BY I 4fS I DATE HEV BY COLOdtNTS PRUDHOE BAY our 091113107 MES ORCINALCOMPLETION 08103/17 RP1JbD SET CMT 1aETANER(06723/17) WELL 127 03/73/17 I FAI.IM)7'CFA;I3FPTH MRRFCTION 08111,17"LI/S.ACPA'FDCMt/rMr 507106,78/171 MUT No '2071040 01/25_/1(1 R(7UM)SET F84H(01/R1116) 383317 MT).AC RFII121 in'- ,I-r AR No 50.029233888.00 02/24/18 HCTI,IMI 4;1 V 00(01/14118) 9)-C 8 111N N13F 77111"FSI E 571'FW 07/05/18 BTN'JM)AUPtT4S 1061781161 0119117 mrnH R.UCYFLSHC I 3T11N RPFxuI,rMir o(AIts kal Figure 2 – N-27 Wellbore Schematic • • N-Pad UZI Injector 114 Mile Radius Map r, -14a 0 500 1000 1 ___ _ _ �___ U.S.surveyor's feet •14A 5970000 13 148P:,,-14 # \,.-148 —_ A -S ✓ ,� `� 5969000 \ ) / / ;� ; -07A Y 411000,1 �' I -07 f 5968000 4.� Y 20# „//�,��/�' 11411IPP . -20 Y '` Itlii `• , -02 02A 5967000 Y y r -27 ' ` J y-21 5966000 Y / % -12 / % -16 ; -30 • ...L 09 .. .. 5965000 ak._z i 5A 632000 634000 636000 638000 640000 Figure 3—Map showing wells within 0.25 mi radius from N-01A, N-07A & N-27 • S OF ro yy,� A THE STATE Alaska Oil and Gas Of LASI�:A Conservation Commission s .�-,� A irtt 333 West Seventh Avenue � Many '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �o- Main: 907.279.1433 O4'ALASVP Fax: 907.276.7542 www.aogcc.alaska.gov Julie Wellman SCANNED LIAR 0 9 Z017, Production Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-01A Permit to Drill Number: 204-113 Sundry Number: 317-024 Dear Ms. Wellman: 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, PPw_-4-& Cathy P. oerster Chair Si-- DATED this I day of February, 2017. II RBDMSV v - 32017 RECEIVED 0 STATE OF ALASKA 0 ,JAN 1 $ ZP17 ALASKA OIL AND GAS CONSERVATION COMMISSION eltS 24 IV) APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 , , OGCC 1. Type of Request: Abandon 0 Plug Perforations II Fracture Stimulate 0 Repair Well H• Operations shutdown 0 Suspend 0 Perforate P 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 Ch nel Squeeze R' �0/-4 N/oma) 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-113 - 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Z. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20079-01-00 - 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 Ii 1 PRUDHOE BAY UNIT N-01A - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028282 • PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 9750 • 8980 , 9662 8944 Casing Length Size MD ND Burst Collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface 4239 13-3/8"68#K-55 31 -4270 31 -4265 3450 1950 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24-8821 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 - Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: ' ` C to V} Oil 0 ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 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 Wellman,Julie be deviated from without prior written approval. Email Julie.Wellman@bp.com Printed Name Wellman,Julie Title Production Engineer Signature Q�-�/- - Phone +1 9075644657 Date j/, /n _ (/// _ COMMISSION USE ONLY pLC� Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 1-7— 0 2L( Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 LK Z/, 1,4 Other: Post Initial Injection MIT Req'd? Yes 0 No 19/: Spacing Exception Required? Yes 0 No UY Subsequent Form Required: `Q-- 4 d Approved by: p)0,e_t_il___oriet7 APPROVED VTL 7/1/19 COMMISSIONER COMMISSION Date: Date: ORIGINAL RSDS of-LLi _ 3 2017 id Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachment 'n Duplicate G • • Wellwork Procedure Request To: Well Services Operations Team Lead Date: 12/08/2016 Wireline Operations Team Lead AFE: APBINJEC From: Josh Allely - Well Intervention Engineer IOR: NA Est. Cost: Subject: N-01A Channel Squeeze Please perform the following steps 1. C Motor/Mill Run. GR/CCL. Perf. Set Composite Cement Retainer. Cement Squeeze. 2. C Mill Composite Retainer and Cement. Pressure Test Cement. 3. E Adperf. Borax Log. 4. F NEL: Injectivity. Borax Log. Current Status: Minimum ID: 3.725" at 8807' MD. HES XN Nipple Max Deviation: 68deg at 9277' MD Top Perf Deviation: 67deg at 9355' MD. Injectivity 5 bpm at 700 psi WHP (observed during previous borax log) Last TD Tag: 02/25/16: EL tagged TD during borax log at 9460' ELM. Last Downhole Op: 02/25/16: EL borax log. SBHP/SBHT: 03/15/08: 3192 psi and 220degF at 8800' TVDSS. Latest H2S: 03/21/15: 8 ppm. AnnComm Status: Not-Operable due to injector conversion. No annular communication. Program Contacts Contact Phone-Work Phone -Mobile/Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Pad Engineer Julie Wellman 907-564-4657 907-265-4397 Page 11 of 7 • i Coiled Tubing Motor/Mill Run. GR/CCL. Perf. Set Composite Cement Retainer. Cement Squeeze. 1. Mill restrictions in liner with a motor/ mill. 2. Drift with GR/CCL. 3. Shoot squeeze perfs. 4. Set composite cement retainer. 5. Perform a cement squeeze of the liner with a combination of HES microfine and class G cement. 6. See [Appendix A] for a detailed procedure. Coiled Tubing Mill Composite Retainer and Cement. 7. Mill composite retainer and cement down to a new TD of 9460' ELMD. 8. Pressure test cement. E-line Adperf. Borax Log 9. Perf 9250-9265' ELMD per attached perf sheet. 10. Borax Log Parameters • 100 bbls of Borax (please try and limit the amount of borax pumped into the reservoir). • 650 bbls of 1% KCI. i. 210 bbls for the initial kill (if necessary) ii. -20 bbls for baseline passes iii. 140 bbls for borax displacement iv. 280 bbls for overflush • Interval to log 9000-9420' ELMD (PBTD). 11. MU and RIH with RST logging tool with fullbore spinner. RIH to just above TD. 12. Establish injectivity with -30 bbls of diesel or methanol with max pressure of 1600 psi. Well needs at least 0.5 bpm of injectivity at 1600 psi to perform log. 13. Liquid pack the well bore with 210 bbls (1.5x volume to perfs) of 1% KCI • This step can be skipped if the well remains liquid packed after squeezing/perforating, which is highly likely. 14. Lower rate to -1.0 bpm (or whatever injectivity is at 1600 psi) and log one baseline pass at 20 fpm followed by a repeat baseline pass at 60 fpm over interval 9420'-9000' MD. 15. Pump -100 bbls of borax followed by 1% KCI at -5.0 bpm. 16.After injecting 30 bbls of borax into the formation, lower rate to -1.0 bpm (or whatever injectivity is at 1600 psi) and log a borax pass at 60 fpm over interval 9420'-9000' MD. 17. RBIH to 9420' MD and increase pump rate such that 60 bbls has been displaced into the perfs Page I2of7 when toolstring is at the bottom interval. 18.After injecting 60 bbls of borax into the formation, lower rate to 1.0 bpm and log a repeat borax pass at 60 fpm over the same interval. Volume from TD to top of interval is -5 bbls. This leaves over 35 bbls of extra borax to perform the last pass. 19. Pump an additional 280 bbls of 1% KCI to flush the borax from the near wellbore. 20. Freeze protect well with 38 bbls of diesel. Page I 3 of 7 • • APPENDIX A: CT Operation for N-01 From: Josh Allely— Intervention Engineer Contact: 907-350-7362 Notes: • The objective of this procedure is to perform a channel squeeze so that the "UZI" perfs can have hydraulic isolation from the Z4 perfs. • Given the poor condition of the liner, this job is designed as a block squeeze through a cement retainer to help keep the cement in place. This will increase the odds of success even if a true "squeeze" is not obtained. • This job is designed as a "two stage" cement job (though the cement will all be pumped at the same time) where the mircofine cement will be pumped first to try and fill the channels with cement, followed by class G to create perf nodes and trap the FineCem cement in the channel. Cement Design (FineCem Cement): BHST—220 deg F. SBHP—3250 psi. BHCT—220 deg F Cement: FineCem. Batch mixed with onsite QC. Density: 13 ppg Thickening time: 7-10 hours API Fluid Loss: 5-15 cc Free Water: 0 Compressive Strength: Minimum of 2000 psi Requested Volume: 20 bbls - The slurry should be smooth and homogenous. - There should be no free water or gelation of the slurry. Cement Design (Class G): BHST—220 deg F. SBHP — 3250 psi. BHCT— 200 deg F Cement: Class G cement. Batch mixed with onsite QC. Density: 15.8 ppg Thickening time: 7-10 hrs. API Fluid Loss: 160-240 cc. (80-120 cc/30 min TEST) Free Water: 0 Filter Cake: 0.75"-1.0" Compressive Strength: Minimum of 2000 psi Requested Volume: 20 bbls - The ratio of cake thickness to filtrate volume should be consistent with lab results. - The filter cake should be firm and dry. - The slurry should be smooth and homogenous. - There should u d be no free water or gelation of the slurry. Page 14 of 7 • • Cement Ramp Time Druation Temp Pressure Activity 0:00 2 90 0 Mix/Shear 2:00 0.5 90 0 QC Cement 2:30 1 90 4000 Pump 3:30 1 200 3300 Laying in 4:30 1 220 4000 Contaminate 6:30 220 4000 Done Planned Procedure 1. MIRU CT. Mill Liner Restrictions. 2. MU and RIH with a 3.70" flat bottom opti-cut (or similar mill suitable for milling through metal). Mill should have no side cutting structure as it will be easy to sidetrack given the condition of the liner. a. Based on the caliper, the restrictions appear to be metal liner damage. b. If the mill is short, a stringreamer should be placed above the mill, below the motor to help prevent sidetracking c. Place a stabilizer above the motor to help keep BHA as straight as possible. 3. Mill liner restrictions to a TD of—9440 CTMD. It is not expected that a hard bottom will be reached as the well has sand at this depth and we are not requesting an FCO for this operation. Returns can be taken to formation for the entire job. GR/CCL Log 4. MU and RIH with a memory GR/CCL in a carrier with a suitable drift for a HES composite cement retainer(OD —3.66"). 5. Drift to TD and log from TD to 8400' MD. Flag pipe for perfs at 9255'-9260' MD and composite retainer at 9150' MD. Ad Perf/Composite Cement Retainer 6. MU and RIH with 5' of 6 spf HES guns. 7. Shoot pert interval of 9255'-9260' MD (see attached pert form for gun specs). 8. MU and RIH with HES composite cement retainer and set at 9150' ELMD. 9. While POOH, keep hole full down the backside by pumping 60/40 methanol. 10. At surface, perform a MIT-T to 1500 psi to ensure retainer is set and holding. If injection can be established into the reservoir, contact town for plan forward. Cement Liner 11. MU and RIH with cement retainer stinger(no check valves). 12. Well should be a closed system so returns will need to be taken from the backside while RIH. Page 15 of 7 4110 • 13. RIH and sting into retainer at 9150' ELMD. 14. Establish injectivity into the formation by pumping down the CT. 15. Pressure up the backside to verify no communication with the CT. 16. Batch mix 20 bbls of FineCem cement and 20 bbls of class G cement. 17. After cement passes QC, pump the following schedule down CT: a. Freshwater spacer. b. 20 bbls of FineCem c. 20 bbls of class G cement. d. Displacement fluid. 18. Downsqueeze cement into the formation until a squeeze is achieved, defined by 2000 psi of CT pressure at minimal pump rate, or until 1 bbls of cement remains in the CT (do not overdisplace cement). 19. Unsting from retainer and lay in 1:1 the remaining cement above the retainer. This cement will immediately be contaminated so it is not necessary to get any cement above the BHA; PUH keeping cement below the BHA. 20. PUH to safety and prepare to reverse out cement. 21. Reverse out cement to 10' above the retainer pumping slick 1% KCI down the backside and up the CT. 22. POOH and FP well to 2500' MD. Wait on cement to reach 500 psi compressive strength. 23. MU and RIH with a 3.700" OD motor/mill assembly. 24. Tag TOC and correct depth to 9140' ELMD. This is the cement retainer set depth minus the 10' of cement placed on top. Verify these depths in the previous CT WSR report. 25. Mill cement down to 9460' ELMD using Powervis and 1% slick KCL. a. If losses become unmanageable, cut clean out short and chase returns as best as possible. 26. POOH chasing returns at 80%. 27. At surface, perform a pressure test of the cement squeeze with 60/40. Pressure up to 2500 psi and watch fall-off for 30 minutes recording data in AWGRS every 5 minutes. If unable to achieve 2500 psi, record injectivity at 1.0 bpm for—5 minutes. Page 1 6 of 7 r • Liner restriction is made of small deposits and some pipe damage. Caliper cross section below shows interval 9150-9340' ELMD. - — — — —- —_._ D10100484 I Modal 3 ' 4634868N41.48,0184,..48644.-686144 IL . 94 3 3 3 MD 52m 61.701M0 9196 8206 9216. .. Cm.06019 9241 13 Diameter l Modal 4.- 3.75 455 _.... 3.36 VI A 1.18 3.A 355 3.36 346 . . .%I, : . . : . . . . . : . : . . . . . : . . . . : . : . . : . . . . : . . . . : : . . . . : . : .2% - 5220 9230 9240 9260 9M0 ffiA Cursor Depth 936313 { - -. Dieme[e1l Modal 4 25 -.. I.. 355 sac 3.T1 355 3.3i 3.16 92A 9260 9260 6300 6910 1 . . . . :- 9320 93]0 CmBor Dep 9311.13 1111 9m DiemelarI Modal 4.75 4i + � 455 I, J ur' tig _... 436 d L1 � 3 �, 366 : 335 316 . . 2.96 1 I I I I . 61330 9060 BXO 9376 9380 9060 9100 Page I7of7 • • II Z 3 ^ 3a S,3„ 0,n 6-w i = O a, (D O aa 6. O t c 0 ,- .,u, -6.r1- a _.,.;32=: ;`4t :it-a _`'.. .4.,V ii; o a — ou b 3 ^y . c.^-C+3-y , "`_O A \..=.. =.S+n;. .,� cta =T O\ a �7 *= , a CO r m ti , 44 -,444 �� co . es ._.... %7 4 ,, s r r z fs ^ . - o my1 S -4 Q Cc _ QC Z' 4 7. 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F —r=r a iia_ai —i—r iii- 1111==== =1=1=r i is■iiirr } ==i�rrarINIIII i rarii==rir—arar�i tri allEl rrii--rir=r-- MN MIN f �ial�allai�r—MII1■t—MU �i1■it—®-- ir—i rr i—====_ .II i —iiirrirri-- :i IIIIII t iirr r iiirrrirrir —ir�r�iia ma rrii -------rr--- =i i rriiiiiriii ri r -=-rrii ---i-iaai1rrriiriuriariiarai--�i - ! —iiiiirfi iianiraa—it—r=�=� � , ! rrr�l1t---�i=iiii�i��i mala iirr--- ----rrii— ---rrirrr— — ----ri i--aaiiiriii 0=1111 - �r—ir— i— rrii r—= --IIM rri= � ii irri—ri i rir i III —iirrrrrrriiiriri=r irri i— _ ._ i • • • Memory Multi-Finger Caliper Log Results Summary Company: BP Exploration(Alaska),Inc. Well N O1A Log Date: January 13,2016 Field, Prudhoe Bay Log No . 17043 State Alaska Run No.: 2 API No 50-029-20079-01 Pipe Description. 4,5 inch 12 6lb. 13CR TC II Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,819 Ft. (MD) Pipe Description 4.5 inch 12 6 lb L-80 IBT-M Top Log Interval: 80819 Ft.(MD) Pipe Use. Liner Bottom Log Interval: 9,413 Ft.(MD) Inspection Type : Corrosive&Mechanical Damage Inspection COMMENTS : This caliper data is tied into the XNNipple at 8,807 feet(Driler's Depth). This log was run to assess the condition of the tubing and liner logged with respect to corrosive and mechanical damage. The caliper recordings indicate the 4 5 inch tubing appears to be in good condition with respect to corrosive and mechanical damage,with no significant wall penetrations,areas of cross-sectional wall loss,or ID restrictions recorded. The caliper recordings indicate the 4 5 inch liner logged appears to be in poor condition with respect to corrosive and mechanical damage Wall penetrations ranging from 41%to 100%wall thickness are recorded throughout the liner logged. Recorded damage appears in the forms of multiple holes and line corrosion. Thirty-five percent cross-sectional wall loss is recorded in a hole in joint 219(9,327 feet) Heavy deposits are recorded in joint 216,restricting the I D to 3.17 inches at 9,185 feet. A graph illustrating minimum diameters on a joint-by-joint basis of the tubing and liner logged is included in this report. The body region analysis and joint tabulation sheets for the 4 5 inch tubing and liner are combined in this report. This is the second time a PDS caliper has been run in this well and the first time the 4,5 inch tubing and liner have been logged. MAXIMUM RECORDED WALL PENETRATIONS : Multiple Holes 100 219 9,327 Ft. (MD) Multiple Holes 100 216 9,185 Ft. (MD) Multiple Holes 100 217 9 249 Ft (MD) Multiple Holes 100 218 9 290 Ft. (MD) Hole 100 207.6 8,336 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Multiple Holes 35 219 9,327 Ft. (MD) Hole 25 207 6 8,836 Ft. (MD) No other significant areas of cross-sectional wall loss(> 18%)are recorded outside of the perforation intervals throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS : Heavy Deposits .3.17 in 216 9,185 Ft. (MD) No other significant I.D. restrictions are recorded outside of the perforation intervals throughout the tubing and liner logged. • • PDS Report Joint Tabulation Sheet WeliN-01 A Survey Date. January 13, 2016 Feld- Prudhoe Bay Analyst. j Paizis Company BP Exploration (Alaska), Inc Ppe Description Nan ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf 13CRTCII Tubing 3.958 in. 0271 in 41t 8,819 ft. 4.5 in. 12.6 pp L-80 IBTM Lirer 3.958 in. 0271 in 8,819 ft. 9,413 ft Joint Jt Depth Pen Pen Metal Min Damage Profile No (Ft) , 0:,.:' Body % Lo I D Comments e% (.owalU (in_) (in) 0 50 100 186 7798 0 002 7 CC 3.91 187 , 7839 2 002 8 2 3 91 188 7881 0.02 3.89 Lt Deposits 133.1 7923 0.03 13 1 3 91 Pip 188.2 7934 2 0 0 0 3.81 GLM 2 (Latch 0 4:00i 188.3 7940 003 10 2 3 90 Pip Lt Deposits. 189 7949 2 Q02 8 2 3.90 190 7991 0.02 7 C. 3.90 191 8032 002 8 3.89 Lt Deposits 192 8074 2 0.02 7 2 3 90 Lt Deposits 193 , 81 16 2 0.02 7 3.90 , 194 8158 r 0.03 1 I 3 3.9Q LL Deposits 195 8200 2 002 7 1 3 91 196 8242 ,. 0.02 7 2 3.89 Lt Deposits 197 8284 2 002 7 2 3 90 _ Lt Deposits 198 8326 2 0.02 6 1 3.91 199 8368 4 Q02 7 2 3.89 Lt Deposits 200 8411 0 0.02 7 1 3.90 Lt Deposits 201 845.3 003 9 2 3 90 Lt Deposits r 202 6495 2 001 5 3.89 Lt Deposits 11 203 8537 C 0.02 9 3 3.89 . Lt Deposits r 203.1 8579 .. 2, 0.03 1 1 1 , 3.91 Ptp 203 2 8590 0 0 0 3.81 GLM 1 (Latch 10301 203.3 8596 0.03 11 1 3.91 Pip N 204 3606 2 004 14 3 3 91 205 8648 2 0.02 6 3.91 206 8690 0.02 8 3 3.90 LL Deposits. III 206.1 8731 2 0.02 7 1 3.90 Pip ■ 206.2 8741 C 0 0 0 3.76 4.5" HES X Nipple 206 3 8743 0.02 6 2 3 88 Pip Lt Deposits 0 206.4 8753. 0 0.02 1 1 3.91 Pip 203 5 8762 0 0 0 3.81 7"x 4.5"BakerS-3Packer 206.6 8767 2 0.01 5 0 3.89 Pip Lt Deposits. 206 7 8776 0 001 5 1 3.91 Pip ii 206 8 8786 C 0 0 0 3.76 4.5" HE S X N ipp le 206.9 8787 2 0.02 6 1 3.90 Pip It Deposits. 207.1 8797 002 8 1 3.90 PW 207.2 8807 0 0 0 3.68 4.5" HES XN Nipple 207 3 8808 0 0.03 10 1 3.39 Ptp It Deposits. 207 4 8819 0 0 0 0 3 80 4 5"WLEG 207 5 8819 C 0 0 0 _ 4.33 7"x 5" BakerZXP Lirer Top Packer 207 6 8835 0 43 1C.0 25 3 9) Tap of 4 5"Lire r Pin Hole in Linnet'Holel 207 7 8836 0.25 93 L' 3.90 _Ptp Hole in Upset! Posible Hole!Lt De..sits. 208 8840 2 i,. 0.1 7 , 6 1 10 3.88 Lire Corrosion Lt Deposits. 209 888 0.11 _ 41 4 , 3.35 Lire Corrosion It Ce ceits. 210 8921 0,1 7 64 6 3.87 Lire Corrosion It Deposits. 211 8962 , 2 , 0.12 45 _ 6 3.88 Lire Corrosion Lt Deposits 212 9003 L , 014 .50 388 Lire Corrosion a 1'eoosit 213 9045 0.14 50 3.86 Lire Corrosion Lt Ceposits, 214 9037 t. , 0 16 59 9 , 3.90 Line Corrosion IPenetration Body Metal Loss Body Page 5 • • PDS Report Joint Tabulation Sheet Welt N-01A Suney Date January 13,2016 Feld Prudhoe Bay Analyst. j Parzis Company: BP Exploration(Alaska),Inc. Ppe Description Nan.ID Body Wall Top Depth Bottom Depth 4.5 in 12.6 ppf 13C R TCI I Tubing 3.958 in 02 71 in 4 ft 8,819 ft 4 5 in. 12.6 ppf LB0 IBTM liner 3.958 in 0.271 in 8,819 ft 9,413 ft. joint jt Depth Pen. Pen. Metal Min Damage Profile No. (Ft) nyz-; Body % loss I.D Comments ('/wall) (in.) % (in) 0 50 100 215 9128 034 100 10 3.89 Hole!It Deposits 216 9170 1 33 100 1 I 3 17 Multle Holes!Heaw Deposits. 217 9210 0 72 ftp 11 3.76 Possble Hole in Upset!Multiple Holes!It Derr. • 21: 9,93 '.6' 11a 1' 3.:. Mult•le Hol-s! t De•osi.• 219 9291 1.51 100 35 3.80 HPI?in Vt7set'N'Multple Hplesl It Deposita. 220 9334 1.95 100 100 3.28 Perforations Heaw D Posts ! U 221 9374 058 100 67 3 Perforation; Depw is 222 9413 0 04.3 100 26 3 54 Perforators DYposic I 1 Penetration Perforatiors n Peretrauon Body I Metal loss Perforations metal loss body • • 0 Producer 7/5/2010 Last PPROF, Teehlo M)nilog gas jet found,did not g Project PBU_GDWFI Well. N-01 A get splits &Thor Laura J.Larson Scale 1 700 3/2/2013 Last RST Date 9/1112014 E Wvte.,, 73.1$ x.434414 sfne)(Are ._..._ - .. USA E wvat.;n rietx,KR • 3+14742211 COIVItM,..:04 20 40 .1$02 0000 ,,„„. N.a D 11' 9730 L .*44111034M Surto . vrudnar Dry Cac' '1a•Spxtrre .4r.;x1p 70.3113397 ;rre«p...s11 Ck+++aec* SPX .. avxA. —7- 41111111111 GR 0� BESTGR x - ,0 AIN 7,407' PE Info v , Rote Of Prnetrotfor) TVOSS (FEET)0 ?VOSS R(S_8fP REST ROP 81ST GH.ROtIP O rO 0 ft/hr Sp0 t:700 3 1:700 . a �t ' ► ;r t 0 2 OHMM 200 T 8690 TSHAr.r.• -$700 7/5/200860C 9287' 3720'1 -alio ~ 3/2/2013 GOC r&T -ono 9290.5'MD(-87235') ilf I 9300 8730 k Gas jet @ 9360', i ' i 8740 { , couldn't get sp`li`ts 8750 r $760 -{ `. 9400 f $770 _ ... .. $ 6/24/2010 PPROF ' it I $790 tag TD Y 9438' 9500 ( 81000 as10 * j t , 8830 8840 8850 f_,._ qb0 f $17i0 -safi0 9700 . 5890 - 8900 1 f 1 TREE= 4'CIW • WE LLHFAD= I143EVOY N i A A SAFETY NOTES. t**OOOA HAS 14-40 CSG.MAX ACTUATOR= BAKER C MIT-000A 1200 PSI*** KB.ELEV= 62.10' ***4-1/2"CFStOME TBG*** BF.E.EV= 43.19' KOP Max = le 68° 92 )— j — 1900' H13-3/8"DV PKR Angie- @ Datum P43= 9487' Datum TVD= 8800"SS I 2187' --14-1/2'FES X MP,D=3.813" O ! 