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Home My WebLink About200-0391. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert to Jet Pump Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5905'feet 5694'feet true vertical 4193' feet None feet Effective Depth measured 4891'feet 4885', 4932', 5007'feet true vertical 3216' feet 3211', 3252', 3319'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 4932' MD 3252' TVD Packers and SSSV (type, measured and true vertical depth) 4885' MD 4932' MD 5007' MD N/A 3211' TVD 3252' TVD 3319' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 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 GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5189' 3485' Burst Collapse Scab Liner Liner Gravel Pack 4856' 898' Casing 3217' 3.32" 4893' 5905' 5695' 4932' 5148' 121'Conductor Surface Intermediate 16" 7-5/8" 80' measured TVD 5-1/2" x 3-1/2" 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-039 50-029-22920-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-110A Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 100 Gas-Mcf MD 600 Size 121' 75 250050 75 17630 150 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 10 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker 91-40 F-1 Perm Packer Packer: SC-1 Gravel Pack Packer Packer: Baker ZXP Mech. Isolation Packer SSSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Senior Production Engineer 5363-5394', 5428-5496', 5519-5566', 5591-5671' 3652-3683', 3717-3785', 3808-3855', 3880-3960' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:27 am, Oct 10, 2023 DTTMSTART JOBTYP SUMMARYOPS 8/23/2023 REPAIR WELL DRIFT TBG TO TOP OF SLIPSTOP @ 4667' MD, PULL SLIPSTOP @ 4667' MD, ATTEMT TO BRUSH TOP OF K3 @ 4669' MD S/D HIGH, RUN 2.5" DRIVE DOWN BAILER, COME BACK WITH MINIMAL FILL AND METAL MARKS ON BOTTOM, RUN 2.313" BLB TO BRUSH TOP OF K3 @ 4669' MD, PULL K3 W/ 19' OF SPACER PIPE FROM 4687' MD, IN PROGRESS 8/24/2023 REPAIR WELL PULL BOTTOM K3 PACKOFF & COLLAR STOP FROM 4690' RKB, TAG FILL @ 4891' MD, DISPLACE IA WITH58 BBLS DSL CLOSE SLIDING SLEEVE @ 4674' RKB, CONDUCT PASSING MIT-IA. 3500 PSI GOOD TEST IN PROGRESS 9/20/2023 REPAIR WELL OPEN 2.81 CMU @ 4674' RKB, LRS PUMPED DOWN IA CONFIRMING CMU OPEN, SET 2.81 CS LOCK JET PUMP ROCK SCREEN SOFT SET & GAUGE (OAL 119.5" / PH-1058 8A RATIO @ 4674' RKB, SET 3 1/2 SLIP STOP ON LOCK @ SAME. PUMPED DOWN IA W/ LRS CONFIRMED JET PUMP WORKING. JOB COMPLETE. 1D-110A Convert to Jet Pump Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag: RKB 4,891.0 1D-110A 8/24/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Opened CMU, set SPJP and slipstop 1D-110A 9/20/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: DUMP BAILED 9' OF CACO3 ON PLUG @ 4916 RKB hipshkf NOTE: 5 1/2 SCAB LINER SPECIAL DRIFTED TO 15.5# (4.825" DRIFT) 3/5/2014 postojl NOTE: WORKOVER - 2014 1/29/2014 postojl NOTE: WORKOVER IN 2012 CONVERTED WELL FROM ESP TO GAS LIFT 6/10/2012 osborl NOTE: Surface Casing Patch Weld to 7" MD 8/30/2006 rmoore22 NOTE: WELL SIDETRACKED TO 'A'3/30/2000 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 22" Insulated 16 15.06 41.0 121.0 121.0 H-40 WELDED SURFACE Post WO 7 5/8 6.87 41.4 5,189.0 3,484.9 29.70 L-80 BTCM WINDOW 6 3/4 5,157.0 5,169.0 3,466.5 from 1D-110 SCAB LINER 5 1/2 x 3 1/2@4,833 - See Note 5 1/2 4.95 36.9 4,892.7 3,217.4 17.00 L-80 BTCM SCC LINER 5 1/2 4.95 5,007.1 5,905.0 15.50 L-80 BTCMOD LINER GRAVEL PACK 3.32 2.44 4,932.1 5,695.0 3,984.3 6.40 L-80 SLHT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.9 Set Depth 4,831.1 Set Depth 3,163.3 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM SCC ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.9 36.9 0.00 HANGER 10.813 VETCO GRAYTUBING HANGER VETO GRAY CWCT- F6H 3.500 4,674.7 3,028.5 31.69 SLEEVE-O 4.150 BAKER "CMU" SLIDING SLEEVE w/ fluted wire protector subs (Opened 09/20/2023) BAKER 2.812 4,720.0 3,067.2 31.02 XO Decreasing 3.500 3-1/2", 9.3#, L-80, IBT AB Modified Box x 2-7/8 EUE 8rd Pin Crossover 2.992 4,729.8 3,075.6 30.88 GUAGE 3.500 BAKER DOWNHOLE GAUGE CARRIER BAKER 2.440 4,808.7 3,143.8 29.58 XO - Increasing 3.500 2-7/8" EUE Box x 3-1/2" EUE Pin Crossover Sub 2.441 4,811.7 3,146.4 29.53 LOCATOR 4.500 BAKER GBH-22 LOCATOR SUB w/ft spaceout BAKER GBH-22 2.990 4,812.1 3,146.7 29.52 SEAL ASSY 3.750 BAKER 80-40 SEAL ASSY overall length 19' (7ft space out) BAKER 80-40 2.990 Top (ftKB) 4,885.4 Set Depth 4,932.0 Set Depth 3,252.2 String Max No 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,885.4 3,211.0 28.14 Packer 5.130 BAKER 91-40 F-1 PERMANENT PRODUCTION PACKER Baker F-1 Packer 4.000 4,888.0 3,213.2 28.09 SBE 5.250 BAKER 80-40 SEAL BORE EXTENSION Baker SBE 4.000 4,916.2 3,238.2 27.52 NIPPLE 4.500 CAMCO DS NIPPLE w/ PLUG & CATHER SUB Camco DS 2.810 4,917.2 3,239.1 27.50 SHOE 3.500 MULE SHOE 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,672.5 3,026.7 31.73 SLIP STOP Set 3.5" Slip stop on top of SPJP (OAL = 19") 9/20/2023 4,674.0 3,027.9 31.70 JET PUMP Set 2.81" CS lock, 3" SPJP (SN: PH-1058, 8A Ratio)(Ava Seals) with Rock screen and gauge below (OAL = 119,5") across CMU 9/20/2023 4,916.1 3,238.1 27.52 NIPPLE REDUCER 2.81" X 2.25" NIPPLE REDUCER @ 4916 12/15/2013 2.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,812.9 3,147.4 29.51 XO - Reducing 6.060 5-1/2", 17.0#, BTCM Box x 5" BTCM Box Crossover Coupling 4.500 4,833.0 3,165.0 29.13 XO - Reducing 5.030 5" BTCM Box x 3-1/2", 9.3#, L-80 IBT- Mod Pin Crossover 2.910 4,881.1 3,207.1 28.23 LOCATOR 4.500 BAKER GBH-22 LOCATOR SUB w/ 3.53-ft space out off bottom 2.992 4,932.1 3,252.4 27.20 Packer 6.690 SC-1 GRAVEL PACK PACKER; SIZE 76B2 OF SC1 PACKER 4.000 4,936.9 3,256.6 27.11 EXTENSION 5.540 80-40 UPPER EXTENSION 4.892 4,940.8 3,260.0 27.03 SLEEVE 5.800 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 4,944.8 3,263.6 26.95 EXTENSION 5.000 80-40 LOWER EXTENSION 4.387 1D-110A, 10/5/2023 4:51:11 PM Vertical schematic (actual) LINER; 5,007.1-5,905.0 LINER GRAVEL PACK; 4,932.1- 5,695.0 IPERF; 5,591.0-5,671.0 FRAC; 5,591.0 IPERF; 5,519.0-5,566.0 FRAC; 5,519.0 IPERF; 5,428.0-5,496.0 FRAC; 5,428.0 IPERF; 5,363.0-5,394.0 FRAC; 5,363.0 SURFACE Post WO; 41.4- 5,189.0 WINDOW; 5,157.0-5,169.0 NIPPLE; 4,916.2 NIPPLE REDUCER; 4,916.1 SCAB LINER 5 1/2 x 3 1/2@4,833 - See Note; 36.9- 4,892.7 Packer; 4,885.4 JET PUMP; 4,674.0 SLEEVE-O; 4,674.7 SLIP STOP; 4,672.5 CONDUCTOR 22" Insulated; 41.0-121.0 HANGER; 36.9 KUP PROD KB-Grd (ft) 111.60 RR Date 9/30/1998 Other Elev 1D-110A ... TD Act Btm (ftKB) 5,905.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292292001 Wellbore Status PROD Max Angle & MD Incl (°) 66.94 MD (ftKB) 2,685.04 WELLNAME WELLBORE Annotation Last WO: End Date 1/29/2014 H2S (ppm) 50 Date 8/12/2016 Comment SSSV: NONE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 4,960.8 3,277.9 26.63 SOS 4.940 9 ea.1/2" Ann. Steel shear screws / 80,640# 4.000 4,963.9 3,280.7 26.57 XO Reducing 5.000 CROSSOVER 4.5"x2.875" 2.441 5,694.6 3,983.9 2.91 PLUG 3.500 BAKER BULL PLUG 0.000 5,007.1 3,319.4 26.01 PACKER 7.875 BAKER ZXP MECHANICAL ISOLATION PACKER 5.500 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 5,363.0 5,394.0 3,652.4 3,683.4 WS C, 1D-110A 7/29/2000 8.0 IPERF 3-3/8" DP HSD, 41B 5,428.0 5,496.0 3,717.4 3,785.4 WS B, WS A4, 1D-110A 7/28/2000 8.0 IPERF 3-3/8" DP HSD, 41B 5,519.0 5,566.0 3,808.4 3,855.4 WS A3, 1D- 110A 7/26/2000 8.0 IPERF 3-3/8" DP HSD, 41B 5,591.0 5,671.0 3,880.4 3,960.4 WS A2, 1D- 110A 7/22/2000 8.0 IPERF 3-3/8" DP HSD, 41B Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 5,591.0 5,671.0 1 FRAC 7/23/2000 0.0 0.00 0.00 5,519.0 5,566.0 2 FRAC 7/26/2000 0.0 0.00 0.00 5,428.0 5,496.0 3 FRAC 7/28/2000 0.0 0.00 0.00 5,363.0 5,394.0 4 FRAC 7/30/2000 0.0 0.00 0.00 1D-110A, 10/5/2023 4:51:13 PM Vertical schematic (actual) LINER; 5,007.1-5,905.0 LINER GRAVEL PACK; 4,932.1- 5,695.0 IPERF; 5,591.0-5,671.0 FRAC; 5,591.0 IPERF; 5,519.0-5,566.0 FRAC; 5,519.0 IPERF; 5,428.0-5,496.0 FRAC; 5,428.0 IPERF; 5,363.0-5,394.0 FRAC; 5,363.0 SURFACE Post WO; 41.4- 5,189.0 WINDOW; 5,157.0-5,169.0 NIPPLE; 4,916.2 NIPPLE REDUCER; 4,916.1 SCAB LINER 5 1/2 x 3 1/2@4,833 - See Note; 36.9- 4,892.7 Packer; 4,885.4 JET PUMP; 4,674.0 SLEEVE-O; 4,674.7 SLIP STOP; 4,672.5 CONDUCTOR 22" Insulated; 41.0-121.0 HANGER; 36.9 KUP PROD 1D-110A ... WELLNAME WELLBORE 11/ era ( c�3' o , Regg, James B (DOA) From: NSK Prod Engr Specialist <n1139@conocophillips.com> Sent: Friday, February 26, 2016 4:11 PM Z*11 To: Regg,James B (DOA) Cc: NSK Fieldwide Operations Supt Subject: 1D AOGCC inspector deficiency reports response Attachments: 1D Deficiencies reports 02-26-16.pdf Jim—enclosed is ConocoPhillips response to the deficiencies noted by the AOGCC inspector during the 2/22/16 SVS testing on 1D pad. Please let me know if any further action is needed. Darrell Humphrey / Bob Christensen ConocoPhillips Alaska, Inc. Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager(907) 659-7000 (924) scow SEP 2 3 2.016 • O ‘10 ConocoPhillips Alaska AOGCC EXCEPTION REPORT Location: 1D Pad Date: 02/22116 AOGCC Inspector: Guy Cook Instructions:All exceptions listed below must be corrected within 7 days of receipt of this notification. Documentation of the work performed is to be entered Into the'Action Taken'section below. Note-Failure to comply with these instructions may constitute a violation of SOA regulations and may be subject to enforcement action under 20 AAC 25.535 EXCEPTIONS NOTED: 1D-02- Possible SSV bonnet seal leak. Choke stem leak, packing needs to be tightened or replaced. This 1D-10.-Choke stem leak, packing needs tightened or replaced. `'�\0A 1D-110-Choke stem leak, packing needs tightened or replaced. 1D-141 -SSV barrel leaking hydraulic fluid from plug Action Taken to Correct Problem: Date: 02/26/16 Initials: JRH 1D-02 choke has been inspected and rebuilt Date: 02/26/16 Initials: JRH 1D-10 choke has been inspected and rebuilt 1D-110 choke was visualy inspected. No apparent leaks. SnoopDate: 02/26/16 Initials: JRH tested the stem and actuated, then used snoop again. No leaks °� 1 D-141 SSV barrerl was serviced by the valve crew. No longer Date: 02/26/16 Initials: JRH leaking. Date: Initials: Date: Initials: Return completed form to Prod. Engr.Specialist: n 1139@conocophillios.com Distribution: CPF DSLT CPF OPS Supv Prod. Engr. Specialist C.C. CPF1&2 Ops Supt CPF3 Ops & DOT Pipelines Supt NSK Fieldwide Operations Supt S • • State of Alaska Oil and Gas Conservation Commission itZ :k Deficiency Report Location: 420.0414 )L /D Date: "2 2-1(0 PTD: 2(5 0 3960 Operator: rPs Type Inspection: 5 v S Operator Rep: a Ja K40 Inspector: GI �k_ Position: �--- / Jr V-5 Op. Phone: 6 9 _ 7 Z3-9 Correct by(date): 2, 2 4_ /G - Op. Email: Follow Up Req'd: Detailed Description of Deficiencies Date Corrected . /C_ 444 /z , necis .71-1yt ,lea © Operator Rep Signatures: � �'• AOGCC Inspector *After signing,a copy of this f--- -----4;:-=V) r is to be left with the operator. 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 taking longer than the"correct by"date must requested and accompanied by justification(Attention: Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 04/2015 • • yw\�or� iv„„ THE STATE Alaska Oil and Gas `` OfALASJ A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OA, Q. ALAS”- Anchorage Main:907 279 1433 Fax: 907.276.7542 Jonathan Coberly saws) Wells Engineer ConocoPhillips Alaska, Inc. ao , _ 031 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-110A Sundry Number: 313-612 Dear Mr. Coberly: 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, 46)// Daniel T. Seamount, Jr. Commissioner DATED this L2- day of December, 2013. Encl. • � RECEIVED•• STATE OF ALASKA •- • AL OIL AND GAS CONSERVATION COMMIOON ,„Y NOV 2 1 201 ' APPLICATION FOR SUNDRY APPROVALS ~ 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell p" • Change A ip oved ogram r Suspend r Rug Perforations r Perforate r Pull Tubing ors` . Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r `Other: ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development pw' 200-039 • 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22920-01 ' 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 r No ri • 1D-110A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 ' Kuparuk River Field/West Sak 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): 5905 4194 - 5777' - 4066' • 4916',5695' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' SURFACE 5148 7.625 5189' 3496' LINER 898 5.5 5905' 4194' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5363-5394,5428-5496,5519-5566,5591-5671 3664-3695,3729-3797,3820-3867,3892-3972 3.5 L-80 4932 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 91-40 F-1 PERMANENT PRODUCTION PACKER MD=4885 TVD=3211 • PACKER-SC-1 GRAVEL PACK PACKER MD=4932 TVD=3264 • PACKER-BAKER ZXP MECH.ISOLATION PACKER MD=5007 TVD=3331 - NO SSSV 12.Attachments: Description Summary of Proposal Fr. 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r Stratigraphic r Development (r°,• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/15/2014 Oil ry, • Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.Coberly @conocophillips.com Printed Name Jonat an Coberly / Title: Wells Engineer Signature G OJ Phone:265-1013 Date 1(- 20 -ZO/3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3t3 —601— Plug Integrity r BOP Test fr Mechanical Integrity Test r Location Clearance r Other: 1 p .F-es r .71-p 3 e,(2 c7r 5 1 Spacing Exception Required? Yes ❑ No [+/J Subsequent Form Required: /b 40 4• APPROVED BY I ,L� ,.� 1> Approved by:// COMMISSIONER �COMMISSIONER THE COMMISSION Date: I , Approved a li ti n is valid for 12 months from the ate of approval. Form 10-403(Revised 10/2012) � 'ply R II-II I Submit Form and Attachments in Duplicate ` �: DEC 13 Z01 • • RECEIVED Iv ConocoPhillips NOV 212Q13 Alaska AOGGO P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 19,2013 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 1D-110A(PTD 200-039). 1D-110 was spud and completed into the West Sak interval in 1998. Due to cement squeezing issues the wellbore was temporarily abandoned. In August 2000,it was sidetracked and re-named the 1D-110A. The well has had two previous rig workovers (2003 and 2012). The first rig workover repaired the ESP and returned the well to production. During the second rig workover to install a packer in the single casing well the casing failed to pass a pressure test. It was determined that the TAM port collar was leaking. Multiple attempts to squeeze and close the port collar were attempted without success. Before rigging down, a tubing string with a permanent packer was installed in the well. The 1D-110A has been shut in since the 2012 RWO. The well is expected to produce an average of 140 BOPD if brought back online. The well currently has corrosion inhibited 9.6 ppg NaCl in the tubing and IA. There is also a plug and catcher in the tubing tail of the packer completion. During May 2012 the ESP pressure gauge showed the SBHP to be 1,571 psi at a depth of 3,806' TVD meaning the required KWF is 8.2 ppg. However,the SBHP will be re-measured pre-rig so KWF can be calculated. In order to bring the well back online; a casing patch will be installed across the leakin_ sort collar and a tie back liner will be installed. A jet pump will be installed in the tubing post rig. If you have any questions or require any further information, please contact me at 265-1013 or Jonathan.Coberly @conocophillips.com. Sincerely, Jonathan Coberly Senior Wells Engineer CPAI Drilling&Wells • 1D-110A Rig Workover Install 5 1/2" Tie-back Liner and 3 1/2" Tubing (PTD #: 200-039) Current Status: West Sak well 1D-110A is a West Sak A,B,and C sand producer. The well is currently shut in due to a failed pressure test on the casing due to a leaking TAM port collar located during the previous rig workover. Scope of Work: Pull 3 V2" completion. Install 7 5/8" casing patch. Install 5 '/2" tie back liner. Install new 3 'A"jet pump completion General Well info: MASP: 1,190psi Reservoir pressure/TVD: West Sak— 1,571 psi/3,806' TVD(8.0 EMW)(ESP gauge May 2012) Updated SBHP planned during pre-rig. Wellhead type/pressure rating: Vetco Gray Horizontall5,000 psi Nordic 3 BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T: Passed to 1,500 psi on 6/11/2012(during RWO) The TAM port collar in the production casing at 998'RKB leaks. Well Type: Producer Estimated Start Date: January 15,2014 Production Engineers: Scott Stanley/Amanda Patterson Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly @conocophillips.com) Proposed Pre-Rig Work: 1. RU slickline. Pull catcher. Pull plug. Get updated SBHP. Set nipple reducer in`DS'nipple. Set plug in nipple reducer. MIT-T. Set catcher. RDMO slickline. 2. Set BPV. Pressure test packoffs. FTLDS. Proposed Procedure: 1. MIRU. Pull BPV. Circulate workover fluid. Set BPV. ND tree. Install blanking plug. 2. NU BOPE. Function test and_pressure test to 3,000 psi. Pull blanking plug. Pull BPV. 3. Circulate and POOH laying down completion. MU storm packer with tubing below. Set storm packer. POOH with setting equipment. ND BOPE. ND tubing head. Install pac of£ NU new casing head and tubing head. PT packoffs. NU BOPE. Shell test BOPE,casing head,and tubing head to 3,000 psi. RIH and release storm packer. POOH with storm packer and tubing. 4. MU casing patch system. RIH and set patch across leaking port collar. POOH. Pressure test patch. 5. MU tie-back liner and RIH. Engage seal locator in SBE. Space out. Swap out the IA to corrosion inhibited seawater followed by freeze protect. Land liner. RILDS. 6. PT the liner. Drawdown the liner. PT the new OA. Drawdown the new OA. 7. PU and RIH with new completion tubing. Space out completion. Swap the new IA to corrosion inhibited seawater followed by freeze protect. Land the tubing hanger. RILDS. 8. PT the tubing. PT the new IA. Bleed IA and tubing. 9. Monitor well. Set TWC. PT TWC. ND BOPE. NU new tree. PT tree and packoffs. Pull TWC. 10. Equalize T and IA to swap freeze protect. Set BPV. RDMO. Proposed Post-Rig Work: 1. Pull BPV 2. Run jet pump 3. Pull catcher and plug 4. Reset the well houses and flow lines. 5. Turn well over to Operations. • • ConocoPhillips Well: 1D-110A 2014 RWO PROPOSED COMPLETION API: 500292292001 Conductor: PTD: 200-039 16", H-40 to 121' MD Wellhead: Vetco Gray DS Surface/Production Casing: 5,000 psi 7.625", 29.7#, L-80 to 5,189' MD Perforations: MD Zone Proposed 3-1/2" Completion 53635428''-53945496'' WS C - WS B • 3-1/2"Vetco Gray Mandrel Hanger 5519'-5566' WS A3 • 3-1/2",9.3#, L-80, IBTM SCC 5591'-5671' WS A2 • 2.875" ID'DS' Nipple • CMU w/2.813" ID'X' Profile. 2.875"'DS'Nipple(-500'RKB) • 80-40 GBH-22 Seal Assembly —7.625"MetalSkin Casing Patch("'998'RKB) cmu 4—Baker CMU Sliding Sleeve w/2.183"ID'X'Nipple Proposed 5-1/2"Tie-Back Liner • 5-1/2"Vetco Gray Mandrel Hanger • 5-1/2", 15.5#, L-80, BTCM SCC 11■04 ♦_20'Baker 80-40 GBH-22 Locator Seal Assembly 20'Baker 80-40 SBE(4.000"ID) • 80-40 Seal Bore Extension • 80-40 GBH-22 Seal Assembly 4 E 4-Baker 91-40 F-1 Permanent Production Packer V r■►l Directional: ;■; 10'Baker 80-40 GBH 22 Locator Seal Assembly Max Incline: 66.9° @ 2696' 10'Baker 80-40 Seal Bore Extension(4.000"ID) Max Dogleg: 7.8° @ 1016' 4—2.81"'DS'Nipple w/2.25"Nipple Reducer Installed 4—Mule Shoe f—SC-1 Gravel Pack Packer w/Lateral and Gravel Pack Completion (Detail on Well View Schematic) Last Updated: 18-Nov-13 X Updated by: J. Coberly c TD: 5,905' RKB a , i KUP 1D-110A • ConocoPhillips a Well Attributes Max Angle&MD TD Alaska 111(: Wellbore API/UWI Field Name Well Status Ind(") MD(ftKB) Act BSc(ftKB) R„44.4.Yslaps 500292292001 WEST SAK PROD 66.94 2,685.04 5,905.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -- SSSV:NONE 5 8/7/2009 Last WO: 6/10/2012 111.60 9/30/1998 Well Confg -1D-110A 62520129'04:45 AM Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,959.0 5/25/2012 Rev Reason:WELL REVIEW osborl 6/25/2012 Casing Strings HANGER,37 Casing Description String O String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String String Top Thrd CONDUCTOR 22" 16 15.062 41.0 121.0 121.0 H-40 WELDED Insulated Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE Post WO 75/8 6.875 41.4 5,189.0 3,496.1 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd WINDOW 63/4 5,157.0 5,169.0 3,477.7 from 1D-110 ill ar 1 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd LINER 51/2 4.950 5,007.1 5,905.0 15.50 L-80 BTCMOD Liner Details Top Depth 22'Insulated, Jt (TVD) Top Teel Nomi... 41-121 Top(ftKB) (((KB) I°) hem Description Comment ID(in) 5,007.1 3,330.9 26.48 PACKER BAKER ZXP MECHANICAL ISOLATION PACKER 5.500 5,021.7 3,343.9 26.17 HANGER BAKER'HMC'HYDRAULIC LINER HANGER 5.500 .' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd y- LINER GRAVEL 3.32 2.441 4,932.1 5,695.0 3,995.4 6.40 L-80 SLHT !L PACK GAS LIFT, - y ails 2,679 w Top Depth (TVD) Top eel Nemi... Top(ftKB) (ftKB) 1°) Item Description' Comment ID(in) 4,932.1 3,263.6 27.20 PACKER SC-1 GRAVEL PACK PACKER;SIZE 7662 OF SC1 PACKER 4.000 - 4,936.9 3,267.8 27.11 EXTENSION 80-40 UPPER EXTENSION 4.892 -- 4,940.8 3,271.2 27.03 SLEEVE 80-40 GRAVEL PACK SLIDING SLEEVE 4.700 GAS LIFT, - - 4,829 4,943.3 3,273.5 26.98 SBE 80-40 SEAL BORE 4.000 ii 4,944.8 3,274.8 26.95 EXTENSION 80-40 LOWER EXTENSION 4.387 4,960.8 3,289.0 26.63 SOS 9 ea.1/2"Ann.Steel shear screws/80,640# 4.000 _ 4,963.9 3,291.8 26.57 XO Reducing CROSSOVER 4.5"x2.875" 2.441 illi 5,321.2 3,621.9 5.88 SCREENS Bakerweld 2-7/8"x.20 gauge x 37-ft w/37-ft wraped on 2-7/8",6.4#, 2.441 SEAL ASSY, L-80 base pipe w/weld on blade type centralizers(4.375"OD)at middle 4883 and pin end w/2-7/8"SLHT B x P.(10 jts)WELL PERF'D PRIOR TO PACKER 4 885 GRAVEL PACK SCREEN SET SHE 4,885 5,694.6 3,995.0 2.91 PLUG BAKER BULL PLUG 0.000 Tubing Strings Tubing Description String 0... String ID. Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd It TUBING WO 31/2 2.992 36.9 4,932.0 3,263.5 9.30 L-80 EUE-MOD Completion Details Top Depth PLUG,6,91fi (TVD) Topincl Nomi... NIPPLE,4,916 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) SHOE,4,917 36.9 36.9 -1.43 HANGER VETCO TUBING HANGER 3.500 4,882.6 3,219.6 28.19 SEAL ASSY BAKER 80-40 GBH-22 BONDED SEAL ASSEMBLY 2.850 4,885.4 3,222.1 28.14 PACKER BAKER 91-40 F-1 PERMANENT PRODUCTION PACKER 4.000 4,888.0 3,224.4 28.09 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 4,916.2 3,249.5 27.52 NIPPLE CAMCO DS NIPPLE w/PLUG&CATHER SUB 2.810 WI 4,917.2 3,250.41 27.50 SHOE MULE SHOE 2.992 Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Or Top Depth (TVD) Topincl Top(ftKB) (ttK8) (°) Description Comment Run Date ID(in) t? 4,916.2 3,249.5 27.52 PLUG 2.81"CA-2 PLUG 6/10/2012 0.000 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (nh.. Type - Comment ' 5,363.0 5,394.0 3,663.6 3,694.6 WS C,1D-110A 7/29/2000 8.0 IPERF 33/8"DP HSD,41B 5,428.0 5,496.01 3,728.6 3,796.6 WS B,WS A4, 7282000 8.0 IPERF 3-3/8"DP HSD,41B ,° „ 1D-110A 5,519.0 5,566.0 3,819.5 3,866.5 WS A3,1D-110A 7/26/2000 8.0 IPERF 3-3/8"DP HSD,41B 5,591.0 5,671.0 3,891.5 3,971.5 WS A2,1D-110A 7/22/2000 8.0 IPERF 3-3/8"DP HSD,41B WINDOW. 5,157,5,169 Stimulations&Treatments SURFACE Post Bottom WO,41-5,199 Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 5,363.0 5,394.0 3,663.6 3,694.6 FRAC 7/30/2000 147 M lbs of 14/18 placed in D sand IPERF, 5,428.0 5,496.0 3,728.6 3,796.6 FRAC 7/28/2000 133 M lbs of 14/18 placed in A4 sand 5,363-5.394 �e�{ 5,519.0 5,566.0 3,819.5 3,866.5 FRAC 7/26/2000 141 M lbs of 14/18 placed in AS sand FRAC 5,363 3,891.5 3,971.5 FRAC 7/23/2000 167 M lbs of 14/18 placed in A2 sand Notes:General 5,591.0 5 671 ,��I &Safety IPERF, End Date Annotation 5 AC.428-5,496 FRAC spze - 3/30/2000 NOTE:WELL SIDETRACKED TO'A' 10/26/2003 NOTE:ESP WORKOVER 5 619-5 s56e 8/30/2006 NOTE:Surface Casing Patch Weld to 7'MD FRAC,5,519 __ t 8/8/2010 NOTE:View Schematic w/Alaska Schematic9.0REV IPERF, - I 6/10/2012 NOTE:WORKOVER IN 2012 CONVERTED WELL FROM ESP TO GAS LIFT 5,591 FRAC,RAC,5,671 - LINER 5 GRAVEL ''` Mandrel Details PACK Top Depth Top Port 4,932-5,695 (ND) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sera Typo Type (in) (psi) Run Date Com... LINER, 1 2,679.3 1,824.4 67.09 CAMCO KBMM 1 GAS LIFT SOV BK-5 0.000 0.0 6/10/2012 TD(ID-110A), 1 2 4,829.1 3,172.8 29.27 CAMCO KBMM 1 GAS LIFT DMY BK-5 0.000 0.0 6/10/2012 5,905 STATE OF ALASKA ALAt OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell 17 Plug Ferforations r Perforate r Other E Alter Casing J Fill Tubing '" Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n 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 p- Exploratory r " 200 -039 3. Address: 6. API Number: Stratigraphic r Service 50- 029 - 22920 -01 ®Q P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number:,. ADL 25650 G 1D-110A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5905 feet Plugs (measured) 4916', 5695' true vertical 4194 feet Junk (measured) None Effective Depth measured 5777' feet Packer (measured) 4885', 4932', 5007' true vertical 4066' feet (true vertucal) 3222', 3264', 3331' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 5148 7.625 5189 3496 LINER 898 5.5 5905 4194' RECEI VED JUL 0 5 2012 Perforation depth: Measured depth: 5363'- 5394', 5428'- 5496', 5519'- 5566', 5591' -5671' AOGC True Vertical Depth: 3664'- 3695', 3729'- 3797', 3820'- 3867', 3892' -3972' Tubing (size, grade, MD, and TVD) 3.5, L - 80, 4932 MD, 3264 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PERMANENT PRODUCTION PACKER - ileff "106 and 3222' TVD PACKER - SC -1 GRAVEL PACK PACKER @ 4932' MD and 3264' TVD PACKER - BAKER ZXP MECHANICAL ISOLATION PACKER @ 5007' MD and 3331' TVD NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable MAR 0 4 2013 Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development wi . Service r Stratigraphic r 16. Well Status after work: r Oil r Gas r VVDSPL Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -202 Contact Erik Nelson 263 -4693 Printed Name Erik Nel .n Title Senior Wells Engineer Signature / Phone: 263 -4693 Date u ,. ?e/2 /� � l - �' �'� mit Original Only Form 10 -404 Revised 1 S JUL 05 2012 l �� Z �' ■ • • s KUP 1D-110A ConocoPhif ips S Well Attributes Max Angle & MD TD Alaska Inc Wellbore API/DWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) c000coPhillips 500292292001 WEST SAK PROD 66.94 2,685.04 5,905.0 °" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NONE 5 8/7/2009 Last WO: 6/10/2012 111.60 9/30/1998 Well Conlin: - 1D-110A, 6/25/2012 9:04:45 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: 4,959.0 5/25/2012 Rev Reason: WELL REVIEW osborl 6/25/2012 HANGER, 37 _ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd - - -- - CONDUCTOR 22" 16 15.062 41.0 121.0 121.0 H- 40 WELDED _ Insulated Casing Description Suing 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE Post WO 7 5/8 6.875 41.4 5,189.0 3,496.1 29.70 L - 80 BTCM ® Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String WL.. String ... String Top Thrd WINDOW 63/4 5,157.0 5,169.0 3,477.7 from 1D - 110 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 51/2 4.950 5,007.1 5,905.0 15.50 L -80 BTCMOD Liner Details mow Top Depth 22" Insulated, _ (TVD) Top Inc! Nomi... 41 - 121 Top (ftKB) (ftKB) (°) Item Description Comment ID (In) 5,007.1 3,330.9 26.48 PACKER BAKER ZXP MECHANICAL ISOLATION PACKER 5.500 5,021.7 3,343.9 26.17 HANGER BAKER 'HMC' HYDRAULIC LINER HANGER 5.500 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd -I LINER GRAVEL 3.32 2.441 4,932.1 5,695.0 3,995.4 6.40 L - 80 SLHT PACK GAS LIFT, Liner Details 2,679 Top Depth (TVD) Top Inc/ Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 4,932.1 3,263.6 27.20 PACKER SC -1 GRAVEL PACK PACKER; SIZE 76B2 OF SC1 PACKER 4.000 4,936.9 3,267.8 27.11 EXTENSION 80 -40 UPPER EXTENSION 4.892 4,940.8 3,271.2 27.03 SLEEVE 80.40 GRAVEL PACK SLIDING SLEEVE 4.700 GAS LIFT, 2 4,943.3 3,273.5 26.98 SBE 80-40 SEAL BORE 4.000 4,944.8 3,274.8 26.95 EXTENSION 80 -40 LOWER EXTENSION 4.387 4,960.8 3,289.0 26.63 SOS 9 ea.1 /2" Ann. Steel shear screws / 80,640# 4.000 4,963.9 3,291.8 26.57 XO Reducing CROSSOVER 4.5 "x2.875" 2.441 5,321.2 3,621.9 5.88 SCREENS Bakerweld 2 -7/8" x .20 gauge x 37 -ft w/ 37 -ft wraped on 2 -7/8 ", 6.4 #, 2.441 SEAL ASSY, L -80 base pipe wl weld on blade type centralizers (4.375" OD) at middle 4,883 and pin end w/ 2 -7/8" SLHT B x P. (10 jts) WELL PERF'D PRIOR TO PACKER, 4,885 GRAVEL PACK SCREEN SET SBE,4,888 5,694.6 3,995.0 2.91 PLUG BAKER BULL PLUG 0.000 ' Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING WO 3 1/2 2.992 36.9 4,932.0 3,263.5 9.30 L -80 EUE -MOD Completion Details Top Depth PLUG, 4,916 NIPPLE, 4,918 (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) SHOE, 4,917 36.9 36.9 -1.43 HANGER VETCO TUBING HANGER 3.500 _,", -. 4,882.6 3,219.6 28.19 SEAL ASSY BAKER 80 -40 GBH -22 BONDED SEAL ASSEMBLY 2.850 4,885.4 3,222.1 28.14 PACKER BAKER 91 -40 F -1 PERMANENT PRODUCTION PACKER 4.000 .c 4,888.0 3,224.4 28.09 SBE BAKER 80 -40 SEAL BORE EXTENSION 4.000 4,916.2 3,249.5 27.52 NIPPLE CAMCO DS NIPPLE wl PLUG & CATHER SUB 2.810 4,917.2 3,250.4 27.50 SHOE MULE SHOE 2 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth annew r ' (ND) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) GNI. ' 4,916.2 3,249.5 27.52 PLUG 2.81" CA -2 PLUG 6/10/2012 0.000 Perforations & Slots Shot Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment ' " ' 5,363.0 5,394.0 3,663.6 3,694.6 WS C, 1D-110A 7/29/2000 8.0 IPERF 3 -3/8" DP HSD, 41B I I 5,428.0 5,496.0 3,728.6 3,796.6 WS B, WS A4, 7/28/2000 8.0 IPERF 3 -3/8" DP HSD, 41 B . .1 1D -110A 5,519.0 5,566.0 3,819.5 3,866.5 WS A3, 1D -110A 7/26/2000 8.0 IPERF 3 -3/8" DP HSD, 41B 5,591.0 5,671.0 3,891.5 3,971.5 WS A2, 1D -110A 7/22/2000 8.0 IPERF 3 -3/8" DP HSD, 41B WINDOW, 5,157-5,169 Stimulations & Treatments SURFACE Post I Bottom WO, 41 -5,189 Min Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 5,363.0 5,394.0 3,663.6 3,694.6 FRAC 7/30/2000 147 M lbs of 14/18 placed in D sand IPERF, 5,428.0 5,496.0 3,728.6 3,796.6 FRAC 7/28/2000 133 M lbs of 14/18 placed in A4 sand 5,363 -5,394 - 5,519.0 5,566.0 3,819.5 3,866.5 FRAC 7/26/2000 141 M lbs of 14/18 placed in A3 sand FRAC, 5,363 - 5,591.01 5,671.01 3,891.5 3,971.51FRAC 7/23/2000 1167 M lbs of 14/18 placed in A2 sand Notes: General & Safety IPERF, ' f D' End Date Annotation 5,428.5,498 FRAC, 5,428 = =- 3/30/2000 NOTE: WELL SIDETRACKED TO 'A' 5,588 10/26/2003 NOTE: ESP WORKOVER g IPERF, �' 8/30/2006 NOTE: Surface Casing Patch Weld to 7' MD FRAC, 5,519 kYYY'ttttllll 8/8/2010 NOTE View Schematic wl Alaska Schematic9.0REV PERF, 6/10/2012 NOTE: WORKOVER IN 2012 CONVERTED WELL FROM ESP TO GAS LIFT 5 FRAC, 5,591 ,591 -5,671 \____Ii ' LINER " - 1 �fl GRAVEL Mandrel Details 5 Top Depth Top Port 4,932-5,695 (ND) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... LINER, 1 2,679.3 1,824.4 67.09 CAMCO KBMM 1 GAS LIFT SOV BK -5 0.000 0.0 6/10/2012 TD 5, - 110 ), 2 4,829.1 3,172.8 29.27 CAMCO KBMM 1 GAS LIFT DMY BK -5 0.000 0.0 6/10/2012 5,905 • DATE SUMMARY 1D-110A Pre Rig Well Work • 2/12/12 BAIL FILL ON SLIPSTOP @ 4839' RKB, ATTEMPT TO PULL SLIPSTOP, , IN PROGRESS 2/13/12 BAILED FILL ON SLIPSTOP @! 4798' SLM, PULLED SLIPSTOP @ 4798' SLM, REPLACED SOV @ 4782' RKB, TESTED D &D PACKOFF ASSY' @ 4799' SLM TO 1250 PSI,; GOOD, PULLED TEST TOOL, IN PROGRESS. 2/14/12 SET SLIPSTOP ON PACKOFF ASSY' @ 4797' SLM, ATTEMPT TO START ESP, DID NOT WORK, PULLED 3 1/2 SLIPSTOP & 3 1/2 PACKOFF ASSY' @ 4797' SLM, IN PROGRESS. 2/15/12 PULLED 36' 3.5" PCP ESP PUMP @ 4805' SLM ( PACKED FULL OF SAND), RAN NEW 33 - PCP ESP ( 35.58'OAL) SET @ 4805' SLM, SET 3.5 D &D PACKOFF ASSY'w /STINGER @ 4805' SLM, RAN PACKOFF TEST TOOL TO 4797' SLM, TESTED PACKOFF 1100 PSI, GOOD, PULLED TOOL, RAN 3.5 SLIPSTOP TO 4797' SLM, COMPLETE. 2/25/12 PRE RWO T -POT BONNET( PASSED ), T -PPPOT BONNET ( PASSED ), T -POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GRAYLOC PPT ( PASSED ), FT -LDS ALL NORMAL. 4/23/12 IA FL @ 100' 5/3/12 BAILED SAND FROM 4752' TO 4780' SLM. IN PROGRESS. 5/4/12 BAILED SAND FROM 4780' TO 4795' SLM. PULLED 3 1/2" SLIP STOP FROM 4839' RKB. IN PROGRESS. 5/5/12 BAILED SAND FROM TOP OF PACKOFF. PULLED 3 1/2" PACKOFF FROM 4840' RKB. IN PROGRESS. 5/9/12 CLEARED SAND FROM TOP OF ESP. PULLED SHEARED SOV FROM 4782' RKB, REPLACED W/ DV. UNSEATED 35.6' x 3 1/2" PCESP @ 4847' RKB. IN PROGRESS. 5/10/12 PULLED 35.6' x 3 1/2" PCESP FROM 4847' RKB. COMPLETE. Note: Tbg and IA displaced w/ diesel as per procedure. • • ConocoPhiilips Time Log & Summary Wel!view Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/22/2012 4:30:00 PM Rig Release: 6/12/2012 2:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/22/2012 24 hr Summary Completed Well 1D -133 Program. RDMO. MIRU at Well Slot 1D -110. PJSM. Pull BPV. Kill Well. Install BPV. ND Tree. Install Blanking Plug. Begin NU of BOP Stack w/ STA and Dutch Riser. 15:00 16:30 1.50 MIRU MOVE MOB P Move Nordic Rig 3 from 1 D -133 to 1D-110. Set down and berm up. Spot auxiliary equipment. Start loading pits w/ 8.5 ppg KWF. Rig accepted at 16:30 on 05/22/2012 16:30 17:30 1.00 MIRU WELCTL MPSP P Lubricate out BPV - Initial Pressures T /IA= 180/180 psi. Complete hardline Rig up. 17:30 18:45 1.25 MIRU WELCTL PRTS P Pressure test hardline 250/3000 psi. Complete loading pits w/ KWF. Rig on High Line at 18:00 hrs 18:45 19:00 0.25 MIRU WELCTL SFTY P PJSM- Job scope and circulating procedures and hazards. Notify DSO and Security of gas venting operations. 19:00 20:30 1.50 MIRU WELCTL CIRC P Reverse in at 4.0 bpm, ICP 270 psi. with Hot Filtered 3% KCL Fresh Water to recover the Diesel Freeze Protect in the Tubing and to "wash" the ESP /HT Cable. Pumped 290 bbls, FCP 290 psi. 8.5 ppg KWF to surface. well on vac. 1:1 returns. 20:30 21:00 0.50 MIRU WELCTL OWFF P Monitor well for flow, well on light vac. 21:00 21:45 0.75 MIRU WHDBO MPSP P Set BPV. RD circulating lines. 21:45 23:00 1.25 MIRU WHDBO NUND P PJSM- Nipple down Tree. Inspect threads, good. Install blanking plug. 23:00 00:00 1.00 MIRU WHDBO NUND P PJSM- Nipple Up 11" 5M Hydrill Triple Gate BOPE w/ STA and Dutch Riser. 05/23/2012 Complete NU of BOP Stack w/ STA and Dutch Riser. Perform Initial BOPE Test. Pull Blanking Plug and BPV. Install Side Port Isolation Sleeve. Circulate Well. Pull Tbg Hanger to Rig floor. Prep to pull Completion. Single down the 3 -1/2" ESP /HT Completion. RIH with the Clean -out String. 