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204-227
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-104 KUPARUK RIV U WSAK 1E-104 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-104 50-029-23234-00-00 204-227-0 W SPT 3352 2042270 1500 890 890 890 890 219 415 322 271 4YRTST P Austin McLeod 6/5/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1E-104 Inspection Date: Tubing OA Packer Depth 40 1790 1720 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605190602 BBL Pumped:1.1 BBL Returned:1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:46:21 -08'00' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Saturday, August 10, 2019 10:17 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: FW: West Sak injector 1 E-104 (PTD #204-227) Suspected IAxOA communication. Attachments: 1 E-104 90 Day TIO plot.JPG Chris - West Sak injector 1E-104 (PTD #204-227) has completed the 30 -day monitor period investigating the suspected IAx0A convergence. There was no evidence of IAx0A communication as the well passed the T and IC POTS, a diagnostic MIT -IA and successfully maintained a substantial differential pressure throughout the monitor period. The well will be returned to normal water injection status. Please let me know if you have any questions or concerns. Attached is a copy of the current 90 day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM corwcop Dips From: Well Integrity Compliance Specialist CPF1 & 2 Sent: Tuesday, July 9, 2019 6:02 PM To: 'chris.wallace@alaska.gov' <chris.wallaceCalalaska.gov> Cc: CPA Wells Supt <n1030(a)conocoohillios.com> Subject: West Sak injector 1E-104 (PTD #204-227) Suspected IAx0A communication. Chris - West Sak injector 1E-104 (PTD #204-227) was reported by operations with IAx0A convergence after attempting to charge both the IA and the OA. CPAI intends to leave the well on injection and conduct a series of initial diagnostics to attempt to identify the leak as an IAxOA breach. After the diagnostics have been completed any attempted repairs will be relayed to the AOGCC and the well will be monitored for 30 days to verify integrity between the IA and OA. The proper paperwork for repair or continued injection will be submitted. Please let me know if you have any questions or concerns. Attached are copies of the wellbore schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 ELLS TEAM WM ConocoF tiips Chris D From: Well Integrity Compliance Specialist CPE1 & 2 <n1617@conocophillips.com> Sent: Tuesday, July 9, 2019 6:02 PM To: Wallace, Chris D (CED) Cc CPA Wells Supt Subject: West Sak injector 1E-104 (PTD #204-227) Suspected IAxOA communication. Attachments: 1 E-104.pdf, 90 day TIO plot.PNG Chris - West Sak injector 1E-104 (PTD #204-227) was reported by operations with IAxOA convergence after attempting to charge both the IA and the OA. CPAI intends to leave the well on injection and conduct a series of initial diagnostics to attempt to identify the leak as an IAxOA breach. After the diagnostics have been completed any attempted repairs will be relayed to the AOGCC and the well will be monitored for 30 days to verify integrity between the IA and OA. The proper paperwork for repair or continued injection will be submitted. Please let me know if you have any questions or concerns. Attached are copies of the wellbore schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist Conocolohillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM CM003FNWps Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave; Suite 100 -4h Anchorage, AK 99501 204227 30497 TRANSMITTAL DATE or � 27 -Mar -19 27Ma r19JW 02 1E-104 50-029.23234-00 tRVICE ORDER EA77.00006 FIELD NAME DESCRIPTION KUPARUK RIVER DELIVERABLE WL DESCRIPTION [PROF DATA I FINAL FIELD r Prints I 20 -Feb -19 CD's 1 to -05 50-029.20627-00 EOSH-00028 KUPARUK RIVER WL IPROF FINAL FIELD 16 -Mar -19 1 IA -07 50-029-20658-00 EOSH-00029 KUPARUK RIVER WL IPROF FINAL FIELD 17 -Mar -19 1 1H-118 50-029-23578-00 EOSH-00030 KUPARUK RIVER WL IPROF FINAL FIELD 18 -Mar -19 1 2A-17 50-103-20193-00 EA77-00009 KUPARUK RIVER WL Caliper FINAL FIELD 18 -Mar -19 1 2V-04 50-029.21041-00 EA77-00010 KUPARUK RIVER WL IPROF FINAL FIELD 19 -Mar -19 1 1H-114 50-029-23584-00 EOSH-00031 KUPARUK RIVER WL IPROF FINAL FIELD 19 -Mar -19 1 3C -15A 50-029-21426.01 EA77-00011 KUPARUK RIVER WL LDL FINAL FIELD 20 -Mar -19 1 ME 1) REGE MAR 2, 8 4 I ATransmittal Receipt signature confirms that a package (box'- 7A, Z l� envelope, etc.) has been received and the contents of the X ( package have been verified to match the media noted above. Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this via courier or sign/scan and email a copy t chlumberger and CPAL point. Schlumberger -Private Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, January 26, 2019 2:19 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: KRU 1 E-104 (PTD 204-227) Update and AA application submittal: Update 1-26-19 Chris, We recently applied for and were granted an AA approval to allow continued water -injection on 1E-104 due to displaying signs of IA x formation communication because of a repeated unexplained slow fall off in IA pressure. The cause of the leak was assumed to be a very small casing leak at an unidentified location below the OA shoe. The well is able to pass MITIAs. We have recently been having success at finding and repairing slow gas -only external leaks at wellhead jewelry on various other wells. Based on that new learning, we went out today to 1E-104 and pressured up the IA with gas and did in fact find an external gas leak coming from a Y2" plug on a root valve of the gauge jewelry. The threads of the plug were retaped and it no longer appears to be leaking. To confirm the repair, CPA[ intends to apply pressure to the IA using gas and monitor the pressure for 60 days. This will be contrary to the stipulation of the AA that the IA be maintained as low as possible. If the pressure fall off does not resume, we then intend to cancel the AA. Please let us know if you disagree with the path forward. Kelly Lyons / Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent: Saturday, January 12, 2019 4:54 PM To: Wallace, Chris D (DOA) <chris.waIlace @alaska.gov> Cc: Sender, R. Tyler <R.Tyler.Senden@conocophillips.com>; CPA Wells Supt <n1030@conocophillips.com> Subject: RE: KRU 1E-104 (PTD 204-227) Update and AA application submittal Chris, KRU West Salk water injector 1E-104 (PTD 204-227) was last reported November 17, 2018 with the update and plan below. Since then the 60 day monitor period has gone as expected. No OAxATMO was exhibited by TIO trend or observed by weekly inspection with gas monitor around the wellhead and conductor. The IA pressure fall off (IAxFORM) continued as expected, although with the well online, after the IA pressure had been charged to monitor for falloff, is losing approximately 25 psi per day. In addition the well passed a SW MITIA to 3310 psi on November 25, 2018. With this information COPA intends to request an Administrative Approval to continue water injection only with known IAxFORM communication. The paper copy is in the mail and the plan is to leave the well on water injection while the AA request is being processed. A digital copy of the AA request is attached. Please let us know if you disagree or have any questions with this plan. Regards, • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, February 2, 2018 7:43 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of IA pressure anomaly 1E-104 (PTD 204-227) update 2-2-18 Attachments: MIT KRU 1E-104 diagnostic MIT 2-2-18.xlsx Chris, 1E-104 appears to have a near-surface,gas-only surface casing leak based on a surface casing leak detect(SCLD) performed today. The MITIA performed today did pass so the tubing and production casing appear to be competent. The surface casing has an open shoe which causes sustained OA pressure to be present. But because this is a gas-only leak, no fluids were released. However, prior to proceeding with any further diagnostics of the surface casing,the well will be shut in and freeze protected as soon as possible and secured with a retrievable tubing plug. The well will remain shut in until diagnostics can be completed, a repair plan formulated and proper paperwork submitted. Please let us know if you disagree with the path forward. Attached is the MIT data. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SUMO From: NSK Well Integrity Supv CPF1 and 2 Se •Tuesday,January 30, 2018 2:41 PM To:Wal Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R. -r<R.Tyler.Senden@conocophillips.com> Subject: Report of IA • -ssure anomaly 1E-104(PTD 204-227) 1-30-18 Chris, West Sak water injector 1E-104 (PTD c -227) has had an unexplained loss in IA pressure over the last several weeks. In addition, attempts to pressure up the OA w- - unsuccessful. This OA pressure fall-off may or may not be related to the IA phenomenon because there is no cemented 0 A ctic-packed shoe so the OA pressure might just be being released at the shoe. DHD will be mobilized to investigate. They •erform packofftesting/MITIA/MITOA/surface casing leak detect as necessary. If the MITIA fails,the well will be freeze s otected and shut in as soon as possible. If testing passes, the well will be placed on a 30 day monitor with follow-up email he conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday,January 30, 2018 2:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of IA pressure anomaly 1E-104 PTD 204-227) 1-30-18 Attachments: 1E-104 schematic.pdf; 1E-104 90 day TIO plot 1-30-18.JPG Chris, West Sak water injector 1E-104(PTD 204-227) has had an unexplained loss in IA pressure over the last several weeks. In addition,attempts to pressure up the OA were unsuccessful. This OA pressure fall-off may may not be related to the IA phenomenon because there is no cemented OA arctic-packed shoe so the OA pressure might just be being released at the shoe. DHD will be mobilized to investigate. They will perform packoff testing/MITIA/MITOA/surface casing leak detect as necessary. If the MITIA fails,the well will be freeze protected and shut in as soon as possible. If testing passes, the well will be placed on a 30 day monitor with follow-up email at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 scANNED !-F: 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TOJim Regg DATE: Monday,April 11,2016 P.I.Supervisor eQefGj 4(1 S(l( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-104 FROM: Brian Bixby KUPARUK RIV U WSAK 1E-104 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1E-104 API Well Number 50-029-23234-00-00 Inspector Name: Brian Bixby Permit Number: 204-227-0 Inspection Date: 3/27/2016 Insp Num: mitBDB160327162238 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 1E104 ;Type Ind 1 w-ITVD 3352 - Tubing 1 595 . 595 - , 595 _ 596 PTD 2042270 - Type Test!SPT Test psi 1500 - IA 1 1570 2200 - � 2170- 2170 • Interval INITAL ;P/F P .' OA 170 - 245 - 1 207 - 188 Notes: Initial Test Post RWO. .i SCOW Monday,April 11,2016 Page 1 of 1 STATE OF ALASKA • AL OIL AND GAS CONSERVATION CO SION REPO T OF SUNDRY WELL OPE TIONS 1.Operations Abandon r Rug Perforations " Fracture StimulatePull Tubing Performed: � A: Operations Shutdown Suspend f Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill I' Perforate New Pool r Repair Well Re-enter Susp Well r Other T'1nfe►^v�t,/� t k5 yr Ci h-5 -tr 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-227 3.Address: Stratigraphic Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23234-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25651 KRU WSAK 1E-104 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kupurak River Field/WSAK Oil Pool 11. Present Well Condition Summary: Total Depth measured 6935 feet Plugs(measured) 5750"" RECEIVED true vertical 3984 feet Junk(measured) None APR 0 4 2016 Effective Depth measured 6783 feet Packer(measured) None AOGCC true vertical 3909 feet (true vertical) N/A Casing Length Size MD ND Burst Collapse Conductor 104' 20" 135' 135' Surface 3605' 7 5/8" 3635' 2440' Production 5524' 5 1/2" 5552' 3346' Production 1368' 3 1/2" 6920' 3977' Perforation depth: Measured depth: 5760'-6395' True Vertical Depth: 3437'-3726' ED APR 2 0 2016 Tubing(size,grade, MD,and TVD) 3-1/2", L-80, 5576' MD/3357'TVD S`OS Packers&SSSV(type, MD, and ND) N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - 1000 300 900 Subsequent to operation - - 1000 300 900 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ;r' Exploratory "' Development r Service Stratigraphic Copies of Logs and Surveys Run fl 16.Well Status after work: Oil r Gas r WDSPL Printed and Bectronic Fracture Stimulation Data r GSTOR ! WINJ F WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 316-025 Contact Email Andrew.T.Beat(a conocophillips.com Printed Name Andrew B a 265-6341 Title Senior Wells Enginner Signature A _� Phone 265-6341 Date 41/1/x izv, v 7-4. 4P2 //L Form 10-404 Revised 5/2015 A te2i(i- Submit Original Only RBDMS 1A, APR 0 5 2016 1 R 4 • • 1 r s Time Log & Summary Report [AOGCC] ► , e[!S' 1E-104 ConocoPhill'aps Well Name: 1E-104 Rig Name: DOYON 142 ask, Job type: RECOMPLETION Rig Accept : 2/26/2016 Rig Release : 3/3/2016 Time Log Dens Last Start Depth End Depth Activity Mud Start Time End Time Dur(hr) (ftKB) (ftKB) Phase Op Code Code (lb/gal) Operation 2/26/2016 10:00 2/26/2016 12:00 2.00 MIRU WELCTL RURD 8.50 Rig accept 10:00 hrs. IA 190 psi Load lubricator onto Rig,check all connection. Pressure test iron in cellar. 2/26/2016 12:00 2/26/2016 13:00 1.00 MIRU WELCTL SFTY 8.50 Crew change out day-PJSM and crew change. 2/26/2016 13:00 2/26/2016 15:00 2.00 MIRU WELCTL RURD 8.50 R/U lubricator on well,pressure test to 2000 psi. 2/26/2016 15:00 2/26/2016 16:00 1.00 MIRU WELCTL MPSP 8.50 Pull BPV OA 185 psi/IA 110 psi/Tubing 50 psi 2/26/2016 16:00 2/26/2016 17:30 1.50 MIRU WELCTL KLWL 8.50 Bleed down IA and tubing pressure to zero. PJSM for pumping SW down tubing to circulate out diesel and WB fluids. 2/26/2016 17:30 2/26/2016 18:00 0.50 MIRU WELCTL OWFF 8.50 Observed Well for Flow 1/2 hour,no flow. 2/26/2016 18:00 2/26/2016 18:30 0.50 MIRU WHDBOP MPSP 8.50 Set BPV. 2/26/2016 18:30 2/26/2016 20:30 2.00 MIRU WHDBOP NUND 8.50 RD and blow down circulating lines. Prep to ND Tree. 2/26/2016 20:30 2/26/2016 23:00 2.50 MIRU WHDBOP NUND 8.50 Nipple down Tree and set aside. Installed test dart. 2/26/2016 23:00 2/27/2016 00:00 1.00 MIRU WHDBOP NUND 8.50 PJSM.PU and NU Spacer Spool. 2/27/2016 00:00 2/27/2016 03:00 3.00 MIRU WHDBOP NUND 8.50 Continue NU BOPE. 2/27/2016 03:00 2/27/2016 04:00 1.00 MIRU WHDBOP SFTY 8.50 Crew change/Hand over-new crew arrived on location. 2/27/2016 04:00 2/27/2016 08:00 4.00 MIRU WHDBOP NUND 8.50 NU BOPE,Choke and Kill Lines. 2/27/2016 08:00 2/27/2016 09:30 1.50 MIRU WHDBOP NUND 8.50 Had to open lower ram doors to ensure crossover 4 1/2"IF to Dart valve would clear closing the lower rams. 2/27/2016 09:30 2/27/2016 11:00 1.50 MIRU WHDBOP RURD 8.50 Shell test BOPE-Call State Inspector. 2/27/2016 11:00 2/27/2016 13:00 2.00 MIRU WHDBOP SFTY 8.50 Safety Meeting while waiting on inspector to arrive. Bridging document Pre spud meeting H2S review 2/27/2016 13:00 2/28/2016 00:00 11.00 MIRU WHDBOP BOPE 8.50 PJSM-BOPE test.Tested Rams,Choke and Kill lines,Choke Valves,and IBOP 250/3000 PSI.Tested Annular to 250/2500 PSI. Tested gas alarms-first test failed due to improper reading of LEL/H2S.Recalibrate and test-Pass. Tested Floor Valves to 250/3000 PSI. FOSV Failed Weatherford rental.Borrowed Back up FOSV from D-25 and Tested 250/3000 psi.Performed AOGCC test and COP test on Closing Unit.Test witinessed by Chuck Shevie AOGCC. Chuck noted 3 changes will be required in kill line(remove 2-non targetted 90's&45 degree elbow). 2/28/2016 00:00 2/28/2016 01:00 1.00 MIRU WHDBOP MPSP 8.50 Clean up rig floor&Pull BPV 2/28/2016 01:00 2/28/2016 03:00 2.00 COMPZN RPCOMP RURD 8.50 R/U power tongs,equipment and landing joint. M/U TD to pull tubing. 2/28/2016 03:00 2/28/2016 04:00 1.00 COMPZN RPCOMP PULL 8.50 PJSM-Pull hanger freel2OK,free travel 79K, down 66K.P/U hanger to rig floor,inspect seals. 2/28/2016 04:00 2/28/2016 04:30 0.50 COMPZN RPCOMP OWFF 8.50 Monitor well for 30 mins. 2/28/2016 04:30 2/28/2016 09:30 5.00 COMPZN RPCOMP PULL 8.50 Continue to pull tubing while monitoring the well. Page 1/4 Report Printed: 4/4/2016 0E - • • 6 Time Log & Summary Report [AOGCC] a 1E-104 Conochillips Well Name: 1E-104 Rig Name: DOYON 142 harks Job type: RECOMPLETION Rig Accept : 2/26/2016 Rig Release : 3/3/2016 Time Log Dens Last Start Depth End Depth Activity Mud Start Time End Time Dur(hr) (ftKB) (ftKB) Phase Op Code Code (lb/gal) Operation 2/28/2016 09:30 2/28/2016 10:30 1.00 COMPZN RPCOMP SFTY 8.50 Full H2S-with Grants crew.Secure well and muster.AAR captured.Response time well secure 45 secs,full muster 2 mins 50 secs. 2/28/2016 10:30 2/28/2016 17:00 6.50 0.0 2,487.0 COMPZN RPCOMP PULL 8.50 Continue TOOH with decompletion.Found failed patch top of joint#80(2,506')from surface. Pitting noticed inside collars starting @ joint #138 OOH(4321')Complete TOOH. 2/28/2016 17:00 2/28/2016 17:30 0.50 2,487.0 COMPZN RPCOMP RURD 8.50 Clear Rig Floor. 2/28/2016 17:30 2/28/2016 18:30 ' 1.00 COMPZN WELLPR RURD 8.50 Moved Tools to the Rig Floor. 2/28/2016 18:30 2/28/2016 19:00 0.50 COMPZN WELLPR RURD 8.50 Installed Wear Bushing. 2/28/2016 19:00 2/28/2016 20:00 1.00 COMPZN WELLPR RURD 8.50 RU to run PH6 Tubing. 2/28/2016 20:00 2/28/2016 21:00 1.00 COMPZN WELLPR BHAH 8.50 PJSM and PU Muleshoe and Casing Scrapper BHA. 2/28/2016 21:00 2/29/2016 00:00 3.00 COMPZN WELLPR PULD 8.50 Single in with 3.5"PH6 Tubing drifting as picked up to 1,088'. 2/29/2016 00:00 2/29/2016 03:30 3.50 COMPZN WELLPR PULD 8.50 Continue TIH with 3.5"DP down to 2837',Up weight 68K,down 65K.Calc disp 13.2 actual 13.1 bbls. 2/29/2016 03:30 2/29/2016 06:00 2.50 COMPZN WELLPR SFTY 8.50 Begin training on Amphion. -TOOH standing back -TIH -Kelly up and circ. 2/29/2016 06:00 2/29/2016 14:30 8.50 COMPZN WELLPR 'SFTY 8.50 Continue training with day crew. -Align Mud pumps on auto drill -Set paremeters train on Amphion system -TOOH standing back -TIH -Kick while tripping drill -Fire drill -Envir/SAA&Hands free training with Grants Crew. 2/29/2016 14:30 2/29/2016 22:00 7.50 COMPZN WELLPR PULD 8.50 Begin TIH singling in PH6 tubing down to PBR @ 5,575'. 2/29/2016 22:00 2/29/2016 23:30 1.50 COMPZN WELLPR CIRC 8.50 Tagged up with No Go on PBR @5,575' Muleshoe @5,593'.RU to Circulate with 3.6' Pup Jt.Circulated with 3 BPM @ 350 PSI inside PBR noted PP increase when No Go tagged confirming we were inside. Pulled out of PBR and increased Pump Rate to 5 BPM @ 985 PSI. CBU. 2/29/2016 23:30 3/1/2016 00:00 0.50 COMPZN WELLPR RURD 8.50 RD Pumping subs and laid down Pup Jt. Blow down Top Drive. 3/1/2016 00:00 3/1/2016 01:00 1.00 COMPZN WELLPR PULD 8.50 LD Joint 178-5585'.P/U weight 98K/Dn 70K. Service TD, Blocks for 30 mins. 3/1/2016 01:00 3/1/2016 04:30 3.50 COMPZN WELLPR OTHR 8.50 Load pipe shed with 3.5"Completion string, strap and tally.Continue training on amphion system on rig floor while loading pipe. 3/1/2016 04:30 3/1/2016 05:30 1.00 COMPZN WELLPR CIRC 8.50 Establish SCR @ 5556' MP#1 2 bpm=160 psi/3bpm=350 psi. MP#2 2 bpm=160 psi/3 bpm=350 psi Circ B/U @ 6 bpm 1355 psi. 3/1/2016 05:30 3/1/2016 12:30 7.00 COMPZN WELLPR PULD 8.50 TOOH laying down 3.5"DP from 5556' 3/1/2016 12:30 3/1/2016 13:00 0.50 COMPZN 'WELLPR RGRP 8.50 Service top drive,skate,drawworks. 