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194-137
RECEWED STATE OF ALASKA NOV 0 7 2013 . A_ _,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LU BrightWater • Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 194-137-0 3.Address: P.O.Box 196612 StratigraphicE Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-22515-00-00' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028330 • PBU 12-34 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 11800 feet Plugs measured None feet true vertical 9227.45 feet Junk measured See Attachment feet Effective Depth measured 11715 feet Packer measured 8879 feet true vertical 9164.23 feet true vertical 7097.92 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3341 9-5/8"40#L-80 24-3365 24-3226.44 5750 3090 Intermediate None None None None None None Production 11367 7"26#L-80 28-11395 28-8933.1 7240 5410 Liner 2808 4-1/2"12.6#L-80 8992-11800 7181.26-9227.45 8430 7500 Perforation depth Measured depth 11360-11380 feet 11470-11484 feet 11484-11490 feet 11490-11508 feet 11508-11514 feet 11514-11528 feet True Vertical depth 8909.13-8922.77 feet 8985.83-8995.83 feet 8995.83-9000.12 feet 9000.12-9013.03 feet 9013.03-9017.35 feet 9017.35-9027.44 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-8998 28-7185.71 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker Premier Packer 8879 7097.92 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): ,��;k 11360'-11380',11470'-11528' SCANNED 1 3 ',%014 Treatment descriptions including volumes used and final pressure: 4146.5 Gallons EC9260A Surfactant,20,081 Gallons EC9408A Polymer, 1000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 7101 0 1032 Subsequent to operation: 0 0 7144 0 1036 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator,❑ Development❑ Service IS • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Li Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG 19 .GINJ ❑ SUSP ❑ SPLUCO 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 Garry ry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 11/7/2013 BBB{MS NOV 1 9 A 1 171-F z �z 1 13 l l Form 10-404 Revised 10/2012 !/ Submit Original Only � y 12-34 194-137-0 Junk Attachment SW Name MD Date Description 12-34 11525 2/27/1995.3 Arm Springs for 4.5" OK-6 12-34 11687 2/18/1996 GLV lost downhole O O 0 To 0 0 (0 N O r) (0 O O 0 �t co N (6 a) O o w. a) o To oa Cl *� -a Cl E n in � c0 O -0 O - a = m a Q 7 uj w a N � O >i a el-0 ° Q O .0 C O Cr) L 2 O D E ° a) ° a) co 0°-CO oo d E a) Q a) co • N � a) co L N a)eL O D 6 CI- • !�1,- L U �` L ° (�\ [_co (n C U) V o0 V p l�J L (n E L O 3 L O �O O L C r- Q D (n lU - O U)O O _� L O ° Q 0) a_ L p p U C o) I--o O U Q) Ln O u) U L L O a) a) a) co .O Lo N- C a) �O O O * a) N .0 I[) -p a E co `— a) a) (o :E O '+a N •C N co a) a) ca O ?� CO C •L C C co 0) 0 .4 C N N a) (p O7 C 4O T- c CD L p o (LO (D p > > O p N O O Q m Y L C) a) a) a) o .L a) Q Q cl a) m 0) a) la O O C U () C > > N m (a , m Q Q * CO (n �� O ww,, M �� C N ? * ,,�nn a) m ,,3nn a)CO L W * L .p �� * V L C r V Q > N * 3 * a) m L * m ° a) * CO < 0 H * � � E 0 * � Hc -- * co O 0 U> c U> ID * >U) C E U) c o 't * U J N o >(f) CL > > ?' 0) 0 < CO N > CO CO +; C CO cn (n ' Q U p > > N (n ° C 0. c6 Q U > , CU U o0 a) d CO co (B C) LO U O p O N- O E .o 00 ° U < .O O - a .0 ¢ O Ce O E o V LL CO a_o CD o ° O a_ , • o o) a. o E o co ?, o O o p o o a) ° v �- � CO° a) co")M a o .,0 M o - o 0) O ._ U ° U w w o C c r u, rn° 0 ° . t a : o a) (3 0-) o mLL! w .° oaw c w • U (f)p oa) E o oo•> N B ID O N -0 'a O a) O d ca O N L p L ) B a a)a) a) O a) a) Lc" N a) H 0 - C 0 N C O C 0 D a D � C m O C CO ( ( C C � � lfrn a Lou)w a C m C C o L C C a)cN C O p C .L c) •— i-_- co L 'L O O O c c c _0 N 0 >, 0 ° C N C c C B 0) ( O ° > O N a (U) 0 0 U U L 0 6 N U Q a) a) C co C a) ° a) Lo 0 a) -Q C a) in' a) cn as o Cl a.t Q'.to j _ a L Q o C -° a a_ O a- a) (n O o o o o E N E • w O E N w U O O C E E U E U w N CO a D B * * D D D V H JO * * 3 a C a C * « (n▪ + 3 n_ CL -4. 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N U)E k � • � / k / 0 \ c 3 m ® # - _ ® cn c ? 2 w o f O• 2000 10750 0 2= \= S / \ % . o C m c E _ . o r m c o > I _ & c.( a s # .- = s c e.- a_ -) EE . E / \ 2 / / / E E / E . E E I _ = u = c _ _ .- = e = ._ i E E c E # '- 9 f E E # Cl_ c E ± ± co co 7 3 _/ N \ TREE= FMC WELLHEAD CM/ i 12 34 SAFETY NOTES: H2S READINGS AVERAGE 125 ACTUATOR= BAKER C ppm WHEN ON MI.WELL REQUIRES A SSSV 114T1AL KB.ELE 71.35' WHEN ON MI. BF.ELEV= 52.51' - KOP= 2181' Max Angle= 50°@ 6568' Datum M3= 11305' I I 2016' H4-1/2'HES X NPPLE,D=3.813" Datum ND= 8800'SS 9-5/8"CSG,40#,L-80,ID=8.835" —I 3365' Minimum ID =3.725" @ 8970' 11 III 8849' —14-1/2' HES X NP,D=3.813" 4-112" HES XN NIPPLE 8 $ 8870' H7"X 4-1/2"BKR PREM PKR,D=3.875' 8949' —4-1/2" HES X NP,D=3.813" la 8970' H4-1/2" HES XN NP,D=3.725" 8970' 14-1/7 XN LOCK,DH CHOKE ASSEMBLY, D=.80"(05/07/13) 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958' —I 8989' "'v 8988' —15"PBR W/SEALS [TOP OF 4-1/2'LNR —I 8992' 7"CSG,26#,L-80,D=6.276- —{ 11326' • ■ PERFORATION SUMMARY REF LOG:BHCA ON 11/22/94 ANGLE AT TOP PEW:47°@ 11360' Note:Refer to Production DB for historical perf data SIZE SR= INTERVAL Opn/Sqz SHOT SQZ 2-1/8" 2 11360- 11380 0 07/26/98 2-1/8" 4 11470- 11490 0 06/19/95 2-1/2" 8 11484- 11514 0 03/07/95 2-1/8" 4 11508- 11528 0 06/19/95 FISH-(3)PKR SLPS(LOST 5/28/03)OR LNR 11525' DAMAGE? I 11687' I--FISH-(3)ARM SPRINGS F/4.5 OK-6 PBTD H 11715' ,,4.44444�4* 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.958" H 11800' DATE REV BY COMVENTS DATE REV BY C OMVENTS PRUDHOE BAY UNIT 01/22/95 ORIGINAL COMPLETION WElL:'12-34 06/02/03 DAV/KK RWO PERMT No:'1941370 05/03/05 TM IPJC FISH(4/12/05) AR No: 50-029-22515-00 02/09/11 M3/JMO ADDED SSSV SAFETY NOTE SEC 18,T1ON,R15E 632'FSL&938'FE_ 01/13/12 TAN/MD ADDED Ii2S SAFETY NOTE 05/17/13 NLW/JWD SET DH CHOKE(05/07/13) BP Exploration(Alaska) 10/16/09 301umberger NO. 5418 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job M Log Description Date BL Color CD Pt -25 AP30 -00063 INJECTION PROFILE — 10/0209 1 1 W -01A B2NJ -00026 MEMORY GLS 10/02109 1 1 12 -06A AZCM -00043 LOL — 10/03/09 1 1 W -36 AV1H-00028 PROD PROFILE W /GL j 09129/09 1 1 E -35A B2NJ -00027 MEM CEMENT BOND LOG 10/03/09 1 1 12-34 AYS4 -00104 INJECTION PROFILE Vw 1 10/11/09 1 1 Z -07A AYS4 -00101 PRODUCTION PROFILE 10/(18109 1 1 15 -18A 82WY -00015 MEM PROD PROFILE 07/01/09 1 1 05 -18A B04C -00069 SCMT — 07/30/09 1 1 U -05A 8148 -00068 USIT — 08/17/09 1 1 P -07A AWJI -00051 MEM P PROFILE 10109/09 1 1 09 -03 AZCM -00044 PRODUCTION LOG 10/10/09 1 1 1- 45/0 -26 92NJ -00032 MEM LDL 105A — 10/10/09 1 1 9-134 AWL8-00039 USIT 09/28/09 1 1 V -105 B3SO -00026 (PROF 10/03/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 14 a �'a -56 tb OPERABLE: 12-34 (PTD #1941 AOGCC MITIA passed post PW line replacement Page 1 ~G Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, December 04, 2008 9:03 PM ~~ ~ ~ 2 ~ S j~vo To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Cooper, Katrina N; Engel, Harry R; GPB, FS1 DS12 Operator Cc: Cooper, Katrina N; Townsend .Eliot; Winslow, Jack L. Subject: OPERABLE 2 34 (PTD #1941370) A GCC MITIA passed post PW line replacement All, Well 12-34 {PTD #1941370) has passed an AOGCC witnessed test to 4000 psi on 12!01!08 and has been returned to Operable status. Please contact me if there are any questions. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: ,ADW Well Integrity Engineer Sent: Sunday, ovember 23, 2008 11:24 AM To: 'Regg, James OA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSi DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization En •GPB, EOC Specialists; Cooper, Katrina N; Engel, Harry R; GPB, FSl DS12 Operator Cc: NSU, ADW Well Integrity Engin • Wellman, Taylor T; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: 12-34 D #1941370) Ready for injection for AOGCC MITIA post PW line replacement Hi all, Well 12-34 {PTD #1941370) has been reclassified ~ the well may naw be placed on injection. Once the We conducted. Evaluatian. The produced Water iine has been replaced and stabilized, an AOGCC MITIA for UIC compliance Will be Thank you, Anna Dube From: NSU, ADW Well Integrity Engineer \ Sent: Tuesday, March 18, 2008 2:11 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; Eng; GPB, Optimization Engr; GPB, EOC Specialists; Gerik, Bob G; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: 12-34 (PTD #1941370) Classified as Not Operable: Wait on PW line replacement for AOGCC MrrIA Hi all, DS Ops Lead; GPB, Wells Opt 12/5/2008 • MEMORAI~1DUli~I TO: Jim Regg ' ~C.~ <- i 2~~ ~~ P.I. Supervisor ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 03, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-34 PRUDHOE BAY UNIT 12-34 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~- Comm Well Name• PRUDHOE BAY UNIT 12-34 Insp Num: mitRCN08 1 202 144208 Rel Insp Num: API Well Number: 5o-oz9-22515-00-0o Permit Number: 194-137-0 Inspector Name: Bob Noble Inspection Date: 12~1~2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well '' 12-34 Type Inj. I N ; 'I'mo II 7091 IA ~ 540 i 4000 i i- 3940 ~ 3940 I P.T 1941370 ~TypeTest ~ sPT ', Test psi aooo ~i OA 6o 7s 7s ~ 7s i ~ Interval 4YRTST p~F P TUl)ln g ~ 350 ' 350 350 ~ 350 ~ i ~__ Notes: Well was shut in. Wednesday, December 03, 2008 Page 1 oS t UNDER EVALUATION: 12-34 (PTD #1941370) Ready for injection for AOGCC MITIA post P... Page 1 of 1 ~~ f~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) ~~~ ~~~~-~z.~ Sent: Sunday, November 23, 2008 11:24 AM I ~' I To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Cooper, Katrina N; Engel, Harry R; GPB, FS1 DS12 Operator Cc: NSU, ADW Well Integrity Engineer; Wellman, Taylor T; Holt, Ryan P (ASRC); Quy, Tiffany Subject: UNDER EVALUATION: 12-34 (PTD #1941370) Ready for injection for AOGCC MITIA post PW line replacement Hi all, Well 12-34 {PTD #1941370) has been reclassified as Under Evaluation. The produced water line has been replaced and the well may now be placed on injection. Once the well has stabilized, an AOGCC MITIA for UIC compliance will be conducted. ' Thank you, Anna Dube ~~~~~ ~~,~ W u ~~~$ From:. NSU, ADW Well Integrity Engineer Sent: Tuesday, March 18, 2008 2:11 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/Z/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Gerik, Bob G; Engel, Harry R Ce: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: 12-34 (PTD #1941370) Classified as Not Operable: Wait on PW line replacement for AOGCC MITIA Hi all, Well 12-34 (PTD #1941370) is due for AOGCC required MITIA. Given the well needs to be on injection and the produced water line to the drillsite is being replaced, the well has been reclassified as Not Operable until ready to go back on injection. Plans continue to have the produced water line replaced by 3Q08. Once complete, the well will be reclassified as Operable, put on water injection, and the AOGCC witnessed MITIA will be conducted at that time. Please let us know if you have any questions. Thank you, ,Anna ~Du6e, ~'.2. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: {907) 659-5100 x1154 11 /24/2008 12-34 (PTD #1941370) Classifies Not Operable: Wait on PW line replent for AOGCC M... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ /(~~1~~ Sent: Tuesday, March 18, 2008 2:11 PM ~~ l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Gerik, Bob G; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: 12-34 (PTD #1941370) Classified as Not Operable: Wait on PW line replacement for AOGCC MITIA Hi all, Well 12-34 (PTD #1941370} is due for AOGCC required MITIA. Given the well needs to be on injection and the produced water line to the drillsite is bein re laced, the well has been reclassified as Not Operable until ready to go back on injec ion. Plans continue to have the produced water line replaced by 3Q08. Once complete, the well will be reclassified as Operable, put on water injection, and the AOGCC witnessed MITIA will be conducted at that time. Please let us know if you have any questions. Thank you, ,~nnn ~u6e, ~? ~E. WeNN Nntegrity Coordinator GPB eNNs Group Phone: (~) 659-51Q2 Pager: (9Q7) 659-5100 x1154 ~~~t~~ APR ~ ~ 2ao~ 3/28/2008 ) ~7~~!:~ !Æ~!Æ~~!Æ / AI',ASIiA. OIL AND GAS I CONSERVATION COMMISSION / ) FRANK H. MURKOWSK', GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~'FYJ Bob Gerik Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 12-34 Sundry Number: 304-416 Dear Mr. Gerik: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been reque~ .œr~ ,/" BY ORDER OF THE COMMISSION DATED this-'Æday of November, 2004 Enc!. SCANNED NOV 1 8 2004 ') ) bp November 9th, 2004 Mr. Bob Crandall Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: 12,.34i Cleanout/Mud Acid BP Exploration (Alaska) Inc., as the Operator of the Prudhoe Bay Un' :~t,^, herewith a request to Cleanout and stimulate 12-34i as follows in accordance 'titH'~" the requirements of 20 AAC 25.280. NO~f 1 Pull SSSV, Drift to TD Cleanout fill to 11650'MD Perform Mud Acid Stimulation Drift to TD, Reset SSSV If you require additional information, please call Bob Gerik at 564-4476 or contact him through email atgerikbg@bp.com Sincerely, r-wt ~ Bob Gerik PBU Waterflood Petroleum Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Telephone (907) 564-4476 SCANNED NO\ll 8 2DD4 \LiGA-- IllltP/~oo+ DTS ilf/6/4- ') STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend D Repair Well D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool 0 4. Current Well Class: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.35 KB 8. Property Designation: ADL-0028330 11. Total Depth MD (ft): 11800 Casing Total Depth TVD (ft): 9227.5 Length Size Conductor 80 Liner 2808 Production 11303 Surface 3341 Perforation Depth MD (ft): 11360 - 11380 11470 - 11484 11484 - 11490 11490 - 11508 11508 - 11514 11514 - 11528 Packers and SSSV Type: 4-1/2" Baker Premier Packer 12. Attachments: Description Summary of Proposal Œ] top 25 8992 23 24 bottom top 105 11800 11326 3365 Tubing Size: 4.5 " 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 8909.13 8922.8 8985.83 8995.8 8995.83 9000.1 9000.12 9013.0 9013.03 9017.4 9017.35 9027.4 PerforateD WaiverD Annular DisposalD StimulateŒ] Time ExtensionD OtherD Re-enter Suspended Well D 5. Permit to Drill Number: 194-1370 25.0 7181.3 23.0 24.0 bottom 105.0 9227.5 8886.0 3226.4 Tubing Grade: L-80 Development D Exploratory D Stratigraphic D Service Œ] 9. Well Name and Number: 12-34 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11715 9092.9 MD TVD 12.6 # 6. API Number 50-029-22515-00-00 Plugs (md): Junk (md): None 11687 Burst Collapse 1490 8430 7240 5750 ~p (ft): iJ;', NOt¡ 1 0 2004 470 7500 5410 3090 Packers and SSSV MD (ft): 8872 Detailed Operations Program D BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG ŒJ GINJD PluggedD AbandonedD WINJD WDSPLD Prepared by Garry Catron 564-4657. November 23, 2004 Printed Name Signature Bob Gerik {7} /1 ~ ':1 il.,Y(P- '" ~ ~~'1v \ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D Other: Contact Title Phone Petroleum Engineer 564-4476 Location Clearance D RBDMS BFl NOV 1 7 2004 Bob Gerik 11/9/04 Sundry NÕÖ'q - 4/ b BY ORDER OF ,~h'h,E THE COMMISSION Date: If I~ IT 0 R f G I N A pCANNED NO\J 1 8 -¿(I\)4 I L SUBMIT IN DUPLICATE Form 10-403 Revised 06/2004 ) TREE = FMC ( W8..LI-EAD = aw 'AcruA TOR-;-,m"'SAK'Ëffë' KtL'ï~LEV~"-'--~---fl' "SF. ELßi'~ 52.51' 'K'ðP;;---"""-------2181"; 'tvî'ãx"A'ngïe ;"'''''Sö''(@' 656Sï [5ãtUïñ'Mtf;;"""",,,,,,",,..m"""1"1"3ïYs^; "".M.. '.','.-.', ......n,'., '~'~"" .",-...,,', ...~,'m.','-m" .. ,..., ,","""""'~'.'.'~m.~' OatumTVD= 8800'SS 19-5/8" CSG, 40#, L-80, D = 8.835" H 3365' ~ Minimum ID = 3.725" @ 8970' 4-1/2" HES XN NIPPLE ) 12-34 I SAÆTYNOTES: . . . . 8 ~ ~ J 14-1/2"TBG, 12.6#, L-80, .0152bpf, 10=3.958" - 8989 .............. Ii ITOPOF4-1/2"LNR - 899; I ~ 17" CSG, 26#, L-80, 10 = 6.276" H 11326' I PERF ORA llON SU'v1MA.RY REF LOG: BHCA ON 11/22/94 ANGLEATTOPPERF:47@ 11360' Note: Refer to R'oduction œ for historical perf data SIZE SFT IN1ERVAL Opn/Sqz DA TE 2-1/8" 2 11360- 11380 0 07(26/98 2-1/8" 4 11470 - 11490 0 06/19/95 2-1/2" 8 11484- 11514 0 03/07/95 2-1/8" 4 11508 - 11528 0 06/19/95 IPBTO H 11715' 14-1/2" LNR,12.6#, L-80, .0152 bpf, 10=3.958" H 11800' DA TE RBI BY COM\i1ENTS 01/22/95 ORIGINAL COM PLETION 06102/03 DAV/KK RWO 111 L ... I I I I ., ~ OA 1E REV BY COM~NTS 2016' H4-1/2" HES X NIPR...E, 10= 3.813" ~ 8849' H4-1/2" HES X NIP, 10 = 3.813" I 8870' H 7" X 4-1/2" BKR FREM PKR, 10 = 3.875" I 8949' H4-1/2" HES X NIP, 10= 3.813" 1 8970' H4-1/2" HES XN NIP, 10 = 3.725" 1 8988' H5" FBRW/SEALS I ~ SCANNEO NO\J 1 8 2.0D4 I 11687' H FISH - (3) ARI\1 SPRINGS F/4.5 OK-6 I PRLDI-OE BA Y UNIT WELL: 12-34 PERMIT No: 1941370 AR No: 50-029-22515-00 SEC 18, T10N, R15E, 4699.28' F8.. & 4635.55' FNL BP Exploration (Alas ka) STATE OF ALASKA ALASKA 01 L AND GAS CONSERVATION COMMISSION E C E IVE D REPORT OF SUNDRY WELL OPERATIONS OCT Iì 5 200~ 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.35 8. Property Designation: ADL-0028330 11. Present Well Condition Summary: Total Depth Repair Well 0 Plug PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D . I t 0 ' OtherF)(1. ÇQRvert te Injector. Stlmu a e AlaSi{ì;J iJ;! !4?Ibas I,..ons. 'OmmISS/01 WaiverD Time Extension[1nchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 194-1370 6. API Number 50-029-22515-00-00 4. Current Well Class: Development ŒI Exploratory 0 Service 0 Stratigraphic D 9. Well Name and Number: 12-34 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool measured 11800 feet None Effective Depth true vertical 9227.5 feet 11687 measured 11715 feet Plugs (measured) Junk (measured) true vertical 9164.2 feet Casing Conductor Liner Production Surface Length 80 2808 11303 3341 Perforation depth: Size 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 TVD Burst MD Collapse 470 7500 5410 3090 25 - 105 25.0 - 105.0 8992 - 11800 7181.3 - 9227.5 23 - 11326 23.0 - 8886.0 24 - 3365 24.0 - 3226.4 1490 8430 7240 5750 Measured depth: 11360 -11380,11470 -11484,11484 -11490,11490 -11508,11508 -11514,11514 -11528 True vertical depth: 8909.13 - 8922.77,8985.83 - 8995.83,8995.83 - 9000.12,9000.12 - 9013.03,9013.03 - 9017.35,9017.35 - 9027.44 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 4-1/2" Baker Premier Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 9d ~ ..~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations. ! Signature SCANNED OCT 0 9 2004 Form 10-404 Revised 4/2004 @ 21 8991 @ 8872 Oil-Bbl 166 0 Tubing Pressure 219 912 0.8 0 920 -4874 1600 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-153 Title Production Technical Assistant Phone 564-4657 Date 9/28/04 œ~ Q ÜI 2iÜ~ ! , R/i,:f -¡Wi" 12-34 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/20/04 First day of produced water injecting. FLUIDS PUMPED BBLS No Fluids Pumped 0 TOTAL Page 1 SCANNED OCT 0 9 2004 TREE = WB..U-EAO: ActUATOR: kB. ELEv';' ..... BF. ELBI ~ kÒp="'" 'Mäx Angle' =.. 'Öä'ïlïïn"MO: . OatumTVO: FMC aN BAKER C """'''''71' 52.51' . 2181' 'so (ff6"56"a: """"""""ff3ös' 8800' SS 12-34 I SAFETY NOTES: . . 19-5/8" COO, 40#, L-80, D : 8.835" H 3365' ~ Minimum ID = 3.725" @ 8970' 4-1/2" HES XN NIPPLE . . 8 29 ~ J ;:.1.:.'.'.. !