00:00 01:30 1.50 MIRU WHDBO NUND P Complete Nipple Up of 11" 5M Hydrill Triple Gate BOPE w/ STA and Dutch Riser. Fill stack. Rig up lines. Page 1 of 24 • • Time Logs Date From To Dur S. Depth E. Depth .Phase Code Subcode T Comment 01:30 05:00 3.50 MIRU WHDBO BOPE P PJSM. Preform shell test. Start Initial BOP Test. Function & PT rams, choke manifold and annular w/ 3 -12" test joint to 250/3000 psi. Koomy draw down, Start 3000 psi, End 1,900 psi, 200 psi recovery 17 seconds, full recovery 95 seconds. RD test equipment States right to witness initial BOPE test waived by AOGCC field rep. John Crisp at 02:05 on 05/23/2012, 05:00 06:00 1.00 COMPZ WHDBO MPSP P - PJSM w/ Vetco -Gray and Nordic 3 crews. Pull blanking plug and BPV. Monitor well. Install Side Port Isolation sleeve and RU circ lines. 06:00 07:30 1.50 COMPZ WELCTL CIRC P Reverse in at 5.0 bpm, ICP 400 psi. with Hot Filtered 3% KCL Fresh Water, Pumped 220 bbls, FCP 480 psi. 8.5 ppg KWF to surface. 07:30 08:00 0.50 0 0 COMPZ WELCTL OWFF P Monitor well 30 minutes, on vac. 08:00 09:00 1.00 4,908 4,908 COMPZ WELCTLTHGR P MU Landing joint. BOLDS. Un land tubing hanger, pulled free at 90k. pull hanger to floor. fill IA with 1 bbl and leak at side port isolation sleeve developed, light (diesel) on tubing side. Reland tubing hanger. 09:00 10:30 1.50 4,908 4,908 COMPZ WELCTL CIRC P Circulate down tubing w/ returns up IA 5 bpm, ICP 480 psi at 1 -1/2 hole volumes, FCP 520 psi 10:30 11:00 0.50 4,908 4,908 COMPZ WELCTL OWFF P Monitor well 30 minutes, on vac. 11:00 12:30 1.50 4,908 4,880 COMPZ RPCOM THGR P POOH laying down TBG hanger and pup joint. 12:30 20:30 8.00 4,880 0 COMPZ RPCOM PULL P PJSM- POOH from 4 -ft w/ 6 joints and string ESP cable over sheaves. Continue to POOH laying down decompletion, kicking out as needed. Inspect, secure and box seals and motor. 20:30 22:00 1.50 0 0 COMPZ RPCOM OTHR P Clean and Clear floors. Off Load de- completion. Change over floors. Set wear bushing Clamps Recovered from De- completion; 2ea. SS flat Bands. 2ea. Amsterguards 35ea. Single chan X -coupl clamps. 77ea. Dual chan X -coupl clamps. (95) 5ea. 3' Dual chan clamps. 5ea. 4' Dual chan clamps. 446ea. 5' Dual chan clamps. (477) 22:00 23:00 1.00 0 34 COMPZ WELLPF PULD P PJSM- MU Clean out / Scraper BHA - 6-3/4" Bit, 7 -5/8" Csg Scraper, Bit Sub, Bumper Sub, and Oil Jars 23:00 00:00 1.00 34 3,225 COMPZ WELLPF TRIP P RIH w/ BHA #1 on 3.5" DP tp 3,225-ft. Page 2 of 24 • i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/24/2012 24 hr Summary RIH with the Clean -out String. Reverse Circulate Well. POOH. RIH with Retrievable Bridge Plug. Fished RBP from Csg Head. RIH w/ RCJB. POOH. 00:00 02:00 2.00 3,225 4,938 COMPZ WELLPF TRIP P Continue to RIH w/ BHA #1 on 3.5" DP from 3,225 -ft, sat down 5K at 4,938 -ft, PUH and wash down 4 bpm at 320 psi, sat down lightly at 4,938 -ft. PUH to 4,930 -ft, Reverse out 120 bbls 4 bpm at 230 psi, clean returns. Found historic BOT drawing in past WO folder of Screen assembly. Confer with town • engineer. appears top of gravel pack SC -1 packer at 4,938 -ft. 02:00 02:30 0.50 4,938 4,940 COMPZ WELLPF OTHR P PJSM- POOH 1 stand and BDTD. 02:30 06:00 3.50 4,940 0 COMPZ WELLPF TRIP P TOOH with Clean Out / Scraper BHA #1, Lay Down same. 06:00 07:00 1.00 0 35 COMPZ WELLPF PULD P PU and MU Test packer assy and RIH to 35 -ft and RBP hung up in the 7 5/8 Vetco Gray Fluted hanger, attempt to release - unsuccessful 07:00 15:30 8.50 35 35 COMPZ WELLPF OTHR T Attempt to release RBP, seen travel of mandrel wickers but the lower up slips wouldn't release from the mandrel, Replacement Baker G plug and Vetco Gray fluted hanger arrived on location, gather measements while continuing motions to release RBP. 15:30 17:30 2.00 35 35 COMPZ WELLPF OTHR T Release Model "L" retrieving tool and call out 5 3/4" Short Catch overshot. Fishing tools arrived on location at 17:00 hrs. Load tools on rig. 17:30 18:15 0.75 35 35 COMPZ FISH OTHR T PJSM- MU BHA #3- Short Reach Over shot w/ 2.0" basket grapple, Bumper Sub, Surface Jars, 2 ea 4 -3/4" DC's 18:15 20:00 1.75 35 0 COMPZ FISH FISH T RIH and set down at 22.5 -ft (top of RBP) Pick up easy w/ Fish, no over pull. 1 complete and 1/4 of 2nd slip missing from RBP. Bring in Baker tools. 20:00 23:15 3.25 0 4,938 COMPZ FISH FISH T PJSM- MU BHA #4, RCJB w/ 6 -3/4" shoe and RIH to 4,930 -ft, establish circ rates, drop ball, Hook up to top drive, bring on pumps 9 bpm at 2700 psi, tag up lighly on SC -1 Packer at 4,938-ft. 23:15 00:00 0.75 4,938 4,875 COMPZ FISH FISH T PUH 1 stand, BDTD, Monitor well, slight vac. 05/25/2012 Continue to POOH with RCJB, recovered small piece of slip. RIH and Set Retrievable Bridge Plug. Test Casing. Release RBP. Circulate Well. TOOH with Pkr and RBP. RU S -line. Drift G.P. Screen w/ Magnet for lost slip, no recovery. RD S -line. Rig up to handle the Completion. MU ESP Motor and Seals. Page 3 of 24 • • Time Logs Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 4,875 0 COMPZ FISH FISH T POOH from 4,875 -ft standing back DP, recovered end piece of slip lost (2.25" x 1" x 7/8 ") LD BHA #4. confer with town engineer. 02:30 03:00 0.50 0 39 COMPZ WELLPF PULD P Mike up Baker Model ".C" Retrievable Bridge Plug and the Baker Retrievamatic Packer. 03:00 05:30 2.50 39 4,908 COMPZ WELLPF MPSP P TIH with Test Packer assembly to 4,908 -ft Up Wt 95k / Dn Wt 70k, set center element at 4,900' RKB. PUH and LD working joint. 05:30 06:30 1.00 4,908 4,875 COMPZ WELLPF PRTS P RU Testing Equipment. Pressure test 7 5/8" Casing to 1500 psi x 30 _minutes and Record on pressure chart. Good Test. RD test lines. 06:30 07:00 0.50 4,875 4,908 COMPZ WELLPF MPSP P RIH and retrieve RBP. 07:00 08:30 1.50 4,908 4,908 COMPZ WELLPFCIRC P Line Up Mud pump and Reverse circulate 1.5 DP Volumes and condition well at 2 bpm, 80 psi. 08:30 09:00 0.50 4,908 4,908 COMPZ WELLPF OWFF P Monitor well for flow on trip tank - well taking fluid 09:00 10:45 1.75 4,908 1,788 COMPZ WELLPF PULD P POOH with Test packer assy laying down 3 1/2 DP from 4,908 -ft to 1,788 -ft 10:45 11:00 0.25 1,788 1,788 COMPZ WELLPF SFTY P Held PJSM with rig crew and crane personel for critical lift of ESP spool swap. 11:00 12:00 1.00 1,788 1,788 COMPZ WELLPF OTHR P Conduct critical lift of Heat Trace decompletion and ESP cable spool swap. 12:00 13:30 1.50 1,788 0 COMPZ WELLPF PULD P Continue to POOH laying down 3 1/2 DP from 1,788 -ft to test packer assy and lay down same. 13:30 14:00 0.50 0 1,755 COMPZ WELLPF TRIP P RIH w/ 3 1/2 DP from Derrick to 1,755 -ft 14:00 15:30 1.50 1,755 0 COMPZ WELLPF PULD P POOH with laying down 3 1/2 DP from 1,755 -ft to Surface. 15:30 16:30 1.00 COMPZ WELLPF OTHR P Change over floor and setup for running TBG. Pull wear bushing. 16:30 19:00 2.50 COMPZ WELLPF OTHR T PJSM- Install dutch riser for making Magnet run into liner to retrieve lost slip segment from RBP on Test packer assy. Bring in Slickline equipment, RU Slickline. 19:00 21:00 2.00 COMPZ WELLPF SLKL T RIH w/ 14 -ft x 1.5" roller stem TS (1.82" roolers) KJ, 1- 11/16" OD x 48" L Bowspring centralizer, 2.12" magnet (BAM), sat down at SC -1 packer top at 4,938 -ft (4,927 -ft SLM) PU and fell by, work tools to 4,959 -ft (4,948 -ft SLM) no spangs, 400# overpull to free tools, attempt one more time w/ same results- POOH, fine metal shavings only on magnet, fine sand all over tools. Confer w/ town engineer. 21:00 22:00 1.00 COMPZ WELLPF RURD T PJSM- RD Slickline and Dutch Riser. Page 4 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 23:00 1.00 COMPZ WELLPF OTHR P Wash BOP Stack. Prep to run completion. 23:00 00:00 1.00 0 0 COMPZ RPCOM PULD P PJSM- Check Cable Integrity. PU Motor centralizer, MGU, ESP Motor, check rotation, MU GRU and tandem seal section, check rotation and service same. 05/26/2012 Run 3 -1/2" completion as designed. Splice cable at tubing hanger. Land completion. RILDS. PT hanger pack -offs. Check Cable integrity. Prep for S -Line ops. Drift and Correlate for WRP. Set WRP. Pump Corr Inhib SW down IA. 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P Continue to service ESP Motor, GRU and tandem seal section assembly. 01:00 05:00 4.00 0 94 COMPZ RPCOM PULD P MU TTC assembly to seal section, Pup joint, Full joint and DGU assembly. Install TEC wire to MGU, RU cable sheave and motor cable, Lower assembly into well, installing MLE, Protectolizers and Clamps per program, MU TEC wire from motor gauge to the discharge gauge. Check cable integrity. 05:00 07:30 2.50 94 1,817 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed to Weatherford Hydrow II Feed -thru Packer checking power cable every 1000 -ft. Up wt 60k, Dn wt 55k 07:30 10:00 2.50 1,817 1,817 COMPZ RPCOM OTHR P MU Weatherford Hydrow II Feed -thru packer, Make splice thru packer. Check cable integrity. 10:00 13:30 3.50 1,817 4,870 COMPZ RPCOM RCST P Continue to RIH w/ remainder of ESP completion as designed from above Weatherford Hydrow II Feed -thru Packer checking power cable every 1000 -ft. Up wt 70k, Dn wt 60k 13:30 14:00 0.50 4,870 4,870 COMPZ RPCOM OTHR P MU landing joint to TBG Hanger and MU to TBG string, install penetrators and space out for final splice 14:00 16:30 2.50 4,870 4,870 COMPZ RPCOM OTHR P Conduct Final Splice and check cable integrity 16:30 17:00 0.50 4,870 4,912 COMPZ RPCOM THGR P PJSM. MU landing joint and land tubing hanger, Up wt 93k, Dn wt 78k. RILDS. 17:00 17:30 0.50 4,912 4,912 COMPZ RPCOM PRTS P PT Hanger packoffs to 5000 psi for 15 minutes. 17:30 18:00 0.50 4,912 4,912 COMPZ RPCOM THGR P Remove landing joint and side port isolation sleeve from hanger and re- install landing joint. 18:00 22:00 4.00 4,912 4,912 COMPZ RPCOM SLKL P PJSM- MIRU Slickline. PIT Lub, RIH w/ 2.78" Drift to 3,350 -ft SLMD. RIH w/ KOT to 3,200 -ft SLMD (3,213 -ft RKB) Flag wire, RIH w/ WRP on 1- 11/16" DPU and set @ 3,238 -ft RKB- POOH stand back Slickline 22:00 22:30 0.50 4,912 4,912 COMPZ RPCOM PRTS P RU test lines and pressure test WRP 300 psi x 5 minutes. Page 5 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 4,912 4,912 COMPZ RPCOM CIRC P Bullhead 110 bbls corrosion inhibited seawater (1% by volume) down IA at 2 bpm, ICP 120 psi, FCP 300 psi at 1 bpm. 05/27/2012 Set Pkr. Test IA, failed, leak down hole. Use decompression sch to bleed IA pressure. Attempt set Pkr at 4000 psi. Test IA. Use decompression sch to bleed IA pressure. Pull DV f/ GLM #1. Reverse Circulate Well. Pull DV f/ GLM #2. RD S -Line. BOLDS. Release Packer. POOH w/ completion to Weatherford packer. MU new packer. Run 3 -1/2" re- designed completion. Damaged ESP cable at 4,368 -ft. Begin ESP cable repair. 00:00 00:30 0.50 4,912 4,912 COMPZ RPCOM PACK P Pressure tubing up in 1000 psi increments per Weatherford Rep. to 3500 psi, set Hydrow II Feed -thru packer, chart 25 minutes. 00:30 04:00 3.50 4,912 4,912 COMPZ RPCOM PRTS P Pressure up on IA to 1550 psi, lost 100 psi in 15 min, Bump IA up to 1600 psi, lost 100 psi in 10 min, bump IA to 1600 psi and watch 45 min, 100 psi loss of pressure every 10 min, no noticeable leaks at surface, Tbg pressure at 0 psi thru out test, confer w/ town engineer, start decompression schedule, try re- setting packer 4000 psi to Tbg. 04:00 04:45 0.75 4,912 4,912 COMPZ RPCOM PACK T Pressure tubing up in 4000 psi, bleed off pressure and fix 2 gray -loc leaks, head pin leak and leak on production valve handle. Pressure tubing up in 4000 psi x 10 min on chart. Swap over to IA. 04:45 05:45 1.00 4,912 4,912 COMPZ RPCOM PRTS T Pressure Test IA to 1600 psi, same 100 psi every 10 minute loss of pressure. 05:45 08:00 2.25 4,912 4,912 COMPZ RPCOM OTHR T Bleed IA per decompression schedule starting from 1200 psi.. 08:00 09:00 1.00 4,912 4,912 COMPZ RPCOM SLKL T PJSM w/ slick line and rig crew. RU slick line and RIH w /AVA catcher sleeve and set on WRP at 3,238 -ft. POOH and change over to kick over tool. RIH and pull dummy valve from Station #1 at 2,969 -ft and POOH. 09:00 10:00 1.00 4,912 4,912 COMPZ RPCOM CIRC T Reverse circulate 140 bbls of 3% KCL at 2 bpm at 250 psi taking returns to kill tank. Blow down kill line 10:00 11:00 1.00 4,912 4,912 COMPZ RPCOM SLKL T RIH and pull dummy valve from Station #2 at 3,206 -ft and POOH. RD and Release Slick line. 11:00 12:00 1.00 4,912 4,890 COMPZ RPCOM OTHR T MU Iso sleeve landing joint to TBG hanger and Top drive. BOLDS, and shear packer at 125k - 32k osw, Pull hanger to rig floor. 12:00 12:30 0.50 4,890 4,890 COMPZ RPCOM OWFF T Meg ESP Cable while Monitoring well for flow on trip tank. ESP Cable Megged Page 6 of 24 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 15:00 2.50 4,890 1,834 COMPZ RPCOM TRIP T Remove TBG hanger and POOH w/ 1 stand, string ESP cable over sheave. Continue to POOH replacing TBG seal rings to packer w/ remaining completion at 1,834 -ft. 15:00 20:30 5.50 1,834 1,800 COMPZ RPCOM OTHR T Inspect packer no visual signs, Meg cable - good. Break down penetrator and lay down packer. PU and make up penetrator thru Packer #2, cable connection short, drop first full joint below packer ( #55) and MU 2 pup joints 10.14 -ft and 9.11 -ft, MU Weatherford Hydrow II Feed -thru packer and spice thru, MEG wire - good. 20:30 23:30 3.00 1,800 4,368 COMPZ RPCOM RCST T PJSM- MU 1 std above packer, GLM #1 and joint 59 (dropped joint 60 from original completion) continue to RIH w/ remainder of ESP completion as designed from above GLM #1, checking power cable every 1000 -ft. Up wt 85k, Dn wt 70k. Damaged cable at top of joint #138 (4,368 -ft) setting clamp down on hole cover, will not MEG, make appropiate calls. 23:30 00:00 0.50 4,368 4,368 COMPZ RPCOM OTHR T Repair ESP cable leg. 05/28/2012 Continue ESP cable repair at 4,368 -ft. Run 3 -1/2" re- designed completion. Splice cable at tubing hanger. Check cable integrity. Land completion. RILDS. PT hanger pack -offs. RU S -Line. Set DV's in GLM's #1 & #2. Set Pkr. Attempt Test IA. Troubleshoot failed IA test. 00:00 02:00 2.00 4,368 4,368 COMPZ RPCOM OTHR T Continue to repair ESP cable leg at 4,368 -ft. 02:00 03:00 1.00 4,368 4,828 COMPZ RPCOM RCST T Continue to RIH w/ remainder of ESP completion as designed. MU landing joint to TBG Hanger with side port isolation sleeve installed, MU to TBG string, install penetrators and space out for final splice 03:00 05:30 2.50 4,828 4,828 COMPZ RPCOM OTHR T Conduct Final Splice thru tubing hanger and check cable integrity - good. 05:30 06:00 0.50 4,828 4,871 COMPZ RPCOM THGR T PJSM. Land tubing hanger, Up wt 82k, Dn wt 65k. RILDS. 06:00 06:30 0.50 4,871 4,871 COMPZ RPCOM PRTS T PT Hanger packoffs to 5000 psi for 15 minutes. 06:30 07:00 0.50 4,871 4,871 COMPZ RPCOM THGR T Remove landing joint and side port isolation sleeve from hanger, re- install landing joint w/ FOSV. 07:00 09:30 2.50 COMPZ RPCOM SLKL T PJSM- MIRU Slickline. P/T Lub, RIH w/ KOT and set DV in GLM #2 at 3,164 -ft, POOH, RIH w/ KOT and set DV in GLM #1 at 2,939 -ft- POOH. stand back S -line Page 7 of 24 Time Logs • • Date From To Dur S. Death E. Death Phase Code Subcode T Comment 09:30 11:30 2.00 COMPZ RPCOM CIRC T RU and Bull head 80 bbls of Corrosion inhibited 3% KCL down IA followed by 35 bbls of 3% KCL at 1 bpm at 350 psi. RD Pump equipment. 11:30 13:00 1.50 COMPZ RPCOM PACK T RU to TBG and pressure up to 500 psi and hesitate, continue to bring pressure up to 1,000 psi and hesitate, continue to bring pressure up to 1,250 psi and hesitate, continue to bring pressure up to 1,500 psi and hesitate, continue to bring pressure up to 2,000 psi and hesitate, continue to bring pressure up to 2,500 psi and hesitate, continue to bring pressure up to 3,000 psi and hesitate, continue to bring pressure up to 3,500 psi and hesitate, Shut in and hold pressure for 20 minutes. Seen pins shear at 1,250 psi and set packer. Bleed off pressure 13:00 19:00 6.00 COMPZ RPCOM PRTS T RU and Pressure test annulus at 1,500 psi - loosing 50 psi in 10 minutes. Continue to attempt to obtain pressure test on packer - with no luck losses stayed close to the same. 19:00 00:00 5.00 COMPZ RPCOM PRTS T Pressure up on TBG to 1,600 psi had same results. Pressure IA to 2,500 psi after consulting with town engr - loss 300 psi in 10 minutes - Release Slick line and allow IA pressure to bleed to zero psi. la at 50 psi, Tbg at 1350 psi. at 24:00. Audit rig for repair and maintenance. 05/29/2012 Continue to troubleshoot failed IA test. RU E -line. Run Leak Detect Evaluation. Confer with town for direction forward. RD E -line. RU Saine._P._ull. WRP. Release Packer. Circulate well. POOH w/ 3 -1/2" ESP completion. 00:00 02:00 2.00 0 0 COMPZ RPCOM PRTS T Continue to allow IA pressure to bleed to zero psi. IA at 50 psi, Tbg at 1350 psi. Audit rig for repair and maintenance. 02:00 05:30 3.50 0 0 COMPZ RPCOM PRTS T IA at 0 psi, Tbg at 1,325 psi. Fluid to surface on IA, Attempt to pressure up IA, Bring on pump at 1/2 bpm at 250 psi for 1 bbl, shut down IA at 150 psi and falling slowly, pump 2 bbls at 1 bpm at 300 psi, shut down IA at 200 psi and falling slowly, IA pressure bled to zero psi in 1 hr, Tbg at 1,325 psi. Continue to monitor well. Audit rig for repair and maintenance. Page 8 of 24 Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 05:30 11:00 5.50 0 0 COMPZ EVALWE ELOG T MI and spot E -line equipment. PJSM- RU E -line. RIH w/ Welltech leak detection logging tools to 3,165 -ft and log out of the hole seen temperature cross over at 1,000 -ft and Noise at 230 -ft. injecting at .25 bpm at 230 psi IIP and 270 psi FIP. RD E line. 11:00 21:00 10.00 0 0 COMPZ RPCOM SLKL T Prep for Slick line to pull Catcher Sub and WRP, Held PJSM w/ rig crew and slick line crew. RU slick line and recover catcher sub. RIH w/ bailer to equalize WRP. RIH and retrieve WRP and POOH. RD Slick line. 21:00 21:30 0.50 0 0 COMPZ RPCOM OWFF T PJSM, Monitor Well- Slight Vac. 21:30 22:30 1.00 0 0 COMPZ WHDBO BOPE T Pull Landing Joint and Install Two Way Check. Kill and Choke line Test 250 / 3000 psi. Due to removal of Kill and Choke line for testing of packer thru the IA valve. Test Ok. 22:30 23:00 0.50 0 0 COMPZ RPCOM THGR T Pull Two Way Check, Install Side Port Iso Sleeve, Install Landing Joint. 23:00 23:30 0.50 0 0 COMPZ RPCOM THGR T PJSM, Back Out LDS. Hanger free at 75K, Shear Packer Release at 125K #, 40k osw, PU 5' 23:30 00:00 0.50 0 0 COMPZ RPCOM CIRC T Up Wt 85k, Dwn Wt 65k. Reland Hanger. Reverse Circ 142 BBLS of 3% KCL at 5 BPM. ICP 360 psi, FCP 370 psi. 122 BBLs to Kill Tank Fluid Loss Today= 80 bbls. Fluid Loss to Date= 898 bbls. 05/30/2012 ., POOH with.S -j /_ "ESP Completion. Test BOPE. E -Line set Retrievable Bridge Plug at 4898'. 00:00 01:00 1.00 0 0 COMPZ RPCOM CIRC T Complete Reverse Circ to Kill Tank. 01:00 03:45 2.75 0 0 COMPZ RPCOM OWFF T Monitor Well. Static/ Slight Vac. RD Circ Hoses. PJSM. Pull Hanger 85k. Continue to Monitor Well. Estimate Losses at 10 BPH. Pull Hanger to Floor and found Side Port Isolation Sleeve Leaking. Reland Hanger, Bullhead 15 bbls down Tubing 230 ICP, 310 FCP. Changout Side Port Iso Sleeve top 0-Ring and Prepare to Pull Completion. 03:45 11:30 7.75 4,871 0 COMPZ RPCOM PULL T POOH w/ 3 1/2" Completion to TTC Coupling. Break down ESP tandem seals and Motor assy. Load ESP components in boxes and offload same. 11:30 12:30 1.00 0 0 COMPZ WHDBO BOPE T RU test equipoment and install test plug. Shell test at 250 / 3,000 psi. 12:30 13:30 1.00 0 0 COMPZ RPCOM OTHR T Held PJSM with Crane operator and off load ESP cable spool and install empty spool. Page 9 of 24 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 17:00 3.50 0 0 COMPZ WHDBO BOPE T Continue with weekly BOP Test at 250 / 3,000 psi. 24 hr Notification was given to AOGCC at 07:00 hrs on 5 -29 -12 and followed up at 11:00 hrs on 5 -30 -12 spoke with Matt Herrera. Test was witnessed by Matt Herrera. RD Test Equipment 17:00 18:00 1.00 0 0 COMPZ EVALWE ELOG T Install Dutch Riser, Spot E -Line unit. 18:00 00:00 6.00 0 0 COMPZ EVALWE PLUG T Hold PJSM with HES E -Line crew. RU Eline and MU Baker Wireline Set RBP and set Same at 4898', POOH. Fluid Loss Today= 135 bbls. Fluid Loss to Date= 1033 bbls. 05/31/2012 Continue E -line Logging to troubleshoot failed IA test. Find IA fluid leak in TAM Port Collar at 997',Att_empt to Shift TAM Collar closed- unsuccessful. 00:00 03:00 3.00 0 0 COMPZ EVALWE ELOG T RD RBP Tool string. MU HES FAST CAST Tool string. Unable to RIH due to Stiff Centralizers. Reconfigure Tool string and loosen Centralizers. Experiencing Tool Telemetry Problems on Surface. Swap out BHA for Caliper LDL Run and get Elec Tech involved in Trouble shooting FAST CAST Telemetry Problem. 03:00 09:00 6.00 0 0 COMPZ EVALWE ELOG T RIH w/ 40 ARM Caliper tools w/ LDL tools in tandem to 4,850 -ft and log out of the hole and find hole at 1,007 -ft. w/ LDL tools. POOH and RD Caliper tool setup. 09:00 17:00 8.00 0 0 COMPZ EVALWE ELOG T Rehead to 7/32" and RU FastcastM tools and RIH to 4,850 -ft and log up to surface. RD E -Line and Dutch riser system. 17:00 19:00 2.00 0 997 COMPZ WELLPF TRIP T MU TAM Port shifting tool and RIH on 3 1/2 8rd TBG to 997 -ft and engage TAM Port collar. 19:00 23:00 4.00 997 997 COMPZ WELLPF OTHR T Cycle TAM Port at 997'open and closed approx 25 times. Port Collar shifting, but not closing completely. Pressure builds up, but not holding. Tool popped out of Latch without turning to Release approx 6 times. 23:00 23:30 0.50 997 0 COMPZ WELLPFTRIP T Pull out to inspect Shifting Tool. All Cups look good, Latch looks good. Find Clay and small Rocks packed in Upper Bottom Sealing Cup. Lay Down Shifting Tool. Page 10 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 COMPZ EVALWE PRTS T Left TAM Collar shifted in closed up position. Attempt PT Casing and pump 1 BPM at 530 psi. Bleed back slowly. Start Picking up Drill Pipe for Baker Full Bore Test Packer Run. Fluid Loss Today= 75 bbls. Fluid Loss to Date= 1108 bbls. 06/01/2012 Verify Casing Compentency above and below TAM Collar, Set RBP at 1210', Dump 500# (calc =181 of 20 -40 ,Sand_ 00:00 01:30 1.50 0 0 COMPZ WELLPFOTHR T Load Pipe Shed with 3 -1/2" Drill Pipe for Baker Full Bore Test Packer Run. 01:30 04:15 2.75 0 980 COMPZ WELLPF PULD T PJSM, MU Baker 7.63 Full Bore Test Packer on 3 -1/2" DP. RIH and to 980' and set Test Packer. 04:15 05:15 1.00 980 980 COMPZ EVALWE PRTS T Pressure up to 1500 psi on Annulus between Prill Pipe and 7 -5/8" above Packer, held solid and charted for 30 minute test. 05:15 05:30 0.25 980 1,014 COMPZ WELLPF TRIP T Release Packer and RIH below and reset at 1014'. 05:30 06:30 1.00 1,014 1,014 COMPZ EVALWE PRTS T Pressure Test Casing below Test Packer to RBP at 4898' to 1500 psi. Charted Good Test for 30 minutes. Release Packer. 06:30 07:00 0.50 1,014 0 COMPZ WELLPF TRIP T POOH. LD Test Packer BHA. 07:00 12:00 5.00 0 0 COMPZ WELLPFOTHR T Clean and organize rig 12:00 13:30 1.50 0 1,210 COMPZ WELLPF TRIP T PJSM PU BHA #6 Baker "G" RBP and RIH to 1,210 -ft 50k up wt 50k do and set RBP w/ top at 1,200 -ft. Release off and pull up 1,180 -ft. 13:30 16:30 3.00 1,210 1,180 COMPZ WELLPFOTHR T Spot 500 lbs of 20/40 sand, POOH to 1,090 -ft wait 1 hr and RIH and Tag top of sand at 1,180 -ft. 16:30 17:30 1.00 1,180 1,180 COMPZ WELLPFSFTY T Held training Halliburton E -line on Cement Bond log operations. 17:30 18:30 1.00 1,180 0 COMPZ WELLPF TRIP T Held PJSM and POOH from 1,180 -ft surface, lay down Model L Retrieving head. 18:30 20:30 2.00 0 899 COMPZ WELLPF TRIP T PU and MU BHA #7 Baker K -1 Mechcanical CMT Retainer - 4AA/7.63" w/ K -1 Snap latch setting tool and RIH to 899 -ft. 48k up wt, 50k dn wt. 20:30 21:00 0.50 899 899 COMPZ WELLPF PACK T Set CMT retainer, set 25 dn wt and pull 25 k OSW of 48k. Release off of CMT retainer and snap back in. 21:00 21:30 0.50 899 899 COMPZ WELLPF PRTS T PJSM, PT Annulus 1500 psi for 10 Minutes. Held Solid. 21:30 00:00 2.50 899 899 COMPZ WELLPF CMNT T Prep Rig for Cement Job, Spot Trucks Fluid Loss Today= 14 bbls. Fluid Loss to Date= 1122 bbls. Page 11 of 24 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/02/2012 24 hr Summary Set Cmt Retainer at 897, Squeeze —80 bbls Cmt into Tam Port Collar at 997', WOC to reach 1000 psi Comp Str. Mill Cement to 1162'. PT Casing Failed. Run CSG Scraper to 1006'. Prep for Second Cement Squeeze. 00:00 00:30 0.50 899 899 COMPZ CEMEN" SFTY T PJSM for Squeeze. 00:30 03:30 3.00 899 799 COMPZ CEMEN" SQEZ T PT Lines & Line up for Squeeze. Bullhead 8.6ppg brine down DP with SLB Cementers to establish Injection Rates. 0.5 bpm @ 425 psi / 1.0 bpm @ 560 psi / 1.5 bpm @ 670 psi / 2.0 bpm @ 800 psi. Pump 3 bbl Fresh Water Spacer. Batch 15.7 ppg ArcticSet 1 Cement. Pump Cement down DP at 2 bpm. Pressure drops and Cmt gets to Port Collar. Pumping 2 bpm Pressure climbs to 1300 psi as Cmt goes out Port Collar. Drop rate to 1 bpm and Pressure stabilizes at —600 psi. Increase Rate in Steps, and Pressure Falls off. Back Rate off to 1 bpm for last 20 bbls and pressure remains about 100 psi. Pump 81 bbls total cmt, follow with 5 bbls FW, Unstab from Cem Ret and pump 2 bbls. Stand back 1 Stand, close Lower PR, and SLB reverse circ 25bbls 8.5 ppg Brine at 6 bpm to clean out DP, Rig Down SLB Cement in Place at 2:30 AM. 03:30 04:00 0.50 799 0 COMPZ WELLPF TRIP T POOH, Lay Down Setting Tool 04:00 13:00 9.00 0 0 COMPZ WELLPF WOC T Prep ESP Spool while waiting on Cement. Clean, paint and organize rig. 13:00 13:30 0.50 0 195 COMPZ WELLPF PULD T PU and MU BHA #10 (6.75" Tri -cone bit, 6- 4 3/4" DC's) 13:30 14:00 0.50 195 840 COMPZ WELLPF TRIP T RIH w/ BHA #10 from 195 -ft to 840-ft 54k up wt, 54k do and Tag cement. 14:00 18:30 4.50 840 1,054 COMPZ WELLPF DRLG T Gather slow pump rates and Parameters. Begin drilling cement from 840 -ft to 871 -ft at 100 rpms w/ 1,550 ft/Ibs. at 1.6 fUmin. ROP. Tag up on cement retainer and drill out retainer w/ variable parameters in 3.6 hrs. drill out cement from 873 -ft to 932 -ft and fell out of cement, kick out rotary and slide down to 992 -ft and drill out to 1,002 -ft and fell thru to 1,054 -ft. CBU at 8 bpm at 320 psi. 18:30 19:00 0.50 1,054 1,054 COMPZ WELLPF PRTS T Close manual top drive vale and UPR's w/ 3 1/2 solid bodies. RU sensor to IA valve for chart recorder and pressure up on IA thru kill line - pumping away at 1 bpm at 450 psi. Page 12 of 24 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:30 1.50 1,054 1,162 COMPZ WELLPFTRIP T Trip in hole on top drive 1,054 -ft to 1,162 -ft - chasing possible debris from cement retainer. 20:30 22:00 1.50 1,162 0 COMPZ WELLPFTRIP T POOH from 1,162 -ft to Bit. Break off bit for CSG scraper run. 22:00 23:30 1.50 0 1,006 COMPZ WELLPFTRIP T PJSM, MU BHA #11, RIH to 1006'. 55k up and down. Monitor Well - Static. 23:30 00:00 0.50 1,006 0 COMPZ WELLPFTRIP T PJSM, POOH From 1006, LD BHA #11 Fluid Loss Today= 10 bbls. Fluid Loss to Date= 1132 bbls. 06/03/2012 Set Cmt Retainer at899',Squeeze 60 of 80 bbls of 15.7 ppg AS1 cement with 2 ppb CemNet into Tam Port Collar at 997' in 3 of 4 stages. 00:00 01:00 1.00 0 0 COMPZ WELLPF OTHR T Load Tools. Prep for Cment Retainer Run. 01:00 02:30 1.50 0 898 COMPZ WELLPF PACK T PJSM. MU Cement Retainer BHA. RIH and set at 898' (top) 02:30 03:45 1.25 898 898 COMPZ CEMEN" CMNT T PJSM. PT Annulus above Cmt Retainer to 1500 psi for 10 minutes and chart. Good Test. Pump injectivity Test through TAM Port Collar at 1 BPM. Pressure between 370 -410 psi. 03:45 09:00 5.25 898 898 COMPZ CEMEN" OTHR T Prep for Cement Squeeze. 09:00 15:00 6.00 898 898 COMPZ CEMEN "SQEZ T PJSM. Fill lines and pressure test at 3,000 psi. Establish injection rate: '/: bpm at 348psi., 1 bpm at 421 psi., 1 %: bpm at 508 psi., 2 bpm at 623 psi., 2 %2 bpm at 677 psi. Change hole over to fresh water above cement retainer (45 bbls). Annular is Closed and leave closed for the rest of the operation w/ pressure set at 500 psi and hydraulic oil on annular. 15:00 16:00 1.00 898 898 COMPZ CEMEN" SQEZ T Stage 1: Volumes included surface of 175 -ft of 2" =.7 bbls. Open HCR and Manual choke lines to Choke manifold and monitor IA pressure. Pump 5 bbls of Fresh water, 2.5 bpm at 677 psi. Mix and pump 20 bbls of slurry at 2.5 bpm @ 673 ICP, 600 FCP with 2 ppb CemNet. Follow by 7.6 bbls of fresh water. Un -sting from retainer. Close HCR on choke lines to Choke manifold. Reverse out with 10 bbls of fresh water with rig pumps taking returns to cuttings box at 3bpm at 120 psi. Sting into Cement retainer . Pump 2 bbls of Fresh water with cementers at 778 psi. Pump total of 120 bbls of fresh used including 30 bbls for wash up + 45 for displ. Page 13 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 898 898 COMPZ CEMEN "SQEZ T Stage 2 : 20 bbls of slurry in place. Un -sting from retainer. Mix 20 bbls of slurry and pump 7.2 bbls of slur rY P P slurry at .5 bpm. Open HCR and Manual choke lines to manifold and monitor IA pressure. Hold 500 psi back pressure lined up, taking returns to kill tank. Sting into retainer. Pump remaining 12.8 bbls of slurry at 2.25 bpm if pressure allows. Follow by 7.6 bbls of fresh water. Un -sting from retainer. Close HCR on choke lines to Choke manifold. Reverse out with 10 bbls of fresh water with rig pumps taking returns to cuttings box, 1/4" bbls back. Sting in and Pump 2 bbls of Fresh water at 400 psi with cementers. 190 bbls of fresh used including 30 bbls for wash up. 17:00 19:00 2.00 898 898 COMPZ CEMEN" SQEZ T Plan for PJSM at 19:00 after all crews get good changeout. 19:00 20:00 1.00 898 898 COMPZ CEMEN" SQEZ T PJSM. Double check all lines and fluid paths. Page 14 of 24 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:30 1.50 898 898 COMPZ CEMEN" SQEZ T Stage 3: 40 bbls of slurry in place. Sting into Cement Retainer and pump 2 bpm of FW at low rate and pressure immediately jacks up to 1150 psi and breaks back to 460 psi at 0.5 bpm. Unsting and get cement to end of stinger. Mix 20 bbls of slurry and pump 7.2 bbls of slurry at .5 bpm. Open HCR and Manual choke lines to manifold and monitor IA pressure. Hold 500 psi back pressure lined up, taking returns to kill tank. Sting into retainer and pump remaining 12.8 bbls of slurry at 1bpm. Pressure approx 220 psi initial pressure cement through port collar at 1 bpm. Slowly pressures up to 330 psi at 1 bpm, drop rate to approx 0.85 psi and pressure remains around 310 psi. Maintain rate and follow by 11.2 bbls of fresh water, pressure comes up to 610 psi with water at TAM. Un -sting from retainer. Close HCR on choke lines to Choke manifold. Reverse out with 10 bbls of fresh water with rig pumps taking returns to cuttings box. 260 bbls of fresh used including 30 bbls for wash up. Sting back into Cem Ret and monitor pressure. Starts at 0 psi after pressure bled off at surface clearing lines, but builds back to 240 psi. Give cement stage time to gel up, plan to reconvene at 4:00. 21:30 00:00 2.50 898 898 COMPZ CEMEN" WOC T Give stage 3 cement time to gel up, plan to reconvene at 4:00 Fluid Loss Today= 0 bbls. Fluid Loss to Date= 1132 bbls. 06/04/2012 Wait on Cement, Drill Cement Retainer and chase to 990'. POOH with DP and RIH with 3 -1/2" Tubing for Balance d Plug Cement Squeeze. 00:00 08:00 8.00 898 898 COMPZ CEMEN" WOC T Give stage 3 cement time to gel up - Conduct contractor change out. 08:00 08:30 0.50 898 898 COMPZ CEMEN - SFTY T Held PJSM with contractors involved in cement squeeze. Page 15 of 24 • • Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 08:30 10:30 2.00 898 898 COMPZ CEMEN" PRTS T Check all valve line up, un -sting from Retainer and pump thru to verify open - good. Stab back in and pressure to 1,000 psi within .10th of a bbl. Notify town and discuss increasing to 1,500 psi and chart test. Continue to pressure up to 1,500 psi and chart with SLB sensor for 30 minutes. Lost 500 psi in 30 minutes. Review results with town engineer. Blow down cementers and release from Retainer. 10:30 11:00 0.50 898 896 COMPZ CEMEN" CIRC T Circulate hole over to 3% KCL Sea water at 8 bpm 11:00 12:30 1.50 896 0 COMPZ CEMEN" TRIP T Change out Nordic crews and POOH w/ setting tool for retainer. Lay down same. 12:30 14:00 1.50 0 897 COMPZ WELLPF TRIP T PU and RIH with DRLG BHA #13 to 897 -ft. 14:00 18:30 4.50 897 983 COMPZ WELLPF DRLG T Tag up on cement retainer, gather parameters and begin drilling on retainer. Drill down to 899 -ft and retainer fell. Chase retainer to 983 -ft and tag up. 18:30 19:30 1.00 983 990 COMPZ WELLPF DRLG T Contiue Drilling down to 990'. Up 54 k# and down 55k# - 8 bpm at 380 psi. Recovered some Metal fines over shakers. 19:30 20:00 0.50 990 968 COMPZ WELLPFTRIP T POOH with BHA #13 to 968' and blow down top drive. 20:00 22:00 2.00 968 968 COMPZ WELLPF PRTS T PJSM. RU to test Casing. Pressure up to 1500 psi and bleed down to 500 psi. Chart leak off. Lose 1000 psi in 1.5 hours. Linear Leak. RD Test Equipment 22:00 23:00 1.00 968 0 COMPZ WELLPFTRIP T PJSM. POOH with 3 -1/2" Drill Pipe BHA #13 23:00 00:00 1.00 0 0 COMPZ WELLPF PULD T PJSM, C/O floor Equip, PRep to RIH with 3 -1/2" Tbg Fluid Loss Today= 70 bbls. Fluid Loss to Date= 1202 bbls. 06/05/2012 Lay in 10 bbls of 15.7 ppb AS1 Cement and Squeeze into Port Collar. Wait on Cement. Start Weekly BOP Test. 00:00 02:00 2.00 0 990 COMPZ WELLPFTRIP T RIH with 3 -1/2" Tubing/ Muleshoe BHA 02:00 02:30 0.50 990 989 COMPZ CEMEN" SQEZ T PJSM. Tag at 990'. Pull up 1' and line up cementers to pump down tubing. Page 16 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:45 2.25 989 714 COMPZ CEMEN' SQEZ T Close Upper Pipe Rams and pump 10 bbls Fresh Water at 2 bpm down Tubing holding 500 psi back pressure, returns up Backside. Shutdown Pumps and batch up 10 bbls of 15.7 ppg AS1. Pump 10 bbls of AS1 at 2 bpm holding 4 -600 psi back pressure. Swap to FW and follow with 6.5 bbls at 4 bpm holding 750 psi back pressure. Shut down and open upper pipe rams. Pull 3 stands at approx 3 min /stand. Cementers line up to Annulus, Close Lower Pipe Rams and Reverse Circ 35 bbls of water to Cuttings Box at 7 bbls a min. Close in Bleeder and pressure up to 750 psi and monitor. Bleed down 100 psi in 15 minutes. 04:45 05:00 0.25 714 0 COMPZ WELLPF TRIP T Bleed off Pressure, open Rams and POOH wirh 3 -1/2" Tubing/ Muleshoe BHA. 05:00 07:30 2.50 0 0 COMPZ WELLPF PRTS T On Surface. Close Blinds and Pressure up to 1500 psi with SBL Cementers and chart leak off. Pressure Reading at 0600, 1286 psi Pressure Reading at 0630, 1140 psi - Bump up psi to 1547 psi. Pressure Reading at 0700, 1127 psi - Bump up psi to 1534 psi Pressure Reading at 0730, 1222 psi - Bump up psi to 1758 psi 07:30 12:00 4.50 0 0 COMPZ WELLPF PRTS T Continue to chart leak off. Pressure Reading at 1,428 psi. 12:00 14:30 2.50 0 0 COMPZ WELLPF PRTS T Continue to chart leak off. Pressure Reading at 1,364 psi. Bump pressure up to 1,526 psi and continue to observe leak off. 14:30 16:30 2.00 0 0 COMPZ WELLPF PRTS T Pressure Reading at 1630 hrs, 1488 psi. 16:30 18:30 2.00 0 0 COMPZ WELLPF PRTS T Pressure Reading at 1830 hrs, 1456 psi. 18:30 20:30 2.00 0 0 COMPZ WELLPF PRTS T Pressure Reading at 2030 hrs, 1424 psi. 20:30 21:00 0.50 0 0 COMPZ WELLPF PRTS T Pressure Reading at 2100 hrs, 1419 psi. 21:00 22:00 1.00 0 0 COMPZ WELLPF PRTS T RD SLB Cementers. 