2291' H10-3/4"DV R<R I 20"CSG,133#/94#,K-55/H-40,D=19.124" }— 2088' -1 2426' 10-3/4"x 9-5/8"XO 10-314"CSG,55.5#,N 80,D=9.953" ----1 2426' •1 2426' 1—TOP OF COMENT(7'TIEBACK LW) F1 Gr�S LEr MA MJF S �/• ST PA) TVD DEV TYPE VLV tATCHI PORT DATE 1 5 3289 3288 3 KBG2 DMY BK 0 01/14/16 13-3/8'CSG,68#,K-55,D=12.415" —{ 4200' ` 4 5536 5589 0 KBG2 DMY BK 0 01/14/16 F 3 7208 7201 2 KBG2 CMY BK 0 12/21/12 1 Minimum ID = 3.725" 8807' ►� 2 7935 7908 27 KBG2 awry BK 0 08/04/04 �� 1 8589 8392 50 KBG2 !)AAY ( BK 0 01/14/16 4-1/2" HES XN NIPPLE I � 7171' 1—7"BKR TIEBACK SEAL ASSY w/CMT FORTS,D=619- 7"TEBACK CSG 26#,L-80 BTC,D=6.276" H 7181' 7171' —9-5/8"X 7°BKR ZXP LNR TOP FKR f &FMCLNRHM3R,13=6.261" MILLOUT WINDOW 7318'-7332' 9-5/8"WFIPSTOCK H 7316' 9-5/8"EZSV(07/25/04) —I 7335' 8742' —14-1/2"HES X NP,D=3.813" TBG STUB(07/03/04) — 7514' 8752' J—J 7"x 4-1/2"BKR S-3 PKR,D=3.875" •, 8786' H4-1/2•1-ES X t4F D=3.813" , It a _ _ .* �r �` ', , I 8807' H4-1/2"HES XN NW,D=3.725" IR 9-5/8"CSG,47#,N-80,D=8.681-"1--ng$09—'—' —I • 8$1$' —7"X 5"BKRZXPLW? I \ TOP FKR&HMD LM V99997777 4, 1 GR ID=3.958" T 8819' —4-1/2"WLEG, PERFORATION SURIVA. Y D=3.958" RFT LOG:SWS-BFCS ON 10/09/70(N-01?) ���14r4 ���v�� "p`1 j` 8838' 1—5"X 4-112"X0, ANGLE AT TOP PERE:67°Q9355' - i D=3.958" Note:Refer to Roduction DB for historical perf data 4-1/2"TBG,12.6#,13CR TCI1, -{ 8819' SIZE SIE INTERVAL SHOT DATE SQZ .0152 bpf,D=3.958" 3-3/8" 6 9355-9375 0 07/25/08 ` / 2-7/8" 6 9380-9394 0 04/26/06 7"LAR,26#,L-80 BTC,.0383 bpf,D=6.276' --f 8968' I ` 01 DO 2-7/8' 6 9380-9420 0 09/18/04 2-7/8' 6 9394-9417 0 02/18106 2-7/8- 6 9430-9455 0 09/21104 fb. PSTDH 9662' j ` 14' Ito 1. 4-1/2"TBG,12.6#,L-80 ET-M,.0152 bpf,D=3.958' H 9748' DATE REV BY COMMENTS DATE I REV BY 00IVIMENTS PRUDEBAY (KT 07/24/74 ORIGINAL COMPLETION 12/27/12 i RKT/JM) GLV GO-SET XXN PLUG(12/21-2: WELL: N-01A 08/10/87 RWO 01/28/13 TRP/JIA) TRE GO(01/12113) PERMt No:"`2041130 08/07/04 N7ES SIDETRACK(N-DIA) 01/28/13 AM/JM) RLL XXN PLUG&GLV GO(01/24 AR No: 50-029-20079-01 04/26/06 GJB/PJC PEW CORRECTION(2/18/06) 01/26/16 S M JJlOD GLV GO(01/14/16) SEC 8,T11 N,R13E, 1519'FSL&556'FWL 04/26/06 GJE3/PJC ADPEFF 09/05/08 JLYPJC PERE(07/25/08) BP Exploration(Alaska) • • d Q O O O O o 0 0 0 CD N O C() N 0 ) LU Cl) L o O V to LU ' CCS LO N- 0 N O o 0 0 0 0 D 0 0 L N CI) N LC) �t CC) CO CO 3 Cr) (U CO N N ' tt m CV N- N COr` N- CO CO 0 0 — LC) CD CO 0) O CD 0) LC) N V N- N CO CO CO H CO CA N 00 O r` O CO CO NI- CO c- CO N N .- (n N N- CO = a r CD O O r O N COCA O) E O OOC) N- a) vco .ctN r r N V C7) r` CO Z N tt r` (N CO 0) CO I I I I +�+ Z aO O CO O) N O O 1- D) 1"-- • } `} CO - CO N N '- CO N r = a -0m � w o CD O LU LUL° ° C � Lc) .zrY O Z O J co C co J Ln J CD N N CO CO Co *k Xi *k c LU co cN N 00CO - O (C) N O N- 00 N N _ U f:LO co co N CV N N N CO t co d N- CD O C.) C.C) r O) O C)) d N (A 0O N N O ~ �t r` N CO W W ,000 Q Q C H H H W 0 '- 0000 (a » DQ22 0 0 a o o c ecc Z ZZZc W W W Wpp O 00DFHzzj O 00cgzZJJ � • . N IC m CO Ln O CO L O V' 1,-. V O M p O I� O H a, M M M▪ 0 0 0 0 0 CO CO 0 CO F Q O 1 LC) CO LC) 0) M r t.+ N O) V' I- V LC) O- N N O O 0 O N M CO CO ct LC') 0 0 0 0 0 0 0 O co co co co co co 0 w W 0 0 0 w Z w w O a w 0 J W gg Y � ° ° Q m O O w Y Y J 0 U w W ++ r Q N- 0) O N LOC) < < < w a a Z c CD as co co V• V' NI- _0 Z 0_ Z 0_ J W W J O O O I 0 O) 0) O Z O J J 0 Z < < < = a 00 a t2 ww --w 0—II(`) Z 2 2 2 O co cn co co co • n Q Q 0. C w IC) � Or- O O N M coOco 0 : .-. 666666 W � Oa it 2 2 O u) cn cn cn co C d no y o 0 U u_ LL LL LL LL m d d d d d W m < a r CC d Q 0 t a> a. a) I- m O CO CO CO CO ;-D j 0 0 0 0 0 0 0 0 0 O O O O O O O W J J Z O N N N N N N Z a 1 1 < w ri NNCVNN � za � � � 0 uWLU LLW • N N- Q 0 _ J 1- J J J a J J 0 < Q m d 11ci) LL LLL. IL cn a a a) E m Z Q Q Q Q Q Q z O o O O O O 0_ C/") CO U- d w a Z Z Z Z Z Z < < m m LL a cn U) a cc • • Packers and SSV's Attachment PRUDHOE BAY UNIT N-01A SW Name Type MD TVD Depscription N-01A PACKER 7184.1 7177.28 7" Baker ZXP Mech Top Packer N-01A TBG PACKER 8763.33 8504.36 4-1/2" Baker S-3 Perm Packer N-01A PACKER 8826.25 8543.97 5" Baker ZXP Top Packer r/'t® L,PR 12 2Ui PRINT DISTRIBUTION LIST BAKER HUGHESPlease sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. DATA LOr^7=D Petrotechnical Data Center,LR2-1 4 Mt, , 4, WELL NAME N-01A 900 E.Benson Blvd. Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE February 25,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE April 11,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF Hi-IIN I S #OF COPIES #OF COPIES #OF COPIES 4 4 4 4 4 4 U 1 BP North Slope. I 0 0 I 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 I 1 I 1 I 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 I 1 I 0 I 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 I 0 I 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** im.:11. I. 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 I 0 I 0 I 0 0 Petrotechnical Data Center,LR2-1 2Ut6 900 E.Benson Blvd. ������� JUN 1 1 V I Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 ::# , 0 TOTALS FOR ALL PAGES: 0 4 4 0 ' . 0 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, December 31, 2015 3:12 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Vohra, Prachi;AK, OPS Well Pad MN;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: NOT OPERABLE:Injector N-01A(PTD#2041130)Injector Conversion All, Injector N-01A(PTD#2041130) has been reclassified as Not Operable until well is ready to be brought online after completing the conversion from Producer to WAG Injector well.Sundry#315-330 have been approved for this conversion, with an AOGCC witnessed MIT-IA required once the well has stabilized on injection. Plan Forward: 1. Slickline: Set Dummy Gas Lift Valves, Caliper 2. Fullbore: MIT-IA 3. Electric line: Set CIBP 4. Slickline:Set SSSV 5. Operations: POI 6. Fullbore:AOGCC witnessed MIT-IA once well has stabilized Please call with any questions. Kevin Parks (Alternate. Whitney Pettus) BP Alaska-Well Integrity Coordinator scow SEP 1 9 2016, GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator('bp.com 1 Jo«► ao1-1' 3 Loepp, Victoria T (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Thursday, June 25, 2015 2:18 PM To: Loepp,Victoria T (DOA) Subject: Clarification to Sundry#315-330, 315-331 &315-332 Follow Up Flag: Follow up Flag Status: Flagged When I submitted the 10-403's&associated documents for the conversion of N-01A, N-07A& N-27 from producers to injectors, it specified that the AOGCC witnessed MITIA will be at 4000 psi. This was incorrect-the AOGCC witnessed MITIA will be at 2500 psi. Please advise if this affects the sundry approval and/or what additional documentation you need. Thanks, Denise Bailey H, N, D&Q Pad Engineer (907)564-4749 denise.bailey@bp.com SCANNED JUL 2 12015 1 V ©F Ty \ �,s� THE STATE Alaska Oil and Gas of/� T j\ }(j\ Conserva ti©n Commission l 11333 West S eventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "•''� Main: 907 279 1433 OFALASICP SCANNED Fax 907 276 7542 JUL 0 8 201 www.aogcc.alaska.gov Denise Bailey 1 Pad Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-01A Sundry Number: 315-330 Dear Ms. Bailey: 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, Daniel T. Seamount, Jr. Commissioner DATED this 'tday of June, 2015 Encl. RECEIVED STATE OF ALASKA MAY 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION �F to APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25 280 1.Type of Request. Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well ❑ Other Convert to Injector • 0 2.Operator Name: 4 Current Well Class 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 204-113-0 ' 3 Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20079-01-00 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU N-01 A Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL0028282 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft) Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft). Plugs(measured): Junk(measured) 9750 ' 8980• 9662 . 8944 - None None Casing Length Size MD TVD Burst Collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment Surface 4182 13-3/8"68#K-55 30.69-4212.27 30.69-4207.75 3450 1950 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft) Perforation Depth TVD(ft): Tubing Size: Tubing Grade Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 24.39-8820.86 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for I" 15.Well Status after proposed work. Commencing Operations: c: a�`5 OIL ❑ WINJ I] WDSPL ❑ Suspended 1=116.Verbal Approval. " l Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Denise Bailey Email Demse.Bailey@BP.Com Printed Name Denise Bailey Title Pad Engineer Signature coli.:) Phone 564-4749 Date 5/94/15 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 315-33C) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test LI/ Location Clearance ❑ Other: arta tr. kv:trr CSS'cd v1,3 J 7-J.-) r-c 'i're c/ t Fre-,- sty. &/ 71- e.ci i y r c /, zk i Spacing Exception Required? Yes ❑ No Subsequent Form Required. /G — 4 0 4 APPROVED6 /1 Q/f1S Approved by- COMMISSIONER THE COMMISSION ION Date: l ( OI \/Cp T6 I NI fol 7 „,•,,,,, >, zv, rS' Form 10-403 Revised 5/2015 p v p I at valid for 12 months from the date of approval. Sub t rm and Attachments in Duplicate RBDM JUN 2 5 2015 NO O Lf) Ln O O O O LU co a v Ln L() co O 0o ao LO r, Ur = Y Y J Z J J Y c Q O 0 0 0 0 0 00 0 LU O O N O Ln 0 L V O Ln O) LO p LU Ln V U o 0 0 0 0 0 0 0 0 L M N N V 1-1) V CO Lf)Lo co co cv cv M N N N CO f- CO CO CO 4) (B O V O) V 0) OO CD O 0 0 N N M I- OV N N- N V (D O O00 V CON Ln N a I- Q ~ O CO O O N I� O CO V V Q M N N - LO M N 1 CO >'s I- L (aN E co C (N coo '- 0ci) 0 0 0 0) N 00 m O O M N CO V N a 7_ N ' I- N 03 0) (N4 00 V 00 D 0) Q � J o0_ (n Q0 M f— D O (V N O - GD N U Q co N N co co N CO O CO O L L0 LL) ' CO 1U 0 0 Ln Ln o Z o J Y M Y 00 1,k °0 co 4:k = J LU J N *k M M *k Ln *k N O (0 ei) Oco N - co _ OO N o O N co O M N N N N T V O V O N- N CO O N- O O O) O 6) O O N- N V N- N- J O ti N O V CO W W 0) 0000 - . o o W W W coDDD22 QU 0 0 0 Q CC CC CC CC LL Z Z Z Z W W W W ED- c.) o o UUU _1c/) 1— Perforation Attachment ADL0028282 Well Date Perf Code MD Top MD Base TVD Top TVD Base N-01A 7/25/08 APF 9355 9375 8822 8830 N-01A 7/25/08 RPF 9380 9394 8832 8837 N-01A 7/25/08 RPF 9394 9400 8837 8840 N-01A 7/25/08 RPF 9400 9417 8840 8846 N-01A 7/25/08 RPF 9417 9420 8846 8848 N-01A 9/18/04 PER 9430 9455 8852 8861 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028282 Well Facility Type MD Top Description TVD Top N-01A PACKER 7184 7" Baker ZXP Mech Top Packer 7178 N-01A PACKER 8764 4-1/2" Baker S-3 Perm Packer 8505 N-01A PACKER 8819 5" Baker ZXP Top Packer 8540 Area of Review PBU Wells N-01A (API No: 50-029-20079-01) N-07A (API No: 50-029-20137-01) N-27 (API No: 50-029-233656-00) This Area of Review is required prior to the conversion of N-01 A, N-07A and N-27 from producers to WAG injectors. This AOR discusses wells within 1/4 mile of each well's entry point into the Sag River formation. Current Status: N-01 A is currently an operable producer. The last well test on 05/02/2015 indicated 590 bopd, 57% watercut, and 21,281 scf/bbl GOR. N-07A is currently an operable producer. The last well test on 10/06/2013 indicated 0 bopd, 100%watercut. N-27 is currently an operable producer. The last well test on 04/26/2015 was 655 bopd, 28% watercut, and 33,962 scf/bbl GOR. All three of these wells are scheduled to be converted to WAG injectors in 2015 as part of the N-pad UZI (Updip Zone 4 Injection) Project. The UZI Project targets remaining oil where the gas cap has expanded into zone 4, and the gravity drainage process is less efficient. The UZI Project achieves improved recovery through pattern injection of water and/or MI. The area of UZI potential is generally identified as immediately upstructure of the existing WF/EOR area. If planned facility work to install MI and water injection headers is completed as scheduled, N-07A will be ready for injection as early as Q3 and N-01 A and N-27 in Q4 2015. N-01 A pf74,0 erhQ'Y Oil /Iegio7 for N-01A Completion: Con c if. GP y Cer ye,-t,''', ry f we//. �/, - 6'/�,j N-01 A is a conventional (max angle is 68°) well that was sidetracked in September 2004 in zone 4. It was side-tracked with future UZI injection potential in Z4. It is currently being pre-produced while waiting for approval and construction of the UZI project. N-01A is completed with 4-1/2", L-80 tubing (wellbore schematic Figure 1). To convert it to an injector, a plug will be set above the existing zone 4 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. - The original well was drilled in 1970 and it was sidetracked in 2004. A CBL shows that the cement behind the waspoor.original 9-5/8" casingHowever duringthe sidetrack in g 2004, a new 7" liner was installed from 8,968'MD to 7181' MD' with a 7" scab liner cemented in place from 7181' to 2426'MD. The liner was cemented with 35 bbls of 15.8 ppg Class G cement. The estimated TOC is 7,884'MD. There are no cement bond logs for this section of pipe, but no abnormalities occurred with this cement job. 4-1/2" tubing was installed from surface to TD @ 9748'MD. It was cemented with 27 bbls of 15.8 ppg Class G cement. No abnormalities occurred with this cement job although—15 bbls were circulated back to surface. Operation of N-01A as a WAG injector is not seen as an issue as long as the well passes - an MIT-IA. The most recent integrity tests are: Dec. 22/2012—MIT-T to 2,500 psi passed (plug @ 8,807'MD) 12/21/2012 —MIT-IA to 2,500 psi passed 1/29/2004 — MIT-OA to 2,500 psi - passed N-01A Area of Review The wells within 1/4 mile of N-01A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Three individual wells (including the N-01 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-01A 50-029-20079-01 ---- TOC calc to be above injection zone behind 7" N-01 50-029-20079-00 1010 7/24/1974 CBL indicated fair cement quality above the Sag. The cement was poor quality in most places - however there was a good section (50') of cement existing (between 8,660- 8,710), combined with production history that had no evidence of barium scaling (which would be indicative of communication with the Cretaceous). These factors indicate zonal isolation. N-14B- 50-029-20594-70 1230 . Only plugback is in AOR & it was cemented. PB1 However the TOC for the 7" liner of the parent well is calc to be above injection zone N-17 50-029-20898-00 1280 TOC calc to be above injection zone behind 9- 5/8" Well Name Csg Hole Volume of Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-01A 7" 8-1/2" 35 bbls of 15.8 ppg Class G 8,968 8,957 N-01 9-5/8" 12-1/4" 9,309 8,613 82 bbls of Class G cement 310 bbls Class G gel N-14B-PB1 7" 8-1/2" PB: 8 bbls of 17 ppg class G 9,405 9,524 7" Liner: 59 bbls of premium Class G 15.7 ppg N-17 9-5/8" 12-1/4" 206 bbls 15.8 ppg Class G 8,720 8,758 23 bbls 15.7 ppg Arctic Set I NOTE: All calculated TOC's assume 30% washout of hole. N-07A N-07A Completion: N-07A is a conventional (max angle is 66°) well that was sidetracked in July 2004 in zone 2B and 2C. It was side-tracked with future UZI injection potential in Z4, and was pre-produced while waiting for approval of the UZI project. N-07A was online as a producer from 2004 until 2013 when it reached high GOR. An unsuccessful squeeze was attempted in mid-2013 and the well has been offline since. N-07A is completed with 4-1/2", 13-Cr tubing & 4-1/2", L-80 liner(wellbore schematic Figure 2). To convert it to an injector, a plug will be set above the zone 2 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. The original well was drilled in 1974 and it was sidetracked in 2004. CBL's were run in 1974 and 1985. Both confirmed good cement for the 9-5/8" casing above 10,150'MD, with the TOC above 9,650'MD. The 9-5/8" casing was cemented with 1270 sacks of Howco Light cement and 41 bbls of Class G cement. As part of the July 2004 sidetrack, a 7" scab liner was installed from surface to 8,921' MD. This was cemented with 106 bbls of 12.5 ppg Litecrete followed by 57 bbls of 15.8 ppg Class G cement. A 4-1/2" L-80 liner was run from 9,826' to 10,832'MD and cemented with 27 bbls of 15.8 ppg Class G cement. No cement bond logs were run in the liner as the tubing wasn't pulled. However a Borax log to look for channeling was run in 2006 and it indicated some channeling around the current perforations only. Operation of N-07A as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: 7/7/2013 MIT-IA to 2500 passed 9/17/2013 —cmt sqz— MIT-T to 1500 psi passed 7/22/2004 - MIT-T to 3500 psi passed 3/24/2001 —MIT-OA to 1500 psi passed N-07A Area of Review The wells within '/4 mile of N-07A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells (including the N-07 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-07A 50-029-20137-01 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-07 50-029-20137-00 95 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-20A 50-029-21320-01 600 The 9-5/8" casing doesn't have good cement (according to CBL) in the N-20 parent wellbore. However the casing and parent wellbore is outside the AOR. Only the liner of N-20A sidetrack is in the AOR. There are no CBL's or Borax logs to show quality of cement in liner- however after 11 years of production, the well is still competitive and there's no communication with the GOC in the heel. This means that the —2000' of cement(based on volumes pumped) above top perfs provides isolation from the heel (and thus parent well). Well Name Csg Hole Size Vol Cement Csg Top of size shoe Sag (MD) depth (MD) N-07A 7" 8-1/2" 41 bbls of Class G 10,642 10,005 1270 sacks of Howco Light N-07 7" 8-1/2" 41 bbls of Class G 10,642 9,998 1270 sacks of Howco Light N-20A 4-1/2" 6" 70 bbls of Class G cement 12,585 9,315 NOTE: All calculated TOC's assume 30% washout of hole. N-27 N-27 Completion: N-27 is a conventional (max angle is 26°) well that was rotary drilled and completed in November 2007 in zones 3 & 4. It was drilled with future UZI injection potential in Z4 and was pre-produced while waiting for approval of the UZI project. N-27 is completed with 4-1/2", 13-Cr tubing and 4-1/2", L-80 liner(wellbore schematic Figure 3). To convert it to an injector, the wireline retrievable plug (set in 2008 to isolate water in zone 3 perfs) will be pulled if possible, a new plug will be set above the existing zone 4 perforations (to ensure zonal isolation) and new perforations will be shot in the bypassed oil lens in zone 4. When the well was drilled and completed in 2007, a 4-1/2" L-80 liner was run from 8,795 to 9,503'MD and cemented with 24 bbls of Class G cement. The 7" casing was run from 26' to 8,967'MD and cemented with 132 bbls of 12 ppg Lite Crete and 38 bbls of 15.8 ppg Class G. A CBL was run on September 12, 2007 in the 7"casing and it indicated an adequate cement bond with the TOC at 6,350'MD. A subsequent CBL run on November 28, 2007 showed a good cement bond in the liner. Operation of N-27 as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: 8/16/2011 MIT-IA to 3000 psi passed 7/9/2011 —MIT-OA to 1200 psi passed No MIT-T N-27 Area of Review The wells within '/4 mile of N-27 are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-27 50-029-23365-00 9/12/2007 CBL indicated TOC @ 6,350'MD with an adequate bond N-16 50-029-20886-00 710 TOC caic to be above injection zone behind 9- 5/8". N-30 50-029-23523-00 1200 TOC caic to be above injection zone behind 7" Well Name Csg Hole Vol Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-27 7" 8-1/2" 132 bbls of Litecrete & 38 bbls of 8,967 8,964 Class G N-16 9-5/8" 12-1/4" 296 bbls Class G with gel 13.2 ppg 9,686 9,688 102 bbls Class G 15.8 ppg 23 bbls Arcticset 15.7 ppg N-30 7" 8-1/2" 47.3 bbls 15.8ppg Class G 9,151 9,150 NOTE: All calculated TOC's assume 30% washout of hole. Plan Forward: 1) Obtain Sundry for conversion of all three wells to WAG injection. 2) Complete installation of produced water and MI headers. 3) Complete downhole work to convert wells to injectors. 4) Place N-07A on water injection in Q3 2015 (depending on timing of completion of surface work) 5) Place N-01A on MI in Q4 2015 6) Place N-27 on water injection in Q4 2015 7) AOGCC witnessed MIT-IA to 4000 psi on each well after injection has stabilized. TREE= 4'CIN ------ ---- — W13LFEAD- IICEVOY N-O A SAFETY NOTES:'"DOOA HAS H-40 CSG MAX ICA 1O C.- BAKER MIT-000A 1290 PSC" KB R FV- 62 1Q "'4-1/2"Cl-ROME TBC7" BL GLV- 43.19 KOP= - .. 39001900 {13-3f8'DV PKR Phu(Angle= 68'@ 9277 WtumtrD= 9467 ' — 2167 I4-1/2'I+SXNPID=1813' Datum TVD= 8800 SS ire _r _ 1-110.3/4'11111 /1140,10 /e98' H10-3/4'x 9-_JR"XO [r.V4"r t;,55 NF,M IIn.LI=5 953" I • 2426' 1 : 2426' 1-170POF CEMENT(7'TIEBACK I.NR1 1 --._.._.__.. O. 11451/I kNNMill:i1:31 •-'' 1.CT 4b TV1) DLV-Frlt- VLV 'iA1[-f;6'OKT PATE S 3289 3286 3 K1302 COM BK 16 01126113 1 13-318'CSG 6147,K-55.ID=12 415' } j 4200' 1. 