~ 14-1/2"TBG, 12.6#, L-80, .0152 bpf, 10= 3.958" H 8989' ~ , ITOPOF4-1/2"LNRH 8992' I ~ 17" CSG, 26#, L-80, 10: 6.276" H 11326' I .. PERFORA llON SlJv11v\A. RY REF LOG: BHCA ON 11/22/94 ANGLEATTOPPERF:47@ 11360' Note: Refer to A-oduction œ for historical perf data SIZE SFF INTERVAL Opn/Sqz DA TE 2-1/8" 2 11360- 11380 0 07(26/98 2-1/8" 4 11470 - 11490 0 06/19/95 2-1/2" 8 11484-11514 0 03/07/95 2-1/8" 4 11508-11528 0 06/19/95 ., IPBTO H 11715' I - 14-1/2"LNR,12.6#,L-80,.0152bpf,ID=3.958" H 11800' I DA TE RBI BY COMMENTS 01/22/95 ORIGINAL COM PLETION 06/02/03 DAV /KK RWO DA TE REV BY COMrvENTS SCANNED OCT 0 9 2004 2016' H4-1/2" HES X NIPR..E, ID = 3.813" ~ 8849' H4-1/2" HES X NIP, 10 = 3.813" I 8870' H 7" X 4-1/2' BKR FREM PKR, 10 : 3.875" I 8949' H4-1/2" HESXNIP, 10=3,813" I 8970' H4-1/2" HES XN NIP, 10=3.725" I 8988' HS' FBRW/SEALS I ~ I 11687' H FISH - (3) A RM SPRINGS F/4.5 OK-6 I PRLOHOE BA Y LNIT WELL: 12-34 PERM If No: 1941370 AA No: 50-029-22515-00 SEC 18, T10N, R15E, 4699.28' FB.. & 4635.55' FNL BP Exploration (Alas ka) ( ( State of Alaska MEMORANDUM TO: Randy R~ ~oner Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor K€1tl ~1'*4-- DATE: Wednesday, March 10,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-34 FROM: Chuck Scheve Petroleum Inspector PRUDHOE BAY UNIT 12-34 8rc: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-225 15-00-00 InspN mitCS040305 I 53045 Inspection Date: 3/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 12-34 Type Inj. P TVD 7091 IA 650 4000 3960 3960 P.T. 1941370 TypeTest SPT Test psi 1772.75 OA 300 600 600 600 Interval Initial Test P/F Pass Tubing 400 400 400 400 Notes: Initial post workover MIT. Pre test pressures observed and found stable. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SAL T WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=Intemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Wednesday, March 10,2004 Page I of I c(r.'¡;\d~\nr~~R:.::(¡,"), 1~'~lliH)) 11 tí7í 2DOL~. ~XJIf"'t,Ð~Ð~!4;,!!,. tt"~Mß:'II -, ß STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ;. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to Injector 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 71.35' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 632' NSL, 938' WEL, SEC. 18, T10N, R15E, UM X = 696667, Y = 5930938 12-34 At top of productive interval 9. Permit Number / Approval No. 194-137 303-153 846' NSL, 4464' WEL, SEC. 19, T10N, R15E, UM X = 693293, Y = 5925784 10. APl Number At effective depth 50- 029-22515-00 4600' SNL, 4656' WEL, SEC. 19, T10N, R15E, UM X = 693106, Y = 5925614 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 4637' SNL, 4699' WEL, SEC. 19, T10N, R15E, UM X = 693064, Y = 5925576 Pool 12. Present well condition summary Total depth: measured 11800 feet Plugs (measured) true vertical 9227 feet Effective depth: measured 11715 feet Junk (measured) 3 Arm Springs F/4-1/2" at approximately 11687' true vertical 9164 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3334' 9-5/8" 895 sx CS III, 375 sx Class 'G' 3365' 3227' Intermediate Production 11370' 7" 445 sx Class 'G' 11395' 8933' Liner 2808' 4-1/2" 250 sx Class 'G' 8992' - 11800' 7181' - 9227' REGE VE D Perforation depth: measured 11360'- 11380', 11470'- 11528' JUN ~ '~ ~_00B ,, true vertical 8909' - 8923', 8986' - 9028' j~laS~(.~ 0i~ & ~',~$ [,~'~- C0~T~Fi~iSS~I'~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8989' Packers and SSSV (type and measured depth) 4-1/2" Baker premium packer at 8870'; 4-1/2" HES 'X' Nipple at 2016' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ,,, 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Servic.e~,.[Vll inject~[,.,,,,,~_.' [] Daily Report of Well Operations "i 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date · ~(,.~o ~ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Well: 12-34 RWO Accept: 05/22/03 Field: Prudhoe Bay Unit Spud: N/A APl: 50-029-22515-00 Release: 05/31/03 Permit: 194-137 Rig: Nabors 4ES Date PRE-RIG WORK 05/20/03 TIO=320/270/200. PPPOT-T PASS, PPPOT-IC PASSED (PRE-RWO). TUBING HANGER TEST VOID BLED TO 0 PSI. PRESSURED TO 5000 PSI, LOST 50 PSI IN 30 MIN. FUNCTION TEST ALL LDS - OK. PPPOT-IC PASSED. lC HANGER TEST VOID BLED TO 0 PSI. PRESSURED TO 3200 PSI, LOST 0 PSI IN 30 MIN. FUNCTION TEST ALL LDS - OK. DRIFT 3.625" CENT TO COLLAPSED TBG @ 6967' SLM (NO PROBLEMS). 05/21/03 T/I/O = SI/240/300. BLEED OAP. (PREP FOR MITOA). OA FL @ 400'. BLED OAP FROM 300 PSI TO 0 PSI IN 45 MIN. MONITORED FOR 20 MIN. FINAL WHP'S = SI/240/0+. CHEMICAL CUT TUBING @ 6915' MD REFERENCED TO TUBING TALLY. PREPPED TUBING W/14' STRINGSHOT PRIOR TO CUT. FIRED CHEMICAL CUTTER. CUT DEPTH = 6915' MD. 3-3/8" ANCHORS SET @ 6905.5 FT. 3-3/8" SEVERING HEAD CENTERED ON CUT DEPTH. NO JARS IN TOOLSTRING. DEVIATION AT CUT DEPTH = 43 DEGREES. SEAWATER IN BOREHOLE AT CUT DEPTH. ONE CENTRALIZER ON CHEMICAL TUBES AND ONE BOTTOM NOSE CENTRALIZER. DID NOT TAG TD, NO PROBLEMS RIH OR POOH. 05/22/03 T/I/O = 0/250/0. CIRCULATE OUT TBG & IA. MIT - OA FAILED. (PRE RWO). PUMPED DOWN THE TUBING TAKING RETURNS FROM IA TO FLOWLINE OF WELL 12-18; 5 BBBLS NEAT MEOH SPEAR, 615 BBLS SEAWATER, 90 BBLS DIESEL. U-TUBE DIESEL FROM TUBING TO IA. FREEZE PROTECT FLOWLINE WITH 10 BBLS NEAT MEOH. MIT OA FAILED. (FAILED ON STABILIZATION). PRESSURED OA TO 2000 PSI WITH 1 BBL OF DIESEL. STARTED 30 MIN TEST. OA LOST 400 PSI IN 15 MIN. RE-PRESSURED OA TO 2000 PSI. OA LOST 125 PSI IN 15 MIN. RE-PRESSURED OA TO 2000 PSI. OA LOST 50 PSI IN THE 1ST 15 MIN AND 75 PSI IN THE 2ND 15 MIN. BLED OA TO 0 PSI. FINAL WHP'S = 0/0/0. BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: 12-34 Common Well Name: 12-34 Spud Date: 10/30/1994 Event Name: WORKOVER Start: 5/22/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 5/31/2003 Rig Name:. NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/22/2003 14:00 - 15:00 1.00 MOB P PRE Scope & lower derrick. 15:00 - 16:30 1.50 MOB P PRE Move rig offX-17 well. 16:30 - 17:00 0.50 MOB P PRE Move rig from x pad to spine road. 17:00 - 19:00 2.00 MOB P PRE Move rig down spine road to DS 12. 19:00 - 20:00 1.00 MOB P PRE Finish prepping DS 12-34 well. Wait to move on well. 20:00 - 21:00 1.00 RIGU P PRE Set matting boards & spot sub module over well 12-34. 21:00 - 22:30 1.50 RIGU P PRE Spot in pipe shed, pits & camp. Plug in & hook up same. 22:30 - 00:00 1.50 RIGU P PRE Raise & scope derrick. Finish rigging up modules & tiger tank. 5/23/2003 00:00 - 01:00 1.00 WHSUR P DECOMP RU lubricator. Pull BPV. LD lubricator. 01:00-01:30 0.50 KILL P DECOMP Test lines to 3,000 psi. Good. Openwell. TbgPress= 160. Annu press = 0. 01:30 - 04:00 2.50 KILL P DECOMP PJSM. Displace well down to chemical cut/collasped jt 6915/6967-ft. at 4.5bpm/400psi. Unable to get full returns...well taking fluid. 04:00 - 05:00 1.00 WHSUR P DECOMP Install and test TWC. 05:00 - 06:00 1.00 WHSUR P DECOMP ND Production Tree. 06:00 - 08:30 2.50 BOPSUI; P DECOMP PJSM. NU BOPE. 08:30 - 09:30 1.00 BOPSUF P DECOMP PU Test Jt. RU to test BOPE 09:30 - 13:00 3.50 BOPSUF~ P DECOMP Test BOPE as per BP/AOGCC requirements.( Note BOP was tested to 4,000 psi as per program) 25/4000psi. Hydrill 250/3500 psi. Good test. Right to wittness test waived by C. Sheve. RD test equipment. Blow down lines. Drain stack. 13:00 - 14:30 1.50 BOPSUF~ P DECOMP M/U lubricator. Pull TWC. LID lubricator. 114:30 - 15:00 0.50 PULL P DECOMP R/U tongs & control line spooler. 15:00 - 16:00 1.00 PULL P DECOMP M/U landing Jr. BOLDS. Pick up to 70 K hanger & string pulled free. Pull hanger to floor. LID hanger & landing Jr. 16:00 - 19:30 3.50 PULL P DECOMP POOH & LID 4 1/2" tubing string. Spool up SSSV control line. ; 19:30 - 20:00 0.50 PULL P DECOMP LID SSSV control line spooler. Recovered 47 bands. :20:00 - 23:30 3.50 PULL P DECOMP Con't to POOH & LID 4 1/2" completion. Recover 164 full Jts, + 20.5' Cut off Jr. Cut was clean wi no belling. 23:30 - 00:00 0.50 BOPSUF~ P DECOMP Clear & clean rig floor. P/U tongs to run DP. 5/24/2003 00:00 - 01:30 1.50 PULL P DECOMP Clear & clean floor. Finish rigging down tbg equip. Install wear bushing. 01:30 - 02:30 1.00 FISH P DECOMP P/U BHA #1 as follows: OS wi4 1/2" Grapple, 5 7/8" Extention, Top Sub, Bumper Sub, Oil Jar, Pump-Out Sub, 9 ea 4 3/4" DP. 02:30 - 06:00 3.50 FISH P DECOMP Begin picking up 3 1/2" DP from Pipe Shed. Tally same. Crew change. 06:00 - 09:00 3.00 FISH P DECOMP PJSM. Continue picking-up 3 1/2" DP from Pipe Shed (207 jts). PUW = 107K. SOW = 85K. 09:00-09:30 0.50 FISH P DECOMP PU Kelly. PUW= 112K SOW= 90K. RW=100K. 09:30 - 10:00 0.50 FISH P DECOMP Latch top of chem cut stump at 6,908-ft Driller's depth. PU 15 K over RW = 15K. Turn pipe to the left. AMPs = 290. With 8 1/2" turns pipe broke free. 10:00 - 13:30 3.50 FISH P DECOMP Set back Kelly. Have normal string weight 107K. TOOH with 3 1/2" DP and BHA #1. 13:30 - 14:30 1.00 FISH P DECOMP LD fish. Recovered chemical cut stump 21.00-ft and 38.67-ft of next jt down. Jt snapped off (not twisted off) right at the top of the collasped section. Using Jt average it is assumed that there is 2.70-ft of collasped tubing to the next collar 14:30 - 15:00 0.50 FISH P DECOMP LD BHA #1. Clear floor. 15:00 - 16:00 1.00 FISH P DECOMP Make up BHA #2 as follows: Metal Muncher Shoe 6 1/$" x 4 1/2", 2 jts 5 3~4" Wash Pipe, Boot Basket, XO, Boot Basket, Bit !Sub, Bumper Sub, Oil Jar, 9 ea 4 3/4" DC Printed: 6/2/2003 8:10:19AM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: 12-34 Common Well Name: 12-34 Spud Date: 10/30/1994 Event Name: WORKOVER Start: 5/22/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 5/31/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/24/2003 16:00 - 19:00 3.00 FISH P DECOMP RIH w/BHA #2 and 3 1/2" DP. 19:00 - 21:30 2.50 FISH P DECOMP P/U kelly. Break circulation. RIH & tag top of fish @ 6967'. Washover fish from 6967 to 6971'. Con't to swallow fish to 6999'. Pull back up over fish & attempt to go back over fish. Would not go deeper than 6969'. Con't to mill down on fish. Rotated for approx 1 hr w/no progress. 21:30 - 00:00 2.50 FISH P DECOMP POOH to check milling shoe & washpipe. 5/25/2003 00:00 - 00:30 0.50 FISH P DECOMP Con't to POOH. Recovered small (6") piece of rolled out tbg in washpipe shoe. Redress washpipe w/new shoe & RIH w/BHA #3. 00:30 - 03:00 2.50 FISH P DECOMP RIH w/washpipe on 3 1/2" DP. 03:00 - 06:00 3.00 FISH P DECOMP P/U kelly break circulation & tag up @ 6967'. Milling ahead from 6967'. 75-80 RPMs, Torq 9-11K, 40 SPM @ 300#. Losses decreased to 12 Bph. P/U 115K, S/O 100K. Crew change. 06:00 - 08:00 2.00 FISH P DECOMP PJSM. Finish dressing collasped section and collar. Fell thru at 6,972-ft. Continue down to 7,002-ft clean. Worked from 7,002'- 6,960' twice with no rotation. Clean. 08:00 - 08:30 0.50 FISH P DECOMP Set back Kelly. 08:30 - 09:30 1.00 FISH P DECOMP Cut and slip drilling line. 09:30 - 11:30 2.00 FISH P DECOMP TOH with 3 1/2" DP (207 jts) 11:30 - 12:30 1.00 FISH P DECOMP LD BHA #3. Clean out mangled junk (3 pieces) from inside wash pipe. 12:30 - 13:30 1.00 FISH P DECOMP Clean floor. MU BHA #4 as follows: 5 7/8" OS wi4 1/2" grapple, 2 ea extentions, Top Sub, Bumper Sub, Oil Jar, Pump-out Sub, 9 ea 4 3/4" DC. 13:30 - 15:30 2.00 FISH P DECOMP TIH with BHA #4 and 209 jts 3 1/2" DP. 15:30 - 16:00 0.50 FISH P DECOMP Pick up kelly, break circulation & tag up on tbg stub @ 6969'. 16:00 - 16:30 0.50 FISH P DECOMP Engauge fish w/Overshot. Attempt blind backoff, string came free. Set back kelly. 16:30 - 19:30 3.00 FISH P DECOMP POOH w/3 1/2" DP. Notice jt that came un- torqued, tighten same. 19:30 - 20:00 0.50 FISH P DECOMP Inspect BHA. Overshot left in hole, It sheared 4 set screws & came unscrewed while performing blind backoff. Now have 4 1/2' tbg stub sticking up above overshot in hole. 20:00 - 21:30 1.50 FISH P DECOMP Clear & clean rig floor. M/U BHA # 5. 21:30 - 00:00 2.50 FISH P DECOMP RIH w/BHA #5. Re-Torque each tool jt while RIH. 5/26/2003 00:00 - 00:30 0.50 FISH P DECOMP Finish running in hole & re-torque each tool jr. 00:30 - 03:00 2.50 FISH P DECOMP P/U kelly & break circulation. Tag up on tbg stub @ 6972'. Mill & dress tbg stub from 6972 to 6975'. losing 8 BPH. 100 RPMs, WOB 1-3K, PP 400#, incresed to 700#. 50 SPM, 124 GPM, Torq 2-5K. 03:00 - 06:00 3.00 FISH P DECOMP POOH w/mill/dress off assy. Crew change. 06:00 - 07:00 1.00 FISH P DECOMP PJSM. Finish TOH with 3 1/2" DP (209jts) and BHA#5. 07:00 - 07:30 0.50 FISH P DECOMP LD BHA #5. Clear floor. 07:30 - 08:00 0.50 FISH P DECOMP PJSM. RU Halliburton S-Line Unit. 08:00 - 09:30 1.50 FISH P DECOMP S-Line RIH w/3.740" Tapered Swedge, Spangs, Oil Jars, weight bars. Enter top of Tbg stump at 6,972-ft (saw a bobble). Got down to 6,988-ft and set down. Work wire. Fell thru. Pull back above top of Tbg and re-enter (3 times) with no problems. Continue RIH. Set down again 7,107-ft sim. Attempt to knock junk down hole several times. Unable to get any deeper. Had to "fire" oil jar to get free on last attempt. Printed: 6~2~2003 8:10:19 AM BP EXPLORATION Page 3 of 5 Operations Summar Report Legal Well Name: 12-34 Common Well Name: 12-34 Spud Date: 10/30/1994 Event Name: WORKOVER Start: 5/22/2003 End: Contractor Name: NABQRS DRILLING CC). Rig Release: 5/31/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/26/2003 09:30 - 10:00 0.50 FISH P DECOMP POOH. Discuss plan forward with Anch Engineer. 10:00 - 11:00 1.00 FISH P DECOMP R/D slick-line equip. Order out 2 7/8" PAC Drill Pipe and 3.750" Mill. 11:00 - 12:00 1.00 FISH P DECOMP Clear & clean rig floor, W/O 2 7/8" PAC DP. 12:00 - 13:00 1.00 FISH P DECOMP Load & tally 2 7/8" PAC DP. 13:00 - 15:30 2.50 FISH P DECOMP M/U BHA #6 as follows: 3 3/4" Flat Btm Mill, Bit Sub, 66 ea Jts 2 7/8" PAC DP, XO, Bumper Sub, Oil Jar, 9 ea 4 3/4" DC. P/U 2 7/8" DP. Start TIH. 15:30 - 18:00 2.50 FISH P DECOMP Continue in w/3 1/2" DP to top of Tbg stump at 6,972-ft. 18:00 - 20:00 2.00 FISH P DECOMP Enter 4 1/2" stubing stub & con't in hole. Took weight @ 7343'. Took 15K to push ahead, then dropped free. Work thru 3-4 times w/mill & cleaned up. Chase junk to bottom @ 8965'. (3rd pup jt below packer) 20:00 - 00:00 4.00 FISH P DECOMP POOH & stand back 3 1/2" DP. Begin laying down 2 7/8" DP. 5/27/2003 00:00 - 01:00 1.00 FISH P DECOMP Finish POOH & lay down 2 7/8" PAC DP. 01:00 - 02:00 1.00 FISH P DECOMP Clear Floor. RU to pick-up 4 1/2" Work String. 02:00 - 02:30 0.50 FISH P DECOMP ~MU BHA #7 as follows: 5 7/8" Guide, 5 7/8" Overshot wi4 1/2" i Grapple, Top Extention, Top Sub, XO. 02:30 - 06:00 3.50 FISH P DECOMP !Start picking up 4 1/2" NSCT Tbg from Pipe Shed. Crew !change. 06:00 - 10:00 4.00 FISH P DECOMP PJSM. Continue picking up 4 1/2" W S from Pipe Shed = 170 Ijts. 10:00 - 10:30 0.50~ FISH P DECOMP Tag top of Tbg stump at 6,972-ft. Latch fish. Pull 20K tension. 10:30 - 12:30 2.001 FISH P DECOMP PJSM with all. RU SWS. Prepare to RIH with String Shot. 12:30 - 14:30 2.00. FISH P DECOMP RIH w/string shot = 14-ft x 2 Strands x 80 grams Prima-Cord. Log Jewery for tie-in. Position String Shot. Shoot 8902'-8916'. POOH. 14:30 - 15:00 0.50 FISH P DECOMP PJSM with all. LID string shot. M/U chemical cutting assy. 15:00 - 17:00 2.00 FISH P DECOMP Begin RIH but had to work thru 7,097-ft, 7,249-ft, 7370-ft. Got down to 7,370-ft could not get deeper. POOH w/3 5/8" cutter. Discuss plan forward with Engineer. 17:00 - 17:30 0.50 FISH P DECOMP Change ot 3 5/8" cutter for 3 3/8" cutter. 17:30 - 19:30 2.00 FISH P DECOMP RIH w/3 3/8" chemical cutter set down at 7,819-ft and 7,985-ft but was able to work thru. Make tie in pass. Log cutter in ;)lace at 8,914-ft. Fire cutter. Good indication on surface that cutter fired. POOH. Stop at 200-ft for safety meeting. 19:30 - 20:00 0.50 FISH P DECOMP . LID cutting assy & RID E-line equip. 20:00 - 20:30 0.50 FISH P DECOMP Work pipe, tubing came free w/195K pull. P/U 5'. 20:30 - 21:30 1.00. FISH P DECOMP R/U circulating head pin & circulate bottoms up. Had small :amount of gas to surface. Monitor well, well static & full. 21:30 - 00:00 2.50 PULL P DECOMP POOH & LID 4 1/2" work string. 5/28/2003 00:00 - 02:30 2.50 FISH P DECOMP POOH & L/D 4 1/2" work string. 02:30 - 03:00 0.50 FISH P DECOMP Disengauge fish from overshot. LID overshot assy. 03:00 - 05:00 2.00 FISH P DECOMP Cont POOH & LID 4 1/2" Prod Tbg. Recovered 45 + 22.04' cut off Jt and the 2 remaining GLMs. 05:00 - 06:00 1.00 FISH P DECOMP RU floor to handle 3 1/2" Drill Pipe. Crew change. 06:00 - 06:30 0.50 FISH P DECOMP PJSM. Lub Rig 06:30 - 07:30 1.00 FISH P DECOMP PU BHA #8 as follows: Guide, OS Bowl wi4 1/2" Grapple, Bushing, OS Bowl wi4 1/2" Grapple, Extention, Top sub, Bumper Sub, Oil Jar, 9 ea DC, Accelerator. 07:30 - 11:00 3.50 FISH P DECOMP Start TIH with BHA #8 and 3 1/2" DP from derrick (207 jts). Continue TIH with 3 1/2" DP from Pipe Shed (63 Jts). Total = 270 Jts. Printed: 6/2/2003 8:10:19 AM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: 12-34 Common Well Name: 12-34 Spud Date: 10/30/1994 Event Name: WORKOVER Start: 5/22/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 5/31/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 5/28/2003 11:00-12:30 1.50 FISH ~ DECOMP P/Ukelly. PUW=142K. SOW=97K. Break circulation at 3 bpm/400 psi. Tag top of fish at 8,903-ft (high ?). Rotate & wash down to 8908'. P/U w/65K overpull. Jar on fish. Rotated K-Anchor in an attempt to release. Cont to jar and rotate. Unable to rotate free, but appears that we jarred K-Anchor free. 12:30 - 14:00 1.50 FISH = DECOMP Circulate bottoms up at 5 bpm/1000 psi. Small amount of gas to surface. Monitor well. Hole remains full. 14:00 - 14:30 0.50 FISH P DECOMP Start TOH w/3 1/2" DP. FMC tested Mandrel Hanger to 4,500 ~si/15 min. Good test. 14:30 - 15:00 0.501 FISH P DECOMP Slip drilling line. 15:00 - 19:00 4.00 FISH P DECOMP Finish POOH w/3 1/2" DP. LID fish. Recovered cut Jt (21.18'), pup jt (9.72') & K-anchor. (Fish covered with scale...no pun , intended) 19:00 - 19:30 0.50 FISH P DECOMP Clear & clean rig floor. 19:30 - 20:00 0.50 FISH P DECOMP M/U BHA #9. Packer milling assy. 20:00-22:30 2.50 FISH P DECOMP RIHw/BHA#9on31/2"DP. 22:30 - 00:00 1.50 FISH P DECOMP P/U kelly & break circulation. RIH & tag up on hard fill @ 8928'. Mill down thru hard scale to 8933'. Begin milling packer. P/U 135K, S/O 100K, ROT 115K. 65 RPMs, 25KWOB, 7-8K torq, 66 Stks, 163 GPM, PP 900#. 5/29/2003 00:00 - 03:00 3.00 FISH P DECOMP Mill on packer. Made 2+ ft. String torqued up. 65 RPMs, WOB 25K, Torq 7-8K, 66 Stks, 163 GPM. PP 900 Psi. P/U 135K, S/O 100K, ROT 115K. 03:00 - 04:30 1.50 FISH P DECOMP String torqued up. Work pipe & jar on packer. Packer came free. Could not release from PRT. Pull up 1 jt. Losing returns. 04:30 - 06:00 1.50 FISH P DECOMP Circulate bottoms up. Work pipe & monitor well. Crew change. 06:00 - 11:00 5.00 FISH !P DECOMP PJSM. TOH with 3 1/2" DP (270 jts) and BHA #9 and fish. 11:00 - 12:30 1.50 FISH I p DECOMP LD BHA, Pkr, and Tail Pipe Assy. 12:30 - 13:30 1.00 FISH P DECOMP Clear and clean floor. Prep for next BHA. 13:30 - 14:30 1.00 FISH P DECOMP PU BHA #10 as follows: Polish Mill, 1 Jt 3 1/2" DP, XO, Csg Scraper, 3 ae Boot Baskets, Bit Sub, Bumper Jar, Oil Jar, 9 ea DC, Super Magnet. 