3/1/2016 13:00 3/1/2016 14:30 1.50 COMPZN WELLPR PULD 8.50 Continue TOOH laying down 3.5"DP 3/1/2016 14:30 3/1/2016 15:30 1.00 COMPZN WELLPR BHAH 8.50 Lay down BHA&K/O BHA&X-overs.Kick out 3.5"DP from pipe shed. Page 2/4 Report Printed: 4/4/2016 • Time Log & Summary Report [AOGCC] 1E-104 GonocoPhillips Well Name: 1E-104 Rig Name: DOYON 142 Job type: RECOMPLETION Rig Accept : 2/26/2016 Rig Release : 3/3/2016 Time Log Dens Last Start Depth End Depth Activity Mud Start Time End Time Dur(hr) (ftKB) (ftKB) Phase Op Code Code (lb/gal) Operation 3/1/2016 15:30 3/1/2016 18:00 2.50 COMPZN RPCOMP OTHR 8.50 Pull wear ring,Tally new completion in pipe shed. 3/1/2016 18:00 3/2/2016 00:00 6.00 COMPZN RPCOMP PUTB 8.50 PU Seal Assembly and RIH with Completion Single in from Pieshed to 3,051'. 3/2/2016 00:00 3/2/2016 05:00 5.00 3,501.0 5,550.0 COMPZN RPCOMP PUTB 8.50 Cont P/U 3 1/2"completion as per running order from 3501 to 5550'.Up weight 79K, Down weight 65K. 3/2/2016 05:00 3/2/2016 06:00 1.00 5,550.0 COMPZN RPCOMP HOSO 8.50 Tag no-go on joint 176+18'of joint 177.Set down 5K,P/U weight 79K,Dn weight 65K. Lay down joint#177 and P/U 10'pup.M/U XO to circulate. 3/2/2016 06:00 3/2/2016 07:30 1.50 COMPZN RPCOMP HOSO 8.50 Crew change-Complete M/U X overs-The TD torque was showing a VFD fault when trying to M/U subs on top of string for pumping.Fixed problem,make up subs. 3/2/2016 07:30 3/2/2016 10:30 3.00 COMPZN RPCOMP CRIH 8.50 Slowly TIH and engage seals,stop pumping- pressure increase 100 psi.-Bleed off line. P/U, lay down 10ft pup&M/U tubing hanger. Circulate 50 bbls of corrosion inhibitor down tubing followed by 25 bbls of SW.Spotted corrosion inhibitor across seal assembly and up backside to 3000'. 3/2/2016 10:30 3/2/2016 12:00 1.50 COMPZN RPCOMP THGR 8.50 R/U cellar pump and hoses,drain the stack and land the tubing hanger.RILDS. Test upper and lower hanger seals to 5000 psi. good test. 3/2/2016 12:00 3/2/2016 15:00 3.00 COMPZN RPCOMP PRTS 8.50 R/U manifold in cellar,Test tubing to 3500 psi, chart for 15 mins.with IA open-no leaks.Bleed down tubing to 2000 psi,pressure test IA to 3000 psi for 30 mins.chart.good test. Shear SOV. 3/2/2016 15:00 3/2/2016 16:00 1.00 COMPZN WHDBOP MPSP 8.50 Lay down landing joint,Set two way check (BPV). Test 1000 psi below. 3/2/2016 16:00 3/2/2016 17:00 1.00 COMPZN WHDBOP OTHR 8.50 Clean up rig floor,demob casing hand and tools. Page 3/4 Report Printed: 4/4/2016 i • • a 0 Time Log & Summary Report [AOGCC] r i 1E-104 Conoco'hillips Well Name: 1E-104 Rig Name: DOYON 142 htska Job type: RECOMPLETION Rig Accept : 2/26/2016 Rig Release : 3/3/2016 Time Log Dens Last Start Depth End Depth Activity Mud Start Time End Time Dur(hr) (ftKB) (ftKB) Phase Op Code Code (Iblgal) Operation 3/2/2016 17:00 3/2/2016 20:00 3.00 COMPZN WHDBOP RGRP 8.50 **Doyon time as of 17:00 hrs**Final test of IATP"black out procedure. Circulate through Stack and choke pumping 2 bpm/holding 200 psi on choke. 18:05-ESD hi-line-did not function-fail Shut down Hi-line from MCC Gen room. 18:08-start up C 27-pass 18:09-start up Gen#1 -Sync with C 27-pass 18:11 -Reset Mcc in pump/pit module. 18:18-pump#1 online pumping 2 bpm @ 200 psi-pass 18:22-Gen#2 online-sync with Gen#1.- pass 18:28-load share 1 &2.-pass 18:30-Start Gen#3,shut down Gen#1 -pass 18:34-load sharing Gen 2&3-pass 18:36-bring pump#2 online-pass Hit ESD on Gens-Did not work.-fail Troubleshoot jumper not connected in Panel of Gen#2.Connected. 19:00 hrs Hit ESD-PASS 19:15-Bring C 27 back online-need to have gen running to open circuit on Hi-line breaker.- pass 19:15 back on Hi-line-bring pump#2 online- pass 19:25-Hit ESD on Hi-line-PASS-black out. Bring C-27 online,bring online Hi-line. Bring pumps online-Pass End of Test-Pass 3/2/2016 20:00 3/2/2016 21:30 1.50 COMPZN WHDBOP OTHR 8.50 Rigged down Test equipment and blew down Topdrive and lines. Pumped out Stack. 3/2/2016 21:30 3/3/2016 00:00 2.50 COMPZN WHDBOP NUND 8.50 Nippled down BOP,Riser,and Choke/Kill Lines. Bled down Closing unit. 3/3/2016 00:00 3/3/2016 01:30 1.50 COMPZN WHDBOP NUND 8.50 ND BOPE 3/3/2016 01:30 3/3/2016 05:00 3.50 COMPZN WHDBOP NUND 8.50 NU tree-test 250/5000 psi with diesel.Pull TWC 3/3/2016 05:00 3/3/2016 09:00 4.00 COMPZN WHDBOP FRZP 8.50 R/U LRS-PJSM-Begin pumping 60 bbls of freeze protect.RD LRS.Let well balance. 3/3/2016 09:00 3/3/2016 10:00 1.00 COMPZN WHDBOP MPSP 8.50 Set BPV. 3/3/2016 10:00 3/3/2016 12:00 2.00 DEMOB MOVE RURD 8.50 Blow down lines,clean remaining pits,rig down hard line to Kill tank.rig down manifold in cellar. ***Rig release @ 12:00 hrs*** Page 4/4 Report Printed: 4/4/2016 KUP INJ 1E-104 • ConocoPhillips 1° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ORB) Act Btm(ORB) ,_ Yet, 500292323400 WEST SAK INJ 67.18 3,937.43 6,935.0 - ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-104.3/18/20169:2E27 AM SSSV:NIPPLE Last WO: 31.11 12/5/2004 Vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,783.0 4/16/2009 Rev Reason:WORKOVER,GLV C/O lehallf 3/17/2016 Casing Strings HANGER,0.1 ail Casing Description OD(in) 10(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread _ CONDUCTOR 20 19.000 31.0 135.0 135.0 110.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 30.2 3,634.9 2,439.7 29.70 L-80 BTCM - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 5.5x3.5 51/2 4.950 27.5 6,919.9 3,976.6 15.50 L-80 BTC-MOD •1 if Tubing Strings Tubing Description String Ma...10(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection a3 1/2"RWO TUBING 3 1/2 2.992 -22.9 5,575.7 3,356.5 9.30 L-80 EUE ' COMPLETION Sil ,9,,Completion Details Top(ftKB) Top(ND)(ORB) Top Incl(1 Item Nominal ID Des Com (in) ' , 0.1 0.0 0.00 HANGER Vetco Gray 11"X41/2"4.909 MCA top connection 3.885 ,o, 5,553.0 3,345.6 60.96 LOCATOR Locator sub 2.990 CONDUCTOR;31.0-135.0 b. 5,557.2 3,347.6 61.16 SEAL ASSY Baker Seal Assembly 2.990 5,558.0 3,348.0 61.20 PBR 80-40 PBR Length 16.88' 2.990 Perforations&Slots Shot Den Top(NO) Btm(ND) (shots/( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE;30.2-3.634.9 1 5,760.0 5,840.0 3,437.5 3,471.7 WS D,1E-104 1/2/2005 6.0-IPERF 2.5"HSD PJ 5,840.0 5,860.0 3,471.7 3,480.3 WS D,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ 5,927.0 5,975.0 3,509.2 3,530.8 WS B,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ GAS LIFT;5,504.9 I1 5,975.0 5,995.0 3,530.8 3,540.1 WS B,1E-104 12/31/2004 6.0 IPERF 2.5"HSD PJ 6,278.0 6,335.0 3,672.3 3,698.6 WS A2,1E- '12/31/2005 6.0 IPERF 2.5"HSD PJ 104 6,335.0 6,395.0 3,698.6 3,725.8 WS A2,1E- 12/30/2004 6.0 IPERF 2.5"HSD PJ 104 Stimulations&Treatments LOCATOR;5,553.0 Min Top Max Btm Depth Depth Top(ND) Btm(TVD) SEAL ASSY;5,557.2 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 5,760.0 6,395.0 3,437.5 3,725.8 Acid Squeeze 12/11/200 115 BBLS SC-6918 ACID,FOLLOWED BY 50 BBLS 8 KI-3908(INHIBITED FRESH WATER) Mandrel Inserts St PBR;5,558.0 on i Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com II 1 5,504.9 3,321.5 Camco KBG-2- 1 GAS LIFT DMY DCK 0.000 0.0 3/13/2016 9 Notes:General&Safety End Date Annotation 8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 Ma a MR IM a' sr y IPERF;5,760.0-5,840.0 ,-- IPERF;5,840.0-5,860.0 8 f YE C INA IPERF;5,927.0-5,975.0 -( IPERF;5,975.0-5,995.0 - Mid Squeeze;5,760.0 8 8 8 8 AI IPERF;6,278.0-6,335.0 IPERF;6,335.0-6,395.0 /I PRODUCTION 5.50.5;27.5- 6,919.9 ti , • OF ��'\��\I �SA THE STATE Alaska Oil and Gas � � A of Conservation Commission *-fi 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *,;t> Main: 907.279.1433 ®FALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Theresa Lee SCANNED ER 1 6 201E Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU WSAK 1E-104 Permit to Drill Number: 204-227 Sundry Number: 316-025 Dear Ms. Lee: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this ? day of January, 2016. RBDMS t,L- JAN 2 5 2016 • STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMISSION 0?ANsN`1a4 r `16 APPLICATION FOR SUNDRY APPROVALS A0 C 20 AAC 25.280 1.Type of Request: Abandon 'r Plug Perforations ...... Fracture Stimulate I....... Repair Well Fi,; Operations Shutdown .._... Suspend F Perforate I' Other Stimulate Pull TubingI P ✓ Change Approved Program 1- Plug for Redrill E Perforate New Pool `-- Re-enter Susp Well 1- Alter Casing P Other: 1--- 2 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory 1 Development I' 204-227 3 Address: 6.API Number: Stratigraphic (— Service 1" ' P.O. Box 100360,Anchorage,Alaska 99510 50-029-23234-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ',7 No 14.cLu WSAK 1E-104 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25651 Kuparuk River Field/WSAK Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth D MPSP(psi): Plugs(MD): Junk(MD): 6,935' 3,984' tEj t 7-(3• 3?° 1507 NONE Casing Length Size MD ND Burst Collapse Structural Conductor 104' 20" 135' 135' Surface 3,605' 7 5/8 3,635' 2,440' Intermediate Production 5,524' 51/2 5,552' 3,346' Production 1,368' 312 6,920' 3,977' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5760-6395 3437-3726 3 1/2 L-80 5,582' Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and TVD(ft): SSSV:None n/a 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic ._. Development r Service 1 14. Estimated Date for 15.Well Status after proposed work: 3/1/2016 Commencing Operations: OIL i WIND lv.. WDSPL l.... Suspended 16.Verbal Approval: Date: GAS r WAG P GSTOR 1--- SPLUG GINJ I OpShutdown .' Abandoned i Commission Representative: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Theresa M.Lee Email Theresa.M.Leeanconocohillips.com Printed Name Theresa Lee @ 263-4837 Title Wells Engineer Signature 3.€12..... Phone: 263 4837 Date \ i 13 / 1 b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5\Le - 025 Plug Integrity ❑ BOP Test LK Mechanical Integrity Test l Location Clears e ❑ Other: Z3Up f rri to 00 0 pS`' /1/!P j P /a l 5-0 --tv7vlrrr pre - /-r 25C7pcl � �ttr ��b_i _Il rel iojecri�� 0" fate lrv1 Sj�d /vi t T- 14 rt gy � Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? Yes ❑ No 2( SubsequentForm Required: j 0 4 17 APPROVED BY -� / Approved by: i)� 0vIdNIAt COMMISSIONER THE COMMISSION Date: / -form 10) �ev11/2015 0 � IS valid2 m nthom the date o Aacesin Duplicate L iia.,/, ��I�IS 'J'' JAN 2 b • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Commissioner State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover the West Sak Injector Well 1 E-104 (PTD#204-227). 1E-104 was originally drilled in December 2004 and completed in the West Sak A, B & D sands as an Injector. The well failed an MIT-T in August 2015 and a tubing leak was found at 2,513'. The CMIT-TxIA passes to 2,500 psi indicating the production casing is intact. The well was shut in August 2015 due to tubing leaks. A tubing patch attempt from 2,508-2,520' failed in November 2015. There is a tested RN plug set in the 2.81" X lock nipple reducer at 5,750' TVD. The workover plans to replace the tubing and return the well to normal status. o This Sundry application is intended to document the proposed work on the Injection well 1 E-104. If you have any questions or require any further information, please contact me at 263-4837. Regards, 141(QVA Theresa Lee Workover Engineer CPAI Drilling and Wells Theresa.M.Lee@conocophillips.com • • 1 E-104 West Sak Injector Rig Workover (PTD #: 204-227) Current Status 1E-104 was originally drilled in December 2004 and completed in the West Sak A, B & D sands as an Injector. The well failed an MIT-T in August 2015 and a tubing leak was found at 2,513'. The CMIT-TxIA passes to 2,500 psi indicating the production casing is intact. The well was shut in August 2015 due to tubing leaks. A tubing patch attempt from 2,508-2,520' failed in November 2015. There is a tested RN plug set in the 2.81" X lock nipple reducer at 5,750' TVD. The workover plans to replace the tubing and return the well to normal status. Scope of Work The proposed workover will pull the existing 3 1/2" completion and install a new 3 1/2" completion. General Well info MPSP: 1,507 psi using 0.1 psi/ft gas gradient and SBHP from November 8, 2015 Reservoir pressure/TVD: 1,845 psi at 3,383' TVD (5,615' MD) SBHP taken on November 8, 2015 Wellhead type/pressure rating: Vetco Gray MB-222 5M BOP configuration: Annular/Pipe Rams/ Blind Rams/Mud Cross/ Pipe Rams MIT Results: MIT-T failed August 22, 2015 MIT-TxIA passed to 2,500 psi on November 9, 2015 Well Type: Injector Estimated Start Date: March 1, 2016 Production Engineer: Michael Sullivan 263-4123/ Michael.Sullivan@conocophillips.com Workover Engineer: Theresa Lee 263-4837/Theresa.M.Lee@conocophillips.com Pre-Riq Work 1. SL: Pull DMY valve from GLM#1 and leave open. 2. Ops: Set BPV within 24 hours of rig arrival. Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate seawater. Obtain SITP and SICP, if still seeing pressure at surface,calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV and blanking plug.ND tree,NU BOPE and test. 4. Pull blanking plug and BPV, screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3 1/2"tubing. a.If seals will not pull free from the PBR, RU E-line: Fire a string shot and cut the tubing at 5,519' (middle of lst full joint above seals at 5,564'). RDMO E-line. b. If tubing is cut,RIH w/spear dressed for 3 1/2"tubing on drillpipe, latch onto tubing stub and jar the seals free. POOH standing back drillpipe. 9. RIH in with new 3 1/2"gas lift completion. Space out 3'from fully located,mark the pipe.POOH two stands. 10. Spot corrosion inhibited seawater into the Tbg&IA. • 110 11. Space out w/pups,MU hanger.Land the hanger,RILDS. 13. PT the tubing to 3,500 psi,bleed tubing to 2,500 psi.PT the IA to 3,000 psi for 30 min and record. Bleed the IA to zero,then the tubing.Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint,install BPV.PT BPV to 1,000 psi from below. 15. ND BOPE. 16. NU tree.Pull BPV and install tree test plug.Test tree.Pull test plug. 17. Freeze protect well w/diesel. 18. Set BPV. 19. RDMO. Post-Riq Work 1. Pull 'H' BPV. 2. RU Slickline: a. RIH and pull RN plug from the 1.71"RN Nipple Reducer. b. RIH and pull the 1.71"RN Nipple Reducer from the 2.81"X-lock nipple c. RIH and pull the SOV from GLM#1.Run GLD. 3. Reset the well houses and flow lines. 4. Turn well over to Operations. KUP INJ • 1 E-104 Conocornmips la ) Well Attributes Max Angle&MD TD Ala`•fa Inc !Wellbore APIIUWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Bam(ftKB) C0rrr9.o.'WBlpa 500292323400 WEST SAK INJ 67.18 3,937.43 6,935.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-104,12/2/20152.12.14 PM SSSV:NIPPLE Last WO 31.11 12/5/2004 Velli/al schemat c(ac/unl) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 6,783.0 4/16/2009 Rev Reason:SET PATCH,RESET PLUG lehallf 12/2/2015 HANGER;22.5 I. Ceasing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I Grade Top Thread CONDUCTOR 20 19.000 31.0 135.0 135.0 110.00 H-40 WELDED 11 H Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 30.2 3,634.9 2,439.7 29.70 L-80 BTCM • Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(101) Set Depth(TVD)...WULen ft..Grade Top Thread I 4 PRODUCTION 5.5x3 5 5 1/2 4.950 27.5 6,919.9 3,976.6 15.50 L-80 BTC MOD '' Tubing Strings , .. , ,, I. L Tubing Description String Ma...Int Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING I 31/21D(i 2.9921 22.91 5,581.71 3,359.21 9.301 L-80 I EUEBRDMOD '' Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 22.9 22.9 0.35 HANGER VETCO GRAY TUBING HANGER 3.500 504.9 503.2 12.71 NIPPLE CAMCO DS NIPPLE w/NO GO PROFILE 2.875 ( .: ^' 5,563.9 3,350.9 61.48 LOCATOR BAKER GBH-22 LOCATOR 2.990 CONDUCTOR;31.0-135.0 5,564.7 3,351.2 61.52 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE;504.9 :I�. Top(TVD) Top Incl Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) 2,509.0 1,927.1 64.18 PATCH HES OOT XSPAN PERM PACKER 11/9/2015 2.250 PATCH;2,509.0 5,750.0 3,433.2 64.48 NIPPLE 2.81 X-LOCK W 1.71 RN NIPPLE REDUCER 11/7/2015 1.710 REDUCER 5,750.0 3,433.2 64.48 PLUG RN PLUG SET IN NIPPLE REDUCER 11/9/2015 Perforations&Slots %..:..1,...i....1.... Shot Dans Top(ND) Btm(ND) (shout( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE;30.2-3,634.9 5,760.0 5,840.0 3,437.5 3,471.7 WS D,1E-104 1/2/2005 6.0 IPERF 2.5"HSD PJ 5,840.0 5,860.0 3,471.7 3,480.3 WS D,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ GAS LIFT;5,541.8 5,927.0 5,975.0 3,509.2 3,530.8 WS B,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ 5,975.0 5,995.0' 3,530.8 3,540.1 WS B,1E-104 12/31/2004 6.0 IPERF 2.5"HSD PJ 6,278.0 6,335.0 3,672.3 3,698.6 WS A2,1E- 12/31/2005 6.0 IPERF 2.5"HSDPJ 104 6,335.0 6,395.0 3,698.6 3,725.8 WS A2,1E- 12/30/2004 6.0 IPERF 2.5"HSDPJ ih 104 LOCATOR;5,563.9 '.. Stimulations&Treatments SEAL ASSY;5,564.7 ('I Min Top Max Btm Depth Depth Top(ND) Btm(NO) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com !! A 5,760.0 6,395.0 3,437.5 3,725.8 Acid Squeeze 12/11/200 115 BBLS SC-6918 ACID,FOLLOWED BY 50 BBLS 8 KI-3908(INHIBITED FRESH WATER) Mandrel Inserts St ate N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sar; Type Type (in) (psi) Run Date Com 1 5,541.8 3,340.1 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/27/2005 12.00 PLUG;5,750.0 9 NIPPLE REDUCER;5,750.0 [{ Notes:General&Safety ! End Date Annotation .:x8/25/2010 NOTE:View Schematic w/Alaska Schematic9.0 12 s IPERF;5,760.0-5,840.0 '1 IPERF;5,840.0-5,860.0 , 3EE am N 1 cr., MB IPERF;5,927.0-5,975.0 • • IPERF;5,975.0-5,995.0 • Acid Squeeze;5,760.0 • IIS - 111k a IPERF;6,278.0-8,335.0 IPERF;6,335.0-6,3950 PRODUCTION 5.503.5;27.5- 8,919.9 411!ConocoP'h hips 1E-104 P&R 3-1/2" Tubing Casing—7-5/8" 29.7#, L-80 BTCM to 3,635' Tubing—3-1/2" 9.3#, L-80 EUE8rdMOD to 5,582 40— Camco 3-1/2" x 1" KBG-2-9 GLM @ 5,517' Casing—5-1/2" 15.5#, L-80 BTCM to 5,565' —� Baker 80-40 Seal Assembly @ 5,565' Baker GBH-22 Locator @ 5,564' in 2.81"X Nipple @ 5,750' WS D Perfs 5,760'to 5,860' —PP- WS B Perfs 5,927'to 5,995' —0- WS ►WS A Perfs 6,278'to 6,395' _ Liner—3-1/2" 9.3#, L-80 BTCM 5,565'to 6,620' --► Date: December 10,2015 Drawn By: Theresa Lee S Bettis, Patricia K (DOA) From: Lee, Theresa M <Theresa.M.Lee@conocophillips.com> Sent: Wednesday, January 20, 2016 2:10 PM To: Bettis, Patricia K (DOA) Subject: Re: [EXTERNAL]KRU WSak 1E-104: Sundry Application Patricia, The last tag was 6,783' MD 3,909'TVD. Thanks, Theresa Sent from my iPhone On Jan 19, 2016, at 3:56 PM, Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov» wrote: Good afternoon Theresa, On Form 10-403, Box 11, information on the effective depth (MD and TVD) for KRU 1E-104 is missing. Please submit that information via email as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907)793- 1238 or patricia.bettis@alaska.gov<mailto:patricia.bettis@alaska.gov>. 