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194-146
STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r- Rug Perforations r Fracture Stimulate r Pull Tubing 1 Operations shutdown r Performed: Suspend r PerforateOther StimulateAlter Casing r r r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Tubing Patch Pr 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 194-146 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r' Service 1;7 ' 50-029-22523-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025628 • - KRU 1R-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): , N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured ., 11470 feet Plugs(measured) None true vertical 6945 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10530 true vertical 0 feet (true vertical) 6262 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121' 0 0 SURFACE 6383 9 5/8 6423 4073' 0 0 PRODUCTION 10669 7 10709 6391' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 11,197-11,237, 11,259-11,288 E 4` ( True Vertical Depth: 6749-6777,6792-6812 E� �Jt:.-- stoiS RECEIVED Tubing(size,grade,MD,and TVD) 3 1/2", L-80, 10545 MD,6272 TVD SEP 0 3 2015 Packers&SSSV(type,MD,and TVD) SEAL-BAKER SEALS @ 10530 MD and 6262 TVD AOGCC NIPPLE-CAMCO DS LANDING NIPPLE @ 532 MD and 531 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F.7 Exploratory r Development fl Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG 17 GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-427 Contact Brent Rogers/Kelly Lyons Email N1617conocophillips.com Printed Name Br t Roq sxrzy Title Problem Well Supervisor Signature Phone:659-7224 Date 08/29/15 Ze 1 9,T'j� RBDIVISeter O i tO Form 10-404 Revised 5/2015 Submit Original Only KUP INJ • 1R-32 Conoco fillips0 Well Attributes Max Angle&MD TD Alaska.Inc. • ° Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(RKB) I rv.,,,,,IP, 500292252300 KUPARUK RIVER UNIT INJ 61.09 81818.41 11,470.0 -°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Rig Release Date 1R-32,9(2(2015 10:18:29 AM SSSV:NIPPLE Last WO: 4200 12/17/1994 Venial achemabc(-actual) -Annotation Depth(ftKB) End Date 'Annotation Last Mod By End Date Last Tag RKB 11,340.0 4/25/2009 Rev Reason:PULL XXN PLUG hipshkf 7/22/2015 Casing Strings HANGER;38.1 9@ Casing Description OD(In) ID(In) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED j Caning Description 0D(In) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...-WI/Len(I...Grade Top Thread PC rf SURFACE 95/8 8.835 40.7 6,423.3 4,073.0 40.00 L-80 BTC Casing Description OD(in) SID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread `a, Mts.PRODUCTION 7 6.276 39.8 10,709.0 6,391.1 26.00 L-80 BTC-MOD Casing Description OD(In) ID(in) Top(ftKB) -Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L LINER 5. 4276 10,508.7 11,468.0 6,943.4 18.00 L-80 LTC Liner Details Nominal ID Top(RKB) Top(TVD)(RKB) Top Incl(°) Item Des Com (in) 10,508.7 6,246.9 44.83 TIEBACK TIE BACK SLEEVE 4.500 _e..i..✓, 10,516.0 6,252.1 44.88 PACKER BAKER H ISOLATION PACKER 4.408 CONDUCTOR;41.0-121 010,521.3 6,255.8 44.87 HANGER HMC HANGER 4.408 10,528.0 6,260.5 44.80 PBR BAKER POLISHED BORE RECEPTICLE 4.000 Tubing Strings Tubing Description String Me...ID(In) Top(local Set Depth(R..Set Depth(TVD)(...Wt(IbRt) Grade Top Connection TUBING 31/2 2.992 38.1 10,546.7 6, .9 9.30 L-80 ABM-EUE NIPPLE;532.0 Completion Details Nominal ID (In) Top(RKB) Top(TVD)(11KB) Top Incl(°) Item Dee 273Com 38.1 38.1 0.04 HANGER FMC GEN IV TUBING HANGER 3.500 532.0 530.9 8.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,482.1 6,228.0 45.08 NIPPLE OTIS XN LANDING NIPPLE 2.813"ID w/2.75 NO GO 2.750 10,515.6 6,251.8 44.88 LOCATOR BAKER LOCATOR 2.992 10,516.1 6,252.1 44.88 EXTENSION 3.000 10,530.2 6,262.1 44.76 SEAL BAKER SEALS 3.000 10,531.4 6,262.9 44.74 EXTENSION 3.000 SURFACE:40.7.6423.3-A A10,544.6 6,272.4 44.33 SEAL BAKER SEALS 3.000 10,546.2 6,273.5 44.29 MULESHOE BAKER HALF-MULESHOE 4.000 Perforations&Slots Shot GAS LIFT:10,436.2 Dens Top(TVD) Btm(TVD( (shots/f Top(RKB) Btm(RKB) (RKB) (RKB) Zone Date t) Type Corn 11,197.0 11,237.0 6,748.7 6,776.6 A-3,1R-32 5/1/1995 4.0'IPERF 2 1/8"Enerjet;180 deg. phasing;Oriented(+/-) 90 deg. 11,259.0 11,288.0 6,791.8 6,811.9 A-2,1R-32 '4/30/1995 4.0 IPERF 21/8"Enerjet;180 deg. NIPPLE;10,4821 phasing;Oriented(+/-) 90 deg. Mandrel Inserts St all on Top(TVD) Valve Latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(In) Sem Type Type (in) (psi) Run Date Com 1' 10,436.2° 6,196.4 CAMCO 'MMM 11/2 GAS LIFT °DMY RK 0.000 0.0 6/29/1996 12:00 Notes:General&Safety LOCATOR;10.515.6 End Date Annotation 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 6/15/2015 NOTE: LEAK BETWEEN 5492-5497 RKB SEAL;16530.2 SEAL:10644.6 MULESHOE;10646.2 PRODUCTION;39.8-10,709.0 IPERF;11,197.0-11237.0 - IPERF;11,259.0-11288.0 LINER;10.506.7-11,468.0 • S 111°-' . . RECEWED ConocoPhillips SEP 0 3 2015 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 August 29, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1R-32 (PTD 194-146). This report is for a patch set to repair a tubing leak above the top packer. After the patch was set, additional tubing leaks were identified and now the well will require a rig work over to repair the tubing. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, 4VBrent Rogers Problem Well Supervisor Attachments • • • 1 R-32 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/25/15 EQUALIZED 2.81"XXN PLUG @ 10,482' RKB, PULLED 2.81"XXN PLUG FROM 10,482' RKB, BRUSHED & FLUSHED PATCH SET AREA FROM 5481' RKB TO 5503' RKB WITH 2.72"x 20' DRIFT/BRUSH. *JOB IN PROGRESS 08/26/15 SET LOWER PARAGON II PACKER @ 5503' RKB. SET TEST TOOL IN LOWER PIIP AND PERFORMED PASSING CMIT TxIA TO 2500#. SET UPPER PATCH ASSY @ 5481'RKB. SET TEST TOOL IN UPPER PATCH ASSY. LRS UNABLE TO PERFORM MIT-T DUE TO IA TRACKING. AFTER CONFERING W/CWG REP, ADVISED TO INSPECT/RESET TEST TOOL AND PERFORM LEAK DETECT LOG IN MORNING. *JOB IN PROGRESS 08/27/15 LRS PERFORMED PASSING CMIT TxIA TO 2500#(COMFIRMING INTEGRITY OF PATCH ANCHOR SEAL ASSY AND TEST TOOL), PERFORMED LEAK DETECT LOG AND FOUND LEAKS @ 5262' RKB AND 3715' RKB (BOTH MID JOINT IN TBG). PULLED TEST TOOL FROM TOP OF PATCH @ 5481' RKB. *JOB IN PROGRESS; DUE TO ADD'L LEAKS JOB SCOPE NOW TO PULL PATCH AND PERFORM SBHPS FOR LATER RWO 08/31/15 PULLED TEST TOOL FROM TOP OF PATCH @ 5481' RKB, PULLED UPPER PATCH ASSY @ 5481' RKB. PULLED LOWER PACKER @ 5503' RKB. PERFORMED 30 MIN SBHPS @ 11197' RKB ( 3232.5 psia; 125.0*F) & 15 MIN GRADIENT STOP @ 11057' RKB ( 3187.7 psia; 139.6*F). *JOB COMPLETE. UPPER PACKER SERIAL#CPP35024 ANCHOR LATCH SERIAL#CPAL35019 LOWER PACKER SERIAL#CPP35025 Summary A Statewide retrievable patch was set. Diagnostics following the patch setting identified additional leaks in the tubing. The decision was made that a RWO tubing swap would be better than additional patches. The Statewide retrieable patch was pulled and the well will remain shutin. . • • • McMains, Stephen E (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, September 18, 2015 7:42 AM To: AOGCC Reporting (DOA sponsored) Cc: Wallace, Chris D (DOA); Regg, James B (DOA); Senden, R.Tyler Subject: KRU 1R-32 schematic Attachments: 1R-32 schematic.pdf Steve, Here is a copy of the current schematic for 1R-32. It does not have the tubing patch on the schematic because the patch was pulled back out. After setting the patch, additional leaks in the tubing were identified and the decision was made that it would require a RWO to repair the well. The 10-404 was submitted to close out Sundry 315-427 for the tubing patch since it is no longer valid with the additional leaks. Please let me know if you need anything else. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 1 tiOF 7.1.1-4' y ��w,,,\ s7 THE STATE Alaska Oil and Gas �,�,,, ��, of Conservation Commission - P- - _ ALASI<:A '. x___, ;_ 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \Tti ______/; Main. 907 279.1433 ALAS� (1 I` Fax: 907.276.7542 ° ••,'i, ''It - www.aogcc alaska.gov Kelly LyonsI L 47 Problem Wells Supervisor I T ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-32 Sundry Number: 315-427 Dear Ms. Lyons: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 2.-tday of July, 2015 Encl. • STATE OF ALASKA .SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate n Pull Tubing r Operations shutdow n r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redd! r Perforate New Pool r Repair Well Re-enter Susp Well r Other Tubing patch 1.7 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc . Exploratory r Development r" 194-146 • 3.Address Stratigraphic r Service r.% 6.API Number P 0 Box 100360,Anchorage,Alaska 99510 50-029-22523-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? .JA -h Will planned perforations require spacing exception? Yes r No r 11.' KRU 1 R-32 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025628 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured) Junk(measured). 11470 6945 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' — SURFACE 6383 9.625 6423' 4073' - RECEIVED PRODUCTION 10669 7 10709' 6391' LINER 959 5 11468' 6943' JUL r4 1Ui5 -- WAS 1/ 1.4.45, - - .AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): _ 11197'-11237'& 11259'-11288'd 6749'-6777'&6792'-6812' 3.5 L-80 10545 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER H ISOLATION PACKER MD=10516 TVD=6252 , NIPPLE-CAMCO DS LANDING NIPPLE MD=532 TVD=531 12.Attachments: Description Suary of Proposal 13. Well Class after proposed workSummaryDetailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P` 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 8/9/2015 OIL r VVINJ r WDSPL r Suspended r GSTOR r- 16.Verbal Approval: N/A Date: GAS r WAG r' SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned 1.- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Kelly Lyons/Brent Rogers Email.n1617@conocophillips.com Printed Name .,,,,,,,,...I/ 0 S� Title.Problem Wells Supervisor Signature _---------- Phone:659-7224 Date 7/12/15 c_--------- �/ '' Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness _ "j(5r q2-7 Plug Integrity r BOP Test r Mechanical Integrity Test 47'Location Clearance r Other. / ‘,7) cc i cN-7 fwrC w , fr7c-5Sfci 1 T - / 4"/ /t re-� I-/ � ,--r-1 4itr%' . t--,g i•li jcci Spacing Exception Required? Yes ❑ No lj Subsequent Form Required: /0 .— ,90 i. �� APPROVED BY _ Approved by: pprov Gcation is va0 rl .°months from thTe EdaPcoor approvaI. Date: 7—2-# a V1'L� / Submit Form and Form 10-403 Revised 5/2 15 0 I G I N A L �II��� Attac a is in Duplicate X79,ern RBDM AUG - 2 2015 • ~7- • • ConocoPhillips Alaska RECERIED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 J U L 1 4 z015 AOGCC July 12, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. KRU well 1R-32 (PTD 194-146). This request is for approval to patch a tubing leak above the top packer. Please call Brent Rogers or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, !