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Home My WebLink About195-181MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-25 KUPARUK RIV UNIT 3R-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 3R-25 50-029-22622-00-00 195-181-0 N SPT 3953 1951810 1500 1925 3020 2990 2985 REQVAR P Adam Earl 8/10/2024 MIT-T / Monobore tesed as per AIO 2B.012 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3R-25 Inspection Date: Tubing OA Packer Depth 435 520 525 525IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812134953 BBL Pumped:0.6 BBL Returned:0.5 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:08:52 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-25 KUPARUK RIV UNIT 3R-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 3R-25 50-029-22622-00-00 195-181-0 N SPT 3953 1951810 1500 1500 1700 1710 1710 REQVAR P Adam Earl 8/10/2024 MIT-IA tested as per AIO 2B.012-monobore well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3R-25 Inspection Date: Tubing OA Packer Depth 420 2550 2440 2430IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240812135539 BBL Pumped:1.2 BBL Returned:1.2 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 AIO 2B.012-monobore well James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:05:44 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: A-1 Injection Valve Re-Installed on 3R-25 (PTD# 195-181) Date:Saturday, August 27, 2022 8:16:24 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Friday, August 26, 2022 6:09 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: NSK Prod Engr Specialist <n1139@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com> Subject: A-1 Injection Valve Re-Installed on 3R-25 (PTD# 195-181) Mr. Regg, The plug was pulled, and the A1 injection valve was re-installed in 3R-25 (PTD# 195-181) on 08/25/2022. The well was brought online today 08/26/2022 and is currently injecting ~1,400 BLPD at 1,975 psi. Thank you, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 From: CPF3 Prod Engrs Sent: Thursday, August 4, 2022 3:50 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: NSK Prod Engr Specialist <n1139@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com> Subject: A-1 Injection Valve Removed on 3R-25 (PTD# 195-181) Mr. Regg, 3R-25 (PTD# 195-181) is an injection well with a completion design that left the production packer ~3600 above the perforated zone. An exemption was granted that requires a state witnessed (SW) MIT-T against a tubing plug set as close as possible to the nipple profile at 6921'. The A-1 injection valve was pulled from 3R-25 on 07/29/2022, and an XXN plug was set at 6,920’ in preparation for state witnessed testing. Upon successful state witnessed testing, the AOGCC will be notified when the plug is removed, and the A-1 injection valve is re-installed. Thank you, Brian Lewis Senior Production Engineer – CPF3 Phone: (907) 263-4535 | Cell: (918) 521-8990 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-25 KUPARUK RIV UNIT 3R-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3R-25 50-029-22622-00-00 195-181-0 N SPT 3953 1951810 1500 2340 3220 3160 3160 REQVAR P Kam StJohn 8/10/2022 MIT-T every 2 years against tubing plug as per AIO 2B.012 Single casing wall 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3R-25 Inspection Date: Tubing OA Packer Depth 160 210 210 210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810180138 BBL Pumped:0.4 BBL Returned:0.3 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 MIT-T AIO 2B.012 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 12:11:05 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3R-25 KUPARUK RIV UNIT 3R-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3R-25 50-029-22622-00-00 195-181-0 N SPT 3953 1951810 1500 2280 2400 2410 2410 REQVAR P Kam StJohn 8/10/2022 MIT-IA every 2 years per AIO 2B.012 Single casing 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3R-25 Inspection Date: Tubing OA Packer Depth 150 1780 1715 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810180521 BBL Pumped:0.8 BBL Returned:0.9 Friday, September 2, 2022 Page 1 of 1          CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: A-1 Injection Valve Removed on 3R-25 (PTD# 195-181) Date:Friday, August 5, 2022 11:21:03 AM Attachments:image001.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Thursday, August 4, 2022 3:50 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: NSK Prod Engr Specialist <n1139@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com> Subject: A-1 Injection Valve Removed on 3R-25 (PTD# 195-181) Mr. Regg, 3R-25 (PTD# 195-181) is an injection well with a completion design that left the production packer ~3600 above the perforated zone. An exemption was granted that requires a state witnessed (SW) MIT-T against a tubing plug set as close as possible to the nipple profile at 6921'. The A-1 injection valve was pulled from 3R-25 on 07/29/2022, and an XXN plug was set at 6,920’ in preparation for state witnessed testing. Upon successful state witnessed testing, the AOGCC will be notified when the plug is removed, and the A-1 injection valve is re-installed. Thank you, Brian Lewis Senior Production Engineer – CPF3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Thursday, August 13, 2020 P.I. Supervisor f ?� Z07,1SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3R-25 FROM: Bob Noble KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed B n P.I. Supry� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 Insp Num: mitRCN200811145502 Rel Insp Num: API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 8/9/2020 Packer Depth Well 3R-25 _Type Inj N ,TVD 3953 PTD ii 1951810 Type Test SPT- Test psi 1500 BBL Pumped: 0.4 IBBL Returned: 0,3 Interval REQVAR �P/F P Notes: MIT -T every 2 years as per AIO 28.012 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2225 - 3000- 2930 2920 - 1A 310 - 350 350 - 350 OA Thursday, August 13, 2020 Page I of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor ��zl i?OZlj FROM: Bob Noble Petroleum Inspector Well Name KUPARUK RIV UNIT 3R-25 IRsp Num: mitRCN200811145952 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 13, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, [nc. 3R-25 KUPARUK RFV UNIT 3R-25 Src: Inspector Reviewed By: P.I. Supry Jbx NON -CONFIDENTIAL Comm API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 8/9/2020 - Packer Depth Well 3R -2s Type Inj N TVD 3953 Tubing PTD ---19518 [ 0 Type Testis sPT -Test psi ! 1500 IA BBL Pumped: 0.8 113131, Returned: 1 OA — --- Intervall REQVAR - P/F P Notes: MIT -IA every 2 years as per AIO 213.012 Pretest Initial 15 Min 30 Min 45 Min 60 Min 2225350+2350 - 2350 310 1720 1650 - 1640 Thursday, August 13, 2020 Page 1 of I I STATE OF ALA"OIL AND GAS CONSERVATION COMMON RECEIVED REPORT OF SUNDRY WELL OPERATIONS OCT (� 1 1 2017 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Performed: Suspend ❑ Perforate ❑ Other Stimulate Q Alter Casing 0 rpfd Program ❑❑ Plug for Redrill 0 'erforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 U Acid Stim 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 195-181 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-22622-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3R-25 ADL 355023 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 7,310 feet Plugs measured None feet true vertical 6,941 feet Junk measured None feet Effective Depth measured 7,310 feet Packer measured 0 feet true vertical 6,941 feet true vertical 0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16" 121'MD 121'TVD SURFACE 4,172 feet 7-5/8" 4,213'MD 4092'TVD LINER 3,252 feet 4-1/2" 7,309'MD 6940'TVD Tubing(size,grade,measured and true vertical depth) 4.5" L-80 4,092' MD 3984'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER ZXP PACKER 4056' MD 3952'TVD SSSV TYPE- NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A �g r nn gg Treatment descriptions including volumes used and final pressure: SCANME� h �r! , 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: o 0 0 91 2835 Subsequent to operation: o 0 2432 1755 2771 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory 0 Development ❑ Service ❑., Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP 0 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-267 Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Contact Phone: (907)265-6097 Authorized Signat �� Date:dor /��0�/ lin-- i6 i 13-1 ! 4 co/if7/7 �,• 11X17 Form 10-404 Revised 4/2017 Submit Original Only • S 3R-25 DTTMST JOB SUMMARYOPS TYP 9/17/17 ACID RIH WITH JET SWIRL NOZZLE, INJECT 100 BBLS OF DAD ACID INTO FORMATION AT 7000' RKB, F/P TBG WITH DIESEL, READY FOR SL TO REPLACE INJECTION VALVE, JOB IN PROGRESS. 9/20/17 ACID SET 3.81"X-LOCK W/A-1 INJECTION VALVE (1"ORIFICE SN: HJS- 962)@ 488' RKB; OBTAINED PASSING CLOSURE TEST. JOB COMPLETE. KUP I 3R-25 ConocoPhillips " Well Attribut Max Angles TD Alaska.It lc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Rho(ftKB) ConocoPhillips 500292262200 KUPARUK RIVER UNIT INJ 26.39 4,142.22 7,310.0 I. °°. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3R-25,10/10/2017 1212:19 PM SSSV:NIPPLE Last WO: 12/8/1995 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'.SLM 7,098.0 4/18/2015 Rev Reason:INJ VLV C/O pproven 9/22/2017 p.,. Casing Strings 38.7 ®' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread ® CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread � 1 SURFACE 75/8 6.875 41.0 4,212.7 4,092.5 29.70_L-80 BTC-MOD HANGER;39.3 -t Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread :Ii:'' LINER 41/2 3.958 4,056.7 7,309.0 6,940.0 12.60 L-80 NSCT L VW r Liner Details TUBING PUP',43.3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 4,056.7 3,952.3 25.77 PACKER BAKER ZXP PACKER 5.750 4,069.2 3,963.5 25.86 HANGER BAKER HMC LINER HANGER 4.892 CONDUCTOR,41.0-121.o-41 L 4,076.5 3,970.1 25.91 PBR BAKER PBR 4.750 TUBING;45.4 6,920.5 6,570.9 18.56 NIPPLE OTIS XN NIPPLE NO GO 3.725 Tubing Strings 3#/ Tubing Description escr prion Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING !String 4 1/21 3.9581 38.7, 4,092.01 3,984.11 12.601 L-80 INSCT .!.. NIPPLE;488 .8 Completion Details VALVE;488.0 Nominal ID l Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) '®I 38.7 38.7 0.07 HANGER TUBING HANGER(TOP) 4,500 39.3 39.3 0.07 HANGER TUBING HANGER(BOTTOM) 3.958 TUBING,489.9 488.8 488.7 0.81 NIPPLE OTIS'X'NIPPLE 3.813 o a 4,050.2 3,946.4 25.72 SLEEVE BAKER SLIDING SLEEVE w/X SELECTIVE PROFILE 3.812 SLEEVE;4,050.2 4,060.8 3,956.0 25.80 LOCATOR BAKER LOCATOR 3.875 4,062.5 3,957.5 25.81 SEAL ASSY BAKER GBH 22S SEAL ASSEMBLY&SPACER BARS 3.875 • 4,091.5 3,983.6 26.02 SHOE MULE SHOE 3.875 }I' (5 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl LOCATOR;4,0608 Top(ftKB) (ftKB) (°) Des Com Run Date ID lin) 488.0 488.0 0.81 VALVE W/3.81"X LOCK&A-1 INJ VLV(1.0"ORIFICE, 9/20/2017 1.000 -I .u,ft SERIAL#HJS-962)OAL=48" III Perforations&Slots mt. Shot 1 Dens SEAL ASSY,4,062.5 Top(TVD) Btm(TVD) (shots/ MI Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 11 I 7,030.0 7,050.0 6,674.8 6,693.8 A-1,A-2,3R- 1/22/1996 4.0 IPERF 180 deg ph;oriented 45 in r25 deg CCW&135 deg;3- SHOE,4.001 5 3/8"BH Csg Gun 7,050.0 7,080.0 6,693.8 6,722,3 A-1,A-2,3R- 1/22/1996 4.0 IPERF 180 deg ph;oriented 45 25 deg CCW&135 deg;3- 3/8"BH Csg Gun Notes:General&Safety End Date Annotation 12/9/2001 NOTE:WAIVERED WELL-Monobore completion;water-only injection. 12/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE',41.0-4,212.7-. IPERF;7,030.0-70500 IPERF;7050.0-7,080.0 LINER',4,056.7-7,309.0 F • . \��j��9 THE STATE Alaska Oil and Gas ti M OPALAsKA Conservation Commission ` -#2 * 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCAM Staff Wells Engineer� SGA ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 3R-25 Permit to Drill Number: 195-181 Sundry Number: 317-267 Dear Mr. Burke: 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, 4)11- 7 aniel T. Seamount,Jr. Commissioner DATED this�(.day of June,2017. RBDMS I,1-/ wI1 c 7 2017 • • RECEIVED STATE OF ALASKA JUN 15 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AG+ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate V Pull Tubing ❑ Change Appr dd Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: ACID STIMULATE 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 195-181 • 3.Address: Stratigraphic 0 Service 0 • 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22622-00'3° 7.If perforating: 8.Well Name and Number: "_ What Regulation or Conservation Order governs well spacing in this pool? N/A W AL/ KRU 3R-25 • Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355023 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,310' • 6,941' • 7310 6941 3353psi NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 4,172' 75/8 4,213' 4,092' Liner 3,252' 4 1/2 7,309' 6,940' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7030-7050,7050-7080 6675-6694,6694-6722 4.500" L-80 4,092' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=BAKER ZXP PACKER MD=4057,and ND=3952 SSSV: NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 • 14.Estimated Date for 7/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com OF �r� / Contact Phone: (907)265-6097 Authorized Signature. Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3( 7— 2L,7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ f- ( (Z(l l kq Other: Post Initial Injection MIT Req'd? Yes ❑ No Er RBDMS Lv JuN L / 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: I � .a 4i APPROVED BY ) I 17 Approved by: COMMISSIONER THE COMMISSION Date: ( 2• ` D VTLA(O/2 Z// O R Jd p Submit Form and Form 10-403 Revised 4/2017 p v p■PI a valid for 12 months from the date of approval. Attachments in Duplicate l. f a 6- f.17 • � • ConocoPhillips Alaska,Inc. `►_'� Drilling&Wells ConocoPhillips Well Intervention. Alaska 3R-25 Acid Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with • dispersing agent F 103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity • Slick-Line: Pull injection valve • Coiled Tubing: Spot 100 bbl of DAD into formation • Slick Line: Replace Injection valve 1. MIRU Slick Line 2. Pull injection valve at 488' MD 3. RDMO Slick Line 4. MIRU 1.5" CT, MU 5 port wash nozzle BHA 5. Begin RIH down to 7080' MD. a. Well has a patch at 6223' MD with a 1.83" ID & fish at 6452' MD 6. When CT has reached depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH to 7000'. Continue injecting DAD into formation and it out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 7. After an additional 5 bbl of fluid has been injected behind the treatment POOH 8. RDMO CT and MIRU Slick Line 9. Replace injection valve at 488' MD 10. Return well to injection. June 7, 2017 3R-25 Well Work Procedure Page 1 of 2 • 110 ConocoPhillips Alaska,Inc. ♦-' Drilling&Wells ConocoPhillips Well Intervention Alaska Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HCl H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal June 7,2017 3R-25 Well Work Procedure Page 2 of 2 KUP 3R-25 ( (}�')QCUPt� 1�3s < ¢`, Well Attrib Max Angl D TD '.. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc, Car000aPhlibps 500292262200 KUPARUK RIVER UNIT INJ 26.39 4,142.22 7,310.0 °°° A M Comment I12S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 312-25,6/12/2017826:31 AM SSSV:NIPPLE Last WO: 12/8/1995 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,098.0 4/18/2015 Rev Reason:SET INJ VLV pproven 8/7/2016 ■ .,-ar l' Casing Sings HANGER;38.7 7gezni Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread ■ CONDUCTOCasingDescripRtion 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Len ...Grade Top Thread ri 4 SURFACE 7 5/8 6.875 41.0 4,212.7 4,092.5 29.70 L-80 BTC-MOD HANGER39.3 III- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ; I ILINER 41/2 3.958 4,056.7 7,309.0 6,940.0 12.60 L-80 NSCT Al Liner Details Nominal ID TUBING PUP;43.3 � Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (In) 4,056.7 3,952.3 25.77 PACKER BAKER ZXP PACKER 5.750 4,069.2' 3,963.5 25.86 HANGER BAKER HMC LINER HANGER 4.892 CONDUCTOR;41.0-121.o-41 4,076.5 3,970.1 25.91 PBR BAKER PBR 4.750 TUBING;45.4 6,920.5 6,570.9 18.56 NIPPLE OTIS XN NIPPLE NO GO 3.725 Tubing Strings NIPPLE;488.8 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..lSet Depth(TVD)(...Wt(11a/ft) Grade Top Connection �t. TUBING 41/2 3.958 38.7 4,092.0 3,984.1 12.60 L-80 NSCT VALVE;488.8 T.' Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 1°) Item Des Corn (in) TUBING;409.9 38.7 38.7 0.07 HANGER TUBING HANGER(TOP) 4.500 • 39.3 39.3 0.07 HANGER TUBING HANGER(BOTTOM) 3.958 SLEEVE;4,050.2 488.8 488.7 0.81 NIPPLE OTIS'X'NIPPLE 3.813 4,050.2 3,946.4 25.72 SLEEVE BAKER SLIDING SLEEVE w/X SELECTIVE PROFILE 3.812 4,060.8 3,956.0 25.80 LOCATOR BAKER LOCATOR 3.875 • 4,062.5 3,957.5 25.81 SEAL ASSY BAKER GBH 22S SEAL ASSEMBLY 8 SPACER BARS 3.875 9 I (f 4,091.5 3,983.6 26.02 SHOE MULE SHOE 3.875 80cnroH.4060.9_ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) F Top(TVD) Top Incl t Top(ftKB( (ftKB) (°) Des Com Run Date ID(in) fl aft 488.8 488.8 0 81 VALVE 3.81"X-LOCK 8 MCX INJ VLV(SN:MCX-304) 8/6/2016 1 090 (BEAN=1.09")(OAL=59",MCX=36") lel I d Perforations&Slots SEAL ASSY,4,062.5 Shot I Dens I Top(TVD) Btm(ND) (shots/ It Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,030.0 7,050.0 6,674.8 6,693.8 A-1,A-2,3R- 1/22/1996 4.0 IPERF 180 deg ph;oriented 45 SHOE 4091.5 25 deg CCW 8 135 deg;3- 3/8"BH Cog Gun 7,050.0 7,080.0 6,693.8 6,722.3 A-1,A-2,3R- 1/22/1996 4.0 (PERF 180 deg ph;oriented 45 25 deg CCW 8 135 deg;3- 3/8"BH Csg Gun Notes:General&Safety End Date Annotation 12/9/2001 NOTE:WAIVERED WELL-Monobore completion,water-only injection. 12/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;41.0-4,212.7 ) fili IPERF;7,030.0-7,050.0 L.-- a a is (PERF;7,050.0-7,080.0 --- LINER;4,056.7-7,309.0 1 1 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 08,2016 TO: Jim Regg Re '31$(,� P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Bob Noble KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jgC.-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804115258 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3R-25 . Type Inj N'TVD 3953 Tubing 1 270 408 427 430 PTD, 1951810 ' Type Test SPT Test psi 1500 - IA I 15 1810 - 1760 - 1 1740 - Interval REQVAR P/F i P OA I[ Notes:• MIT-IA per AIO 2B.012.Mono bore well. SCANNE) MAY 1 0 20i:/: Monday,August 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ? DATE: Monday,August 08,2016 t: 2 Regg / 1 - rNP G vl SUBJECT:Mechanical Integrity Tests J g ty P.I.Su erv�so� 1 P CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Bob Noble KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed By.:, P.I.Supry J � NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 8/2/2016 Insp Num: mitRCNI60804114837 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3R-25 - Type Inj N TVD 3953 Tubing 944 1810 • 1770 - 1760 " PTD 1951810 (Type Test SPT Test psi 1500 , IA 10 10 15 15 Interval REQVAR P/F P ✓ OA Notes: MIT-T per AIO 2B.012.Mono bore well. SCANNED MAY 1 0 2017 Monday,August 08,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Thursday,April 30,2015 P.I. 30 Supervisor �e1 1 4I (,c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Bob Noble KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 4/24/2015 Insp Num: mnRCN150424172539 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 3R-25 J Type In' LN 00 TVD 3953 !Tubing 132505 - 1 2455 2440 PTD� I951810 ' Type TestSPT Test psi isoo IA15 I 15 ' 15 15 r Interval 1REQvAR IP/F _ OA Notes: MIT-T every 2 years Mono-Bore well IN MAY 2 2 ZO1 Thursday,April 30,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim Regg DATE: Thursday,April 30,2015 TO: � P.I.Supervisor � (3Dli SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Bob Noble KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed Byj P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: Bob Noble Permit Number: 195-181-0 Inspection Date: 4/24/2015 Insp Num: mitRCN150424172919 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min well T 3R-25 - fType Inj 1 N 'TVD 3953 Tubing 1065 1225 - 1245 1245 — — PTD] 1951810 Type Test SPT Test psi 1500 - IA 15 2000 1930 • 1930 - ---------- - ---- IntervallREQvAR P/F P y OA — — — � 1 —Notes: MIT-IA every 2 years.Mono-Bore well A'-.C) Z 1z SEAMIMED MAY 2 2 2D15 Thursday,April 30,2015 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File 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. File Number of Well History File PAGES TO DELETE Complete RESCAN ..C.-olor 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: ~ianna Vincent Nathan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: Wednesday,April 17,2013 P.I.Supervisor \ `� 76 i 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Jeff Jones KUPARUK R1V UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: JeffJones Permit Number: 195-181-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416140850 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3R-25 • Type Inj N ".TVD I 3953 IA ? 0 3 3 3 , PTD 1951810 Type Test SPT;Test psi 1500 OA — —_ Interval 'REQVAR P/F P Tubing, 750 3000 • 2900 2880 Notes: MIT-T per AIO 2B.012 SCANNED FEB 2 b 2014 Wednesday, 17,2013 Page 1 of 1 Y April g MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 17,2013 TO: Jim Regg 7Q-e 4(Z�It3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 FROM: Jeff Jones KUPARUK RIV UNIT 3R-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry •:Jf NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3R-25 API Well Number 50-029-22622-00-00 Inspector Name: Jeff Jones Permit Number: 195-181-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416I41317 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 1 Well! 3R-25 - Type Inj 1 TVD 1 3953 IA 2 2810 '' 2720 1 2710 PTD R9 1810 ;Type Test Test psi P OA 563 781 810 814 1951810 SPT p 1500 Interval P/F Tubing, Notes: MITIA per AIO 2B.012 ,- SCANNED FEB 2 5 2014 Wednesday,April 17,2013 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, April 19, 2011 P.I. Supervisor ` 5 (?A i, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R -25 FROM: Lou Grimaldi KUPARUK RIV UNIT 3R -25 Petroleum Inspector Src: Inspector Reviewed By: Pl. Supry f/3 -- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3R -25 API Well Number: 50 -029- 22622 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110417090934 Permit Number: 195 -181 -0 Inspection Date: 4/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' 3R -25 - Type Inj. N ' TVD 3953 ' IA 440 2027 - 1988 1980 — P.T.D 1951810 J TypeTest SPT Test psi 1500 - OA Interval REQVAR P/F P — Tubing 1293 1438 1456 1461 Notes: MIT IA for compliance with AIO 2B.012 AA. Monobore completion, MD @ 4057', W/L plug reported set in HES XN nipple @ 6921'. Successful MITT performed today prior to this test. Pretest pressures are where well came to rest after bleeding from previous MITT. re.fe,4o ZL& ma L6 1104 )70 (1 MAY J4 Z011 Tuesday, April 19, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 19, 2011 TO: Jim Regg � �� 6(2-1 C P.I. Supervisor i1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R -25 FROM: Lou Grimaldi KUPARUK RIV UNIT 3R -25 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .7),t__-- NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3R -25 API Well Number: 50- 029 - 22622 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110417080511 Permit Number: 195 -181 -0 Inspection Date: 4/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 3R -25 Type Inj. 1 N J TVD 3953 • I IA 440 552 - 554 552 - 1 951810 S ( — P.T.D Type i Test psi 1500 - OA Interval REQVAR - P/F P - Tubing 1240 3030 - 2981 2965 - Notes: MIT Tubing for compliance with AIO 2B.012 AA. Monobore completion, MD @ 4057', W/L plug reported set in HES XN nipple @ 6921'. Tuesday, April 19, 2011 Page 1 of 1 Page 1of1 • Regg, James B (DOA) • From: Grimaldi, Louis R (DOA) 11 J`^� i v 1 Sent: Monday, April 18, 2011 7:24 AM To: NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay Subject: RE: 3R -25 testing info Hi Brent, • A follow up e -mail about yesterdays test. The test went very well. Ian lye's and Teddy Westlake were well prepared and ready to start when I got there, I very much appreciate that. Even though Teddy was new to this particular operation he was very familiar with routine well operations and the job went smoothly in part to his experience and solid work ethic. Of course, Ian did his normal outstanding work and was a step ahead all the time. As discussed with you yesterday the only issue I observed that needs some attention is the transmitter to monitor the Casing pressure seemed out of calibration according to the test gauges we used. The mounted transmitter was approximately 71 psi low across the readings observed today when compared to the digital test gauge. I also did not see a calibration sticker on said transmitter. I spoke with you yesterday about this on the phone and you told me that this would be addressed. Please send confirmation of; 1. When this matter is addressed. 2. What was done to correct. 3. Impact of issue to wells with similar AA's using these style transmitters. This information should go to Supervisor Jim Regg. I look forward to working with you and your crew's in the future. Lou Grimaldi From: NSK Problem Well Supv [mailto:nl617 @conocophillips.com] Sent: Saturday, April 16, 2011 3:39 PM To: Grimaldi, Louis R (DOA) Subject: 3R -25 testing info Lou, Attached is a copy of AIO 2B.012 and the schematic for 3R -25. The XXN plug is sent in the XN profile @ 6921'. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 4/18/2011 TRttAmit. ANNULUS PRESSURE TRENDS TRIVOILIMT r-ii) 500. ..., 3000 Sc WELL NAME WLKRU3R . - . - , —1 200. 3000 . ,._ 3000 ._.--„,, . . , 300 2700 0. 3000. 3008. 2400 . / , 3000. 1-v1_1 ,t A i i N 1 / ___. , 2100 .. ,,,,,,--/ / ., 4.,1 .\---",/ \ 1 1800 . . . 1500 I- . 1 • • i I I' 1200 1 A A , 4.A.A4ler—eraipea, ‘14 900 L ;- 44( • • - e 1 1 *- 4,47,4***, ' O. . - Actik e ir* **4 40, itrA" A , *A 600 * i O. 300 O. tail' - - • • ' . , ......i II , i a. 0, - IL I; 0. PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME .. 