1 • S Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, January 19, 2016 3:08 PM To: 'Theresa.M.L33@conocophillips.com' Subject: KRU WSak 1 E-104: Sundry Application Good afternoon Theresa, On Form 10-403, Box 11, information on the effective depth (MD and TVD) for KRU 1E-104 is missing. Please submit that information via email as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • 204-t- 221 • WELL LOG TRANSMITTAL# DATA LOGGED 0 R.r/2015 K.BENDER To: Alaska Oil and Gas Conservation Comm. October 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 995011741 t 1 2 RE: Leak Detect Log with ACX: 1E-104 Run Date: 9/7/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-104 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23234-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-029-23234-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari s 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAL.4....47) ..E:+t�% WELL LOG TRANSMITTAL#902729416 To: Alaska Oil and Gas Conservation Comm. October 9, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 to/2342°15 K.BENDER Anchorage, Alaska 99501 RECEIVED OCT 14 2015 RE: Multi Finger Caliper(MFC): 1E-104 AOGCC Run Date: 9/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-104 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23234-00 scoNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: " Signed: �� OF � • • �w\����7j��s), THE STATE Alaska Oil and Gas ; � Of Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Kelly.,ALASakteie S AN ( !Y[ Problem Well Supervisor h a`ad ConocoPhillips Alaska, Inc. V P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-104 Sundry Number: 315-624 Dear Ms. Lyons: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this day of October, 2015 Encl. JC' RBDMS nrT -9 2015 STATE OF ALASKA ALWA OIL AND GAS CONSERVATION COM.ION APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations I— Fracture Stimulate E Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing E Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well ry7- Re-enter Susp Well rOther:Tubing patch Fli 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. , Exploratory r Development r 204-227 3.Address: Stratigraphic Service P , 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23234-00 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes fl No J KRU 1 E-104 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025651 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 TVDA_ Plugs(measured): Junk(measured): 6935 3984 (:)783 .3901 Casing Length Size t MD TVD Burst Collapse CONDUCTOR 104 20 135' 135' SURFACE 3605 7 5/8 3635' 2440' PRODUCTION 3977' i,:-.., k '� 6892 5.5 x 3.5 6920' ' " ii',1 0 6 201? 7s 11 ''1( 15 P Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5760'-6395' " 3438'-3726' 3.5 L-80 5564 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL ASSY-BAKER 80-40 SEAL ASSEMBLY MD=5565 TVD=3351 ' NIPPLE-CAMCO DS NIPPLE w/NO GO PROFILE MD=505 TVD=503 • 12.Attachments: Description Summary of Proposal 17,7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Stratigraphic Development Service Pi, 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/14/2015 OIL r WINJ WDSPL r Suspended 16.Verbal Approval: Date: GAS r WAG r GSTOR I— SPLUG Commission Representative: GINJ r Op Shutdown I- Abandoned E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelly Lyons/Brent Rogers 'J/ Email: N1617na conocophillips.com Printed Nam_e... II L n Title: Problem Well Supervisor Signature Phone:659-7224 Date 10/04/15 t Commission Use Only Sundry Number:: L( Conditions of approval: Notify Commission so that a representative may witness 3i6 -LoZ- ` Plug Integrity r BOP Test r Mechanical Integrity Test VLocatiioon Clearance r Other: fi� W I f".tf 5-'e.d A41 ,--1 re-I/ i r-e'C 4-1(2-712- C f r �`J �I rfi r Q l �� C c s Spacing Exception Required? Yes ❑ No Ld Subsequent Form Required: h9-404_ / APPROVED BY Approved by: T MI ONER T I dal Date./' 1, S� ppr ved application is va RYor1S2 months fr m th�Edgga l Submit Form and Form 10-403 Revised 5/2011 oRIGINAL ?I ie/ //S ? ' / Attachments in Duplicate VTL /b/ /1 RBDMS - -g nils • • RECEW - -_ . . 0 Z_015 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 04, 2015 Commissioner Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Ms. Foerster: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. KRU West Sak well 1E-104 (PTD 184-051) for repair of a tubing leak with a 10' Halliburton permanent patch. ✓ Please call Brent Rogers or myself at 659-7224 or Jan Byrne/Dusty Freeborn at 659-7126 if you have any questions. Sincerely, Kelly yons ConocoPhillips Problem Well Supervisor Enclosures • • ConocoPhillips Alaska,Inc. KRU West Sak Well 1E-104 (PTD 204-227) SUNDRY NOTICE 10-403 TUBING REPAIR 10/04/15 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk River Unit West Sak Well 1E-104 (PTD 204-227)with a tubing patch. On August 23, 2015, the AOGCC was initially notified of suspected TxIA communication due to a failed MITIA that occurred during routine wellwork. Diagnostics have identified a tubing to IA leak at 2513' which is approximately 3052' above the seal assembly. The plan is to set a permanent patch over the leak ,,,,,,% point, conduct an MITIA, and return the well to normal water injection. REPAIR PLAN 1. Set 10' 3.5"permanent patch over the leak at 2513'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post-repair. NSK Problem Well Supervisor KUP INJ • 1E-104 ConocoPhaIips c1 Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) conna+ndl6p, 500292323400 WEST SAK INJ 67.18 3,937.43 6,935.0 ° ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-104,9/9/2015 4'21'07 PM SSSV:NIPPLE Last WO: 31.11 12/5/2004 Vertcel schematic(actuah Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,783.0 4/16/2009 Rev Reason:Mandrel Orientations lehallf 9/9/2015 r HANGER;229 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread CONDUCTOR 20 19.000 31.0 135.0 135.0 110.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 30.2 3,634.9 2,439.7 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5x3.5 5 1/2 4.950 27.5 6,919.9 3,976.6 15.50 L-80 ETC MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection ...........u."........"4 TUBING 3 1/2 2.992 22.9 5,581.7 3,359.2 9.30 L-80 EUE8RDMOD L , 1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.9 22.9 0.35 HANGER VETCO GRAY TUBING HANGER 3.500 504.9 503.2 12.71 NIPPLE CAMCO DS NIPPLE w/NO GO PROFILE 2.875 ./... 5,563.9 3,350.9 61.48 LOCATOR BAKER GBH-22 LOCATOR 2.990 CONDUCTOR;31.0-135.0 I'. I5,564.7 3,351.2 61.52 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY - 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) NIPPLE;504.9 I Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 5,750.0 3,433.2 64.48 PLUG 2.81"XX PLUG,8x3/16"PORTS,54"GAL 8/22/2015 0.000 Perforations&Slots Shot Dens Top(ND) Btm(2N.8:1)" ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 5,760.0 5,840.0 3,437.5 3,471.7 WS D,1E-104 1/2/2005 6.0 IPERF 2.5"HSD PJ SURFACE;30.2-3,634.9 5,840.0 5,860.0 3,471.7 3,480.3 WS D,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ 5,927.0 5,975.0 3,509.2 3,530.8 WS B,1E-104 1/1/2005 6.0 IPERF 2.5"HSD PJ GAS LIFT,5,541.8 - 5,975.0 5,995.0 3,530.8 3,540.1 WS B,1E-104 12/31/2004 6.0 IPERF 2.5"HSD PJ 6,278.0 6,335.0 3,672.3 3,698.6 WS A2,1E- 12/31/2005 6.0 IPERF 2.5"HSD PJ 104 6,335.0 6,395.0 3,698.6 3,725.8 WS A2,1E- 12/30/2004 6.0 IPERF 2.5"HSD PJ 104 Stimulations&Treatments LOCATOR;5.5639- I Mar Top Max Btm _ Depth Depth Top(ND) Btm(ND) SEAL ASSY;5,564.7 = (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 5,760.0 6,395.0 3,437.5 3,725.8 Acid Squeeze 12/11/200 115 BBLS SC-6918 ACID,FOLLOWED BY 50 BBLS 8 KI-3908(INHIBITED FRESH WATER) Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 5,541.8 3,340.1 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 12/27/2005 12:00 9 Notes:General&Safety End Date Annotation 8/25/2010 NOTE:View Schematic wl Alaska Schematic9.0 PLUG;5,750.0 il IPERF;5,760.05,840.0 1 1 IPERF;5,840.0-5,860.0 : 4 ■' 4. a IPERF;5,927.0-5,975.0 ; IPERF;5.975.0-5,995.0 II Acid Squeeze;5.760.0 a i • 4. it IPERF;6,278.0-6,335.0 1 IPERF;6,335.06395.0 1 PRODUCTION 5.503.5;27.5- 6.9199 • • • Bettis, Patricia K (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, October 07, 2015 1:28 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1E-104: Sundry Application 6783' MD (3909' TVD) Thanks Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, October 07, 2015 1:06 PM To: NSK Problem Well Supv Subject: [EXTERNAL]KRU 1E-104: Sundry Application Good afternoon Kelly, What is the current effective depth of KRU 1E-104, both MD and TVD? Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettisCalaska.gov. 1 111111 • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, October 07, 2015 1:06 PM To: NSK Problem Well Sup/ (n1617@conocophillips.com) Subject: KRU 1E-104: Sundry Application Good afternoon Kelly, What is the current effective depth of KRU 1E-104, both MD and TVD? Thanks, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, August 23, 2015 10:46 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; NSK West Sak Prod Engr; Senden, R. Tyler Subject: KRU 1E-104 (PTD 204-227) Report of failed MITIA Attachments: MIT KRU 1E-104 diagnostic MITT 08-22-15.xls; 1E-104 schematic.pdf Chris, Kuparuk West Sak injector 1E-104 (PTD 204-227) had a failed MITIA during routine wellwork. Slickline was prepping the well for an injection test with heated/filtered seawater by installing downhole pressure and temperature gauges. During the Slickline work, a passing MITIA was unable to be achieved. The initial diagnostics performed at the time indicate possible one way IA to tubing communication. A passing MITT(see attached form) was achieved. Further diagnostics will continue to identify the possible leak source and repair if possible. The appropriate paperwork will be submitted at that time as needed. Also attached is a wellbore schematic and 90 day TIO plot for reference. Please let me know if you have any questions. scp>NHE© AUG 2 42015 1 Well Flame 1E-104 Notes: Start Date 5/25/2015 Days 90 End Date 8/23/2015 2E00 - — 1E _WHP Annular Communication Surveillance IAP DAP — 1` INHT 2CCC 1 — 12 1E0C 11 — 1[ _ 1CC0 • 1.4600411111 5( N _ EC 500 7( C I 1 1 I 1 1 1 EC May-1E May-1E Jur-1E J;,❑-1 Jun-15 Jul-15 Jul-15 Jul-15 Aug-15 Lug-1E Aug-1E Sep-1E —a May-1E 1,1ay-1E Jun-1E Jun-1E Jun-1E Jul-1E Jul-1E Jul-1E Aug-1E Aug-1E Aug-1E Sep-15 Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 41111WELLS TEAM Conor coPhiilps 2 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 L.J- - ~ cl7- Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111' 111111 111111I RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettesl No. J o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: ~ oatetls/07 J I o Other:: BY: VMe 11111111111I11 1111I rl1E + ~ = TOTAL PAGES (p (p (Count does not include cover sheet) /s/ /s/ Project Proofing BY: ~ Date '/S/D7 à- X 30 = 10 0 Date: .5 /s/ Scanning Preparation Produc#onScanning Stage 1 Page Count from Scanned File: h- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: I /~/D7 11/111111111111111I NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES /s/ Mp NO BY: Maria Date: /s/ 11I11111111I11 I11I1 Scanning is complete at this paint unless rescanning is required. ReScanned 11/1111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111111/111111111111 10/6/2005 Well History File Cover Page.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ,:, _ - ;_; ~'~ ;f_~ RE: Bottom Hole Pressure Survey: 1E-104 Run Date: 8/25/2010 August 27, 2010 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 1E-104 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23234-00 Shut In Bottom Hole Pressure Survey Log 1 Color Log 50-029-23234-00 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.cotx~~, ~, ~ -~ ~ `~ fi~ ~ ; ~ , ~, ~n~, Date: .~ ~ +; ~~ ~; . _ ~=• ~~ ~~'~ ~~ ~~ Signed: ~~ . ~~~,~~'. ~ ~ ~~~c ~ ~- ~~- Regg, James B (DOA) ~ 2©4 -~z-7 From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Saturday, June 26, 2010 9:59 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: KRU 4 Yr and Variance MIT's Attachments: KRU 1 G-01 062510.x1s; KRU 2D-04 062510.x1s; KRU 1 E pad 062510.x1s -=~ ~ KRU 1G-O1 KRU 2D-04 KRU lE pad 062510.x1s (21 KB) 062510.x1s (21 KB) 062510.x1s (21 KB) Attached please find the State Witnessed Variance required MIT's for 2D-04 and 1G-O1 and State waived 4 year MIT~s on DSlE. Let me know if you have any questions about the data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 1 FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. 1~'~ ~~~~~(lo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Kuparuk /KRU / 1 E 06/25/10 Ives/Mouser - ASRC Waived by Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1E-21 Type Inj. W TVD 5,943' Tubing 2,000 2,000 2,000 2,000 Interval 4 P.T.D. 1830020 Type test P Test psi 1500 Casing 1,620 3,000 2,960 2,960 P/F P Notes: OA 80 80 80 80 Well 1E-22 Type Inj. N TVD 5,955' Tubing 2,250 2,250 2,250 2,250 Interval 4 P.T.D. 1822140 Type test P Test psi 1500 Casing 740 2,920 2,880 2,850 P/F P Notes: OA 490 520 520 520 Well 1E-104 ~ Type Inj. W TVD 3,351' Tubing 900 900 900 900 Interval 4 P.T.D. 2042270 Type test P Test psi 1500 ~ Casing 61 2,000 ~ 1,980 1,960' P/F P ' Notes: 45 Min T!I/O = 900/1960/200 OA 190 200 200 200 Well 1E-105 Type Inj. N TVD 3,515' Tubing 200 200 200 200 Interval 4 P.T.D. 2050060 Type test P Test psi 1500 Casing 100 2,000 1,940 1,920 P/F P Notes: OA 100 140 140 140 TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1E pad 062510.x1s • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1E-104 Run Date: 4/18/2010 Apri129, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 E-104 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-23234-00 Injection Profile Log 50-029-23234-00 `~ ~:~~ti~r~ ~~'-~''~ ~, '' `~~~~~` 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 _ rafael.barr` a~llihdr~.c'o ~ '~ - ._ __, Date: ,~~~.. ~ , a , - ~z~ ~o~r-a~~ ~ ~~aa - -. _~ -... ~ s'3 Signed: • JAN 0 7 2009 STATE OF ALASKA `~~7Sk~~~ ~8S ~ ALASKA OIL AND GAS CONSERVATION COMMISSION, OOS° ~Ofti1-Tli'$$Ip6 ~:~G'~"r~i ~ REPORT OF SUNDRY WELL OPERATIO~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^/ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development ^ Exploratory ^ 204-227 / ' 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23234-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-104 . 8. Property Designation: 10. Field/Pool(s): ADL 25651 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 6935' feet true vertical 3984' feet Plugs (measured) Effective Depth measured 6825' feet Junk (measured) true vertical 3929' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 107' 20" 135' 135' SURFACE 3607' 7-5/8" 3635' 2440' PRODUCTION 5524' 5-1/2" 5552' 3346' PRODUCTION 1368' 3-1/2" 6920' 3977' Perforation depth: Measured depth: 5760'-5860', 5927'-5995', 6278'-6395' ' ~~~ `)~~ ~' ~ ~Ci~~ ' ' ' ' ' true vertical depth: 3438 -3480 , 3509 -3540 , 3672 -3726 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5582' MD. Packers & SSSV (type & measured depth) Baker 80-40 seal assembly @ 5555' , ~ ~~~ ~ ~ ~ ~~ ~~~f Camco'DS' ni le 505' ~S `~` ~ ' ~j ` pp 12. Stimulation or cement squeeze summary: ` ~~~ ~'~ ~~t3 Intervals treated (measured) 5760'-6395' 115 bbls acid, 50 bbls fresh water Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 411 Subsequent to operation 407 - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-359 Contact Guy Schwartz @ 26 -6958 Printed Name Guy SChwa~t•tr'- Title Wells Engineer Signature /' Phone: 265-6471 Date f ~ ~~ Pre ared b Sharon All u Drake 263-4612 p~~ ~.a ~'7•-1 Form 10-404 R ised 04/2006 ~ ~~~ ~ ~ ~00~ K~ ~i''~ Submit O~ri~gi~nal Only i~e%~"' C/~7~~ KUP - 1 E-104 ..- // ~~~~~~~~~~~ ( ! Weq Attriblates _ Max Angle 8 MD TD t,Y,.1 1 Wellbore APl/U WI Fieltl Name We115tatus Prod/Inj Type Inc! (°) IMD (HKB) Act Btm (ftK8) 500292323400 WEST SAK INJ !PWI 67.18 3,93].43 6,9350 ... well I HANGER, 28 - CONDUCTOR,_ 135 NIPPLE, 505 - GAS LIFT, 5.562 SBE, 5,563 ~ ~- LOCATOR, 5,564 SEAL, 5,665 - PRODUCTION NIPPLE. 5,750 SBE, 5 ]52 - IPERF, 5,]60-5,860 IPERF, 5 800-5,860 NIPPLE. 5.911 SBE. 5,912 IPERF, 5,927-5,975 IPERF, 5,5]5-5,595 Add S4ueeze, 5.]60 NIPPLE, 6,25] SBE. 6,259 IPERf,_ fi,2]8-6.335 IPERF, 6,335-6.395 PRODUCTION 3.5', 6.920 TD. 6.935 Comment H2S (ppm) Entl Date KB-Grd (H) Date (Annotation Rig Release Date SSSV: NIPPLE 0 I ( 7/1/2008 I}Last WO: 31.11 ( 12!5/2004 Annotation Depth (HKB) End Data Annotation IEntl Date Last Tag: ( ( ( 5,808.0 6/7/2008 Rev Reason: Comment ACID STIMULATION I 12/12/2008 ~Casin Strin s String OD ' String ID Set Dep[h Set Depth (ND) String Wt String Casing Description lint lint Top (HKB) (ftK8) (ftK8) (Ibs/H) Gmtl ~ ~ e String Top Thrd 'CONDUCTOR 20 19.000 00 135.0 135.0 ' 110.00 H-00 WELDED SURFACE 75/8^ 6.875 0.0 3635.0 2,439.8 29.70;L-80 IBTCM PRODUCTION 5.6" 51/2 4.950 31 0 5,583.0 3,360.11 15. SOL-80 ~BTCM PRODUCTION 3.5" 31/2i 2.992 5.5840 6,920.0 3,976.61 9.30 `L-80 EUE8rtl Tubing Strings String OD String ID Set Depth Set Depth (ND) String Wt ', Sbing Tubing Descri ption (in) (in) Top (HKB( (ftK8) (ttKB) (Ibs/k) Gratle String TO p Thrd TUBING 312 2.992 0.0 5,582.0 3,359./ 9.30 i. L-80 EUESrd _ _.-. ~ Other I n Hole All Jewelr~r-. Tubin g Run 8 Retrievable, Fish, etc. ___ Top Dopth - - '~ -- T op (ftK8) (TVD) (HKB( lop Inc! (°) Description Gommant Run Date ID (in) _ 28 0 28 0~ 0.81 HANGER '~VETCO GRAY CASING HANGER 12/4/2004 5-500 505.0 503.2 12.71 NIPPLE CAMCO'DS' NIPPLE w1N0 GO PROFILE 12/42004 1 2.875 5 542 0 3,341 8 63.55 GAS LIFT CAMCO/KBG-2-9/1/DMV/TNT//1 Comment: STA 1 12/21/2005 2.900 5,563 0 3,351.2 63.64 SBE CROSSOVER w/80-40 SEAL BORE EXTENSION 12/4/2004 i 2.813 5,564.0 3,351.7 63.64 LOCATOR BAKER GBH-22 LOCATOR 12/4/2004 j 2.990 5,565.0 3,352.1 63.65 SEAL (BAKER 80-40 SEAL ASSEMBLY 12/4/2004 1 2.9901 5,583.0 3,360.1 63.72 CASING XO (PRODUCTION CSG XO 5.5" TO 3.5" 12/4/2004 2.813 5,750.0 3433.5 64.95 NIPPLE HES 'X'NIPPLE 12/4/2004 'I 2.813 5,752.0 3,434.3 64.59 SBE SEAL BORE NIPPLE I 12/4/2004 1 2.813 5,911.0 3,501.6 62.71 NIPPLE 'HES'X'NIPPLE I _ 12/412004 ii 2.813 5,912.0 3,502.0 62.70 SBE _._. 'SEAL BORE NIPPLE ~ 12/4/2004 '.. _.__. 2.813 6,257.0 3,662.6 62.24 NIPPLE _.. __.._._ HES 'X'NIPPLE i 12/4/2004 - __ 2.813 6,259.0 3,663.5'( 62.24 SBE (SEAL BORE NIPPLE 12/412004 ~ 2.813 Perfora tions ~ ~ 'Shot.. ' ', Top (TV D) Btm (TVD) Dens Top (ftK8) ' Btrn (ftK8) ' /ftK8) (HKB) Zone Date (sh... T e Go mmant 5,760.0 ', 5,840.0 3 437.7 3,472.8 WS D, 1E-104 1/2/2005 6.0 IPERF 25" HSD PJ 5,840.0 5,860.0 3,472.8 3,480.7 WS D. 1E-104 I1/1/2005 6.0 IPERF 25" HSD PJ -._ 5,927. t 0 6,975.0 3,508.8 3,530.8 WS B, 1E-104 1/1/2005 6.0 IPERF 2.5" HSD PJ 5,975.0 1 5,995.0 . 3.530.8 3,540.1 WS B, 1E-104 12/31/2004 60 IPERF 2.5" HSD PJ 6,278.0 6,"s35.0 ~ 3.673.7 3698.7~WS A2, 1E-104 12/312005 6.0 IPERF X25"HSD PJ 6,335.0 Stimula 6,395.0 tions 8 3,698./ 3.725 A.WS A2. 1E-104 12/30/2004'( 6.0 IPERF 2.5"HSD PJ Treatments ~ __ Min Top Boftom Max Btm .Top Depth Depth - . , Depth Depth ~, (NDI (TVD) (ftK8) I (ftK8) (ftK8) (HKB) ' Type I Data Comment 5,760.0 ' 6,395.0 3,437.7 3,725.8 Acitl Squeeze '(12/11/2008 115 BBLS SC-6918 ACID, FOLLOWED BY SO BBLS ~ KI-3908 (INHIBITED FRESH WATER) 1 E-104 Well Work Summary DATE SUMMARY 12/11/08 PERFORMED ACID STIMUL~N ACROSS ALL PERF INTERVALS. DI~T OBSERVE ANY BREAKDOWN THRU OUT THE ENTIRE STAGE OF TREATME~I T.-TdTAC~~F'~115 BBLS SC-6918 (A ID) FOLLOWED BY 50 BBLS KI- 3908 (INHIBITED FRESHWATER). AVERAGE INJECTION PRESSURE 1000 PSIG WHP @ .5 BPM. WELL LEFT SHUT IN, TURN OVER TO DSO TO PUT BACK ON INJECTION ASAP. (( COMPLETE )) • SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Wells Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 ~'~~~ `~° Re: Kuparuk River Field, West Sak Oil Pool, 1 E-104 Sundry Number: 308-359 Dear Mr. Schwartz: a~~-a~ ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested.- Sincerely, ~~~~ Daniel T. Seamount, Jr. e ~ Chair DATED this ~ Uday of October, 2008 Encl. v.