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176-030
RECEIVE() STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERAS APR 3 0 2018 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatio s ❑inI Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change 1 p r• dPFbg"rdfn ❑I. Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to Producer l 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-030 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 • AK 99519-6612 Stratigraphic 0 Service RI 6. API Number: 50-029-20207-00-00 7. Property Designation(Lease Number): ADL 028325&028324 8. Well Name and Number: PBU 04-09 1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: ! PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12050 feet Plugs measured 11550 feet true vertical 9116 feet Junk measured None feet Effective Depth: measured 11550 feet Packer measured 10518,10712 feet true vertical 8707 feet Packer true vertical 7933,8065 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33-113 33-113 1530 520 Surface 2627 13-3/8" 31-2658 31 -2658 5380 2670 Intermediate 11060 9-5/8" 30-11090 30-8339 8150/6870 5080/4760 Liner 912 3-1/2" 10786-11698 8116-8829 10160 10530 Liner 1264 7" 10786-12050 8116-9116 8160 7020 Perforation Depth: Measured depth: 11462-11865 feet True vertical depth: 8635-8968 feet SC A\IHED JUN 1 1 2 Q'1 a Tubing(size,grade,measured and true vertical depth) 5-1/2"17#/4-1/2"12.6#L-80 27-10681/10692-10816 27-8043/8051-8138 ! Packers and SSSV(type,measured and 5-1/2"Baker S-3 Packer 10518 10712 true vertical depth) 4-1/2"BOT 3-H Perm Packer 10712 8065 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 787 Subsequent to operation: 480 21731 21 0 1987 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-601 Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FS2 eti'P Contact Email: Bernhard.Stechaunerabp.com r� p Authorized Signature: . ---Date: L{/3 v/w Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 A 1:/4 V V`t' Co/' `1 el RgDMMAY 0 1 Z018 Submit Original Only • Daily Report of Well Operations PBU 04-09 ACTIVITYDATE SUMMARY LRS test unit 1 Inlet 04-09 Outlet 04-41 Flowback Injector-Conversion to Producer/ Opportunistic Flow. Begin WSR 4/19/18 Unit Move to DS4, Rig Up PT,. Continue on WSR 4/19/2018 4/20/18. LRS test unit 1 Inlet 04-09 Outlet 04-41 Flowback Injector-Conversion to Producer/ Opportunistic Flow. Continue from WSR 4/19/18 Complete PT, POP well, Flow and 4/20/2018 stabilize. Continue on WSR 4/21/18. LRS test unit 1 Inlet 04-09 Outlet 04-41 Flowback Injector-Conversion to Producer/ Opportunistic Flow. Continue from WSR 4/20/18 Continue to flow and stabilize well. Start 4/21/2018 12 hr Test. Continue on WSR 4/22/18. LRS test unit 1 Inlet 04-09 Outlet 04-41 Flowback Injector-Conversion to Producer/ Opportunistic Flow. Continue from WSR 4/21/18 Complete 12 Hr test. Continue to flow and 4/22/2018 stabilize well. Begin 12 Hr Test. Continue on WSR 4/23/18. LRS test unit 1 Inlet 04-09 Outlet 04-41 Flowback Injector-Conversion to Producer/ Opportunistic Flow. Continue from WSR 4/22/18 Complete 12 Hr test. Continue to flow and 4/23/2018 stabilize well. TREE= , 5"X7•L FMC 120 NOTES:H2S READINGS AVERAGE 125 WH(HEAD FMC • 04-09 i WHEN ON MI.WELL REQUIRES A SSSV ACTUATOR= BAKER C KB.ELB/= 52.0' WHEN ON ML DEPTH DISCREPANCY BETWEEN BF.aEV= 32.16' BTM OF 5-1/2"SEAL ASSY AND TOP OF BOT PBR KOP- 3300' SEAL ASSY WAS INSERTED AM)TBG SPACED Max Angie= 61'Q 7579' OUT PER RIG REPORT. Datum MD= 117.26' __.... Datum TVD= 8800'SS 2236' 5-1/2"CAMCO BAL-O SSSV NP,D'4.562" 562„ 9-5/8'FOC 2363' —- - - -, 2613' -19-5/8"FCC 13-3/8"CSG,72#,MN-80,D=12.347" 2654' Minimum ID = 2.992"@ 10786' 4112" NO-GO SETTING SLEEVE I I 10489' H5-1/2 HEBXNP,D=4.562" Z X 10511' H9-5/8"X 5-1/2"BKR S-3 PKR,D=4.750 I I 10618' -15-1/2"HES XN NP,D=4.455• 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892' H 10679' NOTE:TBG GAP BETWEEN 10686'-10692 I 10692' J5-1/2•BOT PBR ASSY,7"X 6" 5-1/2'TBG SEAL ASSY w/SEALS,D=4.75" 106$$' -� I PRORATION SU MAARY S� 10711' -19-5/rX 5-1/2'BOT 3-H PKR G. RIF LOBRCS ON 05/02/76 "� 10722' H 5-1/2'X 4-1/2"XO,D=1958' ANGLE AT TOP PERF: 36° ' 11462' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11462-11472 0 12/16/16 2-1/2• 6 11478-11493 0 04/01/17 2-1/2" 4 11580-11600 C 12/14/97 4 10786' {7"BKR MC LNR HGR 4 11600-11620 C 10/04/97 10786' H4-12'NO-GO DEFLOY SLV,D=2.992"l i v. 6 11620-11622 S 06/26/96 10802' H4-12"CAMCO DB NP,D=3.813" 11629-11635 S 06/26(96 2-1/2" 6 11635-11654 C 11/17/01 10814' H4-1/2'TBG,12.6#,L-80,_0152 bpf,D=3.958" 2-1/2" 6 11666-11674 C 03/15/06 / \ 10815' -14-12"TUB/UG TAL(B13-N3 CT LINER) 2-1/2* 6 11682-11696 C 03/15/06 2-7/8' 4 11752-11792 C 09/30/90 10799' H ELM)TT LOGGED 06/29/85 1 3-3/8" 10 11807-11824 C 06/29/85 3-3/8" 10 11840-11865 C 06/29/85 L k-rx1 9-5/8"CSG,47#,MN-80,D=8.681" H 11090' ### '1I 11b60'� B 312"CP(12J1s/1s) 111 11111 ►1111 13-1/2'LNR-CT,9.3#,L-80,.0087 bpf,D=2.992" 11697' *AV 3-12"DAVIS LYNCH DOUBLE VALVE SHOE -1 11698' M • 11957' PI- 7'LNR, 29#,L-80..0371 bpf,ID=6.184" -1 12050' 4�/.111�/.1�1�1, TD H 12053' 1111111 DATE REV BY COMMENTS DATE REV BY COI/ANTS PRUDHOE BAY UNIT 05/11176 ORIGINAL COMPLETION 02/02/17 JUJMD CORRECTED TBG SEAL ASSY WELL: 04-09 05/22/85 MATO 04/03[17 MS/JMD ADPERFS(04/01/17) FERMT No:'1760300 08/19/01 CWKAK MATO AR No: 50-029-20207-00 12/20/16 JR/JMD SET CTB(12/19/16) SBC 27,T11 N,R15E 325'FSL&643'F EL 12/29/16 JUJMD PULL FISH-SHOW AR GAP 01/05/17 JUJMD CORRECTED D AR GAP TO TBG GAP BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,April 18, 2018 4:42 PM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA); Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer 04-09 (PTD#1760300) Injector to producer conversion approved with sundry#317-601 Attachments: Sundry_317-601_011718.pdf All, Well 04-09(PTD#1760300)was made not operable on 10/9/2017 for lapsing its 2 year AOGCC witnessed MIT-IA. The well was approved for injector to producer conversion on 01/17/2018 under sundry#317-601. The well no longer requires AOGCC witnessed MIT-lAs and is hereby reclassified as Operable with well type Producer. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 ,Iro -wr w...«7wt«r. 1 L OF T$ gwP��\I/7:,v THE STATE • Alaska Oil and Gas h 0f® LT Conservation Commission ASJL"�1�1C�1 . = � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �R\ Main: 907.279.1433 L 4A5It' Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner • FS2 Lead PE SCAMED ``F ' BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-09 Permit to Drill Number: 176-030 Sundry Number: 317-601 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P. 'oerster Commis ioner DATED this 17 44- y of January, 2018. RBDMS Lv JAN 1 8 2618 STATE OF ALAS ' •ALASKA OIL AND GAS CONSERVATION COMMON • APPLICATION FOR SUNDRY APPROVALS 7E-_r 2 2 -017 20 AAC 25.280 J 1 0 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 O rtAi n h down 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Convert to Producer I 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 176-030 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 6. API Number: 50-029-20207-00-00 - 99519-6612 Stratigraphic 0 Service RI' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Il PBU 04-09 , 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028324/ADL 02831-50 0 ze7Z j- /4-,...z4,,/7 PRUDHOE BAY,PRUDHOE OIL • 11. ' - PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12050 • 9116 ' 11550 8707 11550 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 33-113 33-113 1530 520 Surface 2627 13-3/8" 31-2658 31-2658 5380 2670 Intermediate 2394 9-5/8" 30-2424 30-2424 8150 5080 Intermediate 8680 9-5/8" 2424-11104 2424-8349 6870 4760 Liner 1269 7" 10788-12057 8118-9122 8160 7020 Production Liner 915 3-1/2" 10783-11698 8115-8829 10160 10530 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11452-11493 8635-8661 5-1/2"x 4-1/2" L-80 x L-80 27-10681/10717-10816 Packers and SSSV Type: 9-5/8"x5-1/2"S-3/9-5/8"x5-1/2"3-H Packers and SSSV MD(ft)and TVD(ft): 10518,7933/10712,8065 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary I2I Wellbore Schematic B 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development I21 . Service 0 14.Estimated Date for Commencing Operations: 5/1/18 15. Well Status after proposed work: Oil WI • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stechauner,Bernhard be deviated from without prior written approval. Contact Email: Bernhard.Stechauner@bp.com Authorized Name: Stechauner,Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2 le.jul PE Authorized Signature: t� Date: I 7Z_ 7(3— COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3)1iDo1 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No I7 Spacing Exception Required? Yes 0 No l Subsequent Form Required: /t9 — 4194 APPROVED BYTHE 4-"I - �� Approved by: COMMISSIONER COMMISSION Date: I TL a/2/I7-- RBDMS t, JAN 1 8 2C18 ODI ( ' M ,!S1 ,� 407 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) December 20, 2017 To Whom it May Concern: Attached please find the Sundry Application for Conversion to Producer from Injection Well for 04-09, PTD # 176-030. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • PBU Well 04-09 (API# 50-029-20207-00) 10-403 Sundry Request to Convert to Production Current Status: 04-09 is a central injector in an active MIST pattern. Since 1985, the well has injected a cumulative 29 BSCF and 128 MMBBL of MI and water, respectively, into Z2 and Z1B. Due to injection line conditions,the pipeline authority required this well to be shut in at the end of 2015.Due to low reserves associated with continued injection in this pattern and the high cost of a full flowline rep accement,the well was shut-in at the end of December 2015 as requested and secured in August 2016; it has not injected since this time. While 04-09 no longer has value as an injector, flowback tests of perforations recently added to Z4 suggest potential as a producer.The well has never injected into this zone. Two separate flowback tests helped demonstrate the production benefits of 04-09. The first test, in February 2017, occurred after the very top of Z4 sands were perforated and the lower Z2 and Z1B intervals plugged back(details provided in 10-403 Sundry#316-588 approved on 11/22/2016).The well was kicked off with coiled tubing Nitrogen lift but did not produce any significant volumes.Although this test produced no oil, lab analysis found that the produced gas was pure returned MI, leading engineers to suspect that an oil column moved by MI from 09-15A sat just beneath the upper Z4 perforations in better quality sand.The top perforations were shot in a very conservative manner to limit gas production and provide maximal standoff to water. In April 2017,additional footage of Z4 perforations was added approximately 8' beneath the initial interval.As summarized below,flowback tests from these perforations to a portable separator showed strong results. Weil Test Data Total Form '.,Form Fluid Oil Water Gas TGLR FGLR .MGOR!GOR TGOR WH Sep WC Well Run Rate Rate Rate Rate (scf/ (scf/ IOR (scf/ (scf/ (scf/ BHP FTP Temp Temp Pd Bore Date Mrs (bpd) (bpd) (bpd) (mscfd) stbo) stbo) (bond) stbo) stbo) stbo) WOR(psi) (psi) (f) (If) Ckk(%) Test Type 04-09 04/10/17 12 590 547 • 42 28,254 47,921 47,921 145 70,200 51,634 52 .1 787 56 54 128 7.2 7-PORT TEST SEP 04-09 04/05/17 8 617 595 r 22 21,958 35,600 35,600 354 91,082 36,892 37 .0 917 43 41 64 3.5 7-PORT TEST SEP 04-09 02/09/17 18 0 0 0 5,130 -63 81,700 299 54 52 128 0.0 7-PORT TEST SEP 04-09 02/08/17 12 0 0 0 5,813 -71 81,740 330 46 44 128 0.0 7-PORT TEST SEP 04-09 does not have gas lift mandrels. Due to liquid loading during long-term shut-in, kicking off the well may require coiled tubing Nitrogen lift.Once online,the well should flow naturally without gas lift.While we do not expect immediate water breakthrough, we do anticipate water production in the future, potentially necessitating N2 kick-offs after shut- ins.The well demonstrates IAxOA repressurization and last operated under an AA granted on 6/29/2015,but passed(to 2452 PSI)the most recent AOGCC MIT-IA test on 10/18/2015.We do not expect the well to have operability issues as a producer. Plan forward: 1. Obtain Sundry for conversion to producer; 2. Connect 04-09 to production manifold by using the 04-07 production line; 3. Once surface kit is Fit for Service,unblind production line; 4. Notify BP Well Integrity Superintendent of change in well type(for AKIMS modification); 5. Place on production,and 6. Monitor IAxOA repressurization. Con Gv l; �)(1 detwoime !P/°�U.� Ike j ccfs'o4 he if /b st' v,f 7ie,Lfo/'e_ The 4vii ecr well (a h Apr- be rely it m lip j .cf'0y Spry,c t. Coi ro c G ,Orod,1opr' Should a it/0►v for lora-ed leaver) Tb•I for,-io' Ttt fool• . • S TTS= 5'x7 L F1C 123 143.1 AD= `R C 04-0 9 SAS"NOTES.1423 READINGS AVERAGE 125 ACTUATOR= BAKEPpm W HE31 ON TM.WELL REQUIRES A SSSV KB aEV- 52 0' WHEN ON ML DEPTH DISCREPANCY BETWEEN BF.REV- 32 1r BTM OF 5-112"SEAL ASSY AND TOP OF BOT PBR KOP 3300' SEAL ASSY WAS INSERTED AND TBG SPACED 1 bx Angle= 61'la 7579 OUT PH4 RIG REPORT. Datum 1D= 1100'26'S Datum ND- 8800 SS • 2238' H5-1,2-CAMDO 6A L 0 SSSV NP,D=4.582' 1 9-5/6'FOC 2313' — 'w 2613' 9-5/8'FOC 113-3/SGSG,rat,14Nd0,D=12.347• H 2661• Minimum ID= 2.992"Q 10786' 4112"NO-GO SETTING SLEEVE I I 10461' I-5-12'KBXMP,D•4.562'I S ( 10611' H9.-5�x 5.1/7 8102 5-3 RRA D•4.750' I ' 10616 H5-1/7 FES XN W.D•4.455.1 LS i/7'13G,1 71.1-80..023bpi.D•4692' 2 p. . 1t 10q!'__.n J _ I NOTE:TBG GAP BETWEEN 10666'-10692' L5-1/2'TBG r/S TBG SEAL ASEALS,D•4.75' 10166' � 10692 J-{5-12'80T PBR ASSY.r X e' _ �otx,xxt SUMMARY� � 10711 H9- x 5-1/2"ear 3-►twos BI REF LOG: OS ON 05102/76 ``�� I 10722' —i 5-1/2'X 4-12'X0,D•3.9517• A!r'4 F AT TOP F$6. 36'1@ 11467 Nose:Refer b Roduclbn DB for habncal pert data SIZE SPF I/IT 2VAL OpNSQ DATE 2-1/7 6 11462.11472 0 12/16/16 2-1/7 8 11478.11493 0 04/01/17 2.172" 4 11580-11600 C 12/14/97 10766 T BKR MC LN2 ttGR 2-1/W' 4 11600-11620 C 1094/97 ' T 10706' H4-12'NO-GO 03,11.011SLV,D=2.912' 11620.11622 S 06(26786 10602' 4.1/7 CAMCO DB PP,D=3.613' J 11629-11635 S 06/26196 2-1/7 6 11635-116'51 C 11/17101 I 10614' H4-1/7MG,12.40.1-80,.0152bpl.D=3.956' I 2-117 6 11666-11674 C 03/15106 1 10616' ---14-1/7 TABNG TAL(B&MD CT LNl32) I 2-1/7 6 11682-11696 C 03/1506 2-718' 4 11752-11782 C 09/30/90 I son" H 9 l )TT Low 06/2985 I 3-3/8' 10 11807-11824 C 0629/85 I.3-378' 10 11640.11865 C 06/29/85 I I 9-576'CSG,470,10-80,D•8.661• 11010' •4• .. = e'�� 11660j---13-1/2-CBP(t27tWte) 441 4441 INN 141• 1111* 1114 I3-t/2"LPf2-CT,9.30.1.80,.0067 bp/,D•2.997 11697' •4.1• 7.4.1' .1111 441 'CI 3-12'CAWS LY NCH DOABLE VALVE SHOE 11606' •• 44•••••44•1-1 11957 Hf TD 444 I T ail. 291,L-80..0371 bpl,D=e.te4• 12060' 4444444414441,,4 :..04 ,ID 12063' DATE REV BY commas DATE REV BY CONLIN S PRUD43E BAY LNR 06111/76 ORIGINAL COMPLETION 02002117 JUJhM CORRECTED TBG SEAL ASSY V eL:04-09 06/27//113 !MVO 04/03117 161J113 A0162FS(0401/17) F$8`R lb:'1160333 06/19/01 CHlKAK Iwo ARK,. 50.029-20207.00 12720116 J18J16) SET(20P(12119/16) SEC 27,T1114,RISE 325'FSL&643 F13 1229116 JUJM) PALL RSH-SHOW AR GAP 0195/17 JUJU) CORNS)AR GAP TO RIG GAP BP Ekploratkrn(Alaska) 411110 S Roby, David S (DOA) From: Stechauner, Bernhard <Bernhard.Stechauner@bp.com> Sent: Tuesday,January 16, 2018 10:34 AM To: Roby, David S (DOA) Subject: RE: Sundry Application for PBU 04-09 (PTD 176-030) Dave, This particular well has its own injection line and no other injectors are impacted by the state of the pipe. The 04-09 pattern is a MIST pattern and the 09-15A well wraps around the central injector. It is open in the base of the Victor(where the vast majority of 04-09 injection has occurred)and will continue to provide pressure support and sweep with MI for the foreseeable future in this area. Please let me know if I can help you with anything else on this request, Kind Regards, Bernhard From: Roby, David S(DOA) [mailto:dave.roby@alaska.gov] Sent:Thursday,January 4,2018 2:01 PM To:Stechauner, Bernhard<Bernhard.Stechauner@bp.com> Subject:Sundry Application for PBU 04-09(PTD 176-030) Bernhard, I have a couple of questions for you on the subject application. In this sundry it's stated the "due to injection line condition,the pipeline authority required this well to be shut in at the end of 2015. Due to low reserves associated with continued injection in this pattern and the high cost of a full flowline replacement,the well was shut-in at the end of December 2015 as requested and secured in August 2016." Is the injection flowline referenced here just for the subject well or are there other DS-04 wells impacted by this? Are there other injection wells supporting the producers in this fault block/area,or has this portion of the pool reached its "end of life" and your just going to blowdown this area to recover whatever remaining oil and injected MI you can? Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or robe@c;' x.gov. 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Flow Back Test Ii 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-030 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20207-00-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number: PRUDHOE BAY UNIT 04-09 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12050 feet Plugs measured 11550 feet RECEIVED true vertical 9116 feet Junk measured feet Effective Depth: measured 11550 feet Packer measured 10518 feet MAY 01 2017 true vertical 8707 feet Packer true vertical 7933.11 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 33-113 33-113 1530 520 Surface 2627 13-3/8"72#MN-80 31 -2658 31 -2658 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet SCANNED MAY 15 2017, True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Long Term Shut-I 500 1266 Subsequent to operation: 547 28254 42.4 5 787 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ® , WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: F.,S2 Lead P Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: Date: ...c7(/l —7 Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 en-L 5//0// /1 07aBDMS LL MAY - 3 2017 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 28, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for 04-09, PTD # 176-030 for Add Perforations and Flow Back Testing of Injector. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 s 0 CD O O O CD 0 0 0 M N N- CO O C!') N CO O CO O O N N- C N r r N- CO f- 0 N0000O000 a. 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Z J 5 - H a' N 9w E (N! E c15 < Q = ZallI w 0_ WII W o Z , a N fn a 0 LL ?�� } zdpXZ00 0 m • � NCO �wO W 00 F- J — 0 p O J 0 � Z5Urn =O > >+ � Q -51(3121 � w0� � 0 > o U p >< ' J uWQ 60Q ¢ � — - o Q Z II m m — Z O 0LoHZQ � (nom N �' O QOJcn J H 0 N U) J J ~ II OLIJ J O Iaj Z Z 5 cc O Il. W D Q w O * Z a 0 a a W H Q N- >- o U) H N _ 5 H U TREE_ ' 5"X7"L FMC 120 "WELLHEAD= FMC NOTES:1125 READINGS AVERAGE 125 _..._ _ _...-_._.. 04-09 ppm WHEN ON MI.WELL REQUIRES A SSSV ACTUATOR BAKER C KB.ELEV= 52.0' WHEN ON MI. DEPTH DISCREPANCY BETWEEN BE ELEV= 32.16' BTM OF 5-1/2"SEAL ASSY AND TOP OF BOT PBR KOP= 3300' SEAL ASSY WAS INSERTED AND TBG SPACED Max Angie= 61°©7579' OUT PER RIG REPORT. Datum MD= 11726' 1 Datum TVD= 88.00'SS 2236' f-5-112"CAMCO BA L-0 SSSV NP,D=4.562" L9-518"FOC - 2363° i' I 2613' H 9-5/8"FOC 13-3/8"CSG,72#,WI-80,D=12.347° -1 2654' Minimum ID = 2.992" @ 10786' 41/2" NO-GO SETTING SLEEVE { 10489' —j51f2""mss x NIP,D=a.ss2" i�� k 1 10611' H9-5/8°X 5-1/2"BKR S-3 PKR D=4.750' L 10618' H5-1/2"HES XN NP,D=4.455" 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" F-L. 10679' j NOTE: TBG GAP BETWEEN 10686'-10692' I10692' -5-1/2"BOT PBR ASSY,7"X&" S1/2'TBG SEAL ASSY w/SEALS,D-4.75' 10686' _ _ __ — • PERFORATION SLMlnM1AR:Y O� ►�!s 10711' H9-5/8"X 5-1/2"B073-11 FKR REE LOG: BRCS ON 05/02/76 10722' H 5-1/2"X 4-1/2°XO,D=3.958" ANGLE AT TOP F EF F: 36°@ 11462' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11462-11472 0 12/16/16 2-112" 6 11478-11493 0 04/01/17 2-1/2" 4 11580-11600 C 12/14/97 10786' --17"BKR MC LNR HGR 2-1/8" 4 11600-11620 C 10/04/97 ji i • 10786• -14-1/2"NO-GO DEPLOY SLV,D=2.992" 11620-11622 S 06/26/96 --10802'J-14-1/2-CAMCO DB NP,D=3.813'J 11629-11635 S 06/26/96 _ 2-1/2" 6 11635-11654 C 11/17/01 10814' }-4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 2-112" 6 11666-11674 C 03/15/06 10816' H4-1/2"TIEING TAL(BEHIND CTLINER) 2-1/2" 6 11682-11696 C 03/15/06 2-718" 4 11752-11792 C 09!30190 10799' -I E LMD TT LOGGED 06/29/85 3-3/8" 10 11807-11824 C 06/29/85 3-3/8" 10 11840-11865 C 06/29/85 I I 6r1E ad 9-5/8"CSG,47#,MN-80,D=8.681" - 11090' V. I11660' H3 1/2"CEP(12/19/16) 1. 41 •*41 111/ 11111 /4111 3-1/2"LNR-CT,9.3#,L-80,.0087 bpf,D=2.992" H 1169T ,141 [3-1/2"DAVISLY NCH DOUBLE VALVE SHOE 1-I 11698' 4.) `V. I v1v1.1.,101.1./ 1195T --I POT° 7"LNR 29#,L-80,.0371 bpf,0=6.184" -I 12050' 1�11�111111v1v1, TD H 12053' 1'1'1'1'1'1'1'1' DATE REV BY COM'vENTS DATE REV BY COMMENTS fS PRUDHOE BAY UNIT 05/11/76 ORIGINAL COMPLETION 02102/17 JUJMD CORRECTEDTBG SEAL ASSY WELL: 04-09 ' 05/22/85 RWO 04/03/17 MS/./M) ADPERFS(04/01/17) PERMIT No:9760300 08/19/01 CI-MAK RWO An No. 50-029-20207-00 12/20/16 JR/J&D SET CEP(12/19/16) SEC 27,T11 N,R15E,325'FSL&643'FEL 12/29/16 JUJMD PULL ASH-SHOW AR GAP 01/05/17 JUJMD CORRECTED AR GAP TO TBG GAP BP Exploration(Alaska) STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Flow Test El 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-030 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20207-00-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number: PRUDHOE BAY UNIT 04-09 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: y�+�_, ®� Total Depth: measured 12050 feet Plugs measured 10550 feet R ./E7► ED true vertical 9116 feet Junk measured feet R n R 0 9 2 n 1 7 Effective Depth: measured 10550 feet Packer measured See Attachment feet MAR U 1 true vertical 7954 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 33-113 33-113 1530 520 Surface 2627 13-3/8"72#MN-80 31-2658 31 -2658 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet SC,A APR , i 2C117 True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -17134 500 1266 Subsequent to operation: 0 5813 0 3 330 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations lid Exploratory ❑ Development ❑ Service El Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ® WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-588 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 3/7/17 Form 10-404 Revised 5/2015 I// 1- `/2 RB5L MAR; 7 2��7 Submit Original Only A1717 �, • • Packers and SSV's Attachment PRUDHOE BAY UNIT 04-09 SW Name Type MD TVD Depscription 04-09 TBG PACKER 10518.46 7933.11 5-1/2" Baker S-3 Packer 04-09 TBG PACKER 10712.29 8064.72 5-1/2" BOT 3-H PACKER 1111/ 1111/ m QCD o 0 0 CD ,1 0 0 0 N N- aD co N 00 O up CO O N O O N lf) C N lC) I- CO r...- c) �U n 0 0C) 0 CD 0 0 C) i M 00 Cn N- CD (0 M up M T- 00 r- 00 c- IC) 00 CO CO I- CO M 00 O O) N M 00 1 N V N N_ V M CD M CO O N N CO CO CA CO 00 CD II H Cn 00 00 M c- O N r I� CO M M M V N O N 00 co op a C) N CO O 00 ON N r v r T- L) L) H 0 i QV M CO I- MT- O N Cp CO co ,77 M M V0 O N O Q N c- c- :Ei co ui O O up O O O 00 CD 00 C) O O co 00 i Z (n Z J o0 i J C 2 0C 2 Z *k •- �/ CI) 4t N 4t M N N U a � COOONNNN N l? if I� O O) N- O O) CD CD CV CD 00 Up CD Ln C 00 CO M CO N O) J N N 00 (A c- O UJ w 0)O — — N 0 0 0 UJ W U D u IX E Z Z z w w w w m m O D H H Z Z D D U U Z Z IP S Cu m co co UP UP V- 00 d co co N N CA c- Cfl N CA Q) CO 00 O) 00 V N v- 00 is tM OO V CO Cfl M N g O CA O co h f< M I: d V V CO Cfl ti CO O O O O v- N N O M CO 0 C° N N- CO00 00 CO 00 CO CO O C3) CD 00 CO M 00 00 CO CO 00 co CO 00 00 C0 O H O) N- co v- r V CO l() r- Cfl t M I- N- Cfl O CA Ln (XJ `- N- M 4 N- CO O = NO 0oMM mr- r- OOOO Nr M CO OD CO OO (b OO O (A O > > oococococococoMaoaoMMMOOMeo 0 2 c ❑ ❑ ❑ wz w W p w a 0 F- F- w g g Y 0 O 00 ‹ O w W o 2m N 0 0 wWzNOONU) MctONtLUNCnMNd- cc wI,- ONNMd- CON- N- N- 0OOAMNO a s Z= yNrCOOOCflCOOCOMMMCOMNCo00 0 0 0 wWa y ¢ Q Q 0 o w a 2 2 2 z ❑ F- ❑ t m 0 0 0 x § z O z c� Z 2220w n wow a � c M QM . 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O N _0 O o u) a) Q_ 0 — 0 H dH � H off > off 0 ") E D o a) �' TI) U a) U a) gip_ Q*K aa_ I, 'E N — E 2 O 6 " c O C C O a) U a) LL a O * O * L � � a Hop o, � HOp � H �' .� � � o HD E E ,- oc) N � _ O c (I• ) - �) * U >' N U ) N U Z p'_' .0 (o U C) N * U z * it_ '5— O c0 D D Z `) c . a) C1- = a) (3- `- D LL °t5 O Oc C E N LL 2 a) N a)-0 a) D N D N +-' E c c c p_' CL ai U o v E .c v E .c v L- 2 ° ami co >, E o v o .c z co c in U> (n U> H• H D Q*k p H o *k O` a * in .11 0) O E 0_ *k 2 d o o_ N ww co H > H U) o cc o — H a °, * ami ? co m :73 a) a) c ,- 1- .� Urn Q U U E Un E -i � : (Jr . > : 0de a) 2 ccom« o � o � U � Q (n (n n3 t * U r r` N- r- r` N- r- r- 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N 0 0 • t e o (1) o (3.) / c c / c = _ � _ 0 0 0 0 00 \ U 0 0 0 0 Z \ \ Cr \ # - cr szt \ / / \ / / / \ / / E / / \ N- \ 77 \ O 0 050 . 2 \ / A c ¥ DO \ E ± o ° $ 2 \ < f --- CV- / \ / / § c \ - -4- , . 0 % \ 5 rX 2 % ƒ ■ 7 U $ o $ $ ¢ _ CV c wm » 20 o - c k \ / § § / / / 2 o o ± 0 G 5 O / - 5 § 6 5 $ \ 0 O 0 c R R y R .c > Ho m ® CLI-- - U 4 U c U £ 2 co O Ti c ® 2 = / 0 N £ / \ t 0 \ s 7 4 -w % I - $ 4 0 ± \ \ / y 7 / 7 k > 1-A1) k 03 / 2 G \ ° in & � 5 \ w G � O & e « I % < 2 < o .� d < 0 --0• 0 z / O ¥ z \ z \ \ / z 2 12 2 6 - * n = o a - : c / c c £ o CIo.g 0 o 8 = ' o - o = » re ZU0 CE W \ / / \ o / ƒ \ w CD f / / / 0 / \ _ 0 _ 0 (06 k b as o Cr e E -) E I E $ U % t R k \ < i & g E % N- & % % \ \ \ U E2e = 2 & � O / t2 � % ,- 629 & 6 e ± e m « _ g@ +, 6 a o 5 A 5 2 0 -0 « ® © m c , E ® � -0 a f \ m _ _c / o ? \ 0 / \ k %/ ± / 2 / 2 /_ / \ f cmc .4- 03/ E / 65 . .., / / c / / / ƒ / \ (1) , a) / (7) _, / - \ $ H o E cn \ \ Q F-U) ? § 2 \ \ \ § � y ) a) / \ O E # - - e t a 4- U 2 t 4_ _J 4_ 6 I ± 4 c Z o U N- N- N- N- N- » » w w \ \ d N / \ d / \ / % r \ � co co co / \ CV Q Q & & t A A R R & TREE= 5"X7"L FMC 120 • WELLHEAD= FMC • NOTES:H2S READINGS AVERAGE 125 ACTUATOR= BAKER 04-09 ppm WHEN ON ML WELL REQUIRES A SSSV 1<B.ELEV= 52.0' WHEN ON MI. DEPTH DISCREPANCY BETWEEN BF.ELEV= 32.16' BTM OF 5-1t2"SEAL ASSY AND TOP OF BOT PBR KOP= 3300' SEAL ASSY WAS INSERTED AND TBG SPACED Max Angie= 61°07579' OUT PER RIG REPORT. Datum MD= 11726' DatumTVD= 8800'SS �` 2236' H 5-112"CAMCO BAL-O SSSV NP,D=4.562" I9-5/8"FOC J—{__._. 2363'_._ .--— — , 2613' --I9-5/8"FOC 13-3/8'CSG,72#,MN-80,0=12,347" — 2654' Minimum ID = 2.992" @ 10786' 14 1/2" NO-GO SETTING SLEEVE 1 1 10489' —I5-1/2"HES X NP,ID=4.562" 10511' -19-5/8"X 5-1/2'BKR S-3 PKR,D=4-750" I r 10618' —I5-1/2"HES XN NP,ID=4.455" 15-112"TBG,17# L-80,_0232 bpf.D=4.892" ,— 10679' I NOTE: TBG GAP BETWEEN 10686'-10692' [5-112"TBG SEAL ASSY w/SEALS,1137 4.75" 1--1,....10686"_-------1 1 D10692' 1-15-1/2"BOT PBR ASSY,7"X 6' , 10711' _-19-5/8"X 5-1l2"BOT 3-H PKR PERFORATION SUMMARY10722' —I5-1/2"X 4-1/2"XO,ID=3.958' REF LOG: BHCS ON 05/02/76 ANGLE AT TOP FERE: 36°@ 11462' Nate:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11462-11472 0 12/16/16 2-112" 4 11580-11600 C 12/14/97 S 10786' LNRHGR 2-118" 4 11600-11620 C 10/04/97 — — 10786' --I4-112"NO-GO DEPLOY SLV,D=2.992" 11620-11622 S 06/26/96 11629 11635 S 06/26/96 10802' 1—I4-1/2 CA MCO DB NP D-3 813" 1 2-1/2" 6 11635-11654 C 11/17/01I L 10814' }—4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" 2-1/2" 6 11666-11674 C 03/15/06 10815' —I4-1/2"TUBING TAL(BEHIND CT LIVER) 2-1/2" 6 11682-11696 C 03/15/06 2-7/8' 4 11752 11792 C 09/30/90 10799' —ELMD TT LOGGED 06/29/85 3-3/8" 10 11807-11824 C 06/29/85 3-3/8" 10 11840-11865 C 06/29/85 L 1v Q441 11111 _ ;�y� 11660' — B {3-1/2"CP(12/19/16)1 111 —_I9-5/8"CSG,47#,MN-80,D=8.681" 11090' 1111 11 1.4 11111 1114 3-1/2"LNR-CT,9.3#,L-80,.0087 bpf,D=2.992' H 11697' 4�1� 111 vire' 13-1/2"DAVIS LYNCH DOUBLE VALVE SHOE IH 11698' .7.7, cc I 11957' —IPBTD 7"LNR 29#,L-80,.0371 bpf,ID=6.184" —1 12050' 11111111/11////1 TD -[ 12053' 111/1//1///1/1/, DATE REV BY COMMENTS DATE REV BY COMW 4TS PR1D-IOE BAY UNIT 1 05/11/76 ORIGINAL COMPLETION 12/20/16 JR/JWD SET GBP(12/19/16) WELL: 04-09 05/22/85 RWO 12/29/16 JUJMD PULL FISH-SI-OW AR GAP UMW v IT No:'1760300 08/19/01 CWKAK RWO 01/05/17 JUJMD CORRECTEDAR GAP TO TBG GA API Na: 50-029-20207-00 09/06/16 JMWYJMD SET PXN PLUG(08/30/16) 02/02/17 JUJMD CORRECTED TBG SEAL ASSY SEC 27,T11N,R15E,325'FSL&643'FEL 12/06/16 JGUJMD PULLED PXN PLUG(12/01/16) 12/20/16 LAC/JMD SET FISH&ADPERF(1217/16) BP Exploration(Alaska) �� • • 0 N 1 0 7 -7 pro 0 X , ro r 0 C7NZ O V W N +- N 0 <—m---- CV CU ....P.rll bp 4-' (6 >, rrC N F Y CC N -0 r6 N o'.' o z O E u v > cr, CU L v a Q ra c E 0 µ,t ra .„, 0 'C +, 'O ` o cE a ra a ,- m EQa x' p _E u g = o4 v s CO in OzZZZo < O r ems- A- M (`+ O @ Y C cn 11 Q. `� U -O r0 o +- CE 1-. QJ > \ u L > 0 72 4J CC iii G G C G G O L(13 � Q1 `n .� L U L O I- W W W W W W LL LL LL LL LL LL +, Q) G) N 'O Q _Q > L▪ N = Q Z Z Z Z Z Z CU 0 r�0 N 44- L • p LL LL LL LL LL LL r > i C y 0 Q Ecia.0 z aa) u 0 H > u N +, . N a F U N y 1- F- < ami a a C0 0 a--1 t, V . . 2 E lha .E µ' p d V W W N • • Q ;: N J J Q R H a CO 2 d d CO CO 0 ca V '�ell > co a0i ID tra pa �j V J U 0 I r6 Z 1 e1oNI Z. clat a , o W a . M � � E E E E Eg zap �� EEE22 v W 0-0 41).--.),..Y1 p v O 2 m Z m m m m4 z 0 D 0 0 0 0 `o p 2 m x 2 2 2 0 m N D m >m L 1 ? a a a a a o0 Uji C u to ro o V c'c....., 1,4 o 0 0 0 o o X v1FO 0 0 0 0 0 0 0 E 0 O o 0 0 0 ® Q N N N N CO W Q 11000000 . t0u CrNO M NOC O O O o O O b4 a N N O M u7 r` 'N C 1COj V M r NL O 0 0 0O UN N N N N N N L Ig 6) 6) O O C) 6) yN N N N N NO O O O O O 3re pp 0 0 0 0 0 0 0 QLJ �. pCp�� C )n )n in v) )n in Qu.` GS cu (Z- 01 v >h L41 d N ` N o N o O 4 . 2M • L^ a o ocvc E Z v r0 Tio .I �. C 44 N Y CP o a �. i.`w` v F- a a Q .�Or TtJ • S .. ,e, �yy�,• • THE STATE Alaska Oil and Gas ��? • � Of A 1 C� Conservation Commission , 1 1LAs `tel 1 t s f£2 i, 333 West Seventh Avenue k,7- r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � .. lok Main: 907.279.1433 Off'A 5 Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE BP Exploration(Alaska), Inc. FEB 27 2.01Z P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU 04-09 Permit to Drill Number: 176-030 Sundry Number: 316-588 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, AI /°)91c/-.,— Cathy Cathy . Foerster Chair DATED this 21 day of November,2016. RBDIVIS i,`' NOV 2 8 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROS 20 AAC 25.280 ' 1. Type of Request: Abandon 0 Plug Perforations ® . Fracture Stimulate 0 Repair Well ❑ Operations shutdown❑ I Suspend 0 Perforate 0 . Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Flow Back Testing 0 ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 176-030 - 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic ❑ Service 0. 6. API Number: 50-029-20207-00-00 7. If perforating: , 2ei7. ` 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool?�' c.J Will planned perforations require a spacing exception? Yes 0 No ® PBU 04-09 9. Property Designation(Lease Number): IL"'k;max' a 10. Field/Pools: ADL 0028324 ' PRUDHOE BAY,PRUDHOE OIL • Nov 1 11. PRESENT WELL CONDITION SUMMARY ?016 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): �° 12050 • 9116 - 10618 I �`4m+' 8000 10618 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#1140 33-113 33-113 1530 520 Surface 2627 13-3/8"72#MN-80 31 -2658 31-2658 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 5-1/2"17#L-80 L-80 I 27-10681 Packers and SSSV Type: 5-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10518, 7933 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service lI' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: . Oil 0 WINJ 0 �, 1L.,WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 J WAG M `Il° GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.com Printed Name Stechauner,Bernhard Title FS2 Lead PE Signature .. /j'` __�` Phone +1 907 564 4594 Date i t/14-/iCOMMISSION USE ONLYYV Conditions of approval:Notify Commission so that a representative may witness Sundry Number:,, Integrity \ `-� ^ 6 Plug 9 ty 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 1 Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No L f Subsequent Form Required: t 0_404 P.7�� APPROVED BYTHE Approved byCV47 (I ��` COMMISSIONER COMMISSION 7Y- Dater��// ORIGINAL RB®MS , `'SOV282vo6 ll. 2l 16 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid'for 12 months from the date of Attachments in Duplicate approval. I�/6 ,, � i(- I7./6 bp • • 8 November, 2016 BP Exploration(Alaska)Inc. Michael Quick 900 East Benson Boulevard P.O.Box 196612 Sr. Petroleum Engineer Anchorage,Alaska 99519-6612 Alaska Oil and Gas Conservation Commission Main 907 564 5111 333 West 7th Avenue Anchorage, AK 99501 Re: Prudhoe Bay Unit 04-09 Injector flowback to evaluate re-conversion Dear Michael Quick, Your approval is requested on the following well intervention: Well 04-09 is a pre-produced injector in the FS2 part of the Prudhoe Bay field. It was converted to injection in 1985 and has been on produced water, seawater, and MI injection since then. This well is the central injector in an active MIST pattern (09-15A). Its injection line has been taken out of service end of 2015 due to corrosion issues and the well was secured in August 2016. This procedure aims to trial a new approach in MIST offtake. The top of the Victor zone in 04-09 has never been perforated. It is very likely that over the course of the previous MI bulbs in 09-15A a significant amount of MI has been trapped in that zone. We would like to set a plug to shut off all existing perforations and then add new perforations in the / top of the Victor to test this theory. Since 04-09 has no production line or gas lift mandrels, we will need service coil tubing and Nitrogen units to supply lift gas, as well as a portable test separator on location to back-flow the well. A minimum of one week flowback is planned to understand the potential of this novel approach. If this backflow is promising, we will evaluate a plan to re-convert this injector back into a producer to / maximize the MIST benefits from the 09-15A MIST injection. No permanent conversion work is proposed at this time. ,% Recent Integrity Issues: None, well is operable > 10/18/15:AOGCC MIT-IA Passed to 2452 psi > 08/30/16: TTP set© 10618' MD for flow restriction A cement bond log will be run to ensure top of cement between the 3-1/2" scab liner and the 7" production liner is above the proposed perforation interval. Respectfully,- r ' per a---" B`efnhard Stechauner Lead Production Engineer, FS2 BPXA, Reservoir Development Attachments: Current wellbore schematic Proposed wellbore schematic • Davies, Stephen F (DOA) From: Stechauner, Bernhard <Bernhard.Stechauner@bp.com> Sent: Thursday, November 17, 2016 12:47 PM To: Davies, Stephen F (DOA) Subject: RE: PBU 04-09 (PTD 176-030; Sundry 316-588) - Question Hi Steve, Thank you very much for your e-mail. We were told by the AOGCC to stop submitting our detailed work procedures that usually contain all the details about the proposed interventions but instead just send a cover letter along with the 10-403 form. I apologize for not including the depths in the letter, but, since this is different to what we were used to submitting for the last several years, it was overlooked. Please see the attached minilog that summarizes our plans for the 04-09 injector. Proposed perforation interval is 11,462 —11,472' MD and the plug will be set at 11,550' MD. May I ask, since you mentioned the Statewide Regulations and Pool Rules, is there anything I missed about performing a less than 30 day production test on an injection well the way the work was proposed? Is there a maximum number of days we are allowed to flowback an injector without any additional permitting requirements? Thank you very much, Bernhard 1 0 • op 0 Injector Minilo LA TechI Minilog Prvlect OS-04 Minlioas futttar Laura J. 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Dr 4 11640 11620 0 10,04.97 L 7 10796~ ,--J4 117 No GO DER.OY SLV,ID-7 tn• 11620 11672 S 0606/96 11629 11635 S 0606/96 Ifni i 10802' Li ii2----6A4,0,i.kip ii:3ii3c- >.1/7 6 116.35 1 1654 0 1107,01 1:- 1-6814. -:',. Fla.MG.17 80 L-80, 0152 VI 1)-3 851F1 :1-10" 0 11000 1111r4 0 03/IWO / \ 2-1/7 6 11682 11696 0 0345.06' 1 lour ' 14 Ir,' 10111M.1All 111/1r41(..11 84 hp 2.Pr 4 11152 11/92 0 09C090 nine* --Lii mu 1-1 LCOGTD 06r29/85 -; 3-vir II) 1180/ 111124 (1 06119/95 3-1#Ir II) t 1540. 11116'', (1 06/19/85 , 16 4c 'we 104 004 40 •4 CSG,471,494-80 0-8 8811.1—iL__11090' .•04 _ .• •• • 1 •I 414 0/ [3-¶/2 LW-CI,931.L-$0. 0081 bpf,Or 2 992-i-1 1169T • . 4.1 1 1 ef o 31-TIQM,VIS LYNCNEMBLE VALVE SE-n- 11698' A 441: I I ........—H 11 96r .-4," 1 'r LNIK 2941.L SO. 03/1 Opt LI 6 134" 12060' .•••••••• ........ 120153' n- hit-v IV i COM IS OA 11- PIN KY EXAM-NIS , 1-3&11KF MA 1.0141 05/11178 ORIGINAL COMPLETION 09/06.'1E, AA/AO SET PXN PLW(38/3G 16) Vail 0409 06/2245 RWO reFAIT Na'1160.10) # _ __ OS/11S91'CHKA8;-Favo All M 50 079 20101 XI 11 FA:11.94) A - SSSV SAFETY NOTE .- SIC 7/ 111N R151,325'ISE 6643'IR 01/13/17 W4.44)AMID F125 SAF ti T NOTE ... 0928,05 OtiAt.1-1111-1-001090'115) BP Exploration IALMIL ad .__ . 0 II Proposed wellbore schematic EWE= vxr L MIL 177 V1BUE/1D FIVE." _� SAFETY NOTES:142S READINGS AVERAGE 125 AMIN TOR. BAKER r;� ppm WP1FNtNi MI WELL aEQ(lY2ESA SSS( KB N t V 57 O WHEN ON ML DEPTH DISCREPANCY BETWEEN BP/LEV- 3716' BTM Of 5-112-SEAL ASSY AND TOP OF DOT Pea KCP- 331-4' SEAL.ASSY WAS INSERTED AND 3BGSPACED IAN An{/4= 61'4 4579' OUt PER RIG REPORT ()Num MO- 11126' CsturnTVD 1800'SS Q `-'-1_.._2238' I_{51/2'CAIK'O OAI.0 SSSV NP,ID 4647"._J 9 SrFOC- 2383' )----. ,.. — 720 13 3 4 I 2513' ' 9N PIX: 4-1--Se, , /11-.!0 E)-12 34r , _ _... �__.__.__._. Minimum ID=2.992"@ 10786' '4 1/2"NO-GO SETTING SLEEVE I 10489' -16-10't KNs>r)-4562' " . 10511' 19`.N'd'X 5 1t2"MO?S 3 NKR,/a-4.750" 1 I 10618' 1.. Ir"I4siNV'r. 44'.": S t@"TBG 144 I !3O 0712 Cpl I) 4 4+7?" 10667' iQ892'� is 712 907 FOR ASSY [5'1,7'ilk.;SFA A SSY W O SFAs S 1)-4 87 10674' 4 !0;SII /'"' _ T"!1 - 1/2' 41 �i-5+9'%5. 847 3-R acR1 Pif6110 ORA N SlA4AA.R1' ` 10771' �5 VT X 4 147'X0 T?-3758"* REF LOG BRCS ON 05442'76 ANGLE AT TOP#14 36-a 11586 Nbio Refer to Product/3r 06'o Slsiwcal pert da .._SIZE SW NTERVAL Oprr156r. _..-DAD. • S !07766' {7'BKR MC I.NR+°1GR{ 2-172' 4 11580-11600 0 12/1491 2-1I8" 4 11800 11620 0 i 100491 _ _ 11670-11677 S !0606196 - 10786 -{s u2"Na GO OER,.OY SI v I) ^:;y 11679 11636 S 0606196 10802 1 14 10"CA4rl:0I II NV Ii 1 81 1 I-117 6 11635-11654 0 11/1N01r :) 10814 ,.I 4.112'TUG,17 831 1 30 0152 CVr 8)-3 958'J 5 h r O 11000 110f4 0 03,1:400 2112' 8 11682 11896 0 0311508 I 10618' 14 10'8.044,1A4 rift 044)t,184717 2118' 4 11f57 11192 0 090090 [ 10.799' 1B.t10 R 1(X;r.,ED 06/20085.1 716 1 10 1180/ 116/4 i) 01(91481 ! .. _4.4_44._. X)M' 10 1160 118115 t) Orit291131 1 Ili a 4444.' '4444. !-�f +it'4 9-528'RSG.a II.1081-80 0-8.881' 1-, 11090' `,ir, 4.44; 13 1 L!.Pt C r.9 344 L d0.0084 5p1 U-2 992' '4.--i_ i 1697' .6�. 44.1 _ — Alf 4.4 r,--.,,,.DAVIS LYNCHMV/WE V At Vt.SHOE -- 11698 , Ii 11957' ._'` r). I /-ENR 298 i 30 0311 5151 LI.6 1!14" ' 12060' 11��i101fi r ( (II) 12063'.. 4 ►,�.1 1.• I 'i m 11 bur BY 1 0314101-NIS DAD H-V Ill (7914.4-NIS 1 143.41-104-FRAY 1141 ,0511118! :ORIGINAL CONK ETION 094/16„*4464)SET PXNILLC(980013) WELL 0409 '05(12/85 I RWO _-. _ FERMI WI.'6010; OMAN1 CI111{AK RWM AR No 50 079 20207 00 ..._.. ;0209tH 441'3 ):AI%7MSSSV SAILTY I It _ SEC 27.111N,R15E,325'1918 64380 0141017 14 49441 ADDED EDS SAFZTY NOT€ 1 ---� 08716/15 IAYJ,R);1141 00(097'116) ' BP E3(pbr,ifton(Alaska) • Quick, Michael J (DOA) From: Quick, Michael J (DOA) Sent: Monday, November 21, 2016 2:56 PM To: 'Alatalo, Travis'; Lastufka, Joseph N; 'bernhard.stechauner@bp.com' Subject: Sundry Application for PBU 04-09, 316-588, PTD 176-030 Bernhard— In reviewing the sundry application for PBU 04-09,there is email correspondence between you and Mr. Davies that states "we were told by the AOGCC to stop submitting our detailed work procedures... but instead just send a cover letter..." If I could correct any statements that I made that were misinterpreted,we need a cover letter that summarizes the work and the basic well diagnostics, in addition to the normal procedures and back up documents that are normally sent. The request was for an addition of the cover letter, with no reduction for the other detail. The cover letter lets everyone who reviews and approves the permit at the AOGCC understand what the request is, without them having to dig it out of the procedure documents, and is consistent with how BP generally submits their requests. I apologize for any confusion within your organization that the request for a cover letter has caused. Please distribute with your organization so we get both the cover letter and appropriate back up for each request. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage,AK 99501 (907)793-1231 (phone) (907) 276-7542 (fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.Guick@alaska.gov. 1 • • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, November 17, 2016 2:34 PM To: 'Stechauner, Bernhard' Subject: RE: PBU 04-09 (PTD 176-030; Sundry 316-588) - Question Bernhard, Is there anything I missed about performing a less than 30 day production test on an injection well the way the work was proposed? Not that I'm aware of. If any of our engineers notice a gap, or have any questions, they will ask you. Is there a maximum number of days we are allowed to flowback an injector without any additional permitting requirements? Any production from this flowback test must be reported to the AOGCC using our Form 10-405. Other than that, a flowback test equal to or exceeding 30 days duration will require BP to file another Form 10-403 informing the AOGCC that BP is terminating the test and requesting approval to convert PBU 04-09 back to injection operations. If you have any other questions regarding testing, please contact Guy Schwartz or Chris Wallace here at the AOGCC. Thanks again for your help, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Stechauner, Bernhard [mailto:Bernhard.Stechauner@bp.com] Sent:Thursday, November 17, 2016 12:47 PM To: Davies,Stephen F(DOA) <steve.davies@alaska.gov> Subject: RE: PBU 04-09 (PTD 176-030;Sundry 316-588) -Question Hi Steve, Thank you very much for your e-mail. We were told by the AOGCC to stop submitting our detailed work procedures that usually contain all the details about the proposed interventions but instead just send a cover letter along with the 10-403 form. I apologize for not including the depths in the letter, but, since this is different to what we were used to submitting for the last several years, it was overlooked. Please see the attached minilog that summarizes our plans for the 04-09 injector. Proposed perforation interval is 11,462 — 11,472' MD and the plug will be set at 11,550' MD. May I ask, since you mentioned the Statewide Regulations and Pool Rules, is there anything I missed about performing a less than 30 day production test on an injection well the way the work was proposed? Is there a maximum number of days we are allowed to flowback an injector without any additional permitting requirements? Thank you very much, Bernhard 1 • • Davies, Stephen F (DOA) From: Stechauner, Bernhard <Bernhard.Stechauner@bp.com> Sent: Thursday, November 17, 2016 12:47 PM To: Davies, Stephen F (DOA) Subject: RE: PBU 04-09 (PTD 176-030; Sundry 316-588) - Question Hi Steve, Thank you very much for your e-mail. We were told by the AOGCC to stop submitting our detailed work procedures that usually contain all the details about the proposed interventions but instead just send a cover letter along with the 10-403 form. I apologize for not including the depths in the letter, but, since this is different to what we were used to submitting for the last several years, it was overlooked. Please see the attached minilog that summarizes our plans for the 04-09 injector. Proposed perforation interval is 11,462 — 11,472' MD and the plug will be set at 11,550' MD. May I ask, since you mentioned the Statewide Regulations and Pool Rules, is there anything I missed about performing a less than 30 day production test on an injection well the way the work was proposed? Is there a maximum number of days we are allowed to flowback an injector without any additional permitting requirements? Thank you very much, Bernhard 1 . • . EPP 0 Injector Ell Techl Minilog Protect DS-04 Montloos Well: 0449 Author Laura J. Lai Scale 1 000 Date 111141: 000•00,00 112 it /111.11 ST 'NP+.0 Ole*14,3444,1 WM* Coarey leila Inwebon datum 100 Y$ustortir c.00000600,Da.1111114144141/011011 TWIT PoiNTlaw Bay lata Oda^INS 1.41144.4. 