16-JAN-11 16 : 39 MAJOR TIME WEEK +02000: 0O HRS ifi*AP 15 : 39 41, OEM ' 1S4 8W Olin MIIIIIIM 151 PTCX TINE: 154PIV.11 - 14:311187 SC TAG RAH DESCRIPTION P-VALUE LATEST WL3R FLOW TUBING CHOKE ??????? PREV WELL DRILLSITE WELL pi W SCRATCH 26 FLOW TUBING PRESSURE 7777777 3r 25 Pr SCRATCH_26 FLOW TUBING TEMP 777777? pi NEXT WELL PI" 7797777 Pir 7 ENTRY TYPE OPERATOR Ply 7777777 Pr OPERATOR VERIFIED Pr SCRATCH_26 INNER ANNULUS PRES 27'7? POI SYSTEM AUTO ENTRY • SCRATCH_26 OUTER ANNULUS PRES 7777777 • BOTH KUP 3R -25 Coinoc Weii att Max ar le & MD To AiaSka, 11C. Welibore APIIUWI Field Name Well Status Prodllnj Type Insl (°) MD (MB) Act Btm (ftKB) m 500292262200 KUPARUK RIVER UNIT INJ PWI 26.39 4,142.22 7,310.0 Comment H2S (ppm) Date Annotation End Date KB - Ord (k) Rig Release Date "' SSSV: NIPPLE 0 1/1/2009 Last WO: 12/8/1995 Well Cons: - 3R -25, 4/22/2009 2.51:38 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation End Date Last Tag: SLM 7,162.0 4/16/2009 Rev Reason: PULL PLUG, TAG FILL, RESET INJ VLV 4/23/2009 Casing Strings - --- -- — - _ - "- String OD String ID Sat Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (ftKB) (ftKB) (kKB) (Ibs/tt) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 121.0 121.0 62.50 H-40 SURFACE 75/8 6.750 0.0 4213.0 4,093.0 29.70 L-80 I LINER 41/2 3.833 4,057.0 7,309.0 6,940.0 12.60 L -80 I Tubing Strings q String OD String ID Set Depth Set Depth (TVD) String Wt String 3 3 Tubing Description (in) (in) Top (ftKB) (kKB) (kKB) (lboXt) Grade String Top Thrd TUBING 41/2 3.833 0.0 4,092.0 3,984.3 12.60 L -80 NSCT Other In Hole (AU Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (71/D) Top Inca Top (ftKB) (kKB) ( °) Description Comment Run Date ID (in) 489 489.0 -0.35 NIPPLE Otis'X' Nipple 12/6/1995 3.813 CONDUCTOR, - 489 489.0 -0.35 VALVE MCX INJECTION VALVE X -LOCK 1" BEAN (SN MCX -347) 4/19/2009 1.000 121 " OAL =36" 4,050 3,947.3 27.51 SLEEVE Baker Sliding Sleeve w/Selective Profile 12/6/1995 3.812 4,057 3,953.5 27.42 PACKER Baker'ZXP' LINER TOP PACKER 12/6/1995 5.750 NIPPLE, 489 4,063 3,958.7 27.35 SEAL Baker 'GBH-22S' SEAL ASSEMBLY 12/6/1995 3.875 4,069 3,964.0 2728 HANGER Baker'HMC' LINER HANGER 12/6/1995 4.892 4,077 3,971.1 27.18 PBR Baker VALVE, 489 :..::;,' 12/6/1995 4.750 4,092 3,984.3 27.00 SHOE MULE SHOE TUBING TAIL 12/6/1995 3.833 6,921 6,571.4 18.56 NIPPLE Otis 'XN' NO GO NIPPLE 12/6/1995 3.725 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (kKB) (ftKB) Zone Date (sh... Type Comment 7,030 7,050 6,674.9 6,693.9 A -1, A -2, 3R -25 1/22/1996 4.0 1PERF 180 deg ph; oriented 45 deg CCW & 135 deg; 3-3/8" BH Csg Gun SLEEVE, 4.050 7,050 7,080 6,693.9 6,722.4 A -1, A -2, 3R -25 1/22/1996 4.0 IPERF 180 deg ph; oriented 45 deg CCW & 135 deg; 3-3/8" BH Csg Gun Notes: General & Safety End Date Annotation 12/9/2001 NOTE: WAIVERED WELL - Monobore completion; water - only injection. PACKER, 4,057 1 SEAL. 4,063 (-- HANGER, 4,089 I PER. 4,077 l SHOE, 4,092 SURFACE. 4.213 -WL plug set in XN NIPPLE. 8,927 Nipple as per Brent Rogers. IPERF, 7030 -7,050 - -�- IPERF, V4 7,050 -7080 — - - LINER, 7,309 TD, 7,310 • ConocoPhliips ~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seaxriount: r ~EC~I~E APR 0 ~ 2010 Ica Oi18~ Gas Cons. Comm~asia~ ~~ ~~~~g~ 3 ~' ~. Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRII). 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 March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, t'op 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, MJ L veland ConocoPhillips Well Integrity Projects Supervisor • I~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 3A_ 3B_ 3C_ 3G_ 3H_ 31.31.3M_ 3A R 3R P01']'e Well Name ~ API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft al 3A-02 50029214310000 1852050 Surface n/a 26" n/a 4.25 3/292010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3292010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3292010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3292010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/28/2010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/272010 3G-08 50103201280000- 1900650 SF 0.65 27" 32/10 5.52 328/2010 3G-09 50103201290000 1900670 SF 0.60 22" 32/10 4.67 3/282010 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 328/2010 3H-01 50103200840000 1871100 SF n/a 21" Na 4.25 3282010 3H-03 50103200850000 1871110 17" 0.40 8" 321/10 1.7 328/2010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 329/2010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/292010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 329/2010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/282010 3J-15 50029214970000 1852890 SF n/a 22" n/a 3.4 3/282010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/292010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/29/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 3/272010 30-16A 50029217960100 1880430 SF n/a 22" Na 3.52 3/27/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/272010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3272010 3R-19 50029222690000 1920460 1" n/a 21" n/a 5.1 3/27/2010 3R-25 50029226220000 1951810 SF n/a 21" Na 5.52 3272010 • • MEMORANDUM State of Alaska Alaska Oit and Gas Conservation Commission DATE: Monday, Apri120, 2009 To: Jim Regg '~ J q P.I. Supervisor ~~ of<~ `tl Zz'~ ~ 1 SUBJECT: Mechanical Integity Tests ( CONOCOPHILLIPS P.I_ASKA INC 3R-~5 FROM: JOhri Crlsp KUPARUK RIV iJNIT 3R-?5 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name• IkUPARUK RIV UNIT 3R-25 API Well Number: 50-029-22622-00-00 Inspector Name: John Crisp Insp Num: mitJCr090419085009 Permit Number: 19s-181-0 ~ Inspection Date• 4!18!2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3R-2s Type Inj. N T~ID 3964 IA 940 1030 1030 -_ 1040 P.T. 19s1s1o TypeTest sPT Test psi 2soo pA Interval REQvaR P/F P ~ Tubing s1o zs~ z4zo zaoo Notes: MITT tubing tail plug set. 1 bbl pumped for test. Monobore injector. Monday, Apri120, 2009 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, Apri120, 2009 TO: Jim Regg ~~t` Q'I2Z (d l SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1% CONOCOPHII.LIPS ALASKA INC 3R-25 FROM: John Crisp xtmARUx Rtv uNiT 3R-zs Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv r~}(~~i Comm Well Name• KUPARUK RIV UNIT 3R-25 • API Well Number: 50-029-22622-00-00 Inspector Name: John Crisp rmUCr090419085422 Insp Num: Permit Number: 195-181 -0 / Inspection Date• 4!18/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3R-25 Type Ill~• N TVD 395a IA 930 2000 1950 1940 ~ P T. 19s~sio TypeTest SPT Test psi 2000 ~ OA Interval REQvAR P/F P Tubing lozo tioo ~t~o itso NOteS: MITIA. 1 bbl pumped for test. No problems. obore Injector. M on (~ ~ ~ See ~~ ~ ~5~~ ,vl;i`J Cri~~t~4(yt~85~ j ~~+w.rd`~~ tip ~ .~ t~ rM1 ~ ~ ~ L~ ~6 Monday, Apri120, 2009 Page 1 of 1 • Conoco~illips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 10, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ^~' ~~® :l~ ~~ ;> ~ 2~)Og d~ (prjS. ~p171r~jSSlp/~ ~Tlp~'!p~-ag@ ~,,:-:~~~~~~.~AN ~ ~~ 2.0(3 Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we113R-25 (PTD 195-181 Sundry 307-050). The proactive surface casing excavation and inspection has been postponed. Anew 10-403 Sundry Approval '` application will be submitted if the work is rescheduled. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, MJ veland ConocoPhillips ~ Well Integrity Projects Supervisor Enclosures • ~ ~EI~ED STATE OF ALASKA ,~,~~ ~ ~~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO'~~ ~'~ ~ ~~~ :ans. Commiss;~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~~ 1~ ancel approv ork Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 195-181 / ' 3. Address: Stretigrephic ^ Service Q . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22622-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 52' 3R-25 - 8. Property Designation: ,~ ~g 10. Field/Pool(s): ADI„35923"~CLK 3573 ~¢vc_ 3sS'a23 /~/. /3 Kuparuk River Field / Kuparuk Oil Poof 11. Present Well Condition Summary: Total Depth measured 7310' feet true vertical 6941; feet Plugs (measured) Effective Depth measured 7310 feet Junk (measured) true vertical 6941 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 4161' 7-5/8" 4213' 4093' LINER 3252' 4-1/2" 7309' 6940' Perforation depth: Measured depth: 7030-7080' true vertical depth: 6675-6722' Tubing (size, grade, and measured depth} 4-1/2" , L-80, 4092' MD. Packers &SSSV (type & measured depth) pkr= BAKER'ZXP~ pkr- 40 57' SSSV=NIP SSSV= 489' 12. Stimulation or cement squeeze summary: y~ Intervals treated (measured) ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA - 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X -work canceled 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 307-050 Contact Loveland/Klein Printed Name MJ Loveland le Well Integrity Supervisor Signature ~ Phone 659-7043 Date ~ ~ L SAN ~. ~ Zoos yj~ ,,~ r.,3.~9 Form 10 4 Revised 04/2004 ~ ~~ « Submit Original Only 3R-25 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/10/2009 Surface casing inspection postponed until further notice. This 10-404 is to close 10-403 307- 050 Work not completed. MEMORANDUM • To: Jim Regg '~ I P.L Supervisor ~~~7~ , ~~l (l`~p FROIVt: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA NC 3R-2s KLPARUK RIV UNIT 3R-25 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: xUPARUx RIV UNIT 3R-2s Insp Num• mitRCN0809271917s2 Rel Insp Num: API Well Number: so-029-zz62z-oo-oo Permit Number: 19s-181-0 ~ Inspector Name• Bob Noble Inspection Date: 9/zs/2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3R-2s 'Type Inj. I W ~ TVD i 39sz ~ i IA 750 1700 i 1660 1660 ~ P.T.D~ 19s1810 ~TypeTest SPT Test psi 1700 'i OA ~ Interval RfiQVAR P/F P ~ Tubing j zz7s zz7s zz7s ~ zz7s ~ ~ Notes: Mono Bore Well ~ ~Y~~~ j } ` (',? ~., '°` '7 ~ J Wednesday, October O 1, 2008 Page 1 of 1 TO: Jim Regg P.I. Supervisor r-'i tl '/ ~::'1~i ! ! Î ( State of Alaska Alaska Oil and Gas Conservation comm. DATE: 1l1ursday, May 03, 2007 SUBJECT: Mechanical [ntegríty Tests CO\iOCOPHlLLIPS .^'-LASKA INC 3R-25 lVIE1VlUKAN DUM . FROM: Jeff Jones Petroleum Inspector KLP\RUK RlV L-'\iIT 3R-25 ~q~_I<Õ1 Reviewed Bv: >fz:,,..., P.I. Suprv. ¡T)ÿ Comm Src: Inspector NON-CONFIDENTIAL Permit Number: 195-181-0 Inspector Name: Jeff Jones Inspection Date: 4/30/2007 Well Name: KUPARUK RIV UNIT 3R-25 Insp Num: mitJJ0705021 04506 Rei Insp Num: API Well Number: 50-029-22622-00-00 Well ' 3R~25 ;Type Inj.: - NTTVD--;-;;-~-'------IA 140' _------L-_~~.~~_____~__~__~~ P.T.D, 1951810 'TypeTest , SPT I Test psi ; 101575 'OA ,', ~~___~. I L.......~_______~------r----~____~__L-_~~ Interval REQV AR P IF P Tubing, 925 3000 2940 2910 --"'''----- --~--------- ------- Notes: Monobore injector; MIT-T. 2 BBLS diesel pumped. 250 15 Min. 30 Min. 45 Min. 60 Min. -~---¡------ 250 250 Packer Depth Pretest Initial - ~.."" - " s~E.D MA'l () 9 2{)1J1 :'~:'''. '-:,,"~" ~~. . .. ..._:...1-.hÖ:.-....~ Thursday, May 03, 2007 Page 1 of I lVl~lVlUKANULJM . State of Alaska Alaska Oil and Gas Conservation comm. DATE: Thursday, May 03, 2007 SVBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ,\LASKi>, [}iC TO: Jim Regg P.I. Supervisor ,rî ( IAI'D) ;¡ , ., 3R-25 FROM: Jeff Jones Petroleum Inspector KLP.\RlTK RlV LNIT 3R-25 /\~ \ \ ~S Reviewed By':-"¡ P.I. Suprv .JJ5¡Z--- Comm Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 3R-25 Insp N urn: mitJJ0705021 05455 Rei Insp N urn: API Well Number: 50-029-22622-00-00 Permit Number: 195-181-0 Inspector Name: Jeff Jones Inspection Date: 4/30/2007 Packer Depth - ._~-~".--~" --~"---_. Well! 3R-25 ¡Type Inj. N, TVD ! 4063 I IA : C----------- , -----+-----~-c_______________! P.T.D¡ l~~~~ ¡TypeTest : SPT: Test psi! l500 OA! Interval REQV AR P¡F P ./ Tubing! Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _._~~-- I I I i .._- ! I 130 2510 ì 2480 , 2460 , ---...-----------¡- I .. I I I ! .-. 1000 1225 1250 1250 ----- ~- _~________L_.~.____~~~_.___.L~____ Notes: M1T-IA monobore injector. SCANNED MAY 0 9 2007 Thursday, May 03, 2007 Page 1 of I . . SARAH PALIN, GOVERNOR AI,A~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 {ó\ \~6' Re: Kuparuk River Field, Kuparuk River Oil Pool, 3R-25 Sundry Number: 307-050 SCANNED FEB 12 2007 Dear Mr. Dethlefs: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 6- day of February, 2007 Encl. . . Conoc;p.,illips Alaska RECEIVED etrð FEB 0 6 ¿DOl Alaska Oil & Gas COilS. CÎfmmissioo t.nchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 5, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we1l3R-25 (PTD 195-181) to excavate and inspect the casing for corrosion damage. Should damage be found, the casing will be repaired. Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, fk~{'~ Jerry Dethlefs Problem Well Supervisor Attachments P/":> . GPr2-"1"DJ . Y. -- RECEIVED STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION .., F 0 ( 2007 APPLICATION FOR SUNDRY APPROVAL "Alaska Oil & Gas Cons. Crnnmission 20 MC 25.280 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver ¡'H~orag2 Other D Alter casing D Repair well 0· Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 195-181 . 3. Address: Stratigraphic D Service 0 " 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22622-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes D No 0 3R-25 , 9. Property Designation: þ.".. ..,.01 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit .ÂÞl- ~-z.$ RKB 52' Kuparuk River Field / Kuparuk Oil Pool . 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7310' . 