/ i / Kelly Lyons Problem Wells Supervisor Attachments ConocoPhillips Alaska, Inc. KRU Well 1R-32 (PTD 194-146) SUNDRY NOTICE 10-403 TUBING REPAIR 7/12/15 On June 8, 2015, the AOGCC was initially notified of suspected TxIA communication. Diagnostics have identified TxIA leak at 5492'-5497' RKB, which is approximately 5019' above the top packer. The repair plan is to set a retrievable patch over the leak point, conduct an MITIA to verify tubing and patch integrity, and return the well to normal WAG injection. REPAIR PLAN 1. Set 22' 3.5"retrievable patch over the leak at 5492'-5497' RKB. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post-repair. NSK Problem Well Supervisor g, KUP INJ 1R-32 ConocoPhillips S Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status InclII MD(ftKB) Act Btm(ftKB) [..r.i7ilhps 500292252300 KUPARUK RIVER UNIT INJ 61.09 8,818.41 11,470.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 114-32,6/20/201 5 4.31D9 PM SSSV:NIPPLE Last WO: 42.00 12/17/1994 Vertical schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:RKB 11,340.0 4/25/2009 Rev Reason:SET PLUG lehallf 6/20/2015 1 Casing Strings HANGER;391-1i IIF Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED Casing Description 00(in) ID(in) Top(kKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �t SURFACE 95/8 8.835 40.7 6,423.3 4,073.0 40.00 L-80 BTC �n l Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread h _n PRODUCTION 7 6.276 39.8 10,709.0 6,391.1 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 5 4.276 10,508.7 11,468.0 6,943.4 18.00 L-80 LTC I Liner Details Nominal ID .H. Top(ftKB) Top(ND)(kKB) Top Incl(') Item Des Com (in) .7� 10,508.7 6,246.9 44.83 TIEBACK TIE BACK SLEEVE 4.500 .11 10,516.0 6,252.1 44.88 PACKER BAKER H ISOLATION PACKER 4.408 CONDUCTOR;41.0-121.0- i + 10,521.3 6255.8 44.87 HANGER HMC HANGER 4.408 10,528.0 6,260.5 44.80 PBR BAKER POLISHED BORE RECEPTICLE 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE;532.0 TUBING 31/2 2.992 38.1 10,546.7 6,273.9 9.30 L-80 ABM-EUE Completion Details Nominal Io Top(ftKB) Top(ND)(ftKB) Top Incl I") Item Des Com (in) 38.1 38.1 0.04 HANGER FMC GEN IV TUBING HANGER 3.500 532.0 530.9 8.26 NIPPLE 'CAMCO DS LANDING NIPPLE 2.812 10,482.1 6,228.0 45.08 NIPPLE 'OTIS XN LANDING NIPPLE 2.813"ID w/2.75 NO GO 2.750 10,515.6' 6251.8 44.88 LOCATOR BAKER LOCATOR 2.992 • • 11516.1' 1252.1 44.88 EXTENSION 3.000 • 11530.2 6262.1 44.76 SEAL BAKER SEALS 3.000 SURFACE;40./.6423.3-� ,. 11531.4. 6,262.9 44.74 EXTENSION 3.000 10,544.6' 6,272.4 44.33 SEAL BAKER SEALS 3.000 10,546.2 6,273.5 44.29 MULESHOE BAKER HALF-MULESHOE 4.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;10,436.2 Top(ftKB) (kKB) (') Des Com Run Date ID(in) III10,482.0 6,227.9 45.08 PLUG XXN PLUG 6/14/2015 Perforations&Slots I Shot Den Top(TVD) Btm(ND) (shotsk NIPPLE;10,482.1 � I Top(ftKB) Btm(ftKB) (kKB) (kKB) Zone Date t) Type Cent I 11,197.0 11,237.0 6,748.7 6,776.6 A-3,1R-32 5/1/1995 4.0 IPERF 2 1/8"Enerjet;180 deg. PLUG;10,482.0 I�fI phasing;Oriented(c/-) 90 deg. • • 11,259.0 11,288.0 6,791.8 6111.9 A-2,1R-32 4/30/1995 4.0 IPERF 2 1/8"Eneriet;180 deg. phasing;Oriented(+/-) 90 deg. Mandrel Inserts 41 st ati LOCATOR;10.515.fi N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 10,436.2 6,196.4 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6129/1996 Notes:General&Safety i/.. . End Date Annotation 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 6/15/2015 NOTE:LEAK BETWEEN 5492-5497 RKB SEAL;10,530.2 ilr�-i 7 SEAL;10,544.6 i 1 MULESHOE;10.546.2 PRODUCTION;39.8-10.709.0 IPERF;11,197.0-11,237.0 i1 IPERF;11,259.0.11,288.0 J LINER;10,508.7-11,468.0 k°0-t- 2 2599-2 WELL LOG TRANSMITTAL DATA LOGGED i/114/2015 K.BENDER To: Alaska Oil and Gas Conservation Comm. June 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501IIr; * '.r` JUIN 26 2tili RE: Multi Finger Caliper(MFC): 1R-32 Run Date: 6/18/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1R-32 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22523-00 gotta III i '- PLEASE .PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signe Ot-E:Ae Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 08, 2015 3:20 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: 1R-32 (PTD 194-146) Report of IA pressure increase. Attachments: Picture (Device Independent Bitmap) 1.jpg; 1R-32 90 day TIO plot.JPG; 1R-32 schematic.pdf Chris, Kuparuk injector 1R-32 (PTD 194-146) was reported with an increase in IA pressure while on water injection. The immediate action was to shut the well in and freeze protected. The well recently passed a witnessed MITIA on 05/08/15 but the follow up MITIA failed. Further diagnostics will be performed with Slickline, E-Line or Digital Slickline as needed. Once the diagnostics have been completed and a path forward has been decided, the appropriate paperwork will be submitted at that time to return the well to service or for repair. The well will be added to the monthly report. Attached is a wellbore schematic and 90 day TIO plot. ME® JUN 3 0 2015 WNNotes: Startell Dateame 3110/20151R-32 Days 90 End Date 61812015 2ECC - — 1 _WHP Annular Communication Surveillance IAP OAP — 1' WHT 2CCC -I 1 1. 1ECC 1 _ 1CCC 91 U) - RI ECC I V7 C r— E i Fet-1E 1:1ar--1E Mar-1E Mar-15 Apr-15 Apr-15 Apr-15 May-15 May-15 May-15 Jun-1E Jun-1E 2 e •' • Fet-1E Mar-1E Mar--15 Mar--1E Apr-15 Apr-15 Apr-15 May-1E May-1E May-15 Jun-15 Jun-15 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907) 659-7000 pgr. 909 iftWELLS TEAM conn,oRrt6q 2 • .,. KUP 1R-32 Col 1ocort Cilligg,�I�.� tWell Attributes Max Angle&MD TD Alaska. Wellbore APWWI Field Name Well Status Ind(1 MD)Rnt(ftKB) AB6n(ftKB) r-nnocy+,llups 500292252300 KUPARUK RIVER UNIT INJ 61.09 8,818.41 11,470.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ""• Well ConSe -1R32,625/201210x1/'.52 AM SSSV:NIPPLE Last WO: 42.00 12/17/1994 Schematic-Actual Annotation Depth(ftKB) End Data Annotation Last Mod...End Date Last Tag:RKB 11,340.0 4/25/2009 Rev Reason:WELL REVIEW osborl 6/25/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED RANGER,38 1:1, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...Strng Top Thrd SURFACE 9 5/8 8.835 40.7 6,423.3 4,073.0 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 39.8 10,709.0 6,391.1 26.00 L-80 BTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd 91LINER 5 4.276 10,508.7 11,468.0 6,943.4 18.00 L-80 LTC Liner Details Top Depth (1VD) lop Incl Nomi... Top(kKB) (ftKB) I") Item Description Comment ID MI 10,508.7 6,246.9 44.83 TIEBACK TIE BACK SLEEVE 4.500 10,516.0 6,252.1 44.91 PACKER BAKER H ISOLATION PACKER 4.408 CONDUCTOR, 10,521.3 6,255.8 44.87 HANGER HMC HANGER 4.408 41-121 10,528.0 6,260.5 44.93 PBR BAKER POLISHED BORE RECEPTICLE 4.000 Tubing Strings Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TED)...String Wt..String... String Top Thrd TUBING 31/2 2.992 38.1 10,546.7 6,273.9 9.30 L-80 ABM-EUE NIPPLE,532 Completion Details Top Depth (TVD) Top Ind Nomi... Top(ftKB) (RKB) r) Item Description Comment ID gn) 38.1 38.1 -0.90 HANGER FMC GEN IV TUBING HANGER 3.500 4. 532.0 530.9 8.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,482.1 6,228.0 44.85 NIPPLE OTIS XN LANDING NIPPLE 2.813"ID w/2.75 NO GO 2.750 10,515.6 6,251.8 44.91 LOCATOR BAKER LOCATOR 2.992 10,516.1 6,252.1 44.91 EXTENSION 3.000 } 10,530.2 6,262.1 44.84 SEAL BAKER SEALS 3.000 SURFACE, ". ' 10,531.4 6,262.9 44.80 EXTENSION 3.000 41-6,423 10,544.6 6,272.4 44.25 SEAL BAKER SEALS 3.000 10,546.2 6,273.5 44.23 MULESHOE BAKER HALF-MULESHOE 4.000 Perforations&Slots GAS LIFT, Shot 10 436 Top(TVD) Bbn(TVD) Dens Top(RKB)Btrn(NKB) (NKB) (kKB) Zone Dab (sh•-- Type Comment 11,197.0 11,237.0 6,748.7 6,776.6 A-3,1R-32 5/1/1995 4.0 IPERF 21/8"Enerjet 180 deg.phasing; Oriented(+/-)90 deg. 11,259.0 11,288.0 6,791.8 6,811.9 A-2,1R-32 4/30/1995 4.0 IPERF •21/8"Enerjet;180 deg.phasing; Oriented(+/-)90 deg. NIPPLE,10,482 1. Notes:General&Safety End Date Annotation 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR, 10,516 SEAL,10,530 SEAL,10645 MULESHOE. 10,646 PRODUCTION.09 Mandrel Details Top Depth Top Port (TED) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) (°) Make Model en) , Sem Type (in) (pet) Run Date Cont.. 1 10,436.2 6,196.4 47.43 CAMCO MMM 1 1/2�GAS LIFT-DMY RK 0.000 0.0 6/29/1996 IPERF, 11,197-11,237 IPERF, 11,259-11,288 LINER, 10,509-11,468 TD,11,470 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Wednesday,May 13,2015 P.I.Supervisor �( I ' SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1R-32 FROM: Lou Grimaldi KUPARUK RIV UNIT 1R-32 Petroleum Inspector Src: Inspector Reviewed By:" P.I.Suprv- L e NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IR-32 API Well Number 50-029-22523-00-00 Inspector Name: Lou Grimaldi Permit Number: 194-146-0 Inspection Date: 5/8/2015 Insp Num: mitLGI50508152525 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1R-32 - Type Inj W•TVD 6253 Tubing 2200 2250- 2250• 2250 • PTD 1941460 - Type Test SPT Test psi 1563 - IA 500 3010 2990 - 2995 Interval 4YRTST P/F P OA 140 440 - 440 - 440 Notes: 2.8 bbl's diesel pumped,4.0 bbl's returned.Good solid test.All required paperwork supplied prior to test. . fr44t<6I,e6L ' t) eQ i- J-- Iso f 5VUe--3 plot 2-) CC•Lrr e- - c,Jp l t S�Ge�,raH C SCANNED JUL 1 0'2015 Wednesday,May 13,2015 Page 1 of 1 duuallamogo 0 CD a C L ; C) 1p I Al II 11 it , I , I, 1 ea ,I , i I I I, I, i II II r I , 1, I; v • I _ m4 : 5, • • • • • • rl Li) • • • ti ; : • I ta • 0- \e' . { cis 2 • • •• : • : r • I • : / • • I • • I rr : : • I w .1 i I' +' I ' I I I '1 1 1 I'�' I I ' I 'I 'I 1 11 1' I e '1 'I I _ � G7 Co c O LL O CD C 1 1 ISd • \ KUP 1 R-32 ConocoPhillips 041 Well Attributes Max Angle&MD TDIMI • AlHske.11x: /i Wellbore APIII Field Name Well Status Incl(') MD B) Act Ben(RKB) c«,ocy,hlu,pl 500292252300 KUPARUK RIVER UNIT INJ 61.09 8,818.41 11,470.0 Comment H2S(ppm) Dab Annotation End Dab KB-Ord(ft) Rig Release Date --- Well Corfig -iR32,825/201210'14x52 AM SSSV:NIPPLE Last WO: 42.00 12/17/1994 Schemeec-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:RKB 11,340.0 4252009 Rev Reason:WELL REVIEW osbod 6/25/2012 Casing Strings re--- --- • Casing Description String 0... String ID...Top(RKB) Set Depth If...Set Depth(TVD)...String WE..String...String Top Thrd CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H-40 WELDED HANGER,38 --1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 95/8 8.835 40.7 6,423.3 4,073.0 40.00 L-80 BTC - Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 39.8 10,709.0 6,391.1 26.00 L-80 BTC-MOD - Casing Description String 0... String ID...Top(KKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd - '"4 LINER 5 4.276 10,508.7 11,468.0 6,943.4 18.00 L-80 LTC Liner Details Top Depth (TVD) Top kiwi Nomi... Top(ftKB) (ftKB) (') Item Description Comment ID(In) 10,508.7 6,246.9 44.83 TIEBACK TIE BACK SLEEVE 4.500 10,516.0 6,252.1 44.91 PACKER BAKER H ISOLATION PACKER 4.408 CONDUCTOR, 10,521.3 6,255.8 44.87 HANGER HMC HANGER 4.408 41-121 10,528.0 6,260.5 44.93 PBR BAKER POLISHED BORE RECEPTICLE 4.000 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd TUBING 312 2.992 38.1 10,546.7 6,273.9 9.30 L-80 ABM-EUE NIPPLE,532 .