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208-193
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-305 (PTD# 208-193) IA Suspect Date:Tuesday, May 30, 2023 3:56:51 PM Attachments:AnnComm Surveillance TIO for CD3-305.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Tuesday, May 30, 2023 3:35 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-305 (PTD# 208-193) IA Suspect Chris, CRU CD3-305 (PTD# 208-193) was reported by operations for high IA. The well has been shut it and initial diagnostics are ongoing. Depending on results, proper notifications will be made as needed. Attached is the 90 day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CD3-305 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD3-305 2023-05-07 2116 1495 -621 IA CD3-305 2023-05-29 2050 1200 -850 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CD3-305 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Inj Valve 4/14/2020 CD3-305 boehmbh Casing Strings Casing Description CONDUCTOR Insulated 34" OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.8 Set Depth (ftKB) 3,529.8 Set Depth (TVD) … 2,467.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.6 Set Depth (ftKB) 15,241.7 Set Depth (TVD) … 6,668.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description SLOTTED LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 15,098.5 Set Depth (ftKB) 16,770.0 Set Depth (TVD) … 6,658.9 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 15,098.5 6,650.9 81.32 HANGER BAKER FLEX LOCK HANGER ASSEMBLY 5.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.5 Set Depth (ft… 15,106.0 Set Depth (TVD) (… 6,652.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.5 31.5 0.00 HANGER FMC TUBING HANGER 3.970 2,303.3 1,995.3 58.07 NIPPLE DB PROFILE NIPPLE 3.813 14,072.5 6,306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 15,095.5 6,650.4 81.26 LOCATOR BAKER FLUTED NO-GO SUB - ABOVE & BELOW PROFILES 3.990 15,105.0 6,651.8 81.46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,303.3 1,995.3 58.07 INJ VLV A-1 INJ VLV (S/N: HSS-164 / 1.25" ORIFICE) 4/14/2020 1.250 7,470.0 3,902.5 69.51 PACKER 4.5" Paragon II Packer (SN:ALP45009)/ Latch (SN:ALP45019) 4/12/2020 2.000 ALPP45009 7,473.0 3,903.5 69.52 SPACER PIPE Spacer pipe 4/12/2020 2.000 7,491.0 3,909.8 69.54 PACKER 4.5" Paragon II Packer (SN:ALP45019) 4/11/2020 2.000 ALPP45019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 15,491.9 16,723.0 6,670.6 6,658.4 2/4/2009 32.0 SLOTS SLOTTED LINER Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 13,959.3 6,260.1 CAMCO KBG-2- 1R 1 INJ DMY BTM 0.000 0.0 12/6/2015 Notes: General & Safety End Date Annotation 3/14/2016 NOTE: View Schematic w/ Alaska Schematic9.0 1/22/2016 NOTE: MILLED ICE FROM 3845' TO 4675. BULLHEADED 75 BBL DIESEL FREEZE PROTECT FROM SURFACE. HORIZONTAL, CD3-305, 5/28/2020 4:23:32 PM Vertical schematic (actual) SLOTTED LINER; 15,098.5- 16,770.0 SLOTS; 15,491.9-16,723.0 INTERMEDIATE; 34.5-15,241.7 WLEG; 15,105.0 LOCATOR; 15,095.5 NIPPLE; 14,176.7 PACKER; 14,072.5 GAS LIFT; 13,959.3 PACKER; 7,491.0 SPACER PIPE; 7,473.0 PACKER; 7,470.0 SURFACE; 36.8-3,529.8 INJ VLV; 2,303.3 NIPPLE; 2,303.3 CONDUCTOR Insulated 34"; 37.0-114.0 HANGER; 31.5 WNS INJ KB-Grd (ft) 41.48 Rig Release Date 2/7/2009 CD3-305 ... TD Act Btm (ftKB) 16,859.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032058900 Wellbore Status INJ Max Angle & MD Incl (°) 92.92 MD (ftKB) 15,504.00 WELLNAME WELLBORECD3-305 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050410 Type Inj N Tubing 2790 3050 3070 3070 Type Test P Packer TVD 6759 BBL Pump 3.8 IA 44 2100 2025 2000 Interval 4 Test psi 1690 BBL Return 1.8 OA 61 63 63 63 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2081930 Type Inj N Tubing 1443 1443 1442 1442 Type Test P Packer TVD 6307 BBL Pump 1.5 IA 1082 2190 2160 2150 Interval 4 Test psi 1577 BBL Return 1.5 OA 16 31 31 31 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD3 Pad Caudle 02/11/22 Notes:Bled IA back to 600 to establish a better DP. Final T/I/O = SI 2902/600/62 Notes: CD3-110 CD3-305 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h anic al Int egrit y Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0211_MIT_CRU_CD3-pad _2wells 9 9 9 9 -%5 02/11/22 CD3-305 MEMORANDUM TO: PimRegg..'Bell ('Jqju'1� PI. Supervisor 1\ FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 29, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD3 -305 COLVILLE RIV FIORD C133-305 Sre: Inspector Reviewed By:: P.I. Supry JyP— Comm Well Name COLVILLE RIV FIORD CD3 -305 API Well Number 50-103-20589-00-00 Inspector Name: Adam Earl IUSp Num: mi[AGE200524190740 Permit Number: 208-193-0 Inspection Date: 5/21/2020 ' Rel Insp Num: Packer Depth Well I CD3 -305 IlType Inj W • TVD 6_307 PTD 2081930 'IType Test SPT Test psi 'I 1577 BBL Pumped: s BBL Returned: 1.8 Interval OTHER P/F I P Notes: MIT IA Tested as per Sundry 320-151/ Post Patch ✓ Friday, May 29, 2020 Page 1 of I Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 1940 'i, 1943 1940 - 1940 - IA 1390 2700 i 2670 2665 ' OA L 200 360 ' 360 36C Friday, May 29, 2020 Page 1 of I https://readcasedhole-my.sharepoint.com/personal/diane_williams_readcasedhole_com/Documents/D Drive/Achives/MasterTemplateFiles/Templates/Distribution/TransmittalSheets/ConocoPhillips_Transmit.docx Well Log Transmittal To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : READ Cased Hole, Inc. Attn: Diane Williams 4141 B Street Suite 308 Anchorage, AK 99503 Diane.Williams@readcasedhole.com 1) LeakPoint™ Survey 03-Apr-20 CD3-305 CD 50-103-20589-00 2) Signed : ______________________________________ Date : ___________________ Print Name: ______________________________________ READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-ANCHORAGE@READCASEDHOLE.COM WEBSITE : WWW.READCASEDHOLE.COM Received by the AOGCC on 04/22/2020 PTD: 2081930 E-Set: 32777 Abby Bell Abby Bell 04/22/2020 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION By Samantha Carlisle at 11:41 am, Apr 08, 2020 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate Ll Pull Tubing Ll Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: MBE MARCIT GEL TRTMT❑✓ 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑� 208-193 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-103-20589-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 372105 ADL 372104 ADL 372103 CRU CD3 -305 • 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field/Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 16,859' feet Plugs measured NONE feet true vertical 6,659' feet Junk measured NONE feet Effective Depth measured 16,670' feet Packer measured 14,073' feet true vertical 6,659' feet true vertical 63,07' feet Casing Length Size MD TVD Burst Collapse Conductor 77 16 114' 114' Surface 3,493' 95/8 3,530' 2,467' Intermediate 15,207' 7 15,242' 6669 Slotted Liner 1,672' 5 1/2 16,770' 6659 Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth) 41/2 L-80 15,106' 6,652' Packers and SSSV (type, measured and true vertical depth) PACKER BAKER PREMIER PKR 14,073' 6,307' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 15491-16723 Treatment descriptions including volumes used and final pressure: 12,045 lbs. of MARCIT GEL 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: m m 2500 635 2100 Subsequent to operation: m m 2500 635 2100 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development ❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑J GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-566 Authorized Name: Steve Drake Contact Name: Steve Drake Authorized Title: Sr. Wells Engineer Contact Email: steye.q.drake(CDcop.com Authorized Signature with date: Steven G Drake 04/08/2020 Contact Phone: (Senior Engineer: VTL 4/8/20 I (Senior Res. Engineer: Form 10-404 Revised 3/2020 SFD 4/10/2020 RBDMS HEW 4/10/2020 f Operations CD3 -305 MBE MARCIT GEL TREATMENT 2/19/20 MISC. PUMPED 414 BBLS OF SW w/ RED TRACER DYE. MONITOR CD3 -304 (PRODUCER) CAPACITY FOR TRACES OF DYE EVERY TWO HOURS. START 3000 PPM GEL STAGE #1 @ SUSTAIN 23:45. MENT 2/20/20 MISC. CONTINUE PUMPING GEL STAGE #1. AS OF 06:30 PUMPING 825 BBLS OF 3000 PPM CAPACITY GEL @ -1750 PSI WHP.STAGE TOT PUMP @ MIDNIGHT 2811 BBLS PUMP SUSTAIN MENT 2/21/20 MISC. CONTINUE PUMPING STAGE #1 @ 01:00 CHANGE TO STAGE #2:4000 PPM, 1.7 BPM CAPACITY @ 10:45 CHANGE TO STAGE #3: 5000 PPM, 1.7 BPM SUSTAIN MENT STAGE #1 ENDED @ 01:00 SUMMARY: 3000 PPM, 2 BPM TO 1.7 BPM, 2914 BBLS PUMPED, FINAL WHP 1954 PSI 2/22/20 MISC. CONTINUE PUMPING STAGE #3 @ 06:05 CHANGE TO STAGE #4:7000 PPM, 1.7 BPM CAPACITY @ 18:00 CHANGE TO STAGE #5: 9000 PPM, 1.7 BPM SUSTAIN MENT STAGE #3 ENDED @ 6:05 SUMMARY: 5000 PPM, 1.7 BPM, 1975 BBLS PUMPED, FINAL WHP 2175 PSI 2/23/20 MISC. CONTINUE PUMPING FLUSH TREATMENT CAPACITY SUSTAIN FLUSH TREATMENT/FP ENDED @ 00:42 SUMMARY: 6 BBLS LINEAR GEL, 15 BBLS MENT OF BREAKER, 191 BBLS SW AND 38 BBLS DIESEL FP TREATMENT SUMMARY: 7381 BBLS OF GEL PUMPED EQUATING TO 12,045 LBS OF PRODUCT PLACED IN FORMATION 3/1/20 ANN (AC EVAL) : SBMS PASSED, POT -T PASSED, PPPOT-T PASSED, UPPER M2M SEAL COMM PASSED, LOWER M2M SEAL PASSED, POT -IC PASSED, PPPOT-IC PASSED, MIT - IA FAILED W/ A LLR-IA OF 1.54 GPM @ 3000 PSI. WNS INJ WELLNAME CD3 -305 ConoeoPhillips Well Attributes Field Name I Wellbore APWWI Wellbore Alaska. Inc. FIORD KI IPARI IK c;njf),2f)qRq()fIIN NONE I I ILast WO: WELLBORE CD3 -305 2172009 HORIZONTAL,CD3-305, 4/3120207:29:12 AM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CD3 -305 Imosbor Last Rev Reason ................ HANGER: 31.5 ........ .......... Annotation End Date Wellbore Last Mod By Rev Reason: T/S AnnComm CD3 -305 clay[g Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I Grade Top Thread CONDUCTOR 16 15.25 37.0 114.0 114.0 62.50 H-40 Welded Insulated 34" Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WHLen (I... Grade Top Thread SURFACE 95/8 8.83 36.8 3,529.8 2,467.3 40.00 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WHLen (I... Grade Top Thread INTERMEDIATE 7 6.28 34.6 15,241.7 6,668.6 26.00 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread SLOTTED LINER 141/23.96 15,098.5 16,770.0 16,658.9 12.60 L-80 ISLHT Liner Details Nominal ID CONDUCTOR Insulated 34% 37.0-114.0 Top (ftKB) I Top (TVD) (ftKB) I Top Incl (°) Item Des Com (in) 15,098.51 6,650.9 81.32 1 HANGER I BAKER FLEX LOCK HANGER ASSEMBLY 5.000 Tubing Strings Tubing Description StringMa... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ib/ft) Grade Top Connection TUBING 41/2 3.96 31.5 15,106.0 6,652.0 12.60 L-80 IBT-M Completion Details Top (TVD) Top Incl Nominal Top (ftKB) (ftKB) (°) Rem Des Co. ID (in) NIPPLE; 2,303.3 31.5 31.5 0.00 HANGER FMC TUBING HANGER 3.970 2,303.3 1,995.3 58.07 NIPPLE DB PROFILE NIPPLE 3.813 14,072.5 6,306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 15,095.5 6,650.4 81.26 LOCATOR BAKER FLUTED NO-GO SUB - ABOVE & BELOW PROFILES 3.990 15,105.0 6,651.8 1 81.46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SURFACE: 36.6-3,529.8 Top (ftKB) Top (TVD) (ftKB) I Tophat (°) I DesCom Run Date ID (in) 14,176.7 6,349.7 1 65.61 PLUG I 3.813" XN CAT STANDING VALVE 3/23/2020 1 0.000 Perforations & Slots Shot Den Top (TV Elm (TVD) (shots/ft Top (ftKB) Bt. (ftKB) (ftKB) (ft 13) Linked Zone Date ) Type Com GAS LIFT; 13,959.3 15,491.9 1 16,723.0 1 6,670.6 6,658.4 2/4/2009 1 32.0 1 SLOTS I SLOTTED LINER Mandrel Inserts St ati N Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Se, Valve Latch Type Type PortSize (in) TRO Run (psi) Run Date Com 1 13,959.3 6,260.1 CAMCO I KBG-2- 1 INJ DMY BTM 0.000 0.0 12/6/2015 1R 1 1 1 Notes: General & Safety PACKER; 14,072.5 End Date Annotation 3/14/2016 NOTE: View Schematic w/ Alaska Schematic9.0 1/22/2016 NOTE: MILLED ICE FROM 384570 4675. BULLHEADED 75 BBL DIESEL FREEZE PROTECT FROM SURFACE. NIPPLE; 14,176.7 PLUG; 14,176.7 LOCATOR; 15,095.5 W LEG; 15,105.0 INTERMEDIATE; 34.5 -15,241.7 - 4.5.15,241.7SLOTS, SLOTS 15,491.9-16,723.0 SLOTTED LINER; 15,096.5 J l 16,770.0 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Collapse Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 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: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15. Well Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13. Well Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Service SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade: Tubing MD (ft): quest: Abandon Plug PerforationsFracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: er Casing ___________________ ame:4.Current Well Class:5. Permit to Drill Number: Exploratory Development Stratigraphic Service 6. API Number: g:8. Well Name and Number: ation or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10. Field/Pool(s): D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): g CollapseTVD BurstMDLengthSize PRESENT WELL CONDITION SUMMARY Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 208-193 50-103-20589-00-00 N/A CRU CD3-305 ADL 372103, ADL 372104, ADL 372105 Colville River Field/Fiord Oil Pool 16,859 6659 16,770 6659 3000 14178 N/A Conductor 77' 16" 114' 114' Surface 3493' 9-5/8" 3530' 2467' Intermediate 15,207' 7" 15,242' 6669' Production Liner 1671' 4-1/2" 16,770' 6659' N/A (slotted liner)N/A 4-1/2"L-80 15,106 Baker Premier Packer 14,073' MD & 6307' TVD 04/11/2020 Stephanie Pilch Well Integrity & Compliance Specialist 4/4/20 Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907)659-7126 ✔Tubing patch ✔ ✔ ✔✔ ✔ By Samantha Carlisle at 8:29 am, Apr 06, 2020 320-151 VTL 4/8/20 X DLB 4/6/20 DSR-4/6/2020GWVComm. on Required? Yes No 4/8/2020 JLC 4/8/2020 ! " #$$% & '! ( )( * ! ) (+ ) ! , -!. /0 &* %1,2& 3* $4 5"!. , ! ! + )6%$* 6)+ +7 . !+ ,! -"+ ! ! ! , -!. !"#$%&'() *!!)*! ! ) + !!! ,- ! )! . !)! !/01$234( , /!! ! !* ! *!!!/ )! . !) ! !, .! ! !! !5 +66 ( !!.!)*! .! ! !(! ! ,! !(!( ! ! ! !* !, Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:CD3-305 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: T/S AnnComm CD3-305 claytg Casing Strings Casing Description CONDUCTOR Insulated 34" OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.50 Grade H-40 Top Thread Welded Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 36.8 Set Depth (ftKB) 3,529.8 Set Depth (TVD) … 2,467.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 34.6 Set Depth (ftKB) 15,241.7 Set Depth (TVD) … 6,668.6 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description SLOTTED LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 15,098.5 Set Depth (ftKB) 16,770.0 Set Depth (TVD) … 6,658.9 Wt/Len (l… 12.60 Grade L-80 Top Thread SLHT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 15,098.5 6,650.9 81.32 HANGER BAKER FLEX LOCK HANGER ASSEMBLY 5.000 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 31.5 Set Depth (ft… 15,106.0 Set Depth (TVD) (… 6,652.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.5 31.5 0.00 HANGER FMC TUBING HANGER 3.970 2,303.3 1,995.3 58.07 NIPPLE DB PROFILE NIPPLE 3.813 14,072.5 6,306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 15,095.5 6,650.4 81.26 LOCATOR BAKER FLUTED NO-GO SUB - ABOVE & BELOW PROFILES 3.990 15,105.0 6,651.8 81.46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 14,176.7 6,349.7 65.61 PLUG 3.813" XN CAT STANDING VALVE 3/23/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 15,491.9 16,723.0 6,670.6 6,658.4 2/4/2009 32.0 SLOTS SLOTTED LINER Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 13,959.3 6,260.1 CAMCO KBG-2- 1R 1 INJ DMY BTM 0.000 0.0 12/6/2015 Notes: General & Safety End Date Annotation 3/14/2016 NOTE: View Schematic w/ Alaska Schematic9.0 1/22/2016 NOTE: MILLED ICE FROM 3845' TO 4675. BULLHEADED 75 BBL DIESEL FREEZE PROTECT FROM SURFACE. HORIZONTAL, CD3-305, 4/4/2020 4:41:16 PM Vertical schematic (actual) SLOTTED LINER; 15,098.5- 16,770.0 SLOTS; 15,491.9-16,723.0 INTERMEDIATE; 34.5-15,241.7 WLEG; 15,105.0 LOCATOR; 15,095.5 PLUG; 14,176.7 NIPPLE; 14,176.7 PACKER; 14,072.5 GAS LIFT; 13,959.3 SURFACE; 36.8-3,529.8 NIPPLE; 2,303.3 CONDUCTOR Insulated 34"; 37.0-114.0 HANGER; 31.5 WNS INJ KB-Grd (ft) 41.48 Rig Release Date 2/7/2009 CD3-305 ... TD Act Btm (ftKB) 16,859.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032058900 Wellbore Status INJ Max Angle & MD Incl (°) 92.92 MD (ftKB) 15,504.00 WELLNAME WELLBORECD3-305 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophiIlips.com> Sent: Monday, February 24, 2020 7:27 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: CRU CD3 -305 (PTD# 208-193) Report of Sustained IA Casing Pressure Attachments: CD3 -305 IA Pressure 2.17.20 to 2.24.20jpg Hello Chris, I wanted to follow up with my email from this weekend regarding CRU CD3 -305 (PTD# 208-193) report of sustained IA casing pressure. The Marcit Gel treatment was completed at 6:00 AM on 2/23/2020. The well is currently undergoing the three-day shut-in period for the gel to set. The IA pressure began dropping when the treatment fluid was swapped from gel to flush fluid. At the end of the treatment, the IA pressure had reduced to 1270 psi and has continued declining. The T/I/O is presently at 1056/1071/8 psi. My previous correspondence stated that our plan was to secure the well after the three-day shut in period. I recently was informed that slickline does not presently have access to C133-305 due to the pump support equipment layout for a Marcit Gel treatment planned for a neighboring well. C133 -305's pressure has declined below DNE post-treatment, so we intend to wait until after the equipment is cleared to secure