1 CAN 4 5596 5589 0 iKBG2 DOBE BK 20 01/26/13 3 7208 /201 2 KBG2 DBK 0 127012 11,- 2 /935 /908 2/ ;KBG2 DAM BK 0 08'04/04 Minimum ID=3.725"s 8807' y I 8969 61192 1'0 KNt.:l DAM BK 0 12121/12 4-112"HES XN NIPPLE ►� 7171' I '7BMI KRTACKSEALASSY w;CMT FORT'S.D=6.I9' f r TIEBACK CSG 266,1-80 BTC,D=6.276' — 7181' 7171' 9-5/8'X r BKR ZXP LNR TCP PKR 8 RAC LN4F 613R.113=6.261' 19-snr WI'ST0Cit 1-$ 7316' I I MILLOU►WINDOW 7311'-7332' I Iavm r7cv rnvrmuno H 7336' I-- '/8C 871.8(07/03(04) 1--! X14• 5 �- 6742' M1/2'HES X 14P,D=3.813' N, 8762' HT'x 4-1/7 SKR 5-3 PKR D=3878' I • • 1, 8786'._.1-14-1;2'1-ES X NP,D=3-813' �' 8807' ] 141/?"1rRXNPIP,D-3725"5 El 1%4 C 9-5(T CSC.478,14-80 ID-8 881' —I 9309' 1 8818' 7 X 5'eKRZXPL TOPFKRaFN1CtNINT 4.4.1,4.8:6/ii-NGR ID=3.968' . \\ 8819' 4 1/2'V&1G, F$7FORATDM4A NSLRY - D=3.956' REF LOG:SINS-81-CS ON 10109/70(N-01?) 118114♦ 111. 4.!4.4.444.4!4 ` 8838' 1 5-x 4-1/2'XO, ANGLE ATTOPPERF':87°tg9355' ` D=3956' Note:Refer bReduction O6fot hetet-calpertdata 4-112'TBG.1264,13CRTCII, 8819'� j Set i SR INTERVAL SHOT GATE SOZ .oi51opt 0-3.958- 33/8' i 6 i 9355 93/5 0 0/25108 NR.288,t-80 BTC. 0383 bp' D-6 776' 6968' 2-718" 16 � 9380-9391 0 0426..06 r 6 I ' 2-715" I 6 9380-9420 0 091113,04 2-718' ) 6 9394-9417 0 02118106 2'7111 j 6 9430.9455 0 0921104 [Am —I 9667 4%6. I 1 .... 14-1;2'TBG12,68,L-80 f3T-M,.0152 bpf..D=3.958' I--t 9748' ' DATE REV BY I COM.(TS DATE RFV BY COkIRJTS I PRI.1[110FR.rAY(M 07/24/74 1011(914)6.1 COMPLETION 1227/12 RITIJMI) GLV/0-SFT XXN P 11G(1271-21 WR.I 14-01A 06/10/87 ,RMO 01128/13 TRRJMD TREE C/0(01/12/13) I P)GNTM.'2041130 •08.107(04 PRES tSK3ETRACK(1401A) 01178113 AM'J6L) NIL XXN PLUG 1 GLV 00(01/24 AP1 No. 50`879.200/9-01 04/2606 C-, JRC IMRE 00132ECT10N(2116836) SEC 8,TINA R13E 15119 F51_8556'ry 04/26106 GJB;PJC!AME 09/45/08 JOPJC 'PERT(071'2568) RPEcp4oretbrr(Alas ka) Figure 1 —N-01A Wellbore Schematic TRa = 4"FP' SAFETY NOTES-•"4-112"CHROME TBG'' VI•ELLEEAD= MCEVOY N-07A ACTUATOR= BAKER N TMLKB.IEE 6140' BF BEV= 4184': KOP- 3100 Max Angie- 64•tfil 10568' Drum U)= 10401' D rum1VD= 8800'SS 204.9 I--,9-518-� 2119' I 14-1/2"i-ES r NU,1.33 813'1 -2808' - 67'TOC OF 9-5/C X 7'K N14.244 I 13-3f8'CSG 7211,N-80,D=12347" 2817' 0. 9 if 0 i S rte_ �itr��tLIFT _��1EVnpC.a Minimum ID=3.725- 9811' + G 4 3315-.3309 13 KB2 00111E BK 16 0918/13 i 3 6313:5578 47 KBG.2; SO BK 20 09/18/13 � 4-112"HES XN NIPPLE ,. 2 8434 7190 34 KBG21 OW BK 0 07123/34 1 9617 8230 31 KB13.2 j Detr BK 0 07123134 LSCA B LNR 26#,L-60,.383 of,D=6.276" I 8921' i i • TOP OF r LIFER 8924' 8831' --F‘-'r x r 1i14QE L OVERS-110T L9-518- 56,4101,l-0 U- 681�0, 8. 1 9 ' ----C:-------- —635' I 8786' H.4_,,,-HE'S x NP,D-s 813• I 1,,;,,1 /) L 9767' ) L''X 4-112'BKR S-3 P101.D=3.875• I 9790' --I4-1n•FESXNP.D-3.81!' I C 9811' I 1.4.172-HES XN NP.D=3.725• 4-112'1B0,12 8*,13CR 99,.0152 Opt D=3.958" I 9824' 1 9824' --4 1!2-ALEG.D-3 958- .1 44 9826' -if X5-BKRZxPI_nH10PPKR8*GR.D-4.42' I PERFORATON SUMMARYJ REF LOG SLB PST/SCA/A ON 0604/04 9818' I 15X4-112"XO.D-3 580" I ANGLE AT TOP FERE 65°102 10606' -- — No1e-Refer to Rodeo bon DB for hwbrical pert data 14.LOUT 4110130W 10014'-1 SIZE SPF INTERVAL IOpn/5gz SNOT - SQZ 3-3/8" 6 10539-10559 ' S 08/10104 119114/13 33/8" 6 10571 10596 S 08/10804 09/14/13I 2-118" 6 10606-10676 0 09/71713 10470 14-172'MARKER JOM 3-319" 6 10634-10639 S 08110804 109'14113 i 1 11411411) I3-t+2"TBC,9.34,N-80,D=2.992' / 048$'_ L PITT,-I ; 10633' •�► ♦res s. ,-�►►4X►N, A.a.4.4.1..4-4.1 4.141' r LINK 298,Io,D=9,184 10642' — I PfIT0 H 10745' ;Mr i4-112'LNR12.139 L-99. 0152 ow.0=3-958' !-- 10832' DATE 1 REV BY (X*6E3TTS DATE REV BY COM48JTS FFZUDHOEBAY II0IT 01724177, OFIGINAL COMPLETION 09/26113 WEGJ.O GLV GO(09119113) WELL'N-07A 03121/89 MO 00/26/13 ATO/-9.0 AOPERFS(09/21113) PRAM Nr"2041050 07/23104 JAFILLH SIDETRACK(N-07AI All hla 50 026 20137 01 069104 4,Ii0i II H 01 V 12(1 51C:8,1119,N131-,7219'FSC.&511'FWI _0/'30 17* PJFIJ114) A111-)1-1-14-18-1-DA II-10/72n6/12) 03'26'13 i JGLiJ1.3 CMT SOZ(09/14/13) T _ _. - BP E4(plorallon(Alaska) i r 2—N- 7A Wellbore Fg u e 0 TREE- 4-1n6'ON WFI I HEADt1'FMIp SAFETY NOTES '"4 12"CHROME TBG"WELL ACTUATOR- BAKER N-27 TWINNED TO NOG FLOW LINE" KB.ELEV= 716' BF Et.EV= 458' - 1 KOP- 500' Max Angle- 26"@ 2160 = 411-4991' H9.S78"TAM PORT COLLAR,ID=S 73"_ Dat urn MD= 9162'.1 Dat urn P/0= 6800'SSI ya _2201' Ha-12-HESx NP,10=3et 3` I I20-COPDUCTOR,91.5#,440,ID=19.124' )-1-- 108' 0 ^ _ 19.8/6`CSG,471,1-80 BTC-M,D=888" H 3222' , GAS LFT MANDRELS ST MD NO DEV TYPE VLV LATCH PORT DATE 4 3811 3631 15 K602 DOME BK 16 09/17711 3 6100 5827 16 KBG2 SO BK 20 09/07111 I7 CSG 2B#,L-80 TUX()TOL-80 BTC-M H 4714' 2 7637 7301 17 KBG2 DAN BK 0 08/16/11 1 8629 6254 14 KBG2 DMY BK 0 09/16111 Minimum ID(N-27)=3.725"@ 8792' ' 412 a s x NP D=3 e1 r 4-112" HES XN NIPPLE g g 1122___ )(4-1f2"5KR.3-3 PKR 0=3.875 en--1 8761' H4-12'HES X NP io=3.813" 1 , 1 6797 H4-12'HES XN NIP,ID=3.725"I 8796' Hr X 5"BKR C-2ZXP LAP,1D=4.440" I 'TOPCfT LMR...) I 9795' 4-112'TBC.12 68.13C194110 VAM TOP 6804' ` 8804' I—'4717 4KEG.ID=3.958- 0157WT.0=3958 I 8813' HTHFLMDTTLOGOEO (64TEa 'X5'B141FLGJC-LDCK R,ID=4440 I 8823' HS"X 4.172"XO.D-3 946"I V CSG 284 L-80 B'C-M =5 275" r I 8967 J- ' f —� 9039' H 4-1/T Ma we;JONT PERFCR,I TION SUMMARY REF LOG.SLB MWLYGR ON 06/30/177 ANGLE AT TOP PERF:12°@ 9144' Note.Refer to Production 08 for N3100418 pert data SIZE NIERVAL ()paw DATE 33/8' 6 9144-9184 O 11)27/08 2-7,6" 6 9172-9192 0 11128437 L 9205�..}`{389'VVRP(0703109) I 2-7kf 6 9214-9219 C 11/28107 PBTD 9417' •1w, 1111111111 14,112'TBG,12.64,L-80 43T-M, 0152 bot iD"3.958' .I— 9503• DATE REV BY COMMENTS 017E REV BY COMMENTS FRWHOE BAY UNIT 09113/97 N7ES ORGINAL COMPLETION 09/01/08 JLJ/PJC GLV GG 10825/06) WEI I N-27 11126/07 JUPJC QV GO 12104/C6 TFAIPJC PERFORATIONS(11/271001 PERMIT No 2071040 12/15/07 TEL/PJC PERFOWA I ONS(11/2 101) 01131)09 RRLYPJC SET IARP(0710309} AR No 50-029-2131356-1X1 01114107 GLWPJC DRLG DRAFT CORRECTIONS 08117/11 GJB/PJC GLV 0/0(8/16/11) SEC 8,7111.1 R13E,2285'FSL&571'FWL 03/19/08 JGRR PJC ORLG DRAFT CORRECTIONS 09120/11 TN PJC GLV 0/0(0907/11) 07/1808 KSB/JMD GLV 00(07/061081 03129/12 LFA)JMD 7'CSG OCPTH OORRFGTON BP Exploration(Alaska) Figure3—N-27 Wellbore Schematic N-Pad UZI Injector 1/4 Mile Radius Map le-146 0 500 1000 I U.S.surveyor's feet - , -14A #'l`1'' 5970000 r ,Nil 4 1 -----••-44-04A 11 ' 148 ,0* ‘, ie •• 5969000 \11111141 '4111' t • 4,,, � A f ' ; ::: • •41/414414 • 20 tAr // Vt • •\ / 2 02A• 1 r 1 27 f � , 21 5966000 1 i % 12 09-06/.,_ 7 • -16 .4-31\0___ • 5965000 41.21A -05 5s?,n)o 634000 636000 638000 640000 Figure4— Map showing wells within 0.25 mi radius from N-01A, N-07A & N-27 Roby, David S (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Wednesday,June 10, 2015 3:38 PM To: Roby, David S (DOA) Cc: Richmond, Diane M; Lastufka,Joseph N Subject: RE: Sundry applications for conversion of PBU N-01A (PTD204-113), PBU N-07A (PTD 204405), and PBU N-27 (PTD 207-104) Please see my answers below. Please call at 907-564-4749 if you need further clarification. Thanks, Denise Bailey H, N, D&Q Pad Engineer (907) 564-4749 denise.bailey@bp.com From: Roby, David S (DOA) [mailto:dave.roby©alaska.gov] Sent: Tuesday,June 09, 2015 11:08 AM To: Bailey, Denise G Subject: Sundry applications for conversion of PBU N-01A(PTD204-113), PBU N-07A (PTD 204-105), and PBU N-27 (PTD 207-104) Denise, I'm reviewing your application to convert the three subject wells from producers to injectors and have a couple of questions for you. 1) If I'm looking at things correctly it appears that you're establishing a new flood patern and that these wells will be the initial injectors in this pattern, is this correct?Yes—these will be UZI (updip zone 4 injection) patterns. 2) It's pretty much a no brainer to convert the N-07A well to an injector since it has watered out but the other two wells are still pretty decent producers with reasonable GORs and water cuts. Why were these specific wells chosen for conversion? BP has had the idea for an UZI project in development for 8+years. There is oil stranded on the shale lenses that these injectors would sweep towards producers surrounding them. To complete this project,we've drilled new injectors(N-28& N-29) and are in the process of installing an MI and PW header to tie-in the converted producers&new injectors. The UZI injection on N-pad (including N-01A, N- 07A, N-27, N-28 &N-29)is meant to cover most of N-pad, particularly the areas where lenses have been seen in surrounding wells. The UZI reserves model indicates that the incremental reserves recovered by converting N-27&N-01A(and losing current production)are greater than if we leave them as producers. N- 27 well was drilled as a future injector-we just pre-produced it while waiting for the UZI project to materialize. N-01A was side-tracked earlier than N-27, but its secondary objective was to maintain options for UZI injection. The UZI project has been sanctioned by partners and has been included in the GPB IPA Plan of Development for the last few years. Thanks in advance, 1 have Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIAUTV NOTICE This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.roby@alaska.Qov. 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, May 28, 2015 3:05 PM To: 'Denise.Bailey@bp.com' Subject: PBU N-01A (PTD No. 204-113) - Conversion to Injection Denise, Regarding the planned conversion of N-01A to injection, please describe BP's surveillance plan for N-01A and surrounding wells that will ensure all injected fluids remain in zone. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ () y.. - 1 L:3 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 111111111111111I11I RESCAN J Color Items: o Greyscale Items: DIGITAL DATA \Ø'6iskettes, No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ , Date: III 8'/ 0 (p /5/ MP Project Proofing 11111111111 1111111I BY: ~ Dale II f? I 0 (p ~ x 30 = 100 Dale II R IO~ /5/ \Mf Scanning Preparation BY: ~ + 11 = TOTAL PAGES 71 (Count does not include cover sheet) ,,, A..D /5/ r V ~ I 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 7 &. Page Count Matches Number in Scanning Preparation: Date: 11 f 15/ 0 ~ (Count does include cover sheet) v/' YES NO BY: ~ /5/ \11f NO Stage 1 If NO in stage 1 page(s) discrepancies were found: YES BY: Maria Date: /5/ III II 111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111I1111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc 22505 O Lo O 0) O O O O O o 0 0 0 0 O 0 O 0 0 10000 O O O O O O O O O O O O O O O O O O U 1 r N • 1 r W O 1 CV 1 mr- I1 ! O 0_ a c a U r _ O `n iv ill a) u) 0 `- Q m 1 v cc, rn , z cc E ° 01 0.$:j cd a l7 rn v (q �S Y_� M M M M M M M M M M M N N CM N N CO M \.` = N Oa., 1 W ..1 W 1. . ti i .- _a U U c c Z. .Q v al r, O 0 R CO co co 8 a) c a) c c a) a) d to iv '•) a a 0) v o 1 x M cd U E m E 2 -) LL ' LL ' ' LL 0 0 -) 4 O a a LL v t .rn -J O v- Cr CO CO 0 0o �t N ,- in oo N C 1,��•' ��y .�.-UJ _ M N N N N N N N r- N CO N X d Q !mot Z ^Y C� ' 0 y O ZO J O Ce M X LL W LL r, LL LL } W 0' iia ce a. a' a' H Q' J W Q' F- X U O as 0 a W a -I > a W W CL �w m > > > W r > -) >- w — - 0 tn N J -I -100 -10 Y O O a a O J J J -I M Z i_ Z Z M 2 Z M a 2 M _ _ M Z Z F- Z Z U y 0 O W W U W W W W m m W U U CO U U I- v) E ; m i I- < X X X X X X X X X M N LL Z N X X X X X X X X X X a p a cc N 0 H '' J L N to W el (p M s- CO O C) M ,- t-- �' OC op O O) N M o0 Ce N R O M N �- O v- 0 Cl) Lu a- o 0 n o m 10 CD Z O O o N a- a- o o r a p O O O O o o O O O O O O o O O O O O CC O o O o 0 0 0 0 W p O 0 0 0 0 o 0 o O >>- CID o ? 0 0 0 0 0 = Q > > m 0 o m X X n X X X m n 2 Ce y 0 o -0 -+ a LL in in in �n n MEN •zr 0) Do O . o N CO U U U U U U U a U OD U U CO m CO U U 03 c ttO 'CS o • G7 ^ Co rn r. L _ Y Ql CO W r U r. CO CO : m CO i N o Q a) g = _ Q .- W CO a N m o r, O ,- o cn N el Cr, J C") La P� a� cc a w O O �- o �- N s �. N O• N O r 7 N O E.) -j CU fp @ m m Z O Z o C7 c a °r° N '� J a o W C'1 a, U CO 0 t LU l7 p .. N E p W t V)▪ O y > N Q " X d CO a) Q V o7/oB/t o $Chl~lllb~f'g61' N0.5557 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil b Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD .,u • • 04-45 AYKP-00086 JEWELRY LOG/PERF RECORD 06/25/10 1 1 L-203 P-28 63S0-00065 AYiM-00047 USIT USR ~ 05/02/10 O6/08/10 1 1 1 1 P-28 BB6M-00018 SONIC CBL 06/14/10 1 1 N-01A B-Ot N-16 AYKP-00092 BCRD-00031 BCRD-00032 PRODUCTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE 07/05/10 07/02/10 .07/04/10 1 1 t 1 1 1 W-21A H-02A B-13B H-23A BAUJ-DOD34 AYKP-00088 AYKP-00091 65JN-00048 MEMORY PROD PROFILE USIT SCMT RST 07/03/10 06/26/10 07/02/10 04/16/10 1 1 1 1 1 1 1 1 B-21 8350-00062 RST 04/28/10 1 1 \ BP Exploration (Alaska)Inc. Pelrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Slreat, Sutle 400 Anchorage, AK 99503.2038 ,~~)1~. ~ ~ ~Q1Q `~ 09/05/08 i ,a ~~ ~~Il~~m~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu .i„ti ~ NO.4865 Company: State of Alaska ,, y,~~~~: ~~~ ~ ~ ~~~~ Alaska Oil & Gas Cons Comm .. ~~. ~.. ~ x~~c' t. ~. Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... nn~...:..f:..., nose o~ r..~... nn L-205L1r 40016965 OH MWD/LWD EDIT 06/08/08 1 B-37 ~ 40017206 OH MWD/LWD EDIT 06/15/08 2 1 N-01 A • 12014032 RST 07/05/08 1 1 B-03B - 12083399 MCNL - CAL 06/07/08 1 1 01-03A 12017505 RST ( -a0~{ - (pgLf 07/15/08 1 1 01-23 12057631 RST (~ c(p 07/16/08 1 1 F-05A ~ 12083402 MCNL -(b 07/1?J08 1 1 09-30 11962609 RST - G( 07/24/08 1 1 rLCAAC NV nrvVVVLtU1at HtGtll' I tlT ,IIarvING AIVU Flt l UFSNIrv(7i UNt GUPY tAGtt I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ! ~',? 1 j' ~,~ZTT^~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950 2838 ATTN: Beth Received by: • y ~ ..,~ ~- STATE OF ALASKA ~ y ~ ~ ~~ ~~ ALA OIL AND GAS CONSERVATION COMt~ION 1U~ ~ ~ REPORT OF SUNDRY WELL OPERATI $ r.~ ~~~ {~. . 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ ,,,,,,,, , Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Exterision ~ '°`'~r'„ Change Approved Program ~ Operat. Shutdown Perforate Q ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' ~ Exploratory ~' 204-1130 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20079-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.88 KB PBU N-01 A ' 8. Property Designation: 10. Field/Pool(s): ADLO-028282 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9750 ~ feet Plugs (measured) None true vertical 8979.65 _ feet Junk (measured) None Effective Depth measured 9662 - feet true vertical 8943.75 feet Casing Length Size MD TVD Burst Collapse Conductor 2059 20"133# K-55 29 - 2088 29 - 2088 2320 1500 Surface 4172 13-3/8" 68# K-55 28 - 4200 28 - 4196 3450 1950 Production 7144 7" 26# L-80 27 - 7171 27 - 7164 7240 5410 Production 4890 9-5/8" 47# N-80 2426 - 7316 2426 - 7309 6870 4760 Liner 1797 7" 26# L-80 7171 - 8968 7164 - 8634 7240 5410 Liner 910 4-1/2" 12.6# L-80 8838 - 9748 8551 - 8979 8430 7500 Perforation depth: Measured depth: see attached - - _ _ _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 23' - 8819' 0 0 - Packers and SSSV (type and measured depth) 7" Baker ZXP Top Packer 7171 4-1/2" Baker S-3 Perm Packer 8762 5" Baker ZXP Top Packer 8818 0 0 12. Stimulation or cement squeeze summary: ~ ~ Intervals treated (measured): ~~16r A~G ~ ~ 208 , Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: shut-in Subsequent to operation: shut-in 14. Attachments: 15. Well Class after proposed work Copies of Logs and Surveys Run Exploratory ~ Development ~ Service ~'' Daily Report of Well Operations X 16. Well Status after proposed work: Oil '. Gas WAG GINJ ~' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble ~.~~~ c ~5~ ~O ~ `~` ~ ` d~ ~ ~ Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/28/2008 Form 10-404 Rwised 04/20(36 ~--~~~ ~ _ Submit Original Only n ~ ~ S ~F~ BUG ~ ~ 1000 ~ N-01 A 204-113 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-01A 9/18/04 PER 9,380. 9,420. 8,831.98 8,847.6 N-01A 9/18/04 PER 9,430. 9,455. 8,851.51 8,861.3 N-01 A 2/18/06 APF _ 9,394. 9,417. 8,837.45 8,846.43 N-01 A 4/26/06 APF 9,380. 9,394. 8,831.98 8,837.45 N-01 A 7/24/08 APF _ 9,400. 9,420. ,,/ 8,839.79 8,847.6 N-O1A 7/25/08 APF 9,355. 9,375. d' 8,822.25 8,830.03 N-01A 7/25/08 APF 9,380. 9,420. 8,831.98 8,847.6 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER __ BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • N-OlA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/24/2008 "`WELL SHUT IN ON ARRIVAL'`"` STANDBY FOR LRS TO LOAD TUBING WITH CRUDE. SPOT ELINE EQUIPMENT AND BEGIN RU FOR PERFORATING. **"JOB CONTINUED ON 25-JULY-2008*"" _._______.~_~ _ _ .__~.._____.___.__..~.._®~___.N_._.______.____~_~.~..._....__.~__ _._..._..__.___.___...w_.~_...__,_____.._.m. 7/25/2008 ""`JOB CONTINUED FROM 24-JULY-2008"'"' PERFORATE WITH 20' - 3.38" POWER JET GUNS INTERVALS 9400'-9420', 9380'-9400', 9355'-9375 WELL LEFT SHUT IN, MASTER-OPEN, SSV-CLOSED, SWAB-CLOSED, IA/OA- OPEN TO GAUGES. FINAL T/I/O = 1175/1450/0/0/0 PSI. *"'JOB COMPLETE`** FLUIDS PUMPED BBLS 1 diesel 1 Total • • ~, =;~r . , -• ~ o3~o~izoos DO NOT PLACE =.,.~ ~~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Nlicrofilm_Marker.doc · .02 't~':~, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: M-38A_PBI, N-01A, P-18 L1, S-18A, W-16A_PB1, W-32A PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 M-38A_PBl: U-1.~ ';)Ol-\'3'd-Û.l4i../lO Digital Log Images: 50-029- 22519-01, 70 1 CD Rom SCANNED FEB 0 1 2007 N-01A: g Cf.1- t 13 ìl 4/...{ 1/ Digital Log Images: 50-029-20079-01 P-18 Ll: dOd. - 03C1 ~ LI'-ID?s Digital Log Images: 50-029-22097-60 1 CD Rom 1 CD Rom S-18A: 6>Od - /03 it l£../L/I d. Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PBl: ~O"'3-IOO 1:1: L./L..!b9 Digital Log Images: 50-029-22045-01, 70 1 CD Rom W-32A_PBl: d08 -80'1 .!i t4L/13 Digital Log Images: 50-029-21790-01,70 1 CD Rom 7- Permit to Drill 2041130 MD r' 9750 REQUIRED INFORMATION -. ,ßpt ~D Lis ~ ~C Lis V 12988 12988 13038 / ~ ÒJt-';1.ö~ b DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. PRUDHOE BAY UNIT N-01A TVD 8980 ,/ Completion Date 9/18/2004 ./ Mud Log No -~~~,-- Name Directional Survey Directional Survey Directional Survey Directional Survey Induction/Resistivity LIS Verification 13038 Reservoir Saturation Reservoir Saturation Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis Received? ~ -'-~- Comments: Interval Start Stop Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L Samples No J/~¿ ;2..)Ju.,~ ~ "( API No. 50-029-20079-01-00 UIC N ----- -._-~--,~----.._~..- Directional Survey Yes .""~---"--'--'-~- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number BP"/ D Asc ~D Asc --_._~~_.- (data taken from Logs Portion of Master Well Data Maint Log Log Scale Media Interval Start Stop 7311 9750 7311 9750 7311 9750 7311 9750 7280 9713 7280 9713 6700 9650 Run No 5 Blu 6700 9650 OH/ CH Open Open Open Open Open Open Case . Received Comments 9/14/2004 IIFR 9/14/2004 IIFR 9/14/2004 9/14/2004 2/3/2005 2/3/2005 2/3/2005 Case 2/3/2005 Sent Received Sample Set Number Comments Daily History Received? 0N ØiN Formation Tops ---l I I I I I rsUsigma and tphi porosity I log I rsUsigma and tphi porosity log __~__~ MWD MWD GR/EWR4/ROP/PWD GRlEWR4/ROP/PWD . ~-------_._~------ --~_._.