■ Completion Details �_ Top Depth (ND) Top not Nornl.,. IIP Top(MB) (RKB) (1 Item D..arlpnon Comment ID(In) 38.1 38.1 -0.90 HANGER FMC GEN IV TUBING HANGER 3.500 5320 530.9 8.26 NIPPLE CAMCO DS LANDING NIPPLE 2.812 • I 10,482.1 6,228.0 44.85 NIPPLE OTIS XN IANDING NIPPLE 2.813"ID w2.75 NO GO 2.750 10,515.6 6,251.8 44.91 LOCATOR BAKER LOCATOR 2.992 • 10,516.1 6,252.1 44.91 EXTENSION 3.000 -� • 10,530.2 6,262.1 44.84 SEAL BAKER SEALS 3.000 SURFACE,_ . 10,531.4 6,262.9 44.80 EXTENSION 3.000 41-0'423 - 10,544.6 6,272.4 44.25 SEAL BAKER SEALS 3.000 _ 10,546.2 10,546.2 6273.5 44.23 MULESHOE BAKER HALF-MULESHOE 4.000 Perforations&Slots CTAS LIFT, C Shot 10,435ri! Top(ND) Oho(ND) Dene Top(NKB)elm(RKB) (KK8) (KKB) Zone Dab (eh--- Type Comment 11,197.0 11,237.0 6,748.7 6,776.6 A-3,1R-32 5/1/1995 4.0 IPERF 2 1/8"Enerjet;180 deg.phasing; Oriented(+/-)90 deg. 11,259.0 11,288.0 6,791.8 6,811.9 A-2,1R-32 4/30/1995 4.0(PERF 21/8"Enerjet;180 deg.phasing; • Oriented(+/-)90 deg. NIPPLE,10,482 - Notes:General&Safety End Date Annotation 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 r LOCATO10,5R5, 1 SEAL,10,530 i°17.. SEAL,10,545 - MULESHOE, 10,546 PRODUCTION, 709 Mandrel Details i Top Depth Top Port (TVD) Incl OD Valve Latch Sins TRO Run Stn Top(MB) (KS) P) Make Model (In) Sero Type Type (in) (Pet) Run Date Com... 1 10,436.2 6,196.4 47.43 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 6/29/1996 IPERF, 11,187-11,237 li M IPERF, 11,250.11,200 11/1 I LINER, 10,509-11,408 N TD.11,470 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ? ~-. / Z//'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~incent TO RE-SCAN Notes: Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si • ~ ~ ~onocoPhi!l~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360-- February 1, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~ ~Ai~ ~ ~ ?Q~Q Dear Mr. Dan Seamount: • ~~rv ~ ~iaska Oil ~ GSS Ceps. Commission d~~cerge R'3~- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIJ). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December 5`t', 2009. The corrosion inhibitor/sealant was pumped December 22°d, 25~`, 26`~ & 28~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ;~ Klei ConocoPhillips Well Integrity Projects Supervisor • u ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuearuk Field . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Kè'tCZ (./4(07 DATE: Fnday, May) 1, 2007 SUBJECT: Mechamcal Integrity Tests CO,\OCOPHILUPS ALASKA INC IR-32 KUPARUK RIV L'NIT IR-32 . /1Uh \ ~LY FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Jl¥'.-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IR-32 Insp Num: mitRCN0705I0213751 Rei Insp N um: API Well Number: 50-029-22523-00-00 Peruùt Number: 194-146-0 Inspector Name: Bob Noble Inspection Date: 5/9/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well! IR-32 ¡Type Inj. ì W I TVD I 6253 i IA I 660 j 2610 : 2590 2580 -- I ' P.T.DI 1941460 ITypeTest I SPT! Test p~ii~325 lOA 1- ;'8;;--T ·····~··,-¡;-;;-¡--6~-_u~ ~-~-- I~;erval=--==-_ P/F-----L.-~ --~ ~.~ . !~bi~gT 2~;S~~-;~;----¡-- .=075' i_ 2075 ....1 : .._._~ Notes: s~ JUN 0 6 2007 ~. ." ~,..' "",;"., "~__ _:""__.,,_.....,..._~~~.~.~........ ,,>0.... Friday, May It, 2007 Page) of I ) ConocóP'hillips ) Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 R-32 (APD # 194-146) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 R-32. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, NtlM~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV 2 4 2004 nICiN..I.Ai !;., L- ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D RepairWell D Alter Casing D Pull Tubing D Change Approved Program D Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 86' 8. Property Designation: ADL 25628, ALK 2561 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D measured 11470' feet true vertical 6945' feet measured 11330' feet true vertical 6841' feet Length Size MD 121' 16" 121' 6337' 9-5/8" 6423' 10623' 7" 10709' 961' 5" 11470' Measured depth: 11197'-11237', 11259'-11288' true vertical depth: 6749'-6777', 6792'-6812' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10547' MD. Packers & SSSV (type & measured depth) Baker 'H' isolation pkr @ 10517' Cameo 'OS' Landing Nipple 532' 12. Stimulation or cement squeeze summary: Stimulate 0 Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 194-146/ 6. API Number: 50-029-22523-00 Exploratory D Service 0 9. Well Name and Number: 1 R-32 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Collapse Burst 121' 4073' 6391' 6945' Intervals treated (measured) 11197'-11237', 11259'-11288' 747 bbls of slick seawater 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 785 1118 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl n/a Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations_X Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney Title Phone II¡. ,i,(~M8I:s"L NOV" 2 1004 0 Form 1 0-404 Revised 04/2004 Casinq Pressure Tubinq Pressure 2157 2174 WDSPLD Kuparuk Wells Team Leader Date Jl /2 'l! () '1 Prepared bv Sharon Allsup-Drake 263-4612 í L-. Submit Original Only ') 1 R-32 Well Events Summary ) Date Summary 11/01/04 POOR BOY HPBD COMPLETED. PUMPED 747 BBLS OF 60 DEGREE SLICK SEAWATER. MAX WHTP 3875 PSI & MAX RATE ACHIEVED 9.6 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN [HPBD] ) ) ConocoPhillips Alaska, Inc. KRU 1 R-32 ¡, r '¡ NIP (532-533, U I 00:3,906) :1 I I ¡ TU 81 NG dill (0-10547, ! !. 00:3,500, I 10:2,992) I II Gas Lift mdrel/Oummy Valve 1 (10436-10437, .. 00:6,018) NIP (10482-10483, 00:3,500) , .............. I I SEAL (10515-10517, 00:4,000) LINER (10509-11470, 00:5,000, WI: 18.00) ! ¡ I I ~! I I . ~1 I I "I '; J Ik Li ¡ft'. ~,..( ! . ; ~. :1 if I MULESHOE (1054fr 10547, -I PROD, CASING t (0-10709, ! I , 00:7,000, ~ Wt26,oo) ~ -'--1 ~ Perf --1 (11197-11237) ~ ~I -'I j! Perf -oJ C (11259-11288) t"-- 3 F 1 R-32 API: 500292252300 SSSV Type: NIPPLE Well Type: INJ Orig 12/17/1994 Completion: Last W/O: Ref Log Date: TD: 11470 ftKB Max Hole Angle: 61 deg @ 8818 Angle @ TS: 42 deg @ 10969 Angle @ TD: 41 deg @ 11470 Rev Reason: Add jewelry Last Update: 6/3/2003 Annular Fluid: Reference Log: Last Tag: 11330 Last Tag Date: 5/16/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16,000 SUR, CASING 9.625 PROD. CASING 7.000 LINER 5.000 Tubing String - TUBING Size I Top 3.500 0 Perlorations Summary Interval TVD 11197-112376749-6777 Bottom 10547 Top Bottom TVD Wt Grade Thread ° 121 121 62.58 H-40 ° 6423 4073 40.00 L-80 ° 10709 6391 26.00 L-80 10509 11470 11470 18,00 L-80 TVD Wt I Grade I Thread 6274 9,30 L-80 ABM-EUE Status Ft SPF Date Type Comment 40 4 5/1/1995 IPERF 2 1/8" Enerjet; 180 deg, phasing; Oriented (+/-) 90 deg. 29 4 4/30/1995 IPERF 2 1/8" Enerjet; 180 deg. phasing; Oriented (+/-) 90 deg. Zone A-3 11259-11288 6792-6812 A-2 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 10436 6196 Camco MMM Other (Jlugs, equip., etc.: - JEWELRY Depth TVD Type 532 531 NIP Camco 'DS' Landing Nipple 10482 6228 NIP Otis 'XN' Landing Nipple 10516 6252 SEAL BAKER SEAL ASSEMBLY WILOCA TOR & EXTENSIONS 10517 6253 PACKER BAKER 'H' ISOLATION PACKER FOR 5" LINER 10528 6261 PBR BAKER POLISHED BORE RECEPTACLE 10546 6273 MULESHOE Baker (half-muleshoe) V Mfr V Type V aD Latch Port TRO Date Run RK 0,000 ° 6/29/1996 Vlv Cmnt DMY 1,5 ID 2,812 2.750 3,000 4.408 4.000 4.000 Description MEMORANDUM TO: THRU: FROM' State of Alaska Alaska Oil and Gas Conservation Commission Commissioner SUBJECT: Mechanical Integrity Tests Jim Regg ConocoPhillips Alaska Inc. P.I. Supervisor~'%~'~. 1R Pad 1R-04, 1R-13, 1R-32, 1R-33 Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I We,,I 1R-O4 J Type,nj.I G I T.¥.D. I~ J Tubing I ~0 I ~0 I~0 I ~,~0 J,ntervalI4 I P.T.D.J 1851780 Type testJ P J TestpsiJ 1596 JCasingJ 1150 J 2500J 2420 J 2410 J P/F I E I Notes: Test fluid: 2.2 bbls diesel. I Packer Depth Pretest Initial 15 Min. 30 Min. weuJ1R-13 Type lnj. J SJ T.V.D. J6420 J Tubingl ~0 I ~,0 I ~0 I~0 I,.,~,14 P.T.D.J 1851500 Type testJ P J TestpsiJ 1605 JCasingJ 1125 I 3000 I 2970J 2940J P/F J __P Notes: Test fluid: 2.5 bbls diesel. Held press, test extra 15 min. Tubing =2350 psi / Casing =2920 psi final. Packer Depth Pretest Initial 15 Min. 30 Min. w~,,I1R-32 I,~,e,.i.I s I T.V.D. I~ J TubingJ 2360 I 2360 I~o I ~o J lntervalI 4 P.T.D.J 1941460 Type testJ P J TestpsiJ 1563 J CasingJ 1350 I 3O4O I 3020 I 3020 I P/F I R Notes: Test fluid: 3.3 bbls diesel. Packer Depth Pretest Initial 15 Min. 30 Min. Jw~,,I 1R-33 ,.i.I s J T.V,D.J 6596 J Tubing J2350 I ~0 I~0 I~0 J lnterva,J 4 P.T.D.J 1941560 IType Type testJ P J TestpsiJ 1649 JCasingJ 225 J 3150 J 3125 J 3125 J P/F J _P JNotes: Test fluid: 8 bbls diesel. /,. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details May 31, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAI) Kuparuk River Field injection wells 1R-04, 1R-13, 1R- 32 and 1R-33, to witness 4 year MITs. Nina Woods was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with all four wells meeting the criteria for successful MITs. The pressure test on well 1R-13 was extended an extra 15 minutes to further demonstrate a non-linear trend toward stabilization. I inspected four well houses and one exception was noted; the swab valve on well 1R-04 was leaking from the balance chamber and was repaired while I was on the pad. Summary: I witnessed successful MIT's on CPAI's injection wells 1R-04, 1R-13, 1R-32 and 1R-33 in the Kuparuk River Field. Four well house inspections, one exception. M.I.T.'s performed: _4 Number of Failures: O Attachments: Wellbore schematics (4) . . Total Time during tests: _5 cc: MIT report form 5/12/00 L.G. 5~NED JUL 0 ? 2003-053 I_M IT_KRU_ 1R-33_jj .xls 6/19/2003 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 1R~04~.. '.':.. ~: ..... '~ SSSV ~ (lS02-1~33, 0D:3.500) PBR OD:3.500) PKR (7815-7816, 0D:6.156) PATCH (784O-7858, 0D:2.750) SLEEVE-C (79&5-7986, 0D:2.750) PKR (8024-8025, 0D:6.156) NIP (8O39-804¢ 0D:2.875) Perf (81168134) KRU 1R-04 APl:15002 92140700 SSSV Type:I Locked out I Annular Fluid:I Reference Log:I Last Tag:18229 Last Tag Date:13/1/2000 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: INJ , 9/18/1985 8440 ftKB 49 de~(~5200 Angle (~ TS:I41 deg @ 7823 Angle @ TD:I38 deg @ 8440 I Rev Reason :1 Sleeve update by Last Update:J6/9/2002 Description Size I Top Bottom TVD I Wt I Grad~l Thread CONDUCTOR 16.000 [ 0 115 115 165.001 H-~0 I SURF CASING 9.625 0 4297 3927 I 36.00 I J-55 I PROD CASING 7.000 0 8427 6853 I 26.00 I J-55 I Comme~{ 5"Expendable HJII;120 stI MD I TVD IManIManI v Mfr Iv Type I v OD I Latc'h I .o. I T.Ol Date I Mfr Type , ,. Run 1 ]2277122751MedaI TMPD [ I DMY 11.0 I BK 10.00010 17,14,19901 2137291 35161 Me,a ITMPD I I DMY I1.0 I BK 10.0001 0 17n4/19901 3151591 45201 Mefla I TMPD I I DaY 11.0 I BK 10.0001 0 17/14/19901 4157841 49381 Mefla I TaPE I I DaY [ 1,0 [BE 10.0001 0 17/14/19901 5'I 62861 52791 Mefla I TaPE I I DaY [1.0 [ BK 10.0001 0 [8/26/1990I 6167841 5632[ Mefla I TaPE I I DaY [1.0 I BEio.oooI0 18/26/19901 7[72541 5973[ aedaITMPD I I' DaY 11.0IBKio.oooI0 [8/26/1990I 8'I 77531 63381 Meda I TPDX I / DaY / 1.5 IRa 10.0001 0 /4/1/20001 9178541 64141 Medal TMPD I ~)MY/PATCI~ 1.0 I BK 10.0001 0 ~10/23/199~ Depth lTVD I Type 1802 118021 sssv 7801 I 6374 I PBR 7815 16384 I PKR 7840 [6403[ PATCH 7985 165121 N~P 8024 16542 I PKR 8039 16553 I NIP 8047 165591 sos 8048 16560 I TTL VIv Cmnt Description I D Baker'FVL' (Locked Out 6/8~95) 2.812 Baker 3.000 Baker 'FHL' 3,000 HES RCP patch, lenth 27.45', isolating station #9 GLM - set 5/712000 1.370 Set 2.75" BPI SLV 4/1/00. 