~~ ' t;'~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~~/t~- 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 204-227 ' 3. Address: Stratigraphic ^ Service ^/ r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23234-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ~ 1 E-104 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25651 RKB 28' ~ Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6935' • 3984' 6825' ~ 3929' Casing Length Size MD ND Burst Collapse CONDUCTOR 107' 20" 135' 135' SURFACE 3607' 7-5/8" 3635' 2440' PRODUCTION 5524' 5-1/2" 5552' 3346' PRODUCTION 1368' 3-1/2" 6920' 3977' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5760'-5860', 5927'-5995', 6278'-6395' 3438'-3480', 3509'-3540', 3672'-3726' 3-1/2" L-80 5582' Packers and SSSV Type: Packers and SSSV MD (ft) no packer Camco'DS' nipple 505' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 20, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU SChW rtz Title: Wells Engineer // Signature l®3 Phone 265-6958 Date _ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ `~ ~S°~ M~ dl~+`'~~' V~-L ~j ®~ -E-C~ S~ Subsequent Form Required: ly~~ APPROVED BY V ~ 2 ~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ' ^; ; ~ ~, ~~'~ ~ ~ ~~~~ ~ ub~ it in Duplica fp./S o$ ;~ ~ r6 ~ I ~~~~~~- i -. '~ i C©nocaPhiQip - Well' coma w~~.. ,,.._,.a Anne kANGER, 28 NIP. 505 s0na« GAS UFT, s,s/2 Protluction xo, s,ss3 OCATOR, 5,561 SEAL, 5,565 XO, 5,583 NIP, 5,750 SBE, 5,752 ,810-5,660, . 7HI2005 NIP, 5,911 SBE, 5,912 ,927-5,975, 1n/2005 ,9755,995, ~_ . 12/3112004 NIP, 6,257 SBE, 8,259 ,2786, 3%, ri 72/3t/iWr ,3356,395, r- . 1v3a~zoo/ Pmductlon ~ To, 6,920 (Last nd Date Annotation 6/7/2008 Rev Reason: Comment: TAG FILL P 1 E-104 .- F:: ,.~ i%ImYm 1 I e[lon t') Total Depth (ttK8) 67 18 6.920.0 KB-Grd )fl) IRig Release Date 31.11 j 12152004 End Date 6/9/2008 nn Msenption On ( 1 In lin! Tip MKB1 ~ Set Depth )RKB) set Depth lT.rn) r}p[BI i~ (IheMt1 ~ mane ~ Tnp ThreM -, 1 _ _ _.._ 5.5820 ,- ~ L-"i:~ Li iE.;~,l 5,750.O iNIP I HES 'X'NIPPLE 12/4/2004 2.813 5,752.0 SBE SEAL BORE NIPPLE , 1214/2004 2.813, 5,911.0 NIP HES 'X' NIPPLE 1 12/4/2004 2.813 5,912.0 SBE SEAL BORE NIPPLE 12/4/2004 2.813 6,257.0 NIP HES'X' NIPPLE 12/4/2004 i 2.813 6.259.0 SBE SEAL BORE NIPPLE 1214/2004 12.813 Sn V l ~ Top )TVD) Btm )TVO) ot Dens a cu... Shot Top (ftK8) Btm (flKe) (RKB) )flKB) Type Zone (shot... Total Date Comment 5,760.0 5,840.0 3,437.7 3,472.8 IPERF 6.0 480 1/212005 2.5" HSD PJ 5,840.0 5,860.0 3,472.8 3,480.7 IPERF 6.0 120 1/1/2005 2.5" HSD PJ i 5,927.0 5,975.0 3,508.8! 3,530.8 IPERF 1 6.0 2881 1112005 2.5" HSD PJ ~ • • 1E-104 Injector Stimulation 10-2-2008 Justification: 1E-104 is a conventional West Sak Injector (3.1/2" monobore) with low injection rates into the combined A,B and D sands. The most recent IPROF indicates fluid entry as, follows: A = 0% B= 57% and D = 43% at total surface injection rate of 460 bwpd. This procedure proposes to do a CTU stimulation using MI's SC-6918 system (Mutual Solvent) in the wellbore in order remove "schmoo" and cleanup other acid soluble solids in the wellbore and near wellbore pore space. A follow-up IPROF will be need to determine the benefits of the treatment and obtain new injection splits from the A, B and D sands. Procedure: The basic process uses coil tubing to lay in MI's SC-6918 mutual solvent product 2:1 along the perforated intervals and letting it soak for 30 mins hrs before pumping away the remainder of the product. 1. RU 1 3/4" CT . SI well at surface and leave SI for entire treatment. 2. RIH with 1 3/4" CT, Nozzle and lay in 12 bbls of MI SC-6918 from bottom perf to top perf. (2:1 ratio of solvent to wellbore volume) 3. Let soak for 30 min. 4. RBIH with Nozzle, stop at mid A sand perfs and pump 33 bbls SC-6918 away at .5 bbl/min 5. Move CT to top of B perfs and pump 35 bbls SC-6918 at .5 bbl/min 6. Move CT to top of D perfs and pump 35 bbls (or all remaining) SC-6918 away at .5 bbl/min 7. Pump 15 bbls of inhibited displacement fluid (1% KI-3908) at .Sbbl/min 8. RDMO CT . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchora e AK 99501 ~~~~~~~ ~ ~ ~ g ~ ,.:~ r~ Fp ~~ 200 ~~ Dear Mr. Maunder: S ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20th -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 1C-178 203-041 8' 1.50 8" 9/11/2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1 Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1 Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 ~~~~ ,..~ 4, ~n ~..g 5~m~. ~ ~ gam. ,'~ ~~ i~ f,1 •Y t_! ~ `~ 7~U~ ;5 _ • ~:~ .. ,., s~"~~ „~::.. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche~CvrPgs_InsBrtslMicrofilm Matker.~c . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 1E-102_L1_L1 PB1_PB1_PB2, 1E-104, 1E-121_Ll. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 U "I C- d 04 -;;)3 / I U 'J:.C,.. g ó4 - d3 d. 1E-102_L1_L1 PB1_PB1 PB2: /L/4{¡;ó IL/¿'/fp( Digital Log Images: 1 CD Rom 50-029-23236-00, 60, 72, 70, 71 1E-104: U Ie.. 804-8d1- Ib IL/LI~7 Digital Log Images: 1 CD Rom 50-029-23234-00 1E-121_L1: ao4-d(/rot£ /4LfS-7r 6)()t...( -d'''(9 -if IL(459 Digital Log Images: I 1 CD Rom 50-029-23238-00, 60 SCANNED FEB 0 1 2007 þ Ç" J~ ~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 MD 6935 / TVD 3984.;/' Completion Date 12/5/2004 /' Completion Status 1WINJ Current Status 1WINJ A:f ~~O-029-23234-00-00 ...~-- Permit to Drill 2042270 Well Name/No. KUPARUK RIV U WSAK 1E-104 Operator CONOCOPHILLlPS ALASKA INC REQUIRED INFORMATION Mud Log No Samples No Directional survey~' DATA INFORMATION Types Electric or Other Logs Run: GRlRes, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr . Data Digital Dataset Log Log Run Interval OH/ ~Med/Frmt Number Name Scale Media No Start Stop CH Received Comments -- --¡ . 0 Asc Directional Survey 0 6935 1/27/2005 IIFR I I ~ Perforation 5 Blu 5891 6468 1/19/2005 PERFORATING RECORD W/SBHP Cement Evaluation 5 Blu 5400 6540 Case 1/19/2005 CEMENT BOND LOG/SLIM CEMENT MAP I TOOL I i'-bd9 Injection Profile 5 Blu 5706 6450 2/22/2006 INJECTION PROFILE I SPINITEMP/PRESS Lis 13700 I ndu ction/Resistivity 215 6935 Open 2/22/2006 ROP DGR EWR SLD CTN plus Graphics Las 12954 Induction/Resistivity F'{~J .........~ 1'( (~I 3559 6935 Open 8/30/2006 NPHI, GR, FET, RHOB (Data Sent back and reused old Data set #) ~/ LIS Verification 0 0 Open 1/27/2005 LIS Verification (recently I found) L-.. . Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM~ON Well Cored? y N::i) Daily History Received? ~ Chips Received? ~ Y.' þJ ~ Formation Tops Analysis Received? ~.. Permit to Drill 2042270 MD 6935 TVD 3984 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 Well Name/No. KUPARUK RIV U WSAK 1E-104 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23234-00-00 Completion Date 12/5/2004 Completion Status 1WINJ Current Status 1WINJ UIC Y ~ Date: ._ '3> ~ ~ 7 ----- . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907 - 793-1005 August 28, 2006 RE: MWD Forrnation Evaluation Logs: IE-I04, CD3-302 PBI, 05-20B, 15-46 LI PBI, MPK-09, MPE-31, MPC-43, MPE-25A. IE-I04';J04... Q~~ 1':).0,5<-( CD3-302 PBI 'Gö<o- 010 IloilO 1 OS-20B v 801../-;[34 14ð4C¡ IS-46 LI PBI JoL(-ID3 I lo/I vO MPK-09 90õ- Oll..{ 14110~ MPE-31 goS"- o'rd.IL./lo3 MPC-43 804- 03G>¡ 14/od MPE-2SA UT.C- Qo4 - 045" I g:5 fji./ Digital LIS DATA: 1 CD Rom 50-029-23234-00,50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00, 50-029-23200-00, 50-029-22980-0 I. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: if/3rJtk> Signed: d~L MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg. ~'t! tJC¡/(j{~ P.I. Supervisor )! ( . f { DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-I04 KUPARUK RIV U WSAK IE-I04 CJ.o4~ û-r 7 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ----if P.I. Suprv, Jbf-'"'" Comm Well Name: KUPARUK RIV U WSAK IE-I04 API Well Number 50-029-23234-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060605141137 Permit Number: 204-227-0 Inspection Date: 6/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IE-104 ¡Type Inj. I W I TVD ! IA I I 2780 2710 2700 3350 20 , ~--r-2042270 I .. I I , I ¡TypeTest : SPT i Test psi 1500 OA I 180 I 470 310 250 I I i- I ...- Tubing I 760 760 i 760 760 Interval 4YRTST P/F P I I .. Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy NON-CONFIDENTIAL Wednesday, June 07, 2006 Page I of I 02/21/06 Schlumberger NO. 3691 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '>-'~~,1,¡ j ~..;.. ,.."H~. "V¡III IH:>SIQl , ?J1ctx¡f¿¡ge Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 FEB 22 2006 Field: Kuparuk . Well Job # Log Description Date BL Color CD . 1B-17 ¡Q4-045" 11216283 SBHP SURVEY 02/18/06 1 1 E-36 /98-t2F3 11216282 SBHP SURVEY 02/18/06 1 3H-07 /B7- 07C/ 11217023 LDL 02/11/06 1 3H-07 ,I 1', 11166757 STATIC SURVEY 01/20/06 1 2A-09 ¡PJ~ b-rn! 11154126 PRODUCTION PROFILE 02/09/06 1 1A-10 ¡A/ - / ú;O 11213710 INJECTION PROFILE 02/08/06 1 2M-14 ¡q,.:; -nln; 11154127 INJECTION PROFILE 02/10/06 1 1E-05 /9/)-1. )5~ 11166747 PRODUCTION PROFILE W/DEFT 12/25/05 1 2H-12 /B5-~'W 11154128 PRODUCTION PROFILE WIDEFT 02/11/06 1 1 C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18 /qO-/ d5' 11154129 PRODUCTION PROFILE WIDEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 1B4-~~ 11166753 PRODUCTION PROFILE 01/14/06 1 1Y-09 ¡8.~-~ 11213128 INJECTION PROFILE 02/06/06 1 1 E·1 05 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 /'f!>3-oqs 11141255 INJECTION PROFILE 01/28/06 1 2C-02 /R7¡- n9!3 11213129 INJECTION PROFILE 02/07/06 1 1 C-25 ¡ qq -C>3/ 11144074 GLS 02/02/06 1 2C-14 /84 - 0 ?tD 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 /B.-f-:' 'It 11144067 PRODUCTION PROFILE 01/26/06 1 1A-18/90-J!j ;3 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 18~-()8? 11213709 INJECTION PROFILE 02/07/06 1 1 D-32 Q()()-J 73 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 /8< -Xto 11141260 PRODUCTION PROFILE 02/02106 1 2C-15 184· ~6~ 11141254 PRODUCTION PROFILE 01/27/06 1 1 J -154 N/A PRODUCTION LOG W/TRACTOR 02/05/06 1 1E-104Ilcll-;;dl 11217024 INJECTION PROFILE 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to'(907) 561-8317. Thank you. .~~ . . WELL LOG TRANSMITTAL Vie J04- ';);)Î To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'11 Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 ) 37($) RE: MWD Formation Evaluation Logs lE-104, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Speny Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 lE-104: LAS Data & Digital Log Images: 50-029-23234-00 1 CD Rom ä~ ~ fjrl00 MEMORANDUM TO: Jim Regg 'J P.I. Supervisor f...~f . Z( ztrjo S' State of Alaska Alaska Oil and Gas Conservation commiss. DATE: Wednesday, February 09, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPIllLLIPS ALASKA INC 1E-104 1 KUPARUK RIV U WSAK 1E-104 ')J) l{ ./ ?- ~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ..::15i2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 1E-104 API Well Number: 50-029-23234-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050203163523 Permit Number: 204-227-0 Inspection Date: 2/3/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 1E-104 IType Inj. I P TVD I 3350 I IA I 800 ¡ 1830 I 1780 I 1780 i i I P.T. I 2042270 !TypeTest I SPT' Test psi I 837.5 i OA I 190 I 250 ! 190 ! 190 I Interval INITAL P/F P Tubing I 1120 i 1120 i 1120 I 1120 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity - .." ~~. Wednesday, February 09, 2005 Page 1 of 1 . . 2e't- 22.7 W 1 L q[1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 15,2004 RE: MWD Formation Evaluation Logs lE-104, AK-MW -3410594 1 LDWG formatted Disc with verification listing. API#: 50-029-23234-00 , \,ú.tfe J)~J\1'\ ~~--,':'::': PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMIITAL LEITER TO THE AITENTION OF: Sperry -Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:# Sign~~ . Conoc~illips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-6830 January 18, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 E-1 04 (APD# 204-227) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk weIl1E-104. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, '-"""..-'--:::" ". \ '---~'~...t\' ('\;<.o,:"A~___ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad C)RIGINAL RECEIVED - STATE OF ALASKA. JAN 2 1 200"" Al~ Oil AND GAS CONSERVATION CO SION ..A. j WELL COMPLETION OR RECOMPLETION REPORilSItUtDJl.OO, Commission 1 a. Well Status: Oil D Gas U WDSPL D GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: WINJ 0 Plugged D Abandoned D 20AAC 25.105 No. of Completions _ Suspended U 20AAC 25.110 Other WAGD - 1332' FNL, 2165' FEL, Sec. 15, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300 y- TPI: x- 553471 y- Total Depth: x- 553608 I y- 18. Directional Survey: Yes 0 NoU 5960021 5962530 5963561 " 5. Date Camp., Susp., or Aband.: December 5, 2004 6. Date Spudded: November 27, 2004 ' 7. Date TO Reached: December 2, 2004 ' 8. KB Elevation (ft): 28' RKB 9. Plug Back Depth (MD + TVD): 6825' MD / 3929' TVD 10. Total Depth (MD + TVD): ,/ ~. 6935' MD / 3984' TVD P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 431' FSL, 224' FEL, Sec. 16, T11N, R10E, UM At Top Productive Horizon: 2361' FNL, 2311' FEL, Sec. 15, T11N, R10E, UM Total Depth: 21. Logs Run: GRlRes, CBL 22. CASING SIZE WT. PER FT. 62.5# 29.7# 15.5# 9.3# GRADE H-40 L-80 L-80 L-80 20" 7.625" 5.5" 3.5" Zone- 4 Zone- 4 11. Depth where SSSV set: Landing Nipple @ 505' 19. Water Depth, if Offshore: N/A Zone- 4 feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 163' 28' 163' 28' 3635' 28' 2440' 28' 5553' 28' 3346' 5553' 6920' 3346' 3977' HOLE SIZE 9.875" 6.75" 6.75" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): , 5760'-5860' MD , 5927'-5995' MD , 6278'-6395' MD 3438'-3480' TVD 3509'-3540' TVD 3672'-3726' TVD 26. Date First Injection January 13, 2005 Date of Test Hours Tested n/a Flow Tubing Casing Pressure 27. 24. SIZE 3.5" 6 spf 6spf 6 spf 1 b. Well Class: Arn:harage Development D Exploratory D Service 0 Stratigraphic TesD 12. Permit to Drill Number: / 204-227 I 13. API Number: 50-029-23234-00 14. Well Name and Number: 1E-104 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25651 17. Land Use Permit: ALK 469 20. Thickness of Permafrost: 1694' MD AMOUNT CEMENTING RECORD PULLED 30" 290 bbls AS I 365 sx AS Lite, 127 sx DeepCrete 240 sx DeepCrete 3.5" x 5.5" tapered casing TUBING RECORD DEPTH SET (MD) 5582' PACKER SET none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> Water Injector WATER-BBL GAS-MCF GAS-MCF WATER-BBL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate Sheet, if necessary). Submit care chips; if none, state "none". Form 1 0-407 Revised 12/2003 NONE RBDMS BFL JAN 2 1 2005 a~t~ 1i'1vAsl CHOKE SIZE GAS-OIL RATIO OIL GRAVITY - API (carr) not available ri5;¡'::iZ:.~T5?{r t r£;:::}'~ði : i \¡o",.,. .."", .1.. j W¡;;'j'''.:::J' .f~-'" '.'. . ~ --" '"'. '\i..i....'....,.~"~~;:; Gf 28. 29. GEOLOGIC MARKER FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-1 04 West Sak A Wes Sak Base 5760' 6723' 3438' 3880' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Signature Kuparuk Drillina Team Leader 2..G. S' r)í?:;; {;) Date ( /;;:'-;/DJ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-104 1E-104 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 11/26/2004 12/5/2004 Spud Date: 11/26/2004 End: 12/5/2004 Group: 11/26/2004 18:00 - 19:00 1.00 MOVE DMOB MOVE Blow down lines and disconnect service loops, moved out pipe shed 19:00 - 20:30 1.50 MOVE MOVE MOVE Moved sub base off 1 E-168 and moved sub base and rig's complex's to 1E-104 (.25 miles) 20:30 - 00:00 3.50 MOVE POSN MOVE Spotted sub base over well and spotted pump, motor and boiler complex's 11/27/2004 00:00 - 01 :45 1.75 MOVE POSN MOVE Finished moving and spotting rock washer and pipe shed 01 :45 - 04:30 2.75 MOVE RURD MOVE Connected service loops to rig complex's, air, water and steam, bermed around rig and rock washer, completed rig acceptance check list and ACCEPTED RIG at 04:30 Hrs 11/27/04 04:30 - 07:30 3.00 WELCTL NUND SURFAC NU 21 1/4" 2M diverter and 16" line, began mixing spud mud and loading 4" DP into pipe shed 07:30 - 09:30 2.00 RIGMNT RSRV SURFAC Changed out 4" XT-39 saver sub on top drive, serviced top drive, pipe grabbers and blocks 09:30 -15:15 5.75 DRILL PULD SURFAC PU and stood back 31 stds of 4" XT-39 DP and 11 stds of 4" HWDP and jars 15:15 -17:00 1.75 DRILL PULD SURFAC PU and stood back 1 std of 6 3/4" NM Flex Dc's, MU 9 7/8" Bit #1 on Sperry Suns 7" motor with 1.5 deg bend, float sub and stab, tagged ice in conductor at 33' 17:00 - 17:45 0.75 WELCTL BOPE SURFAC Function tested diverter and performed accumulator test, Note: Jeff Jones with AOGCC waived witnessing of test 17:45 - 18:00 0.25 DRILL CIRC SURFAC Est circ filling conductor and lines checking for leaks and ck ok 18:00 - 19:45 1.75 DRILL CIRC SURFAC Cleaned out ice and fill inside of conductor from 33' to 163', 340 gpm, 450 psi, 50 rpm's and 2-4K wob 19:45-21:30 1.75 DRILL DRLG SURFAC Spud well and drill 9 7/8" hole from 163' to 212' (49'), ART .5 hrs, 2-4K wob, 50 rpm's, 380 gpm, 550 psi, rot wt 42, up wt 37K, dn wt 44K 21 :30 - 22:00 0.50 DRILL TRIP SURFAC POOH to 35' standing back 2 stds of 4" HWDP 22:00 - 23:30 1.50 DRILL PULD SURFAC MU 9 7/8" BHA #1, MWD W/directional only with UBHO sub and oriented MWD 23:30 - 00:00 0.50 DRILL RIRD SURFAC RU HES Slickline to run Gyro 11/28/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill, slide and survey 9 7/8" hole per directional plan from 212' to 1,245' MD/1, 185' TVD (1,033'), ART 1.9 hrs, AST 3.8 hrs, 1 0-20K wob, 50-60 rpm's, 110 spm, 465 gpm, off btm pressure 1,450 psi, on btm 1,650 psi, off btm torque 1.5K ft-Ibs, on btm 3.5K ft-Ibs, rot wt 67K, up wt 67K, dn wt 67K, 9.0 ppg MW with 210 vis. Ran 6 gyro survey's, @ 81', 172', 258',349',440' and 531' 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill, slide and survey 9 7/8" hole per directional plan from 1,245' to 2,750' MD/2,033' TVD, (1,505') ART 5.1 hrs, AST 2,9 hrs, 5-25K wob, 70 rpm's, 130 spm, 550 gpm, off btm pressure 2,350 psi, on btm 2,525 psi, off btm torque 3K ft-Ibs, on btm 4K ft-Ibs, rot wt 72K, up wt 82K, dn wt 65K, 9.1 + ppg MW, 225 vis, no gas hydrates and phase 2 weather condition in effect 11/29/2004 00:00 - 06:45 6.75 DRILL DRLG SURFAC Drill, slide and survey 97/8" hole per directional plan from 2,750' to 3,640 MD/ 2,441' TVD, (Csg pt) (890') ART 2.8 hrs, AST ,5 hrs, 5-25K wob, 70-80 rpm's, 550-580 gpm, (80 rpm's and 580 gpm at TO) off btm pressure 3,000 psi, on btm 3,100 psi, off btm torque 4K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 76K, up wt 100K, dn wt 60K, 9.2+ ppg MW, 150 vis, no gas hydrates on surface hole 06:45 - 07:00 0.25 DRILL CIRC SURFAC Circ hole to clear BHA and monitored well-static 07:00 - 10:30 3.50 DRILL REAM SURFAC Backreamed out of hole from 3,640' to BHA at 1,165', backreamed out at 80 rpm's and 550 gpm, initial circ pressure 2,900 psi, final pressure 2,000 psi, no problems backreaming out 10:30 - 12:30 2.00 DRILL PULD SURFAC POOH LD ghost reamer and stood back 10 stds HWDP and LD jars and 2 jts HWDP Printed: 1/12/2005 9:59:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-104 1E-104 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 11/26/2004 12/5/2004 Spud Date: 11/26/2004 End: 12/5/2004 Group: 11/29/2004 12:30 - 14:45 14:45 - 15:45 15:45 - 16:00 16:00 - 21 :15 2.25 DRILL 1.00 CASE 0.25 CASE 5.25 CASE PULD SURFAC RURD SURFAC SFTY SURFAC RUNC SURFAC 21 :15 - 22:45 1.50 CEMEN SURFAC 22:45 - 23:15 0.50 CEMEN SURFAC 23:15 - 00:00 0.75 CEMEN SURFAC 11130/2004 00:00 - 00:45 0.75 CEMEN SURFAC 00:45 - 02:15 1.50 CEMEN PUMP SURFAC 02:15 - 03:00 0.75 CEMEN DISP SURFAC 03:00 - 03:45 0.75 CASE DEaT SURFAC 03:45 - 04:30 0.75 CEMEN RURD SURFAC 04:30 - 07:00 2.50 WELCTL NUND SURFAC 07:00 - 08:15 1.25 WELCTL NUND SURFAC 08: 15 - 11:00 2.75 WELCTL NUND SURFAC 11 :00 - 11 :30 0.50 CASE RURD SURFAC 11 : 30 - 18:00 6.50 WELCTL BOPE SURFAC 18:00 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 00:00 0,50 DRILL 0.50 DRILL 1.00 DRILL 4.00 DRILL OTHR SURFAC PULD SURFAC PULD SURFAC PULD SURFAC LD BHA #1, NM Flex Dc's, MWD and motor, cleared rig floor RU Doyon's 