~-~----- Permit to Drill 2041130 MD 9750 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. PRUDHOE BAY UNIT N-01A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20079-01-00 89~O_ _ JJ:tiOO D'te 911812{)04 Completion Status 1-01L Current Status 1-01L UIC N - -- Date: / I Ò ~~Co---- . . ....., ... .. STATE OF ALASKA _ RECEIVED ALA_ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATION~ JUN 292006 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 /8&h tJi'l¡rS, Gå! C Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extensi0'lLJh on!. Comm;sSion Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended WeilD Orage 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development (;'1 Exploratory 204-1130 3. Address: P.O. Box 196612 Stratigraphic 0 Service 6. API Number: Anchorage, AK 99519-6612 50-029-20079-01-00 7. KB Elevation (ft): 9. Well Name and Number: 73.88 KB 8. Property Designation: ADL-028282 11. Present Well Condition Summary: Total Depth measured 9750 true vertical 8979.65 Effective Depth measured 9662 true vertical 8943.75 Casing Conductor Surface Production Production Liner Liner Size 20" 133# K-55 13-3/8" 68# K-55 7" 26# L-80 9-5/8" 47# N-80 7" 26# L-80 4-1/2" 12.6# L-80 Length 2059 4172 7144 4890 1797 910 Perforation depth: Measured depth: 9380 - 9420 True Vertical depth: 8831.98 - 8847.6 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 331 342 x N-01A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD TVD Burst Collapse 29 - 2088 29 - 2087.95 2320 1500 28 - 4200 28 - 4195.55 3450 1950 27 - 7171 27 - 7164.18 7240 5410 2426 - 7316 2425.92 - 7309.11 6870 4760 7171 - 8968 7164.18 - 8633.51 7240 5410 8838 - 9748 8551.36 - 8978.83 8430 7500 9430 - 9455 8851.51 - 8861.3 4-1/2" 12.6# 13CR80 23 - 8819 7" Baker ZXP Top Packer 7171 4-1/2" Baker S-3 Perm Packer 8762 5" Baker ZXP Top Packer 8818 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 835 550 100 578 522 0 15. Well Class after proposed work: Exploratory Development r;;-' 16. Well Status after proposed work: Oil r;;- Gas 0 WAG Tubing pressure 340 800 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJ WINJ WDSPL SUndry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal I Title Data Mgmt Engr s;goal"~ ~ Phooe 564-4424 Foon 10-404 R,,;..d 0412004 0 RIG I N A L Jc RØ/lìÎ'57 1.3 i (} b Date 6/23/2006 ~~bmit Original Only ..",...J1 . . N-01A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL I ACTIVITYDA TE I SUMMARY< 4/26/2006 PERFORATE FROM 9380-9394' WITH 2.875" POWERJET OMEGA AT 6 SPF. *** JOB COMPLETE*** . STATE OF ALASKA _ ALA" Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS D D [] 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development p' Stratigraphic 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 73.88 KB 8. Property Designation: ADL-028282 11. Present Well Condition Summary: Total Depth measured 9750 feet true vertical 8979.65 feet Effective Depth measured 9662 feet true vertical 8943.75 feet Casing Length Size MD Stove Pipe 80 30" Stove Pipe 30 - 110 Conductor 2059 20" 133# K-55 29 2088 Surface 4172 13-3/8" 68# K-55/H-40 28 4200 Intermediate 2398 10-3/4" 55.5# N-80 28 2426 Production 7144 7" 26# L-80 27 7171 Production 4890 9-5/8" 47# N-80 2426 7316 Liner 1797 7" 26# L-80 7171 8968 Liner 910 4-1/2" 12.6# L-80 8838 9748 Perforation depth: Measured depth: 9380 - 9420 True Vertical depth: 8831.98 - 8847.6 9394 - 9417 8837.45 - 8846.43 4-1/2" 12.6# Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) RECEIVED APR 0 4 2006 StimulateD AfMermIJ& Gas Cons. Cnmmiss'on Waiver D Time Extension D Anchorage Re-enter Suspended Well D 5. Permit to Drill Number: 204-1130 6. API Number: 50-029-20079-01-00 9. Well Name and Number: Exploratory Service N-01A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) None Junk (measured) None TVD 30 - 110 29 - 2087.95 28 - 4195.55 28 - 2425.92 27 - 7164.18 2425.92 - 7309.11 7164.18 - 8633.51 8551.36 - 8978.83 Burst Collapse 2320 1500 3450 1950 6450 4020 7240 5410 6870 4760 7240 5410 8430 7500 9430 - 9455 8851.51 - 8861.3 13CR80 24 - 8819 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Top Packer Representative Daily Average Production or Injection Data Gas-Mcf I Water-Bbl I Casing Pressure 1714 674 0 SHUT-IN 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil PI GasD WAG 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 408 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal I - ( 'J/ d I; Signatu~~~ 7171 8762 8818 Tubing pressure 310 Service GINJ WINJ WDSPL ¡Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Form 10-404 Revised 04/2004 Phone 564-4424 Date 4/3/2006 ì~ L RBDMS 8Ft APR 5 100&- .~, :.J. Submit Original Only '" , . . . N-01A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I šIJMm~~'1 2/17/2006 Depth Correlated to SLB RST Sigma/Porosity Log, 27-Aug-2004 Perforated 9394' - 9417' using 2-7/8" HSD 2906 PJ Omega Gun. AWGRs continued on next day. 2/18/2006 ***CONTINUED FROM PREVIOUS DAY*** PERFORATED INTERVAL 9394' - 9417' USING 2-7/8" HSD 2906 PJ OMEGA GUN. TD FOUND AT 9422'. CONTACTED TOWN ENGINEER TO ADJUST PERF INTERVAL. NO PROBLEMS RIH OR POOH. FISH LEFT IN WELL (2 FT ROLLER STEM, 1 3/4 " EXTERNAL FISH NECK). TURNED WELL OVER TO DSO. FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL Schlumbergep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . /'í)-- OiJ E-36 j'1,-,~ð¡¿Z-05 gj -VNR-13 iYfj_ Ie 7 02-07 A !.c;.¡- II ~ N-01A ¡1_ä/ì L5-05 ;, (~tllr F-27 . L-O~1 D.S.06-14A ¡í1-(fr~ D.S.02-27A ''5"J.-/¿3 D.S. 03-22 !C2- C'ì5E-08A qt{ -/5'1- E-19A q5~L '3 C-08A Well . Job # 10679044 10679035 10772272 10772244 108((782 10679070 10662946 10563157 10772247 10687697 10728384 10678042 10728385 /J/,c/ II¿ (7--'--/! -./ /1 .y 02/03/05 NO. 3327 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 12/25/03 1 1 11/28/03 1 1 06/06/04 1 1 04t07/04 1 1 08/27/04 1 1 04/05/04 1 1 09/13/03 1 1 05/13/03 1 1 04/10/04 1 1 07/20/04 1 1 01/01/04 1 1 12/21/03 1 1 01/03/04 1 1 RST RST RST RST RST RST RST RST RST RST MCNL RST MCNL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /Jþ5 h!;/ / Alaska Data & Consulting Services 2525 Gambell Street..., SU.i.te 400 tL: Anchorage, AK_'~03_283f8 ATTN: B~ ///1 ' / ReC-¿d by: t~ ·If ~~ ~' f / . . ./'-ì . o<u-f- /(5 WELL LOG TRANSMITTAL t~~~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: N-01A, AIC-MW-3190325 1 LDWG formatted Disc with verification listing. API#: 50-029-20079-01 PLEASE ACKNOWLEDGE RECEWf BY SIGNING AND RETURNING A COPY OF THE TRANSMIIT AL LEITER TO THE A rrENTION OF: Sperry -Sun Attn: Rob lCalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Dale: ~ ~ jø/ . STATE OF ALASKA _ ALASKA AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 9/18/2004 6. Date Spudded 7/27/2004 21. Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES CASING, LINER AND CEMENTING RECORD SSTINGDI.!PTHMO SrnlNGÐEPTHTVO BOTTOM 80""'OM 30" Stove Pipe Surface 80' Surface 80' 20" 133# / 94# K-55 / H-40 Surface 2088' Surface 2088' 13-3/8" 68# K-55 Surface 4200' Surface 4195' 10-3/4" x 9-5/8" 55.5# / 47# N-80 Surface 7316' Surface 7309' 7" 26# L-80 57' 8968' 57' 8634' 4-1/2" 12.6# L-80 8818' 9748' 8539' 8979' 23. Perforations open to Production (MD + TVD of To)? and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 6spf 2.88" Gun Diameter, 6spf MD TVD MD TVD 9380' - 9420' 8832' - 8848' 9430' - 9455' 8852' - 8861' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3761' SNL, 4724' WEL, SEC. 08, T11N, R13E, UM Top of Productive Horizon: 2733' SNL, 4431' WEL, SEC. 08, T11N, R13E, UM Total Depth: 2248' SNL, 4226' WEL, SEC. 08, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 634414 y- 5967423 Zone- ASP4 TPI: x- 634685 y- 5968457 Zone- ASP4 Total Depth: x- 634880 y- 5968945 Zone- ASP4 18. Directional Survey 181 Yes 0 No No. of Completions 22. 26. Date First Production: September 27,2004 Date of Test Hours Tested PRODUCTION FOR 10/2/2004 4 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 315 1,180 24-HoURRATE Oll-Bsl 1,111 7. Date T.D. Reached 8/4/2004 8. KB Elevation (ft): 73.88' 9. Plug Back Depth (MD+ TVD) 9662 + 8944 10. Total Depth (MD+TVD) 9750 + 8980 11. Depth where SSSV set (Nipple) 2187' MD 19. Water depth, if offshore N/ A MSL RECEIVEr OCT 1 ~{ 2004 Alaska Dil R¡ C.. 1b. Well Class: . un<>. Gommi$ 181 Development 0 ExJiß~gl3 o Stratigraphic 0 Service 12. Permit to Drill Number 204-113 13. API Number 50- 029-20079-01-00 14. Well Name and Number: PBU N-01A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028282 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 36" 26" 17-1/2" 12-1/4" 8-1/2" 6-1/8" SIZE 4-1/2", 12.6#, 13Cr80 300 sx Permafrost II 4500 sx Permafrost II 1860 sx Class 'G', 1800 sx Class 'G' 1510 sx Class 'G', 400 sx Class 'G' 169 sx 'G', 258 sx 'G', 124 sx 'G' 126 sx Class 'G' DEPTH SET (MD) 8819' PACKER SET (MD) 8762' DEPTH INTERVAL (MD) 2200' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls Diesel CHOKE SIZE I GAS-Oil RATIO 960 977 Oil GRAVITY-API (CORR) 27.1 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". GAs-McF 181 GAs-McF 1,086 W A TER-Bsl 321 WATER-Bsl 1,926 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-Bsl 185 None cm'1i;L:ªTrœ¡~-1 ~0TE~t ~{j ¡ED t Form 10-407 vioCd -1 212003 ORIGINAL CONTINUED ON REVERSE SIDE R~ ~ GF 28. GEOLOGIC MARKERS. 29. eRMATlON TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8957' 8627' None Shublik A 9013' 8662' Shublik B 9094' 8708' Shublik C 9124' 8724' Sadlerochit I Zone 48 9176' 8750' Top CGL / Zone 3 9590' 9015' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble '1iM..Z.t ~ ~ Title Technical Assistant Date IO..-ß-Dt{ PBU N-01A 204-113 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dave Wesley, 564-5153 Permit No. I 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. IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation. or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IrEM 4b: TPI (Top of Producing Interval). IrEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only N-01 7/26/2004 FIT 8/3/2004 FIT 7,344.0 (It) 8,990.0 (It) . . 8/9/2004 9:39:46 AM 10.50 (ppg) Printed: 4,719 (psi 900 (psi 8.50 (ppg) (It 8,648.0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 7/22/2004 12:00 - 16:00 4.00 MOB P PRE Move Rig from N-07 to N-01 , spot sub, pits and cuttings tank, hook up service lines. Accept Rig at 16:00 hrs. 7/22/2004 16:00 - 17:00 1.00 KILL P DECOMP RIU DSM lubricator and pull BPV, UD lubricator, Rig up to reverse diesel from well. 17:00 - 21 :00 4.00 KILL P DECOMP Held PJSM, with Co Rep, Toolpusher,and rig crew. Reverse circulate diesel from tubing 50 bbls. Pump down tubing until clean seawater to surface at 3 bpm @ 120 psi. 21 :00 - 21 :30 0.50 WHSUR P DECOMP Install TWC and test to 1,000 psi. from below. 21 :30 - 23:00 1.50 WHSUR P DECOMP Nipple down tree and adapter flange, Inspect lifting threads on tubing hanger and LDS 23:00 - 00:00 1.00 WHSUR P DECOMP Nipple up BOPS. 7/23/2004 00:00 - 02:30 2.50 WHSUR P DECOMP Held PTSM, Nipple up BOP, riser and flow line. 02:30 - 03:00 0.50 WHSUR P DECOMP Rig up BOP test equipment. 03:00 - 06:30 3.50 WHSUR P DECOMP Test BOP as per testing procedure. test all equipment to 250 psi low 3,500 psi high. John Spaulding with AOGCC witnessed BOP test. 06:30 - 07:30 1.00 WHSUR P DECOMP Change out upper and lower IBOP valves, on topdrive. 07:30 - 08:00 0.50 WHSUR P DECOMP Test upper and lower IBOP valves to 250 psi low, 3,500 psi high. Rig down test equipment. 08:00 - 09:00 1.00 WHSUR P DECOMP Rig up DSM lubricator and pull TWC, rig down lubricator. 09:00 - 10:30 1.50 PULL P DECOMP Flow check, Make up landing joint, back out LDS, pull hanger to rig floor (135K) 10:30 - 12:00 1.50 PULL P DECOMP Circulate bottoms up @ 11 bpm 350 psi. Flow check, no flow. 12:00 - 12:30 0.50 PULL P DECOMP Lay down tubing hanger and landing joint. 12:30 - 22:30 10.00 PULL P DECOMP Pump dry job, lay down 5.5" tubing and control line, Rig down Cameo spooling unit. Lay down 4.5" tubing Recovered a total of 58 joints of 5.5" tubing - 1 ea. 5.5" SSSV - 3 ea. 4.5" GLM - 124 joints 4.5" tubing, and 18.04' cut off joint. 25 ea. control line clamps and 4 ea. SS bands. 22:30 - 23:00 0.50 PULL P DECOMP Clean floor and lay down tubing handling equipment. 23:00 - 00:00 1.00 CLEAN P DECOMP Load pipe shed, with DP and BHA 7/24/2004 00:00 - 03:00 3.00 CLEAN P DECOMP Held PTSM, Pickup clean out assembly, 8.5" junk mill - bit sub - upper srting mill - bumper sub - oil jar - XO - 9 6.25" DC - 2 XO - 21 joints 4" HWDP 03:00 - 04:00 1.00 CLEAN P DECOMP Slip and cut drilling line. Service rig and topdrive. 04:00 - 10:00 6.00 CLEAN P DECOMP RIH with clean out assembly, Single in 90 jts 4" DP from pipe shed, run pipe from derrick, tag top of fish @ 7,519' up weight =176k, down weight = 175k, rotating weight = 175k 10:00 - 11 :00 1.00 CLEAN P DECOMP Circulate bottoms up, 550 gpm @ 2,180 psi. 11 :00 - 12:00 1.00 CLEAN P DECOMP Held PJSM, Rig up Little Reds to pump 150 bbls of 150 deg diesel down annulus. Pressure test lines to 3,000 psi. 12:00 - 14:30 2.50 CLEAN P DECOMP Reverse circulate 150 bbls diesel, heated to 150 deg. at 3 bpm,250 psi. Chase with 330 bbls seawater at 6 bpm, 1,400 psi. 14:30 - 16:30 2.00 CLEAN P DECOMP Pump down drill pipe with clean seawater @ 5 bpm, 230 psi. to displace diesel from annulus, taking returns through gas buster. 16:30 - 18:00 1.50 CLEAN P DECOMP Pump 30 bbl detergent pill with (1 drum Safe Surf 0) followed by 45 bbls high vis sweep at 6 bpm 300 psi. 18:00 - 19:00 1.00 CLEAN P DECOMP POH from 7,519' to 7,352', make up 103/4" HES Rtts and set 40' below rotary table, test Rtts to 1,000 psi. Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 7/24/2004 19:00 - 20:00 1.00 CLEAN P DECOMP Nipple dowm BOP and tubing spool. 20:00 - 00:00 4.00 CLEAN P DECOMP Change out seal on 10 3/4" emergency slips, install new intermediate casing spool and packoff, test packoff seals to 2,000 psi. Nipple up BOP. 7/25/2004 00:00 - 01 :30 1.50 CLEAN P DECOMP Held PTSM, Continue to Nipple up BOP 01 :30 - 02:00 0.50 CLEAN P DECOMP Pickup 1 joint of DP, engauge RTTS, pickup on string leaving 25k on Rtts. 02:00 - 03:00 1.00 CLEAN P DECOMP Rig up test equipment, close lower pipe rams and test against Rtts to 250 psi low 3,500 psi high. record on chart. Rig down test equipment. 03:00 - 03:30 0.50 CLEAN P DECOMP Pull Rtts. to floor and lay down same. 03:30 - 07:00 3.50 CLEAN P DECOMP POH with clean out assembly. stand back HW and DC, lay I down mills, clear floor and install wear ring. 07:00 - 11 :00 4.00 DHB P DECOMP Held PJSM, Rig up Schlumberger, RIH with 9 5/8" bridge plug & G/R to top of fish at 7,514', picked up to setting depth 7,335' setting tool misfired, 11 :00 - 14:00 3.00 DHB N DPRB DECOMP POH with Bridge plug, re-dress setting tool & RIH, set bridge plug at 7,335', POH and rig down Schlumberger. 14:00 - 15:00 1.00 DHB P DECOMP Rig up and test casing to 3,500 psi, record on chart. 15:00 - 16:30 1.50 STWHIP P WEXIT Pickup Whipstock & Milling assembly. 16:30 - 21:00 I 4.50 STWHIP P WEXIT RIH with Whipstock to 7,304' 21 :00 - 22:00 1.00 STWHIP P WEXIT Circulate DP volume @ 280 gpm 540 psi. Rig up Sperry E-line , unit and gyro tools. 22:00 - 00:00 2.00 STWHIP P WEXIT RIH with Gyrodata surface readout gyro, Orient whipstock to 354 deg. Magnetic TF. Slack off to setting depth 7,338', Re-seat gyro three times to confirm orientation. 7/26/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT Held PTSM, POH with Gyro, prior to setting whipstock to confirm, tool had seated in orienting sub, Rig down e-line and Gyro tools. 01 :30 - 02:00 0.50 STWHIP P WEXIT Set down 25k to shear trip anchor, shear off whipstock with 40k, Top of the whipstock set @ 7,316' bottom at 7,332', I whipstock oriented 354 deg. magnetic TF. 02:00 - 03:30 1.50 STWHIP P WEXIT Displace well to 10.8 ppg LSND mud prior to milling window, 500 gpm @ 1,620 psi. 03:30 - 09:30 6.00 STWHIP P WEXIT Mill window from 7,316' to 7,332' 2-6k wob, 360 gpm, 1,085 psi, 85 rpm, 2 to 6k torque. up weight = 177k, down weight = 175k, string weight =175k 09:30 - 10:30 1.00 STWHIP P WEXIT Mill formation from 7,332' to 7,344' 5-20k wob, 360 gpm, 1,080 psi, 80 rpm, 3k torque. up weight =177k, down weight = 175k string weight = 165k. Worked mills through window twice with rotary, once with no rotary, no drag pulling through window. 10:30 - 11 :30 1.00 STWHIP P WEXIT Pump 50 bbl high vis weighted sweep, weighted to 12.5 ppg. circulate hole clean 550 gpm, 1,990 psi 11 :30 - 12:00 0.50 STWHIP P WEXIT Pull above top of whipstock, rig up and perform FIT, test mud weight 10.8, tvd 7,309' surface pressure 570 psi. EMW = 12.3 ppg. 12:00 - 16:00 4.00 STWHIP P WEXIT Held PTSM, monitor well, pump dry job and POH to BHA. 16:00 - 17:00 1.00 STWHIP P WEXIT Monitor well, Lay down BHA. 17:00 - 18:30 1.50 STWHIP P WEXIT Pull wear ring, Function rams and flush BOP, blow down choke and kill line, install wear ring. 18:30 - 21 :30 3.00 STWHIP P WEXIT Pickup and orient BHA per directional driller, RIH with HWDP, shallow test MWD. 21 :30 - 22:00 0.50 STWHIP P WEXIT Service rig and top drive. Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 7/26/2004 22:00 - 00:00 2.00 STWHIP P WEXIT Pick up 42 joints 4" DP, RIH out of derrick to 5,047' fill DP @ 4,180' 7/27/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Held PTSM, RIH from 5,047' to 7,310' 01 :00 - 01 :30 0.50 STWHIP P WEXIT Break circulation, establish base line ECD with 500 gpm, 90 rpm ECD = 11.25, 520 gpm, 90 rpm ECD = 11.26 01 :30 - 02:30 1.00 STWHIP P WEXIT Rig up E-line unit and gyro tools, make up side door entry sub. 02:30 - 04:00 1.50 STWHIP P WEXIT RIH with Gyro, orient to 350 deg magnetic TF. 04:00 - 10:00 6.00 DRILL P INT1 Directional drill with Gyrodata continuous read out gyro, from 7,344' to 7,384', 5-10k wob, 500 gpm @ 2,180' psi. Motor stalled twice while washing the last 8' of under gauged hole from milling operation. Stabalizer on top of the motor hung up while sliding through window, pulled above the whipstock, worked assembly through this area twice, jar went off twice while working pipe. AST = 1.77 10:00 - 12:00 2.00 DRILL P INT1 POH to 7,308', POH with gyro, UD side entry sub, UD gyro tools. The last 60' of e-line had several kinks. 12:00 - 13:00 1.00 DRILL P INT1 Directional drill from 7,384' to 7,437' 5-1 Ok wob, 500 gpm, 2,450 psi off bottom, 2,500 psi on bottom, 60 rpm, torque off bottom 3,500, torque on bottom 6,000, up wt. 170k, dn wt. 160k, string wt. 165k. Pulled back and survey at bottom of whipstock survey indicated 2.74 deg. surveyed at 7,349' survey showed 1.6 deg. Bottoms up samples indicates assembly is tracking casing, had a increase in PH. 13:00 - 14:30 1.50 DRILL P INT1 Re-head E-line, Circulate 100 gpm @300 psi. 14:30 - 16:00 1.50 DRILL P INT1 Make up side entry sub, RIH with Gyro, orient. 16:00 - 00:00 8.00 DRILL P INT1 Directional drill by sliding from 7,437' to 7,505' 5-10k wOb, 400 gpm, 1,850 psi off bottom, 1,950 psi on bottom, up wt. 170k, dn wt. 160k, string wt. 165k. Control drill @ 5-10 fph. 7/28/2004 00:00 - 01 :30 1.50 DRILL P INT1 Held PTSM, Directional drill by sliding from 7,505' to 7,518' 5k wob, 400 gpm, 1,850 psi off bottom, 1,950 psi on bottom, up wt. 170k, dn wt. 160k, string wt. 165k. Control drill @ 5-10 fph. stopped drilling at 7,518' to survey, Survey showed 1.62 deg, survey at 7,500' showed 1.99 deg. 01 :30 - 03:30 2.00 DRILL P INT1 Pull up to side entry sub at 7,402', POH with E-line & gyro tools, UD side entry sub and gyro tools, Pump dry job. The last 10' of E-line was bird caged, and will have to be re-connected. 03:30 - 05:30 2.00 DRILL N DPRB INT1 POH with drilling assembly, 05:30 - 08:00 2.50 DRILL N DPRB INT1 Stand back flex collars, down load MWD, UD MWD tools, move orienting sub to top of motor, change bit, adjust motor to 2.00 deg. 08:00 - 11 :00 3.00 DRILL N DPRB INT1 RIH to 7,447' fill pipe as needed, no problem going through window 11 :00 - 13:30 2.50 DRILL N DPRB INT1 Rig up side entery sub, RIH with gyro on e-line 13:30 - 00:00 10.50 DRILL P INT1 Directional drill by sliding from 7,518' to 7,571' 10k wOb, 400 gpm, 1,860 psi off bottom, 1,950 psi on bottom, up wt. 170k, dn wt. 160k, string wt. 165k. Control drill @ 5-7 fph. The first survey @ 7,528' showed 10' with the new assembly, survey showed 2.91 deg. AST = 7.82 7/29/2004 00:00 - 02:30 2.50 DRILL P INT1 Held PTSM, Directional drill by sliding from 7,571' to 7,613' 20k wob, 400 gpm, 1,860 psi off bottom, 1,950 psi on bottom, up wt. 170k, dn wt. 160k, string wt. 165k. Shot a survey at 7,569' Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 7/29/2004 00:00 - 02:30 2.50 DRILL P INT1 survey showed 6.71 deg. interpolated Inclination at the bit 11 deg. AST = 1.24 02:30 - 05:00 2.50 DRILL P INT1 POH to 7,447', POH with gyro, UD side entry sub and gyro tools. The last 150' of e-line had three kinks, no broke strands. 05:00 - 08:30 3.50 DRILL P INT1 Monitor well, pump dry job & POH 08:30 - 11 :00 2.50 DRILL P INT1 Change bit, adjust motor to 1.5 deg, P/U MWD & orient, Initial MWD. 11 :00 - 12:00 1.00 DRILL P INT1 RIH to 935', Pulse test MWD. 12:00 - 12:30 0.50 DRILL P INT1 Service rig and topdrive. 12:30 - 15:00 2.50 DRILL P INT1 RIH from 935' to 7,510', fill DP @ 4,186' 15:00 - 16:00 1.00 DRILL P INT1 MAD pass from 7,510' to 7,613' 16:00 - 16:30 0.50 DRILL P INT1 Drill from 7,613' to 7628', 15k wob, 500 gpm, @ 2,830 psi, 80 rpm, 4K torque on bottom 3k torque of bottom. up wt. =175k, dn wt. = 160k, string wt. = 165k 16:30 - 17:00 0.50 DRILL P INT1 Attempt Survey at 7,628', unable to get a survey, tool not ¡pulsing. 17:00 - 20:30 3.50 DRILL N DFAL INT1 Monitor well, pump dry job, POH to BHA, monitor well. 20:30 - 22:30 2.00 DRILL N DFAL INT1 Down load MWD, Change out pulser, inspect bit, orient motor & MWD. Pulser was packed off with cuttings, (clay & shale), Cleaned suction and discharge screens on both pumps, found I no significant amount of cuttings. Roll surface volume, circulating across top of the hole while making up BHA and RIH. 22:30 - 23:00 0.50 DRILL N DFAL INT1 RIH to 635' pulse test MWD, ok 23:00 - 00:00 1.00 DRILL N DFAL INT1 RIH from 635' to 2,750' 7/30/2004 00:00 - 01 :00 1.00 DRILL N DFAL INT1 Held PTSM, RIH from 2,750' to 4180' fill DP and test MWD ok. 01 :00 - 02:00 1.00 DRILL N DFAL INT1 I Continue to RIH from 4,180' to 7,246' 02:00 - 02:30 0.50 DRILL N DFAL INT1 Break circulation, test MWD ok. work BHA through window, no problem, wash from 7,532' to 7,628', no fill on bottom. 02:30 - 04:45 2.25 DRILL P INT1 Directional drill from 7,628' to 7,724', 10k wob, 500 gpm, 2,450 psi off bottom, 2700 psi on bottom, 60 rpm, 3k torque off bottom, 4k torque on bottom. AST = 1.3 ART = .4 Rig is experiencing SCR problems. 04:45 - 05:15 0.50 DRILL N RREP INT1 I POH to shoe at 7,246' 05:15 - 05:45 0.50 DRILL N RREP INT1 Trouble shoot electrical problem. 