14$2111741 TM* ism Make Coodinaia*mom 0140VMPT USW.le 172407 Opersaar OPxA Company OfPX4k 04 I PI 0- ii 40m10 NIU • TVDSS PAD 0o ralifortgie+ii-"—Argil-% IC GR/841111111111111 I:"" S 1" PE Info . CAti 'Cr"84;thPiLff "7484 mlit41-°1"40 P .... r- eht 09 at GPLLAys. w. RI I S_Of I riftriS SW i et 0 0 ' -.- us 4.• is ro . a- '—- * • '1 1111 .. •. -7 Nirri ir)V11 11414Z -----"-- 'WS* - 1119111K, ''. sso'S Add pert 11.462- 4.0. 411 11 477 1,n Set plug 11,550 MD t- litifr 11450 ....s.; 11"a IS i .111X t. f ..... 17* /11 •-----..---- • S 4700 I I ....J - _ i 5 I lif ilk 244 rat.at _ ; 1111 ar- _.5 ,4111 i i \ if - nc.L. ' --------. WOO 5/27/2013: Tag at — — • _ ___ , 11,733' SLIM I -asso :II 4 4.1.4 1 /1111 ( -$000 ' i * 1 IMO a '... . ( „ I ' 1 U " -VISO ' 1 ( 1 ' ( 1. 11950/ ' • H a -11000 1 € I ± i IL'4050 2 • • • From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, November 17, 2016 10:38 To: Stechauner, Bernhard Subject: PBU 04-09 (PTD 176-030; Sundry 316-588) - Question Bernhard, I'm reviewing BP's Application for Sundry Approvals for PBU 04-09. I notice that this application proposes to add new perforations to the well (within the top of the Victor interval), but I do not see a list of the measured depths for those proposed perforations. Could BP please provide this information? Also, please be aware that, along with Statewide Regulations, Conservation Order No. 341F governs development within the Prudhoe Oil Pool. Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 . • • 0 N Injected Gas (Thousand Cubic Feet ("MCF") per Day) OO O O O O O O , 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CO N t0 1n M N .-I O • `rl //tel Al. O 1 Fl ab p 4 — O �Ol a li O w �� 'tel M ',''‘,;,-,:;'1,:,:'1'''''' ;r ad O — f 67 k.0 x P% I� � 90 'l0 -- �`b co 0 it 46, 10 -0 V� 40� l0 c Q 9' b on C (ch, '10 Q 0 — C — �' to�� to F_ .� OOorO "_ '_ �V u6- v Q E - E ,964 l0 a m QJ 00 LJJ Q 6 r, O 00 M .. O ji< N N s6/ l0 N N �4 'a 0 ` I cu 6'.i O v 9d v CC 0 ,` �6. l0 - O - C CL u O l6 1p I � a I.S >/:°° �JOa (to ,7 8.QbO Oih `° U U O, Sci) l0 o o o o o o o o /7/ 0 0 0 0 0 0 0 l0 Ln o �n O �n o un M M N N .-1 .i /lea aad aa}em j.o slai.ie8 u 0 i • From: Davies,Stephen F(DOA) To: "bernhard.stechaunerCalbp.com" Subject: PBU 04-09(PTD 176-030;Sundry 316-588)-Question Date: Thursday,November 17,2016 10:38:00 AM Bernhard, I'm reviewing BP's Application for Sundry Approvals for PBU 04-09. I notice that this application proposes to add new perforations to the well (within the top of the Victor interval), but I do not see a list of the measured depths for those proposed perforations. Could BP please provide this information? Also, please be aware that, along with statewide Regulations, Conservation Order No, 341F governs development within the Prudhoe Oil Pool. Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 28,2015 TO: Jim Regg i, P.I.Supervisor ee; 131t5" SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-09 FROM: Jeff Jones3 PRUDHOE BAY UNIT 04-09 Petroleum Inspector S pt4NE© 1 1 I'L jvl.. � 1� Src: Inspector Reviewed By: P.I.Supry 'P - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-09 API Well Number 50-029-20207-00-00 Inspector Name: Jeff Jones Permit Number: 176-030-0 Inspection Date: 10/18/2015 Insp Num: mitJJ151020162741 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 04 09 W TVD 8064 Tubin l 613 _ ' 616- 616 - 1 616 - g1 1760300 -,.. Well Type •Ind PTD VAR Type Test sPT Test psi 2016 IA 181 2500 2470 2452 11 Interval Q P/F P OA 253 474 - 496 525 Notes: Initial MIT-IA post AA AIO 04F.003.4.9 BBLS diesel pumped. 1 well inspected,no exceptions noted. ,,, Wednesday,October 28,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, July 04, 2015 9:14 AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Injector 04-09 (PTD #1760300) Attachments: image001.png; 04-09 aio4f-003 AA .pdf All, Injector 04-09 (PTD#1760300) was found to have an impaired tree valve while preparing to bring well on injection. The tree needs to be replaced due to the impaired valve before well can be placed on injection. The well is reclassified as Not Operable until the tree is replaced and tested.The well will be added to the Quarterly Not Operable Injector Report. Plan forward: 1. Valve Shop: Replace and pressure test tree 2. Well Integrity: Reclassify well as Under Evaluation SOWED JUL 0 6 201 3. Operations: Place well on injection 5 4. DHD: AOGCC MIT-IA when well is thermally stable Please call with any questions. Thank you, Kevin Parks (Alter nut(: Whitney Pettus BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIlntegrityCoordinator@bp.com From: AK, D&C Well Integ Coordinator Sent: Wednesday, July 01, 201 • AM To: AK, OPS FS2 OSM; AK, OPS FS2 DS ead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Danie, an; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Injector 04-09 (PTD #1760300) Administrative Appro eady to be put on injection 1 bp RECEIVED 0 AUG 21 2014 AvlatiC BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-031 B-11, B-24, B-25, C-10, L2 -07A, 0-02, M-04, M-05, U-14 The information on this CDS is to be used for BP Exploration (Alaska) Inc. business only. If you are not the owner or licensed user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this Angela K. S; CD by error, please return the CD to the address shown below. BP will pay the postage. Thank you. Please Sign and gancpdcgbp.com Doug Dortch Petrotechnical Data ie Attn: State of Alaska Attn: Makana Bender 333 W. 7th Ave, Suite 1 Anchorage, Alaska 99501 If found please return CL, BP Exploi PO Box 1 Anchorac 99519-6E CD 1 0] 06 0� 09- 1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Thursday, August 14, 2014 4:29 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Injector 04-09 (PTD #1760300) Failed MIT -IA - Outer Annulus Repressurization Attachments: image001.png; Injector 04-09 (PTD #1760300) MIT -OA Form - 08-12-2014.xls All, Injector 04-09 (PTD #1760300) failed two MIT -[As on 08/13/2014 based on pressure loss in the inner annulus and on outer annulus repressurization. The failing tests indicate a lack of two competent barriers in the wellbore. The well is reclassified as Not Operable until inner annulus integrity can be restored and confirmed. The well will be added to the Quarterly Not Operable Injector Report. A copy of the MIT -IA is enclosed for reference. Thank you, Jack Disbrow SCANNEV, BP Alaska - Well Integrity Coordinator G � /� J Global Wells Y V Organization Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@bp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg(Zi)alaska.gov; AOGCC.Inspectors(d_alaska.gov; phoebe.brooks(a)alaska.gov chris.wallace(o)alaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: GPB/PBU/DS4 DATE: OPERATOR REP AOGCC REP: 08/12/14 Jack Disbrow Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-09 Type In'. W TVD 8,064' Tubing 800 800 800 800 Interval 0 P.T.D. 1760300 Type test P Test psi 2016 Casing 12 12 11 11 P/F P Notes: Non Witnessed MIT -OA OA 227 1200 1165 1157 Well I Type In'. TVD Tubing Interval P.T.D. I Type test I I Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type Inj. I TVD Tubing Interval P.T.D. I Type test I I Test psi Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) Injector 04-09 (PTD #1760300) MIT -OA Form - 08-12-2014 (2).xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Tuesday, August 12, 2014 5:04 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); Igbokwe, Chidiebere Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: OPERABLE: Injector 04-09 (PTD #1760300) MIT -IA and OA Passed - Outer Annulus Repressurization Not Observed Attachments: image003 jpg; image001.png; Injector 04-09 (PTD #1760300) TIO and Injection Plot.docx; Injector 04-09 (PTD #1760300) MIT -IA Form - 06-02-2014.xls; Injector 04-09 (PTD #1760300) MIT -OA Form - 08-12-2014.xis All, Injector 04-09 (PTD #1760300) passed an MIT -IA on 06/02/2014 with no indications of outer annulus repressurization. An MIT -OA passed on 08/12/2014. The passing tests indicate two competent barriers in the wellbore. During the Under Evaluation monitoring period the outer annulus pressure did not equalize or track with the inner annulus pressure. The well is reclassified as Operable. Arctic pack was found in the outer annulus jewelry during the monitoring period and four subsequent purges produced a small amount of arctic pack material. Plan forward: 1. DHD: Perform AOGCC Witnessed MIT -IA Copies of the TIO and Injection plots as well as the MIT -IA and OA results are attached. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator SCANNED Global Wells GW Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, July 03, 2014 10:43 PM To: 'chris.wallace@alaska.gov'; 'Regg, James B (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan; Igbokwe, Chidiebere; AK, OPS FF Well Ops Comp Rep Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector 04-09 (PTD #1760300) All, WAG Injector 04-09 (PTD # 1760300) was made Not Operable November 12, 2012 as the well was thought to be exhibiting slow OA repressurization. At this time, BP would like to evaluate the well for future use as it is ideally situated for offset production. Per AOGCC permission, the well has been reclassified as Under Evaluation for diagnostics. Plan forward: Operations: Put well on water injection DHD/WIE: Monitor daily TIO pressures for anomalies 3. DHD: AP dump as needed Use care when bringing well online, as annuli are fluid packed and will be sensitive to thermal affects. A copy of the wellbore schematic has been included for reference. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator GWGiowi Wei is Y Y Organizatton WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com 4.000 3,000 2.000 1,000 4 000 3 000 2000 t.000 Injector 04-09 (PTD #1760300) TIO Plot f win: ao9 Injector 04-09 (PTD #1760300) Injection Plot f WW" �— Tbq t 1A �— OA OOA t OOOA On --*-- Tbq —F w —+-. OA OOA �— OOOA On STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regg(dalaska.gov; AOGCC.Inspectors(Ci)alaska.gov; phoebe.brooksCdalaska.gov chris.wallace(o)alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: GPB/PBU/DS4 DATE: 06/02/14 OPERATOR REP: Laurie Climer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-09 Type Inj, W TVD 8,064' Tubing 12 13 13 13 1 1 Interval p P.T.D. 1 1760300 Type test I P Test psi 2016 Casing 2,505 2,504 2,470 2,458 1 1 P/F I P Notes: Non Witnessed MIT -IA OA 52 49 47 47 Well I Type Inj. I I TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. I Type test I Test psi Casin P/F Notes: OA Well I Type In'. I TVD i Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) Injector 04-09 (PTD #1760300) MIT -IA Form - 06.02-2014.xls INTERVAL Codes 1 = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regq alaska.gov; AOGCC.Inspectors(d)-alaska.gov; phoebe.brooks(a)alaska.gov chris.wallaceCdalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD DATE: OPERATOR REP: AOGCC REP: GPB/PBU/DS4 08/12/14 Jack Disbrow Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-09 Type In'. I W TVD 8.064' T. 800 800 800 800 1 1 Interval 0 P.T.D. 1 1760300 Type test I P Test psi 2016 Casin 12 12 1 P/F P Notes: Non Witnessed MIT -OA OA 227 1200 1165 1157 Well I Type Inj. I I TVD I Tubing I I Interval P.T.D. I Type test I I Test psi Casin P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD I Tubing I I Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. I Type test Test psi I Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) Injector 04-09 (PTD #1760300) MIT -OA Form - 08-12-2014.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, July 30, 2014 3:22 PM To: Wallace, Chris D (DOA) Cc: Igbokwe, Chidiebere; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer Subject: Extending Under Evaluation period for Injector 04-09 (PTD #1760300) Attachments: image002.jpg Chris, Per our discussion earlier, BP will be extending the diagnostic period on Injector 04-09 (PTD #1760300) to observe the OA pressure trend. It is anticipated that 2 weeks will be sufficient additional time for data gathering. Plan forward as agreed upon: 1. DHD: Bleed IA and OA pressure down 2. DHD/WIE: Monitor TIO plot daily Please call with any questions. Thank you, Laurie Climer (,41tcrn«h,:.7ock Dicbrmr•) BP Alaska - Well Integrity Coordinator GW&obalwells Organuaton WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 t'liti R Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Thursday, July 03, 2014 10:43 PM To: Wallace, Chris D (DOA); Regg, James B (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan; Igbokwe, Chidiebere; AK, OPS FF Well Ops Comp Rep Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector 04-09 (PTD #1760300) Attachments: 04-09 Wellbore Schematic.pdf; 04-09 2 yr TIO and Injection Plot 12-01-10 to 12-01-12.docx; image003 jpg All, WAG Injector 04-09 (PTD # 1760300) was made Not Operable November 12, 2012 as the well was thought to be exhibiting slow OA repressurization. At this time, BP would like to evaluate the well for future use as it is ideally situated for offset production. Per AOGCC permission, the well has been reclassified as Under Evaluation for diagnostics. Plan forward: 1. Operations: Put well on water injection 2. DHD/WIE: Monitor daily TIO pressures for anomalies 3. DHD: AP dump as needed Use care when bringing well online, as annuli are fluid packed and will be sensitive to thermal affects. A copy of the wellbore schematic has been included for reference. Please call with any questions. Thank you, Laurie Climer S iMMED i ; 7; ,I i I (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator GYMGk)oai Wells Organaaron WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 I Injector 04-09 (PTD # 1760300) 2 year TIO plot 12/01/10 — 12/01/12 wwi am t neo f- u ooa i ��Ml OLiN] WI�'11 M'1S t} OS'1SY} 0"t6'�} (d^.6'�] 09'f4 is 4 yr Injection Plot w�a� LREE = 5-1/8" FMC WELLHEAD = FMC ACTUATOR = AXELSON KB ELEV = 52 0' BF REV= 32 16' KOP = 3300' Max Angle = 61 ` @ 7579' Datum MD = 11726' Datum TVD = 8800' SS 9-5/8" FOC 2363' 13-3!8"CSG, 72#, MN -80, ID = 12 347" 2654' Minimum ID = 2.992" @ 10786' 4 1/2" NO-GO SETTING SLEEVE L 1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" --F-10667- 5-1/2" TBG SEAL ASSY W/O SEALS, ID = 4.89" 10674' PERFORATION SUMMARY REF LOG BRCS ON 05/02/76 ANGLE AT TOP PERF 35'@11580- 5°@11580'Note Refer to Production DB for historical pert data Note SIZE SPF INTERVAL Opn/Sqz DATE 2-1 /2" 4 11580 - 11600 O 12/14/97 2-1/8" 4 11600 - 11620 O 10/04/97 CWKAK RWO 02/09/11 11620- 11622 S 06/26/96 3-1/2' SCAB LNR (CTD) 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE 11629- 11635 S 06/26/96 2-1 /2" 6 11635 - 11654 0 11/17/01 2-1/2' 6 11666 - 11674 O 03/15/06 2-112' 6 11682- 11696 O 03/15/06 2-7/8" 4 11752- 11792 O 09/30/90 3-3/8" 10 11807- 11824 0 06/29/85 3-3/8" 10 11840 - 11865 O 06/29/85 9-5/8" CSG, 47#, MN -80, ID = 8 681 " 11090' 3-1/2" LNR-CT, 9 3#, L-80, 0087 bpf, ID = 2.992" 11697' 3-1/2" DAVIS LYNCH DOUBLE VALVE SHOE 11698' 7" LNR, 29#, L-80, 0371 bpf, ID = 6.184" I-- 12050' 12053' MI SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON MI. DEPTH DISCREPANCY BETWEEN BTM OF 5-1/2" SEAL ASSY AND TOP OF BOT PBR. SEAL ASSY WAS INSERTED AND TBG SPACED OUT PER RIG REPORT. 2236'` }- 5-112" CA MCO BAL-O SSSV NIP iD = 4 562" 2613' 1-j9-518" FOC 10489' -15-1/2" HES X NIP, ID = 4.562" 10511' -{9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.750" 10618' I—i5-1 /2" HES XN NIP, ID = 4 455" 10692' -15-1/2" BOT PBRASSY 1071'V 9-5/_8_-X_5_-1_/2_- B0T3-H PKR 10722-7-45-1/2- X 4-1/2" XO, ID = 3 958" 10786' -17" BKR MC LNR HGR 10786' 4-1/2" NO-GO DEPLOY SLV, ID = 2 932" 10802' 4-1!2" CA MCO DB NIP, ID = 3.813" 10814' 4-1/2" TBG, 12.6#, L-80, 0152 bpf, ID = 3.958" 10815' 4-1/2" TUBING TAIL (BEHIND CT LINER) 10799' ELMD TT LOGGED 06/29/85 11957' PBTD DATE REV BY COMMENTS GATE I REV BY COMMENTS 05111/76 ORIGINAL COMPLETION 03/15/06 ???/TLH ADD PERFS 05122185 RWO 07/14/06 KNC/TLH PERF CORRECTIONS 08/19101 CWKAK RWO 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE 06/28/96 3-1/2' SCAB LNR (CTD) 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE 04/01/01 1 RN/KAK CORRECTIONS 11/18/01 ITMKAKIPERFS & PULL IBP PRUDHOE BAY UNIT WELL 04-09 PERMIT No '1760300 API No 50-029-20207-00 SEC 27, T11 N, R1 5E, 325' FSL & 643' FEL BP Exploration (Alaska) Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, July 03, 2014 1:07 PM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Permission to put WAG Injector 04-09 (PTD #1760300) Under Evaluation for additional diagnostics, revision Attachments: image001.jpg Laurie, 04-09 is Approved for the 28 days water injection monitoring and evaluation as per your plan forward. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.waIlace@alaska.eov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipienf(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.c�ov. From: AK, D&C Well Integrity Coordinator[ma i Ito: AKDCWeI II nteg rityCoord inator@ bp.com] Sent: Wednesday, July 02, 2014 9:31 PM To: Wallace, Chris D (DOA) Subject: Permission to put WAG Injector 04-09 (PTD #1760300) Under Evaluation for additional diagnostics, revision Good Morning Chris, Per our conversation, BP would like to re-examine WAG Injector 04-09 (PTD # 1760300) condition . The well was made Not Operable November 12, 2012 as the well was thought to have slow OA repressurization exhibiting. At the time, the well injection pattern did not justify additional wellwork, and an AA was not pursued. At this time, BP would like to evaluate the condition of the well for future use, as this well is the ideal primary injection well for a stimulation treatment for offset producers. The well had been treated with Arctic Pack during initial completion, and as a result has anomalous pressure spikes. After looking at the historical TIO data, the OAP and IAP never trended historically, with the OA appearing to have a potential external pressure source. The well had a passing MIT -IA in September 2012 (AOGCC witnessed) and June 2014, with passing PPPOT-T/IC tests as well in June 2014. Plan Forward: Operations to begin water injection for up to 28 days DHD/WIE: Monitor TIO pressures daily for anomalies For reference, I have attached a copy of two year TIO, recent MIT -IA, and Injection plots while the well was online, as well as a wellbore schematic. Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator /'�tAI Gal Wens V 11 M Organizavon WIC Office: 907.659.5102 WIC Email: AKDCWellintep.rityCoordinator@BP.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.reggaalaska.gov; AOGCC.InspectorsCdalaska.gov; phoebe.brooks(5)alaska.gov chris.wallace&alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: Prudhoe Bay / PBU / 04 DATE: 06/02/14 OPERATOR REP: Laurie Climer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. W.11 104-09 Type Inj. N TVD 8,064' Tubing 12 13 13 13 Interval 0 P.T.D. 1 1760300 Type test P Test psi 1 2016 Casing 2 2,504 2,470 2,458 P/F P Notes: Off cycle MIT -IA while shut in for additional OA 52 47 47 47 evaluation. Well I Type In'. I I TVD I Tubing Interval P.T.D. I Type test I I Test psi Casing P/F Notes: OA Well I Type In . TVD Tubin Interval P.T.D. I Type test I Test psi Casin9l I I I I PIF Notes: OA Well I Type Inj.1 I TVD I Tubing Interval P.T.D.1 I Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT PBU 04.0906-02-14.xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance 0 = Other (describe in notes) • Cr Ct_04 - C/l • Pr1J - 76 30o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] e i t o j � � rv- - Sent: Tuesday, October 16, 2012 4:24 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; Brooks, Phoebe L (DOA) Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 04 -09 (PTD #1760300) IAxOA Communication All, After further evaluation of the IAxOA response observed on injector 04 -09 (PTD #1760300), BPXA has decided not to pursue an Administrative Approval at this time. The well is reclassified to Not Operable and should be shut in as soon as safely possible. Please call if you have any questions or would like to discuss further. Thank you, DINED APR 14 2.0 13 Mehreen Vazir BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Thursday, October 04, 2012 5:54 PM To: 'Regg, James B (DOA)'; 'chris.wallace @alaska.gov'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan; Brooks, Phoebe L (DOA) (phoebe.brooks @alaska.gov) Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS, LLC) Subject: OPERABLE: Injector 04 -09 (PTD #1760300) Pursue AA for IAxOA Communication All, Injector 04 -09 (PTD #1760300) has been monitored during day OART to evaluate IAxOA communication and an OA build up rate of ^'93 psi /day was established. An AOGCC nessed MIT -IA was performed and exhibited minimal pressure loss and pressure stabilization proving compe ent tubing and production casing, however the OA continues to exhibit repressurization. The well also passed an MIT •A to 2000 psi proving competent surface casing. At this time, BPXA has approval to pursue an AO CC Administrative Approval for continued water injection only. The well can remain on injection and will be repor ed on the AOGCC Monthly Injection Report while the AA request is progressed. Thank you, Mehreen Vazir BPXA Well Integrity Coordinator 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 12, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-09 PRUDHOE BAY UNIT 04-09 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT 04-09 API Well Number 50-029-20207-00-00 Inspector Name: Jeff Jones Permit Number: 176-030-0 Inspection Date: 9/9/2012 Insp Num: mitJJ121010093923 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min —_ - - Well 04-09 Type Inj w (TVD 1 8064 IA 703 2330 ' 2310 2305 2303 ' 1760300 �� TD Type Test SPT Test psi 2016 ''�, OA 283 432 487 - 562 603 — Interval 4YRTST P/F P Tubing 1117 1102 1101. 1100 1101 Notes: 3.7 BBLS methanol pumped. 1 well inspected, no exceptions noted. 5�"%EC3 OCT 0 92014 Friday, October 12, 2012 1 Page I of I �� Pit b o ,u0 Regg, James B (DOA) From: Regg, James B (DOA) 10 Sent: Friday, October 05, 2012 3:14 PM To: AK, D &C Well Integrity Coordinator Cc: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Subject: RE: OPERABLE: Injector 04 -09 (PTD #1760300) Pursue AA for IAxOA Communication Appreciate your call this afternoon and discussion about how to classify the MITIA on this well. I understand that BPXA's internal policy is that a well must pass an MIT to continue injection. In the case of PBU 04 -09, the MITIA indicates competent tubing (no pressure change during MITIA), indicates stabilizing pressure in the IA (as required for passing MITIA), but does indicate some evidence of pressure communication to the OA (9 -5/8 x 13 -3/8). The passing MITOA you reference indicates the 13 -3/8" casing is competent so whatever communication is occurring while testing the tubing - casing annulus may be a one -way leak (IA to OA only) Considering both MITIA and MITOA, we will consider PBU 04 -09 as passing the 9/9/2012 MITIA which will enable BPXA to pursue the administrative approval from AOGCC necessary to continue injection with an indication of pressure communication from the IA to OA. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SCANNED APR 17 2O13 Anchorage, AK 99501 907 - 793 -1236 From: Regg, James B (DOA) Sent: Thursday, October 04, 2012 8:12 PM To: AK, D &C Well Integrity Coordinator; Wallace, Chris D (DOA) Subject: Re: OPERABLE: Injector 04 -09 (PTD #1760300) Pursue AA for IAxOA Communication Sorry I did not get back to you this afternoon. Regarding the MIT commitment in Admin Approval there are a couple options: 1) MITIA with OA repressure test will allow trending for deteriorating conditions; 2) passing CMIT TxIA should confirm tubing and outer casing integrity; 3) passing MITT would confirm primary barrier. Some combination of these would seem to be prudent; BPXA needs to propose what it believes will best confirm integrity allowing injection to continue. Other conditions you can anticipate are OA pressure limit, doumenting bleeds, and other standard requirements. "AK, D &C Well Integrity Coordinator" <AKDCWeIIIntegrityCoordinator@ bp.com> wrote: All, Injector 04 -09 (PTD #1760300) has been monitored during a 10 day OART to evaluate IAxOA communication and an OA build up rate of ^'93 psi /day was established. An AOGCC witnessed MIT -IA was performed and exhibited minimal pressure loss and pressure stabilization proving competent tubing and production casing, however the OA continues to exhibit repressurization. The well also passed an MIT -OA to 2000 psi proving competent surface casing. At this time, BPXA has approval to pursue an AOGCC Administrative Approval for continued water injection only. The well can remain on injection and will be reported on the AOGCC Monthly Injection Report while the AA request is progressed. 1 • • Thank you, Mehreen Vazir BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto jim.req j alaska.gov] Sent: Monday, September 10, 2012 4:37 PM To: AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Agree with your plan based on what was observed by AOGCC Inspector. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinatorPbp .com] Sent: Monday, September 10, 2012 4:12 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Brooks, Phoebe L (DOA) Subject: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Jim /Chris, An AOGCC witnessed MIT -IA was performed on WAG Injector 04 -09 (PTP # 1760300) on 09/09/2012. The test was determined to be inconclusive by the AOGCC representative, Mr.. eff Jones, as the OA pressure was climbing during the test. The IA exhibited minimal pressure loss during the 45 minute test period with a stabilizing trend as seen in the attached MIT form. This well does ave a history of artic pack in the OA and an artic pack flush was performed on 07/13/2012. An MIT -OA to .00 psi passed on 07/29/2012. The well currently remains on injection and I propose the following pl. forward: 1. Downhole Diagnostics: Perform OA Repressurizatio Test over 10 days with 1500 psi differential between IA and OA. Monitor for equalization of IA and •A or OA stabilization. An OA build up rate can also be established during this period if IAxOA communic. ion is present. 2. Well Integrity Coordinator: Upon completio of test, submit results to AOGCC to determine Operability status. MIT -IA form and recent TIO Plot and Injection Plot are attached for reference: «MIT PBU 04 - 09 09 09 12.xls» «04 - 09 '10 Plot 09 10 12.docx» Thank you, Mehreen Vazir 2 • t 04--09 • ) 76 b 3 Regg, James B (DOA) From: Regg, James B (DOA) �/' 1 to 51 Vv Sent: Wednesday, October 03, 2012 10:23 AM To: 'AK, D &C Well Integrity Coordinator' Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Agree with pursuing Admin Approval for IAxOA communication. I am leaving the test result as inconclusive because of the OA pressure build during MIT. That will not prevent us from issuing an Admin Approval. Jim Regg AOGCC ScAHNEU APR a 8 21113 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: AK, D &C Well Integrity Coordinator [mailto :AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, October 02, 2012 12:27 PM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Hello Jim /Chris, An OA repressurization test was performed on Injector 04 -09 (PTD #1760300) over the period of 09/22/2012 - 10/02/2012 with the well on injection. The starting tubing /IA /OA pressures were 780/1380/0 psi. At the end of the 10 day period the tubing /IA /OA pressures are 1100/1330/926 psi. This indicates an OA build up rate of - 93 psi /day. No significant changes in injection temperature were noted during this period. At this time, the well remains on injection and BPXA would like to pursue an Administrative Approval for IAxOA communication which is manageable with periodic bleeds. Please let me know if this is acceptable and if the AOGCC witnessed MIT -IA on 09/09/2012 should be classified as a Pass or Fail. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator GIAV GIOk}�It�t � eil� 7rg n °.z Lion WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.VazirPBP.com 1 • • From: Regg, James B (DOA) [mailto:jim.recg©alaska.gov] Sent: Monday, September 10, 2012 4:37 PM To: AK, D&C Well Integrity Coordinator Cc: Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: RE: UNDER EVALUATION: Injector 04-09 (PTD #1760300)AOGCC MIT-IA Inconclusive Agree with your plan based on what was observed by AOGCC Inspector. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator @lbp.com] Sent: Monday, September 10, 2012 4:12 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Brooks, Phoebe L(DOA) Subject: UNDER EVALUATION: Injector 04-09 (PTD #1760300)AOGCC MIT-IA Inconclusive Jim/Chris, An AOGCC witnessed MIT-IA was performed on WAG Injector 04-09 (PTD# 1760300) on 09/09/2012. The test was determined to be inconclusive by the AOGCC representative, Mr.Jeff Jones, as the OA pressure was climbing during the test. The IA exhibited minimal pressure loss during the 45 minute test period with a stabilizing trend as seen in the attached MIT form. This well does have a history of artic pack in the OA and an artic pack flush was performed on 07/13/2012. An MIT-OA to 2000 psi passed on 07/29/2012. The well currently remains on injection and I propose the following plan forward: 1. Downhole Diagnostics: Perform OA Repressurization Test over 10 days with 1500 psi differential between IA and OA. Monitor for equalization of IA and OA or OA stabilization. An OA build up rate can also be established during this period if IAxOA communication is present. 2. Well Integrity Coordinator: Upon completion of test, submit results to AOGCC to determine Operability status. MIT-IA form and recent TIO Plot and Injection Plot are attached for reference: «MIT PBU 04-09 09-09-12.xls» «04-09 TIO Plot 09-10-12.docx» Thank you, Mehreen Vazir BPXA Well Integrity Coordinator 907-659-5102 2 • • From: AK, D&C Well Integrity Coordinator Sent: Tuesday, September 04, 2012 9:18 PM To: 'Regg, James B (DOA)'; 'chris.wallace @alaska.gov'; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); AK, D&C Well Integrity Coordinator; Vazir, Mehreen; Murphy, Gerald L; AK, D&C DHD Well Integrity Engineer; Wills, Shane M; Olson, Andrew Subject: Under Evaluation: Injector 04-09 (PTD #1760300) MITIA Passed Post PPPOT-IC All, Injector 04-09 (PTD#1760300) passed an MITIA on 08/17/2012 to 2520 psi after performing a passing PPPOT- IC ( ) p p p g p g IC on 07/13/2012 to 3500 psi. The passing tests indicate two competent barriers in the well. The well is reclassified as Under Evaluation. Plan forward: 1. Operations: Return well to water injection 2. Fullbore: AOGCC witnessed MIT-IA once well has thermally stabilized A copy of the MIT and wellbore schematic have been included for reference. « File: 04-09.pdf» « File: MIT PBU DSO4-09 8-17-2012.xls » Please call if you have any questions or concerns. Thank you Shane Wills filling in for Mehreen Vazir BP Alaska -Well Integrity Coordinator « OLE Object: Picture (Device Independent Bitmap) >> WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir @BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday,July 10, 2012 8:22 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L(DOA)'; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan Cc: AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 04-09 (PTD #1760300) MIT-IA Failed 3 • • All, Injector 04-09 (PTD#1760300)failed an MIT-IA due to the OA pressure tracking the IA pressure. The well is reclassified as Not Operable and should be shut in as soon as possible until integrity can be restored. The plan forward: 1. Wellhead —PPPOT-IC 2. Downhole Diagnostics—Re-attempt MIT-IA A wellbore schematic, TIO plot and Injection Plot are attached for reference. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling &Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com 4 • • Pact 04 -ef p '7( 03Do Regg, James B (DOA) From: Regg, James B (DOA) t � Z— Sent: Monday, September 10, 2012 4:37 PM Loy 1 To: 'AK, D &C Well Integrity Coordinator' // Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: RE: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Agree with your plan based on what was observed by AOGCC Inspector. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 SCANNED WM1 0 7 2013 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWellIntegrityCoordinatorftp .com] Sent: Monday, September 10, 2012 4 :12 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Cc: Brooks, Phoebe L (DOA) Subject: UNDER EVALUATION: Injector 04 -09 (PTD #1760300) AOGCC MIT -IA Inconclusive Jim /Chris, An AOGCC witnessed MIT -IA was performed on WAG Injector 04 -09 (PTD # 1760300) on 09/09/2012. The test was determined to be inconclusive by the AOGCC representative, Mr. Jeff Jones, as the OA pressure was climbing during the test. The IA exhibited minimal pressure Toss during the 45 minute test period with a stabilizing trend as seen in the attached MIT form. This well does have a history of artic pack in the OA and an artic pack flush was performed on 07/13/2012. An MIT -OA to 2000 psi passed on 07/29/2012. The well currently remains on injection and I propose the following plan forward: 1. Downhole Diagnostics: Perform OA Repressurization Test over 10 days with 1500 psi differential between IA and OA. Monitor for equalization of IA and OA or OA stabilization. An OA build up rate can also be established during this period if IAxOA communication is present. 2. Well Integrity Coordinator: Upon completion of test, submit results to AOGCC to determine Operability status. MIT -IA form and recent TIO Plot and Injection Plot are attached for reference: «MIT PBU 04 - 09 09 09 12.xls» «04 - 09 TIO Plot 09 10 12.docx» Thank you, Mehreen Vazir BPXA Well Integrity Coordinator 907 - 659 -5102 1 • • PBU 04 -09 PTD #1760300 9/10/2012 TIO Pressures Plot Well 06-09 12, 71 91 2 015 • 030A De • 1040 ^1"6 6'i2L12 0772 12 060112 059502 0,19e] 0970ID2 _ 04.m12 27 ., _ _ _ g� 4.4,ce OA ePtt' , ? 4ti ©;- Injection Plot x q c0. H.(4, cca:>Fz � — ` / 1' 0 Il v well: am Mr :91.9 rmo 1 .110 traf - fOG 1501 Ur� V , v \ ---✓✓✓ J/ � �� ' .I YSm, riL ly j� f u coo -B000 pew 604 6074 500. -SOOC ]OC -100L 104 01 412 04.12 04.12 040102 05.12 04.1,12 W.S213 06 "2 C4Jfo-12 .1 O'/ffi11 4fl'1I12 OYTwY2 994Y4t2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq doa. aogcc.prudhoe.bavCD.alaska.govi phoebe.brooksOalaska.aov; tom.maunder @alaska.00v OPERATOR: BP Exploration (Alaska), Inc. I l \ I/ q I� 1 v FIELD / UNIT / PAD: Prudhoe Bay /PBU /DS -04 ( J DATE: 09/09/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04 -09 ' Type Inj. W TVD - 8,064' Tubing 1117 1102 - 1101 1100 1101 ' Interval 4 P.T.D. 1760300 ' Type test P Test psi ' 2016 Casing 703 2330 2310 2305 2303 - P/F -P" cI- <<r.YtGCt,$t i t Notes: OA 283 `" 432 487 - 562 - 603 Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inl. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT PBU 04 - 09 09 - 09 - 12 • i, Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, September 04, 2012 9:18 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); AK, D &C Well Integrity Coordinator; Vazir, Mehreen; Murphy, Gerald L; AK, D &C DHD Well Integrity Engineer; Shane.Wills @bp.com; Olson, Andrew Subject: Under Evaluation: Injector 04 -09 (PTD #1760300) MITIA Passed Post PPPOT -IC Attachments: 04- 09.pdf; MIT PBU DSO4 -09 8- 17- 2012.xls All, pm) f e % c)o Injector 04 - 09 (PTD #1760300) passed an MITIA on 08/17/2012 to 2520 psi after performing a passing PPPOT- IC on 07/13/2012 to 3500 psi. The passing tests indicate two competent barriers in the well. The well is reclassified as Under Evaluation. Plan forward: SCAN �ED MAY 0 I Z V3 1. Operations: Return well to water injection 2. Fullbore: AOGCC witnessed MIT -IA once well has thermally stabilized A copy of the MIT and wellbore schematic have been included for reference. «04- 09.pdf» «MIT PBU DSO4 -09 8- 17- 2012.xls» Please call if you have any questions or concerns. Thank you Shane Wills filling in for Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@ BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@ BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, July 10, 2012 8:22 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline 1 • • Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 04 -09 (PTD #1760300) MIT -IA Failed All, Injector 04 -09 (PTD #1760300) failed an MIT -IA due to the OA pressure tracking the IA pressure. The well is reclassified as Not Operable and should be shut in as soon as possible until integrity can be restored. The plan forward: 1. Wellhead — PPPOT -IC 2. Downhole Diagnostics — Re- attempt MIT -IA A wellbore schematic, TIO plot and Injection Plot are attached for reference. Thank you, Mehreen Vazir (Alternate Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 2 TREE= 5 FMC • NOTES: H25 READINGS AVERAGE 125 WELLHEAD = FMC pp HEN ON MI. WELL REQUIRES A SSSV ACTUATOR = - AXELSON 04 WHEN ON MI. DEPTH DISCREPANCY BETWEEN KB ELEV - 52.0' BTM OF 5 -1/2" SEAL ASSY AND TOP OF BOT PBR BF. ELEV = 32,16' SEAL ASSY WAS INSERTED AND TBG SPACED OUT PER RIG REPORT. Max Angle = 61° :∎ 7579' Datum MD = 11726' Datum TVD = 8800' SS 2236' - I5 -1/2" CAMCO BA L-0 SSSV NIP, ID = 4 562" I I9 -5/8" FOC IH 2363' 1- 2613' H9 -5/8" FOC 1 13- 318 "CSG, 72#, MN-80, ID = 12.347" I-- 2654' I" , Minimum ID = 2.992" @ 10786' 4 112" NO -GO SETTING SLEEVE ' I 10489 ' — 15 -1/2" HES X NIP, ID = 4 562" O M I 10511' 1-1915/8" X BKR S -3 PKR, 1 0 - 4 7 5 0 - 1 I 10618' 1- - I5 - 12" HES XN NIP, ID = 4.455" 1 15-1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4,892" 1—[ 10667 I I 10692' H5-1/2" BOT PBR ASSY I 5-1/7 TBG SEAL ASSY W/O SEALS, ID = 4,89" J-- 10674' t �� [ 10711' H9 -5/8 X 5 -1 /7' BOT 3 -H PKR 1 PERFORATION SUMMARY 10722' 5-1/7' X 4-1/2" XO, ID = 3.958" REF LOG: BHCS ON 05/02/76 ANGLE AT TOP PERF : 35 @ 11580' Note. Refer to R'oductaon DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 4 11580 - 11600 0 12/14/97 2 -118" 4 11600 - 11620 0 10/04197 10786' I—{7" BKR MC LNR HGR I 11620 - 11622 S 0626/96 10786' H4-1/2" NO-GO DEPLOY SLV, ID 2.992" 11629 - 11635 S 06/26/96 10802' H4-1/7 CA MCO DB NIP, ID = 3.813" 1 2 -12" 6 11635 - 11654 O 11/17/71 2- 112 6 11666 11674 O 03!15/06 I 10814' I- 14 -1 /2" TBG, 12.6#, L -80, ,0152 bpf, ID= 3.958" I 2 -1 /7 6 11682 11696 0 03/15/06 — J 10815' I--[4 - 112" TUBING TAIL (BEHIND CT LINER) I 2 -7/8" 4 11752 - 11792 0 09/30/90 I 10799' —IELMD TT LOGGED 06/29/85 1 3 -3/8" 10 11807 - 11824 0 0629/85 3-3/8" 10 11840 - 11865 0 06/29/85 • ►N 1'x'1 1 1 •�• 9- 518" CSG, 47 #, MN-80, ID = 8.681" H 11090' ►4141 1�1�1 •• ••• I3 -1/2" LNR -CT, 9.3 #, L -80, 0087 bpf, ID = 2.992" H 11697' 4 IAA- 4,,t. I3 -1/2" DAVIS LYNCH DOUBLE VALVE SHOE 11698' !�`4'� •4•�' 1 ♦����♦ , 1 11957' HPBTD ►1f1e.111 1 7" LNR, 29#, L -80, .0371 bpf, ID = 6 184" H 12050' 44444444 ITDI —I 12053' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/11/76 ORIGINAL COMPLETION 03/15/06 ? ? ?1TLH ADD PERFS WELL. 04 -09 05/22185 ,RWO 07/14/06 KNGTLH PERF CORRECTIONS PERMIT No 1 760300 08119/01 CHPKAK RWO 02/09/11 MB/JM) ADDED SSSV SAFETY NOTE AR No 50-029-20207-00 0628/96 • 3 -1/2° SCAB LNR (CID) 01/10/12 TMWJMD ADDED I-QS SAFETY NOTE SEC 27, T11N, R15E, 325' FSL & 643' FEL 04!01/01 RN/KAK CORRECTIONS 11/18/01 TMN/KAK PERFS & PULL IBP 61f° Exploration (Alaska) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recrnl talaska.gov; doa .aogcc.prudhoe.bay(8alaska.gov; phoebe.brooksalalaska.gov; tom.maunder(8alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay /PBU /DS -04 DATE: 08/17/12 OPERATOR REP: Gerald Murphy /Mehreen Vazir AOGCC REP: N/A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04 -09 Type Inj. WAG TVD 8,064' Tubing Vac Vac Vac Vac Vac Vac Interval 0 P.T.D. 1760300 Type test P Test psi 2016 Casing Vac 2520 2495 2487 2481 2476 P/F P Notes: MITIA for resume water Injection OA Vac 5 11 13 16 18 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA r r Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 (Revised 06/2010) MIT PBU DSO4-09 8- 17- 2012_xls MEMORANDUM State of Alaska Permit Number: 176-030-0 Alaska Oil and Gas Conservation Commission TO: Jim Re -7)8 i gg I1�7 I1 DATE: Wednesday, August 01, 2012 P.I. Supervisor SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial BP EXPLORATION(ALASKA)INC Well 04-09 In' W •TVD 8064 1 IA I 334 2302 J I 04-09 FROM: Jeff Jones PRUDHOE BAY UNIT 04-09 Petroleum Inspector OA I 631 Src: Inspector 924 - Reviewed By: P.I. Suprv� P/F NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-09 API Well Number 50-029-20207-00-00 Inspector Name: Jeff Jones Permit Number: 176-030-0 Inspection Date: 7/10/2012 Insp Num: mitJ.1120730181336 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-09 In' W •TVD 8064 1 IA I 334 2302 J I 2258 - �Type 1760300 SPT TD . Type Test Test psi 2016 � OA I 631 843 924 - Interval 4YRTST P/F F ✓ Tubing 1282 1262 1254 Notes: 4 BBLS methanol pumped. While pumping up the IA the OA began to quickly gain pressure: IA X OA communication. Test discontinued to prevent OA from being overpressured. Wednesday, August 01, 2012 Page 1 of I • • Brooks, Phoebe L (DOA) P11) # 17( -M200 From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, July 31, 2012 4:10 PM To: Brooks, Phoebe L (DOA) Subject: RE: Missing MITs Attachments: 04 -09 (PTD #1760300) wellbore schematic.pdf; 04 -13 (PTD #1780310) welibore schematic.pdf Phoebe, Both of the wells have a stacked packer in them, with your depth being related to the lower one, and the upper packer being related to the depth on the form. If 1 need to change to reflect the lower packer, please let me know, otherwise the depth on the form is currently the highest packer in the well. Please let me know how I can be of further assistance. Jerry Murphy BPXA Well Integrity Coordinator "NED A 2 U From: Brooks, Phoebe L (DOA) [ mailto :phoebe.brooksCa�alaska.gov] Sent: Tuesday, July 31, 2012 3:49 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Missing MITs Jerry /Mehreen, Will you please send me the schematics for wells 04 -09 and 04 -13? The Packer TVD that we have in our database differs from what is on your report (for 04 -09 we have a MD of 10711' with a TVD of 8064' and for 04 -13 we have a MD of 9950' with a TVD of 8355'). Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 -793 -1242 Fax: 907 - 276 -7542 From: Wallace, Chris D (DOA) Sent: Tuesday, July 31, 2012 7:25 AM To: Brooks, Phoebe L (DOA) Subject: FW: Missing MITs Phoebe, Can you please look for these records and see if we have these MIT's and try to establish the timeline of information flows into AOGCC. Thanks, Thanks and Regards, Chris Wallace 1 , NOTES: H2S READINGS AVERAGE 125 WELLHEAD i= FIX 04-09 , s ppm WHEN ON MI. WELL REQUIRES A SSSV ACTUATOR = AXELSON WHEN ON ML DEPTH DISCREPANCY BETWEEN KB, ELEV = 52.0' BTM 0F5-112' SEAL ASSY AND TOP OF ROT P BR BF, ELEA/ = 32,16 SEAL ASSY WAS INSERTED AND TBG SPACED RCP = ' - - 3:300 . OUT PER RIG REPORT. AraXAngle= 7579' turn fik) -44 -= -4444— 11i2 Datum TVD =4-44-444-:ii.--4'. • 2236' }-15-1/2" CAMCO BA L-0 SSSV NIP, ID =-. 4,567 I 9 FOC !H 2363' I- -•• -... A — --, 2613' —9-5/8" FOC 1 13-3/8"CSG, 72#, MN-80, tD = 12 H 2654' 1 ■ . Minimum ID = 2.992" @ 10786' 4 112" NO-GO SETTING SLEEVE I 1 1 10486' H5-1/2" HES X NIP, ID -- 4,562' 10511' 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.750" I • 10618' H5-112" HES XN NIP, ID = 4 455" 15-1/2" TBG, 17 i.. bpf,10-;4 iiieil. 