7 5/8" csg equipment with Franks fill up tool Held PJSM on running of 7 5/8" csg MU 75/8" float shoe, 2 jts 7 5/8",29.7#, L-80 BTCM csg and fit collar, thread locked conn below FC and circ thru shoe track, cont RIH with 7 5/8" csg, MU hanger and landed csg with float shoe at 3,635' and float collar at 3,545', no problems RIH, Ran a total of 83 jts (3,599') of 29.7#, L-80, BTCM csg, total including float equip, csg and hanger, 3,605', ran 15 bow spring centralizers and 1 stop ring per well plan, st wt up 147K, dn wt 77K Circ and cond mud thru Franks fill up tool, staged pump rate up to 6 bpm at 325 psi, circ 1.5X btms up, st wt up 135K, dn wt 74K RD Franks fill up tool, blow down top drive and MU Dowell cement head Cont to circ and cond mud for cementing, circ at 6 bpm, 325 psi, st wt up 135K, dn wt 75K Fin circ and conditioning mud for cementing, circ at 6 bpm at 325 psi, st wt up 135K, dn wt 75K, conditioned mud from 9.25 ppg, 65 vis, 36 PV and 46 YP to 9.05 ppg, 41 vis, 13 PV and 9 YP, held PJSM with rig crew, Dowell and APe vac truck drivers on cementing csg while circ hole Turned over to Dowell and cemented 75/8" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 30 bbls of 10.8 ppg mudpush, dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 290 bbls (365 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 5.5 bpm at 110 psi, followed with 56 bbls (127 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.48 yield with add., ave 5.5 bpm at 160 psi, reciprocated csg and had full returns, shut down and dropped top plug Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 143 bbls of 9.05 ppg mud, displaced cmt at 7 bpm, initial circ pressure 500 psi, max pressure 750 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1,250 psi, checked floats and held, CIP @ 02:50 hrs, had full returns during job and had 43 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:30 hrs, 38 bbls into displacement, approx 250 bbls lead cement out of shoe with traces of dye back to surface Tested 75/8" csg to 3,000 psi for 30 min, RD cement head and LD landing jt ND 21 1/4" 2M diverter, 16" line and starting head, used crane to set out then set in wellhead equipment Orient and NU Vetco Gray 13 5/8" 5M MB 222 wellhead, tested btm wellhead sub to 5,000 psi for 10 min NU BOP stack Cleared rig floor of 7 518" csg equipment RU and tested BOPE, tested rams, valves and manifold to 250 psi low and 3,500 psi high, annular to 250 psi and 2,800 psi, tested VBR's with csg and tbg test jts for completion of well, Note: Jeff Jones W/AOGCC witnessed test Installed wear bushing PU 6 3/4" BHA #2 tools to rig floor PU and RIH with 24 jts of 4" XT-39 DP, POOH and stood back same MU BHA #2 and RIH to 374', MU bit #2, 5" motor with 1.22 deg bend, Printed: 1/12/2005 9:59:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-104 1E-104 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 11/26/2004 12/5/2004 Spud Date: End: Group: 11/26/2004 12/5/2004 11/30/2004 20:00 - 00:00 4.00 DRILL PULD SURFAC MWD and triple combo logging tools, oriented MWD and loaded radioactive sources, PU 3-4 3/4" NM Flex Dc's, xo and 2 stds of 4" HWDP and jars, RIH to 374' 12/1/2004 00:00 - 00:30 0.50 DRILL TRIP SURFAC RIH with BHA#2 on 4" HWDP from 374' to 1,101' 00:30 - 03:15 2.75 DRILL TRIP SURFAC RIH f/1, 101' to 3,437' PU 4" XT-39 DP from pipe shed, then RIH from derrick and tagged float collar at 3,545' 03:15 - 06:15 3,00 CEMEN DSHO SURFAC Drilled out plugs, float collar at 3,545", shoe track, float shoe at 3,635' and cleaned out to btm at 3,640', drilled 20' of new formation to 3,660' MD/2,451' TVD, 5-10K wob, 50 rpms, 220 gpm at 1,250 psi, rot wt 75K, up wt 95K, dn wt 60K ADT .1 hrs 06:15 - 07:00 0.75 DRILL CIRC SURFAC Displaced out 9.0 ppg spud mud in hole over to 9.0 ppg reconditioned LSND mud, circ at 253 gpm, 1,450 psi and 70 rpm's, PU into csg 07:00 - 07:45 0.75 DRILL LOT SURFAC RU and performed LOTto 15.7 ppg EMW, 584 psi, 9,0 ppg mud at 2,441 ' TVD 07:45 - 12:00 4.25 DRILL DRLG PROD Drilled 6 3/4" hole per directional plan from 3,660' to 4,275' MD/2,733' TVD, (615') ART 1.6 hrs, AST 1.1 hrs, 1-5K wOb, 90 rpm's, 71 spm, 300 gpm, off btm pressure 2,000 psi, on btm 2,100 psi, off btm torque 3K ft-Ibs, on btm 3K ft-Ibs, rot wt 76K, up wt 84K, dn wt 70K, 9.0 ppg MW, 60 vis with 2% lubricants in mud 12:00 - 00:00 12.00 DRILL DRLG PROD Drilled 6 3/4" hole per directional plan from 4,275' to 5,480' MD/ 3,380' TVD, (1,205') ART 4.8 hrs, AST 2.6 hrs, 2-12K wob, 100 rpm's, 71 spm, 300 gpm, off btm pressure 2,350 psi, on btm 2,500 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 102K, dn wt 75K, 9.0 ppg MW, 81 vis, pumped weighted hi vis sweep at 5,426' and had 10% increase in cuttings back from sweep, MI Swaco's ECD Snapshot W/9.0 ppg mud, clean hole ECD = 11.0 ppg, Drlg W/Cuttings was 11.3, ave BGG 20 units, max gas 150 units 12/2/2004 00:00 - 14:30 14.50 DRILL DRLG PROD Drilled 6 3/4" hole per directional plan from 5,480' to 6,890' MD/3,962' TVD, (1,410') ART 5.1 hrs, AST 2.9 hrs, 2-15K wob, 100 rpm's, 71 spm, 300 gpm, off btm pressure 2,750 psi, on btm 2,900 psi, off btm torque 5.5K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 94K, up wt 117K, dn wt 79K, 9,05 ppg MW, 76 vis, pumped weighted hi vis sweep at 6,800' and had 10% increase in cuttings back from sweep, after drlg below top of West Sak "D" at 5,760' MD/3,431' TVD, ave BGG 100 units, max gas 700 units 14:30 - 15:00 0.50 DRILL CIRC PROD Circ hole evaluating logs for T.D. 15:00 - 15:30 0.50 DRILL DRLG PROD Drilled from 6,890' to 6,935' MD/ 3,984' TVD (T.D.) (45') ART .2 hrs 15:30 - 16:00 0.50 DRILL CIRC PROD Circ btms up at 6,935', circ at 300 gpm, 2,700 psi, 100 rpm's and 5K ft-Ibs torque, monitored well-static 16:00 - 20:30 4.50 DRILL REAM PROD Backreamed out of hole from 6,935' to 3,624' (7 5/8" csg shoe @ 3,635'), backreamed out at 300 gpm, 2,600 psi, 100 rpm's with no problems 20:30 - 21 :30 1.00 DRILL CIRC PROD Pumped weighted hi vis sweep and circ out, had no increase in cuttings back from sweep, circ an add. btms up and clean at shakers, circ at 300 gpm, 2,100 psi and 100 rpm's 21 :30 - 21 :45 0.25 DRILL OBSV PROD Monitored well-static 21 :45 - 00:00 2.25 DRILL PULD PROD POOH and LD 18 jts of 4" DP and hole was taking calc fill, pumped dry job and cont POOH LD an add. 30 jts of 4" DP to 2,130' 12/3/2004 00:00 - 00:45 0.75 DRILL PULD PROD Fin POOH from 2,130' LD 4" DP and 10 stds of 4" HWDP and Jars to directional BHA #2 at 190' 00:45 - 04:30 3.75 DRILL PULD PROD LD NM Flex Dc's, pulled radioactive sources and downloaded MWD, LD BHA #2 04:30 - 04:45 0.25 DRILL PULD CMPLTN Pulled wear bushing 04:45 - 05:15 0.50 CASE RURD CMPL TN RU Doyon's 31/2" handling tools Printed: 1112/2005 9:59:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/3/2004 05: 15 - 05:30 05:30 - 08:30 08:30 - 09:30 1 E-1 04 1 E-1 04 ROT - DRILLING n1334@ppco.com Doyon 141 Hours Start: Rig Release: Rig Number: Spud Date: 11/26/2004 End: 12/5/2004 Group: 11/26/2004 12/5/2004 0.25 CASE 3.00 CASE SFTY CMPL TN RUNC CMPL TN 1.00 CASE RURD CMPL TN 09:30 - 10:30 1.00 RIGMNT RGRP CMPL TN 10:30 - 10:45 0.25 CASE CIRC CMPL TN 10:45 - 13:30 2.75 CASE RUNC CMPL TN 13:30 - 14:00 0.50 CASE CIRC CMPL TN 14:00 - 14:30 0.50 RIGMNT RGRP CMPL TN 14:30 - 17:45 17:45 - 18:00 18:00 - 22:00 22:00 - 23:00 23:00 - 00:00 12/4/2004 00:00 - 00:45 00:45 - 02:45 3.25 CASE RUNe CMPL TN 0.25 CEMEN RURD CMPL TN 4.00 CEMEN CIRC CMPL TN 1.00 CEMEN PUMP CMPL TN 1.00 CEMEN DISP CMPL TN 0.75 CASE 2.00 CASE DEaT CMPL TN RURD CMPL TN Held PJSM on running of 3 1/2" x 5 1/2" csg RIH with 3 1/2", 9.3#, L-80, EUE 8rd mod csg to 1,325', MU 31/2" float shoe, 2 jts 3 1/2" csg, float collar and 1 jt of 31/2" csg with plug catcher, circ thru shoe track and ck ok, cont RIH with 3 1/2" to 1,325', ran a total of 42 jts 3 1/2" csg with 1 bow spring centralizer per jt, floating, ran 3- 2.813" X nipples per well plan, st wt up 44K, dn wt 43K RD 3 1/2" handling tools and RU 5 1/2" csg equipment, attempted to rig up Franks fill up tool, but would not line up to 51/2" csg, decided to fill pipe with 2" hose Installed stabbing board extension Circ thru 3 1/2" csg at 4 bpm at 250 psi MU XO assembly with seal bore extension and RIH with 54 jts of 5 1/2" 15.5#, L-80, BTCM csg to 3,625', ran 32 bow spring centralizers per well plan, top centralizer at 4,000' Circ a csg cap at 3,625', (Csg Shoe), circ at 2.5 bpm at 500 psi, st wt up 62K, dn wt 52K Attempted to realign top drive for Franks fill up tool with no succes, to cont RIH filling Pipe with 2" hose NOTE: While re-Ieveling rig and attempting to align top drive, 16" riser PU out of air boot causing 1 bbl of water base mud to spill in cellar, spill was contained in secondary containment and cleaned up immediatly, no mud got onto the ground. Cont to RIH with 5 1/2" csg, MU csg hanger and landed 5 1/2" x 3 1/2" csg at 6,920' with plug catcher at 6,825' and XO coupling at 5,563', ran a total of 42 jts 3 1/2" csg and 132 jts of 5 1/2" csg, total including hanger 6,892', lost approx 40 bbls of mud while RIH with csg, no other problems RIH, st wt up 105K, dn wt 60K MU Dowell cement head Circ and cond mud for cementing at 6,920', est circ at 2 bpm at 800 psi with only 50% returns, after circ btms up began to have full returns, circ btms up at 3 bpm at 675 psi with full returns, shut down 10 min and monitored well, gained 1,5 bbls mud back and was slowing down, circ an add btms up at 4 bpm at 650 psi with no losses, st wt up 100k, dn wt 64K, conditioned mud to 9.0 ppg mw, 47 vis, PV 15, YP 16, lost 184 bbls mud while circ 1st btms up, held PJSM with rig crew, Dowell and APC vac truck drivers while circ Dowell cemented 51/2" x 31/2" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 20 bbls of CW 100 (30 bbls total), then pumped 30 bbls of 10.5 ppg mud push, mixed and pumped 96 bbls, 240 sxs of DeepCrete tail cmt at 12.5 ppg and 2.26 yield with additives, ave 4 bpm at 200 psi, reciprocated csg and had full returns, shut down, washed up lines to rig floor and dropped dual plugs Rig displaced cement with 143 bbls to 9.0 brine with 3% KCL, displaced cmt at 4 bpm, initial pressure 300 psi, max pressure 1,125 psi, slowed to 1.5 bpm prior to XO coupling, at 1,5 bpm, pressure ave 850 psi, reciprocated pipe till 23:30 hrs with 48 bbls of cmt out of shoe, saw plugs hit XO and X nipples, bumped plugs on calc displacement to 1,600 psi, checked floats and held, CIP at 23:50 hrs, showed good flow percentage during displacement but checked volumes at end of job and had pumped 143 bbls only getting 110 bbls back, planned TOC 3,975'. RU & tested 5 1/2" x 31/2" csg to 3,000 psi for 30 min, good test RD cement head, LD landing jt and RD 51/2" csg equipment, changed Printed: 1/12/2005 9:59:23 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-104 1E-104 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 11/26/2004 12/5/2004 Spud Date: 11/26/2004 End: 12/5/2004 Group: 2.00 CASE RURD CMPL TN out elevator bales 0.75 WELCTL EaRP CMPL TN Installed 5 1/2" csg pack-off and tested to 5,000 for 10 min 0.50 CMPL TN RURD CMPL TN RU to run 3 1/2" completion and held PJSM with crew 5.75 CMPL TN RUNT CMPL TN RIH with 3 1/2" completion to 5,550', MU 4" seal assembly and GBH-22 locator assembly, 3 1/2" x 1" Camco KBG 2-9' gas lift mandrel with DCK-3 shear valve with pup jts above and below and RIH with 3 1/2", 9.3#, L-80, EUE 8rd Mod tbg, RIH with 176 jts and 2.813" "OS" nipple to 5,550', st wt up 70K, dn wt 52K NOTE: RU on 5 1/2" x 7 5/8" annulus and flushed with 40 bbls fresh water, at 1 bpm, pressured up to 1,850 psi and broke back to 800 psi, ave 1 bpm at 800 psi Est circ and stung into seal bore receptacle at 5,568', tagged no-go at 5,584', PU out of seals to 5,560' Circ hole with 9.0 ppg brine with 3% KCL and spotted corrosion inhibitor in annulus, círc at 5 bpm at 1,350 psi Spaced out 31/2" tbg, MU hanger and landed tbg, RILDS, tested seals to 5,000 psi for 10 min, landed tbg with 2.813" "DS" @ 505', GLM WIDCK shear valve at 5,542' and GBH-22 Seal Locator assembly at 5,564' and end of seal assembly at 5,582' with locator sub spaced out 2.44' above fully located, st wt 70K, dn wt 52K NOTE: Pumped an additional 50 bbls (90 total) water down 5 1/2" x 7 5/8", initial rate 1 bpm at 800 psi, final rate 1.8 bpm at 800 psi 1.25 CMPL TN DEaT CMPLTN RU and tested 31/2" tbg to 1,800 psi for 15 min, then tested annulus to 3,000 psi for 30 min, good test, bled off and sheared DCK valve at 2,300 psi 0.75 CMPL TN RURD CMPL TN LD 3 1/2" landing jt and installed 2-way ck (TWC) 1,75 WELCTL NUND CMPL TN NO BOPE RU little Red on 51/2" x 7 5/8" annulus and freeze protected with 45 bbls diesel (2500' MD, 11900' TVD), pumped at 1 bpm at 850 psi 2.00 WELCTL NUND CMPL TN NU Vetco Gray tree and tested to 5,000 psi, pulled TWC 0.50 DRILL RIRD CMPL TN Cleared rig floor of 31/2" handling tools 2,00 DRILL PULD CMPL TN RU and LD 96 jts of 4" DP from derrick in mouse hole, RU Little Red and freeze protected well with 55 bbls diesel, put tbg and annulus in communication to U-tube to a final depth of 2500' MD 11900' TVD. NOTE: While LD DP Flmousehole floor hand was struck in the hard hat by a joint of 4" dp forcing his safety glasses into the brow portion of his right eye causing a small cut, first aid was given at the rig and hand went to KOC medic, hand received 4 stitch's and was released to return to work with no restrictions Shut down operations and discussed incident with rig crew and the hazards involved with LD DP from mousehole Fin LD 15 jts of 4" DP from derrick, RD mousehole Removed elevator bales and elevators preparing to change out saver sub Changed out saver sub, grabbers and bell guide on top drive over to 5" DP, unhooked U-tube hose on tree after freeze protecting well and drained lines and cleaned out cellar Slip & Cut 71' of Drlg Line and serviced top drive Installed actuator valve on tree, RU scaffolding and installed BPV thru lubricator, RD lubricator and scaffolding, secured well and Released Rig @ 06:00 hrs to move to 1 E-102 12/4/2004 00:45 - 02:45 02:45 - 03:30 03:30 - 04:00 04:00 - 09:45 09:45 - 10:15 0.50 CMPL TN CIRC CMPLTN 10:15 - 12:00 1.75 CMPLTN CIRC CMPLTN 12:00 - 13:45 1.75 CMPLTN SOHO CMPLTN 13:45 - 15:00 15:00 - 15:45 15:45 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 22:00 22:00 - 22:30 0.50 DRILL SFTY CMPL TN 22:30 - 23:30 1.00 DRILL PULD CMPL TN 23:30 - 00:00 0.50 RIGMNT RSRV CMPL TN 12/5/2004 00:00 - 03:00 3.00 DRILL RIRD CMPL TN 03:00 - 05:00 2.00 RIGMNT RSRV CMPL TN 05:00 - 06:00 1.00 WELCTL EaRP CMPL TN Printed: 1/12/2005 9:59:23 AM · 1E-104 Well Events Summary . Date Summary 12/29/04 LOG CEMENT BOND LOG FROM 6540' TO 5400' -- CEMENT QUALITY WAS VERY GOOD FROM 6840' TO 5574' -- DID NOT TAG 12/30/04 PERFORATED 6335' TO 6395',21/2" HSD 6 SPF POWERJET -- MEAS SBHP AFTER SHOOTING 1ST GUN, 6375'-6395': SBHP AT 6385'= 1559.7 PSIA, TEMP= 79.8 DEGF & SBHP AT 6146'= 1507.3 PSIA, TEMP= 73.1 DEGF [Perf] 12/31/04 PERFORATED 6278' - 6335' & 5975' - 5995',6 SPF POWERJET v' [Perf] 01/01/05 PERFORATED: 5927' - 5975' & 5840' - 5860',6 SPF POWERJET .; [Perf] 01/02/05 PERFORATED: 5760' - 5840' WITH 21/2" HSD 6 SPF POWERJET ' [Perf] /I . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 1 E-1 04 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 6,935.00' MD (if applicable) 03-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date À-ì ,J f~'h ~'i J Signed ~J Ow , Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ,Âfjy,-)).. 7 Halliburton Sperry-Sun Western North Slope ConocoPhillips 1E-104 . Surveyed: 29 November, 2004 Survey Report 12 January, 2005 Your Ref: API 500292323400 Surface Coordinates: 5960020.71 N, 550300.35 E (70018' 05.5565" N, 149035'33.3281" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ . Surface Coordinates relative to Structure: 257.71 N, 412.57 E (True) Kelly Bushing Elevation: 94. 10ft above Mean Sea Level Kelly Bushing Elevation: 94. 10ft above Structure spe""""y-sul'"1 DRILLING seRVices A Halliburton Company Survey Ref: svy2088 Halliburton Sperry-Sun Survey Report for 1E-104 Your Ref: API 500292323400 Surveyed: 29 November, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -94.10 0.00 0.00 N 0.00 E 5960020.71 N 550300.35 E 0.00 81.00 1.250 265.000 -13.11 80.99 0.08S 0.88W 5960020.63 N 550299.47 E 1.543 -0.66 172.00 2.000 275.000 77.86 171.96 0.03 S 3.45 W 5960020.66 N 550296.90 E 0.878 -2.41 . 258.00 1.550 319.000 163.82 257.92 0.98N 5.71 W 5960021.66 N 550294.63 E 1.620 -3.24 349.00 3.400 29.000 254.75 348.85 4.27 N 5.21 W 5960024.95 N 550295.11 E 3.536 -0.52 440.00 8.250 48.000 345.26 439.36 11.01 N 0.96E 5960031.72 N 550301.23 E 5.664 8.61 531.00 14.500 49.000 434.42 528.52 22.86 N 14.42 E 5960043.67 N 550314.62 E 6.871 26.48 640.25 14.880 55.490 540.11 634.21 39.78 N 36.30 E 5960060.73 N 550336.38 E 1.545 53.84 739.75 17.690 63.050 635.62 729.72 53.88 N 60.31 E 5960074.99 N 550360.30 E 3.532 80.63 831.80 20.590 67.070 722.58 816.68 66.52 N 87.69 E 5960087.82 N 550387.60 E 3.459 108.71 924.54 21.860 64.360 809.02 903.12 80.35 N 118.28 E 5960101.85 N 550418.09 E 1.730 139.85 1015.77 24.600 66.050 892.85 986.95 95.41 N 150.95 E 5960117.13 N 550450.66 E 3.091 173.34 1106.46 28.090 64.000 974.11 1068.21 112.44 N 187.40 E 5960134.40 N 550487.00 E 3.976 210.85 1212.12 35.040 64.080 1064.08 1158.18 136.63 N 237.10 E 5960158.93 N 550536.53 E 6.578 262.71 1305.49 37.690 62.550 1139.27 1233.37 161.51 N 286.55 E 5960184.13 N 550585.81 E 3.000 314.89 1398.99 39.710 61.490 1212.23 1306.33 188.95 N 338.17 E 5960211.92 N 550637.25 E 2.274 370.41 1492.26 44.280 61.710 1281.53 1375.63 218.61 N 393.05 E 5960241.95 N 550691.93 E 4.902 429.81 1585.72 47.350 59.280 1346.67 1440.77 251.64 N 451.34 E 5960275.37 N 550750.00 E 3.777 493.99 1679.13 48.150 59.560 1409.48 1503.58 286,82 N 510.87 E 5960310.94 N 550809.29 E 0.885 560.58 1772.62 51.460 58.090 1469.81 1563.91 323.80 N 571.95 E 5960348.33 N 550870.12 E 3.738 629.54 1866.11 58.370 59.480 1523.51 1617.61 363.39 N 637.35 E 5960388.36 N 550935.26 E 7.490 703,38 . 1959.29 60.700 60.230 1570.75 1664.85 403.71 N 706.80 E 5960429.14 N 551004.44 E 2.595 780.55 2052.82 60.720 59.650 1616.51 1710.61 444.57 N 777.41 E 5960470.48 N 551074.76 E 0.541 858.91 2146.11 59.920 59.120 1662.70 1756.80 485.85 N 847.16 E 5960512.22 N 551144.24 E 0.989 936.97 2240.04 60.710 61.040 1709.22 1803.32 526.54 N 917.88 E 5960553.38 N 551214.69 E 1.965 1015.29 2333.10 61.730 60.400 1754.03 1848,13 566.43 N 989.02 E 5960593.75 N 551285.56 E 1.251 1093.32 2426.53 63.760 60.890 1796.81 1890.91 607.15 N 1061.41 E 5960634.95 N 551357.68 E 2.222 1172.80 2519.90 64.240 60.800 1837.74 1931.84 648.03 N 1134.70E 5960676.32 N 551430.69 E 0.521 1253.03 2613.38 63.990 59.770 1878.55 1972,65 689.72 N 1207.74 E 5960718.49 N 551503.45 E 1.027 1333.67 2706,91 63.580 59.320 1919.87 2013.97 732.25 N 1280.07 E 5960761.51 N 551575.49 E 0.615 1414.43 12 January, 2005 -10:17 Page2of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1 E-104 Your Ref: API 500292323400 Surveyed: 29 November, 2004 ConocoPhillips Alaska, Inc. ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 2800.30 63.920 59.020 1961.17 2055.27 775.17 N 1352.00 E 5960804.91 N 551647.13 E 0.464 1495.19 2893.74 63.370 58.910 2002.66 2096.76 818.34 N 1423.74 E 5960848.56 N 551718.58 E 0.598 1575.99 2987.20 62.690 58.740 2045.04 2139.14 861.46 N 1495.01 E 5960892.15 N 551789.56 E 0.745 1656.44 . 