Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-209
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 24, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-16A KUPARUK RIV UNIT 1F-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2024 1F-16A 50-029-21029-01-00 201-209-0 W SPT 5114 2012090 3000 2429 2431 2415 2418 147 229 233 233 REQVAR P Kam StJohn 6/12/2024 MITIA to MAIP Per AIO 2C.018 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 1F-16A Inspection Date: Tubing OA Packer Depth 760 3320 3230 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240614074749 BBL Pumped:2.3 BBL Returned:2.1 Wednesday, July 24, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MITIA AIO 2C.018 James B. Regg Digitally signed by James B. Regg Date: 2024.07.24 14:32:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1F-16A KUPARUK RIV UNIT 1F-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1F-16A 50-029-21029-01-00 201-209-0 W SPT 5114 2012090 3000 2611 2589 2587 2623 201 308 310 308 REQVAR P Austin McLeod 6/6/2022 Two year IA to MAIP. AIO 2C.018. 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 1F-16A Inspection Date: Tubing OA Packer Depth 1100 3300 3220 3220IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220606192741 BBL Pumped:1.8 BBL Returned:1.8 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9IA James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:07:00 -08'00' Regg, James B (CED) From: Bixby, Brian D (CED) Sent: Thursday, December 10, 2020 8:37 AM I Qtc l 141 Zi) Zd To: G Scott Pfoff Cc: Regg, James B (CED) Subject: Emailing: 201209 Amaroq Deficiency Report.pdf Attachments: 201209 Amaroq Deficiency Report.pdf Scott, Please take care of the action items on this report and email pictures back to us. Josh did fine on the SVS testing but I would like to have seen a procedure. I verified the permit to drill numbers are correct on the two wells we tested but that was it. I'm sure Josh could have gotten a procedure but we were pressed for time as the pilot wanted to get out of there prior to the weather coming in. Thanks, Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.gov �,4 1 c« 1co(Ct(i Ciet-_l s CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Date:' 9]ZO zo PTD: Operator: A W�ACZO-1 � a ��� Type Inspection: ! 9 s -n -J ir Operator O Rep: _� Inspector. ��i Position: . Op. Phone: oozCorrect by (date): l,ojz Op. Email- Follow Up Req'd: Detailed Description of Deficiencies Date Corrected . p ^� �Pe_ek;' (�r,)AAPAJY 6 64,41J(-7&,'3 a� Attachments: Signatures: Operator Rep _ fza ria _ o ZO.Z AOGCC Inspector *After signing, a copy of this form is to be left wt£RW opera or. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions tatting longer than the "correct by" date must be requested and accompanied by justification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 MEMORANDUM TO: Jim Regg P.I. Supervisor`s FROM: Matt HeTTera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 29, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1F -16A KUPARUK RIV UNIT 1F -16A See: Inspector Reviewed By: P.I. Sup" J bfz — Comm Well Name KUPARUK RIV UNIT IF -16A API Well Number 50-029-21029-01-00 Insp Num: mitMFH2O0623171497 Permit Number: 201-209-0 Rel Insp Num: Inspector Name- Matt Herrera Inspection Date: 6/22/2020 / Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IF -16A - Type Inj N TVD 5114 - Tubi ng 1610 1620 . — — 1620'' 1620 — PTD 2012090 Type Test SPT Testpsi 3000 IA 200 3300_ �I 3220 3200' Pumped: 6B BL Ro o - oBBL Interval RaQvAR p/F P Notes: MITIA to MAID per AID 2C.018 Well shut in for production curtailment Monday, June 29, 2020 Page 1 of I BECEIVLU STATE OF ALASKA • ALI.OIL AND GAS CONSERVATION COMMION JAN 3 0 2018 • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ 40Qpcdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate DI Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD ACID Stimulate El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 201-209 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service Q 6.API Number: 99510 50-029-21029-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1F-16A ADL 25652 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 8,990 feet Plugs measured None feet true vertical 6,289 feet Junk measured None feet Effective Depth measured 8,984 feet Packer measured 7342, 8655 feet true vertical 6,284 feet true vertical 5114, 6017 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80 feet 16 " 110'MD 110 TVD SURFACE 4,467 feet 9 5/8" 4,496'MD 3462 TVD PRODUCTION 7,868 feet 7 " 7,900'MD 5460 TVD LINER A 1,295 feet 5 " 8,984'MD 6284 TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-80 8,652' MD 6,015'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FHL PACKER 7,342' MD 5,114'TVD PACKER-BAKER MODEL D 8,655' MD 6,017'ND SSSV -NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED MAR 0 5 Treatment descriptions including volumes used and final pressure: ?:0 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 117 452 2313 Subsequent to operation: 0 0 637 1099 2564 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1=1 Exploratory D Development ❑ Service D Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil D Gas D WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG D GINJ ❑ SUSP❑ 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: 317-481 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer // Authorized Signatr -- --'' �_. _ Date: (/ 07 Contact Phone: (907)265-6471 rTi-- / '/ d Form 10-404 Revised 4/2017 „ ii://f Dom,,. (' , 1 iQ Submit Original Only • • IF- 16A DAD ACID STIMULATE DTTMST,JOBT'SUMMARYOPS 12/30/17 ACID RIH TO 8,710' CTM. WASH WITH HELIK NOZZLE AND S. DIESEL TO 9,911' RKB. SQUEEZE 100 BBL DAD ACID 9,911' - 8,626'. ****JOB COMPLETE**** KUP I 0 1 F-1 6A ConocoPhillips ,% Well Attribut Max Angle TD Wellbore APIIUWI Field Name Wellbore Status not(") MD(ftKB) Act Btm(ftKB) Alel0ke0,6 b 500292102901 KUPARUK RIVER UNIT INJ 57.93 6,700.16 9,175.0 Qindcal.1- Blips Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) 'Rig Release Date ... SSSV:NIPPLE Last WO: 5/28/2013 30.02 11/15/1983 1F-ISA,1130/201811'43'05 AM Last Tag Verhmlarliemauc{actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:SLM 8,649.0 6/4/2013 hipshkf HANGER;26.7 I;4 - 1 Last Rev Reason Annotation End Date Last Mod By • 11 ■,,: Rev Reason:MANDREL ORIENTATION 12/14/2015 pproven L` Casing Strings ,. ��i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread g CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD lin) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread It SURFACE(Top 19 jts 9 5/8 8.921 29.0 4,496.0 3,461 7 36.00 J-55 BTC 47tl) -^-~CONDUCTOR;30.0-7160r Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I�.. - PRODUCTION-Post SIT 7 6.276 32.1 7,900.0 5,459.6 26.00 J-55 BTC Casing Description OD(in) ID lin) Top(ftKB) 'Set Depth(665) Set Depth(ND)... Wt/Len(I...Grade Top Thread NIPPLE;515.4 WINDOW A 7 6.000 7,867.0 7,879.0 5,446.0 ili Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER A 5 4.276 7,689.4 8,984.4 6,284.0 18.00 L-80 Buttress Liner Details GAS LIFT,3,145.9 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,689.4 5,326.4 51.46 PACKER BAKER'C-2'ZXP LINER TOP ISOLATION PACKER 4.408 1 w/6'TIE BACK RECEPTACLE LI 1 I 7,703.0 5,334.9 51.41 HANGER BAKER FLEX-LOCK HYDRAULIC LINER HANGER 4.276 SURFACE(Top 19 jla 474);29.0 1 [ -4,4968Tubing Strings II Tubmg Description 4 .11D.. (101 Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;5,053.0 TUBING WO 'String 3M 1;2 12 29921 26.71 8,659.91 6,020.5IME 1 9.301E-80 I EUE-MOD Completion Details GAS LIFT;6370.6 Top(ND) Top Incl Nominal Top(ftKB) (ftKB) (") Item Des Com ID lin) 26.7 26.7 0.06 HANGER FMC TUBING HANGER 3.500 I515.4 515.4 0.62 NIPPLE CAMCO DS NIPPLE 2.875 7,311.6 5,096.1 53.55 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 GAS LIFT;7,257.3 7,322.1 5,102.3 53.50 PBR BAKER PBR 2.990 7,342.1 I 5,114.2 53.38 PACKER BAKER FHL PACKER 2.910 ni 7,394.7 5,145.8 53.08 NIPPLE CAMCO DS NIPPLE 2.812 All SEAL ASSN';7,311.6 8,579.9 5,957.8 38.71 SWELL REACTIVE ELEMENT CSG PACKER 3.000 PBR;7,322.1 ' PACKER PACKER;7,342.1 --_ 8,652.3 6,014.5 38.02 LOCATOR BAKER G-22 LOCATOR 1.970 8,654.0 6,015.9 38.00 SEAL ASSY BAKER G-22 SEAL ASSEMBLY 1.970 14 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE;7,394.7 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,635.0 6,000.9 38.19 WHIPSTOCK 3.5"BAKER WHIPSTOCK w/RA TAG 7/21/2013 0.000 li 8,636.0 6,001.7 38.18 TUBING 2"TUBING PUNCH,0 DEG Phase,4SPF 7/14/2013 2.992 GAS LIFT;7,047.2 PUNCH 8,655.0 6,016.7 37.99 PACKER BAKER MODEL'D'PERMANENT PACKER SET IN 5" 11/13/200 3.680 iffi LINER-2013 TUBING COMPLETION STABS INTO 1 PACKER Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com WINDOW A;7,e67.0-7,879.0 8,516.0 8,536.0 5,908.1 5,923.6 Com,1F-16A 11112/2001 6.0 IPERF 33/8"HSD Powershot,60 PRODUCTION-Post S/T;32.1- 7,900.0-* s I. deg phase 8,540.0 8,560.0 5,926.7 5,942.3 C-4,1 F-16A 11/12/2001 6.0 IPERF 3 3/8"HSD Powershot,60 IPERF;8,518.0.8,536.0 I deg phase I 1 8,690.0 8,704.0 6,044.3 6,055.4 A-5,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing IPERF;6,540.0.8,580.0 I-. 8,692.0 8,702.0 6,045.9 6,053.8 A-5,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient 8,726.0 8,752.0 6,072.9 6,093.6 A-4,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing SWELL PACKER;8,578.9 8,72S.0 8,738.0 6,074.5 6,082.5 A-4,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient IStimulations&Treatments Proppant Designed(lb) Proppant In Formation(Ib) I Date 12/1/2001 !I (, Stimulations&Treatments 6 mein Vol Clean Pump LINER AL1-02(0 wellbore);8,626.5-11,9550 3 Stg 0 Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid I (bbl) I Vol Slurry Rabb TUBING PUNCH;8,838.0- 11 1 8,690.0 8,7520 12/1/2001 Il WHIPSTOCK;8,835.0 4 Proppant Designed(Ib) Proppant In Formation(Ib) Date 1 3/3/2002 I. Stimulations&Treatments vol Clean Pump Stg# Top(ftKB) I Btm(ftKB) I Date I Stim/Treat Fluid (bbl) I Vol Slurry(bbl) 1 8,690.0 8,752.0 3/3/2002 LOCATOR;8,652.3 - Mandrel Inserts SEAL ASSY;8,654.0 _ , St PACKER,8,655.0 ati N Top(TVD) Valve Latch Port Size TRO Run q Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com APERF;8,690.0-8,704.0 : 1 3,145.9 2,598.5 CAMCO KBMG 1 GAS LIFT GLV R-20 0.188 1,310.0 10/3/2013 5:30 APERF;8,692.0-8,702.0 2 5,053.0 3,806.1 CAMCO -KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/20/2013 7:00 HPBD-02;8,890.0 3 6,370.6 4,575.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/20/2013 1:00 HPBD-INITIAL;8,890.0 APERF;8,728.0-8,738.0 4 7,257.3 5,064.0 CAMCO KBMG 1 GAS LIFT OV BK-5 0250° 0.0 10/3/2013 5:00 APERF;8,726.0-8,752.0 5 7,447.2 5,177.4 CAMCO .KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 9:00 Notes:General&Safety End Date Annotation 11/15/2001 NOTE:WORKOVER LINER A;7,669.4-8,984.4 1 1 Ilk KUP I. 40 1F-16A Conoc©Phillips Alaska.i . CcxlocsPhfli ps ••- 1F-10A,1130/201811:43:06 AM VarS Ieohernapc,(aod+alj. HANGER;26.7 Ea [ ( LII Notes:General&Safety : Nil End Date Annotation AB 11/15/2001 NOTE:WELL SIDETRACKED 11/3/2009 NOTE:View Schematic w/Alaska Schematic9.0 10/1/2013 NOTE:ADD LATERALS AL1,AL1-01,AL1-02(off main wellbore) ---ti CONDUCTOR;30.0-710.0 I 1.. 6/4/2015 NOTE:WAIVERED WELL T x IA ON GAS INJECTION-WATER ONLY INJECTION ALLOWED fil NIPPLE;515.4 i, a. GAS LIFT,3,145.9 OF I SURFACE(Top 19,05 4710;29.0il , -4,4960_ ati GAS LIFT;5653.0 III GAS LIFT;6370.6 .„, ., If II GAS LIFT;7,257.3 - lit in SEAL ASSY;7,311.6 _. PBR;7,322.1 PACKER;7,342.1 NIPPLE,7,394.7 7.4 111ilIIEI GAS LIFT;7,447.2 at A WINDOW A;7,887.0-7,879.0 PRODUCTION-Post SIT;32.1- 7,900.0 (PERF;8,516.0-8,536.0---ii I. IPERF;8,540.0.8,560.0 I riiii SWELL PACKER;8,579,9 LINER AL1-02(off main wellbore);8,626.5-11,955.0-, TUBING PUNCH;8,636.0, ,1,' WHIPSTOCK 8,635.0 LOCATOR;8,852.3 ia SEAL ASSY;8,654.0, E PACKER;8,655.0 . APERF;8,690.0-8,704.0 �'.,:: APERF;8,592.0-8,702,0 fr HPBD-a2;8,890.0@@@@ HPBD-INITIAL;6,6900 APERF;8,728.0-8,738.0 APERF;8,728.0-8,752.0 i d LINER A,7,689.4-8,984.4 LOF TAr \*I%%�sTHE STAT Alaska Oil and Gas 4 ,,—i—Q&'��, ®fA S KA Conservation Commission U ,..x _ _- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 9A' " ALA9ii*Q. Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke sCANNED INOV 2 22017 Senior Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-16A Permit to Drill Number: 201-209 Sundry Number: 317-481 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, Hollis S. French Chair DATED this -2, day of October, 2017. RBD MS j 2017 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 0 6 2017 • APPLICATION FOR SUNDRY APPROVALS Dr3 6odiz_fi 7 20 AAC 25.280 `^_1.Type of Request: Abandon H Plug Perforations H Fracture Stimulate ❑ Repair Well ❑ AOqhs shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 2 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: DAD Acid StirrO 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 201-209 ' 3.Address: Stratigraphic 111Service Q j 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21029-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ElNo 0 KRU 1F-16A 9.Property Designation(Lease Number): 10.Field/Pool(s): o2,S(ps UN- Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total D12.5e. th IT(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ° 'i� 6,289' 8984' 6284' 2100 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 110' 110' Surface 4467' 9-5/8" 4496' 3462' Intermediate Production 7,868' 7" 7,900' 5460' Liner 1295' 5" 8984' 6284' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8516'-8536' 5908'-5924' 8540'-8560' 5927'-5942' 3.5" L-80 8,660' 8690'-8704' 6044'-6055' 8726'-8738' ' 6073'-6075' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER ' MD=7342 TVD=5114 PACKER-BAKER'C-2'ZXP LINER TOP ISOLATION PACKER " MD=7689 TVD=5326 PACKER-BAKER MODEL'D'PERMANENT PACKER SET IN 5"LINER MD=8655 TVD=6017 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ ^ 14.Estimated Date for 15.Well Status after proposed work: 11/1/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • 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 Contact Phone: (907)265-6097 Authorized Signatur Date: CO ISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3 17• q- / Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ NodRBDMS L"- tjlr,1 1 3 2017 Spacing Exception Required? Yes El Subsequent Form Required: /d — 40 4 6227.— APPROVED BY i t I II_ I Approved by: COMMISSIONER S O Date: L. `� 7i QtE Submit Form and Form 10-403 Rev�'edf/2017 �� �� roved application is valid for 12 rim e a e p r va. Attachments in Duplicate )/� X 7 ,e/04l1 • • ConocoPhillips Alaska,Inc. Drilling&Wells COnOCoPhIllIpS Well Intervention Alaska 1F-16A Acid Treatment (10404367) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. 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 • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 8626' MD. 3. Continue RIH until end of first liner section at 9911' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 8626' MD (At 9911' MD 100 bbl/1 BPM=100 min & 1285 ft / 100 min=12.5 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HCI 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 October 3, 2017 1F-16A Well Work Procedure Page 1 of 1 KUP ii 1F-16A ConocoPhillips "' Well Attrib Max AngD TD Alaska.Ilk:. Wellbore API/UWI Field Name Wellbore Status ncl)°) MD(ftKB) Act Btm(ftKB) co,,«opi,85, 500292102901 KUPARUK RIVER UNIT INJ 57.93 6,700.16 9,175.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date " 1F-16A.10/4/20174.06:37 PM SSSV:NIPPLE Last WO: 5/28/2013 30.02 11/15/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,649.0 6/4/2013 Rev Reason:MANDREL ORIENTATION pproven 12/14/2015 HANGER;28.7 - Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread """"'"""""""""""""-"'"°"'""""J""" ('j CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread al.7 SURFACE(Top 19 jts 9 5/8 8.921 29.0 4,496.0 3,461.7 36.00 J-55 BTC 47#) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...°WtlLen(I...Grade 'Top Thread PRODUCTION-Post S/T 7 6.276 32.1 7,900.0 5,459.6 26.00 J-55 BTC • Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread -ti CO IDUCToa;38.011o.0 WINDOW A 7 6.000 7,867.0 7,879.0 5,446.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • LINER A 5 4.276 7,689.4 8,984.4 6,284.0 18.00 L-80 Buttress NIPPLE;515.4 Liner Details i. I Top(ftKB) Top(TVD)MB) Top Incl(°) Item Das Com Nominal ID (In) 7,689.4 5,326.4 51.46 PACKER BAKER'C-2'ZXP LINER TOP ISOLATION PACKER 4.408 GAS LIFT;3,145.9 a w/6'TIE BACK RECEPTACLE 7,703.0' 5,334.9 51.41 HANGER BAKER FLEX-LOCK HYDRAULIC LINER HANGER 4.276 Tubing Strings • Tubing Description String Ma...ID(in) Top)ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibift) Grade Top Connection SURFACE(Top 19 Its 478),29.0 1 TUBING WO 31/2 2.992 26.7 8,659.9 6,020.5 9.30 L-80 EUE-MOD -4,496 0 Completion Details GAS LIFT;8,053.0 III Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(1 Item Des Com (In)26.7 26.7 0.06 HANGER FMC TUBING HANGER 3.500 ' GAS LIFT;6,370.6 lin 515.4 515.4 0.62 NIPPLE CAMCO DS NIPPLE 2.875 ' 7,311.6 5,096.1 53.55 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 • I 7,322.1 5,102.3 53.50 PBR BAKER PBR 2.990 • 7,342.1 5,114.2 53.38 PACKER BAKER FHL PACKER 2.910 7,394.7 5,145.8 53.08 NIPPLE CAMCO DS NIPPLE 2.812 GAS LIFT,7257 3 8,579.9 5,957.8 38.71 SWELL REACTIVE ELEMENT CSG PACKER 3.000 PACKER 8,652.3 6,014.5 38.02 LOCATOR BAKER G-22 LOCATOR 1.970 SEAL ASSY;7,311.6 1. 8,654.0 6,015.9 38.00 SEAL ASSY BAKER G-22 SEAL ASSEMBLY 1.970 PBR;7,322.1 ' f PACKER;7,3421 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(kKB) (ftKB) (°) Des Com Run Date ID(in) 8,635.0 6,000.9 38.19 WHIPSTOCK 3.5"BAKER WHIPSTOCK w/RA TAG 7/21/2013 0.000 NIPPLE;7,394.7 8,636.0 6,001.7 38.18 TUBING 2"TUBING PUNCH,0 DEG Phase,4SPF 7/14/2013 2.992 e PUNCH ill. , 8,655.0 6,016.7 37.99 PACKER BAKER MODEL'D'PERMANENT PACKER SET IN 11/13/2001 3.680 GAS LIFT;7,4azz 5"LINER-2013 TUBING COMPLETION STABS INTO PACKER Perforations&Slots Shot Dens - Top(TVD) Btm(TVD) (shots/ 4aI- 8,516.0 1. Top(ftKB) Btm(ftKB) (ftKB) (MB) Zone Date ft) Type Com e 8,536.0 5,908.1 5,923.6 C-4,1F-16A 11/12/2001 6.0 IPERF 3 3/8"HSD Powershot, 60 deg phase WINDOW A;7,867.0-7,679.0 8,540.0 8,560.0 5,926.7 5,942.3 C-4,1F-16A 11/12/2001 6.0 IPERF 3 3/8"HSD Powershot, PRODUCTION-Post S/T;32.1- 60 deg phase 7,900'0 8,690.0- 8,704.0 6,044.3 6,055.4 A-5,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing IPERF;8,516.0-8,536.0 II II 8,692.0 8,702.0 6,045.9 6,053.8 A-5,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient (PERF;8,540.0-8,560.0II 8,726.0 .8,752.0 6,072.9 6,093.6 A-4,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing a 8,728.0 8.738.0 6,074.5 6,082.5 A-4,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient SWELL PACKER;8,579.9 I Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(lb) Date 12/1/2001 Stimulations&Treatments Vol Clean Pump -= Stg# Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) LINER AL7-02(off main 1 8,690.0 8,752.0 12/1/2001 waebors);8,626.511,955.0' _ TUBING PUNCH;8,636.0, I A Proppant Designed(Ib) Proppant In Formation(Ib) Date WHIPSTOCK 8,635.0 YY 3/3/2002 1 Stimulations&Treatments St 9 To ftKB Btm(ftKB) Date Stim/Treat Fluid Vol Clean Pump fl P( ) (bbl) Vol Slurry(bbl) 1 8,690.0 8,752.0 3/3/2002 LOCATOR;8,652.3 11111 _ Mandrel Inserts St SEAL ASSY;8,654.0+ aft PACKER;8,855.0 = on Top(TVD) Valve Latch Port Size TRO Run N, Top(ftK131 (ftKB) Make Model OD(in) Sery Type Type (in) (pal) Run Date Com -, eie 1 3,145.9 2,598.5 CAMCO KBMG 1 GAS LIFT GLV R-20 0.188 1,310.0 10/3/2013 5:30 11. APERF;8,892.0-8,702.0 2 5,053.0 3,806.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/20/2013 7:00 APERF;8,880.0$704.0, 3 6,370.6 4,575.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/20/2013 1:00 HPBD-92;8,690.0 HPBD-INITIAL;8,690.0 4 7,257.3 5,064.0 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 10/3/2013 5:00 APERF;8,728.0-8,738.0 . 5 7,447.2 5,177.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 9:00 APERF;8,726.0-8,752.0 Notes:General&Safety End Date Annotation 11/15/2001 NOTE:WORKOVER LINER A;7,889.4-8,984.4 `, KUP 4 1F-16A ConocoPhillips '',' Alaska, Inc. ConocoPhlllips 1 • ••• 1F-16A,10/4/20174;08;37 PM Vertical schematic(actual) HANGER;28.7 I t Notes:General&Safety End Date Annotation ' ' ' ' ' i 1f' ti 11/15/2001 NOTE: WELL SIDETRACKED 11/3/2009 NOTE:View Schematic w/Alaska Schematic9.0 10/1/2013 NOTE:ADD LATERALS AL1,AL1-01,AL1-02(off main wellbore) L • 6/4/2015 NOTE:WAIVERED WELL T x IA ON GAS INJECTION-WATER ONLY INJECTION ALLOWED "~A-CONDUCTOR,300.110.0~7 a NIPPLE;515.4 a I a GAS LIFT;3,145.9 a • SURFACE(Top 19 its 47*),29.0 4.496.0 a GAS LIFT;5,053.0 11 • GAS LIFT;6,370.6 oi GAS LIFT;7,257.3 g • • i• SEAL ASSY;7,311.6 PBR,7322-1 PACKER;7.342.1 a • • NIPPLE;7,394.7 f • a GAS LIFT;7,447.2 a a a a WINDOW A;7,867 0-7.879 0 PRODUCTION-Post SIT;32.1- 7,900.0 IPERF,8,516.0-8,536.0 I 'I (PERF;8,540.0-8,560 0 I'. :I 'a SWELL PACKER,8.579.9 ' I 1 -t LINER AL1-02(off main 111 wellbore);8,626.5-11,955.0 TUBING PUNCH;8636.0, WHIPSTOCK;8,635.0 I 111 LOCATOR;8,652.3 IIII , SEAL ASSY;8,654 0, PACKER,8,655.0 '4 Y' IIIII III,, APERF;8,692 0-8,702.0 y1- :y APERF,8,690.0-8,704.0 IIII HPBD-#2,8,690.0 HPBD-INITIAL,8,690.0 • ■ ■ APERF;8.72S 0-8.738 0 s= = APERF;8,726.08,752.0 1■ ■ LINER A;7,689.4-8,984.4 • • • Bettis, Patricia K (DOA) From: Burke,Jason <Jason.Burke@conocophillips.com> Sent: Tuesday, October 10, 2017 9:11 AM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1F-16A (PTD 201-209): Sundry Application The 8990' MD and 6289'TVD is accurate, sorry for the mix up Jason ConoocoPlhillips Jason Burke Staff Wells Engineer CO) 907-265-6097 CM) 907-231-4568 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday,October 09, 2017 3:00 PM To: Burke,Jason<Jason.Burke@conocophillips.com> Subject: [EXTERNAL]KRU 1F-16A(PTD 201-209):Sundry Application Good afternoon Jason, On Form 10-403, Box 11,the total depth for the well is stated as 9175' MD and 6,289'TVD. Form 10-407,Well Completion or Recompletion Report and Log, has the total depth of the well as 8990' MD and 6289'TVD. Sperry-Sun Drilling Services Survey Report also has the total depth as 8990' MD and 6288.7'ND. Please confirm the correct total depth for the well. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, March 22, 2015 1:58 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly KRU injector 1F-16A (PTD 201-209) 3-22-15 Attachments: 1F-16A schematic.pdf; 1F-16A 90 day TIO 3-22-15.JPG; 1F-16A 450 day TIO 3-22-15.JPG Chris, KRU WAG injector 1F-16A(PTD#201-209) is displaying an unexpected rise in IA pressure while on gas injection. The well was reported in the summer of 2014 for probable thermal increases of the IA and OA while it was on MI injection. It was pre-emptively reported because of a suspicious slow build up in IA pressure, in addition to the thermal effects. But after a successful 30 day monitor, the well was returned to normal operating status. Shortly after the monitor period,the well was WAG'ed to water in July. The well was WAG'ed back to gas injection on 1-12-15. On Friday, 3-20-15,the IA was bled after it showed a relatively fast rise in pressure. The character of the current unexplained IA pressurization is different than the 2014's reported event(attached is a 450 day TIO plot, in addition to the standard 90 day plot). Temperature does not currently appear to be the cause of the IA anomaly now. However, due to the well's historical atypical thermal response, CPAI believes it prudent to perform diagnostics(MITIA, drawdown test, packoff testing) and put the well on a 30 day monitor on gas injection. If the well continues to display suspect behavior on gas injection,the well will be WAG'ed to water for 30 days in anticipation of an AA submittal. If the well fails the MIT,the well will be shut in and freeze protected as soon as possible. A followup email will be submitted at the conclusion of the monitor. Please let us know if you disagree with the plan. 1 Well Name 1F-16A Notes: Start Date 12/22/2014 Days 90 End Date 3/22/2015 4000 _wHP Annular Communication Surveillance _IAP 3E00 — OAP ------- - 3000 2E00 VI NI 2000 VA 1E00 O. 1000 I) IL ECO • 11.1 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Mar-15 Mar-15 I =4 O 3R'0 d m IiiLJTTTf#%TTAP%%vsv jr.V*41%.\A'1%\i\f d 'SC— 2 .cc:— Dec-14 Dec-14 Jan-15 Jan-15 Jan-1E Feb-1E Feb-1E Feb-1E Mar--1E Mar--1E I Date / 2 • ' Well Name 1F-16A Notes: Start Date 12/27/2013 Days 450 End Date 3/22/2015 WHP Annular Communication Surveillance 3E00 — r'.i+`�► 3000 2E00 t" 2000 1 ` L i I Ti 1E00 C. 1000 E00 14-1 kwY► 0 Nov-13 Jan-14 Mar-14 Apr-14 Jun-14 Jul-14 Sep-14 Nov-14 Dec-14 Feb-15 Apr-15 m � :r:— wn mx+ TIL111.1114trifill"11111‘1111 nx Nov-13 Jan-14 Mar-14 Apr-14 Jun-14 Jul-14 Sep-14 Nov-14 Dec-14 Feb-15 Apr-15 h Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 3 • KUP INJ 1F-16A Iotry-. } • CocoPhillips Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status Inc'I°) MD(ftKB) Act Btm(ftKB) t twvrilaflips 500292102901 KUPARUK RIVER UNIT INJ 57.93 6,700.16 9,175.0 ... Comment H2S(ppm) Date Annotation End Dab KB-Grd(ft) II Rig Release Date 1F-16A,10/23/20139:41:41 AM SSSV.NIPPLE Last WO: 5/28/2013 30.02 11/15/1983 Vertical schematic lamed) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------------------------ Last Tag.SLM 7,501.0 11/26/2011 Rev Reason:PULL PLUG/CATCHER hipshkf 10/23/2013 HANGER:20.7 inciim Casing Strings 11i Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H-40 WELDED WilCasing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread 1,0 ■. SURFACE476) (Top 19 jts 9 5/8 8.921 29.0 4,496.0 3,461.7 36.00 J-55 BTC Casing Description OD(in) "ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION-Post S/T 7 6.276_ 32.1 7,900.0 26.00 J-55 ETC Casing DescriptionOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ^-^-7 ooirliuctio seal-1io.o°" 1 ll WINDOW A 7 6.000 7,867.0 7,879.0 Casing Description OD(in) ID in Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)... Wt/Len(I...Grade Top Thread 11 LINER A 5 4.276 7,689.4 8,984.4 18.00 L-80 Buttress NIPPLE;515.4 Liner Details Nominal ID I Top)ftKB) Top(ND)(RKB) Top Ind I") Item Dee Com lin) 7,689.4 5,326.4 51.46 PACKER BAKER'C-2'ZXP LINER TOP ISOLATION PACKER 4.408 • w/6'TIE BACK RECEPTACLE GAS LIFT;3,145.8 I 7,703.0 HANGER 'BAKER FLEX-LOCK HYDRAULIC LINER.HANGER 4 276 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(R..Set Depth(TVD)(...Wt(tb/ft) Grade Top Connection SURFACE(Top 19)f6479);290_ a TUBING WO 31/2 2.992 26.7 8.659.9 9.30 L-80 EUE-MOD -4.480.0 Completion Details Nominal ID GAS LIFT;5,053.0 Top(ftKB) Top)TVD)(ftKB) Top net(°) Item Des Com (in) 26.7 26.7 0.06 HANGER FMC TUBING HANGER 3.500 515.4 515.4 0.62 NIPPLE CAMCO DS NIPPLE 2.875 ' GAS LIFT;8,370.8 7,311.6 5,096.1 53.55 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,322.1 5,102.3 53.50 PBR BAKER PBR 2.990 7,342.1 5,114.2 53.38 PACKER BAKER FHL PACKER 2.910 7,394.7 5,145.8 53.08 NIPPLE CAMCO DS NIPPLE 2.812 GAS LIFT;7,257.3g "€ 8,579.9 SWELL REACTIVE ELEMENT CSG PACKER 3.000 PACKER - - 8,652.3 LOCATOR BAKER G-22 LOCATOR 1.970 SEAL ASSY;7,311.6 foll 8.654.0 SEAL ASSY BAKER G-22 SEAL ASSEMBL Y ' 1.970 ' PER;7,342.1 PACKER;7,342.1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 8,635.0 WHIPSTOCK 3.5"BAKER WHIPSTOCK w/RA TAG 7/21/2013 0.000 NIPPLE;7,394.7-€A 8,636.0 TUBING '2"TUBING PUNCH,0 DEG Phase,4SPF 7/14/2013 - 2.992 PUNCH 8,655.0 PACKER BAKER MODEL'D'PERMANENT PACKER SET IN 11/13/2001 3.680 5"LINER-2013 TUBING COMPLETION STABS GAS LIFT;7,447.2_1 E INTO PACKER i -- Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shota/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type ' Corn 8,516.0 8,536.0 C-4,1F-16A 11/12/2001 6.0 IPERF ' 33/8"HSD Powershot, 60 deg phase 8,540.0 8,560.0 C-4,1F-16A 11/12/2001 6.0 IPERF 33/8"HSD Powershot, 60 deg phase WINDOW N;Post SITE2 8,690.0 8,704.0 A-5,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing 7,1367.0-7.879.0- PRODUCTION-Post SR;32.1- 7,900.0� - 1 8,692.0 8,702.0 A-5,1F-16A 2/15/2002 4.0 APERF '1-11/16"Pivot,0 orient IPERF;8,518.0.8,536.0- 8 726.0 8,752.0 A-4,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing IPERF;8,540.0-8,500.0 8,728.0 8.738.0 A-4,1F-16A 2/15/2002 4.0-APERF '1-11/16"Pivot,0 orient • Stimulations&Treatments • SWELL PACKER,8,579.9 Min Top Mae BM Depth Depth Top(TVD) Bbn(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com j 8,690.0 8,752.0 HPBD-INITIAL 12/1/2001 !. 