14:30-18:00 3.50 CLEAN P DECOMP RIHw/BHA#10on31/2"DP. 18:00 - 19:00 1.00 CLEAN P DECOMP P/U kelly & break circulation. RIH & tag up @ 8989' Polish recepticle down to 8993'. Took 15K weight on would not drill off. Torq smoothed out. PP increased from 1500 to 1800 Psi. Rotated @ 100 RPMs. P/U 145K, S/O 100K, ROT 115K. 19:00 - 20:00 1.00 CLEAN P DECOMP Circulate bottoms up. Losing 50+ BPH. Had gas to surface.. SD & monitor well. Stand back kelly. 20:00 - 23:00 3.00 CLEAN P DECOMP POOH w/BHA # 10. 23:00 - 00:00 1.00 CLEAN P DECOMP LID BHA #10. Inspect polish mill, good indication mill bottomed out on tie-back recepticle. Clear & clean Floor. 5/30/2003 00:00 - 12:30 12.50 CLEAN P DECOMP P/U RTTS packer. RIH on 3 1/2" DP. 12:30 - 01:30 13.00 CLEAN P DECOMP Cut & slip 84' of drilling line. Adjust brakes. 01:30 - 03:30 2.00 CLEAN P DECOMP Con't to RIH w/RTTS on 3 1/2" DP to 8870'. P/U 2 singles & fill hole. 03:30 - 04:00 0.50 CLEAN P DECOMP Set packer @ 8920'. Fill annuls. Test lines to 4000 psi, OK. 04:00 - 05:00 1.00 CLEAN P DECOMP Pressure up annulus to 4000 psi & hold for 30 min. monitored annulus (open to atmosphere) Tested good. Charted same. Bleed off annulus. 05:00 - 06:00 1.00 CLEAN P DECOMP Release RTTS. POOH & L/D 3 1/2" DP. Crew change. 06:00 - 12:30 6.50 CLEAN P DECOMP Finish POOH laying down 3 1/2" DP -- 271 jts, DC -- 9 Jts, and Halco RTTS Pkr. C&C floor. Printed: 6~2~2003 8:10:19 AM BP EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: 12-34 Common Well Name: 12-34 Spud Date: 10/30/1994 Event Name: WORKOVER Start: 5/22/2003 End: Contractor Name: NABORS DRILLING CO. Rig Release: 5/31/2003 Rig Name: NABORS 4 Rig Number: 4ES Date From-To Hours Task Code NPT Phase Description of Operations 5/30/2003 ~ 12:30 - 15:00 2.50 RUNCOr~I:' COMP PJSM. RU 4 1/2" handling equipment, casing tongs and Torque Turn equipment. 15:00 - 00:00 9.00 RUNCOr~I:' COMP MU Tail Pipe Assy (Baker Loc all connections below Pkr). PU Baker Premier Pkr. Start RIH with 4 1/2" 12.6 Ib/ft L-80 TC II completion as per program. Make-up torque 2,700 fi/lbs. Had some initial thread interference in the beginning. (Rejected Jt # 31). Have 105 Jts RIH. 513112003 00:00 - 06:00 6.00 RUNCOr~ COMP Completed RIH w/4 1/2" completion as per program. Crew change. 06:00 - 07:00 1.00~ RUNCOr~ COMP PJSM. Reverse circulate well with 140 bbls of 140 deg F. SW at 3 bpm/150 psi. 07:00 - 07:30 0.50 RUNCO~/P COMP Land Seal Assy into 4 1/2" Liner with 10K set down. Measure landing JT. Pull back out of Liner. Land SA again to verify measurement. Same mark. Fill backside and pressure up to 500 psi. Good. 07:30 - 08:30 1.00 RUNCO~/P COMP LD Landing Jt (#214) and top Jt (#213). Add a 3-ft Pup Jt. Add Jr# 213. Make up Pup Jt and Tubing Hanger. 08:30 - 09:30 1.00 RUNCO~/P COMP Circulate down BS with 140 bbls of 140 deg F. SW w/Corrosion Inhib. at 3 bpm/150 psi 09:30 - 10:00 0.50 RUNCOr P COMP HB&R circulate down BS with 45 bbls of diesel. 10:00 - 10:30 0.50 RUNCOr P COMP Set TWC. Land Tbg Hanger. RILDS. 10:30 - 11:00 0.50 RUNCO~ P COMP HB&R pump 4 bbls diesel down BS. Pressue up to 500 psi/5 min to verify that Seal Assy is stung into liner with the hanger landed. Good test. 11:00 - 13:00 2.00 RUNCOkP COMP ND BOPE. 13:00 - 14:00 1.00 RUNCOkP COMP NU Prod Tree. 14:00 - 14:30 0.50 RUNCOr~P COMP Pressure Test Prod Tree and adaptor flange to 5,000 psi. Good test. 14:30 - 15:30 1.00 RUNCOr~P COMP PU lubricator. Pull TWC. LD same. 15:30 - 16:00 0.50 RUNCOI~F' COMP HB&R pump 34 bbls diesel down Tbg. 16:00 - 18:00 2.00 RUNCOI~P COMP Drop 1 7/8" Ball/Rod. WO Ball/Rod to fall. HB&R pump 4 bbls diesel...ball on seat. Walk pressure up to 4,200 psi. Hold for 5 min. Pkr set. Bleed pressure to 4,000 psi and chart Tbg at 4,000 psi/30 Min. Good. Bleed Tbg press to 1,500 psi and close wing valve. 18:00 - 19:00 1.00 RUNCOI~P COMP HB&R hook up to annulus. Pump 4 bbls diesel. Walk pressure up to 4,000 psi. Chart 4,000 psi for 35 min. Good. Check Tbg pressure at 2,000 psi. Bleed off pressure from annulus and tubing. 19:00 - 20:00 1.00 RUNCOI~F' COMP Set BPV. Blow down lines. Secure cellar. Release Rig. 20:00 - 00:00 4.00 RIGD P POST RDMO. Printed: 6/2/2003 8:10:19 AM 1Z-34 bundry, Approval Subject: RE: DS12-34 Sundry Approval Date: Fri, 23 May 2003 13:06:28 -0500 From: "Chan, Paul (PRAt)" <¢hanpl @BP.eom> To: "'Winton Aubert'" <Winton_Aubert~admin.state.ak.us> Winton We noticed that the 12-34 and B-17 wellbore schematics have an error on the completion jewelry. The Otis HXO SSSV at 2200' should be an Otis X nipple. Can you annotate the schematics for us or should we.submit a new schematic? Sincerely > Paul Chan > Workover Engineer > BP Alaska/Wells Group > (907) 564-5254 > (907) 440-0183 (cell) > (907) 564-5510 (fax) ..... Original.Message ..... From: Winton Aubert [mailto:Winton Aubert®admin.state.ak.us] Sent: Thursday, May 22, 2003 9:58 AM To: Chan, Paul (PRA) Cc: Sarah H Palin; Randolph A Ruedrich; Daniel Seamount Subject: Re: DS12-34 Sundry Approval Paul, This confirms AOGCC's verbal approval of the DS 12-34 workover (PTD 194-137, Sundry App. No. 303-153). Conditions of approval are (1) 3500 psi BOPE test, (2) MIT is required, and (3)subsequent Form 10-404 is required. Please give the Inspectors 24 hour notice (907 659-2714) to witness the BOPE test and MIT. Winton AUbert AOGCC 793-1231 "Chan, Paul (PRA)" wrote: winton The X-17 RWO was completed much quicker than estimated, thereby~moving up the DS12-34 workover date to May 22, 2003. The Application for Sundry Approval to convert this well to injection has been submitted, would it be possible to get a verbal approval on this ApplicationF Sincerely Paul Chan Workover Engineer BP Alaska/Wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) Re: DS 12-34 Sundry Approval , ~ubject: Re: DS12-34 Sundry Approval Date: Thu, 22 May 2003 09:57:37 -0800 From: Winton Aubert <Winton_Aubert~admin.state.ak.us> Organization: AOGCC To: "Chan, Paul (PRA)" <chanpl ~BP.com> CC: Sarah H Palin <sarah_palin~admin.state.ak.us>, Randolph A Ruedrich <randy_ruedrich~admin.state.ak.us>, Daniel Seamount <dan_seamount~admin.state.ak.us> Paul, This confirms AOGCC's verbal approval of the DS 12-34 workover (PTD 194-137, Sundry App. No. 303-153). Conditions of approval are (1) 3500 psi BOPE test, (2) MIT is required, and (3) subsequent Form 10-404 is required. Please give the Inspectors 24 hour notice (907 659-2714) to witness the BOPE test and MIT. Winton Aubert AOGCC 793-1231 "Chan, Paul (PRA)" wrote: Winton The X-17 RWO was completed much quicker than estimated, thereby moving up the DS12-34 workover date to May 22, 2003. The Application for Sundry Approval to convert this well to injection has been submitted, would it be possible to get a verbal approval on this Application? Sincerely Paul Chan Workover Engineer BP Alaska/Wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 1 of I 5/22/2003 9:58 AM BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson BIvd Anchorage, Alaska 99519-6612 bp May 20, 2003 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Sundry Notice for 12-34 Conversion from Producer to WAG Injector. Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for Prudhoe Bay production well 12-34 (PTD 194-137). This request is for approval to convert this well from a producer to a WAG injection well. Well 12-34 injection will support the proposed 12-08C location, the 12-35 and 12-36 wells to the south, and any future development wells drilled in the seismic "hole" around the Deadhorse airport. A Schlumberger CBL was run on this well December 8, 1994 from 8474' to 11597', inside the 7" casing and 4-1/2" liner. A RWO scope of work and current and proposed wellbore schematics are attached. During the RWO, casing and tubing integrity will be confirmed. If you require any additional information or clarification, please contact Paul Chan at 564-5254. ~PauhChan. ~_____~~ GPB Workover Engineer Attachments {~ STATE Of ALASKA {" ~ ~"~ //~-~' /0 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~' ~/Z ~'rd/~ APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Convert to Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 632' NSL, 938' WEL, SEC. 18, T10N, R15E, UM At top of productive interval 846' NSL, 4464' WEL, SEC. 19, T10N, R15E, UM At effective depth 4600' SNL, 4656' WEL, SEC. 19, T10N, R15E, UM At total depth 4637' SNL, 4699' WEL, SEC. 19, T10N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 696667, Y '- 5930938 X = 693293, Y = 5925784 X = 693106, Y = 5925614 X = 693064, Y = 5925576 6. Datum Elevation (DF or KB) KBE = 71.35' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 12-34 9. Permit Number 194-137 /' 10. APl Number 50- 029-22515-00// 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Casing Present well condition summary Total depth: measured 11800 feet true vertical 9227 feet Effective depth: measured 11715 feet true vertical 9164 feet Length Size Structural Conductor 80' 20" Surface 3334' 9-5/8" Intermediate Production 11370' 7" Liner 2808' 4-1/2" Plugs (measured) Junk (measured) Cemented 260 sx Arcticset (Approx.) 895 sx CS III, 375 sx Class 'G' 445 sx Class 'G' 250 sx Class 'G' MD TVD 110' 110' 3365' 3227' 11395' 8933' 8992'-11800' 7181'-9227' Perforation depth: measured 11360' - 11380', 11470' - 11528' true vertical 8909' - 8923', 8986' - 9028' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8999' RECEIVED MAY 2 0 2003 Alaska 0il & las Cons, Commission Anchorage Packers and SSSV (type and measured depth) 4-1/2" Baker 'SABL-3' packer at 8944'; 4-1/2" Camco 'BAL-O' SVLN at 2189' 13. Attachments I~! DeS'~fi~tion Summary of Proposal [] Detailed Operations Program . [] BOP Sketch 14. Estimated date for corqynencing,!~peration. ~"~"'~ 115. Status of well classifications as: /~03 /{/~ ~"~'i 'Z-.7_~ ~..~0~ [] Oil [] Gas [] Suspended 16. If proposal was verba[I,.y app(oved I, ~U, A u(,I) ¢~v'~"' ' ~'/z.z../z,~o '~ Service Nb. me of approver '" Date AiSp,roved -I Contact Engineer Narne/N~ Paul Chun, 564-~2'~4 Prepared By Name/Number'. Terrie Hubble, 564-4628 17. I hereby certify tha~he f°r"FegoiqE~ FO~ and correct to the best of my knowledge [ ~'" Signed Paul Chan ~(// /~.~,,,,~ Title Drilling Engineer Date ~-'-'['~](~.~ :.:i::.'~ .".....:..: '...'.' '..'.......:. :: :.'::~' ':,;.. :: .:?:::.: ...:.: ? ..: ::.' '....:;.... ?..:;:::~::~:'...':... ::': ~:~;~.~.~.~::~.~;~:~i~:~;;~.~i~is~s~"~:~:~i1~:y~:/.' ::.:..= ..?':: :':~.:'!:.::.~: Conditions of Approval: Notify Commission so representative may witness ' Approva~ ~o. · Plug integrity ___ BOP Test X Location clearance I Mechanical Integrity Test X Subsequent form required 10- q O ~ T~c~f. ~ OI') ~-,~-~ z~ ~;)O ~,~,I I~pprovea Dy oraer of [ne L;ommission /.,,~ ~'2 '...,f..,,.~, ,-£~, n"_v3...~ ~ ~;ommissioner a e Form 10-403 Rev. 06/15/88 ..... ~./~?'"'"":'-' 17 I t\l NNF_D', JUN1t ~20E't Submit ~ Trip[ic_~. t~ ...'3 Proposed Rig Workover Procedure , 1. MIRU. ND tree. NU and test BOPE. 2. Circulate out freeze protection fluid and circulate well to clean seawater. 3. Recover 4-1/2" tubing string to top of packer.... 4. M~II and retneve Baker 7 SABL-3 packer. 5. Scrape casing to TOL at 8992' and dress 4-1/2" tie back receptacle with dressing mill. Circulate the hole clean. 6. Pressure test casing from TOL to surface with RTTS for 30 minutes. 7. Run 4-1/2" L-80 TCII premium connection tubing with 7"x 4-1/2" packer and tailpipe. Tailpipe to have tie back stem with seals. 8. Displace the IA to packer fluid and sting the tie back stem into the top of liner. Set the packer. Pressure test tubing and annulus. Freeze protect to 2200' MD. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = ' FMC WELLHEAD = ° CIVV AC~A'TOj~'= ........B~i~'C .... BF. ELEV = 'KoP'= 2i81 Max'~,ngle =' 50 @ 6568' Datum MD = 11305' Datum TVD = 8800' SS [ 9-5/8" CSG, 40#, L-80, ID = 8.835" Id 3365' IMinim,,um ID = 0.0" @ 8945' 4-1/2 DB-6 PLUG, NO KEYS OR PACKING 7" CSG, 26#, L-80, .0383 bpf, ID: 6.276" Id 7029' ITOPOF 7" CSG Id 7029' 12-34 AFETY NOTES: TxlA COMMUNICATION. COLLAPSED TBG @ 6974', 11/6/98, CATCHER SUB REMAINS BELOW COLLAPSE AREA. OA FL DROPS - 300'IMONTH. 2189' Id 4-1/2" CAM BAL-O SVLN SSSV ! NIP, SSSV OOH, ID = 3.81 GAS LIFT MANDRELS IsTI MD I T~I ~VI ~" Iv,vl~c.I .O~TI D^~ 1 __1113576133881 41 IKBG2LSl I BKP I I I 12 16753156131 45 IKBG2LSl I BK I I I318e411e925143IK~G2LSl I ~K I I I I 4 1879217034l 43 IKBG2L,SI , I B,K I I J TOP OF 4-1/2" LNR ]--~ 8992' 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.87" 4-1/2" DB-6 PLUG, NO KEYS OR PACKING 8g;~7' H4-1,2,, CAM DB-6 NO-GO NIP, ID= 3.5" 14-1/2"TBG, 12.6#,L-80,.0152bpf, ID=3.958" Id 9000' I7,' cSG' 26#' L'80, ID = 6'276" Id 11395' PERFORATION SUMMARY REF LOG: BHCA ON 11/22/94 ANGLE AT TOP PEP, F: 47 @ 11360' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 11360 - 11380 O 07/26/98 2-1/8" 4 11470- 11490 O 06/19/95 2-1/2" 8 11484 - 11514 O 03/07/95 2-1/8" 4 11508- 11528 O 06/19/95 ~d [ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" Jd 11715' ~ 11800' J · 9000' I 8984' Id4-1/2" WLEG, ID= 3.95" Id ELMD 'FY LOGGED 06/18/95 ~dFISH-(3) ARMSPRINGS F/4.50K-6 I DATE REV BY COMMENTS DATE REV BY COMMENTS 01/22/95 ORIGINAL COMPLETION 12/18/00 SlS-SLT CONVERTEDTO CANVAS 02/23/01 SlS-LG FINAL 10/26/01 RN/TP CORRECTIONS 02/06/03 ATD/TP DELETE WAIVER SAFETY NOTE PRUDHOE BAY UNIT WELL: 12-34 PERMIT No: 1941370 APl No: 50-029-22515-00 SEC 18, T10N, R15E, 4699.28' FEL & 4635.55' FNL BP Exploration (Alas ka) , 'TREE = ~ CIVV EAD = ' FMC I~'Bi"'~i'EV ":7'1" BF. EEEv = i. i'..'ii Max Angle = 50 @ 6568' Datum MD = 11305' DatUm ']'VD 8800, SS 12- 0-+ Proposed Compi 2200' [ 9-5/8" CSG, 40#, L-80, ID= 8.835" ]'--{ 3365' ~-~ 8855' 8914' -8950 -8980 I TOP OF 4-1/2" LNR Id 8992' 8992' I 4-1/2" TBG 12.6# L-80 NSCT PREMIUM THREAD Id 9000' I 7" CSG, 26#, L-80, NSCC Id 11395' PERFORATION SUMMARY REF LOG: BHCA ON 11/22/94 ANGLE AT TOP PERF: 47 @ 11360' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 11360- 11380 O 07/26/98 2-1/8" 4 11470- 11490 O 06/19/95 2-1/2" 8 11484 - 11514 O 03/07/95 2-1/8" 4 11508- 11528 O 06/19/95 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" Id 11715'I 11800,I ~ L } { 11687' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/22/95 ORIGINAL COMPLETION 12/18/00 SIS-SLT CONVERTEDTO CANVAS .... 02/23/01 SIS-LG FINAL 10/26/01 RN/TP CORRECTIONS ,,, ,, tion Id7" X 4-1/2" BAKER S-3 PKR TIE BACK STEM W/ SEALS HFISH-(3) ARM SPRINGS F/4.5 OK-6 I PRUDHOE BAY UNFF WELL: 12-34 PERMIT No: 1941370 APl No: 50-029-22515-00 SEC 18, T10N, R15E, 4699.28' FEL & 4635.55' FNL BP Exploration (Alas ka) :~-LL DA_:. Casing:., 7" Shoe: II'q% ~D {qg~ Tv-D; DV: --.= Packer {qq?. ~ T'~; Set at / '. "o~ s!~ ~-~ ~" ~ & " ; P~=~ 11~o ~o 1152f .' ~CF~2qiC~L iNTEGRITY - P&RT f! Annulus Press Test: 2P ; !5 rain ; 3 0 rain ,w~--~CH~-NiCA-L iNTEGRITY - PART ~2 Cement Voltnnes :- A~nt. Liner 2~O % ~; Csg qq5 ~.; DV Theorenical TOC Cement Bond Log (Yes or No) C~L Evaluation, zone above perf~ Production Log: T~e ; Evaluation MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~JN~ Commissioner Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday, Ma.y 7,.2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with I failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhouse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaska Oil and Gas Conservation CommisSion Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 WeB Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE 12-01 1790230 12-02 1790320 12-03 1~90410 160 150 150 P P "' OIL 12-04A 1811870' 160 '150 150 P P OIL 12-05 1790550 12-06A 1920540 160 150 150 P V OIL 12-07A 1811750 160 150 1401 P P OIL 12'08B 18116~0 1~0 150 140 P e .... OIL 12,09 1800930 ' 16~ " 150 125 ' P P OIL 12-10A 1920890 160 150 150 P P OIL 12-11 1810730 12-12 1810830 1~0 150 90 'P 4 " OIL 12-13B 1960170: 160 150 '150 P '"P OIL 12-14A 1981460 160 150 150 P P OIL i ,, 12-15 1830320 160! 1502 150 P P OIL 12-16A 1931480! '160 1501 1~0 P P OIL , , 12-17 1830040i 1601 1501 150 P P OIL 12-18 ' 1822060! 160 150i 150 P' P OIL '~2-19 '1821980! 12-20 18219101 ' 12-21 1840480 " ' , , , 12-22 1840600 160 150 125 P P OIL 12-23 1840580 12-25 1831'660 " 12-26 1840140 "'160 150 '125 e P 'OILi 'i'2-27A 1990390 " 12-28A 1990330 160 150 170 P P OIL 12-29 1840320 , , , 12-30 1881420 12-31 1890010 'i2-32 " 1890'110 160 150 150 P P " OIL ., 12-33 1890100 12-34 1941370 i60 150 150 P' P ' OIL .. 12-35 1951300 160 150 100 .. 12-36 1951580 160i 150! 150 P P OIL ., RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4~C~S Well ]'Permii'T Separ'l' '~et ]" L/p '1 "~st i,,Test ['Test 'I Date oil, WAG, Number I Number / PSI I PSI ] Trip ] Code I C°del Code / Passed GASorCYCLE Wells: 21 Components: 42 Failures: 1 Failure Rate: 2.38% [-I 90 Remarks: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS .. STATE OF ALASKA '--" ALASKA OIL AND GAS CONSERVATION COMMISSIOI, ~ APPLICATION FOR SUNDRY APPROVALS I1. Type of request AIt~ ca,~ng _ Change approved program _ Abandoo _X Suspend _ Opera,on Shutdown _ Repair wall _ Flugging _X 'lime extensio~ _ PuN lubing_ Variance_ Per[orate_ Reenter suspended wetl _ Stimulate _ Olher _ 2. Name of Operator. ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory _ St~alagrapic _ Service _ 4. Location of well at surface: 632 NSL, 938' WEL, Sec 18, T10N, R15E, UM At top of productive interval: 792' NSL, 4509' WEL, Sec 19, TION, R15E, UM At effective depth: At total depth: 644' NSL, 4681' WEL, Sec 19, TION, R15E, UM 12. Present well condition summary 6. Datum of elavation (DF or KB feet): 71'RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 12-34 9. Permit number. 94-137 10. APl number: 50-029-22515 11. Field/Pook Prudhoe Bay Oil Pool Total Depth: measured 11800 feet true vertical 9227 feet Effective Depth: measured 11499 feet true vertical 9007 feet Casing Length Size Plugs (measured) PBTD Tagged @ 11499' MD (7/23/98) _ · .... Junk(measured) Cemented Measured depth True vertical depth Conductor 80' 20" Surface 3294' 9-5/8" Production 11324' 7" Liner 2808' 4-1/2" 260 Sx Arcticset 895 Sx CS III & 375 Sx Class G 445 Sx Class G 52 bbls Class G ~edoration Depth measured 11360'- 11380'; 11470'- 11528'. true vedical 8909' - 8923'; 8986' - 9028'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 NSCT 'l"bg @ 9000' MD. 110' 110' 3365' 3231' 11395' 8933' 118.00' 9227' ORIGINAL Packers and SSSV (type and measured depth) 4-1/2" Baker SABL-3 Packer NSCT @ 8944' MD; 4-1/2" Camco Bal-O SVLN SSSV @ 2189' MD. 13. Attachments 14. Estimated datefor commencing operation Description summary of proposal _X 16. If proposal was verbally approved October, 1998 Name of approver Date approved 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed ~ Detailed operations pr~ram_ BOP sketch _X 15. Status of well classification as: Oil _X Gas _ Service Questions: Call Steve Ward at 265-1305. Suspended_ Erin Oba Title: Engineering Supervisor Date /~?-- "7- '~ F FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness Plug integrety BOP test,~ Location clearance_ OO~)~J Mechanical integrety test __ Subsequent form required 10- __t~:~7 ~I;~%~¢~(:~..,~ Original Signed By ~ Approved by order of the Commissioner David W. Johnston Commissioner Prepazed by Paul Rau/263-4990 I' pr°va' N°' Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE Objective: DS 12-34 Intended P&A Procedure P&A existing interval in preparation for CT sidetracking operations. Intended Procedure RU SL. Tag bottom. RU coiled tubing trait and tag bottom. Pump 7 bbls Class 'G', 17 ppg fibered cement. Clean cement top to-11490' md in 4-1/2" (KOP for CTU drilling at 11478') WOC, Tag top of cement. October 7, 1998 6 5 4 3 2 I 1 ! CO ! L ED TUB !NG UH ! T BOP EOU! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS! 4 1/16" PIPE RAMS ,3. ~000 PSI 4 1/6" HYD~UL~ SLIPS 4. 5000 PS! 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 4 3 · J 2 BOP EflUIPMENT 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE '. 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) ; ' ;). 5000 PS! 4 I/6" LUBRICATOR ', 4. 5000 PS! 4 1/6" FLOW TUBE PACK-OFF 1 '~ STATE OF ALASKA --, .,SKA OIL AND GAS CONSERVATION COMMIS, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate__ Plugging_ Perforate _X Pull tubing_ Alter casing_ Repair well_ Other_ 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development j~ 71' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 632 NSL, 938' WEL, Sec 18, T10N, R15E, UM 12-34 At top of productive interval: 9. Permit number/approval number: 792' NSL, 4509' WEL, Sec 19, T10N, R15E, UM 94-137 At effective depth: 10. APl number: 50-029-22515 At total depth: 11. Field/Pool: 644' NSL, 4681' WEL, Sec 19, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 11800 feet Plugs (measured) PBTD Tagged @ 11499' MD (7/23/98) true vedical 9227 feet Effective Depth: measured 11499 feet Junk (measured) true vedical 9007 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 260 Sx Arcticset 110' 110' Surface 3294' 9-5/8" 895 Sx CS 111 & 3365' 3231' 375 Sx Class G Production 11324' 7" 445 Sx Class G 11395' 8933' Liner 2808' 4-1/2" 52 bbls Class G 11800' 9227' Perforation Depth measured 11360' - 11380'; 11470' - 11528'. RECEIVED true vertical 8909'-8923'; 8986'-9028', 0CT Alaska 0ii & Gas ~ ComPri Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 NSCT Tbg @ 9000' MD. Packers and SSSV (type and measured depth) 4-1/2" Baker SABL-3 Packer NSCT @ 8944' MD; 4-1/2" Camco Bal-0 SVLN SSSV @ 2189' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) , ,~ ';~ .... Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 643 582 8888 278 Subsequent to operation 734 9168 8871 305 5. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repod of Well Operations _ Z Oil_Z Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~).d. ~ Title: Engineering Supervisor Date Erin Oba Prepared SUBMITIN DUPLICA~FE ~ Form 10-404 Rev 06/15/88 7/23/98: RIH & tagged PBTD @ 11499' SLM. 12-34 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/26/98 - 7/27/98: MIRU & PT'd equip. RIH w/perforating gun & shot 20' of Add perforations as follows: 11360'- 11380' MD (Sag) Ref. Log: BHCA 11/22/94. Used a 2-1/8" carrier & shot 2 spf, at 0° phasing, & at 90°/180o phasing. POOH w/perf gun. ASF. RD. Returned the well to production & obtained a valid well test. ,'3 c ~ ~ o 9 i c a 1 i,"i a !: e r" i' a 'l s I n v e n i: o r"i D/~.TA T DATA._F'L..LIS t~1~ I1715,-'" 94- i 3. 7 6360 94 .--- 137 S U R ',7 E \; H \q D 94 ..... 13'? E, HC/'AC/'GR 94 - 137 C E, T .... "GR/GR 94 '137 DIFL,, 94. ~-- I .37 J ',,? !... 94-'~ i ~ 7 PERF ~ ~ 9.q-~'--'f 37 F'E~.~F REC.: ~""~ 94 - t 'S 7 94..- I 3 7 SS~VD / U S I - 8600-i1595 11347~'i i64-8 .J~-"'i 1280'- 1 1590 I i304'--, i t778 8474~-1 '159'1 ,..., r" e d r" y c.~ i t c h rs a rlxp 'i e ss r'e q u. ',,.,t a s i: h e v,; e i i c o r' e d '2 y e s ~.__~, n a 'i y s i s a: d e s c r' i p t 'i o n r" e c e 'i' v ,.'-} d '2 STATE OF ALASKA -- ALASK,~---iL AND GAS CONSERVATION CL ~MISSION REPORT OF SUNDRY WELL OPERATIONS .. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage', AK 99510-0360 4. Location of well at surface 632' NSL, 938' WEL, Sec 18, T1 ON, R15E, UM. At top of productive interval 792' NSL, 4509' WEL, Sec 19, T10N, R15E, UM. At effective depth At total depth 644' NSL, 4681' WEL, Sec 19, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-34 9. Permit number/approval number 94-137 10. APl number 50 - 029-22515 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11800 feet 9227 feet Plugs(measured) Fill Cleanout to 11650' MD (2/26/96). Effective depth: measured 11650 feet true vertical 9116 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 260 Sx Arcticset 110' 110' Surface 3294' 9-5/8" 895 Sx CS III 8, 375 Sx G 3365' 3231' Production 11324' 7" 445 Sx G 11395' 8933' Liner 2808' 4-1/2" Class G 11800' 9227' Perforation depth: measured 11470 - 11528' true vertical 8986 - 9028' Tubing (size, grade, and measured depth) 4~1/2", 12.6#, L-80, NSCT Tubing @ 9000' MD. Packers and SSSV (type and measured depth)Baker SABL-3 Packer @ 8944' M D; CamcL)l?lT~. CLiV~),~. ~ 89' M D. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached MAR 2 0 199G 14. Treatment description including volumes used and final pressure Alaska 011 & gab Ct}ns. Commission Anchorage Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 321 665 65 -- 306 Subsequent to operation 877 416 2311 -- 317 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~'~ ~1/~. (X~. Title Engineering Supervisor Form 10-404 Rev 06/15/88 I,,(' ~ IE ~-r,. P, AID Date 3-//~-¢~ SUBMIT IN DUPLICATE 12-34 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE TREATMENT OF ZONE 4 2/1/96' RIH & tagged PBTD at 11507' MD. 2/18/96' RIH w/dump bailer & dumped 70 lbs of sand on top of fill to spot a sand plug to 11498' MD. 2/25/96' Performed a Zone 4 Hydraulic Refracture Treatment as follows: MIRU & PT equipment to 9000 psi. Pumped the Refracture Treatment through the open perforations located above the sand plug at: 11470 - 11528' MD (Z4' partly sand covered) Pumped: a) b) Resumed c) d) Ref. Log' BHCA 250 bbls Pre Pad Gel @ 26 - 30 bpm, followed by Shutdown. ISI P @ 2175. pumping Datafrac: 400 bbls Crosslinked Gel @ 15 - 31 bpm, followed by 64 bbls Scour Stage w/1 ppg proppant @ 30 bpm, followed by e) 283 bbls Flush _@ 30 bpm, followed by f) Shutdown. ISIP @ 1350. Resumed pumping Fracture Treatment: 11/22/94. g) 200 bbls Crosslinked Pad @ 30 bpm, followed by h) 632 bbls Crosslinked Slurry w/proppant concentrations @ 2 - 10 ppg, followed by i) 170 bbls Gelled Flush @ 5 - 30 bpm, followed by j) Shutdown. ISlP @ 2175. Placed a total of 92,500 lbs of proppant into the formation. Rigged down. 2/26/96 · RIH w/CT & jetted a proppant fill cleanout w/biozan from 11105' to 11650' MD. Placed the well on production w/gas lift & obtained a valid welltest. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9566 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 7/1 1/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-22 ~ ~ I ~_~ PERF RECORD 950618 I I " D.S. 3-24 ~, ~ ~ %c~ IBPSETr~.NGRECORD 95..0.621 I 1 D.S. 4-48 ~' (- i ~ (3-/ PROD PROFILE 9 5 0 6 2 2 1 1 ........ D.S. 6-14A c~ ,)_ -,j"-~ PRODLOG 950623 I 1 D.S. 7-06 -/'~ ! ~ PERF RECORD 95061 9 I 1 D..S. 9-16 ~ ~ 3"7' PERF.REC0.R.D 950620 1 1 D.S. 12-34 ~'l I , ,~ --3 JEWELRYLOG COLLAR LOCATOR 950619 I 1 .... D.S. 12734 I '~.1 [ ') I PERFRECORD 950619.. 1 1 iD:.s. 13-1 '7? ~ O BAKER INFLAT BRIDGE PLUG 950623 I 1 D.S. 17-05 ~. ~j (~ IBP SETrlNG RECORD 95.0618. . 1 1 ,, , , ..... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED . . DATE: ~tli ~ I995 Alaska Oil & G~s Cons. Commission STATE OF ALASKA _, ALASKA ~' AND GAS CONSERVATION CC llSSION REPORT L,r: SUNDRY WELL OPEdATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 632' NSL, 938' WEL, Sec. 18, T10N, R15E, UM. At top of productive interval 792' NSL, 4509' WEL, Sec. 19, T10N, R15E, UM. At effective depth At total depth 644' NSL, 4681' WEL, Sec. 19, T10N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Pr_udh~e Bay Unit 8. '"W~¢r~ .m be r 12-34 ? 9. Permit"ndrrf6..,er/approval''>' number 94-137 10. APl number~ 50 - 029-2251.5 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11800 feet Plugs(measured) 9227 feet Effective depth: measured 11715 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 260 sx Arcticset 110' 110' Surface 3294' 9-5/8" 895 sx CS III & 375 sx G 3365' 3231' Production 11324' 7" 445 sx G 11395' 8933' Liner 2808' 4-1/2" Class G 11800' 9227' Perforation depth: measured 11484-11514' true vertical 8996-9018' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, NSCT Tubing Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8944' MD; Camco BaI-O SLVN SSSV @ 2189' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 841 1008 0 Tubing Pressure - 305 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Engineering Supervisor hiornm]0-404 Rev 06/15/88 r,r,. If7 .IWP Date ~'/°~/~'- SUBMIT IN DUPLICATE 12-34 DESCRIPTION OF WORK COMPLETED INITIAL ROPE PERFORATIONS & HYDRAULIC FRACTURE TREATMENTS OF ZONE 4 3/7/95: Shot Initial ROPE Perforations: 11484- 11514' MD (Z4) Ref. Log: BHCA 11/22/94. Ran 2-1/2" carrier into position, then pumped 283 Mscf N2 & shot 4 spf at 180 degree phasing with 7609 psi on the well for ROPE perforations. POOH w/perf gun. Rigged down. 4/1 8/95: Performed a Hydraulic Fracture Treatment as follows: MIRU & PT equipment to 7500 psi. Pumped the Fracture Treatment using 16/20 mesh proppant, through the open perforations (listed above). Pumped Datafrac #1 consisting of 250 bbls 20# Pre Pad Gel @ 10 - 20 bpm, followed by Shutdown. ISIP @ 2250. Resumed pumping Datafrac #1, consisting of 53 bbls 30# Crosslinked Gel @ 15 bpm, followed by 170 bbls 30# Flush @ 5 - 15 bpm, followed by Shutdown. ISlP @ 2410. Resumed pumping Datafrac #2, consisting of 35 bbls 30# Crosslinked Gel @ 15 bpm, followed by 170 bbls 30# Flush @ 5 - 15 bpm, followed by Shutdown. ISlP @ 2465. Resumed pumping Fracture Treatment consisting of 15 bbls 30# Crosslinked Pad @ 15 bpm, followed by 140 bbls Crosslinked Slurry w/proppant concentrations @ 2 - 10 ppg, followed by 53 bbls 20# Gelled Flush, followed by Shutdown. Placed a total of 2,200 lbs of proppant into the formation. 4/21/95 & 4/23/95: RIH w/CT & jetted proppant fill cleanouts to 11699' MD. 4/24/95: Reperforated: 11484- Rigged down. 11514' MD (Z4) Ref. Log: BHCA RECEIVED JUN 1 $ !9°~5 &t~,.¢(a 0il & Gas Cons. Commission Anchor: ' 11/22/94. POOH w/perforation gun, then performed a Hydraulic Refracture Treatment as follows: MIRU & PT equipment. Pumped the Refracture Treatment using 20/40 mesh proppant, through the perforations (above). Pumped 25 bbls Xylene @ 1 - 5 bpm for asphaltene removal, then continued pumping 250 bbls 20# Pre Pad Gel @ 15 - 25 bpm, followed by Shutdown. ISIP @ 1850. Pumped Datafrac consisting of 53 bbls 30# Crosslinked Gel @ 20 bpm, followed by 175 bbls 30# Gelled Flush @ 5 - 20 bpm, followed by Shutdown. Resumed pumping Fracture Treatment consisting of 50 bbls 30# Crosslinked Pad @ 20 - 25 bpm, followed by 157 bbls Crosslinked Slurry w/proppant concentrations @ 1 - 10 ppg, followed by Shutdown. Placed a total of 19,400 lbs of proppant into the formation. Rigged down. 4/25/95 & 5115195: RIH w/CT & jetted proppant fill cleanouts to 11715' MD. Placed the well on production w/gas lift & obtained a valid welltest. I Schlumberqer I GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9463 Company: 5/12/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job # Log Description Date BL Prudhoe Bay Floppy RF Sepia DIR MWD Disk D.S. 2-18 ~-'c~ ~ CNT-D 042595 1 1 D.S. 3-19 ~,~ ._c]~... PERFRECORD 042095 I , 1 D.S. 5-6. (31-6-10-15) -~5-50 PROD PROFILE 042095 I 1 D.S. 6-04 ~ ~-- ~c~. DUAL BURST TDT-P 042095 I 1 D.S. 7-3 "7 ;~-" /~ GCT ,, 042695 I 1 D.S. 9-30 ST1'' ¢5 '- I ~Z/rPERF RECORD 042495 .".'i 1 D.S. 12-21 ~ 41/- L~' PERF RECORD 0426 95 I 1 D.S. 12-34 ~z./..-/~'7 PERFRECORD 042495 I 1 D.S. 16-1 ~)- {3 ~ PERFREC0RD 042395 I " 1 D.S. 17-15 (~o~-,/~) PERFRECORD 042595 1 I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ~x~ ' - [¢,~,( t'5 !995 ~as~ Oil & G~s C~s. Oom~ssion GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9366 Company: 3/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Well Job # Log Description Field: Prudhoe Bay Floppy Date BL RF Sepia DIR MWD Disk ~/DW 2-1 'STATIC TEMP-INJ PROF 031795 I 1 O.S. 02-13 !POGLM SE'ri'lNG RECORD 031 095 I 1 D.S. 03-09 PERF RECORD 031 095 I 1 D.S. 3-29 PERF RECORD 031895 I 1 D.S. 4-12 TUBG PUNCHER RECORD 030395 I 1 D.S. 4-38 TUBG CUTI'ER RECORD 031 695 I 1 D.S. 7-18 PROD PROFILE 030495 1 1 D.S. 11-27 BASELINE TEMP 031795 I 1 D.S. 12-14 ST1 PERFRECORD 030495 1 1 D.S. 12-34 ROPE PERF REC/FLD DET 030795 1 1 D.S. 16-13 PROD PROFILE 030695' I 1 D.S. 16-27 PERFRECORD 031 895 I 1 'D.S. 1-22A 95049 DUAL BURSTTDT-P 020395 1 D.S. 4-37 95037 CNTD 01 2095 I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED MAH a 1 1995 ~ _ Alaska Oil & Gas Cons. Commissi.on Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVl. 2. Name of Operator - . 7. Permit Number ARCO Alaska, Inc. ~ } 94-137 3. Address.."~ ~"% "~"'%f 8. APl Number P. O. Box 196612, Anchora~le, Alaska 99519-6612 50- 029-22515 4. Location ofwellat surface ~ ~ ......... K~/,,.~,,r,~ ~ ~,1~, 9. Unit or Lease Name i' '.;¥ -:,:'~ i~ ; :,~: ;i-"~ Prudhoe Bay Unit 632' NSL, 938' WEL, SEC. 18, TION, R15E ,~,.....,-,.. 10. Well Number At Top Produc' g te ;.-. 792' NSL, 4509' WEL, SEC. 19, TION, R15E '.'~i!~_~ '~ ..... ' '-fl 12-34 At Tota Depth .- ~1 ~¢~-.~._. ...... '~-~,~, ,'~ 0ii & Gas Co~. Co~mt$~to ~ 1. Field and Pool ...... ' ~fiCh0ff2 !, ..,~"!~] .....,, Prudhoe Bay Field/Prudhoe Bay Pool 644' NSL, 4681' WEL, SEC. 19, TION, R15E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ' KBE = 71.35' I ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 10/30/94 11/21/94 3/7/95I N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11800'MD/9227' TVD 11715'MD/9165' TVD YES [] NO []I 2189' feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run GPEBHCS/DIL 123. CASING, LINER AND CEMENTING RECORD SE-f-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FFOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.51/ H-40 30' 110' 30" 260 sx Arcticset (Approx.) 9-5/8" 401/ L-80 31' 3365' 12-1/4" 895 sx CS 111/375 sx "G" 7" 261/ L-80 25' 11395' 8-1/2" 445 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD) Gun Diameter 2-1/2" 4 spf 4-1/2", L-80 8999' 8944' MD TVD 11484'-11514' 8996'-9018' 26. ACID, FRACTURE, CEMENT SQUEF7E, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/21/95 Gas Lift Date of Test Hours Tested fEsTPRODUCTIONpERIOD FORi~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,.¢. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 11350' 8832' Shublik 11382' 8854' Sadlerochit 11468' 8913' 31. LIST OF A'FI'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. 'f~ ~ Title DrillingEngineerSupervisor Date ~,~///~'¢'fI~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 : If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28; If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 12-34I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/29/94 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: 10/30/94 (1) TD: 110'( 0) 10/31/94 ( 2) TD: 359' ( 249) 11/01/94 ( 3) TD: 1570' (1211) MIXING SPUD MUD MW: 0.0 VIS: 0 MOVE RIG AROUND PIT WITH DERRICK UP FROM WELL DS 12-07A TO WELL DS 12-24I, SPOT RIG OVER NEW WELL, SPOT IN PITS AND CAMP. LEVEL UP AND SHIM RIG OVER WELL. NIPPLE UP DIVERTER SYSTEM, MODIFY 20" RISER & DRIP PAN. TIME CHANGE. N/U FLOW LINE & 20" RISER, HOOK UP DIVERTER LINES, TAKE ON WATER IN PITS. MIX SPUD MUD, CONTINUE NIPPLE UP DIVERTER SYSTEM, P/U DRLG TOOLS. WORK ON CONVEYOR MW: 0.0 VIS: 0 MIX SPUD MUD, WORK ON DIVERTER SYSTEM. M/U 12 1/4" BIT & DRILL COLLARS. FUNCTION TEST DIVERTER SYSTEM,. M/U 10 3/4" X 20" FMC CSG HGR ON L/D JT, RUN HGR THRU 20" RISER TO INSURE NO ID RESTRICTIONS, LANDED HGR IN LANDING RING @ 29.55' BRKB. CONTINUE M/U BHA, RIH TAG BTM CONDUCTOR @ 110' BRKB, M/U KELLY. FILL HOLE AND SYSTEM WITH SPUD MUD, VALVE CONTINUES TO LEAK, CHANGE OUT VALVE, CIRC WITH SPUD MUD, VALVE HOLDING OK. SPUD IN WELL, DRILL 122', FLOW LINE PLUGGED OFF WITH LARGE PIECES OF PLASTIC FROM INSIDE CONDUCTOR, PACKER OFF POSSUM BELLY @ SHAKERS. CLEAN PLASTIC OUT OF COMPLETE FLOW LINE SYSTEM AND LINES. DRILL FROM 122 - 151', CONVEYOR SYSTEM PLUGGED OFF, CLEAN OUT GRAVEL. DRILL F/ 151 - 309', CONVEYOR SUSTEM PLUGGED OFF. CLEAN OUT CONVEYOR SYSTEM, REPLACE BELT DRIVE. DRILL F/ 309 - 339', CONVEYOR SYSTEM PLUGGED OFF. CLEAN OUT CONVEYOR SYSTEM, WORK ON BELT DRIVE SYSTEM. DRILL F/ 339 - 359', CONVEYOR SYSTEM PLUGGED OFF. CLEAN OUT CONVEYOR SYSTEM, WILL ATTEMPT TO TIME DRILL @ SLOWER FLOW RATES, CURRENT CONVEYOR SYSTEM CANNOT HANDLE OUTPUT OF DUAL SHAKERS. DRILLING MW: 0.0 VIS: 0 CIRC BTTMS UP TO CLEAN UP HOLE. DRILL 12 1/4" OPEN HOLE FROM 359 - 639' WITH REDUCED PUMP RATES. CONVEYOR PLUGGED OFF WITH CUTTINGS, WORK ON CONVEYOR, ADD 5 MORE PADDLES, REPAIR SPROCKET ON DRIVE MOTOR, ADJUST DRIVE CHAIN. DRILL 12 1/4" OPEN HOLE FROM 639 - 1505', NO PROBLEMS WITH CONVEYOR. BEGAN KICKOFF @ 1505', ORIENT MOTOR AND SLIDE, DRILL AHEAD @ 1570'. Cons. Commission Anchor~ '" WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 2 11/02/94 ( 4) TD: 3375'(1805) 11/03/94 ( 5) TD: 3375' ( 0) 11/04/94 ( 6) TD: 3375' ( 0) 11/05/94 ( 7) TD: 3912'( 537) CIRC BTTMS UP MW: 0.0 VIS: 0 DRILL 12 1/4" OPEN HOLE FROM 1570' TO TD 12 1/4" SURFACE HOLE @ 3375', NO CONVEYOR PROBLEMS, HOLE IN GOOD CONDITION. CIRC BTTMS UP, PREPARE FOR SHORT TRIP TO HWDP. RUNNING 9 5/8" CSG MW: 0.0 VIS: 0 CBU. SHORT TRIPPED TO 835'. HOLE TIGHT F/ 2650 - 2050'. PU KELLY @ 2475' AND 2050' TO WORK THRU TIGHT SPOTS. RIH, PU KELLY AND REAMED F/ 2289 - 2342' AND AT AGAIN AT 2643'. CIRCULATED HOLE CLEAN. MU AND DROPPED TANDEM SURVEYS. POH F/ CSG. HOLE FILL NORMAL. SLM, NO CORRECTION. LD BHA #1 AND CLEARED FLOOR. RU NCS. RUNNING 9 5/8" 40# BTC L-80 CASING, 66 JTS IN GROUND. TESTING BOPE MW: 0.0 VIS: 0 FINISHED RUNNING 9 5/8" 40# L-80 CASING. RAN TOTAL OF 87 JOINTS. MU HANGER AND LANDING JT, LANDED CASING AND MU CEMENT HEAD. BROKE CIRCULATION AND BEGAN RECIPROCATING, INCREASED RATE TO 12 BPM W/ FULL RETURNS. CONDITIONED MUD F/ 2 FULL ANNULAR VOLUMES. PUMPED 5 BBLS WATER, PRESSURE TESTED LINES, PUMPED 45 BBLS WATER, DROPPED BOTTOM PLUG, PUMPED 306 BBLS (895 SX) CS III + 34#/200SX R-7, 77 BBLS (375 SX) CLASS G + 2% A-7 + 1 GHS FP-6L. DROPPED TOP PLUG AND KICKED OUT W/ 15 BBLS WATER, DISPLACED W/ RIG PUMPS @ 13.5 BPM. BUMPED PLUG ON CALCULATED STROKES TO 2000 PSI. RECIPROCATED THROUGHOUT JOB, W/ FULL RETURNS. SOME CONTAMINATED RETURNS SEEN AT SURFACE. RELEASED PRESSURE, FLOATS HELD. PERFORMED TOP JOB W/ 47 BBLS CS II. RD BJ, NCS, CLEARED FLOOR. ND DIVERTER, NU SPLIT SPEEDHEAD, NU BOPE. BEGAN BOPE TEST. DRILLING MW: 0.0 VIS: 0 CONTINUED STATE BOPE TEST. KILL LINE HCR FAILED, REPLACED SAME. CONDUCTED D4 DRILL AS PART OF TEST. INSTALLED WEAR RING, MU BHA #2. BEGAN FLOW TEST, FLOWLINE LEAKING. CHANGED OUT AIR BOOT ON FLOWLINE. FLOW TESTED MWD AND MOTOR, MU NEW BIT AND RIH W/ BHA #2. SLIPPED AND CUT DRLG LINE. RIH. TAGGED FLOAT COLLAR AT 3285' TESTED CASING. NO LOSS. HELD BOP SAFETY MEETING. PERFORMED D2 AND D5 BOP DRILLS. DRILLED FLOAT EQUIPMENT + 10' NEW HOLE TO 3385' CIRCULATED AND CONDITIONED MUD TO 9.2 PPG. PERFORMED LOT; LEAKOFF @ 600 PSI. DRILLED F/ 3385 - 3912'. RECEIVED MAR 28 1995 A!ssk~ 0il & Gas Cons. Commission Anchors." WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 3 11/06/94 ( 8) TD: 5783' (1871) 11/07/94 ( 9) TD: 6544' ( 761) 11/08/94 (10) TD: 7704' (1160) 11/09/94 (11) TD: 8429' ( 725) 11/10/94 (12) TD: 9775' (1346) CIRCULATING