2.750 Baker 'FB-I' 4,000 Camco 'D' Nipple NO GO. 2.250 Camco 2.441 2.441 Other (plugs, equip, etc.I - SLEEVE DepthI TVD I Type Description I ID 7985 I 6512 I SLEEVE-C BPI lSD sleeve set4/1/2000 I 2.310 Fi~I¥i~:!F!S!H~';::::!?.;..';..:i:?::.:?:'::... ::.,:::::.::;:.'i:,;! ::?;i:;~.'.i: :?~.~.;'~;:.:::::i.'::'.::::::?:i?'..":i::i'?.: i:;~;.:.i::..:? !::':!; ..!'ii.'::; i': ::?,: ;~'~:" !:.:;~.'.i :/:./' :i?'==:.'=~ ?? !?.;!~i'i .?? ~/:: :::=;?./i,i .?.:?'~/?~:.~i ~= :~= !??:' Date I Note 3/1/2000 IFound possible leaks (~ 7858' WLM & 7842' WLM; Ref: WSR 3/1/2000 4/2/2000 I Drifted tubing w/23.5" X 2.79 dummy patch to 7910' WLM. 4/10/2000~ Drifted tubing w/27' x 2.473" dummy patch to 7900' PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY (1824-1825, 0[:):2.875) NIP (7822-7823, OD:2.875) SBR (7861-7862, 0D:2.875) PKR (7880-7881, OD:6.156) PERF (8O3O-8O40, OD:2.875) PKR (8096-8097, OD:6.156) Nlf (8116-8117, 0D:2.875) TUBING (0-8124, OD:2.875, ID:2.441) Perf (8210-8266) Ped (8290-8300) Perf (8330-8340) KRU 1R-13 .... .A_ngl.e~, T__S:.__45.~ddeg @ 7969 .Angl_o_~ T.~D:. 4.4~deg @ 8570 .. ~ Rev Reason: Tag fill La. st .Updato: ' 3,?/01 11R-13 SSSV T~__e:..TRDP · Orif~ .ComF'et!(jn_:..~:~2.9/8.5 Annular Fluid: Last W/O: 11110/88 Reforonce Log~ .......... + .RefLog Date:' Last Tag: ' 8303 TD:'i 8~70 'ftKB .... Las: Taq Date: 3i6101 Max Hole Angl.e.'.!..5_l_d.eg ~' 67_.00_ .... iCa_s, in_.q._S_t, ri__n.9 - ALL STRINGS Description SURFACE PRODUCTION CONDUCTOR Tul:/ing Strin[I - TUBING Size ] Top 2.875I 0 p~rforafiOns Summary Interval 'rVD 8030 - 8050 6525 - 6539 8210 - 8266 6652 - 6692 8290 - 8300 6709 - 6716 8330 - 8340 6737 - 6744 Gas Lift Mandrels/Valves · · St I MD I TVD I ManI Man i V Mfr I VType I v OD Latch I Port I TRO: Date Mfr Type I [ Run 1 7806 6368 Mede TGPD DMY 1.5 TG 0.000 0 ' 11/11/88 2 I 7915 6445 Mede ! T-MPD I . DMY 1.0 BK 0.000 I 0 111/10/88 3 7982 64921 MedaI TMPD DMY I 1.0 BE 0.000I 0 : 11/10/88 4180731 65561 MedaI TMPD I I DMY I 1.0 I I~K 10.0001 0 '11/10/88 I Other (plugs; equip., etc - BLAST JOINTS PERFORATED .... · Description Blast Joints Perforated @ 4 SPF on 7/19/87 Blast Joints Perforated ~ 2 SPF on 2/1/87 -JEWELRY" ' · ...... . · Description Size Top Bottom TVD ' Wt Grade Thread 7.000 8561 6904 I 26.00 I J-55 I 16.000 115 115 I 62.50 t H-40 I Bottom 'i'VD Wt Grade Thread ' 8124 6591 6.50 J-55 EUE 8RD AB MOD Zone Status Ft SPF Date Type Comment C-I,UNI;'BI 1201 12 I 10/17/85 I IPERF 15" HJ II Csg Gun; 120deg'phasing A'4'A';I ,1 56 I 4 I 10/17/85 IIPERFI4"HJIICsgGun;90deg'I , [phasing A-2 I 10 I 4 I 10/17185 I IPERF 14" HJ II Csg Gun; 90 deg. I I I I I I phasing A-2 j I 10 I 4 I 10/17185 I IPERF 14" HJ II Csg Gun; 90 deg. I I I I I I phasing · . VIv Cmnt ID 2.441 Depth TVD Type 8030 165251 PERF 8037 I 6530 i PERF I Other (plugs~ equip.~.etc 'DepthI 7VD I Type 1824 118241 SSSV 7822 t 6379 I NIP 7861 164071 SBR 7880 164201 PER 8096 165721 PKR 8116 I 6586 I NIP 8123 6591I SOS 8124 6591 TTL 2.441 ID Camco q'RDP-1A-SSA' 2.312 Otis 'X' 2.313 Camco 'OEJ' 2.297 Camco 'HRP-1-SP' 2.340 Baker 'DB' 3.250 Camco 'D' Nipple NO GO 2.250 Camco 2.441 2.441 NIP (532-533, 0.3 3..~,5) (0-1C,~7. 0D:3.500, ID:2.992) Gas Utt ~ndrel/Durnmy Valve 1 (10436-1O437, 0D:6.018) NIP (10482-10483, OD:3.500) PROD. CASING (0-107O9, OD:7.000, Wt26.00) LOCATOR (10516-10517, 0D:3.500) LINER (10510-11470, OD:5.000, Wt18.00) MULESHOE (10546-1O547, Pe~ (11197-1123~ (11259-11288) Conoc0PhilliPs AlaSka, Inc. KRU 1R-32 11R~32 ::.i SSSV Type: Annular Fluid: Reforonce Lo( Last Tar Last Tag Date: Casing String APl: 500292252300 Well Type:l INJ Angle @ TS:142 deg @ 10969 NIPPLE Orig 112/17/1994 Angle @ TD:I41 deg @ 11470 Completion:I I Last W/O:I Rev Reason:lTAG FILL Ref Log Date:I Last Update:15'23.'2003 1330 TD:111470 ftKB I 5;16/2003 Max Hole Angle:161 deg ~ 8818 ALL STRINGS Description Isize I Top leo.om TVD I Wt I Oradel Thread CONDUCTOR I16.000 I 0 I 121 121 162.581 H-40 I SUR. CAS~NG I9.625I 0 I 6423 4073 140.001 L-B0 I PROD. CASINGI7.000I 0 I 10709 6391 126.001 L-80 I UNER I5.000I 1O510 I 11470 11470118.001 L-S0 I SizeI Top I e°tt°m I WO I' Wt IGrade I Thread 3.500 I 0 I 10547 I 6274 19.30 I L-80 I ABM-DUE Perforations Summary . .. Interval TVD Zone I StatusIFt SPF Date I Type I Comment 11197- 11237 6749-6777 I A-3 I I 40 I 4 I 5/1/1995 I IPERF 12 1/8"Enerjet; 180deg. I I I I I I 1phasing;Oriented (+/-) 90 I IIII II 111259- 11288 6792-6812 A-2 29 4 4/30/1995 IPERF 2 l/8"Enerjet; 180deg. I I I I I I 1phasing;Oriented (+/-) 90 I I I I I I Ideg. Gas Lift Mandrels/Valves stI MD I TVDI Man I Man I V Mfr I VType I v OD I Latchl Port I TRO I Date I V~v ; Mfr Type Run :1 ]1o436r 6196]Camco I ~ I I DMY 11.5 IRK ]0.000 I 0 [6/29/19961cmnt Other (plugs, equiP., etc.) - JEWELRY .. Depth lTVDI Type I I 532 I 531 I N~P ICamco'DS' Landing Nipple Description I ID 2.812 10482 I 6228 I NIP /Otis 'XN' Landing Nipple 2.750 10516 16252 I LOCATOR 1Baker 3.00O ' 10546 I 6273 IMULESHOEJBaker (half-muleshoe) 4.000 NIP (480.481, OD:3.500) TUBING (0.15096, OD:3.500, ID:2.992) Gas I.ift ~ mdrel/Dummy Valve 1 (2069-2070, 0D:6.018) SLEEVE-C (14972-14973, 0D:3.500) 'Con:oc0Phillips: AlaSka, Inc, KRU 1 R-33 AP1:J500292252900 Well Type:JlNJ J Angle @ Ts:J48 deg @ 14912 sssv Type:il Nipple Completion: jOrig I 12/30/1994 J Angle @ TD: J 47 deg @ 15530 Annular Fluid:I Last W/O:I I Rev Reason:~Tag Fill Reference Log:l Ref Log Date:J Last Update:J3/11/2003 Last Tag:115294 15520 ftKB Last Tag Date:12/24/2003 Max Hole Angle:l ! 74 deg @ 4571 ~:ALL iSTRi NGS :! ~:i:;~ :i i:: !.':. i::'.ili :'. ::::i i:/:.i!:!ii~ iii~ i~i;!! ;:iii i'i: ~:;::.i :,:i?:.:::i:: :: (' ~. :i, i::i ii~. ii ::::~:~ ~:: i i :ii .:: ~:i :i :i :.'il i;:i:,ii:::: ?.:!.: .:~:~ i~ ?,:: ;i'~:. Size Bottom Thread 16.000 9.625 7.000 5.000 Size 3.500 Bottom J TVD I W'~ I(~rad~'l Thread 15096 6649 I 9.30 I L-80 I EUE 8RABM Comment 3 3/8" HSD TBG CONV; 180 deg, ph; Orient165 deg. Side 3 3/8" HSD TBG CONV; 180 deg. ph; Orient165 deg, Side VIv Cmnt PKR (15018-15019, OD:6.156) Depth I T;~D I ,,,T~[~e 480 14801 NIP 14972 J 6565 J SLEEVE-C 1501816596 1 PKR 1'~5o94j 6647 J SOS 15096 J 6649 I 'I-I'L Fish - FISH ... Depth J Description 15302 J128' Spent Tbg Perf Guns in J Rathole Description I ID Camco 'DS' Landing Nipple NO GO 2.812 Baker ~CMU' Sliding w/Camco 'D' Profile 2.750 Baker 'FB-I' 3.000 XSAR Schlumberger 2.992 3.5" Tubing 2.992 .. JPerf on 3/28/95 3 3/8" (sws HSD) Comment SOS (15094-15095, OD:3.500) Tn. (15O96-15O97, 0D:3.500) Perf (15132-15165) Perf (15186-15212) 9h .... iz~6 UST. T I _1_i 9~ ,z" o97o .... i1 Ts 9a.~1a-6 GCS/GCT ~ 50--'1 I292 94--lZ~6 SL/'HGR ~0800.- i lZ~O0 L ,~'!,SOSO-. ~ 1,. i2800-~ />-, r"e d r' y d '¥ !: c h s amp 'i e s Was the wei'i cor'ed? r'equ'¥r'ed? yes ~ And r'ece-i'ved? yes ~aiysffs a; descr' i'1 C', - ~0 ~ Rece-¥ved? y~ .~(a, Inc. .~st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 121S June 2, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1R-32(Permit No. 94-146) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 1R- 32. Sincerely, Kuparuk Drillsite Development Supervisor MZ/skad RECEIVED JUN -,5 1995 A. iaska Oil & Gas Cons. Commission Anchor~'.., STATE OF ALASKA ,-,~ASKA OIL AND GAS CONSERVATION C,~_,~V~MISSION WELL COMPLETION OR RECOMPLETION REPORT A[q_D LOG ~ status or We,, C,~sifi~,t,o~'of Classification chan ed to"~ n e OIL ~ GAS ~ SUSPENDED ~ ABAN~NED ~ SERVICE ~ 2 Name of Operator 7 Permit Numar ' ~/~/ A~CO Alaska, Inc ~4-~4~ -~ 3 ~0ross 0 ~1 ~um~or ~.O. Box 1003~0, Anchora~o, ~K ~510-03~0 50-02~-22523 4 kocatioa of woll at suvaco . .................. ~.~ ~ ~nit or kobo 681' FSL, 146' ~L, Sec. 17, T12N, R10E, UM ~ ~ ~ ~' . Kup~uk River Unit 1352' FNL, 726' FEL, Sec. 7, T12N, R10E, UM KUPARUK RIVER · 5 Elevation in teet (indicaie KB, DF, etc.) ~ 6 Lease Designation ~d Serial No. RKB 86' 44.4' pad~ ADL 25628 ALK 2561 12 Date Spudded 13 Date T.D. Reached 14 Date ~mp., Susp. orA~d. ~ 15 Water Depth, if o~hore ~16 No. of Com~etions 02-Dec-94 14-Dec-94 3~/1995 (Comp)~ NA feet MSL} 1 11470' MD & 6945'WD 11377' MD &6876'~D YES ~ NO ~ NA IoetMD 1575' APPROX 22 Ty~ Elec~ic or Other Logs Run USIT, GR, CBT, GCT, CCL 23 CASING, LINER AND CEMENTING RE.RD SE~ING DEPTH MD CASING SIZE ~ G~DE T~ ~ H~ S~E 16. 62.5" H-40 Sud 121' 24" 274 sxs ASI Lead 9.625 40" L-80 Sud 6423' 12.25" 1260 sxs ASIII Lead, 610 sxs G tail 7. 26" L-80 Sud 10709' 8.5" ~210 sxs G T~I 5. 18" L-80 10510' 11470' 8.5" 98 sxs G Lead 24 Pedorations o~n to Production (MD+TVD of Top ~d BoSom ~d 25 TUBING RECORD inte~al, size ~d numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2', 9.3~, L-8O 10~7' m casin~, ~al bore extension ~ 10516' 4 spf 11259' - 11288' MD 6771' - 6791' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf 11197' - 11237' MD 6728' - 6756' ~D DEP~ INTERVAL (MD) AM~NT & KIND OF MATERIAL USED 27 PR~UCTI~ ~ST Date Fimt Production ~Me~od of O~ra~on (Flowing, g~ li~ etc.) I Date of Test Houm Tested PR~UCTION FOR OIL-BBL GA~MCF WATER-BBL CH~E S~E GAS~IL RATIO TEST PER~D Flow Tubing C~ing Pressure CALCU~TED OIL-BBL GA~MCF WATER-BBL OIL G~VlTY-API (~rr) Press. 24-H~R RATE 28 C~E DATA {Bdefdescription of lithology, ~rosi~, ~amures, apparent dips ~d ~en~ of oil, g~ or water. ~u~it core chips. JUN - 5 1995 A~ska 0ii & Gas Cons, C0mmis~i0r~ Anch0r~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH i!i TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10969 6585 Base Kuparuk C 11032 6631 Top Kuparuk A 1 1171 6731 Base Kuparuk A 11323 6836 RECEIVED JUN - 5 199,5 A!~ska 0il & Gas Cons. 31. LIST OF ATTACHMENTS ~J'J¢~or~ .'.~ 32. i hereby certify that the foregoing is true and correct to the best of my knowlege. /.7 Signed '-" Title /~---~ /.~ ?~--/..//.~V' DATE 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". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE 1 %VELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1R~32 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER ADL 25628 ALK 2561 50-029-22523 94-146 ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: WO/C RIG: 11-30-94 22:30 12-02-94 01:00 PARKER 245 12-01-94 ( PARKER 245 TD: 1) PREPARE TO SPUD 16"@80' MW: ACCEPT RIG AT 2230 HRS. 11/30/94. PREP TO SPUD. CUM:$14395 12-02-94 (2) PARKER 245 TD: 559' (559) 12-03-94 (3) PARKER TD: 5186 (4627) 12-04-94 (4) PARKER TD: 6338 (1152) 12-05-94 (5) PARKER 245 TD: 6443' (105) 12-06-94 (6) PARKER TD: 6443'(0) 12-07-94 (7) PARKER TD:9375' (2932) DRILLING 12.25" HOLE 16"@80' MW: 9.0 VIS 110 CUM:$75,788 NU & FUNCTION TST DIVERTER. AOGCC REP BOBBY FOSTER WAIVED FUNCTION TST PU BHA & DP. SPUD WELL @ 121' @ 0100 12/02/94. DRLG 12-1/4" HOLE. DRILLING 12.25" HOLE DRILLING 24 HRS DRILLING 12.25" HOLE 16" @80' MW: 10.0 VIS 62 CUM:$141,581 DRILLING. TRIP TO CHANGE OUT BIT AND MOTOR. TROUBLESHOOT TOPDRIVE PROBLEMS AND REPAIR. CEMENTING 16" @ 80' MW: 10.1 VIS 46 CUM: $304,567 CBU AND SHORT TRIP. CIRC AND COND MUD. POOH AND LD BHA. RUN 160 JTS OF 9- 5/8",40g,L-80,BTC CASING TO TD. CIRC AND COND FOR CEMENTING DRILLING 9-5/8" @ 6424' MW:10.1 VIS 46 CUM: $565,189 CIRC & COND MUD. CMT W/1260 SX ASIII 12.1 PPG LEAD CMT AND 610 SX 'G' 15.8 PPG TAIL CMT. RD CMTRS, ND DIVERTER AND CLEAN SAME. PERFORM TOP JOB W/15 BBL H20 FLUSH AND 15 BBLS ASIII 12.1 PPG CMT. SET PACK-OFF AND MU SPEED HEAD. NU BOPE. TEST BOPE (WITNESSED BY L. GRIMALDE). RD TEST TOOLS, PULL TEST PLUG AND SET WEAR BUSHING. BLOW DOWN CHOKE MANIFOLD, KILL LINES, AND MUD LINE. PU BHA#3 AND RIH TO FIRST JT OF DP. C&S DRLG LINE. DRILLING 9-5/8" @ 6424' MW:9.0 VIS 32 CUM:$667,720 RIH TO 6300', FILL PIPE AT 3200'. BREAK CIRC., WASH TO TOP PLUG AT 6342'. RAJ AND TEST CASING TO 2000 PSI FOR 30 MINUTES, 10 PSI LOSS. DRILL PLUGS AND ,/UN -5 1995 A!aska 0il & Bas Cons. Commission 16"@80' MW: 10.0 VIS 44 CUM: $223,074 WELL: 1 R- 3 2 APl: 50-029-22523 PERMIT: 9 4 - 1 4 6 PAGE 2 CONTINUED FROM DAY 12-08-94 (8) PARKER TD:10719' (1344) 12-09-94 (9) PARKER TD: 10719'( 0) 12-10-94 (10) PARKER TD: 10719' (0) 12-11-94 (11) PARKER TD: 10,859 (140) 12-12-94 (12) PARKER TD: 11,276 (417') 7 FLOAT COLLAR AT 6345', CEMENT AND SHOE AT 6422'. DRILL 10' NEW FORMATION TO 6453'. CIRC. PERFORM FORMATION INTEGRITY TEST TO 12.5 PPG, EMW. SEE LEAK OFF GRAPH. DRILL TO 6475'. SERVICE TOP DRIVE. DIRECTIONAL DRILL 8.5" HOLE FROM 6475' TO 9375', 170.5 FPH AVG. POOH TO RUN 7" CSG. 9-5/8" @ 6424' MW:9.1 VIS:35 CUM: $745,733 DIRECTIONAL DRILL 8.5" HOLE FROM 9375' TO 10719' CIRC. BOTTOMS UP TO PREP. FOR SHORT TRIP. SHORT TRIP 46 STDS. TO CASING SHOE. NO HOLE PROBLEMS. LOST HIGt-ILINE POWER. START RIG GENERATORS. CIRCULATE TO CONDITION HOLE FOR 7" CASING. TRIP OUT TO HOLE TO RUN 7" CASING. NIPPLE UP CASING SPOOL 7"@10,709' MW:9.2 VIS:35 CUM:$956,668 POH TO RUN 7" CSG. L/D BHA. PULL WEAR BUSHING. R/U CASING TOOLS AND CLEAR FLOOR. HOLD PRE-JOB SAFETY MEETING. RAN 250 JTS. 7" CASING TO 10,709'. BROKE CIRC. AT 9-5/8" SHOE AND 8500'. R/U DOW'ELL AND CIRC. HAD PROBLEMS WITH HOLE PACKING OFF. OBTAINED GOOD CIRC. AT 7 BPM. SEE CMT. DETAIL FOR ADDITIONAL INFO.CEMENT 7" CASING. CIP AT 0309 HRS. SEE CMT DETAIL FOR ADDITIONAL INFO. NIPPLE DOWN STACK. SET SLIPS WITH 125K. ROUGH CUT 7" AND SET OUT SAME. PICK UP 3.5" DP 7"@10,709' MW:9.1 VIS: 36 CUM:$1,049,536 INSTALL PACKOFF AND FLANGE UP CASING SPOOL, TEST TO 3000 PSI FOR 15 MIN, NIPPLE UP BOPE, CHANGE UPPER AND LOWER RAMS TO 3.5". CHANGE GRABS AND 3. SAVER SUB ON TOP DRIVE. RIG UP TO TEST BOPE. TEST UPPER AND LOWER PIPE RAM CHOKE AND KILL LiNE FLANGES, TIW AND IBOP TO 300/3000 PSI. WITNESS OF TEST WAIVED BY LOU GRIMALDI (AOGCC). RIG DOWN TEST TOOLS AND BLOW DOWN. LAY DOWN 52 STANDS OF 5" DRILL PIPE. PICK UP 6.125' BIT AND 4.75" SPIRAL DRILL COLLARS. TEST MWD, PICK UP 3.5" DRILL PIPE (2 HRS). FREEZE PROTECTED 9,625" X ANNULUS WITH 70 BBLS DIESEL WHILE PICKING UP BHA. FLUSHED ANNULUS WITH: BBLS WATER AHEAD OF DIESEL. SLIP AND CUT DRILL LINE 90'. PICK UP AND RABBI7. 3.5" DRILL PIPE. DRILLING 7"@10,709' MW:ll.5 VIS: 46 CUM:$1,135,901 P/U AND RABBIT 3.5"DP. BREAK CIRCULATION. HOLD FIRE DRILL AT CAMP. MUSTER FIRE TEAM TO CAMP. CRITIQUE DRILL. TEST CASING TO 3000 PSI F/30 MIN. OK. DRILLING CEMENT F/10485'-10622'. TAG UP ON FLOAT COLLAR 10622'. SERVICE TOi DRIVE. DRILLING FLOAT COLLAR, CMT, AND FLOAT SHOE (10709') AND 10' NEW HO! TO 10729'. CHANGE OUT MUD TO 11.4 PPG. PERFORM FIT, T/13.5 PPG EMW. HELD SO] F/15 MUN. DRILL 6.125" HOLE FROM 10729' TO 10859'. CIRC. BOTTOMS UP 7"010709' MW 11.5 VIS:44 CUM:$1,219,282 DRILLING 6.125" HOLE FROM 10,859 TO 11276'. i~ E C ElY E D WELL: API: PERMIT: 1R-32 50-029-22523 94-146 PAGE 3 12-13-94 (13) PARKER TD: 11,354' (78') 12-14-94(14) PARKER TD: 11,470' (116') 12-15-94(15) PARKER TD: 11470' (0) 12-16-94(16) PARKER TD: 11,470'(0) 12-17-94 (!7) PARKER TD:l1470' (0) DRILLING 7"@10709' MW 11.5 VIS:44 CUM:$1,294,501 CIRC. BOTTOMS UP. DROP SINGLE SHOT SURVEY. POOH. RETRIEVE SURVEY AND MWD. CHANGE BITS, PLACE LEAD COLLAR BETWEEN 2 BOTTOM STABS DUE TO ANGLE INCREASE. SERVICE TOP DRIVE AND MWD. RIH WITH DRILL COLLARS TEST MWD (FAILED) PULL MWD FOUND PROB. IN SURFACE HARDWARE, RERUN MWD AND TEST SAME OK. RIH, FILL PIPE AT 5000' AND 10709'. RE-I, LOG WITH MWD FROM 11015 TC 11040' AND 11165' TO 11276'. DRILL 6.125" HOLE FROM 11276' TO 11354', LOG WI'I MWD. ADT=5.62. TRIPPING 7"@10,709' MWll.8 VIS:46 CUM:$1377411 DRILL 6.125" HOLE FROM 11354 TO 11426, LOG WITH MWD. DRILL 6.125" HOLE FROI 11426 TO 11470, LOG WITH MWD. CBU. SHORT TRIP INTO CASING (NO EXCESS DRAG, FIIL). CIRC. (OIL CUT MUD ON BOTTOMS UP). POOH (PRECAUTIONARY PUMPED 10 ST INTO CASING. BLEW DOWN KELLY. CONT POOH. AT 35 STDS, FILL VOLUME WAS 2 BBI UNDER. MONITORED WELL. WELL FLOWING SLIGHTLY. RIH TO BO'I'rOM. CIRC AND RAISE MUD WEIGHT TO 11.8 PPG. POOH (PRECAUTIONARY PUMP 10 STDS OUT. MONITOR WELL. CONT TO POOH). CE, MENTING 7"@10709' MW:ll.8 VIS:47 CUM:$1459318 CONT. POOH. LD BHA. HOLE TOOK 17 BBLS MORE THAN CALCULATED VOLUME.RU T£ RUN 5", 18#, L-80, LT&C CASING LINER F/10510' T/11470'. HELD SAFETY MEETING.RUN CASING LINER TO TD FILLING CASING EVERY 10 STANDS. CIRCULATE PRIOR TO RUNNING INTO OPEN HOLE. CONTINUE TO RIH WITH CSG TO 11470'. CIRC & COND MUD. WORK CASING TO BOTTOM. HOLE PACKING OFF WHEN RATE IS > 3.2 BPM HELD SAFETY MEETING. CEMENT CASING W/98 SXS CLASS G CMT AND ADDITIVES. FLOW CHECK PRIOR TO POOH 5" LINER @ 11,470 MW 8.4 VIS 28 CUM$1,587,38: FINISHED CEMENTING 5" LINER. ACTIVATE BAKER "H" PACKER WITH 4200 PSI AND SET BOT PACKER TOL @ 10510' SHOE @ 11,470' SEE A'I-'FACHMENTS FOR DETAILS. PULLED UP 15' AND REVERSE CIRCULATED WELL CLEAN. NO CEMENT IN RETURNS. ESTIMATED 19 BBLS OF 12.5#/GAL SPACER OF 30 RETURNED. CALCULATED TOC @ 10,510'. RIG DN. CMT. HEAD. POOH WITH LINER RUNNING TOOLS. SERVICE RIG AND TOP DRIVE. FINISH POOH WITH LINER RUNNING TOOLS AND LD SAME. PU 3-3/4" STC ECONOMILL AND SPAGETI'I CLEAN-OUT STRING AND RIH TO 9500' ON 3-1/2 DP. CU'I DRILLING LINE. BREAK CIRC. AT TOL AND FINISH RII-I TO PBTD (11,375). RIG UP LIN~ AND TEST LINER TO 3500 PSI FOR 30 MIN LOST 100 PSI. DISPLACE CASING WITH FILTERED SEA WATER PER PROGRAM. RIG RELEASED 5" LINER @11470 MW 8.5 VIS 28 CUM$1661496 FINISH DISPLACING WELL WITH FILTERED SEAWATER. MONITORED WELL FOR FLOV~ NONE. POOH. LDDP. RIG SERVICE. CONTINUE POOH. DISPLACE WELL WITH 75 BBLS © DIESEL @ 2506'. FINISH LAYING DOWN THE TUBING AND BHA. ND BOPE. INSTALL 7" R C 1¥ I/D ~ia. ska Oil & ~as Cons. Commission SUB- SURFACE DIRECTIONAL F~ UIDANCE F~ ONTINUOUS F~ COL SURV CROFILMED RECEIVED ., FEB 14 1995 Alaska Oil & Gas Cons. Commission Anchorage Company ARCO ALASKA, INC. Well Name 1R-32 (681' FSL, 146' FWL, SEC 17, T12N, R10E) Field/Location KUPARUK, tt0RTH SLOPE, ALASKA Job Reference No. 95014 Loqqed BV: S INNONS Date 24-DEC-1994 Computed By: KRUg/ELL · SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1R - 32 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE: 24-DEC-1994 ENGINEER: SIMMONS METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 4 DEG 48 MZN EAST ~ 8'[ J_. N ~1 ~ 1~ /- Fl 9/_ M P~ Z N ~ ~ P~ Z. 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9¥DI±W3A 3$W~OD V38-8~$ Hid30 V3S-SNS dO 133d 00I N3A3 aOd S3N]¥A (Yfll¥90flB3±NI SNOW,IS 'W33NIDN3 Id 00'98 'NOIIYA3-F_I 9NIHSa8 Xq-~N 5,661-83~-5,a 'X3AWgS dO 3±¥0 9 39¥d 96-~3~-0I '3±¥O NOI±¥_LFSd~O~ VNS¥]¥ '3dOqS HI,ON IINN NSAI~ 'DNI 'VHSVDV OD~V ~ ~ 9 N SI'0098 ~ ~P'~06 N 98'~SS9 00'0 L6'9~8 ~ O~ ~ N 6I 9~ 88'IS89 98'Z~69 O0'OZ~lI ~ S 9 N 99'9~99 ~ I0'S06 N 89'86~9 00'0 ~ 0I 9 N 96 ~ SI 9 N ~ ~ 9{ 9 N ~S ~ 6I 9 N ~6 ~ 6I 9 N 9L ~ 6I 9 N ~I ~ I~ 9 N ~ M ~ g N Z8 8818 ~ 99 8908 ~ al S£6i M S6 IiSi M 69 i06 N I0 PO6 N ~Z 868 N OS 0£8 N aO I98 N P6 P688 I0 8618 O0 6018 aO 6108 gO Pa6l I0 M Pa 9 N 82 IPgz M 6a IS8 N aa P6sl ao 0 M Pa 9 N 99 M SE 9 N 8I M gE g N lg M Ia g N IP M Z1 9 N 99 M a1 9 N Z1 M 8 g N OS M i g N 98 M i 9 N 66 aOSi M SO 8989 M SO iO/9 M P9 PSS9 M SO gssg M 80 P919 M 8L 618 N gE 669 N 08 819 N I9 889 N I8 1999 I0 96P9 I0 OaS9 I0 6PI9 I0 M 6 9 N IS aI09 M I6 SP9 N S6 ll6S I0 0 M 81 9 N 9P 6998 M 88 M aa 9 N II aass M a9 M Pa g N gE 166P M 89 M gE g N aP'OPSP M a6 M la 9 N a6'PL9P M M OS 9 N tO'lOSP MOl aS9 N SO P08S aO 0 aa9 NlI ssgs I0 0 109 N Oa agPs O0 0 069 N Pa 68aS I0 0 PiS N Bl OalS I0 0 ISS N PO ggGP O0 0 1PS N 66 608P tO 0 SaS N IS S~9P I0 0 S0'86S8 3 OP I N 6I 9P 00'0089 00'9999 09 i9 99 P8 88a8 3 a I N P 9P O0 1818 M gE I N Ia PP O0 P608 M iS a N 6 aP OO SO08 M ES P N S~ IP OO aIgl M ES P N S9 lP O0 0019 O0 0099 O0 oosg O0 OOP9 O0 0099 O0 ooa9 oo 0019 O0 0009 O0 99Z9 9899 9899 86 9899 66 9819 9809 SO 80III Ol60t IOZOt SE 96PZ M 6 9 N aP ES OO 0069 OO 9868 aa 9tlOt 80 91 69 Oi It 6SSi M El 9 N IS iS O0 OOal M OS S N ia 88 O0 SPOI M SE 8 N 9 iS O0 S689 M 6a l N 6 ZS O0 0~i9 M 9P 6 N iS iS O0 S889 M a1 6 N 8P 68 O0 S~P9 M PS 9 N P I9 O0 IPa9 M SP 9 N II 09 O0 SZO9 M PI 9 N ia 69 O0 0089 O0 OOZS O0 0099 O0 OOSS O0 OOPS O0 OOSS O0 ooas oo OOIS O0 O00S O0 9889 Si 98iS SO 9898 ES 9888 IS 9919 9996 PO06 PO88 I098 80 9069 M IP S N OS 09 O0 O06P O0 986P 08 aoa8 Ii OSLS M 68 S N OS 68 O0'O09P O0 998P 06 IS sgss M aa S N I 68 O0'OOZP O0 981P 89 Oa a6SS M aP S N 9a og O0'OOg~ O0 989P 66 gE lEES M 68 S N SP 69 O0'OOSP O0 989P gP ii PSOS M 6a S N Ot 68 O0'OOPP O0 98PP LB 96 I06P M gS S N S iS O0'OOSP O0 988P 18 ii ltlP ~ gE 9 N BP iS O0'OOaP O0'99aP S8 90 S88~ M 0I S N OP 68 O0'OOIP 00'98IP 9P PS'61PP M S S N Ia 88 00'000~ 00'980P 86 I008 S08I Pog/ 9889 S~99 9P'gsaP M I P N li 69 00'006S 00'986S i8 PSa9 NIR D3G J_BBd .1_33~ 133~ OOI/OBQ ±33d NIR OBQ NIR OBq H±dBO HldBa H±dBa Hln~IZV 'lSIa ISBM/±S~B HInOS/HL~ON AII~BABS N011338 HInMIZV NOIIVIABG 3WFLLWYd3Q 'ZIMOH S31VNIQ~OOD h±d3~ v~s-ans do i~3d 0ot NBAB ~Od sBn~VA OB±V~Od~B±NI SNORRZS 'M33NZDN3 ¥NS¥~¥ 'BdOqS H±~ON llN~ ~BAI~ Nn~vdnN I-4 00'98 :NOIIYA3-13 DNIHSn8 g 3OYd S6-83d-0t :31VQ NOIl¥1ndRoD ~ ~'E06 ~ ~P'g06 ~ P~'S06 ~ E~'906 N N N N 0S'9~9 96'S9L9 SO'OSZ9 9S'Z969 96'IZ99 90'9999 O0'O~II 00'0~I (Il ~lSd (~M) ¥ >lflbl¥clFl>l BS¥8 M~ ~06 M 6S 806 M ~E 906 M 9~ ~06 M O~ 889 M P6 809 B 0~'0 B o~'0 B 00'0 N 06'S~P8 N i6'9SS9 N lO'O~a8 N P~'Z618 N S9 ZS~ N Sa 0 N Ea 0 N O0 0 P9 6P ~99 96 I~ S099 ~Z I9~9 OP Z96E O0 0 O0 0 O0 ~g ~I99 6~ oszg 96 osgg Il I699 ZZ Z~a9 O~ EZO~ O0 98 O0 98 O0 ~ O0 O0 O0 O0 69601 O0 60ZOI O00ISOI O0 ~9 O0 98 O0 98 O0 9~ ±S3M/IS~3 HJJqOS/H±~ON S31VNIO~003 VBS-SAS 8~ ~08~ QA_I. 8N MO-lB8 H/d3O a3ansv3~ MN 3 0I~ Ell ZIDBS '-IM__-I ,9¢"[ ~ 9Sd ~ I99 = NOI/¥309 33¥d~NS SNOZI~OH NBSOH3 ~Od SBNqYA QBIYqOd~BINI SNOW,IS :aB3NIgN3 1~ o0'g9 :NOI±¥A3~ DNIHSa8 Xq~H ~66I-3BG-~a :ABACAS dO 31¥G (a~) v ~navdn~ (G~) D ~N~VdNH DN~SYD dOl ~BN~ DN~SYD .8/S 6 8N~ YN$¥gv '3d09S HIWON llNn W3AI~ ~fl~VdflN 'DNI 'VNSYq¥ OD~V i 3DVd S6-~3d-0I :3lVG NOI£VJJ]d~OD ~ ~ 9 N S['0098 NI~ D30 133~ H_Ug~IZ¥ 3DNV±SIq 3~LLWYd3fl 9V±NOZIHOH 8~'~S~9 8~'Z969 O0'OZ?