1 : 10692' — 5-1/2" BOT PBR ASSY [5-1/2" TBG SEAL ASSY W/O SEALS, ID = 4.89" —I 10674' ' 10711 1 — 9-5/8" X 5-1/2" BOT 3-H PKR PERFORATION SUMMARY 10722' --15-1/2" X , 4-1/2" X0, ID = 3,958"1 REF LOG: BHCS ON 05/02/76 ANGLE AT TOP PERE: 35• i. 11580' Note. Refer to FI-oduction DB for historical pert data .. SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11580 - 11600 0 12/14/97 107: i' —[7" BKR MC LNR FIGR 2-1/8" 4 11600 - 11...4 0 10/04/97 11620 - 11622 S 06/26/96 II 10786' H4-1/2" NO-GO DEPLOY SLV, ID = 2,992" „ .. 11629 - 11. '.. 2-1/2" 6 11635 - 11654 0 11/17/01 I :0 4 CA 12 D , ID = 3,958„ 2-1/2" 6 11666 - 11674 0 03/15/06 2-1/2" 6 11682 - 11696 0 03/15/06 10815' H4-1/2" TUBING TAIL (BEHIND CT LINER) 1 2-7/8" 4 11752 - 11792 0 09/30/90 [ 10799' — 1 - ELM0 TT LOGGED 06/29/85 1 3-3/8" ' 10 11807 - 11824 0 06/29/85 3-3/8" ' 10 11840 - 11:::. 0 06/29/85 IWI ... 1 * • . 4 4.4.1 9 CSG, 47#, MN ID = 8681" H 11090' *4: 4 4` / 4 I 4 : 13-1/2" LNR-CT, 9 3#, L-80, .0087 bpf, ID = 2.997 1 EMI 4... ..: 3-112" DAVIS LY NCH DOUBLE VALVE SHOE MEM I I F • v.. 4 11957' — PBTD T' LNR, 29#, L-80, .0371 bpf, ID= 6,184" 12050' • * •1 , , • • • A •,•.; [ ID 12053' ' AAAAA DATE REV BY COMMENTS .4 DATE REV BY COMMENTS i PRUDHOE BAY UNIT 05/11176. ORIGINAL COMPLETION 03/15/06 ???/TLH ADD PERFS WELL. 04-09 , 05122185 MO 07/14/06 KNCITLH PERE CORRECTIONS PERMIT No: '1760300 06119101 CH1KAK RM/0 02/09/11 MB/J MD ADDED SSSV SAFETY NOTE AF1No: 50-029-20207-00 4. : • . 3-1/2' SCAB LNR (CTD) 01/10/12 TMil/JMID ADDED H2S SAFETY NOTE SEC 27, T11N, R15E, 325' FSL & 643' FEL 04/01/01 ' RNIKAK CORRECTIONS 11/18/01 TMN/KAK PERES & PULL IBP BP Exploration (Alaska) . ' ' , aa- -vq P71) 17� Dko Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Tuesday, July 10, 2012 8:22 PM jf 71alizv To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; Daniel, Ryan Cc: AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 04-09 (PTD #1760300) MIT -IA Failed Attachments: 04-09.pdf; 04-09 TIO Plot 07-10-12.docx .� All, Injector 04-09 (PTD #1760300) failed an MIT -IA due to the OA pressure tracking the IA pressure. The well is reclassified as Not Operable and should be shut in as soon as possible until integrity can be restored. The plan forward: 1. Wellhead — PPPOT-IC 2. Downhole Diagnostics — Re -attempt MIT -IA A wellbore schematic, TIO plot and Injection Plot are attached for reference. «04-09.pdf>> «04-09 TIO Plot 07-10-12.docx>> Thank you, .Mehreen Vazir (Alternate: Gerald Xfurphv) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office 907.659.5102 Email: AKDCWeIIlntegrityCoordinator@BP.com SCA I. 1 PBU 04-09 PTD #1760300 7/10/2012 TIO Pressures Plot M, Im Inject TREE = , - 5-1/8" FMC WELLHEAD = FMC ACTUATOR= AXldSON KB. ELEV = 52.0' BF ELEV = 32 16' KOP = 3300' Max Angle = 61 ° @ 7579' Datum MD = 11726' Datum TVD = 8800' SS 9-518" FOC -j 2363' 13-3/8"CSG, 72#, MN -80, ID = 12.347" 2654' Minimum ID = 2.992" @ 10786' 4 112" NO-GO SETTING SLEEVE= 5-1/2" TBG, 17#, L-80_0232 bpf, ID = 4,892" J_L 10667' 5-1/2" TBG SEAL ASSY W/O SEALS, ID= 4.89" 10674' PERFORATION SUMMARY REF LOG BRCS ON 05/02/76 ANGLE AT TOP PERF 35°@111580' Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2' 4 11580 - 11600 0 12114197 2-1/8" 4 11600 - 11620 0 10104197 06/28/96 3-112" SCAB LNR (CTD) 11620 - 11622 S 06/26/96 11629 - 11635 S 06/26/96 2-112' 6 11635 - 11654 0 11/17/01 2-112" 6 11666 - 11674 O 03/15/06 2-112" 6 11682 - 11696 0 03/15/06 2-7/8" 4 11752 - 11792 0 09!30/90 3-3/8" 10 11807 - 11824 0 06129/85 3-3/8" 10 11840 - 11865 0 06/29/85 9-518" CSG, 47#, MN -80, ID --'8'681 - 11090' 13-'/2" LNR-CT, 9 3#. L-80, ,0087 bpf, ID = 2.992" 1169T 3-1/2" DAVIS LYNCH DOUBLE VALVE SHOE 11698' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" f---) 12050' 206' a� J []l SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES SSSV WHEN ON MI. DEPTH DISCREPANCY BETWEEN BTM OF 5-1/2" SEAL ASSY AND TOP OF BOT PBR. SEAL ASSY WAS INSERTED AND TBG SPACED OUT PER RIG REPORT. 2236' —15-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" 2613' i—i 9-518" FOC 10489` —15-1f2" HES X NIP, ID = 4.562" 10511' {9-5/8 X 5-1 t2" BKR S-3 PKR, 10 = 4.750 10618 5-112" NES XN NIP, ID = 4 455" 10692'--{5-112" BOT PBR ASSY 10711' 9 -_5/_8 -_X_5_1_/2_ - 10722' 5/8"X51/2"10722' 5-112" X 4-112" XO, ID = 3.958" 1 10786' �--j7" BKR MC LNR HGR 10786' 4.112" NO-GO DEPLOY 5LV, iD = 2.992 .10802' 4-112" CA MCO DB NIP, 10 = 3,813" 10814' � 4-1/2" TBG, 12 6#, L-80, .0152 bpf, ID = 3.958" 10815' 4-1/2" TUBING TAIL (BEHIND CT LINER) 10799' ELMD TT LOGGED 06129/85 11957' 1—IPBTD D\TE REV BY COMMENTS DATE REV BY COMMENTS 05/11176 ORIGINAL COMPLETION 03115/06 ???/TLH ADD PERFS 05/22185 RWO 07/14/06 KNCITLH PERF CORRECTIONS 08/19101 CHIKAK RWO 02/09111 MB/JMD ADDED SSSV SAFETY NOTE 06/28/96 3-112" SCAB LNR (CTD) 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE 04/01/01 RN/KAK CORRECTIONS 11/18/01 TMN/KAK I PERFS & PULL IBP PRUDHOE BAY UNIT WELL: 04-09 PERMIT No1760300 API No. 50-029-20207-00 SEC 27, T11 N, R15E, 325' FSL & 643' FEL BP Exploration (Alaska) TO: Jim Regg ~~ j ~~'~l t ~ +r`~`~', P.I. Supervisor FltoNt: Chuck Scheve Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Iuly 23, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 04-09 PRUDHOE BAY UNIT 04-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~"+'~ Comm Well Name• PRUDHOE BAY UNIT 04-09 Insp Num: mitCS080722194348 Rel Insp Num: API Well Number: 50-029-20207-00-00 Permit Number: 176-030-0 Inspector Name• Chuck Scheve Inspection Date: 7/222008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well oa-o9 ;Type Inj. `r' ~~ TVD 79zs IA i ao z19o ~ z17o z13o I 2110 ~ p.T. 1760300 TypeTest SPT ,Test psi 19sz pA ]zo ~ ]zo lzo ]zo ]zo Interval 4YRTST per, P ~ Tubing ~ I300 I 1300 1300 1000 ' 1000 Notes: ~rr'N~~ AUG ~ ~ 2Q~8 Wednesday, July 23, 2008 Page 1 of l R~~":'~v ~ù AUG 0 8 2006 Scblum~erger .~ Oil & Gas Cons. Commj$~ NO. 3883 Anchorage ~ ~ SCi\NNEXJ; !\Ub - Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth l/IC'... rKc, -O~3C) Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII C J b# L D D BL C e 0 og escrlptron ate olor D NK-43 11211388 PROD PRUI"lLI: vvlDEFT 04/0~06 1 NK-22A 10568415 PROD PROFILE W/DEFT 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02105 1 X-15A 11212877 USIT 07/18/06 1 J-01 B 11511430 USIT 07/24106 1 15-12A 11221595 USIT 07/25/06 1 Z-14B 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF US IT 01/26106 1 D-03A 11217269 USIT 07/31106 1 05-28A 11217267 US IT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consultmg Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/01106 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ?J1A ,/ ( P.I. Supervisor, "'ï. 1 7(14- ú4 DATE: Wednesday, July 28, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) lNC 04-09 PRUDHOE BAY UNIT 04-09 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed BY5Ct- P.I. Suprv Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-09 API Well Number: 50-029-20207-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ040728 I 12251 Permit Number: 176-030-0 Inspection Date: 7/22/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-09 Type Inj. s TVD 9113 IA 930 4000 3960 3920 3900 P.T. 1760300 TypeTest SPT Test psi 1982 OA 690 910 1020 1100 1140 Interval 4YRTST PIF p Tubing 1600 1600 1600 1600 1600 Notes: Pre-Ml swap. 6.7 BBLS SO/50 methanol pumped. 1 well house inspected; no exceptions noted. Test was extended 15 minutes to further analyze casing integrity. Although the MITIA pressure data observed meets AOGCC requirements for a passing MIT, the increasing OA pressure may indicate a small IA x OA leak. rJ ~ i~j -h, aU fBt{ Gì\ -0 1 -k> }.4Y\¥J¡ i t\~c~ wilt MfM~J I iSt-1' ~ ~J\~ . Wednesday, July 28, 2004 Page I of I PBU 04-09 (PTD 1760300) Subject: PBU 04-09 (PTD 1760300) From: James Regg <jim_regg@admin.state.ak.us> Date: Thu, 29 Jul 2004 13:39:24 -0800 T,;';"',",.,','N,,S-U," 'A~,U1"" 'W"eJl'Jn',t ",f:b,,';H":"""'" "',II",<N'SU' :A"D",WW, 'll'In'"t;,',":",',tv.,'",:w;",.,','::,',',,"M,,:,:",,"!t,n"",',',:i,',~,i"""!rj.,:n,,',',',',::,;,~~,',:,',!',':),':,~,;¡~~j,¡,"l',;}¡"¡¡¡¡,',~~'ii,'~,"~,"" O.~" " ~I¡n ,e811'\1 ,ngmeer, " e, egn~.1p~,F~~~~Ð~~~,¡';4~~~:' *PBU 04-09* MIT dated 7/22/04 (witnessed by Jeff Jones) reportedly passed but showed a 230 psi increase in OA pressure during the 45 minute test. Please add this well to the monthly injector well list so we can track the pressures in the CA. * *Thanks. Jim Regg AOGCC 1 of 1 7/29/2004 1 :39 PM l" STATE OF ALASKA ~" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] SuspendE] Operation ShutdownE] Perforate E] varianceE] Annuar DisposalE] After Casin~lE] RepairWellE] Pluq Perforationsr-I Stimulate[] Time Extension[-'] Other[-'l Change Approved Program[--] Pull TubingE] Perforate New PoolE~ Re-enter Suspended we, E] SCHMOO-B-GONE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement El Exploratoryr-] 176-030 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic El Service · 50-029-20207-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 04-09 8. Property Designation: 10. Field/Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12050 feet true vertical 9116 feet Plugs (measured) Tagged TD @ 11806' (01/05/2003). Effective Depth measured 11806' feet Junk (measured) true vertical 8919 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' 40K 520 Surface 2622' 13-3/8" 2654' 2654' 80K 2670 Intermediate 11058' 9-5/8" 11090' 8339' 80K 4760 Liner 1264' 7" 10786'-12050' 8116'-9116' 80K 7020 ScabCT Liner 912' 3-1/2" 10786'-11698' 8116'-8829' 80K 10530 Perforation depth: Measured depth: Open Perfs 11575'-11615', 11635'-11654', 11752'-11792', 11807'-11824', Open Perfs (continued) 11840'-11865'. True vertical depth: Open Perfs 8728'-8761', 8777'-8793', 8874'-8907', 8920'-8934', 8947'-8967'. Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 TBG @ 10722'. 5-1/2" x 4-1/2" XO @ 4-1/2" 12.6# L-80 TBG @ 10815'. Packers& SSSV (type& measured depth) 9-5/8" x 5-1/2" BOT 3-H Packer @ 10711'. JUN ][ ?_003 5-1/2" CAMCO BAL-O SSSV Nipple @ 2236'. ,~,~r~,-~.,, f'~;~ ,'~'~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 13407 1104 Subsequent to operation: 17654 2748 14. Attachments: 15. Well Class after proposed work: Exploratory['-I DevelopmentE] Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: Oil[--] Gas[--~ WAG· GINJI--I WlNJr-] WDSPLF-I Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: "~' .... """' "'--'~"--" I N/A Contact DeWayne R. Schnorr Printed Name DeWavne R. Schnorr ,, Title Techical Assistant Signature"'"~,5~~.,~z~, ~;~. ~)'~-t4-3,7~ Phone 907/564-5174 Date June04,2003 issb~ Form 10-404 R~~''~''~ JUL 0 8 20113 OR,IG'INAL 04-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/23/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 05/27/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MITIA 05/30/2003 ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR 06/04/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 2,748 TYPE: MI VOLUME: 17,654 MSCF. EVENT SUMMARY O5/23/O3 PUMPED 2 BBLS METHANOL, 280 BBLS SBG, 5 BBLS METHANOL, DOWN INJECTION LINE TO TUBING. CALLED DSO WITH JOB INFORMATION. O5/27/O3 T/I/O=VAC/VACNAC. MITIA TO 4000 PSI. PASSED. IA FL @ 150' (7 BBLS). TBG FL @ NEAR SURFACE. PT TO 4200 PSI. MANIFOLD LEAK REPAIRED MANIFOLD. PUMPED 10 BBLS TO 2640 PSI RUN OUT METHANOL. SD TO GO GET MORE METHANOL FOR 45 MINUTES. PUMPED 3 MORE BBLS OF METHANOL TO 4000 PSI. PRESSURED IA TO 4000 PSI WITH 13 BBLS OF METHANOL. STARTED TEST LOST 20 PSI IN THE FIRST 15 MINUTES, LOST 10 PSI IN THE SECOND 15 MINUTES FOR A TOTAL OF 30 PSI. BLED IA TO 100 PSI. FINAL T/I/O = VAC/100/VAC. 05/30/03 T/I/O= 2400/50/60 (POST MITIA) TEMP HOT lAP DECREASED 50 PSI IN 3 DAYS. 06/O4/O3 TESTEVENT--- INJECTION PRESSURE, PSI: 2,748 TYPE: MI VOLUME: 17,654 MSCF. FLUIDS PUMPED BBLS 7 METHANOL 280 SCHMOO-B-GONE 287 TOTAL Page I Re: 04-09 Request to cancel AOGCC Sundry;~,~ce # 300-145 dated 06-05-2000 Subject: Re: 04-09 Request to cancel AOGCC Sundry Notice # 300-145 dated 06-05-2000 Date: Wed, 09 Jan 2002 16:04:36 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Kevin, I appreciate your following up with this request. I think the sundry essentially gets canceled through the performance of the workover. The need of the sundry is due to the MIT failure which the workover corrected. By my thinking the sundry then becomes superfluous. Your request to drop the sundry requirements is approved. Hope all is well. Tom "NSU, ADW Well Integrity Engineer" wrote: Tom & Winton Injection Well 04-09 (PTD # 176-030) has recently had a RWO completed to repair communication. On 01/08/02 after the RWO it passed a state inspector witnessed MIT test reflecting integrity. I would like to cancel this sundry # 300 - 145 that requires a 2 year CMIT and rep/ace it with the standard 4 year test and to eliminate for this well only the monthly report of we//head and injection pressures submitted to you. _ Should the well demonstrate communication problems, diagnostic work will be initiated and appropriate notification and action commenced. Thanks, Kevin. Tom Maunder <tom maunder _~.admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of I 1/9/02 4:04 PM MEMORANDUM TO: Camille Taylor Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 8, 2002 __ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~.~~~..2~ B PX P.I. Supervisor DS-4 & 11 4-9, 4-13, 11~35 FROM: John H. Spaulding PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ' WellJ 4-09 Typelnj.I S I T.V.D. 17928 I Tubingl 2000 12000 i'2000 ! o00 I,nterva, I I P.T.D.I'1760300 TypetestI P ITestpsil 1982 ICasingI 620 I 2600,,I 25901 25851 P/F I P Notes: WellI 4-13 I Typelnj. I S I T.V.D. 18210 I Tubing I~000 I~000 I~000 I~000I,nte~va, I, P.T.D.I 17880310 Tyl~etestI P ITestpsil 2053 ICasingI 1050I 2600I 2600I 2600I P/F I P Notes: I I I ¢0 , 'P.T.D.I 1940650 ITypetestI P ITestpsil 2050 I CasingI 1580 I 2600 I 2550 I 2550 I P/F I P Notes: P.T.D.I Notes: WellI P.-I-.D.I . Notes: Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F: FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4--= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Both 4-09 and 4-13 were post rig workovers, while 11-35 recently was converted from a producer to an injector. All thre wells passed their respective MIT's and are in compliance with area injection orders. M.I.T.'s performed: 3 Attachments: none Number of Failures: 0 Total Time during tests: 1.5 hrs cc: none MIT report form 5/12/00 L.G. MIT PBU FS-2 1-08-02js.xls 3/7/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _X Alter casing _ Repair well _X Other _X (RWO, WAG convert) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 52 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4955' FNL, 643' FEL, Sec. 27, T11 N, R15E, UM (asp's 712178, 5952179) 04-09i At top of productive interval 9. Permit number/approval number 3595' FNL, 1511' FEL, SEC. 35, T11 N, R15E, UM (asp's 716703, 5948387) 176-030 / approval # 301-230 signed 8/6/2001 At effective depth 10. APl number 50-029-20207 At total depth 11. Field / Pool 3893' FNL, 1345' FEL, Sec. 35, T11 N, R15E, UM (asp's 716879, 5948093) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12050 feet Plugs (measured) Tagged top of fish @ 10739' SLM 9/10/01. true vertical 9116 feet Effective depth: measured 10739 feet Junk (measured) Stuck IBP @ 10739' SLM in 4-1/2" tubing. true vertical 8084 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 240 Sx AS 80' 80' Surface 2602' 13-3/8" 5300 Sx PF II 2654' 2654' Production 11038' 9-5/8" 750 Sx Class G & 125 Sx PF II 11090' 8339' Liner 1264' 7" 31o Sx Cross O 10786' - 12050' 8116' - 9116' Scab CT Liner 912' 3-1/2" 6 bbls I_ARC 10786' - 11698' 8116' - 8829' Perforation depth: measured (Isolated below IBP Fish 11580' - 11620'; 11752' - 11792'; 11807' - 11824'; 11840' - 11865'). true vertical (Isolated below lBP Fish 8732'-8766'; 8874'-8907'; 8920'-8934'; " 'RECEIVED Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 Tubing @ 10711' MD; 4-1/2", 12.6#, L-80 Tubing @ 10815' MD. SEP 1 4 200 Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" Baker S-3 Packer @ 10511' MD; 9-5/8" X 5-1/2" BOT 3-H Packer @ 10711' MD. 4-1/2" Camco BAL-0 SSSV Nipple @ 2236' MD. Alaska 0il & Gas Cons. Commission 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measu red) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation (shut in) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service WAG 17. I hereby certify that the foregoing 'is true and correct to the best of my knowledge. Signed ~1~,~~ ~ ~_ Title: AD&W Drilling Engineer-----._ Date September 13, 2001 Vern Coyner Prepared by Paul Rauf 564-5799 Form 10-404 Rev 08/15/88 · SUBMIT IN DUPLICATE 04-09i DESCRIPTION OF WORK COMPLETED RIG WORKOVER / CONVERSION FROM WATER INJECTOR TO WAG INJECTOR Date Event Summary 5/31/2001: 6/01/2001' 6/1012001' 6/24/2001' 7102/2001' 8/09/2001 - 8/19/2001: 8/24/2001' 8/29/2001' 8/30/2001' 8/31/2001' 9/07/2001' 9/08/2001' 9/09/2001' 9/10/2001' MIRU CTU. PT'd equip. RIH w/CT & pumped 252 bbls of Schmoo-be-gone (SBG). PUH w/ CT. Let soak for 3 hrs. Jetted SBG from wellbore & POOH w/CT. Performed full BOPE test. RIH w/CT & set IBP in the 4-1/2" Tubing Tail @ 10756.5' MD (mid element depth). Top of IBP @ 10750'. Tagged IBP. Pumped a gelled sand slurry consisting of 500 lbs of 20/40 mesh Carbolite Sand ontop ofthe IBP. Made a final TOS tag @ 10713.5' & POOH w/CT. FP'd well. RD CTU. RIH w/Slickline & drifted to 10700'. CMIT - IA + OA to 2000 psi - passed. RIH w/chem cutter & cut the 5-1/2" tubing @ 10650'. Performed R WO w~ Doyon 16 Rig (see attached operations summary). RIH & pulled 5-1/2" Camco DSSSV. Pulled Ball & Rod. Pulled 5-1/2" RHC Plug Body. Tagged TOS @ 10709' SLM. MIRU CTU. PT'd equip. Performed FCO to the top of the IBP @ 10722' CTM. Made several attempts to fish IBP from tubing - no recovery. Made several attempts to fish IBP from tubing - no recovery. RD CTU. MIRU CTU. Ran LIB to 10691' SLM - impression of half moon. Ran Venturi Junk Basket to 10770'. POOH - recovered frac sand. Made several attempts to fish IBP from tubing - no recovery. Tagged fish @ 10792' CTM. RIH & washed down on fish to 10792'. Latched fish & POOH - recovered fishing neck & part of IBP internals. FP'd well. RD CTU. With Slickline, ran LIB to 10737'. Ran Pump Bailer - recovered frac sand. Made several runs to 10739' w/Pump Bailer - recovered frac sand. Well 04-09i is currently shut in, awaiting the successful recovery of the IBP & a state witnessed MITIA. It will be initially put on water injection service but later, be placed on MI service. The well is now considered a WAG Injector. Page 1 Legal Well Name: 04-09i Common Well Name: 04-09i Event Name: WORKOVER Start Date: 8/10/2001 End Date: 8/9/2001 (ft) NU TREE ON 15-05A. RD MO 15-O5A. MOVE RIG TO DRILL SITE 4 8/10/2001 (ft) MOVED RIG TO DRILL SITE 4. MOVED ONTO 4-09i. R/U RIG. ClRC TBG. 8/11/2001 (ft) ClRC WELL w/SEAWATER,N/D TREE, N/U & TST BOPE, R/U TO PULL TBG 8/12/2001 (ft) FISHED TBG W SPEAR. LAYED DOWN 5 1/2 TBG. RIH TO FISH SEAL ASSY. 8/13/2001 (ft) FISHED SE. AL ASSY & POH. RIH WITH RTTS TO 100' & TESTED TO 3000 PSI.O 8/14/2001 (ft) PRES TEST CSG, L/D R'I-FS, RIH W/MILL & SCRAPER, ClRC CLEAN 8/15/2001 (ft) LD DP, RIH GAGE RING JUNK BASKET, RIH W/BAKER PKR/5 1/2" COMPLETIO 8/16/2001 (ft) F/RIH W/5 1/2" COMPLETION STRING, DRIFT & TEST EVERY 2000' 8/17/2001 (ft) PRES TEST FI SSSV TO SURFACE, RET SSSV DUMMY, FISH BALL/ROD 8/18/2001 (ft) RET W/L PLUG, SET SSSV DUMMY CHG T/SEA H20, FREEZE PROT ND BOP N 8/19/2001 (ft) TEST TREE TO 5000 PSI, INSTALLED BPV, RELEASED RIG AT 0300 HOURS Printed: 9113/2001 1:15:05 PM TREE = , 5-1/8" FMC NELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 52.0' BF. ELEV = 32.16' KOP = 3300' Max Angle = 61 @ 7579' Datum MD = 11726' Datum TVD = 8800' SS 19-5/8'' FOCI-t 2363' [ 13-3/8"CSG, 72#, MN-80, ID = 12.347" Id 2654,' 04-09i SAF' ~.NOTES: DEPTH DISCREPANCY BETWEEN BTM OF 5- ,,z" SEAL ASSY AND TOP OF BOT PBR. SEAL ASSY WAS INSERTED AND TBG SPACED OUT PER RIG REPORT. 8/30/01 - FCO & ATTEMPT TO FISH IBPWHICH FELL TO 10792' CTMD 2236' 1_15-1/2" CAMCO BAL-O SSSV NIP, ID=4.562" 2613' I-I~-,~",ooI IMinimum ID = 2.992" @ 10786' 4 1/2" NO-GO SETTING SLEEVE 15-1/2"'rBG, 17#, L-80, 0.0232 bpf, ID=4.892" Id 10667' 15-1/2"TBGSEALASSY W/OSEALS, ID=4.89" I--I 10674' 10,489' 10511' 10618' 10692' 10711' 10722' I--~5-1/2" HES X NIP, ID = 4.562"I I--~9-5/8"X5-1/2"BKRS-3PKR, ID=4.750" I I--]5-1/2" HES XN NIP, ID= 4.455"I I--]5-1/2" BOT PBR ASSYI 1-19-5/8,, x 5-1/2" BOT 3-H PKR I I--]5-1/2" X 4-1/2" XO, ID= 3.958"I PERFORATION SUMMARY REF LOG: BHCS 05/02/76 ANGLEATTOP PERF: 35 @ 11580' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11580- 11600 O 12/14/97 2-1/8" 4 11600- 11620 O 10/04/97 2-7~8" 4 11752 - 11792 O 09~30~90 3-3~8" 10 11807- 11824 O 06~29~85 3-3~8" 10 11840 - 11865 O 06~29~85 I 9-5/8" C, SG, 47#, MN-80, ID = 8.681" Id 11090' 10786' 10786' 10802' 1081~ 10815' I 10799' 3-3/8" BKR IBP Stuck I I-I.-~,, .o-~o DEPLOY SLV, ID = ~..0~"I CAMCO DB NIP, ID = 3.813" 1_.14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-~4-1/2" TUBING TAIL (BEHIND CT LINER) 13-1/2" LNR-CT, 9.3#, L-80, .0087 bpf, ID = 2.992" Id 11697' 13-1/2"DAVISLYNCHDOUBLEVALVESHOE I--I 11698' I 17"LNR, 29#,L-80,0.0371 bpf, ID=6.184" Iff 12050' ~ ~ r~d 12053' I 11957' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/11/76 ORIGINAL COMPLETION 04/01/01 RN/KAK CORRECTIONS 05/22/85 RWO 06/01/01 DYK/tlh IBP SET 06/28/96 3-1/2" SCAB LNR (CTD) 08/19/01 CH/KAK RWO 12/28/00 SIS-MWI- CONVERTED TO CANVAS 08/30/01 ATD/tlh FCO & IBP FELL 02/08/01 SIS-MD FINAL 09/13/01 pcr RWO corrections PRUDHOE BAY UNIT WELL: 04-09i PERMIT No: 176-030 AP! No: 50-029-20207-00 SEC. 27, T11N, R15E, 325' FSL & 643' FEL BP Exploration (Alaska) Legal Well Name: 04-09i Oommon Well Name: 04-09i 8pud Date: 8/10/2001 Event Name: WORKOVER 8tart: 8/~ 0/200~ End: Oontractor Name: DOYON Rig Release: 8/~9/2001 Rig Name: Doyon 16 Rig Number: 8/9/2001 12:00 - 00:00 12.00 MOB P PRE MOVE RIG TO DRILL 81TE 4 8/10/2001 00:00 - 05:00 5.00 MOB P DECOMP MOVED RIG FROM DS 15 TO DS 4 05:00 - 06:00 1.00 MOB P DECOMP MOVED RIG ONTO DS 4 AT 05:00 HRS. REMOVE BOOSTER WHEELS. 06:00- 07:00 1.00 RIGU P DECOMP PJSM. RAISED DERRICK 07:00 - 08:00 1.00 RIGU P DECOMP LAYED HERCULITE AND MATS, RU HOISTS AND FLOOR. HUNG BRIDLE LINE. 08:00 - 09:00 1.00 RIGU P DECOMP MOVED OVER WELL, 4-9i AND LEVELED RIG. 09:00 - 12:00 3.00 RIGU P DECOMP BERMED UP HERCULITE. P / U KELLY. INSTALLED NEW KELLY HOSE AND SET BACK. R / U FLOOR. 12:00 - 13:00 1.00 RIGU P DECOMP HAD PRE-SPUD MEETING AT CAMP. RIG ACCEPTED AT 13:00 HRS ON 8-10-01. 13:00 - 14:00 1.00 RIGU P DECOMP HAD SAFETY MEETING ON DROPPED OBJECTS. GIVEN BY MEL O'BRIEN. 14:00 - 16:30 2.50 RIGU P DECOMP INSTALLED ANNULAR VALVE AND R / U LINES TO TOP OF PRODUCTION TREE AND IA. RIGGED UP HARD LINE FROM IA TO WELL #38 FLOW LINE. 16:30 - 18:00 1.50 RIGU P DECOMP HELD PJSM. P / U DSM LUBRICATOR AND RETREIVED BPV. R / D SAME. 18:00 - 20:00 2.00 RIGU P DECOMP HELD PJSM. MIXED H2S SCAVANGER AND CAUSTIC SODA IN SEAWATER AND TRANSFERED SEAWATER TO TIGER TANKS. 20:00- 20:30 0.50 RIGU P DECOMP HELD PJSM. HELD H2S DRILL PRIOR TO CIRCULATING. 20:30 - 00:00 3.50 RIGU P DECOMP CIRULATED SEAWATER DOWN TUBING AT 70 SPM AND 1000 PSI. TOOK RETURNS FROM ANNULUS DOWN HARD LINE TO WELL #38 FLOW LINE. 8/11/2001 00:00 - 01:00 1.00 KILL P DECOMP CONTINUED TO CIRCULATE WELL DOWN TUBING. TOOK RETURNS THROUGH IA DOWN HARDLINE TO WELL #38 FLOW LINE. PUMP RATE 6 BPM AT 1,000 PSI. TOTAL PUMPED 1,200 BBLS. 01:00 - 01:30 0.50 WHSUR :' DECOMP HELD PJSM. R / U HB&R. PUMPED 90 BBLS OF DIESEL TO FREEZE PROTECT #38 FLOWLINE. R / D HB&R. NOTE: HELD H2S DRILL, GOOD RESPONSE TIME BY CREW. 01:30 - 04:00 2.50 WHSUR :) DECOMP HELD PJSM. N / D PRODUCTION TREE. BOLTS RUSTED, JARRED TREE LOOSE AND SET BACK. CHECKED HANGER THREADS. 04:00 - 05:00 1.00 WHSUR P DECOMP M / U AND INSTALLED BLANKING PLUG IN BPV & HANGER. 05:00 - 09:00 4.00 BOPSUF~,P DECOMP HELD PJSM. N / U BOPE. SINGLE RAM w/3-1/2" x 7" VARIABLES, DOUBLE RAM w/BLIND RAMS IN MIDDLE AND 3-1/2" x 6" VARIABLES ON TOP, w/ANNULAR PREVENTER. DIFFICULTY MAKING UP CHOKE LINE DUE TO EXTENDED HEIGHT OF STACK CAUSED BY TALL TUBING SPOOL. (6-1/2" AGL). 09:00 - 10:00 1.00 BOPSUF P DECOMP FUNCTION TESTED BOPS, OK. 10:00 - 10:30 0.50 BOPSUI; P DECOMP ia / U & SET TEST JOINTAND XO's 10:30 - 18:30 8.00 BOPSUF; :' DECOMP TESTED BOPE. TESTED BLIND RAMS, CHOKE LINE, Printed: 8/21/2001 3:57:55 PM Legal Well Name: 04-09i Common Well Name: 04-09i Spud Date: 8/10/2001 Event Name: WORKOVER Start: 8/10/2001 End: Contractor Name: DOYON Rig Release: 8/19/2001 Rig Name: Doyon 16 Rig Number: 8/11/2001 10:30 - 18:30 8.00 BOPSUR P DECOMP CHOKE MANIFOLD AND VALVES, TIW VALVES AND ALL SURFACE EQUIPMENT TO 3,500 PSI HIGH / 250 PSI LOW. TESTED ANNULAR TO 3,500 PSI HIGH / 250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/NO LEAKS OR PRESSURE LOSS. ATTEMPTED TEST ON UPPER PIPE RAMS, DOOR SEAL LF_AKED, REPLACED DOOR SEAL AND ATTEMPTED RE-TEST, STEM PACKING ON KILL LINE HCR VALVE LEAKED. TESTED PVT EQUIPMENT, OK. TESTED LEL AND H2S GAS ALARMS, RE-CALIBRATED, OK. TESTS WITNESSED BY LOU GRAMALDI - AOGCC 18:30 - 20:30 2.00 BOPSUF.N DECOMP HELD PJSM. CHANGED OUT KILL LINE HCR VALVE. 20:30 - 21:00 0.50 BOPSUF N DECOMP TESTED HCR VALVE AND KILL LINE TO 250 PSI LOW FOR 5 MINUTES AND 3,500 PSI HIGH FOR 10 MINUTES. TESTS HELD w/NO PRESSURE LOSS OR LEAKS. 21:00 - 21:30 0.50 BOPSUF~ ~ DECOMP PULLED BLANKING PLUG AND TEST JOINT. 21:30 - 23:30 2.00 BOPSUF~ ~ DECOMP P / U LUBRICATOR AND PULLED BPV. DSM HAD TO MAKE FIVE ATTEMPTS TO SUCCESSFULLY PULL BPV. 23:30 - 00:00 0.50 CLEAN P DECOMP P / U BAKER SPEAR AND ONE JOINT OF 3 1/2 TUBING. FMC BACKED OUT LDS. REPLACED TWO DHCV NIPPLES WITH DHCV BLANKS. RU TBG TONGS AND CONTROL LINE SPOOL. 8/12/2001 00:00 - 01:00 1.00 WHSUR P DECOMP HELD PJSM. FINISHED BACKING OUT LDS AND PLUGGING CONTROL LINE PORTS. BROUGHT TUBING TONGS AND CONTROL LINE SPOOL TO FLOOR. 01:00 - 01:30 0.50 PULL P DECOMP HELD PJSM. M / U BAKER DOUBLE SPEAR w/PACK OFF TO ONE JT OF 3-1/2" DP. ENGAGED SPEAR THROUGH TUBING HANGER. PULLED ON SPEAR TO 160,000#, NO MOVEMENT. WORKED SPEAR FROM 0~ TO 175,000# TUBING MOVEMENT BEGAN AT 195,000~. SLOWLY PULLED TUBING HANGER TO FLOOR. WEIGHT UP 165,000~. NOTE: MEASUREMENT FROM RIG FLOOR TO BOTTOM OF TGB HGR - 20.34' 01:30 - 02:00 0.50 PULL :) DECOMP BROKE OUT AND L / D BAKER SPEAR. BROKE OUT AND L / D TUBING HANGER AND PUP JOINT. 02:00 - 02:30 0.50 PULL :~ DECOMP i CHANGED OUT ELEVATORS. R / U TUBING TONGS AND CAMCO CONTROL LINE SPOOLER. 02:30 - 06:30 4.00 PULL P DECOMP POOH AND L / D 51 JOINTS OF 5-1/2" TUBING SPOOLED UP CONTROL LINE. RECOVERED 26 CLAMPS AND 4 METAL BANDS. 100% RECOVERY. 06:30 - 07:00 0.50 PULL P DECOMP R / D CAMCO LINE SPOOLING EQUIPMENT. 07:00 - 15:30 8.50 PULL P DECOMP POOH AND L / D 204 JOINTS OF 5-1/2" TUBING. TOTAL FULL JOINTS L / D 255. L / D CHEMICALLY CUT JOINT #256. LENGTH 23.46'. NOTE: LENGTH OF FISH IN HOLE 43.74', TOP OF FISH 10,667'. 15:30- 16:00 0.50 PULL P DECOMP RD TUBING EQUIPMENT 16:00 - 19:00 3.00 PULL :) DECOMP CHANGE BOTTOM RAMS TO 3 1/2. TEST RAMS TO 250 / Printed: 812112001 3:57:55 PM Legal Well Name: 04-09i Common Well Name: 04-09i Spud Date: 8/10/2001 Event Name: WORKOVER Start: 8/10/2001 End: Contractor Name: DOYON Rig Release: 8/19/2001 Rig Name: Doyon 16 Rig Number: 8/12/2001 16:00- 19:00 3.00 PULL P DECOMP 3,500 PSI. 19:00 - 21~00 2.00 PULL P DECOMP PU BAKER FISHING ASSEMBLY AND 9 6 3/4 DCs AND RIH. 21:00 - 00:00 3.00 PULL P DECOMP PU 3 1/2 DP FROM PIPE SHED AND RIH. RAN 320' TO 2700'. 811312001 00:00 - 04:30 4.50 PULL P DECOMP HELD PJSM. P / U, DRIFTED AND RIH w/125 JTS OF 3-1/2" DRILL PIPE. 04:30 - 07:00 2.50 PULL P DECOMP HELD PJSM. M / U & TIGHTENED KELLY. PT UPPER & LOWER KELLY COCK, KELLY HOSE AND STAND PIPE MANIFOLD, 250 PSI LOW FOR 5 MINUTES, 3,500 PSI HIGH i FOR 10 MINUTES. ALL TESTS HELD w/NO PRESSURE !LOSS OR LEAKS. 07:00 - 10:30 3.50 PULL P DECOMP P / U, DRIFTED AND RIH w/64 JTS OF 3-112" DRILL PIPE TO 10,617'. 10:30 - 11:30 1.00 PULL P DECOMP M / U KELLY AND CHECKED PARAMETERS. STRING WEIGHT UP 185,000#, STRING WEIGHT DOWN 115,000~, ROTATING STRING WEIGHT 140,000~, ROTARY 30 RPM, TORQUE 190 AMPS. STARTED PUMP, PUMP RATE 3.5 BPM, PRESSURE 450 PSI. RIH TO 10,652' PUMP PRESSURE INCREASED TO 600 PSI. SHUT DOWN PUMPS AND ENGAGED FISH. SET DOWN 15,000~ TO ENSURE FISH ENGAGEMENT. PULLED UP TO 200,000#, 15,000~ OVER STRING WEIGHT AND LET JARS BLEED OFF. PULLED UP TO 260,000~, 75,000~ OVER STRING WEIGHT AND SHEARED PBR OUT OF PACKER. PULLED UP 35'. STARTED PUMP, PUMP RATE 3.5 BPM, PRESSURE 450 PSI. LOWERED STRING 15', PUMP PRESSURE INCREASED TO 600 PSI, AS SEAL ASSEMBLY REENGAGED PACKER. SHUT DOWN PUMPS AND PULLED KELLY BUSHINGS ABOVE TABLE. 11:30 - 13:30 2.00 PULL 3 DECOMP PUMPED AND CIRCULATED AROUND 45 BBL HI-VIS SWEEP. PUMP RATE 6 BPM, SPP 1,600 PSI. NO GAS TO SURFACE. 13:30 - 14:00 0.50 PULL P DECOMP HELD PJSM. SET KELLY BACK. 14:00 - 18:30 4.50 PULL 3 DECOMP POOH w/3-112" DP. STOOD DP IN DERRICK. 18:30 - 19:00 0.50 PULL P DECOMP POOH w/9 6-3~4" DC. 19:00 - 20:00 1.00 PULL P DECOMP POOH AND LAYED DOWN BAKER FISHING ASSY AND 43' OF FISH. SEALASSY OD IS 6.10" AND ID IS 4.75". CLEARED RIG FLOOR. 20:00 - 21:00 1.00 PULL P DECOMP RIH WITH 3 STANDS OF 6 3/4" DCs, RTTS AND 1 STAND OF 3 1/2" DP. RTTS AT 100'. 21:00 - 22:00 1.00 PULL ~P DECOMP SET RTTS AT 100'. OPENED AND MONITORED CA. CLOSED UPPER PIPE RAMS AND TESTED 9 5/8" CASING AND WELL HEAD TO 3,000 PSI FOR 30 MINUTES. OK. 22:00 - 23:00 1.00 PULL P DECOMP POOH WITH DP. LAYED DOWN RTTS. SET BACK DCs. 23:00 - 00:00 1.00 PULL P DECOMP PU HOWCO RBP, PUP JOINT AND RTTS. 8/14/2001 00:00 - 02:30 2.50 CASE ~ DECOMP PJSM, MU DC'S RIH W/RBP ON 3 1/2 DP 02:30 - 04:30 2.00 CASE ~ DECOMP ATTEMPT TO SET RBP AT 2993', SET RTTS AT 3070', PRESSURE TESTED TO 3000 PSI, UNSET RTTS 04:30 - 06:00 1.50 CASE ~ DECOMP POOH W/RTTS/RBP BHA 06:00 - 07:00 1.00 CASE 3 DECOMP CLOSED BLINDS, PRESSURE TESTED 9 5/8" CASING FROM SURFACE TO 10750 TO 3000 PSI HELD PRESSURE 30 MIN ( OK ) Printed: 8/2112001 3:57:55 PM Legal Well Name: 04-09i Common Well Name: 04-09i Spud Date: 8/10/2001 Event Name: WORKOVER Start: 8/10/2001 End: Contractor Name: DOYON Rig Release: 8/19/2001 Rig Name: Doyon 16 Rig Number: 8/14/2001 07:00 - 07:30 0.50 CASE P DECOMP L/D RTTS AND RBP BHA 07:30 - 08:30 1.00 CASE P DECOMP L/D 6 X 6" DRILL COLLARS 08:30 - 10:30 2.00 CASE P DECOMP MADE UP 5 1/2" MILL/9 5/8" SCRAPER BHA 10:30 - 12:30 2.00 CASE P DECOMP SLIP & CUT DRILLING,SERVICED RIG 12:30 - 17:00 4.50 CASE P DECOMP RIH WITH MILL/SCRAPER BHA ON 3 1/2" DP TO 10,675 17:00 - 22:30 5.50 CASE P DECOMP PUMPED 2 X 25 BBL HI VIS SWEEPS, PUMPED 50 BBL DIRT MAGNET SWEEP, PUMPED 25 BBL HI VIS SWEEP, CIRC OUT SWEEP'S, DUMPED DIRT MAGNET SWEEP, ( NOTE!! RECIPITATE AND ROTATE WIHLE CIRCULATING TO 10,695' ) CLOSED ANNULAR PUMPED 25 BBL VIS SWEEP, REVERSED OUT, 22:30 - 00:00 1.50 CASE P DECOMP POOH LAYING DOWN 3 1/2" DP ( 55 JT'S DOWN AT REPORT TIME ) 8/15/2001 00:00 - 06:00 6.00 CASE P DECOMP FINISHED LAYING DOWN 3 1/2" DP AND BHA, RECOVERED 1/2 HAND FULL METAL SHAVINGS IN BOOT BASKETS, BROKE KELLY CONNECTIONS LAID DOWN SAVER SUB & LOWER KELLY COCK 06:00 - 14:00 8.00 CASE P DECOMP HALLIBURTON RAN 9 5/8" X 47 LB CASING GAGE RING ( 8.55" ) AND JUNK BASKET TO 10685' ( RECOVERED 1/2 CUP OF RUBBER IN JUNK BASKET, R/D HALLIBURTON 14:00- 14:30 0.50 CASE P DECOMP RETRIEVED WEAR BUSHING 14:30 - 16:30 2.00 CASE P DECOMP RIG UP TO RUN 5 1/2" TBG COMPLETION, PICK UP OLD SEAL ASSEMBLY 16:30 - 18:00 1.50 CASE P DECOMP WAIT ON TORQUE TURN EQUIPMENT 18:00 - 19:00 1.00 CASE P DECOMP RIGGED UP / CHANGED OUT TONGS, RIGGED UP COMPUTER 19:00 - 20:00 1.00 CASE P DECOMP WAIT ON 5 1/2" LTC TBG SEALS FROM TOOL SERVICES 20:00 - 00:00 4.00 CASE P DECOMP RIH WITH 9 5/8" BAKER S-3 PACKER COMPLETION BHA PICKING UP AND DRIFTING 5 1/2" SLHC TBG ( 50 JOINTS IN HOLE AT REPORT TIME ) 8/16/2001 00:00 o 01:30 1.50 REST ::) DECOMP PJSM, HUNG WIRELINE SHEAVE, DRIFT FIRST 50 JOINT'S 5 1/2" TBG WITH 4.70" DRIFT 01:30 - 14:30 13.00 REST ::) DECOMP CONTINUE RIH WITH 5 1/2" TBG/9 5/8" BAKER S-3 COMPLETION, ( DRIFT AND PRESSURE TESTED TBG TO 3500 PSI EVER 2000', CHARTED FOR 30 MINUTES 14:30 - 16:00 1.50 REST :) DECOMP INSTALLED SSSV, AND RIGGED UP CAMCO FOR RIH CONTROL LINE 16:00 - 22:00 6.00 REST :) DECOMP CONTINUE RIH CAMCO CONNECTING CONTROL TO TBG, TAG AT 10, 675' 22:00 - 23:30 1.50 REST P DECOMP SPACED OUT, MADE UP HANGER AND LANDING JOINT 23:30 - 00:00 0.50 REST P DECOMP FMC CREW CONNECTING SSSV CONTROL LINE TO HANGER AT REPORT TIME 8/17/2001 00:00 - 04:00 4.00 RUNCOI~P COMP PJSM, FINISH CONNECT SSSV CONTROL LINE TO HANGER, TEST SSSV CONTROL LINE, PRESSURE TEST TBG, LANDING JOINT LEAKING, REPLACED BROKEN SEAL, PRESSURE TESTED TBG TO 3500 PSI 1/2 HOUR CHARTED. LAID DOWN LANDING JOINT 04:00 - 23:00 19.00 RUNCOI~ P COMP HALLIBURTON RAN 4.70" TBG DRIFT TO SSSV @ 2237', RUN # 1-RETRIEVED SSSV DUMMY, RUN # 2 TRIP IN FOR BALL AND ROD ( NO RECOVERY ) RUN # 3 RERUN OVERSHOT ( NO RECOVERY ) RUN # 4 RAN IMPRESSION BLOCK ( MARK ON OUTER EDGE OF BLOCK LOOK LIKE TOP OF FISHING NECK, RUN # 5,6 & 7 WITH DIFFERINT Printed: 8/21/2001 3:57:55 PM Legal Well Name: 04-09i Common Well Name: 04-09i Spud Date: 8/10/2001 Event Name: WORKOVER Start: 8/10/2001 End: Contractor Name: DOYON Rig Release: 8/19/2001 Rig Name: Doyon 16 Rig Number: 8/17/2001 04:00 - 23:00 19.00 RUNCOI~P COMP OVERSHOTS ( NO RECOVERY ) RUN # 8 RAN IMPRESSION BLOCK ( MARK ON BLOCK INDICATED ROD LAYING ON LOW SIDE ) RUN # 9 RAN OVERSHOT WITH 4.55" BELL GUIDE DRESSED WITH I 3~8" GRAPPLE, ( RECOVERED ROD AND BALL ) ( 1 3~4" O.D. FISHING NECK LEFT IN HOLE ) NOTE!! I.D OF RHC PLUG 1" 23:00 - 00:00 1.00 RUNCO~ I3 COMP HALLIBURTON RIGGING UP RETRIEVING TOOL FOR RHC PLUG AT REPORT TIME 8/18/2001 00:00 - 02:00 2.00 RUNCO~ COMP RETRIEVED RHC PLUG/FISHING NECK OFF ROD 02:00 - 02:30 0.50 RUNCOI~ COMP SET SSSV DUMMY 02:30 - 03:00 0.50 RUNCOI~ COMP PRESSURE TESTED SSSV CONTROL LINE TO 5000 PSI 03:00 - 03:30 0.50 RUNCOI~ COMP RIGGED DOWN HALLIBURTON SLICKLINE UNIT 03:30 o 04:00 0.50 RUNCOI~ COMP HOOKED UP CIRCULATING HOSE ON LANDING JOINT, LEFT HAND ACME THREADS ON LANDING JOINT AND INSIDE HANGER RUFF ( UNABLE TO MAKE UP ) 04:00 - 07:00 3.00 RUNCOI~ COMP FMC EMPLOYEE DRESSED HANGER THREADS AND LANDING JOINT THREADS 07:00 - 10:00 3.00 RUNCOI~ COMP DISPLACED HOLE TO SEA WATER ~ 10:00 - 13:00 3.00 RUNCOI~ !:) COMP FREEZE PROTECT WITH DIESEL ( 140 BBL ) 13:00 - 14:00 1.00 RUNCOI~P COMP ;LAND TUBING HANGER, FMC RILDS 14:00 - 16:30 2.50 RUNCOI~P COMP DROPPED BALL/ROD, SET BAKER S-3 PACKER WITH 3500 PSI, HELD FOR 30 MIN, PRESSURE TESTED CASING TO 3000 FOR 30 MIN 16:30 - 17:00 0.50 RUNCO~ 13 COMP FMC EMPLOYEE INSTALLED BACK PRESSURE VALVE 17:00 - 21:30 4.50 RUNCO~ P COMP PJSM, REMOVED BOPE 21:30 - 23:30 2.00 RUNCO~ P COMP INSTALLED TUBING HEAD AND TREE 23:30 - 00:00 0.50 RUNCO~ P COMP FMC PRESSURE TESTED TUBING HANGER TO 5000 PSI ( 10 MIN ) 8/19/2001 00:00 - 03:00 3.00 RUNCOI~P COMP CHANGED BPV TO TEST PLUG, TEST TREE TO 5000 PSI, RETRIEVED TEST PLUG INSTALLED BACK PRESSURE VALVE RELEASED RIG AT 0300 HOURS, 08/19/2001 Printed: 8/21/2001 3:57:55PM Re: ~,WO's, 4-09i & 4-13i Subject: Re: RWO's, 4-09i & 4.13i Date: Thu, 02 Aug 2001 15:51:05-0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Coyner, Veto M" <CoynerVM@BP.com> Skip, Thanks for the information. ! hope our discussion helps the work. The only other item I can think of is that when the rig are testing the "squeezes", I would recommend that a chart recorder be employed. When an injector is employed in Mi service, the pressure test of the annulus must be acceptable. The Commission does not allow an injection well to be in gas or Mi service with an MIT failure. Good luck. Tom Maunder, PE Petroleum Engineer AOGCC "Coyner, Veto M" wrote: To answer some of your questions from this morning: 1. During the leak rate test on 4-09i, returns were taken from the OA. 2. During the leak rate test on 4-t3i, returns were taken from the OA. 3. Well 4-09i was circulated with seawater during rig prep. 4. Well 4-13i was circulated with seawater during rig prep. 5. The CCL to be run in 4-09i will start at +/- 3000'. Thanks for catching that one. 6. On both wells, we will run the new completion, button up the tree, freeze protect & then set the packer. No diesel in the stack. Skip Coyner Drlg/WO Engr (907) 564,4395 (907) 440-0191 Tom Maunder <tom maunder~.admin.state, ak. us> Petroleum Engineer Alaska C~ and Gas Consen~alion Commission I of I 8/3/01 12:07 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,SSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~ V~ ~ 325' NSL, 643' WEL, SEC. 27, T11N, R15E, UM At top of productive interval 3595' SNL, 3767' EWL, SEC. 35, T11N, R15E, UM At effective depth 3773' SNL, 3866' EWL, SEC. 35, T11N, R15E, UM At total depth 3891' SNL, 3933' EWL, SEC. 35, T11N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED 6. Datum Elevation (DF or KB) RKB = 52' 7. Unit or Property Name AUG 0 1 2001 Alaska 0il & Gas Cons. Commission 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Scab CT Liner Prudhoe Bay Unit 8. Well Number 04-09i 9. Permit Num)3er 176-030 ',/ 10. APl Number 50- 029-20207-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool v/, Aud~u~a9~ 12050 feet Plugs (measured) PBTD Tagged at 11820' (11/97) '~/ IBP Set at 10750' (06/01) 9116 feet 11820 feet Junk (measured) 8931 feet Length Size Cemented M D TVD 80' 20" 240 sx Arcticset (Approx.) 80' 80' 2654' 13-3/8" 5300 sx Permafrost II 2654' 2654' 11090' 9-5/8" 750 sx Class 'G', 125 sx PF II 11090' 8339' 1264' 7" 310 sx Class 'G' 10786' - 12050' 8116' - 9116' 912' 3-1/2" 6 Bbls LARC 10786' - 11698' 8116' - 8829' Perforation depth: measured true vertical 11580'-11622', 11629'-11643', 11670'-11675', 11687'-11695', 11752'-11792', 11807'- 11824', 11840'-11865' 8732'-8766', 8772'-8784', 8806'-8810', 8820'-8826', 8874'-8907', 8920- 8934'-8947'-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 10722'; 4-1/2", 12.6#, L-80 to 10815' Packers and SSSV (type and measured depth) Camco BaI-O SSSV Nipple at 2164'; Baker '3-H' packer at 10711' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation August 6, 2001 16. If proposal was verbally approved Tom Maunder Name of approver 8/1/2001 Date Approved Contact Engineer Name/Number: Skip Coyner, 564-4395 15. [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that th~ forgoing is true and correct to the best of my knowledge _ Signed SkipCoyner ,,... //,j~_.~,..F'~~/~~ Title Drilling Engineer Date ~-"///~:::~/ Notify Commission so representative may. witness Conditions of Approval: . Plug integrity ~_ BOP_ Test _~ Location clearance ____ Mechanical Integrity Test'".~. Sub' sequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission D Ta~lo." Form 10-403 Rev. 06/15/88 ~' ~""~-[~ I r'~ ['~1 ~ i I Approval No. Commissioner Date ,.., ~ ~)~ ~ Submit In'"'¥ripl~ate BP al-evB BRll I Ills & K il BP Exploration DOYON 16 Well: 04-09 Workover AFE: 4J9127 Classification: AFE Amount: Capital Work Over $1,250,000 Days: 12 Estimated Workover Date: July 14, 2001 Prepared By: Skip Coyner WELL OBJECTIVES: 1. NO ACCIDENTS 2. NO SPILLS OR ENVIRONMENTAL VIOLATIONS 3. NO POLICY OR REGULA TORY VIOLA TIONS 4. MEET OR EXCEED COST AND QUALITY OBJECTIVES 5. REVIEW AND FOLLOW ALL PROCEDURES No portion of this work is so urgent that time cannot be taken to do it without injuring yourself or others Approved By: Drilling/WO Engineer Date Distribution: Steve Rossberg 1 Copy D. Babcock 1 Copy S. Coyner 1 Copy Well File 1 Original Doyon Rig 16 6 Full copies Baker - Mail Slot 1 Copy Baroid - Mail Slot 1 Copy Doyon - Mail Slot 1 Copy Schlumberger - Mail Slot 1 Copy Halliburton - Mail Slot Drilling Superintendent Date Attachments: Tubing Tally Current Well Schematic Proposed Well Schematic Back up Proposed Well Schematic Halliburton Cement Recommendation DS 4 Plat Contacts Name Work Home Cell Drlg. Superintendent Steve Rossberg 564-5637 345-7634 240-8069 Drilling/WO Engineer Skip Coyner 564-4395 622-0030 440-0191 Pad Engineer Dan Babcock 564-5735 746-0274 250-1466 Current Well Information Well Name: APl Number: Well Type: Current Status: 04-09 50-029-20207 Injection The well has IA x OA communication BHP: BHT: 3450 psi @ 8800' TVDss Ivishak 210 o F @ 8800' TVD ss. Mechanical Condition: Tubing: 5-1/2", 17 #/ft, L-80 to the packer at 10711'. A 3-1/2" CT liner is hung in the tail pipe at 10786'. The 3-H packer has an 18' PBR and Iocator seal assembly pinned to 74,000#. There is an SSSV nipple with control lines at 2164'. See current schematic. Casing: There is a leak in the 9-5/8" casing: +/- 2 gpm at 2700 psi. The IA x OA CMIT tested to 2000 psi. OK. An "FO" tool is un-cemented at 2363'. A cemented "FO" tool is below it at 2613'. TD / PBTD / Fill: Kick Off Point: Maximum Angle: Max Dogleg of interest: TD 12053' MD 2800' MD 61.5° at 8200' MD 6.5°/100' at 6000' MD Tbg. Spool: Tbg. Hanger: Tbg. Head Adapter: Tree: BPV Profile: ssSv Nipple: Control line clamps SS Control line bands: FMC, 13-5/8" x 13-5/8" (5M) Gen I FMC, 13" x 5-1/2" BTC FMC, 13-5/8" x 5-1/8" FMC, 5-1/8" (5M) FMC CAMCO, BAL-O Nipple, 4.562" ID, WL valve pulled 5/96 26 Standard Clamps 4 steel bands Open Perforations: 11580' -11622', 11629' -11643', 11670' -11675', 11687' -11695', 11752' -11792', 11807' -11824', 11840' - 11865' Tubing Fluids: Annulus Fluids: Sea water / diesel Sea water / diesel 9-5/8" PPPOT, lC: MIT, IA: CMIT IA x OA: Passed 2/03/01 Failed 5/15/00 Passed 5/15/00 (2000 psi) Completion: Materials Required for Workover Operations 11000' lx10' 1 1 1 1 1 1 5-1/2", 17#, L-80, NSCT Tubing Locator Seal Assembly for BOT PBR: 6" OD x 4.75" ID Baker, 9-5/8" x 5-1/2" SB-3 Stacker/Packer (back up plan) 5-1/2" 'X' Nipple 5-1/2" 'XN' Nipple (if needed) 5-1/2" SSSV Nipple (if needed) Tubing hanger and adapter flange with control line fittings (if needed) 5-1/8" x 5000 psi carbon tree (if needed) DS 04-09 RWO Page 2 Short Scope There is pressure communication between the IA and OA indicating a 9-5/8" casing leak. The 9-5/8" packoffs have tested good. The IA x OA communication will be repaired by cementing the OA. The existing 5-1/2" tubing will be replaced with premium, L-80 tubing. This well is being converted to a WAG injector. Drilling Hazards and Contingencies ***See Pad Data Sheet for details of previous wells drilled on DS 04 1) Hydrogen Sulfide DS 04 is considered an H2S drill site. Standard Operating Procedures for H2S precautions should be reviewed and followed at all times. The most recent level of H2S measured near DS 04-09 bottom hole location was 215 ppm from well 04-31 on 1/15/01; however, concentrations higher than 600 ppm have been recorded in the last two years. The highest concentration seen on DS 04 to date is 1500 ppm from well 04-49. (See Pad Data Sheet). Reference: Hydrogen Sulfide under Standard Operating Procedures 2) Well Control Pressures · Production Section max anticipated BHP: Production Section max surface pressure: · Planned completion fluid: 3450 psi (7.5 ppg EMW) @ 8800' TVD - Ivishak 2570 psi (based on BHP & full gas column at 0.1 psi/ft) 8.5 ppg sea water / 6.8 ppg diesel Drillin_q Pro_qram Overview Surface Issues Rig Move Issues and Shut-in Requirements: There is no surface shut in requirements for the rig move to 04-09. The nearest adjacent wells are 04-08 (120' away) and 04-38 (58' away). Workover Fluid Program and Properties I Sea water I Present Casing/Tubing Program: Csg/Tbg OD #/Ft Grade Conn Length Top (MD) Btm (MD) 20" 94 H-40 Welded 110' Surface 110' 13-3/8" 72 L-80 BTC 2654' S u dace 2654' 9-5/8" 47 L-80 BTC 11090' Surface 11090' 7" liner 29 L-80 BTC 1264' 10786' 12050' 3-1/2" CT liner 9.3 L-80 CT 912' 10786' 11698' 5-1/2" tubing 17 L-80 AB Mod 10711' Surface 10711' Proposed Tubing Program: I 5-1/2"tubing I 17 I L-80 INSCTI 10690' I Surface I 10690' DS 04-09 RWO Page 3 04-09 RWO Detailed Operations Pre-Riq O[~erations 1. Flush the tubing with _+ 375 bbl of produced water. Set an IBP in the 4-1/2" tubing tail at + 10750' MD. Pressure test IBP to 1000 psi (note: pressure limited due to IA x OA c-ommunication). Dump + 50' of sand (or CaCO3) on top of the IBP. 2. Chemically cut the 5-1/2" tubing at_+ 10650' MD'. 3. Circulate the well with produced water. 4. Freeze protect the tubing, IA and OA with diesel from 2000' to surface. 5. Set a BPV and remove the wellhouse. 