22:00 00:00 2.00 0 0 COMPZ WELLPF BOPE P Start Weekly BOP test- Test waived by State Inspector Lou Grimaldi at 07:25 on 6/5/12. Pull Wear Bushing and Install Test Plug Fluid Loss Today= 10 bbls. Fluid Loss to Date= 1212 bbls 06/06/2012 Perform W eekly BOP Test. Drill out Cement to TOS at 1180'. PT 7 -5/8" Casing to 1500 psi- Failed. RIH Reverse Circ Junk Basket to 1186'. Page 17 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:30 5.50 0 0 COMPZ WELLPF BOPE P Fill 11" 5M Class III stack and lines with water and RU Test equipment. Held PJSM and Test BOPE at 250 / 3,000 psi. Perform Accumulator Draw Down Test- System pressure 3,000 psi, After Close 1,950 psi. Function Tested both Chokes. 05:30 06:30 1.00 0 0 COMPZ WELLPF BOPE P Pull Test Plug and Install Wear Ring 06:30 07:45 1.25 0 778 COMPZ WELLPFTRIP T MU & RIH Cement Milling Assembly (6 3/4" Bit ) Tagged TOC at 778 -ft. PUH 10 -ft and Set Parameters. Obtained Slow Pump for Mud Pump #1 & #2 at 1 bpm,2 bpm,3 bpm,was 60 psi. Up Wt & Dn Wt 52k, Rotating Wt 54k, Free Torque 950 -1 K, 07:45 12:00 4.25 778 1,039 COMPZ WELLPF MILL T Starting milling cement at 8 bpm, 340 psi at 90 RPM. Continue to mill down to TOS at — 1,180 -ft. 4 -9k WOB. 12:00 15:15 3.25 1,039 1,168 COMPZ WELLPF MILL T Continue Milling operation f/ 1,039 -ft. Up & Dn Wt 54k, Rotating Wt 55k, pumping at 8 bpm, 400 psi. Hard Tag at 1,164 -ft observed rubber at shakers. 15:15 15:30 0.25 1,168 1,168 COMPZ WELLPF CIRC T Circulate 25 bbls High -vis sweep at 8 bpm, 375 psi, while reciprocating. Seen heavy pieces of rubber from sweep at shakers 15:30 17:00 1.50 1,168 1,181 COMPZ WELLPFMILL T Continue Milling operation f/ 1,168 -ft. Up & Dn Wt 54k, Rotating Wt 55k, pumping at 8 bpm, 430 psi. Dry Tag at 1180', Circ down to 118, Pickup Dry Drill to 1181', Circulate Bottoms Up 17:00 19:00 2.00 1,181 0 COMPZ WELLPFTRIP T PJSM, Blow Down Top Drive, Monitor Well, Staic. POOH 55k# up /down. 19:00 20:30 1.50 0 0 COMPZ WELLPF PRTS T Test Casing to 1500 psi- Failed, Drops 900 spi in 30 minutes 20:30 22:00 1.50 0 1,181 COMPZ WELLPFTRIP T PJSM, MU BHA #16 Reverse Circ Junk Basket. RIH and Tag at 1181'. 22:00 22:30 0.50 1,181 1,186 COMPZ WELLPF FCO T Wash Down to 1186'. Staging up Pump Rate with each one foot Bite. 5 bpm at 600 psi up to 8 bpm at 1360 psi. Pull up hole to 1173' and Circulate Bottoms Up. Blow Down Top Drive and pull up and Overpull 20k #. 22:30 00:00 1.50 1,186 997 COMPZ WELLPFTRIP T Blow Down Top Drive and pull up and Overpull 20k #. Circulate another Bottoms Up at 8 bpm and Rotate 40 rpm and Pull through. Overpull again at 1073 and Circulate 18 bbl High Vis Sweep. More Snags at 1035' and 997'. Continue POOH. 0 bbls Loss to Formation Today. 1212 bbls Loss to Formation Total. Page 18 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2012 24 hr Summary Run RCJB until clean. Circ out Sand above RBP at 1210' and pull. 00:00 01:00 1.00 997 0 COMPZ WELLPFTRIP T Continue POOH. 01:00 02:00 1.00 0 0 COMPZ WELLPF PULD T Inspect Junk Basket. Junk Basket full of Metal Debris from Cement Retainers. MU RCJB for second Run. 02:00 02:30 0.50 0 1,185 COMPZ WELLPFTRIP T RIH with 2nd Run RCJB. Tag at 1185'. 02:30 03:00 0.50 1,185 1,190 COMPZ WELLPF FCO T Wash Down to from 1185' to 1190'. Staging up Pump Rate with each one foot Bite. 5 bpm at 540 psi up to 8 bpm at 1320 psi. 03:00 03:30 0.50 1,190 1,178 COMPZ WELLPFTRIP T Pull up hole to 1178' and Circulate Bottoms Up. Blow Down Top Drive and Pull Up. 03:30 04:00 0.50 1,178 1,119 COMPZ WELLPFTRIP T Begin POOH. Hang up at 1119'. Able to RIH and Circulate. Attempt to pull through while rotating and circulating, and still hanging up. 04:00 07:00 3.00 1,119 1,119 COMPZ WELLPFCOND T Batch up High Viscous Sweep and Wait on Dirty Vac suck out Pits, Crew C /O. 07:00 09:30 2.50 1,119 0 COMPZ WELLPFCIRC T Start Circulating Sweep at 8 bpm, 1180 psi while rotating and reciprocating at 45 RPM. Able to work passed tight spot, continue OOH. Lay down and inspect RCJB. Recover large amount of Metal, cement 09:30 12:00 2.50 0 1,191 COMPZ WELLPF FCO T PJSM. RIH with RCJB and Boot Basket down to 990 -ft to 1161 -ft circulating, continue in hole to TOS at 1189 -ft, Circulated at 8 bpm, 1400 psi to 1191 -ft rotating at 40 RPM,850 ft -Ibs of torque, up wt 58k, dn wt 56k. 12:00 13:30 1.50 1,191 0 COMPZ WELLPF TRIP T POOH f/ 1191 -ft to 1086 -ft washing CSG at 7 bpm, 1090 psi. Continue OOH and Inspect RCJB. 13:30 14:00 0.50 0 0 COMPZ WELLPFOTHR T OOH, lay down and inspect RCJB and Boot Basket. Recover another 5 or so pounds of debris. 14:00 15:30 1.50 0 1,192 COMPZ WELLPF FCO T PJSM. RIH with RCJB and Boot Basket down to 990 -ft to 1161 -ft circulating, continue in hole to TOS at 1191 -ft, Circulated at 7 bpm, 1302 psi to 1192 -ft rotating at 40 RPM,800 ft-Ibs of free torque and 900 ft -Ibs rotating, up wt 58k, dn wt 56k. 15:30 17:30 2.00 1,192 0 COMPZ WELLPFTRIP T POOH f/ 1192 -ft to 1086 -ft washing CSG at 7 bpm, 1090 psi. Continue OOH and Inspect RCJB - Very little Metal recovered. Swap out BHA. 17:30 18:15 0.75 0 0 COMPZ WELLPF PULD T PJSM, MU RBP Retreiving Tool 18:15 19:00 0.75 0 1,100 COMPZ WELLPFTRIP T RIH to 1100' and Prepare to Slip & Cut Drilling Line. Page 19 of 24 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:00 2.00 1,100 1,100 COMPZ WELLPFSLPC P PJSM, Slip & Cut Drilling line, Reset Block Height, Check Crown 0 Matic. 21:00 22:30 1.50 1,100 1,193 COMPZ WELLPF FISH T Continue RIH with RBP Retrieving Tool. Tag Sand at 1193', Up 53k# Down 52k #. Wash Down to 1199'. Latch onto RBP, Allow Elements to Relax, Monitor Well- Static 22:30 00:00 1.50 1,193 0 COMPZ WELLPF TRIP T POOH with RBP, LD Drill Pipe, LD Fish Fluid Loss Today= 00 bbls. Fluid Loss to Date= 1212 bbls. 06/08/2012 Lay Down and Kick Out Drill Pipe, Pull Second RBP at 4898' with 3 -1/2" 8rd Tbg, Swap ESP Spool, Clean Out Upper GP Assembly to 4955'. 00:00 01:30 1.50 0 0 COMPZ WELLPF PULD T Kick out Drill Pipe. RIH with 4 -3/4" DC to 183'. POOH, LD, and Kick Out Same. 01:30 02:30 1.00 0 0 COMPZ WELLPF PULD T Change Out Floor Equipment and Prep to RIH with Tubing. 02:30 08:00 5.50 0 4,838 COMPZ WELLPF TRIP T PJSM, MU and TIH with RBP Retreival Tool on 3 -1/2" Tubing stands and singles down to 4,838 -ft. Up Wt 75k / Dn Wt 60k. 08:00 11:00 3.00 4,838 4,898 COMPZ WELLPF CIRC T Circulate at 6 bpm, 360 psi for 218 bbls, trip in to 4898 -ft. Latch and Retrieve RBP and confirm latched. PUH and CBU at 4 bpm, 300 psi. 11:00 12:00 1.00 4,898 4,866 COMPZ WELLPF OTHR T Monitor well. Crane on Location. PJSM, Swap Out ESP spool. Fluid Losses at 6 BPH. 12:00 15:30 3.50 4,866 0 COMPZ WELLPF TRIP T PJSM. TOOH standing back 3 1/2" Tubing, maintaining proper hole fill. Up Wt 75k / Dn Well 60k. 15:30 16:00 0.50 0 0 COMPZ WELLPF PULD T OOH. Lay Down Lower RBP Assembly. 16:00 16:15 0.25 0 0 COMPZ WELLPF SFTY T Hold PJSM. Discuss Hazard for MU BHA and TIH with same. 16:15 16:45 0.50 0 0 COMPZ WELLPF PULD T MU and TIH with Clean Out Assembly. 16:45 19:30 2.75 0 4,955 COMPZ WELLPF TRIP T RIH to 4920'. Up 72k #, Down 60k #. Continue RIH and Locate SC -1 PKR at —4940' with Mule Shoe depth 4955'. 19:30 22:00 2.50 4,955 4,955 COMPZ WELLPF CIRC T Reverse Circulate 8 bpm at 600 psi.. Some Gas in Returns, Shut down and Monitor Well. Load Fluid in Pits and Circulate 215 bbls 8.6 Brine down Tubing up Annulus at 6bpm. ICP Tubing 500, Ann 100. FCP T 620, Ann 200. 22:00 23:00 1.00 4,955 4,955 COMPZ WELLPF OWFF T Monitor Well, Static. Page 20 of 24 Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 4,955 2,723 COMPZ WELLPF TRIP T PJSM, POOH with Cleanout Assembly. At 2723' at Midnight. Up 55k #, Down 50k #. Fluid Loss Today= 158 bbls. Fluid Loss to Date= 1370 bbls. 06/09/2012 Set and Test Lower F -1 Packer Assembly on 3 -1/2" Tbg, Start RIH with Upper Suspension Completion as per Addendum 00:00 02:00 2.00 2,723 0 COMPZ WELLPFTRIP T Continue POOH with Cleanout Assembly. 02:00 04:30 2.50 0 0 COMPZ WELLPF PULD T LD Cleanout Assembly. PJSM, MU Lower F -1 Packer Assembly. 04:30 08:00 3.50 0 4,932 COMPZ WELLPFTRIP T RIH with Lower F -1 Packer Assembly down top of the SC -1 packer. Up Wt 74k / Dn Wt 60k. Continue in hole until fully located. PU to neutral weight ( 2 -ft ) 08:00 09:00 1.00 4,932 4,932 COMPZ WELLPF CIRC T Drop 1- 7/16" Ball and allow ball to seat. Kick on charge pump. Kick in mud pump and pressure up to 2000 psi and hold for 5 minutes. 09:00 09:30 0.50 4,932 4,873 COMPZ WELLPF PRTS T Hold 2000 psi and pull 10k and cofirm packer is set, continue to PUH and release from F -1 Packer. (Top Of F -1 Packer at 4,872 -ft) 09:30 10:45 1.25 4,873 4,779 COMPZ WELLPF PRTS T PUH and stand back 1 stand and set test packer at 4841 -ft. PJSM. Discuss High Pressure pumping and testing. PT between F -1 Packer and Test Packer to 1500 psi for 15 minutes and chart same. 10:45 18:00 7.25 4,779 0 COMPZ WELLPFTRIP T Obtain good pressure test. Bleed PSI to zero, release test packer. TOOH sideways with 3 1/2" TBG. 18:00 19:00 1.00 0 0 COMPZ WELLPF PULD T LD Lower Packer Set/Test Packer BHA. 19:00 21:00 2.00 0 0 COMPZ WELLPF PULD T Prepare Completion and Kick Out Bakwer Tools 21:00 21:30 0.50 0 0 COMPZ WELLPF SEQP T Pull Wear Ring 21:30 00:00 2.50 0 2,366 COMPZ WELLPFTRIP T Pick Up Seal Assembly and Tubing Completion, RIH. At 2366' at Midnight. Fluid Loss Today= 0 bbls. Fluid Loss to Date= 1370 bbls. 06/10/2012 Circulate Corrosion Inhibited Brine, Land Hanger, Test Packoffs to 5k psi- OK. Attempt to shear SOV Tbg to Casing- failed at 900 psi. RU Slick Line for Leak Detect and Leak determined to be above 100'. Unsting Hanger, find Lock Down Screw Dimples 1 inch below Bevel on Hanger and Cement Debris. Attempt to clear Hanger Bowl and Re -Land unsuccessful. Prepare to set Storm Packer and Nipple Down to clean Bowl. 00:00 03:00 3.00 2,366 4,870 COMPZ WELLPFTRIP T Continue RIH with Completion to 4870' 03:00 04:00 1.00 4,870 4,885 COMPZ WELLPF OTHR T Locate Seals at 4885'. Page 21 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:30 1.50 4,885 4,795 COMPZ WELLPF CIRC T LD 3 Joints of Tuibing. Circulate 210 bbls 9.6 ppg Corrosion Inhibited Brine (1% CRW -132 by volume). ICP 80 psi, FCP 130 psi. 05:30 07:00 1.50 4,795 0 COMPZ WELLPF HOSO T PU Hanger, MU Dummy Penetrators, Monitor Well- Static. MU Landing Joint & Land Completion Up Wt 72k / Dn Wt 62k. RILDS. 07:00 07:30 0.50 0 0 COMPZ WELLPF PRTS T PT Hanger Void to 5000 psi. 07:30 09:00 1.50 0 0 COMPZ WELLPF PRTS T PJSM. RU Test Hoses. PT LINES to 1000 psi. WHile attending to PT tubing the SOV Sheard at 980 psi. 09:00 09:30 0.50 0 0 COMPZ WELLPF OTHR T Call Discuss SOV with Town Engineer. Dispatch SLick -Line. 09:30 11:30 2.00 0 0 COMPZ WELLPF RURD T LD Landing Joint. Pull Side Port ISO Sleeve, install Landing Joint and Rig up X -over for Slick -line. 11:30 11:45 0.25 0 0 COMPZ WELLPF SFTY T PJSM. Discuss hazard for Slick -line operation with HES and Nordic. 11:45 16:30 4.75 0 0 COMPZ WELLPF SLKL T MIRU Slick -line Unit and Load Equipment to Rig Floor. MU pulling tool and RIH to GLM at 2,679 -ft, pulled SOV and POOH and Inspect same. SOV was not shear, RU and RIH with a new SOV and Installed in GLM #1 at 2679 -ft. POOH and standback Slick -line. 16:30 16:45 0.25 0 0 COMPZ WELLPF PRTS T RU Testing Equipment and Test 3 1/2" Tubing. Still Unable to Test Tubing. Rig Down Test Hoses and RU SLick -line to check lower GLM 16:45 18:15 1.50 0 0 COMPZ WELLPF SLKL T RU D &D hole finder. RIH with slick -line down to top DS nipple 18:15 20:00 1.75 0 0 COMPZ WELLPF PRTS T On Depth with Slick -line test tools. RU and PT down TBG to find leak off area. Set Test Tool at 4902' 4869' 4800' 4300' 3800' 3300' 2800' 2600' 2100' 1600' 1100' 600' 100' all failed. Discuss Plan Forward with Town Engineer. 20:00 21:00 1.00 0 0 COMPZ EVALWE SLKL T PJSM, Rig Down Slick Line 21:00 22:00 1.00 0 0 COMPZ WELLPF HOSO T Remove Landing Joint. Install Side Port Isolation Sleeve 22:00 00:00 2.00 0 0 COMPZ WELLPF HOSO T Pull Hanger. Inspect, Clean, and Re -Dress Hanger. Find Dimples —1 inch below Bevel, Cement Debris on Hanger, and Chunks missing from O- Rings. Fluid Loss Today= 23 bbls. Fluid Loss to Date= 1393 bbls. 06/11/2012 Set and Test Storm Packer at 70', Nipple Down BOPs, Clean Hanger Bowl, Nipple Up BOPs, Shell Test 250/ 3000 psi -OK, Retreive Storm Packer,_ Land Hanger, PT Hanger PackOffs 5000 psi : OK, PT Tbq 1500 pnd Chart- OK, Shear SOV at 2400 psi and monitor 30 minute NFT- no flow. Prepare to RDMO. Page 22 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 WELLPF HOSO T Attempt to Re -Land Hanger, Still not Seating. Try to clean Hanger Bowl while waiting on Baker Storm Packer 03:00 04:00 1.00 0 70 WELLPF TRIP T LD Hanger and Landing Joint. Stand Back 3 Joints of Tubing and Pick up Storm Packer. 04:00 11:00 7.00 70 70 WELLPFTHGR T RIH and Set Storm packer at 70 -ft LD Tubing, PT Storm Packer to 500 psi. OK. Nipple Down BOP Stack. Found Cement sheet around and on the seating area for hanger, also the threads had cement on there profile area. Clean and Inspect Hanger Bowl. Make Dry run with Hanger, set good. Mark landing joint and LD same. 11:00 15:30 4.50 70 70 WELLPF NUND T PJSM. NU BOPE and Wash same. Set test plug and PT Test line and shell test BOPE to 250/3000 psi. Pull Test Plug. 15:30 18:00 2.50 70 70 WELLPF PULL T Pick up Storm Packer Retrieval Tool and Attempt to Pull Storm Packer, Unable to get screwed on due to Debris on top of Storm Packer 18:00 19:00 1.00 70 70 WELLPF OTHR T Wait on Cleanout Tools to from Baker. 19:00 19:15 0.25 70 70 WELLPF PULD T MU Wash Over Tool. 19:15 19:30 0.25 70 70 WELLPF FCO T RIH and Tag Packer and circulate 12 bbls HighVis Sweep off top of Packer. 19:30 19:45 0.25 70 70 WELLPF TRIP T POOH 19:45 20:00 0.25 70 70 WELLPF PULD T LD Washover Cleanout Tool and MU Snorkle Cleanout Tool to Washout inside Storm Packer Profile. 20:00 20:15 0.25 70 70 WELLPF FCO T RIH and Tag at 70', PU 1 ' and circulate 12 bbls HighVis Sweep 20:15 20:30 0.25 70 70 WELLPF TRIP T POOH 20:30 20:45 0.25 70 70 WELLPF PULD T LD Cleanout Tool and MU Strom Packer Retrieval Tool 20:45 21:00 0.25 70 70 WELLPF FISH T RIH and Screw into Storm Packer. 21:00 21:15 0.25 70 0 WELLPF TRIP T POOH 21:15 23:00 1.75 0 0 WELLPF HOSO T PU !single and Hanger, MU Landing Joint. See weight bobble when Elements enter SBR, RIH '-9' and Land Hanger, Up 72k# Down 62k #. Run in Lock Down Screws. PT PackOffs 5000 psi- OK. 23:00 00:00 1.00 0 0 WELLPF PRTS T Test Tubing 1500 psi and Chart for 30 minutes. OK. Bleed down to 0 psi and pressure up Tubing and Shear SOV at —2400 psi. Start No Flow Test. 06/12/2012 ND ROPE, NU Tbg_Head and Tree, Test Tree Packoff 50001si, Displace Well to Diesel, Install BPV, RDMO Page 23 of 24 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 WELLPF PULD P End 30 minute NFT- No Flow Detected. Lay Down Landing Joint. 01:00 01:30 0.50 0 0 WELLPF PULD P Remove Side Port Isolation Sleeve. Instsall Two -Way Check. 01:30 04:00 2.50 0 0 WELLPF NUND P Begin ND BOPs. NU Tree. 04:00 08:30 4.50 0 WELLPF PRTS P PJSM. RU testing equipment and test tree, Test fail, C/O TWC and Re -test to 5000 psi for 15 minutes and chart same. Test passed. Pull TWC valve. 08:30 10:00 1.50 WELLPF CIRC P PJSM with LRS and Nordic. Discuss hazard for pumping operation. RU + PT line, circulate 124 bbls of diesel down IA taking returns up TBG at 2 bpm until diesel was seen at surface. RDMO LRS and Blow down hardline. 10:00 10:30 0.50 WELLPF MPSP P Install CIW 3" Type 'H' BPV. 10:30 14:00 3.50 WELLPF DMOB P Clean Pits. PJSM RDMO 1D-110a, Release Rig at 1400 hours. Page 24 of 24 • 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT /CASTM /Plug Setting Record/Leak Detect Log: 1D -110A Run Date: 5/31/2012 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 1D -110A Data in LAS /DLIS format, Digital Log files, Interp Report, 3D Viewers 1 CD Rom 50- 029 - 22920 -01 ACE Log 1 Color Log 50- 029 - 22920 -01 AUG 0 3 201 CAST -M Field print 1 Color Log 50- 029 - 22920 -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: '"7 in �2- Signed: / Gti R. • • P 7,03 036/0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, June 08, 2012 9:10 AM 1? ' 6l6III To: 'Nelson, Erik Q' Subject: RE: Request regarding lowering of BOPE testing requirements on 1D-110A (PTD# 200 -039) (Sundry# 312 - 202)... Given circumstances as outlined in my message, and confirmed by your response below, AOGCC accepts the 3000psi tests of BOP rams and valves performed on KRU 1C -110A to date. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 'j Anchorage, AK 99501 JUL .Li 3 2014 907 - 793 -1236 From: Nelson, Erik Q [mailto: Erik .Nelson@lconocophillips.com] Sent: Thursday, June 07, 2012 3:29 PM To: Regg, James B (DOA) Subject: Request regarding lowering of BOPE testing requirements on 1D -110A (PTD# 200 -039) (Sundry# 312 - 202)... Mr. Regg, I called Mr. Schwartz and he directed me to send an e-mail to you requesting allowance for a lower BOPE test pressure on our workover of 1D-110A. As noted in your e-mail to Nordic's personnel this afternoon (07 June 2012) we did not have the approved sundry in hand when we performed our weekly BOPE tests. We were operating under a verbal authorization from Victoria Ferguson pending approval of a formal Application for Sundry Approval. Thus we tested to a pressure just above what is specified in the ConocoPhillips Well Control Manual for an MASP of 1190 psi not knowing that this fell below AOGCC's minimum BOPE pressure test requirements. All BOPE tests on this well from here out will be in accordance with the specifications of the approved Application for Sundry Approval. I appreciate you bringing this to our attention and thank you for your consideration of our request of this allowance. Erik Nelson Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #2040 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 1 i�(I.(, • • P 7CCo3 <c Regg, James B (DOA) From: Regg, James B (DOA) , h Sent: Thursday, June 07, 2012 2:22 PM 1 b 71/ y To: 'Nordic 3 Toolpusher'; Nordic 3 Company Man; Wedin, Ben (Nordic Calista) Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Subject: RE: Emailing: Nordic 3 6- 6- 12.xls Approved sundry requires BOPE test to 3500psi (you tested to 3000psi); appears from my records the sundry for KRU 1D -110A (PTD 2000390) workover was not approved until 6/5 and courier picked it up yesterday 6/6; so, you probably did not have the approved sundry in hand when performing 6 -6 -12 BOPE test. Spoke with Guy Schwartz and he required 3500psi BOPE test since there was no test pressure proposed in sundry application. 2 options as I see it: 1) request change to sundry for lower test pressure (3000psi), which appears justified based on planned well work, or 2) subsequent BOPE tests need to be done to 3500psi as required in approved sundry. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 Original Message From: Nordic 3 Toolpusher [ mailto :n1434(aconocophillips.coin] Sent: Thursday, June 07, 2012 4:56 AM To: DOA AOGCC Prudhoe Bay; Nordic 3 Company Man; Regg, James B (DOA); Brooks, Phoebe L (DOA); Wedin, Ben (Nordic - Calista) Subject: Emailing: Nordic 3 6- 6- 12.xls The message is ready to be sent with the following file or link attachments: Nordic 3 6- 6- 12.xls Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e -mail security settings to determine how attachments are handled. 1 • SlfAITE ALAS-1A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Senior Wells Engineer _ O �� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-110A Sundry Number: 312 -202 Dear Mr. Nelson: SLANIWE JuL 3 zo iz 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. Sincerel i/ o . or 4 � i t oner DATED this t? day of June, 2012. Encl. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED JUN 01 2012 01 June 2012 AOGCC Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to squeeze cement to plug off a leak in the 7 -5/8" casing on the Kuparuk Well 1D-110A (PTD 200 -039). Well 1D-110A is a sidetrack from the original 1D-110 motherbore. In September 1998, the well 1D-110 was drilled and cased as part of the West Sak 1D drilling program. Upon attempting a frac job, it was determined that the cement quality was very poor behind pipe and required a cement squeeze. The squeeze attempt resulted in a stuck retainer and the wellbore was temporarily abandoned. In August 2000, it was sidetracked 34' away from the original wellbore into the D, B, and A sands. In order to bring 1D-110A into compliance with ConocoPhillips Alaska's recently adopted policy of having two barriers between any energized fluid and • _ le . . - - ,..••• well ove in order to establish the required second barrier in the, • form of a packer. The ur ose of this workover was to remove the existing completion, letion , p ressure test the 7 -5/8" p p casing, and install a new electric submersible pump (ESP) completion with a feed -thru packer. This in itself does not require sundry approval. However durin• the course of th- • • kov-r (RWO) we inadvertently shifted a port collar and have been unable to shut it. Thus we have lost one of our tested barriers. In order to re- establish competency of the 7 -5/8" casing we plan on squeeze cementing the port collar. This should provide us with the required barriers and allow us • to bring the well back on production in a timely manner. Squeeze cementing the 7 -5/8" casing requires a Sundry. Therefore we are submitting this Application for Sundry Approval. If you have any questions or require any further information, please contact me at 263 -4693. Regards, d Erik Q. Nelson Wells Engineer CPAI Drilling and Wells STATE OF ALASKA RECEIVED f 7 AI DA A OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS JUN 0 1 2012 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell ' - Chan el QPQam r Suspend r Rug Perforations r' Perforate r Pull Tubing r Time Extension E Operational Shutdow n r Re -enter Susp. Well r Stimulate J°"` Alter casing jd - Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory j "' 200 - 039 • 3. Address: Stratigraphic r Service _ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22920 - 01' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 1D -110A " 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25650 . Kuparuk River Field / West Sak 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): 5905 • 4194 ` 5678' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' SURFACE 5148 7.625 5189' 3496' LINER 898 5.5 5905' 4194' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5363' 5394', 5428' - 5496', 5519' - 5566', 5591' - 5671' 3664' 3695', 3729' 3797', 3820' 3867', 3892' - 3972' 3.5 L -80 4908 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SC -2 GRAVEL PACK PACKER MD= 4990 TVD= 3316 BAKER ZXP MECH. ISOLATION PACKER MD =5007 TVD =3331 NO SSSV 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development i✓ Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/2/2012 Oil Gas (— WDSPL r Suspended f 16. Verbal Approval: Date: 6/1/2012 WINJ r GINJ r WAG r Abandoned C Commission Representative: Victoria Ferguson GSTOR r SPLUG i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson © 263 -4693 Printed Name Erik Nelson Title: Senior Wells Engineer Signature ,„,77.,..4...4.---7 Phone: 263 -4693 Date OAL/1P Z4 Commission Use Only Sundry Number: • / �C/ 12 -2 n2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test '' Mechanical Integrity Test r Location Clearance r 1 .0 7 Other: '- 35 0° r r , S ubsequent Form Required: i e l APPROVED BY Approved by: ' C• MISSIONER THE COMMISSION Date: a�i'/ Form 10-403 Revised 1/2010 7 ' 0 ` 1�! 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Scope of Remaining Work ♦ Set RBP below TAM port collar at 997' MD f/ ♦ Dump sand on top of RBP • Set cement retainer above TAM port collar • Squeeze cement into TAM port collar ♦ Pull cement retainer after WOC ♦ Mill up cement inside of 7 -5/8" csg down to TOS • PT 7 -5/8" csg to 1500 psi ♦ Clean sand off of RBP and pull RBP ♦ Run new 3 -' /2" ESP completion below a feed -thru pkre, General Well info MASP: 1190 psi Reservoir pressure/TVD: 1571 psi / 3806' TVD The Baker Guardian gauge was still functioning in this well. The well was SI when the pump went down on 04 February 2012. Pressure had built up and leveled off at 1300 psi at the gauge depth of 4864' MD (3192' TVD). Assuming a maximum seawater gradient below the gauge to the mid -pert depth of 5517' MD (3806' TVD), the maximum expected SBHP = 1571 psi, equivalent to 7.9 Ib /gal. 8.5 lb/gal seawater has . been more than adequate to keep this well static. Wellhead type /pressure rating: Vetco Gray Horizontal / 11" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: N/A — Single Csg Producer Well Type: Producer Estimated Start Date: 02 June 2012 Production Engineer: Suzanne Short RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophillips.com • • Proposed RWO Procedure: NOTE: Nordic #3 performed their weekly BOPE test on 30 May 2012 at 250/3000 psi. 24 -hr notification was given to AOGCC and the PT was witnessed by Matt Herrera. Squeeze cmt into TAM port collar: 1. TIH w/ RBP and set it — 1200 ft MD. Set wt down and pull wt to ensure it is set. 2. Dump — 20' sand on top of RBP (— 500 #s). 3. TOOH and MU cmt retainer. TIH and set cmt retainer -- 897 ft MD. Test backside to 1500 psi to ensure it is set. 4. Bullhead 8.6 lb/gal seawater down DP into port collar to establish injection rates. 5. Start cmt squeeze job as per SLB pumping supervisor: Cmt Req'd: 82 bbls ArcticSet 1 (AS1) Weight: 15.7 ppg Yield: 0.93 cuft/sk Mix Water: —3.6 gallons per sack 6. When there are 2 bbls cmt left above retainer un -stab DP from cmt retainer and PU one stand. NOTE: DO NOT go above 2000 psi injection pressure. If 2000 psi injection pressure is reached un -stab DP from cmt retainer, PU one stand and reverse circulate at max rate until returns are clean. 7. Reverse circulate — 50 bbls at max rate to clean up DP. 8. TOOH racking back DP. WOC to reach 1000 psi compressive strength (— 8 —10 hrs). 9. MU and TIH w/ cmt milling BHA. Gather free -spin parameters and begin m ling cmt to TOS. 10. Once TOS is reached TOOH racking back DP. k_ r NOTE: Notify AOGCC 24 -hrs prior to testing 7 -5/8" csg. �° 11. PT 7 -5/8" csg to 1500 psi. -3z) a. If csg passes PT proceed w/ RWO procedure. If it doesn't contact town engineer for plan forward. 12. MU and TIH w/ RBP retrieval tool. Iu ,, ; ° „ AD 13. Clean sand off top of RBP. Release RBF - and allow elements to relax. TOOH sideways w/ DP and lay down RBP assembly. 14. MU RBP retrieval tool and TIH on 3 -'/" 9.3# L -80, 8rd EUE -Mod tbg. 15. Release RBP and allow elements to relax. TOOH racking back 3 -W 9.3# L -80, 8rd EUE -Mod tbg and lay down RBP assembly. 3 - %" ESP Completion: �'�'" ` R P` 1. TIH with 3 -%" 9.3# L -80, 8rd EUE -Mod tbg ESP completion w/ feed -thru pkr. Space out so that btm of ESP completion is — 4907' MD and the feed -thru pkr is — 3096' MD. 2. Load tbg and IA with diesel and gelled diesel respectively. PT tbg and IA to 1500 psi. 3. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 4. Pull 2 -way check. Freeze protect well. Set CIW 3" Type 'H' BPV. 5. RDMO Nordic #3. Post -Rig Work: 1. Pull catcher sub and plug. Run pump, slipstop, and packoff. PT tbg to 1500 psi. Run DV and SOV in GLMs. PT tbg to 1500 psi. 2. Handover to Ops for startup of ESP. • • • Ferguson, Victoria L (DOA) From: Nelson, Erik Q [ Erik.Nelson @conocophillips.com] Sent: Friday, June 01, 2012 1:12 PM To: Ferguson, Victoria L (DOA) Subject: RE: Request for authorization to proceed with Sundry application and approval to follow regarding Kuparuk Producer Well 1D-110A (PTD# 200 - 039)... Thank you Victoria. I'm hoping to have that delivered to your office this afternoon. I appreciate your assistance on this. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #2040 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 From: Ferguson, Victoria L (DOA) jmailto:victoria.ferquson(a alaska.govi Sent: Friday, June 01, 2012 1:10 PM To: Nelson, Erik Q Cc: Norman, John K (DOA); Schwartz, Guy L (DOA) Subject: [EXTERNAL]RE: Request for authorization to proceed with Sundry application and approval to follow regarding Kuparuk Producer Well 1D -110A (PTD# 200 - 039)... Erik, You have verbal approval to proceed with a cement squeeze of a TAM port collar in the 7 -5/8" casing, Please submit a formal request for sundry approval(10 -403) as outlined below. Victoria Victoria Ferguson 1 " 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 1 • • From: Nelson, Erik Q f mailto: Erik.Nelson@conocophillips.comj Sent: Friday, June 01, 2012 10:55 AM To: Ferguson, Victoria L (DOA) Subject: Request for authorization to proceed with Sundry application and approval to follow regarding Kuparuk Producer Well 1D -110A (PTD# 200 - 039)... Ms. Ferguson, As per our phone conversation ConocoPhillips hereby requests authorization to proceed with a cement squeeze of a TAM port collar in the 7 -5/8" casing without an approved Sundry. The port collar was inadvertently shifted during previous rig operations and or attempts to shift it close have failed. Of the few remaining options an attempted cement squeeze is the only option we have available at this time in order to facilitate bringing this well back on to production. I am currently working on submitting a formal Request for Sundry Approval (Form 10 -403) but the rig will be ready to do the work before this can be approved and signed by AOGCC. Attached is a non - current schematic (i.e. the 3 -1/2" ESP completion has been removed) and a casing tally in order to assist you in visualizing what we are proposing. Thank you for your consideration of our request. Q Erik Q Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #2040 700 G. Street Anchorage, AK 99501 Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 2 z0Q-03 _ • • 2t C 2,7 LIG TRANSMITT ! L PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Shartzer 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 /j 50 JUL 12 LW 1) Leak Detection - WLD 26- Apr -12 3F-05 1 CD 50- 029- 21460 -00 2) Leak Detection - WLD 29 -May -12 1D-110 1 CD 50- 029 - 22920 -01 Signed : , •.../ Date : Co/t5A 2_ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245-8952 E -MAIL : PDSANCHORAGE CCd1,MEMORYLOG.COM WEBSITE : WWW.IVIEMORYLOG.COIVI D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips_Transmit.docx • ~ifEL~ LC"1G TR,~4/V~'/TTAL ,I. PIroAcrive DingNOSric SeRVicFS, INC. To: AOGCG Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE ; Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) MTT Report 20,1un-10 50-029-22920-01 2) MTT Report 20,1un-10 -o~~ 1 Q110A 1 Report 1 D-134 1 Report ~`~- itr Signed : 1.., Print Name: 50-029-22892-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: {907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchorageCaamemoryloa.com WEBSRE : www.memorvloa.com C:\Documents and Settings\Diane Williams\Desktop\Transmit_Conoco.doca L J Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-110A Log Date: June 20, 2010 Field: West Sak Log No.: 10639 State: Alaska Run No.: 1 API No.: 50-029-22920-01 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 188 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 BCTM Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 188 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Hanger @ 0'. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5° tubing, 7.625" surface casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 188'. Changes in metal volume are relative to the calibration points at 31' and 105', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 12% relative metal loss between the casing collar at 45' and the bottom of the conductor at 79' in the 10Hz pass. Over the same interval, the 8Hz pass indicates up to 10% relative metal loss and the 5Hz pass indicates a maximum of 4% relative metal loss. The spread in tool response at different logging frequencies over this interval points to the probability that the metal loss is spatially closer to the tool, and because the higher frequency passes show more metal loss response than the lower frequencies suggests the metal loss is from the inner strings of pipe rather than the conductor. The upper bound of the recorded metal loss extends past a tubing collar but stops at a casing collar leading to the conclusion the recordings predominantly represent metal loss to the surface casing rather than the tubing. No other significant areas of metal loss are indicated throughout the interval logged. Log plots of the entire 10Hz and 5Hz passes and an expanded log plot of the top 30' of the 5Hz pass are included in this report. A maximum -12% circumferential metal loss is indicated in the interval between 45' - 79' in the 10Hz pass. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5°, 7.625" and 16"pipe. If all of the metal loss is speafic to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: G_ Etherton Analyst: HY. Yang, M. Lawrence & J_ Burton Witness: 8. Boehme Yo:"~`.i'YE~' ~Ir3~i1C5tiC Se:"4`!~e`i, ?i`ii~. % t'' ~. Bc,t: 1 ~~~9 ~~a~`o'v ~'; . ~~}t? Phone: (~4~ o~ ,,S~t3) 555-908 Fay: ~81~ r~55-x359 E3rrEaif: P~?~~arr~emoryiog.con~ PI'il~j~na-Csa'p' ~ei~i li`~li;e P~~O~ ie: ~W `j-'~ ~35s'_^~n-~ ~t ;`i r ~-Z,_' -, ~v, Fax.: `~ ~l ~,_.1 ~~~u ~-a39 A o`~~wEus 5Hz, z and 10Hz Delta Metal Thi ess Passes Overlay Q~ A~~~ ~ N 1 D-110A June 20, 2010 PnoAcrirc Dinynosric Scaviccs Database File: d:lwarriorldatal1d-110\overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Mon Jun 21 17:11:03 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 Tubing 20 40 60 Joints Joint Delta Metal 10Hz Delta Metal 80 of 16" Delta Metal A o``~M~E~s Re rded Magnetic Thickness Lo Data - 10Hz Pass Q~ ~~~y !` 1 D-110A June 20, 2010 r~aa~~~~ o~,.tihos.~~ s~Rw~«s Database File: d:lwarriorldatal1d-1101passes.db Dataset Pathname: 10HzPass Presentation Format: 32 Dataset Creation: Wed Jun 23 08:41:51 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (%) 50 3.2 MTTP01 (rad) 0 Line Speed (ft(min} ?00 -5.6 MTTP12 (rad) ' Hanger _- ' 3.5 " Collar -- _ "' Line Spee -- Pups ~ --- : Delta Meta l Th ickness 3.5" Co llar ' Tubing Jt. 1 40 ' 7.625" Collar i .5" Co llar ~ 60 Tubing Jt. 2 12% Metal Loss , Bottom of 16" Conductor OV 5" Col lar ~ ' 7. 625" Col lar ~ Tubing Jt. 3 i 100 13.2 3.5" Co llar ' 625" Co 7 llar . .~ ' Co llar a 7.625" Co llar 3.5" Collar • 120 Jt. 4 140 160 Jt. 5 180 Delta Metal Thickness Tubing Jt. 6 Line Speed -50 Delta Metal Thickness (%) 50 0 Line Speed (ft/min} X00 i i i 3.2 MTTP01 (rad) -5.6 MTTP12 {rad) 13. 