~ 9¥DIIW3A 9¥DI~3A ¥39-~R$ 3R~LL :CLL £¥ NOI±¥309 993~ 9¥NI~ S~'906 9~'906 ~'S06 99'906 N 99'~SS9 n 99'~SS9 N 09'9~9 96'9~Z9 SO'OSZ9 99'&~69 89'Z969 96'~&89 S0'9999 O0'OZklT 00'9~9ll ROI 108 W3NI9 .~ G-LSd (GR) ¥ >IN~IVdN>I 35¥8 ~ zi Z06 ~ 69 806 ~ 99 906 ~ 9~ ~06 ~ o~ 888 ~ P6 30~ 0 30~ 0 3 O0 0 N 06 S~8 N 16 9998 N ~0 0~8 N ~ Z6~8 N ~9 ~08 n 9~ k88Z N S9 lS~ N 9~ 0 N 9~ 0 N O0 0 P9 8~/9 6~ ~99 96 ~99 g~ 86~9 ~ S099 LI I919 O~ Z869 O0 0 O0 0 O0 I~- ~9 6~ 09Z9 96 0999 99 ~899 II I6S9 ii O~ O0 98 O0 98 O0 S~ O0 E6EII O0 IZIII O0 ~90II O0 69601 O0 60~0I O00ISOI O0 ~a~9 O0 98 O0 99 O0 9~ ISBM/ISV:J HInO$/HIWON S31¥NI~WOOD WVqNONV±DBW VBS-SNS 8M ROMd GAL hld3(] ~nsv3~ p~l 30IS ~I1 /_IDBS '-IM_-I ,91~I ~ -lSd ,I89 = NOI/VDO-] 3DYd~nS SNOM~IS :~33NIDN3 ±d 00'98 :NOI±¥A393 DNIHSR8 ~993N ~66~-D3G-~a :A3A~R$ ~0 3~¥G VNSVg¥ '3d09S H±WON ±INn W3AI~ NN~VdNN '3NI 'VNSV~V ODWV 8 3OVd S6-EF3~-OI :3±¥G NOI±V_Lnd~oD d Z >- Z 0 0 Z n' tu rtl Z ZD Z I-. 0 ~ c~ LLI Z rtl n' ILl ~IELL' 1R-32 (681' FSL, 146' FWL, SEC 17, TNN 12N, RNG IOE) HORIZONTAL PROJECTION NORTH 12000 10000 800O 6000 4000 2000 -2000 SOUTH -4000 REF 95014 SCALE = 1 / 2000 INIFT ' '~ ~ ~ ": : .... I-~"-i---~'! ...... ~ .... i !--:- -;-" ;- '~-.' ..... ! ~ , . ~':" .' 'i ' ~'-i' i"i" !"-i i '~ .... i"? -i"'¥ ':'"'i "": ..... ¥'"i -' : ........ :"~ : ....... ~ .... ~"'.' I'"!' '!" 7-'. '?' '~"!-':' ~"'~ "~"- ..... ~-?'"~ !' 'i'"!-'i--i' --F'!'"i'; -' !'"!'"!'"! .... i'"?'!'"!"'!'-'i'"~-"i'"! ..... !'" ":'": ...... i";' '!"i ~ ~"! ...... ~ i": ....... ~" · :. ! . : ...... : ...... :...:..; .... :.. :...: ...... ; ..... ;...: ...;...;.. ~ ..: .... :..;...~..; ....... : ....... : ..... ;...;...;..: ..... ~...:...;...: ..... ;...;..,;...~ .... ~.. :..~ ....... :.. ~...: : : : :. ~ ' ~'-"-:' ::?::'~-~:-:"~:-'~ '~:-:~ ::~:'~::~:~::'-:~-':~:'~; ':':' ";:"::' ;:: :' :~:::~i'i';~ ;:~::::'::~::::: ': ~':'::~::::: :::::::::::::::::::::::::::::::::::::: ':":":':'~: :. :.: ~'~ ~ ~' ~' ' . ; . ;. ~. . 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J ~. . ~ : ._ : . . : : : - ~ : ~ : . : - : : :...~. ..:...:..: : .... i. ~ · : : , : · . . .-. 1-:::::.i:~:::::-; :: I: - i - [ ;'4 ~Ooo: ::::: .:..: ::.. :.: , ~ .. ~ J ;,, ;L .... , , t ........ ~ : ; : : , : I : : ............... -8000 -6000 -4000 -2000 0 2000 4000 6000 8000 WEST EAST ~ELL- 1R-32 (681' FSL, 146' I~L, SEC 17, T'~ 12N, RNG IOE) VERTlCAL PROJECTION 185.0 -4000 -2000 0 0 2000 4000 6000 8000 10000 i'i[ ii:' i i-i.'i[~):Z~:Zi[:j~:_.~oool.i ..ii;.i..i .ii..il ~:.i.i.. i-i.-.i.; .... i..Li.-.:: i i:..i...'~...~:.'~.i:.i: ..... i il.i iii! · . : . : .. .;.; .: ;..; .; ; ; .: .... ;..: , ; ; ; ...; .; : ,.:. .:. , :.: . .:.: ..... : : : : .. ;...: : . ; ..... : . : ; ; ; . ;:i-i i- i' ......... )L!-!"? , : ! ! i i ! -i-.-!--!---i ~ .... : ~ : : -... ! ; ;-~'- 6000 : ..... :: '~"i'~ '~' ; "'~':~':'" :'~'"~ ' ' ...... : "": ..... .' .......... ..... ~"~" '~ : · '~ ...... ~ ~ ~' ": ~': ~ .... ' ..... ~'¢ ..... Io~0o ............. : ;-: .... : --~-~ -t ~-: -!--:--:: -"~ '~--~':: :'-;~' --~-";~-'~--'~'~'~'~ 7-;-)-;"-~'";'"~ : :' ':"':': ': ! - ~ .... I ' : ~'i ~'' ] : ' ; - : : ' ' : ] · ' ' : ...... I . : ~ . : : .... : : : ~:: .1: ~ - - . ~ ; ............... ~ .... . ; 12000 : - , ;: I ...... ............ :. ;" . . .. . 12000 5.0 PROJECTION ON VERTICAL PLANE i85.o - 5.0 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 2000 IN/FT ARCO Alaska, Inc. Date: March 24, 1995 Transmittal #: 9216 RETURN TO' ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. /5(~1 R-33 2., 1 R-34 I_~ 2T-21 ~$'---/,:7 2T-21 1/-/'~,1 R-32 2Z-23 ''~ / O 2Z-23 Z-22 . CDR Depth Shifted ¢~"z/,-/ 2Z-22 CDN e thShifted CDR Final Print CDR Final Print CDR Depth Corrected CDN Depth Corrected Slim GR MWD Depth Corrected CDR Depth Shifted CDN Depth Shifted · 12/28/94 1/13/95 Feb16-21/95 Feb16-21/95 Dec11-14/94 Feb7-10/95 Feb7-10/95 Feb1-4/95 Feb1-4/95 Date: Ref#95009 Ref#95060 Ref#95077 Ref#95077 Ref#95024 Ref#50-029-22544 Ref#50-029-22544 Ref#50-029-22524 Ref#50-029-22524 DISTRIBUTION' Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 RECEIVED Clifton Posey Ge~l~ Oil & Gas Cons. Commission ATO 1251 Anchorage Erickson/Zuspan NSK Central Files NSK 69 '."Larry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lemke ATO 1336 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Co/nmission TO: David J~ Chairma~ TRRU: Blair Wondzell 4i:~ P. I. Supervisor DATE: FILE NO: FROM: John bpau~a~ng.'~c,,-t. SUBJECT: Petroleum insp'" March 1,1995 AAULCACD.doc BOP Test Nordic 1 Arco KRU well 1R-32 Kuparuk River Unit PTD 94-146 Wednesday March 1,1995' I witnessed the BOPE test on Nordic rig 1 at Arco's Kuparuk River Field welllR-32. The AOGCC BOPE test report is attached for reference. ~.k~Fr' Nordic 1 has been stacked for some time and.,this was ~aer-e initial test. The rig was well prepared when it was stacked andLtested very well with no failures observed. The area around the rig was well laid out with very good access. Summary: I witnessed the BOPE test on Nordic rig 1 with 0 failures and 4 hr. test time Attachments: aaulcacd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: ~ Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Nordic Rig No. 1 PTD # Arco Rep.: 1R-32 Rig Rep.: Set @ Location: Sec. Weekly Other 94-146 DATE: 3/1/95 Rig Ph.# 659-7115 Shane Mc Gahan Don Breeden 17 T. 12N R. 10E Meridian ': :F}:i:i:i .............................................. i · ' ~ I ~ I~ Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: X WeJl Sign X Upper Kelly / IBOP , , Housekeeping: X (Gert) Drl. Rig X Lower Kelly/IBOP PTD On Location X Hazard Sec. X Bali Type Standing Order Posted X Inside BOP Test Quan. Pressure 300/3,000 BOP STACK: Annular Preventer 1 , , Pipe Rams 1 Pipe Rams Blind Rams 1 Choke Ln. Valves 1 r HCR Valves 1 Kill Line Valves 2 Check Valve 300/3,000 300/3,000 30013,000 300/3,000 3O0/3,OO0 300/3,000 Quan. Pressure 300/3,000 300/3,000 300/3,000 300/3,00,0 1 PIF Test P Pressure P 300~3,000 N/A P P CHOKE MANIFOLD: No. Valves 12 No. Flanges 30 Manual Chokes 1 Hydraulic Chokes 300/3,000 P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 1 Blind Switch Covers: Master: Nitgn. Btl's: 2 AVG. 2300 MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK 'OK Meth Gas Detector OK OK" H2S Gas Detector OK OK P/F P P Functioned P Functioned P 3,000 ] P 2,275 ' ,'P ,, minutes 18 sec. minutes 10 sec. X RemOte: X Psig. -N-~.~-~r-:-~t:.~-ai-l~i;es:.:--:-:.! ............ ~ .................. ;:T~;~:-~:i;~;-i:'::-'~$-'":::l~l'~u:r~-:::-::~i~f'~:l~es tested "18' 'Repair or RePiacement'of'Fajled ] Equipment will be made w~ 0 days. Notify the Inspector and follow with"~en or Faxed verjfJcatJon to the AOGCC Commission Office at: Fax No'. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 j if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: I 279-143;~ I I I I ' I I Il . . I I I I I I . .Il I I . I , I I . I I REMARKS: Distribution: orig-Well File c - Oper.lRig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding , , , ARCO Alaska, Inc. Date: January 27, 1995 Transmittal #: 9188 RETURN TO: ARCO Alaska, Inc. A'I'TN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of thiS transmittal. 1 R-32 Gyro Continuous Survey GCT 12-24-94 Receipt AC kn ow i e d g~~/----~/~'~~~'~~t e: Please acknowledge 50-11292 DISTRIBUTION: Delia Brown Kuparuk Drilling ATO-1276A Larry Gram (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 RECEIVED JA[ !995 Alaska .Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' February 22, 1995 Transmittal Cf: 9197 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. 1 R-32 Directional Survey 12/24/94 /'7/ Receipt ' , Y, ---'" Acknowledged: ~-~~~~~~~e ' Please acknowledge receipt and 95014 DISTRIBUTION: D&M State of Alaska (2 copies) RECE[VED JAil 25 1995 ttlaska 0ii & Gas Cons. Commission Ar~chorage ARCO Alaska, Inc. Date: January 13, 1995 RETURN TO: ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk AT©-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 9178 Transmitted below are the following Cased Hole items. ~receipt and return one signed copy of this transmittal. I _ t'~1 R-32 Cement Evaluation Log CBT 12-24-94 1 R-32 USIT 1 2-24-94 Receipt Acknowledge,;,.-~. ~,~.~.. /.' ,,~/...;..,..~ Date: DISTRIBUTION: Delia Brown Kuparuk Drilling ATe- 1420A Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 11273-11375 10570-11310 Carolyn Haynes NSK Central Files NSK-29 A' A OIL AND GAS CONSERVATION COMN.. JON APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program ~ Pull tubing _ Variance _ Perforate _ Other ;2. Name of Operator ARCO Alaska, IDC. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory _ Stratigraphic _ Service i 4. Location of well at surface 681' FSL, 146' FWL, Sec. 17, T12N, R10E, UM At top of productive interval 1500' FNL, 600' FEL, Sec. 7, T12N, R10E, UM (proposed) At effective depth At total depth 1294' FNL, 617' FEL, Sec. 7, T12N, R10E, UM (proposed) 2. Present well condition summary Total Depth: measured 11,276 feet Plugs (measured) true vertical 6794 feet Effective depth: measured feet Junk (measured) true vertical feet 6. Datum elevation (DF or KB) RKB {)6.' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-32 9. Permit number ~)4-146 10. APl number 5o- 029-22523 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner (proposed) Perforation depth: Length Size Cemented 80' 16" 6382' 9.625" 1O668' 7" 1035' measured true vertical i! Measured depth True vertical depth 225 sx AS II 121' 1260sxASIII & 610sxG 6423' 210 sx G 10709' 121' 4055' 6374' 120 sx G 1154 ECEI ) Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) DEC '1 2 1994 ~iaska 0ii & Gas Cons. Commission ..... 13. Attachments Description summary of proposal ~ Detailed operation program I BOP sketch _ Change proposed casing plan from 7" production and 5" tail to 7" intermediate and 5" liner through zones. 14. Estimated date for commencing operation ~ 15. Status of well classification as: December 12. 1994 drilling 6-1/8" h01e I Oil .X (proposed) Gas_ Suspended 16. If proposal was verbally approved Name of approver Blair Wondzell Date approved 12/12/94 Service 17. I hereby ce~fy that therforegoing is true and correct to the best of my knowledge. Signed r"~<'/~-~.-.