the well. This will prevent delaying the second treatment and moving the equipment two additional times. The second treatment is expected to be completed in two weeks. In the meantime, the well will remain shut in and DHD will perform initial diagnostics on the well including an MIT -IA and packoff testing. Please let me know if you have any questions or disagree with the plan forward. I have attached a summary of the IA pressure through the duration of the treatment period. Sincerely, Sa*1 iCGW1A9Pi i Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, February 22, 2020 9:17 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: CRU CD3-305JPTD# 208-193) Report of Sustained IA Casing Pressure Attachments: CD3-305.pdf, MIT CRU CD3 Pad 02-10-18.xlsx; CD3 -305 MIT 1.23.20.xlsx; CD3 -305 90 Day TIO.pdf Good Morning Chris, Water injector CRU CD3 -305 (PTD# 208-193) developed sustained casing pressure last night, Feb 22, 2020 while undergoing a Marcit Gel Treatment approved under Sundry 319-566. The inner annulus pressure has risen to 2443 psi and is presently rising as the pump treatment continues. We believe this IA pressure is correlated to the applied tubing injection pressure for the pumping treatment. The production casing is 7", 26 Ib/ft, L-80, BTC with an internal yield pressure of 7,240 (45% is 3258 psi). The well has a history of a passing MIT -IA to 3000 psi performed on 1/23/2020 prior to starting the treatment (see attached for details). The most recent AOGCC witnessed MIT -IA was performed 2/10/2018. It appears that TxIA communication developed during the treatment. The success of the Marcit Gel treatment requires continual pumping. Shutting down injection will compromise the results of the treatment. Pumping operations are presently ongoing with the expectation of 48 hours until conclusion of the treatment. A bleed was made from 2280 psi to 1430 psi at midnight; However the IA pressure quickly rose, so the decision was made to forgo bleeding the IA while pumping operations continue to reduce the chance of pulling Marcit Gel into the IA. CPAI intends to continue pumping operations while monitoring the inner annulus pressure, not allowing the pressure to exceed 45% of the burst pressure of the casing. Upon concluding pumping operations CPAI intends to shut in the well for three days for the gel to set. The well will then be secured and remain shut in to commence diagnostics to investigate the sustained casing pressure. Please let me know if you have any questions or disagree with this plan forward. Sincerely, Sara.Carllsl& of es4w) / Ste}iha vl L& Paclv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549(@cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Steve Drake Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3 -305 Permit to Drill Number: 208-193 Sundry Number: 319-566 Dear Mr. Drake: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the 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, r Jssic"A elowski Commissioner DATED this A day of December, 2019. gBDMS-114C19 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AArr. ?s 9nn DEC 13 90fn Psi 6ZJ181/9 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate LJ Repair Well own Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Program ❑ ggAp�oved Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing LIOther: Ma1Lit6Gel Treatment ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development❑ Stratigraphic ❑ Service LZ 208-193 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20589-00-6c� 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 ❑ No Q CRU CD3 -305 9. Property Designation (Lease Number):ield/Pool(s): 10. F ADL 372105, ADL 372104, ADL372103 Colville River Field / Fiord Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft) Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 16,859' • 6,659' • 16770' 6659' 3000 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 3,493' 9-5/8" 3,530' 2467' Intermediate 15,207' 7" 15,242' 6669' Production Slotted Liner 1672' 4-1/2" 16,770' 6659' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A 4.500" L-80 15106' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER - BAKER PREMIER PACKER MD= 14073 ND= 6307 12. Attachments: Proposal SummaryL:�J Wellbore schemi 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ service (] ' 14. Estimated Date for 15. Well Status atter proposed work: Commencing Operations: 1/27/2020 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG 171 - GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Steve Drake Contact Name: Steve Drake Authorized Title: Sr. Wells Engineer Contact Email: steve.g.drake@conocophillips.com Contact Phone: X907) 263-4062 Authorized Signature: aJ r Date: / COMMISSION US ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSI me 19 2019 Post Initial Injection MIT Req' Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required:�.Cd� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (21(�� 1 Fnrm in_ana as /icon annn e...... --- ......::.....:.._ :...._....�_ .� _� _.._- . Subm Form and - - -- -----.r-......... .��. � . _ :.. r <vr r r. r m me pace ora approval. 1 .,,,, ��//�//v �/ Attachments in Duplicate /9 Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, December 18, 2019 6:54 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CRU CD3-305(PTD 208-193, Sundry 319-566) MBE Marcit Gel Treatment Victoria, SW MIT -IA passed on 2/10/18. Data is below. Thanks, Steve (SW) CD3 -305 Lou Laubenstein MITIA Passed to 2990 psi. Initial T/1/0 = 2190/670/36 IA FL @ SF LRS pressured with 3 bbl to T/1/0 = 2192/2990/63 15 min: 2190/2970/63 (-20 psi). 30 min: 2190/2970/63 LRS bled for 3 min to T/1/0 = 2188/670/36 (3 bbl). Final T/1/0 = 2188/670/36 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 17, 2019 9:26 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: (EXTERNAL]CRU CD3-305(PTD 208-193, Sundry 319-566) MBE Marcit Gel Treatment Steve, Please provide latest MIT -IA results. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoePeiia.a laska.00v 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 Proposed CD3 -305 MARCIT Gel Treatment Analysis of the injection history of CD3 -305 and production history of CD3 -304 shows a strong interaction between the two wells. An injection profile run on March 05, 2016 showed majority of the injection occurring below 16500'. The well had intersected faults beyond 16500' while drilling and had encountered mud losses at 16525' (@ 25 Bbl/hr) and at 16600' (@ 60 Bbl/hr). We hypothesize that these faults act as conduits between CD3 -305 and CD3 -304. Based on this information, the decision was taken to perform a gel treatment in CD3 -305. Due to the limitations in completions of the well, the specific treatment interval cannot be isolated and hence the gel has to be pumped in the entire wellbore. However, the gel is designed to enter mostly void space, and therefore it is anticipated that there will be limited damage to matrix rock. It is proposed that a fullbore MARCIT Gel job (crosslinked polymer) be pumped into CD3 -305 to partially fill these faults and improve OOIP recovery in the waterflood pattern between CD3 -305 and CD3 -304. The gel jab targets a total of 40,000 barrels over 8-10 days. Procedure Rig up polymer mixing equipment on location. 1. Perform a SRIT at 1.38 BPM, 2.08 BPM, 2.77 BPM and 3.47 BPM for 4 hours at each rate. 2. Pump the gel with the following pump schedule: Target Concentration (ppm) Design Volume (bbl) Treatment Rate Total Treatment (hpd) Rate (bpm) Target Polymer g (Ibs) Days Bagslhr 4,000.00 16,000.00 4,500 3.13 6,293.71 3.6 4.8 6,000.00 12,000.00 4,500 3.13 9,440.56 2.7 7.2 81000.00 8,000.00 4,000 2.78 11,188.81 2.0 8.5 10,000.00 4,000.00 3,000 2.08 10,489.51 1.3 7.9 Total 40,000.00 83,916.08 9.6 3. Evaluate pressure changes over time to target final pump rate and pressure of 4000 BWPD at a stable WHP of 2000 psi (500 psi additional pressure due to friction). 4. After pumping the gel volume, displace the final stage of Marcit Gel with -2 barrels of uncrosslinked gel, 15 barrels of breaker solution and 191 bbls of seawater and 38 bbls of diesel for surface freeze protection to 2500'. With this pump design, there will be crosslinked gel from TD up to 16164, un-crosslinked viscous gel between 16164 and 16032, breaker between 16032 and 15046, seawater between 15046 and 2495 and diesel between 2496 and surface. 5. Leave the well shut in for more than 6 days or as directed by the on-site supervisor to allow the gel to become fully crosslinked. 6. Bring the injection system online and gradually ramp up injection: a. Start injecting at 500 BWPD. Allow rate and pressure to stabilize for several days. b. Ramp up rate by 500 BWPD every week till we are pumping at maximum system pressure. 