05:45 - 06:00 0.25 DRILL N RREP INT1 RIH from 7,246' to 7,724' 06:00 - 12:00 6.00 DRILL P INT1 Directional drill from 7,724' to 7,935', 10k wob, 500 gpm, 2,550 psi off bottom, 2780 psi on bottom, 80 rpm, 3k torque off bottom, 5k torque on bottom. ECD = 11.27 AST = 2.74 ART = .8 12:00 - 16:00 4.00 DRILL P INT1 Directional drill from 7,935' to 8107', 10k wob, 500 gpm, 2,550 psi off bottom, 2780 psi on bottom, 80 rpm, 3k torque off bottom, 5k torque on bottom. up wt =178k, dn wt. = 160k, string wt. = 170k, ECD = 11.27. 16:00 - 16:45 0.75 DRILL P INT1 Change swab on #1 Mud pump. 16:45 - 00:00 7.25 DRILL P INT1 Directional drill from 8,107' to 8,394', 10k wob, 500 gpm, 2,640 psi off bottom, 2850 psi on bottom, 80 rpm, 3k torque off bottom, 5k torque on bottom. up wt =183k, dn wt. = 163k, string wt. = 175k, ECD = 11.37. AST = 5.93 ART = 1.92 7/31/2004 00:00-10:15 10.25 DRILL P INT1 Directional drill from 8,394' to 8,970', 10k wob, 500 gpm, 2,980 psi off bottom, 3,150 psi on bottom, 80 rpm, 4k torque off bottom, 5k torque on bottom. up wt =195k, dn wt. = 165k, string Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 7/31/2004 00:00 - 10:15 10.25 DRILL P INT1 10:15 - 12:00 1.75 DRILL P INT1 12:00 - 13:30 1.50 DRILL P INT1 13:30 - 14:30 1.00 DRILL P INT1 14:30 - 15:30 1.00 DRILL P INT1 15:30 - 17:30 2.00 DRILL P INT1 17:30 - 18:30 1.00 DRILL P INT1 18:30 - 21 :00 2.50 DRILL P INT1 21 :00 - 23:15 2.25 DRILL P INT1 23: 15 - 23:45 0.50 DRILL P INT1 23:45 - 00:00 0.25 CASE P INn 8/1/2004 00:00 - 01 :00 1.00 CASE P INn 01 :00 - 03:30 2.50 CASE P INT1 03:30 - 04:00 0.50 CASE P INT1 04:00 - 04:30 0.50 CASE P INT1 04:30 - 08:00 3.50 CASE P INT1 08:00 - 09:00 1.00 CASE P INT1 09:00 - 12:00 3.00 CASE P INT1 12:00 - 14:00 2.00 CEMT P INT1 14:00 - 15:15 1.25 CEMT P INT1 wt. = 175k, ECD = 11.37. AST = 2.55 ART = 5.20 Circulate Bottoms up for sample, circulate one additional bottoms up, 500 gpm @ 2,980 psi, rotating string at 100 rpm, torque = 4k. Monitor well. POH from 8,970' to 7,246', excess drag of 15 - 20k from 8,420' to 8,390'. Slip and cut 136' drilling line, service rig and crown. RIH from 8,246' to 8,871' ream from 8,871' to 8,970' as a precaution, no fill on bottom. saw nothing from 8,390' to 8,420' going in the hole. Pump 40 bbl high vis sweep around, 500 gpm, @ 3,100 psi, rotating string at 100 rpm, torque = 4k. reciprocate pipe from 8,970' to 8,920' POH 9 stds. to 8,107', monitor well, pump dry job and drop 2.25" rabbit POH from 8,107' to BHA Lay down BHA. Clear floor of directional equipment, clean floor. Rig up 7" casing equipment. Continue to rig up casing equipment, Held PJSM, with CO. Rep Toolpusher, Baker and rig personel. Make up 7" float equipment and bakerlok first two connections, run a total of 44 joints of 7" L-80 26# BTC-M casing plus Baker 7" X 9 5/8" HMC liner hanger, ZXP mechanical set liner top , packer, with C2 running tool with rotating dog sub. Makeup torque = 7,200 ftlJbs. Rig down 7" casing equipment, change over to DP handling tools, Make up 1 stand 4" DP. Make up topdrive, circulate liner volume 1.5 times @ 6 bpm, 140 psi. Up wt. = 75k, down wt. = 75k. RIH with 7" liner on 4" DP, to 7,224' fill DP every 10 stands. Circulate liner and DP volume @ 6 bpm, 600 psi. make up Baker cement head on joint of DP and lay on skate. RIH with 7" Liner on 4" DP from 7,224', took wt. @ 8,501' worked down to 8,597', washed from 8,597' to 8,789' @ 3 bpm, 420 psi, RIH from 8,789' to 8,953', washed from 8,953' to 8,970', picked up to 8,968' Up wt = 205k down wt = 150k. Stage up pumps to 6.5 bpm, 1,100 psi. PJSM for cement job while circulating. Pump 5 bbls of water test lines to 4,000 psi, pump 25 bbls 11.8 ppg mud push 35 bbls of 15.8 ppg class G cement, drop DP dart flush lines with 5 bbls water and displace with rig pumps at 7 bpm. latched up liner wiper plug with calculated strokes, bumped plug with 1,300 psi to set liner hanger. hold pressure apply 70k down to set hanger, bleed off pressure and check floats. rotate string 15 turns to the right, apply 500 psi to DP, picked up until pressure bled off to exposing rotaing dog sub, pump 15 bbls to clear cement, rotate string at 15 rpm torque 2000 ftllbs. slack off 70k to set ZXP packer repeat twice to ensure set. CIP @ 14:45. Liner set @ 8,968' top of tie back @ 17, 171'. Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 8/1/2004 15:15 - 16:30 1.25 CEMT P INT1 Circulate bottoms up @ 7 bpm, 925 psi, no cement to surface. 16:30 - 17:00 0.50 CEMT P INT1 Lay down cement head and single of DP, blow down cement lines, pump dry job. 17:00 - 20:00 3.00 CEMT P INT1 POH 18 stds, P/U cement head and break out single,continue POH lay down liner running tool. 20:00 - 20:30 0.50 CEMT P INT1 Clear & clean floor, pull wear ring. 20:30 - 21:00 0.50 CASE P TIEB1 Rig up 7" casing tools, PJSM with Co. Rep, Toolpusher, Baker I and rig crew. 21 :00 - 00:00 3.00 CASE P TIEB1 Run 7" 26# L-80 BTC-M Tie back assembly, Baker tie back seal assembly, one joint of 7" casing, HES 7" ported float collar bakerlok first two connections, Run casing to 2,543', makeup torque = 7,200 ftllbs. 8/2/2004 00:00 - 05:00 5.00 CASE P TIEB1 Held PTSM, Continue running 7" 26# L-80 BTC-M tie back, run a total of 172 joints plus a 10' pup, makeup torque = 7,200 ftllbs. Run casing to 7,161' ( jt# 172) Up wt = 205k, down wt = 180k 05:00 - 06:00 1.00 CASE P TIEB1 Change over to the long bails, make up XO to cement head on joint #173, load plug in cement head, P/U joint #173 and run in 106:00 - 08:00 to 7,181', set 10k down on locating ring. (9' inside tie back extension) 2.00 CEMT P TIEB1 Locate seals and circulating ports on tie back seal assembly, pick up to expose circulating ports,circulate liner volume, 6 bpm @ 1,100 psi. 08:00 - 11:15 3.25 CEMT P TIEB1 Pump 5 bbls water and test lines to 4,000 psi. Pump 95 bbls fresh water spacer, initial rate 4 bpm, 650 psi, final rate 4 bpm @ 920 psi. Pump 180 bbls of 9.0 ppg Mapco - 200, initial rate 4 bpm @ 1,050 psi, final rate 4 bpm @ 1,450 psi. Drop bottom plug, pump 96 bbls 12.5 ppg class G lead cement, 26 bbls 15.8 ppg class G tail cement, 4 bpm @ 820 psi. Pump 5 bbls water, drop top plug and displace cement with 10.8 ppg mud at 6 bpm @ 50 psi. with 225 bbls away caught up with cement, slowed rate to 2 bpm 10 bbls prior to bumping plug, FCP 575 psi. bump plug with 1,000 psi. Lower second seal into tie back extension, bleed pressure to zero, no flow back, set down 10k with locator ring on top of tie back extension, to ensure seals are fully inserted, bottom of tie back seal assembly @ 7,181' pickup to string wt. 205K. CIP @ 11 :05. Got back 60 bbls Mapco 200. 11 :15 - 12:00 0.75 CEMT P TIEB1 Rig down cement equipment. 12:00 - 14:00 2.00 BOPSUP P TIEB1 Drain BOP stack, pump mud out of 7" casing for cut, N/D BOP, raise BOP, install 7" emergency slips (set 200k string weight on slips) RILDS. 14:00 - 15:30 1.50 WHSUR P TIEB1 Rig up WACHS casing cutter, cut 7' casing, UD joint #173 and 6.22' of Joint #172 15:30 - 18:00 2.50 WHSUR P TIEB1 Set BOP on stand, nipple up new tubing head with 7" packoff installed, test packoff seals to 4,300 psi for 15 min. 18:00 - 20:00 2.00 BOPSUF P TIEB1 Nipple up BOP 20:00 - 21 :00 1.00 BOPSUF P TIEB1 Install wear ring, check gland packing nuts on tubing spool, close blind rams and test flanges and 7" casing to 3,500 psi for 15 min. 21 :00 - 21 :30 0.50 BOPSUP P TIEB1 Change bails on top drive. 21 :30 - 00:00 2.50 DRILL P PROD1 P/U 6 1/8" BHA orient motor & MWD, P/U remaing BHA and pulse test MWD. Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 8/3/2004 00:00 - 03:30 3.50 DRILL P PROD1 Held PTSM, RIH with 6 118" drilling assembly from 294', fill DP @ 4,081' & 6,568', tag cement plugs at 7,098' 03:30 - 04:30 1.00 DRILL P PROD1 Break circulation, drill cement from 7,098' to 7,110', drill float collar @ 7,110', clean out cement to 7,190', wob 2-5K, 240 gpm, @ 1,960 psi, 40 rpm, torque 2k, up wt. 155k, down wt. 135k, string wt. 145k 04:30 - 05:00 0.50 DRILL P PROD1 RIH form 7,190' tag cement @ 8,860' 05:00 - 06:30 1.50 CASE P PROD1 Fill DP, break circulation, stand back one stand. Rig up testing equipment. Test 7" casing to 3,500 psi for 30 min. and record on chart. 06:30 - 08:15 1.75 DRILL P PROD1 Drill landing collar at 8892', float collar at 8930' and cement in shoe track to 8958' 08:15 - 09:30 1.25 DRILL P PROD1 Displace 10.8 ppg mud in hole with new 8.6 ppg FloPro. 260 gpm @ 1,600 psi. 09:30 - 10:00 0.50 DRILL P PROD1 Drill out 10' of cement and shoe and 20' of new hole to 8990'. 10:00 - 10:45 0.75 DRILL P PROD1 Perform FIT on 7" liner shoe at 8968' with 900 psi. EMW 10.5 ppg. 10:45 - 00:00 13.25 DRILL P PROD1 I Directional drill 6 1/8" prodiction hole from 8,890' to 9,700', 20k wOb, 260 gpm, 1,810 psi off bottom, 2,025 psi on bottom. 70 rpm, 3k torque off bottom, 4k torque on bottom. up wt =180k, dn wt. = 158k, string wt. = 172k. AST = 4.23 ART = 5.38 8/4/2004 00:00 - 00:30 0.50 DRILL P PROD1 Circulate bottoms up sample, at 9,700' 260 gpm 1,810 psi. 00:30 - 01 :30 1.00 DRILL P PROD1 Directional drill 6 1/8" prodiction hole from 9,700' to 9,750', 20k wob, 260 gpm, 1,810 psi off bottom, 2,025 psi on bottom, 70 rpm, 3k torque off bottom, 4k torque on bottom. up wt =180k, dn wt. = 158k, string wt. = 172k. ART = 1.0 01 :30 - 02:30 1.00 DRILL P PROD1 Ciculate bottoms up at TD 9,750' with 260 gpm, 1,810 psi. 02:30 - 03:00 0.50 DRILL P PROD1 POH from 9,750' to 7" liner shoe at 8,958' no problems. 03:00 - 04:00 1.00 DRILL P PROD1 Service rig, topdrive and crown. 04:00 - 04:30 0.50 DRILL P PROD1 RIH from 8,958' to 9,750', no fill on bottom. 04:30 - 06:00 1.50 DRILL P PROD1 Pump 40 bbl high vis sweep, 260 gpm, 1,820 psi, rotating string 100 rpm, reciprocate string full stand. Monitor well, static. Pump dry job. 06:00 - 09:30 3.50 DRILL P PROD1 POH to 7" liner shoe at 8968'. Drop drill pipe drift. Remove top drive blower hose. Continue POH to top of BHA. 09:30 - 11 :30 2.00 DRILL P PROD1 Lay down 21 joints HWDP, down load MWD and lay down same. 11 :30 - 12:00 0.50 CASE P PROD1 Clear rig floor and clean up. Rig up to run 4 1/2" liner. 12:00 - 15:30 3.50 CASE P PROD1 Make up 4 1/2" liner shoe track. Check floats OK. Thread lock first three joints. Run 22 joints 41/2" 12.6# L-80 IBT-M liner. Make up Baker 41/2" x 7" HMC liner hanger with ZXP liner top packer and liner running tool. 15:30 - 16:00 0.50 CASE P PROD1 M/U & RIH 1 stand DP & circulate 2X liner volume. 16:00 - 20:00 4.00 CASE P PROD1 Run 4 1/2" liner on 4" drill pipe on stands from the derrick to 8,874'. 20:00 - 20:30 0.50 CASE P PROD1 P/U & M/U Cement Head to DP single & UD on Skate. 20:30 - 21 :15 0.75 CASE P PROD1 CBU, staging pumps up to 6 BPM @ 1100 psi. 21:15-22:30 1.25 CASE P PROD1 Continue RIH to 9,734 - No excess drag. P/U single with cement head & Break circulation. Tag bottom @ 9,750'. 22:30 - 23:30 1.00 CASE P PROD1 Stage pump up to 6 BPM /1100 psi. Circulate while reciprocating pipe 10'. P/U WT = 175 K, S/O Wt. = 167 K. Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 8/4/2004 22:30 - 23:30 1.00 CASE P PROD1 Hold PJSM with all hands. 23:30 - 00:00 0.50 CEMT P PROD1 Switch over to Dowell and cement as follows: Pump 5 bbls water and test lines to 3500 psi. Pump 10 Bbls, 8.4 ppg, CW-100, Pump 15 Bbls, 9.8 ppg MudPush, followed by 27 bbls ( 150 Sks), 15.8 ppg, class 'Go slurry w/1.20 cu. ft. I sx yield. All pumped @ 6 BPM. Displace with rig pumps, first pumping 15 Bbl perf pill followed by 9.7 ppg FloPro Mud @ 6 BPM. Reciprocating Liner throughout job. 100 % returns throughout cementing and displacement. 8/5/2004 00:00 - 00:30 0.50 CEMT P PROD1 Complete displacement, latching DP wiper to Liner Plug and displacing final 13 bbls to float collar with shoe positioned 2 ft off bottom @ 9,748' and TOL @ 8,817'. Bump plug & pressure up to 3500 psi to set HMC Liner Hanger. Slack off to comfirm set. Rotate 20 turns to right to release running tool. Pressure up to 1000 psi & PU. When pack-off out (pressure drops), pump 15 Bbls mud to clear cement off TOL. P/U to set packer by setting down 45K while rotating 10 RPM. Repeat 3X to insure set. 00:30 - 01 :30 1.00 CEMT P PROD1 Circulate cement out @ 7 BPM /1120 psi. Appoximately 15 Bbls cement to surface. 01 :30 - 02:30 1.00 CASE P PROD1 Displace FloPro mud with Seawater @ 7 BPM /1100 psi. 02:30 - 03:00 0.50 CEMT P PROD1 R/D cement head & UD. 03:00 - 04:30 1.50 RUNCOrvP RUNCMP POH & stand back 50 stands of 4" DP for Move. 04:30 - 09:00 4.50 RUNCOrvP RUNCMP Lay Down remaining 4" Drill Pipe - 132 Jts. 09:00 - 09:30 0.50 RUNCOrvP RUNCMP C/O Baker C-2 running tool - OK. UD Same. 09:30 - 10:30 1.00 RUNCOrvP RUNCMP Clear Floor, Pull Wear Bushing, Make Dummy run with Hanger & mark landing jt. 10:30 - 12:00 1.50 RUNCOMP RUNCMP R/U to run 4.5" 13 CR Completion String. 12:00 - 13:00 1.00 RUNCOMP RUNCMP R/U & test Liner to 3500 psi & chart for 30 minutes. 13:00 - 00:00 11.00 RUNCOrvP RUNCMP Run 4.5", 12.6#, 13 CR, VamTop Completion String as per Program. 192 Jts ran. 8/6/2004 00:00 - 01 :30 1.50 RNTBHG P TUBHGR Continue running 4.5" 13 Cr Completion String. Space out WLEG into Tie Back Receptacle. M/U space -out pups below last Jt. of Tubing. Total 206 Jts of tubing ran. WLEG @ 8,820'. 01 :30 - 03:00 1.50 SIT P TUBHGR Reverse circulate 60 Bbls. corrosion inhibited seawater followed by 105 Bbls. Clean seawater @ 3 BPM. 03:00 - 04:00 1.00 RNTBHG P TUBHGR M/U Cameron Tubing Hanger & landing Jt. Run in and land Hanger. R.I.L.D.S. Drop Ball/ Rod. 04:00 - 06:00 2.00 SIT P TUBHGR Pressure tubing to 3500 psi to set S-3 Packer. Hold & chart pressure for 30 minute test. Bleed tubing pressure to 2000 psi, then pressure annulus to 3500 psi - chart & hold for 30 minute test. Bleed annulus to '0' then tubing. Pressure up annulus to 3000 psi to shear 'DCK' valve in GLM # 4. Pump couple bbls each way to insure good shear. 06:00 - 07:30 1.50 WHSUR P WHDTRE Remove landing Jt. Install TWC & Test from below to 1000 psi. 07:30 - 09:00 1.50 BOPSUP P WHDTRE N/D & set back BOP Stack. 09:00 - 12:00 3.00 WHSUR P WHDTRE N/U Adapter Flange & Tree. Test Adapter Flange to 5000 psi. - OK. Attempt to test tree. NG. 12:00 - 14:30 2.50 WHSUR N SFAL WHDTRE Trouble shoot problem. Determined the TWC was leaking. RIU DSM lubricator and change out TWC. Test Tree to 5000 psi. - OK. Pull TWC. 14:30 - 17:00 2.50 WHSUR P OTHCMP R/U Cirulating lines. PJSM with Little Red. Pressure test lines Printed: 8/9/2004 9:39:53 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-01 N-01 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/21/2004 Rig Release: 8/6/2004 Rig Number: Spud Date: 9/2/1970 End: 8/6/2004 17:00 - 17:30 17:30 - 18:00 0.50 DHB P 0.50 WHSUR P OTHCMP to 2500 psi. Pump 75 Bbls Diesel down annulus. Shut in and allow to U-Tube to freeze protect to 2200' MD. POST Set BPV. Test from below to 1000 psi. R/D Uttle Red. POST R/D & B/O Cìrc lines. Secure Well. RIG RELEASED @ 18:00 HRS. 8/6/2004. 8/6/2004 14:30 - 17:00 2.50 WHSUR P Printed: 8/9/2004 9:39:53 AM . . Well: Field: API: Permit: N-01 A Prudhoe Bay Unit 50-029-20079-01-00 204-113 Accept: Spud: Release: Rig: 07/22/04 07/27/04 08/06/04 Nabors 7ES POST RIG WORK 08/25/04 PULL B&R, PULLED STA'S 1,3,4,5. RAN STA'S 5, 4, & 3. 08/26/04 SET STA # 1, PULLED RHC. 08/27/04 A RST WAS RUN TO DETERMINE PERF INTERVALS AFTER A RECENT SIDETRACK. FIELD PICK GOC WAS 9214'. TD TAGGED @ 9655. JEWELRY LOG RAN TO 6700'. DEPTH CORRELATED INTO ORIGINAL WELL USING BHCS LOG AROUND 7000'. WELL LEFT SHUT IN PAD OPERATOR NOTIFIED. RDMO. 09/18/04 PERFORATED INTERVAL 9380'-9420' WITH 2 7/8" 2906 PJ 6 SPF 60 DEGREE PHASING, 15 GRAM CHARGE, 27.7" PENETRATION, 0.36" ENTRY HOLE, 242 SHOTS TOTAL. 09/21/04 DEPTH CORRECTED TO SLB RST DATED 27-AUG-04. SHOT 2.88" HSD 6SPF 60 DEG PHASED PJ 2906 GUN FROM 9430'-9455' AS PER PROGRAM. WHP WAS 400 PSI FOR ENTIRE JOB. RAN HEAD, CCL, 20 & 5 FT GUN CONNECTED WITH TCP ADAPTERS AND 3FT BY 31N STEM ROLLERS ON BOTTOM. TAGGED BOTTOM AT 9648'. ALL SHOTS FIRED. PAD OP NOTIFIED WELL SECURE AND SHUT-IN. . . 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well N-01A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,311.78' MD 7,316.00' MD 9,750.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date JYJ~Y-)JJ6 c! Signed JkVJdjJ ðJLJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) },O-{ ~ )I:?- Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA N Pad N-01A Job No. AKZZ3190325, Surveyed: 4 August, 2004 Survey Report 25 August, 2004 Your Ref: 500292007901 Surface Coordinates: 5967423.00 N, 634414.00 E (700 19' 08.1830" N, 148054' 37.2370" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 967423.00 N, 134414.00 E (Grid) Surface Coordinates relative to Structure Reference: 1983.09 N, 1047.14 E (True) Kelly Bushing Elevation: 73.88ft above Mean Sea Level Kelly Bushing Elevation: 73.88ft above Project V Reference Kelly Bushing Elevation: 73.88ft above Structure Reference 5pararaY-5Ufl DRILLING SERVICES A Halliburton Company DEFINITIVE . . Survey Ref: svy4346 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A Your Ref: 500292007901 Job No. AKZZ3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7311.78 2.000 329.000 7231.02 7304.90 74.73 N 66.82 W 5967496.53 N 634345.86 E 50.55 Tie-on Point AK-6 BP -'FR-AK - MWD+IIFR+M 7316.00 1.990 330.130 7235.23 7309.11 74.86 N 66.89 W 5967496.65 N 634345.78 E 0.962 50.65 Window Point 7332.00 2.740 359.770 7251.22 7325.10 75.48 N 67.03 W 5967497.27 N 634345.63 E 8.814 51.20 7377.50 1.850 356.380 7296.68 7370.56 77.30 N 67.08 W 5967499.09 N 634345.54 E 1.978 52.91 . 7385.50 1.950 356.280 7304.68 7378.56 77.57 N 67.10 W 5967499.36 N 634345.52 E 1.251 53.16 7395.50 1.930 354.200 7314.67 7388.55 77.91 N 67.13 W 5967499.69 N 634345.49 E 0.732 53.47 7406.50 1.990 1.800 7325.67 7399.55 78.28 N 67.14 W 5967500.07 N 634345.47 E 2.423 53.83 7423.50 1.830 354.950 7342.66 7416.54 78.85 N 67.15 W 5967500.63 N 634345.44 E 1.638 54.36 7489.00 1.620 354.060 7408.13 7482.01 80.81 N 67.34 W 5967502.59 N 634345.22 E 0.323 56.17 7519.00 2.310 353.240 7438.11 7511.99 81.83 N 67.46 W 5967503.61 N 634345.09 E 2.302 57.11 7536.00 3.450 357.180 7455.09 7528.97 82.68 N 67.52 W 5967504.46 N 634345.01 E 6.802 57.90 7569.00 6.710 7.540 7487.96 7561.84 85.59 N 67.32 W 5967507.37 N 634345.16 E 10.223 60.72 7595.86 9.030 10.150 7514.56 7588.44 89.22 N 66.74 W 5967511.01 N 634345.67 E 8.737 64.35 7627.61 11.090 12.030 7545.82 7619.70 94.66 N 65.67 W 5967516.47 N 634346.65 E 6.569 69.86 7654.89 13.360 13.100 7572.48 7646.36 100.29 N 64.40 W 5967522.13 N 634347.81 E 8.362 75.61 7689.29 15.690 14.070 7605.78 7679.66 108.68 N 62.37 W 5967530.54 N 634349.69 E 6.810 84.22 7720.32 17.540 14.880 7635.51 7709.39 117.27 N 60.15 W 5967539.17 N 634351.76 E 6.008 93.07 7752.01 19.250 16.910 7665.58 7739.46 126.88 N 57.41 W 5967548.83 N 634354.33 E 5.761 103.06 7784.20 20.560 16.040 7695.85 7769.73 137.39 N 54.30 W 5967559.40 N 634357.25 E 4.172 114.02 7815.91 21.700 16.710 7725.43 7799.31 148.36 N 51.08 W 5967570.42 N 634360.28 E 3.675 125.45 7847.22 22.770 17.510 7754.41 7828.29 159.68 N 47.59 W 5967581.80 N 634363.56 E 3.552 137.29 . 7879.88 24.360 18.390 7784.34 7858.22 172.10 N 43.56 W 5967594.29 N 634367.36 E 4.986 150.35 7911.93 25.790 18.670 7813.37 7887.25 184.98 N 39.24 W 5967607.25 N 634371.45 E 4.477 163.93 7943.27 27.510 19.490 7841.38 7915.26 198.26 N 34.65 W 5967620.61 N 634375.81 E 5.612 177.98 7975.19 29.090 19.420 7869.48 7943.36 212.53 N 29.61 W 5967634.97 N 634380.59 E 4.951 193.11 8007.38 30.350 19.960 7897.44 7971.32 227.56 N 24.23 W 5967650.08 N 634385.70 E 4.002 209.06 8036.91 31.710 20.200 7922.74 7996.62 241.85 N 19.00 W 5967664.47 N 634390.67 E 4.624 224.27 8070.67 33.320 20.970 7951.21 8025.09 258.84 N 12.62 W 5967681.57 N 634396.75 E 4.924 242.40 8104.84 34.640 21.080 7979.55 8053.43 276.66 N 5.77W 5967699.52 N 634403.28 E 3.867 261.47 8132.32 36.430 20.940 8001.91 8075.79 291.57 N 0.04W 5967714.53 N 634408.74 E 6.521 277.41 25 August, 2004 - 10:39 Page 20f4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A Your Ref: 500292007901 Job No. AKZZ3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska Measured True Sub-5ea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8169.80 38.780 21.420 8031.60 8105.48 312.90 N 8.22 E 5967735.99 N 634416.62 E 6.318 300.25 8201.67 40.730 21.490 8056.10 8129.98 331.86 N 15.68 E 5967755.09 N 634423.73 E 6.120 320.59 8228.27 42.620 21.350 8075.96 8149.84 348.33 N 22.14 E 5967771.67 N 634429.90 E 7.114 338.24 8265.12 44.760 22.010 8102.61 8176.49 371.98 N 31.54 E 5967795.48 N 634438.88 E 5.938 363.64 8297.21 46.760 22.620 8125.00 8198.88 393.25 N 40.27 E 5967816.90 N 634447.22 E 6.379 386.56 8325.47 47.820 22.600 8144.16 8218.04 412.41 N 48.26 E 5967836.21 N 634454.86 E 3.751 407.25 . 