4. A o`~`"~E``s R rded Magnetic Thickness L Data - 5Hz Pass C~ ~c~ F- 1 D-110A June 20, 2010 PouAcrivc Dinynosric Scwviccs Database File: d:lwarriorldatalld-1101pas Dataset Pathname: 5HzPass Presentation Format: 18 Dataset Creation: Mon Jun 21 17:56:10 2010 Charted by: Depth in Feet scaled 1:15 ses.db 0 -50 Delta Metal Thickness (%) 50 1.8 ' 0 Line Speed (ft/min) ?00 -7 Tree Hanger r r ~ ~_ ~ Lin e S pee ' Pups De lta Meta l Thickness " 3.5 Co llar i 1 Tubing Jt. 1 7 625" Co llar . 3.5" Co llar 1 60 ' Tubing Jt. 2 4°I° Metal Loss Bottom of 16" Conductor 80 3.5" Collar 7.625" Collar MTTP01 (rad) 11.8 MTTP12 (rad) 3 Isolated Metal 1 -- Tubi .3 -- - 3 5" Co llar ~ . ' 120 I ~ 7 625" Co llar . Tubin Jt 4 g . r 140 3.5" Co llar ~ Tubing Jt. 5 160 i , De lta Meta l Th ickness ' 7.825" Collar Line S eed -50 Delta Metal Thickness (%) 50 0 Line Speed (ft/min} X00 180 1.8 MTTP01 (rad) 11.8 -7 MTTP12 {rad) 3 o`~"`WE"s E anded 5Hz Pass Magnetic T ~ckness Log Data C~ Agcy N 1 D-110A June 20, 2010 PIIOACCIV[ Dl.~.ynOSi1C SCRVICCS Database File: d:lwarriorldatal1d-1101expanded 5hzpass.db Dataset Pathname: 5HzPass Presentation Format: 18 Dataset Creation: Wed Jun 23 12:16:38 2010 Charted by: Depth in Feet scaled 1'60 -50 Delta Metal Thickness (%) 50 1.8 MTTP01 (rad) 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 Tree - _ - --- -- -- -- Hanger i --f ~._,_. _. , ~ , - ~~ _ } ,- - _ _- i ~ ~ I i - =----'_" ~_ - _ J i i i - ~ -- _- i ~ ~ ~ - i 4 1 I S 1 i ~ ~... Line S e d - _.. _. - - .~ = _ - ---- _ - ~ - ~~ - , ~ Pups _ I ~ 10 i r -- ~ r f D l M l T hi k e ta e ta c ness ~ f Pup f ~~ s f f ~ ~Z 20 5 '~ ` 3 5" Co llar ~ - . Tubing Jt. 1 t ' -50 Delta Metal Thickness (%) 50 1.8 MTTP01 {rad) 11.8 0 Line Speed (ft/min) -200 -7 MTTP12 (rad) 3 a ConocoPhillips Alaska, Inc. • KRU 1 D-110. 1D-110A ll T W PROD An le TS: de API: 500292292001 e: e TUBING SSSV T e: NONE Orig Co letion: 4/5/2000 Angle TD: 6 de 5905 (~~~ OD:3.500, Annular Fluid: Last W/O: 11/5/2003 Rev Reason: Set ESP Pump assembl , SOV ID:2.992) :_ Reference Lo 37' RKB Ref Lo Date: Last U date: 11/25/2003 Last Ta : 5500' ELM TD: 5905 ttK6 Last Ta Date: 7/28/2000 Max Hole An le: 67 de 2685 Casin Strin -ALL Descri tion Size To Bottom TVD Wt Grade Thread i CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE 7.625 0 5189 3485 29.70 L-80 BTCM SCREEN LINER 2.875 4932 5695 3984 6.50 L-80 EUE 8RD LINER 5.500 5007 5905 5905 15.50 L-80 BTC MOD CSG WINDOW 6.750 5157 5169 3467 0.00 from 1 D-110 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 4908 3231 9.30 L-80 EUE 8RD Perforations Summar Interval TVD Zone Status Ft SPF Date T e Comment 5363 - 5394 3652 - 3683 WS D 31 8 7/29/2000 IPERF 3-3/8" DP HSD, 41 B 5428 - 5496 3717 - 3785 WS B,WS A4 68 8 7/28/2000 IPERF 3-3/8" DP HSD, 41 B 5519 - 5566 3808 - 3855 WS A3 47 8 7/26/2000 IPERF 3-318" DP HSD, 41 B 5591 -5671 3880 - 3960 WS A2 80 8 7/22/2000 IPERF 3-3/8" DP HSD, 41 B Stimulations & Treatments Interval Date T Comment 5591 - 5671 7/23/2000 FRAC 167 M Ibs of 14/18 laced in A2 sand 5519 - 5566 7/26/2000 FRAC 141 M Ibs of 14/18 laced in A3 sand 5428 - 5496 7/28/2000 FRAC 133 M Ibs of 14!18 laced in A4 sand SEAL 5363 - 5394 7/30/2000 FRAC 147 M Ibs of 14/18 laced in D sand (~~~, Gas Lift Mandrels/Valves OD:5.130) GEARBOX St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt (4898-4900, 1 4009 250 7 Camco KBUG-M DMY 1.0 BK-5 0.000 0 11/3/2003 OD:5.250) 2 4783 312 2 CAMCO KBUG-M SOV 1.0 BK-5 0.000 0 1/19/2003 2000# Other lu s ui ., etc. -JEWELRY De th TVD T e Descri tion ID 37 37 HANGER TUBING HANGER SET 11/3/2003 3.500 3017 1963 CABLE Ra Chem Heat Trace Cable; 3017' len h 0.000 4862 3190 GAUGE GUARDIAN GAUGE, SET 11/3/2003 3.500 4870 3197 PUMP 3.5" TTC PCP PUMP, PACKOFF AND SLIPSTOP set 11/19/2003 0.000 4880 3206 NIP BAKER 3.5" Slotted Ni le Intake set 11/3/2003 2.867 4883 3209 X-OVER Centralift 3.5" TTC Crossover set 11/3/2003 2.867 PKR 4885 3211 SEAL Centralift Seal Section GSB3DBUTILH6PC92AFLAS/HSN SET 11/3/2003 0.000 (49~~933 4898 3222 GEARBOX Centralift Gearbox 9:1; 525 Series 0.000 OD:6.690) 4900 3224 MOTOR PCESP Motor 57 HP SET 11/3/2003 0.000 4906 3229 CNTRLZR Centralift Motor Centralizer SET 11/3/2003 2.000 4932 3252 PKR Model 'SC-1' Gravel Pack Packer; size 7682-40 4.000 SLEEVE ~ ~ 4941 3260 SLEEVE Baker 80-40 Gravel Pack Slidin Sleeve 4.000 (4941-4942, 5001 3314 SBE SEAL BORE 80-40 4.000 OD:5.800) 5007 3319 PKR Baker'ZXP' Mechanical Isolation Packer 5.500 5350 3639 SCREEN GRAVEL PACK SCREEN 2.441 General Notes Date Note 11/3/2003 TREE: 4 1/16" SM VETCO ESP TREE CAP CONNECTION: 7" OTIS PKR (50075008, OD:7.625) FRAC (5363-5394) Pert (53635394) FRAC !5428-549E'i) - ` .- !49GK ' ~ ~i~ °`M1 t~[i~~. ~ ~~'~ ~ 4.tQ ~'z~'~r -, ff *~ y r # ~ q, r r4l S~fs7Rl7~ ~'R~`~. ~ l ---,w.,~...,...«,.-f....Y._. ~....-..a.W.~.,..:...:..» R ~.~...,.....~:,......,..,m....,.~..-... .,4 ...,.~. _.___.__... _ .... _. - ... _. " ~~}6yd ~3~r~.: :t~'i$~Fi • ~ ' L;~1'r"i+C?i ~°)1+!'aQ, 1 ~-1 ~ 4r~ 1 Ft ~3il #° ~t41~t+if~ [3'~~~3; 1$F3+''10{~3 CCU' V4'~" t~~m~` 1L~ ~i~[3!i 3 . ' ~:~~y ~~¢l"i~ r sp ' p`y ! ?''M7~ r' ` yy pry~*)~y !~ ~9 ~1{.kPF Yi#t,ti9 ~i~(~. ~~. .~y w a 5..:. R, ryhj'.a. T ~~`'~.. ,p . ti ,.. _ .. . _..._ ,. G UTBn'Q~i ~~>1~~~~W~'~ S~ T~~r ~~, t C~t~+++: ~ ta M~" ~ y ~2:~ ~.=i:~ ;,fa`.~~ ~ ~n~ Q crt dx+r+ i ~ '4I~~f3 ~~ ~~ " t~ ~~7 ~F El+rra~n. 7~. 1~; {ft3 ~ {~m*eYt~{~ {LA} ~ r ! '~' ~~ { ~. c " ~..~,~µ ~g~~E Al+,a1 La~~. ~3 l4.~1 Ga [;u~t: _ t t~~ fl~~~ ~a~r~n ra ~«~ fir" ~,r-,;: „ a ~ ! .. a~~jg ti fF~~11~ ~~vTiRL®~8 1~~1$4 R.lN~ : • 1 is •#r_ay7'a~'t:x. 'M~N:.'a.Y foi.l,f '1~t'yljlR~ ; ~'~i~,F£au!t ~Q~ryI FlAtian'.~i 1,;;,w ~,r,.,vp ,.. '~ ~~ e~3.~ctY!!f k"kdx.'~'- 3T~+dl ~~°~~i~~,~ iaip " ~f?zar? i . ~ t?} ri_ ;.7 ~1 ~9~ .., ,.~.. ; i ~t~~~l~~'>~.~tr~fl~ ~~~~ ! i •~w,ra !~^:+ 'iti~'~?Jfi$ 4i~'~3+' Yt.~ ^qi $fi'?;n;r~} ,iTn Le's1'h l.i't~S I^~'~ ~C#~ ~syn f~~~~fu ~ f~atlNi 'ai.C;?Le ~~m..r i_.x t ; -. ' i { ~" •d ,w.' 6.~.;'~ F .L , 4~~v ~ ,~5 _ '.., ~ waYa i ~ 6~i ' ~. 8 t~+~m~%; ~ , p~ ~ ~.AEN:- Yy ~!' y ;, ~ p~~ ~Ak!' ~:: ` L~ ,' .t i *~ y~..d a<$+ ~.. p€! es r t~:r7, i 49,x+ y_;~ a.' ~'-1' ,a ~' , ~ 'a ~::. 4.4 a ~. °~:'', a z ~.~.b.°-~..o {; ., S 1 ~A+E ~e ,'4.. ~ ?. .,, ._ . ~. ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, AlÞ5KA 99510-0360 December 29, 2006 SCANNED JAN 1 6 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 d.öb·Oâq Dear Mr. Maunder: 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 by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water ±rom 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expandocement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cO~ Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-O 1 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 1 0-1 09 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13' 6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . PHilLIPS Alaska, Inc. A SUbsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 30, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 1 3 2ûDß Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for Phillips Alaska, Inc., wells CD2-47 (PTD 201-205, Sundry # 306-271), lD-llOA (PTD 200-039 Sundry # 306-249), and lD-lll (PTD 198- 166 Sundry # 305-072). The 10-404 Sundry on CD2-47 is for the installation of a K-Valve in the SSSV profile. The Sundry 10- 404's for both lD-llOA and lD-lll are post surface casing patch documentation. , Please call Marie McConnell/Perry Klein at 907-659-7224, or Jerry Dethlefs / MJ Loveland @ at 659- 7043 if you have any questions. Sincerely, . /..y /. ,A?, »,/_~ ~ /, >" .' .~.'/ .- /. iÿ" ; -- /. '-1 - ,I ~--~ j' /' //i/j~¿' '/# i7~ ~ I; MJ J¿'oveland f ;- çÓnocoPhillips Well Integrity Project Supervisor Attachments Ç)åD -Q'f) 1. Operations Performed: RECEIVED STATE OF ALASKA. SEP 0 6 20) ALASKA Oil AND GAS CONSERVATION COMMISSION ( 6 REPORT OF SUNDRY WELL OPERA TIONSaska Oil & Gas Cons. Commis . Abandon 0 Repair Well 0 - Plug Perforations 0 Stimulate 0 Other Anc~age Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-0391 ' 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22920-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1D-110A . .. 8. Property Designation: Kuparuk River Unit Apt. 2.'1 ¡'ÇO P'1''7'''(, 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool . Total Depth measured 5905' . feet true vertical 4194' feet Effective Depth measured 5905 feet true vertical 4194 feet Casing Length Size MD Structural CONDUCTOR 121' 16" 121' SURFACE 5089' 7-5/8" 5189' CSG WINDOW 12' 5-1/2" 5169' LINER 898' 5-1/2" 5905' SCREEN LINER 763' 2-7/8" 5695' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3485' 3467' 4194' Perforation depth: Measured depth: 5363-5394,5428-5496,5519-5566,5591-5671' true vertical depth: 3652-3683,3717-3785,3808-3855,3880-3960' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4908' MD. Packers & SSSV (type & measured depth) pkr= MODEL 'SC-1' GRAVEL PACK PACKER; SIZE 76B2-40; BAKER 'ZXP' MECHANICAL ISOLATION PACKER pkr= 4932'; 50 no SSSV no SSSV 12. Stimulation or cement squeeze summary: NA SE? 1 1 2006 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 0 0 0 400 250 Subsequent to operation 0 0 0 0 0 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0' Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10· Gas 0 WAG 0 GINJD WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-249 Printed Name Signature Title Phone 659-7043 Well Integrity Project Supervisor Date ORIGINAL fi ~tß 1·7·~ ~i9;JanIY · 1D-110A . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/20/2006 Loaded w/SW & Cut conductor window - Prep for Conductor removal & Surface Casing inspection. T/I= 200/350. Little Red pumped 290 bbls SW down T & fA. FP 2,000' down T & IA with diesel. Attached window cutter and removed a 20" X 16" window 7' below top of landing ring. Cut conductor off @ 9' below top of landing ríng for upcoming removal & inspection of SC. Removed cement inside widow, found good clean cement & pipe. Final T/I=200/350 8/22/2006IAOGCC ínspector Jeff Jones inspected casing damage, took photos 8/24/2006 Conductor Repair Prep, Purge N2 into IA. Initial T/I- SI/220, Purged 8 - bottles of N2 into the IA. Shot IA FL 150' Final T/I= SI/380 8/27/2006 Install 7' patch on SC, welders welded bands & QC had them checked - install & weld out SC patch. 8/28/2006NDE crack checked welds and insulators denso wrapped SC patch. 8/29/2006( Weld conductor patch) 8'6" of new conductor welded in place. -'¡' ConocoPhillips Alaska Inc; ID-II0A Surface Casing Repair e e ,((ù,., , ,'',IF' ',.',lÆ, '8" ,'V,I rr" ,\. - ·ü· ',' . 'U' lb' n\' Ii, '. ' ' \.!::.I U " , rmu' , ' rF~' . fi\ ~!II,' If=I," llJ,' ItQJ¡ In\ " h: f.J" ", ' " u ',(fù, rn,' (", , ri\,ð ;:;..' Uk \, ! º \ (Q) ¡Ût.{ù FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-110A Sundry Number: 306-249 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. "> .~"",- t-,.'¡' '-"-",-;, I ~ ~, t'~¡ ~GJ'\¡1t:\lbj ,! fh. / Sincerely, DATED thist~YOfJUlY, 2006 Enc!. ~cÞ·-o3'\ 87/23/2006 ()V3 9076597314 ~2.vb ý RECË1~E1' STATE OF ALASKA ~b~ JUL 2 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION . ., ission APPLICATION FOR SUNDRY APPROVA~laska Oil & Gas Cons. Comm Anchorage 20 AAC 25.2.80 NSK WELLS GR04iÞ 15:29 1. Type of R~uest AbandOn 0 SllSØ~nd 0 Opel'!lli0I1!11 $hlMown 0 i='erforate 0 Waiver 0 Otner 0 Alter C:<lSll1g 0 F!.epalr well 0' i='lug PerforatJol1S 0 Stimulate 0 Time Extension 0 Change approved program 0 i='un Tubing 0 Perforate New Pool 0 F!.e·f,!l1ter SU\\pended Well D 2. Operntor Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alsska, Inc. OevelQpment 0 ExplolBtory 0 200-039 ;,' 3. Address; StratigraPhic 0 Service 0 a. AFlI Number; P. O. Box 100360, Anchorage, Alaska 99510 50-029-22920-01 '" 7. If perforating. closest approach In pool(s) opened by this operation to nearest property line 8. Well Name and Number: wher. owner$hip or l~ndown.l'Ship changes: Spacing Exception Requires? Yes 0 No 0 1D-110A" 9. Property Designation: 1 O. KB Elevation (fI): 11. Field/Pool(s): K:uP$l\Ik River unit 4- /;> L ;2.5~S'V 'þÞ "7 2-'¡.:cCc RKB 100' Kuparuk River Fiêld I Wê$t Sail: Oil ÞOOI 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft); Total Depth TVD (ft): Eff~tive Depth MD (ft): Effective Depth rvD (ft): Plugs (measured): Junk (measured): 5905' 4194' 5905 4194 Casing Length SlzQ MD TVD Burst CQllapse CONDUCTOR 121' 16" 121' 121 SURFACE 5089' 7-518" 5189' 3485 CSG WINDOW 12' 5-112" 5169' 3467 LINER 898' 5-112" 5905' 4194- SCREEN LINER 763' 2-7/8" 5695' 39B4 Perforntlon Depth MD (It): Flerforatlon Depth ND (ft)~ Tubing Size: Tubing GrSde: Tubing MD (ft): 5363-5394. 5421M496, 5519.55£16, 5591-5671' 3852.3683,3717.3785, 36OS.3B55. 3SBIJ.39BO' 3-1/2" L-80 4908' Packers and SSSV Type: Packê~ and SS$V Mù (ft) pkï-' MODEL 'Sc-1' GRAVEL PACK PACKER; SIZE 76B2-40; B pkr= 4932'; 5007' no SSSV no SS$V 13. Attachments: Description Summary of PtOpO$sl 0 14. \/IIell CI~!¡¡!¡¡ after prgpQsed work: DQtalled Operations Pl'(gram 0 BOP Sketch D Exploratory D Development 0 Service 0 15. Estimated Date fQr 16. Well Status after proposed work; Commencing Operations: July 28, 200S Oil 0 - Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ D WDSPL 0 CommissiQn Representative: 18, I hel'E!by certify that the foregoing is true and CQrrect tg the best of my knowledge. Contact: McConnÐlI/Klein Printed Name ~ Dethlefs D-~~~ Title: Problem Well Supervisor Signature -- 0:.. -- - ~ C- Phgne 659·7043 Date ~h ~ i1¿ ~ / CØA1'mission Use Only , Sundry Number: 4P\.J' r1t . Conditions of approval: Notify Commission so that a rE!pr.$E!n\$tive may witness ~O... 7'" , , Plug Integrity 0 sOP Îest 0 Mechønicallntegrity Test 0 Location Clearnnce 0 Other; c..c,,~' 1:~~L.\o~, o~~~~~ \0 \{'..~~~\- SO~~ç., ~ Subsequent Form Reql,lire<: '-\C) ~ ~, . ~ O~ \"-~~(èL~'\~"- \ ~~\, '(7)I~ o~ Approved by; .-1 ~ A APPROVED BY 'lft17ðé COMMISSIONER THE COMMISSION Date; Fonn1~03_"d06l2OërR \ õfN Ä R8DMS 8Ft JUt 2 5 2UGS Submit ¡f, Ol,lj1>ate . .' j '/' q(-~ ~ ~ct5 87/23/2006 15:29 9076597314 e NSK WELLS GR04íÞ PAGE 03 ConocoPhillips Alaska, Ine. Kuparuk WelllD-llOA (PTD 200-039) SUNDRY NOTICE 10-403 APPROVAL REQUEST July 23,2006, This application for Sundry approval for Kupamk well 1 D-ll OA is for the proactive inspection and possible repair of the production casing near surface. This well is a single casing producer that has no surface casinK It was completed in 2000 and has been produced by ESP and gas lift, This well is in an area that has a high incidence of casing leaks to suri'ace and is directly adjacent to injection wells ID-109 and 111 which had confirmed leaks, 1D-11OA has shown no signs or indications of a production casing leak, however ConocoPhilIips requests approval to pro actively , excavate.... 10', remove the top portion of conductor and inspect the production casing. If damage is present a patch wìll be ìnstalled. With approval, repair of the production casing wîl1 require the following gen.eral steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well as needed and load the tubing a.nd IA with the appropriate weighted brine and diesel freeze protection cap, 3. Remove the floor grate and equipment from around tbe wellhead. 4. Install nitrogen purge equipment for the conductor (and lA if needed) so that hot work may be co,nducted in a safe manner. 5. Cut away the conductor casing and remove cem.ent around surface casing for inspection. 6. Notify the AOGCC Inspector for opportunity to inspect the exposed ca,sing. 7. CP Al Mechanica.l Engineers will determine if patcb or repair is needed to return the casing to operational integrity. 8. If a patcb is required, QA/QC wíll verify the repair for a. final integrity check. 9. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to production service, 13. FHe 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 7/23/2006 B7/23/2005 15:29 ,.." TUBING (()'49œ, OD:3,500, IO:2,99;¡j SEAL (48e54'198, OP:5,1301 GEARBOX (4898-4900, OO:5,2iiO) PKR (4932-4933. OD:6,690) SLEEVE (4941-4947., OD:5.BOD PKR ~&J07~ooa, OD:7.625) 9075597314 e COOOcQPhHUps AI.ska~ Inë. " ¡ ~ ",'I;' , , 11.1 . ,. . .. . " :.:. ;';" ".' ... "::::1 ". """.." ....'. . riT" ',',' ,", ,', ......." ..,....... ~;g" :~~¡Wt=m~1 .........'......" ..,......,.,...'. .:.::.........;,....' .. FAAC .!f,i. . (5m.5394} ~ ~ Perf ~" ~. ra3Q,ì~4 Fi ~ FRAC ~ ~ 1565496) ~~ 1D410A; I API: 500292292001 $$$V T\i)I!!: NoNE Annular Fluid: Reference Log: 37' RKB Last Taa: 5000' ELM Last Tag Date: 712812000 Caslnèi StririiCi .. Au.. ; · . De5lcrll:ltlon CONPUCTO" SURFACE SCREEN LINER I.INER CSG WINDOW ,1'Ubil'l\:!·strina·...ruBING :" Size I TOD $.500 I 0 . Pilil1l:1fatloht: $Wmmärv" Interllal Tl/O ~e3 - 5394 :;¡e52 " J6æ 5428 - 5496 3717 - 3785 '. NSK WELLS GR04iÞ KRU . . .. . .. ...... .... .... ........ .. Well Tvee: PROD Orid CQniblétÏQh: 41S12oo0 L.ast WlO: 11/5/2003 Ref l.,oa tIIIte: TD: 5905 ftKB Max Hole Anale: 67 deg @ 2685 PAGE 04 , ....."..... .... .... , " ..... .........................., .... 1D·110A Anale rm TS; d- e Anllle rm TD: 6 deD C 5905 RIW Reason: Sét ESP Pump assémblv. SOV L::Ist U cclate: 11/2St2003 ., .... , '" ....",... ".. ...,.... ,,,.. ....................,...", . ........... "."., . ...... ....... ..... . ".................... . ",. SIlO 1 MOO 7.625 2.875 5.500 6,750 TI::":' o o 4932 5007 5157 Bottom 121 5189 5695 5905 5165' TvO 121 34SS 3984 sacs 3467 'Nt 62.58 29.70 8.50 15.50 0.00 Grade H·40 L·ao 1.-60 1.-S0 Thread WELDeO STCM eUE 8RD arC MOD from 1 D-110 ..",,,,..,.., .". '''' ".. ..,.., , . ..... . .. .. . ................. ............... I Bottom I I 4908 I I Wt I Brade I I 9,30 I L-BO I ".".", ,,,,..,,.... TVC 3231 Thread i:uE 8RD Zone WSD Ws e,ws A4 ws A'J WSA2 .. "".............. .. '", ,I, .. " .. ".... ............ ... , '" "" ..."",,,,,,, '"'' ,,,,. SPF Date Type Comment 8 712912000 IPERF 3-3Ifr' DP H$D 418 13 712812000 IPERF 3·318" DP HSD. 41B 8 712512000 IPERF 3-3IB" DP H$C 41B 6 712212CCO IPeRF 3-318" DP HSD 41 B '" .. , ' TIIbe FRAC FRAC FRAC FRAC Comment 167 M Ibs of 14/18 claced in A2 aand 141 M Ibs of 1411S clacéd ÏI'I A3 SBhd 133 M Ibs of 14/18 Dlaeêd In A4 $;IU'Id 147 M 11:1$ Qr 14/1& I:Ilaced in D sand ",. ... .. . H . .. . .. ...... TR.O O..œ Vlv Run Cmnt 111312003 1/1912003 2000# 5519 - 55t!16 :;Iaoe - 3ass 5591 - 5671 3880 - 3eeD ;StittJulätiölià. & TnYtM!nts' , ' nterv=-' D~t~ S591 . 5671 7123/2000 5519 - 5566 712612000 5428 . 5496 712812000 5363·53S4 713012000 GII$' LlftM:andNiI!:No1lVéii. . St MI) TVI) Man Man I)/pe V Mfr Mfr 1 4009 ~07 Cameo KBUG·M 2 4783 3122 CAMCO KBUG·M 'OthÍ!H1 II.IU 'e UiD,,,·etc. -JI5W~L~Y Depth TVC Tvee 37 37 HANGeR 3017 1963 CABL.!:; 4862 3190 GAUGE: ~ 'J197 PUMP 4S8O 3208 NIP 4Sa3 3209 X·OVER 4885 3211 SeAL 4898 3222 GEARBOX 4900 3224 MOTOR 4901.1 3229 CNTRLZR 4932 3252 PKR 4941 3250 SLeEVE 5001 3314 SSE 5007 3319 PKR 5350 :'3639 $CREEN :~ener31.Not.5: . . . Date I Note 111312003ITRee: 41/1e" 5M VETCO ESP I TReE CAP CON NECTION: 7" OTIS StatUI! pt 31 as .. ., ...... . ...." o o DueriDticn TUBING HANGER SET 111312003 R~vCh(lm Heat fraeê Ç"þlé' 3017 lendth GUAROIAN GAUGE SET 1113/2003 3.5" TTC PCP F'UMP I='ACKOFF AND $I.IPSTOP Ge! 1111912003 BAKER 3.5" Slot\er:l NII)"'o InÞkê SC,lt 11/312003 Cel1trBlift 3,5" TIC Crossover !IC!t 11/3/2003 CC,lntrallft sur $oaction GSB3DBUTILH6PC92AFI..AS/H$N SET 111312003 Cêntrallft Géarbox 9:1' 525 Series PCESP Motor 57 Hi=' SET 11/312003 Centra 11ft Motor COI'1tr=-IIZtf SET 11/312003 Model'SC-1' Gravel Pack ~ekllr' $Izo 7aB2.40 a;.kil>r e0-40 Gravél Pack Slidin.. SleeVl! Sf;;AL. SORE 80.40 Baker 'ZXP' MClleh:lnl=ll~orration Pec:kér GRAVEL PACK SCRE:EN 47 eo ..",,,.,, "'''' '''' ,,,.,,,,,,..... "... . .......... "..... ......,.,..,.. , .. V Type LiMY SOV VOD Latch 1.0 1.0 8"'·5 BK-5 ...... . ...".. .... Port 0.000 0.000 ....... . ..... ..., .......... II) 3,500 0,000 3.500 o .oeo 2.8137 2,&67 0,000 0,000 0.000 2.000 4.000 4.000 4.000 5,500 2,441 , . ,.. . , . e e Thomas Maunder wrote, On 7/25/20067:29 AM: Jerry, I agree that it is a good idea to inspect and take precautions on this well and others as you are able. I also agree that it is probable that all the single casing wells will be excavated and inspected/repaired. Good luck, dCJO -(J ~ ~ Tom \ NSK Well Integrity Proj wrote, On 7/24/2006 4:50 PM: Tom: Up to this point we have been digging individual wells. Sloughing to a certain degree encroaches on the neighboring wells, but we have been able to control that fairly well. We just started using insulation blankets to cover the walls and that seems to help a lot. 10 pad has a long history of subsidence and sinkholes, etc., so it does not surprise me it is fairly unconsolidated. By excavating both sides of 10-11 OA it really slumped a lot--just to square up the hole most of the fill around the well needed to be removed. The main benefit of looking at this well now while it is exposed is that we will not have to dig it up later for inspection and possibly degrade the "rebuild" we have done on the neighboring wells. Doing the whole thing as a package is just common sense. But common sense sometimes goes counter to the way things really work around here! Getting the internal approvals for this is considerably harder than digging the well up. With luck there will not be any corrosion at all, but we will also have the opportunity to wrap the casing and provide protection so that it will never happen in the future. I think it is likely that over time we will dig up and inspect all of the single casing wells. At least by doing so we can ensure they are protected for the future. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 '·c~t\I\.¡II..t:.:r\ 0C-' ? {; ?r .~ ·nð·t~~~'.ò'J.' \),~ ~ ,~~ ,) ~J -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, July 24, 2006 8:22 AM To: NSK Well Integrity Proj Subject: Re: West Sak welllD-llOA casing inspection Jerry, On the "big dig", is this the first time that you have excavated wells so close together? Probably not surprising that ID-IlOA needed to be exposed as well. Tom NSK Well IntegrityProj wrote, On 7/23/2006 4:06 PM: Tom: As per my fax, attached are supplemental documents for the 10-403 request to inspect the casing on 10-11 OA. These may be easier to read than the faxed version. I have not included the 10-403. I would appreciate an email or verbal approval on the request, the paperwork can be sent back snail mail. Thanks for the help! «1D-110A.pdf» «1D-110A 10-403 SC inspection Discussion 07-23-06.doc» 7/25/20067:34 AM 07/23/2006 15:29 9076597314 e NSK WELLS GROUP e PAGE 01 It PO BQX 100360, NSK 6Q Anchorage, AK 9951 0 ConocoPhillìps Alaska, Inc. I ~ Fax To: Tom Maunder From: Jeny Dethlefs Fax: 276-7542 Pages: 4 Phonø: 793~ 1250 Date: 7/2312006 Re= 1o.110A Casing Inspection cc: 1:1 Urgent [J For Review 1:1 Please Comment x PI.._. R.-ply r:J Please Recycle Tom: Attached is a 10-403 for West Sak well 1 D-110A. The request is for approval to cut and remove 1he conductor for inspection of the casing. During the excavation of 1 D-109 and 1 D~ 111 (which are on both sides of 1 0-110A) the gravel was very unconsolidated and completely sloughed in. Consequently, we had to excavate around 1 D-11 OA to complete the excavations on the other two wells. Since the casing is already excavated we would like to take the opportunity for an inspection of this casing as well. 1 D~110A was secured and the flowline dismantled for the work on the other two wells. No ,,/ further safeout is required for the operation to continue. The details of our proposal are the same as the others and are attached in the Sundry Discussion document With approval it is our intent to work on this well right after the others, which could be within a week from now. Expediting your approval is appreciated. Please note I am faxing one copy of this package. I am also sending the attachments again via email (no 10-403). Please let me know if you have any questions. Jerry Dethlefs ConocoPhillips Alaska, Inc. . . Guy Schwartz Senior Wells Engineer Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 July 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West y'h Avenue Suite 100 Anchorage, Alaska 99501 Subject Application for Sundry Approval, West Sak 1 D-11 OA Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak well 1 D-11 OA. 1 D-11 OA was sidetracked in March of 2000 due to the Qoor cement job in the initial wellbore which prevented the well from being fracture stimulated properly. 1 D-11 OA was sidetracked 34' away from the mother wellbore's BHL and fractured in each of the four targeted West Sak zones. The well was completed with gravel packed screens and a TIC-PCP for artificial lift. 1 D-110A has had three pump failures to date. The first two failures were fixed by simply running a new pump on wireline. When the well started to experience problems again in August of 2001, a new pump was again run and set, but it failed to lift the well. After additional diagnostics it was determined that the motor had failed. 1 D-110A was brought-on-line with gas lift in January of 2002. The well is currently producing up the 7 5/8" x 3 W' annulu~. Due to the failed heat"trace, MeOH must be pumped twice a day while gas lifting to keep this well from freezing off. This workover will pull the broken TTC-PCP completion, run new heat trace and TTC-PCP completion in the well. The procedure for this workover also includes a casing pressure test and a USIT log to evaluate casing integrity after 21 months of annulus production. The data from this and the other 3 West Sak workovers is critical in determining how West Sak workovers and motor failures are handled in the future. If the casing fails to pressure test or if the USIT indicates serious casing damage, then the workover will be suspended. If you have any questions or require any further information, please contact me at 265-6958. Sincerely. Lj ~Za? Senior Wells Engineer · CPAI Drilling and Wells GLS/skad OR' h' t\f ð L . . ~~ - STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~ ~ ~ (,'\. 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 Alter casing 0 Repair well ~ Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-039 ./ 3. Address: Stratigraphic 0 Service 0 6. API Number: ./ P. O. Box 100360, Anchorage, Alaska 99510 50-029-22920-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1D-110A 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5905' 4194' 5500' ELM 3789' 4832' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121 ' 121' SURFACE 5089' 7-5/8" 5189' 3485' LINER 898' 5-1/2" 5905' 4194' SCREEN LINER 763' 2-7/8" 5695' 3984' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5363'-5394',5428'-5496',5519'-5566',5591'-5671' 3652'-3683',3717'-3785',3808'-3855',3880'-3960' 3-112 " L-BO 4910' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= MODEL 'SC-1' GRAVEL PACK PKR; BAKER 'ZXP' MECH ISO PKR pkr= 4932'; 5007' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 11, 2003 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name Guv Schwartz Title: Senior Wells Engineer Signature q~ S:--/ _d-- Phone Date '7-/? ðJ / .,,/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry NU305 ..,q " Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ~ 5'C!.J ~ .'. ~\~ '\ 'N;. ~ ,"" ~'\>-\<ts~ "- :':>- Subsequent Form Required: YO L\ RBDMS BfL jUl 2 1 'lU03 ~ ~ß^, R".-j-1/1/ BY ORDER OF 7//r3jtJ3 Approved by: ~ COMMISSIONER THE COMMISSION Date: \ I l [ l ,."."'- , I Form 1 0-403 Revised 2/2003 . 0, \ I SUBMIT IN DUPLICATE . . West Sak ID-ll0A GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. 5-7 days before RWO, RU Slick Line Unit. RIH and pull OV from GLM @ 4788' leaving an open pocket. Pull Packoff and KOBE Knockout. 2. Kill well by pumping down tubing, taking returns up the annulus. 10.1 ppg KWF is expected. 3. Set BPV in tubing. 4. Prepare Location for Nabors 3S: Remove well house(s) , check tubing hanger LDS's, Test tubing and casing packoffs. GENERAL WORKOVER PROCEDURE: 1. MIRU Nabors 3S. Lay hard-line to tree. 2. Verify if well is dead. If not circulate well with appropriate KWF based on surface pressure. Install BPV. 3. ND tree/ NU BOPE. Function test BOPE. Pull BPV. Install test plug. 4. Test BOPE to 5000 psi. Pull test plug. 5. Screw in landing joint ( 4.909 MCA thread connection). POOH standing back 3-1/2" tubing and spooling up ESP Cable and Heat Trace (BOT gauge wire is embedded in the power cable). 6. . RIH with retrievable bridge plug on 3 W' tubing. Set at 4900 ft and release from plug. Test casing to 2500 psi for 30 min. POOH standing back 3 ¥2 tubing. 7. Inspect wellhead and annular valve for erosion. 8. RIH w/RBP latch and casing scraper assembly. ~'''';' ;.. 9. Cleanout (reserving out) to 4900', relatch packer and release. POOH with plug. 10. PU and RIH wÆline USIT casing inspection log. 11. RIH w/ 3-1/2" tubing and TTC ESP Assembly. Space out heat trace and splice power cable. 12. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 13. ND BOPE /NU Tree !fest. 14. Freeze protect with diesel to +/- 2000' TVD. Set BPV. RDMO workover rig. Lower Limit: Expected Case: Upper Limit: 4.0 days 5.0 days 7.0 days No problems encountered. Problems pulling ESP completion, Space out problems and control line issues. GLS 6/30/03 PHILLIPS Alafa, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY . KRU 1Ð-110A TUBING »>i ,.>"....".".,.,'.".".....,..... ,.,d,·.',i.. >.......»... » ""'>i (()491 0, API: 500292292001 Well Type: PROD An¡¡le @ TS : deo ía) 00:3.500, SSSV Type: NONE Orig 4/5/2000 Angle @ TO : 6 deg @ 5905 10:2.992) Completion: Annular Fluid: Last W/O: Rev Reason : Reset OV, set packoff/KOBE by ImO Reference Loa: Ref Loa Date: Last Update: Last Taa: 5500' ELM TD: 5905 ftKB Last Taa Date: 7/28/2000 Max Hole Angle: 67 deg @ 2685 4L >id i.ii d ,...,.".........."...,.".".,.. '·.d"·.'>d· Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED PACKOFF SURFACE 7.625 0 5189 3485 29.70 L-80 BTCM SCREEN LINER 2.875 4932 5695 3984 6.50 L-80 EUE 8RD (4832-4833, LINER 5.500 5007 5905 5905 15.50 L-80 BTC MOD 00:3.500) CSG WINDOW 6.750 5157 5169 3467 0.00 from 10-110 iTi ,..i.. » Ti » ......'. ,.,.",.,.,.",',.' ",. ,..,..,."."., """ .......... NIP Size I Top I Bottom I TVD Wt I Grade I Thread (48834884, 3.500 I 0 I 4910 I 3233 9.30 I L-80 I EUE 8RD 00:3.500) » "",ii:> .i,d. ,.".".,',',i:i:> .·.:·..·,,·,::i Interval TVD Zone Status Ft SPF Date Type Comment 5363 - 5394 3652 - 3683 WSD 31 8 7/29/2000 IPERF 3-3/8" DP HSD, 41B X-OVER 5428 - 5496 3717 - 3785 WS B,WS 68 8 7/28/2000 IPERF 3-3/8" DP HSD, 41B (488&4887, A4 00:3.800) 5519 - 5566 3808 - 3855 WSA3 47 8 7/26/2000 IPERF 3-3/8" DP HSD, 41B 5591 - 5671 3880 - 3960 WSA2 80 8 7/22/2000 IPERF 3-3/8" DP HSD. 41B ,.,i'".,:iii....·.... ...i.'. ··'>".".:ii SEAL Interval Date Tvpe Comment (48884889, 5591 - 5671 7/23/2000 FRAC 167 M Ibs of 14/18 placed in A2 sand 00:5.130) 5519 - 5566 7/26/2000 FRAC 141 M Ibs of 14/18 placed in A3 sand 5428 - 5496 7/28/2000 FRAC 133 M Ibs of 14/18 placed in A4 sand GEARBOX 5363 - 5394 7/30/2000 FRAC 147 M Ibs of 14/18 placed in D sand (4901-4903, .......... ......>Tii >, "'.·i » ii""'i 00:5.250) St MD TVD Man Man I V Mfr V Type I V OD I Latch Port I TRO I Date I Vlv Mfr Type Run Cmnt 1 4788 312 6 Cameo KBMM-2 I Cameo I OV I 1.0 I BK 0.188 I o I 9/25/20021 (1\ MOTOR 1. NO CHECK (49034910, IVlner ..""... ......."..,...>.' "i.'...». .....ii .'.,......'....',..' >','i"iiT 00:5.620) Depth TVD Type Description ID 3017 1963 CABLE RayChem Heat Trace Cable; 3017' length 0.000 4831 3163 SLlPSTOP 3" SLlPSTOP SET ON TOP OF PACKOFF 9/25/2002 2.992 CNTRlZR 4832 3164 SPACER 2.10" X 12' SPACER PIPE set 9/25/2002 1.350 (491()4911, 4832 3164 PACKOFF K-3 PACKOFF PLUG W/KOBE EQUALIZING SUB & KNOCKOUT SPACER 1.350 00:6.750) PIPE set 9/25/02 4883 3209 NIP 3.5" Slotted Nipple 2.875 tc:1 4886 3212 X-oVER Centralift 3.5" TTC Crossover 3.500 PKR 4888 3213 SEAL Centralilt Seal Section GST3 4B IL H6 PFS 0.000 (4932-4933, 4901 3225 GEARBOX Centralilt Gearbox 9: 1 ; 525 Series 0.000 00:6.690) 4903 3227 MOTOR PCESP Motor 57 HP 1315/26 KMH 0.000 4910 3233 CNTRLZR Centralift Motor Centralizer (Baker Sentry Gauge@4801' MD, 3190' TVD) 0.000 SLEEVE 4932 3252 PKR Model 'SC-1' Gravel Pack Packer; size 76B2-40 4.000 4941 3260 SLEEVE Baker 80-40 Gravel Pack Sliding Sleeve 4.000 (4941-4942, 5001 3314 SBE SEAL BORE 80-40 4.000 00:5.800) 5007 3319 PKR Baker 'ZXP' Mechanical Isolation Packer 5.500 5350 3639 SCREEN GRAVEL PACK SCREEN 2.441 PKR (5007-5008, 00:7.625) FRAC I (5363-5394) ~ ~ Perf (5363-5394) FRAC { (5428-5496) F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~~~ .... ". .to,.:.&. _.. .... Mike Mooney Wells Group Team Leader Drilling & Wells Cono cÓPh ¡IIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 6,2004 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 10-11 OA (APD # 200-039) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 10-11 OA. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )It. IJ(~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 13 2004 ~ 0" & Gas Cons Commission A\asl\3 , . Anchorage r:¡:'(-'.{', t~~Þ..nEtn \1 fH\.~\ "11 5i 2004 ",~~!r\IJ~~~..,tI,.!, ,.,}Ii'~ll'! J" ~ OR\G\NAL 1. Operations Periormed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon Alter Casing 0 0 0 Suspend 0 RepairWeli 0 Pull Tubing 0 Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 37' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE LINER SCREEN LINER Perforation depth: measured true vertical measured true vertical Length 121' 5089' 898' 763' 5905' 4194' 5500' ELM 3789' Size 16" 7-5/8" 5-1/2" 2-7/8" Operation Shutdown 0 Plug Periorations 0 Periorate New Pool 0 4. Current Well Status: Development 0 Stratigraphic 0 feet feet feet feet MD 121' 5189' 5905' 5695' Measured depth: 5363'-5394',5428'-5496',5519'-5566',5591'-5671' true vertical depth: 3652'-3683',3717'-3785',3808'-3855',3880'-3960' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2" , L-80, 4910' MD. no production packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 22 72 47 68 15. Well Class after proposed work: Exploratory 0 Development 0' Service 0 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Guy Schwartz @ 265-6958 Mike Jv1ooney ¡fA I ¡¡/ ~ I""T¥I... 'v .. ;~\:;:-.¡" 'NIM " W'IJI" Form 1 0-404 Revised 2/2003 . Contact Printed Name Signature Oil-Bbl 235 268 : JMltJ I Title Phone \G\NAL Perforate 0 Variance 0 Annular Disp. 0 Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 200-039/303-192 6. API Number: 50-029-22920-01 Exploratory 0 Service 0 9. Well Name and Number: 1 0-11 OA 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool Plugs (measured) Junk (measured) 48321 TVD Collapse Burst 121' 3485' 4194' 3984' RECEIVED JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage Casino Pressure Tubino Pressure 233 233 - - WDSPLD Wells Group Team Leader, J 7 2 Date 1/12/0 1 Prenared bv Sharon AII.