~, Title: Drill Site Dev. Supervisor I ' (,, ./J ~ FOR COMMISSION USE ONLY I Conditions of approval: Nd~ify Commission so representative may witness Date~_~ {/'~ ¢¢_~ IApprov~ N/o/ Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test Su,,bseguent form require 10-~O'7 ~[~!JrovedOopy 7 -- ~eturned urig,nal Signed By ¢ David W, Johnston Approved by the order of the Commission Commissioner 'Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KRU 1R-32 Attachment to Form 10-403 Changing Casing Plan The original Permit to Drill submitted to the AOGCC included a plan to drill an 8.5" hole ~from surface shoe to TD and run 7" 26# L80 BTC casing with a 5" 18# L80 LTC tail through the Kuparuk sands. Recent pressure data had indicated the possibility of higher Kuparuk reservoir pressures than anticipated at the time the Permit to Drill was prepared. Thus ARCO set intermediate 7" casing above the Kuparuk sands and plans to drill to TD and run a 5" liner. Prognosed target and bottomhole locations have not been changed. If you have any questions or comments regarding the attached permit to drill or the overall development program for Kuparuk Drill Site 1R, please contact the Drilling Engineer for Parker 245, Denise Petrash at 263-4183, or the Kuparuk Drill Site Development Supervisor, Mike Zanghi at 265-6224. Thank you for your expedient response to this request. RECEIVED DEC 1 2 1994 Alaska Oil & Gas Cons. Commission Anchora, .~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation ~'ommission TO: THRU: David John ~~on, Chairmarr'c~ Blair Wondzell '-~~ P. I. Supervisor FROM: Lou Grimaldi,¢~¢~- SUBJECT: Petroleum Inspector DATE: FILE NO: December 6, 1994 AAXJLFBD.DOC BOP Test Parker 245 Arco Well # 1 R-32 Kuparuk River field PTD # 94-146 Monday, December 5, 1994: I traveled to Parker rig #245 to witness the Initial BOP test on their rig which is presently drilling BPX well #1 R-32 in the Kuparuk River Field. The rig was still nippling up when I arrived. The test once started went very well with all components functioning properly and holding their pressure test with the exception of a valve on the choke manifold which stripped its stem. The test lasted 2.5 hours. This was the first test since this rig came out of stack and I found the rig to be in very good condition. Summary: I witnessed the initial BOP test on Parker rig #245. Test time 2.5 hours. One failure. Attachment: AAXJLFBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Parker Drilling Operator: ARCO Alaska, Inc. Well Name: KRU 1R-32 Casing Size: 9-5/8" Set @ Test: Initial X Weekly Rig No. 245 PTD# Rep.: Rig Rep.: 6,404 Location: Sec. Other 94-146 DATE: 12/6/94 Rig Ph.# 659-7670 James Tranthem GRANVILLE RIZEK 17 T. 12N R. 10E Meridian UM TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 300/3000 P 2 300/3000 P 1 300/3000 P 2 300/3000 P 1 300/3000 P 2 300/3000 P 2 300/3000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK =it Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 300/3000 P 300/'3000 P 300/3000 P 300/3000 P CHOKE MANIFOLD: No. Valves 16 No. Flanges 36 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 300/3000 F 300/3000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 3,000 I P f, 850 P 0 minutes 29 sec. minutes 30 sec. OK Remote: OK 2300Avg Psig. TEST RESULTS Number of Failures: 1 ,Test Time: 2.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: First test since mobe, Choke manifold cold and slushy. Steamed and tested OK, Maintain temperature during rig op's. Inside Choke manifold valve stem stripped, repair and retest before drilling out. Otherwise good test! Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector FI-021L (Rev. 7/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AAXJLFBD.XLS Louis R Grimaldi MEMORANDUM State of Alaska Alaska Oil and Gas Conservation C6mmission TO: THRU: FROM: David John~ Chairmaff,,~ DATF,: Dec. 2, 1994 Blair Wondzell, P. I. Supervisor FILE NO: Doug Amos, ~ ~ SUBJECT: Petroleum Inspector eaxhlbbd.doc Diverter Inspection Parker 245 Arco KRU 1R-32 Kuparuk Rv. Field PTD No. 94-146 Friday, Dec. 2, 1994: I traveled to Arco's KRU 1 R-32 well to inspect the Diverter System on Parker Rig 245. I did not arrive from Anchorage in time to witness the function test conducted early in the day on 12/1/94. As the attached AOGCC Diverter Systems Inspection Report form indicates, the diverter system was in compliance. As per James Tranathan, Arco representative, the function test was successful and all equipment functioned properly. Parker 245 has been stacked for most of the summer. During the summer the diverter system was upgraded from a Double 10" Divert Valve and Vent Line System to a Single 16' Straight Line and 16" Full Opening Hydraulically Operated Knife Valve System. This is a marked improvement over the old double line system. With the new system, the 16" Vent Line is mounted on 22" wheels for mobility and the line can be rotated in any number of configurations to clear well heads and flowlines. In addition to these benefits four targeted tee's and one divert valve was eliminated. SUMMARY: I inspected the New Single Line 16" Diverter System on Parker Rig 245 at Arco KRU 1 R-32 well. 6 Components No Failures Attachment: EAXHLBBD.XLS STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION COMl,,fSSlON Diverter Systems Inspection Report Operation: Ddg Contractor: Parker Ddlling Rig No. Operator: Arco KRU Oper. Rep.: Well Name: 1R -32 Rig Rep.: Location: Sec. 17 T. 12N R. t0E Development 245 PTD # Date: 12/2/94 X Exploratory: 94-146 Rig Ph. # 659 - 7670 Granny James Tranathan Merdian Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: Not Witnessed psig Housekeeping: OK (Gen.) Ddg. Rig: OK Pressure After Closure: Not Witnessed psig Reserve Pit: N I A Flare Pit: N t A 200 psi Attained After Closure: ~ min. ~sec. Systems Pressure Attained: ~ min. ~ sec. Nitrogen Bottles: 7 ~ 2300 DIVERTER SYSTEM INSPECTION: Diver{er Size: 20 in. Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16" in. Vent Line(s) Length: 90 ft. Line(s) Bifurcated: NO Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: NIA psig MUD SYSTEM INSPECTION: Light Alarm Trip Tank: YES NW Mud Pits: YES NW Flow Monitor: YES NW GAS DETECTORS: Light Alarm Methane YES NW Hydrogen Sulfide: YES NW I. ,. Manifold Blda. .~- Production Flow Lines ~ ~ ................... ~ ~ ~ ~ ~ ~ Annular Preventer J ~ ~ ~ ~ ~ W~h 16" FO Hydraulic Prevailing Winds Knife Valve ~ Pad Access I .................... ' ~ , Edge of Pad / , Non Compliance items 0 Repair Items W~ir 0 Day (s) ~d contact ~e Inspector ~ 659-3607 Remarks: t did not a~e on ~e No~ Slope un~i after ~e DNe~er Func~on Test on 1~1/95. ~aveled to ~e location and did an inspec~on of ~e en~re system on 12/2i94. Distribution orig. - Well File c - OpedRep c- Database c - Tdp Rpt File c- Inspector AOGCC REP.: OPERATOR REP.: Doug Amos FI-022 (Rev, 7~93 EAXHLBBD.XLS November 18, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1R-32 ARCO Alaska, Inc. Permit No: 94-146 Sur. Loc. 681'FSL, 146'FWL, Sec. 17, T12N, Ri0, UM Btmhole Loc. 1294'FNL, 617'FEL, Sec. 7, T12N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commis s ioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (~ prir,led on recycled pape~ b y C, ~. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISS,,.,N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [~1 Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone [] 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41' Pad 45' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 681' FSL, 146' FWL, Sec. 17, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1500' FNL, 600' FEL, Sec. 7, T12N, R10E, UM 1R-32 #U-630610 At total depth 9. Approximate spud date Amount 1294' FNL, 617' FEL, Sec. 7, T12N, R10E, UM 1 2/1/94 $200,000 12, Distance to nearest 13. Distance to nearest well 14. Number of acres in pro~l:~erty 15. Proposed depth (MD and TVD) property line 1 R-20 ~-~5~ %"~')l(.~"/ 11544' MD 617'@ TD feet 11.6' @ 375' MD feet~ 6993' TVD feet 16. To be completed for deviated wells 17, Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 59.4° Maximurnsudace 2407 psig At total depth (TVD) 3850 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD {include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 6361' 41' 41' 6402' 4066' 1260 Sx Arcticset III & HF-ERW 610 Sx Class G 8.5" 7" 26.0# L-80 BTCMO£ 11109 41' 41' 11150' 6693' 400SxClassG HF-ERW Top 500' above Kuparuk 8.5" 5" 18.0# L-80 LTC 394' 11150' 6693' 11544' 6993' HF-ERW 1 9, To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented RE cl~el~(~ True Vertical depth Conductor Surface Intermediate Production ~. 0 V '~ ¢O 'i9 9 ~ Liner A!as~a Oil & Gas Cons. Commission Perforation depth: measured AFIC[101'~,,;0 true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [-1 Seabed report [] 20 AAC 25.050 requirements X 21' I hereby cer~Tat the f°reg°'llg is true and c°rrect t° the best °f my kn°wledge~.4;., Signed (/~ ~'~ (~"~"/~1' Title Drill Site Develop. Supv. Date Permit Number I~(:~ Commission Use Only be, ]Approvaldato // /f,~)/~/~; ] Soo covor letter for y.~,.J/-~" .2_~' -- ,~_ ~ ,.~'.2_.~ - other requirements Conditions of approval Samples required [--~ Yes [] No Mud Icg required [~ 'Yes J~] No Hydrogen sulfide measures J~ Yes E] No Directional survey required ,~ Yes E~ No Required working pressure for DOPE r-1 2M ~ 3M [] 5M [] 10M [] 15M Other: RUSSELL A, DOUGLASS by order of// Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate Mr. Wondzell: I have made a few changes to the "standard" Permit to Drill that the Kuparuk drilling group submitted prior to rig shut-down earlier this year. I have outlined each one below with a brief explanation where appropriate. . Signing the Permit to Drill is the new Drill Site Development Supervisor, Mike Zanghi. I am attaching the latest organizational chart for the Kuparuk organization, in case you have not seen it previously. The drilling organization is now under the DSD Group mentioned above. I will be the primary drilling engineering contact, at 263-4183. Mike Zanghi, my supervisor, can be reached at 265-6206. . General Drilling Procedure. 1 R-32: Under #15. I have included a description of the "packerless" completion run with the 7" x 5" tapered production casing string. Following this page are two schematics which show the tapered casing design and completion. . Drilling Fluid Program1 1 R-32 and 2Z-22: Per our conversation last week, I have added a paragraph under the "Notes" section on risk evaluation and reduction. . 20" Diverter Schematic: I have changed the diagram and description to match the planned single 16" diverter line and HCR knife valve. DS 1 R is planned to be our first pad, with 2Z following sometime in January. However, the 1R/1Y flowline break that occurred on the slope a few weeks ago has hampered our efforts at pressure reduction on DS 1 R. We are evaluating current 1R and 2Z pressures to determine which pad will be first. For that reason, I am including the Permit to Drill for 2Z-22, which would be the first well we would drill if we ended up going to 2Z first. Spud date for both wells is listed at 12/1/94 for this reason also. Rather than change Permits at the last minute, I wanted to give you the time to evaluate both. I will notify you as soon as we have determined which drillsite will be first. Please call me if you have any questions or would like to discuss any part of the Permits. Thank you, Denise Petrash Drilling Engineer ARCO Alaska, Inc. 263-4183 RECEIVED NOV 1 6 1994 Alaska Oil & Gas Cons. Commission Anch0ra~, ~: .