3080.64 62.940 58.520 2087.73 2181.83 904.72 N 1565.97 E 5960935.90 N 551860.23 E 0.340 1736.78 3174.12 62.130 58.560 2130.84 2224.94 948.01 N 1636.73 E 5960979.66 N 551930.69 E 0.867 1816.99 3267.56 61.560 59.580 2174.94 2269.04 990.36 N 1707.39 E 5961022.48 N 552001.07 E 1.139 1896.46 3361.01 63.370 61.040 2218.14 2312.24 1031.39 N 1779.38 E 5961063.99 N 552072.78 E 2.381 1975.90 3454.44 61.980 61.370 2261.02 2355.12 1071.37 N 1852.11 E 5961104.46 N 552145.25 E 1.520 2055.10 3547.99 62.180 61.480 2304.83 2398.93 1110.91 N 1924.71 E 5961144.48 N 552217.58 E 0.238 2133.87 3595.54 62.260 61.700 2326.99 2421.09 1130.92 N 1961.71 E 5961164.74 N 552254.44 E 0.443 2173.93 3654.49 60.910 61.970 2355,04 2449.14 1155.40 N 2007.42 E 5961189.52 N 552299.99 E 2.325 2223.23 3747.54 58.710 63.850 2401.83 2495.93 1192.03N 2079.01 E 5961226.63 N 552371.33 E 2.939 2299.21 3842.23 60.030 64.550 2450.08 2544.18 1227.49 N 2152.36 E 5961262.58 N 552444.45 E 1.532 2375.57 3937.43 67.180 60.470 2492.38 2586.48 1266.90 N 2227.89 E 5961302.50 N 552519.71 E 8.433 2456.29 4031.28 63.780 61.250 2531.33 2625.43 1308.48 N 2302.46 E 5961344.57 N 552594.00 E 3.701 2537.91 4122.94 63.390 61.220 2572.10 2666.20 1347.98 N 2374.42 E 5961384.56 N 552665.69 E 0.426 2616.22 4215.30 64.000 57.810 2613.04 2707.14 1389.98 N 2445.75 E 5961427.03 N 552736.74 E 3.375 2695.90 4303.25 65.230 53.750 2650.76 2744.86 1434.66 N 2511.42 E 5961472.16 N 552802.11 E 4.399 2773.61 4401.90 64.480 51.030 2692.68 2786.78 1489.15N 2582.16 E 5961527.11 N 552872.49 E 2.609 2861.89 4495.00 62.880 48.610 2733.97 2828.07 1542.98 N 2645.92 E 5961581.36 N 552935.88 E 2.895 2944.87 4587.39 63.170 44.670 2775.89 2869.99 1599.49 N 2705.76 E 5961638.28 N 552995.34 E 3.813 3027.08 . 4679.62 62.480 42.010 2818.02 2912.12 1659.16 N 2762.07 E 5961698.32 N 553051.25 E 2.673 3109.11 4774.42 61.360 40.600 2862.64 2956.74 1721.98 N 2817.28 E 5961761.51 N 553106.04 E 1.766 3192.67 4866.47 61,160 37.910 2906.91 3001.01 1784.47 N 2868.35 E 5961824.34 N 553156.69 E 2.571 3273.12 4955.34 61.490 35.730 2949.55 3043.65 1846.88 N 2915.07 E 5961887.06 N 553202.99 E 2.184 3350.51 5052.94 60.640 30.730 2996.80 3090.90 1918.29 N 2961.87 E 5961958.78 N 553249.31 E 4.567 3434.44 5136.81 59.650 28.250 3038.55 3132.65 1981.59 N 2997.68 E 5962022.32 N 553284.70 E 2.823 3504.92 5238.00 59.120 25.480 3090.09 3184.19 2059.26 N 3037.03 E 5962100,26 N 553323.53 E 2.413 3588.22 5331.32 59.100 22.840 3138.01 3232.11 2132.32 N 3069.80 E 5962173,53 N 553355.81 E 2.428 3663.64 5430.36 58.810 21.900 3189.08 3283.18 2210.79 N 3102.10E 5962252.22 N 553387.58 E 0.864 3742.63 12 January, 2005· 10:17 Page 3 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1E-104 Your Ref: API 500292323400 Surveyed: 29 November, 2004 ConocoPhillips Alaska, Inc. ConocoPhil/ips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5521.66 59.440 21.060 3235.94 3330.04 2283.71 N 3130.79 E 5962325.32 N 553415.78 E 1.049 3815.12 5612.60 63.840 16.820 3279.14 3373.24 2359.38 N 3156.69 E 5962401.16 N 553441.18 E 6.342 3887.67 5706.67 64.220 11.790 3320.35 3414.45 2441.29 N 3177.57 E 5962483.22 N 553461.51 E 4.824 3961.26 . 5802.08 64.800 11.770 3361.41 3455.51 2525.60 N 3195.15E 5962567.64 N 553478,53 E 0.608 4034.28 5895.90 64,530 9.630 3401.56 3495.66 2608.91 N 3210.90 E 5962651.06 N 553493.71 E 2.082 4105.32 5991.13 62,270 8.830 3444.20 3538.30 2692.95 N 3224.56 E 5962735.19 N 553506.81 E 2.489 4175.44 6084.32 61.760 9.370 3487.93 3582.03 2774.21 N 3237.58 E 5962816.53 N 553519.28 E 0.749 4243.11 6176.59 62.420 8.120 3531.12 3625.22 2854.80 N 3249.97 E 5962897.20 N 553531.14 E 1.395 4309.86 6271.12 62.210 8.210 3575.04 3669,14 2937.66 N 3261.86 E 5962980.14 N 553542.47 E 0.238 4377.90 6363.45 63.170 8.510 3617.40 3711.50 3018.82 N 3273.79 E 5963061.38 N 553553.85 E 1.079 4444.75 6456.11 62.560 7.680 3659.66 3753.76 3100.46 N 3285.40 E 5963143.10 N 553564.92 E 1.034 4511.72 6551.36 61.730 7.630 3704.17 3798.27 3183.92 N 3296.62 E 5963226.63 N 553575.58 E 0.873 4579.73 6644.16 61.780 5.970 3748.09 3842.19 3265.09 N 3306.30 E 5963307.87 N 553584.71 E 1,577 4645.02 6736.76 61.290 6.100 3792.22 3886.32 3346.05 N 3314.86 E 5963388.87 N 553592.73 E 0.543 4709.39 6829.12 60.380 5.400 3837.23 3931.33 3426.29 N 3322.94 E 5963469.17 N 553600.28 E 1.187 4772.90 .t 6872.64 60.040 5.360 3858.85 3952.95 3463.89 N 3326.48 E 5963506.80 N 553603.57 E 0.785 4802.50 6935.00 60.040 5.360 3890.00 3984.10 ... 3517.68 N 3331.53 E 5963560.62 N 553608.25 E 0.000 4844.82 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. . The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 43.790° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6935.00ft, The Bottom Hole Displacement is 4844.91 ft., in the Direction of 43.443° (True). 12 January, 2005 - 10:17 Page4of4 DrillQuest 3.03.06.008 . /90· I~· 20 'I" ;10 I .. h4-. !8h- I ~o 4. ;2.0 (. . 1/19/05 Schlumberger NO. 3313 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description BL Color CD Date /1ø7 1A-25 10942816 PRODUCTION PROFILE/DEFT 12/25/04 1 Ðqí "'D-10 10942818 LDL & MUL TIFINGER CALIPER 12/27/04 1 of' 1E-112 10715441 MPSP PRODUCTION PROFILE 11/12/04 1 /!If 1C-119 10942819 INJECTION PROFILE 12/28/04 1 t2. "7 1 E-1 04 10942821 PERF RECORD WISBHP 12/30/04 1 ZC¡ 2T-12A 10922519 PRODUCTION PROFILEIDEFT 01/03/05 1 2-2..1 1 E-1 04 10942821 SCMT 12/29/04 1 2.) ( 1 E-1 02 10942815 USIT 12/24/04 1 ^ SIGNED, rl~l. Ù ~~~ -- DATE: /-(9- tJ5 .G1 U Please sIgn and return one copy of this transmIttal to Beth at the above address or fax to (907) 561-8317. Thank you. · . ~1r~1rŒ (ID~ ~~!Æ~~~ AI4ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-104 ConocoPhillips Alaska, Inc. Permit No: 204-227 Surface Location: 431' FSL, 224' FEL, SEe. 16, TIIN, RI0E, UM Bottomhole Location: 1322' FNL, 2137' FEL, SEe. 15, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to itness any required test. Contact the Commission's petroleum field inspector at 659- 0 ager). BY ORDER OF. :IHE COMMISSION DATED this)þ;ay of November, 2004 cc: Department ofFish & Game, Habitat Section WiD end Department of Environmental Conservation WiD encl. Conoc~hillips Alaska e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com Novemeber 5,2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1E-104 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore well. A conventional injection well is to be drilled through the West Sak sands. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-104 is November 26,2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader OR1GINAL " STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMIS::'ION PERMIT TO DRILL 20 AAC 25 005 ,ft ~\J Jl> !{ .<-'+ 1 a. Type of Work: Drill~ Redrill U 1 b. Current Well Class: ExploratoryU /I- Development OiIU. ....... Mtlltiþle Zone 0 Re-entry 0 Stratigraphic Test 0 Service0 ì- ¡';.'~;.J Development Gas 0 . :3irigleZone 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc, Bond No. 59-52-180 1 E-1 04 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage. AK 99510-0360 MD: 6964' rvD: 3974' / Kuparuk River Field , 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 431' FSL, 224' FEL, Sec. 16, T11 N, R1OE, UM / West Sak Pool , ADL 25651 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2335' FNL, 2317' FEL, Sec. 15, T11N, R10E, UM ALK 469 11/26/2004 Total Depth: 9. Acres in Property: 14. Distance to 1322' FNL, 2137' FEL, Sec. 15, T11N, R10E, UM - 2560 Nearest Property: 8243' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 550300 - y- 5960020 Zone- 4 28 Well within Pool: 1 E-20 , 350' (Height above GL): feet 16. Deviated wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) , / Kickoff depth: 300 ft. Maximum Hole Angle: 63° Downhole: 1508 psig Surface: 1139 psig / 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20· 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 3472' 28' 28' 3500' 2295' 320 sx AS Lite, 185 sx DeepCrete 6.75" 5.5"x3.5" 15.5x 9.3~ L-80 Hydril511 6936' 28' 28' 6964' 3974' 240 sx DeepCrete &IBTM 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth rvD (ft): 20. Attachments: Filing Fee 0 BOP Sketch W Drilling Program~ Time v. Depth Plot U Shallow Hazard Analysis U Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature ~ 1 \ ~ Phone L.(;.Ç''' -z3o Date ufS!O'1 " """"- -...... ~ Prenarl''' h "'h..~, All - Commission Use Only Permit to Drill 'i-' API Number: Permit Approval See cover letter Number: 2D - 2-2-~7 50- 6zfl- 2 3 2..3 i/ - 60 Date: ////¿,Þø for other requirements Conditions of approval: Samples required 0 Yes gNo Mud log required DYes ~ No ;;:: ,on ,"';de m,os""" 0 Ye, ~ No D;,oo«oo", '""'ey 'eq""ed ~es 0 No Other: ~- ~';'~<;.-\~rl.o.,,~d, \-'\\\~. C-ftJ'« V\+<1ruoSr\¡ \c,~, '>L\)+ "1_ C>.,c....Ç",C) - ~ / ~\O J ß. II ~/ ptf '--V [AI' - BY ORDER OF Approved by: I /l , .~ ~ THE COMMISSION Date: '-" '-"" / f , Form 10-401 Revised 12/2003 ORfGfNAL Submit in Duplicate · Aetion for Permit to Drill, Well 1 E-1 04 Revision No.O Novemeber 6,2004 Permit It - West Sak Well #1 E-1 04 Injector Application for Permit to Drill Document MoximizE Well VQII,J~ Table of Contents 1. Well Name..................................................................................................................... 2 Requirements of 20 AAC 25.005 (f) ..... ...... '..... .......... .... ...... ,. ..... ...... ....... ...... ....... ...... ...... ..... .......... .,. 2 2. Location Su m mary....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......... ...... ...... .............. ...... ....... ....... ...... ...... ....... ............. ......... 2 Requirements of 20 AAC 25.050(b) . ............ ..... ........................... ...... ,...... ......................... ........ ......... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25.005(c)(3) .., ...... ........ ...... ....... ....... .... ........ ........ ..... ..... ......... ..... ...... ......... 3 4. Dri II i ng Hazards Information ...................................................................................... 3 Requirements of 20 AA C 25.005 (c)(4) .... ...... ....... .............. ............. ............ ...... ............... ..... ............. 3 5. Procedure for Conducting Formation Integrity Tests .............................................4 Requirements of 20 AAC 25.005 (c)(5) ............................................................................................... 4 6. Casi ng and Ceme nting Prog ra m................................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ... ...... ........ ,.... ....... ........ ..... ....... ......, ........... ........ ,...... ....... ....... 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25.005(c)(7) ........... ....... ............ ............. ....... ....... ............ ............ ........ ....... 4 8. Drilli ng Fluid Program ...................... ................................................................... ... ..... 5 Requirements of 20 AA C 25,005(c)(8) . ........... ....... .............. ....... ..... ....... ........ ..... ....... ...... ..... ...... ....... 5 Lateral Mud Program (MI FloPro NT) .. ..... ...... ........ ............. ....... ............. ....... ..... ............. ...... ...... ....... 5 9. Abnormally Pressured Formation Information ........................................................ 5 Requirements of 20 AAC 25.005 (c)(9) .... ........ ....... ....... ............. ....... .................. ...... ........ ..... ............ 5 1 O. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ........... ................ ...... .................... ............ ....... ...... ........ ....... 5 11. Seabed Condition Analysis ................... ........... ........... ............. ............................ ...... 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 5 12. Evidence of Bonding ........... ........................................................... ............................. 6 Requirements of 20 AAC 25.005 (c)(12) .......... ........ ...... ................... ......... ..... .................. .................. 6 ORIGINAL PERMIT IT (Injector) RevO.doc Page 1 of7 Printed: Novemeber 6,2004 e A/AJtion for Permit to Drill, Well 1 E-1 04 .. Revision No.O Novemeber 6,2004 13. Proposed Drilling Program .........................................................................................6 Requirements of 20 AAC 25.005 (c)(13) . ....... ..... ...... ........ ............ ....... ....... ........... ....... ..... .......... ....... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) ...... ............' ........ ........... ....... ....... .... ....... ....... ..... ......... ......... 6 15. Attach ments.................................................................................................................. 7 Attachment 1 Directional Plan .... ............. .... ........ ........ ..... ...... ...... ...... ........ ............ ....... ..... ........ ......... 7 Attachment 2 Drilling Hazards Summary.... ........ ..... ....... ...... ....... ...... ..... ......... ,.... ...... ....... .... ......... ..... 7 Attachment 3 Cementing Data ...... .................. '..... ............. ....... ..... ....... ............. ....... ,..... .............. ...... 8 Attachment 4 Well Schematic ... ....... ..... ......., ...... ..... ....... ........ ........... ............ ....... ,....... ,..... ....... ........ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lE-l04. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlvey in the National Oceanic and Atmospheric Administration' (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Surface ASP Zone 4 NAO 27 Coordinates Northings: 5,960,020 / Eastings: 550,300 - I FNL:4850', FEL:224', Sec 16, T11N/Rl0E, UM I RKB Bevation I 94.1' AMSL I Pad Bevation I 66.1' AMSL ./ Location at Top of Productive Interval FNL2335, FEL 2317, See: 15, T11N/Rl0E, UM (West Sak "A" Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 5808' Northings:5,962,556 Eastings: 553,465 Total Vertical Depth, RKB: 3448' Total Vertical Depth, 55: 3353' Location at Total De th ASP Zone 4 NAO 27 Coordinates Northings:5,963,570 Eastings: 553,636 FNL 1322, FEL 2137, Sec 15, T11N/RlOE, UM Measured De. th, RKB: Total Vertical De. th, RKB: Total Vertical De. th, 55: 6964' 3974' 3879' and (0) other information required by 20 AAC 25.050(b/· ORIGINAL PERMIT IT (Injector) RevO.doc Page 2 ofl Printed: Novemeber 6,2004 e A~tion for Permit to Drill, Well 1 E-104 .. Revision No.O Novemeber 6,2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a pla~ drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well' Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as reqUired by 20 MC 25.0J~ 20 AAC 25.03~ or 20 MC 25.037, as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-104. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. Once surface casing is run a 5 ksi RSRRA BOP stack will be nippled up and tested. Even though this stack is rated for 5,000 psi it is requested to designate it as a 3,000 psi stack due to the formation pressures in the West Sak being well under 3,000 psi (+/-1600 psi). Therefore, intermediate casing rams can reside in one of the pipe ram cavities throughout the drilling of the well and the intermediate hole will be drilled to the landing point of the well in the West Sak sands. A 3,500 psi test is required on the BOPE. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountere~ criteria used to determine i~ and maximum potential surfàce pressure based on a methane gradient/ The expected reservoir pressures in the West Sak sands in the 1E-104 area vary from is estimated at v 1510 psi or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the maximum pressure gradient of .45, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is psi, calculated thusly: MPSP =(3350 ft)(.45psi/ft - 0.11 psi/ft) = 1139 psi ./ (B) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. ./ and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strat0 lost circulation zones, and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. ORIGINAL PERMIT IT (Injector) RevO.doc Page 3 of 7 Printed: Novemeber 6,2004 · A~tion for Permit to Drill, We1l1E-104 _ Revision No.O Novemeber 6,2004 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25. 030(f); The parent wellbore,lE-l04, will be completed with 5 1/2" X 3 1/2" intermediate casing landed in the West Sak A-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030- and a description of any slotted line/; pre- perforated line/; or screen to be installed,' Casing and Cementing Program See also Attachment 3, APD for lE-104: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (ini (in) (Iblft) Grade Connection {ftJ (ft) (ft) Cement Program 20 Driven 94 K55 Welded 80 28 / 28 108 / 108 Cemented to (Encountered surface with water) 260 cf ArcticCRETE 7 5/8 9 7/8 29.7 L-80 STCM 3472 28 / 28 3500 /2295 Cemented to Surface with 320sx ASLite Lead, 185sx DeepCRETE Tail 5 1/2" X 6 3/4 15.5# L-80 Hydril 511 6936 28 / 28 6964 / 3974 Cement Top 3 1/2 &9.3# & IBTM planned @ 3975'MD Cemented w/ 240 sx DeepCRETE 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and Identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of lE-104. Please see diagrams of the Doyon 141 diverter system on file with the Commission. ORIGINAL PERMIT IT (Injector) RevO.doc Page 4 of 7 Printed: Novemeber 6,2004 · A~tion for Permit to Drill, Well 1 E-1 04 _ Revision No.O Novemeber 6,2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033/ Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program () Properties Surface Production Density (ppg) 8.5-9.0 9 Funnel <6 <6 Viscosity (seconds) Yield Point <500 <500 (cP) Electric Stability NA NA Chlorides (mg/I) <500 <500 pH 9 9 API filtrate <6 <4 (ec / 30 min) **HTHP filtrate <10 <10 (ec / 30 min) MBT (lb / gal) NA NA -' Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as reqUired by 20 MC 25.033(f)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25,005 (c){10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 AAC 25.061(a)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (11) for a well drilled from an offShore platform, mobile bottom-founded structure, jack-up rig, or fioating dolling vesse¿ an analysis of seabed conditions as required by 20 AAC 25.061(b)/ Not applicable: Application is not for an offshore well. ORIGINAL PERMIT IT (Injector) RevO.doc Page 5 of 7 Printed: Novemeber 6,2004 · A~tiOn for Permit to Drill, We1l1E-104 _ Revision No.O Novemeber 6,2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: The proposed drilling program for 1E-104 is listed below. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 9 7/8" hole to casing point at +/- 3500' MD /2295' TVD as per directional plan. ' Run MWD tools as required for directional monitoring. 4. Run and cement 7 5/8",29.7#, L-80, STCM casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 6. PU 63/4" bit and drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 5 1/2" X 3 1/2" casing point at 6964 MD / 3974' TVD. 9. Run 5 1/2" X 3 1/2", 15.5# & 9.3## L-80, Hydril 511 & IBTM Mod casing to surface. Pump cement and displace with mud and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead 5 1/2" X 3 1/2" packoff and test to 5000 psi. 11. Flush 7 5/8" x 5 1/2" X 3 1/2" annulus with water, followed by diesel. .; 12. Run 3 V2" completion with seal assembly and and land tubing with seals stung in for a monobore completion, shearout GLM and freeze protect well, RDMO ~ \\ .¢ c.~~~~ \-~\Jú\\~ le>~ 1ft-'1Jv1\V [( () -0"1 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25. 