6. Clear and level the pad in preparation of the rig move. Ri~ Operations . . . * Review the Hydrogen Sulfide Standard Operating Procedures prior to opening the well * * Complete a pre-rig inspection with the DS Operator prior to the rig moving on the well * * Notify the AOGCC representative 24 hours in advance to witness BOP testing * Note tubing and annular pressures (trapped gas). Bleed-off as required prior to MIRU. MIRU workover rig. RU to the tree to circulate out the diesel freeze protection. Pull BPV with lubricator. Confirm the amount of diesel used to freeze protect on the hand over form. Cimulate out the diesel freeze protection and displace it with seawater. Confirm the well is dead. Install the TWC and test to 3500. Nipple down the tree and adapter. Send tree and adapter in for inspection and/or repairs. The adapter and tree will be reused if possible. NORM test all well head and completion equipment. Reference 'De-Completions' RP for details. Nipple up and test the BOPE. Test the BOP equipment to 250 psi Iow and 3500 psi high. Test the annular to 250 psi Iow and 3500 psi high. Pull the TWC with lubricator. PU landing joint and screw into the tubing hanger. Pull and lay down the tubing hanger. Note the length from the drill floor to the bottom of the tubing hanger = "B" to be used for space out later. Send in the hanger for inspection. Pull and lay down the control line. Four steel bands and 26 clamps were run on the control line. Have spooling unit rigged up to recover the control line. An SSSV Nipple will be run in this well when re-completed. Inspect all completion equipment for NORM. Reference: SSD Decompletion RP Pull and lay down the 5-1/2" tubing from the cut at 10650'. Try not to exceed 50% of the 5-1/2" tubing body tensile rating (198,500 lbs). NOTE: Estimated buoyed string weight in seawater down to the cut is _+157,600# + the blocks, etc. . RIH with an overshot and fishing BHA on drill pipe. Dress the overshot to catch the 5-1/2" tubing stub. Use a cut lip guide with mill control. Check the string weight. Engage the fish with the pump idling and note the pressure increase. Kill the pump and swallow the fish. Pull the PBR seal assembly, which is pinned to shear at 74,000# (jar if necessary). Pump a Hi-Vis sweep and circulate the well clean with produced water. POOH. LD the fish and overshot. Note the condition.of the seal assembly and caliper the OD/ID. If the seal assembly is 6" x 4.75", it (or a new seal assembly) will be re-run. If not, a stacker/packer will be run. . A leak exists between the 9-5/8" and 13-3/8" casing strings. Set a 9-5/8" RTTS at +/- 100'. Close the pipe rams and test the wellhead to 3000 psi. Bleed off, open and monitor the OA while pressure testing. Even though the PPPOT-IA passed, the leak may still be in the wellhead. If no leak is found in the wellhead, proceed with step 6 below. . There is a cemented "FO" tool at 2613' and a circulated "FO" tool at 2363'. The current leak is small but it has communication to the surface in the OA; therefore, the leak is in (or above) the top "FO" tool at 2363'. RIH with a 9-5/8" RTTS and RBP to locate the leak. Bleed off and monitor the OA while pressure testing. Set the RBP at + 3000' and set the RTTS at + 2700'. Test the RBP to 3000 psi. Re-set the RTTS at _+ 2400' (between the "FO" tools). Test below the RTTS to 3000 psi. Re-set the RTTS at _+ 2200' (above both "FO" tools). Test below the RTTS to 3000 psi. Then test above the RT'I'S to 3000 psi. Re-set the RTTS and re-test as needed to locate the leak. 7. Once the leak is located, dump sand on the RBP, POOH and prepare to cement the OA. DS 04-09 RWO Page 4 . . RU WL. Run a CCL strip log from +/- 2000' to 1000' to confirm the location of the "FO" tools, etc. Perforate 8 squeeze hOles in the 9-5/8" casing just below the "FO" tool at 2363' (or as appropriate). Note: Arctic Pack was left in the OA in 1976). RD WL. Close the rams and establish circulation through the perforations. (Note: it is assumed that the "FO" tool is not functional and we do not intend to use it). Set a Cement RTNR +/- 100' above the squeeze holes on drill pipe. Break circulation with produced water and circulate the OA clean in preparation for cementing. Recover and properly dispose of the Arctic Pack from the OA (_+ 137 bbl). Pump detergent, Hi-Vis sweeps and heated seawater, etc. as necessary to remove the Arctic Pack fluid and clean out the OA. Pump at maximum rate while displacing and cleaning the OA. 10. RU Halliburton complete with squeeze manifold (drill pipe & OA). Test to lines 3000 psi. Close the annular BOP and pressure the IA to +/- 500 psi with the rig pump and monitor the IA while cementing. Mix and pump _+ 400 sx of Type "E" Permafrost cement. Tail in with 100 sx of Premium + 2% CaCI2. Displace the drill pipe to the RTNR with fresh water. Reverse _+ 2 bbl of dead oil (or other freeze protect fluid) down the OA to clear the valves, etc. Shut in the OA. Pressure up below the RTNR to 1000 psi. Bleed off the IA. Pull out of the RTNR and LD 1 jnt. Reverse circulate + 200 bbl of produced water ~ 100° F). POOH. 11. 12. 13. Note: Pilot test the cement slurries using actual mix water. The desired pump time is + 3 hours. Run compressive strength tests to determine drill out time. Catch and monitor surface samples for initial set time. After initial set of the cement, RIH with an 8-1/2" bit and BHA. Drill out the RTNR and cement to 20' above the perforations. Test the casing to 3000 psi. Drill the remaining cement and re-test the casing to 3000 psi. RIH. Clean out sand and debris to the RBP at +/- 3000'. Circulate the hole clean at max rate with seawater. Sweep the hole with Hi-Vis pills as needed while drilling cement. LD 3000' of drill pipe. RIH with a bit and casing scraper to the RBP. Circulate bottoms up. LD 3000' of drill pipe and the BHA. RIH with RBP retrieving tool. Wash down to the RBP and circulate the hole clean above the RBP. Catch and release the RBP. POOH. Lay down remaining drill pipe and tools. Run 5-1/2", 17#, L-80, NSCT tubing with a new (or re-dressed) seal assembly for the existing PBR. Above the seal assembly, run a 10' pup, a 5-1/2", "X" nipple and another 10' pup. Run the SSSV Nipple with 4.562" ID at + 2,200' MD. Run 10' pup joints above and below the SSSV Nipple. Be sure to drift the "X" nipple and SSSV before RIH. Drift and Rabbit the tubing. Run and test the control line for the SSSV. Back up plan: If the PBR is not re-usable (from step 4 above), a stacker/packer will be run. If so, run the old PBR seal nipple w/o seals to align the tubing tail in the old PBR. Run the old seal nipple followed by a 10' pup jnt, an "XN" nipple (w/RHC sleeve) and another 10' pup jnt. Run a mill out extension and the new SB-3 stacker/packer. Above the stacker/packer, run equipment as described in the previous paragraph. 5-1/2", 17#, L-80, NSCT Collapse Burst Tensile ID Make-up Torque 100% 6280 psi 7740 psi 397,000 lb 4.892" ID 4950 fi-lb min 80% 5020 psi 6190 psi 317,000 lb 4.767" Drift 6050 fi-lb max **Use "Best-O-Life 2000" Thread Compound 14. Tag the old PBR and "space out" the tubing. MU the tubing hanger, control lines and landing joint. Length from DF to the 1st collar below the Tubing head = "A" Length from Drill Floor to the bottom of Tubing Hanger = "B" Length of Seal Assembly to the bottom of its Iocator = "C" Pick up Length for Flowing Temperature Compensation = "D" A - B + C - D = Length of subs needed below the Hanger 15. Close the pipe rams and displace the IA with Clean seawater containing corrosion inhibitor followed by 140 bbl of diesel. Tie in the IA to the landing joint. U-tube _+ 46 bbl of diesel from the IA into the tubing to freeze DS 04-09 RWO Page 5 16. 17. protect both to 2000'. Allow the tubing and IA to equalize. Open the BOP's. Lower the tubing and sting into the PBR. Land the tubing hanger in wellhead. RILDS. Back up Dian: If the stacker/packer was run, sting into the PBR with the stripped down seal nipple and land the tubing hanger. RILDS. Drop the ball/rod. Pressure up on the tubing and set the packer. In either case, test the tubing to 3500 psi for 30 minutes. Test the packer seals, IA and tubing hanger to 3000 psi for 30 minutes. Set a BPV in the tubing hanger. Back out the landing joint and circulate any remaining diesel, etc. out of the BOPE with seawater. Lay down the landing joint. ND BOPE. NU the 5" x 5,000 psi Tree. Test the tree to 3500 psi for 30 minutes using a TWC. Replace the TWC with a BPV using a lubricator. 18. RD and MO Rig 16. * Complete a post-rig inspection with the DS 04 Operator prior to the rig moving off the well * Post-Riq Operations 1. Retrieve the BPV. 2. RU CTU. RIH and circulate the sand (or CaCO3) off the IBP in the 3-1/2" scab liner (recover the freeze protect fluid). Retrieve the IBP. 3. Hook up flow lines. Hook up control lines. Replace the wellhouse. 4. POP. DS 04-09 RWO Page 6 TUBING TALLY SHEET Well- NO. 1 1 51 1 1 1 2O5 1 1 1 1 1 2 2 2 1 Well' 04-09 Item RKB - Tbg Hd Flange FMC Tubing Hanger 5-1/2" Pup Joint: AB-Mod 5-1/2, 17#, L-80 Tubing 5-1/2" Flow Coupling CAMCO SSSV 5-1/2" Flow Coupling 5-1/2, 17#, L-80 Tubing 5-1/2" Pup Joint: AB-Mod PBR w/Seal Nipple BOT, 3-H Packer Mill Out Extension 4-1/2" X-O 4-1/2" Tubing 4-1/2" CAMCO "DB" Nipple 4-1/2" pup joints Shear out sub Length 26.11 1.38 6.08 2120.43 10.07 18.43 8.50 8495.07 6.31 18.89 5.33 5.35 0.92 79.31 1.42 10.12 1.00 Date: 5/21/85 Top I.D. O.D. 26.11 4.892 27.49 4.892 5.500 33.57 4.892 5.500 2154.00 4.892 5.500 2164.07 4.562 5.500 2182.50 4.892 5.500 2191.00 4.892 5.500 10686.07 4.892 5.500 10692.38 4.750 6.000 10711.27 4.750 8.312 10716.60 5.625 6.250 10721.95 3.826 7.375 10722.87 3.810 5.030 10802.18 3.813 5.000 10803.60 3.950 4.500 10813.72 3.950 4.500 End Of Tubing 10814.72 DS 04-09 RWO Page 7 2654' No.: 04-09 (Current) ~ IA x OA Communication FO Tools at 2363' & 2616' '-' 13-3/8", 72#, L-80 BTC 5-1/2", 17#, L-80 Tubing BOT, 7" x 6" x 4.75" PBR 3-H PKR at 10711' 4-1/2" Tail Pipe assembly 7" TOL: 10786' , 47#, L-80, BTC 3-1/2" CT Liner: 10786'- 11698' -- Perforations: 11580' - 11865' 7" Liner DS 04-09 RWO Page 8 2654' W=il No.: 04-09 (Proposed) Cement circulated to surface Between the 9-5/8" & 13-3/8" FO Tools at 2363' & 2616' 13-3/8", 72#, L-80 BTC New, 5-1/2", 17#, L-80 Tubing New/Re-dressed PBR Seal Nipple 3-H PKR at 10711' 4-1/2" Tail Pipe assembly 7" TOL: 10786' , 47#, L-80, BTC 3-1/2" CT Liner: 10786'- 11698' Perforations: 11580' - 11865' 7" Liner DS 04-09 RWO Page 9 2654' Wu ' l No.: 04-09 (Back Up Plan) Cement circulated to surface Between the 9-5/8" & 13-3/8" FO Tools at 2363' & 2616' 13-3/8", 72#, L-80 BTC New, 5-1/2", 17#, L-80 Tubing SB-3 Stacker/Packer with used PBR seal nipple alignment guide 3-H PKR at 10711' 4-1/2" Tail Pipe assembly 7" TOL: 10786' , 47#, L-80, BTC 3-1/2" CT Liner: 10786'- 11698' Perforations: 11580' - 11865' 7" Liner DS 04-09 RWO Page 10 PHILLIPS Alaska, Inc. A Subsidiary o~ PHILLIPS PETROLEUM COMPANY May 24, 2000 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: DS 04-09 Sundry Notice and Variance Request Dear Mr. Wondzell: Enclosed please fred a Sundry Notice 10-403 variance request to continue produced water injection into Phillips Pmdhoe Bay well 04-09. The well recently failed a diagnostic MITIA, which was reported to the AOGCC. Attached is a discussion of the current well conditions and a proposed Action Plan. Please contact Joe Anders or me at 659-5102, or by email, should you have any questions or need additional information. Sincerely, Jerry Dethlefs Phillips Problem Well Specialist STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance X Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 52 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4954' FNL, 642' FEL, Sec. 27, T11N, R15E, UM (asp's 712178, 5952178) 04-09 At top of productive interval 9. Permit number ! approval number 3594' FNL, 1505' FEL, SEC. 35, T11N, R15E, UM (asp's 716709, 5948388) 176-030 At effective depth 10. APl number 50-029-20207 At total depth 11. Field / Pool 3891' FNL, 1344' FEL, Sec. 35, T11N, R15E, UM (asp's 716879, 5948093) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12053 feet Plugs (measured) Tagged PBTD @ 11820' on 11/28/1997. true vertical 9118 feet Effective depth: measured 11820 feet Junk(measured) ORIGINAL true vertical 8931 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 240 Sx AS 80' 80' Surface 2602' 13-3/8" 5300 Sx PF II 2654' 2654' Production 11038' 9-5/8" 750 sx Class G & 125 Sx PF I1 11090' 8368' Liner 1264' 7" 31o Sx aass G 12050' 9113' Scab Liner 912' 3-1/2" 6 bbls LARC 11698' 8828' :. Perforation depth: measured 11580'- 11620'; 11752'- 11792'; 11807'- 11824'; 11840'- 11865'. true vertical 8732' - 8765'; 8873' - 89085'; 8918' - 8832'; 8945' - 8965'. 0 ?-000 Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 NPCT @ 10722' MD; 4-1/2", 12.6#, L-80 NPCT @ 10815' MD. AJaska 0it & Gas C~s~ Commissio~-~ Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BOT 3-H PACKER @ 10711' MD. 5-1/2" CAMCO BAL-O SSSV @ 2164' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: May 26, 2000 16. If proposal was verbally approved Oil __ Gas __ Suspended __ Name of approver Date approved Service Water Inj 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders/Jerry Dethlefs @ 659-5102 Signed ~"~"~"'~~--r~,~~ Title: Phillips Problem Well Specialist Date Jerry Dethlefs Prepared by Paul Rauf 263.4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test__ Location clearance __j ~ 0O-' / Mechanical Integrity Test__ Subsequent form required 10- i1~.,~.. ~,~.~... ~ pI~,l~ ~ ~ Approved by order of the Commission .'~ T~Vt~r _Co, gJ'nmis Date v '"'-.-.--'~ --~'~ ~'~-")~ ~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE DS 04-09 Sundry Request SUNDRY DISCUSSION AND PROPOSED ACTION PLAN May 24, 2000 DISCUSSION Well 04-09 is a PWI injector that exhibits 9-5/8" (IA) x 13-3/8" (CA) annular communication. An MITIA was performed on 5/15/00 as part of an investigation to convert the well into an MI injector. The 3000 psi MITIA failed, during which the CA pressure increased. The leak rate from the IA to the CA is approximately 2 gpm ~ 2750 psi while bleeding the CA to atmosphere. The AOGCC was notified 5/16/00 of the communication. At the time of the test on 5/15/00, a combination MIT (CMIT IA x CA) was performed ~ 2000 psi which lost 0 psi in 30 minutes. The test confirmed the integrity of the casing strings, packer, and CA cement shoe. The wellhead packoff assemblies were tested and found to be competent. This variance request is to continue water injection into the well, based on the following information: · A combination MIT (IA x CA) passed 5/15/00 demonstrating mechanical integrity and injection in the approved zone; · The CMIT IA x CA pressure was equal to the minimum test pressure required (8064' TVD to packer = 2016 psi); · Wellhead packoff assemblies have been tested and found to be competent; · Normal wellhead injection pressure is 1800-2000 psi on PWI service. PROPOSED ACTION PLAN 1. Continue water injection into the well; 2. Perform 2-year CMIT IA x CA ~ 2016 psi (minimum) in lieu ofnormal 4-year MITIA; 3. Monitor wellhead pressures daily; 4. Shut-in and secure the well should MIT's or wellhead pressures indicate problems, and notify the AOGCC. [.';;,,v bO 2000 Alaska Oil & Gas Cons. Commissm Anchora¢:ie WSSSV Tubing-NPC Casing Casing PBR PKR xo Tubing-NPC OTHER Liner-CT Liner NIP SOSUB TTL Perf ...... Perf ;/ Perf ...... TTL 04-09 H~:. 500292020700 SSSV Typel 2 Annular Fluid: Diesel/8.6 NaCI Reference Log:I BHCS Last Taft: Rev Reason:l RPERF Well Type: INJ Spud: 3/21/76 Orig Compltn: 5/11/76 Last W/O: 5/21/85 Ref Log Date: 5/2/76 Last Taft Date: Last Update: 4/16/98 RKB: 52 fl KOP: 0.00 ftKB P6TD: 12050.00 flKB TD:112050.00 flKB I Max Hole Angle:161 deg @ 7700 Angle ~ TS:136 den ~ 11460 An.~le ~, TD:] 38 den ~ 12053 EleVati~:hs KB I 52 ft Grd I 0 fl KB-Grd 52 fl Othe~ (plugs; equiPi, etC,)- All Depth ID Type 2164 4.562 IWSSSV 10692 0.000 PBR 10711 0.000 PKR 10722 0.000 XO 10786 2.992 OTHER 10802l 3.813 INIP I 1081410'000 ISOSUB I 1081s10.000 ITTL I 1169810.000 ITTL Gehe~ai N~t~s ::: o" Cas Flng Tub Head Description 5-1/2" Camco BAL-O SSSV Nipple 5-1/2" BOT PBR Assembly 9-5/8" x 5-1/2" BOT 3-H Packer Crossover 5-1/2" x 4-1/2" 4-1/2" No-Go Setting Sleeve 4-1/2" Camco DB Nipple (Behind CT Liner) 4-1/2" BOT Shearout Sub (Behind CT Liner) 4-1/2" Tub nft Tail (Behind CT Liner) 3-1/2" Davis Lynch Double Valve Shoe Date Note 10786 Min iD = 2.992" (4-1/2" No-Go Setting Sleeve) I TTL ELM ~. 10799: ELM Tubin~ Ta (Lo.qfted 06/29/85)(Behind CT Liner) Daterun: 1976-05-11 Ca sin;;I StH ng~:S U RFAC E Item Top I Btm I 7 Wt 2.00 (in) (ftKB)0.00 (ftKB) 13.375 in Casing 2654.00 casing String ~ PRODUCTION Item Top I Btm I 4 Wt 7.00 Grd (in) (ftKa)0.00 (flEa) 11090.00 MN-80 Grd MN-80 9.625 in Casing ::C~i~ String ~: El N E R Item (in) 7.000 in Liner L500 in Liner-CT Tubing string ~TUBING Item (in) 5.500 in Tubing-NPC 4.500 in Tubing-NPC pe~ratibhssdmmary Interval Zone 11580 - 11600 ZONE 2 11600- 11620 ZONE2 ZONE2 11620- 11622 11629 - 11643 ZONE 2 11670 - 11675 ZONE 2 11687 - 11695 ZONE 2 11752 - 11792 ZONE 2,ZONE lB 11807 - 11824 ZONE lB 11840 - 11865 ZONE lB stimUlatibns & Treatments Top (ftKB) 10786.00 10786.00 BtmI wt29.0° (ftKB) 1 12050.00 11698.00 9.30 Top Bottom (ftKB) (ftKB) 0.00 10722.00 10722.00 10815.00 Statu~ Feet SPF D~ O / 20 4 12. O ! 20 4 10, C / 2 0 6/: ~ 14 0 6/; / 5 o 6/; / 8 o 6/: 0 / 40 4 4/; / O / 17 10 6/; O / 25 10 61~ Grd L-80 L-80 (ft)10722 17.00 L-80 I 931 12.601 L-80 I te Type Ic°mment 14/97 I RPERF I 4/97 RPERF 7/96 I Sqz 7/96 I I 7/96 I I 7/96 I 8/77 IPERF [ 9/85 I RPERF I 9/85 I RPERF I Interval Date 11580 - 11695 6/27/96 Type Comment SQZ $0 2.000 Cons. Comm ss o A aska & Gas Anct or je STATE OF ALASKA ~ ALA~rtA OIL AND GAS CONSERVATION COMMISSION 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: 15. Type of Well: 16. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 52' RKB 3. Address: Exploratory_ '-~. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage~ AK 99510-0360 Service _X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 325' FSL, 643' FEL, Sec 27, T11N, R15E, UM. 4-09i At top of productive interval: 9. Permit number/approval number: 3594' FNL, 3774' FWL, Sec 35, Tll N, R15E, UM. 76-30 At effective depth: 10. APl number: 50-029-20207 At total depth: 11. Field/Pool: 3893' FNL, 3942' FWL, Sec 35, T11N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12050 feet Plugs (measured) PBTD Tagged @ 11820' MD (11/28/97). true vertical 9113 feet Effective Depth: measured 11820 feet Junk (measured) true vertical 8931 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 240 Sx AS 80' 80' Surface 2602' 13-3/8" 5300 Sx PF II 2654' 2654' Production 11038' 9-5/8" 750 Sx Class G & 11090' 8368' 125 Sx PF II Liner 2602' 7" 310 Sx CIG 12050' 9113' Scab Liner 912' 3-1/2" 6 Bbls LARC 11698' 8828' Perforation Depth measured 11580- 11620'; 11752 - 11792'; 11807 - 11824'; 11840- 11865' true vertical 8732 - 8765'; 8873 - 8905'; 8918 - 8932'; 8945 - 8965' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10722' MD; 4-1/2", 12.6#, L-80, NPCT @ 10815' MD. R E C E ! V 5 a DIe 0 1997 Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2164' MD; BeT 3-H Packer @ 10711' MD. Alaska Oil & Gas Cons. Com~is~,~ 13. stimulation or cement squeeze summary Atlchor~e 14. Representitive Daily Averaee Production or Iniection Data _ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 17020 1926 Subsequent to operation - 20666 1927 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~~ ~, ~_ F~/I 6~ Title: Engineerin~Supervisor Date ~2./~/~'7 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 4-09i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 11/28/97: RIH & tagged PBTD at 11820' MD. 12/14/97: MIRU & PT equipment. RIH w/perforating gun & shot 20' of reperfomtions as follows: Reperforated: 11580- 11600' MD (Z2) Ref. Log: BHCS 5/2/76. Used a 2-1/2" carrier & shot the perfs at 4 spf at 60/120 degree phasing at balanced pressure POOH w/perf gun. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. STATE OF ALASKA ALASKA OIL AND OAS CONSERVATION COMMISSI~,, 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 elavation (DF or KB feet): ARCO Alaska, Inc. Development_ 52' RKB 3. Address: Exploratory _ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 325' FSL, 643' FEL, Sec 27, T11N, R15E, UM. 4-09i At top of productive interval: 9. Permit number/approval number: 3594' FNL, 3774' FWL, Sec 35, T11N, R15E, UM. 76-30 At effective depth: 10. APl number: 50-029-20207 At total depth: 11. Field/Pool: 3893' FNL, 3942' FWL, Sec 35, T11 N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12050 feet Plugs (measured) PBTD Tagged @ 11820' MD. true vertical 9113 feet Effective Depth: measured 11820 feet Junk (measured) true vertical 8931 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 240 Sx AS 80' 80' Surface 2602' 13-3/8" 5300 Sx PF II 2654' 2654' Production 11038' 9-5/8" 750 Sx Class G & 11090' 8368' 125 Sx PF II Liner 2602' 7" 310 Sx CIG 12050' 9113' Scab Liner 912' 3-1/2" 6 Bbls LARC 11698' 8828' Perforation Depth measured 11600- 11620'; 11752 - 11792'; 11807- 11824'; 11840 - 11865' true vertical 8748 - 8765'; 8873- 8905'; 8918 - 8932'; 8945 - 8965' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10722' MD; 4-1/2", 12.6#, L-80, NPCT @ 10815' MD. Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2164' MD; BOT 3-H Packer @ 1071 i' MD. RECEtVFD 18. Stimulation or cement squeeze summary Intervals treated (measured) see attached 0(-~'T ~ ,,,r- ORIGINAL Intervals treated (measured) Alaska Oil & Gas Cons. Cornmissio~ 14. Representitive Daily Average Prod~lS~l~l~l~tion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10249 1934 Subsequent to operation - 21018 2125 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~.~,~ '~l,~ , ~ Title: Engineering Supervisor Date /O., //~,, "' c~,~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLI.~_E_E~ 4-9i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I013197: RIH & tagged PBTD at 11820' MD. 10/4/97: MIRU & PT equipment. RIH w/perforating gun & shot 20' of reperforations as follows: Reperforated: 11600- 11620' MD (Victor) Ref. Log: BHCS 5/2/76. Used a 2-1/8" carrier & shot 4 spf at zero degree phasing at overbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. STATE OF ALASKA ~.~-~, ALASKA'i'~"~AND GAS CONSERVATION CC .illSSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Stimulate Plugging Perforate Pull tubing -...- Alter casing .-... Repair well -.-- Other X__ 6. Datum of elevation(DF or KB) 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM. At top of productive interval 3594' FNL, 3774' FWL, Sec 35, T11N, R15E, UM. At effective depth At total depth 3893' FNL, 3942' FWL, Sec 35, T11 N, R15E, UM. Development Exploratory Stratigraphic Service 52' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-9i 9. Permit number/approval number 76-30 10. APl number 50 - 029-20207 11. Field/Pool Prudhoe Ba~, Oil Pool 5. Type of Well feet 12. Present well condition summary Total depth: measured true vertical 12050 feet 9113 feet Plugs(measured) Fill Tagged @ 11815' MD (7/11/96) Effective depth: measured 11815 feet true vertical 8924 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 240 Sx AS 80' 80' Sudace 2602' 13-3/8" 5300 Sx PF II 2654' 2654' Production 11038' 9-5/8" 750 Sx Cl G & 125 sx PF II 11090' 8368' Liner 1264' 7" 310 Sx Cl G 12050' 9113' Scab Liner 912' 3-1/2" 6 Bbls LARC 11698' 8828' Perforation depth: measured 11752 - 11792'; 11807- 11824'; 11840 - 11865' true vertical 8873 - 8905'; 8918 - 8932'; 8945 - 8965' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10722' MD; 4-1/2", 12.68, L-80, NPCT @ 10815' MD. Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2164' MD; BeT 3-H Packer @ 10711' MD RECEIVED 13. Stimulation or cement squeeze summary Intervalstreated(measured) See Attached ORIGINAL Treatment description including volumes used and final pressure AIask~- 0!l & ~s Co~s. ~ff~jssi0i] 14. Reoresentative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 8153 -- 1512 Subsequent to operation 7884 -- 1695 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil...._ Gas__ Suspended.._ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~.,~ ~ . ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 A ID ,~,-. · I%MD Date SUBMIT IN DUPLICATE 4-09i DESCRIPTION OF WORK COMPLETED CT CONYEYED SCAB LINER INSTALLATION FOR PROFILE MODIFICATION 5/16/96' RIH & tagged PBTD at 11852' MD. 6/24/96 · MIRU CTU & PT equipment. 6/25/96 · RIH w/nozzle & jetted a fill & schmoo cleanout to 11880' MD. POOH w/nozzle. RIH w/sand dump nozzle & spotted 4000 lbs sand to 11692' MD, to place an isolation sand plug over the lower open perforation intervals located at: 11752 - 11792' MD (Z2/1B) 11807 - 11824' MD (Z1B) 11840 - 11865' MD (Z1B) Ref Log: BHCS 5/2/76. Reversed off top of sand plug down to 11705' MD. conveyed 3-1/2" Scab Liner assembly. POOH w/sand dump nozzle. MU & RIH w/CT 6/26/96' Landed Scab Liner at 11698' MD, to isolate the upper thief perforation intervals at: 11580 - 11622' MD (Z2) 11629 - 11643' MD (Z2) 11670 - 11675' MD (Z2) 11687 - 11695' MD (Z2) Ref Log: BHCS 5/2/76. Pumped 22 bbls of Latex Acid Resistive cement to set the Scab Liner from 10786' to 11698' MD. Displaced cement past liner shoe w/Seawater & squeezed 6 bbls of cement behind pipe at 1000 psi maximum squeeze pressure. POOH & WOC. RIH w/milling BHA & tagged cement at 11165' MD. Milled cement from liner to 11215' MD. 6/27/96 · Milled cement from liner to the cement/sand interface at 11698' MD, then circulated out sand & fill from the wellbore to 11925' MD w/biozan to uncover the lower perforation intervals (above). POOH w/BHA displacing the well to Seawater. 6/28/96 · ND/NU. Secured well. RDMO CTU. 6/30/96 · RIH & tagged PBTD at 11765' MD. 7/8/96' RIH w/CT & jetted biozan for fill cleanout to 11942' MD. 7/11/96' RIH & tagged PBTD at 11815' MD. JUL 2 $ ~Q~ Oil & 6~,s C Placed the well on produced water injection & obtained a valid injection rate. NO. 9448 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: 5/5/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk · . "'J D.S. 15-21 95158 DUAL BURST TDT-P 041995 1 ""-J D.S. 15-22 95157 IDUALBURSTTDT-P 041995 1 ~ ~i,~'D.S. 4-9 ~-- INJEC PROFILE 041595 I 1 ~3' J~-'7 D.S. 4-23A PERFRECORD 041595 I 1 C~-5'7 D.S' 6-14A PERFRECORD 041795 I 1 ~'"~., D.S. 9,10 INJECPROFILE 041895 1 1 ~ I - ( [ ! D.S. 9-33 PERF RECORD 041 8 95 1 1 ~O-~ i D.S. 15-21 DUAL BURST TDT-P '041995 I 1 ~0-'~'7 D.S. 15-22 DUAL BURST TDT-P 041 995 I 1 c~,~-50~ D.S. 18-02A PDC&PERFRECORD 041895 I I RECEIVED SIGNED: ~1 ~'G~ Cons. C0mmis ' MAY IVb{k 99 DATE: Alaska Anchora~nchora~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-9-93 ~5~q~ 1-5ST q~-l~Z I:24A 7051-25 -~-~</2-10 \2-10 ~-~5 2-13 ~.~S 2-21 ~o--q'z. 3-1~ ~l-ll 4-4 qt-~z 4-38 R~9-29 ~-I~ 11-9 -q~ 11-22 ~ 12-28 ~% 12-30 ~-~ 13-12 ~t 14-13 /16-29A /16-29A ~2-ql 17-18 %-Ig5 17-21 8-14-93 8-6-93 8-8-93 8-13-93 8-13-93 8-14-93 8-9-93 8-9-93 8-6-93 8-8-93 8-11-93 8-16-93 8-14-93 8-5-93 8-15-93 8-7-93 8-11-93 8-11-93 8-15-93 8-7-93 8-8-93 8-9-93 8-10-93 8-12-93 8-16-93 Production Perf Record Perf Record CNL ~oo- q Prod Profile Prod Profile Perf Record Perf Record CNL i~5oo- Perf Record Inj Profile Production q0 Run 1.5" 6ch Run 1.5" Sch Run 1, 5" Sch R.n 1.5" Sch Run 1.5" Sch R.m 1.5" Sch R.n 1, 5" Sch R..n 1.5" Sch Run 1.5" Sch R,m 1.5" Sch Rim 1. 5" //ich R.n 1.2"&5" Sch Baker IBP 5%o- io>6z R,m 1.5" ~h TBG Patch Set Record R-n 1.5" q~-l~h I.,e~k Detect ~0 - lt:~ Rl~n 1.5" Sch Perf Record.z~o- )'z/z~ R,,n 1.5" Sch Perf Record ~1070-1 tqu0 R.n 1.5" Seh TBGPatch ~5'7o-.-~,~t0 Run 1.5" Inj Profile/~-.~?-~Run 2, 5" ,~q~o- Perf Record n~oo-I~z~z R-n 1, 5" ~h ~c~seismtc S~ey R-n 1, 5" ~-[~~h ~j ~o~e]s~m-~?~ R,m 1, 5" ~~ ~c~s~mtc S~ey R.m 2. 5" l~q ~o- ~h ~ ~ o Pe~ Record %~~ R-n 1, 5" ~h ~mpleflon~~Sao R~ 1, 5" ~h RECEIVED BY~~ Have A Nice Dayi Sonya Wallace ATO-1529 * The correct API# for 1-5ST is 50-029-2007C~00. STATE OF ALASKA ALASK~ ,~%:_ AND GAS CONSERVATION C( !~llSSION REPORT' F SUNDRY WELL OPE.' oA, eTIONS 3.' Address ! Stratigraphic, 7. Unit or Property. P.O. Box 100360, Anchorage, AK 99510-0360 I serv,ce x.... Prudhoe Bay Unit 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11N, R15E, UM 8. Well number 4-09 9. Permit number/approval number 76-30 10. APl number 50 - 029-20207 11. Field/Pool Prudhoe Bay Oil pool 12. Present well condition summary Total depth' measured true vertical Effective depth' measured true vertical Casing Length Conductor 80' Surface 2602' Production 11038' Liner 1264' 12050 feet Plugs(mea.s. ured) 9113 feet 11957 feet 9042 feet Junk(measured) Size Cemented 20" 240 sx AS 13-3/8" 5300 sx PF II 9-5/8" 750'sx CI 'G' & 125 sx PF II 7" 310 sx CI 'G' Measured depth True verticaldepth 80' 80' 2654' 2654' 11090' 8368' 12050' 9113' Perforation depth: measured 11580-11622';I 1629-11643'; 11670-11675"11687-11695';11752-11792';11807-11824" 11840-11865' true ve rtica! 873'2-8766' ;8772-8783' ;8806-8810' ;8820-8827' :8874-8907' ;8919-8933';8947-8968' Tubing (size, grade, and measured depth) 5-1/2",17#,L-80,NPCT @ 10722' MD, 4-1/2",12.6#,L-80,NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BOT 3-H pkr @ 10711' MD; Camco BaI-O SSSV @ 2164' MD 13. Stimulation or cement squeeze summary RECeiVeD Intervals treated(measured) Treatment description including volumes used and final pressure s E P - 9 1993 Alaska 0il & Gas Cons. Commisslo' 14. Prior to well operation _.~.presentatiVe Daily Averag..e Production or Injection Data Anchorage OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure - - 31500 1525 2075 Subsequent to operation 31200 1380 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~'i~ Oil.__ Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~,¢~, ~"~ ~ Title FS-2 Senior Engineer Form 10-404~ev 06/1~/88 2040 Injector SUBMIT IN DUPLICATE /~'~ILY REPORT OF WELL OPER. iONS DS 4-09i Perforating Operations: ARCO Alaska, Inc. perforated DS 4-09i at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 8/8/93. The interval perforated was the following: 11.629' - 11643' MD (Reference Log: BHCS dated 5/2/76). Injection fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 8/8/93. RU perforating unit, depressed fluid level to 4000' with 1800' gas, pressure tested BOP's and lubricator to 2500 psi, okay. RIH, open well to flow and perforated 11629'-11643' MD at 4 SPF, POOH, and confirmed all shots fired. (reft BHCS of 5/2/76). Rigged down and secured well. RECEIVED S E P - 9 1993 Alaska Oil & Gas Cons. oummisslo" Anchorage RDC: 8/24/93 ----, STATE OF ALASKA ALASKA,.. AND GAS CONSERVATION CC~'~flSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Requesi: Abandon Suspend Operation shutdown __ Re-enter suspended well , Alter casing Repair well Plugging Time extension Stimulate Change approved program "--~ull tubing Variance Perforate X,, other __ 5. Type of Well 6. Datum of elevation(DF or KB) Development Exploratory Stratigraphic Service X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11 N, R15E, UM RECEIVED J UN 1 5 199; Alaska 0il & Gas Cons. C0mmissio ~_ .ch'orage 52' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number ,,~.,~.,, 9. Permit number 76-30 10. APlnumber --,~ J ~1 50 - 029-20207 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12050 feet Plugs(measured) 9113 feet Effective depth: measured 11957 feet true vertical 9042 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 240 sx AS 80' 80' Sudace 2602' 13-3/8" 5300 sx PF II 2654' 2654' Production 11038' 9-5/8" 750 sx Class G & 125 sx PF II 11090' 8368' Liner 1264' 7" 780 sx Class G 12050' 9113' Perforation depth: measured 11580-11622';11670-11675';11687-11695';11752-11792"11807-11824';11840-11865' true vertical 8732-8766';8806-8810';8820-8827';8874-8907';8919-8933';8947-8968' Tubing (size, grade, and measured depth) 5-1/2",17#,L-80,NPCT @ 10722' MD;4-1/2",12.6#,L-80,NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BeT 3-H pkr @ 10711' MD;Camco BaI-O SSSV @ 2164' MD 13. Attachments Description summary of proposal x Detailed operations program .. BOP sketch x...&_ 14. Estimated date for cOmmencing operation I July 1993 16. If proposal was verbally approved Oil .. Gas Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '*~C.,x~ b ~w',~ Title FS-2 Senior Engineer 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- zf'0~f' 15. Status of well classification as: Suspended Injector Date / Approval No.~ .,~ -/,.[.-.~ Approved ~npy Returned Approved by order of the Commissioner Original Signed By David W. Johnston Commissioner Form 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE DESCRIPTION SUMMARY OF PROP~" AL ARCO Alaska, Inc. proposes to perforate injector DS 4-9i at selected intervals within the Sadlerochit formation. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. These perforations are in the Victor waterflood zone. Seawater will be in the wellbore during the perforating operation. The reservoir pressure at the perforation depths is approximately 3650 psi. Proposed Perforation Depths: 11629' - 11643' Ref: BHCS 5/2/76. J UN 1 199i) A~aska Oi~ & Gas Gons. Gore~ss'~°~ Anchorage WDM: 6/10/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS ~>~1>~_ ~3-22 "-'k3-22 [3-29 ~~ ;~ ~3-31 -~'~'~3-31 -2 6-4 4-23 5-20 /16-14 ~6-14 ~?~/~_~_~18-17 10-17-92 PSGT - Computed Results Run 1, 5" 10-17-92 PSGT R~m 1, 5" 1-25-93 PSGT - Computed Results R._n 1, 5" 1-25-93 PSGT R"" 1, 5" 2-19-93 PSGT - Computed Results Run 1, 5" 2-19-93 PSGT R~_~_- 1, 5" 7-24-93 PSGT - Computed Results R,_- 1, 5" 7-24-92 PSGT R,m 1, 5" 2-18-93 PSGT - Computed Results R~_~_- 1, 5" 2-18-93 PSGT Run 1, 5" 2-21-93 PSGT - Computed Results Run 1, 5" 2-21-93 PSGT Run 1, 5" 1-24-93 PSGT - Computed Results Run 1, 5" 1-24-93 PSGT Run 1, 5" 8-2-92 TMD Run 1, 5" 12-28-92 TMD R._n 1, 5" 12-9-91 TMD R~_m 1, 5" 8-1-92 TMD R~_m 1, 5" 9-17-92 PSGT - Computed Results R~_m 1, 5" 9-17-92 PSGT R~_m 1, 5" 8-17-92 TMD R~_m 1, 5" Please sign ,nd return th~ attached copy as ~eceipt of data. RECEIVED BY_-~~...~.~.~ Have A Nice Day! Sonya Wallace AT0-1529 # CENTRAL CLINT CHAPM~.. m:XON MOBIL Z/ Trans# 93047 PB ~E~ ~ # BP~ # STATE OF ALASKA * The coreect API# for 14-23 is 50-029-20757-00. /-'% ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-7-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS --~~tol'~ 10-17-92 .3-29 ~li/ 1-25-93 3-31 ~l~ 2-19-93 ~3-32 ~~ 4-25-93 ~0~-33 ~al 7-24-92 90-~~4-2 ~a/ 2-18-93 ~4-4 ~O 2-21-93 ~._[~--14-37 S~ 4,13-92 ~.. ~;~ -~16-14 ~'~9-17-92 ~.~Si Z -A 6-21~ 7-23-92 ~~-9 ~.~_ 1-24-93 2}-i~11'1 ~~ 4-21-92 ~/~ 114---11-18 ~/o~'~ 4-14-92 \ff ioc~14-12 ff:/~4-24-92 PSGT Ru_n 1 PSGT Run 1 PSGT R~m 1 PSGT Run 1 PSGT ' Ru_n 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 PSGT Run 1 TMD Run 1 PSGT ' Ru_n 1 PSGT Run 1 PSGT Run I job#L84611-X Job#L92001-8 Job#L92012-8 Job#L66798-6 Job#L84725-3 Job #L92011-7 Job#L92013-9 Job#L83200-7 Job#L66796-4 Job#L66795-3 Job#L66797-5 Job#L73961-8 . Job#L667942 Job#L84609-8 Job#L84724-2 Please sign and return t~he attached copy. as receipt of data. RECEIVED BY__~_~// Have A Nice Day! R£C£1VED APPROVED_ ~ Sonya Wallace ATO-1529 Ap~ 1 9 199 ' Alaska-oil'& Gas Cons. # CENTRAL FILI~~ CHEVRON D&M BOB ~AS (OH/GCT) # EXXON MARATHON MOBIL Trans# 93045 # PHIL~ PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO STATE OF ALASKA 0 J{ I G I N A L ALASKA?-'"_ AND GAS CONSERVATION C¢~"VllSSION '~, REPORT' JF SUNDRY WELL OPI-HATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11N, R15E, UM Repair well Other 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52' RKB 7. Unit or Property Prudhoe Bay Unit 8, Well number 4-09 9. Permit number/approval number 76-30 10. APl number 50 - 029-20207 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12050 feet Plugs(measured) 9113 feet Effective depth: measured 11957 feet true vertical 9042 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 240 sx AS 80' 80' Surface 2602' 13-3/8" 5300 sx PF II 2654' 2654' Production 11038' 9-5/8" 750 sx CI 'G' & 125 sx PF II 11090' 8368' Liner 1264' 7" 780 sx CI 'G' 12050' 9113' Perforation depth: measured 11580-11622';11670-11675';11687-11695'; 11752-11792';11807-11824';11840-11865' true vertical 8732-8766' ;8806-881 O' ;8820-8827' ;8874-8907' ;8919-8933';8947-8968' Tubing (size, grade, and measured depth) 5-1/2",17#,L-80,NPCT @ 10722' MD, 4-1/2",12.64t, L-80,NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BOT 3-H pkr @ 10711' MD; Camco BaI-O SSSV ~j~2~4~ MD n r'E/ 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. C0mm'tss'~o~ Prior to well operation Representative Daily Average Production or In!ection Data ~'"' ...... "' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 19411 800 Tubing Pressure 1275 Subsequent to operation 18602 760 1177 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil.._. Gas__ Suspended.__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢~ Title FS-2 Regional Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~;~ _alLY REPORT OF WELL OPERa. iONS DS 4-09i Perforating Operations: ARCO Alaska, Inc. perforated DS 4-09i at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 3/13/92. The interval perforated was the following: 11580'- 11622' MD (Reference Log: BHCS dated 5/2/76). Injection fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 3/13/92. RU perforating unit, pressure tested BOP's and lubricator to 2500 psi, okay. RIH and perforated 11580'-11622' MD at 4 SPF, POOH, and confirmed all shots fired. (ref: BHCS of 5/2/76). Rigged down and secured well. RDC' 4/30/92 ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: 2~-*- 7 1-15 ?~'3 3-7 '7~****" ? ~ ,~ 4-78T 4-7ST ARCO CASED HOLE FINALS 2-9-92 2-27-92 3-1-92 3-13-92 3-15-92 3-1-92 3-1-92 4-9 ~'g'3 ~ ?~-)? 4-15 ?/**/¢$ 4-42 ~ 5-12 2?-/¢ 2-11-92 TM 2-18-92 7-1 2-18-92 9-1 2-28-92 9-2 2-8-92 9-18 3-14-92 9-27 2-7-92 9-31 2-8-92 Prod Prof Run 1, 5" Camco InJ Profile R;,- 1, 5" Camco Jewelry R.n 1, 5" Camco Prod Prof R.n 1, 5" Camco InJ Prof Ru- 1, 5" Camco InJ Prof Run 1, 5" Camco PITS Run 1, 5" Camco Prod Prof Run 1, 5" Camco Jewelry Run 1, 5" Camco Prod Prof R~n 1, 5" Camco GR/CCL/Jewelry Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof Run 1, 5" Camco Prod Prof Run I, 5" Camco [nj Prof Run 1, 5" Camco Prod Prof Rl~n 1, 5" Camco Prod Prof Run 1, 5" Camco Please sign and return the attached copy u receipt of data. RECEIVED BY ~_~ ~[ ~[[IV~[O AP P R OV El~sk~'~~/~ Con? 0omm~ssion Trans# 9207~-T--'A~~ Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct well name for this log is 4-78T. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 1-5ST 3-23-92 PFC/GR R~m 1.5" Atlas 2-26 3'10-92 Perf Record Ru_n 1, 5" Sch 4-7ST 3-24-92 MSI Carbon/Oxygen R~_m 1, 5' Atlas 4-9 3-13-92 Perf Record Ru_n 1, 5" Sch 4-12 3-13-92 PerfRecord Run 1, 5" Sch 5-36 3-21-92 Prism Run 1, 5" Aths 14-7 3-26-92 Perf Record Run 1, 5" 8ch (16-24 3-9-92 Co!lnr/Perf Run 1, 5" Atlas ~16-24 3-9-92 Tubing Cutter Run 1, 5" Atlas {16-24 3-16-92 Diff. Temperature R~_m 1, 5" Arks ~16-24 3-16-92 Vertilog (7") Run 1, 5" Atlas ~16-24 3-16-92 Vertilog (9 5/8") Run 1, 5" Arks Pleuesignandretum,fl~_~c°pyasreceipt°fdata'~C~/V~RECEIVED BY Have A Nice Day! Alaska 01~ (]as/Cons. Commission Sonya Wallace APPR OVED_..,.,~,/.~_°..ral~e ATO- 1529 Trans# 92077 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct APl# for I-5ST is 50-029-20076-00. The correct well name for this log is 4-7ST. RIEFliE. I:;,'IENCIE: ARC(] CASED HOI_E FINALS' t ....c,,, .6 .... t 2-9 t PEiRF'-'(...OI...L. AR RUN ... -~1 .... ~ '" i''~ · ~ ~,'.-.!~,~ 6 I 2'"'? t !" I:=RI ..... .,OI..i..AI'~ \ RUN ~ , 5 ' :;~'-' '7 6-" t t -' ? t F:' F:' C.- 6 R ( F:' A C K E R S E T T I N (:.;) ~ R LJ N --, 5 ' J.~ .... t '? 6"" t 0 ~ t F" I"-' I~: I: - C Ct I_ L.. A F:: 1'4:I..)N ~ .. DI...--' V DI... '"' ..":~ .... tT 6 ..... 1.8'"(7t AC" ' r'" RUN ~, ..5" '"t .5' 4-? 6'"'<?""<7t .S'F'INNIER (WII"I"I TEEHF') kEN .. -. "" "' '1 " "I ~" , c ..... t8 6 .... t4 9t I::'EF'..F .... L,L.I...I...AR RLN 1, ...... . .... "l ..... t 'l t :.'.~ 6 5 9t F:'DK-t GO/(.,..,l..'"t.,l:,' RUN t ',?.'; "" c? E~ 6""':2'-9t CNI... -' EPI 1:I--IE:RMAI... RUN t :~.-98 6-2-?t CNI.....- THERHAI.. RUN ::~6, 5 'i :':~ ..- 98 6 - t ..'.,i -9 ~ D I T-. F.i: R U N J 4 -- t ~.~ 6- '?- <? J F' I T $ !;: I.J N i " !" 'l - · '1" ·" FL.E.A,.~E. ,.?I()N ANI) RE..1LJRN I'FIE AI'I'ACHED COPY AS' F, EC, E:.]:F'T OF' DATA, I~ECI:'. I VED BY .... HAVE: A NICE I) AY! ,.$'ONYA WAL..I..ACE: Al'()--- t ~S29 'I'RAN$:~ 9 DISTRIBUT]:ON :.": CENTRAL. F II_E~' ~' CHEVRON D& M ~. EXTENSION EXPLORATION :~ · E.'XXON HARAI'HON ~,.~ MOBIL F'HILL:[F'$ F'8 WELL FILES · "' BF'X '"' STATE OF' ALASKA .~. TEXACO * THE CORRECI'ED AF'I$ FOR 9-t8 IS .50-029'2~259 ka dUL 1 1 oii ' as r~ STATE OF ALASKA ALASK~-"L AND GAS CONSERVATION C( ~,/IISSION REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed: Pull tubing ~ Alter casing 2. Name of Operator ARCO Alaska, Inc. Operation shutdown Stimulate __ Plugging -- Perforate X~ Repair well Other 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 52' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-9 9. Permit number/approval number 76-30/90-536 10. APl number 50 - 029-20207 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2602' Production 11038' Liner 1264' 12050 feet Plugs(measured) 9113 feet 11957 feet 9042 feet Junk(measured) Size Cemented Measured depth 20" 240 sx AS 80' 13-3/8" 5300 sx PF II 2654' 9-5/8" 750 sx Cl 'G' & 125 sx PF II 11090' 7" 310 sx 12050' True vertical depth 80' 2654' 8368' 9113' Perforation depth: measured 11580'-11622', 11670'-11675', 11687'-11695', 11752'-11792', 11807'-11824 11840'-11865' true vertical 8732'-8766', 8806'-8810', 8820'-8827', 8874'-8907', 8919'-8933', 8947'-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10722' MD; 4-1/2", 12.6~, L-80, NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 1071 ~,~.D; Camco BaI-O SSSV @ 2164' MD 1 Stimulation or cement squeeze summary Intervalstreated(measured) N/A JL~[~ 2 5 .~ 99] Treatment description including volumes used and final pressure ~~0~.~ ~a$-- Co.s. 14. Reoresentative Daily Average Producti~'~i~l~ii~)ata OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 13835 270 Tubing Pressure 1930 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 14312 275 16. Status of well classification as: Oil__ Gas__ Suspended__ Service 2005 Wa, ter Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. { Signed ~,~ (~ ~ ~~,~' Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 .ql Ikl/nh Date SUBMIT IN DUPLICATE · H ~y REPORT OF Wl~ ~I. OPER.. iONS DS 4-9 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-9 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/30/90. The interval perforated was the following: 11580'-11622' MD (Reference Log: BHCS dated 5/2/76). Injection water was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 9/30/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated 11580'-11622' at 1/2 SPF (ref: BHCS of 5/2/76). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/14/91 Ai:-J. CHL]RAC-E: AL.A~K A 995'i E:, D ATE · "-2- i -9 i ARCO CA"-JED HOLE FZNAL2 i -i A i -23-'91 2 -'7 9 - 2 £:' - 9 ':E) 3; '- 5 i - '25 - 9 i 3-29 +~ -~ 6-9~ S-27 +i -2(b-9i a _c, ,:~' -- ~ P, -- 0 A 6'- i 2 '+' i -'SC:'-9 i ,. '- .,~i ~ -i 3,-9i 9--45 i '2- 2 ~:,- 9,:Z:, ii'--i i6, .... 8-9C) i ,~..-.:'u. 4.~. , --i 6-91 i i '-- ":: TMi ~ - -9 ~:~ -..m ¢, ! ~.-22 i --P6.-9i i 6 .... i 9 i -i 8 ..... ~. 8-24 + i - ° °-.9,_,= i CCL F'ACKER C:OR-'¢~" 1", .- ,. l*-~ 'T ! 0 N CCL F'DK - i 6,,3,/D i FF-., CORR ,. F' T", ~" - ~ ;:",,':~ / C' i J:; F:' F' f! F: i:;.' .~. t% : -..- .-- .- .,. ~ .... P !ii: R F R E C O F;.: D c,Y.-,K _ ~ ¢:;¢;/r., 'r ~.:~.: ;-'-pc, c, (':OLLAR ~.~::r.:c, ,..,,, RECORD F' R i Si!: PERF ::" ~F" ;", ~:'"', P D K - i ,:'},:-} / D .[ F' F', C !'-t F;..' R, S i ,'.:; i'*, A pr.:-RF RECORD F:ERF OR i EN"f'A T i ON/CCL. t:'DK -i ,.":),::;,/D i F"F' ~ t'St']i-~:i-i.' ,. ,'~' I ":cc'~.iVED BY ~ HAVE A NIr'c. ..,,_ DAY'. $IGb~,A ,., $.~.'r 5MA SIGN AND RFi"UF..'N THE ATTACHED COF'Y A'S REC'.E:Ir-"T SHARON WiL. SON ATO- i 529 f;.'