~ ~o Kuparuk Development --~ I DEVELOPMENT MANAGER ~ ~ ~ I S~o.~rr -. I I sR. SECRETARY ~ I ~ Glenda DeVore/ ~' [ IJeanne R°sauer*** , L EO.' " ' I . DRILL SITE D~ELOPMENT I . I I I I FACIUTY PLANNING RESERVOIR P~NNING I ..??~?EE. "~"OLEU~E.~. ~ I Ryan S,ram- Victoria Ferguson I ~ DRILUNG I ~ DRILLING SUPERVISORS I I ~v,%~?~.,~, I I I G,~ M~Oum~ I ~ " II ~,~ G¥~on I G~ M~k~W~n~,. I I I Don McK~vey ~ · ony ~cnwanz I EricSt.art I I ~ I~ PhiIH~ges I I William Isaacson ~ Dave Bumgarner ~ I O~n. To~v~ I I II S~o. W~m~, I / ~'~ Johnson I I I aobby Mo-~on/~ ~ II I GEOSC~ENCE I I~ ~ /~°m"~c~ I II J~m.T,~n,~. I. . I Mlke W~ner I / /Denise Petrash I I ~ -- TJ Barnes John Howle** ............... I ' ~ Jori Konkler ~ ~= ~nna Burl~o~ I a ~ I . : MATEmA~ SPEC~AUST -~ IB.,~ M~G,.,~ I I ~J""""H~v~"" II PROJECT ENGINEERS II I P~ROLEUM ENGINEERS ' I m , I Steve M~tha~ I I ~ Steve Cam ~ Diane Prince .............. ' I~ ENGINEERING AIDEI I D..Sh.~.r I I ~ ~'~['~ II I S,.cvS,.c~,~?~ I q T.c,,~r~IIN..c~V.~ghn I I ~ Go,do. K.., II I J.ne, W.. ............... ~ ' I ~ ~ ' ' I I Jam~Zernell~ - ~CUMENTCONTROL : [ , I~ '- ............ : I GEOTECHNICALAIDE II I MATERIA~ SPEClAUS~ I I I ENGINEERING AIDES * Shared with Production Manager ** Until 1/01/95 *** Job Share 8111/94 , . . 10 11 12 13 14 15 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1 R-32 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,402')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (11,544') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" x 5" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" x 5" casing to 3500 psi. Perforate and run completion assembly. This is a "packerless" completion that utilizes a 4" seal bore extension (SBE) run in the 7"x 5" casing string. The seal assembly is run on the end of the completion string, stung into the SBE, and tested to ensure tubing x casing annular integrity. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED NOV 1 6 Ai~ska 0ii & Gas Cons. Commission Anchorc. 7" x 5" Tapered Casing Design 12-1/4" Hole 9-5/8" 40# L-80 BTC 200' TVD below base West Sak Circ cement to surface 8-1/2" Hole TOC min 500' MD above top Kuparuk 7" 26# L-80 BTC Mod surface to +70 ' above top Kuparuk 5" 18# L-80 LTC Mod to TD Base of West Sak Top of K-lO 5" x 4" SBE/Casing XO +70' above top Kuparuk Top of Kuparuk C Base of Kuparuk A Completion Diagram 7" x 5" Tapered Casing 1/4" Control Line 3-1/2" BP-61 Landing Nipple (2.812") 3-1/2" Special clearance tubing surf-800' WRDP-1A SSSV @ 800' TMD 3-1/2" 9.3# L-80 Mod 8rd 7" 26# L-80 BTC Mod Drift = 6.151" ID = 6.276" 3-1/2" GLMs for gas lift 4" Locator Seal Assembly w/3.00" ID 5" x4" SBE @ 70' above top perf SBE & XO f/7" to 5"casing --- C sand perfs -- A sand perfs 18# LTC 5" L-80 Drift = 4.151" ID = 4.276" RECEIVED CortllTIIS.~lO0 Gas Cons. ' - '"' Anchor:..,' DRILLING FLUID PROGRAM Well 1 R-32 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9,5-10 ___10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,407 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 R-32 is 1R-20. As designed, the minimum distance between the two wells would be 11.6'@ 375' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 1 R-32 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED Oas Cons. Commission Al~chor: ARCO ALASKA, ilCrea(ed by : jones For: D PETRASHi iD~(e plo(ted ' 6-Nov-94 iPlot Reference is 32 Version //6. iCoordinotes ore in feet reference slot #52.i i iTrue Vertical Depths are reference RKB. i Baker Hughes INTEQ --- 8 Structure : Pad 1R Well : 52 Field : Kuparuk River Unit Location : North Slope, Alaska N 5.09 DEG W 8412' (TO TARGET) JTD LOCATION: J 1294' FNL, 617' FEL SEC. 7, T12N. RIOE ESTII4ATED RKB ELEVATION: 85' KOP TVD=SOO TMD=500 DEP=O 5.74 BEGIN TURN TO TARGET TVD=468 TMD=467 DEP=5 JTARGET LOCATION: J 1500' FNL, 6DO' FEL SEC. 7, T12N, RIOE TARGET - A3 SANDS TVD=6747 TMD=11222 DEP=8412 NORTH 8579 WEST 746 <-- West 1 BOO 1200 600 0 600 I I I I I I I II I , .gO00 40 DEG TD / 7" CSG PT TVD=6993 T~,lD=llfi44 DEP=§619 0 400 800 12 0 1600 20 0 2400 28 0 5200 56 0 4000 4400 4800 52 0 56 0 6000 6400 6800 76 8000 8400 8800 Scole 1 : 200.00 Verticol Section on 354.91 ozimufh wlfh reference 0.00 N, 0.00 E from slot #32 7200 , 1 1.03 ~,~ 16.80 16® 22.69 30EC / too' bLS _ 'k,, 28.62 x,,k,, 34.57 _30oo '~ ¢'~,N'~°.''x "0:~=51 B/ PERMAFROST WD=1551 TMD=1797 DEP=524 ~-..~ - ~2.49 TMD=2332 OEP=941 2400 12o0 _ C E VED T/ W SAK SNDS TVD=3391 TMD=5077 DEP=3303 ~ O B/w ~K sNos ~=~ ~,o=~o,o o~=4,o~~ ~~. Oil & Gas Cons. Commission ~R~[~,O,' ~ ~ 9 5/8" CSG PT WD=4066 IUD=6402 D~=4444 AVERAGE ANGLE ~ 59.4 DEG ~ ~~~~732 ~[P=~310 ~ ~ ~~MD~877 DEP=7434 ~8.~ K~ TM~102~EP=7775 ~ ~.~ 6~ DROP 2 OEG / I~' ~D~846 DE~ 70 ~2 ~ ]/ ZO~~7 m~=lO~7 DEP=8261 ~ TARGET ANGLE v zo~ ~=,~ ~.=~ ~. B/ KUP SNDS ~D=68~0 1HD=11344 DEP=8490 ~ 66oo ARCO ALASKA, Structure : Pad 1R Field : Kuparuk River Unit Location : North Slope, Alaska <-- West Scale l : 20.00 560 520 ~ 440 400 360 ~,20 2~0 240 200 160 120 80 40 0 40 I~O 120 160 200 24O 13201 12801 1240~ 1160~ 1120~ 1080~ 1040~ 1000~ 22OO _1320 _ _1040 _ . IOO0 92O ~0 1700 840 800 760 720 1900 - 6~0_ - 640_ - 600 - 56O _ - 520 _ 480 _ 40O 360 .. 320 920 I I 84O z 1500 ,i~27c~ , ~'1600 1900 400 . 5~ Cons Commission ~o ~ A!~s~ Oil & Gas . g ........................ ~¢hog,. ' ............. 560 520 4~ ~ 4~ 3~ 320 2~ 240 2001 ~ 120 0 ~ ~ 120 1 ~ 200 2~ <-- Wesf o.oo At, CO ALASKA '][nC. Sfrucfure : Pod 1R Field : Kuporuk River Unif Locofion : Nodh Slope, Alosko _ 6JOOi _ 6000_ _ 5900_ 51800_ - 5700_ _ 5600_ _ 5500_ _ §400_ _ 5300_ _ 5200_ _ 5100_ - 5000_ - 4900_ - 4800_ _ 4?00_ _ 460'0_ _ 4§00_ 4409. 4300. _ 4200_ 3600_ < - - We s f Scole 1 : 50.00 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 60{1 biD{)400 300 200 lOO 0 109 200 300 IIlIIIIIIIIIIIIIIII~IL36~ ~ 5~00~ 4100 5 C~,O0 1 3900 5,.5o0 5300 71 51~ 4~' ~c~-~,~ 0i[ & Gas Cons. Oommi~ion Anchor[.,~ 1700 160~ 1500 1400 1300 1200 1100 1000 900 800 700 38O0 600 500 400 300 200 100 0 100 200 300 Wesf Scale 1: 50.00 6200 5900 · .5800 _ _5700 _ _5600 _ _5500 _ _5400 _5300 _5200 _ _5100 _ - I _4900 - Z - -5 _4700 ~ Casing Design / Cement Calculations 9-Nov-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, A3 Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 1R-32B 6,402 ft 4,066 ft 11,544 ft 6,993 ft 5,077 ft 10,846 ft 6,747 ft 3850 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {( 13.5* O. 052)-0.11 }*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 4,066 ft 2,407 psiJ 3,850.0 ppg 6,747 ft 150 psi 11.4 PPgl Surface lead: Top West Sak, TMD = 5,077 ft Design lead bottom 500 ft above the Top of West Sak = 4,577 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,483 cf Excess factor = 65% Cement volume required = 2,447 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 1,260 sxI Surface tail: TMD shoe = 6,402 ft (surface TD - 500' above West Sak) * (Annulus area) = 572 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 606 cf Excess factor = 15% Cement volume required = 696 cf Yield for Class G cmt - 1.15 Cement volume required =1 610 sxJ RECEIVED NOV I 6 i994 0[t & Gas ~' --- uor~s. Corr4rnission Anchor: Casing Design / Cement Calculations 9-Nov-94 Production tail: TMD = 11,544 ft Top of Target, TMD = 10,846 ft Want TOC 500' above top of target = 10,346 ft 5" casing tail top (100' above C sand) =1 11,150 ft 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 261 cf Length of cmt wanted in csg = 80 ft Internal csg volume - 0.0997 Cmt required in casing - 8 cf Total cmt = 269 cf Excess factor = 75% Cement volume required = 470 cf Yield for Class G cmt = 1.19 Cement volume required =J 400 sx TENSION - Minimum Design Factors are: T(pb)=l.5 and Tqs)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 916000 lb 6,4O2 ft 40.00 Ib/ft 256080.0 lb 43426.0 lb 212654.0 lb 4.31 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 979000 lb 6,402 ft 40.00 Ib/ft 256080.0 lb 43426.0 lb 212654.0 lb 4.6i Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =b 604OO0 lb 11,544 ft 26.00 Ib/ft 300144.0 lb 51610.4 lb 248533.6 lb 2,4J Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =L 667000 lb 11,544 ft 26.00 Ib/ft 300144.0 lb 51610.4 lb 248533.6 lb 2.71 Casing Design / Cement Calculations BURST- Minimum De~,ign Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE- Minimum Desian Factor = 1.0 -- Surface Casing 1. Design Case - Lost circUlation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 9-Nov-94 5750 psi 2407.1 psi 7240 psi 7646 psi 3236 psi 4409 psi 1.6J 3090 psi 0.593 Ib/ft 1475 psi 2.11 5410 psi 0.593 Ib/ft 4146 psi 1.3J RECEIVED ....... ~:~ Oil & L~ Cons. C~l~rni~sion AnChor~ Casing Design / Cement Calculations 9-Nov-94 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi ,~UPARUK RIVER UNI, 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 6. 20" - 2000 PSI ANNULAR PREVENTER. 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. RECE!V[D Anchor: 0 ~ O~ ~ Z~ -- 02~ ~0~ zz. 0~~0 ~ ~uoo~o~o ~O0~OtnO O0 O0 o §W-'-'m-'~-' WELL PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] /// 0 ~DMINISTRATION 1. Permit fee attached ................... t N 2. Lease number appropriate.. ] ] i N 3. Unique well name and number, i i i i i i i i i i N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N '7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ........ ..... N 10. Operator has appropriate bond in force ........ N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ....... ~ ....... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B a permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ psig~_~.- 27. Choke manifold complies w/~LPI RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones ......... / N 33. Seabed condition survey (if off-shore) ....... ~ Y N 34. Contact name/phone for weekly progress reports . ./. · Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ TAB ,:.~ . Comments/Instructions: Z HOW/jo - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX InfOrmation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. J ch].t;mber(~F .~ ] esk:a Co',~put !..nc. C"enEe.r 1 7 - .~. P f.-:' - ! 9 9 5 i. 4: 2 "7 PAGE 5 0 -(') ? 9 - 2 ?. 5 2 3 - 0 S l.,i lx 0 ) i. ,.'.1, a 4 5 . 0 L> 50-029-22523-00 1 c I i. [:: ['~ e ,..fi. c ..] r v e $ ~ a]..], bit rttns F., e r o e r"], PAC, E: C; ..P. 0 L( ]g I ST Y P .i'. [< iF' t. 4 ? ~,.: .1. 7 ',- ~ F,' (~ ,,- 1 9 g 5 1 4.: ? 7 -9999.000 68. 900 ~t. (i7 ! 9. t) ,",PF'''~ ,~.!~i[,~,~., i_~TT 31'ZF ( Il'.., ): 6, I .2.5 (, l !,,,! J: I.,~T5 FOR,"A'J' P, AT~\ ,-1.1276" I~5 PF:R G..EU!..,OGIST, I$ 'T'ar'.e 'tt~r~Jcat.~ior: t..il, st f.'nq i't-:APP-I(.?g5 14.:77 !2.600 -9999.000 · ~: ;{.~ '~, ?. ~.;'.,, !:ii o : i'i] :.,~ '~,.! '.~ 'i':~']' ~,~ ,..~ ~"~