6941' I 7310 6941 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 4161' 7-518" 4213' 4093 LINER 3252' 4-1/2" 7309' 6940 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7030-7080' 6675-6722' 4-1/2" L-80 4092' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'ZXP' pkr= 4057' SSSV= NIP SSSV= 489' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 . 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 1 st half 2007 Oil D Gas D Plugged D Abandoned D 17. Verbal Approval: Date: WAG D GINJ D WINJ 0 . WDSPL D Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Jerry Dethlefs Printed Name ~ Dethlefs L j~ Title: Problem Well Supervisor Signature "4Ã:~ C . <----~ ~ Phone 659-7043 Date ¿;;<' / s-; {:? "/ .~ , ." Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness .~ J7- ()5() Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: <.c(~L\-'!: '-'~Q:.C\-cr-~ \~'>\><t.~-\- ~h.~~Cê. . ~ ~\~ ðcc..~\-\.L~~\-\()\'O~ c.. ~\ 't)0-""",,,-"::¥' I ~~~. ~ RBDMS BFl ¡ 2 1DOí s,""",ot Fo"" R',"m" í\Q W ~ ApP"WOO by, ' ~ CoMMISSIONER APPROVED BY Date: t.-g,~ THE COMMISSION Form 10-403 Revised 06/2006 0 RfG N A L ..q0 ~submit in Duplicate 7I~7 /I'Þ Z-7· 67 Ai . . ConocoPhillips Alaska, Inc. Kuparuk We1l3R-25 (PTD 195-181) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 5, 2007 This application for Sundry approval for Kuparuk well3R-25 is for inspection and possible ,,- repair ofthe surface casing due to corrosion. The well is a water injector, drilled and completed in 1995. This is a single casing well constructed similar to other wells that have been found to have surface casing damage due to corrosion. This request is for approval to excavate, inspect and repair if needed, before any leaks occur. - With approval, inspection and repair ofthe surface casing will require the following general steps: 1. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing to return the casing to operational integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-IA to verify integrity. 8. Install anti-corrosion coating on exposed surface casing. 9. Replace the conductor and top offvoid with cement and waterproof sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to water injection. 12. Submit 10-404 report of repair operations to AOGCC. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1 Report 3K-22 3R - 25 MTT 11 - Oct- 06 U:r.c. 1C\ 1- -O(oG:, -f!: 1 - Oct - 06 (AC" 10, 5" - ;:;;0 1) 2) 3) 4) 5) 6) 7) 1 Report MTT Print Name: íL-- c- ~\ \A P - mr\.kJv\./J\ Signed: Date : PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: .0J·V':.: ::;., ::":.:..:;;'3",:::: >:J"'j _:::;n~ ;'" WEBSITE: '/t,'¡',V.:Æ:"':::K'i:":JU.,::,;,n D,\OO _ PDSANC-2006\Z. W ord\Dis1nbutIon\Transmittal. Sheets\Transmit. Ongmal.doc I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3R-25 Log Date: October 11, 2006 Field: Kuparuk Log No. : 8056 State: Alaska Run No.: 1 API No.: 50-029-22622-00 Pipe1 Desc.: 4.5" 12.6 Ib L-BO NSCT Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 191 Ft. (MD) Pipe2 Desc.: 7.625" 29.71b L-80 Top Log I ntvl.: Surface Pipe2 Use: Surface Casing Bot. Log Intvl.: 191 Ft. (MD) Pipe3 Desc.: 16" 62.50 Ib H-40 Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Suñace Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 4.5" tubing and 7.625" surface casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 4.5" tubing, 7.625" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 191'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 3% circumferential metal loss is recorded in the interval between 38' - 45'. No other apparent metal loss is recorded in the interval logged. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 4.5",7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 16" conductor. I Field Engineer: R. Richey Witness: C. Fitzpatrick I Analyst: M. Tahtouh & J. Burton F~"n;"¡' Pf-.Y:'::::Ö·.,rner-n, on/·i!"]c·)· rnnRECE IVED ~. ,"-"'" . --, '-"','-" - Þ'- ,_, '""'.," "'.....' -. -., Fax: 659--2.314 - UId.-t~ 6 -/ "ð I NOV 0 3 2006 Alaska 011 & Gas Cons. Commission Anchorage I I I I I I I I I I I I I I I I I I I ~ Magnetic Thickness To og (8Hz Pass) PROActivE DIAqNQ!;f;C SERvicES, INC. Database Fìle: d: \warrìor\data \3r - 25\3r -25. db Dataset Pathname: 8Hz.1 Presentation Format: 22SCAL -1 Dataset Creation: Thu Oct 12 06:46:28 2006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 - 0 LSPD (ftlmìn) -200 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 ! Tree -. e 0 4.5" Coli Pup Jt -- Pup Jt. I f----- ~ 4.5" Collar~ 20 .. .. 4.5" f--.~ ~_.. -. ~- --- Joint 1 ..- b45" Collar I I 40 I I 3% Metal Loss I ..!. I--·T.... '-7. 625" Collar 4.5" Joint 2 -.- - 60 - ~ I ----- gS"COllar - _! Batt: Of-1~ ~nductor I!' j ¡::¡¡ ~ 80 - r-- 7- I r-- . ~. ~~ ·~I .~. _.~ -- ~f---_. ~ 0- I I 45" r II fl! I I I I I I I I I I I I I .. - ::;g::¡;: I I I int 3 ~ 7625" Collar l- I m-. ~ 1-, -~ 100 - .A.5" Collar -= -f-- - ,.....~ f-- -f-- f-- -f-- .~ r-- -c--- 4.5" I--- f-..:: ~ r-- I--- - f-- --- ~ Joint 4 - ~ 1-··- ,..... -.-- 120 .,¡ t= ~ r-- +-- .-- -- -- - =- 1- ~- ;: -I - ~ =7 625" Colla ~ . ~ I I I .,.1 1 ~c--- +-- 1- 4..5" Collar I ... I 140 !Í: ~ r-- , "'---- r-- .1' tl 4.5" 1 -. Joint 5 :~ {l . I ~ r-- .-- ) r--L- 1- .--- 160 ~ f r-- ~ ,.,. >- .5" Collar -- ~ f-- ^--~ f-- ?o- +-- t-- ~~ '- +-- I f--~~ ~ <····79 r::.. 7625", Collar_ ;:;. - ) f - 180 - 4..5" ¿.I - §;t Joint 6 - - End of Log .1 '-- - !'" 0 LSPD (ftlmin) -200 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickness To og (8Hz Pass) p~ ÐÎAq""""ic SERvlcð, INC. Database File: d\warrior\data\3r-25\top metal loss\3r-25.db Dataset Pathname: 8Hz. 1 Presentation Format: 22SCAL -1 Dataset Creation: Thu Oct 1206:46:282006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 160 10 - - .- LSPD (ftlmin) -200 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 =:: ~ LV ~:. c: # ~... -. .- # <; , .<:;. . ~. t p " I 4.5" I Joint 1 -} I : ðfrØ'·· I -l:- I < 30 '? " i I·¿ ; Ii" I)" .¿ .,; <: ~._j ,~ < ~ , sA - ".5" Collar ~ 40 ,{ < .~ ~...- ~. :> ~ I -=- ...r :S t# <;;;. I ¡....-7.625" Collar 1-== ¡.:::¡or , I I i I :? ¿ ~ <:: ~ { .¡:;; I. I 50 ~ ;?, ~þ. ~ ~ ;~; f---- . ...~ ,d-. . : 4.5" ~. þ.- I<~ ~) ¡ ~ Joint 2 -~ :: ~ I~ - r ~ ~ ;, 0 LSPD (ftlmin) ·200 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -66 MTTP12 (rad) 3.4 I I KRU 3R-25 INJ 7021 12/811995 I 7310 ftKB 26 de 4142 I Thread SLEEVE (4050-4051 , I 00:4.500) TUBING Ft SPF I (0-4092, 00:4.500, 50 4 10:3.833) PKR (4057-4058, I 00:7.000) Descri ticn II) 3.813 3.812 SEAL 5.750 I (4063-4064, 3.875 00:4.500) 4.892 4,750 3.833 3.833 I 3.725 I PBR I (4077-4078, 00:5.000) I SHOE (4092-4093, 00:7.000) I I Toe (5922-5923, 00:4.500) I NIP (6921-6922, I 00:4.500) Perf I (7030-7050) Perf I (7050-7080) I • FRAMK H. MURKOIMSKI, GOVERRIOR ~ ~~ ~1~L ~ 3 TM AATT~+ A ®1~s7~~~6~~®~ ~®~~~~~®~ 3 3 W. 7 AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907} 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPR®VAL AI® 2B.012 1~1r. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RE: Kuparuk River Unit 3R-25 (195-181) Request for Administrative Approval Dear NIr. Dethlefs: ~~jh. ~~ JAN ~ ~ 2QQ~ On May 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") 2B to allow continued water injection in Kuparuk River Unit ("KRU") well 3R-25. The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below. As constructed, KRI/ 3R-25 does not meet the requirements of 20 AAC 25.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length for possible leakage. Some 3600' of this w-ellbore cannot be monitored. Where fresh water is not affected, 20 AAC 25.450 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary authority and approved injection operations with the fluid limited to water only. CPAI has provided pressure test information, dated April 27, 2005, using water that demonstrates that the injection string (combination of tubing and liner) and the surface casing (the 7-5/8" casing above the packer) do have integrity. Accordingly, the Commission believes that the well's condition will not result in an increased risk of movement of fluids outside the injection zone. Per Rule 9 of Area Injection Order 2B, the Commission hereby grants CPAI's April 27, 2006 request to continue injection in KRU 3R-25 on the following conditions: 1. Injection is limited to V4'ATER ONLY; Administrative Approval AIO 2B.OI2 June 27, 2006 Page 2 of 2 2. CPAI shall monitor and record tubing, inner annulus pressures and injection rate daily; 3. CPAI shall submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; 4. CPAI shall perform a mechanical integrity Cest of the tubing ("v1IT-T") every 2 years with a plug set in the nipple profile at 6921' measured depth to demonstrate continued integrity- of the injection string; CPAI shall perform a mechanical integrity test of the inner annulus ("MIT- IA") every 2 years to demonstrate continued integrity of production casing; 6. CPAI shall immediately shut in the well and notify the Commission if there is any- change in the well's mechanical condition; and 7. After well shut in due to a change in the wen's mechanical condition, Commission approval shall be required to restart injection. 8. For administrative purposes, the MIT anniversary date is April 27, 2003. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 Pti1 on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ska and dated June 27, 2006. f / ~~ f ' - /..~ i' 1 Daniel T. Seamount, Jr. Commissioner ~1,,~~~. ,, . //~~ ? 3 \/ \~~ ~~ y~l-r' ~ - ~C ~...t ~'/' , %~ ~~~ :: " ~ ~ u ~ < ~ ! d a~.! Cathy ~'. Foerster Commissioner • Maunder, Thomas E (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs@conocophillips.com] Sent: Friday, September 23, 2005 4:41 PM To: Maunder, Thomas E (DOA) Cc: 'NSK Problem Well Supv' Subject: RE: Monobore Injection Wells Tom: To my knowledge you are correct. Since we recently "discovered" 2M-09A, I cannot guarantee there are not other anomalous wells out there we do not know about. But your list looks complete for the wells we do know about. Should we come across another in this situation you will be the first to know. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder [mailto:tom maunderCadmin.state.ak.us] Sent: Friday, September 23, 2005 9:22 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Monobore Injection Wells Jerry, et al: We are checking our records and wanted to confirm the wells that are monobores. There are various wells out there that have had the name "monobore" attached to them. For this message, monobore means a well that does not have a separate production casing set proximate to the injection horizon and the packer is set a significant distance above the zone. The first 4 wells on the list have the packers set in the surface casing. The wells on our "list" are: 3K-22 30-19 3Q-21 3R-25 -~~\~ and possi~y-~~09A 3H-lOB would also be on the list, converted. but it is a producer never having been Thanks in advance for your assistance. Tom Maunder, PE AOGCC 1 MEMORANDUM ) Jim Regg ~~ c:J1 5 II '6(0'6"" P.I. Supervisor { State of Alaska Alaska )nd Gas Conservation Commission DATE: Wednesday, May 18,2005 TO: NON-CONFIDENTIAL SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 KUPARUK RlV UNIT 3R-25 ,,{/\Cð \ /\(}.,? Src: Inspector FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UN1T 3R-25 Insp Num: mitCS050427172450 Rei Insp Num: MITOP000000600 API Well Number: 50-029-22622-00-00 Permit Number: 195-181-0 Inspector Name: Chuck Scheve Inspection Date 4/27/2005 Packer Well 3R-25 Type Inj. N TVD P.T.D 1951810 TypeTest SPT Test psi Depth 3952 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1500 IA OA o 1600 1550 1550 Interval Other (describe in nor..,,) Notes: This Well is a Monobore completion. A plug had been set in the tubing at 6921' and the top perfat 7030', PIF Pass Tubing 750 900 900 900 SCJ'\NNED MAY 3 1 2005 Wednesday, May 18,2005 Page I of I ) Alaska State of Alaska ~d Gas Conservation Commission MEMORANDUM DATE: Wednesday, May 18,2005 TO: Jim Regg 0 ( P.I. Supervisor ¡'\~q 6 ;'t/ Ctb Chuck Scheve Petroleum Inspector SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3R-25 KUPARUK RIV UNIT 3R-25 Src: Inspector \t(j\ \q-'Ç; ~ FROM: NON-CONFIDENTIAL Well Name: KUPARUK RIV UN1T 3R-25 Insp Num: mitCS050427171621 Rei Insp Num: MITOP000000599 API Well Number: 50-029-22622-00-00 Permit Number: 195-181-0 Inspector Name: Chuck Scheve Inspection Date 4/27/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3R-25 Type Inj. TVD 3952 IA 0 0 0 0 P. T.D 1951810 TypeTest SPT Test psi 3000 OA Interval Required by Variance PIF Pass Tubing 1100 3000 2925 2910 Notes: This Well is a Monobore completion. A plug had been set in the tubing at 6921' and the top perf at 7030'. The tubing was then pressure tesed. SCJ~NNEf) MAY ;t 1 20Œ"1 Wednesday, May 18,2005 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich ~'~ ~C~,\~S~UCommissioner DATEi April 29' 2003 ~,~1/~ BJECT. Mechanical Integrity Tests THRU: Tom Maunder Conoco\Phillips Petroleum Engineer 3-R pad 3R-25, PTD #195-1810 FROM: Lou Grimaldi KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I WellI3R-25 , I I Tubi,gl ,o 117so I lntervallV I P.T.D.I 1951810 ITypetestl P ITestpsil 1643 I CasinglVacuumlVacuumlVacuumlVacuumI P/F I PI Notes: Tubing test, WL plug set in nipple ~ 6921' MD. w~,,I 3R-~S I T~,e,.j.I N I T.V.D. I 6071 I Tubingl 6oo I 7oo I~o I~o I lntervall V P.T.D.I 1951810 ITypetestl P I TestpsiI 1518 ICasinglVacuurnI 1600I 1540I 15'3oI P/F I ~ Notes: Casing test performed after .above tubing test, tubing bled to 600. ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure'Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) I arrived 3R pad before the test crew and stood-byuntil they arrived. The test consisted of two parts, tubing integrity then IA integrity due to this being a monbore completion, above results showing good tubing and IA integrity. Note; the tubing had an mechanical plug set at 6921' RKB. 1750 psi on tubing prior to test. M.I.T.'s performed: Two Number of Failures: None Total Time during tests: 3 hours Attachments: cc: Jerry Detlefs MIT report form 5/12/00 L.G. MIT KRU 3R-25 04-29-03 LG.xIs 5/9/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder @ admin.state.ak, us and Bob_Fleckenstein @ admin.state.ak, us OPERATOR: FIELD ! UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. ,Kuparuk - KRU - 3R 04/29/03 APC - Sauva~leau Leu Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. I We"laR-2SI TypoI.j I ~ I T.V.D. I ~0~ I~'ub,ngl I I I I,.,erv~,l OI P.T.D. I1951810 Type Test Test psiI 150o I Casin~l I I I I I P/F Notes: 2-Year MITIA to existing packer (monobore completion) i g i i i I i,n o ,l.oI P.T.D. I1951810 Type Test Test psi I 1643 I Casin~l P/F Notes: 2-Year MITT to XN-Plug set at 6921' MD, 6571' TVD. T.V.D. Intervall IP/F Notes: T.V.D. Intervall ]P/F Notes: WellI T.V.D. Interval P.T.D.I P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3R-25 04-29-03.xls 4/29/2003 A Subsidiary of PHILLIPS PETROLEUM COMPANY 0D:4.500) (O-4092, 0D:4.500, ID:3.833) (4050-4051, OD:4.500) PKR (4057-4058, OD:7.000) SEAL (4~, OD:4.500) (4069-4070, OD:6.375) PBR ~ (4077-4078, OD:5.000) SHOE (4092-4093, OD:7.000) TOC (5922-5923, 0D:4.500) NIP (6921-6922, 0D:4.500) Perf (7030-7050) Perf (705O-7080) KRU 3R-25 API:J 500292262200 J ' Well Type: J lNJ Angle (~ TS:118 de~:j ~ 7021 SSS¥ Type: NIPPLE I Angle ~ 18 Odg Completion: J 12/8/1995 TD:J deg @ 7310 Annular Fluid: J Last W/O: Rev Reason: J Pull XN Plug 4/15/01 R ere ~.~a~.~ 'TL~~1 R.o..f_L__og_ .D...~.t.e = = I by ImO _¥_7.~"~'-~'1~' -_ ..' TD: 7310 ftKB Last Update: ! 1;18/2002 .._.L._ast Tag Date:1101312000 , Max Hoi~-A..__n~i~:~26 deg @ 4142 ' C...asing String-_ALL STRINGS Description , Size Top [- Bottom · TVD : Wt Grade Thread - oo. o o. .000 0 SUR. CASING 7.625 0 LINER 41500 .4._.057 |_7309 I 6940 I 12.60I L-80 I iTubing String - TUBING Size Top ..... I.._Bottom 4.500 0 4092 Perforations Sum.mary 'rVD ~ Wt I Grade~ Thread , 3984 : 12.60 L-80 NSCT -- Interval I TVD Zone · StatusI Ft SPF Date 7030 - 7080 i' 66~§ - ~72'2---'j - A-~,~,-'I i J 50 4 ' 1/22/1996, ,PERF Other {plu§s, 'equip., etc, Depth J'l'VD J Type Description 489 J 489 J NIP Otis 'X' Nipple 4050 J 3946 J SLEEVE Baker Sliding Sleeve w/Selective Profile 4057 J 3952 J PKR Baker'ZXP' 4063 J 3958 J SEAL Baker'GBH-22S' SEAL ASSEMBLY 4069 J 3963 J HNGR Baker'HMC'Uner HNGR 4077 J 3970 J PBR Baker 4092 J 3984 J SHOE MULE SHOE TUBING TAIL 5922 J 5644 J Top of Casing 6921 J 6571 J Otis 'XN' NO GO NIPPLE Comment 180 deg ph; oriented 45 decj j j j CCW & 135 dog; 3-3/8" BH Csg Gun -'JEWELRY ".~" :'" ' ':= '" .... "" ' "' ':: .... '"' .... ::"' ":-DI 3.813 3.812 5.750 TOC NIP General .Ni~te's ' ~.,..'. Date Note 12/9/2001 WAIVERED WELL - Monobore completion; water-only injection. 3.875 4.892 4.750 3.833 3.833 3.725 PHILLIPS Alaska, Inc. ! 'PARUK RIVER UNIT WELL SERVICE REPORT 3R-25(4-1)) WELL 3R-25 DATE 04/26/03 JOB SCOPE STATE TESTING{240) DAILY WORK SET XN PLUG DAY OPERATION COMPLETE 1 ('~ Yes ~ No FIELD ESTIMATE JOB NUMBER 0405030906.2 UNIT NUMBER 356 10026759 I SUCCESSFUL I KEY PERSON ~ Yes ~'~ No HES-HANSEN 10028957 $5,313 $5,313 ,nitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA I'l-I'LSize IMinlD 2700PSII 2900PSII 200PSI 200PSI 0PSII 0PSII 0.000 " 0.000 " SUPERVISOR FITZPATRICK Signed Depth OFT DAILY SUMMARY GAUGED TBG TO 3.40" & TAGGED FILL @ 7195' RKB, EST. 115' RATHOLE. SET & TESTED 3.81" XN-PLUG @ 6921' RKB. READY FOR STATE MIT. [Open-Close A Sand] TIME LOG ENTRY 06:00 WEEKLY SAFETY MTG W/CWG SUPV. 07:30 CONFER W/CWG SUPV, TRAVEL TO LOCATION 08:30 MI-TGSM-RU HES, W/L EQUIPMENT 1.875" TOOL STRING, RS.QC.5'.KJ.5'.KJ.QC.LSS.QC. 09:00 LRS ON LOCATION RU-EQUIP PT 3000 PSI GOOD, DISPL TBG 20 BBL DSL, RIG LRS DOWN LOAD UP W/20 BBL METHANOL 10:00 RIH-W/3.40" GAUGE RING, TAGGED FILL @ 7174' WLM, 7195' RKB, EST. 115' RAT HOLE, POOH 11:30 STAND BY FOR DSO TO DISPL FLOWLINE W/METHANOL 12:00 LRS ON LOCATION RU, IN MANIFOLD BUILDING, 13:00 DSO LOCATION, LRS DISLPACING FLOWLINE 13:30 RIH-W/4.5" X-LINE + 3.81" XN-PLUG, SET @ 6900' WLM 6921' RKB, POOH 15:00 PRESSURE TEST TBG TO 3500 PSI GOOD TEST, BLED TBG DOWN TO 2700 PSI GOOD TEST. 15:30 BEGIN RIGGING EQUIP DOWN. 16:00 FINISH IFluid summary DISPL FLOWLINE W/20 BBL METHANOL, DISPL TBG 50 BBL DSL. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $120.00 $120.00 FWX $250.00 S250.00 HALLI BURTON $2,861.50 $2,861.50 HES-SAFETY $332.00 $;332.00 LITTLE RED $1,750.00 $1,750.00 'TOTAL FIELD ESTIMATE $5,313.50 $5,313.50 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Tesl E-Mail to; Tom_Maunder@ admin.state.ak.us and Bob_Fleckenstein@ admin.state.ak.us OPERATOR: Phillips Alaska, Inc. FIELD ! UNIT ! PAD: Kuparuk / GKA /3R DATE: 4/14/2001 .~.:...::PERMIT:':=.':.:.=.:?........_....... = .. ~"'..:.;:;.~ ..:...'": ~:"~":' '.":' PRETEST START 15 MIN 30 MIN ' = ..: 'N U'MBER :~.~.:=!:=! :=.:.::=.!' ':;;T'~i~.i!: TYPE PACKER REQ TBG TIME TIME TIME i'.=:'::'&'"=':'i':".:"::.':';i:i=::.'='.''-'' ''=' :':'i:::=.iN'~i!:i::.i' -"'="' TEST ANN. TVD CASING TBG TEST CSG TaG TBG TaG START ': 'i... 'ii!'WE=.LL.i=~.':.:=..::i:'=:.? :.EE'...:U.!D. TYP. FLUID MD SIZE I WT ! GRADE SIZE PRESS PRESS CSG CSG CSG TIME "" . =': NUM.~.ER .:."".' :.i'. PTD: 1951810 S P D'SL" 3,9~2 7'5/8;'/2917/L-80 4.5"" 988 2,650 2,800 2,800 2,770 15:00 r~l r-1 Well #: 3R-25 4,057 0 1,600 1,560 1,500 COMMENTS: 2-Year MITIA to existing packer (monobore complettion) · Well #: 3R-25 4,057 0 100 125 125 COMMENTS: 2-Year MI7-I-monobore injector. MIT tubing with plug set in the nipple at 6921' MD, 6571' TVD. . ~e",~: I I I I I1°1 I I I I I~1~ COMMENTS: ~:,::: COMMENTS: ~"e,~:: I I I I I I°1 I I I I I~1~' COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig- Well File c - Operator c- Database c - Trip Rpt File c- Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 6.8 O. 35 0.00 8.5 0.44 0.00 0.00 WELL TEST: Initial 4 - Year Workover Other X OPERATOR REP SIGNATURE: Peter Nezaticky , AOGCC REP SIGNATURE: JeffJones MIT KRU 3R-25 04-14-01.:xls (Rev 9/23/99) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Pedorale _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1914' FNL, 2862' FEL, Sec. 9, T13N, R9E, UM At top of productive interval At effective depth At total depth 2507' FNL, 4578' FEL, Sec. 9, T13N, R9E, UM 5. Type of Well: Development __ Exploratory __ Stratigraph ic _ Service__X (asp's 520724, 6031446) (asp's 519010, 6030849) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3R-25 9. Permit number / approval number 195-181 10. APl number 50-029-22622 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SUR. CASING 4161' LINER 3252' Size 16" 7-5/8" 4-1/2" 7310 6941 7178 6815 feet Plugs (measured) feet feet Junk (measured) feet Cemented 200 sx AS I 750 sx AS III, 280 sx Class G 280 sx Class G Measured Depth 121' 4213' 7309' 6940' True verticalDepth 121' 4093' Perforation depth: measured 7030'-7080' true vertical 6675'-6722' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 4092' MD. BAKER 'ZXP' @ 4057' MD. OTIS 'X' @ 489' MD. RECEIVED JUN 27 2001 Alaska 0il & (;as Cons. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation June 11,2001 6/11/Ol Date approved 16. If proposal was verbally approved Tom Maunder Name of approver 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water Iniector 17. I hereby certify_ that the foregoing is true and correct to the best of my knowledge. Questions? Call Jerry Dethlefs 659-7224 Signed ~-.¢...¢.~~ ~_.~ (.._~~ Title: Problem Well Supervisor Date Je~'fd C. Dethlefs ~'~ Prepared b~' Sharon Al/sup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval Location clearance_ - I Plug integrity__ .i~OP Test __ . ri°' ,"~O/ Mechanical !ntegrity Test ~' Subsequent form required 10- ~'~ "~ , Approved by order of the Com~sion .,-- Ul~g~¢~;~. ~, Commissioner Date Form 10-403 Rev 06/15/88 * Return to: Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3R-25 SUNDRY NOTICE 10-403 VARIANCE REQUEST 06/23/01 The purpose of this Sundry Notice variance request is to clarify Mechanical Integrity Test (MIT) requirements for the 3R-25 monobore completion. The requirements were determined in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 2001. These terms modify and supersede the conditions sent in a letter to ARCO Alaska, Inc., from the AOGCC (Blair WondzelI) dated May 2, 1997. Kuparuk well 3R-25 is a monobore injection well classified as a "failed Mil" due to the construction of the wellbore (i.e., the packer is not set within 200' of the perforations). Extensive portions of the casing/tubing cannot be monitored from the surface so communication or leak problems may go undetected. The well passed an AOGCC witnessed MITT / MITIA 04/14/01 against a wireline-set plug in the landing nipple @ 6921' md. ACTION PLAN From this date forward 3R-25 will be subject to the following requirements: o 3. The MIT-tubing requires a tubing plug set in the existing landing nipple @ 6921' md. 4. Perform an MIT-IA to a minimum of 1500 psi to the existing packer @ 4057' md. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well and notify the AOGCC should MITs or injection rates and pressures indicate further problems; 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. The well will be used for water injection only (no gas injection is allowed); Perform an MIT-tubing every 2-years subject to standard test criteria ( 0.25 x tvd @ or 1500 psi ~nimum, wNchever is Ngher); NSK Problem Well Supervisor 06/23/01 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY NIP (489-490, OD:4.500) TUBING (0-4092, 0D:4.500, ID:3.833) SLEEVE (4050-4051, 0D:4.500) PKR -- (4057-4058, OD:7.000) SEAL -- (4063-4O64, OD:4.500) HNGR -- (4069.4070, 0D:6.375) PBR -- (4077-4078, OD:5.000) SHOE -- (4092-4093, OD:7.000) TOC (5922-5923, 0D:4.500) NIF (6921-6922, 0D:4.500) Perf (7030-7050) Per[ (7050-7080) KRU 3R-25 APl: 500292262200 SSSV Type:! NIPPLE Annular Fluid: ~ Reference Log:i Well Type: ~ INJ [ Odg Completion:~ 12/8/95 Last W/O:i i Ref Log Date:l Angle @ TS: 18 de~g_~ 7021 Angle ~ TD: 18 deg @ 7310 Rev Reason:: Set XN plug by ImO Last Update: :4/13/01 Last Tag: i 7178' WLM Last Tag Date:i 10/3/00 ~ Ca~in~ String; AELSTRINGS TD:17310 ftKB Max Hole Angle:i 26 deg @ 4142 i Description i Size Top i Bottom TVD Wt o Grade! Thread H-40 CONDUCTOR i 16.000 : 121 121 ' 62.50 SUR. CASING i 7.625 0 4213 4093 ' 29.70 L-80 :__ 4057 7309 6940 ; 12.60 L-80 ' 'FVD : Wt , Grade Thread LINER ! 4.500 Tdbingstring~TUBING: i: Size :~ Top ', Bottom 4.500 i 0 i 4092 3984 12.60 ~ L-80 NSCT i Perforations Sum~a~; ::: : Interval 703o-7o80 'rVD i Zone Status=: Ft iSPF'r Date 6675-6722 : A-2,A-1 ~ : 50 i ' : ! 4 . 1/22/96 Type Comment ' IPERF ~ 180 deg ph; odented 45 deg J CCW & 135 deg; 3-3/8" BH i Csg Gun iiOthe~: plugs;iequip;; etc.), JEWELRY Depth 489 4O5O 4057 4063 4069 4O77 4O92 5922 6921 TVD 489 3946 3952 3958 3963 3970 3984 5644 6571 Type NIP SLEEVE PKR SEAL HNGR PBR SHOE TOC NIP Description Otis 'X' Nipple Baker Sliding Sleeve w/Selective Profile Baker 'ZXP' Baker 'GBH-22S' SEAL ASSEMBLY Baker 'HMC' Liner HNGR Baker MULE SHOE TUBING TAIL Top of Casing Otis 'XN' NO GO NIPPLE - SET 3.813" XN PLUG 4/13/01 3.813 3.812 5.750 3.875 4.892 4.750 3.833 3.833 3.725 MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas COnservation Commission Julie Heusser ~,;'~ DATE: April 14, 2001 Commissioner I SUBJECT: Mechanical Integrity Tests Tom Maunder /~L/~ ~ Phillips Alaska Inc. P.I. Supervisorf~J~'''- ~ [~..~Dx. 3R Pad 3R-25 Jeff Jones KRU Petroleum Inspector KRF NON- CONFIDENTIAL WellI 3R-25 ' P.T.D.I 1951810 Notes: WellI 3R-25 P.T.D.I 1951810 Packer Depth Pretest Initial 15 Min. 30 Min. Typelnj.i S I T.V.D. ! 3952 I Tubingl 2650 I 2800 I 2800 I 2770 ]Interval[ 2' Type testI P I TestPsil 988 I Casingl zero 1160011560115501 P/F I P Type testI P I Testpsi] 988 I CasingI zero I 100 I 125 I 125 I P/FI P Notes: Well P.T.D. Notes: P.T.D. Notes: Well P.T.D. Notes: IType Inj. Type test IType I nj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard. Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Saturday, April 14, 2001: I traveled to PAl's Kuparuk River Field monobore well 3R-25 to witness a 2 year MIT. pete Netazicky was the PAl representative in charge of testing. The pretest pressures were observed to be stable and the MIT was performed in two steps. The casing was pressured up to 1600 psi and it passed the 30 minute pressure test. The casing was bled to zero and the tubing pressured up to 3350 psi and it passed the 30 minute test. The test data above indicates this well is suitable for continued injection. Summary: '1 witnessed a successful MIT on PAl's KRU monobore well 3R-25 in the Kuparuk River Field. M.I.T.'s performed: 2 Number of Failures: 0 Total Time during tests: 2 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT KRU 3R-25 4-14-01 JJ 6/9/01 ,3 e o ] o g 'i ¢: ,:~ 'l ivi a fi' e r' 'i ,:i~ '1 ::.: :i~ n v e il L (..