7. Asa contingency for cleaning up the heel, a CT FCO may also be performed in the heel of the well utilizing the breaker solution. s jjj� WN$ INJ WELL -NAME CD3 -305 WELLBORE CD3 -305 OtlOCO 1 Ips rven Maneuxea Max An Mie & MD TD AIX51W.1 it Fleltl Neme 5010325PIIUWI Wellbore9Mu5 Icl (°I MD(RK6) A11MIKKBI FORD PAR 5010 2 8900 IN 2.92 15,50rl 16,859.0 CommerX X3S (ppm) Date JA ......n FnO DMe K1..48 (rel -9B "'oI ase Uate SSSV: NONE 4 Last WO: 1.48 XORlz-i-eDxaos 11111 -1 -1,11 - AM Last Tag Ver6ulecnemelk gawp ANnEMtlen depth I.KBI End.. Wide- L,et MOE9y Lasl Tag: C03305 ImosWr Last Rev Reason XINGER: e14 ... v Annelallon Entl ONa Wellbore Out ModB.......... r -Rev Reaspn: SET AI INJ VLV 3114/2016 CD33gr pplweR Casing Strings a,mg De,erptlon un.,V a. Top pses) SrtD pin (nrcel Sm Oapin Fru''.. Wllten (L_Gntle Top mre.a TO CONDUCTOR CONDUCTOR to 1525 3>.0 114.0 114.0 62.50 H-00 Welded l pip"Apeom y t a,me DeacnpDen oo pnl ID (1n) ToI(ftKDI SD.pm(Rtte) SO Depth RVDl... -ed (i... Gra a Tap Theatl SURFACE 95/8 8.83 36.8 3,5298 2,46].3 40.00 L-80 BTCM Oaeinp Deacrisoon OO(Inl ID(in) iopm1 8rt Daptn (ryKBI Set Depth (NO)..--09._Gntle Top Tnrntl INTERMEDIgTE ] fi.28 34.6 15,241.] 6,668a 26.00 L80 BTCM Ce,lnp pe6ctlpllon OD (in) IO (II Led (I Set Dep TvXS) SO DeathD)... n MWVlen (L.. Gretle ID,Tunurd SLOTTED LINER 4112 3.96 15,0985 16,])00 fi,fi58.9 12.60 L-80 SLHT Liner Details - BIG, C9NOVCTOR m,3Ie0.431'� Tap TITop(rv0)(Kleel 111-11', Item De, cool Nominal (inl 15,098.5 6,650.9 flt32 HANGER BAKER FLEX LOCK HANGER ASSEMBLY 5.11[0 Tubing Sttlngs TUEInpG cnglon Sfeing Ma... IO (Try Ti IRKB) 11,l)on% 111.. 561 pap1n (rv0I.([.I Gretle Top Correglon TUBING 41¢ 3.9E 31.5 5106 6,6520 1260 L-80 IST -M Completion Details I Top(WD) Top Incl Com Nominal iop (nKBI (nKBI (°I IMm IX6 IDQn) 31.5 31.5 0.00 HANGER FMC TUBING HgNGER 3,970 as, NL¢x.mse v 1 2.303.3 1,9953 58.07 NIPPLE DB PROFILE NIPPLE 3.813 NI WLE; x,mA.] 14.072.5 6.306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 14,1]6.] 6,349.7 65.61 NIPPLE HEB XN NIPPLE 3.725 15,0955 &650.4 81.26 LOCATOR BAKER FLUTED NOW SUB - ABOVE &BELOW PROFILES 3,990 I 15,.415.0 6SI 81.46 WILED BAKER WIRELINE ENTRV GUIDE 3.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, eta.) Tap(rvD) Top mtl Top (ttNBI 2,3(33,0 (nKBI 7 1,995.1 56.06 INJ Dev Com VLV A-11NJ VLV (S/N: H554fi411.26"ORIFICE) Run Deb 11/161201 ID (in) 1,250 SURFACE: d6ee5xGa 6 Perforations&Slots snm I Topless) elm (nKBI Top (ND) (nKBI atm (rvDl (ryK5) WkeEZane IX4 IXn, pnomm I type Cem 15.491.9 16,]23.0 6,6]0.8 Q658.4 2/.42009 32.0 SLOTS SLOTTED LINER Mandrel Inserts ru s., lseeex aI N Top (ftKB) 1 13,959.3 Top(NDI (M1KB) 6,2fi0.i M,Ae CAMCO Kso 0 MOOeI R Celia) 1 Sery INJ V,Ive Type DMV LittM1 type BTM Port Slze (Inl 0.000 TRORun (WI) 0.0 Run Oate 1 B.2015 Com Notes: General & Safety Fntl Dae Mnomlon RADKEe. 11 111 122/2016 NOTE: MILLED ICE FROM 3845 -TO 4675, BULLHEADED ]5 SSL DIESEL FREEZE PROTECT FROM SURFACE, 3114201fi NOTE: VieWSchemallciWAlsses SCM1ematic9.0 NIPRE', 14, IMM LOCATOR, 1sa955 r,UD3 15" INIERMEDIATE:a4.Y15241.7� 1 IY l SLOT6. 164p14ta TT3p�7 i.. BLOTTED LINER 15.038 S Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Wednesday, December 18, 2019 6:54 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]CRU CD3-305(PTD 208-193, Sundry 319-566) MBE Marcit Gel Treatment Victoria, SW MIT -IA passed on 2/10/18. Data is below. Thanks, Steve (SW) CD3 -305 Lou Laubenstein MITIA Passed to 2990 psi. Initial T/1/0 = 2190/670/36 IA FL @ SF LRS pressured with 3 bbl to T/1/0 = 2192/2990/63 15 min: 2190/2970/63 (-20 psi). 30 min: 2190/2970/63 LRS bled for 3 min to T/I/O = 2188/670/36 (3 bbl). Final T/1/0 = 2188/670/36 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, December 17, 2019 9:26 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]CRU CD3-305(PTD 208-193, Sundry 319-566) MBE Marcit Gel Treatment Steve, Please provide latest MIT -IA results. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeoDCadalaska.aov 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 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,February 20,2018 P.I.Supervisor e7, (17-":7( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-305 FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-305 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jet-- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-305 API Well Number 50-103-20589-00-00 Inspector Name: Lou Laubenstein Permit Number: 208-193-0 Inspection Date: 2/10/2018 Insp Num: mitLOL180212124044 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD3-305 rType Inj W 'TVD 6307 [Tubing' 2190 'I 2192 2190 2190 - PTD 2081930 Type Test SPT Test psi 1577 IA 670 2990 2970 2970 - BBL Pumped: 3 BBL Returned: 3 OA 36 63 - 63 ' 63 �. Interval 4YRTST jP/F P Notes: Tuesday,February 20,2018 Page 1 of 1 • I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, May 22, 2017 2:46 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE:CD3-305 (PTD#208-193) Low OA pressure Chris, CPAI has performed diagnostics on Alpine injector CD3-305(PTD#208-193)and no problems have been found. The well passed an MIT-IA to 3000 psi, and the tubing and inner casing packoffs both passed positive and negative pressure tests. The OA was charged to approximately 300 psi and has held pressure thus far. We will put the well on a 30-day monitor and ensure the OA pressure continues to behave normally. If no problems are seen during this monitoring period,we intend to treat it as a normal well. If a problem is found we will report it to you with a proposed course of action. Please let me know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent: Friday, May 12, 2017 9:49 AM SCANNED iv,, n ttz7 To:chris.wallace@alaska.gov Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CD3-305(PTD#208-193) Low OA pressure Chris, Alpine injector CD3-305 (PTD#208-193)was noted to have unusually low OA pressure for an online injector. CPAI intends to investigate the reason for the low OA pressure as soon as possible. We will keep you updated with our findings and plan forward. The injector is currently on seawater injection. Attached is a 90-day TIO plot and schematic. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, May 12, 2017 9:49 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: CD3-305 (PTD# 208-193) Low OA pressure Attachments: CD3-305 90-day TIO plot 5-12-17.JPG; CD3-305 schematic.pdf Chris, Alpine injector CD3-305 (PTD#208-193)was noted to have unusually low OA pressure for an online injector. CPAI intends to investigate the reason for the low OA pressure as soon as possible. We will keep you updated with our findings and plan forward. The injector is currently on seawater injection. Attached is a 90-day TIO plot and schematic. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED MAY 1 72Oj7 • L • a cc L.. G z a E ri r r- 2 V C e N O � a r f+ O � a O C a r4 LL ti LL M N C N th r N U N lA gills r- I N c ° 1 1 1 1 1 STATE OF ALASKA RECEIVED • ALSOA OIL AND GAS CONSERVATION COMOION M 6„' ;'017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Li Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Marcit Gel Treatment Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska Inc Development ❑ Exploratory ❑ 208-193 3.Address: Stratigraphic Service ❑✓ 6.API Number: PO Box 100360,Anchorage AK 99510 50-103-20589 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 372104,372105,372103 CQ U CD3-305 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Fiord Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 16770 feet Plugs measured N/A feet true vertical 6659 feet Junk measured N/A feet Effective Depth measured 16770 feet Packer measured 14072 feet true vertical 6659 feet true vertical 6306 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114 16” 114 114 1640 psi 630 psi Surface 3530 9-5/8" 3530 3467 5750 psi 3090 psi Intermediate 15241 7" 15241 6668 7240 psi 5410 psi Production Liner 1672 4-1/2" 16770 6659 Slotted Slotted Perforation depth Measured depth N/A feet SCANNED APR d 12017, True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) 4-1/2" L-80 15106' 6660' Packers and SSSV(type,measured and true vertical depth) Baker Premier 14072' 6306' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Pumped 3000 bbl of a 30000 bbl treatment into suspected fault—16,000'before equipment failure caused the job to be cancelled Treatment descriptions including volumes used and final pressure: 3000 bbl of Marcit Gel©1500 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A 4000 bbl 256 psi 935 psi Subsequent to operation: N/A N/A 3780 bbl 210 psi 1681 psi 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ 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: 316-578 Contact Jason Burke Email lason.burke(a�cop.com Printed Name Jason Burke Title Staff Wells Engineer Signature �''-- ..,... _...,. Phone 907-231-4568 Date 2/27/2017 ! 