8421.72 48.200 22.630 8208.56 8282.44 478.45 N 75.77 E 5967902.73 N 634481.19 E 0.395 478.55 8517.41 48.930 22.110 8271.88 8345.76 544.79 N 103.07 E 5967969.55 N 634507.29 E 0.865 550.08 8613.19 50.210 20.620 8334.00 8407.88 612.69 N 129.62 E 5968037.91 N 634532.63 E 1.785 622.85 8707.85 49.680 20.650 8394.91 8468.79 680.50 N 155.15 E 5968106.16 N 634556.94 E 0.560 695.22 8802.98 51.200 21.460 8455.50 8529.38 748.94 N 181.50 E 5968175.07 N 634582.06 E 1.727 768.45 8897.90 50.780 21.080 8515.25 8589.13 817.67 N 208.26 E 5968244.26 N 634607.59 E 0.541 842.08 8968.00 50.640 21.010 8559.64 8633.52 868.30 N 227.74 E 5968295.24 N 634626.16 E 0.214 896.25 8990.35 51.140 21.100 8573.73 8647.61 884.49 N 233.97 E 5968311.53 N 634632.10 E 2.259 913.57 9023.00 53.210 20.460 8593.76 8667.64 908.60 N 243.12 E 5968335.80 N 634640.81 E 6.526 939.32 9054.81 54.920 20.920 8612.42 8686.30 932.69 N 252.22 E 5968360.06 N 634649.48 E 5.502 965.05 9086.17 56.470 21.140 8630.10 8703.98 956.87 N 261.52 E 5968384.40 N 634658.34 E 4.976 990.91 9118.10 58.310 21.200 8647.30 8721.18 981.95 N 271.23 E 5968409.65 N 634667.60 E 5.765 1017.77 9149.80 59.960 20.780 8663.57 8737.45 1007.35 N 280.98 E 5968435.22 N 634676.89 E 5.328 1044.94 9181.74 62.120 20.860 8679.03 8752.91 1033.47 N 290.91 E 5968461.52 N 634686.36 E 6.766 1072.85 9216.86 65.040 22.240 8694.66 8768.54 1062.72 N 302.46 E 5968490.97 N 634697.39 E 9.028 1104.23 9248.57 67.460 22.450 8707.43 8781.31 1089.56 N 313.50 E 5968518.00 N 634707.94 E 7.656 1133.17 . 9276.80 67.520 23.050 8718.23 8792.11 1113.61 N 323.58 E 5968542.23 N 634717.59 E 1.975 1159.15 9372.79 67.060 21.760 8755.29 8829.17 1195.47 N 357.33 E 5968624.68 N 634749.87 E 1.329 1247.43 9466.86 66.930 24.670 8792.06 8865.94 1275.04 N 391.46 E 5968704.85 N 634782.57 E 2.851 1333.63 9564.26 66.590 23.510 8830.50 8904.38 1356.74 N 427.99 E 5968787.19 N 634817.63 E 1.149 1422.61 9660.30 65.910 22.050 8869.18 8943.06 1437.79 N 462.03 E 5968868.83 N 634850.21 E 1.561 1510.20 9687.60 65.930 22.360 8880.32 8954.20 1460.86 N 471.45 E 5968892.07 N 634859.21 E 1.039 1535.05 9750.00 65.930 22.360 8905.77 8979.65 1513.55 N 493.12 E 5968945.14 N 634879.94 E 0.000 1591.85 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 17.920° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9750.00ft., 25 August, 2004 - 10:39 Page 30f4 DrilIQuest~0~0~006 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A Your Ref: 500292007901 Job No. AKZZ3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska The Bottom Hole Displacement is 1591.86ft., in the Direction of 18.046° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7311.78 7316.00 9750.00 7304.90 7309.11 8979.65 74.73 N 74.86 N 1513.55 N 66.82 W 66.89 W 493.12 E Tie-on Point Window Point Projected Survey . Survey tool proaram for N-01A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7311.78 0.00 7304.90 7311.78 9750.00 7304.90 BP High Accuracy Gyro (N-01) 8979.65 AK-6 BP _IFR-AK - MWD+IIFR+MS (N-01A) . 25 August, 2004 - 10:39 Page 4 of4 DrillQuest 3.03.06.006 . . 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well N-01A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,311.78' MD 7,316.00' MD 9,750.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date [<--( ~01 /]/ J. ('lILt Signed )H/VJ'/V-¿ U.Þ ./ß. Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Å D ~(-! ( S Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA N Pad N-01A MWD . Job No. AKMW3190325, Surveyed: 4 August, 2004 Survey Report 25 August, 2004 Your Ref: 50292007901 Surface Coordinates: 5967423.00 N, 634414.00 E (70· 19' 08.1830" N, 148· 54' 37.2370" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 967423.00 N, 134414.00 E (Grid) Surface Coordinates relative to Structure Reference: 1983.09 N, 1047.14 E (True) Kelly Bushing Elevation: 73.88ft above Mean Sea Level Kelly Bushing Elevation: 73.88ft above Project V Reference Kelly Bushing Elevation: 73.88ft above Structure Reference 55pa............y-55LJr1 DAILLING SEAVlces A Halliburton Company Survey Ref: svy4347 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A MWD Your Ref: 50292007901 Job No. AKMW3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7311.78 2.000 329.000 7231.02 7304.90 74.73 N 66.82 W 5967496.53 N 634345.86 E 50.55 Tie-on Point MWD Magnetic 7316.00 1.990 330.130 7235.23 7309.11 74.86 N 66.89 W 5967496.65 N 634345.78 E 0.962 50.65 Window Point 7332.00 2.740 359.770 7251.22 7325.10 75.48 N 67.03 W 5967497.27 N 634345.63 E 8.814 51.20 7377.50 1.850 356.380 7296.68 7370.56 77.30 N 67.08 W 5967499.09 N 634345.54 E 1.978 52.91 7385.50 1.950 356.280 7304.68 7378.56 77.57 N 67.10 W 5967499.36 N 634345.52 E 1.251 53.16 . 7395.50 1.930 354.200 7314.67 7388.55 77.91 N 67.13W 5967499.69 N 634345.49 E 0.732 53.47 7406.50 1.990 1.800 7325.67 7399.55 78.28 N 67.14 W 5967500.07 N 634345.4 7 E 2.423 53.83 7423.50 1.830 354.950 7342.66 7416.54 78.85 N 67.15W 5967500.63 N 634345.44 E 1.638 54.36 7489.00 1.620 354.060 7408.13 7482.01 80.81 N 67.34 W 5967502.59 N 634345.22 E 0.323 56.17 7519.00 2.310 353.240 7438.11 7511.99 81.83 N 67.46 W 5967503.61 N 634345.09 E 2.302 57.11 7536.00 3.450 357.180 7455.09 7528.97 82.68 N 67.52 W 5967504.46 N 634345.01 E 6.802 57.90 7569.00 6.710 7.540 7487.96 7561.84 85.59 N 67.32 W 5967507.37 N 634345.16 E 10.223 60.72 7595.86 9.030 10.150 7514.56 7588.44 89.22 N 66.74 W 5967511.01 N 634345.67 E 8.737 64.35 7627.61 11.090 12.030 7545.82 7619.70 94.66 N 65.67 W 5967516.47 N 634346.65 E 6.569 69.86 7654.89 13.360 13.100 7572.48 7646.36 100.29 N 64.40 W 5967522.13 N 634347.81 E 8.362 75.61 7689.29 15.690 14.250 7605.78 7679.66 108.67 N 62.36 W 5967530.54 N 634349.71 E 6.825 84.22 7720.32 17.540 15.040 7635.51 7709.39 117.26 N 60.11 W 5967539.16 N 634351.80 E 6.006 93.07 7752.01 19.250 16.930 7665.58 7739.46 126.87 N 57.35 W 5967548.82 N 634354.39 E 5.714 103.07 7784.20 20.560 15.950 7695.85 7769.73 137.38 N 54.25 W 5967559.39 N 634357.30 E 4.199 114.02 7815.91 21.700 16.770 7725.43 7799.31 148.35 N 51.03 W 5967570.41 N 634360.32 E 3.714 125.45 7847.22 22.770 17.600 7754.41 7828.29 159.66 N 47.53 W 5967581.79 N 634363.62 E 3.562 137.29 7879.88 24.360 18.430 7784.34 7858.22 172.08 N 43.49 W 5967594.27 N 634367.44 E 4.973 150.35 . 7911.93 25.790 18.870 7813.37 7887.25 184.95 N 39.14 W 5967607.22 N 634371.55 E 4.500 163.93 7943.27 27.510 19.070 7841.38 7915.26 198.24 N 34.57 W 5967620.59 N 634375.88 E 5.496 177.99 7975.19 29.090 19.910 7869.48 7943.36 212.51 N 29.52 W 5967634.94 N 634380.68 E 5.105 193.11 8007.38 30.350 20.460 7897.44 7971.32 227.48 N 24.01 W 5967650.02 N 634385.92 E 4.005 209.06 8036.91 31.710 20.740 7922.74 7996.62 241.73 N 18.66 W 5967664.36 N 634391.02 E 4.631 224.26 8070.67 33.320 21.470 7951.21 8025.09 258.66 N 12.12W 5967681.40 N 634397.25 E 4.908 242.38 8104.84 34.640 21.580 7979.55 8053.43 276.42 N 5.11 W 5967699.29 N 634403.94 E 3.867 261.44 8132.32 36.430 21.430 8001.91 8075.79 291.28 N 0.74E 5967714.25 N 634409.52 E 6.522 277.38 25 August, 2004 - 10:39 Page 20f4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A MWD Your Ref: 50292007901 Job No. AKMW3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8169.80 38.780 21.580 8031.60 8105.48 312.56 N 9.12 E 5967735.67 N 634417.53 E 6.275 300.21 8201.67 40.730 21.920 8056.10 8129.98 331.49 N 16.68 E 5967754.73 N 634424.74 E 6.157 320.54 8228.27 42.620 21.710 8075.96 8149.84 347.91 N 23.25 E 5967771.27 N 634431.02 E 7.125 338.18 8265.12 44.760 22.520 8102.61 8176.49 371.49 N 32.83 E 5967795.02 N 634440.18 E 6.002 363.57 8297.21 46.760 23.140 8125.00 8198.88 392.67 N 41.76 E 5967816.36 N 634448.72 E 6.384 386.47 8325.47 47.820 23.090 8144.16 8218.04 411.77 N 49.91 E 5967835.60 N 634456.53 E 3.753 407.15 . 8421.72 48.200 23.210 8208.56 8282.44 477.55 N 78.03 E 5967901.87 N 634483.47 E 0.406 478.39 8517.41 48.930 22.150 8271.88 8345.76 543.74 N 105.69 E 5967968.55 N 634509.94 E 1.128 549.88 8613.19 50.210 21.510 8334.00 8407.88 611.42 N 132.80 E 5968036.70 N 634535.83 E 1 .430 622.62 8707.85 49.680 21.020 8394.91 8468.79 678.94 N 159.08 E 5968104.68 N 634560.89 E 0.686 694.95 8802.98 51.200 21.150 8455.50 8529.38 747.37 N 185.46 E 5968173.57 N 634586.05 E 1.601 768.18 8897.90 50.780 20.670 8515.24 8589.12 816.27 N 211.79 E 5968242.93 N 634611.13 E 0.592 841.83 8968.00 50.640 21.010 8559.63 8633.51 866.97 N 231.09 E 5968293.97 N 634629.52 E 0.425 896.02 8990.35 51.140 21.310 8573.73 8647.61 883.15 N 237.35 E 5968310.25 N 634635.49 E 2.468 913.33 9023.00 53.210 20.780 8593.76 8667.64 907.21 N 246.61 E 5968334.48 N 634644.32 E 6.468 939.08 9054.81 54.920 21.290 8612.42 8686.30 931.25 N 255.85 E 5968358.68 N 634653.13 E 5.530 964.80 9086.17 56.470 21.520 8630.10 8703.98 955.37 N 265.31 E 5968382.97 N 634662.16 E 4.980 990.65 9118.10 58.310 21.570 8647.30 8721.18 980.39 N 275.18 E 5968408.16 N 634671.58 E 5.764 1017.49 9149.80 59.960 21.160 8663.57 8737.45 1005.73 N 285.09 E 5968433.67 N 634681.04 E 5.322 1044.66 9181.74 62.120 21.200 8679.03 8752.91 1031.78 N 295.19 E 5968459.90 N 634690.67 E 6.764 1072.55 9216.86 65.040 22.580 8694.66 8768.54 1060.96 N 306.92 E 5968489.29 N 634701.87 E 9.028 1103.93 9248.57 67.460 22.790 8707.43 8781.31 1087.74 N 318.11 E 5968516.26 N 634712.58 E 7.656 1132.85 . 9276.80 67.520 23.360 8718.23 8792.11 1111.73 N 328.33 E 5968540.43 N 634722.37 E 1.877 1158.82 9372.79 67.060 22.030 8755.29 8829.17 1193.42 N 362.50 E !?968622.72 N 634755.07 E 1.365 1247.06 9466.86 66.930 24.920 8792.06 8865.94 1272.83 N 396.99 E 5968702.74 N 634788.13 E 2.831 1333.23 9564.26 66.590 23.820 8830.50 8904.38 1354.35 N 433.91 E 5968784.90 N 634823.59 E 1.095 1422.16 9660.30 65.910 22.300 8869.18 8943.06 1435.23 N 468.35 E 5968866.38 N 634856.57 E 1.612 1509.71 9687.60 65.930 22.670 8880.32 8954.20 1458.26 N 477.88 E 5968889.58 N 634865.69 E 1.240 1534.55 9750.00 65.930 22.670 8905.77 8979.65 1510.83 N 499.84 E 5968942.54 N 634886.71 E 0.000 1591.33 Projected Survey All data is in Feet (US Survey) 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. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 17.920· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9750.00ft., 25 August, 2004 - 10:39 Page 30f4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-01A MWD Your Ref: 50292007901 Job No. AKMW3190325, Surveyed: 4 August, 2004 BPXA North Slope Alaska The Bottom Hole Displacement is 1591.37ft., in the Direction of 18.306° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7311.78 7316.00 9750.00 7304.90 7309.11 8979.65 74.73 N 74.86 N 1510.83 N 66.82 W 66.89 W 499.84 E Tie-on Point Window Point Projected Survey . Survey tool prOf/ram for N-01A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 7311.78 0.00 7304.90 7311.78 9750.00 7304.90 BP High Accuracy Gyro (N-01) 8979.65 MWD Magnetic (N-01A MWD) . 25 August, 2004 - 10:39 Page 4 of4 DrillQuest 3.03.06.006 N-01A .. þ I &: ~ ~ w: t· ~ I fi, Þ 1 &. I~~~~~ ~9~~;4~~ /1 2088' 11...0.3/4' CSG, 5. .5.5# ;>:/-J N-SO. ID =9.953" . I 242õ /13-3/8" CSG, te#. K'li 4200' 55. D = 12.415" 19 5/8" DV Pa eke r -j 6,500' 7" X9 5/8" Bå<:er Ht.£ liner hanger, ZXP liner top packer (0) itt. lBS. 7,171' I::~:~ :~:'e~~:.Stoek 11 7,33£ 1=9 :':~,:7#, N-ffi. ID 11 9:IJ9' . . SAFETY CSG. TES: "'OOA HAS H-40 ,MT ..()OA 1200 PSI'" -I 1900' H 13- 3/8" DV PKR / 2,187 -j4 2291' H 10-3/4' DV PI-<R 1 242õ H1()'3/4' x9-5/S"XO --¡: 8,741' H41/2" 'X' Landing Nip. I.D. =3.813" I 8762' 1-17" X41/2" Bå<:er S-3 production pkr 1 8785' 1-14 1/2" 'X' Landing Np. !.D. = 3.S13" I 0006' H41/2" 'XN' Landing Nip. I.D. =3.725"/ I 8,819' H41/2". 12.6#. 13Cr-00, ~ _ Mapco 200 _ Cement . L. L GAS LIFT M'\NDRB..S DBI 38" .3" 5 4 3 IvÐ 3289 500S 7XJ7 7934 S$9 ND 3300 5600 7200 7900 8400 1.8 25.S" 50.2" 2 =-------. ~ . La. VA lV' E Durrrny DCK Du rTrn>,' DUrTfTf\' Durrrny LATCH BK BK BK BK BK - 5" X 7" Bå<:er HM: liner hanger, ZXP lin er top pa eke r w ith Tie B aek S leev e. 8, 008' ~xY¡Y:i:'!YlY;'x.) ;1 >.~{.: . XY.~~ .. . ¡.'/.. 'XX . '. ,oJ',/.. X , 9, 748' 9,662' 07124/74 OS/10.€l7 11.05.01 10/16.02 12/17.02 OS/1 6.03 RBI EIY COtut.18'-1TS ORIGIAALC OM PL ET ION RWO RN/TP CORRB:;TONS MI-VKAK GLV C/O A ID/14< CORRB:;TONS C MJ/lLP MAX. AN GLE CO RR ECTION C OMtvENTS 10/04103 DACfTLP Dt...tr EX1ENDED PACKNG 07/14104 dew Proposed Completion PRUDHOE BAY UNIT' WELL: N-01A PBiMT No: API No: 00-029·20079-01 SEC S, T11N. R13E'. 4724 WB.. &3761' SNL SP &ploratjon (Alas ka) . íñì lW . I~\ ,- !fJ\ LrJ ~ U\J FRANK H. MURKOWSKI, GOVERNOR A. I/ASJiA OIL AND GAS CONSERVATION COMMISSION 333 W. 'JT" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27&7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay N-OIA BP Exploration (Alaska) Inc. Permit No: 204-113 Surface Location: 3761' SNL, 4724' WEL, SEe. 08, TIIN, R13E, UM Bottomhole Location: 2920' SNL, 4266' WEL, SEC. 08, TI1N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) -3607 (pager). BY ORDER OF THE COMMISSION DA TED thisi!. day of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \¡J 6ft 4' /2.,. ~ (Z.CO t , . STATE OF ALASKA I ALASKÀ OIL AND GAS CONSERVATION CO MISSIQ,N"._ PERMIT TO DRILL o Drill III Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3761' SNL, 4724' WEL, SEC. 08, T11N, R13E, UM Top of Productive Horizon: 2687' SNL, 4402' WEL. SEC. 08, T11N, R13E. UM Total Depth: 2920' SNL. 4266' WEL, SEC. 08, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-634414 y-5967423 Zone-ASP4 16. Deviated Wells: Kickoff Depth 1~t\Casing Program Size Casinç¡ 7" 20 MC 25.0052 ìììfH rb. Current Well ClaÖ Stratigraphic Test 8 ~~~f~:torY,,~~;~~~~:g: g~~g ~,~~il~~~~~e 5. Bond: a Blanket 0 Single Well' '11.' Well \ am.e ,andNumber: Bond No. 2S100302630-277 PBU N-01A / 6. Proposed Depth: 12. Field / Pool(s): MD 9596 TVD 8927 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028282 8. Land Use Permit: 13. Approximate Spud Date: July 10, 2004 14. Distance to Nearest Property: 23,000' 9. Acres in Property: 2560 7300 ft Maximum Hole Angle 680 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 71.69 feet N-14A is 1275' away at 9595' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200 psig Surface: 2320 psig / Settingq~P!Þ Top>'> " .' ' 'Bôttôm MD TVD MD TVD 7150' 7143' 8949' 8639' 8799' 8538' 9596' 8927' Hole 8-1/2" 6-1/8" 4-1/2" Weiç¡ht 26# 12.6# Grade L-80 L-80 Coupling Lenç¡th BTC-M 1799' IBT-M 797' (includinç¡ swç¡e data) 169 sx Class 'G' /' 111 sx Class 'G' ,./ PRESENT,.w.ELLCONDITION SUMMARY' . (To be complEltEldfOl' Redl'iU',A.ND Re-entryOperatjøoª) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD 9340 9332 8896 8896 8888 Structural Conductor Surface Intermediate Production Liner 80' 2088' 4200' 9309' 30" 20" 13-3/8" 10-3/4" X 9-5/8" 300 sx Permafrost II 4500 sx Permafrost II 1860 sx Class 'G', 1800 sx Class 'G' 1510 sx Class 'G', 400 sx Class 'G' 80' 2088' 4200' 9309' 80' 2088' 4195' 9301' 20. Attachments a Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8772' - 9004' a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report a Drilling Fluid Program a 20 AAC 25.050 Requirements Perforation Depth MD (ft): 8780' - 9012' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Date: ' Contact Dave Wesley, 564-5153 Phone 564-5521 Date '/zz/d1 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill Number~ r¡t - //.3 50-029-20079-01-00 Conditions of Approval: Samples Required 0 Yes ~o _ '_ Hy~rogen Sulfide Measures . ~es 0 No f' Other: I fÇ,/- B{/ }L:" +C 3'500 r1':.i p ~ý c. o. rï:;1'c - S.O"5S (h J Lt \) "'Hu.....t€. APProVedB'/~ OnlCINAL Form 10-401~~003 ~ \ ' Permit Approv~ . See cover letter for Date: U' other requirements Mud Log Required 0 Yes ßNo Directional Survey Required ~es 0 No 5/fo,occ gaPE 1(,. C\.(J fJ1)I/<:d. BY ORDER OF Gh.Ä1cA I THE COMMISSION Dale ~,;'~ ~J.;ica~ - . Well I I N-01A . Planned Well Summary Well Type Conventional II Target Sidetrack Objective Zone 4A I AFE Number: I PSD 4P2205 I Surface Location Northing 5,967,423.00 Target Location Northing 5,968,503.00 Bottom Location Northing 5,968,832.00 I Planned KOP: Planned Spud: 17,300' md 07/10/04 I Rig: I Nabors 7ES I / Approved Well plan: Maximum Hole Inclination: Proximity Issues: Survey Program: Nearest Well within pool: Nearest Property Line I API Number: I 50-029-20079-01 Easting I Offsets 634,414.00 3,761' FNL / 4,724' FEL I TRS I 11 N, 13 E, 08 -- Easting I Offsets 634,713.00 2,687' FNL / 4,402' FEL I TRS I 11 N, 13 E, 08 .- Easting I Offsets I TRS I 634,842.00 2,920' FNL / 4,266' FEL 11 N, 13 E, 08 -- I Planned TD: 19,596' md Planned TVD: 8,927' -- I BFE: I RTE: 171.69' 143.19' Directional ProQram Wp04 I Exit point: I 7,300' md /7,221' sstvd _7° at 3,900' in the original well bore, 68.0° in the planned 6 1/8" production section from 9,210' md to TO at 9,596' md. There are no close approach issues in drilling N-01 A. All surrounding wells pass major risk criteria. Standard MWO with IIFR I Cassandra. Well N-14A, with center-to-center distance of -1,275' at 9,595' md. 23,000' to the nearest PBU property line. LOQQinQ Proqram Hole Section: 8 W' intermediate: 6 1/8" production: Cased Hole: Open Hole: Required Sensors I Service Real time MWO Oir/GR/PWO throughout the interval. Real time MWO Oir/GR/Res throughout the interval. Two sample catchers will be required at company man call out. None planned None planned N-01 A Sidetrack Page 1 . . Mud Pro~ram Type LSND Hole Section I operation: I Density (ppg) I Viscosity I PV 10.8 50 - 60 10 - 15 Set Whip stock I mill window in 9 5/8" casing VP I Tau 0 I API FL I pH 40+ 5 - 9 5 - 7 9.0 - 9.5 Hole Section I operation: Type I Den~g) I Viscosity I LSND er 45 - 55 Hole Section I operation: Type I Density (ppg) I Viscosity I FloPro SF 8.5 - 8.6 45 - 55 PV 12 -16 Drilling 8 %" interval from window to section TD VP I Tau 0 I API FL I pH 22 - 28 3 - 7 4 - 5 9.0 PV 8 -12 Drilling 6 1/8" production interval VP I MBT I API FL 25 - 30 <3 4 - 6 pH 9.0- 9.5 Casin~ I Tubin~ Pro~ram Hole CasingITubing Wt. Grade Connection Length Top Bottom Size Size / .-/ md I tvd md I tvd 8 Y2" 7" 26.0# L-80 BTC-M 1,799' 7,150/7,143 8,949 I 8,639 61/8" 4 Y2" 12.6# L-80 IBT-M 797' 8,799 I 8,538 9,596 I 8,927 Tubing 4 Y2" 12.6# 13Cr-80 VAM TOP 8,799' Surface 8,799 I 8,538 Casing String: Slurry Design Basis: Fluids Sequence I Volume: Casing String: Slurry Design Basis: Fluids Sequence I Volume: N-01 A Sidetrack Cementin~ Proqram 7",26#, L-80, BTC-M drilling liner Lead slurry: None planned Tail slurry: 1,000' of 7" X 8 %" annulus with 40% excess, plus 85' of 7", 26# shoe track. Pre-Flush Spacer Lead Slurry Tail Slurry None planned 45bbls MudPUSH at 11 .8ppg None planned /j /.'~// ,; 34.9bbl I 196 c~sx Class 'G', 15.8PP9;~/Sk. 41/2",12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Tail slurry: 647' of 41/2" X 61/8" annulus with 40% excess, plus 85' of 4 1/2", 12.6# shoe track, plus 150' of 7" X 4 %" liner lap, plus 200' of 7" X 4" drill pipe annulus. Pre-Flush Spacer Lead Slurry Tail Slurry 15bbls CW 100 25bbls MudPUSH at 9.6ppg None planned .L i .r::.'.A 23.8bbl I 134 cf C~x Class 'G', 15.8PP9;~f/sk. Page 2 . Test 95/8" casing to surface Intermediate casing window 9 5/8" casing / 7" liner Intermediate liner shoe . Casinq I Formation InteQritv TestinQ Test Point Bridge plug to surface 20' beyond middle of window Float equipment to surface 20' new formation beyond shoe Test pressure 3,500psi surface 12.3ppg EMW 3,500psi surface 10.0ppg EMW Test Type 30 min recorded FIT 30 min recorded FIT / ,/ Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: BOPE configuration for 7" drilling liner. Well Interval: Maximum anticipated BHP: Maximum surface pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned completion fluid: 8 W' intermediate drilling liner section 3,100psi at 8,500' sstvd. 2,~i (based upon BHP and a full column of gas from TD @ 0.10 psilft) )fÍfiniWwith 11.1 ppg EMW FIT /' ~si low / 3,500psi high -14 day test cycle ,/ Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams. * The rig will follow the current, best practice of picking up a joint of drill pipe, crossed over to casing thread, in the event of a kick. This configuration provides two sets of employable rams, rather than one. 6 1/8" production liner section 3,200psi at 8,800' sstvd. 5' psi (based upon BHP and a full column of gas from TD@0.1 0 psi/ft) finitp' with 10.0ppg EMW FIT. "si low / 3,500psi high 8.4ppg seawater /7.1 ppg Diesel Disposal No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. Any metal cuttings should be sent to the North Slope Borough. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for injection. All Class I wastes are to be hauled to Pad 3 for disposal. Annular Injection: Cuttings Handling: Fluid Handling: N-01 A Sidetrack Page 3 . . GeoloQic ProQnosis Formation MD TVDbkb TVDss Comments SV1 Above Kick off point UG4 Above Kick off point UG4A Above Kick off point UG3 Above Kick off point UG1 Above Kick off point WS2 Above Kick off point WS1 Above Kick off point CM3 Above Kick off point CM2 Above Kick off point CM1 Above Kick off point THRZ Above Kick off point BHRZ Above Kick off point LCU Above Kick off point ID.t' TKNG 7,219 TJG 7,394 7,315 TJF 7,748 7,658 TJE 7,956 7,847 TJO 8,245 8,085 TJC 8,569 8,311 TJB 8,738 8,425 TJA TSGR 8,949 8,567 TSHU 9,005 8,605 TSAOffZ4B 9,122 8,672 PGOC 9,225 8,716 POWC 8,786 TCGLfTZ3 9,483 8,813 -3,200psi (7.0ppg EMW) BCGLfTZ2C 8,893 Below planned TO TD Criteria I TD Criteria: I 200' MO below the POWC. This includes -100' for shoe track. Fault Proclnosis Fault Fault #1 Formation Encountered Kingak (T JF) MD Intersect 7,770 TVDss Intersect -7,678 Estimated Throw -36' Direction of Throw SW Uncertainty +/- 1 00' N-01 A Sidetrack Page 4 . . Operations Summary Pre-Riq Operations: 1. Function all tubing hanger and 10 3fi¡" casing lock down screws and verify free movement. Completely back out and check each lock down screw for breakage. 