. LJ iq J';..' U N F:..' U N R U N R U N R U N R LJ N RUN RLJN RUN f;..' U N RUN RUN RUN F,:.'U N RUN A P P i:'.: 0 V E. $J,~~ 0t:" DA DISTRIBUTVON~. CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON HARATHON MOBIL 'Ti4F-'-,,,_ APl",':.- F'OR INDICATES THE DATE 'THE LOG WAS F'RINTED., ~ F' Iq I t_ L.,.T ,r' ,.,.~" PB WELL FILES R & D · :~ E~F'X S'i-A'¥E OF ALASKA '11' "FEXACO RECEIVED FEB 8 1991 Alaska Oil & Gas Cons; Commission Anchorage DA'FI!ii' i (i)- 2 9-' 9 (=,~ R E:' F= E F;,' Iii: N C E ' A F;,' C 0 C A $ E D I"10 I... E F= I N A 1... $ 4'"- 9 t (')'"' 3 "" 9 g I N ...J E C "i" I 0 N F:' R 0 t::' :t: t... lei: I:;: l..J N 4 - i S i (')'"' :3 - 9 ¢'I N...J E C '¥' I 0 N F:' R 0 F:' I t... ti.:. R U N 6 - 4 i f)'"' 6 - 9 (') F:' R 0 D lJ [:: T I 0 N F:' R 0 I::' I I... E I:;.'. (..I N 6 '"' 6 i (') '"' 4 .... 9 (') F:' I '1" ;'.<; R U N 6. .... ~:;', i ":;,, '"' ..,.'::: "" ~:.~, '":',, F:' R 0 D U C 'f' I 0 N P R 0 F: ]: t... E I:< U N 6 .... t ':'.i:' t (')'"' 4"- 9 E:'F' R 0 D t..J C'¥' I 0 N F' R 0 t::' I i... Iii: F;.'. LJ N i i .... 2 i (') .... i 4':" 9 (') C: 0 L 1... A R / F:' Ii:i:;.'. F:' I:;,' U N i :?. '"' 8 8'i ~;'"" :5 .... 9'::} I... E A I< D E '¥' Ii':. C l" t 0 N I<.' U N i 4 .... i 9 i (i:' .... i 9-9(') COL. I...AR/F:'ItF;.:F: I:,..'UN i 4 .... 2 (') i ;5 .... i 9'-" 9 (:) C 0 t... I... A F;..' /F:' Iii: 1:;,' F F;.'. t.J N )_ I:;~i: 'i" U R N ]" i"t Iii: A 'i" T A C i"! Iii: i) C 0 F:' Y A $ I:'..' iii: C E I F" "i" (:J i::' D A T A :S" A L. L Y t"10 f:' F'E C t< Iii: R - '~ A P P R 0 V Ii!: D . A"I" 0 .... i !S 2 9 l" !:;.'. A N S :,'I: 9 ('.".¢:'.",. i 4 C A M C [) C A M C 0 C?.~MCO C A d C 0 C A M C 0 C A i",; C 0 ATLA,.S' C r:, f'"i C 0 A'F I...A,S' A i t...A D I S' T t:;.', i B U "f' I 0 N "" ;" E ~-..i 'i" F;.: A I._ F:' i I... ti{: S "" · ,,.:.,, · -,- F:' H i L L I F:' ,S' · ,,-"" f":... H Ii!: V 1:;..' 0 i':i F:' B W E.". ....i i,... ,r':' ]: i... E. ,S D & M i:;: .?!.,. D · ,-'"' ............. t::'X 'i" i::' N,.:.t' I ...,;'; .i".~, F' 'x' i::'1 F,: F.' A "f' i i"'~ .... i".; ~: B F:' X "" Iii: X X 0 N il' . ' · ,; .- :!{: TA T iii: f.)i::' r:'~ I... A :!; t< ,'::; M A R A l" H 0 i".! 'i" iii: X A C 0 · ",': H 0 B t L ., , ~' STATE OF ALASKA ~ ALAS~IL AND GAS CONSERVATION ~MMISSIOI~ !:~ I r_ ! N APPLIC, TION FOR SUNDRY APPROVAL J' Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change appro=~ program Pull tubing Vadance Perforate X Other 1. Type of Request: 2. Name of Operator 5. Type of Well ARCO Alaska, Inc. Development Exploratory 3. Address Stratigraphic P.O. Box 100360, Anchorage, AK 99510-0360 ser~ce 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11N, R15E, UM 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-9 9. Permit number 76-30 10. APl number 50 - 029-20207 12. Present well condition summary Total depth: measured 12050 feet Plugs(measured) true vertical 9113 feet ;JUL ! 2. ]990 Effective depth: measured 11957 feet true vertical 9042 feet Junk(measured) J~JasJ~ OJJ Casing Length Size~ Cemented Measu;ea d~i01'~e"vertical depth Conductor 80' 20" 240 sx AS 80' 80' Surface 2602' 13-3/8" 5300 sx PF II 2654' 2654' Production 11038' 9-5/8" 750 sx Cl 'G' & 125 sx PF II 11090' 8368' Liner 1264' 7" 310 sx 12050' 9113' 11. Field/Pool Prudhoe Bay Oil Pool RECEIVED I Perforation depth: measured 11670-11675'; 11687-11695'; 11752-11792'; 11807-11824'; 11840-11865' true vertical 8806-8810'; 8820-8827'; 8874-8907'; 8919-8933'; 8947-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT@ 10722' MD; 4-1/2", 12.6#, L-80, NPC tail @ 10815' MD Packers and SSSV (type and measured depth) ROT 3-H packer @ 10711' MD; Camco Bal-0 SSSV @ 2164' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed,~J~. ~ 1~ ~.~f"/-- ~'a.w'/"~ Title Senior Area Engineer U FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity . BOP Test Location clearance. Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNEO BY LONNIE C. SMITH Approved by order of the Commissioner 15. Status of well classification as: Gas Suspended Injector Date I Approval No. Commissioner Date Form 10-403 Rev 06/15/88 '[^lr~l~lilQI Ikl Inh Approved Copy Returned SUBMIT IN TRIPLICATE DE/~RIPTION SUMMARY OF PK.._ ?OSAL _. ARCO Alaska, Inc. proposes to perforate produced water injector DS 4-9i at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. The well is currently injecting produced water. Produced water will be in the wellbore during perforating operations. These perforations are in the Victor waterflood zone. The reservoir pressure at the perforation depths is approximately 3800 psi. Proposed Perforation Interval: 11580' - 11622' Ref: BHCS 5/2/76. WDM: 7/10/90 4 1. 5000 PSi 7" WE:I. L Hr. AI:) CONN[ C~OR ir I. ANG£ 2. 5000 PSI WlR[LIN£ RAMS (VARIABLE: SIZE:) 3. ~000 I)$14 1/6- LUBR~'roR 4. 5000 PSI 4 1/6" ri. ow tUlC f~c~-orr NIR£LIN~ ~ EOuIPp~N! ARCO AL.A.TKA, INC., F'., 0 ~ BOX i ,."~,:~.~6~3 ANCHORAGE ALA~ KA 99bi DATE: REFERENCE'' ARCO CASED HOLE FINALS i-t7 5-S-90 PERF RECORD RUN ~, ~-~9 5-4-9~3 PERF RECORD RUN ~ ~ 2-~'3; 5-~ 3-9~ F'ERF RECORD RUN ~ , '2-f:3 5-f 4-9~ F'O~T FRAC 'T'EMI::' SURVEY RUN f , 2-''>. F' ~.8 5-8-~() RODUCTION F'ROFILE R. UN ~ , J-f(E 5-re-ge INJECTION PROFII_E RUN f, 4-9 5-t4-9~ INJECTION F'ROFILE R. UN t , 7-2~2, 5-~-9(~ PERF RE~ORD RUN t 7-2J 5--~ ~-9,3 F'O~'T FRAC TEMF' RUN ~, 7-28 5-~ ~-9(} F'ERF RECORD RUN ~, ~t-22 5-.4-9~} ACOU,~ CEMENT BOND RUN ~, ~-22 5-4--9~ F'ULEE ECHO CEMENT (PET) RUN t, ~2-~ 5-9-9() FRODUCTION PROFILE RUN ~, ~ 5-~ J 5-~ ~-9~ CCL TEMF' SURVEY ~ RUN ~, f 7--~ 2 5-~ ~-9~ COLLAR RUN ~, ~8-2~ 5-9-9(~ F'RODUCTION PROFILE RUN ~, i 5' 5' 5' 5' .5 ' 5" 5" 5' 5' 5' 5' 5" 5' HL~' HLZ I'.IL ~' CAi'~CO CAMCCI CAMCO C A i"i [.'. 0 HL'~ CAMCO HL;~ HL,~' · CAMCO CAMCO [;ANCO CAMCO PLEASE SIGN AND RETURN THE ATTAC'.HED COF'Y AS RECEIPT OF DATA. RECEIVED BY _~ HAVE A NICE DAY! dUN-4 ~ALLY HOFF:ECKER ~~0il &G~ c°ns' ~mmi~i°n ' ' ' . AF F ROVED _~_ ATO-~ 529 'A~O~8 TRAN,g'~ 9~.~,~ DISTRIBUTION - CENTRAL FILES ~ ~ F'H ILL_ I.F'i' ¢ · .-'"' CHEVF:ON F:'B WELL F Il. El' D & M R & D · ,~ EXTENSION EXPLORATION ~: BPX · "' EXXON -.-'"' :'."I"A'I'E OF ALASKA MARATHON TEXACO ,~ MOBIL ARCO Alaska, Inc./-''~ Prudhoe Bay .~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 9, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4,9, Permit No. 76-30 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/JCB/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-9)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK,~'"'tL AND GAS CONSERVATION C~-"IMISSION APPLICA 'ION FOR SUNDRY APPROVALS0 I::{ I I 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approTM program Pull tubing Variance Perforate Other 5. Type of Well Development X Exploratory Stratigraphic , Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, T11N, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, T11N, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, T11N, R15E, UM 12. Present well condition summary Total depth: measured 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-9 9. Permit number 76-30 10. APl number 50 - 029-20207 t 1. Field/Pool -.Prudhoe Bay Oil Pool 12050 feet Plugs(measur&dJ:~ true vertical 9113 feet Eff~tive depth: measured 11957 feet true venial 9042 feet Junk(measured~-~..~ Casing Length Size Cemented ~., ~asured depth Conductor 80' 20" 240 sx AS 80' Sudace 2602' 13-3/8" 5300 sx PF II 2654' Production 11038' 9-5/8" 750 sx CI 'G' & 125 sx PF II 11090' Liner 1264' 7" 310 sx 12050' True vertical depth 80' 2654' 8368' 9113' Perforation depth: measured 11670-11675'; 11687-11695'; 11752-11792'; 11807-11824'; 11840-11865' true vertical 8806-8810'; 8820-8827'; 8874-8907'; 8919-8933'; 8947-8968' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT@ 10722' MD; 4-1/2", 12.6#, L-80, NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10711' MD; Camco Bal-0 SSSV @ 2164' MD 13. Attachments Description summary of proposal , X Detailed operations program __. BOP sketch x 15. Status of well classification as: 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Oil Gas Suspended Injector Name of approver Date approved Service 17. I hereby/~certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~~~~~ Title Operations Engineering Manager Date ~ ~': '~ FOR COMMISSION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP TeSt Location clearance Mechanical Integrity Test Subsequent form required 10- .. ~ ~' I Appr°va' N°. ?~/4¢¥~_.~ Approved by order of the Commissioner ORIGINAL SIGNED LONNIF ~ Form 10-403 Rev 06/15/88 Approved L;op~' . Returned Commissioner SUBMIT IN TRIPLICATE Drill Site 4-9i Selective Stimulation Procedure ARC© Alaska, Inc. proposes to perform the following stimulation treatment: 1. Make a gauge ring run to TD with a 3-1/2" gauge ring. 2. MIRU CTU with 3" x 7" inflatable packer and tubing end Iocator. 3. RIH with CT. Locate the tubing end and adjust the depth accordingly. The tubing tail depth is 10799'MD according to the CCL of 6/29/85. 4. Fluid pack the CT x injection tubing annulus. 5. Continue downhole and set the inflatable packer at 11832'MD. 6. Load the following fluids: a. 1250 gal 12%CI with 20% dispersed xylene and additives b. 2500 gal of 12% HCI with additives c. 2500 gal of 6% HC1:1.5% HF with additives d. 4000 gal of 3% HCI with additives e. 5000 gal 2% NaCI water with a biocide - see additive sheet f. 2000 gal 5% HOOH in 2% NaCI (100 deg F) g. 3000 gal 2% NaCI water with 50 Ibs/Mgal HEC and 900 lbs BAF h. 100 bbl warm methanol (70 deg F). 50 bbls needed to dissolve BAF and freeze protect CT. i. 200 to 300 bbl warm (90 deg F) fresh water in an upright tank with a fire hose. j. 300 bbl seawater for fluid packing and maintaining pressure on the CT x inj tbg annulus. 7. MIRU transports, pump trucks and associated equipment. 8. Pump the following fluids down the coiled tubing to stimulate the Lower Romeo interval. (11840'M a. 24 b. 30 c. 24 d. 24 e, 1 f. Shut g. 10 h. 30 i. 30 j. 48 k. 20 D to 11865'MD): bbl of 12% HCI with 20% dispersed xylene bbl of diverter - gelled 2% NaCI with BAF bbl of 2% NaCI water bbl of 5% HOOH in 2% NaCI Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water down for 2 to 3 hours bbl of diverter - gelled 2% NaCI with BAF bbl of of 12% HCI with additives bbl of 6% HC1:1.5% HF with additives bbl of 3% HCI with additives o 10. I. 24 m. 24 n, 1 o.~ Shut p. 10 q. 3O r. 30 s. 48 t. 48 bbl of diverter - gelled 2% NaCI with BAF bbl of 2% NaCI water bbl of 5% HOOH in 2% NaCI Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water down for 2 to 3 hours bbl of diverter - gelled 2% NaCI with BAF bbl of of 12% HCI with additives bbl of 6% HC1:1.5% HF with additives bbl of 3% HCI with additives bbl of warm Methanol (65 deg F) to dissolve BAF and freeze protect the CT. Release CT packer and POOH. Slowly pump seawater down the CT x inj tubing annulus to displace the fluids. RD and release CTU, pump trucks and transports Reference Log BHCS 5/2/86 6 5 4 2 CO~ILED 'I'UBINt~ UN]? BOP EGU ] P~EN~ 1. SOCK) PSI ?" WELLHEAD CONN£CTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. S000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 HIRELINE BOP EQUIPMENT 1. 5000 PSI 9" WELLHEAD CONN£C1OR FLANGE :2.5,000 PSI WIRELIN£ RAMS (VARIABLE ,SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 'I/6" FLOW TUBE PACK-Orr ARCO ALASKA, INC~ P.O. BOX tee~6e ANCHORAGE, ALASKA 995~ DATE: 9-9-88 REFERENCE: ARCO CASED HOLE FINAL 2-t 4 8-3t -88 2-t 6 8-Jt -88 '~-3-5 8-22-88 3- t 2 8-29-88 ~3-25 8-27-88 4- t 8-3 t -88 4-9 8- ~ 9-88 4- t t 8-22-88 ~5-i2 8-4-88 5- t 3 8-4-88 ~&-i 2 8-i 7-88 ~7-8 8-t 7-88 ~7-i5 8-t7-88 ~7-33 9-7-88 9-i3 8-i 8-88 ""-.i t - t 5 9-2-88 t 3-i 8 8-2t -88 t 4-3 8-26-88 "'~i 5-i 8-3i-88 ~t 5-2 t 8-29-88 "'" i 8-3 9-i -88 18-i7 9-1-88 COMPLETION RECORD--GAMMA RAY RUN i, 5" PRODUCTION PROFILE RUN t, 5' PRODUCTION PROFILE RUN i, 5" LEAK DETECTION TEMP RIJN t, 2" FLOWMETER--GAMMA RAY RUN i, PITS RUN INJECTION F'ROFILE TEMP SURVEY RUN INJECTION PROFILE R~JN t, 5' CONTINUOUS FLOW SURVEY RUN CONTINUOU£ FLOW SURVEY RUN F'IT$ RUN i, PRODUCTION PROFILE RUN i, 5" F'RODUCTION F'ROFILE RUN t~ 5' COLLAR RUN t, 5' COLLAR ~UN i, PFC RUN INJECTION PROFILE I'EMP SURVEY RUN i, 5" LEAK DETECTION RUN t, t'&5' PRODUCTION PROFILE RUN i, 5' CCL--GAMMA RAY RUN i, 5' COLI. AR/F'ERF RUN i , 5' P~RFORA'¥iNG RECORD "Ru,~ ...... 'PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T [)F' DATA, SCH CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO GEAR GEAR CAMCO CAMCO CAMCO ATLAS CAMCO' ATLAS CAMCO CAMCO CAMCO CAMCO ATLAS $CH RECEIVED BY HAVE A NICE DAY! £ALLY HOFFECKER AT0-i529 TRAN$ ~88568 ~ APF'ROVED DISTRIBUTION CENTRAL FILES CHEVRON D& M EXTENSION EXF'LORA'/ION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R &D SAF'C STATE OF AI. ASI<A TEXACO F;:I ti".J '2 i:: I::' ~"' ~:'"; ..' '::' '1'~ -~: ¥ ~.,~--~,m ~ ~ ~ ~ Alaska Oil & Gas cons C t::' F::['; [.'; Y '~ A...~,-- · 0 · ;::', 'T' ',"i ..... I ~"::'.? 9 -c,~lurag9 ..... --'~,,,--- :i") T :::..' 'T' F;: T T.:: 1 I'T T ,,"1H ::.::f':!..I ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 20, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-9 Permit No. 76-30 Dear Mr. Chatterton: Attached is the Application for performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp A~ttachment C C." St~r~dard Alaska Production Company J. Gruber, ATO-1478 Pi(DS 4-9)W1-3 Sundry Approval detailing work to be WELLS2/149 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA "~ ALASKa, OIL AND GAS CONSERVATION COMIV,,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,~1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing L~ Time extension [] Change approved program [] Plugging [] Stimulate I~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 325' FSL, 643' FEL, Sec. 27, TllN, R15E, UM At top of productive interval 3594' FNL, 3774' FWL, Sec. 35, TllN, R15E, UM At effective depth At total depth 3893' FNL, 3942' FWL, Sec. 35, TllN, R15E, UM 5. Datum elevation (DF or KB) 52 ' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-9 feet 8. Permit number 76-30 9. APl number 50-- 029-20207 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 12050 feet 9113 feet Plugs (measured) Effective depth: measured true vertical 11957 feet 9042 feet Junk (measured) Casing Length Surface 80' Intermediate 2602' Production 11038' Liner 1264' Size 20" 13-3/8" 9-5/8" 7" Cemented 240 sx AS 5300 sx PF II 750 sx C1 'G' & 125 sx PF II 310 sx Measured depth 80' 2654' 11090' 12050' True Vertical depth 80' 2654' 8368' 9113' Perforation depth: measured 11670-11675'; 11687-11695' true vertical ; 11752-11792' ; 11807-11824' ; 11840-11865' RECEIVED JUN 2 1 1988 8806-8810'; 8820-8827 '; 8874-8907'; 8919-8933'; 8947-8968' Alaska 011 & Gas Cons. C0mm/ssl{: Tubing (size, grade and measured depth) Anchorage 5½", 17#, L-80, NPC tubing @ 10722' MD; 4~"~ , 12.6#, L-80 NPC tail @ 10815' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 10711.' MD; Camco Bal-0 SSSV @ 2164' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation May 1988 14. If proposal was verbally approved Name of approver Subsequent Work Beported on 1Corm No .... Dated /__/__ Date approved 15. I hereb..v certify that the f_oregoing is true and correct to the best of my knowledge Signed ¢1~ ¢,~ 2r~I~ Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness Approved by [] Plug integrity oRIGINAL SIGNEO BY [] BOP Test [] Location clearance Approved Copy Returned Date ~¢f~,.,, { ..... IAppr°va' N°' · Commissioner by order of ~_~(~ the commission Date ~' Form 10-403 Rev 124-85 WELLS2/149 J. C. Braden, 263-4536 Submit in triplicate(~, Drill Site 4-9i Selective Stimulation Procedure ARCO Alaska Inc., proposes to perform tjhe following stimulation treatment: 1. MIRU wireline unit. Log with CCL/GR from above the packer to below the perforations(10650' to 11900'MD). Make a 3.6" gauge ring run and record PBTD. 2. If fill is above 11865' MD then perform a FCO and replace the sump with brine. 3. Load 4000 gals. of 15% HCl acid and 4000 gals. of 12%HCl-3%HF acid. 4. Load 2000 gal 10% H202 (hydrogen peroxide) in a lined tank. 5. Load 10000 gal 2% NH4CI water. 6. MIRUOTU. 7. Before running in hole with CTU, pump the "set ball" through the CTU to make sure the unit is free of restrictions. 8. MIRU pump trucks. 9. RIH with tubing tail locater, Baker 7" inflatable packer and hydraulic disconnect. Use the log from Step 1 to correlate the depth. Locate the packer at 11800'MD. 10. Roll the 15% HCI compartment. 1 1. Pump the following fluids down the CT to clean the CT and the liner. a. 2000 gal. 15% HCI with additives, dispersed with 10% xylene b. 1000 gal. 2% NH4Cl water 12. 13. 14. Set the packer at 11800'MD (BHCS 5/2/86). Roll all acid compartments before pumping fluid downhole. Pump the following fluids through the CT: a. 1000 gal. b. 1000 gal. c. 1000 gal. d. e. 1000 gal. f. 2000 gal. g. 3000 gal. h. 1000 gal. i. 1000 gal. j. k. 1000 gal. I. 2000 gal. m. 4000 gal. 2% NH4CI water 10% H202. 2% NH4CI water. Let the H202 soak for 1 hour. 15% HCI with additives, dispersed with 10% xylene. 12% HCI - 3% HF with additives , dispersed with 10% xylene 2% NH4Cl water 10% H202 2% NH4CI water. Let the H202 soak for I hour. 15% HCl with additives, dispersed with 10% xylene 12% HCI - 3% HF with additives, dispersed with 10% xylene 2% NH4CI water Alaska Oil & Gas ~ns. commission Anchorage Drill Site 4-9 'Hydrogen Peroxide Procedure Page ?~ 15. Release the packer and POOH with CT. Displace CT with 25 bbl Methanol-water. 1 6. Resume water injection when CT is above the packer 1 7. Raise water injection to RIR. Record rate and wellhead pressure. 1 8. RD and release CTU, pump truck and transports ,5 4 2 COILED TUB~Ng UNIT BOP EOU ! PI,.ENT 1. 5000 PSi '7" W£LLHEAD CONNECTOR IrLAI~G£ 2. 5000 PSi 4 1/16" PiP[ RAMS 3. ~g)O0PSI4 1/6" HYORAULIC SLIPS 4. 5000 PSI,ii 1/6" SHEAR RAMS ,5.5000 PSI4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX N]REL]NE BOP EOU]PMENT 1. 5,000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5,000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 3. 5,000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK--DIrF Alaska Oil & Gas Cons. Commission t:' F. [';. F..', Y R t:; N N F T'f' Anchorage ¢~ 'T F/.- i ,:::.,,.'":, <3, .",.7 f'i. 1.4 ?..' r': 1.4 ."< f':.l.-I .'.7 f'". 1-4 :'," f": 1-4 :-.71": ,I--t ARCO Alaska, Inc. .~'-~ P.O. Box ~00360 Anchorage, Alaska 99510 DATE: June t~, ~?B? REFERENCE: ARCO Pressure Data 4-? 5/t6-t8/87 F'towin9 Gradient/Pressure Fat[ o f f Ca n~c o Please sign and return the attached copy as receipt of data. Received By_. NAVE A NICE DAY! Rosa~ne Peek A'l'{3--J~29 TRAN$ ¢87318 _~ ' .Approved _ R , D k_~Naska Oil & Gas Cons. Commission Anchorage ~:e¥1tra[ Fi [es Chevron Extension Exptoration · .-"' Ex xon .~ Hob i [ · ,,"" Phi LLip~ PB WeLL Fi l. es ~ Soh i o at, lot Ata~ka ARCO Alaska, Inc. P.O. Box t Anchorage, Atmskm 99510 DATE' June tO, t987 REFERENCE: ARCO Cased Hole Final 4-c) 5-.t8-87 GR/Temp Survey Run ~, 5' 5-t3 5-t~-.8'? CH CNL Run ~, 5' 6--~5 5-28-87 CET Run 2, 5' 7-~5 5-~5-87 CH CNL Run ~, 5' ~-~5 5-.~6-.87 CH CNL Run ~, 5' 3-98 5-~8-87 CH CNL-Epifherma[ Run 28, 5' ~3-98 5-38-87 CH CNL-Ther~,~a[ Run 28, 5' 3-98 5-38-87 CH DIL/EFL Run 28, 5" 4-7 5-~5-87 CH CNL Run ~, 5' Ca ¢ii~ 0 Dr es.~ Sch Dr es.,; Dress Sch $ch Sch Dress The GR/Ten~p log For' DS~ 4-9 is a corrected copy, 'the first log sent on transn~i+.tal ~87285 dated 6-4-87 was printed as' DS~ 9-4. F'lea~e sign and return the attached COPy at receipt of dat'a. Received By HAVE A NICE DAY! Rosanne Peek ATO-~52~ TRAN$ $87~e~ ..~ Approved ................... ,r Central. Fi Les .,,.'"' Chevron I) & M ~~ Exfens ion Exp loraf ion ~ Ex xon Marathon "~ Mob i [ · .-'" F'hi l l ip.~ PB Well Fi les R & D ~ $oh i o ~-,- State of Alaska ~ Texaco ARCO ALa.~ka, Inc, F:',.O. Box iO(.)S60 Anchorage, ALas'l,,a 995 ~ 0 DATE;* October Si I'~ I::. I" !:'. F~. E N C E ' A R C 0 '""" 4.-..9 7-9-86 'x,.~4..t :.-.2, 7-t t-86 ----' 4-25 7-3t-86 , 1 986 M a g n e 'f i (:: T a p e.s' w / I. i .s' t i n g Mag ~.'ape ECC:II:2476 C'N-MS Magi'ape ECC~:2475 {]N--MS Magtape ECC~:2509 CN.'--MS F:'Lea.s'e .'¢i9n and re't't.t~ tile a~'t'ached copy a.s' receip't' o'f' data, Recei ved Rosanne Peel< ~TO--t 529F T R A N e ~., ~:86689 1 S 1 E I B LIT I 0 N Cen'trat F'i Les' Chevron D & M Ex!'en.sion E:xpl. orat'ion Ex xon Mara ~:hon Mob i [ · ,,-'"' Phi !. Lip s F'B WeLl. F'i Lex R & D ~' Soh i o State of ALa'~ka Texaco ARCO ALaska, Inc, F'~O. Box i OOS60 Anchorage, ALaska 99510 DATE: ~S'ep'~ emb er ,..6, i 986 · REFERENCE · ARCO CaS'ed HoLe Final ~ S-..iO 9-i8-86 Step Rate Inj, F'rofi Le/GR Run t, ~4--'i 9--2t-86 F:'rc~duc:~ion F'rofi [e Run t, ~--4-9 9-.-1~-86 Temp, Log/Inj, Profi Le Run t, 5" ~4"9 9=t5-86 Inj, F'rofi Le R~n ~4-.t0 9-"t0-86 l'emP ~ Log Run t, 5' ~4--t 0 9-'t =' ~ . ~--86 Inj F'rof i le Run -- ~ 9-t t/t ,,..-.66 Sp inner/Iai, F:'rof i Le Run ~-t2 9-.tt/t2--.86 l'emp, Log Run 3, 5" ~9-..t 2 9-.i5-86 l'emp, Log Run t , 5' -- . 5" ~9-t7 9 it-86 Inj F'rofi [e Run t, ~9-..i7 9-tt-.86 l'emp, Log Run %9--2~ 9--.t2-86 Inj, F'rofi Le Run '~9-25~ ~-'2~-86 Inj F'rofi Le Run t ~ -it-2 9-t 4-86 .S'pinner/Temp, Survey Run i, 5" ~ti-.tO 9--2~/2t-.86 Spinner Log Run t ~t---tt 9-t3/t4-.86 .S'pinner/F'roduci'ion ProfiLe Run . 5" -~.t6.-.2 9-t5--86 'reap, Log Leak I)election Run C a (il C C) C a m c o C a m c o C a m c: 0 C 8 f~l C 0 C a m c o C 8 ~ c o C a m c: o C 8 f,! C: C) Camco C a m c: o Camco C a m c o Ca mc o C a fl) C: C) C a ~1C 0 F'l. ea.~e _.','Jgn and )"e/t~ th~..~'~'ach/4)d copy_,,~'¢ receipt of dat'a. HAVE A F~Jtr~: ~, / ~ Oil & Gas bui~mJ~iO~ Ro~ann~" ' / 'r~e~/ ~ch0rage ~To-~ 5~ TRAN$ ¢86597 I) I$1'RIBUI'ION T~ Cent'raL F'i LeK ,.'"'Chevron D &M ~-'"'Extension ExpLorat;ion ~ EX xon Marathon · ~ Mob i ~ · Ir. .,,.'"' F'hi L L ip.s F'B WeLL F'i Les R& D ~-. .S'oh i o ,. State of ALaska · .-"' Texaco Anchorage° _ REFERENCE: - --: ARCO Ca~ed Rote Final ~ - - ~4-t . 7-t0-86 Gamma Ray Log Run t, 5' ~4-9~?~'~-:' 7-9-86 CNL/GR HuLl i-Space Run t, 5' ~tt-t7. 6-29-86 _ ACBL/VDL/$IN/GR Run t, 5' . PLease sign' and return the attached-copy as receipt'"of-dat~.-' Rece i ved HAVE A'NICE DAY Linda Huice - ATO-J 529 TRAN$ Dress Dress Dress Dress Dress 1 5 198 Gas C,o,~. An~orage DISTRIBUTION Central FiLes -Ir Chevron "- - D&.H '"' 1""' Extension- Expiorat ion ~ - Exxorl.-- 1' Hara*hon ~ Hob i L 1' Phi LLips PB WeLL Fi Les R& D $oh i o._ ~ _ ..... Texaco AI-?C:O A I. a s' k a F'. O, Box A'nchorage, AL DATE' ..ja'nuary i6, i986 R E F: Iii: R E N C E · A R C 0 P r e _--:. _~: ~ r e ~..:, '~ a DS 4-'i S i C'-2-85 Surl"ace F're.~.'::.-ure Fa[[off ~-:u. rface F'res'~ure FaLtoff ,?urface F're:.~.~:ure t--al[off ARCO A R C 0 F'l. ea~:e ~ig'n a'nd 'retu'r'r., '~he attached cop'::' a~ 'Feceipt' of data~ F;,'ecei red By ' ~ '"' :" - I :",~-!,,E. A N CE D I i.: T R i B U T I 0 N Cons. Commission Phi I. Lip.?. t::' B W e L L -"' F;.: & D -~ . Sohio State c,f Te×acc, F:'i Le~ A L a .'.=:: 1< a ARCO Alaska, Inc. Post Office Bo~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-9 Dear Mr. Chatterton: Enclosed is a copy of the DS 4-9 Workover with the Well Completion Report, dated If you have any questions, please call Sincerely, · Gruber Associate Engineer JG/tw GRU11/L77 Enclosure cc: DS 4-9 Well File Well Hi story to 7/1/85. me at 263-4944. include ECEI VED S£P £ $ ,1~t85 Alaska 0ii & ~as Corr Anchorag~~' Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~dGae Company '~' Well History- Initial Report - Dally I~~/Prep'are and ~bmit the "l"ltiM ReI~' on the first Wednesd,~y after a well Is spudded or workover operations ere alerted. Daily work prior to N~udding should be au~merized bn the form giving inclusive dates only. Prudhoe Bay Auth, or W.O. no. AFE 403351 Nabors 1-ES APl 50-02g~//~t~ Diet~ot i Coun~/. pa~;ih or borough I Stets Alaska North Slope Borough Field ILeaae or Unit ADL 2832,4 J TItle Recompletion Operator ARCO Alaska, Inc. Spudded or W.O. begun Ioate IHOur W. orkover 5 / 11 / 85 Date and-depth Complete record for each day reporte;] aa of 8:00. a.m. 5/11/85 thru 5113185 5114185 Alaska IWell no. DS 4-9 IARCO W.I, 21.66% Prior status If a W.O. 5115185 5/16/85 5/17/85 5/t8/85 thru 5/20/85 RECEIVED SEP 2 5 19t 5 Alaska For ~orm ~m~rati~ ~d dlatri~utlo~ ~e Proceduffis Manual, Section 10, Drilling, Pages 86 and 87. 1900 hrs. 7" @ 12,050' 11,973' PBTD, ctrc well 9.1NaC1 RIH w/3½" OD tbg cutter w/o rig, tag up on fill @ 10,712', make cut @ 10,711'. RIH aft making cut, could not get into lnr. Appears fsh stopped Just inside TOL, POH, RD Schl, set BPV. Accept ri; @ 1900 hrs, 5/11/85. Kill well w/250 bbls brine & 100 bbls 10.8 ppg kill pill, circ around. ND tree,'NU & tst BOPE. RIH w/spear, shear off BOT PBR, BO spear, BO hgr & LD same. RU Otis & Weatherford, POH, LD 5½" tbg. RU & rev circ well. 7" @ 12,050' 11,973' PBTD, RIH, PU 3½" DP 9.1NaC1 Circ hole vol to level out brine wt, cont POOH, LD 5½" tbg. Chg pipe rams to 3½" & tst. RIH w/3½" DP. 7" @ 12,050' 11,973' PBTD, Circ gas bubble f/pkr RIH W/fsh'g tls, tag fsh @ 10,555' DPM, rotate K-anchor free, circ gas bubble to surf, POH w/PBR bbl & K-Anchor, LD same. PU PRT/JB; TIH to 10,600' DPM, mill over pkr assy, circ hole vol thru choke manifold. 7" @ 12,050' 11,973' PBTD, RIH w/bit/csg scrpr Circ gas bubble f/below pkr, POH w/o fsh. PU spear, RIH, spear into pkr @ 10,646' DPM, POH & LD pkr & fsh'g tls. RIH w/JB/csg scrprs. 7" @ 12,050' 11,973' PBTD, RIH w/3-1/4V spear Fin RIH w/bit & scrprs, tag bridge @ 10,717', wsh to 10,730', RIH to 10,790', CBU, POOH. PU Tri-State spear, tag fsh @ 10,795', POOH; no rec'y. PU spear & RIH. 7" @ 12,050' 11,957' PBTD, POOH, LD DP RIH w/spear, tag fsh @ 11,902' DPM, att to wrk spear into fsh w/o success, POOH. RU DA, rn GR/CCL, tag fsh @ 11,850' WLM (previous logging depths ±50' shallower than actual depths), POOH. RIH w/wsh pipe, rm thru perfs 11,865'-11,872', wsh over fsh, tag LC @ 11,958', circ to cln hole, POOH, rec'd fsh. Rn JB to 11,958', circ to cln hole, POOH. RIH w/RTTS, set @ 10,750', tst 9-3/8" x 3-1/2" ann to 2000 psi; OK, POOH & LD DP. IDate I Title 6/28/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well HistOry-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wetl is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District I County or Parish State Alaska I North Slope Borough Alaska Prudhoe Bay ADL 28324 Auth. or W.O. no. ~Title AFE 403351 I Recompletion Nabors 1-ES API $0-029-~ Operator A.R.Co. W.I. ITotal number of wells '('active or inactive) on this Icost center prior to plugging and _A~CO Alaska, Inc. ?.1 . 66% labandonment of this well Spudded or W.O. begun Date IHour Prior status if a W,O, Workover 5 / 11/85 I 1900 hrs Date and depth Complete record for each day reported as of 8:00 a.m. 5/21/85 5/22/85 7" @ 12,050' 11,957' PBTD, Prep to rn tbg POOH, LD RTTS; left btm centralizing bar in hole. Chg btm rams to 5½", tst to 5000 psi. RU Schl, rn 8.4" gage ring/JB to TOL, rec'd centralizing bar in JB. TIH w/5.9" gage rin~/JB, tag bridge @ 11,650', POOH, tl stuck @ 11,450'. Pull tl free, POOH. RIH w/3-3/8" sinker bars to LC @ 11,956' WLM, POOH, RD Schl. RU & begin rn'g tbg; encountered excessive torque. Pull tbg & prep new 5½" tbg string. 7" @ 12,050' 11,957' PBTD, Wait on wing vlv Rn 206 jts, 5½", 17#, L-80 AB-Mod tbg to 10,815'. Lnd tbg. Set BPV. ND BOP, NU & tst tree~ Pull BPV. Wing vlv on tree would not close. SSSV @ 2164' - 3-H Perm Pkr @ 10,711' - TT @ 10,815' 7" @ 12,050' 11,957' PBTD, RR Repl ~ing vlv on tree & tst to 5000 psi. Displ well w/8.6 NaC1 w/lO0 bbls diesel in ann. Set pkr & tst same. Tst ann to 750 psi. Set BPV. NU tree & tst. RR @ 1630 hrs, 5/22/85. 5/23/85 Old TD I NewTD PB Depth 11,957 ' PBTD Released rigI Date ~ K nd of rig 1630 hrs. 5/22/85 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing J Prudhoe Bay Potential test data Well no. Date R .... oir I:~lu~'flg~l'heJ,,~al) % # I.=, O,~il o r gas Test time Production Oil on test Gas per day _ Pump size, SPM X length Choke size T.P. C.P~ ~ ~e~/o~ GOR Gravity Allowable Effective date corrected Alaska Iii & ~as Co~s. Con,]mission Ar chorale The above is correct For form preparation and di~ribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 12, 1985 Reference: ARCO CH Finals 4~9 Tubing Cutter 5-10-85 Run 1 5" Sch 4-13 Tubing Puncher 5-24-85 1 5" Sch Pam Lambert ATO 1429C Trans 315 Please sign as receipt of data. Received by .... Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Texaco Mobil ARCO Alaska, Inc, ia a Sul~sicliar¥ of AtlanticRichfieldComDany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: August 23, 1985 Reference: ARCO CH Finals 1-9' Spinner ,3-2' Spinner 3-4-*~ Spinner ~4-9~ Spinner 5-17-85 Run 1 5" GO 8-17-85 1 5" Camco 8-17-85 i 5" Camco 8-17-85 1 5" Camco 8-19-85 1 5" Camco Please sign as Received by Pam Lambert ATO 1429C Trans 286 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mob i 1 Phillips PB Well Files R&D Sohio State of Alaska Texa co ARCO Alaska. Inc. ARCO Alaska, Inc. ' Prudhoe Bay ~-.gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 23, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-9 Permit No. 76-30 Enclosed is the Subsequent Sundry Notice for work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:pr Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 4-9)W4-3 AI~s~<~ 0ii & 6as Cons. Com~ss~°n Anchorage ARCO Alaska, Inc, Is a Subsidiary of AtlanflcRIchfleldCompany STATE OF ALASKA ALASKA (JIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND-REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 325' FSL 643' FEL, Sec. 27, TllN, R15E, UM TD: 3893' FNL, 3942' FWL, Sec. 35, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 52' PAD 19 5' · · 6. Lease Designation and Serial No. ADL 28324 7. Permit No. 76-30 8. APl Number 50-- 029-20207 9, Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.$. 4-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations {Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began re-perforating operation on 6-28-85· RU perforating unit and pressure tested equipment. RIH with gun #1, shot interval 11840' - 11865' MD (6SPF). Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 11807' - 11824' MD (6SPF). Shut in well, POOH, all shots fired. Secured well, RD. JUL 2! 9 1~9B5 AlasKa Oil & Gas Cons. commission Anchorage Ref: BHCS 5-2-76 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. -- ~--~~~.~1~~ Title Regional Operations Engineer Signed The space below for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-9 Dear Mr. Chatterton: Enclosed is the Well Completion Report for DS 4-9. I have not yet received a copy of the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L45 Enclosure RECEIVED J U L 0 8 1985 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ' ALASKA~', .~ AND GAS CONSERVATION CO~'X~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REC0MPLET I ON OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICERS] ~/ATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 76-30 , · 3, Address 8. APl Number P, 0, Box 100360, Anchorage, AK 99510-0360 50- 029-20207 4. Location of well at surface 9. Unit or Lease Name 325' FSL, 643' FEL, 5ec.27, TllN, R15E, UN Prudhoe Bay Unit At Top Producing Interval i0. Well Number 3594' FNL, 3774' FWL, Sec.35, TllN, R15E, UM 4-9 At Total Depth 11. Field and Pool 3893' FNL, 3942' FWL, 5ec.35, T11N, ELSE, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 52' RKB ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 03/21/76 05/03/76 05/11/76* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.P!ug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 12050'MD,9113'TVD l1957'MD,9041'TVD YES r~x NO [] 2164 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run DIL/BHC/Sonic/GR, FDC/CNL/GR, Ca1, Gyro, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 80' 32" 240 sx AS (approx) 13-3/8" 72.0# · MN-80 Surf 2654' 17-1/2" 5300 sx PF II · 9-5/8" 47.0# MN-80 & Surf 11090' 12-1/4" 750 sx Class G & 125 s~ PF II s00-95 ~ ~ 7" 29,0# L-80 1.0786' 1205Q' 8-1/2" 310 sx 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) 11,670' - 11,675' 5-1/2" 10~815' 10,711 ' 11,687' - 11,695' 11,752' - 11,792' w/4 spf 26. AClD, FRACTURE, CEMENTSOUEEZE, ETC. 11,807' - 11,824' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11,840' - 11,865' N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 1977 Flowing Date of Test Hours Tested' PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/24/77 4.1 TEST PERIOD I1~ 1152.7 708.7 0 36° 83/641 615 _ Flow Tubing Casing Pressure CALCULATED, I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1035 0 24-HOUR RATE -~ 6748 4149 0 27.0 28. CORE DATA ,, Brief description OfNone lithology, Porosity, fractures, apparent dips and presence of.. °il' gas °r water' Submit ~rL~P~sE IVED JUL 0 8 Alaska 0il & Gas Cons. Commission Anchorage Form 10407 Rev. 7-1-80 NOTE: The well was recompleted as an injection well on 05/22/85. GRU10/WC03Submit in duplicate CONTINUED ON REVERSE SIDE 29. 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. Top Sadl erochi t ~ 1,460' 8633' N/A Base Sadl erochi t 11,8.70' 8969' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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- lng 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". ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1A-3 1A-4 DS 4-9 DS 9-16 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUlO/L37 Enclosures &laf:'.i'~ Almmka. In,~_ is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ..--~ ALASKA~'~L AN D GAS CONSERVATION C iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ WATER INJECTOR OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, AnChorage, AK 99510 4. Location of Well Surface: 325' FSL, 643' FEL' Sec.27, T11N, R15E, UM 7. Permit No. 76-30 8. APl Number 50-- 029-20207 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 52' I ADL 28324 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made []. Other Pull Tubing [] Other []' Pulling Tubing "~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). RU Schlumberger. Chg out top tree flange. wel 1. RIH w/3-1/2" OD tubing cutter and made cut ~ 10,711'. Secured Accepted rig 8 1900 hrs, 05/11/85. Killed well. Set BPV. ND tree. NU BOPE & tstd - ok. Pulled 5-1/2" tubing. Milled over pkr assy. Speared into pkr ~ lO,646'DPM & POH w/fish (pkr & tailpipe). Ran GR/CC1. Tagged fish 8 11,850'. Reamed through Perforations. Washed over fish. POH w/fish. Tstd 9-5/8" csg to 2000k psi - ok. Ran 5-1/2" completion assy W/tail ~ 10,815' pkr @ 10,711' & SSSV @ 2164'. ND BOPE. NU tree & tst~ to 5000 psi - ok. Set pkr. Secured well & released rig ~ 1630 hrs, 05/22/85. RECEIVED JUL 0 ]985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ) Title As:cc',' ~te. Enginccr The space belo~tfor Commission use Conditions of APproval, if any: Approved by COMM ISS ION. ER Form 10--403 GRU9/SN10 By Order of the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 18, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 4-9 DS 4-13 Permit No. 76-30 Permit N°. 78-31 Attached are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFs/jEB/dh Attachments cc: Sohio Petroleum File Pi(DS 4-9)Wl-3 File PI(DS 4-13)W1-3 RECEIVED JUN 2- 1.985 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ~'-~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L L:x~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 325' FSL 643' FEL, Sec. 27, TllN, R15E, UM TD: 3893' FNL, 3942' FWL, Sec. 35, TllN, R15E, UM 7. Permit No. 76--30 8. APl Number 50- 029-20207 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 4-9 1 1. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool RKB 52', PAD 19.5~ I ADL 28324 12. Check Appropriate 8ox To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate Well 4-9 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation intervals: 11840'-11865' MD (25') 11807'-11824~' MD (17') 11752'-11792' MD (40') Ref: BHCS 5-2-76 (re-perf) (re-perf) (re-perf) RECEIVED JUN 2 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~~' '~ 0 I~-~', Title Regional Operations Engineer Signed / The space below for Commission use Conditions of Approval, if any: Approved by / ORiG:NAL BY H~RRY W. KIIGLEI Ap~roved By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. /--~ Post Office Bo=~ 3360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the following wells' 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L56 Enclosures RECEIVED JUN 1 4,1985 A!~ska 0il & Gas Cons. C0mmissJon Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlanticRIchfleldCompany ' ' ~ STATE OF ALASKA ~ ALASKA ~,,L AND GAS CONSERVATION CO,,,,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation)[~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 76-30 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20207 325' 4. Location of Well at surface FSL, 643' FEL, Sec.27, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 52' RKB 9. Unit or Lease Name Prudhoe Bay Unit 6. Lease Designation and Serial No. ADL 28324 10. Well No. 4-9 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of May ,19 . 85 12. Dept~at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1900 hfs, 05/11/85, Killed well. ND tree, NU BOPE & tstd, Pulled 5-1/2" tubing. Milled over pkr. Ran GR/CCL & tagged fish ~ 11,850'WLM. Recovered pkr. Tstd 9-5/8" csg to 2000 psi - ok. Ran 5-1/2" completion assy w/tail ~ 10,815', pkr ~ 10,711', & SSSV ~ 2164'. ND BOPE. NU tree & tstd. Set pkr. Secured well & RR ~ 1630 hfs, 5/22/85. 13. Casing or iner rgn and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run GR/CCL - depths are not available at this time. . . .. 1.6. 'DST-data, perforating data, shows of'H2S, miscellaneous data N/A" j u N _t 4 :[9 5 0il &' Gas Cons. C0mil~issl0 Anch0ra.qa 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-Report l~j/n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Cor~servation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR61 Submit in duplicate ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510 Teiel~l',one 907 276 1215 Date: June 11, 1985 Reference: ARCO CH Finals' ~ 1'18~. Collar Log ,- 5-20-85 "-2-13/J Neutron GR 5-12-85 ---3-9 '/~ Neutron GR ~ 5-15-85 ~ 4~_9~.,~Z/' Gamma Ray~ 5-17-85 ...... 6-~-'/-~ C ET 3-7-85 ~--- 6=~0 / Neutron GR 5-10-85 ~6-24/~.Neutron GR 5-18-85 ~ 7-26 //Neutron GR 5-16-85 ~12-21 ~Spinner 5-15/16-85 ~12-22 ~ Co,ar L~ 5-20-85 ~12-22 / Spinner ' . 5-21-85 ~12-25 /Temp. Log .' 5-22-85 ~2-25 / Spinner / 5-18-85 ~12-28 /Spinner ~, 5-17/18-85 ~ 12-29 / Spinner 5-16/17-85 14-15/Neutron GR ~. 5-11-85 14-35~ Neutron GR 5-11-85 ~15-9 CBL - 11-8-84 Run i 5" Camco 1 5" DA 2 5" DA 1 5" DA I 5" Sch 1 5" DA 1 5" DA 1 5" DA 1 5" Camco 1 5" Camco i 5" Camco i 5" Camco 1 5" Camco I 5" Camco I 5" Camco 1 5" DA 1 5" DA 1 5" Sch PleaSe sign as reciept of data. Received by //~ / Pam Lambert ATO 1429C Trans 148 CheVron D & M " 'i~i.tlips Expl.. Services PB ~ell tiles Ex~. Explora~£on R & D Exxon. Sohio Marathon Sl:al~~'~ of ALaska- ~o b i 1 -.l~csc o STATE OF ALASKA '"' ALASKA (JtL AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WE LLX[~] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.' 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 325' FSL, 643' FEL, Sec.27, TllN, R15E, UN TD: 3893' FNL, 3942' FWL, Sec.35, TllN, R15E, UM 7. Permit No. 76-30 8. APl Number 50- 029-20207 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number #-9 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 52', PAD 19.5' I ADL 28324 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ]~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe ProPosed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date ofstarting any proposed work, for Abandonmentseea0 AAC 25.105-170). ARCO Alaska, Inc., proposes to perform a 'workover on 4-9 in early April, 1985. in the following manner: 1. MIRU workover rig. 2. Kill well. 3. ND tree. NU BOP stack and test. 4. Pull 5-1/2" completion assembly. Alaska 0il & Gas Oons. 5. Clean out to BPTD. --.,Anch0rage 6. Perforate additional Sadlerochit zones to increased water injection capacity. 7. Recomplete well as a single selective (Straddle-Pack) completion w/5-1/2", 17#, IPC tubing. 8. Secure well,and release rig. The workover will be executed RECEIVED o 1 19C5 OTHER Approved Cope/ Returned By Order of Approved by BT [0NNI£ C, S~I~ COMMISSIONER the Commission Date Form 10-403 I~,, -/_1 _~'~ (GLA) $N/017 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate A subsequent sundry will be submitted following the completion of this workover detailing the added perforation intervals and completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within permafrost intervals. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. N'OtE: This workover will convert subject well from a producing well to a water 'in 14. I hereby certify that the foregoing is true and correct to ~"~ ~es~o~ g~ ~n~;d~e~ ' Signed ~~~~~~~ Title A~ea Dr,~],ne Eno, nee~ Date ~ond~' of ~proval, ~an~: ARCO Alaska, Inc. .,"~ ., Post Office B~. ~60 Anchora§e, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska~ Alaska Oil & Gas Conservation Commission 3001 PorcUpine Dri.ve Anchorage, AK 99501. SUBJECT- State Reports Dear Mr. Chatterton- Enclosed are monthly reports for June on these drill sites' 2-24 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13-26 1H-8 14-15 Also enclosed is a well completion report for Kuparuk 1E-12, and subsequent sundry reports for' 3-14 14-6 ~9 15-3 4-15 Eileen No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG:llm Enclosures J U L 1 2 ],982 Alaska 0il & Gas Cons. Comrnissior~ Anchorage GRU1/L48 ARCO Alaska. Inc. is a subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ~'~ ALASKa, JIL AND GAS CONSERVATION C,.,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 3. Address P_ O~ Box 360~ Anchorage, AK 99510 4. Location of Well 325'N, 643'E of SE ct, Sec. 27, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 12. I 6. Lease Designation and Serial No. ADL 283~4 7. Permit No. 76-30 8. APl Number 50-- 029-20207 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-9 (33-35-11-15) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The proposed Work described in our Sundry Notice, dated 09/22/81, has not been performed. Also, the work is not scheduled to be done in the immediate future. RECEIVED J U L 1 2 1982 Oil & Gas Cons. Commission Anchorage 14. I hereby c_~.e,~tify that the fore~going is true and correct to the best of my knowledge. Signed Title Area Dri l 1 i ng Engi neet The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 GRU1/S2 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas/,~,qmpany North Alask _~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 8, 1981 Reference:ARCO Cased Hole Finals D.S.2-17 ~__1/21/81 D S 7-4/~0/81 D S 14-4 ~'8/29/81 DoS.1-4-16~.-~8/31/81 D.s 13-6/9/5/Sl D.S.11-1 9/5/81 CCL/Set Bridge Plug/Circulation Gun Spinner c~/~ CNL/GR ACBL/VDL/GR CNL CNL Run 4 Run 1 Run 1 Run 1 Run 1 Run 1 5v, 5" 5" 5" 5" 5" 5"5" '~e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal#639 DISTRiBUTiON NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company ~s a Division of AtlanticRichfieldCompany EXXON MOBIL GETTY MARATHON ~,e ~ u ~oi : ~ CH~VRON~ka ~ & ~as ~o~s, Gomm~l~ Anchorage ARCO Alaska, Inc. ,~'--~ Post Office B~ · 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 29, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 15-10 State No. 1 Dear Sir: Enclosed please find the Sundry Notice of Intent for the following wells: DS 15-10, East Bay State No. 1, DS 4-9. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GA:sp Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 76-30 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5o-029-20207 4. Location of Well 325'N & 643'E of SE cr Sec 27, TllN, R15E, UH 5. Elevation in feet (indicate KB, DF, etc.) 19.5 Pad, 52' RKB 12. I 6. Lease Designation and Serial No. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-9 (33-35-11-15) 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing ['-J Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well X~X Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to repair leaks in the 5½" tubing and a possible leak in the 9-5/8" production casing. A cast iron bridge plug has been set in the tubing tailpipe. The 5½" tubing above the packer will be pulled. The 9-5/8" casing will be checked for leaks then repaired if necessary. New plastic coated 5½" tubing will then be run. 