KWM MW: 0.0 VIS: 0 DRILLED F/ 3912 - 4286'. CBU. SHORT TRIPPED 10 STANDS TO SHOE. 25K# MAX DRAG, SLIGHT SWABBING. WIPED CLEAN. DRILLED F/ 4286 - 5449'. CBU. SHORT TRIPPED 12 STANDS TO 4286'. SLIGHT SWABBING. DRILLED F/ 5449 - 5783'. INCREASE IN RETURNS WHILE DRILLING, CHECKED F/ FLOW, WELL FLOWING. SHUT WELL IN. PIT GAIN NIL, EST @ 1 BBL. BEGAN CIRCULATING. WILL CIRCULATE UNTIL MW BALANCED @ 10.0 PPG AND EVALUATE WELL PRESSURES AT THAT POINT. DRILLING MW: 0.0 VIS: 0 CIRCULATED 10.0 KWM, BACKPRESSURE ON CHOKE. MW IN 10.0, MW OUT 10.0, CLOSED IN WELL AND OBSERVES. OPENED WELL AND OBSERVED, NO FLOW. DRILLED F/ 5783 - 5793', PR LOW. CIRCULATED HOLE CLEAN. DROPPED ESS. MADE 1 STAND CHECK TRIP. OBSERVED WELL EVEY 5 STANDS, HOLE FILL UP NORMAL, WELL STABLE, NO HOLE PROBLEMS. CBU. NO CONTAMINATION AT BOTTOMS UP, SOME COAL OVER SHAKERS, PROBABLE SOURCE OF PRIOR GAS CUTTING. CIRCULATED UNTIL SHAKERS CLEAN. PUMPED DRY. JOB. POH F/ NEW BIT. MONITORED WELL EVERY 5 STANDS, WELL STABLE. MONITORED WELL, WELL STABLE. HOLE FILL UP NORMAL. NO EXCESS DRAG IN OH. CHANGED OUT BITS, MWD TOOL. SURVEY BENCHMARK AND MWD MATCHED. SERVICED WEAR BUSHING. RIH. WASHED F/ 5750 - 5793', NO FILL ON BOTTOM. TOOK BENCHMARK SURVEY @ 5688' AND 5719', NEW MWD TOOL MATCHES BENCHMARK. DRILLED F/ 5793 - 6544'. DRILLING MW: 0.0 VIS: 0 DRILLED F/ 6544 - 7200'_ CIRCULATED HOLE CLEAN. SHORT TRIPPED 15 STANDS TO 5750' MAX DRAG 20K, HOLE FILL UP NORMAL, WELL STABLE. DRILLED F/ 7200 - 7704'. DRILLING MW: 0.0 VIS: 0 DRILLED F/ 7704 - 7767'. CIRCULATED HOLE CLEAN. POH. 30K# MAX DRAG IN OH, HOLE FILL UP NORMAL. MONITORED WELL @ SHOE. LD BHA #3, MU BHA #4. PU DUAL POWER HEAD MOTOR AND BUMPER SUB, PDC BIT. SERVICED WEAR RING. SLIPPED DRILLING LINE. RIH TO 5766', TOOK BENCHMARK SURVEY, RIH TO 7697', PU KELLY AND WASHED TO 7767' NO FILL ON BOTTOM, NO EXCESS DRAG. DRILLED F/ 7767 - 842~'. DRILLING MW: 0.0 VIS: 0 DRILLED F/ 8429 - 9021'_ CIRCULATED HOLE CLEAN. SHORT TRIPPED 13 STANDS TO 7750'. HOLE FILL UP NORMAL, EXCESS DRAG 20K# MAX. DRILLED F/ 9021 - 9775' BIT @ K-5 MARKER. RECEIVED MAR 28 1995 ~ska Oil & Gas Cons. Commission Anchor~ WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 4 11/11/94 (13) TD:10051' ( 276) 11/12/94 (14) TD:10366' ( 315) 11/13/94 (15) TD:10622' ( 256) 11/14/94 (16) TD:10849' ( 227) CUTTING DRILLING LINE MW: 0.0 VIS: 0 DRILLED F/ 9775 - 10051'. PR DECREASED AS BIT DRILLED BELOW K-5. REQUIRED 30K# WOB TO DRILL 30 - 35 FPH, DECISION MADE TO PULL BIT. CIRCULATED HOLE CLEAN, PUMPED DRY JOB, BLEW DOWN KELLY. MONITORED WELL, WELL STABLE. POH. 15K# DRAG IN OH, HOLE FILL UP NORMAL. MONITORED @ SHOE, WELL STABLE. LD BHA #4, MU BHA #5, CHANGED OUT MWD TOOLS, FLOW CHECKED SYSTEM. PULLED WEAR RING, PERFORMED STATE BOPE TEST. SERVICED AND INSTALLED WEAR RING. RIH. SLIPPED AND CUT DRILLING LINE. POH MW: 0.0 VIS: 0 SLIPPED AND CUT DRILLING LINE. RIH, REAMED 60' TO BOTTOM (PRECAUTION). BENCHMARKED MWD @ 5756'. DRILLED F/ 10051 - 10366'. PR ERRATIC AND LOW, MAX 50 FPH, MIN 20 FPH. TOOK STEPS TO ELIMINATE BIT BALLING W/ MARGINAL SUCCESS. PR DOWN TO 10 FPH. INCLINATION DROPPING. CIRCULATED AND CONDITIONED MUD. PUMPED DRY JOB. BLEW DOWN KELLY. WELL STABLE. POH. OH IN GOOD CONDITION, HOLE FILL UP NORMAL. DRILLING MW: 0.0 VIS: 0 POH. HOLE FILL UP NORMAL. LD BHA #5, MU BHA #6. SERVICED MWD, WEAR BUSHING. RIH AND FLOW CHECKED MWD. RIH. BENCHMARKED MWD AT 5726' OH IN GOOD CONDITION. REAMED F/ 10299 - 10360'. WASHED DOWN F/ 10360 - 10366'' TO CLEAN UP JUNK, 3X. TAGGED BOTTOM AT 10366' AND ROTATED @ 40 RPM, REPEATED SAME. DRILLED F/ 10366 - 10559'. SWIVEL PACKING LEAKING. STOOD BACK KELLY, MU SAFETY VALVE, CIRCULATED AND RECIPROCATED WHILE REPLACING SWIVEL PACKING. DRILLED F/ 10559 - 10622' DRILLING MW: 0.0 VIS: 0 DRILLED F/ 10622 - 10823'. BIT BEGAN 7 DEGREE/100 RH WALK. CIRCULATED HOLE CLEAN AND CONDITIONED MUD. PUMPED DRY JOB AND MONITORED WELL. POH. 25 - 40K# DRAG F/ 10800 - 10400' HOLE FILL UP NORMAL. LD BHA #6, MU BHA #7. ENPTIED BOOT BASKET, NO JUNK. SERVICED WEAR RING, FLOW CHECKED MWD AND MOTOR. RIH. SLIPPED DRILLING LINE, MAD EVISUAL CHECK ON DRAW WORKS CHAINS. RIH, BENCHMARKED MWD @ 5752', REAMED F/ 10780 - 10823'. DRILLED F/ 10823 - 10849' RECEIVED ~aAR 28 199b ~i~3ka ,.~ii & 6as 6ons. 6~mmissior' Anchor2 WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 5 11/15/94 (17) TD:l1409'( 560) 11/16/94 (18) TD:l1409' ( 0) 11/17/94 (19) TD:l1409' ( 0) 11/18/94 (20) TD:l1409' ( 0) MONITORING WELL MW: 0.0 VIS: 0 DRILLED F/ 10849 - 11409' ORIENTING 90 DEGREE LHS TO MAINTAIN AZIMUTH. LOST RETURNS. BIT IN SHUBLIK BASED ON PROGNOSIS, ZONE 4 BASED ON ROP. MONITORED WELL, PUMPING 1 BPM DOWN DP, KEEPING TOPSIDE FILLED F/ TRIP TANK. LOSS RATE 1 TO 1 1/2 BPM. MIXED AND PUMPED 50 BBL LCM PILL, DISPLACED W/ PARTAIL RETURNS @ 4.5 BPM. LOST 130 BBLS. POH 10 STANDS, LOST 2.5 BBLS ABOVE NORMAL HOLE FILL UP. MONITOR WELL CIRCULATING @ 1 BPM. INTAIL LOSS RATE 9 BPH, DECREASED TO 0 BPH AFTER 10 MINUTES. INCREASED CIRCULATION RATE TO 2 BPM, LOSS RATE @ 6 BPH. REDUCED CIRCULATION RATE TO 1 BPM, WILL CONTINUE TO MONITOR WELL AND ALLOW LOSS ZONE TO HEAL. WASH/REAM MW: 0.0 VIS: 0 CIRCULATED AND MONITORED WELL, NO LOSS. INCREASED PUMPS TO 5 BPM, NO LOSS. RIH TO 10617, SPOTTED 50 BBLS LCM PILL. POH 10 STANDS. MONITORED WELL, WELL STABLE. POH, LD 27 JTS DP. MONITORED WELL @ SHOE, WELL STABLE, LOST 11 BBLS ON TRIP. LD BHA #7, MU BHA #8. SERVICED WEAR BUSHING. RIH, PU 22 JTS E DP. SLIPPED AND CUT DRILLING LINE. RIH, HIT BRIDGE @ 10807'. PU KELLY AND BEGAN REAMING, HOLE PACKED OFF AND STUCK PIPE, JARRED FREE. CIRCULATED AND CONDITIONED MUD. REAMED TO 10930', HOLE PACKED OFF AND STUCK AGAIN, JARRED FREE. LCM AND FINE SHALE OVER SHAKERS. RESUMED REAMING, 11099' NO LOSSES TO HOLE WHILE REAMING. CHANGE TOP RAMS T/7" MW: 0.0 VIS: 0 NO STOP CARDS. FIRE DRILLS ON RIG HELD F/BOTH CREWS WASH & REAM T/BTTM F/11099 T/11409, HOLE PACKING OFF. SLOW PUMP RATE. CBU, PUMP HI/LO VIS SWEEP T/CLEAN UP HOLE. POOH 20 STNDS SHORT TRIP. NORMAL HOLE DRAG. HOLE GOOD. CIRC & COND HOLE TO RUN CASG. PUMP HI/LO VIS SWEEP T/CLEAN HOLE. POOH & LD DP, BREAK KELLY & POOH T/RUN 7" CASG. LD BHA & BIT. PULL WEAR RING, INSTALL TEST PLUG, OPEN TOP RAM DOORS, CHANGE RAMS T/7" RIH W/ 7" CASING MW: 0.0 VIS: 0 RUN IN TEST JT, TEST DOOR SEALS, PULL TEST JT AND TEST PLUG. M/U 7" FLOAT SHOE, RUN 2 JTS 7" CSG, M/U 7" FLOAT COLLAR, RIH WITH 7" CSG, SLOW CLEAN, STRAP AND DRIFT CSG ON THE TUN, WELL STABLE. WELL TAKING FLUID WITH CSG SHOE @ 6200', CIRC CSG WITH 50% RETURNS. WELL TAKING FLUID @ 90 BPH WHILE CIRC, STOP CIRC, OBSERVE WELL. HOLE TAKING FLUID @ 25 BPH, KEEPING HOLE FULL, BUILDING SURFACE VOL. CONT TO RIH WITH 7" CSG, SLOW, WELL TAKING FLUID @ 25 BPH. RECEIVED MAr{ 26 ]99b /,.t.~sim. (.iii & Gas Cons. Commission Anchor2 WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 6 11/19/94 (21) TD:l1409' ( 0) 11/20/94 (22) TD:l1481' ( 72) 11/21/94 (23) TD:l1760' ( 279) 11/22/94 (24) TD:ll800' ( 40) RIH, P/U 3 1/2" DP MW: 0.0 VIS: 0 RUN 7" CSG SLOW, WELL TAKING FLUID @ 25-30 BPH. M/U 7 5/8" CSG HGR AND 7 5/8" LANDING JT, LAND CSG IN WELLHEAD, R/U CEMENTING HEAD. BREAK CIRC VERY SLOW, CIRC @ 3PBM WITH PARTIAL RETURNS. PUMP 5 BBLS H20, TEST LINES. DROP TOP PLUG, DISPLACE CMT WITH 428 BBLS MUD, BUMP PLUG WITH 3000#. FLOATS HELD, LOST 368 BBLS MUD WHILE DISPLACING CMT, HAD 60 BBLS MUD RETURNS. BEFORE BUMPING PLUG PLUG SLOW PUMP DOWN TO 30 SPM TO OBSERVE 1500 DIFF PRESS. EST TOP OF CMT @ 9440'. RAN 279 JTS 7" 26# L-80 CSG. R/D CMT HEAD, B/O AND L/D LANDING JT, CLEAR FLOOR CSG RUNNING TOOLS. SET 7 5/8" FMC PACKOFF BUSHING, RILDS, TEST. L/D PORT. CHANGE TOP RAMS FROM 7" TO 3 1/2" X 6" VARIABLES. CHANGE OUT KELLY TO 3 1/2" HEX. TEST BOPE, LOW-HI PRESSURE TEST. M/U 6" BIT AND BHA, RIH, P/U 3 1/2" DRILL PIPE FROM PIPE SHED, THAW, STRAP. CLEAN AND DRIFT 3 1/2" DRILL PIPE ON THE RUN, EACH JT DRILL PIPE PACKED FULL OF SNOW. DRILLING MW: 0.0 VIS: 0 TRIP IN HOLE W/ 3.5" DP STEAM, STRAP AND RABBIT PIPE. BREAK CIRC. CIRC AND CONDITION MUD TO 8.8 PPG @ 7.4 BPM. TEST CSG TO 4000 PSI, OK. HELD D-1 BOP DRILL. DRILL COMPLETE. CLEAN OUT CMT TO FLOAT COLLAR @ 11245', DRILL CMT TO SHOE. DRILL SHOE CLEAN OUT TO BOTTOM PACKING OFF AND VERY TIGHT. DRILLING F/ 11409 - 11481'. TRIP OUT W/ LOGGING TOOL MW: 0.0 VIS: 0 DRILLING F/ 11481 - 11760'. CIRC BOTTOMS UP. SHORT TRIP TO SHOE. TIGHT BELOW SHOE. CIRC SWEEP AROUND. SHORT TRIP TO SHOE. DROP SPERRY SUN SURVEY. TRIP OUT. SLM 8" SHT. RIG UP ATLAS WIRELINE. RUN #I/D.I.F.L. - AC-CN-GR- TEMP TOOL. SHOE WLM @ 11310;. TOOL STOPPED @ 11349'. LOGGING W/ ATLAS WIRELINE MW: 0.0 VIS: 0 RIG DOWN ATLAS WIRELINE. TRIP IN HOLE. SLIP AND CUT DRLG LINE. TRIP IN HOLE TAG BRIDGE @ 11377' PU KELLY WASH AND REAM F/ 11377 - 11385' RIH TO 11450'. TAGGED MORE FILL. KELLY UP, WASH AND REAM TO 11760' DRILLED F/ 11760 - 11800' CIRC BOTTOMS UP AND WORK PIPE. SHORT TRIP TO SHOE. NORMAL DRAG, NO PROBLEMS. CIRC SWEEP AROUND AND WORK PIPE. DROP SPERRY SUN SURVEY. TRIP OUT TO LOG. RIG UP ATLAS WIRLINE. LOGGING W/ W-L M.U DIFL AC GR TEMP TOOL. WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 7 11/23/94 (25) TD:ll800' ( 0) 11/24/94 (26) TD:ll800' ( 0) 11/25/94 (27) TD:ll800' ( 0) 11/26/94 (28) TD:ll800' ( 0) TRIP OUT W/ FISH MW: 0.0 VIS: 0 LOGGED OPEN HOLE (OK) WIRE LINE HUNG UP IN 7" SHOE WLM @ 11300' TORPEDO ON TOP OF TOOL PULLING INTO SHOE. THIS IS -- ABOVE ROPE SOCKET. WOULD NOT PULL THROUGH WITHOUT PULLING OUT OF ROPE SOCKET. RIG UP TO CUT AND STRIP OVER WIRELINE W/ OVERSHOT AND 3.5" DP. TRIP IN HOLE STRIPPING OVER WIRE LINE W/ OVERSHOT AND 3.5" DP. SLACK OFF WIRELINE W/ OVERSHOT 20' BELOW SHOE AND ATTEMPT TO ENGAGE. RIG UP AND CIRC TO CLEAN OUT FISHING AREA 7.7 BPM. ENGAGE FISH PULL UP INTO CSG W/ FISH. RIG UP T-BAR AND PULL OUT OF ROPE SOCKET. RIG UP TO PULL OUT LINE. PULL OUT LINE. RIG DOWN ATLAS WIRELINE EQUIPMENT. CLEAR FLOOR. PUMP PILL, TRIP OUT W/ FISH. TRIP OUT TO RUN 4.5" LINER MW: 0.0 VIS: 0 TRIP OUT W/FISH. LAY DOWN ATLAS WIREL LINE TOOLS & BAKER FISHING TOOLS. CLEAR FLOOR OF UNNEEDED TOOLS. TRIP IN HOLE, CLEAN OUT RUN FOR LINER. SLIP & CUT DRILLING LINE. RIH TAG FILL @ 11377' WASH & REAM TO BOTTOM @ 11800'. CIRC & COND HOLE. PUMP SWEEP AROUND. SHT TRIP TO SHOE. RIH. TAG FILL @ 11772'. WASH & REAM 11772' T/l1800' CIRC. HIGH VIS SWEEP AROUND. I.I BPM @ 3100 PSI. SHT TRIP TO SHOE. RIH TAG FIL @ 11375', 11491' & 11700'_ WASH & REAM F/l1700' TO 11705' FELL THRU. RIH w/KELLEY. WORK TIGHT SPOTS TO 11800'_ CONTINUE TO WORK PIPE PUMP HIGH VIS. SWEEP AROUND @ 116 S.P.M. W/3100 PSI. TRIP OUT TO SHOE OK. BNO DRAG. PUMP PILL & DROP RABBIT DOWN C.P. TRIP OUT S.L.M. TRIP OUT W/LINER RUN TOOL MW: 0.0 VIS: 0 TRIP OUT TO RUN 4.5" LINER. STOOD BACK BHA. RIG UP TO RUN 4.5" LINER. SAFETY MEETING ON RUNNING LINER. RUN 4.5" 12.6# LL-80 NSCT LINER. 67 JTS. P/U BAKER LINER HGR. & CIRC LINER VOLUME. TRIP IN W/4.5" LINER TO 7" SHOE. R/U & CIRC LINER VOLUME. RIH W/LINER TO 11800' BOTTOM. CIRC & RECIPACATE. RIG UP B.J. CMT AS/PER/PROGRAM. BUMPED PLUG W/4500 PSI C.I.P. @ 0310 HRS. HANG LINER, PULL RUNNING TOOL OUT OF LINER. REVERSE OUT. EST. RECOVERY 27 BBLS PREFLUSH. PUMP DRY JOB. L/D BAKER CEMENT HEAD. TRIP OUT. TRIP OUT LD DP MW: 0.0 VIS: 0 (CANNOT READ REPORT FROM 0600-1100 AND FROM 2400-0150). TRIP OUT LAY DOWN EXCESS DRILL PIPE & BHA & BAKER LINER RUNNING TOOL. CLEAR FLOOR. P/U 3-1/8" DCS. & 2-7/8" DP & CLEAR FLOOR. SLIP & CUT DRLG LINE. TIH W/3-1/2" DP TAG CMT @ 11624' KELLEY UP WASH & REAM F/11324-11715' LANDING COLLAR. D-I. CIRC & PREPARE TO DISPLACE HOLE W/SEAWATER. DISPLACE TO CLEAN INHIBITED SEAWATER. MISSING TEXT. TRIP OUT TD DP. RECEIVED MAR 2 8 1995 ~t~$k8 Gill & Gas Cons. Commission Anchor~ · WELL : DS 12-34 OPERATION: RIG : NABORS 2ES PAGE: 8 11/27/94 (29) TD:ll800' ( 0) RIG RELEASED @ 1800 HRS MW: 0.0 VIS: 0 TRIP OUT LAYING DOWN DP TO 2000' PUMP DIESEL AROUND TO FREEZE PROTECT. TRIP OUT L/D 2-%/8" DP & 3-1/8" DCS & CLEAR FLOOR. TOP UP WELL W/DIESEL. PULL WEAR BUSHING. INSTALL FALSE BOWL PROTECTOR W/BPV. NIPPLE DN/BOPS. INSTALL FLG. & VALVE ON WELL. TEST FLG. 5000 PSI. BPV 1000 PSI. CLEAN UP CELLAR (RELEASE RIG). SIGNATURE: (drilling superintendent) DATE: RECEIV D MAR 28 '1995 hiaska Oji& Gas Cons. Commission Anchor~ AN~RAGE ALASKA PBU/12-34 V ~/0~' 30 ]99~ JOB ~BER: AK-~-40088 500292251500 NORTH SLOPE COMPUTATION DAT : TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES PAGE KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC DLS TOTAL RECTANGULAR COORDINATES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -70.10 0 0 N .00 E .00 .00N .00E 241 241.00 170.90 0 24 S 70.80 W .17 .28S .79W 420 420.00 349.90 0 36 N 88.40 W .15 .46S 2.32W 599 598.97 528.87 0 55 N 76.00 W .20 .08S 4.65W 776 775.96 705.86 . 0 36 N 65.10 W .20 .65N 6.87W .00 .67 1.66 2.64 3.25 966 965.95 895.85 0 36 N 83.19 W .10 1.19N 8.76W 1159 1158.94 1088.84 0 36 S 76.40 W .11 1.07N 10.75W 1344 1343.92 1273.82 0 48 N 89.00 W .14 .87N 12.98W 1437 1436.91 1366.81 0 54 S 74.20 W .29 .68N 14.33W 1530 1529.90 1459.80 0 54 S 43.50 W .51 .05S 15.54W 3.84 5.04 6.44 7.34 8.61 1623 1622.89 1552.79 1 0 S 44.70 W .11 1.16S 16.61W 1715 1714.86 1644.76 1 42 S 11.30 W 1.11 3.07S 17.44W 1807 1806.79 1736.69 2 47 S 10.20 W 1.20 6.62S 18.11W 1899 1898.61 1828.51 4 5 S 16.30 W 1.47 11.98S 19.43W 1993 1992.27 1922.17 5 41 S 27.10 W 1.96 19.37S 22.50W 10.13 12.18 15.51 20.71 28.56 2087 2085.56 2015.46 8 6 S 32.60 W 2.65 29.10S 28.19W 2181 2178.30 2108.20 10 36 S 34.60 W 2.68 41.80S 36.67W 2275 2270.20 2200.10 13 36 S 38.60 W 3.31 57.55S 48.48W 2368 2360.06 2289.96 16 12 S 37.20 W 2.82 76.43S 63.15W 2462 2449.72 2379.62 18 42 S 35.80 W 2.70 99.10S 79.89W 39.82 55.09 74.75 98.59 126.73 2553 2535.37 2465.27 20 47 S 41.40 W 3.10 123.06S 99.11W 2648 2623.31 2553.21 23 36 S 42.80 W 3.00 149.67S 123.19W 2742 2708.47 2638.37 26 30 S 41.80 W 3.12 179.12S 149.96W 2835 2791.10 2721.00 28 6 S 42.20 W 1.73 210.81S 178.50W 2929 2873.26 2803.16 30 0 S 41.30 W 2.07 244.86S 208.88W 157.32 192.79 232.12 274.30 319.46 3025 2955.24 2885.14 32 42 S 41.40 W 2.81 282.35S 241.88W 3118 3032.74 2962.64 34 24 S 38.10 W 2.68 321.87S 274.70W 3213 3109.13 3039.03 38 30 S 36.90 W 4.38 366.65S 309.03W 3307 3181.83 3111.73 40 12 S 33.70 W 2.82 415.30S 343.43W 3404 3256.51 3186.41 39 5 S 34.60 W 1.28 466.52S 378.17W 368.93 420.00 476.29 535.85 597.73 3497 3328.22 3258.12 40 0 S 34.20 W 1.01 515.38S 411.63W 3590 3398.88 3328.78 41 5 S 33.00 W 1.45 565.73S 445.07W 3779 3539.77 3469.67 42 30 S 33.20 W .74 671.26S 513.87W 3873 3609.01 3538.91 42 35 S 33.50 W .24 724.35S 548.81W 3967 3678.04 3607.94 42 54 S 32.30 W .92 777.93S 583.46W 656.94 717.39 843.36 906.92 970.72 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTI DEPTH DEPTH DEPTH DG MN DEGREES DLS TOTAL ON RECTANGULAR COORDINATES DO/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4062 3747.57 3677.47 4156 3816.32 3746.22 4250 3885.01 3814.91 4345 3954.26 3884.16 4439 4022.39 3952.29 43 43 43 43 43 0 0 5 17 47 S 31.20 S 31.60 S 31.60 S 32 . 00 S 30.90 W .80 832.97S 617.52W W .29 887.68S 650.92W W .11 942.34S 684.55W W .36 997.61S 718.82W W .97 1052.86S 752.60W 1035.41 1099.48 1163.61 1228.61 1293.33 4532 4089.57 4019.47 43 42 4627 4158.21 4088.11 43 46 4722 4225.99 4155.89 45 10 4817 4292.65 4222.55 45 42 4908 4356.88 4286.78 45 42 S 31.40 S 30.60 S 31.20 S 30.70 S 30 . 70 W .39 1107.89S 785.87W W .59 1164.19S 819.69W W 1.55 1221.29S 853.87W W .66 1279.34S 888.68W W .00 1335.93S 922.28W 1357.59 1423.20 1489.69 1557.31 1623.05 5003 4422.81 4352.71 45 15 5098 4489.83 4419.73 45 0 5193 4556.72 4486.62 45 30 5286 4621.84 4551.74 45 35 5379 4686.60 4616.50 46 8 S 30.40 S 33 . 00 S 32.30 S 32.70 S 32 . 00 W .52 1393.68S 956.37W W 1.96 1450.95S 991.73W W .74 1507.75S 1028.13W W .33 1563.74S 1063.80W W .79 1620.13S 1099.52W 1690.01 1757.29 1824.75 1891.13 1957.86 5472 4750.57 4680.47 46 55 S 32.70 5567 4815.44 4745.34 46 55 S 33.20 5661 4879.58 4809.48 47 1 S 32.50 5723 4921.95 4851.85 46 45 S 32.10 5817 4986.14 4916.04 47 6 S 32.80 W 1.01 1677.15S 1135.63W W .38 1735.39S 1173.38W W .55 1793.12S 1210.66W W .63 1831.38S 1234.84W W .66 1889.33S 1271.69W 2025.34 2094.74 2163.45 2208.71 2277.37 5910 5049.43 4979.33 47 6005 5113.93 5043.83 47 6194 5241.82 5171.72 47 6286 5303.61 5233.51 48 6380 5365.61 5295.51 49 6 22 27 9 17 S 33 . 50 S 34 . 40 S 33.70 S 35.10 S 37.40 W .55 1946.37S 1308.95W W .75 2004.23S 1347.90W W .28 2119.52S 1425.82W W 1.36 2175.76S 1464.33W W 2.20 2232.72S 1506.10W 2345.50 2415.25 2554.40 2622.54 2693.10 6474 5427.34 5357.24 48 35 6568 5488.90 5418.80 49 34 6659 5548.74 5478.64 48 12 6753 5613.08 5542.98 45 24 6846 5678.32 5608.22 45 30 S 36 . 40 S 37.80 S 36.70 S 36.90 S 36.50 W 1.09 2289.40S 1548.67W W 1.53 2346.04S 1591.52W W 1.76 2400.61S 1633.01W W 2.98 2455.47S 1674.05W W .32 2508.61S 1713.66W 2763.85 2834.74 2903.14 2971.54 3037.71 6941 5745.21 5675.11 45 35 7035 5810.50 5740.40 45 47 7130 5876.79 5806.69 45 42 7224 5942.15 5872.05 46 12 7318 6007.21 5937.11 46 12 S 33 . 20 S 32 . 10 S 29.30 S 30.40 S 29.00 W 2.47 2564.55S 1752.61W W .87 2620.87S 1788.70W W 2.11 2679.37S 1823.43W W 1.00 2737.96S 1857.06W W 1.07 2796.89S 1890.67W 3105.85 3172.74 3240.69 3308.11 3375.81 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 7413 6072.84 6002.74 7508 6138.53 6068.43 7603 6204.11 6134.01 7697 6268.69 6198.59 7781 6326.30 6256.20 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST FT. 46 24 S 30.90 W 1.46 2856.39S 1924.96W 46 5 S 29.50 W 1.11 2915.69S 1959.48W 46 35 S 30.90 W 1.19 2975.10S 1994.06W 46 35 S 29.10 W 1.39 3034.24S 2028.20W 46 47 S 30.60 W 1.32 3087.26S 2058.63W VERT. SECT. 3444.35 3512.86 3581.48 3649.64 3710.65 7875 6390.65 6320.55 7969 6454.94 6384.84 8063 6518.68 6448.58 8145 6573.98 6503.88 8250 6645.52 6575.42 46 47 S 30.60 W .00 3146.24S 2093.51W 46 54 S 30.60 W .11 3205.27S 2128.42W 47 42 S 30.70 W .85 3264.69S 2163.63W 47 30 S 28.30 W 2.17 3317.39S 2193.45W 46 35 S 29.00 W .99 3384.83S 2230.29W 3779.08 3847.58 3916.57 3976.97 4053.54 8345 6711.62 6641.52 8439 6778.61 6708.51 8533 6846.28 6776.18 8626 6913.52 6843.42 8721 6982.54 6912.44 45 12 S 28.40 W 1.54 3444.66S 2263.05W 43 54 S 29.20 W 1.51 3502.45S 2294.81W 44 0 S 29.00 W .18 3559.45S 2326.54W 43 24 S 31.70 W 2.11 3614.88S 2358.99W 43 24 S 32.80 W .80 3670.09S 2393.82W 4121.52 4187.24 4252.29 4316.43 4381.68 8813 7049.44 6979.34 8907 7118.19 7048.09 9001 7187.66 7117.56 9095 7257.79 7187.69 9190 7328.66 7258.56 43 17 S 34.50 W 1.27 3722.65S 2428.81W 42 42 S 33.40 W 1.02 3775.83S 2464.61W 42 0 S 32.20 W 1.14 3829.05S 2498.92W 41 30 S 33.40 W 1.00 3881.66S 2532.82W 42 0 S 33.70 W .57 3934.38S 2567.78W 4444.83 4508.93 4572.24 4634.83 4698.09 9284 7397.85 7327.75 9377 7465.75 7395.65 9471 7534.67 7464.57 9564 7603.29 7533.19 9658 7673.20 7603.10 43 12 S 35.30 W 1.72 3986.80S 2603.82W 43 0 S 36.90 W 1.20 4038.14S 2641.26W 42 42 S 34.90 W 1.48 4089.91S 2678.74W 42 12 S 33.30 W 1.28 4141.88S 2713.93W 41 42 S 34.90 W 1.26 4193.91S 2749.15W 4761.69 4825.16 4889.02 4951.78 5014.61 9754 7744.71 7674.61 9847 7813.38 7743.28 9941 7882.63 7812.53 10034 7952.12 7882.02 10128 8023.65 7953.55 10223 8097.31 8027.21 10327 8179.04 8108.94 10388 8226.88 8156.78 10483 8299.59 8229.50 10576 8368.65 8298.55 42 0 S 34.50 W .42 4246.57S 2785.61W 42 47 S 36.40 W 1.62 4297.64S 2821.98W 42 17 S 34.80 W 1.27 4349.32S 2858.99W 41 0 S 35.10 W 1.41 4399.98S 2894.39W 39 54 S 37.00 W 1.76 4449.28S 2930.26W 38 24 S 37.00 W 1.58 4497.18S 2966.36W 38 0 S 36.93 W .39 4548.57S 3005.03W 38 42 S 37.20 W 1.18 4578.77S 3027.84W 41 24 S 38.30 W 2.94 4627.08S 3065.27W 42 42 S 40.50 W 2.11 4675.20S 3104.81W 5078.65 5141.31 5204.82 5266.60 5327.52 5387.38 5451.57 5489.35 5550.30 5612.24 SPERRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/9 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 10672 8438.28 8368.18 44 17 S 39.60 W 1.79 4725.78S 3147.32W 10767 8505.29 8435.19 46 0 S 43.40 W 3.35 4776.18S 3191.96W 10842 8557.01 8486.91 46 47 S 45.40 W 2.21 4814.97S 3229.96W 10935 8620.43 8550.33 47 12 S 46.10 W .70 4862.43S 3278.68W 11028 8682.55 8612.45 49 0 S 49.20 W 3.15 4909.03S 3329.84W 5677.88 5744.54 5797.86 5864.32 5931.41 11123 8745.49 8675.39 48 0 S 48.40 W 1.23 4955.89S 3383.37W 11218 8810.57 8740.47 45 30 S 47.90 W 2.66 5002.04S 3434.91W 11249 8832.28 8762.18 45 35 S 47.90 W .33 5016.88S 3451.32W 11312 8876.00 8805.90 46 30 S 49.50 W 2.32 5046.81S 3485.40W 11409 8942.77 8872.67 46 30 S 49.50 W .02 5092.50S 3538.90W 6000.02 6066.95 6088.38 6132.14 6199.