~ r" "4 9 5 ...... i 8 i ? ''~:.-_ 0 ~:,~, ~-T'"~A R C 5. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10059 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 9950'1 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR IVIWD Tape 3~6~96 3Q-21 96046 ARc5 960103 i i.................. 1 3Q.21 .... 96~46 A'~c 5 TVD .... 960103 I 1...... 3R-25 95407 ARC 5 951203 I I1 ....... SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ,,-~ ~,,,~; ~, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 29, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3R-25 (Permit No. 95-181) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 3R- 25. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad ORISlNA£ 10/24/O0 NO. 633 SchlL.: .... :-r~=j: ~' ':' ,c:' ..: .'; ,'.~;: :: . :tio:-~. by a.'~d through is Geoquest Division 3940.',:, ,ic ,~vd,~:'c.'"~'-. Anch,~ ,_-,;~,~, ','X ~',;:: ::'~:7 .'~ ATT;I: Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk ~'.)i;~ ?ROFILE 001009 I ' -._~..)r~;~' ,, . . -- Color .; ::... Log Description Date BL ,,m~L_ 3ia j Print I{I:LEIVED DATE: 3CT 3 1 nn. Alaska Oil & Gas Cons. Commi~_0m :! :._- ::~ns~:fi~tal to $1]errie at the above address or fax to (907) 561-8317A~l13'~u. SENT BY :ARCO AI_ASKA ; $- 1-99 ; ;3: §lPlg ; KPS/WELLS/CNST/PROJ-+ 907 276 7,542; # 1/ 8 ARCO Alaska, Inc. Kuparuk Opsrations Post Offiae Box 196106 Anchorage, Alaska 99B19-6105 3R-2G Monitoring Repod O T CHOKE N A OR DATE E T % . ---- $I DATA GAS WATER GAS C 7' 10" LIFT INJ INJ H M 0 AMB CSG CSG VOL VOL VOL R I D FTP FTT ~EMP PSI PSI MSCF ~BLS MMSCF S N E 04/01 A SW 100 2836 60 -21 450 2837 0.000 0000 0 04/02 A SW 100 2828 61. -13 450 0 04/03 A SW 100 2821 61 -8 450 0 04/04 A SW 100 2819 61 -11 450 0 04/05 A SW 100 2818 58 -9 450 0 04/06 A S'W 100 2824 57 -4 250 0 0 2776 0.000 0000 0 0 2777 0,000 0000 0 0 2670 0-000 0000 0 0 2792 0,000 0000 0 0 2830 0,000 0000 0 04/07 A S'W 100 2828 64 2 250 0 04/08 A SW 100 2829 65 I 250 0 04/09 A SW 100 2832 65 -5 250 0 04/10 A SW 100 2834 63 -9 250 0 04/11 A SW 100 2835 62 -8 250 0 0 2830 0.000 0000 0 0 2829 0.000 0000 0 0 2847 0,000 0000 0 0 2840 0.000 0000 0 0 2837 0.000 0000 04/12 A Sw 100 2833 B1 -10 250 0 04/13 A SW 100 2931 61 -16 250 0 04/14 A SW 100 2817 61 -13 250 0 04/15 A SW 100 2038 60 -6 250 0 04/16 A SW 100 2637 61 2 Z50 0 0 2842 0.000 0000 0 0 2830 0,000 0000 0 0 2797 0_000 0000 0 0 2940 0.000 0000 0 0 2817 0.O00 0000 0 04/17 A SW 1.00 2781 6& 6 250 0 04/18 A SW 100 2820 65 ]]. 250 0 04/19 A SW 100 2822 61 8 250 0 04/20 A SW 100 2817 58 8 250 0 04/21 A SW 100 2817 62 3 250 0 0 2586 0.000 0000 0 0 2862 0.000 0000 0 0 2843 0.000 0000 0 0 2827 O.O00 0000 0 0 2814 0.000 0000 0 04/22 A SW 100 2821 65 -6 250 0 04/23 A SW 100 2822 63 -4 250 0 04/24 A SW 100 2822 65 -7 2~0 0 04/25 A SW 100 2814 65 -5 250 0 04/26 A SW 100 2810 64 -6 250 0 0 2833 0.000 0000 0 0 2822 0.000 0000 0 0 2813 0.000 0000 0 0 2736 0,000 0000 0 0 2750 0.000 0000 0 04/27 A SW 100 2808 62 -4 250 0 04/28 A SW 100 2802 62 0 250 0 04/29 A SW 100 2801 62 3 250 0 04/30 A SW 100 2791 64 19 250 0 0 2764 0.000 0000 0 0 2743 0.000 0000 0 0 2746 0.000 0000 0 0 2688 0~000 0000 0 ARCO ~a~. In0. la a Su~i~y of ~lanll~ Rl~fl~ C~y SCANNED .SENT BY: ARCO ALASKA ; ~-0-99 ; 9:01Alii ; KPS/WEII.S/CNST/PROJ-, ARCO Alaska, Inc. Kuparuk Operations Post Olfice Box 196105 Anchorage, Alaska 99519-6105 3R-25 Monitoring Report O T CHOKE DATE E T SI DATA GAR WATF~ GA~ C 7" 10" LIFT INJ INJ H ~ O A~B C~G CSG VOL VOL VOL ~. I D FTP FTT TEHP PSI PSI MSCF ~85~ H-/vISCF S N E 02/01 A SW 100 2812 58 -38 200 0 02/02 A SW 100 2827 57 -33 300 0 02103 A SW 100 2830 57 -23 300 0 02/04 A SW 100 2833 57 -30 300 0 0 2881 0.000 0000 0 0 3701 0.000 0000 0 0 3211 0,000 0000 0 0 3216 0,000 0000 0 02/05 A SW 100 2819 58 ...35 300 0 02/06 A SW 100 2721 58 -36 300 02/07 A SW 100 2829 57 -31 300 0 02/08 A SW 100 2833 56 -38 300 0 02/09 A SW 100 2836 56 -45 300 0 02/10 A SW 100 2816 56 -43 300 0 02/11 A SW 100 2836 57 -24 300 0 02/12 A SW 100 2831 60 -10 300 0 02113 A SW 100 2833 61 -15 200 0 02/14 A SW 100 2831 59 -15 200 0 0 3018 0,000 0000 0 0 2483 0,000 0000 0 0 3326 0,000 0000 0 0 3146 0.000 0000 0 0 3122 0,000 0000 0 0 2979 0,000 0000 0 0 3079 0,000 0000 0 0 3034 0,000 0000 0 O 3029 0,000 0000 0 0 3009 0,000 0000 0 02/15 A SW 100 2834 59 -19 200 0 02/16 A SW 100 2837 63 -15 200 0 02/17 A SW 100 2836 63 -17 200 O 02/18 A SW i00 2833 63 -4 200 0 (]2/1.9 A SW ],00 9826 63 -3 200 0 0 3035 0.000 OO00 0 0 3020 0,000 0000 0 0 3008 0.000 O000 0 0 2952 O.O00 0000 0 0 2981 0,000 0000 0 02/20 A SW 100 2842 63 -7 200 0 02/21 A SW 100 2830 62 -10 200 0 02/22 A SW 100 2840 59 -5 '350 0 02/23 A SW 100 2843 59 -13 350 0 02/24 A SW 100 2846 60 -14 350 0 0 3029 0.000 0000 0 0 2909 0.000 0000 0 0 2986 0,000 0000 0 0 2984 0.000 0000 0 0 2988 0.000 0000 0 02/25 A SW 100 2832 61 -6 350 0 02/26 A SW 100 2849 59 -10 350 0 02/27 A SW 100 2816 59 -10 350 0 02/28 A SW 100 2799 62 -16 350 0 0 2862 0,000 0000 0 0 2995 0.000 0000 0 0 2695 0.000 0000 0 0 2712 0.000 0000 0 RFCEIVED 0 9 1999 A,oO A~,~. ~.o. ~,, S.b.~,.~ o~ ~,,,~,~.,~,,,.,, 0.m,..~ Alaska OJ{ & Gas uoiis. U0~JssJ0~ Anch0mgo SCANNED DEC 1 9 2002 STATE OF ALASKA i-- ALAS,,A OIL AND GAS CONSERVATION COMMI, ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS r'~ SUSPENDED E~ ABANDONED [] SERVICE r~ Classification chan~led to Water Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-181 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22622 4 Location of well at surface 9 Unit or Lease Name 1920' FNL, 2419' FWL, Sec. 9, T13N, ROE, UM ?~ ;': -" :::. ~ !~:i :".'::i.'.'" .' Kuparuk River Unit AtTop Producing Interval .. ~.;: '::'. 10 Well Number 2505' FNL, 701 'FWL, SecO, T13N, ROE, UM ~ ~. ~. ;.~_- ' ......... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. RKB 41', Pad 11'J ADL 355023 ALK 3573 12 Date Spudded 13DateT. D. Reached 14 DateComp.,Susp. orAband. 115 Water Depth, ifoffshore 116 No. of Completions December 1,1995 December 5, 1995 22-Jan-96 (perrd) NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 7310' MD & 6941' TVD 7207' MD & 6843' TVD YES X~ NO L_JI NA feetUD =1380'ss APPROX 22 Type Electric or Other Logs Run ARC5/G R,G R/CC L/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WI' GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" +_200 sx AS I 7.625" 29.7# L-80 SURF. 4213' 9.875" 750 sx AS III Lead, 280 sx Class G Tail 4.5# 12.6# L-80 4057' 7309' 6.75" 280 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inlerval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 4092' 4077' (Top of PBR) 7030'-7080' MD 4 spf 6675'- 6722'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lift, etc.) I Injection well .,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ % .-~..;-.._~ -.~.,. ,-,,, ~,.:~,.:. ;: ';~ .."...~ ,~.~.~:.,~ 0 RIG IN A L 0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERS~ SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NNvlE Include interval tested, pressure data, all fluids recovered and gravity, , MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7021' 6666' Bottom Kuparuk C 7029' 6673' Top Kupark A 7029' 6673' Bottom Kupark A 7102' 6743' ~.-' - :-..?:, i: ~.~ .~ ii . . 31. LIST OF A%FACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL ~ate' 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 1 WELL:3R-25 RIG:PARKER 245 WELL ID: AK8389 AFC: AK8389 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ API NUMBER: 50-029-22622-00 OM 11/28/95 ( 1) TD' 121' ( 121) SUPV'RLM DAILY: 11/29/95 ( 2) TD: 121'( 0) SUPV:DCL DAILY' 11/30/95 ( 3) TD' 121'( 0) SUPV'DCL DAILY' 12/01/95 ( 4) TD: 121'( 0) SUPV'DCL DAILY: 12/02/95 ( 5) TD: 2930' (2809 SUPV:DCL DAILY: 12/03/95 ( 6) TD: 4228' (1298 SUPV:DCL DAILY: 12/04/95 ( 7) TD: 4238' ( 10 SUPV:DCL DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG MOVED CAMP TO CONSTRUCTION PAD BETWEEN 3R AND 3Q PADS. MOVED BALL MILL TO 3R PAD. PREPARED RIG FOR MOVE. DRILLING AND UTILITY MODULES CURRENTLY .75 MILES OFF 2X PAD HEADED TOWARDS SPINE ROAD. $135,185 CUM: $135,185 ETD: $0 EFC: $135,185 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Parked rig module at iQ turnoff due to wind. Utility module moving and located 1.2 miles past CPF-3. Plan to move utility module to location then return for rig module. $43,595 CUM: $178,780 ETD: $0 EFC: $178,780 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move utility and rig modules. (Wind died down. Started moving riag module at 0900 hfs) . Utility module arrived at Oliktok staging area at 1530 hrs. Rig module located approx 1 mi from staging area at 0600 hrs. $46,469 CUM: $225,249 ETD: $0 EFC: $225,249 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PU DP Finish move utility and rig modules to 3R-25. Accept rig at 1700 hfs 11/30/95. NU diverter system. Safety meeting. Function test diverter system. PU and stand back DP. $58,868 CUM: $284,117 ETD: $0 EFC: $284,117 MW: 10.0 PV/YP: 29/19 APIWL: 5.5 DRILLING Drilling from 121' to 2930' $106,589 CUM' $390,706 ETD' $0 EEC :.~.~,., .;,5! :~"-"$~90~._ ,706 MW' 10.2 PV/YP: 3.1:0{~T9''' AP~WL: 5.8 RIH WITH 7-5/8" CSG Drilling from 2930' to 4228't RU to run..g~.'- ..--~.x~pr'e'0~b ..... safety meeting. RIH with 7-5/8" csg. $76,226 CUM: $466,932 ETD: sq.,,s?c.~%~{illl..'~466,932 HW: 8.3 PV/YP: 2/ 1 APIWL: 20.0 PREP FOR FIT RIH with 7-5/8" casg. Pump cement. Test BOPE to 300/3000 psi. Test csg to 2000 psi for 30 min. Drill cement, FE, and 10' new form to 4238'. $193,242 CUM: $660,174 ETD: $0 EFC: $660,174 ~ate: 2/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 12/05/95 ( TD: 6451' (2213) SUPV:DCL DAILY: 12/06/95 ( 9) TD: 7310' ( 859} SUPV:rLM DAILY: 12/07/95 (10) TD: 7310' ( 0) SUPV:rLM DAILY: 12/08/95 ( 11) TD: 7310' ( 0) SUPV:RLM DAILY: 12/09/95 (12) TD: 7310' ( 0) SUPV:RLM DAILY: MW: 9.1 DRILLING Drilling from 4238' to 6451' $76,386 CUM: $736,560 ETD: PV/YP: 16/ 7 APIWL: 4.8 $0 EFC: $736,560 MW: 10.3 PV/YP: 22/11 APIWL: 5.0 RUNNING 4.5" LINER Directional drill 6.75" hole from 6451' to 7310' Run 4.5" liner. $130,795 CUM: $867,355 ETD: $0 EFC: $867,355 MW: 10.2 PV/YP: 24/12 APIWL: 5.2 MAKE UP BHA Cement 4.5" liner. CIP at 1615 hrs. 12/6/95. $144,458 CUM: $1,011,813 ETD: $0 EFC: $1,011,813 MW: 10.2 PV/YP: 24/12 APIWL: 5.2 CHANGE OVER TO SEA WATER RIH with 4-11/16" polishing mill to clean out obstruction in 4-3/4" ID PBR. Work mill in PBR and circ. POOH. RIH with seal assembly on completion string, still could not sting into PBR. POOH. RIH with 4-3/4" polishing mill and work into PBR and circ. POOH. RIH with seal assembly on completion string. $73,331 CUM: $1,085,144 ETD: $0 EFC: $1,085,144 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Freeze protect annulus. Set BOPE. Rig release 1800 hrs. 12/8/95. $20,875 CUM: $1,106,019 ETD: $0 EFC: $1,106,019 End of WellSummary for Well:AK8389 .,~CO Alaska, inc. WELL WELL 3R-25 DATE 01/22/96 DAY 1 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK PERF "A" SAND OPERATION COMPLETE YES DAILY SUMMARY KUPARUK RIVER UNIT SERVICE REPORT K1(3R-25(W4-6)) JOB NUMBER 12269,52203.2 UNIT NUMBER SUCCESSFUL I KEY PERSON SUPERVISOR YES S WS-WA R N E R C HAN EY "A" SAND PERF'D @ 7030' - 7080'. USED 50' OF 3-3/8" CASING GUNS - BIG HOLE CHGS - 4 SPF ORIENTATED 2 SPF 45 DEGREES CCW FROM THE HIGH SIDE OF HOLE AND 2 SPF 135 DEGREES CW FROM THE HIGH SIDE OF HOLE. WHTP DROPPED FROM 200 PSI TO 0 PSI AFTER PERFORATING. TIME 14:oo 15:3o 17:3o 18:15 LOG ENTRY MIRU SWS. HELD SAFETY MTG(POLAR BEAR AREA AND THERMAL EXPANSION PROBLEMS. ALSO 4 PEOPLE ON LOCATION) P~D TO 3500 PSI. RIH W/GR, CCL, 20' OF 3-3/8" CASING GUNS - BIG HOLE CHGS. - 2 SPF ORIENTATED 45 DEGREES CCW FROM THE HIGH SIDE OF HOLE AND 2 SPF 135 DEGREES CW FROM THE HIGH SIDE OF HOLE. DEPRESSURED WHTP TO 200 PSI. TIED IN AND PERF'D @ 7060'- 7080', WHTP DROPPED TO 150 PSI. POOH. OOH, WHTP HAD DROPPED TO 0 PSI. ALL SHOTS FIRED. RIH W/CCL AND 30' OF 3-3/8" CASING GUNS - BIG HOLE CHGS - 2 SPF ORIENTATED 45 DEGREES CCW FROM THE HIGH SIDE OF HOLE AND 2 SPF 135 DEGREES CW FROM THE HIGH SIDE OF HOLE. TIED IN AND PERF'D @ 7030' - 7O6O'. POOH. 19:30 OOH AND ALL SHOTS FIRED. 20:30 RDMO SWS, SECURED WELL AND NOTIFIED DSO OF STATUS. *********************************************************** ********* ********* ANADRILL ********** ********* SCHLUMBERGER ~********* ********* ~********* *********************************************************** APl# ~0 0~9 ~ AFE~ AK8389 *********** SURVEY ANALYSIS *********** COMPANY ARCO ALASKA, INC, W£LL NAME 3R-25 LOCATION ! KUPARUX LOCA?ION 2 ALASKA DATE: 01-DEC-95 MAGNETIC DECLINATION 27,~8 GRID WELL NUMBER 0 ************* ANADRILL ************** SURVEY ANALYSIS ************* CIRCULAR ARC METHOD******** MD TVD INC_CHG CUMIHC_CHG i_RA?£ AZM_CH~ CUMAZM_CH~ ?URH_RAT£ ft ft deg deo deg/lOOft deg de~ deg/lOOft CLDSUR~ TOOL FACE DLS DLSRT ft deq deg/lOOft deo/lOOft**2 i2!,0 121,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 467.4 467,42 0,83 0,83 0,24 !38.57 138,57 40,00 2,30 0,00 0,24 0,07 926,2 926,20 -0,37 0,47 -0,08 -i4,47 124,10 -3,15 6,82 162,80 0,09 0,03 !389,3 1389,25 0,87 1,34 0,19 143,65 267,75 31,02 6,86 152,7J 0,38 0,06 i654,3 1854,20 -0,42 0,92 -0,09 -121,25 146,50 -26,07 0,00 0,00 0,43 0,01 23!!,4 23!!,!7 1,37 2,2? 