7 — Form 10-404 Revised 5/2015 �tL— 3�a 'J /7RB®PIIS V A? _ 2011 Submit Original Only � 3r2�/<7 • • CD3-305 DTTMS.JOBTYP SUMMARYOPS 2/9/17 MISC. MARCIT GEL TREATMENT PROCEDURE CAPACITY SUSTAINMENT LRS TOOK OVER PUMPING OPERATIONS FROM TIORCO AFTER TIORCO HAD PUMPED 1834 BBLS OF SW/MARCIT GEL DUE TO TIORCO TRIPLEX PUMP FAILURE. 2/11/17 MISC. MARCIT GEL TREATMENT/ CAPACITY SUSTAINMENT 2/21/17 MISC. DRIFT TO BD NIP @ 2303'RKB. SET A-1 INJ VALVE(SN; HSS- CAPACITY 164) ON 3.81" DB LOCK @ SAME. PASING CLOSURE TEST. SUSTAINMENT JOB COMPLETE. WNSCD3-305 ConocoPhil ips *: Well Attributes Max Angle TD Al4Sk7,{.Itic, Wellbore API/UWI Field Name Wellbore Status F) MD(ftKB) Act Btm(ftKB) a Ct ,aitops' 501032058900 FIORD KUPARUK INJ Inc!92.92 15,504.00 16,859.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD3-305,3/1/2017 8:57.31 AM SSSV:NONE Last WO: 41.48 2/7/2009 Vertical schernaac(acNal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET Al INJ VLV pproven 3/14/2016 '' il° Casing Strings - ' -HANGER;315. nal Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded -7-Z-44.-' Insulated Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread J SURFACE 9 5/8 8.835 36.8 3,529.8 2,467.3 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.6 15,241.7 6,668.6 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 11 j SLOTTED LINER 4 1/2 3.958 15,098.5 16,770.0 6,658.9 12.60 L-80 SLHT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 15,098.5 6,650.9 81.32 HANGER BAKER FLEX LOCK HANGER ASSEMBLY 5.000 CONDUCTOR Insulated 34°;_ Tubing Strings 37.0-114.0 Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 31.5 15,106.01 6,652.0 12.60 L-80 IBT-M Completion Details Nominal ID Top(ftKB) Top(ND)(ft)(B) Top Incl(°) Item Des Com (in) 31.5 31.5 0.00 HANGER FMC TUBING HANGER 3.970 1 2,303.3 1,995.3 58.07 NIPPLE DB PROFILE NIPPLE 3.813 14,072.5 6,306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 INJ VLV;2,303.0 : 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 NIPPLE;2,303.3 .1Y 15,095.5 6,650.4 81.26 LOCATOR BAKER FLUTED NO-GO SUB-ABOVE 8 BELOW 3.990 PROFILES 15,105.0 6,651.8 81 46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc) Top(ftKB) (MB) (°) Des Corn Run Date 10(in) 2,303.0 1,995.1 58.06 INJ VLV A-1 INJ VLV(S/N:HRS-46/1.25"ORIFICE) 3/11/20)6 ).250 SURFACE;38.85,529.8 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 15,491.9 16,723.0 6,670.6 6,658.4 2/4/2009 32.0 SLOTS SLOTTED LINER Mandrel Inserts st tii GAS LIFT,13,959 a 3 on Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) SewType Type (in) (psi) Run Date Com IIII 1 13.959.3 6,260.1 CAMCO KBG-2- 1 INJ DMY BTM 0.000 0.0 12/6/2015 1R Notes:General&Safety End Date Annotation ,Ir g t, 1/22/2016 NOTE: MILLED ICE FROM 3845'TO 4675. BULLHEADED 75 BBL DIESEL FREEZE PROTECT FROM 1• SURFACE. PACKER;14,072.5 - 3/14/2016 NOTE:View Schematic w/Alaska Schematic9.0 I NIPPLE'.14,1767 qiiit It IsLOCATOR,15,095.5 WI.EC:15.105.0 1 :i 1 i 1 INTERMEDIATE;34.5-15,241.7 SLOTS;15,491.9-18,723.0 I -4 • SLOTTED LINER;15,098.5- J I 78,770.0 OF Alaska Oil and Gas ofl 1L1 1 Conse va ion C®Iriril1ssion SKA Fl 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 !' Main: 907.279.1433 FALASBP Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer ConocoPhillips Alaska, Inc. scANNED AR P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CRU CD3-305 Permit to Drill Number: 208-193 Sundry Number: 316-578 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, Daniel T. Seamount, Jr. Commissioner DATED this /day of November,2016. RBDMS Nov 1 6 2016 • • RECEIVED. • STATE OF ALASKA NOV 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AoGcr 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations l- Fracture Stimulate E Repair Well I- Operations Shutdown E Suspend Perforate E Other Stimulate r Pull Tubing E Change Approved Program r Plug for Redrill E Perforate New Pool r Re-enter Susp Well 1 Alter Casing n Other: Marcit Gel Treatment F, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development E 208-193 • 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service " 50-103-20589-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A JJ Will planned perforations require a spacing exception? Yes E No F CRU CD3-305 ` 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,ADL 372104,ADL 372103 ' Coleville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 16,859' 6,659' • 16765' r 6659' 2684 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114" Surface 3,493' 9 5/8 3,530' 2467" Intermediate 15,207' 7" 15,242' 6669" Production Liner 1672' 4 1/2" 16,770' 6659" Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 4 1/2" L-80 15,106' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER PREMIER PACKER MD=14072"TVD=6307" . 12.Attachments: Proposal Summary Wellbore schematic (] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic E Development E Service F, 14.Estimated Date for 2/5/2017 15.Well Status after proposed work: Commencing Operations: OIL E WINJ E WDSPL 1' Suspended 16.Verbal Approval: Date: GAS E WAG F• GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown I- Abandoned 1- 17. 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke @ 265-6097 Email jason.burke@cop.com Printed Name Jason Burke Title Staff Wells Engineer Signature Phone:265-6097 Date 1. ///Vik COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:. \_e. _ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ -.1- 1---. t t I.� 1) L Spacing Exception Required? Yes ❑ No i / Subsequent Form Required: /0 -- eie.),-/ RBDMS ( --NOV 1 6 2016 APPROVED BY 141151 ' C I Approved by:, MMISSIONER THE COMMISSION Date: G / 7` l Form 10-00 Revised 11/20150 O e p i valid focr�12 months from the date of approval. ,/. Attachments in Duplicate `i /x 11( 10 . (Y4'-- �7 470-/4 94 • • Proposed CD3-305 MARCIT Gel Treatment Analysis of the injection history of CD3-305 and production history of CD3-304 shows a strong interaction between the two wells.An injection profile run on March 05, 2016 showed majority of the injection occurring below 16500'.The well had intersected faults beyond 16500'while drilling and had encountered mud losses at 16525' (@ 25 Bbl/hr) and at 16600' (@ 60 Bbl/hr).We hypothesize that these faults act as conduits between CD3-305 and CD3-304. Based on this information,the decision was taken to perform a gel treatment in CD3-305. Due to the limitations in completions of the well,the specific treatment interval cannot be isolated and hence the gel has to be pumped in the entire wellbore. However,the gel is designed to enter mostly void space, and therefore it is anticipated that there will be limited damage to matrix rock. It is proposed that a fullbore MARCIT Gel job (crosslinked polymer) be pumped into CD3-305 to partially fill these faults and improve OOIP recovery in the waterflood pattern between CD3-305 and CD3-304. The gel job targets a total of—30,000 bbls pumped over 5-7 days. Procedure 1. Rig up polymer mixing equipment on location. 2. Preform a SRIT at 1.38 BPM, 2.08 BPM, 2.77 BPM &3.47 BPM for 4 hours at each rate. 3. Pump the gel with the following pump schedule: Target Target Treatment Concentration Volume Rate 3000 ppm 12000 bbls 3.13 BPM 5000 ppm 9000 bbls 3.13 BPM 7000 ppm 6000 bbls 2.78 BPM 10000 ppm 3000 bbls 2.08 BPM 4. Evaluate pressure changes over time to target final pump rate and pressure of"'3000 BWPD at a stable WHP of^'2000 psi. (500 psi additional pressure due to friction). 5. After pumping the gel volume, displace the final stage of Marcit Gel with' 2 barrels of un- crosslinked gel, 15 barrels of breaker solution, 191 Bbls of seawater, and 38 Bbls of Diesel for surface freeze protection to 2500'.With this pump design,there will be crosslinked gel from TD up to^' 16164', un-crosslinked viscous gel between 16164' and 16032', breaker between 16032' and 15046', seawater between 15046' and 2495', and diesel between 2495' and surface. 6. Leave the well SI for more than 6 days, or as directed by on-site supervisor,to allow the gel to become fully crosslinked. 7. Bring the injection system on line and gradually ramp up injection: a. Start injecting at 500 BWPD. Allow rate and pressure to stabilize for several days. b. Ramp up rate by 500 BWPD every week till we are pumping at maximum system pressure. 