080 for an annular disposal operation in the well.,; All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage .; and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ORIGINAL PERMIT IT (Injector) RevO.doc Page 6 of 7 Printed: Novemeber 6,2004 · 14. Attach ments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ORIGINAL A~tion for Permit to Drill, Well 1 E-104 ., Revision No.O Novemeber 6,2004 PERMIT IT (Injector) RevO.doc Page 7 of 7 Printed: Novemeber 6,2004 conoc~illips . e _i. BAKER HUGHES INTEQ ConocoPhillips Alaska, Inc.,Slot #104 Pad 1E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 104 Well path: 104 Ver#3 Date Printed: 4-0ct-2004 Weflbøre Name 104 I Created 4-Feb-2004 I Last Revised 4-0ct-2004 ¡""!itl ~ Installation Pad 1 E I Govemment 10 I ~~te~~v~~~ in 550528.1946 True r N AK-4 on NORTH AMERICAN DATUM 1927 datum I Field ~"kf.'~ LJo' I Eastina 487754.6208 INorthin~ 5 48985.8206 I~"'~"~· ... .. "O<ltl_..... I .. KA· "ßT>U~~DAJUM1927_m< ··········..r~' All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.011 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 51.68 degrees Bottom hole distance is 4871.12 Feet on azimuth 43.61 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL Conoc6Phillips . ConocoPhillips Alaska, Inc.,Slot #104 Pad 1E, Kuparuk River Unit, North Slope, Alaska e PROPOSAL LISTING Page 2 Wellbore: 104 Wellpath: 104 Ver#3 Date Printed: 4-0ct-2004 Bi. BAKER HUGHES INTEQ WellDath ReDort MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North(ft] East[ft] Station Station Dogleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[ North \ . 'East\ loft] It] 0.00 0.00 000 0.00 -A!i.OO O.OON O.OOF FiAfì0021 00 FiFiD:\01.00 000 000 Tie on 100.00 0.00 0.00 100.00 5.00 O.OON O.OOE 5960021.00 550301.00 0.00 0.00 ?OOOO 0.00 0.00 200 00 10Fi.00 O.OON OOOF FiAfìOO?1.00 550301.00 OcOO .0.00 '>.'1'1'1'1 000 000 :10000 ?OFiOO o OON OOOF <:""""'H '1'1 1;1;'1'>.'11 '1'1 000 000 KOP. r-. -" 400.00 3.00 60.05 399.95 304.95 1.31N 2.27E 5960022.32 550303.26 3,00 2.59 500.00 fì.OO fìOOFi 4AA.fì:l 4M.fì::\ Fi.?2N A.OfìF <:"""""Q.2R FiFiD:\10.0:l :1.00 10.35 fìOOOO A,nn fìO.O" 598.77 503.77 11 74N 20.37E AA 550321.29 3.00 23.26 633.33 10.00 60.05 631.64 536.64 14.49N 25.14E 5960035.65 550326.04 3.00 28.71 Build 4/100 3DXS Kick off Point 7'>.'>.'>.'>. 14.00 fìOOl; 729,44 634 44 2487N 43.15E <:O"""A" .15 4.00 49.27 R::\::\ ::\::\ 1R.OO fìO.O" A2Fi."4 T'\o."" 38.63N 67.03E <:a~('\('\~n 07 550367.76 4.00 76.54 933.33 22.00 60.05 919.50 824.50 55.70N 96.65E 5960077.34 550397.27 4.00 110.37 10::\'>. '>.'>. ?fìnO F;OO" 1 '11 0 A1 915.83 7600N 131.89E .88 4.00 150.60 113:1:1:1 :10.00 F;OO!'í 10AA.11 100411 AA.44N 172.!'ífìE !'íAfì0121 !'íR !'í!'í047? R7 400 19704 1233.33 34.00 60.05 1183.90 1088.90 125.90N 218.46E 5960148.34 550518.59 4.00 249,46 1:\:1:1.:1:1 :lROO fìO.O" PF;4.7A 11 F;A.7A 1"".?4N 269.38E 5960178.02 . 1 4.00 307.60 14'>.'>. '>.'>. 4200 fìOO!'í 1:\41:17 1 ?4fì:l7 1 R7 :I?N :I?FiOfìE ~~~^~ '^ AO I;I;(,\~?4 77 400 :l71.1R 1533.33 46.00 60,05 1413.29 1318.29 222.00N 385.23E 5960245.55 550684.70 4.00 439.89 16:1:1:1:1 FiO.OO fìO.O!'í 14RO.19 nRFi.1A ?!'íA.10N 44q.fì1 F 5960283.0R !'í!'í0748.82 4.00 Fi1:140 17'>.'>. '>.'>. Fi4.00 fìO.OFi 1Fi41 ,74 144fì.74 ?9R44N Fi17 R7E ~^~^^^^.R7 FiFiOR1 fì.81 400 59135 1833.33 58.00 60.05 1597.65 1502.65 339.82N 589.68E 5960364.73 550888.34 4.00 673.36 1 a'>.'>..'>.'>. fì2.00 fìO.OFi 1fì47.fì4 1 FiFi?64 :lR:lOfìN fìfì4.71E 4fì I;I;('\a~'>. ('\~ 4.00 759.02 1a!'íF;.14 F;? a1 F;on" 1658.19 1563.19 393 15N 682.23E 4.00 779, End of Build 2000.00 62.91 60.05 1678.16 1583.16 412.65N 716.06E 5960438.39 551014.21 0.00 817.66 ?100.00 F;?q1 F;O,n" 1723.6~ 1628.69 45711N 793.20E ,.36 551091.04 0.00 905.74 R? q1 RO.O" 17RA .2< 1R74.23 501.56N 870.34E 2 551167.87 0.00 993.83 2300.00 62.91 60.05 1814.76 1719.76 546.01 N 947,48E 5960573.29 551244.71 0.00 1081.91 R? q1 F;no" 1 ARn '>.( 17F;" '>.0 590,47N 1n?4 R?F 551321.54 0.00 1170.0C R? Ai ROO" 1AO!'í A< 1R10 A'>. R'>.4 q?N 11'11 7!'íF <:<:11aA 17 O~Oo. 1 ?FiR Of 2600.00 62.91 60.05 1951.37 1856.37 679.37N 1178.89E 5960708.18 551475.20 0.00 1346.17 ?700.00 R?A1 ROO" 1AAR.A( 1901.90 723.83N 1 ?"R.D:\F 15 551552.03 0.00 1434.2t fì?91 fìOO!'í I ?M?,44 1 A47,44 7RR.?RN 1:\:I'>.17F FiAR07AR 11 !'í!'í1 R?A.R7 0.00 1 Fi22.:l4 2900.00 62.91 60.05 2087.97 1992.97 812.74N 1410.31E 5960843.08 551705.70 0.00 1610,42 fì?A1 RO.O!'í I ?1:\:I.!'í1 ?D:\R!'í1 A!'í71AN 14A7,4!'íF 551782.53 0.00 169.8.5C 3100.00 fì?A1 fìO.OFi 217AN 20R4 OFi A01 fì4N 1 FiR4.Fi9f FiFi1RFiA:lR 0.00 17R6.5~ 3200.00 62.91 60.05 2224.58 2129.58 946.10N 1641.73E 5960977.97 551936.20 0.00 1874.67 3:100.00 fì2.91 fìO.O!'í ??70.11 217!'í 12 """ <:<:~ 171 RR7F FiAR1 O?? .A4 Fi!'í?01::\.D:\ 0.00 19fì2.76 '>.400.'10 F;2.91 60.05 ?315.65 2220.65 103FiOON 179fì01E 59fì10fì7.!:¡0 5Fi?OR9.8fì 0.00 2050.84 3500.00 62,91 60,05 2361,19 2266.19 1079,46N 1873.15E 5961112.86 552166.69 0.00 2138.93 '>.F;OO no fì?91 fìO OFi ?4(,\~ 7? ?:Iii 7? 11?:I 91 N 1 al;('\ ?a¡: Fi9fì11 Fi7.8::\ I;I;??411;? 0.00 ???7 '11 :1700.00 R2.Q1 RO.O" ?4"2.21ì ?'>."7.26 116837N 2027,42E 5961202.79 552320.36 0.00 2315.09 3800.00 62.91 60.05 2497.79 2402.79 1212.82N 2104.56E 5961247.76 552397.19 0.00 2403.18 '>.ann.nn 6291 6005 ?543.33 244R:l3 1?57.27/1. ?1R1.70E 59fì1292.7? 55?474.0? 0.00 2491.26 400'1 '1'1 R? Q1 Rnn!'í "&;00 A" ?4a'>. AR nn1 7'>.N ??"A A4¡: 5961337.69 !'í!'í?!'í!'ín A!'í 0.00 ?!'í7A:I!'í 4100.00 62.91 60.05 2634,40 2539,40 1346.18N 2335.98E 5961382.65 552627.69 0.00 2667,43 4?On.no R?Q1 Rn.n!'í ?F;7a.Q1 2584.93 1 2413.12E 5961427.62 552704.52 0.00 2755.52 424fì.14 R2 A1 RO.O!'í 2700 Ç 4 2RO!'í.A4 1411.1!'íN 244A.72F !'íAR1448.37 552739.97 0,00_ 27Afì.1 Ii r.IJrve :1/100 End of H"Ir! 4300.00 62.59 58.27 2725.60 2630.60 1435.69N 2489.82E 5961473.18 552780.91 3.00 2843.63 4400.00 fì2.0!'í !'í4.A:I 277?07 ?R77.07 14R4,42N 2"R'>. 74F 5961522,40 552854,49 3.00 ?9:11.84 4500.00 fì1.5R 51.57 2R19.:l2 ?7?4.:l2 1!'í:l7.14/1. 2R:l4.3FiE Fi9fì1 Fi755A Fi52A24 74 TOO 301993 4600.00 61.21 48.18 2867.20 2772.20 1593.71N 2701,47E 5961632.60 552991 ,48 3.00 3107.66 All data is in Feet unless othe/Wise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 51.68 degrees Bottom hole distance is 4871 .12 Feet on azimuth 43.61 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORt GtNAL · ConocJ'Phillips ConocoPhillips Alaska, Inc.,Slot #104 Pad 1 E, Kuparuk River Unit,North Slope, Alaska e .i. BAKER HUGHU INTEQ PROPOSAL LISTING Page 3 Wellbore: 104 Wellpath: 104 Ver#3 Date Printed: 4-0ct-2004 We II path Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft ] Station Station Dögleg Vertical Station Comment Depth SS Position(Grid Position(Grid [deg/10 Section[ Nnrth) E;:¡!':I) Oft1 11 4700.00 ñO}:¡1 4477 291 Fi ñO ?R20 ñO 1 2764.91 E <=:0"'-1 "'-0'>.?7 553054.51 <\.00 <\194 R( 4800.00 60.71 41.34 2964.39 2869.39 1717.73N 2824.50E 5961757.43 553113.66 3.00 3281.09 4900.00 ñO.Fi9 37.90 3013.41 2918.41 1784.86N 288007E 59ñ182492 553168.78 3.00 <;oon nn ñOFiñ <\44ñ <\Oñ? FiFi ?9ñ7 FiFi 1RFiFi 1 FiN ?9<\1 4RF ~. ... <=:<=: FiFi<\?19 70 <\ 00 5100.00 60.62 31.01 3111.67 3016.67 1928.41N 2978.57E 5961969.11 553266.30 3.00 3532.59 Fi?OO.OO ñ077 ?7.FiR <\1ñO ñ4 <\OñFi.ñ4 2004.44N 302123E .42 "''''''''''0. '4 3.00 3613.2C Fi300.00 ñ1.00 ?4.1Fi 3?09 <\ 1 <\114.<\1 2 <!n<;o <!<!¡:: "i9ñ?1?42ñ <\ 00 <\ñ91 R~ 5329.16 61.08 23.16 3223.43 3128.42 2106.41N 3069.57E 5962147.70 553356.09 3.00 3714.35 5400.00 ñ1.3? ?07Fi <\?57.Fi5 <\1ñ2Hi ?1 ñ<\.9RN 30Q2.77F ~^^^^..~ 42 FiFi<\<\7R.91 <\.00 '>7"'-0 '><= 5500.00 61.73 1737 3305,24 3210.?4 ?247.05N 31 ?1.4ñE R7 55340704 3.00 3R4227 5600.00 62.21 14.01 335225 3257.25 2332.01 N 3145.32E 5962373.78 553430.33 3.00 3913.6 Fi700 00 ñ2.7R 10.ñ9 33QR4::\ ::\<\0::\ 4::\ <!1M?A¡:: <;"1 ::\ 00 <!aA? ?~ Fi7?O,9ñ ñ?91 10.00 <\408.00 3313.00 2436.99N 3167.64E 596247R.90 55345194 3.00 39962E EOC. End of Turn 5800.00 62.91 10.00 3443.99 3348.99 250629N 3179.85E 596254827 553463.69 0.00 4048.82 5808.81 62.91 10.00 3448.00 3353.00 2514.01 N 3181.22E 5962556.00 553465.00 0.00 4054.67 Target, WS 1E B1 0 TOP RVSD090204 Fnrl~ nf H"lrl 5900.00 62.91 10.00 3489.53 3394.53 2593.97N 3195.31E 5962636.04 553478.56 0.00 4115.31 ñ? 91 10.00 <\Fi<\Fi,06 3440.06 268165N 3210.77E .°1 "'''''' '"'' A'> 0.00 4181.8C ñ10000 ñ2.91 10.00 <\FiRO ñ( <\4RFi.ñO 27ñ9.<\?N <\22ñ2<\E FiQñ?R11.FiR <=:<=:,><;nA ,>n 0.00 424R.<\( 6200.00 62.91 10.00 3626.13 3531 .13 2857.00N 3241.69E 5962899.35 553523.18 0.00 4314.79 ñ?91 10.00 <\ñ71.ñ7 <\Fi7ñ.ñ7 ?944 ñRN <\2Fi7,15E 5962987.13 <=:<=:'><:'>A ,,<; 0.00 4<\R1.?P 6400.00 ñ2.91 10,00 ::\717.2( <\ñ?2.20 <\0::\2<\ñN <\27?ñ1 F Fi9ñ<\074,90 FiFi<\"i"i?A? 0.00 4447,77 6500.00 62.91 10.00 3762.74 3667.74 3120.04N 3288.07E 5963162.67 553567.79 0.00 4514.27 6ñOO.00 6291 10.00 ::\ROR 2A <\71 ::\.2R <\?07.7?N <!<!n<!<;<!¡:: "i9ñ<\2"i0.44 "i"i<\"iR?ññ 0.00 4"iR07fì ñ?91 10.00 385381 375881 331R.99E 1 55::\597.53 0.00 4M7 ?<= 6764.10 62.91 10.00 3883.00 3788.00 3351.59N 3328.90E 5963394.47 553607.06 0.00 4689.8 End of Hold ñROO 00 62.91 10.00 <!Aaa "1<= ::\R04::\"i "I"I<ILl 4<;¡:: <;<;'>.R1? 4n 000 471::\74 ñ? 91 1000 <\Q44 RP <\R4Q RR ~14/U. ~I'II '>.'>.4Q a1F ~:->~1hL I j I 000 47RO ?lI 6964.10 62.91 10.00 3974.07 3879.07 3526.95N 3359.82E 5963570.01 553636.81 0.00 4822.86 TO - Casina PI. End of Hold / All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 51.68 degrees Bottom hole distance is 4871.12 Feet on azimuth 43.61 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL · Conoc~illips ConocoPhillips Alaska, Inc.,Slot #104 Pad 1E, Kuparuk River Unit, North Slope, Alaska e PROPOSAL LISTING Page 4 Wellbore: 104 Wellpath: 104 Ver#3 Date Printed: 4-0ct-2004 18 30.2777 W149 340.529 i 553465.00 Surve f 653231 TVD rv T I ISCWSA MWD rr I MWD+SAG - ISCWSA - 28 Ja 03 OJH 5329.16 3223.43 Planned All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 51.68 degrees Bottom hole distance is 4871.12 Feet on azimuth 43.61 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL .¡. BAKER HUGHU INTEQ 5962556.00 ,alliburton Sperry-Su. Anticollision Report spe!I'""I""'y-sun DRILLING seRVICE. 4 MAU.IfIIIQT()NC'OMP.iIM' Company: ConocoPhillips Alaska Inc. Date: 11/5/2004 Time: 11:01:35 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Co-ordinate(NE) Refereuce: Well: 1E-104. True North Refereuce WeD: 1E-104 Vertical (TVD) Reference: 1E-104 94.1 Reference WeDpath: Plan 1E-104 Db: Oracle I GLOBAL SCAN APPLIED: All weJlpaths withiu 200'+ 100/1000 of refereuce Refereuce: Plan: Plan 1E-104 (wp04) & NOT PLANNiF :> Iuterpolation Method: MD Inten'al: 25.00 ft Error Model: ISCWSA Ellipse ¡ Depth Range: 28,00 to 6931.23 ft Scan Method: Trav Cylinder North I Maximum Radius: 890.32 ft Error Suñace: Ellipse + Casing I Casing Poiuts MD TV» Diameter Hole Size Name ft ft in in 6931.23 3958.45 7.000 8.500 7" I Plan: Plan 1E-104 (wp04) Date Composed: 11/5/2004 I Priucipal: Version: 1 Yes Tied-to: From Well Ref. Point Summary [< Offset Wellpath > Referenee Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distauce Area Deviatiou Waruiug ft ft ft ft ft Kuparuk 1 E Pad 1E-07 1 E-07 V1 570.22 600.00 616.86 8.06 608.80 Pass: MajOr Risk Kuparuk 1 E Pad 1E-112 1E-112 V1 346.17 350.00 239.64 5.70 233.93 Pass: Major Risk Kuparuk 1 E Pad 1E-112 1E-112L 1 VO 346.17 350.00 239.64 5.70 233.93 Pass: Major Risk Kuparuk 1 E Pad 1E-112 1E-112L2V1 346.17 350.00 239.64 5.70 233.93 Pass: Major Risk Kuparuk 1 E Pad 1 E-112 1E-112PB1 V2 346.17 350.00 239.64 5.70 233.93 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123 V2 4227.33 4400.00 444.34 120.89 323.45 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123L 1 V2 4227.33 4400.00 444.34 120.89 323.45 Pass: Major Risk Kuparuk 1 E Pad 1E-123 1E-123PB1 V1 4227.33 4400.00 444.34 120.89 323.45 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126 V1 1705.83 1975.00 152.01 43.98 108.03 Pass: Major Risk Kuparuk 1 E Pad 1E-126 1E-126L 1 V1 1705.83 1975.00 152.01 43.98 108.03 Pass; Major Risk Kuparuk 1 E Pad 1E-126 1E-126L2 V1 1705.83 1975.00 152.01 43.98 108.03 Pass: Major Risk Kuparuk 1 E Pad 1E-18 1E-18 V1 742.14 750.00 89.04 11.04 77.99 Pass: Major Risk Kuparuk 1 E Pad 1E-19 1E-19 V1 589.34 600.00 35.51 7.99 27.52 Pass; Major Risk Kuparuk 1 E Pad 1 E-20 1 E-20 V1 338.19 350.00 21.08 5.04 16.04 Pass: Major Risk Kuparuk 1 E Pad 1 E-21 1E-21 V1 337.60 350.00 80.58 4.67 75.90 Pass: Major Risk Kuparuk 1 E Pad 1E-22 1E-22 V1 312.92 325.00 141.15 4.99 136.16 Pass: Major Risk Kuparuk 1 E Pad 1 E-23 1 E-23 V1 383.96 400.00 200.33 5.77 194.56 Pass: Major Risk Kuparuk 1E Pad Plan 1E-168 Plan 1E-168L 1 VO 315.27 325.00 761.28 4.84 756.44 Pass; Major Risk Kuparuk 1 E Pad Plan 1E-168 Plan 1E-168L2 VO 315.27 325.00 761.28 4.84 756.44 Pass: Major Risk Kuparuk Non-Pad KUP-01 KUP-01 VO 2240.38 1825.00 358.47 44.90 313.57 Pass: Major Risk PR ORIGINAL ANTI·COLLISION SETI1NGS NQ~ E¡¡~,,* 55Û)OO.3-5JJ LaIiWM w¡¡¡#ulll' Sb¡ 1\1"1í!-'I)5.556N !4'ì'.35'nn2W NIA Travelling CyJinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [ft] JE.104 (wp04) P1a!IIE~104 RJ¡¡, Doyon 141 R¡:[ThI!urn: 1£-104 94,iOtl ~~~ Origin Siin:tirlg +Bf-W FromT\,1) 43.799'" 0.00 0.00 28.00 0 ToMD 300 400 500 750 1000 15.0 1250 1500 1750 2000 2500 3000 10.0 3500 4000 4500 5000 5500 5.0 6500 7500 8500 9500 10000 10500 0 27 11000 12000 13000 14000 15000 16000 -5.0 17000 18000 19000 20000 -10.0 -15.0 Trave11ing Cylinder Azimuth (TFO+AZI) (deg] VB Centre to Centre Separation (J Oft/in] 4200 3900 3600 3300 3000 2700 2400 ^ I Z" 2100 ( ,) .æ - 1800 .c t:: 0 Z 1500 1200 900 600 ~ 300 0 1.0 ..... II 0 E 0 ( ) -300 ñi 0 C/) N TRUE W ~ E ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E 17-5ep-2003 BGS Global Geomagnetic Model [1945,0-2005.0] Dip: 80.75 deg Field: 57528.0 nT Magnetic North is 25.07 degrees East of TRUE North To correct azimuth from Magnetic 10 TRUE add 25.07 deg Build 4/100 KOP Conoc~illips Slot: Slot #104 Well: 104 Wellbore: 104 TO - Casing PI. reate y : anner Date plotted: 4-0ct·2004 Plot reference is 104. Ref well path is 104 Ver#3. Coordinates are in feet reference Slot #104. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. e WS 1 E B1 D TOP RVS0090204 EOC -300 0 300 Seale 1 em = 150 ft 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 East (feet) -> Curve 3/100 - ¡ : 0 -300 10 ..... II E 0 0 Q) ëii 0 (f) 300 600 900 2100 ( ) 2400 ::J ... ~ I V 2700 3000 3300 3600 3900 4200 .£ iNTiij-- -- RKB Elevation: 95' KOP 6.00 Build 4/100 18,00 26.00 OLS: 4,00 deg/100ft 42.00 50.00 54,00 58.00 62.00 EOC -600 -300 0 300 Seale 1 em = 150 ft 600 900 ConocoPhillips Alaska, Inc. Conoc~illips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #104 Well: 104 Well bore: 104 reate y : anner Date plotted: 4·0ct-2004 Plot re erence is 104, Ref well path is 104 Ver1f3. Coordinates are in feet reference Slot #104. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. WELL PROFILE DATA Point MD Inc Azi rvD North East degl100ft Tie on 0.00 0,00 I 0.00 0,00 0.00 0,00 0.00 End of Hold 300.00 0.00 I 0,00 300.00 0,00 0.00 0.00 I KOP 633.33 10.00 60,05 631.64 1449 25.14 3.00 28.71 End of Build 1956.14 62,91 6005 1658,19 393.16 682.23 4.00 779.03 End of Hold 4246,14 62.91 60.05 2700.94 1411.15 2448.72 0.00 2796.16 End of Turn 5720.96 62.91 10.00 3408.00 2436.99 3167,63 I 3.00 3996.26 Target WS 1E B1 0 TOP 5808.81 62,91 10.00 3448.00 2514.01 3181,22 0.00 I 4054.67 End of Hold 6764.10 62,91 10.00 3883.00 3351.59 3328,90 0.00 4689.87 T.O, & End of Hold 6964.10 62,91 10.00 397407 3526.95 3359.82 0.00 4822,86 I I Curve 3/100 62.05 61 ,5~091 OLS: 3.00 deg/100ft 60.59 60.62 61.00 61.73 62.78 - EOC WS 1E B1 0 TOP RVSD090204 Target TO - Casing PI. 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 Vertical Section (feet) -> Azimuth 51.68 with reference 0.00 N, 0.00 E from Slot #104 e 1 E-1 04 Monobore Injector 2.875" ID 31/2" Tubing Completion with Seals 51/2",15.5#, L-80, Hydril511 3 1/2", 9.3#, L-80, 18TM e 9 7/8" Surface Hole 8.6 ppg mud weight Conventional Directional Motor Hydraulics: Surface: 600-700 gpm 50 YP Production: 250-300 gpm 35 YP 75/8",29.7#, L-80, 8TM Surface Casing 3500' MD, 2369' TVD 63/4" Production Hole 9.0 ppg mud weight Conventional Directional Motor Camco 2.812" ID 51/2" X 31/2" Crossover 5750' MD 3420'TVD 5 1/2" X 3 1/2" Tapered Intermediate Casing Top of West Sak 5808'MD 3448'TVD ORIGINAL e e lE-l04 Drilling Hazards Summarï (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 97/8" Open Hole / 7 5/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low ( Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets), pumping out 63/4" ODen Hole / 5 1/2" X 3 1/2" Casing Interval Hazard Running Sands and Gravels Risk Level Low Stuck Pipe Low Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low I Low Moderate Miti ation Strate Maintain planned mud parameters, Increase mud weight, use weighted swee s. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht BOP training and drills, increased mud wei ht. Reduced um rates, mud rheolo ,LCM Trip speeds, Proper hole filling (use of trip sheets, um in out ORIGINAL 1E-104 Drilling Hazards Summary prepared by Steve Shultz 7/14/20045:15 PM Rig: Doyon 141 Location: West Sak Client CPAI Revision Date: 10/29/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 108 ft. MD < Base of Permafrost at 1,694 ft. MD (1,518 ft. TVD) < Top of Tail at 2,000 ft. MD < 75/8",29.7#, L-80 grade BTC, AB Modified in 97/8" OH TO at 3,500 ft. MD (2,361 ft. TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Schl.b8Pg8P Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. Top of tail slurry is designed to be 306' below base of permafrost.) Lead Slurrv (minimum pump time 180 min.) ArcticSet III Lite @ 10.7 ppg, - 4.45 ft3/sk 3 0.9513 ft 1ft x (108') x 1,00 (no excess) = 0.2148 ft3/ft x (1694' -108') x 3.50 (250% excess) = 0.2148 ft3fft x (2000' -1694') x 1.35 (35% excess) = 102.7 ft3 + 1192.4 ft3+ 88.7 ft3 = 1383.8 ft3 f 4.45 ft3fsk = Round up to 320 sks 102.7ft3 1192.4 ft3 88.7 ft3 1383.8 ft3 311 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 145 min.) LiteCRETE @ 12.0 ppg - 2.52 ft3fsk 3 0.2148ft 1ft x (3500' -2000') x 1.35 (35% excess) = 0.2578 ft3fft x 80' (Shoe Joint) = 435 ft3 + 20.6 ft3 = 455.6 ft3f 2.52 ft3fsk = Round up to 185 sks 435 ft3 20.6 ft3 455.6 ft3 180.8 sks BHST = 53°F, Estimated BHCT = 72°F. (BHST calculated using a gradient of 2SFf100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5.0 10.0 2.0 2,0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 ASL 7.0 260.4 37.2 70.5 DeepCRETE 5.0 81.1 16,2 86.7 Drop top plug 0.0 0.0 5.0 91.7 Mud 7.0 142.0 20.3 112.0 Slow & bump plug 3.0 15,0 5.0 117.0 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-20, Ty ? 