8.690.0 8.752.0 -HPBD-92 3/3/2002 Mandrel Inserts LINER AL1-02(off main SI wellbore);8,628.5-11,955.0 ati C TUBING PUNCH;8,838.01 on Top(ND) Valve Latch Port Sus TRO Run WHIPSTOCK;6,63350 No Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date m 1 3,145.9 2,598.5 CAMCO KBMG 1 GAS LIFT GLV R-20 0.188 1,310.0 10/3/2013 2 5,053.0 3,806.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/20/2013 3 6,370.6 4,575.3 CAMCO KBMG 1 GAS LIFT DMY BK ' 0.000 0.0 10/20/2013 - 4 7,257.3 5,064.0 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 10/3/2013 LOCATOR;8,8523 _ 5' 7,447.2 5,1774 CAMCO KBMG 1 GAS LIFT 'DMY BK-5 0.000 0.0 5/28/2013 SEAL ASSY;8,054.0 18., Notes:General&Safety PACKER;8,855.0 • •. End Date Annotation --• 11/15/2001 NOTE:WORKOVER ' APERF;8,090.02,704.0 = 11/15/2001 'NOTE:WELL SIDETRACKED APERF:8992.02,7D2.0 -a 11/3/2009 "NOTE:View Schematic w/Alaska Schematic9.0 HPBD-INITIAL;8,890.0 10/12013 "NOTE:ADD LATERALS AL1,AL1-01,AL1-02(off main wellbore) ' HPBD-002;8,690.0 �- APERF;8.728.02,738.0 APERF;8,728.02,752.0 I LINER A.7,689.42.964.4 STATE OF ALASKA • AL,A OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell j" Rug Perforations r Perforate r Other Tubing punch in III Alter Casing f Pull Tubing E Stimulate-Frac Waiver injection straddle [-`- Time Extension Change Approved Program "`"`Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory n 201-209 • 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-21029-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652 1F-16A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8990 feet Plugs(measured) 7395 true vertical 6289 feet Junk(measured) none Effective Depth measured 8851 feet Packer(measured) 7342,7689, 8655 true vertical 6174 feet (true vertical) 5114, 5326,6018 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 4467 9.625 4496 3462 PRODUCTION 7868 7 7900 5460 RECEIVED LINER 1295 5 8984 6284 AUG 13 2013 Perforation depth: Measured depth: 8516-8536, 8540-8560,8690-8704, 8726-8752 AOGCC True Vertical Depth: 5908-5924, 5927-5942,6045-6056,6073-6094 Tubing(size,grade,MD,and ND) 3.5, L-80, 8660 MD, 6021 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7342 MD and 5114 TVD PACKER-BAKER C-2 ZXP LINER TOP ISOLATION PACKER @ 7689 MD and 5326 ND PACKER-BAKER MODEL'D' PERMANENT PACKER @ 8655 MD and 6017 ND NIPPLE-CAMCO DS NIPPLE @ 515 MD and 515 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service f • Stratigraphic 16.Well Status after work: Oil ' Gas r WDSPL i Daily Report of Well Operations XXX GSTOR I— VVINJ r WAG (i• GINJ r SUSP r SPLUG 1— 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: 313-295 Contact Jason Burke low.265-6097 Email Jason.Burke@conocophillips.com Printed Name J-_•n Bur.- Title CTD Engineer Signature -/3 Phone:263-6097 Date'.-/Z-- /3 I V'-P RBr M AUG 2 0 7nl..041-e- ,9 .,,, ,,e.4 Form 10-404 Revised 10/2012 jj I/3 Submit Original Only i KUP INJ 1F-16A ConocoPhillips III Well Attributes Max Angle&MD TD Alaska ItiC Wellbore API/UWI Held Name Wellbore Status Intl(°) MD(ftKB) Act Btm(ftKB) canoes 500292102901 KUPARUK RIVER UNIT INJ 57.93 6,700.16 9,175.0 ..' Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 5/28/2013 30.02 11/15/1983 Well Confiq -1F-16A,817/201311:05.28 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .........- Last Tag:SLM 7501.0 11/26/2011 Rev Reason:Add TBG Punch,Set Plug/Pulling haggea 8!7/2013 _..- ---.... Tool HANGER,27 ' _ r.....e Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 29.0 4,496.0 3,461.7 36.00 J-55 BTC (Top 19 jts 47#) _...- Casing Description String 0... String ID...Top(RIO) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION-Post 7 6.276 32.1 7,900.0 5,459.8 26.00 J-55 BTC Sidetrack CONDUCTOR. Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd 30-110 WINDOW A 7 6.000 7,867.0 7,879.0 5,446.0 Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(NO)...String Wt...String...String Top Thrd NIPPLE,5t5 SIX LINER 5 4.276 7,689.4 8,984.4 6,284.0 18.00 L-80 Buttress Liner Details F Top Depth Nomi... (ND) Top Intl or i.. E---. Top OMB) (ftKB) (°) Item Description Comment ID GAS LIFT, 7,689.4 5,326.4 51.46 PACKER BAKER'C-2'ZXP LINER TOP ISOLATION PACKER w/6'TIE BACK 4.408 3,146 11t77 RECEPTACLE 7,703.0 5,334.5 50.88 HANGER BAKER FLEX-LOCK HYDRAULIC LINER HANGER 4.276 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE .. L TUBING WO 3 1/2 2.992 26.7 8,659.9 6,021.4 9.30 L-80 EUE-MOD 47e1.229-0496 Completion Details Top Depth GAS LIFT, (ND) Top Inc! Nomi... 5,053 ` .M- Top(ftKB) (RKB) (1 Item Description Comment ID(in) 26.7 26.7 0.25 HANGER FMC TUBING HANGER 3.500 GAS LIFT, 515.4 515.4 0.62 NIPPLE CAMCO DS NIPPLE 2.875 6,371 7,311.6 5,096.5 53.60 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,322.1 5,102.6 53.53 PBR BAKER PBR 2.990 7,342.1 5,114.4 53.41 PACKER BAKER FHL PACKER 2.910 .- 7,394,7 5,145.8 53.08 NIPPLE CAMCO DS NIPPLE 2.812 GAS LIFT, ■• 8,579.9 5,957.8 38.71 Swell Packer REACTIVE ELEMENT CSG PACKER 3.000 7,257 IMP 8,652.3 6,015.6 38.63 LOCATOR BAKER G-22 LOCATOR 1.970 IF 8,654.0 6,016.9 38.60 SEAL ASSY BAKER G-22 SEAL ASSEMBLY 1.970 SEAL ASSY, 7,312 - Other In Hole(VVireline retrievable plugs,valves,pumps,fish,etc.) PBR,7,322-_ ,j I, Top Depth PACKER,7,342 - (TVD) Top Inc! Ma Top(ftKB) (RKB) t") Description Comment Run Date ID(in) ill 7,394.7 5,1457 53.08 PLUG CSA-2 PLUG,BAITED PULLIING TOOL ON CSA-2 EQ 8/1/2013 0.000 PRONG(OAL 44") PLUG,7.395 : 8,636.0 6,001.7 38.18 TUBING 2"Tubing Punch,0 DEG Phase,4SPF 7/14/2013 2.992 NIPPLE.7,395- G3: PUNCH 8,655.0 6,017.6 38.59 PACKER BAKER MODEL'D'PERMANENT PACKER SET IN 5" 11/13/2001 3.680 LINER-2013 TUBING COMPLETION STABS INTO GAS LIFT, PACKER 7,447 M Perforations&Slots , Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(RKB) (ftKB) (ftKB) Zone Date leh-. Type Comment - • T 8,516.0 8,536.0 5,908.2 5,923.6 C-4,1F-16A 11/12/2001 6.0 IPERF 33/8"HSD Powershot,60 deg phase -' 8,540.0 8,560.0 5,926.7 5,942.3 C-4,1F-16A 11/12/2001 6.0 IPERF 3 3/8"HSD Powershot,60 deg phase WINDOW A 8,690.0 8,704.0 6,044.7 6,055.6 A-5,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing 7,867-7,879N 8,692.0 8,702.0 6,046.2 6,054.0 A-5,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient PRODUCTION y -Post 1 8,726.0 8,752.0 6,072.9 6,093.7 A-4,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing Sidetrack, 32-7,900 4.. 8,728.0 8,738.01 6,074 51 6,082.5 A-4,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient IPERF, 8,516E536 -._ o ' = Stimulations&Treatments I I Bottom IPERF, t Min Top Man Btm Top Depth Depth 6540-8E60 ' -- Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (RKB) Type Date Comment alk Swell Packer, 8,690.0 8,752.0 6,044.7 6,093.7 HPBD-INITIAL 12/1/2001 8,580 8,690.0 8,752.01 6,044.7 6,093.7 HPBD-#2 3/3/2002 Notes:General&Safety End Date Annotation 11/15/2001 NOTE:WELL SIDETRACKED TUBING 11/15/2001 NOTE:WORKOVER PUNCH,8,636 11/3/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR, �,a°. 8,652 1` Mandrel Details SEAL ASSY, 4i Top Depth Top Port S•654---- L- g,,, (ND) Inc! OD Valve Latch Size TRO Run PACKER,8,656 _ N...Top(ftKB) (ftKB) 1°) Make Model lin) Sea Type Type ON (psi) Run Date Com... APERF, 1 3,145.9 2,598.4 50.34 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/4/2013 8,690-8,704 APERF, 2 5,053.0 3,806.1 53.75 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 8,692.8,702 -_ HPBD- 3 6,370.6 4,575.3 56.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 INITIAL 8,690 HPBD-02, a 4 7,257.3 5,064.0 53.86 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 6,680 APERF, - 5 7,447.2 5,177.5 52.76 CAMCO KBMG ( 1 GAS LIFT DMY BK-5 0.000 0.0 5282013 8,728.8,738 APERF, $1 8.726-8,752 4" Y LINER, 7,689-8,984 TO(1F-16A), 8,990 1F-16A Well Work Summary • 1111 • DATE SUMMARY 6/25/2013 RIH AND TAGGED @ 8676', LOGGED WITH 24-ARM CALIPER UP TO 7200', POOH,WELL TURNED OVER TO DSO 6/29/2013 (PRE CTD)TREE TEST; (INCOMPLETE) COULD NOT PRESSURE UP TREE. VALVE CREW WAS CALLED TO RE-INSTALL 2 WAY CHECK VALVE. 7/1/2013 (PRE-CTD): TREE TEST. SV, SSV, MV PASSED POSITIVE TEST. SV, SSV PASSED DDT. UNABLE TO PERFORM DDT ON MASTER DUE TO TWC NOT HOLDING PRESSURE. 7/2/2013 (PRE CTD) : MV-DDT PASSED: BPV- DDT PASSED. 7/14/2013 PERFORATION COMPLETED AT 8636-8638 USING 2"TUBING PUNCH, 0 DEG PHASING, 4 SPF. READY FOR SLICKLINE, JOB IN PROGRESS. 7/18/2013 GAUGED TBG TO 2.80"TO 8652' RKB. DRIFTED WITH 2.62" DUMMY W/S TO 8652' RKB. SET HOLE FINDER @ 8637' SLM. TESTED TBG/SWELL PKRS 1450 PSI, PASSED. READY FOR E/L WHIPSTOCK. 7/20/2013 ATTEMPTED SETTING WHIPSTOCK. JOB CANCELLED AS PER CWG REPRESENTATIVE FOR LATE START TIME. 7/21/2013 RIH WITH WHIPSTOCK. NO PROBLEMS GOING DOWN HOLE. SET TOP OF WHIPSTOCK @ 8635'. DEVIATION OF WHIPSTOCK @-3 DEGREES LEFT OF HIGH SIDE. RA TAG WAS SET @ 8641'. TAGGED WHIPSTOCK TO CONFIRM IT SET. PULL UP HOLE AND BECAME STUCK @ 7340'. COULD MOVE DOWN, BUT NOT UP. CALLED IN LITTLE RED SERVICES TO PUMP ON TOOLSTRING. AFTER 45 BBLS OF DIESEL PUMPED @ 2 BPM THE TOOLSTRING GOT PAST THE OBSTRUCTION. POOH. JOB COMPLETE. 8/1/2013 GAUGED TBG TO 2.84"TO 7395' RKB. SET 2.81" CSA-2 PLUG @ SAME. MIT TBG TO 2500 PSI ( PASS) SET BAITED PULLING TOOL ON CSA-2 EQ PRONG @ 7395' RKB. PERFORMED 15 MIN DRAW DOWN TEST( PASS) JOB COMPLETE. STATE OF ALASKA ' ALA.OIL AND GAS CONSERVATION COMIOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon f Repair w ell Plug Perforations r Perforate [ Other r"< d '1, :C; Alter Casing Pull Tubing g �` 9 IV Stimulate-Frac r Waiver Time Extension r Change Approved Program '"`Operat. Shutdown °"" Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-209 . 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21029-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652 1 F-16A ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CCL Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 8990 feet Plugs(measured) none true vertical 6289 feet Junk(measured) none Effective Depth measured 8851 feet Packer(measured) 7342,7689,8580,8655 true vertical 6174 feet (true vertical) 5114, 5326, 5958,6018 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 110 110 SURFACE 4467 9.625 4496 3462 PRODUCTION 7868 7 7900 5460 LINER 1295 5 8984 6284 Perforation depth: Measured depth: 8516-8536, 8540-8560, 8690-8704,8726-8752 SCANNED NOV 0 h 2013 True Vertical Depth: 5908-5924,5927-5942,6045-6056,6073-6094 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8660 MD,6021 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7342 MD and 5114 ND PACKER-BAKER C-1 ZXP LINER TOP ISOLATION PACKER @ 7689 MD and 5326 ND PACKER-BAKER DUAL SMALL PACKERS @ 8580' MD and 5958'ND PACKER-BAKER MODEL'D'PERMANENT PACKER @ 8655 MD and 6018 ND NIPPLE-CAMCO DS NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation • shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory Development 1— Service F7 Stratigraphic 16.Well Status after work: Oil r Gas r WDSPL r- Daily Report of Well Operations XXX GSTOR F WINJ iv WAG GINJ r SUSP E 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: 313-145 Contact Brett Packer @ 265-6845 Email J.Brett.Packercop.com Printed Name J.�Brett Packer Title Wells Engineer Signature �iv"` -- Phone:265-6845 Date L'(L / / C Form 10-404 Revised 10/2012 3� 13 �'� ��lf� Submit Original Only RBDMS JUL 2 2W3' r KUP 1F-16A ConocoPhillips Well Attributes Max Angle&MD TD Wellbore API1UWI Field Name Well Status Intl(1 MD(ftKB) Act Btm OMB) 500292102901 KUPARUKRIVERUNIT INJ 57.93 6,700.16 9,175.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date -- Co cony -I r-t sA fir4/2o13 10 00 44 AM SSSV:NIPPLE Last WO: 5/28/2013 30.02 11/15/1983 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,501.0 11/26/2011 Rev Reason:WORKOVER osborl 6/3/2013 Casing Strings HANGER.2] Casing Description String 0... String ID...Top(01301 Set Depth(f...Set Depth(TVD)... String Wt_.String... String Top Thrd CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 29.0 4,496.0 3,461.7 36.00 J-55 BTC (Top 19 jts 47#) Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION-Post 7 6.276 32.1 7,900.0 5,459.8 26.00 J-55 BTC Sidetrack Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd WINDOW A 7 6.000 7,867.0 7,879.0 5,446.0 CONDUCTOR, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 30-1 to LINER 5 4.276 7,689.4 8,984.4 6,284.0 18.00 L-80 Buttress Liner Details NIPPLE.515 I% Top Depth (TVD) Top not Nomi... al Top(ftKB) (RKB) 1'1 Item Description Comment ID(i^) 7,689.4 5,326.4 51.46 PACKER BAKER'C-2'ZXP LINER TOP ISOLATION PACKER w/6'TIE BACK 4.408 RECEPTACLE GAS LIFT, 7,703.0 5,334.5 50.88 HANGER BAKER FLEX-LOCK HYDRAULIC LINER HANGER 4.276 3,146 fin I Tubing Strings Tubing Description string 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd TUBING WO 3 1/2 2.992 I 26.7 I 8,659.9 6,021.4 9.30 L-80 EUE-MOD Completion Details SURFACE , L Top Depth Nomi... (,29 t.4W (TVD) Top Intl 47#),29<,498 RKB Top(Rice) (ftKB) 19 Item Description Comment '" GAS LIFT, ]. 26.7 26.7 0.25 HANGER FMC TUBING HANGER 3.500 5,053 1[...... 515.4 515.4 0.62 NIPPLE CAMCO DS NIPPLE 2.875 7,311.6 5,096.5 53.60 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 GAS LIFT, 6,371 - { 7,322.1 5,102.6 53.53 PBR BAKER PBR 2.990 [ 1 7,342.1 5,114.4 53.41 PACKER BAKER FHL PACKER 2.910 7,394.7 5,145.8 53.08 NIPPLE CAMCO DS NIPPLE w/RHC PLUG 2.812 8,579.9 5,957.8 38.71 Swell Packer REACTIVE ELEMENT CSG PACKER 3.000 8,652.3 6,015.6 38.63 LOCATOR BAKER G-22 LOCATOR 2.406 GAS LIFT, r 7,257 t 8,654.0 6,016.9 38.60 SEAL ASSY BAKER G-22 SEAL ASSEMBLY 2.406 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD( To Intl SEAL ASSY, - Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) PBR,7,322 - 8,655.0 6,017.6 38.59 PACKER BAKER MODEL'D'PERMANENT PACKER SET IN 5" 11/13/2001 3.680 PACKER.7.342 LINER-TUBING COMPLETION STABS INTO PACKER NMI VIII Perforations&Slots ® Shot NIPPLE.7.395 Top(TVD) Btm(TVD) Dens INN Top(f9031 Btm(ftKB) (ftKB) (ftKB) Zone Date Ish... Type Comment 8,516.0 8,536.0 5,908.2 5,923.6 C-4,1F-16A 11/12/2001 6.0 IPERF 3 3/8"HSD Powershot,60 deg phase 8,540.0 8,560.0 5,926.7 5,942.3 C-4,1F-16A 11/12/2001 6.0 IPERF 33/8"HSD Powershot,60 deg phase GAS LIFT. 447 8,690.0 8,704.0 6,044.7 6,055.6 A-5,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing IMII 8,692.0 8,702.0 6,046.2 6,054.0 A-5,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient MN 8,726.0 8,752.0 6,072.9 6,093.7 A-4,1F-16A 11/30/2001 4.0 APERF Energjet,0 deg phasing 8,728.0 8,738.0 6,074.51 6,082.5 A-4,1F-16A 2/15/2002 4.0 APERF 1-11/16"Pivot,0 orient • Stimulations&Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) WINDOW A, '.' (ftKB) (ftKB) (BOB) (ftKB) Type Date Comment 7.867-7,879 N. 8,690.0 8,752.0 6,044.7 6,093.7 HPBD-INITIAL 12/1/2001 PRODUCTION f -Pent 8,690.0 8,752.0 6,044.7 6,093.7 HPBD-#2 3/3/2002 Sidetrack, 32-7,900 Notes:General&Safety End Date Annotation IPERF' 8.516-8,536 ( �'- 11/15/2001 NOTE:WELL SIDETRACKED 'I IPERF, 11/15/2001 NOTE:WORKOVER 8,5404.560 t ' stall,I 11/3/2009 NOTE:View Schematic w/Alaska Schematic9.0 Swell Packer, ii. 11/3/2009 8,580 LOCATOR. 8.652 1 � SEAL ASSY, Mandrel Details I 8,654 1 .., -� Top Depth Top Port PACKER.8,655 --" 5... (TVD) Inc' OD Valve Latch Size TRO Run N...Top(R1(13) (ftKB) (') Make Model (in) Sery Type Type (i^) (pei) Run Date Corn... APERF, 1 3,156.0 2,604.9 50.34 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 5/28/2013 DCK2 B,fi904,704 APERF, 2 5,063.1 3,812.1 53.77 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 8,8924,702 HPBD- " 3 6,370.6 4,575.3 56.92 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 INITIAL,8,690 '� HPBD-a2, k 4 7,257.3 5,064.0 53.86 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 8,690 APERF, 6 8,7284,73 5 7,447.2 5,177.5 52.76 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 5/28/2013 8 APERF, 4 8,7264,752 LINER, 7.6894,984 TD(1F-16A). 8,990 • 1F-16A Pre-Rig Well Work Summary • DATE SUMMARY 4/2/2013 E RWO): FT LDS-ALL FUNCTIONED PROPERLY. T POT- PASSED. T PPPOT- PASSED. IC POT- PASSED. IC PPPOT- PASSED. MITOA- PASSED. 4/16/2013 SET CATCHER @ 7530' RKB. PULLED DV @ 7366' RKB. IN PROGRESS. 4/17/2013 PULLED CATCHER &WRP f/7530' RKB. ATTEPTED SHIFT CMU @ 8578' RKB. IN PROGRESS. 4/18/2013 ATTEMPTED SHIFT CMU @ 8578' RKB, NO SUCCESS. IN PROGRESS. 4/19/2013 PULLED DV @ 7542' RKB. MEASURED BHP @ 8675' SLM/8692' RKB: 2960 PSI. COMPLETE. • • Con©c©Phillips Time Log & Summary We!/view Web Reporting Report Well Name: 1F-16 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 5/21/2013 3:00:00 PM Rig Release: 5/29/2013 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 05/20/2013 24 hr Summary Camp moved from 3C to 1L 13:00-16:00. Rig released 17:00. Modules on 1F @ 20:00,sub on 1F 01:30 5/21. 17:00 00:00 7.00 MIRU MOVE MOB P Move rig modules to from 3C to 1F. Camp on 1L.Sub past CPF-3 @ midnite. 05/21/2013 Complete rig move to 1 F-16A and R/U. Dropped tongs 4'from forklift due broken strap, no injuries. R/U tiger tank and choke skid.3.5 bbl spill in containment while offloading brine to pits.Accept rig @ 15:00 hrs. Lubricate out BPV, R/U t/displace.Attempt to displace, no communication between Tbg/IA. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Repair cold start/clear radiator on Sub at CPF3. 01:00 03:00 2.00 0 0 MIRU MOVE MOB P Move Sub from CPF3 to 1F-16A. 03:00 05:15 2.25 0 0 MIRU MOVE MOB P Spot Sub over 1F-16A 05:15 10:30 5.25 0 0 MIRU MOVE MOB P Set matting boards,set complexes, rockwasher,pipeshed 10:30 12:00 1.50 0 0 MIRU MOVE MOB P Build Handy Berm around Rockwasher, hook-up interconnects and electrical service lines. Install drain plugs in centrifugal pumps. hook up steam lines. 12:00 15:00 3.00 0 0 MIRU MOVE MOB P PJSM. Hook up H2O,Air, Berm RAN and Enviro Vac/Boiler Tanks,Work on Rig Acceptance checklist. Rig accepted at 15:00. 15:00 15:30 0.50 0 0 MIRU MOVE MOB P PJSM. Hook up Circulation hoses, Rig Up Tiger Tank and Hardlines, take on Brine. 15:30 16:00 0.50 0 0 MIRU MOVE SFTY X Safety Stand Down With Company Rep,Tool Pusher, DDI HSE and all Rig hands. Discuss recent incidents and re-focus. 16:00 18:00 2.00 0 0 MIRU WHDBO RURD P PJSM, R/U and test lubricator. Pull BPV.Tubing pressure=800 psi, IA pressure=480 psi. Bleed off tubing to 0. 18:00 19:45 1.75 0 0 MIRU WHDBO RURD P Set up and hook up hard lines to choke skid and tiger tank.Cut back 11.0 ppg brine to 9.8 ppg. 19:45 21:15 1.50 0 0 MIRU WELCT[KLWL P PJSM-Ensure lines are clear, PT lines to 3500 psi.Attempt to pump 9.8 ppg brine down tubing taking returns out IA to tiger tank through choke. ICP-750 psi @ 2 bpm. Pressured up to 1550 psi,vent little gas at tank, no returns after 85 bbl pumped.Call eng,decide to pump down IA. Page 1 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:45 1.50 0 0 MIRU WELCTI KLWL T Pump down IA for 6 bbl no returns, pressure up to 1500 psi S/D. Pressure bled to 1400 psi 5 min. Pressure up to 3000 psi and shut in, bled to 2500 3 min. Pump up t/3000 psi shut in, bled to 2400 psi 10 min. Bleed all pressure form surface,shut in and wait on LRS and HES Eline. 22:45 00:00 1.25 0 0 MIRU WELCTL PULD P PJSM-Load pipe shed with 280 jts 4" DP and process. IA=480 psi, OA=200 psi,Tbg=800 psi. 35/22/2013 Attempted to Circ hot kill fluid around, no circ. Punch hole w/E-line at 7,350'. Pumped 6 bbls away trying to establish circulation. R/U LRS and pump 200 degree brine to free possible ice plug, no significant returns. R/U HES t/set WRP in tubing below packer. 00:00 00:30 0.50 0 0 MIRU WELCTISFTY X Safety Stand Down with Company Rep, Doyon Tour Pusher and Rig Crew. 00:30 01:45 1.25 0 0 MIRU WELCTL KLWL T PJSM-R/U Little Red, PT lines to 3000 psi, Bull head 60 bbl at 200 degrees, 9.8ppg brine,down tubing @ 1.3 bpm ICP=750psi on tubing,50 psi on IA, FCP=1.3 bpm 1100psi on tubing, 1400 psi on IA. 01:45 02:45 1.00 0 0 MIRU WELCTI KLWL T S/D and R/D Little Red Svc,monitor pressures. FP on tubing=650 psi, IA= 1450 psi OA=500 psi 02:45 04:00 1.25 0 0 MIRU WELCTL KLWL T R/U,attempt to establish circulation, pump 15 bbl down tubing 2 bpm 1200psi w/no returns out of IA. Line up to pump down IA 2 bpm, pressure up to 3000psi with no returns from tubing, pumped 9 bbl. Bleed off IA and tubing to 0 psi,blow down circulating lines. 04:00 06:00 2.00 0 0 MIRU WELCTI KLWL T Spot E-line unit, PU tools to Rig flr. 06:00 07:45 1.75 0 0 MIRU WELCTL KLWL T PJSM-RU lubricator,MU tools,test lubricator to 2000psi. 07:45 09:30 1.75 0 0 MIRU WELCTI KLWL T RIH w/tubing punch gun,fire at 7350'MD,Attempt to establish circ, pump 6 bbl down tubing @ 2 bpm, FP 800psi, no returns from IA. Bleed off tubing, IA=Opsi Total pumped down hole loss:92 bbl 09:30 11:00 1.50 0 0 MIRU WELCTL KLWL T R/D HES Eline. 11:00 12:00 1.00 0 0 MIRU WELCTI KLWL T Spot Little Red Svc's. 12:00 12:30 0.50 0 0 MIRU WELCTL KLWL T PJSM-Continue Spot Little Red 12:30 14:30 2.00 0 0 MIRU WELCTL KLWL T PJSM-Pump 64 bbl of 200 degree, 9.8 ppg brine down tubing @ 800psi, 1 bpm, no returns at Tiger Tank. 14:30 16:00 1.50 0 0 MIRU WELCTL KLWL T Shut in tubing and monitor tiger tank for returns, initial shut in pressure= 800psi,final shut-in press=120psi. SIMOPS load pipeshed w/4"DP and strap. Page 2 of 9 • • Time,Logs Date From To Our S.Depth E. Depth Phase Code Subcode T Comment 16:00 18:30 2.50 0 0 MIRU WELCTL KLWL T LRS preheat brine to 200 degrees, hook up LRS to IA, PT lines to 3000 psi, pump 19.5 bbl of 9.8 brine @ 1 bpm/200psi,2bpm/900psi. 18:30 19:00 0.50 0 0 MIRU WELCTL OWFF T Monitor shut in pressure on IA of 900 psi, bled to 650 psi in 30 minutes. pressure bled to 600 psi. 19:00 20:00 1.00 0 0 MIRU WELCTL KLWL T Pump additional 18 bbl 200 degree brine down IA, up to 1500 psi shut in. Bled to 1050 psi 10 min. Pump up to 2000 psi w/1 bbl shut in to monitor. 20:00 20:30 0.50 0 0 MIRU WELCTL OWFF T Monitor well,bled down f/2000 t/ 1300 psi 25 min. Line up to pump down tubing. 20:30 21:30 1.00 0 0 MIRU WELCTL KLWL T Pump 16 bbl,200 degree F 9.8 ppg brine down tubing @ 2 bpm-1000 psi, then 40 bbl @ 1 bpm-850 psi. Slight returns to tiger tank from IA.Shut in to monitor and swap to rig pumps. OA=1800 psi 21:30 22:00 0.50 0 0 MIRU WELCTL OWFF T Monitor well,tubing pressure bled to 250 psi over 40 minutes. R/D and release LRS and brine truck. Bleed OA to 200 psi 22:00 23:00 1.00 0 0 MIRU WELCTL KLWL T Pump 66 bbl 100 degree F 9.8 ppg brine down tubing from rig pits down tubing @ 1 bpm, 850 psi-no returns out IA. Increase rate t/1.7 bpm @ 1100 psi-slight returns observed. Decide to set WRP w/HES- en-route.Shut down pumping ops, shut in well, bleed pressure and blow down lines. 23:00 00:00 1.00 0 0 MIRU WELCTL PULD T Load pipe shed w/4"Drill pipe and process. HES Eline on location @ 23:00 hrs and start rigging up to set WRP. Total pumped 226, lost to formation tour= 196 Total to formation 288 bbl. 0 MIRU 05/23/2013 Set plug, NU BOP,Test BOP.C/O annular element due failure on 2-7/8"test jt. 00:00 01:00 1.00 0 0 MIRU WHDBO RURD T Spot HES E-Line unit. Load lubricator extension in pipe shed. 01:00 02:30 1.50 0 0 MIRU WHDBO RURD T PJSM, R/U E-line, M/U tool w/WRP plug. 02:30 03:00 0.50 0 0 MIRU WHDBO PRTS T Pressure test lubricator t/1500 psi. Check pressure on Tbg=0, IA=700 psi. Bleed IA to tiger tank. 03:00 04:30 1.50 0 7,520 MIRU WHDBO ELNE T RIH w/E-line, make CCL pass and set WRP plug @ 7520'MD center of element, in between collars. 04:30 06:15 1.75 7,520 0 MIRU WHDBO ELNE T POOH w/E-line and R/D same. Tbg=O psi, IA 500 psi. Page 3 of 9 • • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06:15 07:45 1.50 0 0 MIRU WHDBO KLWL T Bleed IA to 0 psi,start pumping down tubing w/9.8 ppg NaCI brine taking returns to tiger tank. Pump 3 bpm, ICP 300 psi, IA 100 psi. FCP 400 psi, IA 160 psi. Pumped 270 bbl down tubing,vented gas for the first 118 bbl followed by 152 bbl brine/seawater. 07:45 08:15 0.50 0 0 MIRU WHDBO OWFF T Monitor well 30 minutes-static. 08:15 08:45 0.50 0 0 MIRU WHDBO SEQP P Blow down circ lines,set BPV and blanking plug. 08:45 09:45 1.00 0 0 MIRU WHDBO RURD P PJSM, rig down circ lines and scaffolding. 09:45 10:45 1.00 0 0 MIRU WHDBO NUND P PJSM, N/D tree and adapter flange, FMC prep tree for removal. 10:45 12:00 1.25 0 0 MIRU WHDBO NUND P PJSM, N/U adapter flange and BOPE. 12:00 13:30 1.50 0 0 MIRU WHDBO NUND P PJSM, Continue N/U adapter flange and BOPE. 13:30 14:15 0.75 0 0 MIRU WHDBO RURD P R/U t/test BOPE. 14:15 20:15 6.00 0 0 MIRU WHDBO BOPE P PJSM,Test BOPE:Test w/4"test jt,#1 Upper VBR pipe rams(,valve 1, 12,13,14 and manual kill,#2 upper IBOP, HCR kill,valves 9&11,#3 lower IBOP,valves 5,8 and 10,#4 Dart valve,valves 4,6,7,#5 Floor valve and valve 2,#6 HCR choke,4" kill line Demco valve,#7 manual choke valve, HCR kill,#8 annular preventer,#9 lower pipe rams,#10 Blind rams,valve 3. 20:15 23:00 2.75 0 0 MIRU WHDBO BOPE P Accumulater test system pressure 3000 psi, pressure after closing all 1800 psi,200 psi attained:40 seconds,full pressure attained: 170 seconds. N2 bottle average-2075 psi. 3-1/2"test joint, upper VBR, lower VBR,annular preventer.2-7/8"test jt, upper VBR, lower VBR. Leak down on 2-7/8"annular test. Upper and lower VBR's 2-7/8"x 5".Test waived by State of AK AOGCC Jeff Turkington. 23:00 00:00 1.00 0 0 MIRU WHDBO RURD T PJSM-R/D Test equip, B/D choke manifold and choke&kill lines. Clean and clear rig floor,tested mud pump popoff,vac out stack. Prep to C/O Annular preventer element. 05/24/2013 Complete BOPE testing, retrieve WRP plug. Pull tubing hanger and POOH, UD 3-1/2"tubing completion f/7450'MD t/3232'MD.Spot Polymer pill, losses 4 bph. 00:00 00:15 0.25 0 0 MIRU WHDBO SFTY T PJSM, HRW and HRC on changing out Hydril element. 00:15 04:30 4.25 0 0 MIRU WHDBO RURD T Changeout Hydril Element. 04:30 05:15 0.75 0 0 MIRU WHDBO RURD T Function test Hydril and R/U test. Page 4 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 08:15 3.00 0 0 MIRU WHDBO BOPE P Test Annular w/2.875", 3.5"and 4" Test Jts t 250/3500 psi for 5 min. 08:15 09:00 0.75 0 0 COMPZ RPCOM BOPE P Pull blanking plug and BPV as per FMC rep. (no pressure) 09:00 09:15 0.25 0 0 COMPZ RPCOM BOPE P Blow down choke,choke line and kill line 09:15 09:30 0.25 0 0 COMPZ RPCOM SFTY T PJSM-P/U and M/U slickline. 09:30 12:00 2.50 0 0 COMPZ RPCOM SLKL T P/U and R/U Slickline as per Halliburton rep and test to 500 psi. 12:00 14:00 2.00 0 7,520 COMPZ RPCOM SLKL T PJSM-RIH w/slickline retrieve WRP, POOH UD same. 14:00 14:30 0.50 7,520 7,450 COMPZ RPCOM SLKL T R/D Slickline, R/U to pull tubing hanger and circulate. 14:30 15:30 1.00 7,450 7,450 COMPZ RPCOM CIRC T PJSM-Bleed IA to zero, R/U to reverse circulate, BOLDS, Unseat tubing hanger at 95k,turn on trip tank at 15.8 bbl to fill hole,pull hanger to rig floor,monitor well (losses observed), R/U to circ long way. 15:30 18:30 3.00 7,450 7,450 COMPZ RPCOM CIRC P CBU @ 2 bpm, 175 psi ICP,400 psi FCP, losing 35-40%returns, pump 25 bbl HEC LCM pill @ 2 bpm,spot at 7340'MD.Shut down and monitor for 30 min, (Losses observed)Cont CBU @ 2 bpm for 75 bbl,220 psi,3 bpm,300 psi,80%returns. 