8. As a contingency for cleaning up the heel,a CT FCO may also be performed in the heel of the well utilizing the breaker solution. WNS 40 CD3-305 • 1 Con©coPhillips 3 Well Attribu Max Angle&MD TD Alaska Irk.;, WellboreAPIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btre)ftKB) Conocophiips 501032058900 FIORD KUPARUK INJ 92.92 15,504.00 16,859.0 ... Comment I12S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD3-305,11/7/20162.13-.32 PM SSSV:NONE Last WO: 41.48 2/7/2009 Vertical schematc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET Al INJ VLV pproven 3/14/2016 litiiirtasing rings HANGER;31.5 Casing Description ODID To (ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade TopThread (in) (in) p I L CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded ' 1141 d 34" ID(in) Top(5KB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread 8835 36.8 3,529.8 2467.3 40.00 L-80 BTCM 1 casing Description ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 6.276 34.6 15,241.7 6668.6 26.00 L-80 BTCM ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread 3.958 15,098.5 16,770.0 6,658.9 12.60 L-80 SLHT 11 'C 1 II. Liner Details Top I • I_ -, MKTop(TVD)09 1:9 81 32 HANGER BAKER FLEX LOCK111 CONDUCTOR Insulated 34", 1 Tubing Strings 37.0-114.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibtft) Grade Top Connection 15,1061 6.652 1 12 60 80 1 Completion Details Nominal ID ::- Top(ftKB) Top(TVD)(ftKB) Top Inc!(°) Item Des Com (in) 31.5 31.5 1 11 HANGER FMC TUBING HANGER 3.970 PACKER2,303.3 1,995.3 58 07 NIPPLE DB PROFILE NIPPLE 3.813 14,072.5 6,306.6 65 53 PACKER BAKER PREMIER INJ VLV;2,303.0 ha 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 NIPPLE,2,303.3 15,095.5 6,650.4 81.26 LOCATOR BAKER FLUTED NO-GO SUB-ABOVE&BELOW 3.990 PROFILES 15.105.0 6,651.8 81.46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 2.303.0 1 995.1 58.06 INJ VLV A-1 INJ VLV(S/N HRS-46/1.25"ORIFICE) 3/11/2016 1.250 Perforations&Slots SURFACE;36.0-3,529.8 Shot Dens Top(TVD) Btm(ND) (shots/ Top(5K0) Btm(ftKB) (ftKB) (ftKB) Zone Date R) Type Com 15,491.9° 16,723.0 6,670.6 6,658.4 2/4/2009 32.0 SLOTS SLOTTED LINER Mandrel Inserts St / a e GAS LIFT;13,959.3 - -. o Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 13,959.3 6,260.1 CAMCO KBG-2- t INJ DMY BIM 0.000 0.0 12/6/2015 1R Notes:General&Safety • • End Date Annotation 1/22/2016 NOTE. MILLED ICE FROM 3845'TO 4675. BULLHEADED 75 BBL DIESEL FREEZE PROTECT FROM I SURFACE. 37(5 PACKER;14,0725 3/14/2016 NOTE:View Schematic w/Alaska Schematic9.0 i NIPPLE;14,176.7 LOCATOR,15,095.5 WLEG,15,105.0 Iirm'',If si. L it 4' 1r I �'ff // INTERMEDIATE;34.5-15,241.7 I/ D t( / yCliC_J/y�/ - r SLOTS;15,491.9-16,723.0 SLOTTED LINER,15,098.5- 16770.0 - D cf. 49 % c4 0 w W r Jc�NTo X arm � U _Cs tj C (17 ri 11 Q Ya.9 o �zO z vOp wH >. ° ` o u a U � . > oY (a y to a Q Q p -+ 0. to m co to tO CO m 0 CO tom o 0 M 0 m a 0 G co C m 1@ f0 m m m v, L c C , ~ Q E 2 2 E E E E E E ,- f°' a s M N A e- O T Q N NM M N r- w > C (U a O) O -0E O >- Q V �+ • -- J• J J J J J J J J J C ,- -4-, L- a" W W W W W W W W W W 0.0 C ° F- U. u LL Li- LI- L LL I 11. 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U) 0 CO Tr r• to co M co u uj (.0 ❑ 0) t0 M N M M N O) CO CO 0 M 0 0 0 0 O 0 0 0 O O O O O O O O p O O O • CV 0 0 0 0 0 0 0 0 0 0 (p rn s U v U lta v U U m ❑ ❑ ❑ E cO7O C7 C7 0 C9 `1 r r v O W 0 0 0 0 0 0 0 U U U c d N f7 $1 1 I < g ca C p o 0 0 0 0 o D o o u tD . 0 0 0 0 0 0 0 0 0 u Cr N m u. ti M (00 U)) UCO CO M) IM) (00 rr)) N dM' 14 o N 0 M N 0 N N N N a- O 0 N, p, N N N N N N N N N N n M to O) M to to O 0) to to 0 : O - O N N 0 N N N N N N Q1 • 0 O O O O 0 O O 5) O O O O O O O O O O to to N N O U) to t[) to U N = '- C a) u C _' i_ 0) f0 G) f0 v 0) E a > - 8 z c c .a 'l' N J p o Q r O r CO 4) 7 d E y m O in N M M M a' N 0 a' a+ d7 Q p - E ` F- h T M d' th a O a. d ti n in U U N C C N tn a a Q • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, April 12, 2016 2:06 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R. Tyler Subject: RE: CRU CD3-305 (PTD 208-193) Update 4-12-16 Attachments: CD3-305 90 day TIO 4-12-16.JPG Chris, CRU WAG injector CD3-305 (PTD 208-193) was brought on miscible gas injection on 3-15-16 and has exhibited no signs of IA pressurization during the monitor period which is coming to an end. CPAI intends to return the well to 'normal' status and continue WAG injection in the well. If at any time in the future the well exhibits annular communication, the AOGCC will be notified at that time and diagnostics will begin anew. Attached is a 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn App Y 8 201 6 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager (907) 659-7000 pgr. 123 ( WELLS TEAM co,«oPt iilips From: NSK Problem Well Supv Sent:Thursday, February 18, 2016 4:34 PM To: Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: CRU CD3-305 (PTD 208-193 ate 2-18-16 Chris, CRU Injector CD3-305 (PTD 208-193) was brought on water injection 1-23- and has exhibited no signs of IA pressurization during the monitor period thus far. The plan outlined in the previtemail stated that after 30 days of water injection the well would be WAG'd to miscible injection. However, an Injection Profile Log has been requested by the reservoir engineers therefore CPAI intends to extend the water injection period by no moreat 15 days to allow for the logistics of coordinating and performing the well work(making the final WAG date 3-8-15). Once ttre.IF,,iROF has been completed the well will be WAG'd to miscible injection for that 30 day monitor and the plan will continue as stated below in the previous email. Attached is a 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, February 18, 2016 4:34 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: CRU CD3-305 (PTD 208-193) Update 2-18-16 Attachments: CD3-305 schematic.pdf; CD3-305 Diagnostic MIT-IA 6 Dec 15.xls Chris, CRU Injector CD3-305 (PTD 208-193) was brought on water injection 1-23-16 and has exhibited no signs of IA pressurization during the monitor period thus far. The plan outlined in the previous email stated that after 30 days of water injection the well would be WAG'd to miscible injection. However,an Injection Profile Log has been requested by the reservoir engineers therefore CPAI intends to extend the water injection period by no more than 15 days to allow for the logistics of coordinating and performing the well work(making the final WAG date 3-8-15). Once the IPROF has been completed the well will be WAG'd to miscible injection for that 30 day monitor and the plan will continue as stated below in the previous email. Attached is a 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/ Dusty Freeborn MAY 1 9 2016 Problem Wells Supervisor SCANNED ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 4IVELLS TEAM CortPaps 1 • 410 CHOKE FTP FTT IAP T/UO Plot - CD3-305 OAP , , , , , , .1 , , , , , , , , v /N./ 17) 2500 4 � 2000 ate. 1500 1000 TV \\vv \\ 500 0 - if 1 1 1 1 1 t 1 1 I I 1 19-Nov-15 02-Dec-15 15-Dec-15 28-Dec-15 10-Jan-16 23-Jan-16 05-Feb-16 Date Chris- This email is to serve as an update to the status of Alpine injector CD3-305 (PTD 208-193). The well was originally reported in Feb of 2015 for suspected TxIA communication. As previously reported the well passed the diagnostic MIT- IA and IA draw down test. However, the well showed a slow but consistent IA pressure build up during the 30 day monitor period. During the diagnostic testing a substantial amount of gas was bled off of the IA. Because Most recently the dummy valve at 13,959' was pulled and the IA fluid was replaced with fresh fluid to evacuate the suspected gas entrained fluid that was potentially causing the IA pressure build up due to break out after the WAG to water injection. The dummy valve was replaced and a subsequent MIT-IA passed. It is CPAI's intentions to bring the well on water injection for a 30 day monitor period and if integrity is proven WAG the well to gas injection for an additional 30 day gas injection period. If at any point in time TxIA communication is confirmed the well will be shut in until further diagnostics can be completed. Please let myself or Jan Know if you have any questions or disagree with the plan. Attached are copies of the current 90 day TIO plot, wellbore schematic and the most recent diagnostic MIT-IA 2 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, December 08, 2015 12:03 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: RE: CD3-305 (PTD 208-193) Report of suspect IA pressure increase update 8 Dec 15 Attachments: CD3-305 schematic.pdf; CD3-305 Diagnostic MIT-IA 6 Dec 15.xls Chris- This email is to serve as an update to the status of Alpine injector CD3-305 (PTD 208-193). The well was originally reported in Feb of 2015 for suspected TxIA communication. As previously reported the well passed the diagnostic MIT- IA and IA draw down test. However, the well showed a slow but consistent IA pressure build up during the 