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6201.40 FEET AT SOUTH 34 DEG. 47 MIN. WEST AT MD = 11409 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 213.48 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -70.10 .00 N .00 E .00 1000 999.94 929.84 1.23 N 9.12 W .06 2000 1999.23 1929.13 19.98 S 22.82 W .77 3000 2934.11 2864.01 272.31 S 233.03 W 65.89 4000 3702.21 3632.11 796.91 S 595.47 W 297.79 .06 .72 65.11 231.90 5000 4420.70 4350.60 1391.84 S 955.29 W 579.30 6000 5110.55 5040.45 2001.19 S 1345.82 W 889.45 7000 5786.10 5716.00 2599.62 S 1775.37 W 1213.90 8000 6476.12 6406.02 3224.75 S 2139.94 W 1523.88 9000 7186.91 7116.81 3828.48 S 2498.56 W 1813.09 281.51 310.16 324.45 309.98 289.21 10000 7926.46 7856.36 4381.73 S 2881.56 W 2073.54 11000 8664.08 8593.98 4895.16 S 3314.02 W 2335.92 11409 8942.77 8872.67 5092.50 S 3538.90 W 2466.23 260.45 262.38 130.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -70.10 70 70.10 .00 170 170.10 100.00 270 270.10 200.00 370 370.10 300.00 .00 N .00 E .00 N .00 E .11 S .33 W .34 S .99 W .47 S 1.80 W .00 .00 .00 .00 .00 .00 .00 .01 .00 470 470.10 400 570 570.10 500 670 670.10 600 770 770.10 700 870 870.10 800 .00 .00 .00 .00 .00 .44 S 2.85 W .19 S 4.20 W .19 N 5.76 W .63 N 6.82 W .05 N 7.77 W .01 .01 .02 .01 .04 .01 .04 .01 .05 .00 970 970.10 900 1070 1070.10 1000 1170 1170.10 1100 1270 1270.10 1200 1370 1370.10 1300 .00 .00 .00 .00 .00 .19 N 8.81 W .28 N 9.84 W .04 N 10.86 W .85 N 11.95 W .87 N 13.35 W .05 .01 .06 .00 .06 .01 .07 .01 .08 .01 1470 1470.10 1400 1570 1570.10 1500 1670 1670.10 1600 1770 1770.10 1700 1870 1870.10 1800 .00 .00 .00 .00 .00 1 4 10 .54 N 14.83 W .51 S 15.98 W .84 S 17.15 W .86 S 17.79 W .02 S 18.86 W .09 .01 .10 .01 .12 . 02 .17 .05 .31 .14 1970 1970.10 1900 2071 2070.10 2000 2172 2170.10 2100 2274 2270.10 2200 2378 2370.10 2300 .00 .00 .00 .00 .00 17.40 S 21.49 W 27.25 S 27.01 W 40.53 S 35.80 W 57.55 S 48.48 W 78.76 S 64.91 W .63 .32 1.29 .66 2.57 1.28 4.81 2.24 8.36 3.55 2483 2470.10 2400.00 2590 2570.10 2500.00 2699 2670.10 2600.00 2811 2770.10 2700.00 2925 2870.10 2800.00 104.73 S 84.07 W 133.21 S 108.17 W 165.31 S 137.53 W 202.50 S 170.97 W 243.50 S 207.68 W 13.46 5.10 20.21 6.75 29.28 9.07 41.10 11.82 55.26 14.16 3042 2970.10 3163 3070.10 3291 3170.10 3421 3270.10 3551 3370.10 2900.00 3000.00 3100.00 3200.00 3300.00 289.51 S 248.19 W 342.87 S 290.98 W 407.14 S 337.92 W 475.61 S 384.44 W 544.72 S 431.40 W 72.57 17.31 93.76 21.19 121.59 27.84 151.42 29.82 181.74 30.32 FT. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3684 3470.10 3400.00 3820 3570.10 3500.00 3956 3670.10 3600.00 4092 3770.10 3700.00 4229 3870.10 3800.00 617.93 S 478.98 W 694.52 S 529.09 W 771.69 S 579.52 W 850.94 S 628.41 W 930.46 S 677.24 W 214.49 32.76 250.05 35.56 286.07 36.02 322.71 36.64 359.48 36.78 4366 3970.10 3900.00 4505 4070.10 4000.00 4643 4170.10 4100.00 4784 4270.10 4200.00 4927 4370.10 4300.00 1010.27 S 726.73 W 396.66 37.18 1092.01 S 776.18 W 434.97 38.31 1173.99 S 825.49 W 473.36 38.39 1259.47 S 876.89 W 514.61 41.25 1347.59 S 929.20 W 557.79 43.18 5070 4470.10 4400.00 5212 4570.10 4500.00 5355 4670.10 4600.00 5500 4770.10 4700.00 5647 4870.10 4800.00 1434.39 S 980.98 W 1519.26 S 1035.41 W 1605.58 S 1090.42 W 1694.73 S 1146.92 W 1784.54 S 1205.19 W 599.99 42.20 642.00 42.00 685.09 43.10 730.50 45.41 776.99 46.49 5793 4970.10 4900.00 5940 5070.10 5000.00 6087 5170.10 5100.00 6235 5270.10 5200.00 6386 5370.10 5300.00 1874.81 S 1262.34 W 1964.92 S 1321.23 W 2054.58 S 1382.38 W 2145.16 S 1442.91 W 2236.86 S 1509.27 W 823.33 46.34 870.26 46.93 917.83 47.57 965.72 47.89 1016.79 51.06 6539 5470.10 5400.00 6690 5570.10 5500.00 6834 5670.10 5600.00 6977 5770.10 5700.00 7120 5870.10 5800.00 2328.61 S 1577.99 W 2419.41 S 1647.05 W 2501.88 S 1708.69 W 2585.81 S 1766.53 W 2673.39 S 1820.08 W 1068.91 52.12 1120.63 51.72 1164.17 43.54 1206.99 42.82 1250.32 43.33 7264 5970.10 5900.00 7409 6070.10 6000.00 7553 6170.10 6100.00 7699 6270.10 6200.00 7844 6370.10 6300.00 2763.12 S 1871.78 W 2853.92 S 1923.48 W 2944.25 S 1975.70 W 3035.54 S 2028.92 W 3127.40 S 2082.37 W 1294.29 43.97 1338.93 44.64 1383.45 44.52 1428.95 45.50 1474.88 45.93 7991 6470.10 6400.00 8139 6570.10 6500.00 8285 6670.10 6600.00 8427 6770.10 6700.00 8566 6870.10 6800.00 3219.21 S 2136.66 W 3313.66 S 2191.44 W 3407.55 S 2242.88 W 3495.30 S 2290.82 W 3579.56 S 2337.70 W 1521.09 46.21 1569.16 48.07 1615.66 46.50 1657.09 41.43 1696.01 38.92 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8703 6970.10 6900.00 3660.20 S 2387.45 W 1733.78 37.77 8841 7070.10 7000.00 3738.70 S 2439.84 W 1771.29 37.51 8977 7170.10 7100.00 3815.67 S 2490.49 W 1807.27 35.99 9111 7270.10 7200.00 3890.75 S 2538.82 W 1841.34 34.07 9245 7370.10 7300.00 3965.53 S 2588.76 W 1875.83 34.49 9382 7470.10 7400.00 4041.38 S 2643.69 W 1912.84 37.01 9519 7570.10 7500.00 4116.73 S 2697.39 W 1949.09 36.25 9653 7670.10 7600.00 4191.65 S 2747.57 W 1983.75 34.66 9788 7770.10 7700.00 4265.41 S 2798.56 W 2018.07 34.32 9924 7870.10 7800.00 4339.96 S 2852.48 W 2053.95 35.89 10057 7970.10 7900.00 4412.77 S 2903.38 W 2087.72 33.77 10188 8070.10 8000.00 4479.95 S 2953.38 W 2118.17 30.45 10315 8170.10 8100.00 4542.98 S 3000.83 W 2145.55 27.38 10444 8270.10 8200.00 4607.03 S 3049.56 W 2173.92 28.37 10577 8370.10 8300.00 4676.21 S 3105.68 W 2207.88 33.95 10716 8470.10 8400.00 4749.71 S 3167.79 W 2246.67 38.80 10861 8570.10 8500.00 4824.76 S 3239.88 W 2291.03 44.36 11009 8670.10 8600.00 4899.68 S 3319.15 W 2339.02 47.99 11159 8770.10 8700.00 4974.04 S 3403.81 W 2389.68 50.66 11303 8870.10 8800.00 5042.77 S 3480.67 W 2433.33 43.65 11409 8942.77 8872.67 5092.50 S 3538.90 W 2466.23 32.90 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS FT. ' ~ .... . PAGE 1 SF~-'qY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/12-34 5600292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 112194 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-40092 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 11312 8876.00 8805.90 46 30 S 49.50 W .00 5047.00S 3486.00W 11357 8906.88 8836.78 47 19 S 50.94 W 2.96 5068.12S 3511.37W 11452 8973.29 8903.19 44 45 S 48.68 W 3.18 5112.53S 3563.99W 11548 9042.17 8972.07 43 31 S 49.10 W 1.31 5156.48S 3614.35W 11644 9112.15 9042.05 42 50 S 49.19 W .72 5199.45S 3664.02W VERT. SECT. 6132.63 6164.24 6230.31 6294.75 6357.99 11739 9182.30 9112.20 41 59 S 48.86 W .92 5241.47S 3712.41W 11756 9194.31 9124.21 41 51 S 48.59 W 1.38 5248.58S 3720.51W 11800 9227.08 9156.98 41 51 S 48.59 W .00 5268.00S 3742.54W 6419.73 6430.13 6458.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6462.08 FEET AT SOUTH 35 DEG. 23 MIN. WEST AT MD = 11800 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 213.48 DEG. MICROFILM ) Gas Cons. Commission Anchor; PAGE 2 'S'--'2RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/12-34 5600292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 112194 JOB NUMBER: AK-EI-40092 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11312 8876.00 8805.90 11800 9227.08 9156.98 5047.00 S 3486.00 W 2436.00 5268.00 S 3742.54 W 2572.92 136.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. R ECE VED Anchor~ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 5600292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 112194 JOB NUMBER: AK-EI-40092 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 11312 8876.00 8805.90 5047.00 S 3486.00 W 2436.00 11448 8970.10 8900.00 5110.44 S 3561.59 W 2478.27 42.27 11587 9070.10 9000.00 5173.85 S 3634.40 W 2517.29 39.02 11723 9170.10 9100.00 5234.24 S 3704.14 W 2553.34 36.06 11800 9227.08 9156.98 5268.00 S 3742.54 W 2572.92 19.58 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED MAR 2_ 8 1995 Alaska. 0il & Gas Cons. Commission Anchor~ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 PRUDHOE BAY DRILLING PBU/12-34 5oo2922szsoo NORTH SLOPE COMPUTATION DATE: 11/23 /94 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -70.10 0 0 241 241.00 170.90 0 24 420 420.00 349.90 0 36 599 598.97 528.87 0 55 776 775.96 705.86 0 36 N .00 E .00 .00N .00E S 70.80 W .17 .28S .79W N 88.40 W .15 .46S 2.32W N 76.00 W .20 .08S 4.65W N 65.10 W .20 .65N 6.87W .00 .67 1.66 2.64 3 .25 966 965.95 895.85 0 36 1159 1158.94 1088.84 0 36 1344 1343.92 1273.82 0 48 1437 1436.91 1366.81 0 54 1530 1529.90 1459.80 0 54 N 83.19 W .10 1.19N 8.76W S 76.40 W .11 1.07N 10.75W N 89.00 W .14 .87N 12.98W S 74.20 W .29 .68N 14.33W S 43.50 W .51 .05S 15.54W 3.84 5.04 6.44 7.34 8.61 1623 1622.89 1552.79 1 0 1715 1714.86 1644.76 1 42 1807 1806.79 1736.69 2 47 1899 1898.61 1828.51 4 5 1993 1992.27 1922.17 5 41 S 44.70 W .11 1.16S 16.61W S 11.30 W 1.11 3.07S 17.44W S 10.20 W 1.20 6.62S 18.11W S 16.30 W 1.47 11.98S 19.43W S 27.10 W 1.96 19.37S 22.50W 10.13 12.18 15.51 20.71 28.56 2087 2085.56 2015.46 8 6 2181 2178.30 2108.20 10 36 2275 2270.20 2200.10 13 36 2368 2360.06 2289.96 16 12 2462 2449.72 2379.62 18 42 S 32.60 W 2.65 29.10S 28.19W S 34.60 W 2.68 41.80S 36.67W S 38.60 W 3.31 57.55S 48.48W S 37.20 W 2.82 76.43S 63.15W S 35.80 W 2.70 99.10S 79.89W 39.82 55.09 74.75 98.59 126.73 2553 2535.37 2465.27 20 47 2648 2623.31 2553.21 23 36 2742 2708.47 2638.37 26 30 2835 2791.10 2721.00 28 6 2929 2873.26 2803.16 30 0 S 41.40 W 3.10 123.06S 99.11W S 42.80 W 3.00 149.67S 123.19W S 41.80 W 3.12 179.12S 149.96W S 42.20 W 1.73 210.81S 178.50W S 41.30 W 2.07 244.86S 208.88W 157.32 192.79 232.12 274.30 319.46 3025 2955.24 2885.14 32 42 3118 3032.74 2962.64 34 24 3213 3109.13 3039.03 38 30 3307 3181.83 3111.73 40 12 3404 3256.51 3186.41 39 5 S 41.40 W 2.81 282.35S 241.88W S 38.10 W 2.68 321.87S 274.70W S 36.90 W 4.38 366.65S 309.03W S 33.70 W 2.82 415.30S 343.43W S 34.60 W 1.28 466.52S 378.17W 368.93 420.00 476.29 535.85 597.73 3497 3328.22 3258.12 40 0 3590 3398.88 3328.78 41 5 3779 3539.77 3469.67 42 30 3873 3609.01 3538.91 42 35 3967 3678.04 3607.94 42 54 S 34.20 W 1.01 515.38S 411.63W S 33.00 W 1.45 565.73S 445.07W S 33.20 W .74 671.26S 513.87W S 33.50 W .24 724.35S 548.81W S 32.30 W .92 777.93S 583.46W RECEIVED 656.94 717.39 843.36 906.92 970.72 MAR 28 1995 Oil & Gas Cons. Commission Anchorr ' SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4062 3747.57 3677.47 4156 3816.32 3746.22 4250 3885.01 3814.91 4345 3954.26 3884.16 4439 4022.39 3952.29 43 0 43 0 43 5 43 17 43 47 S 31.20 W .80 832.97S 617.52W S 31.60 W .29 887.68S 650.92W S 31.60 W .11 942.34S 684.55W S 32.00 W .36 997.61S 718.82W S 30.90 W .97 1052.86S 752.60W 1035.41 1099.48 1163.61 1228.61 1293.33 4532 4089.57 4019.47 43 42 4627 4158.21 4088.11 43 46 4722 4225.99 4155.89 45 10 4817 4292.65 4222.55 45 42 4908 4356.88 4286.78 45 42 S 31.40 W .39 1107.89S 785.87W S 30.60 W .59 1164.19S 819.69W S 31.20 W 1.55 1221.29S 853.87W S 30.70 W .66 1279.34S 888.68W S 30.70 W .00 1335.93S 922.28W 1357.59 1423.20 1489.69 1557.31 1623.05 5003 4422.81 4352.71 45 15 5098 4489.83 4419.73 45 0 5193 4556.72 4486.62 45 30 5286 4621.84 4551.74 45 35 5379 4686.60 4616.50 46 8 S 30.40 W .52 1393.68S 956.37W S 33.00 W 1.96 1450.95S 991.73W S 32.30 W .74 1507.75S 1028.13W S 32.70 W .33 1563.74S 1063.80W S 32.00 W .79 1620.13S 1099.52W 1690.01 1757.29 1824.75 1891.13 1957.86 5472 4750.57 4680.47 5567 4815.44 4745.34 5661 4879.58 4809.48 5723 4921.95 4851.85 5817 4986.14 4916.04 46 55 46 55 47 1 46 45 47 6 S 32.70 W 1.01 1677.15S 1135.63W S 33.20 W .38 1735.39S 1173.38W S 32.50 W .55 1793.12S 1210.66W S 32.10 W .63 1831.38S 1234.84W S 32.80 W .66 1889.33S 1271.69W 2025.34 2094.74 2163.45 2208.71 2277.37 5910 5049.43 4979.33 6005 5113.93 5043.83 6194 5241.82 5171.72 6286 5303.61 5233.51 6380 5365.61 5295.51 47 6 47 22 47 27 48 9 49 17 S 33.50 W .55 1946.37S 1308.95W S 34.40 W .75 2004.23S 1347.90W S 33.70 W .28 2119.52S 1425.82W S 35.10 W 1.36 2175.76S 1464.33W S 37.40 W 2.20 2232.72S 1506.10W 2345.50 2415.25 2554.40 2622.54 2693.10 6474 5427.34 5357.24 48 35 6568 5488.90 5418.80 49 34 6659 5548.74 5478.64 48 12 6753 5613.08 5542.98 45 24 6846 5678.32 5608.22 45 30 S 36.40 W 1.09 2289.40S 1548.67W S 37.80 W 1.53 2346.04S 1591.52W S 36.70 W 1.76 2400.61S 1633.01W S 36.90 W 2.98 2455.47S 1674.05W S 36.50 W .32 2508.61S 1713.66W 2763.85 2834.74 2903 . 14 2971.54 3037.71 6941 5745.21 5675.11 45 35 7035 5810.50 5740.40 45 47 7130 5876.79 5806.69 45 42 7224 5942.15 5872.05 46 12 7318 6007.21 5937.11 46 12 S 33.20 W 2.47 2564.55S 1752.61W S 32.10 W .87 2620.87S 1788.70W S 29.30 W 2.11 2679.37S 1823.43W S 30.40 W 1.00 2737.96S 1857.06W S 29.00 W 1.07 2796.89S 1890.67W 3105.85 3172.74 3240.69 3308.11 3375.81 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPEP,_ATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7413 6072.84 6002.74 7508 6138.53 6068.43 7603 6204.11 6134.01 7697 6268.69 6198.59 7781 6326.30 6256.20 46 24 S 30.90 W 1.46 2856.39S 1924.96W 46 5 S 29.50 W 1.11 2915.69S 1959.48W 46 35 S 30.90 W 1.19 2975.10S 1994.06W 46 35 S 29.10 W 1.39 3034.24S 2028.20W 46 47 S 30.60 W 1.32 3087.26S 2058.63W 3444.35 3512.86 3581.48 3649.64 3710.65 7875 6390.65 6320.55 7969 6454.94 6384.84 8063 6518.68 6448.58 8145 6573.98 6503.88 8250 6645.52 6575.42 46 47 S 30.60 W .00 3146.24S 2093.51W 46 54 S 30.60 W .11 3205.27S 2128.42W 47 42 S 30.70 W .85 3264.69S 2163.63W 47 30 S 28.30 W 2.17 3317.39S 2193.45W 46 35 S 29.00 W .99 3384.83S 2230.29W 3779.08 3847.58 3916.57 3976.97 4053.54 8345 6711.62 6641.52 8439 6778.61 6708.51 8533 6846.28 6776.18 8626 6913.52 6843.42 8721 6982.54 6912.44 45 12 S 28.40 W 1.54 3444.66S 2263.05W 43 54 S 29.20 W 1.51 3502.45S 2294.81W 44 0 S 29.00 W .18 3559.45S 2326.54W 43 24 S 31.70 W 2.11 3614.88S 2358.99W 43 24 S 32.80 W .80 3670.09S 2393.82W 4121.52 4187.24 4252.29 4316.43 4381.68 8813 7049.44 6979.34 8907 7118.19 7048.09 9001 7187.66 7117.56 9095 7257.79 7187.69 9190 7328.66 7258.56 43 17 S 34.50 W 1.27 3722.65S 2428.81W 42 42 S 33.40 W 1.02 3775.83S 2464.61W 42 0 S 32.20 W 1.14 3829.05S 2498.92W 41 30 S 33.40 W 1.00 3881.66S 2532.82W 42 0 S 33.70 W .57 3934.38S 2567.78W 4444.83 4508.93 4572.24 4634.83 4698.09 9284 7397.85 7327.75 9377 7465.75 7395.65 9471 7534.67 7464.57 9564 7603.29 7533.19 9658 7673.20 7603.10 43 12 S 35.30 W 1.72 3986.80S 2603.82W 43 0 S 36.90 W 1.20 4038.14S 2641.26W 42 42 S 34.90 W 1.48 4089.91S 2678.74W 42 12 S 33.30 W 1.28 4141.88S 2713.93W 41 42 S 34.90 W 1.26 4193.91S 2749.15W 4761.69 4825.16 4889.02 4951.78 5014.61 9754 7744.71 7674.61 9847 7813.38 7743.28 9941 7882.63 7812.53 10034 7952.12 7882.02 10128 8023.65 7953.55 42 0 S 34.50 W .42 4246.57S 2785.61W 42 47 S 36.40 W 1.62 4297.64S 2821.98W 42 17 S 34.80 W 1.27 4349.32S 2858.99W 41 0 S 35.10 W 1.41 4399.98S 2894.39W 39 54 S 37.00 W 1.76 4449.28S 2930.26W 5078.65 5141.31 5204.82 5266.60 5327.52 10223 8097.31 8027.21 10327 8179.04 8108.94 10388 8226.88 8156.78 10483 829'9.59 8229.50 10576 8368.65 8298.55 38 24 S 37.00 W 1.58 38 0 S 36.93 W .39 38 42 S 37.20 W 1.18 41 24 S 38.30 W 2.94 42 42 S 40.50 W 2.11 4497 . 18S 2966 . 36W 4548 . 57S 3005 . 03W 4578 . 77S 3027.84W 4627 . 08S 3065 . 27W .OSR 5387.38 5451.57 5489.35 5550.30 5612.24 MAR 28 199,5 Oil & Gas Cons. Comrnissior~ Anchor~ SPERRY-SI/N DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23 /94 DATE OF SURVEY: 111594 MWD SURVEY JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC PAGE FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10672 8438.28 8368.18 44 17 S 39.60 W 1.79 4725.78S 3147.32W 10767 8505.29 8435.19 46 0 S 43.40 W 3.35 4776.18S 3191.96W 10842 8557.01 8486.91 46 47 S 45.40 W 2.21 4814.97S 3229.96W 10935 8620.43 8550.33 47 12 S 46.10 W .70 4862.43S 3278.68W 11028 8682.55 8612.45 49 0 S 49.20 W 3.15 4909.03S 3329.84W 5677.88 5744.54 5797.86 5864.32 5931.41 11123 8745.49 8675.39 48 0 S 48.40 W 1.23 4955.89S 3383.37W 11218 8810.57 8740.47 45 30 S 47.90 W 2.66 5002.04S 3434.91W 11249 8832.28 8762.18 45 35 S 47.90 W .33 5016.88S 3451.32W 11312 8876.00 8805.90 46 30 S 49.50 W 2.32 5046.81S 3485.40W 11409 8942.77 8872.67 46 30 S 49.50 W .02 5092.50S 3538.90W 6000.02 6066.95 6088.38 6132.14 6199.77 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6201.40 FEET AT SOUTH 34 DEG. 47 MIN. WEST AT MD = 11409 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 213.48 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -70.10 .00 N .00 E 1000 999.94 929.84 1.23 N 9.12 W 2000 1999.23 1929.13 19.98 S 22.82 W 3000 2934.11 2864.01 272.31 S 233.03 W 4000 3702.21 3632.11 796.91 S 595.47 W .00 .06 .06 .77 .72 65.89 65.11 297.79 231.90 5000 4420.70 4350.60 1391.84 S 955.29 W 6000 5110.55 5040.45 2001.19 S 1345.82 W 7000 5786.10 5716.00 2599.62 S 1775.37 W 8000 6476.12 6406.02 3224.75 S 2139.94 W 9000 7186.91 7116.81 3828.48 S 2498.56 W 579.30 281.51 889.45 310.16 1213.90 324.45 1523.88 309.98 1813.09 289.21 10000 7926.46 7856.36 4381.73 S 2881.56 W 11000 8664.08 8593.98 4895.16 S 3314.02 W 11409 8942.77 8872.67 5092.50 S 3538.90 W 2073.54 260.45 2335.92 262.38 2466.23 130.