18:30 19:30 1.00 7,450 7,450 COMPZ RPCOM OWFF P Pump and spot 25 bbl-3ppb Flozan pill,monitor for 30 min. 19:30 00:00 4.50 7,450 3,232 COMPZ RPCOM PULL P PJSM-UD 3.5"tubing. UD landing jt,tubing hanger, R/D and B/D circ equipment. UD 3.5"tubing, 135 jts total.Calc Fill=14.4 bbl,Actual Fill=27.03 bbl. Total brine lost to formation today 100 bbl, cummulative to formation 388 bbl.Current 4 bph loss. Kick while tripping drill @ 23:30,shut in @ 1:08 min,all crew 1:24 min. 05/25/2013 P/U Baker Fishing assembly,single in and engage PBR. Release packer @ 7464'MD,CBU and POOH w/ fish to collars @ 298'MD. 00:00 01:15 1.25 3,232 3,232 COMPZ RPCOM PULL P PJSM-UD 3.5"tubing. 01:15 02:15 1.00 3,232 3,232 COMPZ RPCOM RURD P Strap tubing and empty pipeshed. 02:15 03:30 1.25 3,232 0 COMPZ RPCOM PULL P Cont. UD 3.5"tubing.236 jts tubing, space out pups,2 DS Nipples, 1 GLM and 1 seal assy. (7,446.84' total strapped) Actual fill=19.04 bbl,Calc fill=10.9 bbl. 03:30 04:30 1.00 0 0 COMPZ RPCOM RURD P Clean and Clear rig floor and strap and empty out pipe shed. 04:30 04:45 0.25 0 0 COMPZ RPCOM SEQP P Install 6.4375"wear ring. 04:45 05:00 0.25 0 0 COMPZ RPCOM RURD P Load and strap collars in pipeshed. Clear Cameron tools off floor. 05:00 05:30 0.50 0 0 COMPZ RPCOM RURD P Mobilize Baker Tools to rig floor. Page 5 of 9 • i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 05:45 0.25 0 0 COMPZ RPCOM PULD P PJSM-M/U BHA 05:45 06:45 1.00 0 298 COMPZ RPCOM PULD P M/U BHA#1 as per Baker Rep. 06:45 12:00 5.25 298 6,428 COMPZ RPCOM TRIP P Single in hole with 4"DP from 298'to 6428'.actual displacement=30.77 bbl,Calc displacement=37.51 bbl 12:00 14:30 2.50 6,428 7,452 COMPZ RPCOM TRIP P PJSM-Cont single in hole w/4"to 7434'MD, Kelly up establish Parameters,obtain SPRs, P/U= 127k,S/O=92k, ROT= 105k,4k TQ @ 10rpm, RIH latch on to fish @ 7452'MD,ensure good latch. 14:30 15:30 1.00 7,452 7,452 COMPZ RPCOM FISH P Straight pull to 185k x 2 increasing at 5k intervals to 230k,decision made to jar up, 1 hit @ 200k,cont to Jar up @ 230k and overpull to 240k, jar down several times,break circ 2bpm @ 110 psi for 5 min,cont to jar up/dn until free, P/U=142k,S/0= 95k 15:30 15:45 0.25 7,452 7,371 COMPZ RPCOM OWFF P Monitor well,slight flow observed at flow line, rk back stand 15:45 17:45 2.00 7,371 7,371 COMPZ RPCOM PULL P CBU @ 2bpm @ 110 psi,observed increasing losses, back pumps to 1.5 bpm,350psi,pump 25 bbl 3ppb flowzan pill,spot on bottom,monitor well 10 min. 17:45 18:00 0.25 7,371 6,900 COMPZ RPCOM PULL P POOH from 7371'to 6900'MD, Calculated fill=2.7 bbl,Actual fill= 1.36 bbl, P/U=135k,S/O=92k 18:00 19:45 1.75 6,900 6,900 COMPZ RPCOM OWFF P Monitor well 15 min(static), Break Circ @ 5bpm,75psi,for 100 strokes, 0 losses, continue monitor well 30 min, (static) 19:45 23:30 3.75 6,900 298 COMPZ RPCOM PULL P PJSM-POOH from 6900'MDto 298' MD(collars),Calculated fill=37.8 bbl,Actual fill=40.83 bbl, P/U=50k 5/0=50k 23:30 00:00 0.50 298 298 COMPZ RPCOM OWFF P Monitor Well @ collars(static) Total losses for day=96 bbl, Cumulative losses to formation=484 bbl 05/26/2013 Clean out assembly P/U, run, UD. 00:00 00:30 0.50 298 0 COMPZ RPCOM PULL P PJSM Rack back 3 stds, collars, UD bumper sub and Jars. 00:30 00:45 0.25 0 0 COMPZ RPCOM RURD P R/U Power Tongs. 00:45 01:00 0.25 0 0 COMPZ RPCOM PULL P UD packer as per Baker Rep. 01:00 01:30 0.50 0 0 COMPZ RPCOM PULL P UD 2 Jts 3.5"tubing,4 blast jts and seal assembly. 01:30 03:15 1.75 0 0 COMPZ RPCOM PULL P UD 32 Jts.2.875"tubing,4 blast joints and seal assembly. (total length of fish=1209.26')Actual fill= 8.5 bbl, Calculated fill=8.88 bbl. 03:15 03:30 0.25 0 0 COMPZ RPCOM RURD P Clean and Clear rig floor Page 6 of 9 • • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 0 0 COMPZ RPCOM SFTY P CPAI Safety Stand down on spills and dropped objects. 04:00 04:15 0.25 0 0 COMPZ WELLPF RURD P PJSM on P/U and M/U Clean out run assy. 04:15 07:00 2.75 0 1,036 COMPZ WELLPF PULD P P/U Baker Tools from beaver slide and M/U BHA#2 as per Baker rep. 07:00 07:15 0.25 1,036 1,314 COMPZ WELLPF PULD P P/U 3 stds of collars. 07:15 10:15 3.00 1,314 8,612 COMPZ WELLPF PULD P RIH from 1314'MD tagging up @ 8612'MD.Actual displacement 50.49 bbl, Calculated displacement= 53.11 bbl. 10:15 10:30 0.25 8,612 8,612 COMPZ WELLPF REAM P Establish parameters, P/U wt= 145k,S/O wt=93k,TQ=4k,3 bpm =390 psi. 10:30 12:00 1.50 8,612 8,660 COMPZ WELLPF REAM P Wash and Ream from 8612'to 8660' MD @ 5 bpm,950 psi,40 rpm,TQ= 5k.Working through perfs three times from 8516'to 8560'MD. 12:00 13:00 1.00 8,660 8,660 COMPZ WELLPF CIRC P PJSM-Cont CBU, pump 24 bbl 3 ppb Flozan Hi-vis sweep @ 5 bpm, 1050 psi,38%flow out, nothing noticable with sweep. 13:00 15:00 2.00 8,660 8,660 COMPZ WELLPF OWFF P Monitor Well(Slight flow observed). Observed until static.SIMOPS drifting tubing in pipeshed. 15:00 15:30 0.50 8,660 8,198 COMPZ WELLPF PULD P PJSM-Pull 5 stands,from 8660'MD to 8198'MD,Calculated fill=2.7 bbl, Actual fill=2.98 bbl, P/U 145k,S/0 =90k 15:30 15:45 0.25 8,198 8,198 COMPZ WELLPF OWFF P Monitor Well(static) 15:45 18:45 3.00 8,198 1,314 COMPZ WELLPF PULD P Pull 5 stds,from 8198'MD to 7727' MD, B/D top drive,cont POOH from 7727'MD to 1314'MD.Calculated fill =42.12 bbl,Actual fill=45.41 bbl. 18:45 19:00 0.25 1,314 1,314 COMPZ WELLPF OWFF P Monitor well at collars(static) 19:00 22:15 3.25 1,314 0 COMPZ WELLPF PULD P PJSM-C/O Elevators, Prep Rig floor to UD pipe, POOH UD 9 collars, clean and clear rig floor, UD excess tools, R/U Power Tongs, UD 31 joints 2 7/8"pac pipe,X-O's,sptring mill,.mule shoe,calculated=9.93 bbl,Actual=11.05 bbl. 22:15 22:45 0.50 0 0 COMPZ WELLPF PULD P PJSM-Clean and clear rig floor, UD excess tools down beaver slide. 22:45 00:00 1.25 0 0 COMPZ EVALWE RURD P PJSM-R/D riser and riser flange for shooting flange N/U. Total losses to formation today=47 bbl, Cumulative for well=546 bbl. 05/27/2013 Run wireline caliper log, R/D wireline, R/U casing and RIH. Land selective completion. 00:00 01:30 1.50 0 0 COMPZ EVALWE RURD P PJSM-N/U shooting flange. 01:30 01:45 0.25 0 0 COMPZ EVALWE RURD P Prep wireline tool for P/U. 01:45 02:00 0.25 0 0 COMPZ EVALWE RURD P PJSM on P/U and M/U wireline. Page 7 of 9 • i Time Logs Date From To, ' Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 02:45 0.75 0 0 COMPZ EVALWE RURD P P/U and M/U wireline as per Halliburton Rep. 02:45 06:45 4.00 0 0 COMPZ EVALWE SRVY P RIH with caliper to model"D"packer @ 8662'MD, logging 5"and 7"back to surface. 06:45 07:30 0.75 0 0 COMPZ EVALWE RURD P R/D wireline as per Halliburton Rep. 07:30 09:15 1.75 0 0 COMPZ EVALWE RURD P PJSM-N/D shooting flange, N/U adapter flange and riser. (Pull wear bushing) 09:15 09:30 0.25 0 0 COMPZ EVALWE SFTY P PJSM-Slip and Cut line. 09:30 10:30 1.00 0 0 COMPZ EVALWE SLPC P Slip and Cut 117' Drilling line(18 wraps) 10:30 11:00 0.50 0 0 COMPZ RPCOM SVRG P Service Top Drive. 11:00 12:00 1.00 0 0 COMPZ RPCOM RURD P R/U to run 3.5"completion. 12:00 12:30 0.50 0 0 COMPZ RPCOM RCST P PJSM-Running Completion,Cont R/U to run 3.5"tubing. 12:30 21:15 8.75 0 8,652 COMPZ RPCOM RCST P Run 3.5"tubing per detail.,270 joints, P/U=93k,S/O=68k, calculated=28.98 bbls, actual= 18.53 bbls. 21:15 22:30 1.25 8,652 8,664 COMPZ RPCOM RCST P PJSM-P/U 12'pup joint M/U on joint 271, M/U circ head, rig up to circ, apply 150 psi tubing pressure, RIH, P/U joint 272, RIH sting into seal assemlbly(200 psi)and tag locator at @8657'MD, P/U 15', line up to reverse circulate. 22:30 00:00 1.50 8,664 8,664 COMPZ RPCOM CIRC P PJSM-(AAR), Reverse circ inhibited brine @ 1.5 bpm,650 psi for 25 bbls, 2 bpm 875 psi.Total loss to formation today=47 bbl, Cummulative loos for well=593 bbl. 05/28/2013 N/D BOPE, N/U tree, Freeze protect well. Rig down. 00:00 01:00 1.00 8,664 8,664 COMPZ RPCOM CIRC P PJSM-Reverse circulate inhibited brine 9.8ppg @ 2bpm,925 psi,fcp= 975. pumped 238 bbls. 01:00 01:30 0.50 8,664 8,663 COMPZ RPCOM RCST P Drop Ball and Rod and let free fall. fully located, P/U to string wt plus 1 ft. 01:30 01:45 0.25 8,663 8,663 COMPZ RPCOM RCST P Set"FHL"packer @ 7340'MD w 2250 psi,pressure test IA to 1500 psi(good). 01:45 02:00 0.25 8,663 8,656 COMPZ RPCOM HOSO P Shear out PBR, Space out 7 ft fully located. Mark pipe and pull seal for PBR. 02:00 02:45 0.75 8,656 8,656 COMPZ RPCOM HOSO P Space out, UD 3 joints tubing and pup joint. P/U 2 pup joints and 1 joint tubing as per Baker. 02:45 03:30 0.75 8,656 0 COMPZ RPCOM HOSO P M/U Hanger, Drain stack, Land Hanger and RILD as per FMC Rep. Page 8 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:00 1.50 0 0 COMPZ RPCOM PRTS P Pressure test tubing to 3000 psi for 10 minutes. Charted(good). Bleed tubing pressure down to 2500 psi, pressure test IA to 3500 psi for 30 minutes.Charted(good). Bleed IA and tubing pressures to zero. 05:00 05:15 0.25 0 0 COMPZ RPCOM HOSO P Pressure up IA to shear out SOV. Sheared at—1000 psi.observed IA and tubing pressures communicate. Bleed pressures to zero. 05:15 05:30 0.25 0 0 COMPZ RPCOM OWFF P Monitor tubing and IA. (static) 05:30 06:00 0.50 0 0 COMPZ RPCOM RURD P R/D landing joint and test eqpt. (Flush both mud pumps w/fresh water.) 06:00 06:30 0.50 0 0 COMPZ RPCOM PRTS P Set BPV and test IA to 1000 psi. (good) 06:30 06:45 0.25 0 0 COMPZ RPCOM RURD P Blow down choke,choke line and kill line.Clean and clear tools off rig floor. 06:45 08:15 1.50 0 0 COMPZ RPCOM RURD P PJSM-N/D BOPE. 08:15 09:45 1.50 0 0 COMPZ RPCOM PRTS P N/U tree adapter flange and test to 5000 psi for 10 min.(good)as per FMC rep. 09:45 12:00 2.25 0 0 COMPZ RPCOM PRTS P N/U tree,pull BPV, install two-way check valve and test tree and tubing hanger packoffs to 250 psi for 5 minutes and 5000 psi for 10 minutes. Charted. 12:00 12:30 0.50 0 0 COMPZ RPCOM PRTS P PJSM-Continue to test tree to 5000 psi. 12:30 13:15 0.75 0 0 COMPZ RPCOM RURD P PJSM, Pull tree test plug, R/U to pump freeze protect. 13:15 14:30 1.25 0 0 COMPZ RPCOM PULD P PJSM-UD 4"DP via mouse hole, UD 39 joints. 14:30 16:00 1.50 0 0 COMPZ RPCOM FRZP P PJSM-Freeze protect IA with 80 bbls diesel, PT lines to 2000 psi, pumped @ 2 bpm, LRS 900 psi @ pump, B/D lines, R/D LRS. 16:00 17:15 1.25 0 0 COMPZ RPCOM FRZP P Put IA and tubing in communication and U-tube well.SIMOPS UD DP. 17:15 19:45 2.50 0 0 COMPZ RPCOM NUND P PJSM-B/D and R/D lines from U-tube, R/U lubricator and set BPV, R/D lubricator. Install flanges,secure well. 19:45 22:15 2.50 0 0 DEMOB MOVE RURD P PJSM-continue L/D DP via mousehole. 22:15 00:00 1.75 0 0 DEMOB MOVE RURD P Wash out drip pan,steam racks, clean pits, prep rig move. 00:00 00:00 0.00 0 DEMOB RIG RELEASED @ 24:00 hrs Page 9 of 9 " 1F-16A Post-Rig Well Work Summary • DATE SUMMARY 6/4/2013 PULLED BALL & ROD FROM 7370' SLM. PULLED SOV&SET DV @ 3146' RKB. MIT IA TO 2500 PSI (PASS); PULLED RHC PLUG BODY @ 7395' RKB. GAUGED TUBING W/2.80"GAUGE RING TO TAG @ 8649' RKB. CLEAN DRIFT W/ 17.4'x 2.62" DUMMY WHIPSTOCK TO 8648' RKB. COMPLETE. • %, \V/ , ■ THE STATE Alaska Oil and aS ®f l L s T i Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue p Anchorage, Alaska 99501 -3572 F ALAS Main: 907.279.1433 53 Fax: 907.276.7542 J. Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. ao P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1F -16A Sundry Number: 313-145 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this � w of of May, 2013. Encl. III STATE OF ALASKA • 0 57/07L3 •SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS *4 J - "-ro -l3 20 AAC 25.280 ' . ; ;CA F, 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool E Repair w ell 51 Change Approved Program E Suspend r Plug Perforations E Perforate r Pull Tubing I✓ Time Extension E Operational Shutdown V Re -enter Susp. Well r Stimulate r Alter casing ( Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory U 201 -209' 3. Address: Stratigraphic r Service ' . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21029 -01' 7. If perforating, hall 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ 1F • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25652 v Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 8990 6289 8851' 6174' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110' 110' SURFACE 4467 9.625 4496' 3462' PRODUCTION 7678 7 7710' 5339' LINER 1291 5 8980' 6280' I Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8516 - 8536, 8540 - 8560, 8690 - 8704, 8726 - 8752 5908 -5924, 5927 - 5942, 6045- 6056, 6073 -6094 3.5 x 2.875 L -80 _ 8655 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL HYDRO SINGLE STRING PACKER MD= 7464 TVD= 5188 - PACKER - BAKER 'C -2' ZXP LINER ISOLATION PACKER MD= 7689 TVD= 5326' PACKER - BAKER MODEL 'D' PERMANENT PACKER SET IN 5" LINE MD= 8655 TVD= 6017 • NIPPLE - CAMCO DS NIPPLE MD= 486 TVD =486 . 12. Attachments: Description Summary of Proposal . [ 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch r Exploratory IE Stratigraphic E Development r Service Rim 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/22/2013 Oil r Gas r WDSPL r ,Suspended E � 16. Verbal Approval: Date: VVINJ 1 GINJ I — WAG !'' 2 � I andoned r Commission Representative: VLFr .- GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer © 265 -6845 Email: J.Brett.Packert conocophillips.com Printed Name J. 5ett tP Pack k er Title: Wells Engineer Signature �� , �4 Phone: 265 -6845 Date 7/2///3 Commission Use Only r Sundry Number? t 3.-- / � IL/ Conditions of approval: Notify Commission so that a representative may witness f1 y \ Plug Integrity r BOP Test M echanical Integrity Test r Location Clearance E RBDMS MAY 1 0 1013(.� a Other: 30 P trSi to 3� c 4/ rrn4tc pack'rY JaC7�-frIt�!1>. <I ro v C/ ao t 2 S.4J 2(b) M 1T l fl re -- c , , cf ` �t r 3¢ olb1 In� a firr , . , � <Gfi (-7c t5 , lrCf`:a'""\ rr�r J4 r vi -'r! , , 5 arvpru v/ Spacing Exception quired? Yes ❑ No Sbsequent Form Required: j 0 — 4 0 4 I APPROVED BY Approved by: ai4� /21.4v.-tir A ro !ca tion is vali tor D months from the 5 daLc o lapproval. Date: 5- (V /.3 10 2012) 1,•,,,, p Submit Form and Attachments in Duplicate '�► 0 flrGiN L ,,, * � kJ ( N 4/1x - • ConocoPhips Alaska j�` (` P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 1' /� �+O'* - ��''` - ' 1 March 21, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7ch Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Injector 1F -16A (PTD# 201- 209). 1F -16 was originally drilled & completed as a 3 -1/2" selective single A &C sand producer in 1983. The well remained online until 1996 when a leak developed in the selective. After a patch attempt and subsequent HPBD, they could not regain a competent selective and the dominant C -sand had apparently watered out and was hydraulically limiting the A -sand. The well was converted to a water injector in August 1996 and remained on water injection until it was SI in June 1999 for reservoir pressure management. They attempted to cement squeeze the dominant C -sand, and while milling up the cement retainer, accidentally damaged the SBR and developed TxIA communication. In November 2001, the well was worked over and a rotary sidetrack drilled a new lateral into the poorly performing A -sand and a 2'/g" x 3 '/z" selective was installed to be able to isolate the C -sand. The new A -sand lateral quit taking water as early as December 2001. Several HPBD's were performed with short-lived success. In 2005 & 2006, the well was chosen for pit - dewatering in hopes that a poor -boy HPBD would help, but the pit - dewatering only resulted in the well being plugged with sludge and still unable to inject into the A -sand at the current water header pressure. In April 2007, an increase in casing pressure indicated a tubing or packer leak and the well was SI. The well was waivered for water injection only but remained SI while trying to diagnose the leaks. Further investigation with a LDL while pumping down the tubing found a leak in the tubing at 8214' in the C -sand selective while taking returns out the IA, indicating a flowpath via the upper packer. A plug was set above the tubing leak and the tubing passed an MIT -T as well as an MIT -IA, but failed an IA drawdown test, thus confirming the one -way packer leak. Although the well was waivered for water -only injection, ConocoPhillips adopted an internal policy not to inject in wells that have TxIA communication if they have J -55 production casing, which this well does. Therefore, the well is to remain SI until a workover can be performed to restore TxIA integrity. The well was recently chosen as a CTD candidate to drill two laterals into the A -sand. Plans are to kickoff in the selective, so this well needs a workover to upsize the selective which will also replace the upper packer and restore TxIA integrity. The proposed workover plans are to pull the 2 7 /s" x 3 ' /z" selective completion leaving the bottom packer intact, run a casing scraper in both the 7" casing and 5" liner, run a caliper log of both strings, and install a 3 'h" selective with swell packers below the C -sand perfs to isolate the C -sand from the upcoming CTD sidetrack that will kick out in the B -sand. The current selective completion in the well has an upper packer set at 7,464' MD which is 1,052' MD above the top C -sand perfs. We are requesting permission to set the new packer 114 ft higher at 7,350' MD which is just above where the current gas lift mandrel sits (see current schematic). The reasoning for this is that we prefer to not set packers in casing that has been subject to stagnant fluid which is what was between the GLM and the upper packer up until we developed a packer leak in 2007. This Sundry is intended to document the proposed work on the injection well, request permission for the alternate packer placement depth which is outside of 20 AAC 25. 12(b), as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 265 -6845. Sincere Brett Packer Wells Engineer CPAI Drilling and Wells • `, KUP 1F-16A ConocoPhilli Well Attributes Max Angle & MD TD Inc - -. Wellbore APW WI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (1tKB) Alaska, ,_ 5 500292102901 KUPARUK RIVER UNIT INJ 57.93 6,700.16 8,990.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ... Well Coned: .7F•tea3n1rm73torsznM SSSV: NIPPLE Last WO: 11/15/2001 30.02 11/15/1983 Schematic -Actual - Annotation Depth (ftKB) End Date Annotation 'Last Mod ... End Date Last Tag: SLM 7,501.0 11/26/2011 Rev Reason. NIPPLE ID CORRECTION osborl 3/21/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER. 27 I 2' I CONDUCTOR 16 15.060 30.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ' SURFACE 95/8 8.921 29.0 4,496.0 3,461.7 36.00 J -55 BTC r (Top 19 jts 47 #) Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION - Post 7 6.276 32.1 7,710.0 5,339.0 26.00 J -55 BTC Sidetrack Casing Descripgon String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 111 _ LINER 5 4.276 7,689.4 8,980.0 6,280.3 18.00 L - Buttress Liner Details - Top Depth CONDUCTOR, (ND) Top Incl Nomi... 3 0.170 Top (ftKB) (MB) Comment Item Description ID (in) 7,689.4 5,326.4 51.46 PACKER BAKER 'C - 2' ZXP LINER TOP ISOLATION PACKER w /6' TIE BACK 2.680 NIPPLE, 486 RECEPTACLE Mt 7,703.0 5,334.5 50.88 HANGER BAKER FLEX -LOCK HYDRAULIC LINER HANGER 4.276 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 3.5 "x2.875" 31/2 2.992 26.7 8,655.0 6,017.6 9.30 L - 80 EUE8rdMOD SURFACE I L Completion Details (Top ISlie •� Top Depth 47s), 29 4496 (ND) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 26.7 26.7 0.25 HANGER FMC TUBING HANGER 3.500 485.7 485.7 0.52 NIPPLE CAMCO 'DS' NIPPLE w/2.875 NO GO 2.875 ar GAS L IFT, 7,411.9 5,156.1 52.98 NIPPLE CAMCO 'DS' NIPPLE w/2.812 NO GO 2.812 7 ,36fi 7,450.3 5,179.4 52.74 PBR BAKER 80-40 PBR 3.000 7,464.0 5,187.6 52.65 PACKER BAKER FHL HYDRO SINGLE STRING PACKER 3.000 se 7,556.9 5,244.3 51.89 XO CROSSOVER 3.5" x 2.875" 2.875 • 8,498.7 5,894.9 39.48 BLAST JOINTS BLAST JOINTS (OAL = 79.36') 2.440 8,578.1 5,956.4 38.73 SLEEVE BAKER CMU SLIDING SLEEVE; 2.31" BX PROFILE 2.312 PBR. 7,450 8,613.6 5,984.2 ' 38.39 NIPPLE CAMCO D LANDING NIPPLE w /2.25" NO GO 2.250 PACKER, 7,464 8,652.2 6,015.5 38.63 SEAL ASSY BAKER G-22 LOCATOR/SEAL ASSY SPACED OUT 1' ABOVE 2.000 PACKER art Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) WRP, 7.530 Top Depth at (ND) Top lent Top (ftKB) (ttK8) C( Description Comment Run Date ID (in) il 7,530.0 5,227.8 51.98 WRP 2.78" WEATHERFORD WRP 6/1/2012 0.000 GAS LIFT IL 8 6,017.6 38.59 PACKER BAKER MODEL 'D' PERMANENT PACKER SET IN 5" 11/13/2001 3.680 7.542 LINER - TUBING COMPLETION STABS INTO PACKER a II Perforations & Slots as Shot I Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.. Type Comment i , , PRODUCTION 8,516.0 8,536.0 5,908.2 5,923.6 C-4, 1F -16A 11/12/2001 6.0 IPERF 3 3/8" HSD Powershot, 60 deg phase - Pont 3 2 .7, ack , 8,540.0 8,560.0 5,926.7 5,942.3 C-4, 1F -16A 11/12/2001 6.0 IPERF 33/8" HSD Powershot, 60 deg phase 32.7,710 8,690.0 8,704.0 6,044.7 6,055.6 A -5, 1F -16A 11/30/2001 4.0 APERF Energjet, 0 deg phasing 8,692.0 8,702.0 6,046.2 6,054.0 A -5, 1F -16A 2/15/2002 4.0 APERF 1- 11/16" Pivot, 0 orient 8,726.0 8,752.0 6,072.9 6,093.7 A-4, 1F -16A 11/30/2001 4.0 APERF Energjet, 0 deg phasing 8,728.0 8,738.0 6,074.5 6,082.5 A-4, 1F -16A 2/15/2002 4.0 APERF 1- 11/16" Pivot, 0 orient 1a1 Stimulations & Treatments IPERF, Bottom 8,516 -8,536 Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) IPERF, Type Date Comment 8.540 -6.560 8,690.0 8,752.0 6,044.7 6,093.7 HPBD - INITIAL 12/1/2001 8,690.0 8,752.0 6,044.7 6,093.7 HPBD - #2 3/3/2002 SLEEVE, 8.578 Notes: General & Safety End Date Annotation 11/15/2001 NOTE: WELL SIDETRACKED 8 WORKOVER 11/3/2009 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE.8,614 tt• 4/22/2012 NOTE: TUBING LEAK IDENTIFIED w/ LDL @ 8214' RKB I SEAL ASSY, 8,652 b PACKER. 8.655 • APERF. Mandrel Details 8,690 -6,704 Top Depth Top Port APERF. S... (ND) not OD Valve Latch Size TRO Run 8.692-6.702 N... Top (ftKB) (MB) ( °) Make Model (in) Sery Type Type (!n) (psi) Run Date Com... HPBD \ 1 7,366.0 5,128.6 53.26 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/23/2001 INITIAL. 8,690 HPSO - a2, 2 7,542.4 5,235.4 51.94 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/2001 8,690 k' APERF, 8,728 -6,7381 APERF, 67264,752 LINER, 7,669 -6,980 TO(1F -76A), • • 8,990 . • 1F-16A Rig Workover Pull 2'/8" x 3 Selective, Install 3 1 /z" Selective (PTD #: 201 -209) Current Status: This well has been SI since 4/13/07 due to a one -way packer leak and a selective leak. The well has been selected as a CTD candidate, but requires a workover to upsize the tubing to 3 ' /2" in the selective. Scope of Work: Pull the 2 %" x 3 'A" selective completion leaving the bottom packer, install a 3 ' /2" selective w/ swell packers below the C -sand perfs to isolate the C -sand from the upcoming CTD sidetrack that will kick out in the B -sand. General Well info: Well Type: Injector MPSP: 2,152 psi using 0.1 psi/ft gradient Reservoir Pressure /TVD: 2,674 psi / 5,220' TVD (9.9 ppg) from Panex gauges on 11/26/11. (A more recent SBHP will be obtained prior to the RWO.) Wellhead type /pressure rating: FMC Gen 2/4 (retrofitted), 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA passed on 6/20/12, MIT -OA passed on 12/1/08. Earliest Estimated Start Date: May 22, 2012 Production Engineer: Dana Glessner/ David Lagerlef Workover Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Install catcher sub on top of WRP, pull DV at 7366' MD, leave pocket open. b. Pull catcher sub, pull WRP at 7530' MD. c. Open CMU at 8578' MD. d. RIH w/ dual Panex gauges, obtain A/C sand pressure. 2. PT tubing and casing packoffs, FT LDS's. 3. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 10.1 ppg NaC1/NaBr brine. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, un -land hanger, and POOH laying down tubing. 5. MU PBR retrieving tool, and single in on 3 -1/2" IF drillpipe, latch onto PBR and jar FHL packer and seal assembly free. 6. RIH w/ tapered string and double string mills and cleanout to the Model 'D' packer at 8655' MD. 7. RU E -line: RIH w/ caliper and log from 8655' back to surface. 8. MU selective assembly w/ swell packer and FHL packer, RIH to just above the SBE in the Model 'D' packer. 9. Spot corrosion inhibited brine below FHL. 10. Sting into SBE until fully located, space out 1 ft, drop ball & rod, set the FHL w/ 2500 psi. PT the 1A to 2500 psi. Shear the PBR. 11. POOH laying down drillpipe. a. If packoffs need replaced: On TOH, set a storm packer at —100' w/ drillpipe hanging below. RU Hydratight equipment. NDBOP & Tbg head, replace tbg head & IC packoffs, NU BOP & test. Pull storm packer. • 1F-16A Rig Workover Pull 2'/8" x 3 Selective, Install 3 1 /2" Selective (PTD #: 201 -209) -- Procedure Continued-- 12. Redress seal assy. (if needed) and single in w/ new 3 -1/2" tubing. Install SSSV at 2000' MD. Continue RIH to just above the PBR. Sting into PBR, space out 7' from fully located, mark pipe and pull out of PBR. 13. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited brine. Land the hanger, RILDS. 14. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 15. Pull the landing joint, install BPV. 16. ND BOPE, NU tree. Pull BPV install tree test plug, test tree. Pull tree test plug. 17. Swap well over to diesel through the SOV. 18. Set BPV. 19. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV & run DV. 4. Turn well over to CTD. • _ • 2ti u3 v c 3u 1F-16A Proposed Completion (post -RWO) J 3 -1/2" SLB TRMAXX- CMT -5 -SR @ 1800' TVD 9 -5/8" 36# J -55 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface shoe @ 4496' MD 3 -1/2" Camco MMG gas lift mandrel Baker 20' PBR /Seal Assy. Baker FHL Packer @ +/- 7350' =' cZ 33,° 7" 26# J -55 shoe in, b• 3 -1/2" Camco MMG injection mandrel @ +/- 7370' @ 7710' MD _ I " 3 -1/2" IBTM -SCC R2 Tubing (above swell packers) 15 i ` C -sand perfs 8516' 8560' MD x 1 Baker 5ft Dual Swell packers (4 1 "OD) @ +/- 8570' 3 -1/2" IBTM -SCC R3 Tubing (below swell packers) CTD KOP @ 8635' MD ■ ■ Weasox near KOP of 8635' Baker Model D packer @ 8655' MD (existing) A -sand perfs 8690' - 8704' MD 8726' - 8752' MD Retain A -sand Perforations 5" 18# L -80 shoe @8980' MD 4.151" Drift • • • Ferguson, Victoria L (DOA) From: Packer, J.Brett <J. Brett. Packer@conocophillips.com> Sent: Tuesday, May 07, 2013 5:56 PM To: Ferguson, Victoria L (DOA) Subject: RE: Well 1F -16A WO sundry(PTD 201 -209, Sundry 313 -145) Attachments: 1F -16A Sidetrack Sundry Docs (PTD 201- 209).pdf Victoria, I apologize for not responding to your previous email, I didn't realize a question was being asked and that you were waiting on information from me. Here is the information you requested pertaining to your comments regarding the cement on the outside of the 7" casing and the 5" liner. 7" Casing To look at the cement on the outside of the 7" casing, you have to reference the original 1 F -16 well (PTD 183 -153) drilled back in 1983. They ran the 7" casing to a depth of 9064' MD and cemented it with 97 bbls cement. Even assuming 100% washout in the drilled hole, that would put the top of cement at 6916' MD. The original CBL obtained on 11/18/83 logged from 6900' -8953' MD. The log showed really good cement bond from 6900' -7800' MD, acceptable cement from 7800' -8600' MD, and poor cement bonding from 8600' -8953' MD (across the Kuparuk interval). Because they had a poor cement bond across the Kuparuk, prior to running the completion, they perforated the 7" casing from 8634' -8636' and squeezed the 7" casing with an additional 36 bbls cement. The completion was run and the well brought on production. The 1 F -16 well was originally a producer and was online up until April 1996, at which point it was converted to an injector. In 2001, the original well was plugged and the well was sidetracked and became 1F -16A (PTD 201 -209). 