~un-Drake 263-4612 SUBMIT IN DUPLICATE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ConocoPhillips Alaska Operations Summary Report 1 D-11 0 1 D-11 0 WORKOVER/RECOMP Nabors3SCompanyM@conoco Nabors 3S 00:00 - 05:00 From - To Hours Sub Code Code Phase 10/26/2003 10/27/2003 10/28/2003 05:00 - 07:00 07:00 - 08:30 08:30 - 11 :00 11 :00 - 18:00 18:00 - 19:00 19:00 - 20:30 20:30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 18:00 18:00 - 18:30 18:30 -19:00 19:00 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 06:00 06:00 - 12:00 5.00 MOVE 2.00 MOVE 1.50 MOVE 2.50 MOVE 7.00 MOVE 1.00 MOVE 1.50 MOVE 1.50 MOVE 0.50 WELLS 1.50 WELLS 5.50 WELLS 0.50 WELLS 2.00 WELLS 3.00 WELLS 1.00 WELLS 1.50 WELLS 0.50 WELLS 4.00 WELLS 0.50 WELLS 0.50 WELLS MOVE MOVE MOVE MOVE SFTY MOVE MOVE MOVE MOVE MOVE RURD MOVE SFTY MOVE RURD WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR 1.50 WELLS NUND WRKOVR 2.00 WELLS NUND WRKOVR 1.50 WELLS SEaT WRKOVR 6.00 WELCT BOPE WRKOVR 6.00 WELLS EaRP WRKOVR Page 1 of 5 Start: 1 0/26/2003 Rig Release: Rig Number: Spud Date: 9/25/1998 End: 11/3/2003 Group: Description of Operations PJSM on rig move with all contractors on location. Secure all service lines and loops. Prepare pad around wellhead. Prepare to scope derrick. Scope and lay down derrick on carrier unit. Blowdown steam. Prepare pit module and move pits away and stage down pad. Pre-Spud meeting with Drilling/Wells Rep G.M. Chaney, Rig Crew, Tool Pusher, Company Reps, Centrilift, Vetco-Gray, Tech Limits.CPAI Drilling/Wells Safety Rep. Review well plan and operational procedures. Move pipe shed away from rig. Prepare and move rig carrier off well 1 D-140. Move carrier down pad. Move Annular and Double Gate BOP and set on mat behind well. Level gravel around well. Set spare 4-1/16" 5 Ksi valve behind well. Lay mats around well. Line up and back over well to check positioning. Pull off well. Lay Herculite under back of carrier. Back rig carrier over well, center up, and jack up and level carrier. Move pipe shed into place. Move pits into place. Prepare to raise derrick. Pre-spud meeting with Drilling/Wells Rep. G.M.Chaney. Rig crew and contractors in attendance. Review well plan and operational procedures. Raise derrick. Hang ESP and heat trace cable sheaves off derrick. Scope up top section of mast.Hook up power lines and turn on derrick lights. Tighten load lines, Raise windwalls, Tighten stablizer lines. Hook up flow line, choke and kill lines, reverse circulating line, and stand pipe manifold. M/U circulating flanges on tree and wellhead. Take on filtered 10 ppg Brine into pits. R/U circulating hoses on tree and annulus. Test choke line, kill line and choke manifold to 250-3500 psi. M/U hi-pressure lubricator on tree. Grease leaking annulus valve. Pull BPV, R/D hi-pressure lubricator. SITP=50psi, SIAP=300 psi. Circulate down tbg with 10 ppg brine taking returns to open top bleed tank. Rate 120 spm (3.5 bpm) 80 psi.Pump a total of 345.5 bbls brine, lost 130 bbls to formation during displacement. Monitor well, loss rate @ 1.5 BPH. Blow down choke, R/D circulating lines. Pump brine to MI filtration unit. Blow down transfer lines to outside tar1ks. R/U lines to fill hole. PJSM on ND tree and NU BOP stack in cellar. NU BOP stack in cellar. Hook up koomey lines. Monitor well loss rate 10 bph. Set BPV with T-bar. MU fill up line on annulus. PJSM on ND tree. Possible leaking penetrator on tubing hanger. Discussed contingencies on removing tree and setting BOP stack. ND tree, Inspect tubing hanger. No visual leaks observed. Retest tubing hanger body to 5000 psi. Inspect running threads on tubing hanger. NU BOPE, MU choke and kill line. NU riser and flowline. MU 3-1/2" landing jt. into tubing hanger. Fill stack. Pressure test BOPE to 250/3500 psi. Continue filling hole every 1/2 hr. Loss rate at 3-5 bph. Test BOPE to 250/3500 psi. Test annular to 3000 psi. Test witnessed by Jeff Jones, AOGCC Field Inspector. Penetrators in hanger holding test pressure, so far. Flange leak on choke manifold. Break out leaking flange on choke manifold. Found adapter flange at Printed: 12/15/2003 1:17:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 0/28/2003 10/29/2003 Page 2 of 5 ConocoPhillips Alaska Operations Summary Report 1 D-11 0 1 D-11 0 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S 06:00 - 12:00 From- To Hours Sub Code Code Phase 6.00 WELLS EaRP WRKOVR 12:00 - 14:00 14:00 - 15:00 15:00 - 22:30 22:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 06:00 06:00 - 07:30 07:30 - 10:30 10:30 - 11 :30 11 :30 - 16:00 16:00 - 17:00 17:00 - 23:00 23:00 - 00:00 2.00 WELLS RURD WRKOVR 1.00 RIGMNT RSRV WRKOVR 7.50 WELLS EaRP WRKOVR 1.50 WELCT EaRP WRKOVR 2.00 WELCT BOPE DECOMP 0.50 WELCT NUND DECOMP 0.50 WELCT SFTY DECOMP 3.00 W~LCT CIRC DECOMP 1.50 WELCT DECOMP 3.00 WELLS TRIP DECOMP 1.00 WELLS SFTY DECOMP 4.50 WELLS PULD DECOMP 1.00 WELLS PULD DECOMP 6.00 WELLS PULD DECOMP 1.00 WELLS PULD DECOMP Start: 1 0/26/2003 Rig Release: Rig Number: Spud Date: 9/25/1998 End: 11/3/2003 Group: Description of Operations Super Choke with deep corrosoin pits in ring groove. Locate replacement Super Choke, spacer spool, and adapter flange in Anchorage and on slope. Tool Pusher picked up same in Prudhoe and Deadhorse. RU spooler for heat trace line. RU containment trunk for ESP cable. RU rig floor camera for ESP spooler. Service rig. Install replacement adapter flange, Super choke, and spacer spool in choke manifold. Make necessary adjustments to fit. Make up flanges. Continued filling annulus to monitor well. Hole taking 5 Bbls every 30 minutes. Note: Decision made to reduce brine weight in pits to 9.8 ppg for hole fill to reduce losses. Decision also made to increase NTU limit to about 50 NTU to reduce filtration requirements. Note: Lost 144 Bbls from 0000 hrs to 1800 hrs, 8 Bbl/hr avg. Reduced wt. of fill-up fluid to 9.8 ppg. Lost 47 Bbls from 1800 hrs to 2400 hrs, 7.8 Bbls/hr avg. Test replaced equipment and all broken flanges in choke manifold to 250 psi and 3500 psi, OK. Witnessing of test waived by Jeff Jones & Chuck Scheve, AOGCC Field Inspectors. LD landing joint. Monitor well, still taking fluid. Offseat BPV, OK. Pull BPV with T-bar. Fluid level in tubing falling. Set two-way check with T-bar. Test blind rams and kill line to 250 psi & 3500 psi, OK. Witnessing of final test waived by Jeff Jones & Chuck Scheve, AOGCC Field Inspectors. Pull two-way check. Set isolation sleeve in hanger. RD circulating hose from annulus. MU landing joint. RU circulating hose to landing joint. PJSM on pulling hanger into 13-5/8" spool and circulating brine around well. BOLDS. PU and pull hanger free at 72K#, continue PU at 52K#. Pull hanger up about 3' into drilling spool. Break circulation. Getting foamy crude oil returns, divert into pit #3. Stop circulating to line up to ship crude out of pit #3 to open top kill tank. Resume circulating, divert foamy crude into pit #3 and transfer out. Estimate 35 Bbls of fluid sent to kill tank, foamy crude and some brine. Continue circulating into pits, reducing brine returns to 9.8 ppg. 3 BPM, 250 psi. Monitor well. Took 5.6 Bbls fill in 1 hr 10 min. Prepare to POOH with ESP completion assembly. PJSM on pulling ESP, tubing and heat trace. Pulled hanger to floor. Disconnected penetrators from ESP cable, heat trace and Century Guages. Laid down hanger and short pups. Pulled cables through sheaves and attached to spoolers. When temp. came up ice was falling from derrick. Shut down and chip ice from derrick to eliminate falling ice hazards. POH standing back tubing, strapping out, spooling up ESP cable and heat trace. Removing clamps and lowering into pipe shed. Keeping hole full, losses are 5 to 6 bbls per hr. Removed sling on sheave for heat trace. Installed longer sling to lower heat trace sheave down inside wind walls. Continued to POH standing back tubing, removing Cannon clamps, spooling up heat trace cable, and ESP cable. Heat trace cable terminated on bottom of stand #48. Strap tubing. Hole taking 4 to 5 Bbls/hr extra fill. Unstring tail of heat trace cable from sheave and finish spooling up cable. RD heat trace cable sheave and clean oil off same. LD cable Printed: 12/15/2003 1:17:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10/29/2003 23:00 - 00:00 10/30/2003 00:00 - 01 :00 01 :00 - 04:00 04:00 - 06:00 06:00 - 11 :00 11 :00 - 17:00 17:00 - 19:00 19:00 - 20:30 20:30 - 22:30 10/31/2003 22:30 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 16:30 16:30 - 19:00 ConocoPhillips Alaska Operations Summary Report Page 3 015 1 0-11 0 1 0-11 0 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S DECOMP spool and sheave into pipe shed. Clear last of clamps off rig floor. Clean up rig floor and prepare to continue POOH. DECOMP Clear and clean rig floor. Transfer 10.0 ppg brine from tanks to rig pits and water back to 9.8 ppg. DECOMP Continue POOH with 3-1/2" ESP completion assembly, spooling up ESP cable with I-wire. Stand back tubing (SLM = -3.99'). Hole took 7.8 BPH extra fill. LD pups, slotted nipple, and ESP seal section, gearbox, motor, and centralizer. Motor appears siezed up. Unstring ESP cable from sheave and let cable down to ground and spool up. Removed all jewelry from ESP equipment, and laid down. Rig down both spoolers. Cleaned up all equipment that came out of hole and removed from pipe shed. Clean rig floor and prep to run casing scraper. Set wear bushing. WRKOVR PU & RIH with 7-5/8" Baker dual casing scraper on the pulled 3-1/2" tubing to 4895' (4910' Rig 245 RKB). Lost 14 Bbls on trip in hole. WRKOVR Break circulation to clear crude off the top, then reverse circulate one hole volume to clean well. 3 BPM, 240 psi. No significant change in returns at bottoms up. Crude continues to break out and float to surface. Lost 40 Bbls while reversing. 1.50 WELLS CIRC WRKOVR Monitor well, flowing back, appears charged from losses while reverse circulating. Circulate bottoms up conventionally, no sign of influx at bottoms up. 2.00 WELLS OTHR WRKOVR Monitor well, fluid level falling, hole resumed taking fluid. Transfer brine from tanks to rig pits for trip out. Skim oil off pits. Hole took 6.5 Bbls to fill, 3.25 Bbls/hr. 1.50 WELLS TRIP WRKOVR POOH. 3.00 WELLS TRIP WRKOVR POOH. LD casing scrapers and steam clean. Clear rig floor and clean up. Hole took 8 Bbls/hr excess fill. 1.00 WELLS PULD WRKOVR Strap & caliper Baker Retrievamatic test packer. MU test packer on 3-1/2" tubing. WRKOVR RIH with slow with Baker Retrievamati packer to 4895'. Up wt. 39k dwn wt 27K. RU circulating head & hose, circ. tbg vol.43 bbls 2 BPM 100 psi. Set packer at 4895'. Pressure tested to 2500 psi for 30 min on chart. Release packer and circulate hole clean @ 2.5 BPM 150 psi. POH with Baker Retrievamatic test packer. Held Pre-job Safety meeting with E-line crew. Discussed rig up procedures and hazards associated with rigging up and running e-line. Installed 7" shooting nipple and rigged up Schlumberger lubricator. MU tool string to run USIT log. RIH with tool string and run USIT log. Finish USIT Log. PJSM. RD Schlumberger e-line and lubricator. Clear and clean rig floor. WRKOVR Pull wear bushing. Clean and send down to pipe shed. CMPL TN Prepare to run ESP completion. Load clamps back into pipe shed. String rope thru sheave and pull ESP cable thru and tie off at rig floor. Bring heat trace cable on spooler to rig floor (3000' cable). Set ESP motor and Gear Reducer on rig floor. 1.00 CMPL TN SFTY CMPL TN Rig floor Pre-Job Safety Meeting with all hands and service company personnel. Discussed proper shut-in procedure with cables beside the string. Went over completion assembly running order and planned 1.00 WELLS 1.00 WELLS 2.00 WELLS 4.00 WELLS 2.50 LOG CIRC DEOT CIRC PULD PULD 19:00 - 00:00 5.00 LOG ELOG 11/1/2003 00:00 - 00:45 0.75 LOG ELOG 00:45 - 02:30 1.75 LOG RURD 02:30 - 03:15 0.75 WELLS RURD 03:15 - 06:00 2.75 CMPL TN RURD 06:00 - 07:00 Start: 10/26/2003 Rig Release: Rig Number: Spud Date: 9/25/1998 End: 11/3/2003 Group: Description of Operations WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR WRKOVR Printed: 12/15/2003 1:17:56 PM ,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ... From.. To 11/1/2003 06:00 - 07:00 07:00 - 12:00 12:00 - 12:30 12:30 - 16:00 16:00 - 19:00 19:00 - 00:00 11/2/2003 00:00 - 06:00 06:00 - 09:00 09:00 -11:30 11 :30 - 13:00 13:00 - 13:30 13:30 - 18:00 18:00 - 20:30 20:30 - 21 :00 21 :00 - 00:00 11/3/2003 00:00 - 00:30 00:30 - 03:00 Page 4 of 5 ConocoPhillips Alaska Operations Summary Report 1 0-11 0 1 0-11 0 WORKOVER/RECOMP N abo rs3SCo m panyM @ co noco Nabors 3S ... .. Sub Hours Code Code Phase ... ... 1.00 CMPL TN SFTY CMPL TN 5.00 CMPL TN RUNT CMPL TN 0.50 CMPL TN DEOT CMPL TN 3.50 CMPL TN RUNT CMPL TN 3.00 CMPL TN RUNT CMPL TN 5.00 CMPL TN RUNT CMPL TN 6.00 CMPL TN RUNT CMPL TN 3.00 CMPLTN SOHO CMPLTN 2.50 CMPL TN SOHO CMPL TN 1.50 CMPL TN SOHO CMPL TN 0.50 CMPL TN NUND CMPL TN 4.50 CMPL TN NUND CMPL TN 2.50 CMPL TN NUND CMPL TN 0.50 CMPL TN DEOT CMPL TN 3.00 CMPL TN RURD CMPL TN 0.50 CMPL TN RURD CMPL TN 2.50 CMPLTN CIRC CMPLTN Start: 10/26/2003 Rig Release: Rig Number: Spud Date: 9/25/1998 End: 11/3/2003 Group: Description of Operations procedure. MU motor centralizer, ESP motor, gear reduction unit, seal section, TIC Crossover, Slotted Nipple w/ 2 tubing pups and Baker Guardian Guage Assembly. Installed MLE cable and instruments to ESP assembly. Surface test MLE cable and instrument lines. Well taking fluid @ 4-5 BPH. RIH with ESP completion on 3-1/2" tubing. Inspect threads and drift tubing with 2.867" rabbit. Installed 2 GLM, one between jts 2 and 3 and the other between jts 26 and 27. Installing Cannon cable clamps on every other collar. Insulator on end of Heat Trace had been cut off with knife. Rigged down the 3000' Heat Trace Spool and rigged up the 2935' spool. As per Raychem end heater needs to be sealed. MEG new heat trace cable, attached same 65' higher, at 11' above pin end of Joint #59 (bottom single on Stand #30). Continue RIH with ESP completion on 3-1/2" tubing in stands. Drift each stand with 2.867" rabbit. Install new seal rings and inspect threads on each stand. Installing Cannon mid-joint clamps and dual channel cross coupling clamps to secure ESP power cable with TEC cable and heat trace cable on every joint. MEG test cables every 14 stands ( approx. 875'). 48 stands run @ 2400 hrs, 76 stands total to be run. Hole continues to take 4 to 5 Bbls/hr. Continue RIH with ESP completion on 3-1/2" tubing in stands. Drift to 2.867", Install new seal rings, and check threads on each stand. Installing Cannon mid-joint clamps and dual channel cross coupling clamps to secure ESP cable with TEC cable and heat trace cable on every joint. MEG test cables every 14 stands (approx. 875'). Space out with 3-1/2" EUE pups jts. M/U Vetco/Gray tubing hanger. M/U landing jt. Orient tubing hanger to alignment pin. M/U Heat Trace to penetrator in tubing head. Megger cable. Make final splice of ESP power cable to penetrator. Megger cable. Land hanger. RILDS. Close pipe rams and test top side of tubing hanger and penetrators to 3500 psi, OK. LD LJ. Set BPV. RD riser. Disconnect Koomey lines, choke line, and kill line. Break down & ND BOPs into 3 chunks for rig move; Annular, Double Gate, and Spool with DSA. Set Annular and Double Gate on mat behind rig cellar. NU Vetco-Gray tubing head adapter and 4-1/8" 5 Ksi valve and tree cap. Test hanger, packoffs, and penetrators to 5000 psi, 10 minutes, OK. Pull BPV. Set TWC. Test tree to 5000 psi, 10 minutes, OK. Pull TWC. NOTE: Inspected, cleaned, serviced, and tested tree at valve shop when pulled off well. MEG test ESP and heat trace lines. RU lines to tubing wing valve and annulus valve to displace and freeze protect well. RU from rig choke manifold to outside lines to tanks. RU & test lines to displace well. Blow air through line to open top tank to verify it's clear. Tie in Little Red Services. Test lines to 2500 psi. Circulate sea water down tubing, taking returns thru rig manifold to outside open top tank. Circulated at 1 BPM initially, getting about 1/2 BPM returns of thick crude for first 50 Bbls pumped. Then got brine returns and increased rate to 2.5 BPM, with full returns. Got seawater Printed: 12/15/2003 1:17:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/3/2003 ConocoPhillips Alaska Operati onsSu m maryReport Page 5 of 5 .. ... 1 0-11 0 1 0-11 0 WORKOVER/RECOMP Nabors3SCompanyM @conoco Nabors 3S From - To Hours Code~.. cfoUJe Phase , .. 00:30 - 03:00 03:00 - 04:00 04:00 - 05:30 05:30 - 06:30 Start: 10/26/2003 Rig Release: Rig Number: Spud Date: 9/25/1998 End: 11/3/2003 Group: Description of Operations .. ... ' 2.50 CMPL TN CIRC CMPL TN returns after 210 Bbls pumped and continued circulating seawater to 290 Bbls pumped. Recovered about 160 Bbls of brine from well. Final circulating pressures 180 psi pump, 90 psi at open choke. Switched to Little Red and reverse circulated 100 Bbls of diesel into annulus, taking seawater returns thru open choke to open top tank. Shut in tubing and bullheaded 20 Bbls diesel into annulus to flush brine away from motor assy. Shut down, initial annulus pressure 675 psi. Connect jumper hose from annulus to tubing. Open valves and let diesel equalize. RU lubricator. Set BPV. RD lubricator. Tubing had 400 psi. Blowdown & RD lines. 400 psi on Tubing and Annulus. Removed 1502 flange and installed blank flange on tubing outlet. Secured well. Release rig from operations on well 1 D-11 OA @ 06:30 hrs. on 11-03-03. 1.00 CMPL TN OTHR CMPL TN 1.50 CMPL TN OTHR CMPL TN 1.00 CMPL TN OTHR CMPL TN Printed: 12/15/2003 1: 17:56 PM TUBING (0-4008, 00:3.500, 10:2.992) SEAL (4885-4898, 00:5.130) GEARBOX (4898-4900, 00:5,250) PKR (4932-4933, 00:6.690) SLEEVE (4941-4942, 00:5.800) PKR (5007-5008, 00:7.625) FRAC (5363-5394) Perf (5363-5394) FRAC (5428-5496) ConocoPhillips Alaska, Inc. II i . ;.... 1D-110A API: 500292292001 SSSV T e: NONE Annular Fluid: 5519 - 5566 5591 - 5671 3808 - 3855 3880 - 3960 KRU 1D-110A PROD 4/5/2000 11/5/2003 Last U date: Size To Bottom TVD Wt Grade Thread 16.000 0 121 121 62.58 H-40 WELDED 7.625 0 5189 3485 29.70 L-80 BTCM 2.875 4932 5695 3984 6.50 L-80 EUE 8RD 5.500 5007 5905 5905 15.50 L-80 BTC MOD 6.750 5157 5169 3467 0.00 from 1D-110 Zone WSD WS B,WS A4 WSA3 WSA2 T e Comment IPERF 3-3/8" DP HSD 41B ¡PERF 3-3/8" DP HSD, 41 B 47 80 8 8 7/26/2000 IPERF 3-3/8" DP HSD, 41B 7/22/2000 IPERF 3-3/8" DP HSD 41B Interval 5591 - 5671 5519 - 5566 5428 - 5496 5363 - 5394 Date T e 7/23/2000 FRAC 7/26/2000 FRAC 7/28/2000 FRAC 7/30/2000 FRAC Comment 167 M Ibs of 14/18 laced in A2 sand 141 M Ibs of 14/18 laced in A3 sand 133 M Ibs of 14/18 laced in A4 sand 147 M Ibs of 14/18 laced in 0 sand St Man Man Type V Mfr Mfr 1 4009 2507 Camco KBUG-M 2 4783 3122 CAMCO KBUG-M Otherlu s e . ui . etc.- JEWELRY,' De th TVD T e 37 37 HANGER 3017 1963 CABLE 4862 3190 GAUGE 4870 3197 PUMP 4880 3206 NIP 4883 3209 X-OVER 4885 3211 SEAL 4898 3222 GEARBOX 4900 3224 MOTOR 4906 3229 CNTRLZR 4932 3252 PKR 4941 3260 SLEEVE 5001 3314 SBE 5007 3319 PKR 5350 3639 SCREEN General Notes " Date Note 11/3/2003 TREE: 41/16" 5M VETCO ESP TREE CAP CONNECTION: 7" OTIS MD V Type Latch Port TRO Date Vlv Run Cmnt BK-5 0.000 0 11/3/2003 BK-5 0.000 0 11/19/2003 2000# VOD DMY SOV 1.0 1.0 Descri tion TUBING HANGER SET 11/3/2003 Ra Chem Heat Trace Cable' 3017' len th GUARDIAN GAUGE SET 11/3/2003 3.5" TIC PCP PUMP PACKOFF AND SLiPSTOP set 11/19/2003 BAKER 3.5" Slotted Ni Ie Intake set 11/3/2003 Centralift 3.5" TIC Crossover set 11/3/2003 Centralift Seal Section GSB3DBUTILH6PC92AFLAS/HSN SET 11/3/2003 Centralift Gearbox 9: l' 525 Series PCESP Motor 57 HP SET 11/3/2003 Centralift Motor Centralizer SET 11/3/2003 Model'SC-1' Gravel Pack Packer' size 76B2-40 Baker 80-40 Gravel Pack Slidin Sleeve SEAL BORE 80-40 Baker 'ZXP' Mechanical Isolation Packer GRAVEL PACK SCREEN ID 3.500 0.000 3.500 0.000 2.867 2.867 0.000 0.000 0.000 2.000 4.000 4.000 4.000 5.500 2.441 Im'- Œ,\ ~- j LJ 1 a)l-Cft 12/08/03 Schlumbepger NO. 3057 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 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 Color CD '.'" 3B-01 ~ ~ .c:;-OSI INJECTION PROFILE 11/24/03 1 1 L-09 ¡c ¡C '-~ :d~ ~L LEAK DETECTION LOG 11/26/03 1 1C-119 ;..., ~O ""- ¡~q INJECTION PROFILE 11/27/03 1 1 C-121 ~ lð --c r')-xt) INJECTION PROFILE ~ 11/30/03 1 1 D-110A 10709648 USIT - \')\" ~ \.. c ("'~\õ .Ù1..Sì~\. u-:.\ \ \:O'7~tl3 10/31/03 1 Ct 1 D-140L 1 10709639 USIT \ I 10/22/03 1 2P-432 ~m'"tJ4 \ SLIM SONIC LOGGING TOOL 11/21/03 1 \ 2P-432 10687658 US IT 11/16/03 1 .. I .. ~r::r .t: 1\ It: I ~ ; I 'L-~ 'L-I VL-I~ ( SIGNE~""~t5\~lt ;;:"'~"'\. C ~ ~ ~/\~ . \ DATE: D~,C 1 2 2003 Aiaska Of! & Gas Cons, Commiøion Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.Anoboœge RßSJ ~'- ~ (~"C-',! 1i\\\!I.,.U:;:!\" ~D' r:((>¡ C) ~\ f')lìO""n ('d>~,?i.!\~IJ'tIlÇ;L ~.., ~~ ÜJ Q]J 'M LU J ", Ke: vves[ ~aK vvorKovers Subject: Re: West Sak Workovers Date: Tue, 04 Nov 2003 07:11:50 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Schwartz, Guy L" <Guy. L.Schwartz@conocophillips.com> CC: "Mooney, M" <M.Mooney@conocophillips.com>, "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> Guy, et al: t ~ ~(~)1~.., \'~ ~ Thanks for bringing over the USlT log on 1D-140. I concur with your assessment of the log. It did not appear that there was any wall loss and a pattern suggestive of the original mill marks was evident. You also provided the report sheets for the boroscope inspections and the Schlumberger engineer's assessment of the log. You emailed me the log for 1D-110A. I agree with ConocoPhillips' proposal to eliminate the casing inspection logs in 1 D-102 and 1 D-129, subject to the assessment of the condition of the tubing and any other factors that would lead one to believe that conditions in one of these wellbores is different than the initial wells surveyed. Based on choosing what you believed were the worst case wells based on annular production time and the flow rates should have given ConocoPhillips the most conservative inspection. I will place a copy of this message in the respective well files. Please call me with any questions. Tom Maunder, PE AOGCC ~, ~'~ - \1;~ '~. ~ "Schwadz, Guy L" wrote: ~ -~ ~ ~ ~ > Tom, > As per our conversation today regarding the ongoing West Sak ESP workovers I wanted formally state the results and discuss further diagnostic procedures. > The wells we have completed are first 1D-140 and 1D-110A. These two wells were chosen to be the first in our set of four workovers due to the longer duration of annular flow with these > wells. It was felt that if the casing and wellhead diagnostics looked favorable that further work on the following two wells (1D-102 and 1D-129) could be re-addressed and possibly reduced in scope. > > Results to date: > 1D-140: Borescope of the wellhead showed no wear or erosion. Inside of the wellhead and VR threads looked to be in "like new" condition. > The 7 5/8" casing was pressure tested to 2500 psi and held solid. > A USIT corrosion log was run overthe entire 7 5/8" casing and showed that it was in very goodcondition. Milling marks were still very visible on the inside of the tubing and virtually no wall loss was seen. > > ID-110A The borescope of the wellhead also showed the wellhead and 2" valve and VR to be in like new condition. > The 7 5/8" casing tested to 2500 psL > USIT corrosion log showed the 7 5/8" casing to be in great shape. > > As a prudent operator we are proposing we continue to pressure test the 7 5/8" casing on the remaining workover wells but discontinue the borescope and USIT log. If conditions warrant change such as corroded tubing being pulled out the remaining two wells we would of course re-look at running the USIT log. > > Thanks foryour consideration, > > Guy Schwartz > > Drilling and Wells Engineer > office: 907-265-6958 > AT0-1548 ,, · l of 2 11/4/2003 7:12 Ar~ ABB Vetco Gray Boroscope Inspection 1 D- 110 ~X 10/21/03 The inspection was conducted by, NSK corrosion, DHD, and Vetco Gray Representatives. The inspection started at the 3 V2" tubing. Due to swabbing grease out of the valve an accurate inspection was not possible. The ID of the wellhead, 2 1/16" Annulus bore was in like new condition, showing no evidence of erosion or rounding. The machined finish of the well bore was also in like new condition and showed no sign of corrosion or pitting. The VR threads also appeared to be in like new condition, sharp and defined. Summary - Inspection through 2 1/16" AV bore showed no sign of erosion corrosion. pitting or metal loss, and appeared to be in like new condition at the time of inspection. Mark Jensen AAB VetcoGray 659-2821 L4uarterly liowline inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1 D-121: PTD 1971810, Sundry #302-304 1 D-127: PTD 1981090, Sundry #353-057 1D-129: PTD 1972130, Sundry #303-092 1D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: ID-110 Insp Log.xls)(See attached file: 1D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1 D-140 InspeCtion Log.xls) Type: EXCEL File (application/msexcel) .,E?.C.O.d,!.n g !,,?a.,s._e.6,4 ..................... ~ ........ ~L~' ' ~' ¢ ~1D-102 Insp Lo.q.xls Name: 1D-102 Insp Log.xls Type: EXCEL File (application/msexcel)t Encoding: base64 ,/ 1D-105 Inspection Loq:x.!s Type: EXCEL File (application/msexcel) Encoding' base64 Name: 1D-110 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Type: EXCEL File (application/msexcel)il Encoding: base64 il 1 D-127 Inspection Log.xls Name: 1D-127 Inspection Log.xls Type: EXCEL File (application/msexcel)l t Encoding: base64 "~' ~ '~ 10/6/2003 3:17 PM (2uarterly llowline inspection repods --~ 1 D-129 Inspection Loq.xls Name: 1D-129 Inspection Log.xls t Type: EXCEL File (application/msexcel)/. Encoding: base64 .~~ 1D-140 Inspection Lo.q.xls Name: 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 !of 2 10/6/2003 3:17 PM 1D.IlOA Special Inspection Request Log DS1D 'lD-110A I~_-_ ........... - 2 in. Annulus flowback inspection JMonthly inspection frequency approved per e-mail from Warren Dobson on 4129/02. B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection B, I, N Worst Case Damage Grade Comments Inspection Locations Wall Loss % -- -- 01/18/02 4 B 0% A Baseline inspection UT Insp only -- NO change to UT inspection locations extablish 02/02/02 10 N 0% A baseline by RT additional inspection locations 02/10/02 5 I 12% B Possible Erosion damage 5 0% Damage noted on 2/10/02 inspection turned out to be variation in thickness of the fitting (geometry). 02/13/02 N A Radiograph shows no damage to fitting. __ -- 03/01/02 5 N 0% A No Change ..... 03/04/02 10 N 0% 30 day RT follow-up of inspection locations no A damage due to erosion noted on radiograph 03/~8/02 5 N 0% A No Change 03/18/02 5 N 0% A No Change _03/25/-0-~ 5 ........ ,. __ N--' 0% A No Change 10 0% 30 day RT follow-up of inspection locations no 04/01/02 N A damage due to erosion noted on radiograph 04/08/02 ~ .... N 0% A No Change 04/15/02 5 N 0% A No Change 04/22/02 5 N 0% A No Change 04/29/02 5 N 0°~o "' A No Change / Inspection to be performed monthly __ ,, 05/28/02 5 N 0% No Change by UT - No RT performed due to A personnel safety due to drilling rig in the area --~'/¥4/-~2 14 N 0_~/o A No Change b.y_ UT or RT on inspection locations. 07/23/02__ 14 N __ 0% A __. No Change by_UT or RT on inspection locations. 08/24/02 0% Line shut in 8/24/02 No Inspection scheduled until further notice New well house piping configuration - New baseline 10/08/02 9 B 0% A established in well house piping. No changes in existi n_g_pi_pi n__.g. 11/04/02 6 __ N .. 0% _ A ' No Change b_y_ UT or RT on inspection lOCations. 12/05/02 6 I~ 0% A No Change by UT or RT on inspection locations. 01/29/03 6 N __ 0% ...... _A ................ _N o __c h .a_n.._.g_e__b...y._...U__.T___.o_r....~.T..9._n_.!_n...s... _p_e__c_..tj_o_n_ I_o__c ~' o_n s. _ 04~30~03 6 N~'--;-- ~ _ Quarterly Inspection / No Changes 07/27/03 ----6 N_,,,---'- o%I ':A--,~ November 6, 2003 Mr. Guy L. Schwartz Phillips Alaska 700 G Street Anchorage, Alaska Dear Mr. Schwartz: Upon review of the Ultra Sonic Imager corrosion log on Kuparuk well 1D-110A dated 31- October-2003. I have come to the conclusion that the log does not show any significant signs of metal loss from corrosion or pipe wear. One interval of note is approximately 1,000' MD. Several of the caliper presentations show some sort of anomaly. After reviewing the casing reports this anomaly is a port collar. These port collars are used in the event that a single stage cement job does not bring cement back to surface. Other than the port collar the log shows the casing to be in very good condition in my opinion. Senior Sales Engineer Schlumberger Oilfield Services 3940 Artic Blvd, Suite 300 Anchorage, Alaska . Quart~'Hy FIowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "rtl 617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1 D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) ~3H-05 Quarterly Inspection Loq.xls Name: 3H-05 Quarterly Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: 1D-102 Insp Log.xls r~l insp Lo.q.xls Type: (application/msexcel) D-1 O2 EXCEL File Encoding: base64 Name: 1D-i 05 Inspection Log.xls Inspection Lo.q xls._. Type'. EXCEL File (application/msexcel) Encoding: base64 ,, Name: 1D-110 Insp Log.xls t [~ 1D-110 Insp L°'q'xls l, Encoding:Type: base64EXCEL File (application/msexcel)it ~1D-121 Inspection Log.xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) i~2oding: base64 j 1 offCOANNIED"JUL .1. 6 2:003 7/14/2003 10:39 AM 1 D-! lOA_SPecia! Inspection Request .Log ..... ' DSlD 1D-110A _ on 4/29/02. ,B,__I~N: (.~_.: b?se_li_ne inspec__t!on~_l, !nc_r~as_e__in_ %.~1_1_!o~s_, NLNo___c_h_~n_ge.from previ_ou.s_..!_n_sP, ec_ti_~_n_) ....................... __ ..................... ~_, .......... ~ ..................................... ; ......................... i , , Date of i# of Inspection Inspection Locations I B, I, N I Wall Loss % ~ Comments 02/02/02 10 N 0% A NO change to UT inspection locations extablish baseline by RT additional inspection locations 02/10/02 5 I 12% B Possible Erosion damage ........................................ 5 0% Damage noted on 2/10/02 inspection turned out to be variation in thickness of the fitting (geometry). 02/13/02 ............................................... ..N_ .................. _A_ .......................... Rgd_!~..g__r_aP__h sho_ws n____o_.._d_..am_a_g_~.?_.._f!t_t_in__g.: ...................... .... _o_3/91/o2_ ........ ................... ff ............................ _N_ ....................... 0_% ............ _..A No Change 03/04/02 10 N 0% 30 day RT follow-up of inspection locations no A damage due to erosion noted on radiograph ..... .o_.3../_9.._8/.o,.2 ............................ 5 03/18/02_ 5 U ...................... 0% A .................................................... _N._o_ C h a__n g_e_ ...... _0...3_!_2_ _.5/_o_8 ........................ .5h .................................. _.N._ ....................... 9.°_/_0_ ............................. 6 ................................................................... _.N._0_C_h_.a_ _n_g_.. _e_ ................................. 10 0% 30 day RT follow-up of inspection locations no 04/01/02 ............................... N A ........... d.a. rn~g_..e....~ .u_e___t_g__er_9_s_!..o__n__.n.o__t_.e._d_o_rLr_a_d_ i_ _o..g_r_ _a_p~_ ......... _.o__4_/_.o__8_/.__o_. 2_ .......................... 04/15/02 ................................... 5 N ........ _0_..°/.o_ ......................... ._A_ ...................................................... __No_C__h_a_ng_ _e.. .............................................. 04/22/02 .......... _5_ ......... N 0% .............. __A. .............................................................. __N_o C h__a_ .n_.g_e_ ............................................. 04/29/02 5 N 0% A NO Change / Inspection to be performed monthly ................................................................................................................................... 05/28/02 5 N 0% No Change by UT - No RT performed due to A P __ __ .___0__6_./_2_ 4/__.0_2. .......................... ~. ..................................... ..N_ .................... 9_°/.o_ ................................ _A._ ............................ _N_,_o__ ._C h_.a._nge._._b..y___u_. T__ o__[r _R__T__o_ni n__s_.p__e_ c_t_i_o_n- !.o___c. _a~.i_o_n__s_: ...... .... ..o_.7,_/.2,. ,3_./_o_2. .............................. !,~ 08/24/02 0% Line shut in 8/24/02 No Inspection scheduled until further notice ....................................................................................................................................................... 10/08/02 9 B 0% A established in well house piping. No changes in ....................................................................................................................... ex i_s__t_i p_g._p_i_.p) n_g_: ...... !_1..,_/.0_4_./0__2 ....................... _6 ........................................... _N .............................. 9%_ ........................ _A_ ......................... _.N__0____C_.h_ .a_..n_.g_e,..b_~_ ..U_r___o_..r._R_T_o n__Ln_s_p_e.._c,.t.~ o, _n_ !.o_c. gt_! o_n.~.: ....... ...... 1_2_/_.0__.5._/_0_2- ....................... __6_ ................ N 0% A No Change by UT or RT on inspection locations. _ _01_/. _2_ 9Lo_ 3_ .............................. _6., ................................ _N__ .................... _0. _°./.o.. ............................... ...A.. ............................. _.,N._..o_. ~ !~__a. _.n, g...e_. _b _y._... _U_T_o_r_ _R_.T_ .o_n_ .!.n_s_ .p_ _e_ c_t!_o_ ._n__l o_ .C. _a._t i_.o..0_ S~: ..... 