2. The 1 0 3fi¡" casing pack off will be changed during this RST. 3. CMIT T X IA to 3,000psi (conducted 1/21/2004, passed.) 4. MIT OA to 2,500psi (conducted 1/29/2004, passed.) 5. R/U slick line. RIH and pull the 'PX' plug from the Sliding sleeve at 8,354'md. 6. R/U slick-line. Drift through the 5 W' X 4 %" tubing and tag fill (apparently tubing plastic coating) on top of the 'PX' plug in the 'X' nipple at 8,480'md. Confirm sufficient clearance for appropriate chemical cutter in the 4 W' tubing above the fill, but below the HBBP packer. Top of fill expected at 8,447' SLM. 7. R/U E-line. RIH and chemical cut the 4 1/2" tubing tail free at -8,445', below the HBBP packer. POOH. 8. Drift through the cut off tail, to near top of fill, and confirm clearance for upcoming coil tubing cement P&A. 9. R/U coil tubing. RIH and P&A the open perforations, and 95/8" casing with Class 'G', 15.8ppg slurry to -8,400'md. The estimated cement volume necessary to plug and abandon the well is 45.0bbls. This consists of 34.3bbls in the 9 5/8" casing below the packer, 0.7bbls in the 4 %" tubing, and -10.0bbls to squeeze the perforations. 10. Pressure-test the cement plug to 1,000 psi. 11. Drift the tubing to the planned chemical cut depth of 7,500'md, if deemed necessary. 12. R/U E-line. RIH and chemical cut the 4 %" tubing at -7,500'md. 13. Circulate the well clean with seawater, through the tubing cut. Freeze protect tubing and casing with diesel from 2,200' to surface. 14. Bleed casing and annulus pressures to zero. 15. Set a BPV. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors rig 7ES. / 2. R/U DSM and lubricator. Pull the BPV. 3. R/U lines and circulate out diesel freeze protection and displace ~. well to seawater. Install TWC. 4. Nipple down the tree. Nipple up the BOPE and test to 3,500psi. 5. R/U spooling unit to retrieve the SSSV control lines. Pull the 5%" X 4 W' tubing from the cut at -7,500'md and above. 6. M/U 8 W' mills assembly on 4" drill pipe. RIH and drift the 10 3,4" X 9 5/8" casing to the tubing stub. POOH. Alternatively, may elect to run in with a Gauge ringlJunk basket on E-line. 7. R/U E-line. M/U a HES 9 5/8" EZSV bridge plug. RIH and set bridge plug at -7,325'md. Set the bridge plug such that a casing collar will not be cut while milling the winqow. POOH. 8. Test the 10 3fi¡" X 9 5/8", against the bridge plug, to 3,OOOpsi. /' 9. N/D the BOPE. 10. N/D the tubing spool. 11. Change out the 10 3,4" casing pack-off. Energize and test the pack-off. 12. Nipple up a new tubing spool. / 13. N/U BOPE and test to 3,500psi. 14. Pressure test the 10 3,4" X 9 5/8" casing to 3,500psi. 15. M/U 9 5/8" Baker bottom trip anchor whip stock assembly. Include UBHO sub in assembly. 16. RIH with whip stock. Orient with gyro and set whip stock on EZSV bridge plug. /' 17. Shear off of whip stock and displace well to 10.8ppg LSND milling fluid. 18. Mill a window, plus -20 feet new formation beyond mid-window point. Work window and circulate the well bore clean. 19. Pull above window and perform an FIT to 12.3ppg EMW. POOH. 20. M/U an 8 %" Dir/GR/Res/PWD assembly. Include UBHO sub in assembly. 21. RIH and drill the intermediate section, according to directional proposal, to section TD at the top of the Sag River formation. Circulate well clean, short trip to window, spot liner running pill, POOH. /' N-01 A Sidetrack Page 5 . . 22. Run and cement a 7", 26#, L-80, BTC-M drilling liner. POOH. / 23. M/U a 61/8" Dir/GR/Res assembly. 24. RIH to landing collar. Pressure test the 9 5/8" X 7" casing to 3,500psi for 30 minutes. Record the test. 25. Drill the float equipment and cement to the shoe. Displace the well to 8.5ppg Flo-Pro mud system. ".--' 26. Drill out the shoe plus 20 feet new formation. Pull into the shoe and perform FIT to 1 O.Oppg EMW. 27. Drill the production interval to TD, according to directional proposal.ßirculate the well clean, short trip to shoe, spot liner running pill, POOH. / 28. Run and cement a 41/2",12.6#, L-80, IBT-M production liner. 29. Displace well to clean seawater above the production liner top. POOH UD drill pipe. 30. Pressure test the 9 5/8" X 7" X 4 112" casing to 3,500psi for 30 minutes. Record the test. 31. RIU and run a 4 1/2", 12.6#, 13Cr-80, V AM TOP tubing completion, placing the 4 1/2" TT into the 4 112" liner tie back sleeve. 32. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 33. Set a TWC and test from below to 1,OOOpsi. 34. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull the TWC. / 35. Freeze protect the well to -2,200'. Install BPV and test to 1 ,OOOpsi. Secure the well. 36. Rig down and move off. ,,/' Post-Ri~ Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Retrieve the DCR shear valve from the GLM. Replace with DV. 3. Install well house and instrumentation. Estimated Spud Date: 07/10/2004 N-01 A Sidetrack Page 6 . . Phase 1: Move In I Riq Up I Test BOPE Planned Phase Time 23 hours Planned Phase Cost $57,670 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards y No wells will require shut-in for the rig move onto N-01. However, N-24 is 60.0' to the North, and N-14 is 156.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. y The N-01 well bore will be secured with 2 barriers, (the P&A cement plug and seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. y N-Pad~desígnated as an H25 sÍte. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL LatestH2S re~ding ¡,/ j N-24 N-14A 5ppm 5ppm N-14A N-17 I 5ppm / ;",m ".,..--."-... The maximum level recorded of H2S on the pad w~~~øbm, in 2/2002. y Post Permit to Drill and Summary of Drilling Hazards in~~~ house and camp prior to spud Phase 2: De-complete Well Planned Phase Time 40 hours Planned Phase Cost $125,298 Reference RP .:. "De-completions" RP Issues and Potential Hazards y The N-01 well bore will be secured with 2 barriers, (the P&A cement plug and the seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. y Monitor the well to ensure the fluid column remains static, prior to pulling the completion. y Have all wellhead and completion equipment NORM-tested, following retrieval. y Note that this wellhead is a McEvoy (Rockwell) Speed head type 'SH'. The tubing hanger is a 135/8" X 8 5/8" McEvoy hanger, with 7" IJ4S lifting thread. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. y There is a 5W' Camco Bal-O SSSV with dual control lines. There are 2 metal bands and 25 rubber protectors securing the control lines. N-01 A Sidetrack Page 7 . . Phase 3: Run Whip Stock Planned Phase Time 30 hours Planned Phase Cost $220,812 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards ~ A 9 5/8" whip stock will be run and set in the existing intermediate casing. ~ According to the initial cementing report, there should be cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled. Phase 5: Drill 8%" Intermediate Hole Interval Planned Phase Time 115 hours Planned Phase Cost $463,814 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards ~ This well bore will exit the original well in the upper Kingak shale, and drill to the top of the Sag River formation. Previous N-pad wells drilled the Kingak with 9.7 to 10.0ppg mud weights. For this well, the HRZ and Kingak will require a mud weight of 10.8ppg, according to the Kingak Polar plot. Maintain mud weight at 10.8 from the window to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 8.6ppg pore pressure at the Sag River depth, a fracture gradi ~. t Ò 11.1 ppg at the 9 5/8" casing window, and 10.8ppg mud in the hole, the kick tolerance is' fini . ~ This well pat II cross a small fault in the Kingak at -7,678' sstvd, -7,770' md. The NW-SE fault has a throw of approximately 36' down to the SW. With the relatively small displacement, and planned perpendicular intersection with the fault plane, the crossing of this fault is deemed a low risk hazard. N-01 A Sidetrack Page 8 . . Phase 6: Run and Cement 7" Intermediate Liner Planned Phase Time 60 hours Planned Phase Cost $411 ,295 Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 50 hours Planned Phase Cost $358,375 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ Two of the near surrounding wells experienced losses during drilling operations. Well N-25 lost 265bbls at -9,355' sstvd while cementing casing. Well N-14 lost 330bbls while drilling at -9,355' sstvd. This depth is below the BSAD. These losses were associated with penetration of fault tip areas. The trajectory of the N-01 A will not penetrate this depth, and will maintain at least 150' standoff from all known fault tip areas. ~ The parent well, N-01, experienced two relevant lost circulation events. At 8,989' sstvd, -70bbls were lost in Zone 2. At 9,270' sstvd, 125bbls were lost below BSAD while cementing casing. Both of these loss events were associated with a large fault system, which N-01 A will not penetrate. N-01 A Sidetrack Page 9 . . Phase 9: Run 4%" Production Liner Planned Phase Time 30 hours Planned Phase Cost $175,160 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a 4 1-'2", 12.6#, L-BO solid liner throughout the production interval. ~ Differential sticking is possible. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. ~ Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner. Phase 12: Run 4 %" 13Cr-80 Completion Planned Phase Time 24 hours Planned Phase Cost $401,440 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. ~ The completion, as designed, will be to run a 41-'2",12.6#, 13Cr-80, VAM TOP production tubing string, stinging into the 4 1-'2" liner tieback sleeve. Phase 13: ND/NU/Release RiQ Planned Phase Time 12 hours Planned Phase Cost $38,589 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards ~ No wells will require shut-in for the rig move off of N-01. However, N-24 is 60.0' to the North, and N-14 is 156.0' to the South. These are the closest neighboring wells. Spotters should be employed at all times. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig away from the well and about the pad. N-01 A Sidetrack Page 10 e POST THIS NOTICE IN THE DOGHOU' N-01A RST Rig site Summary of Drilling Hazards ./ N-Pad r.;]n H2S designated pad, Standard Operating Procedures for H2S prec;¿fio~s should be followed at all times. The highest concentration currently on record is 100 ppm, February 2002. ./ NORM test all retrieved well head and completion equipment. ./ The closest neighboring wells, at surface, are N-24 and N-14. Well N-24 is approximately 60' to the North; N-14 is approximately 156' to the South. No shut- in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ./ This well path will cross a small fault in the Kingak at -7,678' sstvd, -7,770' md. The NW-SE fault has a throw of approximately 36' down to the SW. With the relatively small displacement, and planned perpendicular intersection with the fault plane, the crossing of this fault is deemed a low risk hazard ./ Be prepared to maintain a full column of seawater in the annulus. Remain aware of any well pressure. ./ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE N-Pad PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. N-01A RST , 133# K-55 I 94# ID::: 19,124" CSG, 555#, 11)::: 9.953" TBG 13-318" CSG, 68#, 10'" 12.415" EZ Drill BP 9518", 47#, N-80, ¡D 8.681" DATE 11II I I + & 2088' -j "1 2426' 2509' , ( 2509' 4200' '1 8985' 9309' £31 n '::::::: :ü: '- DATE REV COMMENTS ORIGINAL COM PlErlON 11/05101 10/16/02 12111/02 08/16103 RNITP CORRECTIONS MHlKAK GLV C/O A TDlKK CORRECTIONS CMOffLP MAX ANGLE CORRECTION REV BY 6500' 1900' 2101' 2426' 2509' X4-1Ì2" xo CSG. MAX. TREE: '" GAS LIFT MANDRELS MD ND LATCH DATE 5 3349 3288 3 OTIS [)MY RA 0 10/18/02 4 5786 5717 1 OTIS DMY RA 3 7200 2 OTIS DMY RA 0 10/16/02 2 8137 8088 OTIS OMY RA 1 8286 OTIS "DMY RA 0 .. STA #1 '" EXTENOED PACKING 5/8" OV PKR 8354' OTIS XA SLIDING SL V, II) '" 3.813;' I 8413' SEAL ABSY I X 4-1/2" TfW HBSP PKR, II) '" OTIS X NIP, II) '" 3,813" I 8521' 10 '" 3,95S" I OTIS &, CEJIÆNT CAP 4" 8985' 1" t - BOTTOM NOSE FULL -BORE SPINNER, FISH - 7" OF 00 UR w /3 BLADES, EACH BEING 1-118" x . PARRY INSIDE: OF EZ DRILL SP, COMMENTS [)MY SECS, 1/2" PRtID!-!OESAY UNIT WELL: N-01 PERMIT No: API No: SP SAÆTY NOTES: MAX. , 133# K-55 I 94# 10= "; ~ 1900' OV TREE = ')(' 1.0.= 2008' 10-3/4" CSG, 555#, 10 9.953" -. '1 r 2426' OV A<R I 10-3/4")( 9-5/8" XO 2426' 13-3/8" CSG, 68#, D:::1:2A15" 4200' MO ND DE\! TYPE VALVE LATCH 19 5/8" DV Packer f 5 4 3 :2 1 II!! III 9 5/8" Whip Stock on brídge plug. _ 1"9 Baker HMC liner hanger, ZXP liner top packer w íth Tie Back 1/2" 8141' 4 8166' I I '- 5" X 7" I 5/8",47#, N-BO. ID 9"'......' ::: 8.681" <JV::; OATE 01124174 08/10/frl 11/05/01 10/16/02 12/17102 08/16/03 REV BY COI\I!I\AENTS ORIGINAl. RWO RN!TP CORRECTIONS l\itH/KAK GLV C/O A TD/KK CORRECTIONS CIIAOffiP MAX ANGLE CORRECTION WElL: N-01A PERMIT No: No: TiiN, R13E, Completion BP EKplol'11tiol'l (Ai11ska) COMPANY DETAUS Pjl!.(UK~j: N·{¡JA wp()3 \/4 SURVEY PROGRAM HP Amocn I"rw:North Jkplh Fm Dcp¡jj To Surve-yil'l;;u TWO.no CASING DETAILS 7200--' No. TVD MD Name 8638.69 7" 8926.66 4 ]/2" 7.000 4.500 Size Start Djr 12i100' : 7300' MD, 7293. !2'TVD Stut Dir 4,/100' : 7320' MO, 73J3,09'TVD :5 2: c c ::::;, -" 15. cs 8 E ~ " e f-. FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 9 10 II See MD 1 2 3 4 5 6 7 8 9 End Dir : 8427.55' MD. 8287.6' TVD 8983.46' MD. 8662.ITTVD 8782.09' TVD N:!rœ N-O! [9X4.0Ü Ine pja.n: N-Ü!A wp03 (N-O!/PJan N-01AJ !",),¡! CremcJ By: Ken Allen Dale ¡\in'll) Dale Dat(' N('rt!¡j¡¡g t."'~Üng SIN III N¡¡¡u<! ["VI) NOlihiug 87k3.6'ì ]074.58 31i{,4Ü 5968503.00 8.1:51.69 HHO.12 :W9.26 596iW40.(HJ SECTJON DETAILS AZI TVD +N/-S +E/-W DLeg TFace VSec Target 0.00 12.00 4.00 0.00 0.00 0_00 0.00 8.99 0.10 0.00 0.00 0.00 0.00 0.00 0.00 N-OIA Tl Bl'AJtlO<':O RJlFERENCl~ fNf(mJ·¡fAI'JON fru"N,wth COMPANY DFrAILS E "" '" ß 1500 No. TVD 8638.69 8926.66 CASING DETAILS MD Name 7" 4 1/2" FORI,IATlON TOP DETAILS No, TVDPath MDPath Formation I 2 3 4 5 6 7 8 9 10 II 7393.93 . 9595.46' MD, 8926.66' TVD § ~ .E ;; o en 300 W est( - )/East(-è) [300filinJ 8662.I7'TVD ¡ ¡ I I J ¡ D..:pth Fm Dcplh Tn SlIl'v<.:yrPlau HOOJ)U 'J50~,46 PJat)n"d: N-U!A \.vp03 V4 SURVEY PROGRAM Size 7.000 4.500 TVD , I ' 900 N¡lJJk' N·{J! I'JX4.0(J !\i44.78 See MD ¡ne I 2 3 4 5 6 7 8 9 PJan: N-OIA wpm (N-O!/!>l¡m N-(J1A) rool Cr<;:aki.Í By: K.;u AIle!! ¡)aìe: un/20M MWD C\:¡<;;ckeJ: [hilI.:' Ikviewçd: )ate WELl DETAH S Northing j,¡¡¡¡tudl;' ¡ <>Uì(J!wk slol 63441:1.')2 7(ì"19'UX.l83N 01 L\RUET D¡:'[,;\!J.S Nam(:: ¡VD 'N'·S NortlJing ¡':¡'~!ÌH<é Slwp.:: 318.40 :>9Y26 SECTfON DETAILS AzÎ TVD +Ni-S +Ei-W DLeg TFace 0.00 0.00 12.00 37.33 4.00 37.33 0.00 0.00 0.00 0.00 8.99 0.10 0.00 0.00 0.00 0.00 0.00 0.00 N-OIATJ VSec Target o ¡orJJ ~, I I I ifJOO ifJ ørfJ° J1 II ¡ " ---~- I ....... 'I ·y-sun DRILLING SeRVICES . Sperry-Sun - Draft Co# KW A Planning .\H.U.UIIlttTOt""cœ.lPA!\Y ObP Company: Field: Site: Well: Wellpath: r Plan: Principal: BP Amoco Prudhoe Bay PB N Pad N-01 Plan N-01A N-01A wp03 Date: 1/23/2004 Time: 11 :34:48 Page: Co-ordinate(NE) Reference: Well: N-01, True North Vertical (TVD) Reference: 71.6971.7 Section (VS) Reference: Well (O.OON,O.OOE, 17 .92Azi) Snrvey Calculation Method: Minimum Curvature Db: Yes Date Composed: Version: Tied-to: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB N Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5965420.89 ft 633404.63 ft Latitude: 70 18 Longitude: 148 55 North Reference: Grid Convergence: Oracle 1/13/2004 4 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 48.671 N 7.726 W True 1.02 deg Well: N-01 Slot Name: 01 N-01 Well Position: +N/-S 1984.00 ft Northing: 5967422.98 ft Latitude: 70 19 8.183 N +E/-W 1044.78 ft Easting : 634413.92 ft Longitude: 148 54 37.239 W Position Uncertainty: 0.00 ft Wellpath: Plan N-01A Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 71.69 12/22/2003 57570 nT Depth From (TVD) ft 33.19 +N/-S ft 0.00 Height 71.69 ft Casing Points N-01 7300.00 ft Mean Sea Level 25.32 deg 80.84 deg Direction deg 17.92 MD TVD Diameter Hole Size Name ft ft in in 8948.62 8638.69 7.000 8.500 7" 9595.45 8926.66 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 7393.93 7386.69 TJG 0.00 0.00 7747.65 7729.69 TJF 0.00 0.00 7955.83 7918.69 TJE 0.00 0.00 8245.43 8156.69 TJD 0.00 0.00 8568.68 8382.69 TJC 0.00 0.00 8737.87 8496.69 TJB 0.00 0.00 8948.62 8638.69 TSGR 0.00 0.00 9005.44 8676.69 TSHU 0.00 0.00 9121.99 8743.69 TSADITZ4B 0.00 0.00 9224.72 8787.69 PGOC 0.00 0.00 9483.50 8884.69 TCGUTZ3 0.00 0.00 0.00 POWC 0.00 0.00 0.00 BCGUTZ2C 0.00 0.00 Targets Map Map <--- Latitude --"'> <- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft N-01A T1 8783.69 1074.58 318.40 5968503.00 634713.00 70 19 18.751 N 148 54 27.947 W -Plan hit target N-01A Poly 8851.69 1010.12 399.26 5968440.00 634795.00 70 1918.117 N 148 54 25.587 W ........ of 'V-sun DAII-I-ING SlifAVIC&S Company: Field: Site: Well: Wellpatb: Targets " H,U,UIItJtn'(J ( COMP,t/\y BP Amoco Prudhoe Bay PB N Pad N-01 Plan N-01A . Sperry-Sun - Draft Co~ KW A Planning Name Description Dip. Dir. -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Plan out by 220.57 at Plan Section Information MD ft 7300.00 7320.00 8427.55 8963.46 8983.46 9209.77 9214.05 9395.46 9595.46 Survey MD ft 7300.00 7320.00 7393.93 7400.00 7500.00 7600.00 7700.00 7747.65 7800.00 7900.00 7955.83 8000.00 8100.00 8200.00 8245.43 8300.00 8400.00 8427.55 8500.00 8568.68 8600.00 8700.00 8737.87 8800.00 8900.00 8948.62 8963.46 8983.46 9000.00 9005.44 9050.00 9100.00 9121.99 IncI deg 1.96 4.13 47.64 47.64 47.64 67.99 67.99 67.99 67.99 IncI deg 1.96 4.13 6.73 6.95 10.78 14.70 18.65 20.54 22.62 26.60 28.82 30.58 34.57 38.56 40.37 42.55 46.54 47.64 47.64 47.64 47.64 47.64 47.64 47.64 47.64 47.64 47.64 47.64 49.13 49.62 53.62 58.12 60.09 Azim deg 326.77 347.41 22.38 22.38 22.38 22.42 22.42 22.42 22.42 Azim deg 326.77 347.41 2.90 3.64 11.38 15.06 17.22 17.96 18.64 19.65 20.10 20.42 21.02 21.52 21.71 21.93 22.29 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.38 22.39 22.40 22.40 TVD ft 7293.12 7313.09 8287.60 8648.69 8662.17 8782.09 8783.69 8851.69 8926.66 TVD ft 7293.12 7313.09 7386.69 7392.72 7491.51 7589.03 7684.80 7729.69 7778.37 7869.27 7918.69 7957.06 8041.31 8121.62 8156.69 8197.58 8268.84 8287.60 8336.41 8382.69 8403.79 8471.17 8496.69 8538.55 8605.93 8638.69 8648.69 8662.17 8673.15 8676.69 8704.35 8732.40 8743.69 TVD ft 8851.69 8851.69 8851.69 8851.69 8851.69 +N/-S ft 74.49 75.48 514.92 881.10 894.77 1070.91 1074.58 1230.05 1401.46 Sys TVD ft 7221.43 7241.40 7315.00 7321.03 7419.82 7517.34 7613.11 7658.00 7706.68 7797.58 7847.00 7885.37 7969.62 8049.93 8085.00 8125.89 8197.15 8215.91 8264.72 8311.00 8332.10 8399.48 8425.00 8466.86 8534.24 8567.00 8577.00 8590.48 8601.46 8605.00 8632.66 8660.71 8672.00 ObP Date: 1/23/2004 Time: 11 :34:48 Page: 2 Co-ordinate(NE) Reference: Well: N-01, True North Vertical (TVD) Reference: 71.6971.7 Section (VS) Reference: Well (0.00N,0.00E,17.92Azi) Survey Calculation Metbod: Minimum Curvature Db: Oracle +N/-S ft 1010.12 1482.75 1531.06 1068.34 1230.05 +E/-W ft 399.26 537.76 353.58 220.26 382.53 +E/-W ft -66.64 -66.98 87.90 238.66 244.28 316.88 318.40 382.53 453.24 MapN ft 5967496.25 5967497.24 5967504.15 5967504.88 5967520.13 5967541.64 5967569.31 5967584.63 5967603.01 5967642.56 5967667.12 5967687.79 5967738.46 5967794.32 5967821.35 5967855.12 5967920.55 5967939.35 5967989.20 5968036.47 5968058.02 5968126.83 5968152.90 5968195.65 5968264.47 5968297.92 5968308.14 5968321.90 5968333.41 5968337.26 5968369.78 5968408.31 5968425.88 Map Map Northing Easting ft ft 5968440.00 634795.00 5968915.00 634925.00 5968960.00 634740.00 5968495.00 634615.00 5968659.58 634774.34 <-- Latitude --> Deg Min Sec 70 19 18.117 N 70 19 22.765 N 70 19 23.241 N 70 19 18.690 N 70 19 20.280 N DLS Build Turn deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 12.00 10.87 103.17 4.00 3.93 3.16 0.00 0.00 0.00 0.00 0.00 0.00 8.99 8.99 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MapE ft 634345.96 634345.60 634345.12 634345.14 634347.10 634351.86 634359.40 634363.96 634369.68 634382.65 634391.04 634398.26 634416.41 634437.03 634447.18 634460.01 634485.24 634492.58 634512.07 634530.54 634538.97 634565.87 634576.06 634592.77 634619.67 634632.75 634636.74 634642.12 634646.62 634648.13 634660.85 634675.92 634682.80 VS ft 50.37 51.20 57.68 58.38 73.54 95.51 124.19 140.16 159.42 201.04 226.98 248.85 302.61 362.07 390.88 426.92 496.86 516.99 570.36 620.95 644.03 717.69 745.60 791.36 865.03 900.85 911.79 926.52 938.85 942.96 977.78 1019.03 1037.84 TFO Target deg 0.00 37.33 37.33 0.00 0.00 0.10 0.00 N-01A T1 0.00 0.00 <--- Longitude ---> Deg Min Sec 148 54 25.587 W 148 5421.544 W 148 5426.920 W 148 54 30.811 W 148 54 26.075 W AHVS ft 0.00 1.06 8.06 8.78 24.19 DLS TFO deg/100ft deg 0.00 0.00 12.00 37.33 4.00 37.33 4.00 21.90 4.00 21.16 46.24 74.92 90.90 110.16 151.79 177.75 199.63 253.46 313.02 341.89 378.02 448.15 468.33 521.86 572.61 595.76 669.65 697.63 743.54 817.43 853.36 864.33 879.11 891.47 895.60 930.52 971.90 990.77 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.99 8.99 8.99 8.99 8.99 Tool MWD MWD TJG MWD MWD 13.51 9.92 7.85 7.15 6.52 5.60 5.20 4.93 4.42 4.02 3.87 3.71 3.45 0.00 0.00 0.00 0.00 0.00 0.00 0.00 MWD MWD TJF MWD MWD TJE MWD MWD MWD TJD MWD MWD MWD MWD TJC MWD MWD TJB MWD MWD 0.00 7" 0.00 MWD 0.00 MWD 0.10 MWD 0.10 TSHU 0.10 MWD 0.10 MWD 0.09 TSADITZ4B =1-'= .. 