5" Liner During the sidetrack in 2001, a 5" liner was run to a new TD of 8990' MD. The 5" liner was cemented in place and a liner top packer set. They ran a USIT log from 7674' - 8875' MD, essentially from the liner top packer down close to TD. They confirmed good cement up to 8190', acceptable cement from 8080' - 8190', and deteriorating quality between 7674'- 8080' MD. They perforated the C -sands from 8516' -8560' MD and then set the bottom permanent packer at 8655' MD. They pressure tested the 7" casing, liner top packer, and 5" liner above the permanent packer to 3000 psi and it tested good. Afterwards, they ran the 3-W x 2-%" selective completion across the C -sand with the upper packer set at 7464' MD and then perforated the A -sands below the bottom permanent packer from 8690' -8738' MD post -rig. This is the completion that is currently in the well. I pulled the Permit to Drill documentation for the sidetrack off the AOGCC website. Back in October 2001, as noted by Tom Maunder, a request was submitted and approved to place the upper packer approximately 1000' above the top C- sand perfs. I've attached those documents for your reference, see "1F-16A Sidetrack Sundry Docs (PTD 201- 209).pdf'. The workover completion we are proposing would simply remove the upper packer and 2- selective completion currently in the well and replace it with an almost identical completion, other than we plan to upsize the tubing in the selective to 3 -1/2" and would like to set the upper packer just 100' higher at 7350' MD. The reason we would like to set the packer 100' higher is because we prefer not to set the packer in casing that has been subject to stagnant fluid, which is what was between the GLM and the upper packer up until we developed a packer leak in 2007. As confirmed from the 7" casing original CBL, we do have good cement up to 6900' MD and most likely higher (6900' was as high as they ran the CBL). This gives us a minimum of 450' of good cement above where we would like to set the new packer. Also, from the USIT log run after the sidetrack, it confirmed we have -436' of good cement above the top C -sand perfs outside the 5" liner. I hope this is adequate information to satisfy your concerns. Please let me know if you have any additional questions. Thanks! 1 • Brett Packs? Ong eZ Wefs Wort fiver Engineer Work# (907) 265 -6845 Cell# (907) 980 -9467 From: Ferguson, Victoria L (DOA) [ mailto: victoria.ferguson(aalaska.gov] Sent: Monday, May 06, 2013 10:50 AM To: Packer, J.Brett Subject: [EXTERNAL]Re: Well 1F -16A WO sundry(PTD 201 -209, Sundry 313 -145) The sundry has not been approved. I'm still waiting for your answer to the email. Sent from my iPhone On May 6, 2013, at 9:51 AM, "Packer, J.Brett" <J. Brett .Packer @conocophillips.com> wrote: Victoria, 1F-16A RWO is coming up in a couple weeks, and looking through my emails I found this email you sent back on 4/10/13 that shows you have assigned a Sundry # to this well, but speaking w/ Sharon, she hadn't received the approved sundry yet. It may have gotten lost in the electronic world, so can you please re -send the approved sundry. Thanks! 3. Brett Tacky Orif" ng eZ Was Workover Engineer Work# (907) 265 -6845 Cell# (907) 980 -9467 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson(aalaska.gov] Sent: Wednesday, April 10, 2013 11:26 AM To: Packer, J.Brett Subject: [EXTERNAL]Well 1F -16A WO sundry(PTD 201 -209, Sundry 313 -145) Brett, Please verify good cement of the 7" casing to 300' above the proposed packer depth of 7350'. Also, verify good cement of the 5" above the C sand perforations. Thanks, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a?alaska.gov 2 • 2o\ -2_a 2 tG -6, 7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED MAY 1 3 2013 RE: Plug Setting Record: 1F -16A Run Date: 6/1/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1F -16A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21029 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com e i f t Date: 7 '� z{ 12y Signed: C� • 24t5Z WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNE 1 3 2U13 RE: Leak Detect Log: 1F -16A Run Date: 4/22/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1F -16A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21029 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: ( /1'2 Signed: • • i <2(.{ IF_ /LA Regg, James B (DOA) Zei ze `i'n From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, February 24, 2012 2:56 AM \- Z1Z4I ( I v To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: Monthly Failed MIT report for January 2012 Jim, Below in the body of your email are my answers to each question. , If there are any other concerns, please call. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 $f.. IE ,� FEB 2111 From: Regg, James B (DOA) [mailto:jim.regg@thalaska.gov] Sent: Monday, February 13, 2012 4:51 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Monthly Failed MIT report for January 2012 What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? This well used to have a wireless pressure transmitter attached to the IA, but it was disconnected several months ago in preparation for an upgrade to a hardwire system. The SCADA system is still set up to read these pressures (which is now essentially reading atmospheric pressure). Unfortunately, the daily well walk pressures are often times not input correctly into the system to allow an overwrite of the erroneous wireless transmitter pressure readings. The issue has been brought to the attention of operations and more diligence will be forthcoming. Any diagnostics done on 1Y -08 (PTD 1830620) to evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? Operations intentionally pressured the IA in order to establish a better dP between the IA and OA. We will be pursuing diagnostics in the next couple of days to investigate further. KRU 2B -06 (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for production csg). Why allow 3100psi to remain on IA? The IA was bled several times in January without success. Based on initial diagnostics where the MITIA passed yet failed an IA drawdown test, a packer leak or other one way leak (from formation into the IA) is suspected. On February 1, the IA finally was able to be bled off to - 1750psi and is currently maintaining pressure below 2000 psi. Slickline /E -line work is now under way to secure the well with a downhole plug which will enable us to pursue further diagnostics. What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? This well has wireless pressure transmitters. Reported daily readings are averaged from the entire day's recordings. Occasionally, the transmitters malfunction temporarily, recording very high pressures (several orders of magnitude above actual pressures). These malfunctions usually only last minutes or seconds; but these erroneously high pressures get calculated into the average, causing the reported daily numbers to show up as spikes. Jim Regg AOGCC 1 • 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617Aconocophillips.com] Sent: Tuesday, February 07, 2012 8:46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 2 • • Regg, James B (DOA) From: Regg, James B (DOA) / Sent: Monday, February 13, 2012 4:51 PM Z ! 3 l Z To: 'NSK Problem Well Supv' Subject: RE: Monthly Failed MIT report for January 2012 ✓What are the short pressure spikes in IA of well 1F -16A (PTD 2012090)? Any diagnostics done on 1Y -08 (PTD 1830620) to evaluate sudden pressure build in IA (100 to 900psi on 1/28/11)? KRU 2B -06 (PTD 1840220) indicates IA pressures have stabilized at 3100 psi (62% of MIYP rating for production csg). Why allow 3100psi to remain on IA? What is reason for unusual OA pressure spikes on KRU 3K -11 (PTD 1861640) 1/23 and 1/26? Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617(aconocophillips.com] Sent: Tuesday, February 07, 2012 8:46 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly Failed MIT report for January 2012 Jim, Guy, Attached is the monthly failed MIT report for January 2012. 2B -06 and CD2 -22 were added due to suspect TxIA communication. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 • • 10. 1G-01 — AA 28.035 issued 7/30/2008. D-0 V — D - 0 Q A 9. 1 F -16A — Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passed since. Well last injected 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. Looking at the pressure plot, it is shown that the IA pressure appears to have been bled off in October and November. Was there well work conducted, maybe plug setting? There is email traffic exchanged regarding "what if" for an OA pressure sensor. Such have been installed on other wells, is that possible here? What are the plans for the well? 8. 1 D -40A — Well name is 1 D -40A. MITIA failed - 10/1/2009. Well last injected 9/09. — 7. 1D-119 Single casing well. MITIA failed 7/16/2010. Well last injected 6/ 2010. 6. 1D-106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C -133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. 4. 1C-10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM .IAN 2 0 201 To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1 A -07, 1 A -12 and 1 B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1 A -12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. P Y 00 — -OS From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 - 7000 #909 • 0 ConocoPhillips Well 1F-16A Injection Data • Water Injection A Gas Injection I 4000 3500 3000 °' 2500 N Q a 2000 v 2 1500 • 1000 500 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd `� / Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected Pressure (mscfpd) (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 822 603 100 30- Dec -10 0 0 808 603 97 29- Dec -10 0 0 800 603 97 28- Dec -10 0 0 795 605 102 27- Dec -10 0 0 798 606 103 26- Dec -10 0 0 798 606 104 25- Dec -10 0 0 802 606 104 24- Dec -10 0 0 794 605 102 23- Dec -10 0 0 788 605 103 22- Dec -10 0 0 806 607 107 21- Dec -10 0 0 824 608 106 20- Dec -10 0 0 818 607 105 19- Dec -10 0 0 798 608 106 18- Dec -10 0 0 789 608 106 17- Dec -10 0 0 789 608 105 16- Dec -10 0 0 797 607 104 15- Dec -10 0 0 792 14- Dec -10 0 0 786 13- Dec -10 0 0 800 600 12- Dec -10 0 0 789 600 11- Dec -10 0 0 777 900 100 10- Dec -10 0 0 787 900 100 9- Dec -10 0 0 787 900 100 8- Dec -10 0 0 780 900 100 7- Dec -10 0 0 768 6- Dec -10 0 0 764 600 100 5- Dec -10 0 0 772 600 100 • • 4- Dec -10 0 0 757 3- Dec -10 0 0 739 550 100 2- Dec -10 0 0 741 550 100 1- Dec -10 0 0 721 600 100 30- Nov -10 0 0 705 600 100 29- Nov -10 0 0 730 600 28- Nov -10 0 0 737 600 100 27- Nov -10 0 0 732 600 100 26- Nov -10 0 0 740 25- Nov -10 0 0 754 600 100 24- Nov -10 0 0 756 600 100 23- Nov -10 0 0 766 22- Nov -10 0 0 736 21- Nov -10 0 0 713 550 20- Nov -10 0 0 702 550 100 19- Nov -10 0 0 673 600 100 18- Nov -10 0 0 653 17- Nov -10 0 0 605 16- Nov -10 0 0 936 100 15- Nov -10 0 0 2488 600 100 14- Nov -10 0 0 2489 600 100 13- Nov -10 0 0 2484 100 12- Nov -10 0 0 2480 600 11- Nov -10 0 0 2482 600 10- Nov -10 0 0 2480 9- Nov -10 0 0 2432 600 8- Nov -10 0 0 2261 600 7- Nov -10 0 0 2207 600 100 6- Nov -10 0 0 2285 600 100 5- Nov -10 0 0 2133 4- Nov -10 0 0 1990 3- Nov -10 0 0 2072 2- Nov -10 0 0 2266 1- Nov -10 0 0 2296 31- Oct -10 0 0 2319 30- Oct -10 0 0 2313 29- Oct -10 0 0 2327 550 100 28- Oct -10 0 0 2350 550 100 27- Oct -10 0 0 2216 26- Oct -10 0 0 2214 25- Oct -10 0 0 2197 600 100 24- Oct -10 0 0 2216 600 100 23- Oct -10 0 0 2173 550 22- Oct -10 0 0 2243 550 21- Oct -10 0 0 1490 20- Oct -10 0 0 1304 600 100 19- Oct -10 0 0 1282 600 100 18- Oct -10 0 0 1236 600 100 17- Oct -10 0 0 1220 600 100 16- Oct -10 0 0 1193 600 100 15- Oct -10 0 0 1182 600 100 14- Oct -10 0 0 1206 600 100 • 0 13- Oct -10 0 0 1181 580 100 12- Oct -10 0 0 1149 580 100 11- Oct -10 0 0 1124 580 100 10- Oct -10 0 0 1075 580 100 9- Oct -10 0 0 1888 580 100 8- Oct -10 0 0 2457 580 100 7- Oct -10 0 0 2450 580 100 6- Oct -10 0 0 2450 580 100 5- Oct -10 0 0 2450 580 100 4- Oct -10 0 0 2450 580 100 3- Oct -10 0 0 2448 580 100 2- Oct -10 0 0 2448 580 100 • • ConocoPhillips Well 1F-16A Injection Data • Tbg Psi IA Psi • OA Psi I 4000 - 3500 3000 a) 2500 - ....... .«■•• •.«••••••• •.. a 2000 - •. 2 1500 - • M 1000 - '+ 500 Ion■ I■r . M - -• �1111111•111 0 •YYY•WWYW Y Y Y W Y Y Y •Y• Y W WM&MUM .Y 09/10 10/10 11/10 12/10 01/11 Date PTD: 2012090 AIO 02B.018 issued 10/17/2007 Reason: TxIA comm, IA DD failed 4/12/07 AOGCC witnessed MITIA passed 06/01/08 MITOA passed 12/01/08 Well has been SI since 04/13/07 AIO 2B.018 requires any pressure bleeds to be reported monthly. No pressure bleeds occurred within the last month. r~ u ~ . ConocoPhill~ps Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 18, 2008 ~ ~~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~c~-ao9 ~I ~-IAA Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 February 13~', 2009. The corrosion inhibitor/sealant was pumped March 4`~, 11 ~' & 16~`, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Pen, ~,..,... ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off _ ~ Report of Sundry Operations (10-404) Kuparuk Field Date 3/16/2009 Well Name 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 bbls ft al 1F-01A 205-029 7" N/A 7" N/A 1.7 3/16/2009 1 F-02 182-211 SF N/A SF N/A 2.90 3/4/2009 1F-03A 196-096 SF N/A SF N/A 2.20 3/4/2009 1 F-04 182-172 20" N/A 20" N/A 5.20 3/4/2009 1 F-05 182-132 SF N/A SF N/A 1.60 3/4/2009 1 F-06 182-145 SF N/A SF N/A 2.10 3/4/2009 1 F-07 182-156 SF N/A SF N/A 2.40 3/4/2009 1F-08 182-162 SF N/A SF N/A 2.20 3/4/2009 1 F-10 183-105 20" NA 20" NA 1.70 3/11 /2009 1F-12 183-136 54' 7.50 5'6" 2/13/2009 18.70 3/11/2009 1F-13 183-144 SF NA 6" NA 1.30 3/11/2009 1F-16A 201-209 SF NA 22" NA 1.70 3/11/2009 • MEMDl~ANDLTM State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 To~ Jim Regg ~ P.I. Supervisor ~~~~(' ~~ S ~(a~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 F-16A FROM: Jeff Jones KUPARUK RIV UNIT iF-16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~~'77(/- NON-CONFIDENTIAL Comm Well Name• KUPARUK RN UNIT 1F-16A API Well Number: 50-029-21029-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ080610122045 Permit Number: 201-209-0 J Inspection Date: 6~1~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1F-16A ;Type Inj. ~ N ~ TVD 5188 ~ IA ~ 900 2490 I 2490 i 2490 I - ---- p•T, zolzo9o TypeTest ~ sPTj Test psi isoo ~~ ao ao '~ ~o ~ ~o Interval 4YRTST per, _ P_ _ ~ Tubing ~ goo ~ goo ~ -- - goo '~ goo ~ ~ NOteS' 1.5 BBLS diesel pumped; no exceptions noted. ~~~~~ ~~j i ~y - -- -- - ^~~~ Wednesday, June 11, 2008 Page I of 1 Mitigation idea • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Tuesday, October 30, 2007 6:54 AM To: Regg, James B (DOA) . Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: Mitigation idea Jim, In reference to injection well types (like 1F-16A (201 -209)) where the surface casing has a burst rating of 3520 psi and we need AA approval to have the IA pressure equalize with injection pressure (w/ DNE 3000 psi), would automated OA pressure indication (PI) tied into an alarm back at the facility be sufficient mitigation to allow the higher IA pressure? Wireless Pi's would take some time (and capital) to install, so we would definitely wait until we had the instrumentation in place before requesting or re submitting AA approval for injection with the new IA DNE pressure criteria, but want to know if the concept is acceptable before we pursue the. Pi's. Please advise. Thanks 5 tANNEDJAN 2 0 201E MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7043 Cell Phone (907) 943 -1687 1/3/2011 1F-16A (PTD 2012090) Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 22, 2007 1:57 PM To: NSK Well Integrity Proj; Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 1 F-16A (PTD 2012090) • Page 1 of 3 MJ, It is a good idea to check the original records. It is possible that whoever set up the electronic files may not appreciate the effects that different weights and grades have on pressure limitations. To some, casing is casing ... Good luck reconciling the information. Tom From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, October 22, 2007 1:54 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: RE: 1F-16A (PTD 2012090) Jim & Tom Thanks for the reply I'll do some more research on the tubulars and get back to you with an acceptable plan (which may be to cancel the AA). Most likely the well will remain SI and go on the workover list, as 1500 psi IA limit may not allow the well enough injection pressure to be in-service. Also, in response to a couple questions you had below: The well was SI very shortly after the communication was identified back in April, therefore the higher IA pressure would only show up the Historic TIO plot for a couple days before it was SI. The request for 3000 psi was Item # 4 on the operating plan in the AA request. The incorrectly identified 9 5/8" casing grade was clearly my error, I trusted our electronic files and did not pull the drilling file. I'll try not to duplicate that error in the future. Thank you for your time and consideration on this well MJ Loveland ~~~ h~AR ~ ~ 20D~ Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, October 22, 2007 1;07 PM To: NSK Well Integrity Proj Cc: Maunder, Thomas E (DOA) Subject: RE: 1F-16A (PTD 2012090) ~~ 3/12/2008 1 F-16A (PTD 2012090) ~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Monday, October 22, 2007 1:20 PM To: Regg, James B (DOA); NSK Well Integrity Proj Subject: RE: 1 F-16A (PTD 2012090) MJ, A few comments from a "historic perspective". 1 F-16 (183-153) was completed in early 1984. The early casing and well head designs were much lower pressure rated than designs from say 1985 on. In particular, I believe the operating design maximum for surface pressure was 3000 psi. I remember a lot of workovers to change out the tubing heads to achieve 5000 psi rating. I have to agree with Jim, the mixture of weights and placement is interesting. It appears that the surface casing may have been run with collapse as the dictating design specification which is not unusual. I wonder if operation with sustained pressure on the surface casing was considered in the design. Tom Maunder, PE AOGCC from: Regg, James B {DOA) Sent: Monday, October 22, 2007 1:07 PM To: NSK Well Integrity Proj Cc: Maunder, Thomas E (DOA) Subject: RE: iF-16A (PTD 2012090) MJ = KRU 1 F-16 an interesting well. The request for admin approval incorrectly identifi a grade of the 9-5/$" surface casing a 5.5ppg J55 with an MIY of roughly 7500psi; our well files show. fixed string of 36#, 43#, and 47# J-55 without an dication of which pipe is where. It appears somewhere ~ he 1 F-16/1 F-16A history the Commission was provid ~ncorrect information on a 10-403 or -404 regar 'the surface casing I questioned the inconsistent info about th asing design; Perry researched and cg med the weakest pipe (36# J-55; MIYP = 3520 psi) makes up the top 4 ~ ints of casing. Also, 1 did not s request for 3000 psi allowance for the IA; I guess one could infer that from the TIA done 5/23/2007. ~ ~ The TIO information available to me indicate ~ at the I essures have been around 1500 psi; our decision has to be based on what is provided in your request re was nothing to indicate a problem maintaining the IA pressure at or below 1500 psi. The pressure li ~ e IA was a response to concerns about the strength of both the production and surface casings. Px ction ca ~ is (according to the info provided) 7", J55, 26ppf. An IA pressure of 3000 psi would be 60 per of the MIYP ratr ~ if that pressure were to reach the OA, it would represent 85 percent of the MIYP ra ~ .The message here wit a 1500 psi IA pressure limit in AIO 26.018 is that injecting with pressures that It in 3000psi in the IA would no a acceptable without mitigation. Monitoring alone is too subjective (and to human error} and thus not sufficient address the risk of communication to the OA in this case. You have the abili request reconsideration and should do that if you are convine the well can be operated safely and are c fortable with the operating pressures relative to the burst ratings fort roduction and surface casings. So a additional investigating of your well file (particularly the casing design) migh appropriate. i would al encourage you to consider something other than the field monitoring practices to avo' the potential for hi OA pressure should you choose to request reconsideration. Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 3/12/2008 • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 17, 2007 9:17 AM To: Regg, James B (DOA) Subject: RE: KRU 1F-16A (PTD 201-209) This is interesting. I saw the report about the suspected 1-way leak. I seem to remember another well out there like that. Don't remember specifically if it was this well. Thanks for the info. I will make sure your note gets to the file. Tom From: Regg, ]ames B (DOA) Sent: Wednesday, October 17, 2007 9:14 AM To: Maunder, Thomas E (DOA) Subject: KRU iF-16A (PTD 201-209) FYI -recent info in our well file is wrong regarding the 9-5/8" surface casing; discovered this while reviewing AIO 26 admin approval for the well; confirmed with Perry Klein. Well file indicates 45.5ppf J-55 casing. I checked 1 F- 16 (PTD 183-153) -can not determine when the error occurred. Well completion reports reference drilling history which shows the 9-5/8" casing is actually is a mixed string of 36#, 43#, and 47# J-55 but not in what order. Perry had more details -interesting to me was that the weakest pipe (36# J-55; MIYP = 3520 psi) makes up the upper 43jts of surface casing. The well has communication to the IA which ConocoPhillips thinks may be a small packer leak (well passes positive pressure tests; failed an IA drawdown but unable to establish a leak rate). Info I have from monthly reports indicate max OA pressure of 500 psi; typical and current OA pressure approximately 50 psi. Admin Approval AIO 26.017 (should be approved today) includes usual conditions and imposes a 1500 psi pressure restriction in the IA and reporting of pressure bleeds in all annuli. Heads up in case any well work is proposed. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 3/12/2008 1F-16A (PTD 2012090) . . Page 1 of2 Regg, James B (DOA) From: Regg, James 8 (DOA) Sent: Monday, October 22, 2007 1 :07 PM To: 'NSK Well Integrity Proj' Cc: Maunder, Thomas E (DOA) Subject: RE: 1F-16A (PTD 2012090) ID1 /J ~ c,\'V'V~ ; \<.4{Lt \U \ ~GANNED NOV 012007 MJ- KRU 1 F-16A is an interesting well. The request for admin approval incorrectly identified the grade of th~9:5/8" surface casing as 45.5ppg J55 with an MIY of roughly 7500psi; our well files show a mixed string of 36#, 43#, and 47# J-55 without any indication of which pipe is where. It appears somewhere in the 1 F-16/1 F-16A history the Commission was provided incorrect information on a 10-403 or -404 regarding the surface casing I questioned the inconsistent info about the casing design; Perry researched and confirmed the weakest pipe (36# J-55; MIYP := 3520 psi) makes up the top 40+ joints of casing. Also, I did not see a request for 3000 psi allowance for the IA; I guess one could infer that from the MITIA done 5/23/2007. The TIO information available to me indicated that the IA pressures have been around 1500 psi; our decision has to be based on what is provided in your request and there was nothing to indicate a problem maintaining the IA pressure at or below 1500 psi. The pressure limit for the IA was a response to concerns about the strength of both the production and surface casings. Production casing is (according to the info provided) 7", J55, 26ppf. An IA pressure of 3000 psi would be 60 percent of the MIYP rating; if that pressure were to reach the OA, it would represent 85 percent of the MIYP rating. The message here with the 1500 psi IA pressure limit in AIO 28.018 is that injecting with pressures that result in 3000psi in the IA would not be acceptable without mitigation. Monitoring alone is too subjective (and open to human error) and thus not sufficient to address the risk of communication to the OA in this case. You have the ability to request reconsideration and should do that if you are convinced the well can be operated safely and are comfortable with the operating pressures relative to the burst ratings for the production and surface casings. Some additional investigating of your well file (particularly the casing design) might be appropriate. I would also encourage you to consider something other than the field monitoring practices to avoid the potential for high OA pressure should you choose to request reconsideration. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Sunday, October 21, 20075:17 PM To: Regg, James B CODA) Cc: Maunder, Thomas E CODA); NSK Problem Well Supv Subject: 1F-16A (PTO 2012090) Jim, We received AA 28.018 for 1F-16A (PTD 2012090) and found what we assume is a typo. Condition #4 limits the IA pressure to 1500 psi rather than the requested 3000 psi. Limiting the IA to 1500 psi while the well has TxlA communication will prohibit injection into the well. What process do we need to do to modify the condition? 10/22/2007 1F-16A (PTD 2012090) Please advise. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 10/22/2007 . Page 2 of2 . Page 1 of 1 • Maunder, Thomas E (©OAj From: Regg, James B (DOA) Sent: Wednesday, October 17, 2007 9:14 AM 70: Maunder, Thomas E (DOA) Subject: KRU 1F-1SA ~ ZETf-}- FYI -recent info in our well fi{e is wrong regarding the 9-5/8" surface casing; discovered this white reviewing AIO 2B admin approval for the well; confirmed with Perry Klein. Well file indicates 45.5ppf J-55 casing. i checked 1 F- 16 (PTD 183-153} -can not determine when the error ocxurred. Welt completion reports reference drilling history which shows the 9-5/8" casing is actually is a mixed string of 36#, 43#, and 47# J-55 but not in what order. Perry had more details -interesting to me was that the weakest pipe (36# J-55; MIYP = 3520 psi} makes up the upper 43jts of surface casing. The welt has communication to the IA which ConocoPhiNips thinks may be a small packer leak (welt passes positive pressure tests; failed an iA drawdown but unable to establish a leak rate). info 1 have from monthty reports indicate max OA pressure of 500 psi; typical and current OA pressure approximately 50 psi. Admin Approval AIO 2B.017 (should be approved today) tnGudes usual conditions and imposes a 1500 psi pressure restriction in the IA and reporting of pressure bleeds in all annuli. Heads up in case any well work is proposed. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~'~~~ N0~1 ~~ 9 2C~~7 10/19/2007 • Regq, James B • From: NSK Problem Well Supv [n1617@conocophillips.com} Sent: Tuesday, October 16, 2007 11:53 AM To: Regg, James B (DOA} Subject: Emailing: MtT KRU 1F-16 05-23-07.x1s K~,{~ j~~['~'I (~7 Attachments: MIT KRU 1 F-16 05-23-07.x1s i _~ MIT KRU 1F-16 05-23-07.x1s (21... «MIT KRU 1F-16 05-23-07.x1s» Jim, Enclosed are the MITI result you requested for 1F-16a PTD ## 201-209 The order of the MITs were performed was inner annulus, tubing, then outer annulus. The tubing and IA were bleed to the OA after testing. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com ~p~~~~, ;t`2~t.~.~-- -~.~- 1,~rr.i~~ ~~- t~~ 1 • • 1 3 'r SARAH PAUN, GOVERNOR ALASKA. OIL AND GAS 333 W. M AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 �+ w7 V PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 2B.018 Ms. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. WANAIED JAN 2 0 201 P.Q. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1F -16A (PTD 2012090) Request for Administrative Approval Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order ("A1O ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby grants ConocoPhillips Alaska Inc. ("CPAI ")'s request for administrative approval to continue water injection in the subject well. J subject River Unit ("KRU") 1F -16A exhibits tubing by inner annulus communication. All positive pressure tests performed on the well's tubing, inner annulus and outer annulus have passed since communication was first identified and reported in April 2007. A drawdown test of the inner annulus failed but was unable to determine the actual point of communication. The Commission finds that CPAI does not intend to perform repairs at this time, deferring until location of the communication can be determined. The Commission further finds, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, that KRU 1F -16A exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in KRU 1F -16A is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall limit the well's IA pressure to 1,500 psi; AIO 2B.018 • October 17, 2007 Page 2 of 2 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The MIT anniversary date is May 23, 2007. 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. DONE At ' • • horage, Alaska and dated October 17, 2007. 4 1K A 4 . - Iii . rman Daniel T. Seamount, Jr. Cath P. Foerster • Chai . Commissioner Commissioner 5 �� ' 4 . ; mss ` 4, .Y / C .2 • ' ;: - ., w� :,. se. • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU / 1 F-16a 05/23!07 Greenwood 0 ~b~.a- Packer Depth Pretest Initial 15 Min. 30 Min. Well 1F-16a Ty e In'. N TVD 5,188' Tubing 840 /2000 1975 1965 Interval p P.T.D. 2012090 ~ T e test P Test si /'I 500 Casing 1200 1250 1250 1250 P/F P Notes: MITT -not state witnesed OA 660 675 464 675 Well 1F-16a Ty e In'. N TVD X5,188' Tubing 680 910 929 925 Interval p P.T.D. 2012090 Type test P Test si 1500 Casing 90 2000 1970 1970 P/F P Notes: MITIA -not state witnesed OA 30 40 35 35 Well 1 F-16a Type Inj. N TVD 5,188' Tubing 500 500 550 575 Interval 0 P.T.D. 2012090 Type test P Test psi 1500 Casing 1250 1265 1260 1260 P/F P Notes: MIOA -not state witnesed OA 750 1800 1740 1720 Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing PIF Notes: OA Well Ty e Inj. TVD Tubing Interval P.T.D. Ty e test Test si Casing PiF Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test /' /" /' I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9(1105 M!T KRU 1 F-16 OS-23-O7.xls ~ ConocoPhillips Alaska RECEIVED OCT 0 2 2007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission .4nchorage September 30, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: - ConocoPhillips Alaska, Inc. presents the attached proposals as per AIO 2B, Rule 9, to apply for Administrative Approval to allow wells IF-16A (PTD 201-209) and 3A-ll (PTO 185-238) to remain in water only injection service with known minor annular communication. Also attached is a 10-404 Report of Sundry Operations for 2M-35 (PTD 196-080, Sundry # 306-390) for an OA cement shoe. Given that the MITOA pressure test failed to pass, a supplementary 10-404 will be filed if additional remediation is completed to attain a passing test. If you need additional information, please contact me at 659-7043, or Brent Rogers / Perry Klein at 659-7224. Si~;;/ 4 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments . . ConocoPhiUips Alaska, Inc. Kuparuk WelllF-16A (PTD 2012090) Technical Justification for Administrative ReHef Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection wellIF-16A. Well History and Status Kuparuk River Unit welllF-16A (PTD 2012090) was sidetracked and completed in October 2001 as an injection well. 1F-16A was reported to show signs ofT x IA communication in Apri12007. All positive pressure diagnostics continue to pass integrity testing, however the IA fails a draw down test when bled. There is no recordable leak rate so the exact location of the communication is not detectable but the packer is the suspected. The well passed an MITIA to 3000 psi, as well as, an MITT to 2000 psia, and an MITOA to 1800 psi on 5/23/07. ConocoPhillips intends to pursue repairs in the future if the leak worsens enough to be detectable and located. Barrier and Hazard Evaluation Tuhing: The 3-112" 9.3# L-80 tubing has integrity to the packer @ 7464' MD, based on passing MITT to 2000 psi on 5/23107 and passing MITrA to 3000 psi on 4/13/07 and 2000 psi on 5/23/07. ~ ¡\,~¡: 4C¡to~; Production casing: The 7" 26# J-55 production casing has integrity to the packer @ 7464' MD Q 0/, 'i based on the passing MITIA tests outlined above. TDf 43j-l-s I ß Surface casing: The well is completed with 9-5/8" 45.5# J-55 surface casing with an internal ~:Þ J.t;;5 yield pressure rating of751O psi. The surface casing is set at 4496' MD (3462' TVD). A passingUfy~35zcrsi MrTOA to 1800 psi was perfonned on 5/23/07. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second harrier: The production casing is the secondary barrier should the tubing fail. ~ Third barrier: The surface casing and cement shoe will act as a third barrier should the first two ~ 1UEh,1c... barriers have failures. c~ Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut-in of the well. T /ro plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Well Integrity Supervisor 9/29/2007 . -. ConocoPhilllps Alaska, Inc. TUBING (0-7557, 00:3.500, 10:2.992) TUBING (7557-8655, 00:2.875, 10:2.441) PKR (7689-7702, 00:3.971 ) Blast Joints (8499-8578, 00:4.500) Pert (8540-8560) HPBO - #2 {SS,90-8752) Pert (8690-8704) Pert (8728-8738) Perf (8726-8752) . KRU Lvi re(jr; 1F-16A TVD W 110 62.50 3462 45.50! 5335 26 00 i , - ! LINER 1 5.000 7703 I 8980 J 6280 L 18.00 I L-80 I I Size I Top Bottom I TVD \ Wt I Grade i Thread 3.500 ¡ 0 7557 I 5244 i 9.30 I L-80 I 2.875 I ~57 .~~ St~tus 30~t7 . 6.50 ! L-80 I Interval I Date I TYoe I 8516 - 8536 5908 - 5924 C-4 ! 20 I 6 11/12/20011 IPERF i 33/8" HSD Powershot, 60 I I I idea phase 8540 - 8560 I 5927 - 5942 C-4 i 20 I 6 11/12/2001 ¡PERF 13 318" HSO Powershot, 60 I i 1 idea phase I 8690 - 8692 I 6044 - 6046 A-5 I 2 , 4 111/30/2001 APERFIEneroiet.OdeaDha~ ! I 8692 - 8702 ! 6046 - 6054 A-5 10 8 I 2/15/2002 APERF I 1-11/16" Pivot, 0 orient -1 8702 - 8704 6054 - 6056 A-5 2 4 111/30/2001 APERF ¡ Energjet, 0 deg phasing_I 8726 - 8728 6073 - 6075 A-4 ¡ 2 4 111/30/20011 APERF I Eneraiet, 0 deD ohasinD I 8728 - 8738 6075 - 6082 A-4 10 8 L2/15/2002 í APERF 11-11/16" Pivot 0 orient i 1 8738 - 8752 6082 - 6094 A-4 14 4 .IJ 1/30/20011 AP ERF ' Enelr' 0 deD ohasinD 1 ts;tlJ;i¡iûfªíIÎin$11&)~\ 1~IÆ:ífmê1ît$f?lv7'!:j:;;,wi{&j,f:;!i4@Gi' :'(,.',:1.;' ......... Interval Date Type I Comment 8690 - 8752 I 12/1/2001 HPBO - INITIAL I 8690 - 8752 I 3/3/2002 HPBD - #2 I RSas¥ii;lflf· 11< I St I MD TVD Man Mfr Man Type I V Mfr I V Type VOD Latch I port TRO i Date Run f Vlv i I I ' Cmnt i i 1 \ 7366 5129 CAMCO MMG i CAMCO i DMY 1.5 RK 0,000 0 111/2312001 ; 2 I 7542 523~AMCO I DMY 1.5 RK 10.000 0 ;11/13/2001 DeDth TVD e ID I 486 486 NIP CAMCO 'OS' LANDING NIPPLE w/2.375" NO GO 2.875 ¡ 7412 5156 NIP CAMCO 'OS' NIPPLE w/2.812 NO GO I 2.812 7450 5179 PBR BAKER PBR 30-40 ! 2.992 , 7464 5188 I PKR BAKER FHL HYDRO STAT PACKER 2.992 ~ I ! 7557 5244 XO ! 2.441 7689 5326 PKR BAKER C-2 ZXP RETAINER PRODUCTION LINER PACKER i 2680 , 7702 5334 HANGER BAKER FLEX-LOC HYDRAULIC LINER HANGER 4.276 i 8499 5895 Blast Joints 2.441 I 8578 5956 SLEEVE-C ì BAKER CMU. closed 11/29/01 2.312 I 8614 5985 NIP ¡CAMCO 2 7/8" '0' NIPPLEw/2.25" NO GO PROFilE 2.250 i I 8652 6014 LOCATOR BAKER G-22 LOCATOR/SEAL ASSEMBLY I 2.000 8979 6280 SHOE I I 4.276 ~tà~i l'j,,: " Date I Note 1/15/20011 NOTE: WELL SIDETRACKED I I I ~---1 Corrected Form: IF-16A (PTD 2012090) re.fMIT results -app... Tom, Jim, & Bob, Opps - I just noticed I typo'd the test date on the form by listing the 4th rather than the 12th. Attached is a corrected form. Thanks! Marie «MIT KRU 1 F-16A 04-12-07.xls» From: NSK Problem Well Supv Sent: Friday, April 13, 2007 5:35 PM To: 'Thomas Maunder'; James Regg; bob_fleckenstein@admin.state.ak.us Subject: 1F-16A (PTD 2012090) report of MIT results -apparent one way leak. Tom, Jim, & Bob, Attached are diagnostic MIT results for Kuparuk injector 1F-16A (PTD 2012090) completed on 4/12/07. Testing indicates a one-way leak, the MITIA passed, but the drawdown test failed. The IA repressured / within 30 mins after being bleed. The wellhead packoffs passed testing, indicating the leak is downhole. A leaking dummy valve, seal assembly, or packer is suspected. /The well was SI today, 4/13/07, while waiting on additional wellwork to locate the leak location and evaluate repair options. Please let me know if there are any questions, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com SCAKMEDI þ.?R S 0 2001 «File: MIT KRU 1F-16A 04-12-07.xls» From: NSK Problem Well Supv Sent: Saturday, April 07, 20077:30 PM To: 'James Regg'; 'Thomas Maunder' Subject: 1F-16a PTD # 201-209 Suspect T X IA communication Jim & Tom, 1 F-16a PTD # 201-209, produced water injector is exhibiting signs of T X IA communication. lof2 4/16/20079:15 AM Corrected Form: IF-16A (PTD 2012090) report ofMIT results -app... . . TIIIO observed before bleeding = 2131/2300/360 psi. The IA has been bled twice in the last two days. Immediate action will be to monitor the lA, bleeding pressure if necessary, test pack offs, and perform a MITIA. Let me know if you have any questions. Sincerely Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n 1617@conocophillips.com « File: 1 F-16 90 day pressure plot.gif» «File: 1 F-16 2 week pressure plot.gif» «File: 1 F-16A.pdf » Content-Description: MIT KRU IF-16A 04-12-07.xls KRU IF-16A 04-12-07.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 2 of 2 4/16/2007 9: 15 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test t'7 ~\~~ 0'7 y·~(t11 Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1 F-16A 04/12/07 Ian Ives / Ron Bates / Brent Rogers NA Packer Depth Pretest Initial 15 Min. 30 Min. We1l11F-16A I Type Inj. I W TVD I 5,188' Tubing 1700 1700 1700 1700 Interval 0 P.T.D.!2012090 I Type test I P Test psil 1500 Casing 1775 3000 2975 2950 P/FI P Notes: Diagnostic MITIA. 45 min T/I/O = 1700/2950/60 OA 60 60 60 60 Well!1F-16A I Type Inj. W TVD I 5,188' Tubing 1700 1700 1700 1700 Interval 0 P.T.D.12012090 I Type test I M Test psil 1500 Casing 2950 1000 1700 1775 P/F F Notes: Diagnostic IA drawdown and monitor test. OA 60 60 60 60 Bleed IA to 1000 psi after MITIA Weill I Type Inj.1 TVD Tubing Interval I p.T.D.1 I Typetestl Test psil CasinQ P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type test I Test psi! Casing P/F Notes: OA Weill I Type Ini.1 TVD I Tubing Intervat p.T.D.1 Typetestl Test psil Casing P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Intervall P.T.D.I I Type test I Test psil Casing P/FI Notes: OA / /' D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1105 2007 -0412_MIT _KRU_1 F-16A_drawdown.xls . . KRU 1 F-16A API: 500292102901 Well Tvoe: INJ Angle@ TS: 39 dea tf!) 8512 TUBING SSSV Tvee: Nioole Oria Comoletion: 11/14/2001 Anale (Q) TD: 33 dea tf!) 8990 (0-7557, Annular Fluid: Last WID: 11/15/2001 Rev Reason: Taa Schmoo 00:3.500, Reference Loa: Ref Loa Date: Last Upaate: 9/23/2006 10:2.992) Last Taa: 8562' RKB TD: 8990 ftKB ...: 9/15/2006 Max Hole A ¡¡100 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 WELD SURFACE 9.625 0 4496 3462 45.50 J-55 PRODUCTION &0 7703 5335 26.00 J-55 7703 8980 6280 18.00 L-80 :j:iiiiiYjiijii Size Top I Bottom TVD I Wt I Grade I Thread 3.500 0 7557 5244 9.30 L-80 2.875 7557 I .. Ii I ~L-ISU Interval TVD Zone Status Ft SPF Date Type Comment 8516 - 8536 5908 - 5924 C-4 20 6 11/1212001 IPERF 3 3/8" HSD Powers hot, 60 deq phase 8540 - 8560 5927 - 5942 C-4 20 6 11/1212001 IPERF 3 3/8" HSD Powershot, 60 de¡¡ phase 8690 - 8692 6044 - 6046 A-5 2 4 11/3012001 APERF Energjet 0 dea ohasina 8692 - 8702 6046 - 6054 A-5 10 8 2115/2002 APERF 1-11/16" Pivot 0 orient 8702 - 8704 6054 - 6056 A·5 2 4 11/30/2001 APERF Eneraiet 0 de¡¡ phasina 8726 - 8728 6073 - 6075 A-4 2 4 11/30/2001 APERF Eneraiet 0 deo ohasina 8728~ A-4 10 8 2115/2002 APERF 1-11/16" Pivot 0 orient 8738 - - A-4 14 4 1_ ::::!JiIì I Interval Date Type I I ~ HPBD - INITIAL I HPBD - #2 I I jI:lj jii St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt 1 7366 5129 CAMCO MMG CAMCO DMY 1.5 RK ~1 2,~~i.¡~2i~iD~~Ú" CAMCO DMY 1.5 RK . ,. Ute 01 . Ie: ':~' TUBING Depth TVD Type DescriPtion ID (7557-8655, 486 486 NIP CAMCO 'DS' LANDING NIPPLE wl2.875" NO GO 2.875 00:2.875, 7412 5156 NIP CAMCO 'DS' NIPPLE wl2.812 NO GO 2.812 10:2.441) 7450 5179 PBR BAKER PBR 80-40 2.992 7464 5188 PKR BAKER FHL HYDROSTAT PACKER 2.992 7557 5244 XO 2.441 PKR 7689 5326 PKR BAKER C-2 ZXP RETAINER PRODUCTION LINER PACKER 2.680 (7689-7702, 7702 5334 HANGER BAKER FLEX-LOC HYDRAULIC LINER HANGER 4.276 00:3.971) 8499 5895 Blast Joints 2.441 8578 5956 SLEEVE-C BAKER CMU closed 11/29/01 2.312 8614 5985 NIP CAMCO 2 7/8" 'D' NIPPLEw/2.25" NO GO PROFILE 2.250 8652 6014 LOCATOR BAKER G-22 LOCATORISEAL ASSEMBLY 2.000 8979 6280 SHOE 4.276 General tiløt~~1'È¡;¡;::¡ Date I Note - 11/15/20011 WELL SIDETRACKED Blast Joints (8499-8578, 00:4.500) Perf ----- (8540-8560) HPBO - #2 (8690-8752) Perf (8690-8704) Perf (8728-8738) Perf (8726-8752) L... I F- ¡ 6 week pressure 1267x780 24-MAR-1J7 19:30 SCRATCIC 4 l' 1111111 OUTER PRES 6 pressure 1J1-JAN-(J7 19:25 WEEK OUTER PRES IF-16a PTD # 201-209 Suspect T X IA communication . . Jim & Tom, 1 F-16a PTD # 201-209, produced water injector is exhibiting signs of T X IA communication. T/I/O observed before bleeding = 2131/2300/360 psi. The IA has been bled twice in the last two days. Immediate action will be to monitor the lA, bleeding pressure if necessary, test pack offs, and perform a MITIA. Let me know if you have any questions. Sincerely Perry Klein .:I+ J.AIYf --- #i'~~ Scf> 2~í 4G:.. z-t IÄk(f Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCANNED APR 1 '1 2007 «1F-16 90 day pressure plot.gif» «1F-16 2 week pressure plot.gif» «1F-16A.pdf» IF-16 90 day pressure Content-Description: IF-16 90 day pressure plot.gif Content-Type: image/ gif Content-Encoding: base64 Content-Description: IF-16 2 week pressure plot.gif IF-16 2 week pressure plot.gif! Content-Type: image/gif Content-Encoding: base64 Content-Description: IF-16A.pdf IF-16A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1,~R>"Z- b~ 4/1 0/2007 1 :09 PM F-16 week pressure 24-MAR-07 19::HI SCRATCH 41 FLOW TUBING PRESSURE 1111111 SCRATCH_47 OUTER ANNULUS PRES 111117'1 ofl 4/ ¡ 0/2007 : TUBING (0-7557, 00:3.500, 10:2.992) TUBING (7557-8655, 00:2.875, 10:2.441) PKR (7689-7702, 00:3.971) Blast Joints (8499-8578, 00:4.500) Perf (8540-8560) HPBO - #2 (8690-8752) Perf (8690-8704) Perf (8728-8738) Perf (8726-8752) ----- I.... 8690 - 8692 6044 - 6046 8692 - 8702 6046 - 6054 8702 - 8704 6054 - 6056 8726 - 8728 6073 - 6075 8728 - 8738 6075 - 6082 8738 - 8752 6082 - 6094 ~_muQn$&m[._Ìí:ts Interval Date Type 8690 - 8752 12/1/2001 HPBD - INITIAL ~aa:90 - 8752 _002 HPBD - #2 St MD I TVD Man Mfr Man Type 1 7366 5129 CAMCO MMG 2 75421 5235 C MMG . API: 500292102901 SSSV Tvce: Nipple Annular Fluid: Reference Loa: ~RKB ~006 Description CONDUCTOR SURFACE PRODUCTION LINER :11!¡,¡mñâ~îtil'i(j,I,~I11!IIS:lf!I~ Size I Top 3.500 0 .. Interval 8516 - 8536 TVD 5908 - 5924 8540 - 8560 5927 - 5942 Depth TVD 486 486 7412 5156 7450 5179 7464 5188 7557 5244 7689 5326 7702 5334 8499 5895 8578 5956 8614 5985 8652 6014 8979 6280 ~.lnêtal.Notes Date I Note 11/15/2001 WELL SIDETRACKED Type NIP NIP PBR PKR XO PKR HANGER Blast Joints SLEEVE-C NIP LOCATOR SHOE . ": ------ - .... . KRU 1 F-16A Well Type: INJ Orig Completion: 11/14/2001 Last W/O: 11/15/2001 Ref Loa Date: TD: 8990 ftKB MaXHoleA~6700 Size Top Bottom 16.000 0 110 9.625 0 4496 7.000 0 7703 5.000 7703 8980 Angle Cii> TS: 39 deo fB) 8512 Angle @ TD: 33 dea fB) 8990 Rev Reason: Taa Schmoo Last UlXlate: 9/23/2006 TVD Wt Grade Thread 110 62.50 H-40 WELD 3462 45.50 J-55 5335 , J-55 6280 L-80 C'" '.1 I Grade Thread I L-80 I I L-BO I I Bottom I 7557 ii Zone Status C-4 C-4 TVD 5244 6017 IWt I 9.30 I 6.50 Ft SPF Date Type 20 6 11/12/2001 IPERF Comment 33/8" HSD Powers hot, 60 deg phase 3 3/8" HSD Powers hot, 60 deg phase Eneraiet, 0 deg phasina 1-11/16" Pivot 0 orient Energjet 0 deo phasinG Energjet 0 dea ohasina 1-11/16" Pivot 0 orient 20 2 10 2 2 10 14 6 11/12/2001 IPERF A-5 A-5 A-5 A-4 A-4 A-4 4 11/30/2001 APERF 8 2/1512002 APERF 4 11/3012001 APERF 4 11/3012001 APERF 8 2/1512002 APERF 4 111ìï1i'APERF Comment I I I I . V Mfr V Type VOD latch Port TRO CAMCO DMY 1.5 RK 0.000 0 CAMCO DMY 1.5 RK 0.000 0 Date Vly Run Cmnt ~==j ID 2.875 2.812 2.992 2.992 2.441 2.680 4.276 2.441 2.312 2.250 2.000 4.276 Description CAMCO 'DS' LANDING NIPPLE w/2.875" NO GO CAMCO 'DS' NIPPLE w/2.812 NO GO BAKER PBR 80-40 BAKER FHL HYDROSTAT PACKER BAKER C-2 ZXP RETAINER PRODUCTION LINER PACKER BAKER FLEX-LOC HYDRAULIC LINER HANGER BAKER CMU closed 11/29/01 CAMCO 2 7/8· 'D' NIPPLEw/2.25" NO GO PROFILE BAKER G-22 LOCA TORISEAL ASSEMBLY . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 F-16A (APD # 201-209) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 F-16A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )It I JI/~~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV 2 42D04 ORJ0i ) \! [ì J .oi'~ ,¡ ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing 0 Operat. ShutdownD Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 106' 8. Property Designation: AD L 25652, ALK 2578 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: Stimulate 0 Waiver 0 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201-209 / 6. API Number: 50-029-21029-01 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 Service 0 Other 9. Well Name and Number: 1 F-16A 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 8990' feet true vertical 6289' feet measured 8857' feet true vertical feet Length Size MD 110' 16" 110' 4390' 9-5/8" 4496' 7597' 7" 7703' 1277' 5" 8980' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3462' 5335' 6280' Measured depth: 8516'-8536',8540'-8560',8690'-8704',8726'-8752' true vertical depth: 5908'-5924',5927'-5942',6044'-6056',6073'-6094' Tubing (size, grade, and measured depth) 3.5"/2-7/8", L-80, 7557' / 8655' MD. Packers & SSSV (type & measured depth) pkr::; BAKER FHL HYDROSTAT PKR; BAKER C-2 ZXP RETAINER PRODUCTION LINER PKR pkr::; 7464'; 7689' Camo 'OS' nipple 486' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8690'-8704', 87261-8752' 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 670 bbls of slick seawater Oil-Bbl n/a Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 68 192 TubinQ Pressure 2295 2309 Casinq Pressure 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO GasO WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature WDSPLO Mike Mooney @ 263-4574 Mike Mooney Title Phone Dt(ìG\NAL Kuparuk Wells T earn Leader Date il/ Z. Z /61 Prepared bv Sharol ÀlIsup-Drake 263-4612 NBUMS 8FL NOV 2 2 2004 Submit Original Only NlIM~) Form 10-404 Revised 04/2004 ) 1F-16A Well Events Summary ) Date Summary 10/31/04 POOR BOY HPBD COMPLETED. PUMPED 670 BBLS OF 55 DEGREE SLICK SEAWATER. MAX WHTP 4000 PSI AND MAX RATE OF 5 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN.D [HPBD] ) PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY T(~~~~;, '., ¡, ~ !I IF'16A API, 500292102901 00~3.500,: I~, I' !~ SSSV Type: Nipple 10.2.992) \ " , , . Annular Fluid: ill ! , I! Ii ~ Reference Log: LastTag: 8857 I, . Last Tag Date' 2110/2002 '~ Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 t SURFACE 9.625 PRODUCTION 7.000 I jum I Tubing Str~~~E~TUBING 5.000 .~i,': . ¡, ,i,'1 perto[~1L summ;]; B~ffr " Interval TVD Zone ! 8516 - 8536 5908 - 5924 C-4 I TUBING (7557-8655, 00:2.875, 10:2.441) 'ï\lli,'..,:~" ',' f.) '4i' PKR (7689-n02. 00:3.971) .: Blast Joints (8499-8578, 00:4.500) Perf (8540-8560) ~ - - ~ ;~ ~¡ ~ I I ~ -,.--- I ~ HPBO - #2 (869~752) ........ - , ~: t=. : ""---- ¡ t== -- Perf (8728-8738) :~ ~- ~ u A a.. ') KRU 1 F-16A Well Type: INJ Orig 11/14/2001 Completion: LastW/O: 11/15/2001 Ref Log Date: TO: 8990 ftKB Max Hole Angle: 58 deg @ 6700 Angle@TS: 39 deg @ 8512 Angle @ TO: 33 deg @ 8990 Rev Reason: HPBD by ImO Last Update: 4/10/2002 Top Bottom TVD Wt Grade Thread 0 110 110 62.50 H-40 WELD 0 4496 3462 45.50 J-55 0 7703 5335 26.00 J-55 7703 8980 6280 18.00 L-80 TVD Wt Grade Thread 5244 9.30 L-80 6017 6.50 L-80 8540 - 8560 5927 - 5942 Status Ft SPF Date Type Comment 20 6 11/12/2001 IPERF 33/8" HSD Powers hot, 60 deg phase 6 11/12/2001 IPERF 33/8" HSD Powershot, 60 deg phase 4 11/30/2001 APERF Energjet, 0 deg phasing 8 2/15/2002 APERF 1-11/16" Pivot, 0 orient 4 11/30/2001 APERF Energjet, 0 deg phasing 4 11/30/2001 APERF Energjet, 0 deg phasing 8 2/15/2002 APERF 1-11/16" Pivot, 0 orient 4 11/30/2001 APERF Energjet, 0 deg phasing C-4 20 A-5 2 A-5 10 A-5 2 A-4 2 A-4 10 A-4 14 8690-8692 6044-6046 8692 - 8702 6046 - 6054 8702-8704 6054-6056 8726-8728 6073-6075 8728 - 8738 6075 - 6082 8738-8752 6082-6094 Stimulations & Treatments Interval Date Type 8690 - 8752 12/1/2001 HPBD -INITIAL 8690 - 8752 3/3/2002 HPBD - #2 Comment V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt RK 0.000 0 11/23/2001 RK 0.000 0 11/13/2001 St MD TVD Man Man Mfr Type 1 7366 5129 CAMCO MMG CAMCO DMY 2 7542 5235 CAMCO MMG CAMCO DMY Other {Jlugs, equip., etc.' - JEWELRY Depth TVD Type 486 486 NIP 7412 5156 NIP 7450 5179 PBR 7464 5188 PKR 7557 5244 XO 7689 5326 PKR BAKER C-2 ZXP RETAINER PRODUCTION LINER PACKER 7702 5334 HANGER BAKER FLEX-LOC HYDRAULIC LINER HANGER 8499 5895 Blast Joints 8578 5956 SLEEVE-C BAKER CMU, closed 11/29/01 8614 5985 NIP CAMCO 2 7/8" '0' NIPPLEw/2.25" NO GO PROFILE 8652 6014 LOCATOR BAKER G-22 LOCATOR/SEAL ASSEMBLY 8979 6280 SHOE 1.5 1.5 ID 2.875 2.812 2.992 2.992 2.441 2.680 4.276 2.441 2.312 2.250 2.000 4.276 Description CAMCO 'OS' LANDING NIPPLE w/2.875" NO GO CAMCO 'OS' NIPPLE w/2.812 NO GO BAKER PBR 80-40 BAKER FHL HYDROSTAT PACKER SIDETRACKED I ') i~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2012090 Well Name/No. KUPARUK RIV UNIT 1F-16A Operator CONOCOPHILLIPS ALASKA INC MD ND 6289 ,.., Completion Date 11/14/2001 /' Completion Statu 8990 ..... REQUIRED INFORMATION Sflv.,¿ 71J 4 v' ~ {}O ( API No. 50-029-21029-01-00 =~- __UIC",- Y ~ - 'L - Mud Log No Samples No Directional survey___~l~u- -_u ------ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) -- Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ C 11223 r Jftef D 10726 Interval Start Stop 7850 8990 Log Log Run Scale Media No 1 1 OH/ CH Received Case 7/2/2002 Open 3/13/2002 7850 8939 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y (!j) Chips Received?- Y I N Daily History Received? (ÝYN (Y)/N Formation Tops Analysis Received? ~ Comments: ru~'F!' 10\. VJv\'{.11 tlL,-~':'~ yZ tj D M ~. ( \'1l- U. S 1: . l d-../ù t1 v )..0 \oj l '-It loti' - S ß H.v? S\-'.v v~ V1NU! f'~ 1> û J\t~ V' A.ù \J \ ~ ~ t1 (... . - ~ C:. il.iMtJ(Þ (/6 ' .~ D I I 'v ~ I Comments -- - ---- ---- , I - ---~---u i I j ~~. Date: 2..lL lLáJI - d ð- -~ ) - ._. - --- - Comcliance Reviewed Bv: .,f ~ ,{ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: July 01, 2002 RE: MWD Formation Evaluation Logs IF-16~ AK-MJ\Æ-11186 aO /-dOq 11d.~ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 IF-16A: Digital Log Images 50-103-21029-01 ~. dhpJ 1 CD Rom RECEIVED JUL 2 2002 Alaska Oil & Gas Cons Comm' . An- lIton (" PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 March 19, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations IF-16A (201-209) Dear Commissioner Oechsli Taylor: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent reperf and stimulation operations on the KR U well 1 F-16A. If there are any questions, please contact me at 263-4574. Sincerely, }1.4~ M. Mooney Wells Team Leader Phillips Drilling MM/skad \ , "",,- ,'.", I. :,. i' I " ,\!a£~~~:J ( (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Pull tubing - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 563' FNL, 108' FEL, Sec. 19, T11N, R10E, UM At top of productive interval 754'FSL, 1304'FEL,Sec.20, T11N, R10E,UM At effective depth At total depth 4620'FNL, 1249'FEL, Sec. 20, T11N, R10E,UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Length 110' 4496' Size 16" 9-5/8" 1277' 7" 5" Stimulate _X - HBPD Alter casing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 539866, 5958963) (asp's 543985, 5955025) (asp's 544039, 5954930) 8990 feet 6289 feet Plugs (measured) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (OF or KB feet) RKB 106 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 F-16A 9. Permit number / approval number 201-209/ 10. API number 50-029-21029-01 11. Field / Pool Kuparuk Oil Pool Measured Depth 110' 4496' 7703' 8980' True vertical Depth 110' 3462' 5335' 6280' 8851 feet 6174 feet Junk (measured) Perforation depth: measured 8516' - 8536',8540' - 8560',8690' - 8704',8726' - 8752' Cemented 190 sx CS II 1250 sx AS II, 800 sx Class G 450 sx Class G, 250 sx AS I 200 sx GasBloc true vertical 5908' - 5924',5927' - 5942', 6044' - 6056', 6073' - 6094' Tubing (size, grade, and measured depth) , /,- I I' 3-1/2",9.3#, L-BO Tbg @ 7557' MD; 2-7/8",6.5#, L-80 Tbg @ 8655' MD. Packers & SSSV (type & measured depth) BAKER FHL HYDROSTAT PACKER @ 7464' MD; BAKER C-2 ZXP RETAINER PROD. LINER PACKER @ 7689' MD; CAMCO 'DS' LANDING NIPPLE W/2.875" NO GO @ 486' MD. . 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Injector Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Injector Signed Michael Moone Form 10-404 Rev 06/15/88 . Title: Wells Team Leader ORIGINAL :'Y¡I"_-'I'~"" :-\ CasinQ Pressure TubinQ Pressure Suspended - Service _Water Injector_XX Questions? Call Mike Mooney 263-4574 ~::rnd? :i; A~¡frnk~4612 Date 02/10/02 02/13/02 02/14/02 03/03/02 (' 1 F-16A Event History ( Comment TAGGED @ 8857' RKB EST. 105' RATHOLE. DRIFTED TBG W/ 10' X 1.875" STEM. [PERF] UNABLE TO START PERF JOB DUE TO LOGGING UNIT PROBLEMS. WILL REPAIR AND PROCEED IN AM. [PERF] RE-PERF A SAND INTERVALS (A5 8692' - 8702') & (A4 8728' - 8738') USING TWO 1-11/16" PIVOT GUNS (UCAP/RDX CHGS), 4 SPF, NO ORIENTATION -- 10' EACH. [PERF] PUMP BREAKDOWN AT 40 BPM. SEEN GOOD PRESSURE BREAKDOWN, TP = 7300 PSI. PUMP 7,795# OF 16/20 PROPPANT FOR SCOUR STAGES AND 500# OF ROCK SALT FOR DIVERTER. SEEN GOOD PRESSURE RESPONSE FROM DIVERTING STAGES. PUMP ALL WATER ON LOCATION. FINAL ISIP = 2423 PSI ," Page 1 of 1 3/15/2002 :~ ~ WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 12, 2002 RE: MWD Formation Evaluation Logs IF-16A, AK-MJ\Æ-11186 ë)O)'-d,O9 1 LDWG formatted Disc with verification listing. API#: 50-029-21029-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Signed:(~- ~ Date: RECEIVED t,'1"R ~at~~ 7 J 2002 AnCh Cons. C°f11m¡oø. . Dnt1e -wil( (¡ 12113/01 Scblunlbel'ger NO. 1692 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk "~ Well Job # Log Description Date BL Sepia CD Color ~ 01-,;\ 0'1 ;}. 0' - I «ß3 ;t 0 a-i c;¡q ~ 0' ~cJO1 ;)0 1- ~cf 1 F-16A SBHP SURVEY 11/30/01 1 1 2T-39 SBHP SURVEY 12/04/01 1 1 1C-125 21501 SCMT 11/05/01 1 1 F-16A 21502 USIT 11/12/01 1 2K-28 21503 SCMT 11/20/01 1 " "" - ~El:EI\/I-J ] SIG NED :~ I J.. fl 0 il 'P' ;J D ATE: Q.E C 2 1--2-0-01- -- Alaska Oil & Gas COns. CommiSSiO; Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you'Anchorage ( ( PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 Q-O360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 December 20,2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Aven~e Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for IF-16 P&A and IF-16A (183-153 / 301-295 and 201-209) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Reports for the P&A operations for IF-16 and the sidetrack drilling operations on the Kuparuk welllF-16A. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. C. Mallary Drilling Engineeri g Supervisor PAl Drilling CM/skad RECEIVED DEC 2 0 2001 OR I G\ NAL Alaska Oil & Gas Cons. Commission Anchorage " I'" ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. location of well at surface .," ,_.. " " ',...~. 564'FNL,109'FEL,Sec. 19,T11N, R10E, UM C'.;; ':::.',,",1 i , ,'", ;:: I At Top Producing Interval .', -i.i..:-!...£ .?2.! ~~~~~~~p~~04' FEL, Sec. 20, T11 N, R10E, UM -~ .