04/30/03 6 N 0% A Quarterly Inspection / No Changes '"JUL :[ 6 2.003 ConocoPhillips Alaska PO Box 100360 Anchorage, Alaska 995 I0 December 8, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notice variance requests for ConocoPhillips Alaska, Inc., West Sak wells 1D-110A and 1D-140. The variance request for 1D-140 is to initiate gaslift on a failed ESP well. The variance request for ID-110A is for a'n extension. Also attached are discussions and well schematics. iPlease call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips PrOblem Well Supervisor Attachments RECEIVED DEC I0 2002 Alaska 011 & 8as Cons. Commission /lnchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS IZ-I t:z./o 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other_ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5233' FNL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service_ (asp's 560491, 5959709) (asp's 558586, 5962601) 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-110A 9. Permit number / approval number 200-039 '/ 10. APl number 50-029-22920-01 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" SURFACE 5089' 7-5/8" CSG WINDOW 12' 5-1/2" LINER 898' 5-1/2" LINER 763' 2-7/8" 59O5 4194 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu. Yds High Early 640 sx AS III Lite, 340 sx Class G 110 sx Class G Gravel pack screen 5777 4066 Measured Depth True vertical Depth 121' 121' 5189' 3485' 5169' 3467' 5905' 5905' 5695' 3984' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5363-5394', 5428-5496', 5519-5566', 5591-5394' md RECEIVED 3652-3683', 3717-3785', 3808-3855', 3880-3960' tvd DEC I"0 2002 3-1/2", 9.3#, L-80 Tbg @ 4910' MD. AJ~aS~a 0il & Gas Cons, Commission Anchorage MODEL 'SC-I' GRAVEL PACK PACKER; SIZE 76B2-40 @ 4932' MD; BAKER 'ZXP' MECHANICAL ISOLATION PACKER @ 5007' @ 'MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas __ Suspended __ Service 17. I hereby certify_ that the foregoing is true and correct to the best of my knowledge. Signed /"~-"c-~ ~ ~- ~ Title: Problem Well Supervisor Jerry Dethlefs ~ FOR COMMISSION USE ONLY Date Approved by order of the Commission Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance __ I Mechanical Integrity Test__ Su~bsequent form required 10- Commissioner Date M L. Bill Approval no. B Il NI$ B F L t 3 Form 10-403 Rev 06/15/88 · , SUBMIT IN TRIPLICATE ConocoPhillips Alaska, Inc. Kuparuk Well 1D-110A (PTD 2000390) SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/08/02 The purpose of this Sundry Notice is for approval to~e~l~e permitted length of Sundry #302- 227 for flowing a well on gaslift with a failed ESP 1~. 1D-110A is an ~g_P completion that was permitted to produce with gaslift up the annulus after the ESP failed. The Sundry history is as follows: Sundry (302-018) was approved for 6 months, to expire 6/30/02; Sundry 302-141 was approved 5/6/02, expiring 3/3.!.../~03~ Sundry 302-227 was approved 7/23/02, en0iri~g/1/23//0~. is reques is o ex en e variance perio or~~u~ o one year. The well is scheduled for a Th t t t d th d f~-'u-6 to one workover in early 2003; the request is for a period longer than is expected to account for changes in the rig schedule and eliminate repeated filings with the AOGCC. Production data on 1D-1 IOA is as follows: 1D-110A Allocated Welltest Information as of 12/8/02 FTP Wht Oil Rate Water Rate Formation Gas Gaslift Rate Wc Pct Well Name Welltest Date (PSIG) (Degrees F) (BOPD) (BWPD) (MCFD) (MCFD) (%) 1D-110A 11/30/02 233 38 354 26 118 296 6.8 1D-110A 11/18/02 242 38 256 45 99 310 15.0 1D-110A 11/03/02 235 39 337 35 69 356 9.3 1D-110A 10/24/02 241 41 255 40 86 323 13.5 1D-110A 10/15/02 236 37 365 47 189 262 11.3 The inspection program has continued without interruption on this well, with no degradation noted. Inspection results are as follows: (next page) - 2 in. Annulus flowback inspection - Monthly inspection frequency approved per e-mail from Warren Dobson on 4/29/02. B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection Worst Case Damage Grade Comments Inspection Locations B, I, N Wall Loss % 01/18/02 4 B 0% A Baseline inspection UT Insp only 02/02/02 10 N 0% A NO change to UT inspection locations extablish baseline by RT additional inspection locations 02/10/02 5 I 12% B Possible Erosion damage 5 0% Damage noted on 2/10/02 inspection turned out to be variation in thickness of the fitting (geometry). 02/13/02 N A Radiograph shows no damage to fitting. 03/01/02 5 N 0% A No Change 03/04/02 10 N 0% 30 day RT follow-up of inspection locations no A damage due to erosion noted on radiograph 03/08/02 5 N 0% A No Change 03/18/02 5 N 0% A No Change 03/25/02 5 N 0% A No Change 10 0% 30 day RT follow-up of inspection locations no 04/01/02 N A damage due to erosion noted on radiograph 04/08/02 5 N 0% A No Change 04/15/02 5 N 0% A No Change 04/22/02 5 N 0% A No Change 04/29/02 5 N 0% A No Change / Inspection to be performed monthly 05/28/02 5 N 0% No Change by UT - No RT performed due to A personnel safety due to drilling rig in the area 06/24/02 14 N 0% A No Change by UT or RT on inspection locations. 07/23/02 14 N 0% A No Change by UT or RT on inspection locations. 08/24/02 0% Line shut in 8/24/02 No Inspection scheduled until further notice New well house piping configuration - New baseline 10/08/02 9 B 0% A established in well house piping. No changes in , existing piping. 11/04/02 6 N 0% A No Change b.y UT or RT on inspection locations. 12/05/02 6 N 0% A No Chan,qe by UT or RT on inspection locations. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY TUBING ~ 1D-110A (0-4910, 0D:3.500, ID:2.992) PACKOFF ~ (4832-4833, 0D:3.500) (4883-4884, 0D:3.500) (4886-4887, 0D:3.800) SEAL ~ (4888-4889, 0D:5.130) (4901-4903, OD:5.250) MOTOR (4903-4910, 0D:5.620) CNTRLZR (491O4911, 0D:6.750) (4932-4933, 0D:6.690) SLEE (4941-4942, 0D:5.800) (5oo7-5008, 0D:7.625) FRAC (5363-5394) Per~ (5363-5394) FRAC (5428-5496) KRU 1D-110A APl: 500292292001 PROD SSSV Type: Annular Fluid: NONE Reference Log: Last Taxi: Last Tag Date: 5500' ELM 7/28/2000 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: Casing String - ALL Description CONDUCTOR Size 16.000 SURFACE 7.625 SCREEN LINER 2.875 LINER 5.500 CSG WINDOW 6.750 Tubing String - TUBING Top 0 0 4932 5007 5157 Size I Top 3.500 0 Perforations Summary Interval TVD 5363-5394 3652-3683 5428-5496 3717-3785 5519-5566 3808-3855 5591-5671 3880-3960 stimUlations &:Treatments Interval 5591-5671 Date Bottom I TVD 4910 3233 4/5/2000 IZone I Status I Ft WSD I 1311 wSA3 I 1471 WSA2 I 1801 ~'~fpe 5905 ffKB 67 deg (~ 2685 BottomI 5695 5905 5169 Angle @ TS: Angle @ TD: Rev Reason: Last Update: deg(~ 6deg@5905 Reset OV, set packoff/KOBE by ImO TVD I Wt I Gradel 121 162.581 H-40 I 3485 129.70l L-80 I 3984 16.50 IL-S01 5905 115.501 L-80 I 7/23/2000 FRAC Thread WELDED BTCM EUE 8RD BTC MOD from 1D-110 Wt IGrade I Thread 9.30 I L-80 I EUE8RD Date ITyPe I Comment 7/29,20001 ,PERF 13-3,8" DP HSD. 41B 7/28/2000 ] IPERF ]3-3/8" DP HSD. 41B 7,26,20001 ,PERF .3-3/8" DP HSD. 41B 7/22,2000, PERF,3-3,8 DPHSD. 41B Comment 167 M lbs of 14/18 placed in A2 sand 141 M lbs of 14/18 placed in A3 sand 5519- 5566 7/26/2000 FRAC 5428 - 5496 7/28/2000 FRAC 133 M lbs of 14/18 placed in A4 sand 5363 - 5394 7/30/2000 FRAC 147 M lbs of 14/18 placed in D sand ,Gas Lift.Mandrels/Valves stI MD I TVD I Man I Man I V Mfr Iv Type I V OD I Latchl Port I TRO I Date I Wv Mfr Type Run 11 47881 312610amcol KBMM-2 I Camco I OV I 1.0 I BK 10.1881 0 19/25/20021cmnt(1) 1. NO CHECK Other (p!ugs:i: equiP:; :etc~' Depth/TVD Type 3017 11963 CABLE 4831 13163 I SLIPSTOP 4832 131641 SPACER 4832 /3164 IPACKOFF 4883 13209 NIP 4886 13212 X-OVER 4888 /3213 I SEAL 4901 |3225I GEARBOX 4903 /3227 MOTOR 4910 13233 CNTRLZR 4932 /3252I PKR 4941 132601 SLEEVE 5001 133141 SBE 5007 13319 PKR 5350 13639 SCREEN Description RayChem Heat Trace Cable; 3017' length 3" SLIPSTOP SET ON TOP OF PACKOFF 9/25/2002 ID 0.000 2.992 2.10" X 12' SPACER PIPE set 9/25/2002 1.350 K-3 PACKOFF PLUG W/KOBE EQUALIZING SUB & KNOCKOUT SPACER 1.350 PIPE set 9/25/02 2.875 3.5" Slotted Nipple Centralift 3.5" TTC Crossover 3.500 Centralift Seal Section GST3 4B IL H6 PFS 0.000 Centralift Gearbox 9:1; 525 Series 0.000 PCESP Motor 57 HP 1315/26 KMH 0.000 Centralift Motor Centralizer (Baker Sentry Gauge (~ 4801' MD. 3190' 'I-VD) Model 'SC-I' Gravel Pack Packer; size 76B2-40 Baker 80-40 Gravel Pack Sliding Sleeve SEAL BORE 80-40 0.000 4.000 4.000 4.000 Baker 'ZXP' Mechanical Isolation Packer 5.500 GRAVEL PACK SCREEN 2.441 Permit to Drill 2000390 MD 5905 -I-VD DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. KUPARUK RIV U WSAK 'ID-'I'IOA Operator PHILLIPS ALASKA INC. 4193 Completion Dar 8/4/2000~'''~' Completion Statu 1-OIL APl No. $0-029-22920-0'1-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._~.o Sample No Directional Survey ~ ~/).J~ ,. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~ Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop 4995 5879 OH / Dataset CH Received Number Comments Open 8/10/2000 09589(/~9~-~5-5879 L L~'- L L D -D R R DGPJEWR--I-VD 2/5 FINAL DGPJEWR-MD 2/5 FINAL 9589 2 SRVY RPT 3445 4193 OH 5157 5905 OH OH 5154 5905 OH 8/15/2000 3445--4193 8/15/2000 5157-5905 8/10/2000 9589L~RRY MPT/GR/EWR4 4~24~2000 SPERRY 5154.60-5905. Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis RP.c~.ivP. d ? Daily History Received? ~ N Formation Tops {~)/N Comments: Compliance Reviewed By: Date: t-~'~ ~,~{ 3-, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., West Sak well 1D-110A. The variance request is to change the gaslift and production flowpath currently approved. Also attached is a discussion and well schematic. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, rj :fs Phillips Problem Well Supervisor Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Jz..2 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~ie, AK 99510-0360 4. Location of well at surface 5233' FNL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service_ (asp's 560491, 5959709) (asp's 558586, 5962601) 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-110A 9. Permit number / approval number 20O-O39 10. APl number 50-029-22920-01 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" SURFACE 5089' 7-5/8" CSG WINDOW 12' 5-1/2" LINER 898' 5-1/2" LINER 763' 2-7/8" 59O5 4194 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu. Yds High Early 640 sx AS III Lite, 340 sx Class G 110 sx Class G Gravel pack screen 5777 4066 Measured Depth True vertical Depth 121' 121' 5189' 3485' 5169' 3467' 5905' 5905' 5695' 3984' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3652-3683', 3717-3785', 3808-3855', 3880-3960' tvd . Ii II ?. ~'"'",.-' ~'~'~'"'= 3-1/2", 9.3~, L-80 Tbg ~ 4910' MD. ~k~;~.~..~.(.;~ ~:~¢ ~ '-,~,' ~" . ',.~' ' ....... .:.~, ,'~.~,~ .,;'¥ , ~ .t .':¢: MODEL 'SC-I' GRAVEL PACK PACKER; SIZE 76B2-40 ~ 4932' MD; BAKER 'ZXP' MECHANICAL ISOLATION PACKER ~ 5007' ~ 'MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation ASAP 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"'Y .... Title: Problem Well Supervisor Jerq/ Dethlefs ~ ~/ ~,,~--~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- Ong~nal S~gned By Approved by order of the Commission Camm~f Oechsli Ta)~r Commissioner IAppr°val n°' ..~O2., ,~..~_' Date ORIGINAL Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 1D-110A (PTD 2000390) SUNDRY NOTICE 10-403 VARIANCE REQUEST 07/18/02 Discussion The purpose of this Sundry Notice is for approval to temporarily change the configuration and flow-path of West Sak producing well 1D-110A. The well is an ESP producer with a failed pump, currently gaslifted down the tubing and producing up the tubing x production casing annulus (IA). The current AOGCC approval is via Sundry #302-141. With the current configuration producing rates are acceptable and good engineering data is being acquired; however, there is a constant problem with hydrates forming in the annulus (IA). Approximately once per week the IA will freeze due to the pressure drop at the orifice and the presence of water in the production stream. Thawing of the annulus has proved to be difficult and alternatives going into the colder months are necessary. Phillips proposes to reverse the gaslift direction to a conventional arrangement; gas will be injected down the IA and enter the tubing through the single mandrel. The reason this configuration was not proposed initially was to eliminate potential for the well to flow in an unstable condition, with possible slugs and excessive drawdown at the perforations. The current configuration has proved to be labor and cost intense and not suitable for cold weather conditions. The proposed configuration may also incur problems as yet unknown. Since this well does not have a packer, there have been questions regarding the chance lift gas may enter the perforated interval. The following calculations show that gaslift should not inadvertently be injected into the West Sak formation. Calculations r' / The estimated average reservoir pressure in the 1D-110A area is 1683 psig at 3190'TVD (1865 psig at 3500'SS Datum) taken on 1/12/02. This value was measured by a downhole pressure gauge and was independently verified by dual calibrated Pane~ ~auges for accuracy on 10/3/01. The maximum gaslift surface pressure at 1D pad is 1410 psig. ~At this pressure, and at the conservative wellhead temperature of 40 degrees F (actual measured value), th/e properties of the lift gas dictate that the maximum injection depth is approximately 2780' TVIJ when the well is not producing (circulating lift gas). The top perforation is at -3652' TVD. (Note that if the wellhead temperature is greater than 40 degrees F, the maximum injection depth would be even less due to less gas density.) The calculation indicates that when the well is not flowing to / surface, it is not possible to sustain gas injection into the reservoir because the 2780' TVD max injection depth is 872' less than the 3652' TVD of top perfs. In the case where the well is flowing, the bottomhole pressure near the wellbore will be lower. Since the well is open to flow and gas is less dense than any other wellbore fluid, gas will preferentially circulate through the gas lift mandrel back to surface preventing sustainable gaslif[/ injection into the reservoir. Therefore, in either the flowing or non-flowing situation conditions are not capable of a sustained gas injection into the reservoir. As an extra level of protection, 1 D-110A is equipped with a functional and continuous reading bottomhole pressure sensor that allows continuous monitoring of the bottomhole pressure. The well has an alarm to notify the engineer if the bottomhole pressure changes. // Proposal · Phillips proposes to change the flowpath from gaslift down the tubing and production up the annulus, to gaslift down the annulus and production up the tubing (conventional ,/ arrangement); · Continue with monthly flowline inspections reported quarterly to the AOGCC (annulus piping inspections will no longer be needed); · Shut-in the well and/or gaslift should downhole pressure measurements indicate potential for lift gas to enter perforations; · Approval to be for six months from the date of approval; · Notify the AOGCC should any further production or mechanical problems arise from this temporary production arrangement. PHILLIPS Alaska Inc. A Subsidiary or PHILLIPS PETROLEUM COMPANY (30!7-218, 00:6723) MandrdNave 1 (478¢%4789 O0:5 39©) (0-4910 00:3500 0:2992) (4886*4887 (4886*4889, OD:5130) (4901-4903, OD:5 250) (4983.4910, OD:5620) :l O-110A KRU 10-110A APkj 500292292001 Last W/O: i packoff/slipstop by L~st Update: i14/24/01 Description Size ToB Bottom TVD Wt Grade Thread 3500 0 4910 3233 930 L-a0 EUE 8RD 5363-5394 3652-3683 : WSD 31 8 72900 J PERF 3-3/8 DPHSD, 41B A4 5519-5566 *3808- 3855 WS A3 - --47 % 7/26/00 Interval, Date T~Be , _Commept 5519-5566 7/26/00 FRAC 14~ M ihs of 14/18 placed ~n A3 sand Mfr Z~ Run Cmnt 3017 1963 CA~LE Rayp~)e~) Ide~t 'f'~ ~a~k~; ~0! ? I~0g0~ 0.000 4822 3 56 , PuMP3~'TTESPCPCen a ~Jmpwpacko S~ p~ 4~0 ~ 08~8 {49!0~4911 00:6750) (4932.4933 ODS 6F3) 4932 3252 ]PKR Model 'SC~I' Gravel Pack Packer; size 76B2-40 :4000 5807 i 3319PKR Baker'ZXP' Mechanical isolation Packer 5.500 007 6251 FRAC (53&3-5394) (536~5394) (:~ 28-5496) PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., West Sak well 1D-110. The variance request is for approval to extend the Sundry #302-018 to temporarily use gaslift to produce the ESP-completed well. Also attached :is a discussion, we'll schematic, production data and inspection log. Pl. ease call Jerry Dethlefs or me at 907-659-7224, if you have any questions. Sincerely, Phillips Problem Well Supervisor Attachments Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ,/ v" ~/ 5233' FNL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic _ Service__ (asp's 560491, 5959709) (asp's 558586, 5962601) 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-110A 9. Permit number/,,approval number 200-039 10. APl number 50-029-22920-01 ~' 11. Field / Pool Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" SURFACE 5089' 7-5/8" CSG WINDOW 12' 5-1/2" LINER 898' 5-1/2" LINER 763' 2-7/8" 59O5 4194 feet.s,, Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu. Yds High Early 640 sx AS III Lite, 340 sx Class G 110 sx Class G Gravel pack screen 5777 4066 Measured Depth True vertical Depth 121' 121' 5189' 3485' 5169' 3467' 5905' 5905' 5695' 3984' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 5363-5394',5428-5496',5519-5566',5591-5394' md 3652-3683',3717-3785',3808-3855',3880-3960'tvd 3-1/2", 9.3#, L-80 Tbg @ 4910' MD. MODEL 'SC-I' GRAVEL PACK PACKER; SIZE 76B2-40 @ 4932' MD; BAKER 'ZXP' MECHANICAL ISOLATION PACKER @ 5007' @ 'MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedpeterNozaticky / // Title: Problem Well Supervisor FOR COMMISSION USE ONLY Questions? Call Peter Nezaticky 659-7224 Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission IApproval no.3,~. /~7~/~ - I I I Commissioner Date f/O/~ ~ / Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. KRU 1D-110A A Subsidiary o~ PHILLIPS PETROLEUM COMPANY TUBING ~ . 1D-110A (0-4910, i ~ APl: 500292292001 Well Type: PROD Angle @ TS: deg ~ 0D:3.500, SSSV Type: NONE Orig 4/5/2000 Angle @ TD: 6 deg @ 5905 Completion: ID:2.992) Annular Fluid: Last W/O: Rev Reason: Set OV by ImO Reference Log: Ref Log Date: Last Update: 5/28/2002 Last Tag: '5500' ELM TD: 5905 ftKB I Last Tag Date:. 7/28/2000 Max Hole Angle: 67 deg @ 2685 Casing String - ALL Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED SURFACE 7.625 0 5189 3485 29.70 L-80 BTCM SCREEN LINER 2.875 4932 5695 3984 6.50 L-80 EUE 8RD LINER 5.500 5007 5905 5905 15.50 L-80 BTC MOD CSG WINDOW 6.750 5157 5169 3467 0.00 from 1D-110 NIP ~ Tubing! Strin9 - TUBING 0D:3.500) 3.500 0 4910 3233 9.30 L-80 EUE 8RD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment X-OVER~ 5363- 5394 3652- 3683 WS D 31 8 7/29/2000 IPERF 3-3/8" DP HSD~ 41B (4886-4887, 5428 - 5496 3717 - 3785 WS B,WS 68 8 7/28/2000 IPERF 3-3/8" DP HSD, 41B 0D:3.800) 5519- 5566 3808 - 3855 WS A3 47 8 7/26/2000 IPERF 3-3/8" DP HSD. 41B 5591-5671 3880-3960 WSA2 80 8 7/22/2000 IPERF 13-3/8" DP HSD. 41B SEAL ~ Stimulations & Treatments (4888-4889, Interval Date Type Comment 0D:5.130) 5591 - 5671 7./23/2000 FRAC 167 M lbs of 14/18 Placed in A2 sand 5519 - 5566 7/26/2000 FI=AC 141 M lbs of 14/18 placed in A3 sand 5428 - 5496 7/28/2000 FRAC 133 M lbs of 14/18 placed in A4 sand GEARBOX~ 5363 - 5394 7/30/2000 FRAC 147 M lbs of 14/18 placed in D sand (49014903, Gas Lift Mandrels/Valves 0D:5.250, StI ,~o ITVOl ManI Man I VMfr IVType Ivool atchI co, ITROl Date I Vlv Mfr Type I Run I Cmnt 1 4788 31261 Camco KBMM-2 Camco OV 1.0 BK 0.167 0 15/27/20021 (1) MOTOR ~ 1. NO CHECK (4903-4910, Other:;(~!ugs;i equip~i etC~',~JEWELRY :: ;; i~ :;.~; : ~: :;: ;: :~; : ~;~:: ~;:. ;:: ~: ;i ~ ;~;: :~: ~: 0D:5.620) Depth TVD Type Description ID 3017 1963 CABLE RayChem Heat Trace Cable; 3017' length 0.000 4883 3209 NIP 3.5" Slotted Nipple; Baker K-3 packoff assy. w/bullnose, 12' 6" long, and 2,875 CNTRLZR ~ Slip Stop on topr set 1/15/02 (4910-4911, 4886 3212 X-OVER Centralift 3.5" TTC Crossover 3.500 0D:6.750) 4888 3213 SEAL Centralift Seal Section GST3 4B IL H6 PFS 0.000 4901 3225 GEARBOX CentraliftGearbox9:l; 525Series 0.000 4903 3227 MOTOR PCESP Motor57 HP 1315/26 KMH 0.000 PKR ~~ 4910 3233 CNTRLZR Centralift Motor Centralizer (Baker Sentry Gauge (~ 4801' MDt 3190' TVD) 0,000 ~ ~ 4932 3252 PKR Model 'SC-I' Gravel Pack Packer; size 76B2-40 4.000 (4932-4933, 4941 3260 SLEEVE Baker 80-40 Gravel Pack Sliding Sleeve 4.000 0D:6.690) 5001 3314 SBE SEAL BORE 80-40 4.000 5007 3319 PKR Baker'ZXP' Mechanical Isolation Packer 5.500 SLEEVE ~ 5350 3639 SCREEN GRAVEL PACKSCREEN 2.441 (4941-4942, 0D:5.800) PKR ~ (5OO7-5O08, 0D:7.625) FRAC (5363-5394) Perf (5363-5394) FRAC (5428-5496) 1D-110A Special Inspection Request Log _B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection Worst Case Damage Grade Comments Inspection Locations B, I, N Wall Loss % 1/18/2002 4 B 0% A Baseline inspection UT Ins@ only NO change to UT inspection locations extablish 2/2/2002 10 N 0% A baseline by RT additional inspection locations 2/10/2002 5 I 12% B Possible Erosion damage Damage noted on 2/10/02 inspection turned out to 5 0% be variation in thickness of the fitting (geometry). 2/13/2002 N A Radiograph shows no damage to fitting. 3/1/2002 5 N 0% A No Change 03/04/02 10 N 0% 30 day RT follow-up of inspection locations no A damage due to erosion noted on radiograph 3/8/2002 5 N 0% A No Change 3/18/2002 5 N 0% A No Change 3/25/2002 5 N 0% A No Change 10 0% 30 day RT follow-up of inspection locations no 4/1/2002 N A damage due to erosion noted on radiograph 4/8/2002 5 N 0% A No Change 4/15/2002 5 N 0% A No Change 1D-110 WELL TEST DATA FLOWING FLOWING OIL WATER TOTAL FORMATION LIFT RATE DATE PRESS TEMP bpd bpd FLUID bpd GAS mscf mscf 04/21/02 240 46 335 24 359 0 430 04/21/02 240 46 335 24 359 0 430 04/08/02 242 46 388 22 410 0 475 04/08/02 242 46 388 22 410 0 475 03/29/02 242 43 402 24 425 534 0 03/29/02 242 43 402 24 425 74 460 03/28/02 238 43 408 21 429 549 0 03/15/02 256 44 407 18 425 74 515 03/10/02 254 43 431 19 450 54 640 03/03/02 261 44 470 20 490 87 615 03/03/02 261 44 470 20 490 702 0 03/02/02 256 47 479 23 502 89 555 03/02/02 256 47 479 23 502 644 0 02/18/02 249 43 530 23 553 322 0 02/18/02 249 43 530 23 553 97 225 02/16/02 234 41 387 1 388 71 315 02/16/02 234 41 387 1 388 386 0 02/16/02 198 41 278 1 279 51 189 02/16/02 198 41 278 1 279 240 0 02/14/02 186 32 96 1 97 443 0 02/12/02 190 40 90 39 130 12 0 02/09/02 277 45 530 39 568 121 660 02/08/02 269 44 635 44 679 115 340 02/08/02 269 44 635 44 679 455 0 02/08/02 272 45 660 49 709 397 0 02/03/02 238 43 404 55 459 75 0 02/03/02 238 43 404 54 457 166 0 02/02/02 209 51 203 11 215 37 0 02/01/02 210 52 183 11 194 34 0 01/29/02 215 53 183 11 194 29 0 01/22/02 215 52 197 11 209 36 0 01/19/02 221 52 222 1 223 39 0 01/19/02 221 52 222 1 223 39 0 01/17/02 244 50 314 1 316 57 0 01/17/02 218 47 388 3 391 75 0 01/16/02 246 45 348 7 356 69 0 Phillips Alaska, Inc. Kuparuk Well 1D-110A (PTD 2000390) SUNDRY NOTICE 10-403 VARIANCE REQUEST 04/24/02 The purpose of this Sundry Notice is for approval to extend the length of the Sundry #302-018 and request that UT inspections will be required monthly instead of weekly. 1D-110 is an ESP completion that has a Sundry (# 302-018) to produce with gaslift up the annulus after the ESP failed. The original Sundry was approved for 6 months with weekly ultrasonic inspection on the wellhead and fi. ow lines. The baseline inspection was done on 1/18/02 with subsequent weekly inspections showing no erosion. We are planning on replacing the 2" wellhead spool that we are currently producing through with a 3-1/2" heavy walled spool, eliminating the 2" line, the tee and one of the elbows. The latest production test on 04/21/02 recorded 335 bopd, 24 bwpd, 0 mscf of formation gas with 430 mscf of lift gas. The current sundry was approved on 1/29/02, which allowed lift gas to flow down the tubing and production up the annulus. Phillips is asking for an extension on the expiry date of 06/30/02 until a workover, that will be schedul, ed during the 1st quarter of 2003 is complete. Phillips is also requesting that the frequency of our erosion testing decrease from weekly to monthly inspections as weekly inspections have been performed since 1/18/02 with no signs of erosion. Attached is a wellbore diagram, production test table, and inspection log for supporting information. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of We~l: Development _X Exploratory __ Stratigraphic _ 4. Location of well at surface 5233' FNL, 596' FEL, Sec. 14, T11N, R10E, UM ,At top of productive interval 2319' FNL, 2454' FEL, Sec. 14, T11N, R10E, UM ,At effective depth (asp's 560491, 5959709) ,At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM (asp's 558586, 5962601) 12. Present well condition summary 'Total depth: measured true vertical 5905 feet 4194 feet Plugs (measured) Perforate _ Other_X Gaslift 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-110A 9. Permit number / approval number 50-029-22920-01 11. Field / Pool West Sak Oil Pool Effective depth: measured true vertical feet Junk (measured) feet Casing Length CONDUCTOR 121' SURFACE 5089' CSG WINDOW 12' LINER 898' LINER 763' Perforation depth: Size Cemented Measured Depth True vertical Depth 16" 9 cu. Yds High Early 121' 121' 7-5/8" 640 sx AS III Lite, 340 sx Class G 5189' 3485' 5-1/2" 5169' 3467' 5-1/2" '~ 10 sx Class G 5905' 5905' 2-7/8' Gravel pack screen 5695' 3984' measured 5363-5394'. 5428-5496'. 5519-5566', 5591-5394' md RECEIVED true vertical 3652-3683', 3717-3785', 3808-3855', 3880'3960' tvd FEB i 9 2002 Ataska 0il & Gas C0as. C0mmissi0~ Tubing (size, grade, and measured depth) 3-1/2', 9.3#, L-80 Tbg ~ 491~ MD. Ancho~ Packers & SSSV (~pe & measured dep~) M~EL 'SC-I' G~VEL PACK PACKER; SIZE 76B2-40 ~ 49~ MD; BAKER 'ZXP' MECHANIC~ IS~TION PACKER ~ 5007 ~ ' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 352 Subsequent to operation 606 Representative Daily Average Productipn or Injection Data Gas-Md Water-Bbl 74 6 115 46 Casing Pressure Tubing Pressure 213 212 1216 192 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil B X Gas__ Suspended B Service_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .. Title Production Engineering Supervisor Jeff A Spencer Questions? Call Jeff Spencer 659-7226 D'tpre:are~ ~y F,o~e~h~te 'ns~ 65277 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Phillips Alaska, Inc. February 13, 2002 1 D-110 10-404 Daily Report of Well Operations 02/02/02: 02/10/02: As of February 3, 2002, gas lift was initiated in the West Sak well, 1D-110 oil producer. Gas lift was hard lined from Kuparuk oil producer, ID-03, and injected down the subject well's production tubing string at approximately 830 PSIG and a rate of 340 MCFD. Wellbore fluid production is currently up the inner annulus at rates of 635 BOPD and 455 MCFD, and returned to the conventional, surface flow line via a 2" annular flow line. Surface production flowing pressure is 270 PSIG. This well is not in steady-state production and is experiencing a steady decline in rate due to flush production; therefore, 630 BOPD is the highest rate the well will experience during gas lift. Static reservoir pressure before gas lift production was 1680 PSIG and is expected to severely decline due to a lack of surrounding injection support. The following are corrosion reports and will be followed up with another inspection as of February 13, 2002: Completed Ultrasonic inspection on the drillsite 1D-110A 2" Annulus line. This inspection was requested over concerns of erosion to the impingement areas of the line (elbows) due to production of this well through the 2" annulus line (2"-PC-ID110-F4.4). The results are as follows: Action Items: No.ne Damage Summary: No erosion or damage to the elbows was detected during inspection. Ultrasonic inspection was performed on the 4 elbows located on the line from the wellhead to its tie-in to the 3" production line. The inspection results will serve as baseline for future inspections. Future Inspection Plans: We will re-inspect these elbows when notified within I day after notification, and then after 3 days, then 6 days. Afterwards, will inspect on a weekly basis while the well is in production and not shut in. Completed Ultra-sonic inspection on the drillsite 1D-110A 2" Annulus line. This inspection was requested over concerns of erosion to the impingement areas of the line (elbows & tie-in tee) due to production of this well through the 2" annulus line (2"-PC- ID110-F4.4). The results are as follows: Action Items: None Damage Summary: Slight erosion damage was noted on corrosion ID # 204. 12% damage by UT was noted on this location (3x2 tee). This location is the tie-in for the 2" annulus line to the 3" main towline for well 1D-110A. Ultrasonic inspection was performed on the 4 elbows located on the line from the wellhead to its tie-in to the 3" production line. NO changes were noted on the remaining inspection locations.. Future Inspection Plans: Our next inspection will be in three days 2/13/02. Afterwards, we will inspect on a weekly basis while the well is in production and not shut in. Jason Brink/FULLFIELD PROD ENGR January 14, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Subject: 1 D- 110 Application for Sundry Approvals Supporting Documentation On 1/18/01 Phillips completed an ultrasonic inspection on the drillsite 1 D-110 2" annulus line. The inspection was requested by the AOGCC regarding concerns of erosion to the impingement areas of the line (elbows) due to production of this well through the 2" annulus line (2"-PC-ID 110-F4.4). The results are as follows: Damage Summary: No erosion or damage to the elbows was detected during our inspection. Ultrasonic inspection was performed on the 4 elbows located on the line from the wellhead to the tie-in to the 3" production line. The inspection results will serve as baseline for future inspections. Future Inspection Plans: After 1 day of production and weekly afterwards. Velocity calculations have been done with maximum anticipated flow rates of 500 BLPD and 500 MSCFD up the annulus and through the 2" annular flow line. Production pressure is approximately 230 PSIG. The maximum velocity up the annulus will be 3 ft/s and velocity through the 2", schedule 160, grade 6, A33 line will be 25 ft/s. The best case scenario is not to exceed 12 ft/s for liquids in clean liquid systems and not to exceed 80 ft/s for gas in systems also containing clean liquids. Since this system is mostly gas the flowrates should be in a safe range. The Corrosion Department will be inspecting regularly for erosion damage after 1 day and weekly thereafter. A solids shake out was taken from the well on June 7, 2001 and was 0.01% solids by volume. As an extra safety feature, a valve handle to the IA AP1 valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. Jason Brink/NSK Full Field Production Engineer Jerry Dethlefs/Phillips Problem Well Supervisor SI Wing valve Phillips West Sak Well 1D.110A ~:~ IA Flowline out Phillips Well 1D-110A Sundry Subject: Phillips Well 1D-110A Sundry Date: Fri, 11 Jan 2002 14:45:24-0900 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak, us CC: "NSK Problem Well Supv" <n1617@ppco.com> Tom: I just sent you a fax of a 10-403 for Phillips Alaska well 1D-110A. Attached are supporting documents for the form; I'm sure they will be easier to read. I will be sending another shortly for 30-12. Let me know if you need additional information. Thanks! Jerry Dethlefs Phillips Problem Well Supervisro(See attached file: ID-110 Well Test List.xls)(See attached file: 1D-110A 10-403 Prod Temp 01-11-02.xls)(See attached file: 1D-110A.pdf)(See attached file: 1D-110 Discussion 01-11-02.doc) _ID-110 Well Test List.xls Name: ID-110 Well Test List.xls Type: EXCEL File (application/msexcel) Encoding: base64 [~ 1D-110A 10-403 Prod Temp 01-11-02.xls Name: 1D-110A 10-403 Prod Temp 01-11-02.xls Type: EXCEL File (application/msexcel) Encoding' base64 t~-~ 1D-110A. pdf!l Type: Acrobat (application/pdf) [ ........................... I,, E~.c.0ding: ha. se.? ................................................... 1~1D-11 O-'-~-"~D'i-~'~ussio-~Ol-~'i'~(~'~.do~' Type: WINWORD File (application/msword)I E n.......c.~=~,i.?g~?a se. ,,,,,, .6,.~, 1 of 1 1/15/02 10:37 AM Jan-II-02 03:4Zpm From-KUP WELLS CNST PROJ Problem Well Supervisor 907-659-7224 +g0?-$$g-?314 T-83g P.01/02 F-gT1 Fax 11~: Tom Maunder From: Jerry Dethlef$ Fax= 276-7542 Pages,' 2 l~hone: 279-1433-250 Date." 01/11/02 Re." 1D-110A Sundry 10-403 cC: [] U~gent [] For Revi~N [] Please Comment [] Please Reply [] Please Re,c:ycle Tom: Attached is a signed Sundry 10-403 variance request for Phillips Alaska, Inc., well 1D-110A. I have emailed suppoding documents for this Sundry so they will be easier to read. Let me know if you need the original hardcopy of this and I will snail-mail it. I also will be sending Another Sundry in awhile for 30-12. Thanks, Jerry Dethlefs J an-11-02 From-KUP WELLS CNST PROJ +g0?-$Sg-?314 T-S3g {,' ' STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.OZ/02 1, -I'~l~e of request Abandon_ Suspefld_ Operational shutc~own _ Re-enter st~spended w~l _ Alter casing _ Repair well_ Plugging _ Time extension _ Sflmulale _ Cllange approved prog~m _ Pull lublng _ Varlance_X Perforate .. Other_ 2. Name of OpeTa~or Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchors.ge, AK g~10-0360 ~ ,/ ,/' 4. Location of well at eUrfaee ~ v v ~233' FNL, ~96' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM 5, Type of Well: Development __X EXplorato~ _ Stmllgre~ohio _ Service__ 560491, 5959709) 12. Present well condition summer Total depth: Effective depth: (asp's 558586, 5962601) measured 590~ fact~ true vertical 4194 feet measured feet true vertical teat 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool 8. Well number 1D-11CA 9. Permit number / a, pproval number 200-039 V 10. APl number ~ .60-029-22920-01 11. Field / Pool Plugs (measured) 5~7 4066 Junk (measured) Casing Length CONDUCTOR 121' ~uRFACE 5089' CSG WINDOW 12' LINER 898' LINER 763' Size Cemented Measured Depth 16" e cu. Yd~ High Early 121' 7-$/B' ~0 ex AS Ill Lite, 340 ax Class ca 51 SO' 5-1/2" 5169' S-1/2" ~ lO ex Ola~ G 5905' 2'7/~" Gravel pack ~reen ~69~' True vertical Depth 121' 3486' 3467' .~905' 2984' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (Npe & measured depth) ~$6t~t-5394', 542B-5496', 5619-5666', 6591-6394' md 3717-3785', 3808~as~', 3880-3960' tvd 3.1/2", 9,3fL L-Ce Tbg @ 4910' MD. MODEL'SC-I' GRAVEL PACK PAOKER; SIZE 76EL?.-4o @ 499~ MD; BAKER 'ZXp' MECHANICAL [$OI.ATION PACKER @ 5007' MD; RECEIVED 13. Attachments Description summa~ of proposal ~ Detailed operations program __ BoP st(etCh _. 14. Estimated date for ~omrnenelng operation la, Status of well classification 16. If proposal was verbally approved Oil ~X Gas __ Suspertded Name of approver Ds~ approved Se~ice 17, I hereby ce~ that the Ioregolng is tee end corm~ to the best of my ~owledge. Questions? Call Jer~ Deth}els 659-7~4 ' -~ FOR COMMISSION ~U'SE'"ONLY Conditions of approval: Noti~ Commission so represen~tlve may wit~ess Mocha.leal Integr,~ Te~- ~_~ ~: Subsequen, 1o~ required 10. '0 ~'_ ' Form 10-403 Rev 06/15/88 · u.gmal ~lgneO By Cammy 0echsli SUBMIT IN TRIPLIOATI== Phillips Alaska, Inc. Kuparuk Well 1D-110A (PTD 2000390) SUNDRY NOTICE 10-403 VARIANCE REQUEST 01/11/02 The purpose of this Sundry Notice is for approval to temporarily gaslift West Sak producer 1D- 110A that is completed as an ESP (electric submersible pump) well. The ESP has failed and a workover is planned to pull and replace the ESP. The workover is scheduled for approximately the beginning of the second quarter of 2002. The well makes approximately 450 bopd via ESP, a majority of which may be possible to produce on gaslift. Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate would be 500-600 mcfd. The bottom of the tubing string will be sealed off with a modified packoff to seal the ESP pump intake. Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 300-500 BOPD. Phillips proposes that the AOGCC approve this request for a time period not to exceed 6 months from the approval date. The expectation is the workover will be accomplished well within that time period, and that production will resume via ESP. Attached is a wellbore diagram and well test table for supporting information. Phillips Alaska, Inc. Kuparuk River Unit West Sak Oil Pool January 9, 2002 Well Test Summary WELL: ID -110A Oil Producer (production rates with ESP operating) FORM TOTLi LIFT %WC DATE 5-Aug-01 5-Aug-01 22-Ju1-01 22-Ju1-01 10-Jul-01 1-Jul-01 17-Jun-01 5-Jun-01 5-Jun-01 29-May-01 29-May-01 26-May-01 17-May-01 13-May-01 11-May-01 CHK FTP 100 244 425[ 1171 22 18 65l 424J 121i 22 , i . 64l 483J 110i 19 ! 246 ~ i I 1001 62! 495i 1081 222i 63 63 63 62 lO0 100 256i 100 234! 100 2151 100 210[ 100 2301 ~ 223 lOO! 62 100'. 213, 60 100, 218J 60 59 434, 121, 22 100, 210 433. 121~ 22 444i 1241 22 479[ 124 21 521 117 491 1031 546 92 ! 451 80i 4041 521 57. 366. 42i 56 335i 34' 100j 211 18 FLUID! GAS 541j 95 17 14 15 GOR GLR !PRES, , 25, 1761 739{ 603 81 5451 92 164! 134! 760 217, 169, 739 594i 90 185 151! 758 554 84' 194 1521 772 554 92. 212 165! 772 568, 931 209 163~ 787 , ~ i 72 6021 104 ! 217 1 . 792 638 594 638 531 1001 192J 1561 798 115j 234, 193. 836 112 206 1761 TYP ESP ESP ESP 455 ESP ESP FSi-- ESP ESP ESP ESP 845! ESP 88 1951 16~ 916iESP 78! 1941 172 10231ESP 1001 233 1001 207 407 369 71{ 194j 174.i 1096;ESP 65i 195i 177! 1132!ESR PHILLIPS Alaska, Inc. A Substdlary of PHILLIPS PETROLEUM COMPANY I i4788-4789 005 390) (0 4910 OD 3 FO0 0:2 992) (4888 4888 OD 9 !30) (4901-4903 OD 5 250, MOTOR (4903 4910 00:5620) CNTRLZR (49!0 491i 006750) APl 50029229200 Wetl [tp~: PROD Angle Q IS deg (g SSSV l,pe NONE On9 Cumpleuon 4/b/ols An~ie @ SD. 6 deg (~ 5905 Annda'~-~ud LastW/O RevReason SOx, Se packofbshpstop mO Reference LOE Ref Lo9 Da~e. Las[ JDdate. 4/24/0~ Las(TaE 55OO ELM TD: 59O5 ftKB Last -rag Date 7/28/0cMax Nde Angle 67 de9 ~ 2685 Casing String - ~L Descdp~on Size Top BoSom CONDUCTOR 10 000 121 5UREACE 76z5 ~ 5189 SCREEN LINER 2.875 4932 5695 L~NER 55OO 5007 5905 CSG WINDOW 6 ~50 TVD Wt Grade Thread zl 6256 14u WELDEE 3485 29.70~-8( B]TCM 3984 6 50 ~-sf. EUE 8RD 69Ob 1550 ~-80 B¥C MOD PKR (4932-4933 0©8890) SLEEVE (5007 5008 O07625} Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 25, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-110A (200-039) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the well work on KRU well 1D-110A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad Z[CEIVED k. 'iAY oL,, 2.00! .Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA'";~" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Pull tubing_ Alter casing _ Repair well _ Other_X ESP work 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5233' FNL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval 2319' FNL, 2454' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 2326' FNL, 2475' FEL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 560491, 5959709) (asp's 558606, 5962612) (asp's 558586, 5962601) 6. Datum elevation (DF or KB feet) RKB 100 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-110A 9. Permit number / approval number 200-039 / 10. APl number 50-029-22920-01 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical 5905 feet Plugs (measured) 4194 feet Set ESP @ (10/15/00) 4822' Effective depth: measured true vertical 4822 feet Junk (measured) 3155 feet Casing Length CONDUCTOR 121' SURFACE 5089' CSG WINDOW 12' LINER 898' SCREEN LINER 763' Size Cemented Measured Depth 16" 9 cu yds High Early 121' 7-5/8" 640 sx AS III Lite, 340 sx Class G 5189' 6.75" 5169' 5-1/2" 11o sx Class G 5905' 2-7/8" Gravel pack screen set Inside 5.5" 5695' Perforation depth: measured 5591'-5671', 5540.5'-5565.5', 5519'-5543', 5496'-5428', 5363'-5394' true vertical 3880'-3960', 3830'-3855', 3808'-3832', 3785'-3717', 3652'-3683' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 4910' MD. True vertical Depth 121' 3485' 3467' 4194' 3984' ~,"~ ,~, ~! "? Packers & SSSV (type & measured depth) MODEL 'SC-I' GRAVEL PACK PACKER; SIZE 76B2-40 @ 4932' MD; BAKER 'ZXP' MECHANICAL ISOLATION PACKER @ 5007' MD, No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Shut-In 319 35 1 Casing Pressure Tubing Pressure 184 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil m X Gas __ Suspended _ Service _Water Injector .... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Michael Mooney Form 10-404 Rev 06/15/88 · Title Drilling Engineering Supervisor Questions? Call Pat Reilly 265-6048 Date ~/Z~/~/ Prepared by Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1D-110A Event History 08/02/00 SET ESP PUMP, PACK-OFF & SLIP STOP. [ESP WORK] 08/04/00 SET 1" X 2000# SOV @ 4766' RKB. [ESP WORK] 08/29/00 PULLED BPV. DRIFTED TBG 2.795" TO TOP OF PUMP @ 4809' SLM. SET SOV (2000# TBG SHEAR) @ 4766' RKB. [ESP WORK] 09/12/00 TAGGED TOP OF PUMP @ 4813' WLM. PULLED SLIP STOP. PULLED PACK- OFF TO 4748' WLM, TOOL SHEARED. IN PROGRESS. [ESP Work] 09/13/00 PULLED PACK-OFF ASSEMBLY FROM 4755' RKB. RIG PROXIMITY @ PRESENT PRECLUDES RIGGING UP 40T CRANE TO RETRIEVE PUMP. [ESP Work] 10/15/00 PULLED & REPLACED 3' CENTRILIFT PCESP. SET @ 4822' RKB. SET 3' PACK-OFF ASS'Y & TESTED 2000 PSI, OK. SET 3" SLIP STOP. [ESP Work] 10/19/00 SOV @ 4766' RKB UNSHEARED, REPLACED. REPLACED PACK OFF & SLIP STOP. TESTED TBG AGAINST PUMP TO 1200 PSI, OK. [GLV, ESP Work, PT Tbg-Csg] 04/10/01 BAILED RUBBER FORM TOP OF TBG STOP 4806' TO 4808' SLM, EST. 1' FILL ON TBG STOP. IN PROGRESS. [ESP Work] 04/11/01 PULLED TBG STOP & PACK OFF, BAILED RUBBER FROM TOP OF BOTH. BAILED RUBBER FROM TOP OF PCESP. IN PROGRESS. [ESP Work] 04/12/01 SET NEW PCESP/PACK OFF/TBG STOP @ 4822' RKB. SET SOV (2000# TBG SH EAR) @ 4788' RKB. PFF TBG 1000 PSi GOOD. [ESP Work] 04/21/01 PULLED SLIP STOP @ 4808'. PULLED SOV @ 4788' RKB & LEFT OPEN GLM. PULLED PACK OFF @ 4813' WLM. UNSUCCESSFUL ATTEMPT TO FISH RUBBER ELEMENT LEFT IN HOLE. WILL FISH IN AM.~ [ESP Work] 04/22/01 04/23/01 UNSUCCESSFUL ATTEMPT TO FISH RUBBER PULLED & REPLACED TTESPCP @ 4821' WLM. SET PACK OFF & SLIP STOP @ SAME. SET 2000# TBG SHEAR SOV @ 4788' RKB.~ [ESP Work] Page 1 of 1 5/25/01 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 October 6, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-110A (200-039) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1D- ll0A. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. ,. Sincerely, jame~s Trantnam ~- Drilling Engineering Supervisor PAI Drilling JT/skad STATE OF ALASKA it ALAS ,.)IL AND GAS CONSERVATION COMMI~,.,~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas D Suspended D Abandoned [~ Service 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-039 / 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22920-01 4. Location of well at surface ............... ~ 9. Unit or Lease Name 44' FSL, 596' FEL, Sec. 14, T11N, R10E, UM (ASP:560491,5959709) i -., .j.: i ~ Kuparuk River Unit ~' " ~' ~:~ 10. Well Number At Top Producing Interval 2319' FNL, 2454' FEL, Sec. 14, T11N, R10E, UM (ASP:558606, 5962612) i ~ '!.-;~:'~i::~.~ ;I' ~ _ 1D-110A At Total Depth ". ~_~-.~ 71.1.T..~.~:-~ i ~ 11 Field and Pool 2330' FNL, 2474' FEL, Sec. 14, T11 N, R10E, UM (ASP: 558586, 5962601)~"--'~"~;/ 'Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool RKB 27' feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date C,.omp., ,~u§r~ O.r~A~and. 115. Water Depth, if of/shore 16. No. of Completions I April 1,2000 April 2, 2000 .~~'~b N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 5905' MD / 4193' TVD 5777' MD / 4066' TVD YES [~] No E]I N/A feet MD 1500' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 9 cub. Yds. High Early 7.625" 29.7# L-80 Surface 5157' 9-7/8" 640 sx AS III Lite, 340 sx Class G 5.5" 15.5# L-80 5007' 5905' 6.75" 110 sx Class G 2.875" 6.53 L-80 4932' 5695' Gravel pack screen set inside 5.5" liner 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5591'-5671' MD 3880'-3960' TVD 8 spt all intervals gravel packed 3.5" 4910' (bottom of ESP) 4932' (top gravel pack pkr) 5540.5'-5565.5' MD 3830'-3855' TVD 8 spt 5519'-5543' MD 3808'-3832' TVD 8 spt 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5496'-5476' MD 3785'-3765' TVD 8 spt DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5476'-5456' MD 3765'-3745' 'I'VD 8 spt 5519'-5543' placed 141149# 14/18 sand behind pipe 5456'-5428' MD 3745'-3717' TVD 8 spt 5496'-5428' placed 133385# 14/18 sand behind pipe 5363'-5394' MD 3652'-3683' TVD 8 spt 5363'-5394' placed 147890# 14/18 sand behind pipe 5591'-5671' placed 167569# 14/18 sand behind pipe Date First Production Method of Operation (Flowing, gas lift, etc.) August 30, 2000 Shut-in , Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 8/30/2000 2.0 Test Period > 8 1 0 1001 219 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 155 psi not available 24-Hour Rate > 94 21 1 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A ~ ~,~ ', ...... , i; ..... ' .... ?t i~ ...... '"'\ "'"'! ~' """ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak D 5361' 3650' Base West Sak D 5398' 3687' West Sak Base 5804' 4093' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed ~ I (~.~'"~'-~~ Title DflllinR En,q neer n,q Superv sor Date~~''O ~'-'[~''' ~ James Trantham INSTRUCTIONS Prepared by Sharon AIIsup-Dratce 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 (DF, 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. Item 28: If no cores taken, indicate "none". Form 10-407 PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-110A(W4-6)) WELL 1D-110A DATE 07/30/00 DAY 5 JOB SCOPE DRILLING SUPPORT-CAPITAL DAILY WORK D SAND FRAC OPERATION COMPLETE I SUCCESSFUL YES I YES InitialTbgPress IFinalTbgPress IlnitiallnnerAnn 0 PSI 700 PSI 0 PSI DAILY SUMMARY KEY PERSON DS-GALLEGOS Final Inner Ann I 595 PSI I JOB NUMBER 0722001825.6 UNIT NUMBER SUPERVISOR CHANEY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PUMPED D SANDS FRAC W/50# HEC & 3% KCL. PLACED 147890 LBS OF PROP IN THE FORMATION W/8 PPA OF 14/18 @ THE I PERFS. USED 5% PAD TO SLURRY RATIO. LEFT 976 LBS OF PROP IN THE WELLBORE.[Frac-Refrac] I TIME 04:15 05:00 05:15 05:40 05:45 06:15 08:05 09:35 10:15 LOG ENTRY MIRU DOWELL FRAC EQUIPMENT. HELD PRE-JOB SAFETY MEETING (27 PEOPLE ON LOCATION) PRIMED UP AND PT'D PUMPS AND TREATING LINE TO 7450 PSI. PUMPED BREAKDOWN W/3% KCL @ 30 BPM. MAXIMUM PRESSURE 6500 PSI AND ENDING PRESSURE 5900 PSI. STEPPED THE RATE DOWN AT THE END OF THE STAGE. SHUTDOWN & OBTAINED ISIP OF 624 PSI W/ F.G. OF (.70). SLURRY VOLUME PUMPED 104 BBLS. PUMPED PULSES W/3% KCL @ 5 BPM. SLURRY VOLUME PUMPED 9 BBLS. PUMPED DATAFRAC W/50# HEC & 3% KCL @ 15 BPM. MAXIMUM PRESSURE 2400 PSI AND ENDING PRESSURE 2100 PSI. STEPPED RATE DOWN AT THE ENDD OF THIS STAGE. SHUTDOWN AND OBTAINED ISIP OF 630 PSI W/F.G. OF (.70).SLURRY VOLUME PUMPED 203 BBLS. CLOSURE PRESSURE 2450+- PSI. PUMPED FRAC W/50# HEC & 3% KCL @ 15 BPM. AVERAGE TREATING PRESSURE 2000 PSI. PUMPED 148866 LBS OF PROP INTO THE WELLBORE & PLACED 147890 LBS PROP IN THE FORMATION W/8 PPA CONCENTRATION OF 14/18 @ THE PERFS. LEFT 976 LBS OF PROP IN THE WELLBORE, EST FILL TOP TO BE AT 5325'. SHUTDOWN AND MONITORED WHP FOR 30 MINUTES. RDMO DOWELL FRAC EQUIPMENT AND TURNED THE WELL OVER TO THE RIG. Date: 08/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-110A RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK BLOCK: SPUD:03/29/00 START COMP:03/28/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22920-01 03/28/00 (Cl) TD: 0' PB: 0' 03/29/00 (C2) TD: 4184' PB: 5873' 03/30/00 (C3) TD: 4184' PB: 5873' 03/31/00 (C4) TD: 4184' PB: 5873' CONTINUE INSTALLING BELLY MW: 0.0 SUPV:DONALD L. WESTER Clean up around well cellar while waiting on roads and pads to clean road from CPF-3 to 3H pad. Turn key rig move. Continue rig move to 1D pad. Rig on pad @ 15:00 hrs, 18 mile move. Spot rig. Install belly board and 11" BOP stack. TESTING BOPE. MW: 9.9 BRINE SUPV:M.C. HEIM Accept rig @ 0900 hrs. 3/29/00. PJSM. Move rig over iD-il0, level rig, build cellar berm. PJSM. Pick up lubricator & pull BPV, rig up circ. lines. Ail lines tested, circulate 9.99 brine, displace freeze protect fluid. HOLDING PRESSURE ON CEMEN MW: 0.0 SUPV:M.C. HEIM Continue circ 9.9~ brine, monitor well. Set BPV, N/D tree. N/U BOPE and function test to 300-3000 psi. CBU. Pull 3.5" tubing change seal rings and stand in derrick. RIH with mule shoe and packer. Tag baker cement retainer @ 5636' and CBU. POH, set packer @ 5428', mule shoe @ 5466'. Squeeze cement thru perfs @ 5636' DISPLACE OUT BRINE W/ DRL MW: 0.0 SUPV:M.C. HEIM PJSM. RIH w/gamma ray, CCL and perf guns, log from 5480' to 5050', perf from 5380' to 5384' POH. Set packer and test. Perform squeeze job. Monitor squeeze pressure, hold pressure on cement to keep from flowing back. Reverse circ out injection rate water and clean up DP. POH w/champ packer. Set test plug and test to 300/3000~, pull test plug. RIH with bridge plug and set @ 5179'. Test to 3000~. POH. RIH with whipstock and milling bha. Date: 08/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/01/00 (C5) TD: 4184' PB: 0' 04/02/00 (C6) TD: 4184' PB: 0' 04/03/00 (C7) TD: 4184' PB: 0' 04/04/00 (C8) TD: 4184' PB: 5777' 04/05/00 (C9) TD: 5958' PB: 5777' 07/17/00 (C10) TD: 5958' PB: 5777' 07/18/00 (Cll) TD: 5958' PB: 5777' SLIDING @ 5350' MW: 9.8 LSND SUPV:M.C. HEIM RIH w/whipstock & milling assembly. Tight spots @ 1277' to 1387' & 2163'. Tag bridge plug @ 5177'. Set whipstock. Top of whipstock @ 5157' and bottom @ 5169'. Depart from windo~ @ 5169'. Displace brine w/LSND drilling fluid. Mill window and 20' new hole from 5157' to 5189'. Pump sweep. Perform FIT to 119. POH w/window milling assembly. Wash and ream hole to 5189'. Sliding from 5189' to 5205' ATTEMPT TO WORK THRU TIGH MW: 9.8 LSND SUPV:M.C. HEIM Drilling-sliding and rotating and surveys from 5205' to 5906'. Pump sweep. Rotate and reciprocate while circ sweep and bottoms up. Wiper trip to 5169' and back no hole problems. CBU. Spot pill. LAYING DOWN DP. MW: 0.0 SUPV:M.C. HEIM Run 5.5" casing. Work through tight spots @ 700', 1112', and 1240'. RIH to shoe @ 5169' Finish running 5.5" liner to bottom @ 5905', no hole problems. PJSM. Cement 5.5" liner, bump plug, set hanger, set packer, sting out and reverse circ, losing mud, circ long way, recovered contaminated mud. Reverse circ, confirm mud loss. POH. RIH with Champ packer. CHANGED OVER TO SEA WATER MW: 9.9 LSND SUPV:DONALD L. WESTER Continue RIH 7-5/8" champ test packer to 2493'. Pull up to 2461'. POOH to 1038'. Circulate surface to surface. Test down DP w/packer set @ 1038' to 2000 psi, OK. Test annulus leak. Move pipe up 983' test to 2000 psi, OK. Tam port collar leak. POOH. RIH with Tam port collar shifting tool. RIH with 3.5" tubing. Reverse circ and displace mud w/sea water. RELEASED RIG @ 0800 HRS 4 MW: 0.0 DOILW SUPV:DONALD L. WESTER Reverse circulate and displace mud w/sea water @ 5700' Set BPV, N/D BOPE, N/U tree. Pull BPV, test tree to 500/5000 psi. Pump diesel down annulus to freeze protect. Raise rig move off well. Release rig @ 0800 hrs. 4/5/00. Rig maintenance SUPV:M. C. HEIM Yearly rig maintenance MW: 0.0 Rig maintenance MW: 0.0 SUPV:M. C. HEIM ~..,,,~ i7,,~ ~,, .... i ....... ' {~: ", ::~ Rig maintenance. Scrub and clean derrick and wind~g,!%~..., ']i~.], ?': !:; ', .... "' Date: 08/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT 07/19/00 (C12) Prepare top drive for mag TD: 5958' SUPV:M. C. HEIM PB: 5777' Continue with rig maintenance. MW: 0.0 Page: 3 DOILW 07/20/00 (C13) TD: 5958' PB: 5777' 07/21/00 (C14) TD: 5958' PB: 5777' 07/22/00 (C15) TD: 5958' PB: 5777' 07/23/00 (C16) TD: 5958' PB: 5777' 07/24/00 (C17) TD: 5958' PB: 5777' 07/25/00 (C18) TD: 5958' PB: 5777' 07/26/00 (C19) TD: 5958' PB: 5777' Nipple up bope MW: 8.5 UNKN SUPV:M. C. HEIM Continue cleaning rig, magnaflux top drive components. Move rig off 1D-118, move to iD-Il0. PULL TOP SCRAPER TO SURFA MW: 8.6 SW SUPV:M.C. HEIM Reverse out diesel. Circ clean seawater to well. Set BPV and ND tree. NU BOPE. Test BOPE 250/30009. PJSM. POH w/3.5" tubing. Set test plug, test HCR. RIH. PERFORATING A2 SAND MW: 0.0 SUPV:M.C. HEIM Continue picking up 3.5" DP. Bridge @ 5699'. Wash thru cement stringers from 5699' to 5720'. Rotate from 5720' to 5724'. Attempt to reverse out cement. Worked plug out & circ. bottoms up. POH. RIH w/mill @ 5700' PJSM. Circ caustic wash. PSJ. RIH w/gamma ray, CCL, pressure & temp. BLEEDING PRESSURE DOWN ON MW: 9.8 BRINE SUPV:M.C. HEIM Perforate from 5591' to 5671', all shots fired. PJSM. Rig up for frac job. Frac well. RIG UP LINES & WAIT ON DO MW: 9.8 BRINE SUPV:M.C. HEIM Reverse brine, monitor well, well flowing 10 bph. Circ and displace well w/brine. Monitor well, still flowing. Circ well. CIRCULATE CLEAN FLUID ARO MW:10.0 BRINE SUPV:DON WESTER & BRIAN NOEL Monitor well, flowing 7 to 8 bph. Circulate brine down tubing. RIH ,and tag sand at 5678'. PJSM. Spot sand plug. RIH and tag sand at 5635' Pick up to 5540' and pump sand. RIH and tag sand at 5555' Wash down to 5575'. PJSM. RIH to perforate. Perforate from 5540.5' to 5565.5'. All shots fired. BUILD 10.2 PPG BRINE IN P MW:10.0 BRINE SUPV:DON WESTER & BRIAN NOEL Perforate A3 sand from 5519' to 5543' All shots fired. PJSM for frac. Pump A3 frac. Well flowing 8.5 ppg fluid w/ no sand. Reverse circulate around 10 ppg brine. Date: 08/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 07/27/00 (C20) TD: 5958' PB: 5777' 07/28/00 (C21) TD: 5958' PB: 5777' 07/29/00 (C22) TD: 5958' PB: 5777' 07/30/00 (C23) TD: 5958' PB: 5777' 07/31/00 (C24) TD: 5958' PB: 5777' 08/01/00 (C25) TD: 5958' PB: 5777' A4/B SAND DATA FRAC MW:10.2 BRINE SUPV:DON WESTER & BRIAN NOEL Reverse circulate brine. Pump brine down tubing. RIH tag sand at 5563'. PJSM. Pump sand. RIH and tag sand at 5533' Pump sand, tag top at 5490'. Wash down to 5505', reverse out sand w/ no losses. PJSM. RU to perforate. Perforate A4/B sands. Shot 5496'-5476', 5476'-5456', 5456'-5428' PUMP SAND PLUG TO COVER A MW:10.2 BRINE SUPV:DON WESTER & BRIAN NOEL Continue perforating, 5456'-5428'. PSJM for frac. Pump frac. RIH tag sand at 5544' POOH to 5320'. Pump 20/40 sand. RIH & tag sand at 5480'. POOH to 5320' and pump sand. D SAND DATA FRAC MW:10.2 BRINE SUPV:DON WESTER & BRIAN NOEL Tag sand plug at 5468'. Attempt to reverse, pressured up, tubing plugged. Reverse circ out large volume of sand and gel. CBU & RIH tag firm at 5332' Wash to 5382' and reverse out sand. Continue reverse out sand to 5410'. No sand at 5410'. RIH tag at 5473' and POOH to 5320'. Pump 20/40 sand and POOH to 5260' Circulate brine around. RIH tag firm at 5332'. Wash to 5383' and reverse out sand. Wash to 5408' and reverse. Confirm tag, no sand until 5435'. Pick up to 5414'. Pour sand down tubing. Tag at 5396' Wash down to 5405' and revers out. Good firm tag at 5416'. RIH with perforating gun. Tag sand at 5403' ELM. Perforate 5363'-5394' COMPLETING CLEAN OUT TO 5 MW:10.2 BRINE SUPV:DON WESTER & BRIAN NOEL PJSM for frac. Pump frac. Reverse circulate brine. RIH tag sand at 5244'. Reverse out sand from 5244'-5508' REVERSE OUT PACKER SETTIN MW:10.2 BRINE SUPV:DON WESTER & BRIAN NOEL Reverse out sand from 5508'-5700' with brine. Pick up 60', losing fluid. Cut rate to 2 bpm and fluid loss stopped as sand cleared from work string. Lost 300 bbls during clean out. Tag at 5700', monitor well. Gained 100 bbl over 1 hour w/flow slowing at end. Tag at 5697', SI. Circulate brine down tubing. Tag firm sand at 5700' Monitor well, dead. POOH. Test BOP to 250/3500 psi. RIH with 2-7/8" gravel pack screens and 2-1/16" inner string. RUNNING COMPLETION MW: 9.8 BRINE SUPV:M.C. HEIM RIH slow w/screen assembly on 3.5" dp, tag @ 5695' PJSM. Gravel pack. Shut down and monitor well, circ well, well dead. POH. PJSM. Pick up ESP motor, gear box and seal assembly. Date: 08/25/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 08/02/00 (C26) TD: 5958' PB: 5777' 08/03/00 (C27) TD: 5958' PB: 5777' 08/04/00 (C28) TD: 5958' PB: 5777' PREPARE TO RIH W/ COMPLET MW:10.2 BRINE SUPV:M.C. HEIM Continue picking up motor, gearbox & seal assembly, rig up cable sheave & string up ESP cable, perform electric integrity test & connect to motor, hook up baker sentry gauge & test cable. Set pump and packoff assembly. RIh w/3.5" tubing. Well flowing out tubing & dropping in annulus, pump pill. Continue running completion. 'U' TUBE DIESEL MW:10.2 BRINE SUPV:M.C. HEIM PJSM. Run in hole with completion, testing cable. Space out heat trace cable. Cut & splice 'ESP' cable. NEW WELL MW: 9.8 BRINE SUPV:M.C. HEIM Set BPV. N/D BOPE. Test tree 250/50009. Pump diesel. Prep yard for rig move. Release rig @ 1200 hrs. 8/4/00. North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-110A Surveyed: 2 April, 2000 SURVEY REPORT 14 April, 2000 YOur Ref: API.500292292001 Surface Coordinates: 5959708.86 N, 560490.58 E (70° 18' 01.7503" N, Kelly Bushing: 100.48ft above Mean Sea Level 149° 30' 36.2842" W) CIR I L. L. IN I~ RECEIVED A;~,,a 0~1 & Gas Cons. Commission Anchorage Survey Ref: svy9158 Sperry-Sun Drilling Services Survey Report for 1D-110A Your Ref: API-500292292001 Surveyed: 2 April, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. 5154.60 23.330 288,560 5157.00 23.270 288.470 5194.70 22.900 295.940 5240.16 20.330 306.210 5286.61 14.350 322.000 5336.61 4.460 327.660 5382.42 0.240 225.580 5480.66 0.290 133.240 5577.74 1.550 211.270 5673.97 2.550 229.400 5771.07 4.270 239.990 5849.96 5.900 256.370 5905.00 5.900 256.370 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 3352.79 3453.27 2887.22 N 1817.06W 3354.99 3455.47 2887.52 N 1817.96W 3389.68 3490,16 2893.09 N 1831.62W 3431.95 3532.43 2901.63 N 1845.96W 3476.30 3576.78 2910.94 N 1856.03W 3525.56 3626.04 2917.49 N 1860.89W 3571.33 3671.81 2918.92 N i861.91W 3669.57 3770.05 2918.61 N 1861.88W 3766.63 3867.11 2917.32 N 1862.38W 3862.80 3963.28 2914.81N 1864.68W 3959.73 4060.21 2911.60 N 1869.45W 4038.31 4138.79 2909.17 N 1875.94W 4093.06 4193.54 2907.84N 1881.44W Global Coordinates Northings Eastings (ft) (ft) 5962581.36 N 558650.34 E 5962581.65 N 558649.43E 5962587.11 N 558635.73 E 5962595.53 N 558621.32 E 5962604.77 N 558611.18 E 5962611.27 N 558606.26 E 5962612.70 N 558605.23 E 5962612.39 N 558605.26 E 5962611.09 N 558604.77 E 5962608.57 N 558602.49 E 5962605.32 N 558597.75 E 5962602.84 N 558591.28 E 5962601.46 N 558585.79 E Dogleg Rate (°/100ft) 2.907 7.826 10.041 16.274 19.843 9.859 0.391 1.562 1.226 1.879 2.747 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.671° (31-Mar-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 327.150° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5905.00ft., The Bottom Hole Displacement is 3463.43ft., in the Direction of 327.096° (True). RECEIVED SEP Gg 2000 Alaska 0it & Gas Cons. Gomm~ssio~ Anchorage Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 3411.18 3411.92 3424.01 3438.96 3452.25 3460.39 3462.15 3461.87 3461.05 3460.20 3460.09 3461.57 3463.43 Tie-on Survey Window Point Projected Survey Continued... 14 April, 2000 - 10:21 -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D- 1 I OA Your Reft AP1.500292292001 Surveyed: 2 April, 2000 North SloPe Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 5154.60 5157.00 5905.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3453.27 2887.22 N 1817.06 W 3455.47 2887.52 N 1817.96 W 4193.54 2907.84 N 1881.44 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 5905.00 4193.54 Survey Tool DescriPtion MWD Magnetic RECEIVED Oil & Gas Cons. Commission Anchorage DrillQuest 1.05.05 14 Al3ril, 2000 - 10:22 -3- Date 07/22/00 Well Na 1D-110A Service Type ELECTRIC LINE Desc of Work PERF Supervisor KENNEDY Complet r~ Accident r- Injury F Spill F summary Upcoming I-- Job Num 0722001825.6 Unit 2128 Contractor Key Perso SWS-ELMORE Successful r~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 PERFORATED (INT: 5591 '-5671 ') W/3-3/8" DP HSD (41B), 8 SPF. (Perf] AFC AK0053 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 25WS1 D6 Uploaded to Set Date printed: 08/25/00 at: 15:32:45 Date 07/23/00 Well Na 1D-110A Service Type PUMPING Desc of Work A2 SAND FRAC Supervisor G©BER Complet r~ Accident r Injury l-- Spill r Summary Upcoming F Job Num 0722001825.6 Unit AFC AK0053 0 Prop 25WS1 D6 Uploaded to Se~ Contractor Key Perso DS-GALLEGOS Successful ['~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 Final Tbg Press 520 Final Int Csg Press 520 Final Out Csg Press 0 PUMP A2 SAND FRAC - PUMPED 70# HEC-3% KCL BASE FLUID - PUT 167569 LBS 14/18 SAND BEHIND PIPE (INCLUDING SCOUI STAGE) W/9 PPA ON PERFS - PUMPED JOB WITH 4% PAD TO SLURRY RATIO - LEFT 947 LBS IN WELLBORE - LEFT 520 PSI ON WE [Frac-Refrac] RECEIVED <..,,'.:o C,'3 ?_000 · ,~ Oil & Gas Cons. Go~m~ssie, B Anchorarje Date printed: 08/25/00 at: 15:37:05 Date 07/26/00 Well Na 1D-110A Service Type PUMPING Desc of Work A3 SAND FRAC Supervisor CHANEY Complet r~ Accident r Injury l-- Spill r summary Upcom.~g r- Job Num Unit 0722001825.6 AFC AK0053 0 Prop 25WS1 D6 Uploaded to Se~ Contractor Key Perso DS-GALLEGOS Successful I~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 Final Tbg Press 800 Final Int Csg Press 680 Final Out Csg Press 0 PUMPED A3 SAND FRAC W/50# HEC & 3% KCL WATER. PLACED 141149 LBS IN THE FORMATION W/8 PPA CONCENTRATIOI 14/18 PROP @ THE PERFS. USED 5% PAD TO SLURRY RATIO. LEFT 1145 LBS OF PROP IN THE WELLBORE. RECEIVED qtzp Oq Date printed: 08/25/00 at: 15:37:57 Date 07/26/00 Well Na 1D-110A Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor CHANEY Complet [~ Accident ~-- Injury l- r- Summary ,( Upcorr~u~g r-' Job Num 0722001825.6 Unit 2128 Contractor Key Perso SWS-ELMORE Successful r~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 TAGGED SAND AT 5567' ELM. PERFORATED A3 SAND INTERVAL @ 5519'-5565.5'. AFC AK0053 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 25WS1 DE Uploaded to Se~ Date printed: 08/25/00 at: 15:38:15 Date 07/28/00 Well Na 1D-110A Service Type ELECTRIC LINE Desc of Work PERFORATE A4-B SAND Supervisor CHANEY Complet F~ Accident r- Injury l- I- Summary UpcJn~lng I-- Job Num 0722001825.6 Unit 2128 Contractor Key Perso SWS-ELMORE Successful r~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 PERFORATE A4/B SANDS: 5428'-5496'. TAGGED SAND AT 5500'. AFC AK0053 0 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 Prop 25WS1D61 Uploaded to Ser Date printed: 08/25/00 at: 15:39:15 Date 07/29/00 Well Na 1D-110A Service Type ELECTRIC LINE Desc of Work PERFORATE Supervisor CHANEY Complet Accident F Injury I-- spill l- Summary PERFORATE D SAN DS=5363'-5394' Upcoming I~ Job Num 0722001825.6 Unit 2128 Contractor Key Perso SWS-ELMORE Successful r~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 AFC AK0053 0 FinaITbg Press 0 Final Int Csg Press D Final Out Csg Press 0 Prop 25WS1 D6 Uploaded to Ser Date printed: 08/25/00 at: 15:41:01 Date 07/28/00 Well Na 1D-110A Service Type PUMPING Desc of Work A4/B SANDS FRAC Supervisor CHANEY Complet Accident Injury I- l- Summary Upcoming I~ Job Num Unit 0722001825.6 AFC AK0053 0 Prop 25WS1 D6 Uploaded to Set Contractor Key Perso DS-GALLEGOS Successful F~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 Final Tbg Press 830 Final Int Csg Press 585 Final Out Csg Press 0 PUMPED A4/B SANDS FRAC W/50# HEC & 3% KCL. PLACED 133385 LBS IN THE FORMATION W/8 PPA OF 14/18 PROP @ THE USED 15.5% PAD TO SLURRY RATIO. LEFT 1017 LBS OF PROP IN THE WELLBORE. [Frac-Refrac] Date printed: 08/25/00 at: 15:40:15 WELL LOG TRANSMITFAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 15, 2000 0A, AZ- -00004 The technical data listed below is being submitted herewith. Please address any problems or concerns to the. attention of.' Jim Galvin, Sperry-Sun Drilling Services,. 5631 Silverado Way,.~G, Anchorage, AK 99518 1D-11OA: 2"x 5" MD Resistivity & Gamma Ray Logs: 50,029-22920-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22920-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia AUG 1 5 2000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company r'l R I /I._ I I~1 1"~ ¢;ER~JI C Ecl WELL LOG TRANSMITTAL To: State of Alaska August 10, 2000 Alaska Oil and Gas Conservation Comm. Atto: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs goo 1D-11OA, AK-MM-00004 1 LDWG formatted Disc with verification listing. AP1//: 50-029-22920-01 PLEASE ACKNOWLEDGE RECEIPt BY SIGNING AND RETURNING A COPY OF TI:IE TRANSMI'ITAL LETTER TO TIIE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: ,. ,t, ,~uo 1 S :2',000 Alaska 0il & Gas Cons. Commission Anchorago 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company MEMORANDUM TO: THRU: FROM: Dan Seamount Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 31, 2000 Blair Wondzell ~~ P.I. Supervisor 9/~]c~ Lou Grimaldt~-~- ~ Petroleum InSpector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nordic 3 Phillips Petroleum Co. 1D-110A 200 0390 Kuparuk River Field/Unit Operator Rep.: Don Wester Op. phone: 659-7872 Contractor Rep.: Shane McGeehan Rig phone: 659-7653 Op. E-Mail: N1433@ppco.com Rig E-Mail: N1434@ppco.com Test Pressures Rams: 300/3500 Annular: 300/3000 TEST DATA FLOOR VALVES: P/F Quantity P/F P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 2 P Inside BOP 1 P MISC. INSPECTIONS: P/F Location Gen.: P Sign: ., Housekeeping: P Rig cond: ~ PTD On Location P Hazard: Standing Order: ~ :P BOP STACK: Choke: 300/3500 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P* H2S Gas Detector P :P* Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 11" P CHOKE MANIFOLD: . Time/Psi P/F Pipe Rams 1 27/8X5 1/2 P Quantity P/F System Pressure 3000 P Lower Pipe Rams 1 3 1/2 P No. Valves 12 P After Closure 2100 P Blind Rams 1 11"blind P Man. Chokes 1 P 200 psi Attained :17 P Choke Ln. Valves 1 3" P Hyd. Chokes 1 P Full Pressure 1:04 P HCR Valves 1 3" P Blind Covers (All Stations): P Kill Line Valves 2 2" P N2 Bottles (avg): 4@ 2150 P Check Valve 0 Test's Details John Crisp (A.O.G.C.C. Inspector) and myself traveled to ID pad in Kuparuk to witness the weekly BOP test on this rig. The test began as soon as we arrived. The test went well with all BOP components Functioning properly and holding their pressure tests. There was a door leak on the drillers side Blind rams door and a leak on the inside of the manual choke valve. These were tightened up and retested "OK". The area surrounding the rig was clean although somewhat congested due to Frac equipment that was still rigged up around the rig. The rig itself was clean and orderly which is normal. There is still a problem with proper notification from this rig which makes it difficult to schedule for tests. Total Test Time: 4 Number of failures: _.0 Attatchments: None cc: Morrison/Overstreet (P.P.Co. KRU drillin.q Supt. V16moh5g.xls 8/2/00 14-Apr-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-110A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,154.60' MD 5,157.00' MD 5,905.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) ECE--dVED APR 24 ~000. Ataska Oil & Gas Cons. Commission Anchofacje MEMORANDUM TO' State of Alaska Alaska Oil and Gas Conservation Commission Robert ChristensoJ/~ DATE: April 1, 2000 Chairman L~' THRU' Blair Wondzell, ~ P. I. Supervisor /~/'3'/eo FROM: John Crisp,"'~C--. SUBJECT: Petroleum Ihspector Csg. & FIT Test Nordic 3 Well 1D-110A KRU West SAK .2oo April 1, 2000: I traveled to Arco Alaska's Kuparuk River unit 1D pad to witness the Formation Integrity Test on West Sak well 1D-110A. The well plan called for 11ppg. Formation integrity test for the West Sak side track 1D-110A. The reason for 11 ppg. Integrity was to be able to determine that the West Sak Sands would be able to handle the ECD's that would occur while drilling this sidetrack well. This well was initially drilled to TD with Diverter System. The AOGCC test form is attached for reference. SUMMARY: I witnessed the successful FIT to 11 ppg. On AAI's KRU West Sak well 1 d-110A. Attachments: Csg. & FIT Nordic 3 1D-110A 4-1-00jc cc; NON-CONFIDENTIAL CASING TEST and FORMATION INTEGRITYTEST Well Name: W Sakld-110 Date: 4/1/00 Reason(s) for test: Supervisor: M.C. Heim I~ Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7 5/8" 29.7 # L-80 BTC Casing Setting Depth: 5,169' TMD Hole Depth: 3,470' TVD Mud Weight: 9.8 ppg Length of Open Hole: 5,189' TMD 3,474' TVD 20' EMW = + Mud Weight 220 psi 0.052 x 2385 0.052 x 3,470' EMW = 11.0 ppg + 9.8 ppg Pump output = .101 BPS 3,300 psi 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,30O psi 2,200 psi Fluid Pumped: 0.2 BBL BLED BACK : BBLS 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 pSI 1,400 psi 1 ,~:~o psi 1,2oo psi 1,1oo psi 1,ooo psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi o psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ,. . .C. .h:_ .P_ ?_ .m_ . .p. ...................... _7_.O__p_.s.!: ......................... -~-;i~-;----i----~--~;i'-" ............... -~ ................ ? ................. 1 f ................................ ~- ................. I stks 150 psi 6stks ! 250 psi 2stks 190 psi 9 stks i 500 psi 3stks 220 psi 12 stks ! 800 psi ................................. , ................. , ..................... ;-~-:::::----?-;--~x-,,--:.-:.;--' ................ , ................ i ...................- .................. ¥,¥-;-:zc---r-';'-;,-~;,----z..-- F ................................. ' ................. -I ................................. I- ................. : , 24stks ! 2,100 psi , , 27 stks i 2,400 psi ............... *' ................ t ................. I i ................................. ,,- ................. , , 30 stks ! 2,700 psi [ ................................ : ................. ~ .................... -~-;;/~,-;--'F-~;-~E~;i--' r ................. , I i ................ ~ ................ r ................. '. ................................ ~ ................. -i ................................. F ................. i ............................... i ................. i i ................ .. ................ i .................. '. ............... ; ................ J ..................' ................................. I- ................. I I I F ............... ~ ................ 'i .................-I ................................. ,I- ] ................ .I ................. SHUT IN TIME I , 0.0 min : 3,000 psi ~. ............................... j ................. ~ ................................ ,~ .................. , ................................. ~ .................. , ___?__.m_L~___~ ................ i___3_,._°_°_.°__P.S_!__ I ; I 2.0 min~ i 3,000 psi I , [ I ..................... ~ ........... I- ................. , SHUT IN TIME i SHUT IN PRESSURE 3.0 min i i 3,000 psi ~ 0.0min i 220 psi i 4.0 min ~ i 3,000 psi .......... : ................................... :-i .... ~;6'-r;;i,:,-'-i ................ [-'~ 1.0mln : 210 psi .................................2.0 min i----~-G-;i--i i ~:~'-~;~- i [ 30min . i 210 psi i : ................ 7.0min ': ................ F .... ' .......... ~ ................ t ................. -I I ................................. I- ................. ; 200 psi i ' 4.0 min , . 8.0 min i ! 3,000 ps~ ' . 5.0 min ; 200 psi ; ,-'-~.,,,,,,,", ,'-,.,,,.,,.,,.,-F,:,,--' ~--~:E~i;---' ................ F--~G-;i--'i '--TE6-~i~--i ................ '---:-:-:.--z-..----'., ................ '..----;;;;;-:::;---~ ~ ............ :'--; ................ ~ .............. :--' 20.0 mln , : 3,000 psi 9.0 min ! '; 190 psi i 25.0 min i '.,, 3,000 ps, ~-, .............. ~ .................................f ~ I .................................................. t r 10.0 min ! i 190 psi i 30.0 min : i 3,000 psi i_ ............... ~ ................ ~ ................. J i ................ · ................ ~ ................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY MEMORANDUM TO' State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~/~ DATE: March 30, 2000 Chairman THRU' FROM: Blair Wondzell, P. I. Supervisor 3/'~(oo John Petroleum Inspector SUBJECT: BOP Test Nordic Rig 3 KRU 1D-110A March 30, 2000: I traveled to Arco Alaska's Kuparuk River field to witness Nordic 3's initial BOP test on sidetrack 1D-110A. The lower pipe rams could not be tested due to the X-over sub length after screwing the test joint into the Vetco Gray TBG. Hanger. The lower pipe rams will be tested after L/D tubing. This sidetrack is being performed in the West Sak Sands. The AOGCC test form is attached for reference. The Rig is in very good shape. All personnel showed to be very familiar with test procedures & all BOP equipment. SUMMARY: I witnessed the initial BOP test on Nordic 3 in AAI's KRU on well 1D-110A. Tested BOP's, test time 3 hours, no failures witnessed. Attachments: BOP Nordic 3 3-30-00jc cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Workover: Drlg Contractor: Nordic Alaska Rig No. Operator: Arco Alaska Inc. Well Name: KRU 1D-110A Casing Size: 7 5/8" Set @ 5958' Test: Initial x Weekly Other 3 PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA DATE: 3/30/00 200039 Rig Ph.# 659-7653 Mr. Dink Helm Mr. Lance Johnson 14 T. liN R. 10E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan, Test Press. P/F 25O/3, OOO P 1 250/3,000 P '1 Not Tested I 25O/3, OOO P 1 250/3,000 P I 250/3,000 P 2 250/3,000 P P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector Tested Tested H2S Gas Detector Tested Tested FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F I 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P CHOKE MANIFOLD: No. Valves 13 No. Flanges 28 Manual Chokes Hydraulic Chokes Test Pressure P/F 250/3,000 P 250/3,0OO P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 P 2,200 P minutes 17 '/ minutes 0 Remote: 4 Btls @ 1900 psi. ave. Psig. sec. sec. X Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Lower pipe rams will be tested after LiD tubing. This was very good test. Crew change occurred during BOPE test & was done efficiently with all personnel showing very good knowledge of test procedures. Rig & Location were very neat & clean. Heavier than air & lighter than air gas detectors were tested @ shale shakers. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspe¢t.~lb (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John Crisp "dic 3 3-30-00jc TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 a.e~ Kuparuk River Unit 1 D- 110A ARCO Alaska, Inc. Permit No: 200-039 Sur Loc: 44'FSL, 596'FEL, Sec. 14, T11N, R10E, UM Btmhole Loc. 2318'FNL, 2478'FEL, Sec. 14, T11N, RIOE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORD.ER OF TH_~._OMMISSION DATED this 2.~ day of March, 2000 dlffEnclosures CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environlnental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill r~ Redrill E] I ~.Type ofwell. Exploratory ~1 StratigraphicTest E] Development Oil Re-entry F~ Deepen DI Service F~ Development Gas r'~ Single Zone E] Multiple Zone r"] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 112 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 44' FSL, 596' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2327' FNL, 2461' FEE, Sec. 14, T11N, R10E, UM 1D-110A #U-630610 At total depth 9. Approximate spud date Amount 2318' FNL, 2478' FEL, Sec. 14, T11N, R10E, UM March 20, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2318' @ TD feetI None feet 2560 5900' MD/4189'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAO ~5.035 (e)(2)) Kickoff depth: 5168 MD Maximum hole angle 23 ° Maximum surface 1205 psig At total depth (TVD) 1606 psig 18. casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casin~l Wei~lht Grade Couplin~l Le%lth MD TVD MD TVD (include stage data) 6.75" 5.5" 15.5# L-80 BTC-MOD 875' 5025' 3336' 5900' 4189' 28 bbls Class G sidetrack - top of window @ 5172' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 5973 feet Plugs (measured) true vertical 4228 feet Effective Depth: measured 5874 feet Junk (measured) true vertical 4134 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 9 cub. Yds. High Early 121' 121' Surface 5917' 7.625" 28 sx AS III & 340 sx Class G 5958' 4214' Intermediate Liner Production RECEIVED Perforationdepth: measured 5623'-5712' ORIGINAL '"' true vertical 3895'-3979' ,~a~a 0il & Gas Co~s. Commission 20. Attachments Filing fee [~] Property Plat r'~ BoP Sketch F~] Diverter Sketch F~ Drilling program'~ Dri,,ing fluid program I"¢1 Time vs depth plot E]Refraction analysis D Seabed report E] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Brian Noel 265-697~ Signed ~v..~-- ~. ~.,1~.,. Title: Drilling EngineeringSupervisor Date Chip Alvord Prenared hv Sharon AIl_~lJn-Dr~k~ Commission Use Onl~ Permit Number APl number _ ISee cover letter ~--~'-- (-.~~ 50- ~...~C~,-..,~..~_..Z~,~_~..~/ I Appro~_t_..e(:~)_ ~ If°r°therrequirements Conditions of approval Samples required E] Yes .J~ No Mud Icg required E] Yes ~ No Required working pressure for BOPE D2M; 3M; [~ 5M; F~ lOM;D D Other: ORiGiNAL SIGNED BY Robe~ N. Christenson by order of Approved by Oommissioner the commission Date~ Form 10-401 Rev. 12/1/85 · Submit in triplicate REDRILL PLAN SUMMARY Well 1 D-110 A Type of well (producer/injector): Producer Surface Location: Target I - Top of D: TD: MD: TVD: 44' FSL, 596' FEL, Section 14, T11 N, R10E, UM 2327' FNL, 2461' FEL, Section 14, T11 N, R10E, UM 2318' FNL, 2478' FEL, Section 14, T11 N, R10E, UM 5,900' 4,189' Rig: Nordic Rig 3 Estimated Start Date: Operation Days to Complete: 3/2O/OO 22 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Drilling Fluid 9.1 8-14 15-25 45-55 4-7 8-11 <10 9.0-9.5 4-8 Drilling Fluid System: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: RECEIVED ~.r..,,.~ ] 5 2.000 Alaska 0il & Gas Co~s. Cemfnissio~ Aach0rage Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Casinq/Tubincl Proclram: Hole size Cs_~/Tb_~ Liner 6-3/4" 5-1/2", 15.5#, L-80, BTC Mod Tubing 3-1/2", 9.3#, L-80, EUE 8rd Mod Length Top (MD/TVD) Btm (MD/TVD) 875' 5,025' / 3,336' 5,900' / 4,189' 5,000' Surface 5,000' / 3,314' Cement Calculations: West Sak Abandonment: Casing to be cemented: A2 sand perfs at 5,623' - 5,636' D sand squeeze perfs at 5,380' - 5,384' Volume = 8.7 bbls, Class G Cement per interval Based on: 100' in 10" hole x 7-5/8" annulus and 100' left in 7-5/8" casing 5-1/2" in 6-3/4" open hole Volume = 28 bbls, Class G Cement Based on: Open hole volume + 60%, 150' liner lap, and 200' of cement above liner top. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 1205 psi and is calculated using a gas column to surface with a maximum expected formation pressure in the West Sak of 1600 psi (3650' tvd) and a gas gradient of 0.11 psi/ft. MASP = (3650 ft)*(0.44 - 0.11 psi/ft) = 1205 psi Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: Sidetrack window is in shale below the last Ugnu sand. There is potential of lost circulation in the West Sak sands. Solids control and dilution will be used to maintain mud weight at 9.1 ppg (provides 100 psi overbalance). Lost circulation material will be onsite. No over/under pressured horizons anticipated. None. Directional' KOP: Max hole angle: Close approaches: 5168' MD / 3465' TVD (Nordic 3 RKB) 23° (in sidetrack portion at KOP) 67° (in original portion) Closest well is 1D-111 at the sidetrack KOP with center to center distance of 814'. Loq(3inq Pro(~ram: Open Hole Logs: Cased Hole Logs: GR / Resistivity GR / CCL Notes: All drill solids generated from the 1D-110A sidetrack will be hauled to the designated Prudhoe Bay cuttings facility for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted Kuparuk disposal well. KRU 1D-110 A GENERAL PROCEDURE Pre-Rig Work: 1. Set BPV and VR plug. 2. Remove well house and scaffolding. General Sidetrack and Completion Procedure: 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 9.1 ppg LSND mud and displace well. Shut in and monitor pressures to ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to floor and POOH standing back 3-1/2" tubing. 5. Pick up 3-1/2" DP, RIH with RTTS and set packer at +/- 5470' MD. Pump 8.7 bbls class G cement, squeezing +/- 4.1 bbls cement through A2 perfs at 5623-5636', leaving remainder (100') inside 7-5/8" casing. 6. Release packer, POOH to +/- 5250' MD, circulate well, RU E-line and shoot squeeze perfs at +/- 5380' MD (=5' above top D sand). 7. Set packer at 5230' MD and pump 8.7 bbls class G cement. Squeeze +/- 4.1 bbls cement through perfs, leaving (100') inside 7-5/8" casing. Release packer, circulate well and POOH. 8. RIH and set bridge plug at +/-5201' MD, pressure test casing to 3500 psi, POOH. 9. PU Baker 7-5/8" Window Master Bottom Trip Whipstock and MWD, RIH. Orient and set whipstock w/MWD. Shear off whipstock bolt and mill window in 7-5/8" casing and 15' formation. Perform FIT test to 10.0 ppg (max expected ECD at the window for 9.1 ppg LSND mud), POOH and LD milling assembly. 10. RIH w/6-3/4" bit, MWD / LWD and steerable drilling assembly. Slide out window and directionally drill per plan through the West Sak sands to TD at +/- 5900' MD. POOH and lay down drilling assembly. 11. RIH with 5-1/2" liner to TD (150' overlap above top of window). Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH laying down 3-1/2" DP. 12. Pressure test casing and liner lap to 3500 psi for 30 min (Chart Test for State). 13. PU 3-1/2" by 2-7/8" tapered work string with bit and scrappers. RIH and displace well to 9.1 ppg brine and clean 7-5/8" casing and 5-1/2" liner. Pump caustic wash and acid pickle, POOH. 14. RU E-line and perforate A2 sand. RIH w/mule shoe on work string, land tubing hanger, pump fracture stimulation, pull and LD hanger, kill well, circulate out excess sand, and filter brine, POOH. 15. Repeat step #14 above for the A3, A4/B and D sand intervals. 16. RIH w/mill and clean out frac sand to 15' below bottom of A2 perfs. Circulate and filter brine prior to gravel pack, POOH. 17. PU and RIH with gravel pack assembly, tag sand top and set packer at +/-5260' MD, pump gravel pack, POOH laying down work string. 18. RIH w/ESP completion and heat trace on 3-1/2" tubing. 19. Space out and land hanger, RILDS, install two-way check and test tubing hanger. 20. ND BOPE, NU tree and test. Freeze protect with diesel to +/- 2000' tvd. RDMO Nordic 3. Lower Limit: 21 days Expected Case: 22 days Upper Limit: 25 days No problems. Difficulties cutting window, drilling sidetrack, running ESP completion. BDN 3/11/00 WEST SAK (1D-110) Proposed Plugback J 16" 62.5# H-40 @ 121' MD Tam Port Collar @ +/- 998' MD ARCO Alaska, Inc. APl#: 50-029-22920 Original RKB: 112.1' Directional KOP = 250' Max Angle = 66.94 Deg @ 2696' Avg Angle Thru W.Sak = 17 Deg Depths are Parker 245 RKB 7-5/8" Baker 'Window Master Whipstock' run on bottom trip anchor. 7-5/8" Baker Bridge Plug set on drill pipe @ +/-5190' MD. 9.1 ppg LSND Mud Cement Add Squeeze Perfs above D sand: 5380' - 5384' 9.1 ppg LSND Mud Cement Existing A2-Sand Perfs: 5623' - 5712' ( 12 SPF 4-1/2" HSD Big Hole Charges ) Top of Baker K-1 Cement Retainer @ +/- 5636' ( 13' below top of A-2 Perfs ) Sand Plug PBTD @ 5873' MD 7-5/8" 29.7# L-80 BTC Mod @ 5958' MD BDN 3/9/OO WEST SAK 1 D-110A (Sidetrack, Frac then Gravel Pack) 16" J 62.5# H-40 @ 121' MD Port Collar @ 998' MD Depths are Parker 245 RKB Top of Whipstock at +/-5172' MD Top of BP at +/-5190' MD 9.1 ppg LSND Mud Cement 9.1 ppg LSND Mud Cement Squeeze Perfs A2 Perfs PBTD @ Sand Plug 5873' MD 7-5/8" 29.7# L-80 BTC Mod @ 5958' MD ARCO Alaska, Inc. APl#: Original RKB: 112.1' 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 3-1/2" 9.3# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. Raychem Heat Trace @ +/- 3000' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to Surface. 3-1/2" x 1" Camco 'KBMM' GLM run open @ +/- 5110' MD. After the rig moves off location, the Wells Group will install a Shear Circulating Valve, pinned for 3000 psi Tbg / Csg differentia. I 1 Joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing. Baker Sentry BHP Gauge (attached to 2nd 10' Pup Joint above the Slotted Nipple). 10' Spaceout Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 10' Handling Pup 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing Centrilift ESPCP (components as listed below) w/bottom set @ +/- 4950' MD (total length - 26.8') Centrilift 3-1/2" Slotted Nipple. Centrilift TTC Changeover Centrilift Tandem Seal Section: GSB3 DB IL H6PFS Centrilift PC Pump and Flex Shaft Assembly: KUDU 180ML2000 Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP KMH 1315/26 Centrilift Motor Centralizer Liner Equipment: - Baker 7-5/8" x 5-1/2" 'ZXP' Liner Top Isolation Packer set at +/-5020' MD. - Baker 7-5/8" x 5-1/2" 'HMC' Hydraulic Liner Hanger with 5-1/2" BTC-Mod pin down. - 5-1/2" Liner, Landing collar/Float collar, 2 joints casing, Shoe. D- Sand B/A4 - Sand A3 - Sand Completion Equipment: - Baker Model SC-1 Packer @ +/- 5260' - Top of screen @ +/- 5350 ' - Bakerweld 140 GP Screen, 6.4# L-80 Seal-Lock HT base pipe A2 - Sand 5-1/2" 15.5# L-80 BTC Mod @ +/-5950' MD RECEIVED - Alaska 0il & Gas Cons. Commission Anchorage BDN 3/9/0O DrillQuestTM North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1 D-110A WPs 34OO 3500 5186'MD of Survey Drill out @ 12.000°/100ft, 75.000° TF: 5168.40ft MD, 3465.48ft 'TVD Rate Increase @ 14.000°/100ft: 5201.70ft MD, 3496.01ft TVD 3600 Eastings Scale: linch = 100ft -1900 -1800 I I · t:: 29OO - o Z Dir Rate Increase @ 14.000' Drill out @ 12.000°/100ft, ID-Il0 Polveon [ 5 1/2' Li~er-5895.39 MD, I / To,a, De,h: 5895.39ft MD. I&o~.~ EncJDir: 5360.27ff Mr 3649.50 ryz> Il \ ~ N i ~ , /100f~'~ ~'b, 3496.0'1}t TVa ~5.000o ~-F: 5168.40ft UD, a465.4~.*VD I I -1900 -1800 Eastings ~.184.29 TVD 4184.29ft TVD 3649.50ft TVD .-- - 2900 o Z Reference is True North 370O ID-110 T1 3649.50 TVD 1861.30 Dir: S360.27f. t..M.D., .3.6.4..9:5.gf.t.T.V.D' ........... ]D-HO Polygon 'Top West Sak D - 3649.50 TVD 'Top B- 3712.50 TVD 39OO 4000 - 4100 - O II O ._ '~ 4200 -- I 34OO Scale: linch = 100ft 'Top A4 - 3751.50 TVD · Top A3 - 3796.50 TVD · Top A2 - 3870.50 TVD Digitally signed by Approve,d.D,.irectional Profile cn=Approved Directional Fg°fil'% c=US Date: 2000.03.13 10:03:1'~'-,O~.~0' Reason: Approval Anchorage, AK (fill 5650.00 ................................... TOp AJ - 3985.50 "['VD 5750.0o 5800.00 5850.00 5168.40 5201.70 5201.70 5360.27 ./Total Dept D, 4184.29ft TVD 5895.39 K 5 1/2" Liner - 5895.39 I~D, 4184.29 TVD I I 3500 3600 Vertical Section Section Azimuth: 327.151 © (True North) Current Well Properties Well: 1D-110AWPs Horizontal Coordinates: Ref. Global Coordinates: 5959708.86 N, 560490.58 E Ref. Well: 195.38 S, 4.87 E Ref. Geographical Coordinates: 70° 18' 01.7503" N, 149" 30' 36.2842" W RKB Elevation: 94.50fl above Mean Sea Level 94.50ft above Well North Reference: True North Unite: Feet Proposal Data for 1 D-110 Wp7 Vertical Origin:Well Horizontal Origin: Well Measurement Units: ft North Reference:True North Dogleg severity:Degrees per 100fi Vertical Section Azimuth: 327.151 ° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azlm. Vertical Northlngs Eestlng$ VerticalDogleg Depth Depth Section Rate 22.874287.788 3465.48 2889.64 N 1824.43 W 3417.22 24.201297.238 3496.01 2894.74 N 1836.67W 3428.14 12.000 24.201297.238 3496.01 2894.74 N 1836.67 W 3428.14 0.000 2.000 297.000 3649.50 2911.08 N 1868.43 W 3459.09 14.000 2.0110297.000 4184.29 2919.56 N 1885.07 W 3475.0..4 0.000 Sperry-Sun Drilling Services Proposal Report for 1D-110A WPs - 1D-110 Wp7 Revised: 10 February, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 5168.40 22.874 287.788 3370.98 5200.00 24.120 296.782 3399.97 5201.70 24.201 297.238 3401.51 5210.00 23.038 297.237 3409.12 5220.00 21.638 297.235 3418.37 5230.00 20.238 297.233 3427.71 5240.00 18.838 297.231 3437.14 5250.00 17.438 297.229 3446.64 5260.00 16.038 297,227 3456,21 5270.00 14.638 297.223 3485.86 5280.00 13.238 297.220 3475.56 5290.00 11.838 297.215 3485.32 5300.00 10.438 297.209 3495.14 5310.00 9.038 297.201 3504.99 5320.00 7.638 297.191 3514.89 5330.00 6.238 297.175 3524.81 5340.00 4.838 297.151 3534.77 5350.00 3.438 297.108 3544.74 5360.00 2.038 297.005 3554.73 5360.27 2.000 297.000 3555.00 5400.00 2.000 297.000 3594.70 5423.31 2.000 297.000 3618.00 5462.33 2.000 297.000 3657.00 5507.36 2.000 297.000 3702.00 5581.41 2.000 297.000 3776.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3485.48 2889.64 N 1824.43 W 5962583.72 N 558642.94 E 3494.47 2894.43N 1836.05W 5962588.41N 558631.29 E 3496.01 2894.74 N 1836.67W 5962588.72 N 558630.67 E 3503.62 2896.27 N 1839.63W 5962590.22 N 558627.70 E 3512.87 2898.00 N 1843.01W 5962591.93 N 558624.30 E 3522.21 2899.64N 1846.18W 5962593.54 N 558621.11 E 3531.64 2901.17 N 1849.16W 5962595.05 N 558618.13 E 3541.14 2902.59 N 1851.93W 5962596,45 N 558615.35 E 3550.71 2903.91N 1854.49W 5962597.75 N 558612,78 E 3560.36 2905.12 N 1856.84W 5962598.94 N 558610.42 E 3570.06 2906.22 N 1858.98W 5962600.02 N 558608.26 E 3579.82 2907.22 N 1860.91W 5962601.00 N 558606.33 E 3589.64 2908,10 N 1862.63W 5962601.87 N 558604.60 E 3599.49 2908.87 N 1864.13W 5962602.63N 558603.09 E 3609.39 2909.54 N 1865.42W 5962603.28 N 558601,80 E 3619.31 2910.09 N 1866.50W 5962603.83N 558600.72 E 3629.27 2910.53 N 1867.36W 5962604.26 N 558599.85 E 3639.24 2910.86 N 1868.00W 5962604.59 N 558599.21 E 3649.23 2911.08 N 1868.42W 5962604.80 N 558598.78 E 3649.50 2911.08 N 1868.43W 5962604.80 N 558598.77 E 3689.20 2911.71N 1869.67W 5962605.42 N 558597.53 E 3712.50 2912.08 N 1870.39W 5962605.79 N 558596,81E 3751.50 2912.70 N 1871.61W 5962606.40 N 558595,59 E 3796.50 2913.41 N 1873.01W 5962607.10 N 558594.18 E 3870.50 2914.58 N 1875.31W 5962608.25 N 558591.87 E Dogleg Rate (°/100ft) 12.000 12.000 13.999 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 14.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1 D Vertical Section (ft) 3417.22 3427.54 3428.14 3431.02 3434.32 3437.42 3440.31 3443.01 3445.51 3447.80 3449.89 3451.77 3453.44 3454.91 3456.17 3457.21 3458.05 3458.67 3459.09 3459.09 3460.29 3461.00 3462.17 3463.53 3465.77 Comment Ddll out @ 12.000°/100ft, 75.000° TF: 5168.40ft MD, 3465.48fl TVD Dir Rate Increase @ 14.000°/100ft' 5201.70fl MD, 3496.01fl TVD End Dir'5360.27fl MD, 3649.50Q TVD Top West Sak D Top B Top A4 Top A3 Top A2 Continued... 10 February, 2000 - 10:15 Sperry-Sun Drilling Services Proposal Report for 1D- 110A WPs - 1D- 110 Wp 7 Revised: 10 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 5600.00 2.000 297.000 3794.58 3889.08 2914.88 N 1875.89 W 5962608.54 N 558591.29 E 5696.48 2.000 297.000 3891.00 3985.50 2916.41 N 1878.89 W 5962610.05 N 558588.28 E 5800.00 2.000 297.000 3994.46 4088.96 2918.05 N 1882.11 W 5962611.66 N 558585.04 E 5895.39 2.000 297.000 4089.79 4184.29 2919.56 N 1885.07 W 5962613.15 N 558582.07 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°/100ft) 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section Ct) 3466.33 3469.24 3472.36 3475.24 Comment Top A1 Total Depth: 5895.39ft MD, 4184.29ft TVD 5 1/2" Liner The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 327.151° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5895.39ft., The Bottom Hole Displacement is 3475.24ft., in the Direction of 327.151° (True). Continued... 10 February, 2000 - 10:15 Sperry-Sun Drilling Services Proposal Report for 1D- 110A WPs - 1D- 110 Wp 7 Revised: 10 February, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 5168.40 3465.48 2889.64 N 1824.43 W 5201.70 3496.01 2894.74 N 1836.67 W 5360.27 3649.50 2911.08 N 1868.43 W 5895.39 41 64.29 2919.56 N 1885.07 W Comment Ddll out @ 12.000°/100ft, 75.000° TF: 5168.40ft MD, 3465.48ft TVD Dir Rate Increase @ 14.000°/100ft: 5201.70ft MD, 3496.01ft TVD End Dir: 5360.27ft MD, 3649.50ft TVD Total Depth: 5895.39ft MD, 4184.29ft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 5360.27 3649.50 3555.00 2911.08 N 1868.43 W Top West Sak D 5423.31 3712.50 3618.00 2912.08 N 1870.39 W Top B 5462.33 3751.50 3657.00 2912.70 N 1871.61 W Top A4 5507.36 3796.50 3702.00 2913.41 N 1873.01 W Top A3 5581.41 3870.50 3776.00 2914.58 N 1875.31 W Top A2 5696.48 3985.50 3891.00 2916.41 N 1878.89W Top A1 Continued... 10 February, 2000 - 10:15 Sperry-Sun Drilling Services Proposal Report for 1D- 110A WPs - 1D- 110 Wp 7 Revised: 10 February, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 5171.57 3468.40 5895.39 Vertical Depth (ft) 4184.29 Casing Detail 5 1/2" Liner Targets associated with this wellpath Target Name 1D-110 Polygon 1D-110 T1 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Mean Sea Level/Global Coordinates #1 #2 #3 #4 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3649.50 2904.44 N 1889.26 W 3555.00 5962598.00 N 558578.00 E 70° 18' 30.3157" N 149° 31' 31.3896" W 3649.50 2954.44 N 1888.86 W 3649.50 2954.04 N 1838.86 W 3649.50 2854.04 N 1839.66 W 3649.50 2854.44 N 1889.66 W 3555.00 5962648.00 N 558578.00 E 3555.00 5962648.00 N 558628.00 E 3555.00 5962548.00 N 558628.00 E 3555.00 5962548.00 N 558578.00 E 70° 18' 30.8075" N 149° 31' 31.3783" W 70° 18' 30.8037" N 149° 31' 29.9199" W 70° 18' 29.8201" hi 149° 31' 29.9427" W 70° 18' 29.8239" N 149° 31' 31.4010" W 3649.50 2902.04 N 1861.30 W 3555.00 5962595.82 N 558605,98 E 70° 18' 30.2922" N 149° 31' 30.5741" W Target Shape Polygon Point Target Type 10 February, 2000 - 10:15 --1067 --1000 ~800 --600 --400 --200 ( Field' Site' Well' Wellpath: 33 ,,, Kuparuk River Unit { Kuparuk 1D Pad 1D-110 1D-110A WPs Colour --200 To Depth 200 400 600 800 1000 1500 2000 3500 4500 5000 7500 10000 15000 20000 90 --600 --800 --1000 ; --1067 180 .50 120 Unknown vs East/West [400ft/in] REFERENCE INFORMATION COMPANY DETAILS Reference: Well Centre: ID-110Site Centre Kuparuk 1D PadField Centre: Kuparuk 1D Pad, True North Arco Alaska laac. Reference: 1D-110A WPs 94.5 above Mean Sea Level Engineering Reference: Slot- (0.00,0.00) Kupamk Reference: ID-110A WPs 94.5 above Mean Sea Level Wellpath: (1D-110/1D-110A WPs) Created By: DeWayne Pratt Date: 03/13/20i Checked: Date: 11 ', n00 psi BOP Stack-- N( Kuparuk River Unit 'dic Rig 3 ~J 7 6 1--] I-I H Choke Line ' I L_ ff' ,:3 1 I Accumulator Caoacitv Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws a~e fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws In head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase ' pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as instep 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in ' step 4. Dq) nQt pressure test any choke that is not a full closing ~ positive seal choke. 8. Open top. pipe rams and. close bottom.pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug... Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves [o 3000 PSi for..3 minutes. 12. Test kelly cocks and inside BOp to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor... 14. Pedorm BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head " 2. 11" 5000 psi Horizontal Tubing Head 3. 11 ." 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single .Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams. on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v. 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 13, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Subject: West Sak 1D-110 Abandonment and Permit to Drill Sidetrack Dear Sirs: Attached for your approval are Sundry Form 10-403 to abandon the West Sak 1D-110 and Permit to Drill Form 10-401 for a wellbore replacement sidetrack. Initial cement bond log across the West Sak sands indicated marginal to poor bond quality. An attempt to fracture stimulate the A2 sand was unsuccessful. A USIT log confirmed channeling of the primary cement job across the West Sak and inadequate isolation existed to keep the four individual sand fracs in zone. The upper portion of the cement job did have sufficient bond. Approval to suspend well operations was granted on January 25, 1999. Rather than performing remedial squeeze work, approval is requested to abandon the current wellbore. Abandonment plans include squeezing the existing A2 perfs and then perforating and squeezing cement at the top of the D sand to isolate the West Sak from the Ugnu sands. A bridge plug will be set and the well sidetracked and completed as a West Sak frac-then pack producer. If there are any questions or additional information is required, please call Brian Noel at 265-6979. Sincerely, C. Alvord Drilling Engineer Supervisor AAI Drilling RECEIVED ",, ! g 2000 Alaska Oil & Gas Cons. Commission Anchorage CA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: _X Suspend _ Operational shutdown _ Re-enter suspended well _ ing_ Repair well _ Plugging _ Time extension _ Stimulate _ )roved program _ Pull tubing _ Variance _ Pedorate _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 44' FSL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval 2333' FNL, 2486' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 2311' FNL, 2614' FWL, Sec. 14 T11N, R10E, UM 5. Type of Well: Development _X Exploratory _ St ratig raph ic _ Service __ 6. Datum elevation (DF or KB feet) 41 RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-110 9. Permit number / approval number 98-185 10. APl number 50-029-22920 11. Field / Pool Kuparuk River Field/West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Surface Intermediate Production measured true vertical Length 80' 5917' 5973' 4228' 5874' 4134' Size 16" 7.625" feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cub. Yds. High Early 640 sx AS III & 340 sx Class G Measured Depth True vertical Depth 121' 121' 5958' 4214' Perforation depth: measured 5623'-5712' true vertical 3895'-3979' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 5593' Packers & SSSV (type & measured depth) N/A RECEIVED -'.-, 3 2000 Alaska 0il & Gas Cons. Commiss'~on Anchorage 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation March 20, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __X Service __ 17. I hereby certify that the foregoing is true and correct tothe best o! my knowledge. Signed ,,~/~,/~.- E. ~'~ Title: Drilling Engineering Supervisor Chip Alvord FOR COMMISSION USE ONLY Questions? Carl Brian Noel 265-6979 Date Prepared by Sharon AIlsup-Drake Conditions of approval: Notify Commission so representative may witness Plug integrity _._ BOP Test _ Location clearance .... Mechanical Integrity Test _ Subsequent form required 10-_ ........... Approval no. __.Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ..ARCO Alas ka, ,.~... ! -~,~,,~.. ~'i,,-?.' '71'..;~.i-i",i~ ?~-; .~-i?'. ?..-~.~.;~;..~;~-'--.-. ~i~'- --:---;.. 'o--~~o ~;~iO0"-;i~ ~;i.~ ''~ .~:.~.~i?';~-'?i'i.,~.~;:~!.?~:~.. i?, "'~' AA'i ' pAYABLES .. ' ':" ':: '-. '-'::.-.':!. :.ii.?;:::!: :;;';-:.:.::' .:.:: i:: !:i:'' .i? .::.? C~E'C:1~. NUMBER';:i.:''. ~!~,)~~ ~;O-. ....... .:? ~~?;g~,0~9510-2776 ;.' "~-.;.::.'-:';'..': '" ' ' .. '. : "-' .'""' ".'~: "':'?:'-:' .::'"?" ':';:~.: :~ ::::~-:-' ":::?'-:": .. '.:~' '~.' "- · :...-..-:.: ....:..:- .:- - '.-. ..-..-:~c. ~,-.:~.~.~o::-.-. .-..~.~-::.......¥..:.:~..:........- ~?~.:.~:~-:.. PAY TO THE STATE OF ALASKA .... ': .... ORDER OF: ALASKA OIL & GA:s-.coNS'E'~V-A~ION CQMMI .. 3001 PORCUPINE DRIV.E .....': '- -'"~. ~, votD A'~ 90 DAyS '. ::';'~~..::~:~****~,~*~oo DO~:~S....:~O O0 " c~ ~S-~ ~* * * * * * **~ *:*:'~O0 :O0 ' ":. ' :'?:: The First National Bank 0f' chicago:~'71-'0' . .:..:.~-.::;.;.~::??..~:.- ...: ...... ::.. .-..' ...:..:_-...-: ' '-::':::.' .... :--:.'.:-:.;.~:.:-:'.':'?....~v'"- -:::?:.::~:-~...:::-~'.~.? '::-: .':'::? WELL PERMIT CHECKLIST FIELD & POOL L./',c~/'~)/~-~ WELL NAME IZ:::'~tlO/~ PROGRAM: exp ~ ADMINISTRATION A.~ DATE,, 12. ..3 13. COMPANY '~~ INIT CLASS ENGINEERING 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 wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... dev ~redrll v/ serv~wellbore seg__ GEOL AREA N IiN UNIT# ann. disposal para req __ ON/OFF SHORE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~::~t.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y GEOLOGY A,~ DATE/ ,-._..-, 30. Permit can be issued w/o hydrogen sulfide measures ..... ,,,,-"fY N 31. Data presented~n potential overpressure zones ....... J ,, Y N 32. Seismic analysb of shallow gas zones ........... ,~. ,~/./,,.{ Y N 33. Seabed condition survey (if off-shore) ......... .,,,/.. ""~' ; Y N 34. Contact name/phone for weekly progress reports [e .x~rato~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of 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 AAC 25.412. Y N GEOLQ,GY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: 0 Z 0 c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information· of this nature is accumulated at the end of the file under APPEN. DIXi .. No Special'effort has been made to chronologically organize this category of information. .o Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Aug 09 15:07:30 2000 Reel Header Service name ............. LISTPE Date ..................... 00/08/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/08/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING MWD RUN 2 AK-MM-00004 RORY MCNEILL DINK HIEM (FT FROM MSL 0) OPEN HOLE BIT SIZE 6.750 (IN) 1D-110A 500292292001 ARCO Alaska, Inc. Sperry Sun 09-AUG-00 14 liN 10E 44 596 .00 100.48 70.60 CASING SIZE (IN) 7.625 DRILLERS DEPTH (FT) 5157.0 RECEIVED AU(; 'I 5 2000 Alaska 0il & (]as Cons. Commissior~ Anchorage 2ND STRING 6.750 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTLILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTRO- MAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. MWD DIGITAL DATA ONLY IS DEPTH CORRECTED/SHIFTED TO THE PDC GAMMA RAY LOG (SSDS SGRC 09/28/98) WITH PARENT WELL K.B.E. = 112'. ALL LOG AND LOG HEADER DATA RETAINS ORIGINAL DRILLER'S DEPTH REFERENCES. THIS WELL KICKS OFF FROM iD-il0 AT 5157'MD, 3456'TVD. 5. MWD RUNS 1-2 REPRESENT WELL 1D-110A WITH API#: 50-029-22920-01. THIS WELL REACHED A TD (TOTAL DEPTH) OF 5905'MD, 4193'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA 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 FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP $ START DEPTH 4995 5 5161 5 5161 5 5161 5 5161 5 5161 5 5204 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4995.5 4997 5 5000 5 5002 0 5007 0 5009 5 5017 5 5022 5 5033 5 5038.5 5040 5 5066 0 5072 5 5075 0 5078 5 5081 5 5084 0 5089 5 5104 0 5106 5 5118.0 5134 5 5137 0 5141 0 5151 5 5161 5 5163 5 5170 0 5172 5 5920 5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 4981 5 4983 5 4986 5 4989 5 4992 5 4995 0 5002 0 5006 0 5017 5 5024 0 5026 5 5049 5 5056 0 5058 0 5061 5 5065 5 5068 0 5073 5 5086 5 5089 0 5101 5 5118 0 5120 5 5125 5 5136 0 5147 5 5149 0 5155 5 5157 0 5905 0 STOP DEPTH 5879.0 5886.0 5886.0 5886.0 5886.0 5886.0 5920.5 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 4981.5 5905.0 Depth Units ....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 4995.5 5920.5 5458 1851 ROP MWD FT/H 2.3 771.01 75.921 1433 GR MWD API 20.61 138.86 72.6842 1768 RPX MWD OHMM 1.73 2000 10.7371 1450 RPS MWD OHMM 1.77 2000 23.6067 1450 RPM MWD OHMM 1.3 2000 20.7469 1450 RPD MWD OHMM 0.03 1743.13 11.3514 1450 FET MWD HR 0.3276 2.2578 0.799263 1450 First Reading 4 995 5 5204 5 4995 5 5161 5 5161 5 5161 5 5161 5 5161 5 Last Reading 5920.5 5920.5 5879 5886 5886 5886 5886 5886 First Reading For Entire File .......... 4995.5 Last Reading For Entire File ........... 5920.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4981.5 5863.5 RPX 5147 5 RPS 5147 5 RPM 5147 5 RPD 5147 5 FET 5147 5 ROP 5189 0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE {MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL {FT): BOTTOM LOG INTERVAL {FT): BIT ROTATING SPEED {RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 5870.5 587O.5 5870.5 5870.5 5870.5 5905.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 02-APR-00 Insite 0.41 MEMORY 5905.0 .2 23.3 TOOL NUMBER PB01456GR4 6.750 5157.0 Water Based 9.80 48.0 9.4 2800 3.8 .360 .298 .600 .600 70.0 86.0 70.0 70.0 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HR 4 1 68 Rep Code Offset 0 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name Service Unit Min Max DEPT FT 4981.5 5905 ROP MWD020 FT/H 2.3 771.01 GR MWD020 API 20.61 138.86 RPX MWD020 OHMM 1.73 2000 RPS MWD020 OHMM 1.77 2000 RPM MWD020 OHMM 1.3 2000 RPD MWD020 OHMM 0.03 1743.13 FET MWD020 HR 0.3276 2.2578 Mean 5443.2 75.92 72.762 10.683 23.266 19.37 11.065 0.79809 First Nsam Reading 5 1848 4981.5 1 1433 5189 8 1765 4981.5 9 1447 5147.5 7 1447 5147.5 2 1447 5147.5 9 1447 5147.5 7 1447 5147.5 Last Reading 5905 5905 5863 5 5870 5 5870 5 5870 5 5870 5 5870 5 First Reading For Entire File .......... 4981.5 Last Reading For Entire File ........... 5905 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name .......... ...LISTPE Date ..................... 00/08/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/08/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File