'Y-SU"1 . Sperry-Sun - Draft Co/Þ ObP DAII..I..ING seAVlces A }l.ù.UBl1JO'O!'" ~A \Y KW A Planning Company: BP Amoco Date: 1/23/2004 Time: 11 :34:48 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: N-01, True North Site: PB N Pad Vertical (TVD) Reference: 71.6971.7 Well: N-01 Section (VS) Reference: Well (0.00N.o.oOE.17.92Az:i) Wellpath: Plan N-01A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS AHVS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1 OOft deg 9150.00 62.61 22.41 8757.12 8685.43 5968448.77 634691.76 1062.34 1015.35 8.99 0.09 MWD 9200.00 67.11 22.42 8778.35 8706.66 5968490.90 634708.26 1107.46 1060.60 8.99 0.09 MWD 9209.77 67.99 22.42 8782.09 8710.40 5968499.31 634711.55 1116.46 1069.63 8.99 0.08 MWD 9214.05 67.99 22.42 8783.69 8712.00 5968503.00 634713.00 1120.42 1073.60 0.00 0.00 N-01A T1 9224.72 67.99 22.42 8787.69 8716.00 5968512.21 634716.61 1130.28 1083.49 0.00 0.00 PGOC 9300.00 67.99 22.42 8815.91 8744.22 5968577.19 634742.06 1199.85 1153.28 0.00 0.00 MWD 9395.46 67.99 22.42 8851.69 8780.00 5968659.58 634774.34 1288.08 1241.78 0.00 0.00 N-01A Poly 9400.00 67.99 22.42 8853.39 8781.70 5968663.50 634775.87 1292.28 1245.99 0.00 0.00 MWD 9483.50 67.99 22.42 8884.69 8813.00 5968735.57 634804.10 1369.45 1323.40 0.00 0.00 TCGLITZ3 9500.00 67.99 22.42 8890.88 8819.19 5968749.82 634809.68 1384.70 1338.70 0.00 0.00 MWD 9595.46 67.99 22.42 8926.66 8854.97 5968832.21 634841.96 1472.93 1427.20 0.00 0.00 41/2" N-01A Kick Tolerance .xls . Page 1 of 2 . 6/8/2004 10:13 AM Obp KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Version 6.0, December 2000 Well: I N-01A Wp04 Units (UK/US): I us Kick Zone Parameters: Input Error Messages: 1 Openhole Size? (inch) 8.5 2 Measured Depth? (ft) 8949 3 Vertical Depth? (ft) 8639 4 Horizontal Length (>87 deg) ? (ft) 0 Non-Horizontal 5 Tangent Angle Above Horizontal? (deg) 48 6 Min Pore Pressure Gradient? (ppg) 7.000 7 Max Pore Pressure Gradient? (ppg) 8.600 8 Kick Zone Temperature? (deg.F) 195 Weak Point Parameters: 9 Measured Depth? (ft) 7300 10 Vertical Depth? (ft) 7293 11 Section Angle «87 deg) ? (deg) 5 12 Min Fracture Gradient 1 EMW ? (ppg) 11.100 13 Max Fracture Gradient 1 EMW (ppg) 12.500 14 Weak Point Temperature? (deg.F) 140 Other Parameters: 15 Drill Collar OD ? (inch) 6.75 16 Drill Collar Length? (ft) 95 17 Drillpipe OD ? (inch) 4 18 Surface Pressure Safety Factor? (psi) 100 19 Mud Weight in Hole? (ppg) 10.800 Annular Capacity Around BHA: (bbl/ft) 0.02592 Annular Capacity Around DP: (bbl/ft) 0.05464 At Min Fracture Gradient: Comments: Circulating MAASP (psi) 14 Gas Gradient at Weak Point (psilft) 0.0778 For Min Pore Pressure: Max Allowable Gas Height: (ft) 3557 Extends above weak point Kick Tolerance: (bbl) Infinite / For Max Pore Pressure: Max Allowable Gas Height: (ft) 2071 Extends above weak point Kick Tolerance: (bbl) Infinite At Max Fracture Gradient: Circulating MAASP (psi) 543 Gas Gradient at Weak Point (psilft) 0.0845 For Min Pore Pressure: Max Allowable Gas Height: (ft) 4719 Extends above weak point Kick Tolerance: (bbl) Infinite For Max Pore Pressure: Max Allowable Gas Height: (ft) 3212 Extends above weak point Kick Tolerance: (bbl) Infinite · N-01A Kick Tolerance .xls 300 250 200 III U t:: ~ 150 III Õ ¡... ~ 100 u ~ 50 0 0.00 1.00 2 2 6/8/2004 10:13 AM Fracture 53rad -o-Max Fracture Grad I 2.00 3.00 4.00 Pore Pressure Gradient 5.00 6.00 9.00 7.00 8.00 Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Pressure? Near Surface Casing ID? Near Surface Annular Temperature? Gas Gradient at Max Pres: Near Surface Annular Max Allowable Gas Height at Surface: Max Allowable Vol. on Shut-in: Max Allowable Max Allowable 2500 III 2000 E :::I Õ > II! III G III :ï5 ; .2 « )( III :¡: 1500· 1000· 500- o 0.00 1.00 Height at Surface: Vol. on Shut-in: (psi) (inch) (deg.F) (psi/ft) (bbllft) (ft) (bbl) (ft) (bb!) 14734 Extends to hole TD infinite 13133 infinite hole 2.00 3.00 4.00 Pore Pressure Gradient 5.00 6.00 7.00 8.00 10.00 10.00 TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 117 DATE lio-;¿;2.-0Lf PAYTOTHE \_~ 2~! fV...6'Cc.... $ (OO. 00 ORDER OF ~ ) \ ð'" nu (}.O ~t . <rŸJ;3{lJL) _·_-·~·""··~--"f)OtLAn& First National Bank Alaska Anchorage, AK 99501 .../A' L 11 ~l 11 £þ_ MEMO ¡V"OlA ~ WVLLt C?\. ~~ "Mastercard Check" . I: ~ 2 5 2000bOI:~~ ~a.."lb 2 2 711' ¡. SSb"· 0 ¡.. 7 . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Æ?( ¡1) -0 III PTD# 2ocy-//? X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dumber last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE" Tbe permit is for a new wellbore segment of existing well Permit No, API No. Production. should continue to be reponed as a function 'of tbe original API number stated above. BOLE ]n accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be dearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. _ (Company Name) assumes tbe Jiability of any protest to tbe spacinge:xception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample intervals tbrougb target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT N-D1A Program .DEV Well bore seg 0 PTD#: 2041130 Company BP EXPLORATION (ALASKA) I~ Initial ClassfType _ DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 0 Administration 1 P_ermit fee attache~_ Yes_ _ 2 _Leas~number _appropriate_ _ _ Yes_ 3 _Unique weltn_a[ll~_and ol!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ . - _... - _. Y~s_ __ - - - - - ~ - - - - - - - - - - - - - - - - -- - - -- 4 WellJQcated in.ad.efine~pool . Yes_ 5 WelUQcated proper .distance. from driJling unitb_ound.ary. . Yes. - - - - - 6 WelUQcated pr.operdistance_ from Qther wells_ _ _ . _ _ _ . Y~s _ - - - - 7 .S_uffjcient.acrea9.eavailable ¡ndJiUiog l¡njl _ Y~s 8 Jfdevi;,¡ted, js weJlbQre pl;,¡tincJuded . _ Y~s 9 _O,perator only affected party _ . _ Y~s 10 _O,perator has_appropriate.b.ond inJorce _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . - _. _. _. Y~s_ __ - - - - - - - - - - - - - - - - - - -- - - -- - -- 11 P~rmit can be iSSl!ed wjthQut conserva_tion order. . Yes Appr Date 12 P~rmit. can be iSSl!ed wjthQut ad.ministratÍlle.approvaJ _ . _ - Y~s. RPC 6/23/2004 13 Can permit be approved before 15-day wait Yes . 14 WaJUQcated within ;,¡rea and.strataauthorized by.lnjeçtioo Order # (PuUOtl ¡n_com[T1~nts)(For. NA . 15 _AJI wells. within Jl4JlJite_are.a_of revieW jd~nlified (For $.ervjc~ _well onlyL _ _ _ _ _ _ _ _ _ . _ _ _ _ _NA _ _ _ - - - - - - - - - - - - - - - - - - - - - - -- - -- 16 PJe-produ.cecl injector; .duration.of pre-production less. than 3 months (For .sel'li~ well QnJy) _ _NA _ 17 ACMPJ=indjng of Con..si,Slency.has beenJs_sued_ forthis proiect _.NA - - - - - - - - - ~ Engineering 18 .C.onduJ:lor string_PJQvided . NA - - - - 19 _S.urface .casing. PJQtects all_known USDWs . _NA 20 _CMT vol adeql!ateto circJJlate.o_n .conductor 8< SUJfCJ>g _ . . . . _ .NA. 21 CMT vJ)1 adeql!ate_ to tie-inJQngstrinQ to_surf C$.Q. _ NA. - - - - 22 .CMT_ will çoveraJl know_npro.ductive hQri¡¡:ons . _ Y.es 23 .Casing designs ad.equaJe. for C,_T~ B.&permafr.ost . _ - - - - Y~s_ 24 Adequatetan_kage_oJ reserye pit. _ . - Y~s. Nabors.7_ES, . _ 25 JfaJe-drilt basa. 10:403 for abandonme_nt be~o aPPJoved . _ Y~s 6/1/200A, . - - - - - - 26 Adequate we[lbore $.ep;,¡ratjo_n -Proposed _ . _ _ _ _ _ _ _ _ . . . . _ _ . _ _ _ . _ _ . - - - - - Y~s. __ - - - - - - - - - - - - - - - - - - -- 27 Jfdiverter JeqJJiJed, dQes ilmeet reguJations. . _ .NA_ Sidetrack. _ - - - - - - - - - - - Appr Date 28 DJilIioQ fluid. program schematìc_& eq,uip Jistadequale_ - - - - .Y~s _ . _ Max MW.tO,8ppg. _ _ WGA 6/23/2004 29 .BOPEs,d.o they meet reguJation _ . · Y~s - - -- - - - - . 30 _BOPEpre.ss raJing appropriate; test lo.(pu.t psig incommentsL Y~s_ Te.st to 3500. psi. .MSF' 2320 Psi.. 31 _Choke. manifold cQmpJies w/API. RF'-53 (May 84) . _ . - - -- Y~s 32 WQrk will occur withoutoper¡¡tion .sbl!tdown. . . . _ . _ . . Y~s. 33 J$. presence. Qf H2S gas_ prob.able . - - - - - - - - .Y~s. 1:12S pad 34 Meçha.nic¡¡LcpodJlion J){ wells within ,ð.OR yertfied (For. s_ervice weU on.ly). . · NA - - - - - - - - - Geology 35 P~rmit can be iSSl!ed wlo hydrogen. sulfide measJJres. _ · .No 36 .D_ata.PJeseoted on pote.ntial oveJpres.sure _zones. _ NA. Appr Date 37 Setsmic_analysjs Qf shaJlow Qaszones_ . . NA - - - -- RPC 6/23/2004 38 S~;,¡bed .condjtion survey _(if off-shore) _ . . NA - - - - -- 39 . CQnta.ct namelphoneforwee~ly prpgre$.s.reports [explor¡¡tpryonly] .NA. Geologic Date: Engineering Date Date Commissioner Commissioner: pfCS 6(¿4-/ f--- ~f1t e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . d-ocf-tr;, :JJ~ I ¿9'<5ð Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jan 31 11:05:24 2005 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/31 Origin.. ................ .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... ..... ....LISTPE Date........ ...... ...... .05/01/31 Origin................. ..STS Tape Name... ...... ...... . UNKNOWN Continuation Number. . . . . .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Field MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA N-01A 500292007901 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 31-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003190325 N. WHITE A. MADSEN MWDRUN 2 MW0003190325 B. HENNINGSE D. FERGUSON MWD RUN 3 MW0003190325 B. HENNINGSE D. FERGUSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 MW0003190325 P. SMITH D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 11N l3E 1519 556 73.88 45.63 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 7316.0 8970.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE . . NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE N~Ol WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 7316'MD/7309'TVD. 4. MWD RUNS 1 - 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). MWD RUNS 1 - 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD DATA OVER THE INTERVAL 7520'MD - 7613'MD WERE ACQUIRED WHILE RIH FOR MWD RUN 2. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN ON 27 AUGUST 2004. THESE LOG DATA WERE PROVIDED BY W.TIFENTAL (SIS/BP) ON 20 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 - 4 REPRESENT WELL N-01A WITH API#: 50-029-20079-01. THIS WELL REACHED A TOTAL DEPTH(TD)OF 9750'MD/8980'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/31 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7280.5 7312.5 7312.5 7312.5 7312.5 7312.5 7354.5 STOP DEPTH 9713.0 9720.0 9720.0 9720.0 9720.0 9720.0 9760.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR . . 7280.5 7268.5 7293.5 7281.5 7318.5 7307.0 7338.5 7328.5 7371.0 7362.5 7386.5 7379.5 7527.0 7520.0 7533.0 7527.5 7563.5 7556.5 7570.0 7563.0 7613.5 7603.5 7622.5 7615.5 7633.0 7627.5 7645.0 7636.5 7663.5 7654.5 7689.0 7674.0 7718.0 7704.0 7775.0 7760.5 7784.5 7768.5 7823.0 7807.5 7884.5 7872.0 7910.5 7899.0 7926.0 7914.0 7938.5 7928.5 7951.0 7942.5 7956.0 7948.0 7962.5 7950.5 7965.5 7953.0 7968.0 7957.5 8033.5 8025.5 8101. 0 8095.0 8113.0 8107.5 8121.0 8116.0 8130.0 8124.0 8168.5 8159.5 8180.0 8173.5 8220.0 8211.5 8227.0 8218.5 8232.0 8226.0 8251.5 8247.5 8275.0 8266.5 8297.5 8289.0 8310.0 8302.5 8320.5 8312.5 8332.0 8326.0 8339.5 8332.5 8357.0 8348.0 8367.5 8359.0 8379.5 8373.0 8398.0 8388.5 8411.5 8403.5 8423.0 8415.0 8438.5 8429.5 8448.0 8440.0 8465.0 8455.5 8467.5 8459.0 8481.5 8473.0 8524.5 8516.0 8528.0 8522.0 8546.5 8537.0 8581. 0 8565.5 8644.5 8634.0 8676.0 8664.0 8710.5 8703.5 8727.5 8719.0 8750.5 8743.0 8792.0 8782.0 8802.5 8793.0 8823.5 8813.5 8832.5 8823.0 8837.0 8826.0 8864.5 8854.5 8893.0 8882.5 8900.0 8889.5 8910.0 8899.5 8955.0 8948.5 . . 8962.0 8956.0 8964.5 8958.5 8969.5 8963.5 8973.5 8966.5 9013 .5 9007.0 9018.5 9012.0 9025.5 9019.5 9028.0 9022.0 9032.5 9025.0 9035.5 9028.0 9045.0 9038.0 9047.5 9040.5 9058.0 9051.0 9071.0 9063.5 9078.0 9072.0 9082.5 9076.5 9085.5 9080.0 9088.5 9082.0 9091. 5 9085.0 9094.5 9087.5 9096.0 9090.0 9100.5 9093.5 9109.0 9102.0 9113 . 0 9108.5 9120.5 9114.0 9126.5 9120.0 9128.5 9122.0 9133.5 9126.5 9136.0 9128.0 9159.0 9152.5 9168.5 9159.5 91 72.0 9163.5 9178.5 9170.5 9189.5 9182.5 9205.5 9196 . 5 9209.5 9199.5 9227.0 9217.0 9231.0 9222.5 9235.0 9226.5 9241.5 9233.5 9250.0 9240.5 9269.5 9260.5 9273.5 9265.0 9285.5 9274.0 9298.5 9290.5 9325.5 9316.0 9334.0 9323.0 9341.0 9330.0 9352.5 9343.5 9355.0 9347.0 9374.5 9365.5 9378.0 9369.5 9396.0 9386.5 9400.5 9390.0 9412.0 9401. 5 9422.0 9410.5 9428.0 9416.5 9439.0 9427.5 9441. 5 9429.5 9444.0 9433.0 9448.0 9437.5 9451.5 9441.0 9466.0 9458.5 9475.0 9468.0 9481.0 9473.0 9496.5 9490.0 9507.0 9499.0 9523.5 9514.0 9537.5 9528.5 9557.5 9547.0 9580.0 9571.5 9590.0 9580.5 9601.0 9590.5 9760.5 9750.0 $ # . . MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 7268.5 7520.0 7628.0 8970.0 MERGE BASE 7520.0 7628.0 8970.0 9750.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ............... . Down Optical log depth units. ..........Feet Data Reference Point........... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..... . ." . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7280.5 9760.5 8520.5 4961 7280.5 9760.5 ROP MWD FT/H 0.37 383.61 82.5459 4813 7354.5 9760.5 GR MWD API 15.57 557.97 91.9095 4866 7280.5 9713 RPX MWD OHMM 0.29 1585.61 8.54575 4816 7312.5 9720 RPS MWD OHMM 0.33 1624.92 9.41924 4816 7312.5 9720 RPM MWD OHMM 0.23 2000 18.7686 4816 7312.5 9720 RPD MWD OHMM 0.12 2000 28.2004 4816 7312.5 9720 FET MWD HOUR 0.25 73 .14 4.08412 4816 7312.5 9720 First Reading For Entire File..... .....7280.5 Last Reading For Entire File......... ..9760.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/31 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...... .05/01/31 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 . RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ . header data for each bit run in separate files. 1 .5000 START DEPTH 7268.5 7301.0 7301.0 7301.0 7301.0 7301.0 7345.0 STOP DEPTH 7484.5 7477.0 7477.0 7477.0 7477.0 7477.0 7520.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 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.....O Logging Direction.............. ...Down Optical log depth units.......... .Feet Data Reference Point....... ...... . Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Unit s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 28-JUL-04 Insite 66.37 Memory 7520.0 7344.0 7520.0 .0 .0 TOOL NUMBER 120558 134758 8.500 7316.0 LSND 10.80 50.0 .0 800 5.4 1. 250 .651 1.000 1.900 65.0 131. 0 65.0 65.0 . . Name Service Order Units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOI0 FT/H 4 1 68 4 2 GR MWDOI0 API 4 1 68 8 3 RPX MWDOI0 OHMM 4 1 68 12 4 RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 OHMM 4 1 68 20 6 RPD MWDOI0 OHMM 4 1 68 24 7 FET MWDOI0 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7268.5 7520 7394.25 504 7268.5 7520 ROP MWDOI0 FT/H 0.37 270.68 59.7929 351 7345 7520 GR MWDOI0 API 37.43 112.63 74.1326 433 7268.5 7484.5 RPX MWDOI0 OHMM 0.61 1481. 59 8.91946 353 7301 7477 RPS MWDOI0 OHMM 0.96 1624.92 8.82343 353 7301 7477 RPM MWDOI0 OHMM 0.93 2000 101.941 353 7301 7477 RPD MWDOI0 OHMM 0.12 2000 87.8608 353 7301 7477 FET MWDOI0 HOUR 0.3 8.42 5.28122 353 7301 7477 First Reading For Entire File.. ....... .7268.5 Last Reading For Entire File... ........7520 File Trailer Service name..... ....... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/01/31 Maximum Physical Record. .65535 File Type... .............LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name. ..... .... ...STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......05/01/31 Maximum Physical Record. .65535 File Type... .............LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPX RPM GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 7477.5 7477.5 7477.5 7477.5 7477.5 7485.0 7520.5 STOP DEPTH 7585.0 7585.0 7585.0 7585.0 7585.0 7592.0 7628.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 29-JUL-04 Insite 66.37 Memory 7628.0 . TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 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 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 7520.0 7628.0 .0 .0 TOOL NUMBER 120558 134758 8.500 7316.0 LSND 10.80 50.0 10.2 800 5.4 1. 250 .607 1. 000 1.900 65.0 141.0 65.0 65.0 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 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7477.5 7628 7552.75 302 7477.5 7628 ROP MWD020 FT/H 5.32 215.16 83.5831 216 7520.5 7628 GR MWD020 API 52.52 123.43 93.3667 215 7485 7592 RPX MWD020 OHMM 0.83 1. 86 1.02579 216 7477.5 7585 RPS MWD020 OHMM 0.8 1. 99 1.04255 216 7477.5 7585 RPM MWD020 OHMM 0.75 2 1.03338 216 7477.5 7585 RPD MWD020 OHMM 0.78 1. 72 1.01787 216 7477.5 7585 FET MWD020 HOUR 15.12 41.84 27.4429 216 7477.5 7585 . . First Reading For Entire File......... .7477.5 Last Reading For Entire File. ......... .7628 File Trailer Service name.. ..... ......STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .....05/01/31 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.......05/01/31 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 7585.5 7585.5 7585.5 7585.5 7585.5 7592.5 7628.5 STOP DEPTH 8927.0 8927.0 8927.0 8927.0 8927.0 8934.5 8970.0 # 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: 31-JUL-04 Insite 66.37 Memory 8970.0 7628.0 8970.0 11.1 51. 2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 120558 134758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 7316.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): LSND 10.80 53.0 9.3 800 . . 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: 5.0 1. 250 .501 1. 000 1.900 65.0 172.4 65.0 65.0 # 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.....O Logging Direction........ ........ . Down Optical log depth units...........Feet Data Reference Point............. . Undefined Frame Spacing............. ....... .60 .1IN Max frames per record............ . Undefined Absent value...... . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7585.5 8970 8277.75 2770 7585.5 8970 ROP MWD030 FT/H 1. 39 197.91 77.3691 2684 7628.5 8970 GR MWD030 API 65.58 171 . 92 108.757 2685 7592.5 8934.5 RPX MWD030 OHMM 0.76 8.75 1.98577 2684 7585.5 8927 RPS MWD030 OHMM 0.73 8.56 1.96812 2684 7585.5 8927 RPM MWD030 OHMM 0.71 8.85 2.02715 2684 7585.5 8927 RPD MWD030 OHMM 0.73 8.63 2.06032 2684 7585.5 8927 FET MWD030 HOUR 0.37 25.68 1.65153 2684 7585.5 8927 First Reading For Entire File........ ..7585.5 Last Reading For Entire File.......... .8970 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/31 Maximum Physical Record..65535 File Type..... . . . . . . . . . . . LO Next File Name... ...... ..STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .05/01/31 . Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 5 . header data for each bit run in separate files. 4 .5000 START DEPTH 8927.5 8927.5 8927.5 8927.5 8927.5 8935.0 8970.5 STOP DEPTH 9709.5 9709.5 9709.5 9709.5 9709.5 9702.5 9750.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 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 04 -AUG- 04 Insite 66.37 Memory 9750.0 8970.0 9750.0 51.1 67.5 TOOL NUMBER 62456 130910 6.125 8970.0 Flo Pro 8.70 45.0 9.2 3800 6.2 .300 .111 .260 .310 58.0 168.0 58.0 58.0 . . Data Reference Point...... ....... . Undefined Frame Spacing..................... 60 .1IN Max frames per record........ .... . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8927.5 9750 9338.75 1646 8927.5 9750 ROP MWD040 FT/H 2.76 383.61 96.4188 1560 8970.5 9750 GR MWD040 API 15.57 557.97 66.6827 1536 8935 9702.5 RPX MWD040 OHMM 0.29 1585.61 20.5495 1565 8927.5 9709.5 RPS MWD040 OHMM 0.33 1559.09 23.2547 1565 8927.5 9709.5 RPM MWD040 OHMM 0.23 1937.68 30.2172 1565 8927.5 9709.5 RPD MWD040 OHMM 0.29 2000 63.2564 1565 8927.5 9709.5 FET MWD040 HOUR 0.25 73.14 4.91762 1565 8927.5 9709.5 First Reading For Entire File....... ...8927.5 Last Reading For Entire File.... .......9750 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/31 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name. ..... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/01/31 Origin. . . . . . ............ .STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.... .............STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .05/01/31 Origin.................. .STS Reel Name.... ............UNKNOWN Continuation Number..... .01 Next Reel Name. ......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . .