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -70.10 70 70.10 .00 170 170.10 100.00 270 270.10 200.00 370 370.10 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .11 S .33 W .00 .00 .34 S .99 W .00 .00 .47 S 1.80 W .01 .00 470 470.10 400.00 570 570.10 500.00 670 670.10 600.00 770 770.10 700.00 870 870.10 800.00 · 44 S 2.85 W .19 S 4.20 W .19 N 5.76 W .63 N 6.82 W .05 N 7.77 W .01 .01 .02 .01 .04 .01 .04 .01 .05 .00 970 970.10 900.00 1070 1070.10 1000.00 1170 1170.10 1100.00 1270 1270.10 1200.00 1370 1370.10 1300.00 .19 N 8.81 W .05 .01 .28 N 9.84 W .06 .00 .04 N 10.86 W .06 .01 .85 N 11.95 W .07 .01 .87 N 13.35 W .08 .01 1470 1470.10 1400.00 1570 1570.10 1500.00 1670 1670.10 1600.00 1770 1770.10 1700.00 1870 1870.10 1800.00 1 4 10 .54 N 14.83 W .51 S 15.98 W .84 S 17.15 W .86 S 17.79 W .02 S 18.86 W .09 .01 .10 .01 .12 .02 .17 .05 .31 .14 1970 1970.10 1900.00 2071 2070.10 2000.00 2172 2170.10 2100.00 2274 2270.10 2200.00 2378 2370.10 2300.00 17.40 S 21.49 W 27.25 S 27.01 W 40.53 S 35.80 W 57.55 S 48.48 W 78.76 S 64.91 W .63 .32 1.29 .66 2.57 1.28 4.81 2.24 8.36 3.55 2483 2470.10 2400.00 2590 2570.10 2500.00 2699 2670.10 2600.00 2811 2770.10 2700.00 2925 2870.10 2800.00 104.73 S 84.07 W 133.21 S 108.17 W 165.31 S 137.53 W 202.50 S 170.97 W 243.50 S 207.68 W 13.46 5.10 20.21 6.75 29.28 9.07 41.10 11.82 55.26 14.16 3042 2970.10 2900.00 3163 3070.10 3000.00 3291 3170.10 3100.00 3421 3270.10 3200.00 3551 3370.10 3300.00 289.51 S 248.19 W 342.87 S 290.98 W 407.14 S 337.92 W 475.61 S 384.44 W 544.72 S 431.40 W 72 .57 17.31 93.76 21.19 121.59 27.84 9.82 I E. EIVEI o MAR 28 1995 Oil & Gas Cons· CommJsslor~ Anchor[ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3684 3470.10 3400.00 3820 3570.10 3500.00 3956 3670.10 3600.00 4092 3770.10 3700.00 4229 3870.10 3800.00 617.93 S 478.98 W 694.52 S 529.09 W 771.69 S 579.52 W 850.94 S 628.41 W 930.46 S 677.24 W 214.49 32.76 250.05 35.56 286.07 36.02 322.71 36.64 359.48 36.78 4366 3970.10 3900.00 4505 4070.10 4000.00 4643 4170.10 4100.00 4784 4270.10 4200.00 4927 4370.10 4300.00 1010.27 S 726.73 W 1092.01 S 776.18 W 1173.99 S 825.49 W 1259.47 S 876.89 W 1347.59 S 929.20 W 396.66 37.18 434.97 38.31 473.36 38.39 514.61 41.25 557.79 43.18 5070 4470.10 4400.00 5212 4570.10 4500.00 5355 4670.10 4600.00 5500 4770.10 4700.00 5647 4870.10 4800.00 1434.39 S 980.98 W 1519.26 S 1035.41 W 1605.58 S 1090.42 W 1694.73 S 1146.92 W 1784.54 S 1205.19 W 599.99 42.20 642.00 42.00 685.09 43.10 730.50 45.41 776.99 46.49 5793 4970.10 4900.00 5940 5070.10 5000.00 6087 5170.10 5100.00 6235 5270.10 5200.00 6386 5370.10 5300.00 1874.81 S 1262.34 W 1964.92 S 1321.23 W 2054.58 S 1382.38 W 2145.16 S 1442.91 W 2236.86 S 1509.27 W 823.33 46.34 870.26 46.93 917.83 47.57 965.72 47.89 1016.79 51.06 6539 5470.10 5400.00 6690 5570.10 5500.00 6834 5670.10 5600.00 6977 5770.10 5700.00 7120 5870.10 5800.00 2328.61 S 1577.99 W 2419.41 S 1647.05 W 2501.88 S 1708.69 W 2585.81 S 1766.53 W 2673.39 S 1820.08 W 1068.91 52.12 1120.63 51.72 1164.17 43.54 1206.99 42.82 1250.32 43.33 7264 5970.10 5900.00 7409 6070.10 6000.00 7553 6170.10 6100.00 7699 6270.10 6200.00 7844 6370.10 6300.00 2763.12 S 1871.78 W 2853.92 S 1923.48 W 2944.25 S 1975.70 W 3035.54 S 2028.92 W 3127.40 S 2082.37 W 1294.29 43.97 1338.93 44.64 1383.45 44.52 1428.95 45.50 1474.88 45.93 7991 6470.10 6400.00 8139 6570.10 6500.00 8285 6670.10 6600.00 8427 6770.10 6700.00 8566 6870.10 6800.00 3219.21 S 2136.66 W 3313.66 S 2191.44 W 3407.55 S 2242.88 W 3495.30 S 2290.82 W 3579.56 S 2337.70 W 1521.09 46.21 1569.16 48.07 1615.66 46.50 1657.09 41.43 1696.01 38.92 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 PRUDHOE BAY DRILLING PBU/12-34 500292251500 NORTH SLOPE COMPUTATION DATE: 11/23/94 DATE OF SURVEY: 111594 JOB NUMBER: AK-MW-40088 KELLY BUSHING ELEV. = 70.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8703 6970.10 6900.00 3660.20 S 2387.45 W 1733.78 37.77 8841 7070.10 7000.00 3738.70 S 2439.84 W 1771.29 37.51 8977 7170.10 7100.00 3815.67 S 2490.49 W 1807.27 35.99 9111 7270.10 7200.00 3890.75 S 2538.82 W 1841.34 34.07 9245 7370.10 7300.00 3965.53 S 2588.76 W 1875.83 34.49 9382 7470.10 7400.00 4041.38 S 2643.69 W 1912.84 37.01 9519 7570.10 7500.00 4116.73 S 2697.39 W 1949.09 36.25 9653 7670.10 7600.00 4191.65 S 2747.57 W 1983.75 34.66 9788 7770.10 7700.00 4265.41 S 2798.56 W 2018.07 34.32 9924 7870.10 7800.00 4339.96 S 2852.48 W 2053.95 35.89 10057 7970.10 7900.00 4412.77 S 2903.38 W 2087.72 33.77 10188 8070.10 8000.00 4479.95 S 2953.38 W 2118.17 30.45 10315 8170.10 8100.00 4542.98 S 3000.83 W 2145.55 27.38 10444 8270.10 8200.00 4607.03 S 3049.56 W 2173.92 28.37 10577 8370.10 8300.00 4676.21 S 3105.68 W 2207.88 33.95 10716 8470.10 8400.00 4749.71 S 3167.79 W 2246.67 38.80 10861 8570.10 8500.00 4824.76 S 3239.88 W 2291.03 44.36 11009 8670.10 8600.00 4899.68 S 3319.15 W 2339.02 47.99 11159 8770.10 8700.00 4974.04 S 3403.81 W 2389.68 50.66 11303 8870.10 8800.00 5042.77 S 3480.67 W 2433.33 43.65 11409 8942.77 8872.67 5092.50 S 3538.90 W 2466.23 32.90 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9167 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/29/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk D.S. 12-34 /~([ "'~"7 USlT (12-8-94) I 1 D.S. 12-34 -I'-I'''~ ]-) CBT (12-8-94) I 1 ,,oo D.S. 3-7 ~ (n- ~~ INJEC PROFILE (12-1-94) I 1 D.S. 5-11~~ ~~ DUAL BURST TDT-P (12-2-94) I 1 D.S. 9-8 ~ ~ - ~ INJEC PROFILE (12-5-94) 1 1 D.S. 11-36 ~ ~-~ SE~ING RECORD (12-1-94) 1 1 D.S. 14-4 ~ ~ ~~~ STATIC PRESS SURVEY (12-3-94) 1 1 D.S. 14-4 / ~~~ PROD LOG (12-6-94) 1 1 D.S. 17-19 ~/~ ~ STATIC PRESS SURVEY/JEWELRY LOG (12-10-94) I 1 D.S. 18-20 ~/~) DUAL BURST TDT-P (12-9-94) 1 1 , SIGNED: ~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: .~ . c LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 1 December 1994 Transmittal of Data ECC #: 6306.00 Sent by: MAIL Data: LDWG Dear Sir/Madam, Reference: ARCO DS 12-34 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below:~_ Tapes/Diskettes: 1 LDWG TAPE & LISTER Run # 1 Please sign and return las?Wire ervices 5~ B Street ,/,'Anchorage, AK 9951'8 / Attn. Rodh~¥ D. Paulson J / O FAX to (90-~F~5~-7803 Received by:~~ ~ ~ Date'S.. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 November 1994 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DS 12-34 DESCRIPTION 1 DIFL FINAL BL + RF 1 BHC FINAL BL + RF 1 SSTVD FINAL BL + RF Run # 1 Run # 1 Run # 1 ECC No. 6306.00 Please sign and return to:~Atlas Wireline Se~s ~00 B Str~e~t~/--~ ~Attn. Rodney D. Paulson /~ Or FAX to (907) 563-7803 Recelved D~~O ~~~ Date. 0 !::! I I__1__ I I~i G S EI:I~./I C ~ S -_ November 28, 1994 ARCO Alaska, Inc. AOGCC, Larry Grant PO Box 100360 Anchorage, AK 99510-0360 Re: Survey Data- Well 11-34 and 12-34 Dear Mr. Grant, Enclosed are two hard copies (each) of the MWD surveys on wells 11-34 and 12-34. Please call me at 563-3256 if you have any questions. Sincerely, Sandra Lufkin Region Assistant Enclosure. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company BP EXPLORATION R ska, Inc. To: Nabors 2ES Rig Supervisor _~.,,_~.:>~,2 0ii~,° Oas Cons. Commission PBU November 18, 1994 From: Zeljko Runje MB12-1 Prudhoe Bay Drilling Subject: Amen~iement #2 to an approved Well Plan for DS 12-~4i due to Potential Hazard #3 as stated in original well plan ( LOSt Circulation ) NOTE: The following plan was verbaly approved by Mr. B. Wondzel (AOGCC) at 14:30 hrs on 11/18/94. After 7" casing is set and cemenP( d please proceed as 1. Drill 6" production hole while maintaining inclination and azimuth as per Directional Plan or as necessary to achieve target. Short tdp as needed to condition and wipe the hole. Casing point will be picked by onsite geologist in conjunction with the drilling supervisor. Puli and clean the bowl protector on every trip to prevent sticking. . Circulate and condition hole for open hole logs. Short trip to at least the depth of the last bit trip. Drop survey and CBU, POH. Run logs as per the well plan summary. , TIH with BHA to circulate and condition the hole for running liner. Drop the appropriate rabbit attached to 120' .092 wire. SLM POH. Lay down BHA. 5. Pull wear bushing. 6. Change pipe rams to liner size (if needed) and test bonnet seals to :3,000 psi. CASING RUNNING PRE-JOB CHECKLIST · Tally all pipe as it is loaded on the pipe racks. Remove all thread.~rotectors, visually inspect threads for cleanliness and damage. Measure pipe from end of box to first full thread on pin end. · Drift casing while on rack. · Have float equipment, landing collar and mill end connections of float joints threadlocked. · Visually inspect float equipment to insure floats are clear of debris. · Install turbulators while pipe is on rack if possible. · If applicable, review the Chrome Handling Procedures to pick up and run the liner. · Have a safety valve (i.e.: full opening valve) made up to the cementing swedge on the floor for circulation and/or well control situations. · Have a mix water sample taken to test with cement blend. Verify mix water temperature with cementers, make arrangements to have water of correct temperature on location. · Ensure compatibility exists between cement arid mud and cement and spacers. . Rig up casing running equipment. Check calibration papers of casing tongs. Make sure that tieback line of power tongs is level and secured at a right angle to ensure accurate torque is being applied. Have at least one backup for power tongs, hydraulic unit, and elevator on location. .. STATE OF ALASKA ,~,_. ,~r,~ OIL AND GAS CONSERVATION COMMISSiL.,,~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend __ Operation Shutdown __ Re-enter suspended well Alter casing __ Repair well__ Plugging __ Time extension __ Stimulate Change approved program X Pull tubing__ Variance__ Perforate Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic Service Datum elevation (DF or KB) KBE = 69.16 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 631' NSL, 938' WEL, SEC. 18, TION, R15E At top of productive interval 9. N/A At effective depth 10. At total depth 491' NSL, 4560' WEL, SEC. 19, TION, R15E 12. Present well condition summary Total depth: Effective depth: measured 11409 feet Plugs (measured) true vertical 8943 feet measured feet Junk (measured) true vertical feet Well number 12-34 Permit number 94-137 APl number 50- 029-22515 11. Field/Pool Prudhoe Bay Field/Oil Pool ORIGINAL Casing Length Structural Conductor 80' Surface 3334' Intermediate Production Liner Perforation depth: measured None Size Cemented 20" 260 sx Arcticset (Approx.) 9-5/8" 895 sx CS 111/375 sx "G" true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Measured depth 110' 3365' NOV ?_'t !Y94 ui! & Gas Cons, gomm~ssior~ Anchor:., True vertical depth 110' 3324' 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 11/19/94 16. If proposal was verbally approved Name of approver B. Wondzeli 11/18/94 Date approved 15. Status of well classification as: Oil x Gas Suspended Service Signed ~/~,,~ ~ '~4F~ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test__ Subsequent form required 10- Original Signed By Approved by order of the Commission David W. Johnston I Approval Nc.c/..//_ Approved Copy Returned ommissioner uate :orm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 12-34i Well Plan, .~,~dum November 18, 1994 8. Run production 4.5" 12.6# L-80 NSCT liner as follows: . 11. 12. Float Shoe One (1) joint, production casing. Float Collar One (1) joint, production casing. Landing Collar Production casing to @ 9000 MD Hydraulic-set liner hanger Hydraulic-set liner top packer with tieback receptacle. TURBULATOR PLACEMENT & CASING RUNNING NOTES · Run two turbulators per joint over the entire production interval except for the joint that will be reciprocating in and out of the intermediate shoe. (1/8" under hole size) Do not run more than one turbolator per every third joint inside of 7" liner. · Liner hanger and packer should be pinned to _+2,500 psi and _+3,500 psi, respectfully. · Break circulation after liner is fully made up and note weight of liner in mud. · Ensure Driller knows the proper displacement volumes for the casing being run. · Test fillup system prior to running in the hole with casing. · Use Mercasol Multi-Make White thread compound on all connections. · Laid down all joints that do not make up within the specified torque ranges. '4-1/2" 17_.6# L-80 NSCT torque = 3,61 0-4,340 ft-lbs · Bring casing to a complete stop before setting slips. · Keep liner full while running in hole. · Monitor Pick-up and Slack-off weights while running hole. Record Hanging Weight, PU weight, and SO weights with casing on bottom. · Maximum pull at the liner should be 80% of the connection or pipe yield, which ever is less. · Monitor mud flow while running pipe in hole. If returns decrease or are lost, slow running speed. Break circulation before entering the open hole (do not exceed 1,500 psi at surface). Break circulation once the liner is on bottom. While circulating, tag bottom with the liner. Space out accordingly to get the cement head at a convenient height for reciprocating the liner. Begin reciprocating pipe 20' to 30' per stroke. Circulate and condition mud at least 3 annular volumes at 5-6 bpm or at a maximum surface pressure of 2,000 psi. Slow rate if lost circulation is encountered. Reciprocate the liner throughout circulating and cement operations. Cement the casing as follows: ao b. Batch mix cement per cementing page. (The dry additives should be premixed with the mix water in the batch mixer before adding the cement. The thickening.time does not start until the cement is added to the mix water.) Mix and pump specified spacer per cementing page. Follow the spacer with the batch mixed slurry. Drop drill pipe wiper dart. Displace the cement with mud using the rig pumps at 5-6 bpm ( This will give us AV of 350 ft/min. Ensure that liner is in bottom position as spacer rounds shoe. Wait until the cement starts out of the shoe before reciprocating. If returns are lost, do not reduce displacement rate. Slow pump rate to 3 bpm just prior to bumping the plug. DS 12-34i Well Plan .... ,dum November 18, 1994 With the liner on bottom (5 to 10 bbls before latch up), bump the plug to 3,000 psi to set liner hanger and then pressure up to 4,200 psi to set the liner top packer. (Do not overdisplace by more than 1/2_ the volume in the shoe joint) Bleed pressure to 800 psi. 13. Release from the liner hanger/liner top packer (turning to the right) and PU to break the cementing seal within the setting tool. Note the loss of pressure to indicate that liner is free (as well as loss of liner weight). Begin reverse out to circulate out excess cement. Monitor pressure/rate to determine whether liner top packer has sealed. If so, continue to reverse circulate out excess cement out of well and POOH. (If liner top packer is not holding, POOH immediately and RIH with an isolation packer). DO NOT PULL TEST ANY LINER TOP PACKER. CEMENT SUMMARY: Preflush' 20 bbls of water + 50 bbls of MCS-4 @ 1 ppg > mud weight Slurry: 250 sks ( 292 cf = 52 bbls ) Class G, 150 ghs BA-86L + 0.2% FL-33 0.6% CD-32 + 0.2% A-2 + 0.5% Gel + 1 ghs FP-6L at 15.7 ppg, yield = 1.17 cf/sk, mix water = 5.08 gals/sk, TTime = 2.5-3.0 hrs + 45 min surface, Fluid Loss < 50 CCs / min, C. Strenght 12 hrs = 2350 @ 24 hrs = 2800. REMARKS' Top of liner is assumed to be @ 9000' MD inside 7" OD csg set at 11400' MD. Annular Velocities - 300 ft/min at 4.6 bpm / 400 ft/min at 6.1 bpm. Drillin~ Engineer,,/ / Approved bY~rilling Superintendent ×C' N2ES Supervisor Well file Approved bY.Engineerm~ Supvervisor MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 4, 1994 THRU: Blair Wondzell, ~~ P. I. Supervisor FROM: Bobby Fos~~-- S UBJ EOT: Petroleum In~i~ector FILE NO: AEMIKDBD.doc BOPE Test- Nabors 2ES ARCO - PBU - DS 12-34i PTD # 94-0137 Prudhoe Bay Field Friday, November 4, 1994: I traveled this date to ARCO's DS 12-341 well being drilled by Nabors 2ES and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 failure. The kill line valve leaked. The valve was greased and cycled but would not test. The valve was replaced and tested OK. The H2S gas detectors were tested to the Iow level alarm worked OK. Due to not having enough test gas on hand to raise the percentage high enough~ the high level alarm could not be tested. I spoke with Charlie Henley, Nabors toolpusher, concerning this and he said he would get a new bottle ordered today and in the interm he would go to another rig and borrow their test gas bottle and test the alarm today and notify me of the results. I was notified that a 47 bbl. cement top job was done on this well. Good cement was circulated back to surface when the 80' top job was done. Summary: I witnessed the BOPE test on Nabors rig 2ES - test time 6 hours - 1 failure. Attachment: AEMIKDBD:XLS Friday, November 5, 1994: I was notified this date that the gas detectors had been tested and were OK. The HCR valve had been replaced and the replacement had tested OK. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initial X Workover: NABORS Rig No. 2ES PTD # ARCO Rep.: 12-34i Rig Rep.: Set @ 3365' Location: Sec. Weekly Other DATE: 11/4/94 94-0137 Rig Ph.# 659-4835/36 GENE BECK CHARLIE HENLEY 18 T. 1ON R. 15E Meridian U MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N lA Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 300/3,000 P 1 500/5,000 P 1 500/5,000 P I 500/5,000 P 1 500/5,000 P 2 500/5,000 P 1 500/5,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector note note FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes I 500/5,000 P I 500/5,000 P I 500/5,000 P Test Pressure P/F 500/5,000 P 14 36 500/5,000 P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2100 Functioned Functioned 3,100 I P 1,550 P minutes 22 sec. minutes 38 sec. YES Remote: YES Psig. Number of Failures: I ,Test Time: 6.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The kill line HCR valve leaked - was greased,cycled and retested - sSIi would not test - valve change out and retested OK NOTE: H2S detectors tested to Iow a/arm level - not enough test gas on iocat/on to do high alarm test Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) AEMIKDBD.XLS MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 30, 1994 THRU: Blair Wondzell, ~ P. I. Supervisor ,~/r/~ FROM: Lou Grimaldi, ~"~,~,c SUBJECT: .,I Petroleum Inspector FILE NO: EEMJJ4BD.DOC Diverter inspection Nabors rig # 2-ES Arco well # 12-34 Prudhoe Bay Field PTD # 94-137 Sunday, October 30, 1994: I witnessed the Diverter function test on Nabors rig #2-ES, drilling Arco well # 12-34 in the Prudhoe Bay Field. This is the first time that a Diverter was rigged up on Nabors 2-ES, this rig has never drilled surface hole before. The layout was done quite well with only a short section of 10 inch needed to extend beyond the knife valves at the bifurcation. A 5 foot section was added. The function test went well with a quick closure time of 24 seconds and a full recharge of the accumulator in 1 minute 25 seconds. I discussed Diverter procedures with Charles Henley (Nabors toolpusher) and his crew, a Diverter drill will be staged before they begin to drill surface hole. SUMMARY: I witnessed the first Diverter function test on Nabors rig #2-ES. Attachments: EEMJJ4BD.XLS cc: Drilling superintendent (Prudhoe Bay Drilling) ~--~TATE OF ALASKA ALASKA OIL A. GAS CONSERVATION COMMISS,,..,~I Diverter Systems Inspection Report Operation: Drlg Contractor: Nabors Rig No. Operator: Arco Alaska Inc. Oper. Rep.: Well Name: '12-34 Rig Rep.: Location: Sec. 18 T. 10N R. 15E Development 2-ES PTD # Date: '10-30-94 X Exploratory: 94-137 Rig Ph. # 835/4837fax Nick Scales Charlie Henley Merdian UMIAT MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3000 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1700 psig Reserve Pit: OK Flare Pit: N/A 200 psi Attained After Closure: 0 min. 29 sec. Systems Pressure Attained: 1 min. 25 sec, DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: Four 2100 Diverter Size: 20 in. Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 in. Vent Line(s) Length: 60 ft. Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES MUD SYSTEM INSPECTION: Light Alarm Trip Tank: X X Mud Pits: X X Flow Monitor: X X GAS DETECTORS: Light Alarm Methane Y Y Hydrogen Sulfide: Y Y psig [-~--~ater Inj. Non Compliance Items 1 Repair Items Withi N/A Day (s) And contact the Inspector @ 659-3607 Remarks: First time rigup of diveder on this rig. Good layout Distribution orig. - Well File c- OpedRep c- Database c- Trip R~_~'~ (Rev. 7/93 c- Inspector AOGCC REP.: EEMJJ4BD.XLS OPERATOR REP.: Louis R Gr#naldi Charles Henley ALASKA OIL AND GAS CONSERVATION .COMMISSION October 21, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCItORAGE, AI~SKA 99501-$192 PIIOINE: (907)279-1433 TELECOPY: (907)276-7542 Terry Jordan Drilling Engineer Supervisor ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 12-34 ARCO Alaska, Inc. Permit No: 94-137 Sur. Loc. 631'NSL, 938'WEL, Sec. 18, T10N, R15E, UM Btmhole Loc. 491'NSL, 4560'WEL, Sec. 19, T10N, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairma~ ~ BY ORDER OF COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA fOIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillOllb. Type of well. ExploratoryD Strut/graphic Test [] Development Oil [] Re-Entry [] DeepenI-iI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 69.16 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. 0. Box 196612. Anchorac;e. Alaska 99519-6612 ADL 28330 4. Location of well at sudace 7. Unit or property Name 11. Type Bond(~,e 20 Mc 25.025 631'NSL, 938' WEL, SEC. 18, TION, R15E Prudhoe Ba~/ Unit At top of productive interval 8. Well number Number 754' NSL, 4385' WEL, SEC. 19, TION, R15E 12-34 U-630610 At total depth 9. Approximate spud date Amount 491' NSL, 4560' WEL, SEC. 19, TION, R15E 10/22/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. P~:oposed depth (Mo and 'rVD) property line ADL 28335-491' feet No close approach feet 2560 11819'MD/9110' TVD feet 1 6. To be completed for deviated wells 17. AnticiPated pressure (~ 2o A^C 25.035 (e)(2)) Kickoff depth ~oo feet Maximum hole an~lle4¢.9~ o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) .... 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 40# NTaOLS NSCC 3370' 28' 28' 3370' 3200' 853 sx CS ll~'400 sx "G"/250 sx CS # 8-1/2" 5-1/2" 17# .-aO/N-aO BTC 11819' 27' 27' 11819' 9287' 848 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Conductor Sudace Intermediate OCT '~ 7 Production Liner j~j~$ki~, Oil & Gas Cons. Commission Perforation depth: meaSured Anch0ra._,e true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis l'-I Seabed report[-I 20 AAC 25.050 requirements[] 121. I hereby ced..~ y that the foregoing is true and correct to the best of my knowledge Signed Title DH/ling Engineer Supervisor Date /g-//-- / / (,,_/' Commission Use Only Number IAPI number IApproval date ISee cover letter Permit, t~.~(,_//,...,~ ~ J50- O .~..,,~' -- ~ ~-- ...~/"-...5-' J /~),,,,,q / .,- ~'~" Jfor other requirements Conditions of approval Samples required [] Yes ~No Mud log required []Yes..J~ No Hydrogen sulfide measures I-1 Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; 'I~[5M; I-I10M; I-i15M; by order of Other: Original Signea By Commissioner [ne commission Date Approved by Rmlid t/~I Inhnqfnn . Form 10-401 Rev. ) Submit in Well Plan Summary [Well Name: Type of Well (producer or injector): ! DS 12-34i Pre-produced WAG Injector [ Surface Location: Target Location: Bottom Hole Location: 631' FSL 938' FEL Sec 18 T10N R15E UM 754' FSL 4385' FEL Sec 19 T10N R15E UM 491' FSL 4560' FEL Sec 19 T10N R15E UM i AFE Number: i Estimated Start Date: IMD: i 11819' I Well Design (conventional, slimhole, etc.): 14J0252 ! I Rig: I Nabors 2-ES I ! Oct 22, 1994 I [.Operating days to complete: I 1S I ITVD: 19218ss' I IRT'GLI I I KBE: 69.16' [ Ultraslim hole injector ] Formation Markers: Formation Tops MD TVDss K-15 5213' 4459' Top Ugnu 6662' 5503' West Sak 7604 6181' K-12 Absent Absent K-10 8642' 6929 K-5 9715' 7702' Sag River 11226' 8791' Top Shublik 11265' 8819' Top Sadlerochit 11364' 8890' Top Zone 2 11748' 9167' TD 11819' 9110' Casing/Tubin: Program: Hole Size Wt/Ft Hole Size Csg/ Wt/l~t Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' 30'/30' lift/il0' 12.25" 9-5/8" 40g NT-80LS NSCC 3370' 28/28 3370'/3200' 8.5" 5.5" 17# L-80/N-80 BTC 11819' 27'/27' 1181979287' N/A 3.5" Coil 7.148# L-80 N/A -9000' 29'/29' 9000'/7400' Tubing Equipment D,x E (~ [ Ill, · ~. ~..,~ Ih Well Plan Summary OCT ] ? 1994 ~asha Oil & Gas Cons. Commission gnchora.,~: I Logging Pro8 [Open Hole Logs: 12-1/4" Hole 8-1/2" Hole Cased Hole ram: None GR/DIL/BHCS. If possible will run nuclear logs while drilling if not will mn DP conveyed lo~s. Cement bond lo[[ to 500' above top of Sadlerochit Mud Program-. [Special design considerations I None Surface Mud Properties: [ SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 200 30 30 40 9 15 to to to to to to to 9.5 300 60 60 80 10 25 Intermediate Mud Properties: ! N/A Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss N/A Production Mud Properties: [LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 25 8 3 7 8 5 to to to to to to to 9.8 50 13 10 15 10 10 NOTE: Keep annular velocities around drill pipe at or above 220 ft/min wherever possible Directional-. IKOP: l~600' [ Maximum Hole Angle: !43-91° I Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressur~s.r.[~l. C I~'lr! V E r~ Diverter, BOPE and drilling fluid system schem atics on file with AOGCC. ( Also all are enclosed here) OCT I 7 1994 Well Plan Summary ~,iaska Oil & Gas Cons. Commission PROPOSED DRILLING AND COMPLETION PROGRAM WELL DS 12-34i EOA PBU 1. MIRU. NU diverter and function test same. . Drill 12.25" hole to surface casing piont. Run and cement 9-5/8", 4045, NT-80 Buttress casing to surface. . Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Function test BOPE to 5000/250 psi. . P/U 8.5" drilling assembly and RIH. Test 9-5/8" casing to 3000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 9-5/8 csg. . Drill 8.5" hole to TD ~ 11819'MD / 9218' TVDss. Primary objective is to log with LWD from 200' above top of sadlerochit to the base of same. If not possible then will log via DP conveyed method. Will perform conditioning trip after wireline logs. 6~ Will run and cement 5.5" 17# production casing. Bump plug with seawater. Test casing to 3500 psi for 30 minutes. 7~ RIH with 3.5" DP to 2000' and displace seawater with diesel for freeze protection purposes. POOH and L/D 3.5" DP. 8. F/P top of 5.5" x 9-5/8" annulus with 50/50 methanol water mixture. 9. N/D BOPs. N/U dry hole tree and test same. 10. Release the Nabors 2ES 11. MIRU E-Line and run cement bond log to 500' above top of Sadlerochit. 12. MIRU CTU and perform CTU Completion. Note: Maximum anticipated BHP = 3700 psi. Well Plan Summary RECEIVED OCT 1 7 1994 Alaska 0il & Gas Cons. Commission Anchom,,]. DS 12-34i Cement Plan Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement: 9-5/8" SURFACE CASING 9-5/8", 40# 38°F 50 bbls fresh water ahead of lead slurry Coldset III Additives: Retarder Weight: 12.2 ppg Yield: 1.92 cuft/sx Volume (sacks): 853 Mix Water: 10.5 gps Thickening Time: > 4 hrs @ 50°F Class G Volume (sacks): 400 Additives: 2% A-7, FP-6L lghs Weight: 15.8 ppg Mix Water: 5.0 gps Yield: 1.1 5 cuft/sx Thickening Time: >3-1/2 hrs @ 50°F Top Job: Coldset II Volume (sacks): 2 5 0 Additive: Retarder Weight: 15.6 ppg Mix Water: 3.7 gps Yield: 0.95 cuft/sx Thickening Time: >2 hrs @ 50°F Cement Volume Summary: (1) Lead slurry to surface w/ 100% excess (2) Tail slurry volume: 400 sx, (to cover at least 500' of casing shoe w/100% excess + 80' shoe vol.). (3) Top job volume 250 sx (fixed volume) 5-1/2" LONGSTRING CASING Casing Size: Circ. Temp.: Spacer: 5-1/2", 17# 140OF 70 bbls of MCS-4 Spacer weighted I ppg above current mud weight Lead Cement: Class G Volume (sacks): 398 Additives: A-2: 3%, FL-52: 0.4%, CD-32: 0.5%, FP-6L: l ghs Weight: 11.0 ppg Mix Water: 20.92 gps Yield: 3.31 cuft/sx Thickening Time: >5 hrs @ 140°F Fluid Loss: 150-250 cc Free Water: 0.0 cc Tall Cement: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 450 A-2: 0.1%, FL-52: 0.3%, CD-32: 0.5%, FP-6L: lghs 15.8 ppg Mix Water: 4.85 gps 1.14 cuft/sx Thickening Time: 3.5 - 4.5 hrs @ 140°F 100-150 cc Free Water: 0.0 CC Cement Volume Summary: (1) Lead Slurry to 500' MD above top of Cretaceous with 30°1o excess (2) Tail Slurry to 500' MD above Top of Sag River with 30% excess plus 80' of 5-1/2', 17# capacity for float joints Z.R / October 17, 1994. RECEIVED OCT 1 7 Alaska Oil & Gas Cons. Commission Anchor~. PRUDHOE BAY DRT LLTNB GROUP MDr~.'r I8eni ~ f ~r. 8t ~o,q w,;, N/r4 E/K B) XOP,'SU~L~ ~.5/100 ~63~ 0 C) CUR~ ~'.5/~OO ~DOG 6 6 O) ENO ~¢ 2;.5/100 CURVE 3350 5~7 36 F] ....... TARGET ....... J ~36~ 5J 56 3428 Gl 7' CA~iNG POINT J~SJB 5~20 3502 H) TD ~8~g 5~20 3602 DS 12-34 (PS) PLAN VZEN CLOSURE ' 6508 feet at Azjmutrl 2,~3.52 DECLINATION.: 29.524 E SmA,~ · i jr, ch = g00 feet DR~WN ....... : 09/21/94 - 450 i' J il 5E50 5~00 i~950 4500 '-,DO FT TAP',GET .bAD Ii 2700 2250 _ _ _ ] ski Oil 0 i450 , gOo ........ J35 700 ' 3:50 3500 I a05O ~", I'" ! ~J' r' I'~ I 4500' i : zoSC T ,1 7..1.9.94--~ : . Gas Coris~ CommiSsion ' Anchor~,,,~ ~ D~c,o 4050 I 3500 3'.,50 I !BO0 350 200 i ' 5650 450 0 ~50 ~- ~EST · EAST -> PRUDHOE BAY DRTLLING GROUP <KB> o I A 600 ~200 5400 · - ~'=~i ...... 720O I , DS ~P-34 (PS) VERTICAL SECTION VZEW i I ! 7800- 2~3.48 inch - ]200 feel inch = ~200 feet 09/2]/9~ Section mt: TVO Scale.: Oep Scale.: Dn8wn ..... : Anadr.J ] ] S£h } umberger Marker Ioent:f)cat)on MD BKE SECiN A) KB 0 O 0 B) KOF/BUILD 2.5/~00 ~600 1500 -0 C) CURVE 2.5/~00 ~800 !800 D) ~ND ~ 2.D/:CO CURvC 5360 E) ~-5/8" CASING POIN? ~370 3200 FI ....... IARGEi ....... ~3E.~ B959 6~92 G) 7' CASING POINi ~B~9 92~7 650B H) TD 11B~9 ~287 6508 : ] lr;CLN o .oO 0.00 5.00 43.~t 43.e~I 43.9~, 240,2 3000 ~ ~t,ion De~anture I i i iAWska 011 & ~ns. Commissio~ 'i. . ........ :: :~ ........z ..=;_ 3500 ~200 4B00 5~00 6000 6500. 7200 7800 I]OP 5T,Z~K E1E'~AIlON 5Ut'~FACE DI~,RTER BIFURCATED ([ slwtrl~irl T'-'~-'l I,,/F-.T---~- ~, i -J-l-l-C~" .-----~ -' 4..'_; ............................................................... ....... ............... ..................................... ...................... II ;-I '-- ~ :.-::_~:z::z::-7..::'. '~ r"'=':~--:'.,-:,-,--':'-~ :~.~:~-~--`.:L~:-.`--~.`~.:~-.--.~--..~:~---~u-~---~-~-~::.-:-...~:.:-~.:~:-:`-: // I'--F---frei, . I/ j / ': ~..-_: '~- ::.'- r_=:_~ ::.: ~l-- ~---,1: :..-,'---:---,:---~-- :'~ :1"1~1:.,-:---,-- :,-'~,:--::/.: ILl I / ......~ ........ I'"t t"' a'r~,:~ ~.' / I,,,l,-~,,om,,, ! II:,,,~,~I ! t I/ .-I',. .... ........... '-, /I I 'J ....................................................... I' --Lg(~ ~0- ~[$-.~001 ~11 ~_.,,/ ............. · --~-- . ....... !.. . I ". ! r ., ,t.]-., -- ............... \ -1 , ..,.__, , ..... l,- ......... Ii ........... ~ ........... I .......... ~ ,i _--. ,I I/ I [ ............................................. L____J I'?.~ ..... i ................ ,~:--i-H:~.; ,-~--_---F:".'--'r,~: 'i'-"'"L~.-..!~x,'-7---~'/ ..! .................................................... cu, ::,¢: I .--. I ,:-, ~ I /I ~kI~ C-- J -- ' I ~!(._.~,~l/~.~j ..... 7'~" 1'--I/I--'1 / 'J" C[.l'tTIRIf'lJ6£ ' I ~I,E! ~ ,, , ,, ,.., , : I . ( ,..: -.- m,.= ~.~ I '19~ iii! iii r.__; ............... ,..__l ....... .' .... ~ ....... -' I~ ....... I I '!i i{i!.i~i ...... r--r.-l ...... [ ..... m-~ ';: .:. ,,-~I '~--~: I I / I - !. I'.'--:,":P ''~ :':. ':- '. ~ t :~ ~:Z': II'~- ........... : ' ! / J?.l l I I- " I I I ..... I Il 6 I Il I r: I i:UMi, ~ 1~ I IqJUP I ~, t §' PUMP COMPAR1 ~I'_HI C:APACI'IY COMPARIUENI (".5 · . (!.) it) WELL PERMIT CHECKLIST COMPANY .,,~ c_-~ ~N~ cms /-~.~,~. ADMINISTRATION 1. 3. 4. 5. 6. ' 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE__~m~ 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation p~oposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~d~,~ psig 27. Choke manifold complies w/API RP-53 (M~y 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N / 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... y../ N 33. Seabed condition survey (if off-shore) ............ ~ N 34. Contact name/phone for weekly progress reports . . . ~/~ Y N [exploratory only] / GEOLOGY: ENGINEERING: COMMISSION: TaB ~ Comments/Instructions: "' '-',~,tist rev 03194 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.S. 12 - 34 O ALASKA INC PRUDHOE BA RECEIVED DEC 02 ~5~/ OH & Gas Cons. Cornrnls~ Anch~ Run 1' 22 - November - 1994 DIFL/AClGR 11304 1778 M-I CI G L F n , ,SR m Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6306.00 BRAD ESARY SEE REMARKS REMARKS: D.S. 12 - 34 500292251500 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 30-NOV- 94 OPEN HOLE RUN 2 RUN 3 18 10N 15E 631 938 70.80 69.40 40.38 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 11326.0 8.500 11409.0 6.000 11800.0 DIFL/AC/GR. CIRCULATION STOPPED AT 2200, 21-NOV-94. LOGS WITNESSED BY: E. POTTER & A. MARSDEN. LOG DATA FROM CASING SHOE AT 11304' TO 11372' IS FROM DOWN PASS. UNABLE TO PULL CABLEHEAD INTO CASING SHOE. TOOLS FISHED BY CUT AND THREAD. GAMMA RAY AFTER LOG VERIFICATION & ACOUSTIC AFTER LOG CASING CHECK NOT PERFORMED. LOST TOOL SIGNAL WHILE ATTEMPTING TO PULL INTO CASING SHOE. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (8.5" to 11409' & 6.0" to T.D.). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL $ depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 11304.0 11731.0 11304.0 11749.0 11304.0 11778.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA EQUIVALENT UNSHIFTED DEPTH - BASELINE DEPTH DT LL8 ILD SP 11308.5 11308.0 11309.0 11309.0 11314.0 11314.0 11325.0 11325.0 11327.0 11326.5 11329.5 11329.5 11346.0 11346.0 11353.0 11353.0 11363.5 1~363.5 11380.5 11380.5 11383.0 11382.0 11383.5 11382.0 11390.0 11390.0 11390.5 11390.5 11394.0 11393.5 11402.0 11401.0 11402.5 11401.5 11401.5 11411.5 11411.0 11410.5 11431.5 11431.0 11445.0 11445.0 11447.5 11447.0 11448.0 11448.5 11449.5 11449.5 11453.0 11453.5 11461.0 11460.5 11462.0 11462.0 11467.5 11466.5 11468.0 11467.5 11468.5 11468.5 11469.0 11469.0 11470.5 11469.5 11471.0 11470.0 11473.0 11473.5 11474.0 11477.0 11475.5 11477.5 11477.5 11481.0 11479.5 11485.0 11488.0 11487.5 11488.5 11488.0 11498.5 11498.5 all runs merged; 11394.0 11470.5 11483.5 no case 11500.0 11500.5 11501.5 11504.5 11505.0 11505.5 11506.0 11512.0 11512.5 11513.5 11514.5 11532.5 11533.0 11536.0 11538.0 11539.5 11542.0 11542.5 11543.5 11547.0 11548.0 11551.0 11555.0 11557.0 11558.5 11562.5 11563.0 11564.0 11565.5 11566.0 11571.5 11572.0 11575.0 11591.0 11605.5 11611.0 11611.5 11612.0 11612.5 11614.0 11615.0 11615.5 11619.0 11619.5 11629.5 11630.5 11645.5 11646.0 11653.5 11663.0 11666.5 11667.0 11668.0 11684.5 11685.0 11707.5 11708.5 11712.0 11723.0 11725.5 11505.5 11532.5 11619.0 11646.0 11666.0 11684.0 11712.0 11505.0 11532.0 11557.5 11620.0 11670.0 11685.5 11725.5 11501.5 11502.5 11503.0 11504.5 11512.5 11513.5 11514.5 11515.0 11538.0 11539.5 11543.0 11543.5 11544.0 11547.5 11548.0 11551.0 11561.0 11561.5 11562.0 11563.5 11565.5 11571.0 11572.0 11605.5 11610.5 11611.0 11612.0 11612.5 11613.0 11614.0 11615.0 11629.0 11653.5 11663.0 11708.0 11709.0 11500.0 11535.0 11553.5 11557.0 11574.5 11591.0 11619.5 11631.5 11646.5 11666.5 11685.5 11722.0 11727.0 11727.5 11730.0 11745.5 11746.5 11747.5 11749.0 11769.0 11769.5 11770.0 11770.5 11772.5 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. GR 1 BCS 1 DIL 1 $ REMARKS: MAIN PASS. 11745.0 11746.0 11746.5 11748.0 11768.5 11769.0 11770.0 11770.5 11773.0 11726.5 11730.5 PASS NO. MERGE TOP MERGE BASE 4 11304.0 11731.0 4 11304.0 11749.0 4 11304.0 11778.0 TEND, TENS, & MTEM, WERE SHIFTED WITH LLS. ILM, RT, & DI WERE SHIFTED WITH ILD. CN WN FN COUN STAT ??MATCH1. OUT ?MATCH2. OUT ??MATCH3. OUT ?MATCH 4. OUT : ARCO ALASKA INC. : D.S. 12-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: 1 2 3 4 5 6 7 8 9 10 11 Name Tool Code Samples Units GR BCS 68 1 GAPI DT BCS 68 1 US/F TEND BCS 68 1 LB TENS BCS 68 1 LB LL8 DIL 68 1 OHMM ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM RT DIL 68 1 OHMM DI DIL 68 1 IN SP DIL 68 1 MV MTEM DIL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 71 023 23 6 * DATA RECORD (TYPE# 0) Total Data Records: 49 1014 BYTES * 44 Tape File Start Depth = 11807.000000 Tape File End Depth = 11295.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12301 datums Tape Subfile: 2 264 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 4 .2500 VENDOR TOOL CODE START DEPTH GR 11300.0 AC 11300.0 DIFL 11300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 11750.0 11768.0 11797.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL CENT $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC-ACOUSTILOG DUAL INDUCTION CENTRALIZER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): 22BNOV--94 FSYS J1V2 BETA RELEASE 4 2200 21-NOV-94 514 22-NOV-94 11800.0 11786.0 11304.0 11778.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 4304NA 6.000 11326.0 11304.0 BIO-P 9.00 42.0 10.6 5.0 187.4 1.660 .590 62.0 187.4 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 12-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA 1.500 62.0 .000 .0 2. 180 62.0 .000 .0 .00 .000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 SPD AC 68 1 F/MN 4 11 RFOC DIFL 68 1 OHMM 4 12 RILM DIFL 68 1 OHMM 4 13 RILD DIFL 68 1 OHMM 4 14 CILD DIFL 68 1 MMHO 4 15 VILD DIFL 68 1 MV 4 16 VILM DIFL 68 1 MV 4 17 RT DIFL 68 1 OHMM 4 18 DI DIFL 68 1 IN 4 19 SP DIFL 68 1 MV 4 20 TEMP DIFL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 40 467 34 0 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 171 Tape File Start Depth = 11807.000000 Tape File End Depth = 11295.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 43030 datums Tape Subfile: 3 249 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 3 .2500 VENDOR TOOL CODE START DEPTH GR 11571.0 AC 11571.0 DIFL 11571.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 11750.0 11768.0 11797.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL CENT $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMARAY BHC-ACOUSTILOG DUAL INDUCTION CENTRALIZER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 22-NOV-94 FSYS JlV2 BETA RELEASE 4 2200 21-NOV-94 502 22-NOV-94 11800.0 11786.0 11304.0 11778.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 4304NA 6.000 11326.0 11304.0 BIO-P 9.00 42.0 10.6 5.0 187.4 1.660 .590 1.500 .000 62.0 187.4 62.0 .0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 12-34 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) 2. 180 62.0 .000 .0 .00 .000 1.5 ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 TlR1 AC 68 1 US 4 5 TlR2 AC 68 1 US 4 6 T2R1 AC 68 1 US 4 7 T2R2 AC 68 1 US 4 8 CHT AC 68 1 LB 4 9 TTEN AC 68 1 LB 4 10 SPD AC 68 1 F/MN 4 11 RFOC DIFL 68 1 OHMM 4 12 RILM DIFL 68 1 OHMM 4 13 RILD DIFL 68 1 OHMM 4 14 CILD DIFL 68 1 MMHO 4 15 VILD DIFL 68 1 MV 4 16 VILM DIFL 68 1 MV 4 17 RT DIFL 68 1 OHMM 4 18 DI DIFL 68 1 IN 4 19 SP DIFL 68 1 MV 4 20 TEMP DIFL 68 1 DEGF 4 4 06 969 49 4 48 852 89 4 81 285 47 4 81 285 47 4 81 285 47 4 81 285 47 4 81 285 47 4 95 558 30 4 95 558 30 4 61 094 30 4 27 515 24 4 06 213 78 4 04 903 06 4 34 704 23 4 04 522 10 4 04 522 10 4 04 903 06 4 06 213 78 4 53 419 67 4 40 467 34 80 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 81 Tape File Start Depth = 11807.000000 Tape File End Depth = 11567.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 32483 datums Tape Subfile: 4 157 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile 5 is type: LIS 94/11/29 01 **** REEL TRAILER **** 94/11/30 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 30 NOV 94 2:21p Elapsed execution time = 4.95 seconds. SYSTEM RETURN CODE = 0