20-25 Centralizers: Minimum 1 per joint across zones of interest for proper cement placement. ORIGINAL Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 10/29/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 75/8",29.7#, L-80 grade BTC, AB Modified at 3,500 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 6 3/4" OH < Top of Tail at 3,975 ft. MD < X-over at 5,731 ft. MD < Top of West Sak at 5,931 ft. MD < 31/2", 9.3#, L-80 grade EUE, 8rd Modified in 6 3/4" OH TO at 6,931 ft. MD (3,958 ft. TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. lehlulhePllP Volume Calculations and Cement Systems (Volumes are based on a 7-y:' "hole). Top of tail slurry @ 3975' MD is designed to be 500' above the Ugnu. Tail Slurrv (minimum thickening time 130 min.) 12.5 ppg OeepCRETE @ 12.5 ppg with Yield of 2.26 ft3fsk 3 0,0835 ft 1ft x 1756' x 1.69 (69% excess) = 0.2400 ft3fft x (6931' - 5731') x 1.32 (32% excess) = 0,0488 ft3/ft x 60' (Shoe Joint) = 247.8 ft3 + 288.0 ft3 + 2.9 ft3 = 528.7 ft3f 2.26 ft3/sk = Round up to 240 sks 247.8 ft3 288.0 ft3 2.9 ft3 538,7 ft3 238.4 sks BHST = 93°F, Estimated BHCT = 82°F. (BHST calculated using a gradient of 2SFf100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) lbb ) lmin) CW100 4,0 30.0 7,5 7.5 Pressure test lines 0.0 0.0 10.0 17.5 MUDPUSH II 4.0 30.0 7.5 25.0 OeepCRETE 4.0 96.1 24.0 49.0 Drop Combo plug 0.0 0.0 5.0 54.0 Mud 4.0 128.0 32.0 86.0 Slow ECO 3.0 9.0 3.0 89.0 Slow ECO & bump 2.0 9.2 4.6 93.6 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 22 - 24, Ty = 24 - 28 Centralizers: 4411 - 5531, 1 bow spring per joint (5 -Y:, ") - 28 total 5821 - 6871, 1 bow spring per joint (3-y:''') - 35 total 2 bow spring per joint on the shoe track - 4 total ORIGINAL Re: FW: lE-104_Traveling Cylinder AOGCC e e Subject: Re: FW: lE-104_Traveling Cylinder AOGCC From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 12 Nov 2004 11 :58:37 -0900 To: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Steve, Thanks much. This answers my questions. Tell the Sperry guys thanks as well. Tom Maunder, PE AOGCC Shultz, Steven M wrote: Tom, We've sent a traveling cylinder from the top of the West Sak to the Base and extended this out to 2250' so that you can see there are no wells intersecting within the 1320'. Thanks Steve -----Original Message----- From: Glenn Andrews [mailto:Glenn.Andrews@HALLIBURTON.com] Sent: Friday, November 12, 2004 11:10 AM To: Shultz, Steven M Subject: 1E-104_Traveling Cylinder AOGCC 1E-104_Traveling Cylinder AOGCC «lE-104_Travelling Cylinder AOGCC.pdf» ~~.s..o''ð\......~ ~ ~'i \\ "Ú.~\'C4 \W \o.\\~\'--~ 'Va? Ç)\-~~ \~ ~~ o\. ~c.., \~ \> \0 \-c.'õ ~~ s .... ¡" \ "£. -() '\ \. \ 6 '\ l ~ \~\o.V".. ~ , lCo~ ~\ ~,~\o.{¡,\ ' \Ctú So o-o..~ '" \ þtørv(,( I¡ 0::. 0 '1 I of I 11/12/2004 12:45 PM ANTI-COLLISION SETTINGS Traveling Cylinder ¡Iii Co Engineering Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Horizontal Plane Error Surface: Elliptical Conic Warning Method: Rules Based Interpolation Method: Depth Range From: Reference: Maximum Range: o 90 180 Highside Toolface Angle n vs Centre to Centre Separation [900 Win] TVD Interval: 1 ft Stations 3447 (top West Sak) To 3867 (Bottom West Sak) Plan: Plan: 1E-104 (wp04) 2500 ft Re: FW: 1£-104 e e Subject: Re: FW: lE-104 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 12 Nov 2004 08:46:34 -0900 To: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Steve, I have been looking at the "1320" plot and have tho following. I may not have been clear on my request. Using the 7-5/8" shoe of 1E-104 gets us in the neighborhood, but that comparison is primarily for annular disposal which is not planned here. The key depths on 1E-104 to define the area are the top and bottom of the West Sak. The top is best defined by the 5-1/2 x 3-1/2 XO and the bottom by TD. What will be defined is a "cylinder of earth of 1320' radius along the wellpath" and where other wellbores penetrate that cylinder. The good news is that at least based on my hand calculations 1E-07 doesn't enter that cylinder, however that is a piece of information you and the Sperry boys will need to provide. On the plot is there a depth reference for the ellipses?? Is it possible to put TVD tick marks on the well paths?? Give a call and we can discuss. Tom Thomas Maunder wrote: Thanks Steve, I was just thinking about this. Tom Shultz, Steven M wrote: Tom, Here is the "1320" plot for 1E-104. Steve -----Original Message----- *From:* Glenn Andrews [mailto:Glenn.Andrews@HALLIBURTON.com] *Sent:* Friday, November12-~ 2004 7:41 AM *To:* Shultz, Steven M *Subject:* 1E-104 Steve, Here is the 1320 plot and report for 1E-104. Let Dennis or I know if you need anything else. Regards, Glenn Phone: 263-4104 Cell: 632-2324 /Quote of the Day/ / / /"Behold the turtle. He only makes progress when he sticks his neck out."/ /- James Bryant Conant/ 10f2 11/12/2004 12:53 PM e e illips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1E Pad Plan: 1 E-1 04 Plan: 1E-104 Plan: 1E-104 (wp04) Anticollision Summary Report 12 November, 2004 ION Co-ordinate (N/E) Reference: Well Plan: 1 E-104, True North Vertical (TVD) Reference: Elev: 94 @ 94.100ft (WBP) Section (VS) Reference: (O.OOON, O.OOOE) Measured Depth Reference: Elev: 94 @ 94. 1 OOft (WBP) Calculation Method: Minimum Curvature Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Plan: 1E-104 Wellbore: Plan: 1E-104 Plan: Plan: 1E-104 (wp04) SURVEY PROGRAM Date: 2004-11-08TOO:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 0,000 6930.892 Plan: 1E·104 (wp04) MWD 3500 3250 3000 2750 2500 2250 ¡;: ~ o o !:!1 1750 :;- 1: 1:: o ~1500 I 1: :; o (f) 1250 o 250 500 750 1500 1750 2000 West(-)/East(+) (500 ft/in) 3000 3250 1000 1250 2250 2500 2750 Co~illips e SPERRY_SUN HES Anticollision Summary Report e Filter type: Interpolation Method: Depth Range: Results Limited by: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen rvD Interval1.000ft Error Model: 2,430.000 to 2,470.000ft Scan Method: Maximum center-center distance of 2,500.000ft Error Surface: ISCWSA Horizontal Plane Elliptical Conic 1 E-07 - 1 E-07 - 1 E-07 3,649.773 2,901.144 1,424.369 1,273.469 9.439 ee, ES, SF 1E-18-1E-18-1E-18 3,649.773 2,560.852 1,947.186 1,814.746 14.702 ee, ES, SF 1E-19-1E-19-1E-19 3,649.773 2,566.585 1,783.220 1,647.785 13.167 ee, ES, SF 1 E-20 - 1 E-20 - 1 E-20 3,649.773 2,753.389 1,355.232 1,228.602 10.702 ec, ES, SF 1 E-21 - 1 E-21 - 1 E-21 3,649.773 2,441.965 2,334.557 2,216.397 19.758 ee, ES, SF 1 E-22 - 1 E-22 - 1 E-22 3,649.773 2,994.679 2,184.798 2,093.361 23.894 ee, ES, SF 1 E-23 - 1 E-23 - 1 E-23 3,649.773 2,718.373 2,251.981 2,153.855 22.950 ee, ES, SF Plan 1E-102- Plan 1E-102B Lat-Plan 1E-102 BLat (wpl 3,649.773 3,224.456 1,400.538 1,259.990 9.965 ee, ES, SF Plan 1 E-102 - Plan 1 E-102 D Lat - Plan 1 E-102 D Lat 3,649.773 3,224.459 1,400.537 1,259.347 9.919 ee, ES, SF Plan 1 E-102 - Plan 1 E-102 D Lat - Plan 1 E-102 D Lat (wP( 3,649.773 3,224,459 1,400.537 1,259.029 9.897 ee, ES, SF KUP-01 - KUP-01 - KUP-01 3,649.773 2,469.021 1,450.509 1,333.521 12.399 ee, ES, SF ce - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/12/2004 7:37:20AM Page 20f3 COMPASS 2003.11 Build 41 e c:onoc6Pí,illips SPERRY_SUN HES Anticollision Summary Report e Reference Depths are relative to Elev: 94 @ 94.1 00ft (WBP) Offset Depths are relative to Offset Datum Central Meridian is -150.00000000 0 Coordinates are relative to: Plan: 1 E-104 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Grid Convergence at Surface is: 0.380 Ladder Plot '2 ~ 1800 o o !B.- e o ~ co c.. Q) CJ) 1200 ~ ë ð I I I I j. I I I I no no _I. om __ ._.. .m --i _ .n. I I I I ........... . .. I I I I .... .m .... .... n_ ----~...+.. : f: ; I . ". 1 .m ..<... _ ... .. ..,. I I I I 2400 ............... ... I I I I ... .. ,. I I I I I I I I ...¡ . ... .... n. ... ...~ .n I I I I .8 ~ ë Q) Ü ....... .... on.J.. . .. I I I I .... .... .... .m out .. I I I I I I I I .... .... .... .... ...! .... .... .... .m on .m .... m. .... ...I I I I I 600 I I I I .L. I I I I 0 0 .... .... .... ... .~. I I I I no... no.n .J.. I I I I 650 1300 1950 2600 Measured Depth (650 ft/in> 3250 3900 LEGEND .... 1 E-23, 1 E-23, 1 E-23 V1 ..... Plan 1 E-1 02, Plan 1 E-1 02 B La P ..... 1E-07, 1E-07, 1E-07 V1 "'*' 1E-18,1E-18,1E-18 V1 "'S- Plan 1 E-1 02, Plan 1 E-1 02 D Lat, Plan 1 E-1 02 D Lat (wp~VliUP-01, KUP-01. KUP-01 VO ..... Plan 1 E-1 02, Plan 1 E-1 02 D Lat, Plan 1 E-1 02 D LatVO -e- Plan: 1 E-1 04 (wp04) CC - Min centre to center distance or covergent point, SF - min separation factor, ES .. min ellipse separation 11/1212004 7:37:20AM Page 3 of 3 COMPASS 2003.11 Build 41 1£-168 Cementing e . Subject: lE-168 Cementing From: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Date: Wed, 10 Nov 2004 17:28:28 -0900 To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> Tom, I've faxed you the info for the 7 5/8" cement job on lE-168, plus sent you the proposed geological depths from the wellplan. Thanks Steve ~\ \~ \ ~ dO~-dOb , 1 of 1 11/12/2004 12:55 PM Re: lE-104 versus lE-07, again e e Subject: Re: 1E-104 versus 1E-07, again From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 10 Nov 200410:49:29 -0900 To: Steve Shultz <Steven.M.Shultz@conocophillips.com> Steve, Further to my earlier message, can you provide the production/intermediate cementing job information for 1E-168. Also, I was just looking at the completion report for 1E-123 and the cement volume for the 7-5/8" job was increased greatly. I also note that there was lots of Ugnu oil seen. Was that the reason for increasing the cement?? Thanks, Tom Thomas Maunder wrote: Steve, I am just starting to look at 1E-104. "1320 plot" starting at the top of WS the wells we identify in the area are neighborhood as well. Thanks in advance. Tom Maunder, PE AOGCC I was wondering if you could provide a penetration and continuing to TD. Most of WS wells, but 1E-07 appears to be in the 1 of 1 11/10/200411:41 AM N ~ / /'-/" i J1 SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G ST. ANCHORAGE AK 99501 PAY TO THE ORDER OF $ ;00. OÒ - tc.e.-- ........ CHASE Cha.a Manhattan Bank USA, N.A. Valid Up To 5000 Dollars '-, 200Whlt.CIayC.n..,D'..N....',D".,11 d .'.0 t6-loci__~~4~-g~ .: 0 3 ¡. ¡. 0 0 ¡. I. I.': 2 ¡. a I. 7 ¡. ~ 0 7 ~ 2 7 bill ¡. 0 a ¡. ( ; e e e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K~t( 1£-/0<1 PTD# 2D f~2Z7 1/ - Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE"· APPLŒS (OPTIONS) MULTI Tbe permit is for a new weUboresegment of LATERAL existing well . Permit No, API No. . (1f APJ Dum ber Production.sbould continue to be reported as last two. (2) digits a fUDction 'of tbe original API number. stated are between 6.0-69) above. PILOT HOLE )n accordance witb 2.0 AAC 25..0.05(1), aU (PH) records, data and logs acquired for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) .' and API Dumber (56 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fun EXCEPTION compliance witb 20 AAC 2S.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J cep1ion. (Company Name) assumes tbe liability of any prot est to the spacing .e:Jception tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 3D' sample intervals from below tbe permafrost or from where samples are first caugbt and ] 0' sample iJiter:vab tbrougb target zones. D D Well bore seg Annular Disposal On Program SER On/Off Shore 11..1.60. E-104 Unit AK Well Name: KUPARUK RIV U SERLPENQ GeoArea 890 No, 4Q66 Entire W~IIIQcatßd InADL02565.1 goYero~d. by .C.oose.rv.ation. Order line.. e ~~ 168L.2_ 1 Area Injectjo_n_Qrde.r No.2B. E;-123.1E;-123J..1,JE:Ol,1E;-16.8!-1 .Yßs .Yßs Yes .Yes Yes .Yes Yes .Yes .Yes _Y.es Yes Yes Yes .Yes _Yes No .NA Initial ClasslType KUPARUK RIVER, WEST SAK OIL - 490150 C ~ attache.d .Leas.e .numb~r .appropriate. _U_nique welt name _aod lJl!mb_er Field & Pool Administration KRU WestSal< OJI Pool, WelJ is more. than 5.00 f~et from all exteJnaJ prope.rty No restrictioos as_ to well s¡pacilJg io CO_ 4.066, No restrictiol)s as_ to well spaciog io CO.4066 W~lIlocated In.a. define.dpool W~IIJQcated prop~rdistaoce. from driJliog unitboundary. We.ll IQcated pr.ope.r _distaoce_ from oth~r welJs .S.ufficient ~ I( deviatec 2 3 4 5 6 7 8 9 IndrilJilJg unit included .~creage_aYailable Js. weJlbore plat _Operator onl}' affeçted party _Opecator bas.appropriateJ).ood in.forCE¡, Permit cao be issued witbQut cons~rvation order Pßrmit c.ao be ISSl!ed witbQut administrative. approval Can permit be approved before 15-c1ay wait W~II located within area and. strata .aut/1Qrlzed by lojectiol) Order # (put 10# in_ commelJts). (For 011 I}') (For_ser:vice welt only) AJI welJs. wit]1ip Jl4_llJiLe_ar~a_of reyiew idel)!ified Pr~-produced iojector; duratiQnof pre-productiol1 less than 3 mOl1tbs .ACMP findjng .of Con.sisteocy h.as beep jssued_ for tbis projeçt (For servJee -",,-et 10 11 12 13 14 15 16 7 Date 11/9/2004 Appr SFD aq.uif~rs; exempted, 40 .CFR 1<47.1 Q2(b)(3). AI be. c.overed, All hYdroçarbon.zol)~s_will. wells. I CLass NQ rese.rve_pJtptaOlJed, AU waste to.approve.daOlJull!s.or Rig isequippe_d_with steelpjts. I?ro~imit}' anjllysis p~r{ored.. çtos~ appro_aches ideotified. _ Tra,,-eling_ cyljnder_pJot !ncl\.lde_d, e PlalJned mud weigbtin WS9,Q ppg.. MASI? çalculat~d.at 1139 psi, 35QOpstBO~ testplaoo~d, H2S bas .not been reported In. WS.. RlgJs equipped. with .sensorsand alacms. I?ro~imtt}' anjllysis CQnfirms.tbere are 00 "oW WS penetrations.withio.1l4_llJileof the pcopoSJ9d wellpat]1. New .Yes NA Yes No Yes .Yes Yes .NA Yes Yes .Yes Yes .Yes .Yes Yes No .Yes .C_oodu.ctor _S_urfaeecasing.protects all.known USDWs string. provided 18 19 20 Engineering 8. su_rf_c¡¡g cond.uctor tie-in long .striog to surf C$.g. CMT. vol. adeQu.ate. to circJJtate. on .CMT. voL adeQ u.ate to I<oown .pro_ductiYe horizon_s C,T, 6.&. permafrost _CMT. Wil! coyeraJ C.asil)g deslgos adeQua_t~ for Adequate.tanJcage_or reserye pit 10.-403 fQr abandonme.nt beeo approved l(aJe-driIL hasa. Adequate wellbore. separatJo_nproposed Jneet reguJatiol1s listadequate it DriUil)g fluid. program sc.hematic& equip Kdivert~r r~qJJiJe.d. does 61:1~ expected aL8]_EMW. in .commel1ts) .BOPEs,.d.o reguJation _BOPE.pr~ss ratiog appropriate;t~st to.(pu.t psig .ChokellJanifold compJies wIAPtR~-53. (May 84) Work will occ.ur they meet withoutoperatjon.shutdown 21 22 23 24 25 26 27 Appr Date 28 TEM 11/12/2004 29 h~~k? ~~ 32 33 34 .Is preseoce. Qf H2S gas_ prob.able Mechanlcalcoodjtloo o{we.Us withio AOR yerified (Foaervice weIJ only) wells. eernel)t OK. Expected res~rvoir preSSl!re Î.s .8]ppg ~MW; wi _Yes .Yes NA NA .NA Î.SSl!ed w/o. hYdcogens.ulfide meaSJJres Permit c.ao be _D_ata.PJeselJted on pote.ntial overpress\.lrezooes 35 36 37 38 39 Geology Appr SFD be drilLed with 9.0 PP9 mud. Date 11/9/2004 .SßÎ.sr:nlc.analysJs Qf sbaJlow gas.zol)~S (if off-shore) .Seabed .cooditiolJ Sl!rvey Date 1'l~c? ic sioner CQnta.ct oamelp]1ooeJorweelsly progress reRorts [exploratory .only). Date Engineering Commissioner: 1- Date: J] J f~) Geologic Commissioner ÐÞ' . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ng Services LIS Scan Utility . :2 0 tf-- 2.2.. 7 $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 15 09:40:56 2004 # p__ ~ ç<1 Reel Header Service name........ ... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.. ....01 Previous Reel Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... ...... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............ ....UNKNOWN Continuation Number.. ....01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1E-104 500292323400 ConocoPhillips Alaska Sperry-Sun Drilling Services 15-DEC-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003410594 J. MARTIN M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11 10 431 224 94.10 66.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 3635.0 # REMARKS: . . 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND STABILIZED LITHO-DENSITY (SLD) . 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER PHONE CONVERSATION BETWEEN M. WERNER (CPAI) AND R.KALISH (SSDS) ON 12/9/04. 6. MWD RUNS 1 & 2 REPRESENT WELL 1E-104 WITH API#:50-029-23234-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6935'MD / 3984'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.0 PPG MUD SALINITY: 250 PPM CHLORIDES FORMATION WATER SALINITY: 6000 - 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... ........ ..STSLIB.001 Service Sub Level Name. . . Version Number...... .... .1.0.0 · Date of Generation..... .~12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF GR FET RPD RPM RPS RPX DRHO RHOB ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3559.5 3560.5 3560.5 3574.5 3595.0 3601.5 3601.5 3601.5 3601.5 3601.5 3627.5 3627.5 3640.5 STOP DEPTH 6852.5 6852.5 6852.5 6868.0 6888.5 6895.5 6895.5 6895.5 6895.5 6895.5 6867.5 6867.5 6935.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: BIT RUN NO MERGE TOP 2 3559.5 MERGE BASE 6935.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type...... ....... .....0 Data Specification Block Type.....O Logging Direction...... ... ...... ..Down Optical log depth units......... ..Feet Data Reference Point............. .Undefined Frame Spacing...... .......... .... .60 .1IN Max frames per record.. ......... ..Undefined Absent value.................... ..-999 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 HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD PEF MWD G/CM BARN . 4 1 1 68 68 13. 14 48 52 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3559.5 6935 5247.25 6752 3559.5 6935 ROP MWD FT/H 0.32 787.14 214.389 6590 3640.5 6935 GR MWD API 15 143.34 77.206 6588 3595 6888.5 RPX MWD OHMM 2.5 2000 28.722 6589 3601.5 6895.5 RPS MWD OHMM 2.55 2000 22.9826 6589 3601.5 6895.5 RPM MWD OHMM 2.64 2000 33.4556 6589 3601.5 6895.5 RPD MWD OHMM 2.43 2000 34.4386 6589 3601.5 6895.5 FET MWD HOUR 0.13 48.88 0.984884 6589 3601.5 6895.5 NPHI MWD PU-S 14.26 101.07 39.2659 6585 3560.5 6852.5 FCNT MWD CNTS 72 1046 228.71 6587 3559.5 6852.5 NCNT MWD CNTS 13425 34651 19364.9 6585 3560.5 6852.5 RHOB MWD G/CM 0.852 3.002 2.17698 6481 3627.5 6867.5 DRHO MWD G/CM -1.341 0.855 0.101579 6481 3627.5 6867.5 PEF MWD BARN 0.94 10.69 2.24841 6588 3574.5 6868 First Reading For Entire File... ...... .3559.5 Last Reading For Entire File.......... .6935 File Trailer Service name.. ......... ..STSLIB.001 service Sub Level Name. . . Version Number..... ......1.0.0 Date of Generation.... ...04/12/15 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..... ..04/12/15 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF GR FET RPD RPM RPS 2 header data for each bit run in separate files. 2 .5000 START DEPTH 3559.5 3560.5 3560.5 3574.5 3595.0 3601.5 3601.5 3601.5 3601.5 STOP DEPTH 6852.5 6852.5 6852.5 6868.0 6888.5 6895.5 6895.5 6895.5 6895.5 RPX DRHO RHOB ROP $ 3601._ 3627.5 3627.5 3640.5 6895.5 6867.5 6867.5 6935.0 # 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 VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 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..................O Data Specification Block Type.....O Logging Direction...... ........ ...Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing........ ............ .60 .1IN Max frames per record.. ...........Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 02-DEC-04 Insite 66.37 Memory 6935.0 3640.0 6935.0 58.7 67.2 TOOL NUMBER 87224 109110 113413 156401 6.750 3635.0 Water Based 9.00 81. 0 9.0 250 4.8 .040 .030 .020 .050 65.0 95.0 65.0 65.0 Name Service Order Units S. Nsam Rep Code Offset Channel . DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3559.5 6935 5247.25 6752 3559.5 6935 ROP MWD020 FT/H 0.32 787.14 214.389 6590 3640.5 6935 GR MWD020 API 15 143.34 77.206 6588 3595 6888.5 RPX MWD020 OHMM 2.5 2000 28.722 6589 3601.5 6895.5 RPS MWD020 OHMM 2.55 2000 22.9826 6589 3601.5 6895.5 RPM MWD020 OHMM 2.64 2000 33.4556 6589 3601.5 6895.5 RPD MWD020 OHMM 2.43 2000 34.4386 6589 3601.5 6895.5 FET MWD020 HOUR 0.13 48.88 0.984884 6589 3601.5 6895.5 NPHI MWD020 PU-S 14.26 101.07 39.2659 6585 3560.5 6852.5 FCNT MWD020 CNTS 72 1046 228.71 6587 3559.5 6852.5 NCNT MWD020 CNTS 13425 34651 19364.9 6585 3560.5 6852.5 RHOB MWD020 G/CM 0.852 3.002 2.17698 6481 3627.5 6867.5 DRHO MWD020 G/CM -1. 341 0.855 0.101579 6481 3627.5 6867.5 PEF MWD020 BARN 0.94 10.69 2.24841 6588 3574.5 6868 First Reading For Entire File.... ..... .3559.5 Last Reading For Entire File...... ... ..6935 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......04/12/15 Maximum Physical Record..65535 File Type.................LO Next File Name.... .......STSLIB.003 Physical EOF Tape Trailer Service name.... ..... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ......UNKNOWN Continuation Number.... ..01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name......... .~KNOWN 4IIÞ Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