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week and operationally tested each trip. Necessary provisions for subsurface safety equipment will be rerun. A nonfreezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. Well will be flowed to production facilities during testing. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start: 10/29/81 RECEIVED SEP 0 198] on Fo~m No. i 0-~,0~ Dated ~_/-~-~? Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: Please not~fy tt~s off±ce so ~t a ~e~~e' ~ ~ess ~ ~es~e co~ol and SSV ~sts. ~pmv~ C~y Approvedby :: ,,~,~ . ..... COMMISSIONER ~e%r~Lqfss, Date ti 'j ~. .... Form 10~03 '' ~mq:~[ ~ ~lJ~ Submit "Intentions" in T'ri~l~f6 Rev. 7-1 ~0 and "Subsequent Reports" in Duplicate ARCO Oil and Gas .~.~ompany Of,~c= ~,.,,x 360 POS~ ~ ~ Anchorage, Alaska 99510 Telephone 907 277 5637 July 25, 1980 Reference: ARCO Magnetic Tapes D.S. 1-14 5/15/80 Tape #60517 5/21/80 Tape #60522 2/3/80 Tape #60234 5/19/80 Tape #60524 gn and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #484 North Geology R&D Drilling Eng. ~anager D&M Geology State of Alaska ./2 DISTRIBUTION Mobil GettF Phillips Sohio Ma:athon ~le~on ARCO Oil and Gas Company rs 1 O~vis,on of Atlanl~c~chheldCompany ARCO Oil and Gas Company Post Offi box 3,30 Anchorages-Alaska 99510 Te!ephone 907 277 .5-637 June 20, 1980 Reference: ARCO Cased Hole Logs D.S. 1-8 5/14/80 D.S. 2-3 6/1/80 D.S. 2-6 5/30/80 D.S. 2-10 5/31/80 ~10/3/78 CNL 5" Caliper Run 1 5" " Run 1 5" CaZiper Run 1 5" .;;.Fluid Density Run 1 5" ._ Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #409 R F_ [! i',./¢' DISTRIBLr~ION North GeOlogy Exxon R & D Mobil Drilling ., Getty Eng. M~ager Phillips D & M Sohio Geology Marathon State of ~aska ~e~on ARCO Oil and Gas Company ,s :l Division of AtlanlicRichfieldCompany AR. CO Oil and Gas,~'"mpany Ai~sk~ Post Office Bc, x 7,$0 Ancho. rage. ~iaska 93510 Telephone 90',' 277 5537 April 3, 1980 Reference: .ARCO Pressure Surveys p.s. 4-1 9/z-3/79 D.S. 4-5 11/7-8/79 9/18/79 3/1~./80 Canlco Camco Dresser Atlas /Please sign return cop)' as receipt and the attached of data. K.' j. Sahlstrom North Engineering TRANSMIT£AL # 254 DISTRIBL~ION North Geology Ih'illing Eng. ~k~nager Geology State o£Ataska blobil Getty Phillips Sohio ~Iarathon O~e~on March 28, 1980 Reference' ARCO Cased Hole Logs · D.S. 1-11 7/4/78 Spinner Run 1 5" D.S. 1-12 7/11/78 Continuous Flow Run 2 5" D.S. 2-11 7/1/78 " " RUn I 5" 6/21/78 " " Run ] 5" 10/4/78 Continuous Flow Run 1 5" 10/3/78 Differential Temp Run 1 5" D S. 7-12 1/29/80 Spinner S" '~~Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL # 239 DISTRIBLrFION North Geology F~x~x o n R & D Hobil Drilling Getty Eng. Manager Phillips D & FI Sohio Geo/ogy Harathon State of Alaska O~evron Posl Ollic,', Bo',' 3.50 Te~pi~o~:e b.., 277 5637 February 22, 1980 Reference' E~closed are Cased Hole Logs for the following ARCO wells' D.S. 2-S 1/20/80 C qL mm 3 D.S. 2-9 1/20/80 " Run I 5" D.S. 4-3 1/30/80 ONL Run 2 5" 1/23/80 Fluid Density Run ]. 5" 2/5/80 CNL Run 2 5" D.S. 5-3 1/22/80 " ~ Run 3 5" D.S. 7~8 1/21/80 " R~m 2 5" D.S'. 7-10 1/20/80 CNL Rm~ 2 5" o... ///~ease sign a~id return [l~e attac}xed copy as receipt c/ of data. K. J. SahlstrOm North Engineering TRf~xlS~IITTAL # 111 DISTRIBLTION North Geology E.x~on R & D Hobil Drilling Getty Eng. Manager Phillips D & H Sohio Geology ' Marathon State of Alaska O~ewron ARCO Oil ..~ r',d (';,a ~ Co,"-p.]nt, i'.i, ,~ Oi,,ti.~ion O! Allanlic qi'_.ht~_eldCompan¥ 307 277 5~;37 November 27, 1979 Reference' Enclosed are Cased Hole Logs for the following ARCO wells: D.S, 1-6 7/7/78 Spinner Survey Run 1 5" D.S. i-.7 10/.21/79 Temperature Run 1 5': D.S. 3--6 5/21/79 Flowmeter 5" · ~- 3/23/79 Epilog 5" ~ 9/2.6/78 Differential Temperature 5" p/~lease sign and return the attached copy as receipt of data. K. J,. SMdstrom North Engineering TP~-~\'S~ II TTA!, ~ 492 DISTRIBUI'ION North Geology t-kxon Drilling blobi] Eng. Manager Getty R & D Sol~io Ge°l°gy bh rathon State of Alaska t~hi].].ips D & M Chevron North Alask'..a_ DiMFJc! Posl Offic ,x 330 Anchora.qe ska 93510 Telephone 907 277 5637 September 25, 1979 Reference' FILF: j Enclosed are Pressure reports fo}' the followi~g ARCO" wells' D.S, 7-4 6/27-28/79 24 Fir ~LP Analysis D.S. 7-5 ~ 6/24-26/79 ,, " D.S. 7-7,-'/ 7/1-2/79 " D.S. 7-8 / 6/29-30/79. " D.S. 7-9 v/ 7/14-15/79 " D.S. 7-10/ 7/16-17/79 " D.S. 9~1'2~/5/11/79 Pressure Data D.S, 4-9~;: 9/6/79 " D.S. 13-4~/ 8/16/79 Pressure Buildup se sign and return the attached copy as r~ceipt ata. C8~1co Otis Gearhart-~ven Dresser Atlas Very truly yours, K. J. Sahlstrom North Engineering 363 · ichfieldCompany Norlh Ameri(~Pl'oducing Division North Alask,~ ,trict Post Office B~x 360 Anchorage, Alaska 99510 TelePhone 907 277 5637 December 1, 1978 State of Alaska Attn: Mr. Hoyle Hamilton 3001 Porcupine Drive Anchorage, Alaska 99501 Dear'Sir: In regards to your request for delinquent reservoir surveilance data, our records indicate the following: . . - Wells #3-3, 3~4. 3-6, 4-1, 4-6 5-16', and 9-4~ per your dates, indicate thai they are Initial Static Surveys where they were shut-in for less than 12 hours and no stabilized flow rates are available. - Copies of surveys for D.S. #9-6 and #1-6 have been sent on ll'28-76~,and should reach your attention . ~ shortly. D.Sf"#5-8.was sent out earlier this year and a copy will beX~A~t with this letter for your information. If further information is needed, please do not hesitate to request it from us. Very..truly yours, J.. A. Rochon District Engineer ral:JR HKVP / /~, t:'/t"' ~AtlanticRichfieldCompany North American Producing Division . Alaska Re gi/~,, Post Office ~..< 360 Anchorage, A~aska 99510 Telephone 907 277 5637 Referehce: Enclosed are the following logs: ~ Continuous Flow 5" D.S. tt7-1 CBL/VDL 5" D.S. #7-1 CNL/GR 5" D.S. tt7-1 CNL 2" & 5" together · D.S. ttl-4 Gamma Ray Neutron 5" Long Spacing D.S. ttl-4 Gamma Ray Neutron 5" Short Spacing D.S. tt3-5 Production Log 5" NGI #10 Production Log 5" Run 2 NGI #10 Production Log ,j~- 2" Run 1 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL 11447 DMsi0n 0f 0il ~1~ 8.~.~,~msorvation AtlanticRichfieldCompan y North American Producing Division Alaska R e,'--m Post Office .,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 16, 19T8 CONFIDENTIAL DISTRIB'UTED TO: STATE OF ALASJ,T,T~k DI\.'[SiON OF OIL & GAS Reference: Enclosed is a 5" Collar Log for D.S. #4-1~. Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #415 AtlanticR{chfieldCompany . North Ame~,~n Producing Division North Alas, 0istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-1 DS 4-2 DS 4-3 DS 4-4 DS 4-5 DS 4-6 DS 4-7 Permit No. 70-42 Permit No. 70-63 Permit No.. 71- 5 Permit No. 71-11 Permit No. 71-25 Permit No. 76-83 Permit No. 75-77 Permit No. 76-10 Permit No. 76-30 Permit No. 76-42 Dear Sir: .~ '~ Enclosed please find a Completion Report/~for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB:lr Attachments RECEIVED '-, C' l..'o.m P-- 7 - ! SUBMIT IN DL ._ );ATE* STATE OF ALASKA ( see other Ill- st ructions on reverse side,~ OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* I.. TYPE OF WELL: OII, ~] ~AS [] W ELI. 1¥ ELL DR Y Other b. TYPE OF COMPLETION: NEW ~1OVERWORK ~ENDEEP' ~ BAcKPLUG ~ DIF~.gESVR. ~ otherPerfOrated WELL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe, Alaska 99510 4, I,OC,*TION OF WELL [Report location c[6arly and in accordance with any State requirements)* At surface 325'N & 643'W of SE cr Sec 27, TllN-R15E, UM At top prod. interval reported below 3594'S & 3774'E of NW cr Sec 35, TllN-R15E, UM At total depth 3893'S & 3942'E of NW cr Sec 35, TllN-R15E, UM 5. API NLrNiFAIlCAJL CODE 50-029-20207 6. I.V,&SE DESIGNATION AND SERIAL NO. APL 28324 7. IF INDIA2q, ALLO'rr~:E OR TRIBE NAME 8. UNIT,FA3LNI OR LEASE NAME Prudhoe Bay Unit 9. WE~L NO. DS 4-9 (33-35-11-15) L Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 35, TllN-R15E, Um 12. PERA, IIT ~0. 76-30 I I 5-11-76 4-- t) 3-21-76 5-3-76 ' /29/7 19.5'Pad elev 52'~KB · ' 9 PLUG B3LCK MD & TV~,p. IF 1VIULT ;Jit'LE COM~L. ] 21. -,NTER~ALS-DRILLED BY BI E TO0, S 18. TOTAL DE.H, N~ & TVD~ .:. , HOW ~Y* ROTARY TOOLS [ CA .... 12,050'MD, 9113'TVD [11,973'MD, 9052',~VD Sinqle I Ail 23 WAS D~RE~IONAL~. PRODUCING !N~VAL(S), OF ~IS COM~TIO~TOP, BOSOM, NAME (~ AND ~)* , · ~ SURVEY MADE Top Sadlerochit ll,460'MD, 8633'TVD Base Sadlerochit ll,870'MD, 8969'TVD . 24. T~E E~CTHIC AND OTH~ LOGS RUN Din, BHC/Son~c/q~t FD~CNL/GR and Cal%D¢~ CAS~G RE. RD (Report all strings set iii weld CASI24G SIZE 20' 13-3/8" 9-5/8" 26. S!Z~ 7" 194# Vetco/ H-ao'I' Rtl' . ' I 37" , 2~n :v Arc~t_ic..qot. [729 Butt IMN-80I 265.4' [17-1/2q 5366 ~ PF II am~ [47~ Bute IMN-80I 11.090' [12-1'/4't 750 s~ c]a~. a } ~S00-9~ - ' I 2pd sta" W/125 ~x PPI TT 27. TUBING LINE~ TOP (A~D) BOTTO}~ (5~D) ;ACKS SC}%E~ (5{D) SIZE DEP~ SET (MD) PACKER SET 28. PERORATIONS 11,670'-11,675' 11,687'-11,695' 11,752'-11,792' 11,807'-11,824 (interval, size and number) 11,~40'-11,865' w/~ shots per ft 29. ACID, SilOT, FiI~CTURE, D-------------------~I~Ii INTEI%VAL (MD) AMOUN£ ;~ND 30. PRODUCTION ' ~' I PI%ODUCTION ME'I'I{OD (Flowi~g, ga3 lifC, pumping--size and type of pump) IV/ELL STATUS (Producing or DATE FIRST Pf~ODUC~ON snuL-in) OCt 1977 t [ Flowing ,~, i proa,,oi DATE OF TEST, HOUES TEST~ ' iCI-tOKE SiZE ''~~D'N PO.~ OI~B~L. "~A~CF. WATE~BBL. ]GX~2OiL 9/24/77, t 4.1 B6° ~3/6~ .... ~' o~c~, ~.~, ,oms~w~-~ (CO~.) I r~K. ~ I~-~OUR R~ I0 I '1 I I 0, ..27'° ~1. DISPOSITION OK GAS (80~d used ~or 7uel, vented, etc.) [TEST Reinjected t Production Operations a2. Li8~ o~ ATTACHMENTS 33. I hereby~~ ~]~certtfy that t~.~and attached information is complete and correct as determined from all-available records *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS Generel: This form is designed for submitting e complete ~nd correct well completion report end log on ell types of I~nJs end leeses irt Al~ske. Item: 16: Indicate which elevation is used Ds reference (where not otherwise shown) for depth meesure- ments given in clher sp~ces on this form ~nd in eny ~ttachments. Items 20, and 22:: If this well is completed for sep~ratc, production from more than one interv,~l zone (multiple completion), so stere in item 20, ~nd in item 22 show the p,c. Jucing intervel, or intervals, top(s), bottom(s) end neme (s) (if eny) for only the interval reported in item 30. Submit e separate report (p~ge) on this form, edequ~tely identified, for eech eddition~l interval to be seperetely produce.J, show- ing the 'edditionel det~ pertinent to such intervel. Item96: "S~cks Cement": Atteched supplemental records for this well shoukJ show the details of ~ny mul- tiple stege cementing end the Iocetion of the cementing tool.' Item 28: Submit ~ seper~te completion report on this form for eech intervel to be seper~tely produced. (See instruction for items 20 ~nd 22 ~bove). .... 34. SUMM'~II~' OF' POPdVI'AT{~)N T~'I~S INcLuDiN(; INTERVAL T~TED, PH~URK DA~ ~ ~OV~l~ OF OIL, GAS. WAT~I AND MUD , , , , , ,, ~ ~ , , , ,,, Top Sadlorochit 11,460' 8633 ~ Base Sadlerochit 11,870' 8969' ........... '. . . ' ~[ , · ~ ..~ ._ AtlanficRichfieldCompany .. North Amer~"m Producing Division North Alaska_ Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 10, 1978 CONFI-DENTIAL DISTRIBUTED TO: STATE OF ALASKA DIVISION OF OIL & GAS Reference: Enclosed are the following logs for D.S. 4-15: FDC 5" DIL 5" DIL 2" CNFD 5" FDC 2" CNFD 2" BHCS 5" BHCS Also enclosed is a BHCS log (2") for D.S. 6-2 if you receive seDias. Please sign smd return the copy as receipt of data. Sincerely, V. G, Reimers North Engineering #840 / Atla nticRichlieldCompany North American Producing Division North Alask~"',i, strict Post Office b. ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Enclosed are prints of the following wells: Log. Compensated Neutron D.Si. #4-1i D.S. #4-14 SI! Continuous Flow Survey D.S. #3-8 Sit Borehole Audio Tracer Survey - Differential Temperature Log NGI '#2 S" Due to an error in reproduction, Some copies of sepias are prefolded. If thisl~of any inconvenience to you, please request another copy and it will be sent as soon as possible. If all data is acceptable to you, please sign attached copy of letter and return it as receipt of data. Very truly yours, R. A. Logue North Operations Engineering RECEIVED ")o Oivi~10n of 011 & {iii North Alaska District Post Off[c~x Anchorage, ..,l~ska DDS-t0 ~.c~, ~Telephone 907 27F 5537 .,~, ~ "'"'" " '"~ ~ 1978 ': ~, ~:J~'a 26, Reference' "Enclosed are copies of the following cased hole logs' Differential Temperature Log NGI #3 NGIt~10 ' Fluid Density , D.S. #3-8 D.S'. '#4-9 . Collar Log D.S. #1-11, D:S. #1-15- · D.$. #1-16 D.S. #1-17 D,S. #4-13 D.S. #4-15- Hydro Log D.S. tt3-8 1! 5tt 1l SII Please sigm and return copy of tra]~smittal as receipt of data. R.A. Logua North Operations Engineering Transmittal #371 North Alaska District Engine¢ )g T RAN SM I T TA L To: From: J. A. Rochoh/R. A[ Logue Transmitted hermvith are the following for the subject well' Run No. Scale Xerox- Sepia BL Line Acid or Fracture Treatment Log · BttP Buildup & Flow Profile Survey Borehole Geometry Log Carbon Ox~,gen Log Casing. Collar Log Cement Bong Log Compensated Neutron Log - Cased ttole Core Analysis - InteF¢al Core No. Core Description (gNC) - Interval COre Description (Cony.) - Core No. ... 'Directional Survey- Gyro - Single Shot - Multishot ___.__J ....... Engineering Production Log Fluid Analysis Fluid Density Gamma Ray Location Plat . ......... Monthly Well Test Data Mud Log . Perforating Record -State Reservoir Pressure Report Surveillance Reports ..... Temperature Log Transient Pressure Surveys TVD Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log - Porosity Log Please Return Receipt To' .bls. R. A. Logue Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 .o North Alaska District Engineering.. . · To' T RAN S ?,I I T TA L Datc: Transmitted herewith are th.e following for the subject well' . · Run No.. ' Scale _ BHC Sonic/Caliper Log --~ BHC Sonic/Caliper - Gam~ma Ray Log '-' BHC Sonic/Gamma Ray Log -- Caliper/CCg Cement Bond Log/VDL "' ' Con~ensated Formation Density Log' _ Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Inter~.al -. - - Core' No', Core Description (SWC)'-'Interval Core Description (Convi9' - Core No, .:. Directional Survey- Gyro ...Single Shot ~'~ltishot Drill Stem Test -7£C'st No. 'Daal Induction' Lgterolog. Fm~nation Density ~Log - Formation Density Log/Gam~a Ray. Gamm. a Ray/CCL Laterolog Location Plat .. '' ~ilcrolatcrolog B'licrolog Nudlog- Inter~al Sample Log (A,R. cg[) - Inten~al Synergetic Log . 'Ia/D- D I L. · RYD-Porosity Log ,. · Xerox . . .. Sepia ,. · . BL L~e - o · . . Rece.q t. Acknowledged For: Date' Attn: Mr. Donovan Jacl:son Please retrain receipt to' Atlar~tJ.c R'lchficld Company North Alaska Engineering P. O. Box 3.60 Anchorage, Alaska 995]0 By' Test Surface Safety Valv~s (SSV), Su~surfaoe Safety Valves (SSSV~, Lo~ Pressure Pilots and Anmi~ar Pressures c~ ARCO's Drill Sites ~1, %4 Subject. test involved t~o separate ~rips to Prudhoe Bay, .the first on January 16, 1978, and the ~ c~ January 22, 1978, with eight cumula- tive days spent testing. Part of the second trip was utilized retest- ing cert_~n wells on drill site $1 after guide lines were agreed upc~ at a meeting be~=en agency and ARCD production personnel c~ January Listed belc~ are the results of the tests: 1-1 1-2 1-3 1-4 1-5 1-6 1-7 1-8 1-9 1-10 4-1 4-2 4-3 4-4 4-5 4-6 4-7 4-8 L.P.Pilot Initial SSV SSV ~- SSSV SSSV 9 5/8" Actuated Flc~Jng Tested Test Tested Test @ PSI Pressure 9 PS_I Results @ PSI P~k~ults PSI. 720 1550 640 OK 825 OK 25 700 1270 675 OK 720 OK 0 700 790 620 OK 660 Failed 0 660 1020 680 OK 700 OK 0 700 900 740 ~ OK 700 OK 90 700 1550 800 OK 810 CK 0 700 1140 6'95 · OK 650 Failed 60 · 700 1140 740 OK 750 Failed 0 700 1600 970 Failed 1000 Failed 0 * ** Inoperable 780 1400 700 OK 700 OK 0 2075 * *** Failed 0 680 1300 750 OK 750 OK 0 775 1450 750 OK 750 C~( 0 670 1560 700 OK 890 OK 0 700 1300 * *** Failed 100 700 1500 775 OK 700 OK 0 700 1350 700 OK 760 Failed 0 650 960 660 OK 650 ~{ 100 650 1450 700 C~( *** Failed 50 * Not tested .. ** SSSV inoperable. Being ~pulled. *** SSSSV would not close. 13 3/8" A~mulas PSI 0 0 0 110 100 0 50 0 0 100 0' 250 0 0 0 0 0 ~ 0 0 ARCO. D.S. #1, %4' F~ 9, 1978 Of the ~_~ty SSSV's tested, n/ne, or 45%, %~re inoperable or failed. F~ SSV's tested successfully and c~e failed. ~hree SSV's ~ not tested af~ar it was found the SSSV's in the %~lls ~ not test. Th~se ~ SSV's %~11 be tested when SSSV's in these w~lls have been rep~ad. production super/n~_]~_nt, and Don Franks, assistant produ~ superintendant. Orig/xkals of the field ~ reports are attached to this re~. Attachmsnt Drlg. Permit No.~._ Opera tom_, Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () (~() (~' ( ) () () () () () () () () () () () () 1. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. RiQ (~Safety Valve Tests 5. Surface-No. Wells__~__- 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos.~,. 8. Hrs. obser , , , 9. BS&W ,~,_ , 10. Gr. Bbls. ( ) Final Abandonment ll. P&A Marker () () lZ. Water well-( )caPped( )plugged ( ) ( ) i~ Oil and Gas Conservation Commi~.. e ~ Field Inspection Report ~) ~'J We 11 / ~ Sec T R__, Represented by~_~~_~ Name & Number ~).~ '~2~-~- _9 Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) .15. "Casin.q set 0 ( ) ( ) 16. les[ fluid-( )wtr.--~-~ )mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- p. sie ( ) ( ) 18. ~'!2 btls. , , , ..psig ( ) ( ) 19. Remote Contr°1~ -- ( ) ( ) 20. Drilling spool- "outlets ( ) ( ) 21. Kill Line-( ) C'heck valve ( ) ( ) 22. Choke Flowline ( ) HCR valve ( ) '( ) 23. Choke Manifold No. valvs flesh__ ( ) ( ) 24. Chokes-( )Remote( )Pos.(-~dj. ( ) ( ) 25. Test Pluo-( )Wellhd(')cs.Q( )..none ( ) ( ) 26. Annular Preventer ,_____~osi .Q ( ) ( ) 27. Blind Rams, psie 28. Pipe Rams .psiq 29. Kelly & Kelly-cock ~psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psin ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves--L-(- -TBV { )Dart Total inspection observation time?~_hrs/mim~ Total number leaks and/or equiP, failures 0 Remarks . cc :. .¢~,~ Noti fy in days or when ready Inspected by~ ~'/~~Date/-~--~ t)~ $;T!*HBUTED TO: North Alaska District .Engineering TRANSMITTAL To' '" From: Date' 'January 9., 1'978 - ' - . - . . Well N~me' · Transmitted herewith are the following for the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log -- BHC Sonic/Gamma Ray Log Caliper/CCL Cement'Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density .... Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core. Description (Cony.) - Core No. DireCtional Survey - Gyro Single'ShOt ~Ultishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gan~na Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog " ' ~dlog - Interval Sample Log (A.R. C6.) - Intemzal Synergetic Log TVD-DIL T~-Porosity Log I~_itia! TrsnsS. ent PrO~re.g~]rvey;Nov 8/77 J. A. Rochon/D. R. Jackson D'.S. 4-9 Sepia BL Line .Receipt Aclmowledged For: Date' Please return receipt to' Attn: ~..~. Donovan Jackson Atlantic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 #737 z'~orth Alaska District Hngineer?'~, TRANSMI TTAL J. A. Rochon/D. R. Jackson Date' . _A~as¢-l~. 1977 Well Name' .D.S.. 4-9 Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BItC Sonic/Caliper Log BHC Sonic/Caliper ~ Gamma Ray Log BHC Sonic/Gan~na Ray Log Caliper/CCL Cement Bond L°g/VDL Compensated Formation Density Log -- -. CompenSated Neu'tron- Formation Density Con~ensated Neutron Log · 5" Core Analysis - Intm~ral Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gmmna Ray - '' Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog Mudlog- Interval Sample Log (A.R. Co.-) - Inte:rva~'E Synergetic Log v TFD-DIL TVD-Porosity Log .e~ I-ea t _ea_ Division oi' Oil 8., G~;,~ O,m~orva[ion Receipt Acknmvledged For: . Please return receipt to: Atl. m~tic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, A].aska 99510 #554 DRILL S I TE # 4- 9 PERFORATION AND CLEANUP RECORD April 27- 29, 1977 D.S. #4-9 has a bottom hole location in the southeast corner, Section 35, TllN, R15E, Pruclhoe Bay Field. Depths of interest: Measured Depth Subsea Dep~t.h Zone Top of Sadlerochit Gas/Oil Contact Perforations Water/Oil Contact Base of Sadlerochit Junk Left in Hole 11461' 8582' Not Present 11840-11865' 8893-8913' 11807-11824' 8866-8880' 11752-11792' 8821-8854' 11687-11695' 8767-8773' 11670-11675' 8754-8758' Not Present 11869' 8916' None SMB SMB LBS LBS LBS RIH with first gmt, tagged bottom at 11920' and ran CCL strip from 11907' to 10400'. Perforated 11855'-11865' with choke at 48/64". Observed a flow rate of 200 BPD but no tubing pressure. RIH with second and third guns to perforate 11840'-11855'. Both guns misfired. RIH with fourth gun and perforated 11840'-11855'. Observed a rate increase to 500 BOPD but no tubing pressure. RIH with fifth gun and perforated 11807'-11824' while flowing on a 48/64" choke. Observed a rate increase to 2300 BOPD and 160 psi tubing pressure in 5 minutes. RIH with sixth gun and perforated 11772'-11792' while flowing on a 32/64" choke. Tubing pressure increased from 300 to 750 psi in 4 minutes. RIH with seventh gun and perforated 11752'-11772' while flowing on a 32/64" choke. Observed tubing pressure increase from 750 to 850 psi in 3 minutes. RIH with eighth gun (select fire) and perforated 11687'-11695' and 11670'-11675' while flowing on 48/64" choke. Observed tubing pressure increase from 720 to 740 psi in 3 minutes. There was no CaC12 water used in completing this well so no cleanup flow was required. RIH with dual Amerada bombs making static stops near bottom. Flowed well for 75 minutes on 48/64" choke. Final flowing tubing pressure, temperature and the average rate were 1200 psi, 59°F, and 8544 BOPD. SI well for 2 hour buildup, recovered Amerada bombs, and determined that the pressure at 8800' ss was 4367 psi and the maximum drawdownwhile flowing was 394 psi giving us an approximate Productivity Index of 21.6 STB/psi. Maximum BHTwas 230°F (likely no good). The total volumes of oil and gas produced during the perforating operations are estimated at 1275 bbls. of oil and 956 MCF of gas. PDL 6/2/77 To: North Alaska District Engineering TRANSMITTAL From: J. A. Rochon/D. R. Jackson Date' May 31, 1977 Well Name' D.S. #4-9 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated FomationDensity Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (~qC) - Interval Core Description (Cony.) - Core No. DireCtional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog FormationDensity Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat b~crolaterolog b~crolog ~hdlog - Interval SampIe Log (A.R. Co.) - Interva% S~mergetic Log TVD-DIL TVD-Porosity Log CaSing Collar Log and Perforating R@cord Xerox Sepia BL Line t ea. ! ea. Receipt Ack~¢l'e~dged For ~?.4::. ? ;,..! .,"Date.: ~ Please return receipt to' Atl~//~c Richfield Company North/Alaska Engineering Manager P. O. Box 360 Anchnrm~m~ Alaska 99510 #435 Atlant~RichfieldCompany North AmeriCan Producing Division North A I a s.~'"""~ i st r ict Post Office ..,dx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 6, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Drill Site 4-7 (31-34-11-15) Dr~te 4-8 ~(33-26-11-15) ~ll ~te 4-~33-35-11-15) Drill Site 4-10(33-27-11-15) 4 , .,,,..j ~ ,r.:: .:(;L ,: .. S_'.C FILl!: Permit No; 75-77 Permit No. 76-10 Permit No, 76-30 Permit No, 76-42 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED ' Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals tO drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) g GAS 1. Ow~LLL WELL [~i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company - 5. APl NUMERICAL CODE 50-029-20207 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360 Anchorage, Alaska 99510 Drill Site 4-9 (33-35-11-15) 27, T11N, R15E, UM 4. LOCATION OF WELL At surface 325'N & 643'W of SE cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 52' RKB CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 3893'S & 3942'E of NW cr Sec. 35, T11N, R15E, UM 12. PERMIT NO. 76 - 30 )ort, or Other Data NOTICE OF INTENTION TO.' SUBSEQUENT REPORT OF-' FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT SHOOT OR ACIDIZE ABANDON* SHOOTING OR AClDIZlNG REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) REPAIRING WELL ALTERING CASING ABANDONMENT* 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Began perf operations on 4/27/77. Tstd tree, csg & tbg. Ran temp survey. Pulled dummy valve. Ran GR/CNL/CCL logs from 11,923'-10,000'. Tstd BOP to 5000 psi OK. Perf'd intervals 11,855'-11,865', 11,840'-11,855', 11,807'-11,824', 11,772'-11,792', 11,752'-11,772', 11,687'-11,695', 11,670'-11,675' w/4 shots per ft. Ran static BH press survey. Flowed well. SI well for press buildup. Ran & set ball valve @ 2183. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production .Dept on 4/29/77. RECEIVED MAY 12 1977 Division of 0il and Gas Ccn~,~'-v0.~?~n 16. I hereby certify that the foregoing is true and correct TITLE District Dri 1 lina Enaineer DATE -- -- (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 0~-001B STATE 6f ALASKA TO: [-- FROM: DATE : SUBJECT: May 13., 1977 1400 psi abo~ SSSV was b~ ~ to 600 psi. ~ was no ~ of presst.we At~t Deg.' Permit .No. 0p'~ ra tor. A/i~ YJ~. Ala~ Oil and Gas Conservation Commit( ~ 'Field Inspection Report Wel 1/P1 atfm Represented by~jF~///y ". .~ ~/~-4!~'_ Name & Number Satisfactory cti on Yes No' Item Location,General ( ) ( ) ~Wel,1 Sign ( ) ( )2. General Housekeeping ( ) ( ) ' 3. Reserve Pit-( )oPen( )filled () I),' ( ) 5. Surface-No. Wells ! (') ~ ~ '6. Subsurface-No. Well's.~/ ( ) Well Test Data 7. Well Nos, , , Satis'Factory Type Inspection Yes No Item ( )BOPE TestS () () () () () ) () () () () () () () () Se~ R , ~ 15. ',Casing set @ 16. Test f'luid-( )wtr.--:--[ )mud ( ) oil 17. Master Hyd. Control Sys.- psi,q 18. N2 btls.. , , , psi.q 19. Remote Controls ( ) 20. Drillin,q spool- "outlets ( ) (). 21. Kill Line-( ) Check valve ( ) ( ) 22. Choke Flowline' ( ) HCR valve ( ) ( ) 23. Choke Manifold No. valvs flas 8. Hrs:. obser__, ,__, ( ) ( ) 9. BS&W , , ,~,, () () 10. Gr. Bbls. , (). Fina~n--d-~-n-n~ent -- 24. Chokes-( )Remote( )Pos.(~dj. 25. Test Plug-( )Wellhd( )cs.o( )none ( ) ( ) 26. Annular Preventer,__psi9 ( ) ( ) 27. Blind Rams,~psig ( )(.) 28. Pipe Rams . psig 29. Kelly~i& Ke~ock ~sig (..) (') 30, LoWer Kel!y valve '(.)' (") 31. Safety Floor valves- Total number leakS, and/or equip, failures () ( ) 1.3. Clean, up () ( ) 14, ~ad'~l:evele~d TOtal :inspectio.~ observation time ..Remarks AtlanticRichfieldCompany North Am.,~rican Producing Division North Alt ~] District POst-Office Box 360 · Anchorage, Alaska 99510 Telephone 907 277 5637 March 25, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Drill Site 4-1 (23-35-11-15) Permit No. 70-42 Drill Site 4-2. (13-26-11-15) Permit No. 70-63 Drill Site 4-3 (23,34-11-15) .Permit No. 71- 5 Drill Site 4-4 (14-36-11-15) Permit No. 71-11 Drill Site 4-5. (23-27-11-15) Permit No. 71-25 Drill Site 4-6 (22-03-10-15) Permit No. 76-83 Drill Site 4-7 (31-34-11-15) Permit No. 75-77 Drill Site 4-8_(33-26-11-15) Permit No. 76-10 ~'~~--S-~te-~L-~(33-35~ll-15) Permit No. 76-30 bfiIISi~--4'10 (33-27-11-15) Permit No. 76-42 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentionedwell. Very truly yours, Frank M..Brown District Drilling Engineer /vp ~closurc Form 1 REV. 1-10-73 Submit "Intentions" in Trlpllcate & "Subsequent Reports" in Duplicate - STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPL ICAT ION FO R PERMIT--" for such proposals.) 1. OWLLL[~ GAS D OTHER WELL ::)- NAME OF OPERATOR Atlantic Richfield Company ~ ADDRESS OF OPERATOR P. O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 325' N &. 643' W of SE cr Sec. 27, T 11 N, R 15 E, UM ]3~'~'LEVATIONS(ShowwhetherOF, RT, GR, etc.) 52' RKB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50 - 029 - 20.207 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM O~ LEASE NAME 9. WELL NO. Drill Site 4-9 (33-35-11-15) 10. FIELD AND POOL, OR WILDCAT 11. SEC.,T.,R.,M.,(BOTTOM HOLEOBJECTIVE). 3893' S & 3942' E of'[~/cr Sec. 35, T 11 N, R 15 E, UM 12. PERMIT NO. 76 - 30~ )ort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* R'EPAi R WELL CHANGE PLANS (Other) (Other) Perforate {NOTE: Report results of multiple completion on Well · ,ComDletlo. n or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ~li p®rtinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 50'00 psi WP wireline lubricator, tested to working presSure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The down hole safety valve will be installed and tested upon conclusion of job. RECE iV F D Estimated start date: MaY 25, 1977 9 1977 16. 'lhe'~by certify that the foregoing is true and correct TITLE District Drilling Engineer. DATE- for State office use) LE Petroleum Engineer See Instructions On Reverse Side DATE' 3-30-77 ~.e~ Copy Returned ~,:~laska District Engineerin~ CONFIDENTIAL DISTRIBUTED TO: STATE OF ALASKA DiViSiON OF OiL TRANStXlI TTAL From: 'J:A. Rochon/17. Toliver ., Date' August 6, 1976 Transmitted herewith are the follm¢ing: ! D..q. #4-9 ' '5'~ 'i2~L, Ruri"#1 ,. "D.S.#S-2 {$Z-35-11-15) Si'' GR/CCL,' ~ #i' 5"CCL, Run #2 5~'CCL, Run #1 D....q.,~5-6 {511'B-10-15) 5"-CC1'., Rni~ //1 Receipt Acknowledged For: 'Please return receipt to:~At;fantic Rich£ield Company North Alaska Engineering ~Ianager P.O. BoX 360 ' ' Anchorage, Alaska 99510 o. Atlantic~[chfieldCompany North Am~,~an Producing Division North Ala{ District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 21, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, AK 99504 RE: DS 4-9 (33-35-11-15) Permit No. 76-30 Dear Sir: We are enclosing the Well Completion Report along with the Well History and Directional Survey for the Above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/jr Enclosures Form P--? ~ SUBMIT IN STATE OF ALASKA , ~'otherin- st ructions on reverse side~ OIL AND GAS CONSERVATION COMMITTEE i W£1. L ¢01vIPL£TI ON OR R£¢OIvIPI.[T ION R£PORT AND LOG * WELL WELL DRY Other b. TYPE OF COMPLETION: WELL OVER E.~' haCK nESVR. Other 2. NAME OF OP]~RATOR · Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage~ AK 99510 4. LOCATION OF WELL (Report location clearl~t and in accordance with any State requirements)* 5. AP1 NUiVI~ CODE 50-029-20207 6. LEASE DESIGNATION AND SERIAJ~ NO. ADL 28324 ~. IF I1N-DIA.N, AJ_J_~ OR TRIBE NA_M~ 8. UNIT~FAAR1VI OR LEASE NA1VIE Prudhoe Bay ~S 4-9~ 33-35-11-15) ~ POOL, OR WILDCAT Prudhoe Bay-Sadleroch±t At surface 325'N & 643'W of SE cr Sec 27, TllN-R15E UM At top prod. interval reported below ~ 3893'S & 3942'E of NW cr Sec 35, TllN-R15E, UM 13' DATE SPUDDED' ]14' 'DATE T'D' RFk~C~ !i5' DJk~E CO1VIP SUSP OrR ABAND~3--21--76 5-3'76 . 5-11-76 ~9.5'[!~"' ELEVATIONS (DF' RK~I'~Pad ele~ 18. TOTAL DEPTI-I, MD & TVD [9. PLUG, B~CK MD & '~. ~ ~L~ ~L., 121. 12,050' & 9113' 11,973' & 9052' ~~Y* ~o~oo~ · ~ Ail ~. PRODUCING I~VAL(S), OF ~IS ~M~IO~, BOSOM, N~E (~ ~D ~)* None u. SEC., T., R.. M.. (myrroM HOL~¥OO1 OBJECTIVE) Sec 35, TllN-R15E, UM 12. PEH1VIIT NO. 76-30 i, GR, ETC)' ] 17. ELEAr. CA$INGHEAD INTERVALS DRILLED BY NoneCABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE .i Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, BItC/Sonic/GR1 CFD/CNL/GR and Cal±per -- CP~SI.NG SIZE 20" 13-3/8" 9-5/8" SIZE CASING RECORD (Report all strings set in well) · lb 1 . .i ,., 194~! Vetco /It-40 180' Be1 ~d. 32" [72~ Butt. !MN-80I 26~4' _ - I LINER ~CO~ ~on¢ szz~. ] cm~mw~G m~com~ 240 sx Arcticset (~pprox) 17-]/2" BJVI OUNT PULLED TOP (MD)' BOTTOM (MD) SACKS CEMENT* SCREEN (iVID) SIZE DEP'iI-I SET (MD) ~ PACKER SET (lVID) ! 28. PEH~ORATIONS OPF_~ TO N/A ACID, SHOT, Fi-CA~'URE, CF-,YiENT SQUEE. ZE, ETC. (MD) ;d~IOUNT ;AD K/ND OF 1VIAI~ER/AL USED DATE FIRST PRODUCTION PRoDucTION METHO~D (Flowh~.g. gas lift, pumping--size and. type of pump) OIL--BBL. GA~--1V~CF. t I DATIg OF T[ST. [I-IOURS TF-~TED "' ]CHOICE SIZE [PROD'N FOR CAS OIL--BBL. 31. DISPOSITION OF OAS (Sold, used for fuel, vented, etc~ ) 82. LIST O~' WELL STATUS (Producing or C- shut-in) [WA~B~. ] GAS-OIL m~TI~ lWA~B~' 1 OIL G~VITY-~I (CO~.) Drilling History a~d D%reCtional Survev certify tha~t the for ;Olng and ttached lnformatidn is complete and correct as determined from allVavailable records SIGNED ..... TITLE DATE ..... ' .... d" -' *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUcTIoNs General: This form is designed for submitting a complete and correct well completion report end I'og on all types of lanJs and leases in Ataska. Item: 16: Indicate which elevation is used as reference (where not othe. rwise sho~.n) for depth measure- meats given in other spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc. Jucinrj interval,, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a seParate report (page) on this form, adequately identified, for each additional interval to be separately producecJ, show- ing the adYJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY O1~ F'O~MATION TE, S'I'S IN('I, UI)IN(; INTERVAL T~TED. I;H~S'IJRE DATA ~'~OVERI~' OF OIL, GAS. 35 G~GIC MARK~ WAT~I AND MUD " Top Sadlerochit 11,460' 8633' Base Sadlerochit 11,870' 8969' . . .~ . .. i - , , ,, i , ,, ,r, , , , ATLANTIC RICHFIELD COMPANY DS 4-9 (33-35-11-15) API 50-029-20207, ADL 28324, Permit No. 76-30 Drillin~g, H,istor~ ~pUd @ 1330 hours 3-21-76. Drilled 17-1/2" hole to 2730'. Ran 13-3/8" 72# MN-80 casing with shoe at 2654' and FC at 2573'- Cemented with 5300 sacks Permafrost II cement. Landed 13-3/8" casing and cemented 13-3/8" x 20" annulus through 2-3/8" risers with 150 sacks Permafrost II cement. ND 20" BOP, installed and tested 13-~/8" BOP. RIH w/12-1/4" BHA, drilled FC, shoe and 10' of formation. Tested to .65 gradient. Directionally drilled 12-1/4'' hole to 8856'. .iThe dedision was made to plug back and sidetrack in order to hit the permitted target. WIH and laid cement plug w/DP @ 6114' w/~op 5900'+. Used 210 sx Class G cmt. RIH w/12-1/4" bit, washed soft cmt 5989'-6020'. POH. Cmtd thru OEDP @ 6020' w/250 sx Class G cmt Dressed top of cmt plug @ 5930' · , directionally drilled a sidetracked 12-1/4" hole to 11,115', POH w/multi- shot Ran 9-5/8" 47# MN-80 butt csg w/shoe @ 11,005'. Cmtd w/750 sx Class G cmt. Installed & tested 9-5/8" x 13-3/8" pk-off. RIH w/RTTS & shifting tool, pumped 125 sx PF II cmt thru lower FO @2613'. QPeneRupper FO @ 2363', place 282 bbls Arctic Pack in 9-5/8" x 13-3/8" anul w/final returns 0% wtr. Closed FO & press test csg @ 3000 psi. RIH w/8-1/2" bit, drld FC, cmt, shoe & form to 11,120'. Tested form to 11.3 ppg equivalent. DireCtionally drilled 8-1/2" hole to 12,050', POH w/multishot. Ran DIL, BHC/Sonic/GR, CFD/CNL/GR and Caliper logs. Ran 7" 29# MN-80 Buttress csg w/shoe @ 12,048', FC @ 11,965t a~.d top of liner @ 10,779'. Cemented w/310 sx Class G cmt. RIH w/8-1/2" bit and 9-5/8" csg scraper to top of liner. POH, ran 6" bit to FC @ 11,973'. Tested 9-5/8" x 7" csg w/3000 psi. Took WSO test, poH.* Ran VDL/~, CCL/GR and Gyro survey. Reversed well to diesel. ~5-1/2'.' 17# L-80 A-B Modified 8rd to 10,712'; Baker SAB packer @ 10,563~,/top BOT packer @ 10,520'. Landed tubing and tested control lines./~ NU tree, pulled dummy valve and tested OK. Set packer, tested csg~and tubing OK. Ran 2-7/8" dummy gun OK. Installed guages and Je~ured well. Released rig 1200 hr.s 5-11-7~. Suspended Oil~well. ~ _ Eastman / Whipstock A PETROLANE ~PANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Richfield D~ COMPANY S. 4-9 WELL NAME Prudho e Bay LOCATION JOB NUMBER A576 G0119 TYPE OF SURVEY Gyro-scopic DATE 5-6-76 SURVEY BY Shy~m Talwar ~ . OFFICE Alaska L0_~P_!, E_'[.. I.O.N.,.,_REP_O_B T L'r_.~.ANT! C__B..I (HF I ELD CO, DRILL SITE 11-9 iY.RQSCO_P_.~_..C..._5.W.BVEY KB ELEV, 52 FT, L~.~.~US Of CURVATURE METHOD OF COMPUfATION$ --t..: ................................................. B.~..C_.,.O_.RD OF SURVEY AL.L___.C__A.L_C_U_.~T_I_ .0NS..P. EREOR_..M__E_~__..BY__.! .... B _~.._~ g.I,,.E.._.C_.TRQ.N_I._~_L~_O_N._._P~T_.E_R ........ ,.TRUE ....... DOG_ LEG T_L~ ~.._. ~IEAS.,,_D_RIFT._.VERT_.I.¢AL ............. SUB ......... DR_IE..T_ ,.. ]LOX. ALC=OORD_INA_T_E&_ _ .C,__L_O_,$_U....R_g__~ ..... '.._fiEV_ER/_ZY SEC 2EP]:H_A~GLF._ ..... DEB.TH ............... 5gA .............. D.Z.B.E_.~ ........ 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S__.6_3.__~.5__~_~__g .... ~,Z60 .1 Q ~ O0 .... 5! ........ 0__~.6 Q_Q_,.3.~ 7.5.~ 8.,.35 S ~. 8.,.Q.~.~__~7__~7.,~..7___.~ ....... 3455_,_.QQ__~ ~ 86 2 ~..7_5_.. ~ .6_~.__~ 6__~_~.__,~ ........ 0_.,_6~ 0 ~.8.~_?_ ~02QO_ 5.Q__.3.~___7_725_~ .... 76!3.,.~ 1 ...... 5~6 .,.0 QE ...... ~.~..~ ~._,._6_Q__5 .... ~.5_69._~ i~__E ....6_Q.~.~,_6.~ .... 5_._6.~_~_8_ ~_ ~ ....... i~_Q.3_Q .... 11000 42 35 8270.84 8218,8~ S36,50E 2263,77 S 3963,~8 E 4564,4Z S 60 16 0 E 0,953 ~5~6,25 .!1!00 40_15 ..... 83.~.5,...8_~...8293.82. S36.005 2317.12 S ..... ~OQ_2.,_~O_.E ~.6_.2.~.~.2 S 5.9. 5.5 5.9 .... E .~.,3~_9 ......... RECORD OF SURVEY [,1.g~ & ,..~R ! E_T_.__V..E_R_T__~..¢.A.L .......... SUB ............. DR ! F.T .................. T_.O._T..A. L__..C.._O..OB D..I N A~_?~] ,Ii.ER_T..H_A~I~I,,.B__]~g.B~H.. ......... _SBAL .... ] ..... D..! REC ~).I $_~.A~..C....E ........... AB~L..E_ ........... D.E.~L1..O.O.F_.T _~_4S_]'.A.N.C.F._ ................. D ..... ~L .................................... DE 6, ............................................................. . 11 ~ 00 .... ~ 6 ...... ~5 ........ 8~O_A, 10 ......... 8 z~52..,. 10 ....... S ~ 1,00 E ......... 2.~+_1.9.,..2..5__.6___~ 069.,. 62 J.l_~._O.O......~6 ..... 0 8.~..8.~.,.62_._: .... 85.32.,62 ........ SBO,OOE ........ 2_z+7_0_,.3.~..S. 4.0..9..~_,_.7.g _.t_.:[600 __3 ~..._~.O__8_?...Z+_?.o ~ 8 .... 869._~..,_6.8 .... '....S Z 9 · 00 E ........ 25 70 o~._~__ 8_ _~_],.57....° ].9 _!.1'900 ..... 36 .... !.5__8.99_3.,..5_.3 ......... 89z+].,.5.3 ...... S30 · OOE 27~1.,,.Z2 ...... S_ .... ~+.2/+0., 5.3__._E.._.: _119~0 ....}6 ..... 45 ....... _9_02.5.,..~_8._ .8973_,.68 ......... S29,00E ..... 27~+]..,.9.3 .... $.___AZ~.Z_,.ZSL._..5..O.5_9.,..6} TRUE CODE MEASURED VERTICAL TOTAL COORDINATES C L 0 $ U R E SUB DEPTH ~ DISTANCE ANGLg NAME DEPTH SEA D M ~ 11~+60 11870 1197~ 12050 9113,2~ 2799,88 S 4285,03 E 5118,68 S 56 50 20 E 9061.24 --N ~A$LJ R-~-D-.. D F.-P-T- N--AN.D--O-T-H 5 R-- DA-T-A---- F-OR -:F.-V. ~R-Y- - F,-VB N-=- 10-~- F--F.-F,J-T-O-F-- SUB---&~A ..... _T..R.U.E_ ~~ F..A S.URE.D ......... V_E.R3..I C A.LS.W B_.--M,.D.,,. I~.V..,D .............. Y.E.P_T_I. CA L. .12EP__T_H .... DE. BTJd__ ...... S.EA._,,D I F.F_E R_EN.C.E ............ .CORRE. C.I LOt4__,___T..OI.A.L_,.COORO ]LNA.IES 15.2 2.5..2 3..5..2 _4.52 .......... 55.2 ...... 6,5...2 152, ............. 100 .= ............ 0 ..................................... 0 ................. -,._ ...... 1.4. L7,8 Z_.N .......... 299, 2.52-. ................ 2,.00 ......... ~ ......... 0 ..................................... ~ ........................ l~.LT..,...7.a.,_.~ ............. 299,7 9 .~ . ,.~.52., ~ 0.0 .............. ~ ............................ ~ i.~. LT_'_ ~5_ J~ ............ 2.9.~., 3.. 7_.W. 5 5 Z. ~ ............... 50.0 ........0 ............... ~ .................... 0 .~..~1.,_0.I_..4~ ........... ' ........ 2..99 ,..l~.... W 6.52.. ...... 60.0 ..... 0 ............ 0 ~k~d~_60.4~ ............. Zg. ~,.8.9_W. 15.2_ ..................... 7 5 2_,, ............... 7..00.]. ............... 0 ................................... 0 .l~!5.,..aS__N .................. Z98..,_75 ...... W_ ........................ 8 5.2 ................... 8_5_2.,_ ......... 8 00_ ................ O 0, 1.(,+..1.5 ,_6.9._N_ ......... Z98 ,.3~.._..W .9_52 932 · __.9..0.0.__ O . 0. L.~_L~_,_.lg___~ ...... 2_91.,..6f_~ ..................... 105 2 105 2, ............. 100.0 ................ 0 ................ ; ........................ .0 ........................ __.1~3..,_99..... N .............. 29..7 ,;.3_3 .... l l ~ ~ 1.1.52 ~ ......... 1.100 0 0 1._~ll, 68:. N ............ .2.97 ,_9 1.252 12.5.2. · ............ 12 00 0 0. L~Li ,..5 0.._. N .............. 298. ,.8. 3. ................ 135 2 1352. ~ .............. 1.300 ............... 0 ................................ 0 .... · K~_I_0..,_9..8_N ............... 299, ~3._W... 1 ~.52 1..~_52 ~ ......... 1.~O0 ....................... 0 ................................................... 0 ......................... _I...~I_0.,...8.~_._ N .................. 2_9.9 _ ,._7. . !552 ..... 1.552.~15 O0 0 0 L_~.o..8,6..._N ............ 2.9..9_,.9..5~ ................... 165 2_ ........................... 1.6.5 2 · ......... 16 O0 ....................... 0 0 ............................... 1.4_1_1,2.~_ _. ~ ........... ~ 00 ,. 17..... W ................ 1..7.5. l 1.752.~ ...... 1..700 ............... O 0 1.~l.1 ~.99_.~ N ............ t9 9, 8.~ 18.5,,2 ............... 19 5_.2 .............. 2052 ......... 6_ .... 225 2 ................... 2.35 2 ...... 18.52_, ......... 18.00 .............. 0 ....... 0 1_9.5. 2., ........ 1900 ................. 0 0 ..... 205 2., ........... 2000 ................ 0 : ........ 0 __. 2.152.~ ....... 2.1 O0 ............. 0 0. ...... ...... 22.52.., ......... 22, 00 .............. 0 ................................ _0 __ .2~..5. Z* .......... 2.300 ............... 0 ........................ = ......... _0. ~.24.5_2_ . ............... 255_2 2 f52 ................. 2.9..5.2 3.05.3 .............. _~ i_5__~ 3255 ~357 3459 2852, 2800 0 0 2952, 2900 0 0 3052.~ 300Q ........... ! ................................... 3152, 3100 1 0 3252,. 3200 3 2 3352, 3300 4 1 3~52, 3400 6 2 .... 2.552~ ........ 250.Q ................. 0 0 ..... l~QS_,._5.1_.N ........ 295.,0? .... W ..... 2.~.52_, ........ 2.600 0 ............. 0 140.6_,_96_.N .......29.~,27 .... W 2752, 2700 0 0 14QS...,_96__N.._..~ ........ 293,.09 W 1~0~,66 ~ 290,90 W 1396,65 N 27~,18 1390,16 N 262*25 ............ 1382,20 ~ 2~8,32 I373,47 N 232,74 1363,19 N 215,48 W 3 5 5 2~. ......... ~,5o.o ..................... ~ ~ ................................. ~..~0..,.o.2... ~ ~ ~s.,,..5 o ..... w ~_E_~_S_~_R_E_d_ D__~?_T_H _A_N~__o_'r_i:.i..E:_F_p:A. ZA.E.O_._R_._E_V_E__ R Y__(_V. E N ..... !P O ..... F_ E E_.~. o E__s U_B__ SEA D_~ ? T~H..,_ __M E A 5 U R E D __V E R T_I_C_A_L__$,p,,B ....... : ..... ~.,D.-,,.T,.yD ................ Y ~ R.?_!,CAL ................ _.D_E,P_T__I:t .................. _D__E?_T_,t:I _S.( .A._DJ, E,F...,ER_,E_,N.~_E_ ......... _c__o....B...R_E_.c[,,_TJ_C~ ............. _~.Q_~_A.L_ ...... :.¢ O,.O.8 D_I..~.A'_[,F._~ ...................... ~665 3652, 3600 12 ~ 1334,96 N 175,2~ W 3-7-g-9 ..................... ~S~'7-~-2", ........ 3'7'0'0 .................. :"6' 4 : ................ 1319 , 3"~'-? ~ 38'52" ....... 38 0 0 ............ 2'-i 5 13'02'"'4 ~ 97 8' ~'9'5"2'~ .... 3'900 ................... 2'g .................................. :'5 i*2"8"2","6-~--~ .............. i-~'0";'~8 .... W '~"~ ........................... ~ O'~ z' · ........... ~000 .............. ~ 7 zz ao. ~8 N 70.8 O-w ~534 4452. ~400 81 16 1130.92 N 84.22 E ~.97 4952, ~900 2~ 50 827.59 N ~90,6~ E 5161 5052, 5000 309 64 733.24 N 480,05 E 5_0.9 .................... ~.7..~ 2 · ........ 5700 ..... 7.~7 6~ ~. 2.6..._99,_ N 6 ? ~. ....................... 58_~ 2 · ......... 58_0 a .......... 8. 2_.~ 66 ................................. =....~5.._6.%_ ~_.8_~9 ............... ~_~.2.,?. 5900 897 7.4 ~2_._50 S 1369,78 E .............. %8~.3 ......................... ~_~_52.. ~400 %3..8.! 10,7 ............. 576.31. S ....... 2027..30.. g 8_0.3.% 65.5&. .... 6,~ 0.9_ ..... !&. 8, 6 10.,5 .......... 687.~_.l_,.~_s ....... 2 !.6_9..,_ ~.~ E .......... 8.2E..~ 6652. 6600 1591 105 797.08 S 2310.31 E 86.~_8 ...................... ~,~_p2.. .............. 6_~.qO ..... !~9~. .............................. ~.oo zo12.62 s 2587.66 E .... 8 8.~_7 ....................... 6.~52 · 690.0 ~895 ._.7_O.O._O. ....... ;L_9_8_9_ 9.4 .~.2.26.._.0.5 S ...... 2849.96 E ...................................................... _M EA S URED=.D E P__T..H__A ND_.Q II=t.E R_.D AT.A._.EO R_ E.V ER Y_ E.V.EN _10 0.~- E E E..Z_O.E_5 IJ..B :_5 EA .... D E P .T.H., .............................................. TR.U..E .................... 9_2_2.8 ............ l!~_2_, ................ Z l_O.,O ........ 2qZ.6 ........................ 8 7 ............................ 13_ _2_~_..Z? _..~ ....... 2.9.7 ~ · 2. 9 .. E 9 '~0 8 7 2 5 2 · .... -7_2.0._0 ..... ~._2 1.!6_ ................................... 80 ................................ :I,_4_1.61,_~._~__$ ............. 2,_0 9_.:1, · 4.2 .... E .................--_ .~.._~.8~.. 7..~.~_Z... 7.~0_.0 .... _Z.2.3 ]. 7,5 _.1_5.0.6_,.,6:,L_,5 ........ ~Z03.,_], 0_F ............... 9_ ~.,5_.. ~. ....... _7._z~.5_.2. ......... _7.. z~..Q 0. ........ .23_.02 ............................ % 1 ............................. :1,~5_9.7._,_ 6_6 ..._5 ...... ~. S..0.'Z....8. 8 ._.E ............... ~, ..................... _~ _~_~.~... ........... ,~_~.o..~ .......... ~_,~ ................................. ~.~ ......................................... :.~_~_,..~_~,._~ .... _~.~._o~,.._~,~_.~ ........... ,_~.o,o~_ ................ ~_~.:,.. ........ ,~,~,~.,o .... z,~ ~ ~.?_ _~_z.,~:...~ ~ .... ~ ........... ~.,~_~.~,.,.~_o ..... ~ .......... '~' _~. .............. 1.0 24_] __7_7.5_2.., ........... _7_7.0_0 ........... 2,A_8 _9 .......................... 5. 8 .......................... :LS_5.k._8.Z .... 5 ............. :~. 5.91. °3.7 .... E _1.O~.9._6~ _7_8_5.2, ............... _78.0_0. ......... 2_.5_~.~ ..................................... 55 ............................. :Lg~S.,9_.._l.9.._5 ............ ~_6 .7.. 5.. ,' .z+ 8 .... E .... ' II C. ,' ~i 1_0,.5.~..7.. .7...9_5_2.. ....... 7..9.QQ ...... 2.,5_9_.~ ................... ._._.~_1._ LOI.9_ _,l.6.._~ ......... ~3.7_,5. 5. .7_1 _E ............... 10 69..z+ .............................. 8_0_5.2, ..8.00.0 ......... 2.6A.Z ..................................... z+.7 ........................................ 2_09..7._._92._.$ ............ 3_82.9..,.32 ..E ................. 1.0 83._7. 8_152.. ......... 8..1.0.0 ..... 26,8_5 ......... _. ......................... ./+~ ............................... __2.1_75_._~_1 ..... S .......... :].8.9 Z+_.._9.7 ._ E .. 1..09.7_..A, ........ 8.25.2_, ....8.Z0.0_~Z_7..Z.Z .............................. _3_7 _~2,,2..~,.9_,.7._.~......5 ........... :B.9.5.2._82 .... E ........ .................. 1.1 10.8 83.5..2, .............. 8._3.0.0 ...... 2_7_5.6 ......................................... 3 .~ ............................ 232.1...~ 3.._5 ....... ..z+.O.Q.5_.,.66 .... E ................ 112 :] .5 _8 _z~_5_2.. .............. 8.~_0.0 ....... 2_7..8. 3 ............................ Z _7 .2~_.86_._0__9 ___S ......... *._0-.z+-9..,..1...8 E 1135..9. 8...%~.2,_.,___8....5,00, .... 2.8.0.7 ...................... 2.,,4. ........ Z_~3_,,,~ 5.,._S ........ *.0.8.-7--"A55 ..... E ......... ........ ~ ;1,48 3 ......................... --865.2 * ..... 8600 ....... ;Z.8:~l ..... 2~+ .............................. 2..5..1.2.*.2t..2 ....:S ~..12.3.'_9.5 E ......................................................... ............ ~ -~6o~ ......... _~_75~. .......... 8.._zo_o .......... z._~_.~3 ........... '~ ...... i ......... ~...'. .......... zz .......................... z_~_z~..,_~.~_...s .... ~+l~..s..,.~_? .... E ............................................. 1~.3..Z6 . ___8_8..5.Z... ..... 8..6.0_0 ..... .Z.87.~ 2 ;I, ..... __Z_6_..~._J..,.Z.6._5 ......... ~_1.%1.,._7 Z ._.F~ ........ :1,_.~8~+9 - 8.952. ........... 89.00 .......2..8..9..6 ................................ ZZ .................................. :Z_..6.9.~...~0 ..6 ...... ~ZZ5.~+7 E ............................................. ........ 1~97~ ..............9_0.,5..Z.. · ........ _9._00.0 ...... 2_92_0 ......................... 2._.4: ........................ _2. _7.~.?._:_2 z+. _S ..... z~_2 6..1 · 9.0 E ......... '":::":'::._-:.": ..................................................... _L.N._T_E_~?_O_O. _L. AT_ .E:p_,._y_A...;L_ y..E_S__E 2~_E_V....g.B .... LO_P~0 ..... .F%E....T_. _9 F__.~_..E..' A.S U. Rg_O_ O E_ Pl. H, ............... .~ :.: MEASURED DEPTH · TRUE VERTICAL SUB DEPTH SEA TOTAL COORDINATES 2 00'b' .................. 1-~-9-"- ......... i'94 7'-. ................... i"2+-~'2-'"2-7-'"F4 ................ 2' 9-~-.'~ ..... W BO00 2999, 2947, 1399.27 N 279.70 W 4000 3e7-2~. ......... ~'20-" ................. i'zT~-,~z~ .... N ..................... ~.'~ w 6000 -7ooo 8000 9000 10000 11000 12000 6036. 5984, 120.98 S 1467.27 E 6~ 3'~' .... ~'4'8'0-; ........................ ~'~'~-~'-~ .......... ~ ~4'~-.-'~-~ .... E-- ......... ~"--: ~ ...... l-- 't. 7030, 6978. 1203.41 S 2823.35 E 8270, 8218, 2263.95 S 396.3,24 E 9073, 9021, 2773.45 S 4269,91 E LVERTICAL]] SECTIO N~Z~2 ATLANTIC RICHF. IELD COMPANY. ~ '---Ir ................. DRILL' SITE 4-9 .......... · ........................................ -~ .......... ; ....................... -~ ............... [ RAD I' O' E?O F.-_C 0 R ~TA T 0 R E-~M'E TH'O D' ........... ~--: ......... ~ ......... GYROSCOPIC SURVEY ...... .'_7. Z.' .._- _~_____~_. __ _ ..... ~ .... L_: .......... ,l ........ : .....l i ......... ' ........... , i ' , ~ . ' I ...............................: --! .............. I ............' ........ i .... i ................. - , t ' I~' t ' ! - 3200 ................................... f-- - . ''- !' - ' ~ ' ~ ~ ~ ~ ~ ~ ' I ARE TVu. - .... ~ .' _: .. _- :-:-.' ~'_-'~ .!_7-:_7:~_ ~!--'::LT~::~ ;_._-.:- .-L "._!. ;-:-.:7; -:-.:.-_';i_ ~Lc_ -:.:__-l.::t: ....... '- "' ' 1' ......... i- I I ..... { 't ; I : : -' ' ~ --I ..... i- ' , .......... . ................ 1 .......... .:.;7 ~;' _:-_.:_: .- ..... ' .-! ........ ~ ....... 'i -: - ~ ........... ] ...... i .... ~ - -" ~ - I t -J .... ~ .........i ................ ~ ............ F ......... ] ..........i ........... ~ .............. i": ........... i ........ TMD = 12,050"- HORIZONTAL_.~.VI EW_ ~. ...... ,!-. DRILL SITE'4-9 ............... T RADIUS OF~CURVATURE METHOD GYROSCOPIC SURVEY ..... _ I ............................ ! .............. ~ ............ -: ........ : ....... 7~oo .:_ ' . . - ........ i'; i'. '---i ....... .... .... .......................................... ; ..................... ~ ........................................................................... :' ' 8000 '~'~ ................. , - .......... ; ......... . .. ~ . ....................... ~ ..................... ~ .......... ~1 ~ ......... t~ ....................................... ~ _ _ . .... .... ~ ~ . , - .... , ~ ........................ :, ..... ~ ..... '"'"""~""' ~ ~ ' -- ~ ........ ~ ' ' ~ ..... ~ ................ -'~ - TMD:I2,050"- ........ '~ .........J LOCATED IN -THE ' APPENDIX UI WFL UI IPR LOG UI CALIPER SURVEY UI VOLAN URVE DATA UI STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: Atla, ntiCRic~hfieldCompany North Amer~'~ Producing Division North Alasi( ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 4-9 Permit No. 76-30 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer Enclosure CRK/BDR/j 1 C. ENO 1 ENG ...... 2 Fi'.,'3 "~./~ 5 ~?,':G ..... 3 G:[OL ...... .... ................... DRAFT SEC CONFER: FILE: F~rm ~o. P--4 lq~V. ~- 1-70 STATE OF~ALASKA OIL AND GAS CONSERVATION CON~I'I-i'EE SUBMIT IN IJUPLICA'I'~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2, NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPEI~TOR P. O. Box 360, Anchorage, Alaska, 99510 4. LOCATION OF WELL 325'N & 643'W of SE cr Sec 27, TllN, R15E, DY4 API NUg~ER/CAL CODE 50-029-20207 LEASE DESIGNATION AND SERIAL NO. ADL 28324 IF INDIA]~, ALOIiE~- OR TRIBE NAME L~,'IT FA/~A~ OR LEASE NA3~B Pm~ ~y ~E~ NO DS 4-9 (33-35-11-15) 10. F~ A_ND POOL, OR WILDCAT ~rudhoe Bay-Sadlerochit Pool ' II. SEC., T., R., I%~.. (BOTTOM HOLE oB,r~m~ Sec 35, TllN, R15E, UM 12. PERMIT NO. 76,-30 '13. REPORT TOTAL DEPTH AT END OF MONTH, CPL~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUM]~ USED. PERFORATIONS. TESTS ANT) 1%ESULTS FISHING JOBS JIj'NK IN HOLE AND SIDE-T'RACKED HOLE A~D ANY OTI-EER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Re~ort on O~erations for the Month of April_ Directionally drilled 12-1/4" hole to 8856'. The decision was made to plug back and sidetrack in order to hit the permitted target. WIH and laid cement plug w/DP @ 6114' w/top 5900'+. Used 210 sx Class G cmt. RIH w/12-1/4" bit, washed soft cmt 5989-6020'. POH. Cmtd thru O~DP @ 6020' w/250' sx Class G-cmt. Dressed top of cmt plug @ 5930', directionally drilled a sidetracked 12-1/4" hole to 11,115', POH w/multi-shot. Ran 9-5/8" 47# MN-80 butt csg w/shoe @ 11,090' and FC @ 11,005'. Cmtd w/750 sx Class G cmt. Installed & tested 9-5/8" x 13-3/8" pk-off. RIH w/RITS & shifting tool, pumped 125 sx PF Ii out thru lower FO @ 2613'. Opened upper FO @ 2363', place 282 bbls Arctic Pack in 9-5/8" x 13-3/8" anul w/final returns 0% ~ wtr. Closed FO & press test csg @ 3000 psi. RIH w/8-1/2" bit, drld FC, cmt, shoe & fora to 11,120'. Tested fora to 11.3 ppg equiv. Drlg 8-1/2" directional hole @ 11,287' on May 1. sm~ ~... . ~r~ District Drilling Eng. D*~ ~y 6~ 1976 NOTE --ReDort on this form is required for .each calendar ~thi regardless of the status of operations, end must ~ flied in duplicate with the oil and gas conservation commlffee bythe 15~ of the succ~ding mon~, ~le~ otherwise directed. Atlanti~RichfieldCompany . North Amer~'~,3 Producing Division North Alaska, 4strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 5, 1976 Mr. O. K. Gilbreth- State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: Drill Site 4-9 (33-35-11-15) Permit No. 76-30 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the aboVe-mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer /cs Enclosure DIVISION OE 0t~- AND GAS AN,~Hr, ~ .... C l~T-m No. P---4 I~"V. 3- I-?0 STATE OF?ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL ~'~LI, 2. NAME OF OP~I%ATOR At]antic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska, 99510 4. LOCATION OF WFJ..L 325'N & 643'W of SE cr Sec 27, TllN-R15E, UM SUBMIT IN D%TPLICA~ [,5. AP1 NU~iEH/CAL CODE 50-029-20207 6 LEASE DESIGIXtATION A.%D SEI~IAL NO. ADL 28324 ? IF INDIA),[ ALOe[ l~-~. OR TRIBE HAME 8. L.~IT FA.R~ OR LEASE NA]VIE Prudhoe Bay 9 WELL NO DS 4-9 (33-35-11-15) 10 lr~ A.ND POOL, OR WILDCAT ...Prudhoe Bas/ - Sadlerochit Pool II SEC., T., R., M.. (SOl'TOM HOLE o~ Sec 35, Tl lN-R15E, UM 12. PER.MIT NO 76-30 13. REPORT TOTAL DEPTH AT END OF MONTH. CI-L~NGF_,S IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLrM]~ USED. PEH.FO~TIONS, TESTS ANT) HESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND A_NY O'I'I~R SIGNIFICANT CHANGES IN HOLE CONDITIONS. REPORT ON OPERATIONS FOR THE MONTH OF MARCH S.p.ud at 1330 hours 3-21-76. Drilled 17-1/2" hole to 2730'. Ran 13-3/8" 72# MN-80 casing with shoe at 2654' and FC at 2573'. Cemented with 5300 sacks Permafrost II cement Landed 13-3/8" casing and cemented 13-3/8" x 20" annulus through 2-3/8" risers with 150 s~cks PermafrOst II cement. ND 20" BOP, installed and tested 13-5/8" BOP. RIH with 12-1/4" BHA, drilled FC, shoe and 10' of formation. Tested to .65 gradient. Directionally drilling 12-1/4" hole at 5829' on April 1. APl4 ? 1976 DIVISION OF OIL AND ©AS 14. 1 here, hX certify,~t~e ~or~k~oing ~ 'true and eormect , ' ' ' N0 --Re~ort on this form Is required for ,each calendar ~th~ regardless of the status of operations, and must ~ flied in dupli~/e wlt~ the ~ oil and gas conservation commiflee by the 15~ of the suocNding mn~ ~ie~ otherwise directed Submit "intentions" In Trip!lcate & '*Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES .AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL ii OTHER 2_ NAME OF OPERATOR .Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360 Anchorage, Alaska 99510 4.,-I~OCATION OF WELL At surface 325' N &. 643' W of SE cr Sec. 27, T 11 N, R 15 E, UM 1'3. ~LEVATIONS {Show whether DF, RI, GR, etc.) 52' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50 - 029 - 20207 6. LEASE DESIGNATION AND SERIAL NO. ADL 28324 7. IF INDIAN, A~LOTTEE OR TRIBE NAME UNIT, FARM'b~ LEASE NAME 9. WELL NO. Drill Site 4-9 (33-35-11-15) 10. FIELD AND POOL, OR WILDCAT , 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 3893' S & 3942' E of NW cr Sec. 35, T 11 N, R 15 E, UM 12. PERMIT NO. 76 - 30' )orr, or Other Data FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: TEST"WATER SHUT-OFF E~ PULL OR ALTER CASING E~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate __ SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) {NOTE'. Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. :DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of · .starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carri'er tyPe guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will' be vented to the atmosphere during perforating operations. The down hole safety valve will be installed and tested upon conclusion of job~. Estimated start date- May 25, 1977 16.-.I hereby certify that the foregoing is true and correct TITLE District Drilling Engineer DATE (~Fh~space for State office use) !'~:~P:P]:~'OVEDBY ~ · ~, ~,~~,TLE. leeltrOleMm Engineer <CONDITIONS OF APPROVAL,. I See .Instructions On Reverse.Side DATE ':)-30-77 APpewed Copy Refurned STAT ~ of ALASKA ~...!~.~ DEPARTMENT:OF NATURAL RESOURCES Dtvlsio~/of Oil and Gas To: [-- O. K. Gilbreth, Jr Director Thru: Hoyie H. Hamil ton . Chief Petroleum Engineer FROM: Petroleum Inspector April 1, 1976 SUBJEC~ .Arco DS .~9~ and Arco DS 9-3 Ma~h 25, 1976 - Depar. ted my'.:~home at 8:.00 AM for 9:00 showup for 10:30 AM d~epa~~ viaWien flight #23. arriving in Deadhorse at 12:45 PM via. Fairbanks. ToOk Arco bus to DS 4 arriving at_l:40 PM. Don McKelvey, Arco drilling foreman, ad:viSed they were doing a top job. and it would probably be the morning of March 26th before tests would";lbegin, Toolpusher for Rowan Rig #26 was L. C. · Baker. Temperature -24° F, clear skies, wind 12 knots from the north, chill factor-44° F. rch 26, 1976 ~ Tests began ~.a~. 12:45 PM, but Sprague .pump problems occurred til-~i~:60 PM-~w~th lower kellY., valve testing to 5000 psig. The hydril would not test and it was decided the .packing element would have to be changed. We closed the pipe rams and tested both wing .valves on the kill line and pipe rams to 5000 psig. By 4:40 PMwe had tested both wing valves on the choke line and nine plug valves and~ forty-six flanges in the choke manifold to 5000 psig. One plug valve on the downstream side of the manual adjustable choke later leaked and will have to be repaired or replaced as noted on the field inspection report. The manual adjustable choke was free moving and the SWaco superchoke actuated. In the interim Shorty Allen replaced Don McKelvey as Arco drilling foreman. . At this point in time we talked to. Russ Douglass who.reported mechanical problems on BP's ~C' pad and we discussed probable .upcoming BOP tests at Arco DS 9-3, MObil Kuparuk, and BP GS-3A.. We also talked with. drill .site #9 who reported they were doing a primary cement job and-it would be sometime tomorrow afternoon before BOP tests would be initiated. We toured t~m location which~was well organized., the rig in good repair, the reserve pit well built, stee)~ welded fuel tanks not~.,bermed and the well sign not yet received from Anchorage, We then checked ~th.e accumulator which tested to 2400 psig. N2 bottles tested to 700, 100-, 1800, 2100, valve problem, 1800, 1'800, and 0 pstg. We also found both .dart and ball ~type valves on the floor. March 27, 1976 - At 1:00 AMWe, tested the check valve, on the kill line and the ~i'ind'i'-rams'to 5000 psig. At i:26 AM we tested the hydril to 3000 pstg. The kelly cock was tested to 5000 psig and tests were concluded at 2:45 AM. A flelct Insertion r~ was prepared ~th the ortg!nal gotng to 5hor~ All, eh, a copy m. tled to Beney Louderm~lk and a copy attached to th~s report. At 1:45 PI~ we departed drl11 st~-~,, a.rrtvlng at drtll s~te..~ at Z:O0 I~ where we met with Buddy Leenard, Arco dr~lllng .f~n, and Cbarlte Ingersaa, Rowan Rt~g ~34 tool- pusher, gt'ppt~-ng up was tn progress. " At 4:15 PI~ ! talked wttb Russ ~iass who advt'sed they could not get a/test on the ball val-ve al: lip s ¢ pad_and_ be 'would be headtng out the Hob. I Kupa uk location 'that eve~t~ for a BOP ~t. 1~ f~r: advised na rtg has, yet moved on BP's GS-3A locatlen. Tests began at 8:30 Pt4.' AccU~ta*~ter- tested to. 2600 pstg. g2 backup bottles tes~ to 2t00, Z350, g300 and 2250 psi~g. Top ptpe .rams, check valve on the ktl! l~ne aed t~stde wlag valve aa t~ cheke 1the'res .ted to 5000 pslg. Bottom p~pe raes tested to .50~~ ps~g- Bl~nd rams, ~ng valve on the k~'11 11ne~ and outst~ wtng valve oa ~t, be choke 11ne tes~ to 5000 pstg. Ten. va]yes and forty-eight flanges tn tbe.cho~...~!.¢old tested to 5000 pslg. The-manual adjustable ~..-was free~ ~ng and. the Swaco superchoke ~Frs actual. Both ball a~d dart type fleer val~es were amuated tn a rack ;~ust !n front of t~ dramm~s~ At 11:45 Pal ~t was fou~ the kelly ~s Croze~ tn ~ rathold and stemntng operations began. Kelly' was-f~ally ptc~ed up, adapte~ subntppled up and kelty ftlled ~rlth dtesel. ZS. 1976 - ]~n the tn.tertm we toured' the locattaa which was well organt~, p~t ~11 ~lt., r~g tn ~ re~l~, ~1 ~ld~~ f~1 ~nks ~t and t~ ~11 st~ ~t .~t ~et~ f~ ~hora~~. Tests resumed at 12=~/Lq wtth the lower kelly valve testing to 5000 pstg. At i :00 AI~ kelly c~k tes~ to ~ ~ps~g. Attempts to screw back ~nto the test pl~ug tn erder to test-the .h~l .~ untt'l ;~:Z$ AM ~ the h)~lrtl tested to 3000 pstg a~ '~ts. were..-co~lluded', A ffeld Inspection report ~as-prepared, the ortgtnal gtven to Beddy Leonard, a copy matled to Benny Leudermtlk and a copy attached to thts report. Departed Dead~orse at 4:50 PM via :~en Fltght ~20 arrtvtng and at ~ ~ at 7::00 !n suasary ! ~-itnes~ BOP' tes~ at Arco locations OS 4-9 and DS 9-3, Attac~aent - ~ a an as Conserva o~ni tree ~ : Field Inspection Report " Prig. --Permi.~ No.~~ ~-~ r~ Wel 1/~m Ser,~% T~ '?~' Oper'ator ,~/-J~. o~ iRepresented- by?~m:-~?,_~ Name &' Number ~.~,~ _..~ ,~ ~ ..--'.L...,,?-;~?-..,..... ~._ Inspec.tio~°~/_ ~q~'~' _~-~._ ~,~.:~,~. ~.-~'~-.'~ Sat~ s'ffactory Type- Inspectl on Satisfactory Type Yes No Item ( ) Location,General Yes 'No Item (~q~OPE Tests 1. Well Sign ($~)~ ( ) 15./~4~'Casing set 2. General HOusekeeping (~ ( ) 16 Test fluid-( )wt~ ( )mud (~)"oil 3. Reserve Pit-( )open( }filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wel'ls ( ) Well Test Data 7. Well NoS. , ,__,~ 8. Hrs. obser ,__, 9. BS&W __,__,__,__ 10. Gr. Bblst , , ( ) Final Abandonment (~() (~)~ ( ) (~() (~- ( ) (~)~ ( ) (,.)~ ( ) (~() (~( (~(') (,~ ( ) 11. P&A Marker (~ ( ) 12. Water well-( )capped( )plugged (~,~"~ ( ) 13. Clean-up (~'~"'() 17. Master Hvd. Control Sys.-,~ff_~_~_psig 18. N2 btls.;~m ,~,~____~&~psig 19. Remote co--n-{~-ols 20. Drilling spoo]-___~"outlets 21. Kill Line-(~,~ Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs_~__flgs~ 24 Chokes-(~-~ti~emote(' )P.,os.(~dj. 25 Test Plug-(~q~ellhd( )cs.o( )none 26. Annular Preventer,~sig 27. Blind Rams 28. Pi pe Rams,~z~_____,_PS i g 29. Kelly & Kelly-cock-~"'~.:-.:,~ psig 30. Lower Kelly valve ~,~psig 31.'Safety Floor valve~-(m,~V (~d)art ( ) ( ) 14. Pad' leveled (~)~ ( ) Total inspe, ction observation time ~ hrs/~,a~y~ Total number leaks and/or equip, failures Remarks ," "~ , ' ' l~,~.~ ~.~.,,,u ~ -~,.~."~,~..'~, ,~.':?~,~'~,F .~~'-'~ Notify in days or when ready Atl~tic RJch~Jeld ~. S~te ~t He. 763O C. R. ~tes P. O. Box ~ Ar~cl~-~e, Alask~ 99510 ~r Str: Encl~ ts the appro~ appltcatl~ for permft to drt'11 the above referenced - well ~t. a !ocatl.on '1r~ Sect, ton ~, Townshtp 11tl, Range 15E,. t~11 ~les, core chlps and a 'mud lng are r, ot required. A directional survey ts requital. · ~ny rivers tn Maska and their drainage systems have been classified as import, ant for the ~!ng or migration of anaoYomous fish. Operations tn these areas are sub~ect to AS 16.60.870 and the regulatt~ promulgated ~~der '(Tttle 5, Al'aska.Adm!ntstrattve .Code), Prior to coe~enctng operations ~ may .be cen~c~ by the 14abttat Coordinator's offtce, Depart- merit of F~tsh. and ~, Pollution of any waters of the. State Is prohlbtted by AS 46, Chapter 03, Article 7 and ~ ~l.atJons ~_p~.lmulgated the~under (Tttle 18, Alaska . Administrative ~, C~pter 70) and by the Federal Hater Pollution Control Act, as amen~, Prior to c~tng operations you may be contacted by a ~sentattve of the Depart of Envt.~tal Conservation. Pursuant to AS 38.40, Local Ht~ Under State Leases, the Alaska Department of Labor Is being not~fted of the issuance of thts permtt to dr111. To aid us In schedulfng fteld ~, we would appreciate your nott'_f~_tng th.~s orifice wtthJn 48 ~ after '~ ~ell ts s~. t~ would also lJke to oe not~fle~ so that a represen~ttve of the Olv. t'ston may be present to wltness testtng of bl~ut preveater equipment befoee surface castng shoe ts drtlled. C. R. Knm~les 2~ March 15, 1976 In the-event of suspensto~ or abandomaent please gtve this office adequate ~V~I~ nettfication so that. we may have a witness present. Very truly yours, O. K. Gilbreth, Jr. ~ Chairman . Alaska Oil and Gas Coaservatton Committee Enclosure cc: ~partment of Fish aad Game, Habitat Section .w/o encl. Oepartment of Envirmmmntal Conservation w/o eric1. Oepartment of Labor, Supervisor, Labor Law Compliance l)ivlston w/ en¢l. AtlanticRichfieldCompany North American L lucing Division North Alaska Dis~Sict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 25, 1976 ~. O, K, 6i!breth State of Alaska Department of Natural Resources D~v!sion of 011 and Gas 3001 Porcupine Drive Anchorage, ~AK 99501 RE: DS 4-9 Dear Mr, Gilbreth: Enclosed herewith is our Application for permit to Drill DS... 4~, a $100.00 ftli.~.~' fee, and the required surYe? plat, For your information, as well as for the State ~Department of LaBor, the surface location is on Lease ADL 28325 and target location is on Lease ADL 28324. Both of these leases have an effective date of October 1, 1965, with a temination date of March 27, 1984. Ye~~ tru!F yours, C, R, o,wles D~.trict Drilling Engineer .F~closures ~-TATE 07 ALASKA ~Otl~er mstruetionl o~ reverse s~de) 11. TYi~I~ Or WORK OIL AND GAS CONSERVATION COMMITTEE PERMIT 'IO DRILL. OR DEEPEN DRILL [~q DEEPEN O API # 50-029-20207 '~, ~ , ~ ~ ,, ADL 28324 ~Jl IF INDIAN. A.I~L~-il-~:i5 OR "r'R.LBE b, T?Pg or WgLL °" °" [2 , w~L ~ ...... WELL O?HBB ZOmm. ZOOm 8 UNIT FARM OR LEASE Z NAME OF OP~TOR P~oe Bay ATL~IC RI~IE~COb~ ' ~.... . [i~ ([a II..!, jj ~,;J ~i ~~ ~ WELL NO. BOX r~c[ ......... N, R15Eu~ [~ r. t~f~~i~ ~ochit ~'~"~' 325~ FSL & 643' FEL Sec 27, 1~19510 l.~k '; . t.:;l]~, n~ ~,= ~oo~. o, J_ HOL~ O~ECTIVE) 1320'N & 1320'W of SE cr Sec 35 ~lSl J Sec 35, I ' [ll. ! Approx~ately 6-1~¢ m~es Northeast of Dear. rs, I~. BOND INFORMATION: ,~p~ Statewides~.,,~.~,o~o Federal Insur~ce Co. ~8011=38-40 ~o=~ $100,000 I5. DISTANCE FROM PHOPOSED' IlO. NO. OF ACR~ IN .LEASE 17. NO. ACRES ASSIGNED ~.o~;~ o~ ~.s~ Lmm. ~. ~ J 2560 ,~,~o ~o ...... ~ ~,~. ~.~. ,f ..,) 1320 320 , 18. DISTANCE F~OM PROPOSED ~A~ON* 11~. PRO~S~ D~ ~. ~OTARY OR CAB~g TOO~ TO NEAREST WELL DRILLING, COMPL~, I OR APPLIED FOR, 2400 * I 12 ,2SO* ~ta~ ~7508: sx 21. ELEVATIONS (Show whether DF. RT, CR. et,.) 19.$ pad. S2' RKB PROPOSED CASING AND CEMENTING PROG~ 22. APPROX. DATE WORK WILL. START' March 27, 1976 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE [ S~ITL~G DEPTH quantity of cement 52,, 20- "r' 94# 'H:.40 100,_+ Cir to sur~.'. ~pprox. ~00 sx .- 17-1/2,, 13-3/8,, 72 L""80 2700,+_ " " " " 5500" 12-'1/4" 9-5/8 47 "sog-95"10'950.i'~ · 120~' cement column"of 1st stg~ q L-80 3,,.00' ant colum on snd stg -i. i.2~' _} 8-1/2 '. .. 7" Li. ner[" ' 2'9 . L-80 .12',2.56...'[cm.t to liner top approx t 270 The Atlantic Richfield Company proposes to directionally drill this well to 12250'MD~_, 9200t TVD, to produce the Sadlerochit zone. Logs will be run across selected intervals. A 20-3/4", 2000 psi Hydril ~ill be used on the' 20" conductor. A 13-5/8", 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A non- freezing fluid will be left in all uncemented ann'uli within the permafrost interval. A 5~-1/2 single completion will be run & the well suspended in an unperforated condition. I1~ ABO~ SPAC~ DI~'rlRIBE I~ROle~OSED PROGRAM: 1El proposal is to deepen give dam on present pr~luettve tone and proposed ruew pro-duc~Ave zone. _l~_~_ro~o0sa..l m to Orill or ac, pen direr, tonally, give pertinent.cLara' on sUbsur[aee l~tlol~ a~d measure~[ m~d t~ue vertical de~tl~. Give blowout prev-e_n~er' program. certify at t e Foregoing True an~ Correc~ SIGNED , . , (This space for State of/ice u:~et tSAMPLES AND CORE CHIPS RE. gIFteD vm ~ NO DI~ON~ SHRV~Y R~~ CONDITIONS OF APPROVAJ.,. IF Alit: JMUD LOG O w~ 7a~o A.P.I, NTJM.ERICAI~ CODI[ 50-029-20207 m~,r .o .... 76- 30 APPROVED Bv ~ .~ov~v^~ March 15, 1976 Tm.=. Cha i rrna n *See lammc, on. 0~ Revefu Side 27 1 ! L -I 26 $5 SECTION 26, 27, 5 4 8~ 3,5 T. '11 N., R. 15E., U.M. WELL No. ? LAT. ,'70° t6' 18.348,.5 LONG. 148° ~ 6' 59. 8785 ASPC ZONE 4 Y 5 951 945.88 X 7t2 235.09 8 LAT. 70° IS' 19.5028' LONG· t480!7'00.GI44 Y 5 952 06;).48 X 71;~ 206.52 9 LAT. 70° 16', 20.652 LONG. 148° i? 01.344 Y 5 952 178.52 X 712 178.18 9 643' 618' 593' :5i35 SCALE 1" = 300' · . CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PRCPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY- MADE BY ME OR UNDER MY SUPER-- VISION, AND ALL DIMENSIONS AND OTHER DETAILS - ARE CORRECT. DATE SURVEYOR A'FE 292931 ASBUILT ATLANTIC RICHFIELD CO. DRILL SITE No. 4 WELL NO. 9 - Located in E I/~.., of PROTRACTED SEC. 27, T. IIN.,R. ISF-w UMIAT MERIDIAN ALASKA PREPARED BY HEWlTT V. LOUNSBURY I~ ASSOC, 723W. 6th. AVE., ANCHORAGE, ALASKA BATE ,)AN.. 8, 1975 SCALE . NOT, ED CHKD BY G.D. FIELD BK .I.,.F~ CHECK LIST FOR NEW I'IELL PERMITS 1. Is the permit fee attached ..................... 2. Is well to be located in a defined pool .............. 3. Is a registered survey plat attached ........... 4. Is well located proper distance from property line ........ 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... ~ Is well to be deviated ....................... 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day wait .......... 10. Does operator have a bond in force .............. ll. Is a conservation order needed ................. 12. Is administrative approval needed....' .............. 13. Is conductor string provided ......... · . . . ~ .... . 14. Is enough cement used to circulate on conductor and surface .... < , Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... all casing give adequate safety in collapse, tension & burst 18. Will 19. Does BOPE have Sufficient pressure rating '. ............ Additional Requirements' Company em/~a r~k~ Yes No R Lease & Well Approval Recommended' Geoloqy Engineering.' TRM ~ HHK/~.~g OKG _~.~ ~HH JAL' ~o~_~ LCS'~/~Z~" JCM ~ Revised 1/15/75 Well History File APPE'NDIX 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS · , Well D.S. 4-9 Field Prudhoe Bay Couney, Stare North Slope, ~ska ,~ Dare 7/Q9/8~.. Curve Name (Abbrev.) S~andard Curve Name Logs Used Scale I I Files 1-3 ~ '. ! CCL ! Casing Collar L°cator CN - Multispace -~- I CN I Compensated Neutron " 60 - 0 I SSN , Short Space 50 - 550 t LSN Long Space " , ~ 0 - 20O I GR Gamma Ray' 0 - 100, 100 - 200 File 4 -, ' · CNAV Average CN " 60 - 0 . . · TIME LO~¢ RECORDED: AVERAGE 5~.7 62.! · 2~ ~ 1'27 s, l~g 4. 6'3 0 56 11450. 113.$ I C",S. 1 ~7 ~ -~ ~6,~ :i: !:.:~,' 0....~..~ ~. ~ ::~'~ 3:-~'~, 5. 5 ~ .-o 1145~. 113.7 104.8 27.! 26.~ 135.9 135.7 ~2.5 70.8 72,9 11~56. 115,4 99,3 28,6 24.4 132,9 130,7 54.5 62.2 "; ~-¢/;~ ~ ~'~ ~ ~:.'~ ~ '~ '~'~'~0' t-64.7 23"~ 28,6 ~41'~2 ....~9' ~ ~,7 ?',9'.~ ~;.n Z5~.ff ~'61J'R ~,.~ ;26.1 11470. 35.7 71 .2 68.1 72.3 77.7 5B.4 53.0 30.5 25.9 21.9 23.4 24.4 '26.1 25.5 2,~.7 -_.7.7 27.7 24.4 114'74. 25 1 23 476 · 11 478. 23.2 2!3 ~ ?.5. 11480. 2t .5 I 8.3 26. 27..6 27.~. 26.7 ·© :,-1~ :::~ ~'- .~i~ ~ ;: 2' - ' '~ ~:51':,~ii:' .~, ¢.,., .~:,,.... : ,, .-. < ..; .: . 11488, ~0,6 17.3 93.5 99,2 243,3 ."~;$~8~,:,. , -! ~.:8 9¢:-,, ~'. ~'-. I I ~y4"":X ':~': '. ' 2~,.~' ,3..~ ' ~'c~';' · ~, "~''~ · ~ ( :~- ~'. '~' ..... - "::,~:::!::f:!: ~::: ~ :::' ~O.., S ;:: ;20,:-:~: ;':"- ;',, 9~.:-5; '.,': <,' ;.~ ~ ', '~' ~:.. . . - ' ,,: - - · , ' , ,, ' 114~6. ~70.2 16.6 :fi1,2 8~,.2 Z21.5 ::.~:,_ ~:'~::- .;~ 4,~'9-. · ~6 :0"~.~3~:8 6 .2.6,2 1' Z~+.~ 23.5 22.5 22.2 23.0 24.9 26.2 24.3 23.1 23,8 Z6.9 'UEUTRON ©. Z$. 0 .4 '~ '- ..... "~ ' ~ ,-, ~ , 4~' ' ._~-?a ' '~ -~/,~;~ ' ~.6.6 27.2 · 21, 21 .3 22.1 2 Z. Z p p -z 21 .g Z} · 5 ZB,7 25.5 26,4 26,5 26,4 :' 5, C- £7.g Zb. 5 ¢. ~,. 5 ?5.2 23.7 23.9 ~5.6 .°.5.3 £6.5 Z6.~ Z.-5. ~ 6 2 28,1 _,, .... , .~ r:~.4 ~2.":: ~l~ 7 ?"'-/ ! 7';, 4 27. 11552. t7.7 17.2 79.2 74.2 2!1.3 226.0 28.¢ 50. 11554. 72.1 ~ ~ ~ O' 115~0. ~o. ~: ~ ,~ '~ 55.~ ~92 ~, 1~~ S 32.~ 32 115~6. Z2.0 17.~ 55.6 ~,3.2 1'~9.2 230.'3 36.S 3~. 35' 11570. 11572. !9.1 1~. 11574. t7,t 11576. t~.3 11578. 2!.1 7 '>7 '~ w ~.... 2 28.3 m 79 4 ~9 0 4 2~.0 t 2-°,2 1 ~1 7 31,5 33.1 33,6 32..? 32.2 31 .! 30,8 32.8 34 · 0 35.? 34.6 38.0 34.5 lS 34.2 ) 37.4 r..7 3/,.1 32.6 I I > · ~ r · u ..... ¢. 34.1 1'I 58 ~ .. , 19.2 15.~ 57. . 3 ~.':-~- _.'; 1~3.7. , t~1 . ~. 33 . ~. 33 . t 3~.2 ~15~!. .... ~.~ 27., .,7.7 ~,., .... q ~.1 ~0~.-.. 3. · , 38.8 35.3 34.2 36.8 35.0 ~.3. 35. 34. 33.7 32.3 36,7 'NE!JTRON AVERAGE ~.~SS ? "~' ~ ~'~ 1 '~2.'~ 33,0 , ·: 51 , ! t7. ? "¸3 to! ,2 33. a. .1 37.7 39,4 38,2 .) 31,2 33,4 11632. 32.4 .5 a . .j AVERAGE % % .77.9 29.1 29.2 2:3.1 29.4 29.1 31 33.0 3 Z.. 'r 30.1 30.9 30.7 30.8 33.3 31 .4 28.3 ]0.7 34.8 3.5.0 32.2 1166~.~ .'q · 61 . 39.© 11672 11674. 4! ~ 34.6 ~.7 ~ 3 .8 41.6 11670. '~6~ .7. 7 O ,.. ~, "~ 3.8.. 40.5 155.7 150 . S 43.©,..., 40.2 ~ ~ , i ~"' ~ .9 44,~ 40.2 t 1.679 9. D , Z. 7 . ~,.,5 ~9 .... 1, ~.3 158..~ ..... 2 110;~0. ,.,,'1.~' 66.I 5~.,,c.., 4~, .4 lS4.5 16~.9. ,'4.-'. S2.Z , .... o .... :o ~ =-~: ., · m ~, : , , ~o '--:,,,:..r.,':~ :- ,,~ ¢ ~ ~ ,~ & ~o~ ? t97.7 ~)6.~, 32.7 38.5 ~9.~ 37.5 38.5 41.7 4Z.o ~2.~., 41 .4 33.3 29.6 34.7 35.3 11686. '~.3.6 x." ? 4? ~ 53,g 167 O ~., ~,L~~ m ~ i ~ i -,_ i -~ i - 8'7~:- -65',6 65.$ 4:5~7 · a?..3 !: ,2 7t:1::691:, -. 4!;3 :.~2o$ - - 54,~ 58,9 19'9,0 ;,193.S 37.5 34.7 36.1 .4 ..,~:,4,. 5 I .4 <;'5.?, 3! . 0 30.1 29.0 33,3 34-6 35.x., 34 · 9 30.3 31 .7 2S.~ 33.2 31 .S ,4 ..-_~: .U 57, 49.8 46.5 38,2 41.4 37.5 · r , :? 0 D ~8 7 38.1 .4 3~.6 ~9.~ ~37.8 38.8 .3 38.8 ~2.5 51,5 47. ? ~ 5, ',7, 45. 48. 47. 44. ,, 11740 ~Z 1 ?,3 O z~, I 40.4 t~'g 4 159 R ~-3 9 ;'~, ~ .... :' "' ~.C" "~-: - ~ p~ ,,,,~'. -.~.,,,,'::, -} ,,..' :.~,'~ ,,[ ~ ~' .: ';l~' .;' 7' '"~' ~;'"' "' ~T:.~':Z~.~,~: ";~ ~:~:.~:-~.':s : ~,.Z .,- . 3:'~~, 5- - ~8,-0 $~Z. Z. -~ 5.6.,1 4 t · 2 11~ ~1 1 6~.5 40 6 ~7 1 15~.2 t51.~ ~o ~ , ~ ~ i ~ ,~ ~ ~ ~ .~ .,, i '_.' AVER/~GE ,. % 45.0 4~.5 ~4.3 42.8 11744. 17~. O. 1'D~,. _.~ ~, ~ .3 3~. ~ 1~:~., ~ . ~. 15D~ . 1 _~,8 . '3 42.2 40.1 1174~. tOZ.~ 1U-,;. 1 ~7.~ 46.4 lol .~ t 73.., ~3.7 .... 5 4.6 '-"'"117-8-. '~'~ ::' '"'~', ~.~ '~' ' ' .,~': ...... ' ~'~' ." ~- '/~U-' .-' I .,T. ~ I .53 ...... , I . ,. 41 ~ ~ 1 -:'~:>!~;~'7~:-,:: )'Z~'~t: :~'S-':}}.-~:3.~::' :.aO, a:: ~:6O,O ~)~.0 38.7 · 2.r,:lq:::7:s'!?::~/: ':: ,?"~3',-:-~,_~ ~ .... .~,~.,~.~ :. 4~..~ q.5.~, z :~.~ ~.-,4 4,, 3 44.1 43 '"" '117D~.:~"' *>.,/'": ~ 4~.1': "'' ~u.3 ~;~ ~'_.9.,~' '1~'o'"'~,, ....1D~.'., ~ ~ ...... 9 ' ~O 1 39 5 ,~: ~'~:. :~ ~ "- ~ :',n- ' 5~6~: ~5~,6 3Q,9 40.8 40.3 11756· 54 5 55 7 36 7 ~7 g 14~ 1 ~5~ 4 4~ .~ 43 o 43 ~ . i i , i ~ i , m . , i .~ i -.. m , i t .~ ~ ~: · ~ ~ ~ ,- ~ ' ~. : . . .~ ~ ~, : ~ . · 117D~. :-/~;;' ~'6~.~;:"'::~L' ~ .... 64.v~ 32.~' /' ::~6.! 137.~' > .... ' t~.~}'"~ ~ 4v~ .~'~ ~:'~...~ 45~ ~4.7 47.6 53.6 1 I 7.64. 50 · 4 45.3 4t .5 8 11765. 61.3 40.7 11770. 5.0 38.6 41.2 11 6c.5 65.7 43.9 46.t 173.3 17::3.5 42.4 4 .3 " ......... 1177..; .~,_,.!X~ ,' ' ~.,~':~'t ',~ .' ~ ..... ~ : ~.~..k: 1~.~"~'~ ~:~ 17.,.1' -~'-' ~n,~.~ ..~.'n 7 1177~. 59.4 6~.7 49.4 46.0 I ~2. ~ !72.0 41.7 ~0.7 · ' ' "~ ~ 'f m ~ ~ ' · · :?-~:~Z~:ZZ'::~;':~ ,:: ~L67,7.-o~,.) ~ 5:.¥,~ : l'.:.~w~ :.:9!~. !:,u 38.2 38.1 11750. ~6.7 69.~ ~0,7 46.t 173.9 175.7 39.0 42.4 . ::,.,, :~:. ,: ~ ,. ....... ,- ~ ~ : ~ . ....... ~ ~ '. ,,,- :, / ~ ~ · ~ ......... 7 9 ' ~ ' ~ ~ · ~''~ %': ':~ ~ X.- ~ "~ ......... -:'.~ ' ~" c, , ' = ? m A '~ '-:*' ~ " >, ' ' ~7 7 I t 7 c, ,,~ r . c, 9 , . .~ D 1 · ~, 4 ~, · ~ I ,..:, ~ · ~ 1 ,, ,~. ~ -., · ~'.~. ~.- ~.., .- .;., -~.: ~.., . ~ . . ~ ~ -. . , , , ,, 39.4 36.7 41.0 4,1 .'~ 42.3 ~0.'~ 39.6 41. 38. 36.3 39.4 40.7 41 .8 40. 39. 39. 3"'~. m ~.0. ALASKA PRUD~OE 3Avon AVERAGE ' 1tF~0.; .... 73.1 64.4 49.~ 50.d' 1,~'3. i 1(~5.~ 3~.~ zs.~ 39.3 / i . ~ i .... ! t¢ ~J . I i r i I., . ~ i :~ / i .+- ! I / :... ~ i I 211 -, i ~ i ' :: :t,:L?~).~:' ..-'--6!':~) .:6~.:7' ':..50'~ 8' - . ~1;..:.? 1-~3~.~-~ 8:6.9 $ 7.4 32.2 ,:i<',:., ..,4 ~, ,,' ,,., , 4:~, .-- ¢ - · , ~:--', .... ' ~ F' ~ ' .: -?.'. ....... :- / ,,:,--' v ,z .,, - . · t.,1~*.~.., :- .U..* ~¢..:'~ . 5:.~.~ : 6.1 ~. 2,dZ,,,,,: . 1~.-..5 3¢.d _..3 -' --.~ ;-" 'p :~ ¥: ~,. L. "]' :.. := .-' ' ;' ~ ("[ ::,, :'-~ ~ .~ ~ ~ ·" ~/ ~ ? ' ..... '~, r~ '~ ¢ z ~ ' , '/ : ~ -~ zg 39,5 ,. ' .,/' ,.: 2: . L . . ." . ,. :. :* :.' · ·: t16-3'~. ~6.~ 9F.5 45.~ ~6.7' i"75.5 ]75'.2 40.6 ' ' 34,5 35.2 ~7.4 37.8 $6.7 35.7 3,5.2 ~7.3 33.2 34,3 ~5,7 .} 33.0 · '-%.1:B2! ",. :"': 73~:. 0,: :6e%~ '--34,.'Z' - 189,:i0 t93.3 39,6 30.9 11,32~ ~:5 7 ~0 4 55 ~ q~ 0 237 & t:5o 4~.5 57 J¢ .U 3¢. U 54:' 8 32 38 .9 .4 .8 ,2 39.8 37.4 38.2 .10.6 3~,.7 39.8 45.6 .5.b.7 39.4 3 3.4 ARCO ALASKA TNC. D.S.4-c ?RUDHOE SAY,N.SLSD~ ALASKA ~i~:~'~/~::H:7~.: A - ' ~ON_~:' ~: ~. :~.RZ.. fi~.E. ~OMP..NEUTRON ~"~ .......... ' ~SS~' 1'~A":SS'z ~S'~'~1 F:SS: 2"~'~SS'~:'~SS Z 'P~Ss ~ ~SS ~VERAGE 33.1 33.1 33,9 11~38. 58.1 57.,5 5t.2 56.6 18-4.2 19t .T 37.1 36.6 36.:£ ;<, ~'~, 9: :~, ; )",5 ' '~51~5 DZ,) ~8~,3 18~.9 37.7 39.1 38.-4 11840. ~7 ~ 54.0 51.~ 50 ~ 1~ · · · ............ ,~.5 t8~ 9 36 7 38 t ~7.1 ::1~:$8~:~','; ;:57':'~' :58,6 D;1-;6u :51-.~ I~'~.t' 1~8,5 3o.7 42.5 39.6 , ~ . ,.,, ,, ~, , . 11~42 ~8 3 ~ S 49 ~ ~8 ~ ~t 4 ,~ 19n Z 199 1 ,~ ! I ¢, b i I ~ , i ~ i - i i i ~J i - "~. ~..~ :)~ ~'3~) ~.~" Z0t,.3 20!.8 31.0 31.4 31.2 ?.:'1:1~8'~;~":~5'6/,1:65.'2 - > :;O _-._~ ~ 70:2'1; t93";9_ 34.5 3t.9 33. '"~"'~%;~'J'~' ' ":~'~ ~ '~2 :-~ ' E'~- ~ 2~' ;~' '/,~ '~ '~A '~ ' ~= ~ 33.7 ~4 6 :2';'~/8~4-9i:: . :-::5 2 : :65 i1' s :iTJ, 60',;'6: 1: ~8' - '_'2-g~.2 35.4 34.5 35.0 '"'~" ~ ~"~"(F : XF'" 4 ~.'~ ~"' "~'4 "5' ('~'."~ ~ ~ 5 .'1" 1 c 4.7' , .:¢~ . ,~ ~ .~ ~ '~-;'~ '- , ., ::: 1:~%~5.t,.:: ..--;5-7,, ~ -~:~....~, 55.::.~ t:,.5.3 ~ 85. ? ¢ .¢. ~ 36.3 35 9 'ii:~'~ ' ='Z z~ ~5 /. S.~ "i ~E 7 ~'~'~-x® "1~0.3" '~4.$ ~5 Z 35 9 11854. 54.3 52.8 )7.1 D3.:~ 1v8.7 190.~ 35.~ 34.3 34.~ 35.6 38.0 I I 360. 57. a 3~ c 1 6.7 37.6 .0 38.5 34. 37. 39. 38. · '¢ · ,~ ~ .?..: Iff: ~::, ~z:~- ;:.' .:4.;: ::'1~Z..,~:::_~?'1.~ 4~.o 40.8 ~""i~78"~'0'-:':" i~'?','~ ' ~'~:z.':~.' '~'~:~" ': ~.'~': i'?~2o ~z~'.~ ~o.~ ~ .3' 43.5 I 1 ~72. 17° 9 1 3p A 5 P i 46 6 ~04, ~ I ~7 4 42 9 40 6 41 11.~74. 1~>.~ 1~e.o ~'~.:, )6.c ,'~D.u' 1~7.~ 4~.a .._. 0 ~9 1 ~!:': 5,'~::"' 5;:5--.~ ,,~ ~-::~:~. i.'5~ ::~31~:':!~5.,5 ~3.2 38.2 40.7 . , ~ ., ¢ . ~ . ~ .' · ~,~., ~. ~, . ~.' . ~ ~ "1187~.~ 'I-S9.~ "i72~'5 '55.~9 62.5 't97.4 21~.i '" 35.2 33.8 34]5 . <~ :~. '~.. ~ ~ .x ~ .., · ~. ' ~ ' Q7 · o 7 ...:': ~::~/15 ~ :. :1 ,5 x. 5:~5 53: :/' 1~8 :-:I98-.~ 38.3 3 9.1 38.7 34.5 '4 54.2 33.1 ""Y . ¢3. o 34,9 3;, 4 3 $. 34.5 z.~ 4 41 .; 42.e 4?.0 41 .9 5,5.1 36.5 3 S . 9 30.5 41, 41. 45, 44 . ,5 ,, 47.1 49.3 45.6 44,~ 41 .7 ! -,, f.~. 40.9 4 4.6 43.1 47 4 · · 7 53.3 4~.5 51,4 51 ,5 41 .8 42.4 &5.4 44,1 45,9 45.1 35.6 .33 .? 35,7 35.! 57.2 3Z',4 55.3 35.0 53.1 55..~ ~RCO ALASK~ ,TNC, PRUDHOE B~Y~N.SLOP.E ,~VERAG~ 29.6 :~9, ;~:~I:'~'9 ~ ,1:: ~3~ ~; ~ :~.5':;:~/.:'. 6~,~q 1~9:~,~',~. ~ 9,5:.~ ~8.6 30.6 "~:"I'93~" 1i6.'5' '!:04.7 "63~7 ' ~..7' i'95.3 i97.4 29.6 Z~.~ 29.~ i" S~': ~1~1.~0'~:0~.n ' ~.~ ' 5b.'O" lOZ.4 tVX.9 "2.~ 3S.X 3~ 0 '; ........... .-'~. ". .... ......... . , ' . '. ' - -. ' '', ~ ' ' ~3 31 .6 'l lY40. I I a.'lYY?'¢¢. J ,b!.U :,~.~ 1'~.6 1x5.~ _.1.'~ ;..~;.I: .' .d 93:'.8 33.0 30.6 31 .8 i I ¢4~. 1 ........... ~ .... ................. 6 3 30.4 30.4 11944 1t,~ 409909 a 62 5 63 O 19~ F lO7 ~ ~0 2 O a 15 ~ I . ~m ,-' r I'~ · ~ . t ..- I ~ I I ::': 'I: ~'.9;:~.~ ~:~'. :':_:I ~8i:~-99'~.,.0:, :' 51:"~3.:I 'L~- -1 i 54995'0 · 7 31 . 3 3.8 I 7.6 11946. 113.4'~a909 ~ ~2 4A54~8 5 1~5 &6~''''p 5 30 ~ ~ .~ 17 1 11950. 11S.499~99.d r' '61.06~458.5 1~'4.06530Z;5 3! ,1 3.8 17.5 HALL/BURTON £ OGLING $~R VIC~S,/NC. OA Halliburton Company LIS TAPE VERIFICATION LISTING LDWG FORMAT Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/03/24 --- ANCH --- 832007 ****************************************************************************** TAPE HEADER RECORD .............................. TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/03/24 --- ANCH ~ 0 ****************************************************************************** COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: 04-09 API NUMBER: 500292020700 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 24-MAR-93 JOB NUMBER: L83200-7 LOGGING ENGINEER: McCARTER OPERATOR WITNESS: T. ALLEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 325 FEL: 643 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 52.00 DERRICK FLOOR: 50.00 GROUND LEVEL: 15.00 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) 1ST STRING 13.375 2654.0 72.00 2ND STRING 12.250 9.625 11090.0 47.00 3RD STRING 8.500 7.000 12050.0 29.00 PRODUCTION STRING 8.500 5.500 10722.0 17.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BCS PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH ........... PSGT 11437.0 11437.5 11461.5 11462.0 11477.5 11478.0 11517.5 11518.0 11570.5 11571.0 11625.0 11626.0 11664.5 11667.0 11726.0 11729.0 $ REMARKS: TIED INTO SWS BHC DATED 02-MAY-76. FILE ORGANIZATION: FILE 1: EDITED PASS i DATA ( .50 FT DEPTH INCREMENT ) FILE 2: EDITED PASS 2 DATA ( .50 FT DEPTH INCREMENT ) FILE 3: EDITED PASS 3 DATA ( .50 FT DEPTH INCREMENT ) FILE 4: EDITED PASS 4 DATA ( .50 FT DEPTH INCREMENT ) FILE 5: EDITED PASS 5 DATA ( .50 FT DEPTH INCREMENT ) FILE 6: AVERAGED PASS 1-5 ( .50 FT DEPTH INCREMENT ) FILE 7: RAW DATA OF PASS i ( .25 FT DEPTH INCREMENT ) FILE 8: RAW DATA OF PASS 2 ( .25 FT DEPTH INCREMENT ) FILE 9: RAW DATA OF PASS 3 ( .25 FT DEPTH INCREMENT ) FILE 10: RAW DATA OF PASS 4 ( .25 FT DEPTH INCREMENT ) FILE 11: RAW DATA OF PASS 5 ( .25 FT DEPTH INCREMENT ) FILE 12: COMPUTED DATA FILE ( .25 FT DEPTH INCREMENT ) $ ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 93/03/24 --- 1024 --- LO ****************************************************************************** Page 3 COMF-~ NT R~CORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 11725.0 11439.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #1. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 i 66 1 5 I 66 1 8 4 73 60 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 832007 GAPI LIRI PSGT 832007 COIR PSGT 832007 AP1 CODE FILE# 00000000 0 00000000 0 00000000 0 00000000 0 SIZE 4 4 4 4 ~SAMP REPR. i 68 1 68 1 68 1 68 Page 4 STUN PSGT 832007 00000000 0 4 i 68 ITCR PSGT 832007 00000000 0 4 i 68 HPLI PSGT 832007 00000000 0 4 I 68 TCCR PSGT 832007 00000000 0 4 1 68 OAI PSGT 832007 00000000 0 4 i 68 SIAI PSGT 832007 00000000 0 4 i 68 RIC PSGT 832007 00000000 0 4 1 68 KIC PSGT 832007 00000000 0 4 1 68 HIC PSGT 832007 00000000 0 4 1 68 SIIC PSGT 832007 00000000 0 4 1 68 CLIC PSGT 832007 00000000 0 4 1 68 CAIC PSGT 832007 00000000 0 4 i 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 i 68 FERC PSGT 832007 00000000 0 4 I 68 TMDS PSGT 832007 CU 00000000 0 4 1 68 TENS PSGT 832007 LB 00000000 0 4 i 68 TEMP PSGT 832007 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11725.000 GRCH = 62.619 LIRI = 1.454 COIR = .502 STUN = .007 ITCR = 5173.593 NPLI = 1.343 TCCR = 5971.042 OAI = 2.905 SIAI = 4.980 RIC = .866 KIC = .396 HIC = .074 SIIC = .055 CLIC = .018 CAIC = .001 FEIC = .090 SIC = .092 FERC = 2.594 TMDS = 41.244 TENS = 1546.138 TEMP = 12.500 DEPT = 11625.000 GRCH = 106.399 LIRI = 1.402 COIR = .471 STUN = .007 ITCR = 4987.434 HPLI = 1.249 TCCR = 6587.992 OAI = 194.444 SIAI = 19.555 RIC = .757 KIC = .408 HIC = .085 SIIC = .062 CLIC = .025 CAIC = -.003 FEIC = .083 SIC = .100 FERC = 2.312 TMDS = 22.628 TENS = 1546.138 TEMP = 12.900 DEPT = 11525.000 GRCH = 15.574 LIRI = 1.356 COIR = .480 STUN = .007 ITCR = 5308.834 HPLI = 1.245 TCCR = 9118.266 OAI = 3.707 SIAI = 3.349 RIC = .582 KIC = .398 HIC = .072 SIIC = .076 CLIC = .016 CAIC = .002 FEIC = .082 SIC = .101 FERC = 2.408 TMDS = 14.158 TENS = 1520.976 TEMP = 13.300 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER --- COMCEN.001 Page 5 DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 93/03/24 --- 1024 --- LO --- COMCEN. 002 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 --- 93/03/24 --- 1024 --- LO --- COMCEN.001 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 11726.0 11441.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: O1 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 11442.0 11441.0 11462.0 11462.0 11478.0 11477.0 11518.0 11517.0 11571.0 11571.0 11626.0 11625.0 11667.0 11666.0 11729.0 11728.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #2. $ LIS FORMAT DATA Page 6 DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i 1 66 0 2 I 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 832007 GAPI 00000000 0 4 1 68 LIRI PSGT 832007 00000000 0 4 i 68 COIR PSGT 832007 00000000 0 4 1 68 STUN PSGT 832007 00000000 0 4 1 68 ITCR PSGT 832007 00000000 0 4 1 68 HPLI PSGT 832007 00000000 0 4 i 68 TCCR PSGT 832007 00000000 0 4 1 68 OAI PSGT 832007 00000000 0 4 1 68 SIAI PSGT 832007 00000000 0 4 1 68 RIC PSGT 832007 00000000 0 4 1 68 KIC PSGT 832007 00000000 0 4 1 68 HIC PSGT 832007 00000000 0 4 i 68 SIIC PSGT 832007 00000000 0 4 1 68 CLIC PSGT 832007 00000000 0 4 1 68 CAIC PSGT 832007 00000000 0 4 1 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 1 68 FERC PSGT 832007 00000000 0 4 i 68 TMDS PSGT 832007 CU 00000000 0 4 1 68 TENS PSGT 832007 LB 00000000 0 4 1 68 TEMP PSGT 832007 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11726.000 GRCH = 134.027 LIRI = 1.367 COIR = .469 STUN = .007 ITCR = 4905.424 HPLI = 1.267 TCCR = 6304.889 OAI = 5.919 SIAI = 11.205 RIC = .778 KIC = .403 HIC = .072 SIIC = .059 CLIC = .020 CAIC = .004 FEIC = .087 SIC = .099 FERC = 2.291 TMDS = 28.593 TENS = 1495.813 TEMP = 14.200 Page 7 DEPT = 11626.000 GRCH = 111.374 LIRI = 1.406 COIR = .468 STUN = .006 ITCR = 4950.221 HPLI = 1.266 TCCR = 6543.297 OAI = 209.460 SIAI = 21.404 RIC = .757 KIC = .407 HIC = .085 SIIC = .066 CLIC = .018 CAIC = .000 FEIC = .081 SIC = .098 FERC = 2.357 TMDS = 25.521 TENS = 1546.138 TEMP = 14.900 DEPT = 11526.000 GRCH = 34.776 LIRI = 1.328 COIR = .482 STUN = .006 ITCR = 5743.626 HPLI = 1.105 TCCR = 9458.682 OAI = 3.118 SIAI = 4.463 RIC = .607 KIC = .394 HIC = .071 SIIC = .076 CLIC = .014 CAIC = .004 FEIC = .089 SIC = .108 FERC = 1.843 TMDS = 14.258 TENS = 1512.588 TEMP = 15.600 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 93/03/24 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 93/03/24 --- 1024 --- LO --- COMCEN.002 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH Page 8 PSGT 11726.0 11437.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH PSGT 11437.5 11437.5 11462.0 11462.0 11478.0 11477.5 11518.0 11517.5 11571.0 11570.5 11626.0 11625.5 11667.0 11666.5 11729.0 11728.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #3. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH PSGT 832007 LIRI PSGT 832007 COIR PSGT 832007 STUN PSGT 832007 ITCR PSGT 832007 HPLI PSGT 832007 TCCR PSGT 832007 GAPI API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. i 68 1 68 1 68 1 68 1 68 I 68 1 68 I 68 Page 9 OAI PSGT 832007 00000000 0 4 1 68 SIAI PSGT 832007 00000000 0 4 i 68 RIC PSGT 832007 00000000 0 4 i 68 KIC PSGT 832007 00000000 0 4 i 68 HIC PSGT 832007 00000000 0 4 i 68 SIIC PSGT 832007 00000000 0 4 I 68 CLIC PSGT 832007 00000000 0 4 I 68 CAIC PSGT 832007 00000000 0 4 1 68 FEIC PSGT 832007 00000000 0 4 I 68 SIC PSGT 832007 00000000 0 4 i 68 FERC PSGT 832007 00000000 0 4 1 68 TMDS PSGT 832007 CU 00000000 0 4 1 68 TENS PSGT 832007 LB 00000000 0 4 1 68 TEMP PSGT 832007 DEG 00000000 0 4 I 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11726.000 GRCH = 148.308 LIRI = 1.390 COIR = .484 STUN = .007 ITCR = 4629.356 HPLI = 1.266 TCCR = 6054.277 OAI = 6.627 SIAI = 12.364 RIC = .765 KIC = .392 HIC = .073 SIIC = .056 CLIC = .014 CAIC = .002 FEIC = .091 SIC = .098 FERC = 2.744 TMDS = 32.639 TENS = 1529.363 TEMP = 16.500 DEPT = 11626.000 GRCH = 115.312 LIRI = 1.413 COIR = .479 STUN = .006 ITCR = 5247.601 HPLI = 1.264 TCCR = 6836.396 OAI = 240.001 SIAI = 24.635 RIC = .768 KIC = .405 HIC = .084 SIIC = .068 CLIC = .019 CAIC = -.001 FEIC = .082 SIC = .098 FERC = 2.203 TMDS = 26.996 TENS = 1546.138 TEMP = 17.300 DEPT = 11526.000 GRCH = 55.518 LIRI = 1.355 COIR = .472 STUN = .006 ITCR = 5225.508 HPLI = 1.282 TCCR = 8828.246 OAI = 2.881 SIAI = 3.631 RIC = .592 KIC = .396 HIC = .072 SIIC = .075 CLIC = .014 CAIC = .004 FEIC = .083 SIC = .098 FERC = 2.381 TMDS = 14.296 TENS = 1520.976 TEMP = 18.100 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 --- 93/03/24 --- 1024 --- LO --- COMCEN.004 Page 10 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 93/03/24 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 11726.0 11439.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 11440.0 11440.0 11462.0 11462.0 11478.0 11478.0 11518.0 11517.5 11571.0 11570.5 11626.0 11625.5 11667.0 11666.0 11729.0 11728.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #4. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: Page 11 TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 88 4 1 66 1 5 I 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT GRCH PSGT 832007 LIRI PSGT 832007 COIR PSGT 832007 STUN PSGT 832007 ITCR PSGT 832007 HPLI PSGT 832007 TCCR PSGT 832007 OAI PSGT 832007 SIAI PSGT 832007 RIC PSGT 832007 KIC PSGT 832007 HIC PSGT 832007 SIIC PSGT 832007 CLIC PSGT 832007 CAIC PSGT 832007 FEIC PSGT 832007 SIC PSGT 832007 F GAPI FERC PSGT t 832007 TMDS PSGT 832007 CU TENS PSGT 832007 LB TEMP PSGT 832007 DEG API CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11726.000 GRCH = 174.125 LIRI = 1.383 COIR = .461 STUN = .006 ITCR = 5175.938 HPLI = 1.247 TCCR = 6309.866 OAI = 8.734 SIAI = 12.870 RIC = .820 KIC = .401 HIC = .075 SIIC = .062 CLIC = .020 CAIC = .003 FEIC = .086 SIC = .100 FERC = 2.413 TMDS = 39.028 TENS = 1495.813 TEMP = 19.100 DEPT = 11626.000 GRCH = 116.050 LIRI = 1.414 COIR = .466 STUN = .006 ITCR = 5020.541 Page 12 HPLI = 1.251 TCCR = 6760.780 OAI = 193.960 SIAI = 21.970 RIC = .743 KIC = .409 HIC = .082 SIIC = .064 CLIC = .018 CAIC = .000 FEIC = .081 SIC = .099 FERC = 2.415 TMDS = 32.583 TENS = 1529.363 TEMP = 20.100 DEPT = 11526.000 GRCH = 57.618 LIRI = 1.348 COIR = .470 STUN = .006 ITCR = 5244.792 HPLI = 1.256 TCCR = 8893.219 OAI = 2.855 SIAI = 4.704 RIC = .590 KIC = .396 HIC = .074 SIIC = .074 CLIC = .013 CAIC = .003 FEIC = .084 SIC = .099 FERC = 2.424 TMDS = 13.820 TENS = 1512.588 TEMP = 20.700 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 ----m 0 --- 93/03/24 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 --- 93/03/24 --- 1024 --- LO --- COMCEN.004 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 11726 . 0 11437 . 5 $ Page 13 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT 11438.0 11437.5 11462.0 11461.5 11478.0 11477.5 11518.0 11517.5 11571.0 11570.0 11626.0 11625.0 11667.0 11666.0 11729.0 11728.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #5. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 832007 LIRI PSGT 832007 COIR PSGT 832007 STUN PSGT 832007 ITCR PSGT 832007 HPLI PSGT 832007 TCCR PSGT 832007 OAI PSGT 832007 SIAI PSGT 832007 RIC PSGT 832007 KIC PSGT 832007 GAPI AP1 CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 I 68 00000000 0 4 i 68 00000000 0 4 I 68 00000000 0 4 I 68 00000000 0 4 i 68 00000000 0 4 i 68 00000000 0 4 I 68 Page 14 MIC PSGT 832007 00000000 0 4 i 68 SIIC PSGT 832007 00000000 0 4 i 68 CLIC PSGT 832007 00000000 0 4 i 68 CAIC PSGT 832007 00000000 0 4 i 68 FEIC PSGT 832007 00000000 0 4 i 68 SIC PSGT 832007 00000000 0 4 i 68 FERC PSGT 832007 00000000 0 4 i 68 TMDS PSGT 832007 CU 00000000 0 4 i 68 TENS PSGT 832007 LB 00000000 0 4 i 68 TEMP PSGT 832007 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11726.000 GRCH = 158.745 LIRI = 1.395 COIR = .445 STUN = .006 ITCR = 5296.965 HPLI = 1.281 TCCR = 6530.047 OAI = 6.300 SIAI = 16.448 RIC = .811 KIC = .399 HIC = .074 SIIC = .064 CLIC = .022 CAIC = .002 FEIC = .084 SIC = .100 FERC = 2.471 TMDS = 38.275 TENS = 1546.138 TEMP = 21.500 DEPT = 11626.000 GRCH = 128.721 LIRI = 1.437 COIR = .483 STUN = .006 ITCR = 5071.105 HPLI = 1.275 TCCR = 6780.435 OAI = 217.891 SIAI = 24.077 RIC = .748 KIC = .406 HIC = .084 SIIC = .066 CLIC = .020 CAIC = -.001 FEIC = .081 SIC = .098 FERC = 2.288 TMDS = 26.541 TENS = 1554.526 TEMP = 22.300 DEPT = 11526.000 GRCH = 79.188 LIRI = 1.358 COIR = .467 STUN = .006 ITCR = 5280.991 HPLI = 1.285 TCCR = 8861.242 OAI = 3.005 SIAI = 4.876 RIC = .596 KIC = .396 HIC = .074 SIIC = .074 CLIC = .015 CAIC = .002 FEIC = .084 SIC = .098 FERC = 2.394 TMDS = 15.296 TENS = 1529.363 TEMP = 23.000 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 93/03/24 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** FILE HEADER RECORD TYPE 128 Page 15 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --- 93/03/24 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PSGT 01,02,03,04,05 $ REMARKS: GRCH, OAI AND SIAI ARE TAKEN FROM PASS #1. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. Page 16 DEPT F 00000000 0 4 1 68 GRCH PGAV 832007 GAPI 00000000 0 4 1 68 LIRI PGAV 832007 00000000 0 4 1 68 COIR PGAV 832007 00000000 0 4 1 68 STUN PGAV 832007 00000000 0 4 1 68 ITCR PGAV 832007 00000000 0 4 1 68 HPLI PGAV 832007 00000000 0 4 1 68 TCCR PGAV 832007 00000000 0 4 1 68 OAI PGAV 832007 00000000 0 4 1 68 SIAI PGAV 832007 00000000 0 4 1 68 RIC PGAV 832007 00000000 0 4 1 68 KIC PGAV 832007 00000000 0 4 1 68 HIC PGAV 832007 00000000 0 4 1 68 SIIC PGAV 832007 00000000 0 4 1 68 CLIC PGAV 832007 00000000 0 4 1 68 CAIC PGAV 832007 00000000 0 4 1 68 FEIC PGAV 832007 00000000 0 4 1 68 SIC PGAV 832007 00000000 0 4 1 68 FERC PGAV 832007 00000000 0 4 1 68 TMDS PGAV 832007 CU 00000000 0 4 1 68 TEMP PGAV 832007 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11725.000 GRCH = 62.619 LIRI = 1.382 COIR = .475 STUN = .007 ITCR = 5082.352 HPLI = 1.287 TCCR = 6290.883 OAI = 2.905 SIAI= 4.980 RIC = .808 KIC = .398 HIC = .073 SIIC = .060 CLIC = .020 CAIC = .001 FEIC = .088 SIC = .097 FERC = 2.460 TMDS = 36.654 TEMP = 16.780 DEPT = 11625.000 GRCH = 106.399 LIRI = 1.408 COIR = .470 STUN = .006 ITCR = 5040.863 HPLI = 1.260 TCCR = 6598.722 OAI = 194.444 SIAI = 19.555 RIC = .764 KIC = .405 HIC = .085 SIIC = .064 CLIC = .020 CAIC = -.001 FEIC = .083 SIC = .097 FERC = 2.290 TMDS = 22.731 TEMP = 17.500 DEPT = 11525.000 GRCH = 15.574 LIRI = 1.352 COIR = .475 STUN = .006 ITCR = 5322.953 HPLI = 1.255 TCCR = 8995.152 OAI = 3.707 SIAI = 3.349 RIC = .592 KIC = .397 HIC = .072 SIIC = .075 CLIC = .015 CAIC = .002 FEIC = .084 SIC = .100 FERC = 2.348 TMDS = 13.936 TEMP = 18.160 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER --- COMCEN.006 ~ 0 Page 17 DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 93/03/24 --- 1024 --- LO --- COMCEN. 007 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 93/03/24 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ LOG HEADER DATA 11734.5 11440.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-JAN-93 2.23 1036 24-JAN-93 11837.0 11440.0 11735.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 114434S O05 8.500 12050.0 Page 18 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #1. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 I 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: Page 19 MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE ~SAMP REPR. DEPT F 00000000 0 4 i 68 CCL PSGT 832007 MV 00000000 0 4 I 68 GR PSGT 832007 GAPI 00000000 0 4 i 68 LIRI PSGT 832007 00000000 0 4 1 68 COIR PSGT 832007 00000000 0 4 1 68 STUN PSGT 832007 00000000 0 4 i 68 ITCR PSGT 832007 00000000 0 4 i 68 HPLI PSGT 832007 00000000 0 4 1 68 TCCR 'PSGT 832007 00000000 0 4 i 68 OAI PSGT 832007 00000000 0 4 i 68 $IAI PSGT 832007 00000000 0 4 I 68 RIC PSGT 832007 00000000 0 4 i 68 KIC PSGT 832007 00000000 0 4 1 68 HIC PSGT 832007 00000000 0 4 I 68 SIIC PSGT 832007 00000000 0 4 1 68 CLIC PSGT 832007 00000000 0 4 1 68 CAIC PSGT 832007 00000000 0 4 1 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 i 68 FERC PSGT 832007 00000000 0 4 i 68 TMDS PSGT 832007 CU 00000000 0 4 i 68 TENS PSGT 832007 LB 00000000 0 4 i 68 TEMP PSGT 832007 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11734.500 CCL = 10923.000 GR = 62.619 LIRI = 1.486 COIR = .507 STUN = .007 ITCR = 5084.700 HPLI = 1.390 TCCR = 5851.009 OAI = 3.247 SIAI = 5.199 RIC = .869 KIC = .398 HIC = .077 SIIC = .056 CLIC = .020 CAIC = .001 FEIC = .088 SIC = .089 FERC = 2.639 TMDS = 39.464 TENS = 1554.526 TEMP = 12.500 DEPT = 11684.500 CCL = 10923.000 GR = 48.636 LIRI = 1.359 COIR = .492 STUN = .007 ITCR = 5235.602 HPLI = 1.241 TCCR = 7803.021 OAI = 2.352 SIAI = 3.372 RIC = .671 KIC = .394 HIC = .069 SIIC = .064 CLIC = .017 CAIC = .002 FEIC = .090 SIC = .101 FERC = 2.407 TMDS = 20.417 TENS = 1546.138 TEMP = 12.700 DEPT = 11634.500 CCL = 10923.000 GR = 66.537 LIRI = 1.373 COIR = .486 STUN = .006 ITCR = 5453.958 HPLI = 1.213 TCCR = 8247.365 OAI = 225.161 SIAI = 21.575 RIC = .661 KIC = .397 HIC = .077 SIIC = .073 CLIC = .016 CAIC = .000 FEIC = .084 SIC = .102 FERC = 2.239 TMDS = 18.876 TENS = 1546.138 TEMP = 12.900 Page 20 DEPT = 11584.500 CCL = 10923.000 GR = 17.951 LIRI = 1.392 COIR = .479 STUN = .007 ITCR = 5275.612 HPLI = 1.268 TCCR = 7794.328 OAI = 3.094 SIAI = 2.810 RIC = .677 KIC = .398 HIC = .084 SIIC = .074 CLIC = .015 CAIC = .003 FEIC = .080 SIC = .095 FERC = 2.446 TMDS = 17.036 TENS = 1520.976 TEMP = 13.100 DEPT = 11534.500 CCL = 10923.000 GR = 1083.830 LIRI = 1.275 COIR = .493 STUN = .007 ITCR = 5433.053 HPLI = 1.266 TCCR = 8535.986 OAI = 2.768 SIAI = 95.196 RIC = .636 KIC = .401 HIC = .072 SIIC = .071 CLIC = .016 CAIC = .002 FEIC = .086 SIC = .100 FERC = 2.360 TMDS = -23.519 TENS = 1520.976 TEMP = 13.300 DEPT 11484.500 CCL = 10923.000 GR = 16.399 LIRI = 1.362 COIR = .490 STUN = .006 ITCR = 5278.488 HPLI = 1.240 TCCR = 9123.906 OAI = 2.859 SIAI = 3.243 RIC = .579 KIC = .393 HIC = .077 SIIC = .072 CLIC = .010 CAIC = .003 FEIC = .086 SIC = .100 FERC = 2.468 TMDS = 13.584 TENS = 1504.201 TEMP = 13.600 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 93/03/24 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 --- 93/03/24 --- 1024 --- LO --- COMCEN.007 ****************************************************************************** COMMENT RECORD TYPE 232 Page 21 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 11734.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 11441.0 24-JAN-93 2.23 1036 24-JAN-93 11837.0 11440.0 11735.0 300.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ 114434S O05 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 12050.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): Page 22 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 i 66 1 5 1 66 1 8 4 73 30 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F CCL PSGT 832007 MV GR PSGT 832007 GAPI LIRI PSGT 832007 COIR PSGT 832007 STUN PSGT 832007 ITCR PSGT 832007 HPLI PSGT 832007 TCCR PSGT 832007 OAI PSGT 832007 SIAI PSGT 832007 RIC PSGT 832007 KIC PSGT 832007 HIC PSGT 832007 SIIC PSGT 832007 CLIC PSGT 832007 CAIC PSGT 832007 FEIC PSGT 832007 SIC PSGT 832007 FERC PSGT 832007 TMDS PSGT 832007 CU API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. I 68 i 68 i 68 I 68 i 68 i 68 i 68 i 68 I 68 i 68 1 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 Page 23 TENS PSGT 832007 LB 00000000 0 4 i 68 TEMP PSGT 832007 DEG 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11734.500 CCL = 10923.000 GR = 134.027 LIRI = 1.386 COIR = .484 STUN = .006 ITCR = 4846.096 HPLI = 1.270 TCCR = 6167.164 OAI = 4.999 SIAI = 9.762 RIC = .786 KIC = .405 HIC = .072 SIIC = .057 CLIC = .019 CAIC = .005 FEIC = .087 SIC = .099 FERC = 2.238 TMDS = 16.051 TENS = 1202.254 TEMP = 14.200 DEPT = 11684.500 CCL = 10923.000 GR = 62.526 LIRI = 1.378 COIR = .499 STUN = .007 ITCR = 4887.056 NPLI = 1.244 TCCR = 7329.993 OAI = 2.727 SIAI = 4.433 RIC = .667 KIC = .392 HIC = .066 SIIC = .061 CLIC = .014 CAIC = .002 FEIC = .093 SIC = .101 FERC = 2.424 TMDS = 20.078 TENS = 1512.588 TEMP = 14.500 DEPT = 11634.500 CCL = 10923.000 GR = 96.786 LIRI = 1.345 COIR = .460 STUN = .006 ITCR = 5331.466 HPLI = 1.218 TCCR = 8222.059 OAI = 226.232 SIAI = 23.559 RIC = .648 KIC = .399 HIC = .076 SIIC = .073 CLIC = .013 CAIC = .001 FEIC = .084 SIC = .102 FERC = 2.317 TMDS = 19.743 TENS = 1529.363 TEMP = 14.800 DEPT = 11584.500 CCL = 10923.000 GR = 28.296 LIRI = 1.357 COIR = .484 STUN = .006 ITCR = 5230.262 HPLI = 1.261 TCCR = 7850.529 OAI = 3.080 SIAI = 3.734 RIC = .666 KIC = .400 HIC = .083 SIIC = .073 CLIC = .017 CAIC = .002 FEIC = .080 SIC = .096 FERC = 2.437 TMDS = 16.892 TENS = 1520.976 TEMP = 15.200 DEPT = 11534.500 CCL = 10923.000 GR = 976.837 LIRI = 1.292 COIR = .483 STUN = .006 ITCR = 5540.664 HPLI = 1.284 TCCR = 8752.021 OAI = 3.301 SIAI= 54.019 RIC = .633 KIC = .401 HIC = .073 SIIC = .073 CLIC = .015 CAIC = .003 FEIC = .084 SIC = .098 FERC = 2.397 TMDS = 9.948 TENS = 1512.588 TEMP = 15.500 DEPT = 11484.500 CCL = 10923.000 GR = 29.197 Page 24 LIRI = 1.329 COIR = .491 STUN = .006 ITCR = 5343.016 HPLI = 1.251 TCCR = 9082.338 OAI = 3.218 SIAI = 4.065 RIC = .588 KIC = .396 HIC = .075 SIIC = .075 CLIC = .012 CAIC = .003 FEIC = .083 SIC = .099 FERC = 2.452 TMDS = 14.875 TENS = 1512.588 TEMP = 16.000 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 --- 93/03/24 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 --- 93/03/24 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 11734.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 11437.5 24-JAN-93 2.23 1036 24-JAN-93 11837.0 11440.0 11735.0 Page 25 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 300.0 NO TOOL NUMBER GR NGRT -A PSGT PSGT-EPG $ 114434S O05 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 12050.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 Page 26 3 2 79 92 4 1 66 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE ~SAMP REPR. DEPT F 00000000 0 4 1 68 CCL PSGT 832007 MV 00000000 0 4 1 68 GR PSGT 832007 GAPI 00000000 0 4 1 68 LIRI PSGT 832007 00000000 0 4 I 68 COIR PSGT 832007 00000000 0 4 1 68 STUN PSGT 832007 00000000 0 4 i 68 ITCR PSGT 832007 00000000 0 4 I 68 HPLI PSGT 832007 00000000 0 4 1 68 TCCR PSGT 832007 00000000 0 4 1 68 OAI PSGT 832007 00000000 0 4 1 68 SIAI PSGT 832007 00000000 0 4 1 68 RIC PSGT 832007 00000000 0 4 1 68 KIC PSGT 832007 00000000 0 4 1 68 HIC PSGT 832007 00000000 0 4 1 68 SIIC PSGT 832007 00000000 0 4 1 68 CLIC PSGT 832007 00000000 0 4 1 68 CAIC PSGT 832007 00000000 0 4 i 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 1 68 FERC PSGT 832007 00000000 0 4 1 68 TMDS PSGT 832007 CU 00000000 0 4 1 68 TENS PSGT 832007 LB 00000000 0 4 1 68 TEMP PSGT 832007 DEG 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 11734.500 CCL = 10923.000 GR = 148.308 LIRI = 1.417 COIR = .487 STUN = .008 ITCR = 4695.122 HPLI = 1.288 TCCR = 6015.841 OAI = 6.897 SIAI = 12.015 RIC = .780 KIC = .392 HIC = .075 SIIC = .056 CLIC = .010 CAIC = .004 FEIC = .089 SIC = .095 FERC = 2.925 TMDS = 38.301 TENS = 1353.227 TEMP = 16.500 DEPT = 11684.500 CCL = 10923.000 GR = 90.544 LIRI = 1.372 COIR = .498 STUN = .007 ITCR = 4922.424 HPLI = 1.241 TCCR = 7342.929 OAI = 2.958 SIAI = 4.671 RIC = .670 KIC = .393 HIC = .066 SIIC = .061 Page 27 CLIC = .016 CAIC = .002 FEIC = .092 SIC = .102 FERC = 2.460 TMDS = 21.815 TENS = 1529.363 TEMP = 17.000 DEPT = 11634.500 CCL = 10923.000 GR = 102.718 LIRI = 1.360 COIR = .479 STUN = .006 ITCR = 5293.925 HPLI = 1.269 TCCR = 8174.800 OAI = 201.922 SIAI = 19.922 RIC = .648 KIC = .398 HIC = .078 SIIC = .074 CLIC = .016 CAIC = .000 FEIC = .083 SIC = .099 FERC = 2.359 TMDS = 17.316 TENS = 1529.363 TEMP = 17.300 DEPT = 11584.500 CCL = 10923.000 GR = 53.543 LIRI = 1.381 COIR = .466 STUN = .006 ITCR = 5339.622 HPLI = 1.290 TCCR = 7882.666 OAI = 2.834 SIAI = 4.256 RIC = .677 KIC = .399 HIC = .083 SIIC = .073 CLIC = .015 CAIC = .004 FEIC = .080 SIC = .094 FERC = 2.367 TMDS = 16.413 TENS = 1529.363 TEMP = 17.600 DEPT = 11534.500 CCL = 10923.000 GR = 959.862 LIRI = 1.266 COIR = .492 STUN = .006 ITCR = 5486.443 HPLI = 1.264 TCCR = 8508.295 OAI = 2.502 SIAI = 64.872 RIC = .645 KIC = .402 HIC = .072 SIIC = .072 CLIC = .015 CAIC = .003 FEIC = .084 SIC = .099 FERC = 2.352 TMDS = 19.672 TENS = 1529.363 TEMP = 18.100 DEPT = 11484.500 CCL = 10923.000 GR = 55.655 LIRI = 1.357 COIR = .483 STUN = .006 ITCR = 5264.046 HPLI = 1.240 TCCR = 8915.836 OAI = 2.881 SIAI = 4.795 RIC = .590 KIC = .395 HIC = .076 SIIC = .073 CLIC = .012 CAIC = .002 FEIC = .086 SIC = .099 FERC = 2.402 TMDS = 13.486 TENS = 1529.363 TEMP = 18.500 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 93/03/24 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** FILE HEADER RECORD TYPE 128 Page 28 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 t~ 0 --- 93/03/24 --- 1024 --- LO --- COMCEN.009 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ LOG HEADER DATA 11734.5 11440.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-JAN-93 2.23 1036 24-JAN-93 11837.0 11440.0 11735.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): 114434S OO5 8.500 12050.0 PRODUCED 0.0 Page 29 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #4. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 i 66 1 8 4 73 30 9 4 65 .lin 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM DEPT CCL PSGT 832007 GR PSGT 832007 LIRI PSGT 832007 COIR PSGT 832007 STUN PSGT 832007 ITCR PSGT 832007 SERVID SERVICE# UNITS F MV GAP I API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 i 68 i 68 1 68 i 68 i 68 i 68 Page 30 HPLI PSGT 832007 00000000 0 4 i 68 TCCR PSGT 832007 00000000 0 4 i 68 OAI PSGT 832007 00000000 0 4 i 68 SIAI PSGT 832007 00000000 0 4 i 68 RIC PSGT 832007 00000000 0 4 1 68 KIC PSGT 832007 00000000 0 4 I 68 HIC PSGT 832007 00000000 0 4 i 68 SIIC PSGT 832007 00000000 0 4 i 68 CLIC PSGT 832007 00000000 0 4 I 68 CAIC PSGT 832007 00000000 0 4 i 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 1 68 FERC PSGT 832007 00000000 0 4 I 68 TMDS PSGT 832007 CU 00000000 0 4 I 68 TENS PSGT 832007 LB 00000000 0 4 i 68 TEMP PSGT 832007 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11734.500 CCL = 10923.000 GR = 174.125 LIRI = 1.380 COIR = .465 STUN = .010 ITCR = 5164.319 NPLI = 1.244 TCCR = 6234.046 OAI = 9.325 SIAI = 11.977 RIC = .828 KIC = .403 NIC = .074 SIIC = .062 CLIC = .019 CAIC = .004 FEIC = .085 SIC = .100 FERC = 2.399 TMDS = 36.849 TENS = 1093.217 TEMP = 19.100 DEPT = 11684.500 CCL = 10923.000 GR = 129.726 LIRI = 1.372 COIR = .509 STUN = .007 ITCR = 4935.305 NPLI = 1.253 TCCR = 7344.103 OAI = 2.447 SIAI = 4.519 RIC = .672 KIC = .394 HIC = .069 SIIC = .062 CLIC = .018 CAIC = .001 FEIC = .092 SIC = .101 FERC = 2.440 TMDS = 21.620 TENS = 1554.526 TEMP = 19.600 DEPT = 11634 500 CCL = 10923.000 GR = 106.737 LIRI = 1.341 COIR = .470 STUN = .006 ITCR = 5335.421 HPLI = 1.223 TCCR = 8066.861 OAI = 241.621 SIAI = 25.289 RIC = .661 KIC = .397 HIC = .076 SIIC = .074 CLIC = .012 CAIC = .001 FEIC = .084 SIC = .103 FERC = 2.221 TMDS = 21.100 TENS = 1537.751 TEMP = 20.000 DEPT = 11584.500 CCL = 10923.000 GR = 65.118 LIRI = 1.399 COIR = .485 STUN = .007 ITCR = 5132.544 HPLI = 1.294 TCCR = 7801.527 OAI = 3.004 SIAI = 4.269 RIC = .658 KIC = .397 HIC = .086 SIIC = .073 CLIC = .016 CAIC = .002 FEIC = .080 SIC = .092 FERC = 2.437 TMDS = 17.332 Page 31 TENS = 1520.976 TEMP = 20.300 DEPT = 11534.500 CCL = 10923.000 GR = 636.587 LIRI = 1.249 COIR = .493 STUN = .006 ITCR = 5929.449 HPLI = 1.276 TCCR = 9026.039 OAI = 3.375 SIAI = 71.967 RIC = .657 KIC = .404 HIC = .071 SIIC = .072 CLIC = .017 CAIC = .002 FEIC = .085 SIC = .100 FERC = 2.370 TMDS = -28.559 TENS = 1520.976 TEMP = 20.600 DEPT = 11484.500 CCL = 10923.000 GR = 65.457 LIRI = 1.349 COIR = .460 STUN = .006 ITCR = 5266.087 HPLI = 1.271 TCCR = 9023.254 OAI = 3.247 SIAI = 5.396 RIC = .584 KIC = .395 HIC = .076 SIIC = .074 CLIC = .012 CAIC = .002 FEIC = .084 SIC = .098 FERC = 2.425 TMDS = 14.037 TENS = 1529.363 TEMP = 21.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.010 --- 93/03/24 --- 1024 --- LO --- COMCEN.011 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 --- 93/03/24 --- 1024 --- LO --- COMCEN.010 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 Page 32 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ LOG HEADER DATA 11734.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TOBOTTOM) VENDOR TOOL CODE TOOL TYPE 11437.5 24-JAN-93 2.23 1036 24-JAN-93 11837.0 11440.0 11735.0 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-EPG $ 114434S OO5 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 12050.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 Page 33 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #5. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 CCL PSGT 832007 MV 00000000 0 4 i 68 GR PSGT 832007 GAPI 00000000 0 4 i 68 LIRI PSGT 832007 00000000 0 4 i 68 COIR PSGT 832007 00000000 0 4 I 68 STUN PSGT 832007 00000000 0 4 i 68 ITCR PSGT 832007 00000000 0 4 1 68 HPLI PSGT 832007 00000000 0 4 i 68 TCCR PSGT 832007 00000000 0 4 i 68 OAI PSGT 832007 00000000 0 4 1 68 SIAI PSGT 832007 00000000 0 4 i 68 RIC PSGT 832007 00000000 0 4 1 68 KIC PSGT 832007 00000000 0 4 1 68 HIC PSGT 832007 00000000 0 4 1 68 SIIC PSGT 832007 00000000 0 4 i 68 CLIC PSGT 832007 00000000 0 4 i 68 CAIC PSGT 832007 00000000 0 4 i 68 FEIC PSGT 832007 00000000 0 4 1 68 SIC PSGT 832007 00000000 0 4 1 68 FERC PSGT 832007 00000000 0 4 I 68 TMDS PSGT 832007 CU 00000000 0 4 I 68 TENS PSGT 832007 LB 00000000 0 4 I 68 TEMP PSGT 832007 DEG 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11734.500 CCL = 10923.000 GR = 158.745 Page 34 LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 1.420 5162.818 5.425 .400 .023 .102 1210.641 COIR = HPLI = SIAI= HIC = CAIC = FERC = TEMP = .437 1.255 13.854 .074 .002 2.472 21.500 STUN = TCCR = RIC = SIIC = FEIC = TMDS = .OO6 6320.052 .817 .064 .083 45.716 DEPT = LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 11684.500 1.376 5054.015 2.435 .393 .017 .102 1546.138 CCL = COIR = HPLI = SIAI= HIC = CAIC = FERC = TEMP = 10923.000 .480 1.250 6.287 .066 .000 2.437 21.800 GR = STUN = TCCR = RIC = SIIC = FEIC = TMDS = 106.442 .007 7463.299 .677 .063 .093 22.909 DEPT = LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 11634.500 1.332 5462.052 233.955 .399 .015 .102 1546.138 CCL = COIR = HPLI = SIAI= HIC = CAIC = FERC = TEMP = 10923.000 .462 1.216 23.433 .076 .001 2.297 22.200 GR = STUN = TCCR = RIC = SIIC = FEIC = TMDS = 114.416 .006 8323.348 .656 .074 .083 18.725 DEPT = LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 11584.500 1.346 5543.904 2.821 .397 .019 .093 1546.138 CCL = COIR = HPLI = SIAI = HIC = CAIC = FERC = TEMP = 10923.000 .474 1.315 6.527 · 086 .001 2. 405 22.500 GR = STUN = TCCR = RIC = SIIC = FEIC = TMDS = 102.297 .006 8419.730 .658 .073 ·080 17.114 DEPT = LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 11534.500 1.329 5446.554 3.057 .400 .016 .099 1529.363 CCL = COIR = HPLI = SIAI= HIC = CAIC = FERC = TEMP = 10923.000 .464 1.276 30.854 .074 .003 2.378 22.900 GR = STUN = TCCR = RIC = SIIC = FEIC = TMDS = 712.885 .006 8583.971 ·635 .072 .084 7.989 DEPT = LIRI = ITCR = OAI = KIC = CLIC = SIC = TENS = 11484.500 1.338 5270.912 3.347 .396 .014 .098 1537.751 CCL = COIR = HPLI = SIAI= HIC = CAIC = FERC = TEMP = 10923.000 .491 1.274 5.083 .076 .002 2.465 23.200 GR = STUN = TCCR = RIC = SIIC = FEIC = TMDS = 73.899 .006 9143.320 .576 .074 .084 13.191 Page 35 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.011 ~---- 0 --- 93/03/24 --- 1024 --- LO --- COMCEN.012 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.012 --- 93/03/24 --- 1024 --- LO --- COMCEN.011 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 12 STATIONS & COMPUTED RESULTS DEPTH INCREMENT 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ REMARKS: 11720.0 11460.0 THIS FILE CONTAINS COMPUTED RESULTS FOR: VSH - SHALE VOLUME SOIL - CASED HOLE OIL SATURATION PHSO - CASED HOLE BULK VOUME OIL PHSW - OPEN HOLE BULK VOLUME WATER PHIE - EFFECTIVE POROSITY = SPHI * (1.0-VSH) ALSO INCLUDED IS OPEN HOLE DATA PROVIDED BY ARCO: OHGR - OPEN HOLE GAMMA RAY OHDT - OPEN HOLE DELTA T OHSW - OPEN HOLE WATER SATURATION RHOB - OPEN HOLE BULK DENSITY SPHI - OPEN HOLE SONIC POROSITY AVERAGE OF PASS #1 - #5 USED FOR COMPUTATIONS. OPEN HOLE GAMMA RAY & SONIC POROSITY USED TO COMPUTE VSH & PHIE. OPEN HOLE DATA HAS BEEN INTERPOLATED FROM 1 SAMPLE/FT. TO 4 SAMPLES/FT. $ Page 36 LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 1 66 0 3 2 79 72 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 OHGR OH 832007 GAPI 00000000 0 4 I 68 OHDT OH 832007 US/F 00000000 0 4 i 68 OHSW OH 832007 % 00000000 0 4 i 68 RHOB OH 832007 G/C3 00000000 0 4 i 68 SPHI OH 832007 % 00000000 0 4 1 68 VSH CHARM 832007 % 00000000 0 4 1 68 SOIL CHARM 832007 % 00000000 0 4 i 68 PHSO CHARM 832007 % 00000000 0 4 i 68 PHSW CHARM 832007 % 00000000 0 4 1 68 PHIE CHARM 832007 % 00000000 0 4 i 68 GR PSGT 832007 GAPI 00000000 0 4 i 68 LIRI PSGT 832007 00000000 0 4 i 68 COIR PSGT 832007 00000000 0 4 i 68 STUN PSGT 832007 00000000 0 4 i 68 RIC PSGT 832007 00000000 0 4 i 68 SIIC PSGT 832007 00000000 0 4 i 68 CAIC PSGT 832007 00000000 0 4 I 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 11720.000 OHGR = 136.729 OHDT = 75.630 OHSW = .979 RHOB = 2.633 SPHI = .127 VSH = .990 SOIL = .004 PHSO = .001 PHSW = .001 PHIE = .001 GR = 62.619 LIRI = 1.365 COIR = .475 STUN = .007 RIC = .798 SIIC = .061 CAIC = .002 DEPT = 11670.000 OHGR = 30.142 OHDT = 86.260 Page 37 OHSW = .325 RHOB = 2.378 SPHI = .192 VSH = .092 SOIL = .448 PHSO = .096 PNSW = .057 PHIE = .174 GR = 27.444 LIRI = 1.374 COIR = .484 STUN = .006 RIC = .654 SIIC = .064 CAIC = .002 DEPT = 11620.000 OHGR = 32.936 OHDT = 92.640 OHSW = .281 RHOB = 2.267 SPHI = .231 VSH = .112 SOIL = .305 PHSO = .143 PHSW = .058 PHIE = .205 GR = 67.560 LIRI = 1.353 COIR = .472 STUN = .006 RIC = .677 SIIC = .077 CAIC = .000 DEPT = 11570.000 OHGR = 22.956 OHDT = 86.710 ONSW = .320 RHOB = 2.330 SPHI = .203 VSH = .046 SOIL = .375 PHSO = .121 PHSW = .062 PNIE = .194 GR = 19.309 LIRI = 1.376 COIR = .480 STUN = .007 RIC = .612 SIIC = .062 CAIC = .001 DEPT = 11520.000 OHGR = 23.754 OHDT = 81.870 OHSW = .251 RHOB = 2.369 SPHI = .177 VSN = .051 SOIL = .423 PHSO = .097 PHSW = .042 PHIE = .168 GR = 17.011 LIRI = 1.318 COIR = .470 STUN = .006 RIC = .586 SIIC = .074 CAIC = .002 DEPT = 11470.000 OHGR = 36.529 OHDT = 89.120 OHSW = .318 RHOB = 2.409 SPHI = .233 VSH = .139 SOIL = .683 PHSO = .063 PHSW = .063 PNIE = .200 GR = 26.921 LIRI = 1.377 COIR = .504 STUN = .007 RIC = .612 SIIC = .060 CAIC = .002 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.012 --- 93/03/24 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER --- COMCEN --- 93/03/24 --- ANCH Page 38 NEXT TAPE NAME COMMENTS: REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN --- 93/03/24 --- ANCH --- 832007 ****************************************************************************** END OF TAPE ENCOUNTERED Page 39 L I S T A P E VERIFI£,~TION LISTING iVP OIO.HOZ VERIFICATION LISTING PAGE I REEL HEADER ** ;ERV[CE NAME :EDIT ~ATE :88/06/[8 IRIGIN : IEEL NAME :72774 :ONTINUATIDN ~ :0! ~REVIOUS REEL : ;OMMENTS :LIS TAPE, ARCO D.S. 4-9, APIe 50-029-20207 :~ TAPE HEADER ;ERVICE NAME :EDIT kATE :88/06/I8 IRIGIN :FSIA ,APE NAME :ONTINUATION # :0! 'REVIOUS TAPE : :OMMENTS :LIS TAPE, ARCO O.S. 4-9, APIa 50-029-20207 ~* FILE HEADER :ILE NAME :EDIT .001 ~ERVICE NAME : ~ERSION ~ : )ATE : {AXIMUM LENGTH : :ILE TYPE : ~REVIOUS FILE INFORMATION RECORDS {NEM CONTENTS :N : ARCO ALASKA, INC. ~N : O.S. 4-9 :N : PRUDHOE BAY {ANG: 14E FOWN: · ;ECT: 35 ~OUN: NORTH SLOPE ~TAT: ALASRA ~ COMMENTS UNIT TYPE CATE SIZE CODE 000 000 018 065 000 000 OlO 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 ,VP OIO.H02 VERIFICATION LISTING PAGE SCHLUMBERGER ALASKA COMPUTING CENTER 'OMPANY = A~CO ALASKAt INC. IELL = D.S. :IELO = PRUOHOE BAY ;DUNTY = NORTH SLOPE BOROUGH ;TATE = ALASKA IDB NUMBER AT AKCC: 72774 :UN ~2, DATE LOGGEO: 28-MAY-B8 .DP: J. KOHRING ~ATE COMPUTED: 16-JUN-88 :ASING(47~) :ASINGC29#) 'UBING(17~) 'UBINGC12.6#) 'YPE FLUID IATRIX SANDSTONE 9.625" O' TO 11090' - BIT SIZE : 12.25" 7.00" 10786' TO 12050' - BIT SIZE : 5.50" O" TO 10772" - TUBING 4.50" 10722' TO 10815' - TUBING TAIL PRODUCED FLUIDS 'OOL STRING(3.375" TOOL): CNC-A 2ZBB SGC-JC 2249 CAL-R 1636 NLM-BC 1.2.34 .VP 010.H02 VERIFICATION LISTING PAGE 3 :IELO REMARKS: TIED INTO D.A. CNL DATED OD-JUL-86. GOC ESTIMATED AT 11556'. ;OMPUTING CENTER REMARKS: THE HODGES-LEHMANN AVERAGED NPHI FROM FIELD TAPE DOES NOT EXACTLY MATCH THE ONE PRESENTED ON THE 8LUELINEo NE RE-CALCULATED IT HERE AND DETERMINED THAT THE AVERAGED NPHI ON THE FIELD TAPE, AS WELL AS THE ONE ON THIS LIS TAPE~ IS MORE CORRECT THAN THAT DISPLAYED ON THE FIELD PRINT. ALL OTHER CURVES ON THIS TAPE EXACTLY MATCH THE BLUELINE. ~*~*~ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WZTH THIS FILE (EOIT.O01>: <SEE FILE EDIT.OO2 FOR COLLAR LO:CATOR DATA> COMPENSATED NEUTRON LOG - PASS ~1 (.PSl) FIRST TO LAST READING: 11B06' TO 11396' .VP 010.HOZ VERIFICATION LISTING PAGE 4 COMPENSATED NEUTRON LOG- PASS #2 (.PS2) FIRST TD LAST READING: 11806m TO 11396' COMPENSATED NEUTRON LOG - PASS #3 C.PS3) FIRST TO LAST READING: 11806' TO 11396' NPHI- HODGES-LEHMAN AVERAGED (,.HLA) FIRST TO LAST READING: 11B06' TO 11396' DATA FORMAT RECORD ** !NTRY BLOCKS TYPE SIZE REPR CODE ENTRY Z I 66 0 4 I 66 1 8 4 73 60 9 4 65 .lin 16 I 66 1 0 1 66 0 )ATUM SPECIFICATION BLOCKS INEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR ID ORDER # LOG TYPE CLASS MOO NO. IEPT FT O0 000 O0 0 0 4 'ENS PS1 L8 O0 635 21 0 0 4 IPHI PS1 PU O0 990 ~ O0 0 0 4 ,N~A PS1 O0 420 01 0 0 4 )TNR. PS1 O0 000 O0 0 0 4 ~CNT PS1 CPS O0 000 O0 0 0 4 tCFT PS1 CPS O0 000 O0 0 0 4 ;NTC PS1 CPS O0 000 O0 0 0 4 3FTC PS1 CPS O0 000 O0 0 0 4 ;R PSI GAPI O0 310 O1 0 0 4 rENS PSI LB O0 635 21 0 O 4 4PHI PSI PU 0.0 890 O0 0 0 4 FNRA PS2 00 420 01 0 0 4 ~TNR PSI O0 000 O0 0 0 4 ~CNT PSI CPS O0 000 O0 0 0 4 PROCESS CODE COCTAL) 1 68 00000000000000 1 68 00000000000000 1 68 0000:0000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 O00OO00000000~O 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000: 1 68 00000000000000 1 68 000000~00000000 ,VP 010.H02 VERIFICATION LISTING PAGE 5 'CFT :NTC :FTC 'ENS IPHI 'NRA ITNR ~CNT ',CFT :NTC ;FTC ;R IPHI IEPT tTNR 3FTC FNRA :NTC JCFT ~PHI ) EPT ~TNR 3FTC r'NRA :NTC ~PHI ~CFT ~PH! DEPT RTNR CFTC TNRA CNTC NPHI RCFT NPHI OEPT RTNR CFTC TNRA C NTC NPHI RCFT NPHI PS2 PS2 PS2 PS2 PS3 PS3 PS3 pS3 PS3 PS3 PS3 PS3 PS3 HLA CPS O0 000 O0 0 CPS O0 000 O0 0 CPS O0 000 O0 0 GAPI O0 310 O1 0 LB O0 635 ~1 0 PU O0 890 O0 0 O0 420 01 0 O0 000 O0 0 CPS O0 000 O0 0 CPS O0 000 O0 0 CPS O0 000 O0 0 CPS O0 000 O0 0 GAPI O0 310 01 0 PU O0 890 O0 0 11902.0000 3.1786 568.7765 -999.2500 -999.2500 -999,2500 -999.2500 -999-2500 I1900.0000 3.1786 568.7765 -999.2500 -999.2500 -999.2500 -999°2S00 -999.2500 11800.0000 .3.0789 557.7013 3,1473 1612.0396 31.3354 532.2710 32.9102 11700.0000 3.1000 656,6846 3.3026 1619.0266 28.8722 536,0573 27.5391 TENS RCNT GR RTNR CFTC TNRA CNTC TENS RCNT GR RTNR CFTC TNRA CNTC TENS RCNT GR CFTC TNRA CNTC TENS RCNT GR RTNR CFTC TNRA CNTC 685.0000 1844.1667 139,.6250 -999.2500 -999.2500 -999.2500 -999.2500 795.0000 184~.1667 139.6250 -999.2500 -999..2500 -999.2500 ,-999.2500 1625o0000 1768.2161 151.1250 3.5323 519.7504 3.1215 1646.5283 1595.0000 2001.6729 49.4063 3.4776 545.2170 2.9864 1679. 7974 NPHI RCFT TENS RCNT GR RTNR CFTC NPHI RCFT TENS RCNT GR RTNR CFTC NPHI RCFT TENS RCNT GR RTNR CFTC NPHI RCFT TENS RCNT GR RTNR CFTC 29.2265 573.1222 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29. 2265 573.1222 -999. 2500 -999.2500 -999.2500 -999. 2500 -999.2500 31.2200 550.9478 1605. 0000 1757. 634.8 143.7500 3.3 S 72 535. 8788 28.2997 636.8066 1545.0000 1'700.6250 77.0000 3.3226 539.5114 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000. 1 68 00000000000000 TNRA 3.0058 CNTC 1674.8403 NPHI -999.2500 RCFT -999.2500 TENS --999.2500 RCNT --999.2500 GR -999.2500 TNRA 3.I152 CNTC 1677.6172 NPHI 31.8062 R'CFT 524.6882 TENS 1670o0000 RCNT 1914.4927 GR 94.5000 TNRA 2.9550 CNTC 1888.8535 NPHI 34.6359 RCFT 555.7913 TENS 1540.0000 RCNT 184'9.3479 GR 66.4375 TNRA 3.0058 CNTC 1672.2249 NPHI -999.2500 RCFT -999.2500 TENS -999.2500 RCNT -999.2500 GR -999.2500 ,VP 010.H02 VERIFICATION LISTING PAGE 6 'EPT 11600.0000 TENS TNR 3.0844 RCNT ,FTC 638.1077 GR 'NRA 2.9542 RTNR :NTC 1873.5596 CFTC !PH! 24.4027 TNRA :CFT 745.9657 CNTC IPHI 25.9766 )EPT 11500.0000 TENS ~TNR 2.8585 RCNT :FTC ~81.1658 GR 'NRA 2.5849 RTNR iNTC 2122.1714 CFTC )PHI 20.0633 TNRA ICFT 924.8251 CNTC IPHI 19.6289 IEPT 11400.0000 TENS :TNR 3.0977 RCNT iFTC 588.4993 GR 'NRA 3.4789 RTNR iNTC 1726.0662 CFTC IPHI 45.7458 TNRA ICFT 452.7010 CNTC IPHI 43.9941 }EPT 11392.5000 TENS ITNR -999.2500 RCNT iFTC -999.250,0 GR rNRA 3.7697 RTNR 2NTC 1304.0930 CFTC IPHI -999.2500 TNRA {CFT -9'99.2500 CNTC IPHI 43.1152 1695.0000 2183.3486 16.5625 3.0119 649.3109 2.7412 1906.9570 1525.0000 2399.6992 2.9029 875.8572 2.4874 2241.¢365 1515.0000 2159.4458 113.2500 3.7069 520.7950 3.9120 1549.9629 -999.2500 -999.2500 -999.2500 4.0698 337.7724 -999.2500 -999.2500 NPHI RCFT TENS RCNT GR RTNR CFTC NPHI RCFT TENS RCNT GR CFTC NPHI RCFT TENS RCNT GR RTNR CFTC NPHI RCFT TENS RCNT GR RTNR CFTC t~ FILE TRAILER ~ =ILE.NAME :EDIT .001 ;ERVICE NAME : ~ERSIO'N~ : )ATE : IAXIMUM LENGTH : 1024 :ILETYPE : IEXT FILE NAME :' ~* FI'LE HEADER *~ =ILE NAME :EDIT ~ERVICE NAME : IERSION ~ : )ATE : .002 28.4330 632.2856 1525.0000 2052.4482 15.8203 3.0617 711.8528 21.2178 897.0236 1485.0000 2405.6665 15.9375 2.6036 940.3319 29.2213 612.7716 1450.0000 1887.6951 144.8750 4.2351 427.8550 -999.2500 '-999.2500 1445.0000 1443.9158 128.3750 -999.2500 -999.2500 TNRA CNTC NPHI RCFT TENS RCNT GR TNRA CNTC NPHI RCFT TENS RCNT GR TN~A CNTC NPHI RCFT TENS RCNT GR TNRA CNTC NPHI RCFT TENS RCNT GR 2.9623 1895.5513 28.2851 648.6161 1490.0000 2105.1382 17.6406 2.5617 2186.7646 21.5821 903.4175 1435.0000 2530.4546 16.1875 3.0056 1810.8457 37.8507 522.3719 1470.0000 1766.0356 18~.7500 -999.2500 -999.2500 43.1512 366.2817 -999.2500 -999.2500 -999.2500 VP 010.H02 VERIFICATION LISTING PAGE 7 AXIMUM LENGTH : 1024 ILL TYPE : REVIOUS FILE : COMMENTS THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (SEE FILE EDIT.O01 FOR CNL/GR DATA> CASING COLLAR LOCATOR CASED HOLE (.PS1) DATA AVAILABLE: 11806" TO 11396' CASING COLLAR LOCATOR- CASED HOLE (.PS2) DATA AVAILABLE:' 11806' TO 11396' CASING COLLAR LOCATOR - CASED HOLE (.PS3) DATA AVAILABLE: 11806' TO 11396' VP 010.HOZ VERIFICATION LISTING PAGE DATA FORMAT RECORD ~ NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 I 66 1 8 4 73 10 9 4 65 .liN 16 i 66 1 0 I 66 0 )ATUM SPECIFICATION 8LOCKS INEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. CODE COCTAL) )EPT FT O0 000 O0 0 0 4 I 68 00000000000000 ;CL PS1 O0 150 01 0 0 4 I 68 00000000000000 ;CL PS2 O0 150 01 0 0 4 I 68 00000000000000 ;CL PS3 O0 150 01 0 0 4 1 68 00000000000000 DATA )EPT 11901.9160 CCL -0.0171 CCL -999.2500 CCL -999.2.500 )EPT 11900.2500 CCL -0.0171 CCL -999.2500 CCL -999.2500 )EPT 11800.2500 CCL -0.0391 CCL -0.0342 CCL -0.019:5 )EPT 11700.2500 CCL 0.0488 CCL 0.0684 CCL 0.0854 )EPT ' '11600. 250~0 CCL -0.0488 CCL 0.0293 CCL -0.0659 )EPT 11500.2500 CCL -O.ZlO0 CCL -0.134.3 CCL 0.0488 )EPT 11400.2500 CCL -0.0806 CCL -0.1318 CCL -0.024,4 JEPT 11392.0000 CCL -999.2500 CCL 0.1587 CCL -999.2500 k:~ FILE TRAILER :ILE NAME :EDIT .002 SERVICE NAME ~ERSION .~ : 3AT E : MAXIMUM LENGTH : 1024 ,VP 010.H02 VERIFICATIDN LISTING PAGE 9 :ILE TYP~ : IEXT FILE NAME '. :* TAPE TRAILER ;ERVICE NAME :EOIT )ATE :88/06/18 IRIGIN :FSIA 'APE NAME :ONTINUATION IEXT TAPE NAME ;OMMENT$ :LIS TAPE~ ARCO D.S. 4-9~ API# 50-OZg-ZOZ07 ~* REEL TRAILER ** ;ERVICE NAME :EDIT )A'TE :88/06/[8 )RIGIN : IEEE NAME :72774 ;ONTINUATION # :01 iEXT REEL NAME : :OMMENTS ::LIS TAPE, ARCO O.S. 4-9, APIe 50-029-20207 I'1 11 1111 1111 11 11 11 I1 11 11 11 11 111111 llllll 666~66 666666 66 66 66 66 66666666 66666666 66 66 66 66 666666 666666 66 66 66 66 00000o 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777'177 777 7777777 77 77 77 77 '? 7 77 77 77 7'? 77 77 77 222222 222222 22 22 22 22 22 22 22 22 22 22 22 22 2222222222, 2222222222 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 333333 333333 33 33 33 33 33 33 33 33 3,3 33 ,33 33 33 33- 333333 333333 -7777777777 '7777177777 77 77 77 77 77 77 77 77 77 77 77 77 44 44 44 44 44 44 44 44 44 44 44 44 4444444444 4444444444 44 44 44 44 44 44 SSSS F~ Ff ~' L ~' L ~ L SSS FP~F L S P L S F L SSSS F LLLLL PPPP RRRR P P R R P P R R PPPP RRRR P R R P R R P R R U O DDDD U U D D O O D D U U D D U (3 D D U U D D UUUUU DDDD H H 000 EEEEE H H 0 0 E H H O 0 E HMHHH U 0 EEEE H H 0 0 E H H 0 0 E H N 000 EEEEE *START* USER PCAL MONITOR 8~8 KL10E37 *START* USER PCA6 MONITOR 8V~S KLlOE37 [IOZ07,602341 dOB APR 80. *START* [10707,60234] dOB APR-80. *START* SHIP SEQ. 4174 SHIP SEQ. 4174 DATE Ol-dUb-80 DATE Ol-dOb-80 10:04:5b 10:04:56 SSSSSSSS HH HH SSSSSSSS HH HH SS HH HH SS HH HH SS Hh HH SS HH HH SSSSSS H~HHHHHHHH SSSSSS HHHHHHHHHH SS HB HH SS HH HH SS HH HH SS NH HH SSSSSSSS HH HH II SSSSSSSS HH HH II ii 1I II Ii II I1 1i Ii ii II 11 1I ii 1I ii I1 I1 PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTT~ OOOOUO TTTTTTTTI~ OOOOOO TT OO O0 TT OO OO TT O0 O0 TT O0 OO TT O0 OO TT OO OO TT OO OO TT OD O0 TT OO DO TT OO OO TT OOOUOO TT 000000 / *START* USER PCAb [1070'7,602341 dOB SHiP SEO. 4174 DATE OI-JUL-80 MONITOR SWS KLlOE37 APR-80. *START* FILE: DSKH:SHIP TO<255>[10707 602]4] CREATED: 01-jUL-80 09:34:09 PRINTE6:Oi-JUD-80 16:05:12 OUf:UE SWITCHES: /f"ILE:~ORT /COPiES:I /$PACING:I /LIMIT:Il2 /FORMS:NORMAL 10:04:56 SHIP TO : PCCC THANKS SHiPP1NG iNSTRUCTiONS iSSUED I,-dUL-80 06:56 ~Y SFb PCCC VV VV EkEEEEEEEE VV VV kEEELEEE~ VV VV EE VV VV EE VV VV EL VV VV E~ VV VV ELE~E~L VV VV EEELEE~ VV VV EE VV VV LE VV VV ~E VV VV EL VV ~EEEEEEEEE R~R~RRR~ 1II111 R~ RR ii HR RR 1i RR RR II R~ RR 11 RRRRRRRR II RRRRRRRR 11 RR RR II RR RR II RR RR II RR RR Ii RR RR iiiiii RR RR 1IIIii XX YX XX 000000 000000 ,333333 000000 000000 333333 O0 00 O0 00 33 33 O0 O0 O0 O0 33 33 00 0000 O0 0000 33 00 0000 00 0000 33 00 00 O0 00 00 00 33 00 O0 O0 00 O0 00 33 0000 O0 0000 O0 33 0000 O0 0000 O0 33 O0 O0 O0 O0 33 33 O0 O0 O0 O0 33 33 000000 000000 333333 000000 000000 333333 START* USER PCA:6 [1070'7,60234] JOB SHIP SEO MONITOR SWS KLIOE37 APR-BO. *START* FILE: DS2B:¥ERI~¥,O03<057>[10707.60234] CREATED: P~iNTED: OI-JUL-B0 10:05:22 QUEUE SWITCHES: /f'iLE:FURT /COPIES:I /SPACING:i /LIMIT:il2 /FORMS:NORMAL 4174 DATE 01-JU6-80 01-JUL-BO 10:04:04 10:04:56 SCHLUMBERGER COMPUTING CENTRE 10707,60234 PEEL ~LADER LENGTH: 132 BtTES REEL NAME: P.C.A.L. SERVlCL NAME: LD1T REEL CONTINUATION NUMBER: O1 PREVIOUS REEL NAME: COMMENTS: LIS fORMAT CUSTOMER TAPE DATE: 80/ 71 I TAPE HEADER LENGTH: 132 BYTES TAPE NANE: 602]4 DATE: 80/ 7/ ! SERVICE NAME: EDIT tAPE CONTINUATION NUMBER: O1 PREVlOUS TAPE NAME: COMMENTS: TAPE COMMENTS TYPE ~'LUID CRUDE/ALL OTHER INtO NOT AVAILABLE/ TAKEN F~OM RUN TWO CNL LOGGED 2-3-80.......SFL LO~~ ~'iLE HEADER LENGTH: 62 BYTES FILE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FlEE NAME: ~ILE COMMENTS PASS THREE.....LOGGED 2-3-80 1024 BYTES WELL SiTE IN~':ORMATiON RECORD LENG~fB: COMPANi: WELL: ~ IRED: RANGE: TOWN: SECTION: COUNT Y: STATE: i81 BYTES ATLANTIC RICHFIELD CO. D.S. 4-9 ERUDH,OE BAY 14E 35 N. SL,OP~ ALAS~,A DATA ~O~MA~ SPECi~ICATIUN ~N~R~ BLOCK6: ~'PE 0 SIZE REP CODE ENIRX 1 66 0 DATUM SPEC i1~' ICAT.I UN ENTRY lC ~006 2 GR CNL NPHI CNL 4 NRAT CNL 5 NCNL CNL fCNL CNL 6VOI~D# UNI'['S APl APl APl AP1 FIL~,~ ~IZ~., EXP PROC SAM REP D5PT $itl~T FT 0 0 0 0 0 4 0 0 1 68 0 0 GAP1 92 31 32 0 0 4 0 0 1 bB 0 0 PU 42 b8 3 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CP& 42 34 93 0 0 4 0 0 1 68 0 0 DLPTH 11~95.000 11800.000 11700.000 11600.000 11500.000 11400.000 11300.000 11200.000 11100.000 11000.000 MN {JR fCNb G~ fCNb GR FCNL fCNL GR fCNL GR [~CNL GR f-CNL ~CNL f'CNb FCNL VALU -999. -999. 24. 131. 000 000 45O 703 58.350 202.059 26 211 18 312 178 110 131 121, 102 126 -1000 -999 -1000 -999 .950 .497 .050 .741 .750 .b82 .850 .407 .150 .126 .500 .250 .5OO .250 MNLMUNIC NPMi NPHI NPHI NPHI NPHI NPfiI NPHI NPHi NPNi VALUE -999.000 18.200 16.800 15.360 9.160 27.280 20.280 24.420 -99925.500 -99925.500 MN~MUNIC NRAT NRA't NRAT NRAT NRA% NRAT NRA~ NRAT NRAT NRAT VALUE -999.000 2.536 2.479 2.J62 1.882 ].112 2.726 3.002 -999.250 -999.250 MNEMUNIC NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb VALU~ -999.000 251.394 405.465 502.788 579.150 338.481 359.502 347.490 -999.250 -999.250 SUMMARY O~ DA~A ~CURD$ NUMBER 0~' R~,CORDS: 43 LENGTH OF' RS.,CORDS: 1014 B~TES LENGTH OF LAST RECORD: 654 BY'lES ~ILE IHAiLEP L~NGTH: 62 B~TES F1LE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT tILE NAME: 1024 BYTES ~OF FILE ~EADER LENGTH: 62 B~TES ~iLE NAME: EDiT .002 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FiLE NAME: ~;ILE COMMENT5 PASS ~OUR...LOGGED 2-3-80.......8~'L 1024 B~TES WELL SiTE iNFORMATION RECORD LENGTH: COMPANY: WELL: F'IELD: RANGE: TOWN: SECTION: COUNT~: STATE: 181B~TES ATLA,NTIC RICHFIELD CO. D.S. 4-9 PRUDH,OE BAY lin N. SLOPE ALASKA DA'I~A fOrMAT SPLCiFICATION LENGTH: 250 ENI~R~ BLOCKS: 0 SIZE 1 REP CODE 66 0 DATUPt ,SPEClf'ICATION B60C~S: lC 1 DkP?[~ 2 GR CNL NPHI CNL 4 NRA~[' CNb 5 NCNL CNL ~CNL CNL SVORD# UNITS AP1 AP1 AP1 AP1 FILE~ SIZE EXP PROC SAM REP DEP'£ SHifT FT 0 0 0 0 0 4 0 0 1 b8 0 0 GAPI 62 31 32 0 0 ~ 0 0 1 68 0 0 PU 42 68 3 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 q 0 0 1 68 0 0 DEPTH MNLMONlC VALUE 11895.000 GR -999,000 ~CNL -999.000 11800.000 GR 28.250 FCNL 135.564 11700.000 GR 5e.350 ~CNL 204.204 11600.000 G~ 26.850 fCNL 190.905 11500,000 GR 21,350 ~CNL 299.442 11400.000 GR 149.150 P'CNL 104.247 11300.000 GR 137.150 ~'CNL 114.114 11200.000 GR 108.550 P~CNL 117.117 11100.000 GR -1000.500 FCNL -999.250 11000.000 GR -1000.500 ~'CNL -999.250 MNEMONIC VALUE NPMi -999.000 NPHI 17.640 mPni 13.280 NPHI 15.480 NPHI 9.640 NPHI 29.900 NPMI 25,160 NPHI 24.980 NPRI -99925.500 NPHI -99925.500 NRAT NRA~ NRAT NRA~f NRAI NRAT NRA1 NRAT NRAT VALUE -999.000 2.560 2.144 2.436 1.894 3.264 5.022 3.024 -999,250 -999,250 MNEMONIC NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNL VALUE -999.000 364.221 448.305 463.749 556.842 320.463 347.0bl 338.052 -999,250 -999.250 LENGTH OF RECORDS: 101~ 0~g$ LENGTH O~' LAST RECORD: 654 BYTES FiLE TRAILER LENGTH: 62 BYTES FILE NAME: EDiT .002 MAXIMUM PHiSICAL RECORD NEXT FiLE NAME: LENGTH: 1024 BITES FILE HEADER LENGTH: 62 B~TES FILE NAME: EDIT .003 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: FILE COMMENTS BASE LOG..(DiGiTIZED)....LOGGED 1024 B~TES 23APR77.....SF[~ HELL SiIE COMPANt: WELL: ~'IELD: RANGE: TOWN: SECTION: COUNTY: STATE: INFORMATION RECORD 181 ~TES ATLANTIC RI, CHFIELD CO. D.S. 4-9 PRUDHOE BA~ ~5 ,N. S hO P ~ ALASKA DATA ~ORMAT SPECIFiCATI(3N I.,~]NGI~H: 170 BYTES E~TR ~ 8LUCKS: I 0 SIZE 1 REP CODE ~6 ENTRI 0 DATUM ,SPEC 1[:/.CAT 1ON ENTRY lC TOOL SVORD# UNITS AP1 AP]i APl APl FILE# 61Z~ EXP PROC SAM REP DEPT SHIEST DEPT 2 GR CNL NPHI CNL 4 N~AT CNb FT 0 0 0 0 0 4 0 0 1 68 0 0 GAPi 42 3! 32 0 0 4 0 0 I 68 0 0 PU 42 68 3 0 0 4 0 0 I 68 0 0 C/C 42 42 ! 0 0 4 0 0 1 ~8 0 0 / DEPTH 1{895.000 11800.000 11700.000 11600.000 11500.000 11400.000 11300.000 11200.000 11100.000 11000.000 MNEMONIC GR GR GR GI~ VALUL 67.438 28.172 55.531 24.203 18.250 130.875 124.563 101.188 86.500 -999.250 MN LMONiC VALUE NPHI 22.510 NPHI 22.168 NPHI 23.7]0 NPHI 22.510 NPHI 20.459 NPHI 47.363 NPMi 37.158 NPHI 40.625 NPH1 43.262 NPHI -99925.000 MNbMONIC N~AT NRAT NRAI NRA~ NRAI NRAT NRAT NRAT NRAT VALUE 2.979 2.818 2.920 2.949 2.760 4.477 3.789 4.OO0 4.227 -999.250 SUMMAHY O~ DATA RECUHDS NUMBER OF RP.,COFiDS: 29 LENGIH OP RECORDS: 1014 BitTES LENG'I~ OF LASI~ R~CORD: 438 BY%ES . P"ILE ~IRAILER LENGI'H: 62 BYTES ~[L~ NAME: kD1T .003 MAXIMUM PHYSICAL RECURD LENGTH: NEXT ~IL5 NAME: 1024 BYTES TAPE TRAILER LENGTH: 132 BYTES TAPE NAME: 60234 SERVICE NAME: EDIT i'APE CONTINUATION NUSBER: O1 NEXT TAPE NAME: COMMENTS: DATE: 80/ 71 I