0,30 152,81 299,31 33,43 5,87 !60,49 0,69 0,06 2399,1 2398,79 0,0! 2,30 0,01 -38,70 260,61 -44,14 4,33 108,93 1,74 1,20 483,. 2483,17 O,~t 2,82 0,61 -27,18 233,43 -32,19 4,76 .91 O1 s,54 0,23 2585,3 2584,78 !,00 3,81 0,98 13,84 247,27 !3,60 5,88 45,.~)5 1025 0,29 2677,9 2676,83 4,21 8.03 4,55 ,,_0,71 257,98 .,i,57 ?.01 156,53 4,~9 3,72 2770,0 2767,41 4,70 !2,73 5,10 3,61 261,59 3,92 3,26 9,64 5,15 0,50 2860,9 2855,73 2,13 14,85 2,34 0.72 262,31 0,79 -0,35 4,89 2,34 3,08 2954,8 2945,92 2,49 17,34 2,65 -2,04 260,27 -2,17 -4,35 !3,78 2,71 0,39 3044,6 3031,03 2,26 19,59 2,51 -2,41 257,85 -2,69 -7,63 19,86 2,65 0,07 3230.3 3204,15 3,26 22,86 1,76 0,53 258,38 0,28 5,52 20,06 1076 0,48 3413.I 3371,40 1,95 24,80 1,07 -2,54 255,84 -1,39 -20,42 28,91 1,20 0,30 3692,3 3623.55 1,27 26.07 0,45 -3,77 252,07 -1,35 -23,65 53,59 0,74 0,17 3966,4 3870,71 -0,96 25,11 -0,35 -0,73 251,34 -0,27 -22,29 162,08 0,37 0,13 4142,2 402?,08 !,28 26,39 0,73 3,67 255,01 2,09 -23,42 52,94 1,16 0,45 4307,8 4178,71 -2,01 24,38 -1,21 -6,27 248,74 -3,79 -14,38 3,57 2,02 4589,5 4433,57 !,61 25,99 0,57 -3,09 245,65 -1,10 -12,05 40,70 0,74 0,46 4863,4 4679,74 0,09 26,08 0,03 5,85 251,50 2,13 -4,11 90,67 0,94 0,07 5!40,3 4930,~6 -2,43 23.65 -0,88 3,60 255,10 1,30 -5,82 149,66 1,03 0,03 54!8,7 5185,31 0,73 24,38 0,26 -7,41 247,69 -2,66 -3,79 79,80 1,11 0,03 5696,4 5437,85 0,45 24,83 0,16 -3,00 244,69 -!,08 -22,96 129,56 0,48 0,23 5969,5 5686,87 -1,20 23,63 -0,44 5,07 249,76 1,86 18,83 !22,27 0,88 0,15 6253,2 5~47,67 -0,88 22,75 -0,31 4,60 254,36 i,62 !9,5! 118,04 0,7! 0,06 4529,6 6203,66 -I,15 21,60 -0,42 -2,66 251,70 -0,96 18,25 !40,03 0,55 0,06 6902,0 6553,38 -3,00 18,60 -0,81 -6,40 245,30 -1,72 26,36 146,73 1,00 0,12 7219.4 8854,76 -0,63 17.97 -0,20 -i,99 243,31 -0,63 ~,68 7!,55 0,28 0,23 LAST SURVEY PROJSCTE~ TO T~ 7310,0 ~940,94 0.00 !7.97 0,00 0,00 243,31 0,00 44,71 90,05 0°03 0,27 I SURVEY' CALCULATION AND FIELD WORKSHEET Job No. 0450-73393 Sidetrack No. Page 1 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 3R/3R-#25 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. .a~ · ~a~l~ WELL DATA Target TVD (k-r) Target Goord. N/S Slot Coord. N/$ -1920.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Goord. E/W Slot Coord. E/W 2419.00 Magn. Declination 27.980 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: 100ft[~ :30m~ 10m~ Vert. Sec. Azim. 252.37 Magn. to Map Corr. 27.980 Map North to: OTHER ii i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ;[ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT O, ..,EC-95 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH lC-AKO-l.4deg. _ 01 -DEC-95 MWD 467.43 0.83 138.57 346.43 467.42 -1.01 -1.88 1.66 0.24 0.24 01 -DEC-95 MWD 926.24 0.47 124.10 458.81 926.20 -3.52 -5.43 5.42 0.09 -0.08 ., 01-DEC-95 MWD 1389.33 1,34 267.75 463,09 1389,25 0.53 -6.71 1.58 0.38 0.19 01-DEC-95 MWD 1854.32 0.92 146.50 464.99 1854.19 4.75 -10.03 -1.79 0.43 -0.09 ~.~.~.~ 02-DEC-95 MWD 2311.40 2.29 299.31 457.08 2311.1 8 9.98 -8.62 -7.73 0.69 0.30 ~?'-~ ................ 02-DEC-95 MWD 2399.08 2.30 260.61 87.58 21~q8.79 12.92 -8.05 -11.00 1.73 0.01 ~_.~ 02-DEC-95 MWD 2483.54 2.82 233.43 84.46 2483.17 ~ 6.58 -0.57 -14.34 1.54 0.62 ~:!~,:.::ii~ 02-DEC-95 MWD 2585.32 3.81 247.27 1 O1.78 2.584.78 22.30 -12.~ -10.47 1.24 0.07 '~ ........... 02-DEC-95 MWD 2677,88 8,03 257,98 92,56 2676,83 31,80 -14,90 -28.63 4,69 4,56 11,57-'~.~'~-- 02-DEC-95 MWD 2769,99 12,73 261,59 92.11 2767,41 48,23 -17,73 -44,97 5.15 5,10 3.92 ,..- ~- ~EC_95 MWD 2860.94 14.85 262.31 90.95 2855.73 69.60 -20.75 -66.44 2.34 2.33 0.79 ~'L~· ',, ~ ~lk ~_ ...... EC-95 MWD 2954.82 17.34 260.27 93.88 2945.92 95.31 -24.73 -92.15 2.72 2.65 -2.17 ~ 02-DEC-95 MWD 3044.55 19.59 257.85 89,73 3031,03 123.54 -30,15 -120.04 2.65 2.51 -2,70 02-DEC-95 MWD 3230.29 22.86 258.38 185.74 3204.15 190.43 -43.98 -185.84 1.76 1.76 0.29 02-DEC-95 MWD 3413.14 24.80 255.84 182.85 3371.41 264.04 -60.51 -257.82 1.20 1.06 -1.39 -- ,,, 02-DEC-95 MWD 3692.35 26.07 252.07 279.21 3623.56 383.85 -93.73 -372.98 0.74 0.45 -1.35 ... 02-DEC-95 MWD 3966.40 25.11 251.34 274.05 3870.73 502.21 -130.87 -485.37 0.37 -0.35 -0.27 , _. 02-DEC-95 MWD 4142.22 26.39 255.01 175.82 4029.10 578.55 -152.92 -558.47 1.16 0.73 2.09 04-DEC-95 MWD 4307.82 24.38 .248.74 165.60 4178.7.3 649.44 -174.84 -625.89 2.03., -1.21 -3.79 4 3/4'MACH lXL-AKO-1.2deg. 04-DEC-95 MWD 4589.46 25.99 245.65 281.64 4433.60 768.76 -221.36 -736.29 0.74 0.57 -1.10 04-DEC-95 MWD 4863.38 26.08 251.50 273.92 4679.76 888.59 -265.22 -848.09 0.94 0.03 2.14 04-DEC-95 MWD 5140.27 23.65 255.10 276.89 4930.98 1004.94 -298.82 -959.50 1.03 -0.88 1.30 oNj&m SURVEY OALOULATI ND FIELD WORKSHEET Jo ,No.. 7 Sidetrack No. P,,ge 2 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 3R/3R-#25 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. J~Nl"r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1920.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL [~ SS[] Target Description Target Coord. E/W Slot Coord. E/W 2419.00 Magn. Declination 27.980 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: lOOft[~ 30m~ 1Omo Vert. Sec. Azim. 252.37 Magn. to Map Corr. 27.980 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT') (FI') (FT) (Per lO0 FT) Drop (-) Left (-) ~ ~EC-95 MWD 5418.66 24.38 247,69 278.39 5185.33 1118.01 -335.00 -1066.65 1.11 0.26 -2.66 4 3/4'MACH 1XL-AKO-1.2deg. 0-. ,,:0-95 MWD 5696.42 24.83 244.69 277.76 5437.88 1232.95 -381.70 -1172.41 0.48 0.16 -1.08 05-DEC-95 MWD 5969.47 23.63 249.76 273.05 5686.90 1344.45 -425.15 -1275.59 0.88 -0.44 1.86 . 05-DEC-95 MWD 6253.17 22.75 254.36 263.70 5947.69 1456.08 -459.61 -1 381.78 0.71 -0.31 1.62 05-DEC-95 MWD 6529.60 21.60 251.70 276.43 6203.68 1560.38 -489.99 -1481.56 0.55 -0.42 -0.96 05'DEC-95 MWD 6902.00 18.60 245.30 372.40 6553.40 1687.90 -536.35 -1600.64 1.00 -0.81 -1.72 05-DEC-95 MWD 7219.40 17.97 243.31 317.40 6854.78 1786.49 -579.50 -1690.37 0.28 -0.20 -0.63 05-DEC-95 MWD 7310.00 17.97 243.31 90.60 6940.96 1814.09 -592.05 -1715.34 0.00 0.00 0.00 PROJ-BHC @ 1814.64'@ 250.96deg --. ,,, _ ., ., , ICreoted by : jones iDote ptotted : 11-Dec-95 iPlot Reference is 2.5 Version jCoordlnote~s ore in feet referer~e slot j~25. iTrue Vedical Depths ore r~erence RKB (Porker ~245). --- Baker Hogh~ INTEO --- ARCO ALASKA, Inc. Structure : Pad 5R Well : 25 Field : Kuparuk River Unit Location : North Slope, Alaska 0 ,,~ 0 , Tie on 0 04 _ .. 4O0 _ C~ 800 _ 1600_ 2000_ 2400_ -+-- 3200_ - 3600_ 4000_ _ 4400_ _ 4800_ 5200_ 5600_ 6000 _ 6400_ 6800_ 7200 ,Kick off Point End of 7 5/8 Casing <-- West 1950 1800 1650 1500 1350 1200 1050 900 750 600 4-50 300 150 0 150 3R-25(8) 7-Nov-g5 I I I I I I I I I i I I I 400 0 400 800 1200 1600 2000 Scale 1 · 75,00 150 _ .. _ o ~ _ ~5o 0 c' 3aa I 450 [ V L600 750 section on 252.37 ~rzlmutl~ ~lth mference o.oo N, 0,00 £ from ARCO Alaska, Inc. Date: January 31, 1996 Transmittal #: 9327 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. q~- t~/, 3R-25 (CBT) Cement Bond Log ~-'--1~'7 3R-26 (CBT) Cement Bond Log Receipt .~ .~~~~ Acknowledge' 01/02/96 5400-7194 01/0~2/96 7700-8698 Date' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATe-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 .... '~"~'~- Oil & Gas Cons. .... TONY KNowLE$, GOVERNOR ALASKA OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 21, 1995 Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 3R-25 ARCO Alaska, Inc. Permit No: 95-181 Sur. Loc. 1920'FNL, 2419'FWL, Sec. 9, T13N, R9E, UM Btmhole Loc. 2492'FNL, 621'FWL, Sec. 9, T13N, R9E, 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. Chairman BY ORDER OF THE C ISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ~ ALASr,~ OIL AND GAS CONSERVATION COMMISSk.,. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry [-'] Deepen D Service [--] Development Gas D Single Zone X aultipleZone 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 11' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 355023, ALK 3573 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.O25) 1920' FNL, 2419' FWL, Sec. 9, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2454' FNL, 739' FWL, Sec. 9, T13N, R9E, UM 3R-25 #U-63061 0 At total depth 9. Approximate spud date Amount 2492' FNL, 621' FWL, Sec. 9, T13N, R9E, UM 1 1/24/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3R-17 7310' MD 621 ~ TD feet 24.4' ~ 0.0' MD feet 51 75 6899' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 2500' feet Maximum hole angle 25.4° Maximum surface 2428 psig At total depth (TVD) 3400 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Len~lth MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 41 72' 41' 41' 421 3' 41 02' 750 Sx Arcticset III & HF-ERW 280 Sx Class G 6.75" 4.5" 12.6# L-80 NSCT 3197' 4113' 4012' 7310' 6899' 280Sx ClassG Top 1000' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural i' Conductor ~,- '~ ~'~ Surface ~"' ' ~ ~-~ Intermediate Production ~'; ©\/ '! Liner Perforation depth: measured ~.,~$~-.,~ uh true vertical " 20. Attachments Filing fee X Property plat r'~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X TiCe vs depth plot ~] Refraction analysis [~ Seabed report [--~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoir~g is true and correct to the best of my knowledge Signed ¢r¢ .... ~, Title Drill Site Develop. Supv. Date ' ' [ ) / ~. Commission Use Only Permit Number ~-..~/~PI.o~'~- ..~ I Approval da~_ / ~ I See cover letter for ~'5'-/~/ IL~'~. 0 z ~'.- 2 ~,~-, 2 ~ I /I/~1 !~5 I other requirements Conditions of approval Samples required r-] Yes J~ No ~ud I~g required E~] Yes ,~ No Hydrogen sulfide measures ~] Yes D No Directional survey required ~ Yes D No Required working pressure for aOPE D 2M ~ 3M [-~ 5M D 1OM BI 15M Other: Origina~ Signed By David W. J0hnst0n by order of // Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3R-25 o , . Note: Note: 10. 11. 12. Note: 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,213')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing tp 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,310') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" liner on drillpipe, with 5-1/2" polished seal bore. Set liner hanger and liner-top packer with 100' of liner lap from the surface shoe. Release from liner. (See attached completion schematic.) Due to the long length of the liner, the cementing program is not designed to reach the liner lap but to extend 1000' above the top of the Kuparuk. If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Pressure test casing and liner-top packer to 3500 psi. Run 4-1/2" completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. Shut in and secure well. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. DRILLING FLUID PROGRAM Well 3R-25 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 1 5-40 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% 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- Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 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/ff. This shows that formation breakdown would occur before a surface pressure of 2,428 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3R-25 is 3R-17. As designed, the minimum distance between the two wells would be 24.4' @ surface. Annular Pumping Activities' Incidental fluids developed from drilling operations will be pumped down the nearest permitted disposal well, 3R-11, or hauled offsite to another permitted disposal well if needed. The tubing will be left with a non-freezing fluid during any extended shut down (> 4 hr)in pumping operations. The 3R-25 surface/production casing annulus will be filled with diesel after setting the 4-1/2" liner/tubing string and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons sufficient cement volume will be pumped during the production cement job to cover the formation. 3R-25 will not be permitted for annular pumping as the annular isolation packer does not allow for this operation. Drilling Area Risks: Risks in the 3R-25 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. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner 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 10.3 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" 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. Slimhole Monobore Injector KRU 3R-25 5,000 psi starting head / tubing head with metal - metal seal on'~-5/8" 16" Conductor Csg: -100' Profile @ 500' CAMCO DB Nipple ID 3.812" 4-1/2" Tieback NSCT L-80 from surface to top of Liner 7-5/8" -2500-4000' TVD Top of Cement Tubing Hanger w/BPV Profile Option of 4-1/2" on top with 4" below with AVA sleeve instead of a sliding sleeve? 4-1/2" Baker Sliding Sleeve (5.5"OD) with 3.812" "X" profile 4-1/2" Casing w/ 4-1/2" x 7-5/8" Liner Hanger and Liner Top Packer Profile for MIT Camco DB Nipple 3.75" 4-1/2" NSCT Gas Tight Connection L-80 from top of liner to TD A Sands 6 3/4" hole Perforate A sand with 3-3/8" BH casing guns, oriented, 180° phasing. 11/95 jtz ARC0 ALASKA, tnc., © u/3 700 _ 1050_ i 400 i ]750] 25002 3~50_ 3590_' 385o_i ¢2002 s25om 56OOJ 5950_' S!ructure : Pod 3R Well : 25 RKB ELEVATION: 52' Field : Kuporuk River Unit Location : bio,dh Slope, Alaska l SURFACE LOCATION: 1920' FNL, 2419' FWL SEC. 9, T15N, RgE <-- Wesf oo.oo 6500_' 2000 1800 1600 1400 1200 i 000 800 600 400 200 0 200 ~ ' ' I I I I t I ; I I I I I I I I I I I I 200 _ 200 B/ PERMAFROST ,'P/D = 1702 4OO -- ~ ,~ ;',.? '" / %' L ~:" "--~- ?