~::JJ2~-- ; (ASP: 543985, 5955025) 659' FSL, 1251' FEL, Sec. 20, T11 N, R10E, UM :.,.,.... ..._--.",t (ASP: 544039, 5954930) 5. Elevation in feet (indicate KB, DF. etc.) 6. lease Designation and Serial No. Nordic 3 RKB 26.7' ADL 25652 ALK 2578 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. November 7,2001 November 8,2001 November 14, 2001 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 8990'MD/6289'TVD 8851'MD/6174'TVD YES 0 No 0 22. Type Electric or Other logs Run GR/Res, US IT 23. Suspended 0 Abandoned 0 Service 0 WAG Injector 7. Permit Number 201-209 / 8. API Number 50-029-21029-01 toeA t!ON$ ~ Su~ J. r , r , \ !-~,. H. .A .r , - -----,.-.._,.;".¡ (ASP: 539865, 5958963) 9. Unit or lease Name Kuparuk River Unit 10. Well Number 1 F-16A 11. Field and Pool Kuparuk Oil Pool Kuparuk River Field 15. Water Depth, if offshore N/A feet MSL 20. Depth where SSSV set N/A feet MD 16. No. of Completions 1 21. Thickness of Permafrost 1450' (approx) 16" WT. PER FT. 62.5# 45.5# 26# 18# GRADE H-40 J-55 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 4496' Surface 9064' 7703' 8980' HOLE SIZE 24" CASING SIZE 9.625" 12.25" CEMENTING RECORD 190 sx CS II 1250 sx AS II, 800 sx Class G 450 sx Class G, 250 sx AS I 200 sx GasGloc AMOUNT PUllED 7" 5" 8.5" 6.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" x 2.875" TUBING RECORD DEPTH SET (MD) 7557' x 8655' PACKER SET (MD) 7464' & 7689' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 8516' - 8536' MD 8540' - 8560' MD 5908' - 5924' TVD 5927' - 5942' TVD 6 spf 6 spf 27. Date First Production N/A Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for Oll-BBl GAS-MCF Test Period> Calculated 24-Hour Rate> WATER-BBl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RE eEl VE D N/A DEC 2; 0 ZO01 . £~Iaska Oil & Gas Coos. Commissioo Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ("._"~":"'."'¡(""":_:I~ ~,;, L ' ,t. J'. I , 1\, ' ' "i¡f""i',1 ",""\,-,t":,¡!.',, , ! ! \ \, ~ ,I !, , '"","" 1 ð"""" \ ' R B 0 M 5 B F L ~ DEC 2 8 2001 u 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. West Sak D West Sak A3 / 8512' 8798' 5905' 6131' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certi at the following is true ä correct to the best of my knowledge. ~ A / .c{ ~¡t.'7 Signed ~ ¿t ~ 7 ¿ , ! Title Drillina Enaineerina Supervisor C. Mallary Questions? Call Todd Mushovic 265-6974 Date Þ-;/t þ¡ Prepared by Sharon AI/sup-Drake 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 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 (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 DEC 2 0 2001 ,: i ."""1 \ ; ,\, :.' ,;,' " '0...) ~ \\ ~\\",..,,' ~ l , ¡, , i."'"\ L . ~ Alaska Oil & Gas Cons. Commission Anchorage (' Page 1 of 6 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 F-16 Common Well Name: 1 F-16 Event Name: ROT - SIDETRACK Contractor Name: Nordic Rig Name: Nordic 3 Date From-To Hours Code Sub Phase Code 11/3/2001 16:00 - 21 :30 5.50 MOVE MOVE MOVE 21 :30 - 22:00 0.50 MOVE MOVE 22:00 - 00:00 2.00 WELLS PROD 11/4/2001 00:00 - 01 :00 1.00 WELLS OTHR DECOMP 01 :00 - 03:30 2.50 WELLS KILL DECOMP 03:30 - 06:00 2.50 WELLS DECOMP 06:00 - 10:00 4.00 WELLS DECOMP 10:00 - 14:00 4.00 WELLS SEaT DECOMP 14:00 - 19:30 5.50 WELLS OTHR DECOMP 19:30 - 22:00 . 2.50 WELLS SUN DECOMP 22:00 - 00:00 2.00 WELLS OTHR DECOMP 11/5/2001 00:00 - 02:00 2.00 WELLS OTHR DECOMP 02:00 - 04:30 2.50 WELLS OTHR DECOMP 04:30 - 06:00 1.50 WELLS PULD DECOMP 06:00 - 06:30 06:30 - 14:00 0.50 WELLS OTHR DECOMP 7.50 WELLS PULD DECOMP 14:00 - 15:30 1.50 WELLS OTHR DECOMP 15:30 - 22:00 6.50 DRILL TRIP PROD 22:00 - 23:00 1.00 DRILL CIRC PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 11/6/2001 00:00 - 03:00 3.00 ABAND OTHR ABANDN 03:00 - 07:00 4.00 ABAND PLUG ABANDN 07:00 - 07:30 07:30 - 12:00 0.50 WELCT OTHR ABANDN 4.50 WINDO RIP PROD 12:00 - 14:00 2.00 WINDO SETW PROD Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations Moving rig from 1 D-1 05A to 1 F-16A. (6 mile) Spot rig over well # 1F-16A & berm'same. Finish spotting outside equipment & pull VR. plug=rig up hard lines. Pull BPV=rig up kill manifold & test lines. PJSM-400# on tbg. & annulus=circ. seawater around thru choke. Install bpv-nipple down tree. PJSM-nipple up 11"-install 3 112" rams-uppe r & lower. Test bope-Witness test waived by John Cris p- aogcc. Tbg. hanger threads gaulded-make up spear- latch into tbg. wI double spear & packoff-pu II 140k-circ. & attempt to work tbg. free. Lay down spear-PJSM-rig up slick line-set fr ac sleeve in sssv @ 1916', Rig down wirelin e-reverse circ.-verify sleeve in place. PJSM-rig up sws-rih w/ string shot to clean inside tbg. for chemical cut. Continue run in hole wI string shot-f,ire sam e @ 8101'. -poh. PJSM-RIH wI chemical cutter-fire same @ 81 01' WI 85K up wt. on tbg. due to gaulded thr eads in hanger. POH. Pull hanger to floor-lay down same-rig up ca mco control line spool-poh laying down 3 11 2" tbg. Crew change-service rig. POH laying down tbg.=recovered 258 jts. & c ut off piece of 3 1/2.9.3# L-80 eue 8rd tbg. -8 pups-1 sssv-7 glm,s. & hanger. Set wear ring-load hwdp& dc,s-strap same. RIH-picking up dc,s-hwdp-scraper & bit-& 3 1/2. dp to 7959'. Circ. hole clean-working scraper from 7951' to 7867'. POH to run bridge plug. Complete toh. , PJSM. Ru Schlumberger WL, rih wI 7" CI BP , correlate to set 2' above csg collar wi top of cibp @ 7884' wi depth rkb Nordic 3. Test csg to 3000 psi [charted] 30 minutes. Pu,'1 Mu Baker whipstoc,k, mwd equip, orient same, rih & conduct shallow test. Continue to rih whipstock I bha on 3.5- dp t 0 7785', ck up & down wts of 130k & 75k Ib s, orient tool face ot 65? right of high side. Continued wI next 100' slowly to tag cibp @ 7885'. Check tool face 65? right of high s ide. Set bottom trip anchor wI 15k Ibsover, pu 8k Ibsover string wt to verfy same set. Printed: 12/14/2001 10:29:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/6/2001 11n/2001 11/8/2001 ( (" PHilliPS ALASKA INC. . Operations Summary Report . 1 F-16 1 F-16 ROT - SIDETRACK Nordic Nordic 3 2.00 WINDO Phase 12:00 - 14:00 From-To Hours Code ETW PROD 14:00 - 14:30 14:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 06:30 . 06:30 - 08:00 08:00 - 14:30 14:30 - 15:00 15:00 - 17:00 17:00 - 00:00 00:00 -10:30 10:30 - 11 :30 11:30 - 23:00 0.50 WINDO CIRC PROD 8.50 WINDO SCML PROD 1.00 WINDO CIRC PROD 0.50 WELCT CrRC PROD 0.50 WELCT OTHR PROD 1.00 DRILL 1.00 DRILL 3.50 DRILL 1.50 DRILL TRIP PROD OTHR PROD TRIP PROD OTHR PROD 6.50 DRILL TRIP PROD 0.50 DRILL OTHR PROD 2.00 DRILL REAM PROD 7.00 DRILL DRLG PROD 10.50 DRILL DRLG PROD 1.00 WELCT OBSV PROD 11.50 DRILL DRLG PROD Page 2 of 6 Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations Shear milling assmby off whipstock w/ 34k Ibs down. Disp seawater to 11.2 milling mud. Mill 12' window as per Baker Rep from 7867 - 79' & continue to 7900' in formation for u pper mill to clear window by 13' & allow ope n hole for F.I.T. Work window rotating & sl iding for 10 minutes w/ no drag. Return to td & sweep hole. After sweep up magnetes had recovered 120 of 250 calculat ed Ibs of steel. . Pump sweep, pull one stand & set back. F. I. T. @ 5460' tvd : RU to pump down drlg pipe & annulus. Pump a total of 22 gallons of mud [11.2 ppg] @ . 21 bpm [bop test pum p], pressure built to 560 psi, did not break back. Si & pressure bleed to 540 psi in 90 seconds & held @ 540 psi for 5 min w/ no fu rther deacrease. Bleed back 22 gallons. C alculations - EMW = 11.2 ppg +{ 540 psi? . 052 X 5460'} = 11.2 + 1.97 = 13.2 ppg emw. Pump dry pill & pooh 10 stands. Cut 49' of drlg line. Cont to pooh, Id dc, down load MWD. PJSM. Flush strack. Load out drill collars & tools from pipe shed. Pu / mu bha,load s ource in por tool & run below floor. Rih, picking up 33 singles then stands from derrick to 7838'. No problem w/ window. Orient tool face while circulating, difficult s taying oriented. Wash & ream to 7900'. Frequent stalls w/ p ressures to 4000 psi. Difficult holding tool face. Dir drlg 7900 to 8128' [5571 tvd]. Wts up / dwn 105k / 86k & rot 75k Ibs. Pump press 0 n / off bottom 3250 / 3050 psi @ 245 gpm. Rot torq on off bottom 60 rpm = 5800 /.5200 ft Ibs. Frequent stalls when trying to slide R 0 P s err a t ic fro m 1 5 to 70 fp h . 1 5 Ibs of metal recovered in I,ast 24 hrs, tot al recovered of 135 Ibs. Traces of metal b eing recovered @ rpt time. Directional Drill 8128 - 8559'. 3400 psi / 5.2 bpm, torque @ 60 rpm on / off bottom 6 100 / .5000 ft-Ibs. Weights up / dwn =.100k, 75k & rot @ 90k Ibs. Observed 2 bb.1 pit increase, flow ck - very I ight flow & trace of gas bubbles, si no dp / csg pressure. Cir bu, no gas/ qil. Directional Drill 8559 - 8990' md, 6289' tvd 3200 psi @ 5.8 bpm. Torque on / off b '\--,.., Printed: 12/14/2001 10:29:10 AM l ( f PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/8/2001 11/9/2001 1 F-16 1 F-1 6 ROT - SIDETRACK Nordic Nordic 3 From - To Hours Code Sub Phase Code 11 :30 - 23:00 11.50 DRILL DRLG PROD 23:00 - 00:00 1.00 CMPLTN CIRC PROD 00:00 - 00:30 0.50 CASE CIRC CMPL TN 00:30 - 02:00 1.50 CASE OTHR CMPL TN 02:00 - 04:00 2.00 CASE CIRC CMPL TN 04:00 - 06:30 2.50 CASE OTHR CMPL TN 06:30 - 1 0:30 4.00 CASE OTHR PROD 10:30 - 12:00 1.50 CASE RURD PROD 12:00 - 16:30 4.50 CASE RUNC PROD 16:30 - 23:00 6.50 CASE RUNL PROD 23:00 - 00:00 1.00 CASE CIRC PROD 11/10/2001 00:00 - 00:30 0.50 CASE CIRC CMPL TN 00:30 - 02:00 1.50 CASE RUNL CMPL TN 02:00 - 04:00 2.00 CASE CIRC CMPLTN 04:00 - 04:30 0.50 CASE SFTY CMPL TN 04:30 - 06:30 2.00 CEMEN PUMP CMPL TN Page 3 of 6 Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations ottom = 6000 / 5200 ft-Ibs. Wts up / dwn / r ot = 105 / 80 / 95k Ibs. Cir / cond for liner. Cir cond @ td for liner. 8990' md / 6289' tv d. Short trip to 7890' [bit] & return to td, no fi II abnormal drag. Cir cond @ td, sweep hole, shakers clean. Pooh to 7543', pump dry pill. Rig service. Continue trip out, Id non mag collars, PJSM / recover source, down load mwd-Iwd. Break out bit & under-reamer. NOTE: bit & rea mer in gage, very little damage to tools. PJSM & rig up to run liner. Run liner & hanger - packer tools as per pro gram. Continue to run liner on dp to window [7860' ] . Cir con mud above window. Complete cir / conditioning above window @ 7850',850 psi / 3.5 bpm. Ck up / dwn wts of 115k / 65k Ibs Continue to rih w/ liner below window [did n ot see same] to 90' above td. Ck up / down wts of 65k / 125k Ibs. Brk cir @ 1000 psi / 1.5 bpm. Increase cir r ate to 1600 psi / 2.4 bpm. Circulate down t 0 td of 8990' [tally cks w/in 2 ']. Work pipe , numerous instances of packing off, no mud losses. Work up 20' twice, very sticky - w ork to desired setting depth of 8980' & stop reciprocation. Reduce YP to <19. final cir rate 1650 psi /4 bpm. PJSM [cmt ops & as so safety], continue to c ir - condo Batch mix 200 sx / 40 bbl emt & 50 bbls 12.2 ppg mud push. Dowell cmt liner as follows: Pump 5 bbl CW 100 wash, pressure test pump & lines to 300 0 psi /5 min good. Follow w/ 25 bbl CW 10 0,2 bpm /1200 psi. Pump 50 bbl Mud push [12.2 ppg] 3.5 bpm - 1650 psi. Follow w/ 4 0 bbl - 200sx IGasBloc" cmt @ 15.8 ppg [yie Id 1.16/ wtr 5.13 gal/sx, adds = .450% D 065,3.0% D053, 2 gps D600, .2 gpsx 0047, .3% M117]; Pressures / rates [min - max - avg] = 300 - 1800 - 1200 psi / 3.1 - 4 - 3. 8 bpm. Disp w/ 10 bbl fw & 68 bbl mud, pre ssures / rates min - max - avg = 300 - 1700 - 2300 psi / 3.5 - 5.5 - 4.0 bpm. Caught line r wiper plug 2 bbl early, plug bumped 2bbl e arly. Increrased pressure to 3000 psi to set hanger. Ck set w/ up down wts of 1 Ok 0 ver up & down 50k. Set pkr w/ 15 cwise tur Printed: 12/14/2001 10:29:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/10/2001 11/11/2001 (~ (' PHilliPS ALASKA INC. Operations Summary Report 1 F-1 6 1 F-16 ROT - SIDETRACK Nordic Nordic 3 Sub From - To Hours Code Code Phase 04:30 - 06:30 06:30 - 08:30 08:30 - 09:30 09:30 - 12:30 12:30 - 14:30 14:30 - 21 :00 21:00 - 21:30 21 :30 - 23:30 23:30 - 00:00 00:00 - 01 :00 Page 4 of 6 Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations 2.00 CEMEN PUMP CMPL TN n e s & 8 0 0 psi. Set d 0 w n 2 5 k I b s , goo d she ar on pins. Pu off tie back sleeve checking free. 2.00 CEMEN CIRC CMPL TN Pic k u p 2 ' & c i r 1 5 b b I v ¡ad p , sur fa c ere t urns. Set up to rev cir, pressure high [>230 0 psi / < 2 bpm] Ck surface line up. Make t wo attempts. Set up to cir conventionally, high cir pressure but decreasing. Final pre ssure / rate 1750 psi / 4 bpm. Recovered s pacers & 24 bbl cmt contaminated mud to su rface. CIP = 0609 hrs. Work string in tie b ack sleeve. 1.00 CEMEN TRI P CMPL TN P 0 0 h w / c m t s t r i n g . 3.00 RIGMNT RGRP CMPL TN Top d r i v e bin din g 0 n tor que tub e . C I e a n r a i I & replace teflon pads on bushings of TDS. 2.00 CEMEN TRIP CMPL TN 6.50 CEMEN SFTY CMPL TN 0.50 CEMEN COUT CMPL TN 2.00 CEMEN CIRC CMPLTN 0.50 CEMEN CIRC CMPLTN 1.00 CMPL TN CIRC CMPL TN 01 :00 - 02:00 1.00 CMPL TN TRI P CMPL TN 02:00 - 03:00 1.00 WELCT OTHR CMPL TN 03:00 - 06:00 3.00 WELCT NUND CMPL TN 06:00 - 12:00 6.00 WELCT EaRP CMPL TN 12:00 - 15:00 15:00 - 19:30 3.00 WELCT NUND CMPL TN 4.50 WELCT BOPE CMPL TN 19:30 - 20:00 0.50 CMPL TN TRI P CMPL TN 20:00 - 00:00 4.00 CMPLTN TRIP CMPL TN 11/12/2001 00:00 - 04:00 4.00 CMPLTN TRIP CMPL TN 04:00 - 05:00 1.00 CMPLTN OTHR CMPL TN Continue tooh, no damage to liner setting t 001 s. Tih w/ 4 1/8" mil, 5" x 18 ppf csg scraper & 2 7/8" motor on 2 7/8" Hydrill 511 tbg & 3 1/2" dp to 8869' where noted light drag. Wash ream [3 bpm - 1800 psi] 8869 - 8893' [ Idg collar]. Cir bottoms up @3 bpm - 1550 psi, light cmt cuttings to surface @ bu, shakers clean, ci r hole volume x 1.5. Circulated 20 bbl fw weighted [11.5 ppg] pill followed by 35 bbl 11.5 ppg Na Bromide pi I I to spot from 8993' to above liner top [spo t incomplete @ rpt time]. Complete spotting a 11.5 ppg 35 bbl H EC / Na Br Pill as a ball anced pill w/ 52.0 bbl al lowing pill to U-Tube in place w/ last 2.7 bb I for a total disp of 54.7 bbl. Pooh & Id 46 its 3 1/2" dp. Ck up / down wts of 100k / 60k Ibs. Set Bak er storm packer 3.5' below well hd. ND 11 x 5k psi bop& set back. ND 7" x 3000 psi tbg spool, replace packing, install 7" 5000 spool & press test void to 3 000 psi. Nu 11" x 5000 psi bop liners & hydraulics. Set test plug, check annulus valve open. T est BOPE & surface bope to 250 / 4000 psi, 5 min each. Hydrill to 250 / 3000 psi as p er permit. Release Storm packer & pooh w/ same & lay down. Pooh LD 3 1/2" DP. Complete pooh, Id all tublars, w/ liner sett ing tool [undamaged]. PJSM Ru to run US IT / CCI log. Police up f 100 r. Printed: 12/14/2001 10:29:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/12/2001 11/13/2001 ( PHilliPS ALASKA INC. Operations Summary Report 1 F-1 6 1 F-1 6 ROT - SIDETRACK Nordic Nordic 3 Sub From - To Hours Code Code Phase 05:00 - 09:00 09:00 - 09:30 09:30 - 14:00 14:00 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 15:00 15:00 - 16:30 4.00 LOG OTHR CMPL TN 0.50 LOG OTHR CMPLTN 4.50 LOG OTHR CMPLTN 5.00 CMPL TN OTHR CMPL TN 1.00 CASE DEOT CMPL TN 1.50 CMPL TN PERF CMPL TN 2.50 CMPL TN PERF CMPL TN 1.00 CMPL TN PERF CMPL TN 0.50 CMPL TN PERF CMPL TN 4.00 CMPL TN PERF CMPL TN 0.50 CMPL TN RUNT CMPL TN 0.50 RIGMNT RSRV CMPL TN 8.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN RUNT CMPL TN Page 5 of 6 Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations Run US IT from 8875' [did not tag td - tool Ii mitation] to above liner lap7674'. Good cmt to 8190, acceptable cmtd to 8080, & deteri orating quality from 8080 to end of logging i nterval @ 7674'. LD tools & pu GR wI junk basket I gage ring of 4.08". Trip junk basket [ td =8882']. Recovered t hick watery sluge wI traces of metal. No lar ge debris. RIH wI Baker Model D Packer, correlate wI Sperry Sun MWD EWR - DGR log dated 11/10 12001 & set @ 8655',2' deeper than plann ed due to csg collar. Pooh, no damage to t 00 Is. Pressure test csg & liner to 3000 psi: initial pressure 3130, final presure 3100 psi J 30 minutes. PJSM Ru under lubricator wI packoff to per forate 1st 20' section. Correlate w/ Sperry Sun MWD EWR - DGR 10 g dated 11/10/2001 & perforate 8540 -8560', good surface indication of firing. Pooh wI tools, incomplete rpt time. Pooh wI laying down spent guns, all shots g ood. Pu guns for second perf run. Trip in wI perf run #2, correlate Sperry EW R -DGR log [11/10/2001] & perforate 8516- 8536'. 6 spf, 60? phasing 3 3/8" HSD po we rshots. Pooh, all shots good. Fluid level in well bore static. Drain stack & wash out, pull wear bushing & ru floor for running completion. Rig service Pick up & run 2 7/8" x 3 1/2" completion as per program & tih 8620', 33' above Model P acker. ck up I dwn wts of 100k Ibs & 50k Ib s. Mu cir head on last jt 3 1/2" tbg. Break cir [1/2 bpm 750 psi] & rih slowly to observe mule shoe entering sbr & 1st set of seals en tering sbr. WI pump off & tbg string open c ontinue to rih observing string taking weight as locator set down in packer. Pull up out of sbr to installS 1/2' pup to confirm locat or in place. Rih, as mule shoe & seals ente red sbr observed string taking wt & noted sa fety valve on string closed [tbg system is st ill effectively a closed system]. This compr essed the fluid in the string & inadvertenta Ily set 7" FHL packer 5' high, resulting in s eals of Model D packer only being stung in .---. Printed: 12/14/2001 10:29:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/13/2001 (' PHilliPS ALASKA INC. Operations Summary Report 1 F-16 1 F-1 6 ROT - SIDETRACK Nordic Nordic 3 Sub From - To Hours Code Code Phase 15:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 22:00 1.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN OTHR CMPL TN 1.00 CMPL TN PCKR CMPL TN 1.00 CMPL TN PCKR CMPL TN 2.00 CMPL TN PCKR CMPL TN 22:00 - 00:00 2.00 CMPLTN CIRC CMPL TN 11/14/2001 00:00 - 01 :30 1.50 CMPLTN CIRC CMPL TN 01 :30 - 03:00 1.50 CMPL TN DEOT CMPL TN 03:00 - 04:00 04:00 - 05:00 05:00 - 06:00 06:00 - 08:00 08:00 - 12:00 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN NUND CMPL TN 1.00 CMPL TN RURD CMPL TN 2.00 CMPL TN FRZP CMPL TN 4.00 CMPL TN OTHR CMPL TN Page 6 of 6 Start: 11/2/2001 Rig Release: 11/14/2001 Rig Number: 3 Spud Date: 11/4/2001 End: 11/14/2001 Group: Description of Operations 1.5'. Pu 10k Ibs over string wt to confirm p kr set, press up tbg to 800 psi confirming s eals in sbr. Discuss options wI PPCO engineering. Load pipe shed wI 3 1/2" dp & prepare to sh ear out of FHL pbr. Pick up on string to shear out of Pbr, found string free & packer not set as string cantin ued to pull @ 95k Ibs up. After pulling 1 11 2' wt decreased to 90k Ibs as seals pulled 0 ut of sbr in Model D. Confirm w/ PPCO en gineering concerning immediate ops. Space out in Model D wI locator l' above t op of sbr. Pressure up tbg to 3000 psi to s et FHL packer, maintain pressure for 15 min utes to insure pkr set [no pumping]. Bleed t bg to 0 psi, picked up to 125k [35k Ibs over string wt] to shear out of pbr. Spaced out w/ two 10', one 8' & one 2' 3 1/2" pups fo r locator to be 2', above pbr, [pups are 1 jt below hanger]. Pick up out of pbr & cir well bore to sea wat er @ 1800 psi 13 bpm. Continue to circulate [3 bpm - 1750 psi] out mud displacing wI 8.5 ppg sea water. Ldg hanger & run in tie down bolts. ck annu Ius valve open. Pressure test tbg to 3000 p si 115 minutes, bleed tbg press to 1500 psi & hold. Close annulus valve. Pressure te st 3.5 x 7" annulu to 3000 psi 15 minutes. Slowly bleed tbg press down, dump valver s heared @ 2870 psi differential. Tests chart ed. Set bp valve. Nd 11" x 5k psi Bope. Nu tree & retrieve bp valve. Instrall test pi ug. Test tree to 250 psi low & 5000 psi /15 minutes. Test packoff to 5000 psi. Retrie ve test plug. Ru lines tom freeze protect. Freeze protect well to 2200': Pump 76 bbl diesel down annulus, returns up tbg @ 4 bp m I 1140 psi. Manifold tbg to annulus via c hokr & allow to u-tube into place. Rd cir lines, set bp valve, secure well, prep to move, move rig off well head area &polic e location. Rig released for move to 3H-1 6A @ 1200 hrs 11/14/2001. Printed: 12/14/2001 10:29:10 AM If ~ AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( Re: Distribution of Survey Data for Well 1 F-16A dDl- aDO' Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 7,800.18' MD 7,867.00' MD 8,990.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 07-Dec-01 ~~~ r:""> ,t'~ If""-~ií 't !"'E':-. _I- ~ 'I" ""'" :\ì«= , ' ./$ ~, .' l~" \",1' g"""" ~ '01 ..... ' "",.11", DEC 11 2001 i\la~ka, Oil & Ga6 Gems, Ccmm~ss¡on !~nc~orag\B . DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 1 F, Slot 1 F-16 1F-16A --~, Job No. AKMM11186~ Surveyed: 9 December~ 2001 . '( SURVEY REPORT 7 December, 2001 Your Ref: API- 500293102901 Surface Coordinates: 5958962.89 N~ 539865.49 E (70017' 55.7678" N~ 149040' 37.7475" W) Surface Coordinates relative to Project H Reference: 958962.89 N~ 39865.49 E (Grid) Surface Coordinates relative to Structure: 596.28 N~ 276.80 E (True) Kelly Bushing: 106. 18ft above Mean Sea Level ~ sparrY-SUI! tJRILLING " SERVtc:êS A Halliburton Company Survey Ref: svy972o , ,þ Sperry-Sun Drilling Services Survey Report for 1 F-16A Your Ref: API- 500293102901 Job No. AKMM11186, Surveyed: 9 December, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 F , Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7800.18 50.880 144.400 5289.71 5395.89 3381.27 S 3760.24 E 5955601.62 N 543643.61 E 3381.27 Tie on point 7867.00 50.350 144.720 5332.11 5438.29 3423.34 S 3790.18 E 5955559.70 N 543673.78 E 0.875 3423.34 Window Point 7965.92 47.410 146.770 5397.16 5503.34 3484.90 S 3832.15 E 5955498.36 N 543716.07 E 3.357 3484.90 ---" 8158.39 43.470 151.260 5532.22 5638.40 3602.30 S 3902.85 E 5955381.35 N 543787.40 E 2.636 3602.30 8255.22 42.290 148.800 5603.17 5709.35 3659.37 S 3935.75 E 5955324.45 N 543820.60 E 2.115 3659.37 8352.16 40.640 153.670 5675.83 5782.01 3715.58 S 3966.66 E ' 5955268040 N 543851.80 E 3.736 3715.58 8448.96 39.360 150.020 5750.00 5856.18 3770.43 S 3995.98 E 5955213.71 N 543881.42 E 2.761 3770.43 8546.56 39.030 150.770 5825.64 5931.82 3824.06 S 4026.45 E 5955160.24 N 543912.17 E 0.592 3824.06 8644.38 38.100 153.290 5902.13 6008.31 3877.90 S 4055.06 E 5955106.55 N 543941.06 E 1.866 3877.90 8741.35 37.080 151.630 5978.97 6085.15 3930.35 S 4082.40 E 5955054.25 N 543968.68 E 1 .482 3930.35 , 8837.13 35.410 151 .180 6056.21, 6162.39 3980.07 S 4109.50 E 5955004.67 N 543996.04 E 1.766 3980.07 8926.37 34.090 150.140 6129.53 6235.71 4024.42 S 4134.41 E 5954960.46 N 544021.19 E 1.621 4024.42 8990.00 33.150 149.400, 6182.52 6288.70 4054.86 S 4152.15 E 5954930.12 N 544039.09 E 1.612 4054.86 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 106' MSL. Northings and Eastings are relative to 564' FNL & 109' FEL. Magnetic Declination at Surface is 25.965° (05-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 564" FNL & 109' FEL and calculated along an Azimuth of 180.000° (True). , .-." Based upon Minimum Curvature type calculations, at a Measured Depth of 8990.00ft, The Bottom Hole Displacement is 5803.64ft, in the Direction of 134.321 ° (True). 7 December, 2001 - 9:03 Page 2 of 3 DrlllQuest 2.00.09.003 , ,þ Kuparuk River Unit Comments Measured Depth (ft) 7800.18 7867.00 8990.00 .'. . ~._' Sperry-Sun Drilling Services Survey Report for 1F-16A Your Ref: API- 500293102901 Job No. AKMM11186, Surveyed: 9 December, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5395.89 5438.29 6288.70 3381.27 S 3423.34 S 4054.86 S Survey tool program for 1 F-16A Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 7 December, 2001 - 9:03 0.00 To Measured Vertical Depth Depth (ft) (ft) 8990.00 6288.70 Comment 3760.24 E 3790.18 E 4152.15 E Tie on point Window Point Projected Survey Survey Tool Description MWD Magnetic (1 F-16A) ------ - Page 3 of 3 . North Slope, Alaska Kuparuk 1 F .-~" ,~. DrmQuest20~0~003 II 'I, ~' \ qo I-dOC¡ Phillips Alaska. Inc. Pad 3H 16A slot #16A Kuparuk River Unit North Slope. Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: PMSS <9810-10943'> Our ref: svy6749 License: API# 500292102901 Date printed: 3-May-2002 Date created: 2-May-2002 Last revised: 2-May-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is n70 24 45.853.w150 0 39.451 Slot Grid coordinates are N 6000550.093, E 498654.336 Slot local coordinates are 1107.00 S 281.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North (' (' t Phillips Alaska. Inc. SURVEY LISTING Page 1 Pad 3H.16A Your ref: PMSS <9810-10943'> Kuparuk River Unit.North Slope. Alaska Last revised: 2-May-2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 9698.00 86.12 210.42 5965.21 674.69S 6882.86W 0.00 6298.07 491772.02 5999876.97 9700.00 86.24 210.63 5965.35 676.41S 6883.87W 12.07 6299.81 491771.01 5999875.25 9735.42 88.65 202.94 5966.93 707.97S 6899.80W 22.73 6329.39 491755.07 5999843.70 9771.87 90.74 206.76 5967.12 741. 04S 6915.12W 11.95 6359.18 491739.75 5999810.64 9799.30 91. 57 210.32 5966.57 765.12S 6928.22W 13.32 6382.57 491726.65 5999786.56 9810.00 91.80 212.55 5966.25 774.25S 6933.79W 20.90 6391.96 491721. 07 5999777.43 9837.99 78.46 211.04 5968.62 797.90S 6948.46W 47.98 6416.49 491706.40 5999753.79 9863.52 90.65 212.56 5971.04 819.45S 6961.83W 48.11 6438.84 491693.03 5999732.24 9895.34 91.51 211.10 5970.44 846.48S 6978.60W 5.32 6466.89 491676.25 5999705.22 9931. 36 89.57 208.93 5970.10 877.675 6996.62W 8.08 6498.08 491658.23 5999674.04 9965.03 91.23 212.66 5969.87 906.585 7013.85W 12.13 6527.47 491640.99 5999645.13 9998.26 90.68 215.93 5969.31 934.035 7032.57W 9.98 6557.40 491622.26 5999617.69 10032.87 89.69 217 .88 5969.20 961.705 7053.35W 6.32 6589.23 491601.48 5999590.02 10062.76 90.83 220.64 5969.07 984.845 7072.27W 9.99 6617.18 491582.56 5999566.89 10092.36 90.12 223.89 5968.82 1006.745 7092.17W 11. 24 6645.37 491562.66 5999544.99 10120.77 90.74 227.69 5968.61 1026.555 7112. 53W 13.55 6672.91 491542.29 5999525.20 10150.10 93.41 228.75 5967.54 1046.085 7134. 38W 9.79 6701. 60 491520.44 5999505.68 10188.81 92.36 230.47 5965.60 1071.135 7163.83W 5.20 6739.62 491490.99 5999480.63 10225.52 92.33 234.44 5964.09 1093.475 7192.91W 10.81 6775.98 491461.91 5999458.30 10253.25 91.41 235.34 5963.19 1109.415 7215.58W 4.64 6803.58 491439.24 5999442.36 10283.04 91.26 237.70 5962.49 1125.845 7240.42W 7.94 6833.31 491414.40 5999425.94 10313.19 91.56 241.58 5961.75 1141.075 7266. 42W 12.90 6863.44 491388.39 5999410.72 10353.35 90.49 242.99 5961.03 1159.755 7301.96W 4.41 6903.56 491352.85 5999392.05 10383.23 91.69 246.95 5960.47 1172.385 7329.03W 13.85 6933.32 491325.79 5999379.42 10417.85 94.48 247.96 5958.60 1185.645 7360.95W 8.57 6967.59 491293.86 5999366.18 10448.03 94.73 250.29 5956.18 1196.365 7389.06W 7.74 6997.29 491265.76 5999355.47 10478.44 93.43 252.84 5954.01 1205.955 7417.83W 9.39 7027.00 491236.98 5999345.88 10508.89 92.73 255.26 5952.38 1214.305 7447.06W 8.26 7056.50 491207.75 5999337.54 10538.81 92.40 257.31 5951.04 1221.395 7476. lOW 6.93 7085.19 491178. 72 5999330.46 10568.90 91.96 261. 49 5949.89 1226.925 7505.65W 13.96 7113.54 491149.17 5999324.93 10603.35 90.71 265.49 5949.09 1230.82S 7539.86W 12.16 7145.12 491114.96 5999321.04 10633.23 90.15 268.54 5948.87 1232.385 7569.70W 10.38 7171. 74 491085.13 5999319.49 10663.25 89.91 270.44 5948.85 1232.645 7599.71W 6.38 7197.87 491055.11 5999319.23 10693.37 89.39 273.49 5949.04 1231.615 7629.81W 10.27 7223.41 491025.02 5999320.27 10723.20 88.13 275.52 5949.68 1229.275 7659.54W 8.01 7247.99 490995.29 5999322.62 10753.15 88.65 278.14 5950.52 1225.715 7689.26W 8.92 7271.95 490965.58 5999326.18 10795.31 88.80 282.89 5951.46 1218.025 7730.69W 11.27 7303.98 490924.15 5999333.88 10825.61 87.61 284.74 5952.41 1210.795 7760. lOW 7.26 7325.84 490894.75 5999341.12 10856.36 86.69 288.47 5953.94 1202.015 7789.53W 12.48 7346.93 490865.33 5999349.90 10884.15 85.95 290.07 5955.72 1192.865 7815.70W 6.33 7365.03 490839.15 5999359.05 10914.14 87.79 292.25 5957.36 1182.05S 7843.63W 9.50 7383.81 490811.24 5999369.87 10943.00 89.60 294.40 5958.02 1170.635 7870.12W 9.74 7401. 04 490784.75 5999381.29 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16A and TVD from wellhead (68.72 Ft above mean sea level). Bottom hole distance is 7956.70 on azimuth 261.54 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 240.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke. 1866 spheroid Presented by Baker Hughes INTEQ ~' Phillips Alaska. Inc. Pad 3H.16A Kuparuk River Unit,North Slope. Alaska MD TVD .- - - ----- - -. --.----- -- .--. - --- - ---- - - --- ----------------- -.------ - ---- -- - --- - --------- - - -.-- --- ---- --- - --.- 9810.00 5966.25 Top MD Top TVD Rectangular Coords. Comments in wellpath Comment (" SURVEY LISTING Page 2 Your ref: PMSS <9810-10943'> Last revised: 2-May-2002 Rectangular Coords. Bot MD Bot TVD Casing positions in string 'A' Rectangular Coords. 0.00 0.00 ----.------------------------------------.------------.-------------.-.------------.----------------------- Casing Target name 774.25S 6933.79W Tie-in Point 1170.63S 7870.12W 2-3/8" 1266.95S 7945.85W O.OON O.OOE 10943.00 5958.02 Geographic Location T.V.D. Targets associated with this wellpath Rectangular Coordinates Revised -. - - - -- - - - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - -. - - - - - -- - - - - - - - - - - - - - - -. - -. - - - - - - - - - - - - - - - - - - - - -. - -.. - - - -... ---- 8-Jan-2002 ------------------------------------- ---------------- ------------ 3H-16B BHL Rvsd 07-J 490709.000.5999285.000.2.0000 5915.72 #'" ( ~ ðOI-aoc¡ \. \ ~ Phillips Alaska, Inc. Pad 3H 16APB1 slot #16A Kuparuk River Unit North Slope. Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: PMSS <9700-10457'> Our ref: svy6746 License: Date printed: 3-May-2002 Date created: 17-Apr-2002 Last revised: 2-May-2002 Field is centred on n70 16 18.576.w150 5 56.536 Structure is centred on n70 24 56.740.w150 0 47.688 Slot location is n70 24 45.853.w150 0 39.451 Slot Grid coordinates are N 6000550.093. E 498654.336 Slot local coordinates are 1107.00 S 281.00 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ( ~. Phillips Alaska. Inc. SURVEY LISTING Page 1 Pad 3H.16APB1 Your ref: PMSS <9700-10457'> Kuparuk River Unit.North 5lope. Alaska Last revised: 2-May-2002 Measured Inclin Azimuth True Vert R E eTA N G U LA R Dogleg Vert G RID C a a R D 5 Depth Degrees Degrees Depth C a a R DIN ATE 5 Deg/100ft 5ect Easting Northing 9698.00 86.12 210.42 5965.21 674.695 6882.86W 0_00 6298.07 491772.02 5999876.97 9700.00 86.24 210.63 5965.35 676.415 6883.87W 12.07 6299.81 491771.01 5999875.25 9735.42 88.65 202.94 5966.93 707.975 6899.80W 22.73 6329.39 491755.07 5999843.70 9771.87 90.74 206.76 5967.12 741. 045 6915.12W 11. 95 6359.18 491739.75 5999810.64 9799.30 91. 57 210.32 5966.57 765.125 6928.22W 13.32 6382.57 491726.65 5999786.56 9825.98 92.15 215.87 5965.70 787.455 6942.77W 20.90 6406.34 491712.09 5999764.23 9856.48 94.03 222.20 5964.06 811.105 6961.94W 21.62 6434.77 491692.92 5999740.59 9886.32 93.90 226.46 5961. 99 832.395 6982.74W 14.25 6463.42 491672.12 5999719.31 9915.88 94.24 231.84 5959.89 851.675 7005.03W 18.19 6492.37 491649.82 5999700.04 9946.82 91.93 237.08 5958.23 869.625 7030.16W 18.49 6523.11 491624.69 5999682.09 9976.54 91.45 242.37 5957.35 884.595 7055.81W 17.86 6552.80 491599.04 5999667.13 10009.81 89.94 248.05 5956.94 898.535 7086.00W 17.66 6585.92 491568.85 5999653.20 10038.12 91.50 254.78 5956.59 907.555 7112.81W 24.40 6613.65 491542.04 5999644.19 10069.03 90.65 256.72 5956.01 915.155 7142. 76W 6.85 6643.39 491512.09 5999636.59 10109.09 89.47 263.39 5955.97 922.075 7182. 20W 16.91 6681.00 491472.65 5999629.68 10143.01 88.51 266.90 5956.56 924.945 7215.99W 10.73 6711. 70 491438.87 5999626.82 10171. 92 88.15 270.77 5957.41 925.535 7244. 87W 13.44 6737.01 491409.99 5999626.24 10204.76 87.54 276.39 5958.64 923.485 7277 . 61W 17.20 6764.34 491377.25 5999628.29 10240.49 86.75 274.64 5960.42 920.055 7313.13W 5.37 6793.38 491341.74 5999631.73 10271.42 88.10 271.18 5961.81 918.485 7343.98W 12.00 6819.32 491310.89 5999633.30 10300.82 87.64 267.54 5962.91 918.815 7373.36W 12.47 6844.92 491281.52 5999632.98 10330.71 87.67 263.21 5964.13 921.225 7403.12W 14.47 6871.90 491251.76 5999630.58 10360.79 88.89 258.18 5965.03 926.085 7432.78W 17.20 6900.01 491222.10 5999625.73 10392.22 93.01 256.07 5964.51 933.085 7463.41W 14.73 6930.04 491191. 47 5999618.74 10421. 33 93.04 250.39 5962.97 941.465 7491.23W 19.49 6958.32 491163.65 5999610.36 10457.00 94.00 244.00 5960.78 955.255 7524.03W 18.08 6993.63 491130.85 5999596.58 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16A and TVD from wellhead (68.72 Ft above mean sea level). Bottom hole distance is 7584.43 on azimuth 262.76 degrees from wellhead. Vertical section is from S 0.00 W 0.00 on azimuth 240.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid. Presented by Baker Hughes INTEQ Ii (~ ( Phillips Alaska. Inc. Pad 3H.16APB1 Kuparuk River Unit.North Slope. Alaska SURVEY LISTING Page 2 Your ref: PMSS <9700-10457'> Last revised: 2-May-2002 MD TVD Rectangular Coords. Comments in wellpath Comment ---------------------------------------------------------------------..---------.-------------------------- 10457.00 5960.78 955.25S 7524.03W PROJECTED DATA to TD Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised --- --- - - --- -- - - -- ------ -- - - - --- - -- - -- - -.- -- - - --- -- ------- - - - - -- - - - ----- - - - -- -- - -.- --- -- - - - - ----- - - --- - - - -'- 3H-16B BHL Rvsd 07-J 490709.000.5999285.000.2.0000 5915.72 1266.95S 7945.85W 8-Jan-2002 Date 10/14/01 10/19/01 10/20/01 (' 1 F-16 Event H ¡story ( Comment TAGGED @ 8822' RKB, EST. 14' RATHOLE. DRIFTED TBG W/ 2.75" X 4' DMY TO 8810' RKB, NO PROBLEM. [TAG] WEATHERFORD 2.749"X1.46' CEMENT RETAINER SET AT 8447' RKB. 44 BBLS OF CLASS "G" CEMENT PUMPED BELOW RETAINER (12 BBLS INTO TBG/CASING, 32 BBLS BEHIND PIPE). CEMENT CAP LAYED FROM TOP OF RETAINER AT 8447' RKB TO LEAK AT SBR AT 8346'. TUBING / MANDRELS WAS CARRY-OVER FROM PREVIOUS DAY'S JOB (ENDED @ 3:00 AM 10/20/01). [CEMENT-POLY SQUEEZE] 10/23/01 10/25/01 11/04/01 STATE WITNESSED MIT. GOOD UNABLE TO DETERMINE TOP OF CMT PLUG. TAGGED (2.30") @ 8241' WLM & GETTING STUCK. [MIT, TAG] CUT PIPE AT 8234' (ELM) WITH 2.7" JET CUTTER. CCL TO CENTER OF JET CUTIER: 4.4 FT, STOP CCL: 8229.6 FT SET FRAC SLEEVE @ 1896' RKB. [SSSV WORK] Page 1 of 1 12/14/2001 Date 11/22/01 11/23/01 11/26/01 11/27101 11/28/01 11/29/01 11/30101 12/01/01 12/11/01 (" 1 F-16A Event History ( Comment PULLED SOV F/7366' RKB, ATTEMPTED TO PULL BALL & ROD FI RHC PLUG @ 8578' RKB, UNSUCCSSFUL DUE TO THICK FLUID, IN PROGRESS. [OPEN-CLOSE C SAND] SET DV @ 7366' RKB, PfTBG GOOD, TAGGED FILL IN TBG @ 8562' RKB, HAVE SAMPLE OF DRILLING MUD, [OPEN-CLOSE C SAND] CLEANED OUT MUD TO TOP OF BALL & ROD/RHC PLUG AT 8565' CTM WI SEAWATER J313 AND DIESEL GEL, USING A 1.75" VORTECH NOZZLE. WELL FREEZE PROTECTED WI DIESEL TO 2500'. [FCO, VORTECH] PULLED RHC PLUG @ 8578' RKB. 1"OD BALL IN TBG. DRIFTED TBG (14' X 1.875") &TAGGED FILL @ 8719' RKB. *******NOTE 1" OD BALL SOMEWHERE IN TBG********* [TAG] OPENED SLIDING SLEEVE @ 8578' RKB, IN PROGRESS [OPEN-CLOSE C SAND] DRIFTED TBG WI 15' OF 1.875" & TAGGED @ 8886' RKB, C SAND STATIC @ 8538' & 8438' RKB, SHUT SLIDING SLEEVE @ 8578' RKB, [TAG, PRESSURE DATA, OPEN-CLOSE C SAND] PERFORATED BOTH A SANDS, GOT SBHP. WELL PREP'D FOR HPBN TOMMOROW. PUMPED INITIAL HPBD. PUMPED 1745 BBLS SLICK SEAWATER AND 5000# 20/40 SAND IN 2 SCOUR STAGES AND 1 DIVERSION STAGE (150# ROCK SALT). RATES FROM 20 BPM TO 36 BPM, TREATING PRESSURE VARIED FROM 5900 PSI TO 9000 PSI. SAW VERY HIGH PERF FRICTION IN FIRST S TAGGED SOFT BOTTOM @ 8852' WL, EST. 100' RATHOLE. INJECTIVITY TEST: INJ 10 BBL DSL @ 1 BPM, 2300 PSI. [TAG] Page 1 of 1 1211412001 i: ~V!A\VŒ ffi)~ !A\~!A\~~!A\ / ALAS IiA. 0 IL AND GAS / CONSERVATI ON COMMISSION ,~ ~ TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. . PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit IF-16A Phillips Alaska, Inc. Petmit No: 201-209 Sur. Loc. 564' FNL, 109' FEL, Sec. 19, TIIN, RI0E, UM Btmhole Loc. 599' FSL, 1528' PEL, Sec. 20, TIIN, RI0E, UM Dear Mr. Mallary: Enclosed is the approved application for petmit to drill the above referenced w~ll. The petmit to drill does not exempt you from obtaining additional petmits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit IF-16A. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S incerel y, ~ ,OLtU c ii-/ camm~dLhSli Taylor Chair BY ORDER OF THE COMMISSION DATED this 30thday of October, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ (' :j ~ Note to File KRU 1F-16A...201-209 Phillips has applied to redrill KRU well 1 F-16. This well is a class II R injector that as originally drilled in late 1983 (183-153) and converted to injection service in August 1996. In late April, 2000 the Commission was notified of annulus pressure problems which were later identified as a leaking SBR. Since identification of the problem, the well has not been used for injection. The purpose of this note is to document the proposed placement of the upper packer in the new completion. Phillips is proposing to run a straddle packer completion to allow selective injection in the A and C sand as appropriate. The packer for the lower A sand will likely be set within the required 200' md of the perforations. The upper packer could be set as much as 1000' above the top of the C sands. The upper packer is intended to be set near the new liner top. Given the new wellbore geometry and with no USDWs present in the Kuparuk Field, the proposed packer depth is acceptable. Phillips intends to fully cement the new liner and have it equipped with a liner top packer. They also intend to run a bond log to assess the condition of the newly cemented liner. While doing this it should be possible to run the log over the portion of the 7" casing that will be below the packer. According to the cementing information on the original well, sufficient cement was circulated to bring the cement top well above the intended sidetrack point. The condition of that cement should have only improved with time. As noted, when the new liner is logged that portion of the casing below the intended packer depth can be examined as well. I have included that requirement as part of the approval. I recommend that the permit for 1 F-16A be approved. ~~ Tom Maunder, PE Sr. Petroleum Engineer Re: 1F-16A Information ~\ ," ;~. Subject: Re: 1 F-16A Information Date: Wed, 24 Oct 2001 11 :43:35 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Todd J Mushovic <tmushov@ppco.com> Todd, Thanks for the info. My questions are answered and I will move the permit on. Tom Todd J Mushovic wrote: > Tom, > > Here are the answers to the questions that you ask earlier this morning. > > The cement volume for the liner is 47 bbls. > > The BOP test will be 5000 psi unless a pressure is mandated by the AOGCC. > > The hole diameter that is planned is 6.5" and will be achieved with a near > bit reamer. By opening the hole up the chances are greater that the liner > will get to bottom and a more successful cement job will be completed. > > If you have any questions please feel free to give me a call. > > Thanks > > Todd J. Mushovic > Drilling Engineer > Phillips Alaska Inc. > (907) 265-6974 .. office > (907) 240...5740 ... cellular ,---.-.-- ~~ Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ---- 1 of 1 -If { 10/24/0111:43AM PHILLIP...; Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (" Post Office Box 100360 Anchorage,AJaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Emai/: jtranth@ppco.com October 12,2001 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 RECEIVED OCT 1 9 2001 Re: Application for Permit to Drill, Kuparuk Injector 1 F-16A Alaska Oil & Gas Cons. Commission: Anchorage Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, Kuparuk well #1F-16A. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). Subject to AOGCC approval, fluids generated from drilling the sidetrack will be pumped down an approved KRU Class" disposal well and all drill solids will be hauled to an approved facility for grind and inject disposal. If you have any questions or require any further information, please contact Todd Mushovic at 265-6974. C. R. Mallary Drilling Engineering Supervise OR\G\NAL \ t ( 8T A TE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Ir l°b-'l 1a. Type of work: Drill b!J Redrlll U Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 10.0.360. Anchorage, AK 99510-0.360. 4. Location of well at surface 564' FNL, 109' FEL, Sec. 19, T11 N, R10.E, UM At top of productive interval 886' FSL, 1538' FEL, Sec. 20., T11N, R10E, UM At total depth 599' FSL, 1528' FEL, Sec. 20., T11 N, R10.E, UM 12. Distance to nearest property line 13. Distance to nearest well 599' @ TD feet none 16. To be completed for deviated wells Kickoff depth: 7878 MD 18. Casing program size 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone G1,,¿, ~ 5. Datum elevation (DF or KB) RKB = 10.7 feet AMSL feet 6. Property Designation ADL 25652 ALK 2578 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 F-16A #59-52-180. 9. Approximate spud date Amount October 31,20.0.1 $20.0.,0.0.0. 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8950. ' MD / 6256 ' TVD 17. Anticipated pressure (see 20 MC 25.035 (e)(2)) Maximum surface ~sig At total depth (TVD) 3812 psig Settine Depth (}\o ~";r.. ", I Bottom TVD Development Oil U Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk Oil Pool Maximum hole angle 51° Hole Casing Weight Specifications Grade CouplinQ LenQth Top MD TVD MD Quantity of Cement (include staç e data) 6.5" 5" 18# L-80. FL-4S 130.0.' 7650.' 530.0' 8950.' 6256' Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Kt:l;t:IVED Total Depth: measured true vertical 9175 feet 6386 feet Plugs (measured) OCT 1 9 2001 Effective Depth: measured true vertical 8727 feet 6041 feet Junk (measured) Alaska Oil & Gas Cons. Commission Anchorooe Measured depth True \Tertlcal depth 110' 110' 4496' 3462' 9064' 630.0.' Casing Conductor Surface Production Length 110.' 4390.' 8958' Size Cemented 16" 190. sx CS II 9-5/8" 1250 sx AS II & 80.0 sx Class G 7" 450. sx Class G & 250. sx AS I Perforation depth: measured to be squeezed off: 8544'-8568', 8572'-8603', 8634'-8636', 8700'-870.2',8742'-8756',8780'-880.8' true vertical 5905'-5922',5925'-5948',5971'-5973', 60.21'-60.22', 60.52'-60.63', 60.81'-6102' 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I' hereby ce?ltha~ ?t;i:9 ~ (f f'\(~or_rect to the best of my kn.oWledge Questions? Call Todd Mushovic ~5-697. I Signed c.:M~; V~ I/.:/L /1-- TrUe: Drimng Engm"""ng SUP",V"" D~ / ? .t?- u ~:... f ) Commission Use Onl~ Permit Number. . Q API number , . ð I Approval dat~ ~1 r\ ..<\ /'!'"\ See cover lett.er 7-6/- P.D7 50- Dz.q- 2.-1 62!:-I-DIf)/~K) I for other reqUIrements Conditions of approval Samples required 0 Yes [EI No Mud log requlredl ( 0 Yes Œf No Hydrogen sulfide measures ~ Yes 0 No Directional survey required 00 Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D 0 ~~c:;\ M\"\""'\.:.1"\ \SeJ?~-\ Other: c..~CV'<c.~-\ ~'-J~\~~\-'\(:)~ ~~.~ ~. ~~ \ \ 4c>~à ~ Q:l.b~~x. ~~~ ~r~þ~ by order of l'r) " , Approved bv Original {'\«, . Rv Commissioner the commission Date I (J ::.-x.) In Cammy Oechsri Form 10-40.1 Rev. 12/1/85. 0 H / G I NALriPlicam (" Appj" 'ion for Permit to Drill, Well 1 F-16A , Revision No.O Saved: 17-0ct-O1 Permit It - Kuparuk Well 1 F-16A Application for Permit to Drill Document Mc.:<imizE Well Value Table of Contents 1. Well Name.... ............................. ............................................................. ............. ...... 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary ................... ... ....................................................... ...... .... ....... ..... 2 Requirements of 20 AAC 25. o05(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.o50(b)........................................................................................................2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25. o05(c)(3) ........................................................................ ."..... ...................3 4. Dri II i ng Hazards I nformati on ...... .................................................. ..................... ...... 3 Requirements of 20 AAC 25.005 (c)(4) .."".""""""."'.""""'.".""."""".""""""""""""""""""""""'" 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementi ng Program ........................................................... ........... .......3 Requirements of 20 AAC 25.oo5(c)(6) ................................."................................................................3 7. Diverter System Information..... .................................................. ...................... ...... 4 Requirements of 20 AAC 25.oo5(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program.................................................................. ............. ......... ..... 4 Requirements of 20 AAC 25. o05(c)(B) ..................................................... """""'" .................................4 9. Abnormally Pressured Formation Information ...................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 10. Seismic Analysis ................ ....... ................................. ........................ ...................... 4 Requirements of 20 AAC 25.005 (c)(1 0) ........................................................................................... ..... 4 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ........ ................................................ ........ ................. ............... 5 12. Evidence of Bond i ng........................ ................................. ........... ............................ 5 Requirements of 20 AAC 25.005 (c)(12) '........"""'.."...""""......'..""'."..""".".'...................................5 13. Proposed Dri II i ng Program............... ................................ ........... ............................ 5 1F-16A PERMIT IT DOC Page 1 of 6 V ¡~n,ec~;t~~c~o;. ¿. (' Apl1F +ion for Permit to Drill, Well 1 F-16A ~ Revision No.O . Saved: 17-0ct-O1 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 5 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 5 15. Attachments..... ..... ........ .............................. .... ........... ....... ....................... ................6 Attachment 1 Directional Plan................................................................................................................ 6 Attachment 2 Well Schematic..............................................................................................6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number ass(qned by the COlnJm:t;5iol7 under 20 MC 25: 040(b). For a well with multiple well branches, each brancl7 must similarly be identified by a unique name and APi number by adding a suffix to the name designated for the well by the operator and to the number assigned to tl7e well by tf7e commis..c,ion. The well for which this Application is submitted will be designated as IF-16A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dnll must be accompanied by each of the following items, eXCtpt for an item already on file with the commission and Identified in the application: (2) a plat identifying the property and the propelty's owners and showing (A)tht? coordinates 01' the prop05è~d location 01' the well at the surface/ at the top of each ol~jective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of tIle well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administratiol7¡' (C) the proposed depth of the well at the top of' each objective formation and at total depth' Location at Surface I 564' FNL, 109' FEL, Sec 19, Tl1N, Rl0E, UM NGS Coordinates RKB Elevation 107.1' AMSL Northings: 5,958,963 Eastings: 539,865 Pad Elevation 76.8' AMSL Location at Top of Productive Interval Ku aruk "A3" Sand NGS Coordinates Northings: 5,955,155.53 886' FSL, 1538' FEL, Sec 20, TllN, Rl0E, UM Eastings: 543,749.99 8498' 5907' 5800' Location at Total De th 599' FSL 1528' FEL NGS Coordinates Northings: 5,954,868.34 Eastings: 543,762.91 8950' 6256' 6194' and (D) other 1Ì7forrnation required by 20 AAC 25. 050(b),- Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application (or a Permit to Drill (Form .10,.401) must (1) ti7e1ude a plat drawn to a sUltaIJle sc.;¡lel showing the patl7 of the proposed wellbore1 1¡7e1uding all adjacent wellbores withli7 200 feet of any portion of the proposed well¡, Please see Attachment 1: Directional Plan 1 F-16A PERMIT IT. DOC OFlfðÏfJA L ,. ( Ap¡:t ~ion for Permit to Drill, Well 1 F-16A , Revision No.O Saved: 17-0ct-O1 and (2) for all wells within 200 feet of the proposed wellbore (A) list tl7e names of the operators of those wells, to the extent that those names are known or discoverable in public records; and show that each named operator has been furnished a copy of the application by certified mai~' or (B) state that tbe applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(e)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.03~ as applicable; Please reference BOP schematics on file for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (e)(4) An application for a Permit to Drill must be acr:ompanled by each of the following Items/ except for an item already on file wlZh the commission and Identified in tbe application: (4) information on dn/ling hazards, including (A) the maximum downhole pressure that may be encountere4 cTiteria used to determine it and maximum potential swface pressure based on a methane gradient: ~ {¡PO 77~ (), Q'p ~i./.fÎ:- /0.-7 ¡:;e~ emtJ " The ~ected res air press e in'the Kupßruk A3 sand for the IF-16A well bore replacement sidetrack is 3~B7 ;>185 psi at 5 ' tvd, ~ psi/ft or lU'Ppg EMW (equivalent mud weight). This press,ure was ~btained . . '. from 3G-l and matc es offset pre~re data for the Kuparuk sands. .~ ð.."WI'~'¡'(.ir11S rf. <!-ý -rodd Jt(".$/¡o~.J(c. It), Zg 'L'? I ;--$.:Jy- The maximum potential surface pressure (MPSP) while drilling the sidetrack is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the A3 sand target at 5865' tvd: MPSP =(5865 ft)*(~- 0.11 psi/ft) = 3167 psi C:.S~... 0 .l\ ') -:.. ~ lø ~, ~')\ Â~7f1 ,o/~", (8) data on potential gas zone5~' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems slJCh as abnormally geo-pressured strata, lost circulation zones, and zones that 17ave a propensity for differential sticking; See attached drilling hazards summary page. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (e)(5) An application for a Permit to Drill must be accompanied by eacf¡ a/the following items, except for an item already on fìle wIth the commi!:í"sion and Identified in the application: (S) a desaiption of the procedure for conducting folmation integrity test~ as required under 20 AAC 2S.030(f); Perform FIT test to 13.0 ppg (expected ECD at window for 11.2 ppg LSND mud) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(e)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already 017 file wIth the commission and Identifïed in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a desaiption of any slotted lil7e~ pre"" perforated lil7e~ or screen to be installed; 1 F-16A PERMIT IT. DOC poR1ŒNAL f ApAJ' .ion for Permit to Drill, Well 1 F-16A ~- Revision No.O Saved: 17-0ct-O1 Casing and Cementing Program Hole Top 8tm CsgíTbg Size Weight Length MOfTVO MOfTVO 00 (in) (in) (Ib/tt) Grade Connection (tt) (tt) (tt) Cement Program 5 6-1/2 18 L-80 FL-4S 1300' 7650' 1 5300' 8950' 1 6256' Class G wI additives* *Cement volume sufficient to bring TOC 150' above liner top. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items/ except for an item already on file wIth the commission and Identified in the application: (7) a diagram and dô-cription of "the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); N/A - Sidetrack out of 7" with BOP installed. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must" be accompanied by ead7 of the fbllowing items~ except for an item already on file with the commission and identified in the application: (8) a dn/ling fluid prograrn induding a dÌt.'7gram and desCTiption oftl7e drilling flwd systern as required by 20 MC 25.033/' Drilling will be done with a freshwater GEM system having the following properties: Millin Drillin 11.2 45-65 20- 25 11-25 11.2 45-65 20- 25 11-27 Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application fbr a Permit to Drill must be accompanied by each of the following items, except for an item already 0/7 file with the commission and identified in the applicat¡()f7: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths' of predicted abnormally qeD-pressured strata as- required by 20 MC 25: 03J(f}; N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to On!1 must be accompanied by each of" the following Item.'i¡ except for an item already 017 tHe with the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seismic rekaction or reflection analysis as required by 20 MC 25. 061 (a)/ N/A - Application is not for an exploratory or stratigraphic test well. 1 F-16A PERMIT IT. DOC Page 4 of 6 (rrted: 17-0ct-O1 .. L \I11'U'~VM , (' APlt tion for Permit to Drill, Well 1 F-16A ~ Revision No.O Saved: 17-0ct-O1 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a PermIt to Dnll must be accompanied by each of the following Items¡ except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobIle bottom-founded structure, jack-up rig, or floatti7g drilling vessel an analysis of seabed condItions as required by 20 MC 25.061(b): NI A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the followti7g items, except for an item already on file with the commi5:c;ion and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the {o/Iowing items, except for an item already on file wIth the commi.~1on and Identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 2, Well Schematic. 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Circulate well to seawater through tubing cut at 7556' MD. Verify well is dead. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. 6. RU E-line Unit. RIH and set Bridge Plug at 7897' MD. Test bridge plug/7" casing to 3000 psi. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, etc and RIH. Circulate well to 11.2 ppg milling fluid, orient and set whipstock wI MWD. Shear off whipstock bolt and mill window in 7" casing and 20' formation. Perform FIT test to 13.0 ppg (expected ECD plus SF at window for 11.2 ppg LSND mud). POOH and LD milling assembly. Note: If unable to obtain adequate FIT, squeeze window with cement, redrill and test again. 8. RIH wI 6-1/2" bit, MWD I LWD, and steerable drilling assembly. Slide out window, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH and lay down drilling assembly. 9. Run 5" liner to TD wI 150' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH. 11. PU scraper and RIH to Shoe. TOH laying down DP. 12. RU Schlumberger and run a bond log, Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). Set bottom selective packer wI E-Line. Perforate C sands. RD Schlumberger. 13. RIH wI 3-1/2" x 2-7/8" completion assembly and sting into Bore Seal. Space out. Displace well to seawater, set top packer, and land tubing. Test annulus to 3000 psi. 14. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic 3. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mu.'itc be accompanied by each of the following items~ except for an item already on file with tile commis..c,jon and idenl7lìed in the application: (14) a general description of how the operator plans to dispose or drilling mud and cuttings and a 5.tatemen{ of whell7er the operator intends to request autholizatio/7 under 20 AAC 25.080 for an an/7ular disposal operatio/7 ín the well.; 1F-16A PERMIT IT DOC otfl~ A L {' , APij," tion for Permit to Drill, Well 1 F-16A \ Revision No.O Saved: 17-0ct-O1 Waste fluids generated while drilling the sidetrack will be hauled to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for annular disposal operations in this well. 15. Attachments Attachment 1 Directional Plan Attachment 2 Well Schematic. 1F-16A PERMIT ITDOC Page 6 of 6 (}Î;,: uj¡~ A L Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. 9-5/8" J-55 casing @ 4496' MD I 3462' TVD 5-1/2" liner top @ +/-7650' MD Sidetrack KOP @ +1- 7878' MD Baker "K-1" BP @ 7897' MD Tubing cut at +/- 8100' MD Cameo HRP-1-SP Packer @ 8367' Current C Sand Perfs Baker FB 1 packer @ 8641' MD Current A Sand Perfs 7", 26#, J-55 casing @ 9064' MD ( 1 F-16A Proposed Çompletion ( 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down 3-1/2",9.3#, L-80 EUE 8rd tubing to surface 3-1/2" Camco 'DS' landing nipple with 2.875" ID No-Go profile set at +1-500' MD 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM 3-1/2" x 1-1/2 " MMG mandrel (Max OD 5.968, Min ID 2.867) 1 joint 3-1/2" L-80 9.3# EUE 8rd Mod tubing. 3-1/2" Camco 'DS' landing nipple with 2.812" ID No-Go profile 1 joint 3-1/2" L-80 9.3# EUE 8rd Mod tubing. Baker 7" FHL Retrievable Packer set @ +1- 7478' MD 2 joints 3-1/2" L-80 9.3# EUE 8rd Mod tubing. 3-1/2" x 1-1/2 " MMG mandrel (Max OD 5.968, Min ID 2.867) 1 joint 3-1/2" L-80 9.3# EUE 8rd Mod tubing. 3-1/2" X 2-7/8" x-over 2-7/8" L-80 6.5# EUE 8rd Mod tubing. Liner Top @ +/- 7678' MD Baker 5" x 7" 'ZXP' Mechanical Set Liner Packer wi 6' Tieback Recepticle. ID 4.875". C-2 setting tool. Baker 5" x 7" 'HMC' Hydraulic Liner Hanger with BTC pin down. Min ID 4.915" X-over - 5" BTC box by 5" FL-4S pin 2-7/8" Baker CMU Sliding sleeve wi a 2.31" "BX" Profile. EUE threads and a RHC plug run in place. Future C Sand Perfs TOC @ 8345' MD Sqz'd below cmt ret set @ +1- 8450' MD. 2-7/8" Camco 'DS' landing nipple with 2.25" No-Go Baker 5" Model D permanent packer (Minimum I.D. 2.688"). Baker '32-26' Sealbore recepticle wi 10' of effective stroke (3.5" 0.0. wi 2.68" I.D. seal bore - seals 1.968" I.D.). 2-3/8" wireline entry guide wi 6' pup jt. Future A Sand Perfs 5" 180#L-86.RI~N~lD a :J:J ~ C': ~.. ........~~-- c:::. -"""'- ~ r---' . Kuparuk River Unit North Slope, A/~s/(~ ' ,'., Kuparuk 1F, S(C}t f'~~~; 1F-16A PLAN: 1 ¡;;-;c1¡#..~1l-1'6A (wpO1) Rèji§ecf:~23 Septemfier, 2001 --'" - - - 'n- ---,- . .. - - - - t:l1tt!JPOSAL REPORT n_- - -- 24 September, 2001 Your Ref: ... Per Prelim Plan Version NO.A (9-21"()1) Surface Coordinates: 5958962.89 H, 539865.49 E (700 17' 55.7678" H, 149040' 37.7475" W) Surface Coordinates relative to Project H Reference: 958962.89 H, 39865.49 E (Grid) Surface Coordinates relative to Structure: 596.28 H, 276.80 E (True) Kelly Bushing: 107.100 above Mean Sea Level --, Proposal Ref: pro9632 Å~~ r.:.'-~. 0 :::J:J - - c-) - - ~ r-- Kuparuk River Unit Measured Depth (ft) 7878.00 7890.00 7900.00 7908.00 8000.00 8068.49 8100.00 8113.27 8200.00 8300.00 8328.21 8400.00 8497.95 Incl. 50.265 51.238 51.238 51 .238 44.961 41 .289 39.968 39.490 39.490 39.490 Azim. 144.783 146.903 146.903 146.903 159.136 169.909 175.351 177.728 177.728 177.728 39.490 177.728 39.490 ..177]28 . -- 39.49Ò177.128 8500.00.... 39.490 8600.00 . 39.490 8685.84 8700.00 8711.76 8750.63 8800.00 8900.00 8950.00 39.490 39.490 39.490 39.490 39.490 39.490 39.490 177.728 177.728 177.728 177.728 177.728 177.728 177.728 24 September, 2001 - 14:40 Sub-Sea Depth (ft) 5338.55 5346.14 5352.40 5357.41 5418.95 5469.00 5492.92 5503.13 5570.06 5647.23 5669.00 5724.41 5800.00 5801.58 5878.75 5945.00 5955.93 5965.00 5995.00 6033.10 6110.27 6148.86 Vertical Depth (ft) 5445.65 5453.24 5459.50 5464.51 5526.05 5576.1 56oo~02 561 0~23 ..5677.16 .... 5754.33 5776.10 5831.51 5907.10 5908.68 5985.85 6052.10 6063.03 6072.10 6102.10 6140.20 6217.37 6255.96 Sperry-Sun Drilling Services Proposal Report for PLAN: 1F-16A - 1F-16A (wp01) Your Ref: ... Per Prelim Plan Version #O.A (9-21-01) Revised: 23 September, 2001 Local Coordinates Northings Eastings (ft) (ft) 3429.68 S 3437.37 S 3443.90 S 3449.13 S 3509.74S 3554.67. S 3575.00 S 3583.47 S 3638.58 S 3702.12 S 3720.05 S 3765.67 S 3827.91 S 3829.21 S 3892.76 S 3947.31 S 3956.30 S 3963.78 S 3988.48 S 4019.85 S 4083.39 S 4115.17 S 3794.65 E 3799.87 E 3804.13E . 3807.53Ë u3838.79 E 3851.39 E 3854.04 E 3854.55 E 3856.74 E 3859.26 E 3859.97 E 3861 .78 E 3864.25 E 3864.30 E 3866.82 E 3868.98 E 3869.34 E 3869.64 E 3870.62 E 3871.86 E 3874.38 E 3875.64 E Page 2 of 5 Global Coordinates Northings Eastings (ft)(ft) 5955553.39 N 5955545.73 N 5955539.22 N 5955534.01 N 5955473.57 N 5955428.70 N 5955408.38 N 5955399.92 N 5955344.82 N 5955281.29 N 5955263.37 N 5955217.76 N 5955155.53 N 5955154.23 N 5955090.70 N 5955036.16 N 5955027.17 N 5955019.70 N 5954995.00 N 5954963.64 N 5954900 .11 N 5954868.34 N 543678.28 E 543683.54 E 543687.83 E 543691 .27 E 543722.85 E 543735.69 E 543738.44 E 543738.99 E 543741.47 E 543744.33 E 543745.14 E 543747.19 E 543749.99 E 543750.05 E 543752.91 E 543755.36 E 543755.77 E 543756.10 E 543757.21 E 543758.62 E 543761.48 E 543762.91 E Dogleg Rate (o/100ft) 15.900 0.000 0.000 12.000 12.000 12.000 12.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 3429.68 3437.37 3443.90 3449.13 3509.74 3554.67 3575.00 3583.47 3638.58 3702.12 3720.05 3765.67 3827.91 3829.21 3892.76 3947.31 3956.30 3963.78 3988.48 4019.85 4083.39 4115.17 A"< - .. . North Slope, Alaska Kuparuk 1 F Comment Top of Whipstock in 7" Csg (15.9°/1OC DLS across Face): 7878.00ft MD, 5445.65ft TVD 7" Casing - Base of Whipstock; Begin RatholL 51.24°: 7890.000 MD, 5453.24ft TVD -- Begin Dir @ 12.00/100ft (in 7" Hole): 7908.00ft MD, 5464.51ft TVD Top HRl End Dir, Start Sail @ 39.49° : 8113.27 MD, 5610.23ft TVD Base HRl Target: 8497.95ft MD, 5907.1 Oft TVD Target (Top C), 250.00 Radius., Curre Target -., Top A5 Top A4 Base of Pay Total Depth: 8950.00ft MD, 6255.96ft TVD 5-1/2" Flush Jt. Casing -.-- ---- DrillQuest 2.00.09.003 C :::x::J ~ G2. Kuparuk River Unit Sperry-Sun Drilling Services Proposal Report for PLAN: 1F-16A - 1F-16A (wp01) Your Ref:... Per Prelim Plan Version #O.A (9-21-01) Revised: 23 September, 2001 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 107.1' MSL. Northings and Eastings are relative to 564' FNL & 109' FEL. Magnetic Declination at Surface is 26.003° (23-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 564' FNL & 109' FEL and calculated along an Azimuth of 180.000° (True): 24 September, 2001- 14:40 Based upon Minimum Curvature type calculations, at a Measured Depth of 8950.00ft., - The Bottom Hole Displacement is 5652.89ft., in the Direction of 136.71 r (True). Station Coordinate~s .. TVD Northings EaStil1gs. eft) eft) ..(ft) .. . 5445.65 3429.68 S 3794.65 E 5453.24 3437.37S 3799.87 E 5464.51 3449.13sn 3807.53 E 5610.23 3583.47 S 3854.55 E 5907.10.. 3827.91 S 3864.25 E .6255.96 4115.17 S 3875.64 E Top of Whipstock in 7" Csg (15.9°/100' DLS across Face): 7878.00ft MD, 5445.65ft TVD Base of Whipstock; Begin Rathole @ 51.24°: 7890.000 MD, 5453.24ft TVD Begin Dir @ 12.0°/1000 (in 7" Hole): 7908.00ft MD, 5464.51ft TVD End Dir, Start Sail @ 39.49° : 8113.27ft MD, 561 0.23ft TVD Target: 8497.95ft MD, 5907.100 TVD Total Depth: 8950.000 MD, 6255.96ft TVD Comments Measured Depth eft) 7878.00 7890.00 7908.00 8113.27 8497.95 8950.00 -nn-.- - Page 3 of 5 . North Slope, Alaska Kuparuk 1 F --. ------ DrillQuest 2.00.09.003 c ~ - .., ('", -.. - ~ Kuparuk River Unit Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Proposal Report for PLAN: 1F-16A - 1F-16A (wp01) Your Ref: ... Per Prelim Plan Version #O.A (9-21-01) Revised: 23 September, 2001 Penetration Point Sub-Sea Depth Northings Easting$ (ft) (ft) (ft) " 5469.00 0.000 0.304 8068.49 5576.10 5469.00 5669.00 0.000 0.304 8328.21 5776.10 5669.00 5945.00 0.000 0.304 8685.84 6052.10 5945.00 5965.00 0.000 0.304 8711.76 6072.10 5965.00, 5995.00 0.000 0.304 8750.63 6102.10 5995.00 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> 7878.00 <Surface::> " 5445.65 .. To u ", Measured," Vertical Depttl DttPth (ft}tft) 7878.00 aS50.00 5445.65 6255.96 3554J>] s , ~720.05S , 8947,31 S 39f)$:78 S 3988.48 S Casing Detail 7" Casing 5-1/2" Flush Jt. Casing " 3851.39 E .3859.97 E '3868.98 E 3869.64 E 3870.62 E FormatiQn Name Top HRZ Base HRZ Top A5 TopA4 Base of Pay ~ "-,<.. .t ~ 24 September, 2001 - 14:40 Page 4 of 5 . North Slope, Alaska Kuparuk 1 F -"> ~ ---- .- ----- DrillQuest 2.00.09.003 c :::J:) - ~ ~- ~.J: Kuparuk River Unit Targets associated with this wellpath Target Name Target (Top C) Sperry-Sun Drilling Services Proposal Report for PLAN: 1F-16A - IF-16A (wpOl) Your Ref: ... Per Prelim Plan Version #O.A (9-21-01) Revised: 23 September, 2001 Mean Sea Level/Global Çoordinates: Geographical COordinates: . Target Radius: - ---..- -=::::: 24 September,2001- 14:40 ~ r-- Target Entry Coordinates TVD Northings Eastings . (ft) (ft) (ft) 5907.10 5800.00 3827.91 S 3864.25 E 5955155.53 N 543749.99 E 70017' 18.1070" N 149038' 45.1459" W 250.000 Page 5 of 5 --~---------..._- dIP .,' . North Slope, Alaska Kuparuk 1 F Target Shape Target Type Circle .----. Current Target --. DrillQuest 2.00.09.003 Sper;y-Sun Drilling Sel"ices Proposal Data - PLAN: 1F-16A -1F-16A (wpO1) MD \ Delta Inclin. Azimuth TVD Northings Eastings Dogleg A. Build A. Turn I Toolface (ft) ,MD (ft) (O) (O) (ft) (ft) (ft) (0/100ft) (o/lOOft) (0/100ft) (O) -1 : 78?8:00L.-.:.__._-:~:9~6~C.-.:!~:!~~~_:.-5~~;~~L..~~~-.~~-~...-,~7~.~~-~r-----:-.--:-~-'.-~.::._:_::--~.::_:.:-..- ...:::-.-_._-- ~ ~ ~-:~~:6~1_~~~~ ~~:~~~~-;~;~_:~~~~ .~;{~~!--~~':i~~"--~~~i:~~ ~¡ __1~::~ . ~':'Ö~ ___1_~:: 6~:~~ 4 8113.27 205.27 39.490 177.728 5610.23 3583.47 S 3854.55 E 12.000 -5.723 15.017 128.568 5T 8497.95 384.69 39.490 177.728 5907.10 3827.91 S 3864.25 E 0.000 0.000 0.000 0.000 . , 6 ~8950.0õl._._~.?:g~_._..~~:~~._.__..~_!!:.?g~._._§.g~~.:_~~_._.~~_!.?:1_? §.-_..~~!~:.~~_.~~--~,~0~=~9:9~_.._~:::~.~g9.._.:=::}~§~q. 23 September, 2001-13:28 -1 - ORIG IMAL DrillQuest S perf y -s un Dri /I in 9 Seltli ces Proposal Data - PLAN: 1F-16A -1F-16A (wpO1) MD, Delta Inclin. Azimuth TVD Northings Eastings Dogleg I A. Build A. Tum Toolface (ft) I MD (ft) (O) (O) (ft) (ft) (ft) (°/1000) , e /1000) (0/100ft) (O) ~1_; 7878.00t-~'u_:_~_:.~~2..?~_~ ~~:~~--~~-~:$~¡--~~~~:.~~:~---~~~~~:.?~(._- -, ;-' .u. . i L~¡~L-- ~ ~:~J }:~:.i~~:1~1 ~~~:~~~:~Ji~::f.~6~¡,~i .. 1~:'~~~::~ 4 8113.27 205.27 39.490 177.424 5503.13 5955399.92 N 543738.99 E 12.000 -5.723 15.017 128.568 5T 8497.95 384.69 39.490 177.424 5800.00 5955155.53 N 543749.99 E 0.000 0.000 0.000 0.000 . ~..... ._-ã~šo.o~l._~~~:9~_~=~.~;.!~Qn=~.??:~g,!._..~1_~~.:_~~----~~~-~~~~:~~_.~.._?~??g:~~..~.. -~.000[._..g_:2~_.- .._no _~:~2.... ....__9.:.~Q. 23 September, 2001 - 13:28 - 1 - ORIGINAL DrillQuest 5400 5600 5800 .c ã.. CD~ om -::.::; roC[ u~ "2 CD > 6000 6200 6400 3300 iii Alaska, Inc. North Slope, Alaska Kuparuk River 1 F Pad in 7" Csg (15.9"/100' DLS across Face): 7878.00ff MD, 5445.65ff TVD of Whipstock: Begin Rathoie @ 51.24': 7890.00ff MD, 5453.24ff TVD Begin Dir @ 12.0"/1O0ff (in 7" Hoie): 7908,00ft MD, 5464.5tft TVD Dir, Start Saii @ 39.49' . 8113.27ff MD, 5610.23ft TVD 3500 3700 3900 4100 4300 -3400 -3600 (j) 0) c £; -3800 0 Z -4000 "" 0 0 C\J " .r: () .!;; ':-: -4200 OJ -¡¡¡ () if) Css<ng Eastings 5445 65ft TVO Begin Dir @ 7908.001t MD, End Dir, Start Sail @ 39.49' 8113.27ft MD, S6W.23ft TVD 5.1/2' F'ush," C,s<ng B95D.OOft MO 6255.96ft TVO Totai Depth: 8950,00ft MD, 6255.96ft TVD (599'FSL&1528'FEL, SEC.20-T11N-R10E) 3600 3800 4000 Scaie: 1 incll = 200ff -3400 -3600 -3800 (j) 0) c £; 0 Z -4000 -4200 4200 Well : Current Well Properties ----,---,--- PLAN: 1F-16A Horizontal Coordinates: Ref. Global Coordinates. Ref. Structure: Ref. Geographical Coordinates: 5958962.89 N, 539865.49 E 596.28 N, 276.80 E 70' 17' 55.7678" N, 149' 40' 37.7475" W (564' FNL & 109' FEL, SEC. 19-T11N-R10E) 107. 10ft above Mean Sea Level True North Feet (US) RKB Elevation North Reference. Units. '-"'. Phillips Alaska, Inc. 1 F-16A (wpO1) MD Inc Azim. SSTVD TVD NIS E/W Y X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 7878.00 50.27 144.78 5338.55 5445.65 3429.68 S 3794.65 E 5955553.39 N 543678.28 E 0.00 3429.68 Top of Whipstock 7890.00 51.24 146.90 5346.14 5453.24 3437.37 S 3799.87 E 5955545.73 N 543683.54 E 15.90 3437.37 Base of Whipstock; Begin Rathole 7908.00 51.24 146.90 5357.41 5464.51 3449.13 S 3807.53 E 5955534.01 N 543691 .27 E 0.00 3449.13 Begin Dir (6-3/4" Hole) 8068.49 41.29 169.91 5469.00 5576.10 3554.67 S 3851.39 E 5955428.70 N 543735.69 E 12.00 3554.67 Top HAl 8113.27 39.49 177.73 5503.13 5610.23 3583.47 S 3854.55 E 5955399.92 N 543739.00 E 12.00 3583.47 End Dir 8328.21 39.49 177.73 5669.00 5776.10 3720.05 S 3859.97 E 5955263.37 N 543745.14 E 0.00 3720.05 Base HAl 8497.95 39.49 177.73 5800.00 5907.10 3827.91 S 3864.25 E 5955155.53 N 543749.99 E 0.00 3827.91 Target (Top C) 8685.84 39.49 177.73 5945.00 6052.10 3947.31 S 3868.99 E 5955036.16 N 543755.36 E 0.00 3947.31 Top A5 8711.76 39.49 177.73 5965.00 6072.10 3963.78 S 3869.64 E 5955019.70 N 543756.10 E 0.00 3963.78 Top A4 8750.63 39.49 177.73 5995.00 6102.10 3988.48 S 3870.62 E 5954995.00 N 543757.21 E 0.00 3988.48 Base of Pay 8950.00 39.49 177.73 6148.86 6255.96 4115.17 S 3875.65 E 5954868.34 N 543762.91 E 0.00 4115.17 Total Depth .-' C ::x:J - - ~ - - ~ r--- ( ( Sperry-Sun Anticollision Report Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 1 F Pad Reference Well: 1F-16 Reference WeUpatb: Plan: 1 F-16A GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 7878.00 to 8950.00 ft Maximum Radius: 1091.97 ft Date: 9/2412001 TIme: 14:06:46 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 1 F-16, True North 1 F-16A w/ Nordic 3107.1 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive WeUpath Date: 9/23/2001 Validated: No Planned From To Survey ft ft 107.10 7878.00 7878.00 8950.00 Version: Toolcode 1 Tool Name 1 F-16 Planned: 1F-16A (wp01) V1 MWD MWD MWD - Standard MWD - Standard Casing Points MD TVD Diameter Hole Size ft ft in in 7878.00 5445.65 7.000 8.500 8950.00 6256.09 5.500 7.000 Name 7" 5-1/2" Flush Jt. Summary <-~~------~_..~-~~-----~ OtTset.Welipath .~~~~~~--~-.._~-~~~~~~-~> Site Well WeUpath Reference Offset MD .MD ft ft Ctr~Ctr No-Go I)istance Area .ft ft Allowable Deviation ft Warning Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad Kuparuk 1 F Pad 1 F-05 1 F-06 1 F-07 1 F-13 1 F-14 1 F-15 1F-16 1F-19 1 F-20 1 F-20 1 F-05 V1 1F-06 V1 1 F-07 V1 1F-13 V1 1 F-14 V1 1F-15V1 1 F-16 V1 1 F-19 V1 1 F-20 V1 1 F-20PB1 V1 7899.96 7900.00 0.64 21.03 0.03 Out of range Out of range Out of range Out of range Out of range Out of range Pass: No Errors Out of range Out of range Out of range ORIGINAL ;¡ .- - , " If g 'f '" '2? -( L -< ~ Z ~ - " " , ------ ---- ---- ------- " ~g c=R õ '-' - 9 -- c.. '" ;¡; ::;:: ~ :q :q '" 'ì :??, -._u_---- -----.--..--- ---------.- ~ 2 r- ù3 Z 0 i-ù Z û :J 'R ~ <C -0 -0 ~~~ ;;; co '" F' '" co :q ! ~ co í --------. ~ := - :s g ~ § " 2. v if) ~ 8 ~. ~ ü v 5' Ch v :':'. I ::::ï <C + 0 I.l- t: ~ .;::1 <C t; :s C;' ~ -;::; ii ,::: - ,,- { ( . J / \ American Expressœ> Cash Advance Draft 171 DATE /1 O~ÞPv' 2€0 L-"","" PAY TO TH E ORDER OF ---- DOLLARS Issued by Integrated Payment System. Inc. Englewood, Colorado Payable at Norwest Bank of Grand junction - Downtown. NA Grand junction. Colorado PERIOD ENDING N~RAMOUNTQ R$IOOO HAR~ AL p-~tr~ I: .0 2 ~ DOL. 00 I: ~ 5 811 0 . 7 5000 5 ~ bill 0 ~ 7 ~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION 7L INJECTION WELL REDRILL ( { TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ¡¿ K /{ / ç-, /? /I "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. Production should continue to be reported as a function of the original API number stated above. (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) In accordance with 20 AAC 25.005(1), all records, data and. logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR ISPOSAL . L:1.JNO Annular disposal has n.ot been requested. . . ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST FIELD & POOL 0 0 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available'in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y ~ i ~~~~;;~~:I~:;~I~:'~~~~~ i ~~rt '~g: .: : ': : ~ ~( ~:t::. ~ ~ ~ ~ t ~- ~~ 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y N) ~ 18. CMT will cover all known productive horizons. . . . . '. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N l 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N 4ê.......'tc;.~~ ,"t~ "-.D ~~~(£ ~,,\ç- 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~~\ -;}. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N . 23. If diverter required, does it meet regulations. . . . . . . . . . TIh. 24. Drilling .fluid program schematic & equip list adequate. . . . . Y- N ~ /1 ~ TE,-< . ~~: ~g~~Spr:.:"~~=:'~~~~~I~sit¿ . . . . ~6' . ¿sig: ~ w.. ':> ~ Cè"-> ~ ~ ;}(,,",> '\ \>': \ ~ ~\' 27. Choke manifold complies w/API RP-53 (May 8~ . . . . . . N . ~:: ~~~::~~rH-::'::: =~::f: ~~U~d~: : : : : : : : : : : ~ ~ ""~ ".~~~ \"" c: \ ~.. ~ "> '" <-- ""'~ ~Ö 50 ,,~~ "'.. ~\) "'" r se.~~ ~C). ~"~"'. . 30. Permit can be issued w/o hydrogen sulfide measures. . . .. Y N ,J, ç -D" t4 .' u 'Z, ~ ~ I '/ý¡' ~ ' ,~ 31. Da~a ~resented. on potential overpressure zones. . . . . . . ~ ~ ~r~ ~oLV. va. I;" ~~L" r<'- t!i. fð,sz:' f5 ¿ é!.-y' /t? -7 ~ß EI11 f¿.r'f"'tdd 32. SeIsmIc anal~~ls of shallo~ gas zones. . . . . . . . . . . ~. . Y'. ~~ - ~c.t\O Vl~, 10-2..;:> '0 I :~ fI (j AP~ DATE 33. Seabed condItion survey (if off-shore). . . . . . . . . . . . . Y N --4J:;2::::. /O.¿g,D( 34. Contact name/phone for weekly progress reports {explorato only] Y N ANNULAR DlSPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; , (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: Rþ~~ WM'----- SO~ (~~ Af? R ~A~ r I. .0 NGINEERING GEOLOGY APPR DATE COMPANY . INIT CLASS WELL NAME ¿ý\l' ( c-¿ PROGRAM: exp - dev - redrtl GEOLAREA L) N N serv wellbore seg _ann. disposal para req - ~ ON/OFF SHORE' W UNIT# Y N Y N ~ ~~~~ ~~~ ~ Com mentsllnstructions: ~ Va.YÎQ.()cL fur ~a..c.kc.r p1ctc.e.n1.U\t . J'N H- 10/30/0] c:\msoffice\wordian\diana\checklist (rev. 11/01/100) , OI1.S/oJ c 0 Z 0 -I ~ ÃJ ( - -I m - Z -I J: - en :Þ :xJ m » ( (' ( Well History File APPENDIX Information of detailed nature that is not , particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of infonnation. (I' S!="I";:' .;:'y-:3u n [);-'i.: 1 :i nq Se ~-\'.i '...é::'~' LIS Scan Util.icy $Re'iisi,y-,: J :;' LisLib $Revision: 4 $ Man Feb 25 17:12:10 2002 kt,ei ì-iedder Service name.. ...........LISTFE Date"",_""""""",'~12/\:12/2:, Ori,;)in...................STS Reel ¡..J¿¡me................Ul'JKtJO1\];; Continuation Number......Ol Previous Reel Name.......UNKNO~~ Comments.................STS LIS Tape Header Service name.............LISTPE Date..........._.........02/02/2::¡ Origin...................S1'3 Tape Name................UNKNOWN Continuation Nurnber......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/rvIAD LOGS # WELL NAME: At' 1 NUMß1~H: OPERATOR: LOGGING COMPANY: TAPE CREJ\TION DJ\TE: II JOB DATA ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11186 R. MGN.EILL R. FRAZIER # SURFACE LOCATION SECTION: 'I'OINNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSJ-IING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOT.f~ BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ,ii " Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 1 F-16A 5002.92102901 PHILLIPS Alaska, Inc. Sperry Sun 25-FEB-02 19 llN 10E 564 109 .00 106.18 76.80 CASTNC:; SIZE (IN) 16.000 9.625 7.000 DRTLT,ERS DEPTH (FT) 110.0 4496.0 7867.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE S'l'A'l'l:.;D. 2. MWD RUN 1 IS DIRECTIONAL ONLY FOR SETTING WHIPSTOCK AND IS NOT PRESENTED. ~OJ~cJu9 ! [; -/:) ~, ( ( ~ . MWD RUN .2 IS DIRECTIONAL ~'JITH DUAL GAl-I",!}\ ¡U\Y (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (E~\1R4 ), CO~IPENSATED THER:--L'U, ;~EUTRON POROSITY (CTN), .'\ND STABILIZED LITHO-DENSITY (SLD\. ,1. H1~Lì DATA IS CO¡"¡SIDJ:;Hl.::D l'DC l'l:;Ì\ THl:; l:;-j-iAIL EkOH L,. SCHirJARTZ OF PHILLIPS ALASKA, INC. DATED 01/04/02. AUTHORIZED BY GKA GEOSIENCE GROU MWD DATA NOT SHIFTED TO PARENT WELL IN POST PROCESSING. THIS WELL IGC]-(S OFF FROM 1F-16 ,'\T 7867' MD, 5439' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUN 2 REPRESENTS WELL 1F-16A WITH API # 50-029-21029-01. THIS WELL REACHED A TOTAL DEPTH OF 8990' MD, 6289' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOO'1'H1W GAMMf\ RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED SBD2 = SMOOTHED 8C02 = SMOOTHED BIN) FORMATION EXPOSURE TIME BULI< DENSI'I'Y (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT SN P 2 = ABSORPTION TNPS =: ( SANDSTONE: CTFA = RATE CTNA = RATE SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC FACTOR (LOW-C SMOOTFfED THERMAL NEUTRON POROSITY MATRIX, FIXED HOLE SI SMOO'U1ED AVEFtAGE OF' FAR DETECTOR I S COUNT SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DI\TA: HOLE SIZE: MUD WEIGI-i'!': MUD FILTRATE SALINITY: CHLORIDES FORMATION WATER SALINITY: CHLORIDES FunD DENSITY: MATRIX DENSI'I'Y: LITHOl,OGY: 6.5" 11.2 peG 1100 PPM 20000 PPM 1.00 GICC 2.65 G/CC SANDSTONE $ File Header Service name.............STSLIB.OOl Service Sub Level Name... V(~rsion Number...........l.O.CJ Date of Generation.... ...02/02/25 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWO Depth shifted and 1 clipped curves; all bit runs merged. ( '( ~;E?T:-! INCREHENT: .5000 ::':;:l-!:: SUMHARY ::'E,'j TOOL CODE ¡lCNT START DEPT!-! '.'e~o. u STOP DEPT!-i r..~\."" ~ ,_.J, 1 ¡ 851) . (i 7850.0 ::.-'.9C1j. I.' ,t: 903. '. NPHI f:9O3.C (3f, 785 C, . C' 8939.:] h::-'D ~'857.C, ,S 9"¡ ó..'] 7868.0 7868.0 7900.5 7900.5 8946.5 8946.5 8946.5 8918.0 8918 . (I 8918.1:, RP;': DRHO RHOP- E-'EF ROP FET 7857.0 7857.0 7857.0 7868.0 RP/,-1 RPS 8990.(1 89,16. .5 " ,? # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO 2 MERGE TOP 7850.0 MERGE BASE 8990.0 # REMARKS: MERGED MAIN PASS. ~) # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...... .....Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record........ .....Undefined Absent value......................-999 Dep.th Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DJë.:!:".L' 1:".1.' 4 1 68 0 1 ROP MWD FT/H -1 1 68 -1 2 GR MWD API 4 1 68 8 3 RPX MV\ìD OrIMM 4 1 68 12 4 RPS MWD OHMtJI <1 1 68 16 5 RPH HWD OHHM 4 1 68 20 6 RPD l'1WD Ol-IMM 4 1 68 24 7 FET MWD tlR 4 1 68 28 8 NPHI ~1WD PU-S 4 1. 68 32 9 FCNT HWD CP30 4 1 68 36 10 NCNT MIND CP30 4 1 68 40 11 RHOB MlrilD G/CM 4 1 68 44 1:2 DRHO l'1WD G/CH 4 1 68 48 13 PEF MWD B/E 4 J. 68 S2 14 I:lL'st LdöL Name Servj.ce Uni.t Min Hax Mean Nsam Reading Reading DEPT Frr 7850 8990 8420 2281 7850 8990 ROP HWD FT/J-I 0 182.99 52.1674 2180 7900.5 8990 GR l'1WD API 31. 88 :)31.9 143.771 ::180 7850 8939.5 RI?X MWD OHMM 0.94 1423.42 5.70308 2180 7857 8946.5 RPS MWD OHMH 0.97 2000 10.9783 2180 7857 8946.5 RPH l'1WD OHMtJI 0.97 2000 19.01323 2180 7857 8946.5 RPD HWD OHMM 0.82 1378.96 10.2525 2180 78.57 8946..5 FE 'I' MWD HR 0.7 20.39 1.19835 2093 7900.5 8946.5 NPHI HWD PU-S 18.44 55.98 34.4875 2107 7850 8903 FCNT MWD CP30 116 868 309.506 2107 7850 8903 IJCìr:' Iv¡~'JD CF31) ::\:-JOE ì'í1'J[! DRHO Ì'11rJ[! ,::;iCH P:::F ¡vn,¡c G/CH B/::: ( 14419 ::: .18 -0.34 4.06 { 3'¡8:')::) :2.95 _,179:,.3 78:')( :? 10: nCll :::: 1 1:1} 891:\.:, :::: - 4::::471 (1.038"7815 7 :::6:3 ::91: 0.::: ::.. 4. 3.:1 7868 8918 6.8::::36:::: "786i:: t ~1 ~~ .~ l,J 1 First Reading For Entire File..........7850 Last Reading For Entire File.... .......8990 ¡:'ile Trailer 3ervice name... """" ..3T31IB.001 Service Sub Level Name... Version Number. ..........1.0.0 Dale oI GeCleLal.i.oll.......û2/0::::/::::S Maximum Physical Record..65535 File Type................10 Next File Name... ........STS1IB.O02 Physical EOF File Header Service name.............STSLIB.OO::: Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/25 Maximum Physical Record. .65535 ~'.i.le 'l'ype................LO Previous File Name..... ..STSLIB.OOl Comment Record FILE HEADEP.. FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPD RPM RPS RPX DRI-IO RHOB PEF ROP FET $ 2 header data for each bit run in separate files. 2 .5000 START DEP'rH '18bO.0 7850.0 7850.0 7850.0 7857.0 785'7.0 7857.0 7857.0 7868.0 7868.0 7868.0 7900.5 7900. ::) # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (F'T): BOTTOM LOG INTERVAL (F'T): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM .ANGLE: MAXIMUM ANGLE: i¡ STOP DEPTH 8903.0 8903.0 8903.0 8939.5 8946.5 8946.5 8946.5 8946.5 8918.0 8918.0 8918.0 8990.0 8946.5 08-NOV-01 Insi.te 4.05.5 66.16 Memory 8990.0 33.2 50.9 TOOL STRING (TOr TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RJ\Y EWR4 ELECTROMA.G. RESIS. 4 TOOL NUHBER PB02268HAGR,j PB02268HAGR4 ( CTN COMP THERMAL NEUTRON STABILIZED LITHO DEN SLD ~ SOREHOLE AND CASING DATA OPEN HOLE 811' SIZE (IN): DRILLER'S CASING DEPTH (FT): " dOk~HOL~ CONDITIONS Ì'1UD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (3): HUD PH: MUD CHLORIDES (PPM): fLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT .MEASURED TEMPE,RATURE (MT): MUD .7-\1' MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT ¡VIT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): jf TOOL STANDOFF (IN): EWR FREQUENCY (HZ): jl REMT\.RKS: $ # Data Format Specification Record Data Record Type........... .'.. ...0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet !Jat.a Rf>.fel'-ence Pcdnt..............1Jndf>.fined Frame Spacing. .... ..... "..' "" ..60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( PBO2213NL':; PBO221 3NL.:; 6.500 Nater Ease.j 11.ICI 5.J . I:, 9.~ 950 2.5 3.900 1.933 1.900 2.000 6.5.0 13e..O 65.1:1 65.0 Name Service Order Uni.ts Size N s a.Yn Rep Code Offset Channe1 DEPT FT 4 1 68 0 1 kOk' MWO020 1::"1'/1-1 4 1 68 4 ,-, "- GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1. 68 20 6 RI?D MIÑD020 OHMM 4 1 68 24 7 FET MWD020 ¡-IF, 4 1 68 28 8 NPl-II MWDO20 pu-s 4 1 68 32 9 FCNT MWD020 CP30 4 1 <Sf! 36 10 NCNT MWD020 CP30 4 1. 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 GICM 4 1 68 48 13 PEF MWD020 B/E 4 1. 68 52 14 First Last Name Service Unit Min Max Mean Nsarn Reading Reading DEPT FT 7850 8990 8420 2281 7850 8990 ROP MWD020 FT/I-I 0 182.99 52.1674 2180 7900.5 8990 GR MWD020 API 31.88 531.9 J.43./71 2180 1850 8939.!:J RPX MWD020 OHMM 0.94 1423.42 5.70308 2180 7857 8946.5 RPS MWD020 OHMM 0.97 2000 10.9783 2180 7857 8946.5 RPM MWD020 OHMM 0.97 2000 19.0823 2180 7857 8946.5 1'\1:'0 MWDO20 OHMM 0.82 1378.96 10.252~) 2180 7857 8946.5 FET MWD020 HR 0.7 20.39 1.19835 :2093 7900.5 8946.5 NPHI MWD020 PU-S 18.44 55.98 34.4875 2107 7850 8903 FCNT M'iriJD020 CP30 116 868 309.506 2107 7850 8903 NCNT MWD020 CP30 14419 34 83~) 21795.3 2107 7850 8903 ( ( :\i-10t?, Ì'n-,jDO20 G/CH ., 18 r; 95 ::: 424;1 2101 '7863 8918 . . 'J~HO M¡~DI) 2 I) G/CM -0. 34 O. r; O. 0387815 2101 7868 8918 " :o:,¡::¡:- MND020 8/E ' 06 14 .J9 6. 82362 ::::l 0 1. 7 l~ l) e, ,-:;91e, " . Fi~st Reading For Entire File...... ....7850 Las~ Reading For Entire File...........8990 File Trailer Service name.... ... ......STSLI8.002 Service Sub Level Name... Version Number.... .... ...1.0.0 Ddle or GeneLdlion.......O2/0:2125 Ma~imum Physical Record..65535 File Type................LO Next File Name.......... .STSLIB.OO3 E'hysi.cal EOr Tape Trailer Service name.. .""'" ...L1STPE Date.....................O2/02/2~ Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol NexL ~ape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Scrvicc namc...... '" ....L1STPE Date.................... .02/02/2~) Origin...................STS Reel Name........ ........UNKNOWN ContimJat.ion NumbE'r...... 01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Phys:Lcal EOF Physical EOF 1::,00. Of LIS file