30 day monitor period. During the diagnostic testing it was suspected that the cause of the IA pressure build up was due to gas break out post WAGing the well to water injection. Most recently, the dummy valve at 13,959' was pulled and the IA fluid was replaced with fresh fluid to evacuate the suspected gas entrained fluid. The dummy valve was replaced and a subsequent diagnostic MIT-IA passed. It is CPAI's intentions to bring the well on water injection for a 30 day monitor period. If TxIA integrity is proven during the water injection period the well will be WAG'd to gas injection for an additional 30 day monitor period. If at any point in time TxIA communication is confirmed the well will be shut in until further diagnostics can be completed. Please let myself or Jan know if you have any questions or disagree with the plan. Attached are copies of the current 90 day TIO plot, wellbore schematic and the most recent diagnostic MIT-IA SCANNED AUG 1 0 2016 Well Name CD3-305 Notes: Start Date 9/9/2015 Days 90 End Date 12/8/2015 Annular Communication Surveillance IAP VJHR OAP 400 —4'JHT 3E00 3000 —1 N 2E00 a _ 2000 1`00 1000 r - E00 Aug-1` Sep-1` Oct-1E rl c;-1S C ec- DGI - M G I a -- PVA Er 51'n 8LPG 4+ug-1s Sep-15 Oct-1E Flea-1S Dec' Date Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 From: P obtem WelI Supv Sent: Monday, April 20, 20 PM To: Wallace, Chris D (DOA) 2 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, April 20, 2015 8:20 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK DHD Field Supervisor Subject: FW: CD3-305 (PTD 208-193) Report of suspect IA pressure increase update 4/20/15 Attachments: Picture (Device Independent Bitmap) 1jpg; CD3-305 90 day TIO 2-21-15.JPG; MIT KRU CD3-305 diagnostic non witnessed 02-13-15.xls; CD3-305 90 Day TIO plot.JPG Chris- Alpine injector CD3-305 (PTD 208-193) is nearing the end of its 30 day monitor period. The IA continued to show a slow but steady increase in IA pressure and therefore will be shut in. Diagnostics will be scheduled as needed to attempt to identify the pressure source. Depending on the results of the diagnostics,the proper notifications for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a 90 day TIO plot Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 SCANNED APR 2 3 2015 • Well Name CD3-305 Notes: Start Date 1/20/2015 Days 90 End Date 4/20/2015 Annular Communication Surveillance -EOCVJHP - 1€ . 00C - - 1E — 1= 2500 — 12 2000 112 2ECO to — 11 sZ 2000 10 1E00 1000 — 8C - 7C Dec-14 Jan-15 Feb-15 Mar-15 Apr-1E 60CC DGI _ GIGI o —- PyIII 461"\IVILA iftagm"° d gyyl BLPD lax r Dec-14 Jan-15 Feb-1E Mar-1E Apr-15 Date From: NSK Problem Well Supv Sent: Saturday, February 21, 2015 1:35 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: CD3-305 (PTD 208-193) Report of suspect IA pressure increase update 2-21-15 Chris, CD3-305 was shut in on 2/10/15. Diagnostics with DHD were completed on 2/13/15. Both the MITIA and IA drawdown tests held rock solid. Since that day,the IA has shown no build up in pressure. The IC-packoff tests passed as did the 2 positive pressure tubing packoff test and the lower metal to metal seal. However, the negative tubing packoff test as well as the upper metal-to-metal seal did fail. But due to the redundancy of the seals and the passing tubing packoff tests,the wellhead seals are not believed to be a source of any potential communication at this time. CPAI intends to return the well to water injection today for a 30 day monitor period. If during the course of the monitor period,the well continues to demonstrate signs of communication,the well will be shut in again. A follow up email will be provided at the conclusion of the monitor. Attached are an updated 90 day TIO plot, and the diagnostic test data of the MIT and drawdown test performed on 2/13/15. Well Name CD3-305 Notes: Start Date 11/23/2014 Days 90 End Date 2/21/2015 Annular Communication Surveillance 4E0 0 6'JHP — 1C 4000 — + — 1E - 1< 2500 — 13 2000 — 12 2E00 to — 111 o 2000 — 10 1E00 1000 — 80 500 tt — 70 0 1 e e CO Nov-14 Now14 Deo-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-1E Feb-15 Feb-1E Mar1E — DGI MGI 0 m Nfif‘a L.c._ SYIA :—_ BLPD Noy-14 N1 Deo-14 Dec-14 Dec-14 Jan-1E Jan-1E Jan-15 Feb-15 Feb-15 Feb-15 Date Brent Rogers/Kelly Lyons 3 Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 From: NSK Problem Well Supv Sent: Tuesday, February 10, 2015 4:03 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CD3-305 (PTD 208-193) Report of suspect IA pressure increase Chris, Alpine injector CD3-305 (PTD 208-193) has exhibited a suspect IA pressure increase. The well is to be shut in and freeze protected as soon as reasonably possible. Initial diagnostics to be performed will include an MIT-IA, pack off tests and an IA draw down test after which Slickline or Eline may be utilized if deemed necessary. CPAI will provide an email with the plan forward and submit any required paperwork upon the outcome of the diagnostics. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 « File: CD3-305 90 day TIO 2-10-15.JPG » 4 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, March 22, 2015 11:54 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: FW: CD3-305 (PTD 208-193) Report of suspect IA pressure increase update 3-22-15 Attachments: Picture (Device Independent Bitmap) 1.jpg; CD3-305 90 day TIO 2-21-15.JPG; MIT KRU CD3-305 diagnostic non witnessed 02-13-15.xls; CD3-305 90 day TIO plot.JPG Chris, Alpine injector CD3-305 (PTD 208-193) is about to complete the 30 day monitor period investigating the increase in IA pressure. As reported before the MIT-IA and IA draw down tests both passed and the tubing pack offs proved integrity with passing positive pressure tests and passing tests on the lower metal to metal seal. During the 30 day monitor the IA initially showed a small gradual increase in pressure but started a stabilization trend. The injection rate was increased at that point in time which caused an increase in IA pressure. It is CPAI intentions to monitor the IA pressure for stabilization for an additional 30 days with a request to operations to leave the injection rate as stable as possible. If the IA shows continual pressure increase the well will be shut in and freeze protected. A plan for diagnostics will be formulated at the time. Depending on the results of the monitor period the appropriate paperwork for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a current 90 day TIO plot gjakED 1 Well Name CD3-305 Notes: Start Date 12/22/2014 Days 90 End Date 3/22/2015 Annular Communication Surveillance 4E00 - — 1E WHP 4000 — — 1E — 14 3E00 — 3000 — 12 2E00 �ta — 11 2000 - 10 1E00 1000 — 80 500 — 70 Cec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Mar-15 Mar-15 Mar-1E --c•-- DGI xt':— MGI — a 4Cr:.— ?IAA Kr,_- S1M BLPD riff\ ,cfa Dec-14 Dec-14 Jan-15 Jan-1E Jan-1E Fel;-1E Feb-1E Feb-1E 1-lar-1E Mar-15 Mar-15 Date Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 From: NSK Problem Well Supv Sent: Saturday, February 21, 2015 1:35 PM 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regqOalaska.gov AOGCC.Insoectorsjalaska.gov phoebe.brooks@alaska.gov chris.wallacena.alaska.00v OPERATOR: ConocoPhillips Alaska,Inc. FIELD I UNIT 1 PAD: Alpine/CRU/CD3 DATE: 02/13/15 OPERATOR REP: Beck/Manjarrez AOGCC REP: non witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-305 Type Inj W TVD 6,30T Tubing 790 790 790 790 Interval 0 P.T.D 2081930 Type test P Test psi 1576.75 Casing 515 2,500 2,500 2,500 P/F P Notes: diagnostic MITIA OA 42 49 49 49 Well CD3-305 Type Inj. W TVD 6,30T Tubing 790 790 790 790 790 790 Interval 0 P.T.D.2081930 Type test P Test psi 1576.75 Casing 2,500 550 550 550 550 550 P/F P Notes: diagnostic IA DDT OA 49 40 40 40 40 40 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU CD3-305 diagnostic non witnessed 02-13-15.xls Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, February 21, 2015 1:35 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: CD3-305 (PTD 208-193) Report of suspect IA pressure increase update 2-21-15 Attachments: CD3-305 90 day TIO 2-21-15.JPG; MIT KRU CD3-305 diagnostic non witnessed 02-13-15.xls Chris, CD3-305 was shut in on 2/10/15. Diagnostics with DHD were completed on 2/13/15. Both the MITIA and IA drawdown tests held rock solid. Since that day,the IA has shown no build up in pressure. The IC-packoff tests passed as did the positive pressure tubing packoff test and the lower metal to metal seal. However, the negative tubing packoff test as well as the upper metal-to-metal seal did fail. But due to the redundancy of the seals and the passing tubing packoff tests,the wellhead seals are not believed to be a source of any potential communication at this time. CPAI intends to return the well to water injection today for a 30 day monitor period. If during the course of the monitor period, the well continues to demonstrate signs of communication,the well will be shut in again. A follow up email will be provided at the conclusion of the monitor. Attached are an updated 90 day TIO plot, and the diagnostic test data of the MIT and drawdown test performed on 2/13/15. 