~ TARGET,' LOCATION: KOP TVD=2500 TMD=2500 DEP=O "'~ 800 , 2454' Fi'IL, 739' FWL 5.0o '~,o 6.o0 T/ UGNU SNDS e SEC. 9. l~31'.,I, R9E moo TV0=2752 TM0=2733 DEP='~ 4 12.00 TARGET 15.00 BUILD 3 DEG / !00' TVD=6658 ~ 8.00 TD LOCATION: TM D = 7022 DEP=1763 2~.oo 2492' FNL, 621' FWL SOUTH '~ WEST 1680 24.oo EOC WD=5520 TMD=3345 DEP=185 SEC. 9, T13N. RgE T/ '6' SAK SNDS ~"-'L2=3452 T,MD=5494 DEP=245 ,, B/ w q_AA SNDS T',/0=3902 TMD=3992 DEP=462 7 5/8" CSG PT TVD=4i02 TMD=4213 DEP=557 S 72.37 DEG W .,, ,'g'u,~~ e-rw.- qo,z ~-.q~l~ 1763' (TO TARGET) \, \ ~¢,' . . ~, AVERAGE ANGLE ' ', 25.43 DEG .... ~' ' ' ~ / ., i ' "' '. '., ,, xx ~. ~t. _~1 , '/~, i,, D UNIT WD=6560 TMD=6935 OEP=' ~26 ., 6650_] ;~.,' KUP SNDS Tv'D=6718 TMD=7!~G 3E3=180! 7OO0~ 7350 ~ 35( O 8/ HRZ WD=5312 TMD=6661 0EP=~608 ~-: %'0=6422 TM0=5782 DEP=;6~C TARGET - ~/ C UNIT TVD=6638 TMD=7022 DEP=I763 ~.,' A UNIT %'u=6648 TMD=7033 :~EP=1768 TD - 1/2" CSG PT TVD=6899 TMD=7310 DEP=1887 Creoted t~ 'jones 350 700 ! 050 i ':90 : 750 21 O0 2450 ic,aie I : !75.00 Vertical Section on 252.57 azimuth with reference 0.00 N, 0.00 E from slot #25 For: D PETRASH Dote plotted : 7--NOv--9§ Plot Reference is 25 Version ~6. Coordinates ore in feet reference elo~ ~25. ~True Verlico~ Depths ore r~feret~e RKB (Porker #245). iCreoted by : jones For: D PETRASH ioe~e plotted : 7-Nov--95 jPIot Reference is 25 Version J6. jCoordlnates are in feet reference slot #25. iTrue Vertical Depths are reference RKB (Parker #245). 0 0 0 240 .. -8 200 ARCO ALASKA, Inc. Structure : Pod SR Well : 25 Field : Kup(~ruk River Unit Locotion : North Slope, Alosko ~= West ~co,~ ~. ~o.oo 520 480 440 4.00 ;360 ;320 280 240 200 160 120 80 40 0 40 80 120 280 I I I I I I I I I I I I I I I I I I I I I t I I I 160 2700 2500 5500 110 1300 120 8O 2700 53OO 1300 11oo 9OO 120 I I 160 20O 2500 2100 4700 2300 4100 2100 310( ~700 3300 47( 280 ¢) c) 24-O .. 200 0 160 120 8O 4O 0 40 0 80 ~ 12O I 160 I V 20O 240 280 320 360 4OO 440 48O 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 <-~ West ~ca,~ ~. ~o.oo _ 24O _ 280 5300 _ 32O 36O 4O0 _ 440 _ 480 } I [ .JPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 5 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. 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) 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. 6. 20"-2000 PSI ANNULAR PREVENTER. DKP 11/9/94 10. 12. 13. 14. 13 5/8" 5000 PSI. OP STACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUliC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BOq-i'OM PIPE RAMS. TEST BO'FrOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BliND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510~03¢.,0 Telephone 907 276 1215 November 9, 1995 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Permit to Drill for Slimhole Monobore Well KRU 3R-25 Dear Mr. Johnston: We are submitting a Permit to Drill for the first KRU monobore injector, 3R-25. This well will be drilled as a Kuparuk slimhole (9-7/8" surface hole and 6-3/4" production hole). Expected spud date is November 24, 1995. It is called a "monobore" because a 4-1/2" liner is cemented across the reservoir, with a 4-1/2" completion stung into a seal bore at the top of the liner. All injection fluids will be pumped down the 4-1/2" casing/tubing with no other mechanical barriers between the injected fluids and the formation. ARCO is pursuing the monobore concept in an effort to continue reducing development costs and therefore increase the amount of opportunities for adding proven reserves. The monobore injectors have several additional features over our standard slimhole designs to ensure mechanical integrity. The injectors will have gas-tight, metal-to- metal connections for all 4-1/2" casing/tubing. The wellhead has been upgraded to a metal-to-metal seal on the 7-5/8" surface casing, and the pressure rating has been increased to 5000 psi to accommodate high-pressure gas injection. MITs will be conducted by use of a nipple to provide a pressure test from surface to just above the injection zone; frequency will be per current injector requirements. Please note that the monobore wells will not be used for annular pumping operations as the annular isolation packer does not allow it. Jim Zernell and personnel from Pt. MacIntyre have opened discussions on monobore wells in the past, and Pt. Mac has recently completed a similar design to the Kuparuk monobore with injector P2-34. If you have any further questions or concerns on the design in general or this well in particular, please contact the Drilling Engineer, Denise Petrash at 263-4183; the Reservoir Engineer, Jim Zernell at 263-4107; or myself at 265-6206. cc: J. Zernell B. Wondzell AR3B-6003~93 Supervisor ATO-1278 AOGCC 'Anchorage 2,12-2,303 WELL PERMIT CHECKLIST ADMINISTRATION COMPANY INIT CLASS 1. 2. 3. 4. 5. 6. ~ 7. 8. 9. -- 10. Il. APPR /~ 12. · - Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropria%e bond in force ......... Permit can be issued without conservation order .... Permit can be issued without adminisr, rative approval. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... 15. Surface casing protects all known USDWs'. ....... 16. CMT vol adequate to circulate on conductor & surf cng. 17. CM~ vol adequate to tie-in long string to surf cng . . 18. CM~will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B'& permafrost.... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abnd~mnt 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 ~C~ psig.~ 27. Choke manifold complies w/A~I RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. .Is presence of H2S gas probable . . .. ......... PROGRAM: exp [] dev [] redrll [] .serv~ ///~ ON / OFF SHORE ~/~J GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB ~~ Comments/Instructions: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding informatiOn, information, of this. nature is accumulated at the end of the file under APPENDIXl .. No 'special'effort has been made to chronologically organize this category of information, ALASKA COMPUTING CENTER * SCHLUMBERGER * COMPANY NAME : ARCO ALASKA, INC. WELL NAME · 3R - 25 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA APl NUMBER : 50-029-22622-00 REFERENCE NO : 95407 Tape Verification Listinc oc~lumoerger Alaska Computind. Center 26-FEB-1997 10:44 **** REEL HEADER **** SERVICE NAME : EDIT DATE ' 97/02/26 ORIGIN : FLIC REEL NAME : 95407 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 3R-25, API #50-029-22622-00 *~ TAPE HEADER **~* SERVICE NAME : EDIT DATE ' 97/02/26 ORIGIN ' FLIC ~ITAPE NAME ' 95407 CONTINUATION # ' 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC., KUPARUK 3R-25, API #50-029-22622-00 TAPE HEADER KUP~RUK MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION' TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 3R - 25 500292262200 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 27-FEB-96 1ST STRING 2ND STRING 95407 KADRMAS MORRISON BIT RUN 2 BIT RUN 3 9 13N 9E 1920 2419 52.00 52.00 11.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4213.0 PAGE: Tape Verification r,,isting oc~lumoerger Alaska Computing Center 26-FEB-J997 t0:44 3RD STRING PRODUCTION STRING REMARKS: Well drilled 03-DEC through 05-DEC-95 with ARC5 only. Ail data was collected in a single bit run. No MAD data was collected. **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' 001C01 DATE · 97/02/26 MAX REC SIZE · 1024 FILE TYPE ' LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and cl~ppgd curves; DEPTH INCREMENT: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH all bit runs merged. STOP DEPTH MWD $ BASELINE CURVE SH BASEL 4169.0 7310.0 CURVE FOR SHIFTS: GR IFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH INE DEPTH MWD 88888.0 7153.0 7100.5 7050.5 7037.5 7009.5 6973.5 6942.0 6924.0 6887.5 6798.0 6667.0 6628.0 6616.0 65?6.5 6569.0 6509.0 6474.5 88888.5 7153.5 7100.0 7050.5 7037.0 7009.5 6973.5 6941.5 6924.0 6886.0 6796.5 6666.5 6627.5 6615.0 6576.0 6568.5 6507.0 6473.5 Tape Verificakion List$~g chlumberger Alaska Computing Center 26-FEB-1997 10-44 6434.0 6432.5 6407.0 6405.5 6386.5 6385.5 6316.0 6315.5 6239.5 6238.5 6130.5 6129.0 6113.0 6111 .5 6065.5 6063.5 5863.0 5861 .5 5836.5 5835.0 5741 .0 5740.5 5681 .5 5680.5 5644.5 5645.0 5601 .0 5602.0 5565.0 5569.0 5531 .5 5535.5 100.0 104.0 MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: BIT RUN NO. MERGE TOP MERGE BASE The depkh adjuskments shown above refleck the MWD GR ko the CBT GR loqged by SWS. Ail other MWD curves were carried with the GR. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 1 4 65 FT 15 66 68 16 66 1 Tape Verification Listing C~lumoerger Alaska Computing Center 26-FEB-1997 10:44 PAGE: TYPE REPR CODE VALUE 0 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 00 000 00 0 1 ] 1 4 68 ROP MWD F/HR 00 000 00 0 ] ] 1 4 68 ..FET MWD HR 00 000 00 0 1 1 1 4 68 CGR MWD GAPI 00 000 00 0 1 ] ] 4 68 GRCH MWD GAPI 00 000 00 0 ] ] 1 4 68 RPXX MWD OHMM 00 000 00 0 1 1 1 4 68 RPX MWD OHMM 00 000 00 0 ] ] ] 4 68 RPS MWD OHMM 00 000 00 0 I ] t 4 68 RPM MWD OHMM 00 000 00 0 ] ] 1 4 68 RPD MWD OHMM 00 000 00 0 ] 1 1 4 68 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 DATA DEPT. 7310.000 ROP.MWD 73.333 FET;MWD -999.250 GRCH.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPM.MWD -999.250 RPD.MWD -999.250 DEPT. 7000.000 ROP.MWD 27.]23 FET.MWD 0.547 GRCH.MWD 83.063 RPXX.MWD 2.738 RPX.MWD 2.736 RPM.MWD 2.742 RPD.MWD 2.774 DEPT. 6000.000 ROP.MWD 152.308 FET.MWD 0.225 GRCH.MWD 59.500 RPXX.MWD 3.422 RPX.MWD 3.255 RPM MWD 3.185 RPD.MWD 3.135 DEPT. 5000.000 ROP.MWD 76.154 FET.MWD 0.508 GRCH.MWD -999.250 RPXX.MWD 2.476 RPX.MWD 2.483 RPM.MWD 2.430 RPD.MWD 2.409 DEPT. 4176.000 ROP.MWD 180.000 FET.MWD 6.458 GRCH.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPM.MWD -999.250 RPD.MWD -999.250 GR.MWD RPS.MWD GR.MWD RPS.MWD GR.MWD RPS.MWD GR.MWD RPS.MWD GR.MWD RPS.MWD -999.250 -999.250 105.393 2.731 79.959 3.198 89.380 2.464 37.352 -999.250 ** END OF DATA ** ~l~6~r~r Alaska CompuE lng Center **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C0] DATE ' 97~02/26 MAX REC SIZE ' 10 4 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C0] DATE · 97/02/26 MAX REC SIZE - ]024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separake files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD $ LOG HEADER DATA DATE LOGGED' SOFTWARE' 4169.0 7310.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME)' TD DRILLER (FT): TOP LOG INTERVAL (FT}: BOTTOM LOG INTERVAL (FT) · BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 3-DEC-95 40B05 40B09 MEMORY 7310.0 4169.0 7310.0 80 18.0 26.4 TOOL NUMBER ARC-5 RESISTIVITY GR GAMMA RAY $ ARC5-475 SLIM1-A Schlumberger Alaska Compu ~ng Center F BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN]' DRILLERS CASING DEPTH{~T)- BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G)' MUD VISCOSITY (S)' MUD PH: MUD CHLORIDES (PPM)' FLUID LOSS (C3): . RESISTIVITY (OHMM} AT TEMPERATURE (DEGF)' MUD AT MEASURED TEMPERATURE (MT)' MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION TOOL STANDOFF /IN/- EWR FREQUENCY HZ (IN): REMARKS: DIST BIT TO RES: 42.6 FT. DIST BIT TO GR: 47.7 FT SOFTWARE' IDEAL40B03/SPM 40B05/ TS 40B]6?DH 40B09 LIS FORMAT DATA 6.750 4213.0 LiGNO GEL 10.20 42.0 IO.O 9.5 3.830 3.510 20000 55.0 55.0 mT ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 Schlumberger Alaska Computing Center TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 i SET TYPE - CHAN ** NAME DEPT SERV ID LW1 UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE T 00 000 00 0 2 1 1 4 68 HR 00 000 00 0 2 1 1 4 68 PROCESS (HEX) 0000000000 0000000000 ROP FET LW1 GR LW1 RPXX LW1 RPX LW1 RPS LW1 RPM LWi RPD LW1 HR 00 000 00 0 2 1 1 4 68 GAPI 00 000 00 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 OHMM 00 000 00 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. RPXX.LW1 RPD.LW1 DEPT. RPXX.LW1 RPD.LW1 DEPT. RPXX.LW1 RPD.LW1 DEPT. RPXX.LW1 RPD.LW1 DEPT. RPXX. LW 1 RPD. LW1 7309.500 ROP.LWl 73.333 FET.LW1 0.778 1 .871 RPX.LW1 1 .891 RPS.LW1 1 .915 1 .920 7000. 000 ROP. LW1 27 . 1 23 FET. LW1 0. 547 2.738 RPX. LW1 2.736 RPS.LW1 2.731 2.774 6000 . 000 ROP. LW1 1 52 . 308 FET. LW1 0 . 231 3 . 1 39 RPX. LWl 3 . 253 RPS. LWl 3 . 235 3.306 5000.000 ROP.LW1 132.000 FET.LW1 0.478 2.351 RPX.LWl 2.367 RPS.LW1 2.372 2.396 41 76. 000 ROP. LW1 1 80 . 000 FET. LW1 6 . 467 14.152 RPX. LW1 2.454 RPS .LW1 1 .570 0.732 GR. LW 1 RPM. LW 1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 90.480 1 .927 105.393 2.742 81 .041 3.214 93.556 2.379 42.209 1.154 END OF DATA ~ 'ra~e verlrlcaclon mls~ng Schlum erger Alaska Compucing Center **** FIT~m TRAILER ***~ FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 97/02/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER . DiT DATE · 97/02/26 /~.ORIGIN ' FLIC TAPE NAME ' 95407 CONTINUATION # ' PREVIOUS TAPE ' COMMENT ' ARCO ALASKA INC., KUPARUK 3R-25, API #50-029-22622-00 **** REEL TRAILER SERVICE NAME ' EDIT DATE · 97/02/26 ORIGIN : FLIC REEL NAME : 95407 CONTINUATION # : PREVIOUS REEL ' COMMENT ' ARCO ALASKA INC., KUPARUK 3R-25, API #50-0~9-22622-00