1 Well Name CD3-305 Notes: Start Date 11/23/2014 Days 90 End Date 2/21/2015 Annular Communication Surveillance 4500 _ 15 1NH P — 1E, 4000 — — 14 3E00 — 13 3000 — 12 2E00 f ~" I • uo — 11 a 2000 — 10 1E00 — 90 1000 '� _� - — . y — 80 500 - 70 0 I 60 Nov-14 Nov-14 Dec-14 Dec-14 ea14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 IAar-1E xc 7rcc— DGI IIAGI sac— P1M m crKtf_ 51M .Sac— BLPD =cc loon Nov-14 Nov-14 Dec-14 Dec-14 Dec-14 Jan-15 Jan-15 Jan-15 Feb-15 Feb-15 Feb-15 Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907) 659-7224 Pager (907)659-7000 pgr 909 From: NSK Problem Well Supv Sent: Tuesday, February 10, 2015 4:03 PM To: Wallace, Chris D (DOA) 2 Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: CD3-305 (PTD 208-193) Report of suspect IA pressure increase Chris, Alpine injector CD3-305 (PTD 208-193) has exhibited a suspect IA pressure increase. The well is to be shut in and freeze protected as soon as reasonably possible. Initial diagnostics to be performed will include an MIT-IA, pack off tests and an IA draw down test after which Slickline or Eline may be utilized if deemed necessary. CPAI will provide an email with the plan forward and submit any required paperwork upon the outcome of the diagnostics. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7126 « File: CD3-305 90 day TIO 2-10-15.JPG » 3 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, February 10, 2015 4:03 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: CD3-305 (PTD 208-193) Report of suspect IA pressure increase Attachments: CD3-305 90 day TIO 2-10-15.JPG Chris, Alpine injector CD3-305 (PTD 208-193) has exhibited a suspect IA pressure increase. The well is to be shut in and freeze protected as soon as reasonably possible. Initial diagnostics to be performed will include an MIT-IA, pack off tests and an IA draw down test after which Slickline or Eline may be utilized if deemed necessary. CPAI will provide an email with the plan forward and submit any required paperwork upon the outcome of the diagnostics. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Thank you, Jan Byrne/Dusty Freeborn SCANNED MAR 0 2 2015 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7126 - CHOKE FTP FIT IAP - CAP T!I!O Plot-CD3-305 3000 — FP 2000 1000 0 I 'l u u I + 1 1 1 1 I 1 1 1 1 11-Nov-14 24-Nov-14 07-Dec-14 20-Dec-14 02-Jan-15 15-Jan-15 28-Jan-15 Date 1 �;,+ ,Y.Yee,�,�:'r./".�._�.�gh'+itil + �#.`.�5`:. k•.Y ��t ayls�-' ,ow+ b .074-t.:7--:-;-------:;17:1z) i 4 !, -,�y _, 333 \��61 Seven'n fwen�e I2\i, \ i I 1 ! Anchorage A. ko. 99501 3572 TYnC-'-:797(—/-3.3 MJ Loveland �,E ® r, ' rL�l Well Integrity Project SCAR"' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 OS'..... I.c 3 Re: Colville River Field, Fiord Oil Pool, CD3-305 Sundry Number: 314-033 Dear Ms. Loveland: 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, IL1 P;;L,c4/1--.__ Cathy Foerster Chair DATED this 7 day of January, 2014. Encl. . STATE OF ALASKA :It S ,.-..+ f. i AL,_,KA OIL AND GAS CONSERVATION COMMISSION let APPLICATION FOR SUNDRY APPROVALS LA /`,'' ' `'' r I 20 AAC 25.280 0A-ss a�'N. 1.Type of Request: Abandon r Plug for Redrill E Perforate New Pool r Repair well r Change ApprAtI— "' Suspend r Plug Perforations r Perforate r Pull Tubing E Time Extension E Operational r Re-enter Susp. r Stimulate r Alter casing r Other:Conductor Extension F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Developmen r 208-193 3.Address: 6.API Number: Stratigraphi r Service F • P.O. Box 100360,Anchorage,Alaska 99510 50-103-20589-00 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes f No F. CD3-305 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0372104,0372103- Colville River Field/Fiord 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): 16859 • 6659 . Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3493 9.625 3530' 2467' INTERMEDIATE 15207 ' 7 15242' 6668' SLOTTED LINER 1672 4.5 16770' 6659' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 15492'-16723' 6670'-6658' 4.5 L-80 15105 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) INJ VLV-A-1 INJECTION VALVE(S/N:HACS-0026) MD=2303 TVD=1995 PACKER-BAKER PREMIER PACKER MD=14073 TVD=6307 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch r Exploratory r Stratigraphic r Development r Service F• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil E Gas r WDSPL r Suspended . F- 16.Verbal Approval: Date: WINJ r GINJ r WAG F• Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the t of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878Acop.com Printed Name ,e�MJ Loveland Title: --11V 1E Integrity Project Signature !" f _ Phone:659-7043 Date 1/11/14 �` Commission Use Only Sundry Number3\y,o33 Conditions of approval: Notify Commission so that a representative may witness JJ —1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS INAY 0 9 2014 Spacing Exception Required? Yes 0 No Subsequent Form Required: /D — 4 Q i. teyAPPROVED BY Approved by: P i7 COMMISSIONER THE COMMISSION •pproved appleiKG ni 1Ls from the dte of approval. Date: —//— Form 10-403(Revised 10/2012) AAIis l Submit Form and Attachments in Duplicate VLF /// / . , OfMe i INNS INJ CD3-305 ConocoPhillipst. Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) lmornP,cmpc 501032058900 FIORD KUPARUK INJ 92.92 15504.00 16,859.0 ••• _ ' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date HORIZONTAL-CD3-305,9/24/201310.1734 AM SSSV:WRDP Last WO: 41.48 2/7/2009 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:RESET INJECTION VLV osborl 9/24/2013 "MiliRER ...•••.•"••.••••••••.•.••HANGER;31.5""_ ........ Casing Strings Casing Description OD((e) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 37.0 114.0 114.0 62.50 H-40 Welded Imo- Insulated 34•" 1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade 'Top Thread LI SURFACE 95/8 8.835 36.8 3,529.8 2,467.3 40.00 L-80 BTCM Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtILen(I...Grade Top Thread INTERMEDIATE 7 6276 34.6 15,241.7 6,668.6 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top OMB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SLOTTED LINER 41/2 3.958 15,098.5 16,770.0 6,658.9 1260 L-80 SLHT II Liner Details [5 JI Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl(3 Item Des Corn (in) 15,098.5 6,650.9 81.32 HANGER BAKER FLEX LOCK HANGER ASSEMBLY 5.000 Tubing Strings CONDUCTOR Insulated7.0-340 • Tubing Description String Ma...IDI TopftKB Set Depth ft Set Depth(TVD)(...Wt lb/fl Grade TopConnection S 4.0 9 P tort 9l n) (ftKB) P ( ( ) TUBING 41/2 3.958 31.5 15,106.0 6,652.0 12.60 L-80 IBT-M I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.5 31.5 0.00 HANGER FMC TUBING HANGER 3.970 2,303.3 1,995.3 58.07 NIPPLE DB PROFILE NIPPLE 3.813 I 14,072.5 6,306.6 65.53 PACKER BAKER PREMIER PACKER 3.980 I INJ VLV;2,383,3 _ w` 14,176.7 6,349.7 65.61 NIPPLE HES XN NIPPLE 3.725 NIPPLE;2,303.3, -15,095.5 6,650.4 8126 LOCATOR BAKER FLUTED NO-GO SUB-ABOVE 8 BELOW ..^`-I 3.990 PROFILES 15,105.0 6,651.8 81.46 WLEG BAKER WIRELINE ENTRY GUIDE 3.970 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • Top(ND) Top Incl Top(ftKB) (ftKB) (3 Des Com Run Date ID(in) 2,303.3 1,995.3 58.07 INJ VLV A-1 INJECTION VALVE(S/N:HACS-0026) 2/1/2013 1.250 Perforations&Slots SURFACE;36.&3,529.8 a Shot Den Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 15,491.9 16,723.0 6,670.6 6,658.4 '2/42009 32.0 SLOTS SLOTTED LINER Mandrel Details • St I Ott C GAS LIFT;13,959.3 on Top(TVD) Valve Latch Port Size TRO Run _ Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date 1 13,959.3 6,260.1 CAMCO KBG-2- 1 INJ 'DMY BK 0.000 0.0 4/30/2009 1R Oki*:General&Safety End Date Annotation It 2/16/2009 NOTE:View Schematic w/Alaska Schematic9.0 ui PACKER;14,072.5 ,R„ I NIPPLE;14,176.7 II I LOCATOR;15,095.5 WLEG;15,105.0iii INTERMEDIATE;34.5.15.241.7— .. - SLOTS;15,491.9.16,723.0 — SLOTTED LINER;15.098.5- , 10.770,0 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 10,2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-305, PTD 208-193 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, jc MJ L eland Co coPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Alpine Well CD3-305 (PTD 208-193) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-305 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 8". With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor
