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Home My WebLink About201-202C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-23_22024_KRU_1D-105A_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22024 KRU 1D-105A 50-029-22843-01 Caliper Survey w/ Log Data 23-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:201-202 T36681 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.03 09:04:29 -08'00' 5HJJ-DPHV%2*& )URP0RUDOHV7RQ\7RQ\0RUDOHV#QDERUVFRP! 6HQW6DWXUGD\0D\30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F+HQVRQ-DPHV&R]E\.HOO\16.5:2&0 6XEMHFW(6.58'$%23(7HVW $WWDFKPHQWV1DERUV(6[OV[ dŽŶǇDŽƌĂůĞƐ ϳ^ZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'/E͘ KĨĨŝĐĞϵϬϳϲϳϬͲϲϭϯϮDŽďŝůϴϬϱϳϵϳͲϲϳϮϬ ƚŽŶǇ͘ŵŽƌĂůĞƐΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:7ES DATE: 5/19/22 Rig Rep.: Rig Phone: 670-6132 Operator: Op. Phone:670-6130 Rep.: E-Mail Well Name: PTD #22012020 Sundry #322-218 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:646 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1P Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 2P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 2 7/8"x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 3 1/2" x 5 1/2"NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2 1/16 Gate P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1550 P Quantity Test Result 200 psi Attained (sec)20 P No. Valves 16 FP Full Pressure Attained (sec)113 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5@1994 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:6.0 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5-17-22/ 18:37 Waived By Test Start Date/Time:5/18/2022 21:00 (date) (time)Witness Test Finish Date/Time:5/19/2022 3:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Nabors Tested with 3 1/2" test jnt. CMV #12 FP grease valve, retest, passed. Tony Morales / Paul Yearout ConocoPhillips L. Toussant / Mark Adams KRU 1D-105A Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0519_BOP_Nabors7ES_KRU_1D-105A 9 9 9 9999 9 9 9 9 9 9 -5HJJ FP CMV #12 FP 5HJJ-DPHV%2*& )URP:DUG'XVW\.'XVW\:DUG#FRQRFRSKLOOLSVFRP! 6HQW7KXUVGD\0D\30 7R'2$$2*&&3UXGKRH%D\/RHSS9LFWRULD72*& &F6HQGHQ57\OHU16.5:2&0:DUG'XVW\. 6XEMHFW1RWLILFDWLRQRI%23XVHRQ1DERUV(6RQ $WWDFKPHQWV'$%23(/HWWHUBBGRF sŝĐƚŽƌŝĂĂŶĚƚŽǁŚŽŵŝƚŵĂǇĐŽŶĐĞƌŶ͕ WůĞĂƐĞƐĞĞĂƚƚĂĐŚĞĚĚŽĐƵŵĞŶƚŝŶƌĞƐƉŽŶƐĞƚŽƵůůĞƚŝŶϭϬͲϬϬϯŝŶŽƌĚĞƌƚŽĚŽĐƵŵĞŶƚƚŚĞƵƐĞŽĨKWĞƋƵŝƉŵĞŶƚŽŶϭͲ ϭϬϱ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͘'ŽŽĚĚĂǇ͘ ƵƐƚǇtĂƌĚ ^ĞŶŝŽƌtĞůůƐŶŐŝŶĞĞƌ KĨĨŝĐĞ͗ϵϬϳͲϮϲϱͲϲϱϯϭ Ğůů͗ϱϬϯͲϰϳϲͲϮϱϭϵ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .58'$ 37' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 19, 2022 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 5/19/2022 at 04:30 hours Well Location: 1D-105A API Number: 50-029-22843-01 PTD Number: 201-202 Rig Name: Nabors 7ES Operator Contact: Dusty Ward. (o) 907-265-6531. (c) 503-476-2519. Dusty.Ward@conocophillips.com Operations Summary: The well had been on losses with seawater fluid from the previous day. The well was being fed about 10 bbls per hour. Fluid level shots should the IA fluid level were dropping and staying at about ~400’ below surface. At approximately 04:00 on 5/19/2022, the BOPE test on 1D-105A was just finishing up. The poppet on the BPV was pressed and fluid began filling the stack, indicating some pressure had built up under the BPV during the BOPE test. The BOPE Blind rams were closed to prevent fluid from filling the stack further and to assess the situation. It was also observed about this time that the IA had increased in pressure to 90 psig. The tubing and IA were both bullheaded for a time, which brought the IA back to 0 psig, but the tubing still seemed to have pressure under the BPV. The well was then circulated down the tubing through BPV and up the IA through a choke house to try and clear any residual gas. After the circulation, both tubing and IA went back on losses. The well continued losses as completion has been getting pulled and laid down. BOPE Used: Blind Ram Reason for BOPE Use: After testing BOPE equipment, the BPV poppet was pressed, fluid began to fill the stack. Actions To Be Taken: Seawater was circulated down the tubing and up the IA to clear any packer gas that had migrated through an open GLM below the packer and up the tubing possibly during BOPE tests. An offset injector that had been on injection through the well kill time frame was turned off in case there was some communication, even though the injector only injects about 100 bbls per day and 1D-105A had been on a vac with feeding it about 10 bbls per hour. The blind rams will be re-tested after laying down the completion. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Dusty Ward Rig Workover Engineer CPAI Drilling and Wells 9 9 9 9 9 9 9 -5HJJ ! " # $! % " & '$ ("" )*$ &+ *# , # -.$ /. 0$$ " ## ! 1 +1 2 $ 3* 45 $6 784 6 * 9*4 6 * :*4 6 & #* 9* & #* :* 94 6 49*6 ;<49*6 30'7=$ " 5 < : < :9*4 6:*4 6 ' ," !< * >< &+ *# # (& * ) !< " .5 .$; *5 -:# * ? ? ? 5@? ?"" #?.$; ! 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°fALASKA GOVERNOR MIKE DUNLEAVY September 4, 2019 Mr. Erik Keskula Manager, North Slope Integrated Operations and Projects ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH 19-026 Defeated Safety Valve System KRU 1D -105A (PTD 2012020) Dear Mr. Keskula: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed ConocoPhillips Alaska Inc (CPAI)'s August 28, 2019 explanation regarding the defeated safety valve system on Kuparuk River Unit ID -105A. CPAI presented the findings from its internal investigation and actions that are being implemented to prevent recurrence of defeated well safety valve systems at CPAI- operated wells within Alaska, specific to those systems incorporating the Bettis surface safety valve actuator. The continuous improvement actions listed in CPAI's response address the concerns identified in the violation. The AOGCC does not intend to pursue any further enforcement action regarding the Kuparuk River Unit 1D -105A defeated safety valve system. Sincerely, �p %�%� r�Yl� e :7�. C `- Jessie L. Chmielowski Commissioner cc: AOGCC Inspectors (via email) ConocoPhillips August 28, 2019 Jessie L. Chmielowski Commissioner Alaska Oil and Gas Conservation Commission 333 West 71h Avenue Anchorage, AK 99501-3572 Erik Keskula Manager North Slope Integrated Operations and Projects Post Office Box 100360 Anchorage, Alaska 99510 ATO -1220 Phone 907.263.4822 Erik, Keskula@conocophillips.com Re: Docket Number: OTH3�0� Defeated Safety Valve System KRU 2W1% (PTD�191A�86j� I T) , 1 Uy ��TD Zb12o20 Dear Commissioner Chmielowski: On August 2, 2019, the wellhead safety valve system (SVS) was found to be defeated during an AOGCC witnessed performance test of the 1D -105A well in the Kuparuk River Unit (KRU). ConocoPhillips Alaska (COPA) started an investigation of the matter on the same day. In a letter received August 14, 2019, the AOGCC asked COPA to provide the Commission with a written summary of its internal investigation report, and to describe what has been or will be done in the future to prevent recurrence. This letter is COPA's response to that request. Description of Incident: The State witnessed 6 -month pad test for DS -1D was being conducted on August 2, 2019. During the testing of 1D -105A, the surface safety valve (SSV) did not actuate when it should have, and the well failed the test. The low pressure pilot (LPP) was set to trip at 100 psi, but failed to trip even when the pressure was bled to below 60 psi. At that point in the test, the SVS technicians began to troubleshoot. They noticed that the reset valve toggle lever for the Bettis SSV actuator, which allows the pilot to automatically reset after the low pressure and high pressure switches are satisfied, was in the inverted position (pointing up instead of down). In this inverted position, the toggle lever can — and in this case did — prevent the pilot from automatically resetting, effectively defeating the SSV. Jessie L. Chmielowski Commissioner, AOGCC Page 2 When the SVS technician flipped the toggle lever back to the auto/run position, the SSV immediately tripped. The well was immediately retested with the toggle lever in the same inverted position and the well passed the second test. The SVS technician returned the auto/run toggle lever to the normal orientation of hanging down. Summary of Findings From Investigation: COPA completed an investigation into the defeated SVS on August 5, 2019, and found the following: • Well 1D -105A has a Bettis SVS system, this Bettis system is used on several West Sak and Tabasco wells on DS1C, 1D and 2T. It is not the most commonly used SVS system at Kuparuk. • The Bettis SSV actuator utilizes a manual reset valve that has a shaft that retracts ^7/16" when low pressure is sensed. There is a toggle lever at the end of the shaft that normally hangs loose with —1/16" clearance when in the auto/run position. When the valve needs to be reset, the toggle lever is flipped out horizontal, which is the manual reset position. The manual reset position pulls the shaft out "3/8", which allows the system to be repressured. • When the system is fully pressured, it extends the shaft the extra 1/16" which allows the toggle lever to automatically return to the auto/run position. There is a spring in the toggle lever to ensure that regardless of the orientation of the toggle lever, that the toggle lever will not remain in the horizontal (manual reset) position. This functionality is intended to ensure that the system cannot be left in a defeated state. • This toggle lever and the shaft freely rotate so the toggle lever can be in any orientation -- downward, on its side, or inverted (i.e., toggle lever positioned upward). The spring built into the toggle lever is designed to keep the lever at enough of an angle that the shaft will fully retract and actuate the SSV no matter the orientation of the toggle lever. • The manufacturer does not specify a required position for the toggle. It can be pointing up, down or to the side. The spring in the toggle lever is intended to keep it at enough of an angle that it will always allow the shaft to fully retract. • From field testing, it appears that if the toggle lever hangs at an angle of less than 20 degrees in an inverted position, there is a potential for the toggle to get pulled into the manual reset or a defeated position instead of getting pulled into the auto/run position. • The investigation found that the toggle lever was inverted, and the spring had weakened enough that it could allow the toggle lever to lay down close enough to horizontal so that Jessie L. Chmielowski Commissioner, AOGCC Page 3 when the pressure switch saw a low pressure and dumped the SSV, the toggle lever hung up in the horizontal position and didn't allow the SSV to actuate. Auto Run Position, Hanging down Auto Run Position, Inverted Manual Reset Position As a result of this incident, we are focusing our continuous improvement efforts in these areas: • We are updating our procedure to include the consequence of deviation for leaving the toggle lever in the inverted position and an explanation of why the toggle lever should not be left in the inverted position so that the learnings are carried forward to new Operators over time. • We have modified the toggle levers to accept a custody seal to ensure that the toggle will be positioned to reliably trip regardless of the condition of the return spring or orientation of the toggle lever. This will also require the custody seal to be broken if the switch is required to be placed in the manual reset position. • We are distributing a fieldwide bulletin that highlights the importance of the orientation of the toggle switch and illustrates the correct installation of custody seals. • We have added a step to test the SSV with the toggle switch in the inverted position during our SVS PM's to verify that the spring and custody seal are allowing the switch to operate normally and not allowing the device to be defeated. Conclusion: ConocoPhillips has developed a robust SVS management program over the past eight years that has improved overall performance, and we regret this setback. It is important to note, however, that this incident was not the result of improper operation. The failure that occurred was the result of an unexpected confluence of circumstances — primarily, the inverted orientation of the Bettis valve Jessie L. Chmielowski Commissioner, AOGCC Page 4 — that prevented the system from working as designed. Inverted orientation of the Bettis valve toggle lever will not always (or even usually) prevent proper resetting, but it can. With the learnings we have obtained from a close analysis of the incident, we have implemented steps to help ensure it does not happen again. COPA is dedicated to continued improvement of our SVS performance, and we recognize that reliable SVS performance in compliance with AOGCC regulations is required. We will provide updates on the status of these efforts to the AOGCC during our annual face to face meetings. Yours truly, Erik Keskula THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY August 12, 2019 CERTIFIED MAIL — RETURN RECEIPT REQUESTED 7015 0640 0006 0779 5234 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH 19-026 Notice of Violation Defeated Safety Valve System KRU 113-105A (PTD 2012020) Dear Mr. Wolfe: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov On August 2, 2019 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed a safety valve system test on Kuparuk River Unit (KRU) 1D -105A that was performed by a ConocoPhillips Alaska Inc (CPAI) representative. The safety valve system on KRU 1D - 105A was found defeated. Investigation revealed that the low-pressure pilot was in the incorrect operational position preventing pressure from dumping and actuation of the surface safety valve. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. CPAI is reminded that a completed well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph (m) of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on KRU 1D -105A that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system — except as provided in 20 AAC 25.265 — will not be tolerated. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written summary of its internal investigation report and describe what has or will be done in the future to prevent its recurrence at CPAI-operated fields in Alaska. Failure to comply with this request will be an additional violation. Notice of Violation Docket Number: OTH 19-026 August 12, 2019 Page 2 of 2 The AOGCC is reviewing this violation as well as past commitments made by CPAI to implement corrective actions in response to defeated safety valve systems. We reserve the right to pursue additional enforcement action in connection with the recent defeated safety valve systems in the KRU. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Je ie�ielowski Commissioner Attachment cc: P. Brooks AOGCC Inspector Reviewed By: Safety Valve & Well Pressures Test Report P.I.Supry Comm Pad: KRu_ID InspDt: 8/2/2019 Inspected by Adam Earl Interval InspNo sysAGE190805074325 Related Insp: Field Name KUPARUK RIVER Operator ConocoPhillips Alaska, Inc. Operator Rep Joey F Reason 180 -Day Src: Inspector Well Data Pilots SSV SSSV Shutla DL Well Type Well Pressures Gas Lifr Waiver Comments Well Permit Separ Set UP Test Test Test Date Sl Oil,WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code OAR rYr1 E St pSt M? Der veerno, vnv_ ID -01 1790590 90 70 68 P P NA 1 -OIL 1200 1000 170 Yes Yes IA X OA ID -04A 2080540 90 85 78 P P NA 1-0B. 1175 t 150 161 Yes Yes IA X OA ID 08 1770530 90 70 56 P P NA 1-0I1, 1100 250 161 Yes No ID -105A 2012020 90 100 0 43 P NA 1 -OIL 50 202 No No Mono bore. Failed to trip due to ID -108 1981870 90 100 97 P P NA 1-0d 350 153 No No switch defeating safety system, was reset and passed retest @ 102psi. mono bore 10.11 1990720 2000 1732 P P NA WAGIN 1050 240 2764 No No gas inj. 10.112 1981830 90 100 96 P P NA I -OIL 200 171 No No mono bore 10.115 1972320 90 100 46 P P NA 1 -OIL 680 165 No No mono bore ID -116 1981720 90 100 94 P P NA 1 -OIL 940 170 No No mono bore 10.12 1990840 90 85 87 P P NA I -0Q. 1050 650 159 Yes No ID -123 1981700 90 100 98 P - P NA 1-0IL 25 166 No No mono bore ID -124 1972170 90 70 75 P P NA ]-OIL 120 157 No No mono bore ID -129 1972130 90 85 85 P P NA 1 -OIL 100 164 No No mono bore 10.133 1972060 90. 100 96 P P NA 1 -OIL 850 163 No No mono bore 10.141A 2080160 90 70 80 P P NA 1-0IL 700 0 176 Yes No ID -143 2141450 90 100 87 P P NA 1_OIL 600 150 172 Yes No ID -145 2141380 90 100 98 P p NA 1-0I1, 170 280 168 No No ID -146 2141390 90 70 63 P P NA 1 -OIL 375 100 164 Yes No 1D-28 2042370 90 85 86 P - P NA 1 -OIL 1250 350 165 Yes No ID -30 2001040 90 85 75 P P NA 1 -OIL 1050 300 169 Yes No ID -36 2001300 90 70 70 P P NA 1-0IL 1100 400 174 Yes No ID -37 2002040 90 100 94 P P NA 1-0IL 800 200 166 Yes Yes OA X OOA ID40A 1D-41 2001900 2051880 90 2000 85 2019 79 P P P P NA NA WAGIN I -OIL 1650 1000 400 350 3541 164 No Yes No No gas inj 10.42 2001640 90 85 91 P P NA 1 -OIL 600 500 185 Yes No Comments Monday, August 12, 2019 Page I of I Performance Wells Components Failures Failure Rale 25 50 I 2 a Er M1 F[3R�R l Fee M1 C3 es&Faesfcheckbu`, add laeu eppmpnadl ceipt lflaMd p}'�cpt(aiivvrv`4 $ FoalreelkOall nesnnea Delivery S Here Onature negulred $ C3 S< o s Mr. Patrick Wolfe Lr, : ConocoPhillips Alaska, Inc- a P.O. Box 100360 E3 171 , Anchorage, AK 99510-0360 ■ Complete items 1, 2, and 3. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach'this'batd to. the back of theit ce, fn or on the front if space permits. Mr. Patrick Wolfe ConocoPhillip's Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 III�III�I IIII I�IIII II II II III I I�IIIII�IIII II SII 9590 9402 3704 7335 2702 29 Article Number firsnsrer rrom �_, •�_ •��•• 7015 0640 0006 0779 523L PS Form 3811, July 2015 PSN 7530-02-000-9053 X _ d! U' Adc R. Received (Print d-ql e) C. Date of l OZIv s a O l idress different from item 17 1 Yes -; delivery address below: ❑ No 3. Service Type U.S. Postal Service'" 0 Certifled Mail® [3Centied Mail Restricted Delivery Deli❑ Return Receiptfar ❑ Called on Delivery Collect on Delivery Restricted Delivery Merchandise ❑ Signature Confirmation•'" [I 0 Signature Confirmation BailI. — __.. __....__. Restricted Delivery CERTIFIED MAIL® RECEIPT Domestic Mail Only For delivery information. visit our website at www.usps.com'. Er M1 F[3R�R l Fee M1 C3 es&Faesfcheckbu`, add laeu eppmpnadl ceipt lflaMd p}'�cpt(aiivvrv`4 $ FoalreelkOall nesnnea Delivery S Here Onature negulred $ C3 S< o s Mr. Patrick Wolfe Lr, : ConocoPhillips Alaska, Inc- a P.O. Box 100360 E3 171 , Anchorage, AK 99510-0360 ■ Complete items 1, 2, and 3. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach'this'batd to. the back of theit ce, fn or on the front if space permits. Mr. Patrick Wolfe ConocoPhillip's Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 III�III�I IIII I�IIII II II II III I I�IIIII�IIII II SII 9590 9402 3704 7335 2702 29 Article Number firsnsrer rrom �_, •�_ •��•• 7015 0640 0006 0779 523L PS Form 3811, July 2015 PSN 7530-02-000-9053 X _ d! U' Adc R. Received (Print d-ql e) C. Date of l OZIv s a O l idress different from item 17 1 Yes -; delivery address below: ❑ No 3. Service Type ❑ Priority Mail Express® ❑ Adult Signature ❑ Adult Signature Restricted Delivery 0 Registered MajITM d Mall Restricted El Registered 0 Certifled Mail® [3Centied Mail Restricted Delivery Deli❑ Return Receiptfar ❑ Called on Delivery Collect on Delivery Restricted Delivery Merchandise ❑ Signature Confirmation•'" [I 0 Signature Confirmation BailI. — __.. __....__. Restricted Delivery Domestic Return Receipt STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL7 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Opefatiod5.shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well M Re-enter Susp Well ❑ Other: CO ESP 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development G] Exploratory ❑ Stratigraphic❑ Service ❑ 201-202 3. Address: P. O, Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22843-01 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1D -105A ADL 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,820 feet Plugs measured None feet true vertical 3,830 feet Junk measured None feet Effective Depth measured 9,805 feet Packer measured 2635, 5150, 5460 feet true vertical 3,830 feet true vertical 1962, 3551,3775 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80 feet 16 121' MD 121' TVD PRODUCTION 5,172 feet 7 5/8 " 5,212' MD 3608' TVD SCREEN LINER 4,660 feet 4 1/2 " 9,810' MD 3830' TVD Perforation depth: Measured depth: 5597-9725 feet True Vertical depth: 3790-3830 feet Tubing (size, grace, measured and true vertical depth) 3.5" L-80 5,116' MD 3,521' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- WEATHERFORD HYDRO 11 PACKER 2,635' MD 1,982' TVD PACKER- BAKER ZXP LINER TOP PACKER 5,150' MID 3,551'TVD PACKER- BAKER PAYZONE EXTERNAL PACKER 5,460'MD 3,775'TVD SSSV-NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 105 35 17 15 200 Subsequent to operation: 145 48 88 10 210 14. Attachments (required per 20 AAC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations [21 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-278 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: kyle.hampton@cop.com Authorized Title: Sr. Wells Engineer n Contact Phone: (907) 263-4627 Authorized SignatureDate : -112-1 1 I9 IF Form 10-404 Revised 4/2017 V7-1— Submit Original Only 10K'1/ RBDMS�`"'JIUL 3 12919 VEI KUP PROD WELLNAME 1D -105A CO(IOCOPFIill)p5m'' Wall Attributes IFIetl Name WeIIWre APWW1 WeIIWre Alaska. h10. WEST SAK SOn"I'sai0, oGnn WELLBORE 1D -105A tOnISA 743120912ffi15 PM Last lag VM4d acremaEc l+sVel) Anapidlan I Ba,"Ll' B1 I En0eH0 I WNlban, InstMpl By Last Tag: 1D-1054 Imosbor .........._.................x..wii.3._._ ...._. Last Rev Reason Arnaud-En00ate Welllgre LaarMW By Rev Reason'. Installed PCP 8 pro, set Prod PKR, swapped SOV anb DV ]/12019 1D -105A haze mc Casing Strings Caslnp Dasnlptlon OO(in) In (I"rpp hail CONDUCTOR 16 15.06 OTO SN Deptn IKI Set Depth(NO)... ads 121.0 121.0 62.58 (I.. GnEe Top Th. H40 WELDED 4slnp Desenpron OD Pro IO fnlTov MKS) PRODUCTION Post ]SIB 6.87 405 Sidetrack $M Dep1n Mae) Set thotn(1Pd[d Nadal 5,212.0 3,608.4 29.]0 K... craEe Top Tnread L-80 BTCM CONpDOTOR. 4, 0-1210 Capnp DescnpWn OB(In) 1Olin, Top(KKal IS. SCREEN LINER 4112 396 5,149.6 Depen MKB) Sad Depth nal WVIea 9,8100 3,830.3 1260 (I_. GnM rev Tnreae L-80 EUEBRD Liner Details Nominal ToplKKe) rpp (TV.) Muse) top Incl I') onlD s com p0-) 5,td9.6 3,551.1 2420 PACKER BAKER ZKP LINER TOP PACKER 4.8 ---57182 3.568.1 23.59 HANGER BAKERCMCLINERHANGER 57 5,460.2 37]49 71.52 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.30 avz waM9 Menprel 1117 5523.1 3,]8].4 85.5] SLEEVE BAKER CMD SLIDING SLEEVE 3.430 Tubing Strings Tueias De... pmn senna Ma_ID Tubing -ESP 31/2 Production lent 2.99 Top (nKBI aet 353 5,1162 Deptn 10-_$81 Depen mDl l-. 3.520.8 wr nlMl 9.30 Grade L80 ropconn-pan EUE a ii all Completion Details PsbC i.aLs TOP (ND) Toplhcl Nominal Top Lasup MN.) I.1 It.. IS. Com 10 (in) 353 35.3 000 Hanger Vetco Giaytt"x3112"Hanger EUE-ModOxP 2.90 7,6345 1,982.4 51.67 Decker Weatherford 3- 'X]-51 'Hydra 11 Packer 1l NU It 2908 toad NU (2630') alar KaMp Manan zmDs 50098 3,426.0 25616 DiSMarge Sub Summit presure discallge sub, ACE, 3-12'BE 2.992 (ESP) 5,0823 3,490.3 26.39 Bushing Summit TCEDE Receiving base 2992 5,0869 3,4944 26.24 Seel Seal 5104.8 3,518.5 2566 E P Motors GRU to seal Sdepter Gwlarq 8i01ESP1; Sol Cables 5,1074 3,512.8 25.58ESP Met.,. Motor 562 Series. KMI 60HP18)9V/3)A, High Frequency Cables 5,113.] 3,518.5 253] auge omp Sensormator Adapterandsensor supsrop;spe4.o Sensor 5,115.6 3,520. 25.31 Generalizer CentralizerIMobr Guide PADKOFF, s,o4so Ogler In Hole (Wirolino rtrievable pluga, valves, pumps, fish, aft.) Top LIVID) I Ta lnc ESPcp PUMp;s,tua.o Tap OMe) InKB) r) Des Co. Run Dare In (in, 5,044.0 3,456.1 2].65 SUPSTOP 3.5"SUPSTOP )/V2019 1600 5,00.5.0 3,45].0 2].61 PACKOFF 15 PAOKOFR (011=93.6") 6130 18 1.625 5049.0 3,46.6 2)48 ESPCPPUMP J 5"x It U Support ESPCP RKIR Tc7pOF 6/302019 PUMP @ 5051 RKB) I m Perforations & Slots ESP miar s S Cegss 5,10] 4 $hd I TepnIXB) Bbn 1dK6) iap (N01 IKKBI Bbn(TV01 IBKB) UnRMInne peer Mns (sho6M ) TyPo Gem 3,829.6 WSg10-105A 110-2001 500 SLOTK SCREENS I ja'k.' e5) ALTERNATING WITH BLANK PIPE (31,5' ea) Mandral Inserts 0 N Tap(KKBI Top 1N0) MIKE) III Model Val" OO(iia sa- Type Iakh Type Pon Ske TRO (ln) (pap Run Run Oeb tom PRI ACTIONPutSMepckl Wsaana.- 1 215]7] 1,949.6 JVMO,I KBMG 1 ESP lov BK 0.3]5 ]112819 2 2,6902 14) Camce KBMG t ESP SOV BK )112019 psI Wpi n 9 Notes: General 8 Safety 4 End Da Ann..,...11/22001 NOTE: SIDETRACK 8 ESP WORKOVER 7021/2005 NOTE: ESP WORKOVEH 8/1912010 NOTE: View Scheman.1 Alaska Schern ic9.0 ..a sswae,]a o_ 1 SCREEN LINER: 5,169. ` 9.510 I Report Pnnted: 7/16/201 Summary (Detailed) FiSOperations 1D-105 Rig: NABORS 7ES Time Log Job: RECOMPLETION Sfart Time no Time 6/22/2019 6/23/2019 Dur (hr) Phase 13.00 MIRU Op Cone Activity Code MOVE MOB Stan Depth (fiK8) End Dept (flKBj Dept Prog (ft) 11:00 00:00 Finalize Rigging downOpeneboand mobilize 0.0 0.0 6123/2019 6/23/2019 7.00 MIRU MOVE MOB from 1 F-12 to 1D-105 00:00 07:00 Cont. moving sub from 1 F. Spot sub .0 0 0.0 over well. Back pits up to sub. 6/23/2019 6/23/2019 Spread herculite and set pits down. 07:00 14:00 7.00 MIRU MOVE RURD Set cuttings box. Install safety nets .0 0 0.0 on derrick lights. Hook up steam, water, mud lines and electrical in interconnect. Set tiger tank. R/U hard line and choke house. Finish berming rig. Raise derrick. Bridle down. Raise cattle shoot. Hang rig tongs. Take on 8.6 PPG 3% KCL. 6/23/2019 14:00 6/23/2019 1.00 MIRU WHDBOP MPSP Rig accepted at 13:00 Install secondary IA valve. Pull tree 1500 cap. Depress poppet on H BPV. Pull 0.0 0.0 BPV. Install HP BPV. Install test 6123/2019 15:00 6/23/2019 15:30 0.50 MIRU WHDBOP PRTS dart, Pressure test HP BPV from above 0.0 1000 PSI for 10 Min - Good test. B/D 0.0 6/23/2019 15:3 6/23/2019 6.75 MIRU WHDBOP NUND tree. R/D testing equipment. ND tree and adpter and NU BOPE 22:15 0.0 0.0 6/23// 2019 6/23/2019 0.25 MIRU WHDBOP SFT Y prepare for testing. PJSM for testing BOPE. 22:15 22:30 0.0 0.0 6/23/2019 22:30 6/24/2019 00:00 1.50 MIRU WHDBOP BOP E Test BOPE Witness waived by 0.0 AOGCC rep Brian Bixby 0.0 Test 1: BR, CMV's 1,2,3,16, 2" Demco Kill, IBOP Test 2: BR, CMV 456 HCR Kill, Saver sub(TD) Test 3: BR, CMV's 7,8,9, Manual Kill, 6/24/2019 0000 6/24/2019 4.00 MIRU WHDBOP BOPE HT 38 SV Test 4: Super choke, Manual Choke, 04:00 Test 5: Annular, FOSV, HT38 Dart 0.0 0.0 Valve, CMV 10,11 Test 6: UPR, CMV, 12,13,15, Manual Kill Test 7: UPR, CMV's 14, Manual Kill Test 8: UPR, Choke HCR, Man Kill Test 9: UPR, Manual Choke, Man. Kill Test 10: LPR Koomey test Time to recover = 119 seconds. All gas alarms, PVT system. Witness waived by AOGCC rep Brian Bixby F/P on annular. Functioned annular 6/24/2019 04:00 6/24/2019 3.00 MIRU WHDBOP RURD and passed re -test. R/D testing equipment. B/D 07:00 all surface equipment. 0.0 0.0 R/U Summit ESP sheave in derrick with trunk and herculite to spooling 6/24/2019 07:00 6/24/2019 09:00 2.00 MIRU WELCTL WAIT unit. Wait on GE isolation sleeve to seal 0.0 6/24/2019 6/24/2019 0.50 MIRU WELCTL MPSP off horizontal port on hanger. 0.0 09:00 09:30 Pull test dart and HP BPV. Installed 0.0 0.0 09:30 019 6/24/2019 10:30 1.00 MIRU WELCTL RURD isolation sleeve in hanger. M/U landing joint, XO, side entry sub 0.0 and top drive. 0.0 6/24/ 10:30 019 10:30 6/24/2019 11:00 0.50 MIRU WELCTL SFTY PJSM with LRS, GE and rig crew on 0.0 pulling hanger antl packer and 0.0 bullhead kill. Paa¢ 1/d Report Pnnted: 7/16/201 Operations Summary (Detailed) 1 D-105 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Time End Time Our (hr) Phase Op Code Activity Code Opemuon sled Depth (ftKB) End Depth (rtl(B) 090 Pmg (ft) 6/24/2019 6/24/2019 0.25 MIRU WELCTL PULL Close annular. BOLDS. Pull hanger 0.0 0.0 11:00 11:15 came off seat at 100K. Packer released at 190K. P/U 6' into stack. 6/24/2019 6/24/2019 0.75 MIRU WELCTL PRTS Pressure test with LRS against kill 0.0 0.0 1115 12:00 HCR and lo -torque on cement line to 3000 PSI - Good test. 6/24/2019 6/24/2019 6.00 MIRU WELCTL KLWL LRS pump 15 Bbls 170 degree diesel 0.0 0.0 12:00 18:00 down tubing at 3/4 BPM. No pressure LRS pump 50 Bbls 170 degree diesel down IA at 3/4 BPM. 500 Pressure Let diesel soak for 30 Min. Attempt to bullhead 140 degree 8.6# 3% KCL down IA pressured up to 2500 PSI. Allowed packer to relax for additional 30 min. Pulled string additional 4' up hole placing hanger above mud cross Bullhead 50 Bbls KCL down IA 1.7 BPM 2500 PSI Bullhead 60 Bbls KCL down tubing 4.5 BPM 400 PSI Bullhead 180 Bbls KCL down IA 1.25 BPM 2500 PSI 6/24/2019 6/24/2019 0.50 MIRU WELCTL OWFF Pre tour/Crew C/O. OWFF for 30 0.0 0.0 18:00 18:30 minutes no flow. 6/24/2019 6/24/2019 1.50 MIRU RPCOMP RURD RD circulating lines verify no flow at 0.0 0.0 18:30 20:00 annulus or tubing. 6/24/2019 6/24/2019 0.50 MIRU RPCOMP CIRC Turn on hole fill get static fluid 0.0 0.0 20:00 20:30 volume of 22BBL's 6/24/2019 6/24/2019 1.00 MIRU RPCOMP THGR Pull hanger to floor, disconnect ESP 0.0 0.0 20:30 21:30 cable from pentrator. Break out hanger and inspect. Summit rep performed continuity check on cable. DHD shot fluid level at 637 after 30 minutes. 6/24/2019 6/24/2019 0.25 MIRU RPCOMP RURD Rig summit esp cable through 0.0 0.0 21:30 21:45 sheave to spooler. 6/24/2019 6/25/2019 2.25 MIRU RPCOMP PULL Start pooh with completion from 0.0 0.0 21:45 00:00 5092' LD 3-1/2" tubing F/5116' to 4800'. hole fill 5 BBL's every 10 joints. 6/25/2019 6/25/2019 2.00 COMPZN RPCOMP PULL Continue to LD 3-112" tubing from 0.0 0.0 00:00 02:00 4800' hole fill 5 BBL'S every 10 jts. Top off hole with 35 bbl's. Fluid level at approximately 1029'. Fill hole again 35 BBL's fluid to top off the well. Over pulled 30K 2 times while POOH. PU WT=130K worked back to 100K PU. 6/25/2019 6/25/2019 0.50 COMPZN RPCOMP PULL Well started to U-tube up the tubing. 0.0 0.0 02:00 02:30 Stabbed safety valve shut in and secured well. 6/25/2019 6/25/2019 0.50 COMPZN RPCOMP OTHR All personnel) affected by diesel from 0.0 0.0 02:30 03:00 U-tube went to medic for evaluation. Ordered more fluid to double displace disel from wellbore to the top perfs. 6/25/2019 6/25/2019 4.50 COMPZN RPCOMP OWFF Tubing out of balance by 100 psi on 0.0 0.0 03:00 07:30 tubing gauge. 0 psi on casing gauge. Wait on fluid for double displacement. Clean rig. 6/25/2019 6/25/2019 1.00 COMPZN RPCOMP RURD RU to circulate down the IA laking 0.0 0.0 07:30 08:30 I I returns up the tubing. and down the tubing taking returns up the IA. Page 214 ReportPrinted: 711612019 Operations Summary (Detailed) 1D-105 Rig: NABORS 7ES Job: RECOMPLETION Time Log stan rime I End rime Dur (no Phase op Coda Activity Code Operation start Depin (111(6) End DeW (nke) Depth Pmg (d) 6/25/2019 6/25/2019 3.25 COMPZN RPCOMP CIRC Reverse circulate down the IA taking 0.0 0.0 08:30 11:45 returns up the tubing. maintained a 25% average return rate, diesel in returns for 250 BBL's. Circulated at 4BPM until dean 8.5 ppg returns at lank. Caught fluid at 20 BBL'S, returns at 32 BBL'S. 268 total BBL'S purred 90 BBUs returned. Shut down and swapped to pump dawn the tubing taking returns up the IA. staged pump up to 5 BPM. maintained average return rate between 17% and 20%. Lost returns with 400 BBL'S pumped to IA. 550 total BBL's were pumped to well. 6/25/2019 6/25/2019 0.50 COMPZN RPCOMP OWFF Monitor well for flow bled off tubing. 0.0 0.0 11:45 12:15 no flow after 30 minutes from IA or tubing. 6/25/2019 6/25/2019 3.75 COMPZN RPCOMP RURD Blow down top drive and kill tank line 0.0 0.0 12:15 16:00 RD circulating lines. Continue Monitoring well static losses Average loss 18-25 bbls hrs 6/25/2019 6126/2019 8.00 COMPZN RPCOMP PULD Continue POOH w/ ESP cable L/D 3 0.0 0.0 16:00 00:00 1/2" EUE 9.3 # L-80 Tubing 6/26/2019 6/26/2019 3.00 COMPZN RPCOMP SHAH L/D ESP perforated unit / Intake 0.0 0.0 00:00 03:00 Tandem seal section RID ESP cable and Clean up floor and C/O cable spool R/U New ESP cable spool hold PJSM. Simultaneously monitor and fill hole every hour. 6/26/2019 6/26/2019 6.00 COMPZN WHDBOP BOPE PU test joint and lest plug run in- 0.0 0.0 03:00 09:00 kind, RU test hose fill stack, purge system. Test Annular to 250/2500 psi Pull Test plug and test joint Continue R/U Summit as we go 6/26/2019 6/26/2019 3.50 COMPZN RPCOMP PUTB RU Summit and pick ESP completion 0.0 0.0 09:00 12:30 equipment MU motor assemble splice connection fill motor MU and run. Siultaneously fill hole every hour. 6/26/2019 6/26/2019 9.50 COMPZN RPCOMP PUTB Pick up first joint of tubing at 12:00 0.0 0.0 12:30 22:00 RIH W/2 Jt's MU discharge sub and terminale control line. make up splice at Jt 3 in hole. Splice and continuity check from 1300 tol530. Filled hole at 1200 36 BBL'S 1330 32BBL's,1500, 32 BBL's 6/26/2019 6/27/2019 2.00 COMPZN RPCOMP PUTB PIU weatherford Hydrow 11 Dual - 0.0 0.0 22:00 00:00 string PKR and Summit make a splice through the Pkr. 6/27/2019 6/27/2019 2.50 COMPZN RPCOMP PUTB Continue with wealherford Hydrow 0.0 0.0 00:00 02:30 11 Dual -string PKR and Summit make a splice through the Pkr.and test same All good 6/27/2019 6/27/2019 5.50 COMPZN RPCOMP PUTB Continue P/U and RIH 3 1/2" EUE 0.0 0.0 02:30 08:00 Tubing w/ ESP cable 6/27/2019 6/27/2019 1.00 COMPZN RPCOMP SVRG Slip and cut drilling line, 0.0 0.0 08:00 09:00 6/27/2019 6127/2019 4.50 COMPZN RPCOMP PUTB Continue to RIH with completion pick 0.0 0.0 09:00 13:30 up pup joints and make up last full joint below hanger. MU hanger to string with HP BPV installed. Terminate ESP cable, splice to penetrator, verified continuity at floor. Page 314 Report Printed: 711612019 Operations Summary (Detailed) 1D-105 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Time I End rme our (hr) Phase Op Code Ac dy Code Operation Start Depth (ft(B) End Depth (ftKB) DepU Pmg (ft) 6/27/2019 6/27/2019 1.00 COMPZN RPCOMP THGR Landed tubing hanger RILDS and 0.0 0.0 13:30 14:30 tested seals to 5000 psi for 10 minutes. Tested HPBPV l0 1000 psi from above for 10 minutes. tested good. Pulled landing joint and L/D. 6/27/2019 6127/2019 1.00 COMPZN WHDBOP RURD PJSM RID ESP cable and sheave, 0.0 0.0 14:30 15:30 clear floor prep to ND BOPE. 6/27/2019 6/27/2019 6.00 COMPZN WHDBOP NUND ND BOPE and NU/ adapter and tree. 0.0 0.0 15:30 21:30 6/2712019 6/28/2019 2.50 COMPZN RPCOMP DHEO Test Pack off and test Tree 250/5000 0.0 0.0 21:30 00:00 PSI all good Pull test Plug and install BPV Secure well and release Rig 0000 Page 414 Report Printed: 7/1 612 01 9 1«t t D ,lob Re2q, James B (CED) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Tuesday, June 25, 2019 2:54 PM To: Loepp, Victoria T (CED); DOA AOGCC Prudhoe Bay Cr. Senden, R. Tyler; NSK RWO CoMan; Hampton, Kyle Subject: Notification of BOP use on Nabors 7ES on 6/25/2019 Attachments: 1 D-105 BOPE Letter 6_25_2019.doc Victoria, Please fine) the attached BOP use notification document in response to Bulletin 10-003 on 1D-105 (PTD# 197-236). Let me know if you need anything else. Thanks, Kyle Hampton Senior Wells Engineer 4 Office. 907-263-4627 1 Cell, 832-421-1506 1 Kyle. Hampton@cop.cam ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 25, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up on BOPE usage on Nabors 7ES with a written report. Time of BOPE Use: 6/25/2019 at 02:15 hours Well Location: ID -105 API Number: 50-029-22843-00 PTD Number: 197-236 '� Ria Name: Nabors 7ES Operator Contact: Kyle Hampton (o) 907-263-4627 (m) 832-421-1506 (e) Kyle.Hampton@conocophilIips.com Operations Summary: On 6/24/2019 at 12:00, the well was killed by bullheading 8.5ppg KCl brine down the tubing and IA. We pumped 125% of the tubing and IA volume and performed a no -flow test. The well was losing consistently at 30 bph. On 6/24/2019 at 21:45, we began pulling tubing out of the hole from 5,116' to 3,900'. On 6/25/2019 at 01:30, we then performed a fluid level check by pumping 33 bbls of fluid down the IA. At the point that we caught the fluid level, the tubing began to flow. When flow was observed, the TIW was stabbed into the ttkbing and annular was shut-in on the IA. No pressure was observed on the IA, but 200 psi was observed on the tubing. We then bullheaded 8.5ppg KCI brine down the tubing and IA, returning to the original fluid level prior to pulling tubing. Our plan forward will be to finish pulling tubing out of the hole, filling the hole at the observed loss rate of --35 bph. The annular preventer will be retested once current operations of pulling the tubing out of the hole is complete. It will be tested to 250 psi and 2500 psi. BOPE Used: Annular Reason for BOPE Use: The annulgr preventer was closed to contain a fluid imbalance in the wellbore. Actions To Be Taken: The annular preventer will be retested once the current operation of pulling tubing is finished. If you have any questions or require any further information, please contact me at 263-4627. Sincerely, Kyle Hampton Rig Workover Engineer CPAI Drilling and Wells THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-105 Permit to Drill Number: 197-236 Sundry Number: 319-278 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907 279.1433 Fax: 907.276.7542 www.00gcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JnLCelowski Commissioner DATED this J day of June, 2019. 1BDMS 4V".1uN 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well try Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 • Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other eO E-5 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 1-1 ' Stratigraphic ❑ Service n 197-236 3 Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 e 50-029-22843-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? i a KRU WSAK 1 D-105 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025650 1 1 KUPARUK RIVER 1 WEST SAK OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi). Plugs (MD): Junk (MD): 9810 3830 9805 3830 1,392 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16" 121 121 Surface 5174 7-518" 5212 3608 Intermediate Production Liner 4660 4-1/2" 9810 3830 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft) 5597'- 9725' 3790'- 3830' 3-112" L-80 5119 Packers and SSSV Type: Packer (Weatherford Feed-Thru Hydro II) Packers and SSSV MD (ft) and TVD (ft): Packer (2657' MD 11995' TVD) SSSV (n!a) SSV (nla) 12. Attachments: Proposal Summary 0 Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 613012019 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. Wells Engineer Contact Email k le.ham toll co .COm 3Contact Phone: 263-4627 Authorized Signature- Date: t�b� COMMISSi USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /0-2'13 q1j Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: B'oP t,_,5 f fb z J Up p 9 fir, rl i/ 14 r P fz r 4t 15;F_ tv Z S D U %i s -`_y ii'' nn +VN �t ! U �� Past Initial Injection MIT Req'd? Yes ❑ No 7f��DIYI�i Spacing Exception Required? Yes ❑ No tle3` Subsequent Form Required: 10-1104 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �Q 1 - 7 9 pp pp cR �&Mtk-pp ,( AS rit, Form and Form 10 3 Revised 4!2017 A roved a lication iS va td of a rova . ents in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 31 May 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 711 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over West Sak Producer ID -105 (PTD# 197-236). Well 1 D-116 was drilled and completed in January 1998 as a West Sak producer well. In December 2005, the ESP failed, and a workover was completed to replace the ESP. In September 2011, the ESP failed again, and another workover was performed to replace the ESP. In February 2019, the ESP failed; the well was shut in for the workover. The objective of this rig workover is to pull 3-112" tubing and ESP from 5,117' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). If you have any questions or require any further information, please contact me at 263-4627. Sincerely, Kyle ampton Senior Wells Engineer CPAI Drilling and Wells 113-105 RWO Procedure West Salk Producer PTD #197-236 Current Status: The well is currently shut in. In February 2019, well passed MIT -T and CMIT to 2500 psi. Scope of Work: Pull 3-1/2" tubing and ESP from 5,117' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). General Well info: MPSP: 1,392 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: West Sak —1,775 psi / 3,830' TVD (8.9 ppg 1=MW) 9.1 ppg KWF Wellhead type/pressure rating: Gray Horizontal, 3 1/8" 5M BOP Config: Annular / Variable Pipe Ram / Blind Ram / Variable Pipe Ram MIT results: CM IT -- Passed to 2,500 psig/Opsig on 2/10/2019 Well Type: Producer Estimated Start Date: June 30, 2018 Production Engineers: Pete Fox (265-6481 / Pete. B. Fox@conocophillips.com) Workover Engineer: Kyle Hampton (263-4627 / Kyle.Hampton@conocophillips.co m) Remaining Pre -Rig Work 1. Pull lower GLV. Vent gas to surface. Replace with DMY. 2. Swap to dry hole tree configuration for RU. 3. Install BPV, Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and bullhead KWF from surface to the pump. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure, and weight up fluid as necessary. Complete 30 -minute NFT. Verify well is dead. 3. Set BPV, ND Tree, NU BOPE and test to 250/ 1,500 psi. Test annular 250/1,500 psi. a. Notify AOGCC of BOP test 24 hours prior to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 4. Pull BPV and MU landing joint. 5. Pull 4--1/2" tubing and lay down the tubing and ESP. Install Tubing 6. MU 4 %" completion with ESP, motor, gauges, and packer. RlH and place the ESP on depth. Set packer with ball and rod. 7. Pressure test tubing to 1,500 psi for 5 minutes. 8. Pressure test inner annulus to 2,500 psi for 30 minutes on chart. ND BOP, NU Tree Page 1 of 2 ID -105 RWO Procedure West Sak Producer PTD #197-236 9. Confirm pressure tests, then shear out SOV with pressure differential. 10. Install BPV. 11, ND BOPE. NU dry hole tree. 12. Freeze protect well. 13. RDMO. Page 2 of 2 KUP PROD 1D -106A ConoCdPhilli� Well Attributes Max Angle & MD TD Alaska, IFIL, Wellbore APNUWI Fleltl Nama Wellboro Status ncf (•] MD IHKDI Act etm IHNe) 500292289301 WEST SAK PROD 91.97 9.037,07 9,820.0 CommelR H25 (pp.) Date SSSV:NONE 0 21472016 Annclatlon Entl Dale KBLrtl {H) Rig Release Date Last WO: 91122011 11 L50 126/1998 10-105A 5n2R0T11268.14 PM eNce nchemetic ldCWlII AnnotatlPn Depth (ttK8) Entl Date La51Tag: Annotation Rev Reason: GLV CIO, REPLACED SLIP TOP, Last Mad By Entl ppmven Dale 511212017 - PACKpFF 8 ESP rIANGER:36.6 y Casing Strings Casing D -011 -OD (fn) ID pnt Top [kK6} Set Depth [HHB) Sel Oapth [TVD(., Wln.on {I... Glade Top Tltreatl CONDUCTOR 16 15.062 410 121.0 121.0 62.58 M40 WELDED C - Ing DaecrlPtlen OD (In) ID {In] Top ("KA) Set Depth [HKDI Sol Depth [TVD}.,. WUun p... Wed. Tap Throaty PRODUCTION POST 7 5/S 6.875 40.5 5,212.0 3.608.4 29.70 L-80 BTCM S)lietrack Caaing Deecrlptlon SCREEN LINER OD [In} 41/2 ID (In) Top [HIS) 3.958 5,149.6 Set Depth [hK8) 9,810.0 ser Depth (TWj 3.830.3 WULM {f... 12.66E-80 Gratle Top Thmad EUE8R0 Liner Details ID WNo. Top(HKnI Top [TVD) Top Ind Ile. Des Co.Com [In) 5,149.6 3,551.1 24.20 PACKER BAKER ZXP LINER TOP PACKER 4.860 5,1682 3,568.1 23.59 HANGER BAKER CMC LINER HANGER 5.760 5,4602 3,774.9 71.52 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.930 5,523.1 3,787.4 85.57 SLEEVE 1 BAKER CMD SLIDING SLEEVE 3.430 ESP MONDREL: 2.529,5 Tubing Strings Tubing De6arlplfon SMng Ma.__ ill (!n) Top 1kKSl Sat Dnpth (H.. Set Depm ITW) (... Wt 0M) Grade Top Conneellon TUBING W02011 31/2 2.992 36-8 5,1192 3.5235 9.301L.00 EUE-MOD Completton Details Nominal ID Tap (HIS) Top ITW) (HKS) I Top Inc11.1 Hem Den Co. (in) 36,8 36.8 0.00 HANGER VETCO GRAY TUBING HANGER 2.910 PACKER. 2.856 ,5 2,656.5 1,995.1 54.64 PACKER ESP FEED-THRU PACKER, WEATHERFORD HYDROW 3.250 II DUAL STRING PACKER 5,016,6 3,432.0 28.54 GAUGE WELLIFT DISCHARGE GAUGE UNIT(SIN', 11932576) wl 2.992 (2).W Xos 5,087.1 3,494.6 26.24 INTAKE CENTRILIFT TTC RECEIVER XO COUPLING wl 2.992 PERFORATED INTAKE (SIN: 11945095) ESP SVNDREL. 2 769.3 5,091,6 3,498.6 26.09 SEAL CENTRILIFT TANDEM SEAL SECTION (SM'. 11623188 8 11615890) 5,105.4 3,511.0 25,64 GEARBOX CENTRILIFT GEAR REDUCTION UNIT (SIN: 10645680) 5,1072 3,512.7 25.58 MOTOR CENTRILIFT ESPMOTOR,76 HP KMH 1360Vf34A(SIN: GAGGE; 5,Q16,8 10615041) 5,115,4 T.20-0 2532GAUGE WELLIFT MOTOR GAUGE UNIT(S1N; 192-00685) 5.1172 3,521.7 25.25 I Centmilzer I GEN I IRLIFT MOTOR CENTRALIZER Other In Hole (Wlrellne retrievable plugs, valves, pumps, fish, etc.) SlIPs70P: 5.ON.0Top(TVp) Tapinel PAC NOFF;8645.0 Tcp(HK5) IRKS) I, Des COM Run Dale D (in) 5,044.0 3.456.1 27.85 SLIPSTOP 3.5" SLIP STOP 5111/2017 1.600 ESPCP PUMP; 5.053-0 5,045. 3,457.0 27.61 PACKOFF 3.6"PACKOFF(OAL=92-) 51112017 1.625 5,053.0 3,464.1 27.35 ESPCP 3.-x34.7ESPCP w1 TEST SUR (ZERO@PUMP 5/11/2017 PUMP EYE) TO TTC-XO @ 504T SUM t508T RKB, TOP OF PUMP @ 5053' RKB) INTAKE; 607.1 Perforatlons & Slots SEALL:5 691.8 Shot Dane GEARSOX:5,105.4 Tap [Hx6) M. {kKS) Top (TVD) ptKel Sem(TW) [kNS) Zeno Dare (ahINAH 9 Type Com MOTOR:5,f073 5,597.4 9,725.0 3,790.3 3,829.6 WS D, 179-- 11112001 50.6 SLOTS 4'x4,5" SCREENS (37.5 1O5A ea) ALTERNATING GAUGE: SA15.4 WITH BLANK PIPE (31.5'ea) Gntreezer.3,tt T.1 Mandrel Inserts 61 all onTap (TWI K Tpp HIKSI (kKB] Make Medea 00 (in) Senr Vw- Laich Per! Slxe TRO Run Type Type V (poll Run Date Co. 1 2,5295 1,921.8 CAMCO KBMG 11JESP GLV BK -5 0.373 1,042.0 212412015 2 2,769,3 2,060.6 CAMCO KBMG 1 ESP SOV BK 0.000 0.0 lbilur2ul7 Notes: General & Safety End Date Annobanen PRODUCTION Pmt_ 1 112120 0 1 NOTE', SIDETRACK 6 ESP WORKOVER Sdouack; 405-5.212.p 12212005 NOTE', ESP WORKOVER 8119)2010 NOTE-. View Schematic wl Alaska Schemadc9.0 b J) V SLOTS: S.597.4-1.725,0 SCREEN LINER, 5.te9 96100 well iD-los API 5002922843 PTD 197-236 Rig (R1(B) 121' Max DLS 6.7°1100ft @ 920' RKB Max Pad HZS 214 ppm Well Category Category 1 ConocoPhillips PROPOSED RWO COMPLETION Network #! (Drilling) Network # (Wells) AFE Cost AFE Time Max Angle 56.81 @ 2,154' RKB Max Well H2S 10 ppm H2S Radius of Exposure Wellhead Vetco ESP Production Tree ITubing Hanger Tubing Head I Tbg Head Adapter WELL OBJECTIVE Pull 3-1/2" tubing and ESP from 5,117' RKB. Shear the packer in tension and pull the tubing out of the hole. Run in the hole with new completion string (ESP, motor, gauge, packer, and gas lift mandrel). WELL HISTORY Drilled and completed in January 1998 as a West Sak producer well. In December 2005, the ESP failed, and a workover was completed to replace the ESP. In September 2011, the ESP failed again, and another workover was performed to replace the ESP. In February 2019, the ESP failed; the well was shut in for the workcver. HSE CONSIDERATIONS CASING INFO MD (ft RKB) TVD OD ID (ft RKB) (in) (in) Weight (Ib/ft) Grade Thread (top) Thread (btm) Conductor 121' 121' 16" 62.5 H-40 Welded MPSP Surface 5,212' 3,608' 7-5/8" 29.7 L-80 BTCM BTCM Production IBTM Liner (Slotted) 9,810' 3,830' 4-1/2" 12.6 L-80 BTCM BTCM Tubing (Previous) 5,119' 3,523113-1/2" 9.3 L-80 JIBTM IBTM Tubing (Proposed) 5,120' 3,523'13-1/2" 9.3 L-80 jIBTM I IBTM Top Perf Bottom Perf PERFORATIONS (RKB) (RKB) West Sak D 5,597' 9,725' 1,775 psi I 3,830' TVD 5/10/2019 EMW 8.9 ppg IBTM Gas Column 383 psi (@ 0.1 psi/ft) IBTM COMPLETION EQUIPMENT PRESSURE CALCULATIONS SBHP 1,775 psi I 3,830' TVD 5/10/2019 EMW 8.9 ppg IBTM Gas Column 383 psi (@ 0.1 psi/ft) IBTM MPSP 1,392 psi 3,000' COMPLETION EQUIPMENT MD TVD (ft RKB) (ft RKB) 00 ID (in) (in) Thread (top) Thread (btm) Comments E5 / Motor / Gauge 5,498' IBTM IBTM 4-1/2" X Nipple 5,420' IBTM IBTM 4-1/2" x 10-3/4" Packer 3,000' IBTM IBTM Gas Lift Mandrel 2,860' IBTM IBTM FLUIDS Weight Comments / Additives Primary Workover Fluid 9.1 ppg Seawater Back-up Workover Fluid KWF in hole, no back up fluid Corrosion Inhibitor 9.1 ppg Inhibited brine w/ I% CRW-132 Freeze Protection Diesel Nabors 7ES 00 Nabors Alaska Drilling Rig - 7ES Material List Rem Description A 3.1/8' 5000# Remote Hydraulic Operated Choke B 3-1/8' 5400# Adjustable Choke 1-14 3-118' 5000# Manual Gate Valve 15 2-1116' 5000# Manual Gate Valve To.SaoondAY ChoksLk% In Cellar WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. d () J ;:)-0;)- Well History File # Digital Data Added to LaserFiche File o DVD's - # - DYes o No DYes o No DYes o No o CD's - # - o Diskettes - # - Oversized Material Added to LaserFiche File 0 Maps # 0 Mud Logs # _ 0 Other # - DYes o No DYes o No DYes o No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA ALASKA OI AND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell {;7 Plug Perforations r® Stimulate r Other J"" Alter Casing f Pull Tubing jai Perforate New Pool f Waiver r Time Extension f Change Approved Program r Operat. Shutdow r Perforate r Re -enter Suspended Well f 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development { Exploratory r • 201 - 202 3. Address: 6. API Number: Stratigraphic r Service I P. O. Box 100360, Anchorage, Alaska 99510 ' 50 - 22843 - ^ 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650, 25649 ' 1D-105A 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 9820 feet Plugs (measured) None true vertical 3830 feet Junk (measured) None Effective Depth measured 9810 feet Packer (measured) 2656, 5150, 5460 true vertical 3830 feet (true vertucal) 2006, 3562, 3793 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 PRODUCTION 5171 7.625 5212 3602 SCREEN LINER 4660 4.5 9810 3841 RECEIVED [ C1 0 7 2011 Perforation depth: Measured depth: 5597' -9725' Alaska Oil & Gas Cons. Commission True Vertical Depth: 3801' -3840' Anchorage Tubing (size, grade, MD, and ND) 3.5, L - 80, 5119 MD, 3534 TVD Packers & SSSV (type, MD, and ND) PACKER - ESP FEED -THRU PACKER, WEATHERFORD HYDROW II DUAL STRING PACKER @ 2656 MD and 1995 TVD PACKER - BAKER ZXP LINER TOP PACKER @ 5150 MD and 3562 TVD PACKER - BAKER PAYZONE EXTERNAL CASING PACKER @ 5460 MD and 3793 ND NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 167 28 6 -- 204 Subsequent to operation shut - in 13. Attachments 14. Well Class after work: 1 Copies of Logs and Surveys run Exploratory r Development p. - , Service r Stratigraphic r 15. Well Status after work: _ Oil J Gas r WDSPL r Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 16. 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: none Contact Ian Toomey C 263 -4773 Printed Name Ian Toomey Title Wells Engineer Signature Phone: 263-4773 Date / _ 6 // J ti Form 10 -404 Revised 10/2010 RSDMS OCT 17 2011 e' / Submit Original Only • K U P • 1 D-1 05A CL7C#oKU e > elib re A A t P I IUWI s Max Angle & MD TD Naz„a $5(; e ms " WellboPW WI Field Name Well Status Inc! ( °) IMD (ftKB) Act Btm (ftKB) , , ; 500292284301 I IWEST SAK PROD 91 97 9,037 07 _ 9,820 0 C ment H2S (ppm) [Date 'Annotation End Date KB (ft) Rig Release b Da wn)confi u - .11 tU:27,4a AM SSSV NONE �. � last WO: 9/13/2011 111.50 1/26/1998 - 9, ' A_ Annotation Depth (ftKB) End Date Annotation Last Mod ... End Dab Last Tag- I / Rev Reason. WORKOVER I ninam _ 9/17/2011 [Casinq Strings HANGER. 37- - - , Casing Description 'String 0... String ID ... Top (ftKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd > r CONDUCTOR 16 15.062 41.0 121.0 121.0 62.58 H WELDED Casing Description String 0._ String 1D... Top (ftKB) Set Depth (f... Set Depth (TVD) .. Sting Wt... String... String Top Thrd PRODUCTION 7518 6.875 40.5 5,212.0 3,602.0 29.70 L-S0 BTCM Post Sidetrack Casing Description String 0... String !D ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... . String Wt.. String ... String Top Thrd SCREEN LINER 41/2 3.958 5,149.6 9,8100 3841_0 1260 L - 80 EUE8RD LrO71DUCTOR. , 111 7 15. _.. -_: _. _- _.__.. ..._. -_- -...._ _.__- - -_ 4,- 12 . Liner Details Top Depth (TVD) Top Inc/ Nenel... Top (ftKB) (ftKB) ( °) Item Description Comment 112 (in) 5,149.6 3,561.8 23.82 PACKER BAKER ZXP LINER TOP PACKER 4.860 5,168.2 3,578.8 23.49 HANGER BAKER CMC LINER HANGER 5.760 5,460.2 3792.5 85.04 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.930 5,523 1 3 798.1 86 76 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 ESP T ttbtng St rings MANDREL, -- -- - -- -- . Tubing Description String 0... String ID - Top (ftKB) Set Depth (f... Set Depth (TVD) .. Stri g Wt..- String _ring Top Thed 2'529 WO TUBING 31/2 L 2.992 _.. 368 51192 3534.2 9.30 L80 EUE -MOD Completion Details Top Depth (TVD) Top Inc! Nomi... Top(ftKBL (9KB) (°1 Item Description Comment ent ID (in) PACKER. 2,656 36 -8 36.8 -0.28 HANGER VETCO GRAY TUBING HANGER 2.910 _ _ 2,656.5 2,005.9 54.72 PACKER ESP FEED -THRU PACKER, WEATHERFORD HYDROW II DUAL 3.250 STRING PACKER 1 5,016.6 3,443.2 28.54 GAUGE WELLIFT DISCHARGE GAUGE UNIT(S /N: 11932576) w/ (2) .80' XO's 2.992 5,087.1 3,505.4 24.92 INTAKE TTC RECEIVER XO COUPLING w/ PERFORATED INTAKE (SIN: 2.992 ESP 11945095) MANDREL... 2,769 5,091.6 3,509.4 24.84 SEAL TANDEM SEAL SECTION (SIN: 11623188 & 11615890) 5,105.4 3,521.8 24.60 GEAR BOX GEAR REDUCTION UNIT (S /N: 10645680) 5,107 -2 3,523.4 24.57 MOTOR ESP MOTOR,76 HP KMH 1360V/34A (S/N: 10615041) _ 5,115.4 3,530.8 24.42 GAUGE WELLIFT MOTOR GAUGE UNIT (S /N: 192-00685) GAUGE, 5,017 5,117 -2 3,5324 24 39 Centralizer MOTOR CENTRALIZER Perforations &Slots - sno< I Top (TVD) Bfm (TVD) Dane Top ( Bon (8 _ lam) ( B) _ zone Date (sh. -. Type comment 5, 9,725 3,800.8 3,840.3 WS D, 1D-105A 11/1/2001 50.0 SLOTS 4"x4.5" SCREENS (37.5' ea) ALTERNATING WITH BLANK PIPE (31.5'ea) 1 Notes: Gen eral & Safety End Date Annotation 8/19/2010 I NOTE: View Schematic w/ Alaska Schematic9.0 INTAKE, 5.087 SEAL, 5,092 1 ' ^ ' GEARBOX, -- _ IV 5,105 MOTOR, 5,107 GAUGE, 5,115 CentrMZer 5,117 iv I PRODUCTION Post Sidetrack.__ 41 -5,212 ,Mandrel Details Top Depth Top I 1 Port (350) Inc! OD Valve Latch 1 Size TRO Run Stn Top (960) (ftKB) 7) Make Model 0s/ Se.-v Type Type (in) ' (psi) Run Dab Com... 1 2529.5 1 533.5 55.08 CAMCO KBMG 1 ESP DMY BK -5 0.000 0.0 9/13/2011 2 2 /69 4 2, 0/1.4 54.40 CAMCO KBMG 1 ESP IDMY BK -5 0.000 0.0 9/13/2011 SLOTS, " g g 1. 5,597 -9,725 .: 1`._... SCREEN 4 It LINER, 5,150 -9,910 TD (10105A), 9,820 III 1.05A Pre and Post Rig Well Work DATE SUMMARY 8/23/11 PRE RWO - -T -POT (PASSED), T -PPPOT (PASSED), FUNCTION TESTED LDS'S 8/29/11 PULLED 3 1/2" TBG STOP @ 5043' RKB.SET BAITED TEST TOOL ON PACKOFF AND REPLACED SHEARED 1" SOV WITH DV.TESTED TBG TO 1500 #.GOOD.PULLED BAITED TEST TOOL.IN PROGRESS. 8/30/11 PULLED PACKOFF ASSY FROM 5045' RKB.PULLED 44T250 ESPPCP (OAL= 35.3') FROM 5052' RKB.WILL RETURN FOR SBHPS. 9/2/11 PERFORMED 30 MIN SBHPS @ 5030' RKB (701 psi) WITH 15 MIN GRADIENT. 9/14/11 ** *RIG JOB * ** PULLED DV @ 2769' RKB. PUMPED 25 BBL DSL FREEZE PROTECT. SET DV © SAME, GOOD TEST. COMPLETE. 9/23/11 GAUGE 2.80" TO 2761' SLM, REPLACED DV @ 2769' RKB w/ 2000# SOV TBG TO CSG SHEAR,PULLED 3 12/ AVA CATCHER, PULLED 3 1/2 WRP @ 2765' SLM, IN PROGRESS. 9/24/11 ESP HAD NO FISHNECK ON IT. ABORT JOB; NO ETA ON PART AVAILABILITY. 10/2/11 DISPLACED TBG WITH 50 BBL'S 60/40 AND GAUGED TBG WITH 2.79" TO 5049' SLM.RAN 3 1/2" PACKOFF ASSY SCREWED INTO 2 7/8" PCP WITH 3 1/2" PUMPEYE (OAL= 32'10 ") TO 3300' SLM INSTRUCTED TO PULL OUT OF HOLE TILL SOME ISSUES ARE RESOLVED. • • onocoPhiilips Time Log & Summary Wellview Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/10/2011 1:30:00 AM Rig Release: 9/15/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/10/2011 24 hr Summary MIRU on 1D-105A. RU Kill tanks, treating iron and test. Pull BPV. Circulate Hot diesel. Circulate Hot 8.6 ppg w/ 3% KCI KWF. Set BPV. ND and inspect Tree. NU and Test BOPE. Pull BPV. Set Side Isolation sleeve. Pull Tubing Hanger to Floor. Single down the 3 1/2" ESP /HT Completion. 00:00 04:30 4.50 0 0 MIRU MOVE MOB P Move Rig well to well 1D-116 to 1D -105A. MIRU. Level Rig. Berm Rig. Accept Rig @ 01:30 hours. Spot Equipment and Tanks. R/U treating iron. 04:30 05:00 0.50 0 0 COMPZ WELCTL SFTY P Hold Pre Spud Meeting, Major steps to pull and replace ESP with Feed -thru Packer. 05:00 06:00 1.00 0 0 COMPZ WELCTL PRTS P Fluid Pack & Test Treating iron to Kill Tanks to 3,000 psi. 06:00 07:30 1.50 0 0 COMPZ WELCTL OTHR P Lubricator out BPV. PJSM. 07:30 12:00 4.50 0 0 COMPZ WELCTL KLWL P Pump 1 TBG volume w / Hot Diesel. Pump Hot diesel down IA taking return up Tubing at 5 bpm, 80 psi to wash wellbore. Took 108 bbls to see returns at surface.Total Diesel 270 bbls. Swap over pump to Brine and circulated until 8.6 ppg Brine was seen at surface. (519 bbls) 12:00 12:30 0.50 0 0 COMPZ WELCTL OWFF P Monitor Well for 30 mins. Well Dead. 12:30 13:00 0.50 0 0 COMPZ WELCTL OTHR P Set BPV. Rig on Shore Power @ 12:45. 13:00 13:15 0.25 0 0 COMPZ WELCTL SFTY P PJSM. Discuss Hazard for N/D Tree. 13:15 14:15 1.00 0 0 COMPZ WELCTL NUND P Nipple Down Tree Stack. 14:15 16:30 2.25 0 0 COMPZ WELCTL NUND P PJSM. Nipple Up BOPE with VBR's in Lower and Uooer body of BOPE. ( 16:30 20:00 3.50 0 0 COMPZ WHDBO BOPE P Rig up test equipment. Test BOPE per ConocoPhillips and AOGCC 60e requirements at 250/3,000 psi. Perform Koomey draw down test. Record pressure tests on chart. The State's right to witness the test was waived by B. Noble 20:00 20:30 0.50 0 0 COMPZ WHDBO NUND P Done with testing operation. Rig down hoses and testing equipment. Clear Floor of Spools and Un- needed equipment, test joints etc. 20:30 21:00 0.50 0 0 COMPZ WHDBOTHGR P PJSM. Pull Blanking Plug. Pull BPV. Install Side Isolation Sleeve in Tubing Hanger. Page 1 of 5 • • •Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 5,118 5,085 COMPZ WHDBOTHGR P PJSM. Pick -up and make -up Landing Joint. BOLDS. Tubing Hanger broke free at 190K. Pulled the Tubing Hanger to Floor at 105K. 21:30 22:30 1.00 5,085 5,085 COMPZ RPCOM CIRC P Circulate and condition Well with 8.6 lb /gal Seawater w/ 3% KCI at 5.0 bpm /40 psi. Total circulated = 250 bbls. 22:30 00:00 1.50 5,085 5,016 COMPZ RPCOM PULL P PJSM. Ready Floor. Remove Penetrators from Tubing Hanger. Hang sheaves and string ESP and Heat Trace Cables over same. Begin to pull 3 1/2" ESP /HT Completion. 09/11/2011 Continue to Single down the 3 1/2" ESP /HT Completion. MU the clean out BHA TIH and Clean out well to 5,175 -ft. Slip and Cut 84 -ft of Drilling Line. TOOH with Scraper/ Clean out BHA. 00:00 10:00 10.00 5,016 39 COMPZ RPCOM PULL P Continue to Single down the 3 1/2" ESP /HT Completion. 10:00 12:00 2.00 39 0 COMPZ RPCOM PULD P Lay Down Pump Intake and Lower ESP completion. Obtain oil sample from motor. 12:00 14:00 2.00 0 0 COMPZ RPCOM PULD P PJSM.Kick out 3.5" Completion and ESP Equipment, Clear and Clean floor. Recover (94) cross coupling dual channel (7) 4' mid -jt dual channel (454) 5' mid -jt dual channel (39) Cannon Clamps (2) 6' Flat Guards (1) 4' Flat Guards (15) SS bands. 14:00 14:15 0.25 0 0 COMPZ RPCOM PULD P PJSM. Load Baker Scraper assembly to rig floor. 14:15 15:45 1.50 COMPZ RPCOM OTHR P PJSM with Crane Operator. Swap out ESP Spools and Un -load Heat Trace Spool. 15:45 16:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for M/U BHA. 16:00 17:30 1.50 0 241 COMPZ RPCOM PULD P M/U 7 5/8" Scraper Assembly with , Drill Collars. 17:30 20:30 3.00 241 5,175 COMPZ RPCOM TRIP P TIH with Scraper assembly on Drill Pipe. Up wt 115K, Dn wt 75K at 5,175 -ft, did not see top of ZXP Liner. PUH 4 -ft and prep for circulating. 20:30 21:30 1.00 5,171 5,171 COMPZ RPCOM CIRC P Circulate to clean up well 339 bbls of 8.6 ppg 3% KCI, ICP 70 psi @ 8 bpm, slight returns at 50 bbls away. FCP 250 psi @ 8 bpm, total of 20 bbls returned. 21:30 22:00 0.50 5,171 5,070 COMPZ RPCOM PULL P RD circulating equipment. PUH 1 stand prep for Slip & Cut. 22:00 22:15 0.25 5,070 5,070 COMPZ RPCOM SFTY P PJSM- Discuss hazards associated w/ Slip and Cut of drilling line. 22:15 23:30 1.25 5,070 5,070 COMPZ RPCOM SLPC P Slip and Cut 84 -ft of Drilling Line 23:30 00:00 0.50 5,070 4,401 COMPZ RPCOM PULL P TOOH w/ Scraper assembly standing back DP to 4,401 -ft. Up wt 100K / Dn wt 67K Page 2of5 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/12/2011 24 hr Summary Continue TOOH with Scraper/ Clean out BHA. LD BHA. Pick -up and TIH with 7 5/8" Test Packer and RBP. Test Casing. TOOH with RBP/ Test PKR BHA. LD BHA. Rack and Tally 3 1/2" Completion, ESP equipment. Run New TTC -ESPCP 3.5" TBG Completion with Feedthru PKR. 00:00 02:00 2.00 4,401 241 COMPZ RPCOM PULL P Continue TOOH w/ Scraper assembly standing back DP. 02:00 03:15 1.25 241 0 COMPZ RPCOM PULD P Single down 4 3/4" DC's, Lay Down Scraper / Clean Out BHA and kick out. 03:15 03:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for MU of RBP / Test Packer BHA. 03:30 04:00 0.50 0 25 COMPZ RPCOM PULD P Load and MU 7 5/8" RBP -Test Packer BHA. 04:00 07:30 3.50 25 5,133 COMPZ RPCOM TRIP P TIH with 7 5/8" RBP- Retrievomatic Test Packer on 3 1/2" DP. Set RBP and release. Pull up 1 Stand and Set Test Packer at 5044' md, fluid pack drill pipe. 07:30 09:15 1.75 5,133 5,044 COMPZ RPCOM PRTS P Rig up testing equipment. Test between test packer and RBP to 1500 psi for 30 mins. Bleed down psi from drill pipe. Test 7 5/8" CSG to 1500 psi for 30 mins. Lost 50 psi in 15 mins and 40 psi for 30 mins. Total lose for 30 mins 90 psi. 09:15 09:30 0.25 5,044 5,044 COMPZ RPCOM SFTY P PJSM. Discuss hazard for TOOH with Drill pipe and testing bha. 09:30 10:00 0.50 5,044 5,133 COMPZ RPCOM TRIP P Release test packet, RIH and Latch and release RBP. Monitor well. 10:00 10:15 0.25 5,133 5,133 COMPZ RPCOM SFTY P PJSM- Discussed Hazards with TOOH laying down Drill Pipe. 10:15 17:00 6.75 5,133 25 COMPZ RPCOM TRIP P TOOH laying down Drill Pipe. Up wt 105k 17:00 18:00 1.00 25 0 COMPZ RPCOM PULD P Lay Down Test Packer / RBP BHA. PU and TIH with remaining 3 stands DP, Single down and kick out 3 1/2" DP. 18:00 21:00 3.00 0 0 COMPZ RPCOM OTHR P Pull Wear Ring. Continue Rack and Tally 3 1/2" Tubing and jewelry. 21:00 22:30 1.50 0 0 COMPZ RPCOM OTHR P Call from Baker Machine Prudhoe that remainder of equipment finished but delivery truck broke down. Bring in Lower ESP equipment onsite verify lengths and OD's. 22:30 23:30 1.00 10 10 COMPZ RPCOM PULD P PU MU ESP Lower Assembly to top of motor. 23:30 00:00 0.50 10 10 COMPZ RPCOM PULD P Bring in remainder of ESP Completion, verify lengths and OD's 09/13/2011 Run New TTC -ESPCP 3.5" TBG Completion with Feedthru PKR. Land Hanger. Test Packoffs. RU Slickline. 00:00 00:15 0.25 12 12 COMPZ RPCOM SFTY P PJSM- Discussed hazards with Running ESP completion. 00:15 01:15 1.00 12 107 COMPZ RPCOM PULD P Continue MU ESP completion. MU Tech Wire and record readings. 01:15 07:30 6.25 107 2,653 COMPZ RPCOM TRIP P TIH with TTC -ESPCP 3 1/2" Tubing completion. 07:30 14:00 6.50 2,653 2,661 COMPZ RPCOM PACK P Stop and make splice at Packer. Page 3 of 5 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 19:00 5.00 2,661 5,083 COMPZ RPCOM RCST P Continue RIH w/ ESP Completion from 2,661.0 -ft to 5,083 -ft Megging cable every 1,000 -ft. Up wt 68k / Dn wt 52k 19:00 19:30 0.50 5,083 5,083 COMPZ RPCOM THGR P Pick -up and Make up Tubing Hanger and Landing Joint. Up wt 99k / Dn wt 63k 19:30 21:00 1.50 5,083 5,083 COMPZ RPCOM OTHR P Perform Final Splice of ESP Cable at tubing hanger. 21:00 22:00 1.00 5,119 5,119 COMPZ RPCOM THGR P Land Completion and RILDS. Clamp Count: 4 ea. Protectolizers 3 ea. Flat Guards 4 ea. Single Channel Cross Coupling Clamps 83 ea. 2' Mid Joint Dual Channel Clamps 22:00 22:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Rigging up Slickline Equipment. 22:15 23:15 1.00 0 0 COMPZ RPCOM RURD P Bring in Slickline equipment and Rig Up same. Pressure test 3000 psi. 23:15 00:00 0.75 0 0 COMPZ RPCOM SLKL P RIH w/ Slickline tools, locate Top of Lower GLM at 2,755 -ft SLM (2,769 -ft RKB) Flag Wire- POOH X9/14/2011 Set WRP. Set Catcher. Load IA with 95 bbls Gel- Diesel. Set Packer. Test IA / Pkr 1500 psi. De- pressure IA per schedule. Freeze Protect Tubing. ND BOPE. NU Tree and Test. Make Final Checks. Set BPV. Secure Cellar. RDMO. Rig Released. 00:00 02:00 2.00 0 0 COMPZ RPCOM SLKL P On surface with Slickline, MU WRP to HES 1 11/16" DPU and RIH w/ Slickline tools, Set WRP in middle of� first joint below Lower GLM at 2.789 -ft SLM (2 805 -ft RKB)- POOU 02:00 02:30 0.50 0 0 COMPZ RPCOM SLKL P RIH w/ Slickline and Set Catcher (29" oal, AVA style) at 2,786 -ft SLM (2,802 -ft RKB)- POOH. 02:30 03:30 1.00 0 0 COMPZ RPCOM FRZP P LRS load IA with 95 bbls gelled diesel 1.5 bpm at 300 psi.. 03:30 09:00 5.50 0 0 COMPZ RPCOM PACK P Circulate and Pressure up tubing to set Hydrow II packer. Increase pressure from 1500,2000,2500,3000 and 4000 psi and set packer. Bled psi to zero and PT IA 1525 P psi for 30 P minutes. Bled per schedule. 09:00 09:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM with LRS, HES and Rig crew on pulling Dummy valve and freeze protecting well. 09:15 10:30 1.25 0 0 COMPZ RPCOM SLKL RIH and recover Dummy valve from GLM (Station #2) at 2,769 -ft. and POOH with same. 10:30 11:00 0.50 0 0 COMPZ RPCOM FRZP Bullhead 25 bbls of diesel down TBG through Open pocket at 2,769 -ft. Page 4 of 5 • , ,.Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 0 0 COMPZ RPCOM SLKL RIH w/ Dummy valve to 2,769 -ft and set in GLM station #2, Pump 10 bbls of diesel and began to pressure up. Bring pressure up to 1,200 psi. - good seal on Dummy valve. Shear off off valve and POOH w/ slickline. RD HES slickline unit and LRS hot oil unit. 12:30 13:00 0.50 37 37 COMPZ WHDBO MPSP P Dry rod and Set 3" H -BPV. 13:00 13:30 0.50 0 0 COMPZ RPCOM SFTY Held PJSM with Crane operator and rig crew on off loading ESP spooler and misc. equipment. Rig off Highline at 13:15 13:30 14:30 1.00 0 0 COMPZ RPCOM OTHR P Off loading ESP spooler and misc. equipment with Crane. 14:30 14:45 0.25 0 COMPZ WHDBO SFTY P Held PJSM on ND BOPE and NU Tree with rig crew 14:45 16:30 1.75 0 0 COMPZ WHDBO NUND P ND BOPE and set back on stump. 16:30 18:00 1.50 0 0 COMPZ WHDBO NUND P NU Tree 18:00 18:30 0.50 0 0 COMPZ WHDBO PRTS P Pressure test Hanger Void 5000 psi 15 minutes. 18:30 19:00 0.50 0 0 COMPZ WHDBO PULD P Pull BPV and Set TWCV 19:00 20:00 1.00 0 0 COMPZ WHDBO PRTS P Pressure Test Tree 250/5000, RD test equipment. 20:00 20:30 0.50 0 0 COMPZ WHDBO PULD P Pull TWCV and SET CIW 3" Type 'H' BPV 20:30 20:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM- Discussed hazards of moving off well. 20:45 21:45 1.00 0 0 COMPZ WHDBO DMOB P Secure Well and Cellar for RDMO. Final Pressures Tbg= 0 psi / IA 0 psi 21:45 23:00 1.25 0 0 COMPZ MOVE DMOB P Pull off well, load out 11" 5M BOPE from rig for Travel to 3K- pad 23:00 00:00 1.00 0 0 COMPZ MOVE DMOB P Clean around cellar box and well. Nordic Rig 3 released at 24:00 on 09/14/2011 I I Page 5 of 5 i/ 1/~L.~ L~V p. PROAcrive DiAgnostic SertvicES, livc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~ ; -:`sus:- ~' ~y~ ~~; ~. ~: ~"~~'1 Anchorage, AK 99518 Fax: (907j 245-8952 1) MTT Report 21-Jun-10 2) MTT Report 21-Jun-10 1 D-105A 1x108 1 Report 50-029-22843-01 ~_~~ 1 Report 50-029-22921-00 ~~r-aaa !~~- <~S~ Signed Print Name: ,~ Date : II I(~ ~'~+~~ ~ ~. C'~PYttSSir a4nrher~, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: pdsanchoraaeC~Dmemorvloq.com WEBSITE : www.memorvloa.com C:\Documenis and SettingslDiazie Williams\Desktop\Tiaz~smit Conoco.docx • Memory Magnetic Thickness Toof Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-105A Log Date: June 21, 2010 Field: West Sak Log No.: 10643 State: Alaska Run No.: 1 API No.: 50-029-22843-01 Pipet Desc.: 3.5° 9.3 Ib. L-80 EUE 8RD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 174 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvll.: Surface Pipet Use: Production Casing Bot. Log Intvl1.: 174 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl1.: Surface Pipe3 Use: Conductor Bot. Log Intvl1.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0' Dept. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing and 7.625" casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 174'. Changes in metal volume are relative to the calibration points at 48' and 86', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates an area of up to 13% relative metal loss over the interval (24' - 37') in the 5Hz pass. Over the same interval, the 8Hz pass indicates up to 5% relative metal loss and the 10Hz pass indicates a maximum of 1 % relative metal loss. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) in this interval. The source of an indication of a general increase in relative metal volume over the interval (4' - 24') is unknown. A log plot of the entire 5Hz pass and an expanded log plot of -top 30' of the 5Hz pass are included in this report. A maximum -13% circumferential metal loss is indicated in the interval between 24' - 37' in the 5Hz pass. (A tubing joint collar appears to be masking some potential casing damage in this interval.) A maximum ^-6% circumferential metal loss is indicated in the interval between 158' - 174' in the 5Hz pass, which appears to be associated with a tubing joint manufactured with a slightly thinner wall or a slightly different material. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16fl pipe. If all of the metal loss is speafic to the 7.625" casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. ii Field Engineer: G. Etherton Analyst: HY. Yang/J. Burton Witness: 8. Boehme pr t ryi nl `'~ SE[" ' r;'C° '~~ '~, t~~X ~.~?6S' ~~r,TfC:'G' Tx''74~? Q,rlCt?l~ ~., ~ JIt~CS .~_., ~` ,~ ~, ~. Pti~'2. 'Iii; .,; t~~ ~.__-.x,14_`, max. _f~ ~ ~e_'_,5-i~~~? E-fT7dil: PL)~~:-'t7i~~lt~f"y'IOQ.CCiI""i ~''!'l1`.7.~ri~)`t F?c~,} t'I2~C7 ~';f¢i`~ ~'ri~lC~f?~ tF~(" .~ (J'~~ ~e;~) I-~X; {.~+~~'a C?7~}-L11~ ~o r -~~a o`~"`WF"sA~ 5Hz, and 10Hz Delta Metal Thi ess Passes Overlay C~ oy M 1 D-105A June 21, 2010 Pn°Acrivr ~inyn°sric Srevicrs Database File: d:\warnorldatal1d-105aloverlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Tue Jun 22 10:20:08 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) 50 -50 Delta Metal Thickness 201D (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 0 5Hz Delta Metal Thickness -1 I ~ I I I i I i I i I i I _8Hz Delta Metal Thickness ' ' ' ' ' ' ' ' i i` ~`-a. ~~-~ 10Hz Delta Metal Thicknes 20 Inverted Casing Collar (8Hz and 1 60 80,Bottom of 16" Conductor ~~ t 120 140 Delta Metal 160 10Hz Delta Metal Thickness End of 10Hz Log - Hz Delta Metal Delta Metal Thickness 2010 (10Hz) 50 Delta Metal Thickness 2010 (8Hz) (°1°} 50 Delta Metal Thickness 2010 (5Hz) (%) 5D o`~"`wE"sAF R rded Magnetic Thickness L Data - 5Hz Pass C~ ~4 1 D-105A June 21, 2010 ~in5nosric Suviccs Database File: d:lwarriorldatal1d-105a15hzpass.db Dataset Pathname: 5hzpass Presentation Format: 20 Dataset Creation: Tue Jun 22 11:14:17 2010 Charted by' Depth in Feet scaled 1:15D -50 Delta Metal Thickness {%) 50 2 MTTP01 12 0 Line Speed (tt/min) -200 -6.8 MTTP12 3.2 Tree 5" Collar Metal Thickness Tubing Jt. 1 20 Metal 5" 40 625" Jt. 2 6D 3.5" Jt. 3 Bottom of 16" Conductor 625" Colla A o`~"`~F"s E anded 5Hz Pass Magnetic T ickness Log Data C~ icy i ' ~ ~ !` M 1 D-105A June 21, 2010 '~ Pn°nc.ivc o~nrn°s.~~ s~av~ccs ' '' Database File: d:lwarriorldatal1d-105a1expanded 5hzpass.db Dataset Pathname: 5hzpass Presentation Format: 20 Dataset Creation: Tue Jun 2211:14:17 2010 Charted by: Depth ~n Feet scaled 1'60 ~' -50 D elta Met al Thick ness {% ) 50 2 MTT P01 ' 0 Li ne S peed (ft /min) -200 -6.8 MTT P12 - _ - ~ ~. ' Lin e S pee d Tree ~ ~ ' ' i ~ ~ - -- ~Hanger~ _ 3 .5" Coll a ~ t 10 I II Tubing Jt. 1 i ' Delt a Me tal Thickness r 20 3 13% Me tal Loss ' 30 3 5" C ll . o ar ' -50 Delta Metal Thickness {%) 50 2 MTTP01 0 Line Speed (ft/min) -200 -6.8 MTTP12 12 3.2 12 3.2 ~ i GonocaRhillips Alaska, Inc. ~RU 1 D-105A ~' 1D-105A ___ API: 500292284301 Well T : PROD An le TS: d TUBING SSSV T N_ON_E _ Or' Com letion: 11/3/2001 An le TD: 90 d 9820 (o-5os7, OD:3.5o0, Annular Fluid: Last W/O: 1 1 /31200 1 Rev Reason: Set SOV, ESP PUMP ASSEMBLY ID:2.992) Reference Lo Ref L Date: _ Last U ate: 3/1 2120 0 6 'RODUCTION Last Ta TD: 9820 ftK8 (0-5212, Last Ta Date: Max Hole An le: 92 d 9219 oD:7.sz5, wc:zs 7o) ' _ Casin Strin - ALL STRINGS . ; : ` Description Size To Bottom ND Wt Grade Thread PUP CONDUCTOR 16.000 0 121 127 62.58 H-40 WELDED (4998-5707, PRODUCTION 7.625 0 5212 3608 29.70 L-80 BTCM oD:3.5o0) LINER 4.500 5749 9808 3830 12.60 L-80 EUE8RD Tubin Strin - TUBING _ Size To Bottom ND Wt Grade Thread 3.500 0 5097 3504 9.30 L-80 EUE8RD PUMP Perforations Su mma (sos4-soss, Interval ND Zone Status Ft SPF _Date T e Comment OD:2.790) 5565 - 9725 3789 -3830 _ WS D 4160 50 17/7/2001 Screens 4"x4.5" SCREENS Gas Lift Mandr elsNalves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO - Date Run Vlv Cmnt - 1 4992 3417 CAMCO _ KBUG _ SOV 1.0 BK 0.000 2000 1/3/2006 Other lu s e ui .etc. - JEWELRY NIP (s1m-s1oa De th ND T e Descri lion ID , OD:3.5o0) 4998 3416 PUP 2.992 5094 3501 PUMP 1 7/8" TS; RS OC 8' OC KJ LSS, 3 1/2 GS, 250T7800LT2000 PUMP. 33.40' LONG. SET AT 506T SLM - 1/3/2006 0.000 PUP ~ 88" PACKOFF ASSEMBLY 5060; SLIPSTOP 5013' -set 1/3/2006 (51os-5112, 5107 3513 NIP CENTRILIFT SLOTTED NIPPLE _ 2.992 OD:3.500) 5108 3514 PUP 2.992 SEAL 5112 3517 SEAL ESP SEAL GST3 DB IL H6 PFS 0.000 (5112-5126, 5126 3530 GEARBOX ESP GEARBOX 9:1 525 SERIES KMH 0.000 OD:5.130) 5127 3531 MOTOR PCESP MOTOR 57 HP 1315/26 KMH _ 0.000 5134 __ 3.537 Other ~ lu s, a Centralizer ui ., etc. - Centralizer w/BAKER Sentr Gau a 5094' MD, 3500' ND LINER JEWELRY 0.000 GEARBOX (s1z6-s127 De th ND T e Descri lion ID , OD:5.250) ' - 5149 3551 PACKER BAKER ZXP LINER TOP PACKER 4.860 5168 3568 HANGER BAKER CMC LINER HANGER 4.860 MOTOR 5442 3767 VALVE BAKER HM CEMENT VALVE 3.950 (5127-5134, 5460 3771 ECP BAKER 20' PAYZONE ECP 3.930 OD:5.620) 5523 3786 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 5565 3789 _ SCREEN 4.5 BAKER EXCLUDER SCREENS 2000, ALTERNATING BLANK LINER & SCREENS 4.000 9808 3830 SHOE 5" BAKER'GPV' SHOE 5.000 PACKER (514&5150, OD:6.550) II ~ Pert (5565-9725) SCREEN (5565-9725, OD:4.500) LINER (5149-9808, '~ OD:4.500, Wt:12.60) ~~ L'~I t> ~ it ~ ~ ~~ ~~ ; ~~~~~ a a ~ , ~d Q ' ; ' t . , , r. n , < , ,, ~ y .. .... .~,,,..~..,..,,,., . ~"~~ti1'za ~ k 3';.`< ';3 ~. KI - hag ~~~~ ~ti~ ~~.~~ ~~ -.__ ~~~ $ ~. ~ ;: , _..._.. __ .._..,_ 4 ~.,,,~ ~ ..: ~~ v _._ ~ _..~,~, ,.... .__. m ~ ~ E I X t. ( f ,> ....,F , ..._.., ,~ .,_.. ~ t r y -. .ta4 fi:? '~~-a .~.~~ i ~~p~ D ~ t F~ f {! {. j ~'%! ~ ~ h F g~, 7 x'.~ ,., ~J ._' i }" , ...,.,_-, .a:W .-... _'-,e. ~.... ~... ~« ~~S`° ~.~ P' ~.... ~ ,~ ~~ t ~ ~ i ~~ 4 } ~ ~' ~ t ~ 3~ ~~'~ 3 ti ~ ~9 S f . 1:;. ~d E ~ ~ + , - ~ --~. _...._..<,.-~.,...,.,..r,.r,_e...» w :. ,~ ~RB~~I~ ~~?" ~c-~~~c~ N1~~{~~a ~. ,.. ~.~ ~~F~ ~'~~' 14~e~i~a~ 1~7 !i~' ~~~sr'~#~i 1{Mft ~,.~`.~" cif ,~ _ ~, N~l~~f~ar ~~nCr~~f,c~~r ~ ~~~~~~~~ ~x~~tt~~ y r~,~efi~~ ,,1~C~~ ~~~ ~? ~~ ~~"~'~~ ~~, ~ ~~ ~ ~..~~ ~~` ~~,.~t3 ~~~~ • • Page 1 of 1 Regg, James B (DOA) ~ ~ ~ ' ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, January 23, 2010 3:08 PM ~ ~IZ~~o To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1 D-105A (PTD 201-202) Report of failed ESP Attachments: 1 D-105A schematic.pdf Tom, Jim, Guy i West Sak ESP lifted producer 1 D-105 (PTD 201-202) has a failed ESP motor. The motor electrically grounded downhole and will require a RWO to repair. The well is a single casing well and will remain shut in until it can be repaired. Attached is a 90 day TIO plot and a schematic. r Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. ~~~~8~~t`:.~1;!'~ ~. ~~ Z~) Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 1/25/2010 KRU 1D-IOSA PTD 201-202 1/23/2010 TIO Pressures TRN_ANNL ANNULUS RRESSURE TRENDS ''t1~I ^~ELL ,,;*!~• WLSHSID-105 3000. sC 3000 zaD. 3D00. 3000. 2700 3Dan. 240D 3000. D. 0. 0. 0. 0. f) . 0. 2100 leoo 1500 1200 900 600 300 0 ------------------------------------------------------------------------------------------------------------------- _-------------- PLOT START 'PINE MINOR TIME PT.~?"1' DC7RA"PION PL0"t END "LIME 25-OCT-09 14:14 MAJOR TIME WEEK +02160:OO:DD HRS 2~-JAN-10 14.59 PICx TIxE:23-J AN-10 14:09:19 ~;~~ TdG N~HE DESCRIPTiOH P-~~~~`.~'°~ LhTEST WL1D-105-CHOKE FLOW TUBING CHOKE ????~?? ~ SCRATCH 42 FLOW TUBING PRESSURE ??????? SCRATCH_42 FLOW TUBING TEMP ??????? PI-1D5302-105 GL CASING PRESSURE ??????? ???7??? ~ ??????? SCRATCH 47 INNER A!IlJIILUS PRES ???~??•~ SCRATCH_42 OUTER ANNULUS PRES ??????? ~~~~ ~~ DRILLSITE WELL PREY WELL 1 d 10 5 NEXT WELL ~~rrr?,z~~ 'r'dPF•: OPERATOR ~ OPERATOR VERIFIED ~ SYSTEM AUTO ENTRY ~ BOTH • • Well T e: PF Orig 11 -.~--- TUBING (0-5097, OD:3.500, 10:2.992) PRODUCTION (0-521 z, OD:7.625, wc2s.7o> PUP (49985107, OD:3.500) PUMP (5094-5127, OD:2.790) NIP (51075108, OD:3.500) PUP '~.. (5108-5112, OD:3.500) SEAL (51125126, OD:5.130) GEARBOX (5126-5127, OD:5.250) MOTOR (51275134, OD:5.620) • KRU I I '. 1 .i~ . . r.. l~Ay4. Annular Fluid: Las ~ Reference Log_ Ref Lo - ~~ Last Ta ~ ~ _Last Tag Date: __ Max Hole r Casing String -ALL STRINGS Descri lion Size 1 CONDUCTOR 16.000 PRODUCTION 7.625 LINER _4.500 5 ,Tubin Sirin -TUBING ~ __ Slze To Bottom r 3.500 0 _ _ 5097__ Perforations Summary Interval TVD Zone _ Ste 5565 - 9725 3789 - 3830 WS D ,Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr 1 4992 3411 CAMCO KBUG Other (plugs, equip., etc.) - LINER JEWE 1 D-105A An le TS: de Angle @ TD: 90 deg @ 9820 Rev Reason: Set SOV 5212 3608 29.70 L-80 BTCM 9808 3830 12.60 L-80 EUE8RD 1`VD Wt Grade Thread 3504__ 9.30 L-80 EUE8RD Ft SPF Date ~ Type_ Comment 4160 50 11/1/2001 Screens 4"x4.5" SCREENS Tvoe I V OD i latch i Port TRO Date Run Vlv 5442 3767 VALVE BAKER HM CEMENT VALVE s•a5u 5460 3771 ECP BAKER 20' PAYZONE ECP 3.930 5523 3786 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 5565 3789 SCREEN 4.5 BAKER EXCLUDER SCREENS 2000, ALTERNATING BLANK LINER & SCREENS 4.000 9808 3830 SHOE 5" BAKER'GPV' SHOE 5.000 ;Other ~plugss equip.L et_c. -COMPLETION ~ _ _ De th ~ TVD T e Descri tion ID 4998 3416 PUP 2.992 5094 3501 PUMP 250T1800LT2000 PUMP. 33.40' LONG. SET AT 5067' SLM - 1/3/2006 - 88" PACKOFF ASSEMBLY 5060'; SLIPSTOP 5013' -set 1/3/2006 0.000 5107 3513 NIP CENTRILIFT SLOTTED NIPPLE 2.992 5108 3514 PUP 2.992 5112 3517 SEAL ESP SEAL GST3 DB IL H6 PFS 0.000 5126 3530 GEARBOX ESP GEARBOX 9:1 525 SERIES KMH 0.000 TVD PACKER (5149-5150, OD:6.550) Perf (5565-9725) SCREEN (5565-9725, OD:4.500) LINER (5149-9808, OD:4.500, Wt:12.60) ConocoPP~lttips Alaska, Inc, 1 D-105A ., . Conoc6Phillips Alaska RECEIVED .JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AI< 99501 d-,O \ ~ )-0 'J- 5{;ANNED JUL 1 1 2007 Dear Mr. Maunder: ....: ,,~ ... ;.;:,,; Enclosed please find a spreadsheet with a list of wells fi"om the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water fi"om 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. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name pro # cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 6/912007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 619/2007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 619/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 619/2007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 619/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 61912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 619/2007 Kuparuk Field June 9,2007 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc ) ) Jim Ennis Wells Group Engineer Drilling & Wells ConocciP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 January 20, 2006 RECEIVED JAN 2 4 2006 Alaska Oil & Gas Cons Cn.mrni . · vm"qSSIOn Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 Subject: Reports of Sundry Well Operations for 1 0-1 05A ~O\ - d-.Or Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover on the West Sak well 1 0-1 05A. If you have any questions regarding this matter, please contact me at 265-1544. 5(;B\NNED ,"U\N 2 5 2006 J. Ennis Wells Group Engineer CPAI Drilling and Wells JE/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ) RECEIVED JAN 2 4 2006 1. Operations Performed: REPORT OF SUNDRY WELL OPERA TIOtl~"A n:1 g. a.u~ I'"no Î Abandon D Repair Well D Plug Perforations D Stimulate D ..........""- Other Ancho~e Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension [j Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 201-2021 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22843-01 7. KB Elevation (ft): . 9. Well Name and Number: RKB 26' 1 D-1 05A 8. Property Designation: ADL 25650 & 25649, ALK 467 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Total Depth measured 9820' 3830' feet feet feet feet Plugs (measured) Junk (measured) true vertical Effective Depth measured true vertical Casi ng Structural CONDUCTOR PRODUCTION LINER Length Size MD TVD Burst Collapse 80' 5186' 4661' 16" 7-5/8" 4-1/2" 121' 5212' 9810' 121' 3608' 3830' Perforation depth: Measured depth: slotted liner 5565'·9725' true vertical depth: 3789'·3830' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5097' MD. Packers & SSSV (type & measured depth) Baker ZXP @ 5149' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft .IAN 2 4 2006 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 33 15. Well Class after proposed work: Exploratory D Development D Service D 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl SI 272 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casina Pressure Tubina Pressure 28 -- 239 Daily Report of Well Operations _X WDSPL D Contact Printed Name Signature Jim Ennis @ 265-1544 l~niS Title Phone Wells Engineer (~OÎ 72~S-/JLLf Date I ¿) Dip PreDared bv ~;on ~SUD-Drake 263-4612 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/15/2005 04:30 - 06:00 06:00 - 08:00 08:00 - 12:00 12:00 - 14:30 14:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 12/16/2005 00:00 - 01 :00 01 :00 - 06:00 06:00 - 09:00 09:00 - 11 :00 11 :00 - 15:00 15:00 - 21 :00 21 :00 - 00:00 12/17/2005 00:00 - 04:00 04:00 - 11 :00 11 :00 - 12:00 12:00 - 12:30 12:30 -13:15 13:15 - 18:00 18:00 - 00:00 12/18/2005 00:00 - 02:30 102:30 - 05:00 I I i 05:00 - 06:00 ! 06:00 - 12:00 12:00 - 14:00 14:00 -15:17 10-105 10-105 WORKOVER/RECOMP Start: 12/15/2005 Rig Release: 12/21/2005 Rig Number: Spud Date: End: 12/21/2005 Gro up: Nabors 3S .H!ÖursCqde ·8ü6·· QPd$ ... .... PescriptlÖh·pf qp~rc;¡tiOh~ 1.50 MOVE Completed pit cleaning. Released rig @ 5:00 on 12/15/05. Prep for rig move. Begin moving to 1D-105. Scope down derrick, lower mast. Brake down berm. Jack up complxes, move pipe shed, pits, carrier off well, clear of wellsite 1 D-131. Move rig from 1 D-131 to 1 D-1 05 Begin to spot up rig mats and spot BOPE behind wellhead. Set herculite, spot rig over wellhead. Spot pits and pipe shed. Raise derrick. Scope up derrick. Install berms. rig up lines. Rig accepted @ 22:00 on 12/15/05. Rig-up lubricator, pull BPV. Load pits with seawater. 1.00 WELLS PLGM WRKOVR Finished pulling BPV. Rig lines for well kill. pt lines to 2000 psi. 5.00 WELCTL KILL WRKOVR Kill well with 8.6 ppg seawater @ 130 degrees. Pumping down IA @ 4 BPM and up the tubing. Inital pressures tbg 250psi IA 1000 psi. Total of 325 bbls pumped. Crude oil mist noticed on pad. Called all parties to notify. 3.00 WELCTL OBSV WRKOVR Monitor well conditions prior to installing BPV. 2.00 WELLS PLGM WRKOVR Set BPV. ND tree 4.00 WELCT NUND WRKOVR Pick up 11" BOP stack. NU BOPE. Unable to rig-up riser. Rig to far off center. Decide to re-spot rig. Scope down and lay down derrick. Move rig back 6". Level sub. raise and scope derrick up. Continue resetting rig and finish nippling up BOPE. Begin BOPE test, function and PT BOP rams and choke manifold to 250/3000 psi, Annular to 250/2500 psi, AOGCC Chuck Scheive waived witnessing test. 1.00 WELLS NUND WRKOVR Prep rig floor for Test dart and BPV removal. Remove same. No pressure in IA or tubing. 0.50 WELLS SFTY WRKOVR Tool box safety meeting. Pre-pull. 0.75 WELLS PULD WRKOVR Pull hanger to rig floor. Up wt = 87K to break free. Tubing and IA liquid level below rig floor. Took 11 BBLS to fill hole. Will fill hole with 3-5 BBLs every hour. 4.75 WELLS RURD WRKOVR Rig up to spool ESP cable. Confirm no heat trace. Strip tubing hanger and lay dwn same. Prepare to pull tubing. 6.00 WELLS TRIP DECOMP POOH wI old 3.5" ESP completion, laying down jewerly, standing back tubing in derrick. With pipe displacement and fluids loses. Currently losing 10-12 bbls per hour. DECOMP Continue POOH wI ESP completion. Still losing 10-12 bbls per hour of fluid. DECOMP On surface with completion. Lay down pump assembly. Shaft broken at top of seal section. All clamps/bands recovered. Install wear ring. Change out elevators. 1.00 WELLS~ RURD WRKOVR Make up test packerlRBP assembly 6.00! WELLSR TRIP ! WRKOVR I Trip in hole monitoring hole conditions. Well currently drinking 5 BPH. I ! I Dwn wt = 34K. UP WT = 56K. Install head pin and prepare for Casing : I i test. 2.00 I WELLSR PLGM . WRKOVR Set Baker plug with four turns to the left. Nominal torque. Set 20K down on packer and prepare to pump. Pressure up 7 5/8" casing to 12,500 PSI. 1.281 WELLSR PLGMWRKOVR I Release packer. RIH to liner top packer and prepare to POOH. ~ Decided to tag Liner top packer to ensure that test packer is on tubing string. UP WT = 56K. Filling hole with 5 BBLS every hour plus pipe I displacement. RURD MOVE 2.00 MOVE 4.00 MOVE RURD MOVE RURD MOVE 2.50 MOVE 6.50 MOVE MOVE MOVE RURD MOVE 1.00 MOVE 2.00 MOVE RURD MOVE RURD MOVE 6.00 WAlTON OTHR WRKOVR 3.00 WAlTON OTHR WRKOVR 4.00 WELCTL NUND WRKOVR 7.00 WELCTL BOPE WRKOVR 2.50 WELLSl TRIP 2.50 WELLS PULD Printed: 1/20/2006 11 :20:57 AM ) ) Legal Well Name: 10-105 Common Well Name: 10-105 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S ···Date ,.sÜb!. OQq!e,.! 12/18/2005 TRIP WRKOVR 18:00 - 22:30 TRIP WRKOVR 22:30 - 00:00 RURD WRKOVR 12/1 912005 00:00 - 02:00 2.00 CMPLTN PULD CMPL TN 02:00 - 05:00 3.00 CMPL TN PULD CMPL TN 05:00 - 12:00 7.00 CMPL TN TRIP CMPL TN 12:00 - 18:00 6.00 CMPLTN TRIP CMPL TN 18:00 - 00:00 6.00 CMPL TN TRIP CMPL TN 12/20/2005 00:00 - 01 :00 1.00 CMPL TN TRIP CMPL TN 01 :00 - 04:00 3.00 CMPLTN RURD CMPL TN 04:00 - 12:00 8.00 CMPL TN NUND CMPL TN 12:00 - 16:30 4.50 CMPLTN SEOT CMPL TN 16:30 - 17:00 0.50 CMPL TN DEOT CMPL TN 17:00 - 18:00 1.00 CMPLTN CIRC CMPL TN 18:00 - 00:00 6.00 WELLS PLGM CMPL TN 12/21/2005 00:00 - 01 :00 1.00 WELLS RURD WRKOVR Start: 12/15/2005 Rig Release: 12/21/2005 Rig Number: Spud Date: End: 12/21/2005 Group: D¢sþr!þtion ÔfOperatidn~ Continue to POOH. Continue to monitor fluid lose rate and fill hole as needed. On surface with packer assembly. All seals intacted on packer. Lay down packer assembly. Change out handling equipment. Pull wear bushing. Prep for completion run. Rig cable from spooler over sheave to rifg floor, clean rig floor. Conduct pre-job safety meeting. Begin making up motor. Made up motor and begin servicing same. Make up guardian gauge on collar between first stand of tubing. Continue to RIH megging every 1,000'. Torque value of 2,400#. Begin heat trace 3,000' from surface. Meg ESP cable. Continue to RIH. Installing Dual channel clamps. Continue in hole with completion Continue RIH wI completion, installing clampslbands as per program, checking cable every 1000'. Well is static. Make up hanger to tubing string, install landing joint. Install penetrators, cut cables and make splices. test, heat trace and power cable tested. Install BPV and nipple down stack. NU tree I adapter. Pull BPV and install 2-way check. Test tree to 5000 psi, test void to 5000 psi -- good. Perfom final check on heat trace, power cable, I-wire -- all good. Call out AES valve shop. Rig up lubricator and pull 2-way check. Rig up Hot Oil to pump freeze protect. Equalize diesel in tubing and lA, rig up and set BPV. Clean pits Clean pits and prepare to move rig Release rig @ 1 :00 AM 12/21/2005 Printed: 112012006 11 :20:57 AM ') Conoco!PhUUps Alaska, ,Inc.. ) KRU 1)-105A .. 1D;.105~ .·...i.·..·.····· ..... ......... ..................... ....,....... '" .... '" ." ..... ...... ..... ..' ...... '. .... .' ..... ..... .... '. API: 500292284301 Well Tvpe: PROD Anale (ã) TS: dea (ã) TUBING - SSSV Tvpe: NONE Oria Completion: 11/3/2001 Anale (ã) TD: 90 dea (ã) 9820 (0-5097, ., Annular Fluid: Last W/O: 11/3/2001 Rev Reason: SET DMY 00:3.500, Reference Loa: Ref Loa Date: Last Update: 12/15/2005 10:2.992) Last Taa: TD: 9820 ftKB :lROOUCTION M Last Taa Date: Max Hole Anale: 92 dea (â) 9219 (0-5212, Qåsiha$ttitló..ÄLL. S"'~ltsJG$ ......... ···.····.i··.··.....·· '.. ...... ..'>/ .... .... ...... ....,. .... .' ...... ........ ....... ............ ..... 00:7.625, Wt:29.70) Description Size Top Bottom TVD Wt Grade I Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 I WELDED PRODUCTION 7.625 0 5212 3608 29.70 L-80 I BTCM PUP LINER 4.500 5149 9808 3830 12.60 L-80 I EUE8RD (4998-5107, .... Tubine Strine - TUBING 00:3.500) Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 1 5097 1 3504 I 9.30 1 L-80 I EUE8RD " pet'førâtiøÒS$Urrih1ª·ry. ..... ........................ ,.....<.......«.. ...... . ......< '" .'. ....... ..... ...............,... ." ............ ... ......... .......,.. ..... ............ ............ Interval TVD I Zone I Status I Ft ISPFI Date Type I Comment NIP 5565 - 9725 3789 - 3830 1 WSD 1 141601 50 1 11/1/2001 Screens 14"x4.5" SCREENS (5107-5108, Gas Lift Mandrels/Valves 00:3.500) St I MD I TVD I Man Mfr Man Type I V Mfr I V Type V 0 D I Latch I Port I TRO I Date I Vlv Run Cmnt pup 1 I 49921 34111 CAMCO KBUG 1 I DMY 1.0 1 BK 1 0.000 I 0 1 12/1/2005 I (5108-5112, Othér rtiluåsi\éâ Oir:>.,.···êtc;l....··JE\lVËLRY ..... "'> i ............... .... ....' ........ ........... ...... .'. ...'........... .... ............ .... .. .'. 00:3.500) Depth TVD Type Description ID SEAL 4998 3416 PUP 2.992 (5112-5126, 00:5.130) 5107 3513 NIP CENTRILlFT SLOTTED NIPPLE 2.992 5108 3514 PUP 2.992 5112 3517 SEAL ESP SEAL GST3 DB IL H6 PFS 0.000 5126 3530 GEARBOX ESP GEARBOX 9:1 525 SERIES KMH 0.000 GEARBOX 5127 3531 MOTOR PCESP MOTOR 57 HP 1315/26 KMH 0.000 (5126-5127, 5134 3537 Centralizer Centralizer w/BAKER Sentry Gauae (â) 5094' MD 3500' TVD 0.000 00:5.250) Othêr [plUåš,eâûiP. , etc.)i:.LlNERJEVVEI..R-r ...... ......... ....... ............ ..... ....... ................ ...... .' ..... ..... ..- ." MOTOR DeDth TVD TVDe Description ID (5127-5134, 5149 3551 PACKER BAKER ZXP LINER TOP PACKER 4.860 00:5.620) 5168 3568 HANGER BAKER CMC LINER HANGER 4.860 5442 3767 VALVE BAKER HM CEMENT VALVE 3.950 5460 3771 ECP BAKER 20' PAYZONE ECP 3.930 5523 3786 SLEEVE BAKER CMD SLIDING SLEEVE 3.430 5565 3789 SCREEN 4.5 BAKER EXCLUDER SCREENS 2000, ALTERNATING BLANK LINER & 4.000 SCREENS 9808 3830 SHOE 5" BAKER 'GPV' SHOE 5.000 GeriêrãlNQtås '...... '.. ..... .'. '. .. Date I Note 8/25/2002 I CONFIRMED MOTOR SHAFT IS BROKEN 12/30/20031 WAIVERED WELL: T x IA COMMUNICATION' PACKERLESS WELL FAILED ESP PACKER (5149-5150, 00:6.550) I I LINER It. (5149-9808, .'. 'I 00:4.500, ....> U Wt:12.60) ECP (5460-5461, 00:5.660) SLEEVE (5523-5524, 00:5.500) Perf (5565-9725) SCREEN ----e (5565-9725, 00:4.500) j ~ Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 101' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION SLOTTED LINER Perforation depth: P~"-"-·_·-'--'''-·,-, - .,....,.......~~,..,-..,..=~.,...",..~~..,..-=...,.,.,..,~--.~-~~~-=<'",..,..",.,.,.,.,.",.~~...,..-,'~. ..,.~..,..,....."".,..,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 L.005 Abandon D Alter Casing 0 o Repair Well 0 Pull Tubing 0 Operat. ShutdownD (:, .1 .'- Stimulate 0 Other ."¡ f'l.,."h,Q. n.'.:!! ~~~~I'~,~I~~~~~ Waiver 0 Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 201·202 6. API Number: 50-029-22843-01 Plug Perforations D Perforate New Pool 0 Perforate D 4. Current Well Status: Development _ 0 Stratigraphic 0 Exploratory 0 Service 0 9. Well Name and Number: 1 D-105A 10. Field/Pool(s): West Sak Oil Pool measured 9820' feet true vertical 3830' feet measured feet true vertical 6276' feet Length Size MD 121' 16" 121' 5111' 7-5/8" 5212' 4661' 4-1/2" 9810' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3608' 3830' Measured depth: No perfs, slotted liner true vertical depth: No perfs, slotted liner SCANNED FED 2 4 2DD5 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5097' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 0 0 0 Subsequent to operation Not avail Not avail Not avail 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-028 Contact Printed Name Signature Brad Gathman/MJ Loveland @ 659-7224 Brad Gathm OR\G' ¡~NA' l .' . '.'"'1\ \ . _ Submit Original Only Form 10-404 Revised 04/2004 ~.~~~~..............~~."..,.,.,..,.."...,.....,.....",.,.,,..,,.,..,-.~~~.~...,...,..,""'.,..-~~~-<,.,.....,.....,.,..,..,...~~,'~..........~~.~...,....,..,.......,'"'..----.--'".,..,....._~............,_._.~.,__""'="""'""".----,......-._,~-e-__~"...,,....,.,..,...-e.,.,~~"..,..,"""'""'...,..,-.,-...,,..-.~..,.._.,,................-,..,,.....,.,.,.."",................,=...,..----,--,.-~ 1D-105A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/18/2005 PULLED 3" SLIP STOP @ 50791 SLM. EQUALIZED & PULLED K-3 PACK OFF PLUG @ 50821 SLM.- Prep for conventional direction Gas lifted production ) ') FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~b,i.,- ~O~'ii Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99501 Re: West Sak ID-I05A Sundry Number: 305-028 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours 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 0 liday or weekend. A person may not appeal a Commission decision to Supe . r Co unless rehearing has been requested. DATED this l"Yday of February, 2005 Encl. SCANNE[) FEB 1 5 2005 02/08/2005 15:32 9075597314 ) RECEJVf:õ~ STATE 01" ALASKA /«0 ílfL,s- .q AU SKA OIL AND GAS CONSERVATION COMMISSION ' " , ¡.:¿ APPLII :ATION FOR SUNDRY APPROV"QI&Gllc..~., AtQ NSKWELLS GROIIQ) 11. Total depth MD (ft): 9820' ca$lng CONDUCTOR PRODUCTION Total Depth TVD (ft): Effecl 3830' Length 121' 511 l' 4661! 20AAC 25,280 ... uspend 0 Operation Shutd~f'I 0 P~rforate 0 Waiver 0 Annul~r Dlsp. 0 alrwell 0 Plug PerloT'ation~ 0 $timulato 0 Time e~en!3lon 0 other 0 Tubing 0 Perforate New Pool 0 , Ré-énter sospendad wall 0 , 4. Currant well Class; ", , 5. ~ermlt to Orin Number: Development _ Q] Expror~tëry D 20h202 Strat¡g~phiç 0 Service 0 6. API Number: 50-029-22843-01 9, WQII Name and Number: , 1 D·105A 10, Freld/Pool(s); West Sak Oil Pool PRESeNT WELL CONDITION SUMMARY ,a Depth MD(ft): Effective Depth TVD (ft): PI\.IQs(measured); Junk (measured): Slite MIJ TVD Elur!d Collapse 16" 121' 121 7-5/8" 5212' 3608 4.1/21/ 98101 3830 ·~tion Depth TVD {ft); Tubing Size: Tubing Grade: Tubing MD (ft)~ rl$, slotted liner 3·1/2" L-80 5097' Packers and SSSV MD (ft) no SSSV II 0 13. Well Cla$$ after proposed work: 3ketch D Exploratory D Development, ø Service D 15. Well Status after proposed work: ~eb-05 Oil 0 Gas 0 F'lugged 0 Abandoned 0 WAG D GINJ 0 WINJ D. WDSPL 0 !orrect to the best of my knowlêdge. COl'ltaèt; Gathman/Loveland 659-7224 )~~ Title: Problem Well SupervisQr Phone 659-7043 Date ~/~2?~ , Commission Use On J 1. Type of Request: Abandon 0 Alter casIng D REI C::hengê approv~d program 0 PL" 2. Operator Name: ConocoPhilli s Alaska! Inc. 3. Address: P. O. Box 100360 7. KS Elevation (ft); AK8101' 6. Property Designation: Kuparuk River Unit Perforation Oepth MD eft): Perf¡: No errs, slottêd liner No I ~ackel'$ and S$SV Type; no packer no SSSV 12. Attaèhrnen1:$; Description Summary of Propmi Detailed Operations Program D BOF' 14. Estimated Date for Commencing Operations: 1~, 16. Verbal Approval; Da.~ê: Commission Representative: 17. I hereby certify that the forégoing is true and Printed Name Jerry Dethlefs r· SignaturE! ~ød C-L. ConditiOI'1$ of approval: Notify Commission so thl ~ Q representative may witness Sundry Number~ ,5'oS:- Oô). g- Plug Integrity 0 BOP Test D Other: \.\~~\'~--\ ~ ~ Macl· mica! Intêgrit.y Test D Location Clearance D ""'-'J0s\>hl\.\,-e2). s..:,'~"'E~\~ Q /¡S -0 ~ þfVl..(}j ~K ~ \1'<:. u...J ~() ~ RBDMS BFL FES 1 4 2005 COMMISSIONER BY ORD~R OF THE COMMISSION Form 10-403 Revised 12/.2003 Im1~11#el: Submìt in Duplicate ') ) ConocoPhillips Alaska, Inc. Kuparuk We1l1D-105A (PTD# 2012020) SUNDRY NOTICE 10-403 VARIANCE REQUEST 2/7/2005 The purpose of this Sundry Notice is for approval to renew Sundry #303-259 for a 12-month period, to produce West Sak well1D-1 05A on gaslift with a failed ESP completion. West Sak well1D-105A is an ESP completion operated under Sundry (#303-259) approval to produce with gaslift after the ESP failed, which expired 9/11/04. The original Sundry (302-294) was approved for 12 months, which expired on 9/11/03. This well is currently being evaluated for a workover. Previous attempts of gaslift production have failed due to insufficient pressure support in the reservoir. Since the previous attempts the bottom-hole pressure has significantly increased to a level that should be able to sustain gaslift production. This increased support is believed to be supplied by 1C-190 that was brought online 6/12/03. The purpose for flowing this well temporarily with gaslift is to determine if the reservoir response shows that 1 C-190 is in fact providing pressure support, which would support the justification of a workover. The most current Sundry approved lift gas to be inj ected down the tubing and production up the annulus. For this application, ConocoPhillips proposes: 1. To initially allow an attempt to flow the well conventionally with lift gas injected down the annulus and production up the tubing; 2. Should conventional gas lift not work to reverse the flow, i.e., lift gas injected down the tubing with production up the annulus; 3. Maintain a quarterly inspection schedule that was previous approved for this well and other similar Sundry requests should annular production be required (not for conventional flow); 4. Approve the request for a period not to exceed twelve months from the approval date. Attached is a summary of the flowline inspection reports. i.'\)- \(:)5: ,\", c- ~-\-~~ ~~~ZL'\ ...r( 0.. \\\:1 \t", b X>, \N~~~ \<íl'S~~~ \""- ~\'\- C)~ \ \- (J.v~~~ ~'Yb k~ ~,--\-k dO fu'f> ~~ðl.J<=-~~ T ":.0 \>~'Cr-\--<2-\' l\ Y 's ~ro~ \ 'm \~ \.Je:~\\ ':JCt-~ ~ \\-ì!'-.~ -\.-\-.-\:<> "".¿ 1 '\ <\. ~ ~\O~0L\-'t'ö~. C:P..\ 4' '\{'-~ ì.~~\-M.OJt1ö,,-ö~ ~ ~'f~'-à", ~0 ~{b~ ,,<? ().\""'O 0.. '\Jc..\ \¿; ~Ù'ço<;e:. I\- ~\~~~, ~~\ð"'S.ú.!\. 1\Aú.'-{ 1t3J\ -\-tolM.- \-k ,\",-~~iM.D-~~"-,- ~\\-~rt~~ ~\~~I'\.. \'ù~-\~ .~~ J 'A:ì \ \ \ vtJO \~ o.~ "\'4: \. \'V\IJ \ ~ "g "'l(,)~\~~ t--~ "0 <;.. \\~~ -\ ~ S. \ã-i}G: ~Il.\- ~s. ~~\M.Ç\G~ '1) ''. ~f( \. \s '\ ~\"'\S.S:CLN\.~ ?JI?~.2&-( ~) ) The following is the inspection log results: 1 D-1 05 Special Inspection Request Log DS1D 1D-105 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection Worst Damage B, I, N Case Wall Comments Inspection Locations Loss % Grade 10/11/02 6 B 0% A Baseline Inspection 10/28/02 6 N 0% A 2 Week Follow-up 11/12/02 6 N 0% A 2 Week Follow-up Line shut in No insp required 05/07/03 6 B 0% A New baseline established for well head riser 05/31/03 6 N 0% A Monthly follow-up 08/31/03 Quarterly ) ) ConocoPhillips Alaska, Inc. KRU 1 D-1 05A 1D-105A API: 500292284301 Well Type: PROD Anqle @ TS: deg@ TUBING SSSV Type: NONE Oriq Completion: 11/3/2001 Angle ~ TD: 90 deg ~ 9820 (O-fmï Annular Fluid: Last W/O: 11/3/2001 Rev Reason: Waivered Well 00:3.500. Reference LOQ: Ref Log Date: Last Update: 12/30/2003 10:2.992) Last Taa: TD: 9820 ftKB Last TaQ Date: Max Hole Angle: 92 dea ICù 9219 OOUCTION '1 ! Casina Strina - ALL STRINGS (0-5212, . Description Size Top Bottom TVD Wt Grade Thread 00:7.625, CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED Wt:29.70, ., PRODUCTION 7.625 0 5212 3608 29.70 L-80 BTCM SLOTTED LINER 4.500 5149 9810 3830 12.60 L-80 EUE8RD - I W/SCREENS PUP Tubina Strina - TUBING (4998-5107. Size 1 Top 1 Bottom 1 TVD I Wt 1 Grade 1 Thread 00:3.500) I I 3.500 1 0 1 5097 I 3504 I 9.30 1 L-80 I EUE8RD ; Perforations Summary Interval TVD 1 Zone 1 Status I Ft 1 SPF 1 Date Type 1 Comment 5149 - 9810 I 3551 - 3830 I WS D 1 146611 50 111/1/2001 Screens 14"x4.5" SCREENS ¡ Gas Lift MandreJsNalves : St I MD I TVD I Man Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date I Vlv Mfr Run Cmnt NIP ~. ~.~ . ,. ,.,~... 1 I 49921 34111 CAMCO KBUG I I OV I 1.0 1 RK 1 0.188 I 0 110/30/20021 (5107-5108. ~. t~~~.... .:..c.':., 'IIo"f-o ..: Other (I luas. eauiD.. etc.) - JEWELRY ~ .'::r. ·.;t t y ~ 00:3.500) I¡'~ Depth TVD Type DescriDtion ID ; ;,.:;~( 4998 3416 PUP 2.992 :- ·;t-;;·~ .c~.~~. 5071 3480 SlipStop/ Slipstop/Packoff set 10/3/2002 0.000 ;-; ... '.f.~...~ ; Packoff : 5107 3513 NIP CENTRILlFT SLOTTED NIPPLE 2.992 PUP (5108-5112. 5108 3514 PUP 2.992 00:3.5ùOI 5112 3517 SEAL ESP SEAL GST3 DB IL H6 PFS 0.000 5126 3530 GEARBOX ESP GEARBOX 9: 1 525 SERIES KMH 0.000 SEAL 5127 3531 MOTOR PCESP MOTOR 57 HP 1315/26 KMH 0.000 (5112-5126 5134 3537 Centralizer Centralizer w/BAKER Sentry GauQe ~ 5094' MD, 3500' TVD 0.000 00:5.130, General Notes Date I Note 8/25/20021 CONFIRMED MOTOR SHAFT IS BROKEN 12/30/2003 WAIVERED WELL: T x IA COMMUNICATION; PACKERLESS WELL, FAILED ESP GEARBO:< (5126-512ì 00:5.250) MOTOR (5127-5134. 00:5.620) Perf (5149-9810) SLOTTED LINER ¡SCREENS (5149-9810. 00:4.500 Wt:12.6ü 1st Quarter 2004 Flowline Inspections Subject: CPAI 1st Quarter 2004 Flowline Inspections From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 04 Apr 2004 14:07:31 -0800 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us> CPAI flowline inspection reports for ConocoPhillips wells that have annular flow. Please lD-121 are both shut-in with reservoir problems and we have suspended the flowline resume the inspections if and/or when the wells return to production. Well 3H-05 is flowing continue, but the well will (hopefully) get a workover this summer and will no longer have Tom: Attached are the latest note that wells lD-105A and inspections. We will and inspections will annular flow Please call if you have any questions Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 «lD-105A Qrty Inspection.doc» Qrty Inspection.doc» 1D-105A Qrty Inspection.doc application/msword base64 «3H-05 Content-Description Content-Type: Content-Encoding: Inspection. doc» Qrty ID-I05A Qrty Inspection.doc «lD-121 ¿Lot - dDd.- Content-Description: 1D-121 Qrty Inspection.doc application/msword base64 Content-Type: Content-Encoding: Qrty Inspection.doc ID-121 4/5/20047:46 AM Content-Description: 3H-05 Qrty Inspection.doc application/msword base64 Content-Type: Content-Encoding: 3H-05 Qrty Inspection.doc of -----Original Message----- From: NSK Corr DS Coord Sent: Thursday, November 27, 2003 6:07 AM To: CPFl Prod Supv Cc: CPFl DS Lead Techs; NSK Corr Chem&Monitoring; NSK Corr Insp Piping; NSK Corr Vessel Insp; NSK DS Fac Engr; NSK Engr&Corr Supv; NSK Full Field Prod Engr; NSK Problem Well Supv Subject: ID-lOS Quarterly Inspection Results John I Van: On 11/26/03 we completed our quarterly follow-up inspection on the drillsit 10-105 rise and flowline. This inspection was originated due to our agreement with the AOG over cerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-1 D13-F4.4) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 05/31/03. This inspection consisted of Radiographic inspection on the divert tee to the test and production headers as well as the lower elbows to the headers. No Ultrasonic inspection of the 2 elbows located at the wellhead could be performed at this time since the well was shut-in. Please refer to the attached corrosion spreadsheet for our inspection summary on 1 D-1 05. Future Inspection Plans: We will re-inspect these locations again on a quarterly basis (2/28/04) as referenced in your e-mail dated 11/21/02. All UT data and film is on file with corrosion and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or AI Dahlquist at ext 7773. Thank you, George Foley / Chuck Froiland OS Inspection Coordinator NSK-39 4 f:k. ~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 API No. 50-029-22843-01-00 CONOCOPHILLlPS ALASKA INC Operator KUPARUK RIV U WSAK 1D-105A Well Name/No. 2012020 Permit to Dri UIC N 1-01L Current Status 1-01L Completion Status ,--/ 11/3/2001 Completion Date .,; 3830 TVD ,.-- 9820 MD REQUIRED INFORMATION .we-- y)../).... Master Well Data Maint Directional Survey (data taken from Logs Portion of No Samples No Mud Log DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: ......... Comments Digital Data: Rate o-f--l Penetration, Dual Gamma I Ray, Electormagnetic ' Wave Resistivity I i i j ¡ _____J Electr Dataset Number cJJ260 Log/ Data Type ED Received 11/1/2002 OH CH Case Interval Start Stop - - 5205 9820 Run No Log Media Log Scale Name Digital Med/Frmt C 5/2002 3/4/2002 3/1 Case Open 2828 9766 10 5205 -1Ó709 J0647 C D ED ED Wel Sample Set Number Interval Stop Cores/Samples Information: Comments Received Sent Start Name ADDITIONAL INFORMATION Well Cored? Y 10 -- =ß'/N tYlN Daily History Received? Formation Tops Y/N No 'r t'^ v I,A.. 'i I ~ L IL J ~... ~ \3 ~ rì S ~ I4"-U- Mt l~ yll't~r /t-~ I ì J~ ^ÚJJÂ. Analysis ReceitJ Comments: ~ ~T S\\ - ~J v Date: Compliance Reviewed By: Uuarterly tlowline inspection reports (' Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom _ maunder@admin.state.ak.us, bob _fleckenstein@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> ( Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 10-102: PTO 2000750, Sundry #302-101 10-105A: PTO 2012020, Sundry #302-294 1 0-110A: PTO 2000390, Sundry #302-227 10-121: PTO 1971810, Sundry #302-304 10-127: PTO 1981090, Sundry #353-057 10-129: PTO 1972130, Sundry #303-092 10-140: PTO 2001360, Sundry #302-376 3H-05: PTO 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 10-102 Insp Log.xls)(See attached file: 10-105 Inspection Log.xls)(See attached file: 10-110 Insp Log.xls)(See attached file: 10-121 Inspection Log.xls)(See attached file: 10-127 Inspection Log.xls)(See attached file: 10-129 Inspection Log.xls)(See attached file: 10-140 Inspection Log.xls) ¡ Name: 3H-05 Quarterly Inspection Log.xls (, ~3H-05 Quarterlv Inspection Loq.xls, Type: EXCEL File (application/msexcel) i..... ... ........ '" ....... . . ... .... .. ........ . . ¡ ~ncoding:b~se64 . . ...... .... .....H. l<6'ì-O,\ ji ¡Name: 10-102 Insp Log.xls : ~10-102 Insp Loq.xlsi Type: EXCEL File (application/msexcel) ¡ I Encoding: base64 : ~ÖO-()\5 J ! ~ . Name: 10-105 Inspection Log.xls ~10-105 Inspection Loq.xls, Type: EXCEL File (application/msexcel): Encoding: base64 (¡ ~ Name: 10-11 0 I~sp Log.~ls . : ~ 1 0-11 0 Insp Loq.xls Type: EXCEL File (appllcatlon/msexcel) J\)O - 0 ~ <; , Encod~ng: base64 ~() \- àCd ~..,..,"..".- I Name: 10-121 Inspection Log.xls ¡ ! ~ 1 0-121 Inspection Loq.xls' Type: EXCEL File (application/msexcel)i \ <1 ~ _ \ %' \ . Encoding: base64 ! J¡ Name: 1D-127 Inspection Log.xls , ; ~ 1 0-127 Inspection Loq.xls Type: EXCEL File (application/msexcel)! \ S. '6--l 0<; Encoding: base64 1 of 2 10/6/20033:17 pt\ Re: 10-105 Quarterly Inspection Results (' Subject: Re: 1 D-1 05 Quarterly Inspection Results Date: Mon, 6 Oct 2003 19:34:33 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> \ Tom, The 10-105 erosion damage ended up not being "real" Below is the update report and inspection log Please let me know if you have any questions MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224,659-7043 ----- Forwarded by NSK Problem Well Supv/PPCO on 10/06/2003 07:32 PM ----- NSK Corr OS Coord 10/06/2003 07:28 PM To: CPF1 Prod Supv/PPCO@Phillips cc: CPF1 DS Lead Techs/PPCO@Phillips, NSK Corr Chem&Monitoring/PPCO@Phillips, NSK Corr Insp Piping/PPCO@Phillips, NSK Corr Vessellnsp/PPCO@Phillips, NSK OS Fac Engr/PPCO@Phillips, NSK Engr&Corr Supv/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips Subject: Re: 10-105 Quarterly Inspection Results(Oocument link: NSK Problem Well Supv) CareyNan, I would like to clarify that the reported "possible damage" as referenced in the inspection report below is incorrect. The area in question was the cosasco fitting o-Iet weld on the welline. There was suspicion of erosion to the weld area of the o-Iet from the initial radiograph. A confirmation radiograph was taken which verified that there was no damage and that the suspected erosion was actually shading on the radiograph due to the inconsistent geometry of the weld. The "possible damage" should have never been reported initially, as it is our policy to confirm whether there is or is not any damage and report it as such. I have revised the Inspection Log and attached it for your reference. (See attached file: 1 D-1 05 Inspection Log.xls) Thank you, George Foley OS Inspection Coordinator NSK-39 n1016@conocophillips.com Office: (907) 659-7209 NSK Corr OS Coord 1 of 3 10/7/20036:52 AM 10-105 Quarterly Inspection Results (" Subject: 1 D-1 05 Quarterly Inspection Results Date: Mon, 6 Oct 2003 16:14:24 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> Tom, Here is the inspection report. It doesn't give much detail - I called the Corrosion Dept and asked them to send me a summary explaining the damage a little better. I will forward that to you as soon as I get it. The 1 D workovers will start in -2 weeks. We will start the boroscope inspections with in the next week or so. Would you like us to call an Inspector to witness? MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 ----- Forwarded by NSK Problem Well Supv/PPCO on 10/06/2003 04:03 PM ----- NSK Corr DS Coord 09/02/2003 12:52 PM ( To: CPF1 Prod Supv/PPCO@Phillips cc: CPF1 DS Lead Techs/PPCO@Phillips, NSK Corr Insp Piping/PPCO@Phillips, NSK DS Fac Engr/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips, NSK Engr&Corr Supv/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips, NSK Corr Vessellnsp/PPCO@Phillips, NSK Corr Chem&Monitoring/PPCO@Phillips Subject: 1 D-1 05 Quarterly Inspection Results CareyNan, On 8/30/03 we completed our quarterly follow-up inspection on the drillsite 1 D-1 05 riser and flowline. This inspection was originated due to our agreement with the AOGCC over concerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-1 D13-F4.4) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 05/31/03. This inspection consisted of Ultrasonic inspection of the 2 elbows located at the wellhead on the 3" production line and Radiographic inspection on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for our inspection summary on 1 D-1 05. We did find an area of possible damage on a previously uninspected area but, the damage is not caused by the piping arrangement in question since it is located at least 2 elbows away from the tie-in to the production header piping. Future Inspection Plans: We will re-inspect these locations again on a quarterly basis (11/31/03) as referenced in your e-mail dated 11/21/02. 1of2 10/6/20034:12 PM 1 LJ-1 05 Uuarterly Inspection Results ( ( All UT data and film is on file with corrosion and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or AI Dahlquist at ext 7773. (See attached file: 1 D-1 05 Inspection Log.xls) Thank you, George Foley / Chuck Froiland DS Inspection Coordinator NSK-39 n 1 016@conocophillips.com Office: (907) 659-7209 L__.....,~__~__~._.___.. .,__.^~,_.~_~_T__·'~cm~_c^.,,~ ~ "" ""'''''_"'''' ,~,~..M.._~."·"._,,,~_,.,, ,~_, ~w,~n."'''_~''_--''~'".",~~~."".,_''''"", . ""·~,,~,_·,,,"',~nn.,_ ~~"., Name: 1 D-1 05 Inspection Log.xls ~ 1 D-1 05 Inspection Loq.xls·. Type: EXCEL File (application/msexcel) Encoding: base64 2of2 10/6/20034:12 PM ... QUàrtérly Flowline line inspections (' " Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "n1617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 10-102: PTO 2000750, Sundry #302-101 10-105A: PTO 2012020, Sundry #302-294 10-110A: PTO 2000390, Sundry #302-227 10-121: PTO 1971810, Sundry #302-304 10-127: PTO 1981090, Sundry #353-057 10-129: PTO 1972130, Sundry #303-092 10-140: PTO 2001360, Sundry #302-376 3H-05: PTO 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 31:-1-05 Quarterly Inspection Log.xls)(See attached file: 10-1021nsp Log.xls)(See attached file: 10-105 Inspection Log.xls)(See attached file: 10-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1 0-127 Inspection Log.xls)(See attached file: 10-129 Inspection Log.xls)(See attached file: 10-140 Inspection Log.xls) 3H-05 Quarterly Inspection Log.xls ~3H-05 Quarterly Inspection LOQ.xls Type: EXCEL File (application/msexcel) _ . . Encoding:~ase64 Name: 10-102 Insp Log.xls ~10-102 Insp Loa.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~~.~~1~~.:"~:::~::~~:~~.~~~1~~.~;i;U~~iE~"~~~~~:~::~.:x~::)J ....................................".......................···············,,"··..··r·····..·..··,,···········..·..····........................................,.........,............................~.......,._,..."......"."........._..,... I Name: 1 0-110 Insp Log.xls ~ 1 0-11 0 Insp Loa.xls ¡ Type: EXCEL File (application/msexcel) ! Encoding: base64 Name: 10-121 Inspection Log.xls i ~ 1 0-121 Inspection LOQ.xls Type: EXCEL File (application/msexcel) ¡ Encoding: base64 ¡ ---.J 1 of 2 7/14/2003 10:39 AM Ke: Quarterly flowline inspection reports ( Subject: Re: Quarterly flowline inspection reports Date: Mon, 06 Oct 2003 15:28:04 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@conocophillips.com> ~( MJ, I received the quarterly flowline inspections for those wells with "alternate" lift/flow paths. The only one remarkable is 10-105. There is a comment regarding a "report for new damage found at carr 1040 @ 1'0" at cosasco fitting." I was wondering what was found and if it was possible to get a copy of the report? 00 you have any information regarding the workover program and how close the work is getting on some of these wells. It will be interesting to see what a physical inspection shows on some of these flowlines when they are removed. Thanks in advance for your reply. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom, > > Here is a copy of the quarterly flowline inspection reports required to > fulfill the Sundry requirements for the following wells. > > 10-102: pro 2000750, Sundry #302-101 > 10-105A: pro 2012020, Sundry #302-294 > 10-11 OA: pro 2000390, Sundry #302-227 > 10-121: pro 1971810, Sundry #302-304 > 10-127: pro 1981090, Sundry #353-057 > 10-129: pro 1972130, Sundry #303-092 > 10-140: PTO 2001360, Sundry #302-376 > 3H-05: pro 1870770, Sundry #302-102 > > Please let me know if you have any questions. > > Problem Well Supervisor > ConocoPhillips Alaska Inc. > (907) 659-7224, 659-7043 > > (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: > 10-1021nsp Log.xls)(See attached file: 10-105 Inspection Log.xls)(See > attached file: 10-110 Insp Log.xls)(See attached file: 10-121 Inspection > Log.xls)(See attached file: 1 0-127 Inspection Log.xls)(See attached file: > 10-129 Inspection Log.xls)(See attached file: 10-140 Inspection Log.xls) > > ------------------------------------------------------------------------ > > > > > Name: 10-102 Insp Log.xls > 10-1021nsp Log.xls Type: EXCEL File (application/msexcel) > Encodmg:base64 > > > > > Name: 3H-05 Quarterly Inspection Log.xls 3H-05 Quarterly Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: 10-105 Inspection Log.xls 10-105 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 1 of 2 10/6/20034:12 PM Re: 10-105 Quarterly Inspection Results (' ( 09/02/2003 12:52 PM To: CPF1 Prod Supv/PPCO@Phillips cc: CPF1 DS Lead Techs/PPCO@Phillips, NSK Corr Insp Piping/PPCO@Phillips, NSK DS Fac Engr/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips, NSK Engr&Corr Supv/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips, NSK Corr Vessel Insp/PPCO@Phillips, NSK Corr Chem&Monitoring/PPCO@Phillips Subject: 1 D-105 Quarterly Inspection Results CareyNan, On 8/30/03 we completed our quarterly follow-up inspection on the drillsite 1 D-1 05 riser and flowline. This inspection was originated due to our agreement with the AOGCC over concerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-1 D13-F4.4) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 05/31/03. This inspection consisted of Ultrasonic inspection of the 2 elbows located at the wellhead on the 3" production line and Radiographic inspection on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for our inspection summary on 1 D-1 05. We did find an area of possible damage on a previously uninspected area but, the damage is not caused by the piping arrangement in question since it is located at least 2 elbows away from the tie-in to the production header piping. Future Inspection Plans: We will re-inspect these locations again on a quarterly basis (11/31/03) as referenced in your e-mail dated 11/21/02. All UT data and film is on file with corrosion and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or AI Dahlquist at ext 7773. (See attached file: 1 D-1 05 Inspection Log.xls) Thank you, George Foley / Chuck Froiland DS Inspection Coordinator NSK-39 n1016@conocophillips.com Office: (907) 659-7209 \"'.........."''''..". ,,,",,",.,....,,,'"\..·,,,,',.,,,','..M.M.\,,.~"W,',," .""",' ,. ~...."",...^\",."'"".".II,..,.......\....""I"',.""",',,"-¡""',,,,...........',..""".....,",'"."""""\'n"'n.'...""''''''.,_''"..",.~,,, ,\,"~,..,""..,,,' .........,...,,,,..,, .."..,1" ,.........."......., ."",".I"",~,.."."", , ...m,. ~",..",w"\""'"'''''''''.''."II,,,,,'I..,,,"_,,,,,.,...,,,,,,,,,.,,,,,,"'"'''.M'''^''''''''''''''''''..'m''''''''"''^',''.''' "'"'''''''''' M.",..".""",w,'~"""" _...,.",.. "''',,.~ ,.....,,'."' ,.'",~,., """III.."".,,,,,,,'m",,W",,,,',', "',"n.',.. ""n'WO.""..' , "'n' r Name: 1 D-1 05 Inspection Log.xls ~ 1 D-1 05 Inspection Loq.xls ¡ Type: EXCEL File (application/msexcel) , Encoding: base64 Name: 1 D-105 Inspection Log.xls ~ 1 D-1 05 Inspection Loq.xls Type: EXCEL File (application/msexcel) Encoding: base64 2 of 3 10/7/20036:52 AM ( ~ ~~~:~.5~!~~t:t:~::~n::::~-,~~=t-=----~,,-==~--==~===','=- - =--=-~-~_~ - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B~ I, N -(B-:baseTine- inspection, I - Increäse-iïi % wall loss, N - No change from previous inspection) f-'- ~-------- I ----,-------- -~at~-~f---~r-#--Of In~~ection j B I N- ~:::tL~::e Damage 1- ----- Comments Inspection Locations ' , o¡. Grade I--_____~___ ________ 0 ---- 10/11/02 6 B 0% A Baseline Inspection 10/28/02 ---I 6 N 0% A 2 Week Follow-up -- 11/12/02 6 N 0% __~_ _~YVeek Follow-up ________ Line shut in No i~~p required -------~-- -- ------ .--- ----- ,..- 05/07/03 05/31/03 -- 08/30/03 -------.--- --- 0% A -6%-- .~ 0% ~ ------- Y;') f7IIl" lQ I k§)- ~ ~ "-v New baseline established for well head riser Monthly follow-up No changes t~ inspection locations, s~e report for new ___~amage found at corr ID 40@ 1'0" at cosasco fitting -- 6 6 6~ \ '- B .. __r-- 1'1 N .- --f------ ---- -- --- --- .---- -- ------ -- ------- ---- --- --- .- - --_. - -----. -.----- -- ---- -- .- ---- ~-, - .- -- --------- '-- -.-------------..------ --.- - 1-- ---- --------- 1---- 1---,- 1---- f----.- -- ------- f-- 1--- ,( ConocciP'hillips (' Nina Woods/MJ Loveland Problem Well Supervisor P.O. Box 100360, NSK 69 Anchorage, AK 99510-0360 Phone 907-659-7224 August 24, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7lh Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., West Sak well ID-I05A. The variance request is to extend the length of Sundry (#302-294) to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call MJ Loveland or myself at 907-659-7224 if you have any questions. ConocoPhillips Problem Well Supervisor Attachments ORIGINAL '.... ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ( ~~~ ~~6 /) 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 5141' FNL, 596' FEL, Sec. 14, T11 N, R10E, UM At top of productive interval At effective depth At total depth 3285' FNL, 3170' FEL, Sec. 12, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR PRODUCTION SLOTTED LINER' Length 121' 5111' 4661' Size Cemented Measured Depth True vertical Depth 16" 9 cu yds High Early 121' 121' 7-5/8" 570 bbls AS III LW 366 bbls Class 5212' 3608' G, 60 sx Class G 4-1/2" Excluder Screens 9810' 3830' Perforation depth: Operational shutdown _ Plugging _ Pull tubing 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service (asp's 560490,5959800) (asp's 563130,5966959) 9820 feet 3830 feet Plugs (measured) feet feet Junk (measured) measured No Perfs - Slotted Liner with Screens in Lateral true vertical Tubing (size, grade, and measured depth 3-1/2",9.3#, L-BO Tbg @ 5097' MD. Re-enter suspended well _ Time extension _ Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name \l.-ù~,ù \t- Q', 'Vetr P'oH:U ~ Unit 8. Well number 1D-105A 9. Permit number I approval number 201-202 10. API number 50-029-22843-01 11. Field I Pool ·nt cl Oil Pool W~S\ ~~\(.." Other X ( I' "'I Packers & SSSV (type & measured depth) Old completion squeezed beneath cement retainer @ 5229' MD and Top of window 5210' MD/ 3597' TVD. 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation 16. If proposal was verbally approved Detailed operations program _ 15. Status of well classification as: Oil_X Name of approver Date approved Service 17. I hereby certi t the fo egOin~~true and correct to the best of my knowledge. Wø'~ Title: Problem Well Supervisor BOP sketch Gas Suspended _ Questions? Call Nina Woods/MJ Loveland 659-7224 Date 8 ... ).. /P-q; FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ((.,'{ D\ '"<t ~ Plug integrity _ BOP Test _ Location clearan\:e_ Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission ~ Form 1 0-403 Rev 06/15/88 · ~L. ORIGINAL IRBDMS BF;L ~~~ 1 ;"C,('~' )nn,:~\ SUBMIT IN TRIPLICATE \ '''.:;:11 TUBING (0-5097, 00:3.500, 10:2.992) ~OOUCTlON (0-5212. 00:7.625, Wt29.70) PUP (4998-5107, 00:3.500) NIP (5107-5108, 00:3.500) PUP (5108-5112, 00:3.500) SEAL (5112-5126, 00:5.130) GEARBOX (5126-5127, 00:5.250) MOTOR (5127-5134, 00:5.620) SLOTTED LINER N/SCREENS (5149-9810, 00:4.500, Wt:12.60) ConocoPhillips Alaska, Inc. (" (" KRU 1D-105A API: 500292284301 SSSV Type: NONE Well T e: PROD Orig 11/3/2001 Com letion: Last W/O: 11/3/2001 Annular Fluid: Bottom 121 5212 9810 Slipstop/Packoff set 10/3/2002 5107 3513 5108 3514 5112 3517 5126 3530 5127 3531 CENTRIUFT SLOTTED NIPPLE Rev Reason: Set slipstop on packoff. GL V by ImO Last U date: 10/24/2002 TVD 121 3608 3830 Wt 62.58 29.70 12.60 Grade H-40 L-80 L-80 ESPSEALGST3DBILH6PFS ESP GEARBOX 9:1 525 SERIES KMH PCESP MOTOR 57 HP 1315/26 KMH CentrFili7f!rw'êAKER Sentry GFlllq~ ~ 5094' ~~1D. 3500' TVD 1D-105A Thread WELDED BTCM EUE8RD Thread EUE8RD Vlv Cmnt ID 2.992 0.000 2.992 2.992 0.000 0.000 0.000 0.000 (' ( ConocoPhillips Alaska, Inc. Kuparuk WelllD-105A (PTD# 2012020) SUNDRY NOTICE 10-403 VARIANCE REQUEST 8/14/2003 The purpose of this Sundry Notice is for approval to extend the length of Sundry #302-294 for a 12-month period. West Sak well ID-I05A is an ESP completion that operates under Sundry (#302-294) approval to produce with gaslift down the tubing after the ESP failed. The original Sundry was approved for 12 months, which expires on 9/11/03. A baseline inspection was done on 10/11/02 with subsequent inspections showing no erosion. The latest production test on 4/29/03 recorded 360 bopd, 24 bwpd with 520 mscfd of lift gas. This well has not been online consistently. Lack of reservoir support has kept the well shut in. An injector was recently drilled, but pressure support has not been noticed in the area at this time. The current sundry was approved on 9/19/02, which allowed lift gas to be injected down the tubing and production up the annulus. ConocoPhillips proposes to maintain an inspection schedule that was approved for all identical Sundry requests. Future Inspection Plans: Recurring Quarterly inspection schedule will be as follows: Submit inspections on a quarterly basis to the AOGCC. ConocoPhillips proposes that the AOGCC approve the above variance request for twelve months from. the approval date. Attached is a wellbore schematic. ( ('" The following is the inspection log results: 1 D-1 05 Special Inspection Request Log DS1D 1D-105 - 2 in. Annulus flowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection Worst Damage B, I, N Case Wall Comments Inspection Locations Loss % Grade 1 0/11/02 6 B 0% A Baseline Inspection 1 0/28/02 6 N 0% A 2 Week Follow-up 11/12/02 6 N 0% A 2 Week Follow-up Line shut in No insp required 05/07/03 6 B 0% A New baseline established for well head riser 05/31/03 6 N 0% A Monthly follow-up 08/31/03 Quarterly Production Well Individual Summary by Month: CONOCOPHILLIPS ALASKA INC Operator: 2012020 Permit to Dri 50-029-22843-01-00 API: KUPARUK RN U WSAK ID-I05A KUP ARUK RNER, WEST SAK OIL Name: Wel Dee Flowing 29 0,126 517 -OIL Current Status 1-0 IL Final Status: 104 Acct Grp: 40 Sales Cd: FieldIPool Nov Flowing 1 Oct Sep Aug Jul Jun May Apr Mar Feb Jan 24 ~S\\~\-C'\ 2 úOO\O\)~J \ èum Gas #Error 2001 Meth Days Oil Wtr Gas .=- Cum Wtr 10,150 Cum Oil #Error Gas 519 Water 10,150 Oil Totals: 2001 Dee Shut-In o o o Nov Lift 3 o o Gas Oct Lift 20 4,468 12 Gas Shut-In o o o Aug Shut-In o o o Jul Shut-In o o o Jun Flowing 14 3,377 29 May Flowing 31 7,947 83 Apr Flowing 30 8,146 54 Mar Flowing 31 9,027 48 Feb Flowing 28 8,694 36 Jan Flowing 31 10,148 31 2002 Meth Days Oil Wtr Gas #Error Cum Gas 812 Cum Wtr 61,957 Cum Oil #Error Gas 293 Water Oil 51,807 Dee Nov Oct Sep Aug Jul Shut-In Jun Shut-In May Gas Lift Apr Gas Lift Mar Shut-In Feb Shut-In o o o o o o 16 1,790 135 3 152 41 o o o o o o Jan Shut-In o o o Totals: -,~ 2002 2003 Meth Days Oil Wtr Gas Page #Error Cum Gas L..... ¿}OD hw \J0rc \ \ "'-CJ. c" 0 I'- \ì 'f~~ \~ ^:::.r S ~~~"'-~ ( ~ ~"S ~Q:\\8~Ñ)~ ~ú\Lfè -\-""~\~ '"?ïOfO~Cr "\t..:D ,\W \.)~ \r;.CS'lè CV '-.) \ L , 988 ç,~oO 'bo ~ Cum Wtr 63,899 ~ Cum Oil #Error Gas 176 Water 1,942 \\Jo ,,~~ . ~\~ ~\<;~~lk' ~ Oil Totals: 2003 (. (' 1 D-1 05 Special I nspection Request Log DS1 D 1 D-105~~~~-_-.~-~~~~~=__ - -: __ ~~º__S:_:~_~_Qcl_-~m~_ -2 in. AIl_,!~I~~_~~_~_~~_~_ll1_~p~cti_on m_____u__. __ .__ _.__ __ __u_ __ _m._____ .__ _m - Twic~ ~C?Il!~!~ in~_e.~E.!!C?Il.freqlJency Jo~_~__~_C?!!!!'1~_!.h~.Il re'yiew ~y op~r_~!i~_I1~_!.~_JIl~J>~~!i~~!~~g_~~r1.~y_ B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) --.: -::~=~-=~~.I~==::'==-~=::'-=--=--=~~~~-_ . -. - - ---- - - - -- ---=i-Wi~t-C~~~-¡~ ----~- - -- - -. -----~--~: =-=-=~~=-~- ------~:-~=- -~~::~=--=-::.--.:.=====--==-=-=:-::-- ~- -= - -==:--- Date of # of Inspection' B, I, N I Wall Loss I D~m:ge Comments 1~1~1;/~182~;/~oi~2n Loca~6tions ..:I-----~~Nm-I-·=~o.-~o~--t~ r~Aa e _ . _ =-~n~~~----__~a;~H~r,~~~~~~=-=== _ ." __ J n .._ ___.J_V\IeE¡k Fall 0IN-uP. . _ un . __ Line s~LJ_t_~~_~_~J!!se.req~~d _~~L~==~_--- ____.__________ __ '''___n''__~ ~_u_ - -. - ".-".-.- ~- - - ----,-..-~--_.___,_ ____.___....___._._______.-____ __0 _ ~__, .__.._ _ _._._. __.__._____ .__.. _.u _____ -. -- --- --,-------.-. -_._------------- -------..----,..- ------..-----..--.--,---..-..---..---------.-.----.-.- -."- -.-- 05/07/03 6 B 0% A · .-..-".,-.-..--..-____""'_. _.._..____~._._____.____.~__._.~ .._ ______.__... ..-'un______ _.._~.______" ____.u"' 05/31/03 6 N 0% A - ._'._._.._ ___ "___.___.~_....____.._.__.__.______ __..__..__.n_.___.__ ...______._.___._.__.._._..____.._._...._ ___. _n_ _._._..._ 08/31/03 -.. -." .._._....._..""__.__ ,__.._~_._._.___..__,___.______ _____..._. ___.._..__.. __..__,__._ ..__. _... _. n.._..__. __.'_'_'___'_"_'_ _,,______ _ _____._.____.. 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'._.... .._.._._._,__........__ ...._ ,._ ._..___,_ ---. ._---_.._......_....~.._- -. ,---"....__... - . ---.--.____._._.._._..._~.__._.._.__.__,...___.._._ ___""__'_"""'__"'''h_'___ _ _._....___~ ..~~_.. _ _._ _. .___.._______.._...____... ..__.____..,...._...... _,..__ _,,,_ --' .---.- ..-..- --_.-..--- -.-.,-,-..~---~--_._- _._--"...---... ..- _.~. . ---"'''-"'.'- ". _ --........--."...-..-----.......-..----.--- -.-'." ...--..---.......- . - ---.., ~ ..---...-.... ...-...--- ...-.. .--...-".-.-.... -..--...,..-.-..-.-..-......., ..- , aO{-~C0 Il~da WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 October 31, 2002 RE: MWD Formation Evaluation Logs: 1D-105~ AK-:MM:-11172 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., J\nchorage, AK 99518 ID-I05A: Digital Log Images: 50-029-22843-01 1 CD Rom ~~ RECEIVED NOV 0 1 200::~ Alaska OJ) & Ga~¡ C~n.:;. Ccmmi~sion Ariz~Jt.tir¡~ ~:~ '... W6A- ~ lYTS APPLICATION FOR SUNDRY APPROVALS ( "Ilulf) L ~/r;(~ 9 j 'ì }o 2- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ( 1. Type of request: Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5141' FNL, 596' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 3285' FNL, 3170' FEL, Sec. 12, T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 121' 16" PRODUCTION 5111' 7-5/8" SLOTTED LINER' 4661' 4-1/2" Perforation depth: Operational shutdown _ Plugging _ Pull tubing 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service (asp's 560490,5959800) (asp's 563130,5966959) 9820 feet 3830 feet Plugs (measured) feet Junk (measured) feet Cemented 9 cu yds High Early 570 bbls AS III LW 366 bbls Class G. 60 sx Class G Excluder Screens measured No Perfs - Slotted Liner with Screens in Lateral true vertical Tubing (size, grade, and measured depth 3-1/2",9.3#, L-BO Tbg @ 5097' MD. Packers & SSSV (type & measured depth) Re-enter suspended well _ Time extension Stimulate _ Variance Perforate 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Other X Point Mcintyre Unit 8. Well number 1 D-1 05A / 9. Permit number I approval number 201-202 10. API number 50-029-22843-01 11. Field / Pool Point Mcintyre Oil Pool Measured Depth 121' 5212' 9810' True vertical Depth 121' 3608' 3830' j, ~i "r,.,ß; C···'·:-',.i ~.Jt.., .,:, . ~) j \L ~...) \;Il~~ :;11 Old completion squeezed beneath cement retainer @ 5229' MD and Top of window 5210' MD/ 3597' TVD. 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation September 16, 2002 16. If proposal was verbally approved Detailed operations program 15. Status of well classification as: Oil_X Service FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance ~ff~n:~re¥ p..' r-< s 'ì III( ;tquent form required 10- Approved by order of the Commission Onglnal Slgn~ By Commissioner Title: Problem Well Supervisor Form 1 0-403 Rev 06/15/88 · BOP sketch Gas Suspended _ Questions? Call Pete Nezaticky 659-7224 Date 9 '9/c:) Z- Date 2 SUBMIT IN TRIPLICATE ( ( Phillips Alaska, Inc. West Sak WelllD-lO5A SUNDRY NOTICE 10-403 VARIANCE REQUEST 9/07/02 The purpose of this Sundry Notice is for approval to t~orarily gaslift West Sak producer ID- 105A that is completed as an ESP (electric submersible pump) well. The ESP has failed and a workover is required to pull and replace tpe ESP, and is expected to occur during 2003. The well makes approximately 250 bopd via ESP,/a majority of which may be possible to produce on gaslift. Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel:, A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed /" allowing reverse-direction flow. The maximum anticipated gaslift rate will be 1000-1500 mcfd. .f' The bottom of the tubing string will be sealedpf(~ith a modified packoff to seal the ESP pump intake. Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 150-200 BOPD. ~,..- The basic gaslift and production facilities layout for ID-I05A (under construction) will be identical to the current 1D-110A and 1D-102Iayout. Phillips has presently started fabrication and will install a new 3" annulus flowline on 1D-102 to replace the existing 2" flowline prior to production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design is being implemented for ID-II0A and 1D-I02 as a pro-active measure, even though there was no indication of active erosion in the 2" line that was on we1l1D-110A.) Velocity calculations have been done with maximum anticipated flow rates of 200 BLPD and 2 MMcfd up the annulus ang through the 3" annular flow line. Production pressure is approximately 230 PSIG.'" The maximum velocity through the NPS 3" sch 160 A333 Gr6line will be 60 ftls. <;' There have been six (6) solids shakeouts on we1l1D-105A since December 2001 and they range from 0.0% to 0.05% by volume. Phillips intends to take production shakeouts both initially and periodically to monitor future performance. Below is a table of recent well test information. Well 1 D-1 05A Oil Producer (Production with ESP in operation) FTP FTT Oil Water WC Form gas Form GaR Form GLR ESP speed Well Name Choke Position (psiQ) DeQ F' BOPD BWPD % mcfd scf/stb scf/stb HZ 1 D-1 05A 100 256 79 254 3 1 268 1052 1040 26.9 1 D-1 05A 100 245 79 256 1 0 260 1016 1011 26.9 1 D-1 05A 100 256 79 265 3 1 273 1028 1014 26.9 1 D-1 05A 100 282 78 272 3 1 270 992 981 26.9 1 D-1 05A 100 271 78 280 1 1 255 911 906 26.9 1 D-1 05A 100 269 78 286 1 0 246 860 856 26.9 1 D-1 05A 100 271 78 293 2 1 255 870 864 26.9 1 D-1 05A 100 273 77 302 1 0 249 825 821 26.9 1 D-105A 100 283 77 317 1 0 252 796 793 26.9 1 D-1 05A 100 264 77 328 2 1 238 725 720 26.9 1 D-105A 100 272 76 317 1 0 150 474 472 20.9 1 D-1 05A 100 355 76 340 1 0 143 421 419 20.9 1 D-1 05A 100 359 76 378 2 0 116 309 307 20.9 1 (' (' Future Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows: Inspect after 1 day of production or gas lift " kickoff and bi-weekly once stable production is established. Inspections will be decreased to monthly intervals after two-months of inspections providing degradation is not detected. As an extra safety feature, a valve handle to the IA API valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. Phillips proposes that the AOGCC approve this request for a time period not to exceed 12 ,/ months from the approval date. If a workover is not completed within that time period, the AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. 2 PHilliPS Alaska, Inc. A Subsidiary of PHILliPS PETROLEUM COMPANY TUBING 1D-105A (0-5097, 003500, 102,992) ,OOUCTION (0-5212, 007625, Wt29.70) PUP (4998-5107, 003500) NIP (5107-5108, 003,500) PUP (5108-5112, 003,500) SEAL (5112-5126, 005,130) GEARBOX (5126-5127, 005,250) MOTOR (5127-5134, 005,620) SLOTTED LINER NISCREENS (5149-9810, 004500, Wt1260) KRU API: 500292284301 SSSV Type: NONE Well T e: PROD Orlg 11/3/2001 Com letion: Last W/O: 11/3/2001 Annular Fluid: Size 16,000 7,625 4,500 To 0 0 5149 Bottom 121 5212 9810 Descri tion CENTRILIFT SLOTTED NIPPLE 1D-105A TVD 121 3608 3830 Wt 62,58 29.70 12,60 Grade H-40 L-80 L-80 Thread WELDED BTCM EUE8RD Thread EUE8RD 3600' TVD ID 2,992 2,992 2,992 0,000 0,000 0,000 0,000 03/06/02 SeblUII_erger NO. 1874 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk --- Well Job# Log Description Date BL Sepia CD Color "--' 1 D-01 Jlq ~Oc. q PRODUCTION LOG WIDEFT 02118/02 1 1 1 D-01 DEFT LOG 02118/02 1 1 1 D-01 ~ l/ GLS 02118/02 1 1 1 D-119 Yj-d.< )é). INJECTION PROFILE 02120/02 1 1 1M-17 ~ O/-d';' () TEMP LOG 02115/02 1 1 30-09 I ~E' -O( )} PRODUCTION PROFILE 02125/02 1 1 1D-105A ~Oh~C d.. 22068 RST -SIGMA 01/17/02 1 1 1 RI=r.I::I\ leI SIGNEd ~A \ D DATE: ~ r: 2002 ¡I I. , .J- Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Alaska Oil & Gas Cons. Commission Ancb orage j' ., II WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 26, 2002 RE: MWD F ot111ation Evaluation Logs ID-I05^ AK-MM-11172 1 LDWG fot111atted Disc with verification listing. ~I#: 50-029-22843-01 ðo)-a~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 995 18 Signed~ . fA ~ p..J Date: RECEIVED H;~ p 0 / ':.'110" 1."'1., -r L.. L Alaska Oil & Gas Cons. Commission Anchorage ,. ( (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 December 12, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for ID-I05A (201-202) RECEIVED DEe 1 3 ZOOt Alaska Oil & Gas Cons eomm' . Anchoragå . fSSion Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well1D-105A. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. -Y'c. I"l q It 'Ý ( C. Mallary Drilling Engineering Supervisor P AI Drilling CM/skad ORIGINAL (' STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ø Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator ~_..~ 7. Permit Number Phillips Alaska, Inc. Ü'LOCA hOt'4:j 201-202 "' 3. Address ,~~, 8. API Number e ' P. O. Box 100360, Anchorage, AK 99510-0360 j S:;~...'--' " 50-029-22843-01 4. Location of well at surface f): ~'-1- ~ 9. Unit or Lease Name '. '(ASP: 560490, 5959á~0:¿r.:...,-~...-,~d 134' FSL, 595' FEL, Sec. 14, T11 N, R1OE, UM ' ," Kuparuk River Unit . - -" At Top Producing Interval .. .. 10. Well Number ""' ' 2197' FNL, 1366' FWL, Sec. 13, T11 N, R1OE, UM ,..1L:-?~'Q l ' (ASP: 562425, 5962764) 1 D-105A At Total Depth ..~,~~.è;Ji?~~-~:::~.,",;(ASP: 563130, 5966959) 11. Field and Pool 1992' FSL, 2107' FWL, Sec. 12, T11 N, R10E, UM West Sak Oil Pool 5. Elevation in feet (Indicate KB, OF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field RKB 26' feet ADL 25650 & 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions October 18, 2001 October 24, 2001 November 3,2001 NIA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9820' MD I 3830' TVD 9810' MD 13830' TVD YES ø No 0 NIA feet MD 1744' MD 22. Type Electric or Other Logs Run ," GR/Res -r / f),/""dO'1'Ú S"Z-o S' ,w1,Ó 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE wr. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 121' 24" 9 cu yds. High Early 7.625" 29.7# L-80 Surface 5212' 9.875" 570 sx AS III LW, 366 sx AS I, 60 sx Class G (from original well) 4.5" 12.6# L-80 5149' 9810' 6.75" 190 sx Class G - ECP to liner top pkr 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 5097' 5150' & 5460' 5597' - 9810' MD Baker Screens in horizontal hole 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 30, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/6/2001 6 hours Test Period> 73 7 12 100 134 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 307 psi not available 24-Hour Rate> 283 38 48 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED NIA DEC 1 3 2001 AlaSka Oil & Gas Cons. Commission- Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 0 R \ G \ N A L R B 0 M S B F l \) f DEC I 8 200i 29. 30. GEOLOGIC MARKERS FORMATION TESTS MEAS. DEPTH TRUE VERT. DEPTH Include Interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top D Sand Base D Sand 5428' 9820' 3763' 3830' Annulus left open - freeze protected with diesel. ECEIVED DEC 1 3 2001 . Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey :~gn~ 2'~e toll~lng Is I ;;~~~::I:: ~~::r~g SupeNloor C. Ma/Jary Questions? Call Todd Mushovic 265-6974 Date -.lIz Iu. />( 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL '" ~ - ~~PHILLïps ~~ ~ 'V Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/13/2001 10/14/2001 10/15/2001 10/16/2001 t 't í' PHilliPS ALASKA INC. Operations Summary Report 1 D-1 05 1 D-1 05 ROT - SIDETRACK n1433@ ppco.com Nordic 3 Sub From - To Hours Code Code Phase 18:00 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 13:00 13:00 - 16:00 16:00 - 18:00 18:00 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 00:30 00:30 - 05:00 05:00 - 07:30 07:30 - 08:00 08:00 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 02:30 02:30 - 05:00 05:00 - 06:00 06:00 - 10:00 1.00 WAlTON ORDR MOVE 4.00 MOVE 1.00 MOVE MOB MOVE RURD MOVE 13.00 WAlTON EOIP MOVE 3.00 MOVE POSN MOVE 2.00 CMPL TN RURD ABANDN 2.00 CMPLTN CIRC ABANDN 1.00 CMPL TN OBSV ABANDN 3.00 CMPL TN NUND ABANDN 0.50 ABANDI\ NUND ABANDN 4.50 WELCTL BOPE ABANDN 2.50 WELCTL OBSV ABANDN 0.50 ABANDI\ SFTY ABANDN 14.00 ABANDI\ RTRV ABANDN 2.00 ABANDt-. RURD ABANDN 1.00 WELCTL EORP ABANDN 1.00 WELCTL BOPE ABANDN 0.50 WELCTL BOPE ABANDN 2.50 ABANDt-. PULD ABANDN 1.00 ABANDt-. OTHR ABANDN 4.00 ABANDf'. TRIP ABANDN Page 1 of 8 Start: 1 0/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Description of Operations WO field wide crew change & clearance from security to move on road way. Road rig from 1C-102 to 1D105A. Prepare to move over well, load tree in cell ar. Unable to move over well due to thermal "cold sink" - need 2 additional feet. Undable to move over well due to thrmosphy one [need 2 morer feet], callout crane to re move same [0300 hrs], unable to pull. Call out generators to heat same [0600hrs], add 2nd electrical source @ 0900 hrs. @ 1230 h rs unable to pull same. Pad personnel ck fo r no internal pressure & cut same off wi cut off tool [cold cut]. Rig accepted for duty 0000 hrs 10/14/2001. Move over I center over well bore. Berm up around rig, spot miscellaneous equip. Rig u p tarps I wind walls. Pull bpv I vr plug & prepare to cir well. Ru I press test cir lines to flow back tank. Pump 85 bbl 105? diesel down annulus takin g returnes from tbg diverting for recycle, la rge amt of crude in returns [ 4 bpm max pre ss 1100 psi]Follow wi 240 bbl 100? sea wtr. Returns cleaned up well. Monitor well dead, set bpv & rd cir lines. Nd tree I Nu bope. Complete nu bope. Pull bpv install 2 way check valve. Test 2. 875" pipe rams, annular, choke manifold & fl oor safety valves to 2500 I 250 psi. Test w itnessed by John Crsip, Aogcc. Pull test it [2.875"], 2 way ck, pull hanger t 0 floor [65k Ibs], monitor well, & Id pups un der hanger & hanger. PJSM - tbg I esp pump recovery. Pooh wi 2.875" tbg - esp completion. Spool ing heat trace & pump cable. Lost [unaccou nted for] one 1.5" wide x .125" x 6.5" band s & 1 clips. All trays recovered. Ld 165 It s tbg & 10 pups. Rig down handling gear & clean floor. FI uid lost to hole/24 hrs = 252 bbl sw Current oss rate 25 bbl/hr Set test plug, change out upper & lower pip e rams to 4.00". Test upper I lower pipe rams 250 I 2500 psi. Set wear bushing. Load pipe shed wi 170 its 4" dp & strap sam e. Pu I mu bit & scraper. Tih wi bit & scraper. string taking 5 - 25k Printed: 12/6/2001 2:50:20 PM Legal Well Name: Common Well Name: Event Name: Contractor' Name: Rig Name: Date 10/16/2001 10/17/2001 t ( Page 2 of 8 PHILLIPS ALASKA INC. Operations Summary Report 1 D-1 05 1 D-1 05 ROT - SIDETRACK n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 06:00 - 10:00 10:00 - 11 :00 11:00 -12:30 12:30 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 20:00 20:00 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 03:30 03:30 - 04:00 04:00 - 06:30 06:30 - 08:30 4.00 ABAND TRIP 1.00 ABAND TRIP ABANDN ABANDN 1.50 ABAND CIRC ABANDN 2.00 ABAND TRIP ABANDN OTHR ABANDN 0.50 ABAND SFTY ABANDN 4.50 ABAND TRIP ABANDN 0.50 ABAND TRI P 2.50 ABAND TRIP 1.00 ABAND TRIP 3.50 ABAND TRIP ABANDN ABANDN ABANDN ABANDN 0.50 ABAND RURD ABANDN PUMP ABANDN 2.00 CEMEN OTHR ABANDN Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Description of Operations Ibs on last 1500'. Hole deviation up to 56? & dog leg severity to 6? Run in to 5290', p roposed retainer setting depth 5219'. Strin g taking wt wi stand all the way down. Pick up single & ck td @ 5290' rkb Nordic 3. When picking up off bottom a hydraulic qu ick connector [1" to 1.125' od x 2.125" Ion g] fell from TDS to floor & bounced in hole. Inspect stack wi no sighting of same. Well file schematic shows a Baker SC - 1 " tool" @ 5299' rkb Parker 245 [Nabors 245]. WI kb correction of -14' this is 5285' rkb Nordic 3. Circulate one hole volume. Pooh, rotating & working pipe each 1000'. Did not observe any drag or torque. Drain up stack wi scraper below bop. While observing, ease top of scraper juxtapose t 0 top of wear bushing. No recovery. PJS M Ru Schlumberger & make 2 iunk basket runs to 5270' rkb wi md wi 6.5" gage ring {Nor dic 3 depth}. 1st run rec band & small de bris & mangled clip. 2nd run rec small rec ognizable debris of quick disconect. 3rd ru n no recovery RD iunk basket assmby & Mu retainer to wi t 001 string. Tih wi retainer. Run strip charts & correlat e to set retainer top @ 5219' rkb Nordic 3. Drop back down & ck retainer on depth. Poo h wI string I visually ck tools ok. LD retainer running tools & pu stinger for ce menting. Fluid lost to well last 24 hrs = 3 75 bbl Total to well since start ops = 627 b bl Pu & rih wi 132 its + 10 stands of 4' x 14.4 ppf x S-135 pipe. [stinger for retainer alrea dy picked up] Mu cmt lines ck up I down wts @ 95k & 50k I bs. Sting into retainer @ 5219'. PJSM Batch mix 73 sx CI G cmt [.2% 047, .3% D65, .5 % So01 & .4% D167) @ 15.8 pp g, yield 1.16 total pumpable slurry 15 bbl. Establish iniection rate of 2 bpm I 260 psi, pt lines to 3200 psi. Displace cmt to strin g & disp to below retainer wi 57.1 bbl fw. Pressures @ 2 bpm = 250 I 3501 833 psi. 0 bserved cmt on formation where large part 0 f pressure increased occured. Reverse circulate 325 bbl sw, observed a tr ace of dis- coloured water @ bottoms up. S potted 15 bbl of sw treated wi 5 gals retarte Printed: 12/6/2001 2:50:20 PM .... ...... ~ ~'PHILLiPS) [li Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( PHilliPS ALASKA INC. Operations Summary Report 1 D-1 05 1 D-1 05 ROT - SIDETRACK n1433@ppco.com Nordic 3 Page 3 of 8 Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Date From - To Hours Code Sub Phase Code 10/17/2001 06:30 - 08:30 2.00 CEMEN"' OTHR ABANDN 08:30 - 10:30 2.00 CEMEN"' TRIP ABANDN 10:30 - 11 :30 1.00 DRILL OTHR PROD 11 :30 - 12:30 1.00 DRILL PULD PROD 12:30 - 15:30 15:30 - 19:00 19:00 - 20:00 20:00 - 21:00 21 :00 - 00:00 10/18/2001 00:00 . 05:00 3.00 DRILL PULD PROD 3.50 DRILL TRIP PROD 1.00 DRILL OTHR PROD 1.00 DRILL CIRC PROD 3.00 DRILL OTHR PROD 5.00 DRILL DRLG PROD 05:00 - 06:00 1.00 WELCTL CIRC PROD 06:00 - 06:30 0.50 WELCTL TRIP PROD 06:30 - 07:30 1.00 WELCTL OTHR PROD 07:30 - 10:30 3.00 DRILL TRIP PROD 10:30 - 12:00 1.50 DRILL PULD PROD 12:00 - 14:00 2.00 DRILL OTHR PROD 14:00 - 16:30 16:30 - 19:30 2.50 DRILL PULD PROD 3.00 DRILL TRIP PROD Description of Operations d on bottom. Rig down cmt lines. Pooh w/ dp & stinger. Load pipe shed w/remaing bha items & stra p same. Pick up / Make up Bha [Whip stock Assmby], orient - scribe tool face, surface test mwd. Continue to Pu bha. Rih w/ stands to 5150'. Ck up / down wts of 112 & 66k Ibs @ 7 bpm /1070 psi. Orient tool face 25? right of h igh side, slack off to 3' above retainer main taining tool face 25? Slack off to retainer [string taking weight], tool face turned to 1 6? right of high side. Top of retainer @ 522 4.77'. Slack off 22k Ibs & set whipstock an chor. Pick up to ?70 k Ibs verfying anchor set. Set down 30k Ibs & shear mill out ass mby off whip stock assmby. Disp hole & mud system to 9.0 PPG ?550 bbl Isnd mud. Milling window in csg from [top] 5205' to 52 1 2' [i n co m pie t e , total win d ow to b e 1 2 . 5' I on g] 7.3 bpm / 1270 psi. Good steady pump pr essure & reactive milling torque. Complete milling window to 5218' [window 5 205 .5218']. Ream window out several time s. Continue to mill ahd to 5231' [upper mill clear of window. Work mill through window several times w/ no drag. Contine to mill f ormation to 5240'. Cir cond hole to clean returns sweep hole. Spot 15 bbl low water loss pill in new hole. Pull up into csg for formation integrity test. Conduct leak off test to 12.12 ppg emw [Ca I: emw increase = (590 psi)/ (.052 x 3634' t vd) = 3.12ppg emw = 9.0 ppg + 3.12 ppg = 12.12 ppg Pooh w/ milling assmby. Ld down milling assmby. Top mill in gage@ 6.75" Lower string mill 1/16 under @ 6 ?" Starter 1/8 under @ 6.00" Clean floor, replace lights in derrick, flush out surface lines & bop checking for metal scards / debris, adjust torq settings on tds & service rig. Pu bha #2, program mwd & test same. TIH to 5227', wash ream to td of 5240' did n ot observe window. Ck up / down wts of 98 /55 k Ibs & rot of of 75 k while pumping 5.8 bpm /1310 psi. Printed: 12/6/2001 2:50:20 PM - ~ , --, i PHILLIPS ~ . ~ IW 'V' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: "Date 10/18/2001 10/19/2001 10/20/2001 10/21/2001 f ( PHilliPS ALASKA INC. Operations Summary Report 1 D-1 05 1 D-1 05 ROT - SIDETRACK n1433@ ppco.com Nordic 3 Page 4 of 8 Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: From - To Hours Code Sub Phase Code 19:30 - 00:00 00:00 - 14:30 14:30 - 15:00 15:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 08:00 08:00 - 10:00 10:00 - 15:00 15:00 - 15:01 00:00 - 12:00 12:00 - 13:00 13:00 - 15:00 4.50 DRILL DRLG PROD 14.50 DRILL DRLH PROD 0.50 DRILL CIRC 9.00 DRILL PROD DRLH PROD 2.50 DRILL 0.50 DRILL DRLH PROD 5.00 DRILL TRIP CI RC PROD PROD 2.00 DRILL TRIP 5.00 DRILL TRIP 0.02 DRILL PROD PROD DRLH PROD 12.00 DRILL DRLH PROD 1.00 DRILL CIRC PROD 2.00 DRILL TRIP PROD Description of Operations . Dir drlg 5240 - 5390' [3741' tvd]. 1800 psi 1 6 bpm. Very small amt of fine metal on magnates [cleaned prior to start drilling]. T otal recovered on magnates since milling st arted 250 + Ibs, 50% of weight estimated to be trapped sd & cmt cuttings. Dir drlg 5390 - 5714' md [ 3741 - 3790' tvd]. Parameters= 1330 psi I 5.5 bpm, wts up 1 down 1 rot 75 1110 1 50 k Ibs, torque @ 30 r pm on I off bottom 3600 1 3500 ft-Ibs. Disp to BARADRILn Mud Pick up off td 20' to 5694', then reciprocate pipe 5694 - 5674 , while displacing to new mud, return to td a s new mud exits bit for hole cleaning & retu rn to drilling. Dir Drlg 5714 - 6016' md [ 3790 - 3790' tvd] Parameters: 1330 spi 1 5.5 bpm, wts up 1 down I rot 30 rpm 102 155 I 74 k Ibs. adt = 22.67 hrs art = 11.39 ast = 11.28 Dir drlg 6016 -6130' md [3790 - 3792' tvd]. Cir bottoms up. Pump dry sweep based on C aC02. Pooh laying down mud motor & breaking out bit. Down load mwd. Mu motor & bit. Orient ako & program mwd. Tih wI string. Observed window - no proble m getting through same. Tight spots @ 583 0, 5900, 6006 & 6043' that correspond to h ards zones when drilled. Dir drlg 6130 - 6504' md [3792 - s per desired geo tracking]. PP BPM Wts up/dwn/rot rpm on bot 1950 5.5 3 5600 off bot 3801' tvd a P. meters: Tq @ 65 97/55/7 1680 4600 adt = 5.61 hrs, ast = 4.47, art 1.13 Dir drlg 6504 - 7299'md [3801 - 3811 'tvd]. P. meters psi 1 bpm wts up/dwn/rot tq@ 65 rpm on bot 1900/5.8 100/50/70k I bs 5400 15000 ft- Ibs off bot 1750 I 5.8 Sweep hole. recip 1 rot 20 -30' off bottom @ 6.4 bpm 11800 psi. Moderate cuttings to surface, shaker 20% coverage 20 minutes.. Monitor well for 15 min. Pooh to 5210', fina I up wt 105 1 down 50k Ibs. Tight spots @ 6 006 - 6037, 5828, 5784 - 5594,5515 & two s pots not observed on previous bit trip {from 6130'} @ 5594 - 5784 & 5300'. All correlate wI hard stringers or build slides. Printed: 12/6/2001 2:50:20 PM -::: ....... ~ ~~PHILLlPS~ ~ .....,. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~f ( PHilliPS ALASKA INC. Operations Summary Report 1 D-1 05 1 D-1 05 ROT - SIDETRACK n1433@ppco.com Nordic 3 Page 5 of 8 Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Sub From - To Hours Code Code Phase 10/21/2001 15:00 - 15:30 15:30 - 17:30 17:30 - 00:00 10/22/2001 00:00 - 09:30 09:30 - 10:30 10:30 - 11 :30 11 :30 - 19:00 19:00 - 21 :00 21 :00 - 00:00 0.50 DRILL OTHR PROD 2.00 DRILL TRIP PROD 6.50 DRILL DRLH PROD 9.50 DRILL DRLG PROD 1.00 DRILL CIRC PROD 1.00 DRILL TRIP PROD 7.50 DRILL TRIP PROD 2.00 DRILL PULD PROD 3.00 WELCTL BOPE PROD 10/23/2001 00:00 - 00:30 0.50 DRILL OTHR PROD 00:30 - 01 :30 1.00 DRILL OTHR PROD 01 :30 - 04:00 2.50 DRILL PULD PROD 04:00 - 06:00 2.00 DRILL TRIP PROD 06:00 - 06:30 0.50 DRILL OTHR PROD 06:30 - 10:00 3.50 DRILL TRIP PROD 10:00 - 12:00 2.00 DRILL OTHR PROD 12:00 - 18:30 6.50 DRILL DRLH PROD 18:30 - 19:30 1.00 DRILL TRIP PROD Description of Operations . Police floor {wet trip}, service tds. Tih to 7299'. Wash - ream through 5300' ar ea, precautionary wash - ream? 7230' to td of 7299' md [3826' tvd]. Drlg horz section 7299 - 7774' md [3826 - 3 826' tvd]. Disp wI 660 bbl of clean BARAD RILLn mud on the fly after drlg started P.meters: psi I bpm wts up/dwn/rot tq @ 65rpm on bot 1950/5.8 99/55/7 3k Ibs 5800 ft-Ibs off bot 1840 5100 adt = 1 11.25, ast = 6.0 mw=9.8, ecd = 1 22, art = 0.5 eppg Drlg Horizonal section 7774 - 8630' md [382 6 - 3830' tvd]. Resistivity increased from < 200 to > 2000 ohms. P. meters psi I bp m wts up/dwn/rot tq @ 65 rpm on bot 1975/5.9 100155/75 k Ibs 5800 of f bot 1850/5.9 5150 Cir cond for repeat section, pump sweep @ 1850 psi I 6.1 bpm Pooh to 7720 for repeat pass 7720 - 7670' m d. Resistivity readings values in the 2000 0 hm range. Consult wI PPCO engineering - continue to pooh. Continue trip, noted good resistivity while r earning out @ 8400 - 8300' [two tight spots @ 5300 & 5350], consult wI ppco engineerin g & continue to pooh. NOTE: 50% of resi stivity receiver sensor pads [Billy bands co mposed of resin & steel incerts] were damag ed on top set. Do not appear to be damaged by steel to steel [junk] contact. Down load Iwd & Id tools. Pull wear bushing, install test plug. Test b ope 250 psi low 2500 psi high. Annular 250 0 psi. Aogcc notified - waved witnessing 0 f test. Install wear ring Cut & slip drlg. line-check crown-o-matic-se rvice top drive. Pick up BHA #4-upload mwd-shallow test sa me. Run in hole wI 4" dp. Service rig on crew change. Continue rih wI drill pipe filling every 10 st an ds. Mad pass from 8630' to 8440'. Drilling horizontal section from 8630' to 919 6' . Pull 3 stands dp & replace wI 3 stands hwdp -weight needed for sliding. Printed: 12/6/2001 2:50:20 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/23/2001 10/24/2001 10/25/2001 10/26/2001 10/27/2001 10/28/2001 J í PHilliPS ALASKA INC. Operations Summary Report 1 0-1 05 10-105 ROT - SIDETRACK n1433@ ppco.com Nordic 3 Page 6 of 8 Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Sub From - To Hours Code Code Phase 19:30 - 00:00 00:00 - 08:30 08:30 -11:30 11:30 -13:00 13:00 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 03:30 03:30 - 04:00 04:00 - 07:00 07:00 - 10:00 10:00 -11:00 11:00 -19:00 19:00 - 00:00 00:00 - 00:00 00:00 - 03:30 03:30 - 07:00 07:00 -11:30 11 :30 - 14:00 14:00 - 19:30 19:30 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01:30 -10:00 10:00 - 11 :30 11:30 -13:30 4.50 DRILL 8.50 DRILL 3.00 DRILL 1.50 DRILL 6.00 DRILL 4.00 DRILL 1.00 DRILL 3.50 DRILL 0.50 DRILL 3.00 DRILL 3.00 DRILL 1.00 DRILL 8.00 DRILL 5.00 DRILL 24.00 DRILL 3.50 DRILL 3.50 DRILL 4.50 DRILL 2.50 DRILL 5.50 DRILL 1.00 DRILL 2.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 8.50 DRILL 1.50 DRILL 2.00 DRILL DRLH PROD DRLG PROD CIRC PROD TRI P PROD OTHR PROD TRIP PROD PULD PROD PULD PROD OTHR PROD TRI P PROD REAM PROD OTHR PROD OTHR PROD REAM PROD REAM PROD REAM PROD CIRC PROD CIRC PROD CIRC PROD TRIP PROD CIRC PROD TRIP PROD PULD PROD PULD PROD TRIP PROD PULD PROD CIRC PROD CIRC PROD Description of Operations Dr I g. TVD. Down Dr I g. V D) Circ. sweep @ 5.5 bpm-pump 120 bbls. new mud & spot in open hole. Monitor well-poh from 9820 to 8443'. Mad pass from 8443 to 7394-real time from 7394 to 7192. POH wI bha #4-20k over pull @ 5285' & 5775 & sliding from 9196' to 9395'. (3825') (UP WT. Pumping not rotating 110K= wt 40K. & surveys from 9395 to 9820'. (3830 T Lay down BHA & down load mwd. Flush mud motor & mwd-Iay down same-pick up bha #5-hole opener assembly. Change out saver sub & service top drive. RIH wI hole opener assembly to window @ 5 205' . Run thru window wI upper stab & wash & rea m wI hole opener from 5300 to 5536. Circ. while checking malfunction on top driv e. POH to 5157'. Repair upper Quill bushing & Retainer on to p drive-Bolts sheared off-drill out & replace same. Wash & ream hole from 5536 to 6011 '-tight s pots @ 5775'-5945' & 6030'. Washing & reaming Hole wI hole opener ass embly Finish running hole opener to 9820'. (3830' TV D) Circ.-clean hole-rotate & reciprocate-pump s weep. Circ. & reciprocate @ 8 bpm while cleaning pits-loading brine & spotting trucks. Pump spacer-follow spacer wI 8.9# 600bbls. brine-spot 290 bbls. viscosified brine in op en hole. POH wI hole opener assemby-Hole tight agai n from 5440 to 5300'. Work tight spots & cle an up same-spot viscosified brine from 5500 to window. Circ. filtered brine from 5155' to surface. POH wI hole opener assembly. Lay down & send out bha. Lay down bha #5 & send out tools. Pick up bha #6-7 5/811 csg. scraper assembly RIH picking up 57 4 3/411 dc,s & 68 3.5'1 hwd P to 5176'. Rig up & circ. @ 8 bpm 223 bbls. while rot at ing & reciprocating. Rig up for caustic wash-PJSM-Suit up & pum Printed: 12/6/2001 2:50:20 PM 10/29/2001 10/30/2001 10/31/2001 ( . PHilliPS ALASKA INC. Operations Summary Report 13:30 - 15:00 1.50 DRILL CIRC PROD 15:00 - 17:30 2.50 DRILL CIRC PROD 17:30 - 22:00 4.50 DRILL CIRC PROD 22:00 - 00:00 2.00 DRILL TRIP PROD 00:00 - 02:30 2.50 DRILL TRIP PROD 02:30 - 06:00 3.50 DRILL OTHR PROD 06:00 - 07:30 1.50 DRILL OTHR PROD 07:30 - 15:00 7.50 CASE PULR PROD 15:00 - 22:30 7.50 CASE PULR PROD 22:30 - 00:00 1.50 CASE RUNL PROD 00:00 - 04:00 4.00 CASE RUNL PROD 04:00 - 04:30 0.50 CASE CIRC PROD 04:30 - 06:30 2.00 CASE OTHR PROD 06:30 - 08:00 1.50 CASE CIRC PROD 08:00 - 09:30 1.50 CEMEN OTHR PROD 09:30 - 11 :30 2.00 CEMEN CIRC PROD 11 :30 - 15:00 3.50 CEMEN TRIP PROD 15:00 - 16:30 1.50 CEMEN OTHR PROD 16:30 - 20:00 3.50 CEMEN TRIP PROD 20:00 - 21 :30 1.50 CEMEN TRIP PROD 21 :30 - 00:00 2.50 CEMEN TRIP PROD 00:00 - 01 :00 1.00 CMPLTNTRIP PROD 01:00 - 02:30 1.50 CMPL TN OTHR PROD 02:30 - 06:00 3.50 CMPL TN TRI P PROD 06:00 - 07:00 1.00 CMPL TN OTHR PROD 07:00 - 10:30 3.50 CMPL TN TRIP PROD 10:30 - 13:00 2.50 CMPLTN CIRC PROD 13:00 - 13:30 0.50 CMPL TN OTHR PROD 13:30 - 20:00 6.50 CMPL TN AWSH PROD 20:00 - 22:00 2.00 CMPL TN TRIP PROD 22:00 - 00:00 2.00 CMPL TN OTHR PROD Page 7 of 8 Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Legal Well Name: 1 D-1 05 Common Well Name: 1 D-1 05 Event Name: ROT - SIDETRACK Contractor Name: n1433@ppco.com Rig Name: Nordic 3 Date From - To Hours Code Sub Phase Code 10/28/2001 11 :30 - 13:30 2.00 DRILL CIRC PROD Description of Operations P 75 bbls. caustic @ 8 bpm 2700# while circ . & reciprocating. Take caustic returns to va c truck thru wellhead. Circ. hole @ 8 bpm @ 2700#-ntu in 15 out 2 6. PJSM-Test lines to 2500# rig up & pump aci d wash as per program Reverse circ. & filter brine -displace hole to viscosified brine. Poh to run liner. POH scraper assembly-lay down & send out same. Install 2 7/8" rams-pull wear ring -set test p lug & test same-install wear ring. Rig up to run 4" liner wI screens=PJSM. PJSM-Pick up & run 4" blanks wI 4.5" screen s as per program. Pick up & make up 2 7/8" inner string in lin e r . Running liner in hole wI hwdp & dc,s. Run liner & screens-tag bottom @ 9820-Pum p down last 250'-tight hole. Reciprocate & circ.-750# @ 3 bpm. Drop ball-pump down releasing from liner-pu mp to 3000# to shear pins. PJSM-circ. while batch mixing cement. Test lines to 4500#-35 bbls. class 'G' 15.8# cement as per well plan. Circ. out excess cement-dumped 30 bbls. tot al of cement contaminated mud. POH laying down 4 3/4" dc,s & 3.5" hwdp. Rig doen esp unit-remove spool & replace wI new spool. Finish laying down dc,s hwdp & excess 4" dp Change out handling equipment-load out all liner running equipment. POH & stand back 2 7/8" pipe -lay down cup tools. Continue poh-stand back 2 7/8" tbg. Change out saver sub-clean torque tube & s ervice top drive. Run in hole wI cup tool on 2 7/8" tbg. Service rig-crown & crown-o-matic-rig up spi n n e r. Finish rih wI cup tool to 9799. Displace well to clean brine. PJSM on acid. Test lines 3500# pull pipe & pump acid as p er program 2.50 bbls. per screen. Service top drive & rih to 9799'. Acid soak=load pipe shed wI 3 1/2" tbg. clea n floor. Printed: 12/6/2001 2:50:20 PM ~ ~ ~ /' -~ ~ PHilLIPS '! ID ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/1/2001 11/2/2001 11/3/2001 (' ,," ( PHilliPS ALASKA INC. Operations Summary Report 1 D-105 1 D-1 05 ROT - SIDETRACK n1433@ppco.com Nordic 3 Page 8 of 8' Start: 10/13/2001 Rig Release: 11/3/2001 Rig Number: 3 Spud Date: End: 11/3/2001 Group: Sub From - To Hours Code Code. Phase Description of Operations 00:00 - 04:00 4.00 CMPL TN AWSH CMPL TN Can tin u e a c ids a a k - loa d pip e she d . 04:00-07:00 3.00 CMPLTNCIRC CMPLTN PJSM-displace acid with clean filtered brine 07:00 - 08:00 08:00 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 06:00 06:00 - 06:30 06:30 - 09:00 09:00 - 22:00 22:00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 05:30 05:30 - 09:00 09:00 - 14:00 14:00 - 15:00 15:00 - 16:00 1.00 CMPLTN OTHR CMPLTN 15.50 CMPLTN PULD CMPLTN 0.50 CMPL TN OTHR CMPL TN 2.00 CMPL TN SECT CMPL TN 4.00 CMPL TN RUNT CMPL TN 0.50 CMPLTN OTHR CMPLTN 2.50 CMPLTN TRIP CMPLTN 13.00 CMPL TN RUNT CMPL TN 2.00 CMPL TN OTHR CMPL TN 2.00 CMPL TN OTHR PROD 0.50 CMPL TN SOHO PROD 3.00 CMPL TN OTHR PROD 3.50 CMPL TN OTHR PROD 5.00 CMPL TN FRZP PROD 1.00 CMPL TN OTHR PROD 1.00 CMPL TN OTHR PROD Service rig-monitor well for osses-PJSM on I ay down dp. Lay down 4" & 2 7/8" dp-Run excess pipe au t of derrick & lay down same. Change out handling equipment & prep for pi cking up 3 1/2" tbg. Change upper rams from 2 7/8" to 3 1/2"-tes t same-install wear ring. RIH picking up 3 1/2" tbg. Service rig. POH w/ 3 1/2" tbg. & stand in derrick. Pull wear ring & run ESP completion as per program. Install penatraters in tbg. hanger & ESP cab Ie. Continue splicing esp cable & test same. (dr ain Stack) Land tbg. RILDS-Test hanger seals to 5000# 15 mins. Install bpv nipple down bope & remove rams Nipple up tree-check electric lines-test tree & pull 2 way check. Hook up circ. lines-test same-pump 145 bbls . diesel down annulus-allow diesel to equali ze-(170# on annulus=160# on tbg.) Break do wn circ. lines & set BPV. Remove esp spooling unit & all guards from rig floor. Prep rig & move off well-clean location. (rei ease rig @ 1600 hrs. 11/03/2001) Printed: 12/6/2001 2:50:20 PM ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 { Definative Surveys Re: Distribution of Survey Data for Well 10-1 05A ~o,~();;t Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 5,174.98' MD 5,205.00' MD 9,820.00' MD (if applicable) 12-Nov-01 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) I~ECEIV'ED NOV 1 3 2001 Alaska Oil & Gas Cons. Commission Anc~orage :- . . DEFINITIVE , >',,--- Kuparuk River Unit North Slope, Alaska Kuparuk 1 D, Slot 1 D-105 1D-105A Job No. AKZZ11172, Surveyed: 24 October, 2001 ~ I SURVEY REPORT 9 November, 2001 . Your Ref: API 500292284301 Surface Coordinates: 5959798.99 H, 560490.57 E (70018' 02.6368" H, 149°30' 36.2633" W) . Kelly Bushing: 100.80ft above Mean Sea Level ~ ! .:..-..,..-- Ei P E! ...... ...... Y - Ei U ., DRILLING SERVices A Halliburton Company Survey Ref: svy9689 Sperry-Sun Drilling Services Survey Report for 1D-105A DEF\N\1\\f Your Ref: API 500292284301 Job No. AKZZ11172, Surveyed:.24 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 D Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical . Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) \ 5174.98 23.370 1 ---- 30.340 3473.53 3574.33 2813.24 N 1873.79 E 5962627.22 N 562341.65 E 2813.24 Tie On Point 5205.00 22.840 30.880 3501.15 3601.95 2823.38 N 1879.79 E 5962637.41 N 562347.57 E 1.901 2823.38 Window Point / 5340.55 45.930 33.440 3612.26 3713.06 2887.46 N 1920.68 E 5962701.82 N 562387.94 E 17.064 2887.46 5434.21 65.720 31.210 3664.61 3765.41 2952.71 N 1961.76 E 5962767.39 N 562428.49 E 21.219 2952.71 5529.21 86.920 35.070 3686.96 3787.76 3029.46 N 2012.04 E 5962844.55 N 562478.15E 22.658 3029.46 5624.47 89.510 32.140 3689.93 3790.73 3108.75 N 2064.72 E 5962924.26 N 562530.20 E 4.104 3108.75 5674.21 90.800 32.340 3689.80 3790.60 3150.82 N 2091.26 E 5962966.54 N 562556.39 E 2.624 3150.82 5720.43 90.310 30.290 3689.35 3790.15 3190.30 N 2115.28 E 5963006.22 N 562580.10 E 4.560 3190.30 5814.10 89.750 32.210 3689.30 3790.10 3270.38 N 2163.87 E 5963086.68 N 562628.04 E 2.135 3270.38 5909.03 90.310 33.860 3689.25 3790.05 3349.96 N 2215.62 E 5963166.68 N 562679.15 E 1.835 3349.96 5943.73 89.690 34.910 3689.25 3790.05 3378.59 N 2235.21 E 5963195.47 N 562698.51 E 3.514 3378.59 6004.15 90.620 35.540 3689.09 3789.89 3427.95 N 2270.06 E 5963245.10 N 562732.96 E -1.859 3427.95 6071.80 87.660 34.110 3690.10 3790.90 3483.47 N 2308.69 E 5963300.93 N 562771.14 E 4.859 3483.47 6095.64 88.830 32.690 3690.83 3791.63 3503.36 N 2321.80 E 5963320.93 N 562784.10 E 7.716 3503.36 6190.54 87.230 30.720 3694.09 3794.89 3584.04 N 2371.65 E 5963402.01 N 562833.29 E 2.673 3584.04 6284.13 66.520 30.720 3697.56 3796.36 3664.44 N 2419.42 E 5963482.79 N 562880.41 E 1.378 3664.44 6376.66 90.550 27.310 3698.33 3799.13 3747.27 N 2465.36 E 5963565.98 N 562925.68 E 4.189 3747.27 6434.01 - 89.510 24.450 3698.30 3799.10 3796.88 N 2489.43 E 5963615.79 N 562949.35 E 5.518 3796.88 ~ 6473.55 67.910 24.860 3699.19 3799.99 3632.80 N 2505.92 E 5963651.84 N 562965.55 E 4.177 3832.80 6569.14 85.070 22.520 3705.05 3605.65 3920.16 N 2544.25 E 5963739.50 N 563003.16 E 3.847 3920.16 6663.45 86.490 20.510 3711.99 3812.79 4007.65 N 2578.74 E 5963627.27 N 563036.96 E 2.605 4007.65 6759.08 88.150 19.270 3716.46 3817.26 4097.48 N 2611.23 E 5963917.35 N 563068.73 E 2.166 4097.48 6654.53 90.490 16.980 3717.59 3816.39 4168.17 N 2640.92 E 5964006.29 N 563097.69 E 3.430 4168.17 6949.92 91.170 16.470 3716.21 3817.01/ 4279.52 N 2668.37 E 5964099.85 N 563124.40 E 0.891 4279.52 7043.81 90.800 16.560 3714.60 3815.40 4369.52 N 2695.06 E 5964190.06 N 563150.36 E 0.406 4369.52 7136.69 - 90.980 13.960 3713.12 3813.92 4461.23 N 2720.06 E 5964261.97 N 563174.64 E 2.741 4461.23 7234.82 89.750 8.640 3712.51 3813.31 4555.26 N - 2736.86 E 5964376.15 N 563192.67 E 5.692 4555.26 7328.96 89.450 4.600 3713.16 3813.96 4648.75 N 2749.71 E 5964469.73 N 563202.77 E 4.303 4648.75 7423.34 67.410 1.060 3715.75 3816.55 4742.96 N 2754.37 E 5964563.97 N 563206.67 E 4.328 4742.96 7518.86 89.260 0.620 3718.53 3819.33 4838.42 N 2755.77 E 5964659.44 N 563207.30 E 1.991 4838.42 . _. ------- _._---- -------- 9 November, 2001- 16:28 Page 2 of 4 DrillQlJcst 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for 1D-105A Your Ref: API 500292284301 Job No. AKZZ11172, Surveyed: ,24 October, 2001 . ~ North Slope, Alaska Kuparuk River Unit Kuparuk 1 D Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. - Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) f'/100ft) \ 7614.38 87.170 359.480 3721.50 3822.30 4933.89 N 2755.86 E 5964754.91 N 563206.62 E 2.492 4933.89 1 '- 7709.42 89.570 359.680 3724.20 3825.00 5028.88 N 2755.16 E 5964849.89 N 563205.16 E 2.534 5028.88 7804.79 87.970 358.500 3726.25 3827.05 5124.21 N 2753.65 E 5964945.21 N 563202.88 E 2.084 5124.21 7899.82 88.340 357.780 3729.31 3830.11 5219.14 N 2750.56 E 5965040.11 N 563199.03 E 0.851 5219.14 7994.76 90.310 358.120 3730.43 3831.23 5314.01 N 2747.17 E 5965134.95 N 563194.87 E 2.106 5314.01 8089.86 90.680 357.600 3729.61 3830.41 5409.04 N 2743.62 E 5965229.94 N 563190.55 E 0.671 5409.04 8185.32 90.060 356.680 3728.99 3829.79 5504.38 N 2738.85 E 5965325.24 N 563185.02 E 1.162 5504.38 8279.71 89.320 356.040 3729.50 3830.30 5598.58 N 2732.86 E 5965419.39 N 563178.27 E 1.037 5598.58 8373.73 89.630 - 355.740 3730.36 3831.16 5692.35 N 2726.12 E 5965513.10 N 563170.78 E 0.459 5692.35 8466,99 90.860 357.370 3729.97 3830.77 5785.44 N 2720.52 E 5965606.14 N 563164.43 E 2.190 5785.44 8562.79 89.820 358.670 3729.40 3830.20 5881.17 N 2717.21 E 5965701.85 N 563160.35 E 1.738 5881.17 8658.38 89.940 357.990 3729.60 3830.40 5976.72 N 2714.42 E 5965797.37 N 563156.79 E 0.722 5976.72 8751.29 - 91.720 357.770 3728.25 3829.05 6069.56 N 2710.99 E 5965890.17 N 563152.61 E 1.930 6069.56 8848.54 89.260 357.630 3727.42 3828.22 6166.72 N 2707.09 E 5965987.30 N 563147.92 E 2.534 6166.72 8942.96 90.430 356.630 3727.67 3828.4 7 6261.01 N 2702.36 E 5966081.56 N 563142.44 E 1.630 6261.01 9037.07 91.970 357.480 3725.70 3826.50 6354.98 N 2697.52 E 5966175.48 N 563136.85 E 1.869 6354.98 9131.74 91.720 356.770 3722.66 3823.46 6449.48 N 2692.78 E 5966269.94 N 563131.34 E 0.795 6449.48 9219.21 91.970 356.210 3719.84 3820.64 6536.74 N 2687.43 E -5966357.15 N 563125.29 E 0.701 6536.74 ~ '- A 9313.27 88.340 358.540 3719.59 3820.39 6630.68 N 2683.12 E 5966451.05 N 563120.22 E 4.586 - 6630.68 9408.71 89.750 0.980 3721.18 3821.98 6726.09 N 2682.72 E 5966546.46 N 563119.06 E 2.952 6726.09 9503.09 86.920 1.490 3723.92 3824.72 6820.40 N 2684.75 E 5966640.78 N 563120.33 E 3.047 6820.40 9597.32 89.080 2.750 3727.21 - 3828.01 6914.50 N 2688.24 E 5966734.91 N 563123.06 E 2.653 6914.50 9691.52 89.380 2.150 3728.47 3829.27 7008.61 N 2692.26 E 5966829.04 N 563126.32 E 0.712 7008.61 9751.74 89.570 2.050 3729.02 3829.82 7068.78 N 2694.47 E 5966889.24 N 563128.05 E 0.357 7068.78 9820.00 89.570 2.050 3729.54 3830.34 7137.00 N 2696.91 E 5966957.47 N 563129.94 E 0.000 7137.00 Projected Survey -._- --- ------- -----------_-.-__n_..n___- ---_._- . 9 November, 2001 - 16:28 Page 3 of 4 DrlllQuest 2.00.08.005 .. Sperry-Sun Drilling Services Survey Report for 1D-105A Your Ref: API 500292284301 Job No. AKZZ11172, Surveyed:, 24 October, 2001 ~ - Kuparuk River Unit All data is in Feet (US) unless otherwise stated. Direètions and coordinates are relative to True North. Vertical depths are relative to RKB= 111.5' MSL. Northings and Eastings are relative to 134' FSL & 595' FEL. '-.- - Magnetic Declination at Surface is 26.078° (15-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from .134' FSL & 595' FEL and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9820.00ft., The Bottom Hole Displacement is 7629.55ft., in the Direction of 20.700° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment j \ - ,--,- 5174.98 5205.00 9820.00 Tie On Point Window Point Projected Survey 3574.33 - 3601.95 3830.34 2813.24 N 2823.38N 7137.00 N 1873.79 E 1879.79 E 2696.91 E Survey tool program for 1D-105A From To Measured Vertical- Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 9820.00 3830.34 AK-6 BP _IFR-AK (1D-105A) - --."., 9 November, 2001 - 16:28 Page 4 of 4 ..-..- _,n" . North Slope, Alaska Kuparuk 1 D -j ~ DrlllQuest 2.00.08.005 { \ ~.. 12-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-1 05A MWD c90Iw"dO~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 5,174.98' MD 5,205.00' MD 9,820.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) RECEIVED NOV 1 3 2001 A\¡:;¡S¡iX) ,ji:, ' . -- , '-," ~ , ri. <J ';ð -.... 0 '() "- Kuparuk River Unit North Slope, Alaska Kuparuk 10, Slot 10-105 10-105A MWO Job No. AKMM11172, Surveyed: 18 October, 2001 SURVEY REPORT 12 November, 2001 Your Ref: API 500292284301 Surface Coordinates: 5959798.99 N, 560490.57 E (700 18' 02.6368" N, 149030' 36.2633" W) Kelly Bushing: 100.80ft above Mean Sea Level -'- spe""",\/-sur-, DRILLING seRVices A Halliburton Company Survey Ref: svy9692 Sperry-Sun Drilling Services Survey Report for 1D.105A MWD Your Ref: API 500292284301 Job No. AKMM11172, Surveyed: 18 October, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 10 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -'- 5174.98 23.370 30.340 3473.53 3574.33 2813.24 N 1873.79 E 5962627.22 N 562341.65 E 2813.24 Tie On Point 5205.00 22.840 30.880 3501.15 3601.95 2823.38 N 1879.79 E 5962637.41 N 562347.57 E 1.901 2823.38 Window Point '~- 5340.55 45.930 33.680 3612.26 3713.06 2887.35 N 1920.85 E 5962701.71 N 562388.12 E 17.070 2887.35 5434.21 65.720 31.030 3664.62 3765.42 2952.58 N 1961.93 E 5962767.27 N 562428.67 E 21.256 2952.58 5529.21 86.920 34.790 3686.96 3787.76 3029.55 N 2011.90 E 5962844.63 N 562478.02 E 22.640 3029.55 5624.47 89.510 31.890 3689.93 3790.73 3109.08 N 2064.22 E 5962924.58 N 562529.70 E 4.080 3109.08 5674.21 90.800 32.680 3689.80 3790.60 3151.12 N 2090.79 E 5962966.84 N 562555.92 E 3.041 3151.12 5720.43 90.310 30.360 3689.35 3790.15 3190.52 N 2114.95 E 5963006.43 N 562579.77 E 5.130 3190.52 5814.10 89.750 32.350 3689.30 3790.10 3270.51 N 2163.69 E 5963086.81 N 562627.86 E 2.207 3270.51 5909.03 90.310 34.070 3689.25 3790.05 3349.93 N 2215.68 E 5963166.65 N 562679.21 E 1.905 3349.93 5943.73 89.690 35.500 3689.25 3790.05 3378.43 N 2235.48 E 5963195.30 N 562698.78 E 4.492 3378.43 ". 6004.15 90.620 35.870 3689.09 3789.89 3427.50 N 2270.72 E 5963244.66 N 562733.62 E 1.657 3427.50 6071.80 87.660 34.400 3690.10 3790.90 3482.81 N 2309.64 E 5963300.28 N 562772.10 E 4.885 3482.81 6095.64 88.830 32.800 3690.83 3791.63 3502.66 N 2322.83 E 5963320.23 N 562785.13 E 8.312 3502.66 6190.54 87.230 30.770 3694.10 3794.90 3583.27 N 2372.78 E 5963401.25 N 562834.43 E 2.723 3583.27 6284.13 88.520 30.800 3697.57 3798.37 3663.62 N 2420.65 E 5963481.97 N 562881.65 E 1.379 3663.62 6378.86 90.550 27.460 3698.34 3799.14 3746.35 N 2466.75 E 5963565.07 N 562927.08 E 4.126 3746.35 6434.01 89.510 24.830 3698.31 3799.11 3795.85 N 2491.05 E 5963614.77 N 562950.98 E 5.128 3795.85 6473.55 87.910 25.720 3699.20 3800.00 3831.59 N 2507.93 E 5963650.65 N 562967.57 E 4.630 3831.59 6569.14 85.070 22.710 3705.05 3805.85 3918.59 N 2547.06 E 5963737.96 N 563006.00 E 4.325 3918.59 -~~-- 6663.45 86.490 20.530 3711.99 3812.79 4006.02 N 2581.71 E 5963825.66 N 563039.94 E 2.753 4006.02 6759.08 88.150 19.450 3716.46 3817.26 4095.78 N 2614.36 E 5963915.69 N 563071.87 E 2.070 4095.78 6854.53 90.490 16.900 3717.59 3818.39 4186.45 N 2644.13 E 5964006.59 N 563100.91 E 3.626 4186.45 6949.92 91.170 16.330 3716.21 3817.01 4277.85 N 2671.40 E 5964098.21 N 563127.44 E 0.930 4277.85 7043.81 90.800 16.400 3714.60 3815.40 4367.92 N 2697.85 E 5964188.49 N 563153.17 E 0.401 4367.92 7138.89 90.980 12.740 3713.12 3813.92 4459.92 N 2721.76 E 5964280.67 N 563176.34 E 3.854 4459.92 7234.82 89.750 9.020 3712.51 3813.31 4554.10 N 2739.86 E 5964375.00 N 563193.68 E 4.084 4554.10 7328.96 89.450 5.120 3713.17 3813.97 4647.51 N 2751.45 E 5964468.50 N 563204.52 E 4.155 4647.51 7423.34 87.410 1.310 3715.75 3816.55 4741.68 N 2756.74 E 5964562.71 N 563209.05 E 4.578 4741.68 7518.86 89.260 0.700 3718.53 3819.33 4837.14 N 2758.41 E 5964658.18 N 563209.95 E 2.039 4837.14 --_0- -- -- ---_____0 12 November, 2001- 9:50 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun. Drilling Services Survey Report for 1D-105A MWD Your Ref: API 500292284301 Job No. AKMM11172, Surveyed: 18 October, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1 D Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7614.38 87.170 359.840 3721.50 3822.30 4932.61 N 2758.86 E 5964753.65 N 563209.64 E 2.366 4932.61 7709.42 89.570 0.260 3724.21 3825.01 5027.60 N 2758.95 E 5964848.64 N 563208.95 E 2.564 5027.60 7804.79 87.970 359.130 3726.25 3827.05 5122.94 N 2758.44 E 5964943.97 N 563207.68 E 2.054 5122.94 0"- 7899.82 88.340 358.770 3729.31 3830.11 5217.91 N 2756.70 E 5965038.92 N 563205.17 E 0.543 5217.91 7994.76 90.310 358.010 3730.43 3831.23 5312.80 N 2754.03 E 5965133.79 N 563201.74 E 2.224 5312.80 8089.86 90.680 359.080 3729.61 3830.41 5407.86 N 2751.62 E 5965228.83 N 563198.56 E 1.190 5407.86 8185.32 90.060 356.810 3728.99 3829.79 5503.25 N 2748.20 E 5965324.19 N 563194.37 E 2.465 5503.25 8279.71 89.320 356.110 3729.51 3830.31 5597.46 N 2742.37 E 5965418.34 N 563187.79 E 1.079 5597.46 8373.73 89.630 358.000 3730.37 3831.17 5691.35 N 2737.54 E 5965512.19 N 563182.20 E 2.037 5691.35 8466.99 90.860 357.360 3729.97 3830.77 5784.53 N 2733.76 E 5965605.34 N 563177.68 E 1.487 5784.53 8562.79 89.820 357.070 3729.40 3830.20 5880.21 N 2729.11 E 5965700.98 N 563172.25 E 1.127 5880.21 8658.38 89.940 357.930 3729.60 3830.40 5975.71 N 2724.94 E 5965796.44 N 563167.31 E 0.908 5975.71 8751.29 91.720 357.850 3728.25 3829.05 6068.54 N 2721.52 E 5965889.24 N 563163.15 E 1.918 6068.54 8848.54 89.260 357.630 3727.42 3828.22 6165.71 N 2717.68 E 5965986.37 N 563158.53 E 2.540 6165.71 8942.96 90.430 356.590 3727.68 3828.48 6260.00 N 2712.92 E 5966080.63 N 563153.01 E 1.658 6260.00 9037.07 91.970 357.530 3725.71 3826.51 6353.96 N 2708.10 E 5966174.55 N 563147.43 E 1.917 6353.96 9131.74 91.720 356.740 3722.66 3823.46 6448.4 7 N 2703.37 E 5966269.01 N 563141.94 E 0.875 6448.47 9219.21 91.970 356.000 3719.84 3820.64 6535.71 N 2697.83 E 5966356.21 N 563135.70 E 0.893 6535.71 9313.27 88.340 358.520 3719.59 3820.39 6629.64 N 2693.34 E 5966450.10 N 563130.45 E 4.698 6629.64 9408.71 89.750 0.790 3721.18 3821.98 6725.06 N 2692.76 E 5966545.51 N 563129.11 E 2.800 6725.06 '-."- 9503.09 86.920 1.550 3723.92 3824.72 6819.37 N 2694.69 E 5966639.83 N 563130.27 E 3.105 6819.37 9597.32 89.080 2.720 3727.21 3828.01 6913.47 N 2698.20 E 5966733.96 N 563133.02 E 2.607 6913.47 9691.52 89.380 2.100 3728.48 3829.28 7007.58 N 2702.16 E 5966828.09 N 563136.23 E 0.731 7007.58 9751.74 89.570 1.990 3729.03 3829.83 7067.76 N 2704.31 E 5966888.29 N 563137.89 E 0.365 7067.76 9820.00 89.570 1.990 3729.54 3830.34 7135.97 N 2706.68 E 5966956.52 N 563139.71 E 0.000 7135.97 Projected Survey - -- - .- - .- ----- ---- . ---- - --- . 12 November, 2001- 9:50 Page 3 of 4 DrillQuest 2.00.08.005 Kuparuk River Unit Sperry-Sun Drilling Services Survey Report for 1D-105A MWD Your Ref: API 500292284301 Job No. AKMM11172, Surveyed: 18 October, 2001 . All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 111.5' MSL. Northings and Eastings are relative to 134' FSL & 595' FEL. Magnetic Declination at Surface is 26.079° (15-0ct-01) ~ The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 134' FSL & 595' FEL and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9820.00ft., The Bottom Hole Displacement is 7632.05ft., in the Direction of 20.772° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 5174.98 5205.00 9820.00 3574.33 3601.95 3830.34 2813.24 N 2823.38 N 7135.97 N -'-"Survey tool program for 1D-105A MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 12 November, 2001 - 9:50 To Measured Vertical Depth Depth (ft) (ft) 9820.00 3830.34 --'-'-'-'-- 1873.79 E 1879.79 E 2706.68 E Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (1D-105A MWD) Page 4 of 4 . --- .. ---- - . North Slope, Alaska Kuparuk 1 D DrillQuest 2.00.08.005 ( 10-105A Event History ( Date 11/19/01 Comment SET PCESP @ 5090' WLM, 2000 PSI SOV @ 4992' RKB. TBG TEST FAILED. IN PROGRESS [ESP WORK] FAILED TO PT TBG, LEFT PACK OFF @ 5029' WLM, IN PROGRESS [PT TBG-CSG] PULLED PACK OFF @ 5039' WLM, IN PROGRESS [ESP WORK] UNABLE TO PT TBG, IN PROGRESS [PT TBG-CSG] REPLACED SHEARED SOV @ 4992' RKB, SET PACK OFF & SLIP STOP, PT TBG TO 1000# HELD FOR 15 MN'S [GLV, ESP WORK, PT TBG-CSG] ..........-..............................................................................................................................-......-.....-...............................................................-..'-""""-"'-""""-""'-"""""""""""- 12/03/01 RAN 2.25. SAMPLE BAILER,TAGGED SLIP STOP @ 5018' WLM, NO RETURNS IN BAILER, RAN NEW SOV (SHEAR OUT @ 2000 PSI) PRESSURE TEST TBG 1000 PSI GOOD, TROUBLE SHOOT PUMP, SUCCESSFUL RUNNING GOOD. COMPLETE. [ESP WORK] 11/21/01 11/22/01 11/23/01 11/24/01 Page 1 of 1 12110/2001 ....----'...-----..--..,-.. . . .~-N.".-'."," .......,...,...'" ...'.-." f ~lf~1TŒ (ill~ ~~~~[K\~ ¡" ( ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡r>< AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit ID-I05A Phillips Alaska, Inc. Permit No: 201-202 Sur Loc: 134' FSL, 595' FEL, Sec. 14. TlIN, RIOE, UM Btmhole Loc. 1976' FSL, 2112' FWL, Sec. 12, TIIN, RIOE, UM Dear Mr. Mallary: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Aill1ular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit ID-I05A. Blowout prevention equipment (BOPE) nlust be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~v1\ l-"'[; Û--d ~ ¥'-- Cammy Oechsli Taylor '. Chair BY ORDER OF THE COMMISSION DATED thisJlß. day of October, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Envirorunental Conservation w/o encl. 6. Property Designation AOL 25650 & 25649 ALK 467 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 0-1 05A #59-52-180 9. Approximate spud date Amount October 12,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9818' MO / 3799' TVO 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1220 psig At total depth (TVO) 1627 psig SettlnQ Depth ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone [jþ~ 5. Datum elevation (DF or KB) RKB = 100.8 feet AMSL 1a. Type of work: Drill ba Redrlll Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 134' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM At top of productive Interval 2218' FNL, 1357' FWL, Sec. 13, T11 N, R10E, UM At total depth 1976' FSL, 2112' FWL, Sec. 12, T11N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 1976 @ TO feet 10-02 856' @ 5300' 16. To be completed for deviated wells Kickoff depth: 5200 MO 18. Casing program size feet Maximum hole angle 900 Hole 24" Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 HSLHT 4668' Top TVD 100.8' 100.8' 3557' Bottom MD TVD 121' 121' Length 121' 5200' MD 100.8' 100.8' 5150' CaslnQ 16" WelQht 62.5# 29.7# 9.5# 5200' 9818' 3597' 3799' 9.875" 6.75" 7.625" 4" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: feet feet Plugs (measured) measured true vertical Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface 0 Measured depth Length Size Cemented Þ-lOh\ Development Oil b!J Multiple Zone 0 10. Field and Pool Kuparuk River Field West Sak Oil Pool Quantity of Cement (include stage data) 9 cu yds High Early sx AS III L & sx Class G Open hole screen True Vertical depth RECEIVED OCT 1 0 ZO01 Perforation depth: measured Alæka Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments Filing fee ø Property Plat 0 BOP Sketch 0 Dlverter Sketch 0 Drilling program ø Drilling fluid program ø Time vs depth plot ~ DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ø 21. I hereby ce'/7hat tlf:fO,gOing is true an~1Z~he best of my kn.OWledge Questions? Call Todd Mus~ViC165;:: I Signed L-... lV ~ -~V Jc:::a,......- V Title: DrillíngEngineeringSupeNisor Date ItJ va;cJ(,J C. Malian -./ - . nv - iJllcmn-Drakr. r Commission Use Onl, Permit NU~ ( .- 2£.) 2- AP~~_u6~ t}.! ;¿'¿ 8 '13 ' (; I Approval date \ 0 \ \ \ 0'\ ~~:~ho:re:el:~I;:ments Conditions of approval Samples required 0 Yes iii No Mud log required ' 0 Yes 1&1 No Hydrogen sulfide measures 0 Yes ~ No Directional survey required ~ Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D ~ Ò»SOC~i\ ~C~~ Other: Approved by Original Signed By ... ....~ .. by order of the commission Commissioner , Form 10-401 Rev. 12/1/85. ORIGil~AL Date \()/Il () f \ Submit in triplicate (' AP(' ;on for Permit to Drill, Well 1 D-1 05A . Revision No.1 Saved: 10-0ct-O1 Permit It - West Sak Well #1 D-105A App/ícatíon for Permít to Drí// Document MaximizE We-II VQI~I; Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)... ........... .............. ...........". ...........".......... """"'" ..................... .......2 2. Location Sum mary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ....... .............. ................. ............................... ............. .................2 Requirements of 20 AAC 25. 050(b)... .......................,. ........ ...... ..... ......... ........... ............................ .........3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AA C 25. 005( c)(3) .................................................................................................., 3 4. Dri II i ng Hazards I nformati on ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) """"""""""""""""""""""""""""""""""""""""""""""""" 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3 6. Casi ng and Cementi ng Program ................... .............. ... .............. .... ........ ............... 4 Requirements of 20 AA C 25. 005( c)(6) ...................................................................................................4 7. Diverter System I nformati on ................................................................................... 4 Requirements of 20 AA C 25. 005( c)(7) ................................................................................................... 4 8. Dri II i ng FI u i d Prog ram............................................................................................. 4 Requirements of 20 AAC 25. 005( c)(B) """"""""""""""""""""""""""""""""""""""""""""""""'" 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 O. Seism i c Analys is...................................................................................................... 5 Requirements of 20 AA C 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) .......... ....... ................. ............... ...... ...................... .."............... 5 12. Evi dence of Bond i ng................................................................................................ 5 Requirements of 20 AAC 25.005 (c)(12) .. ""'" """"" """"""""""""" ....... ................. ........ ..... ......... ..... 5 Page 1 of 6 Printed: 10-0ct-O1 (' Ap,pi" >ion for Permit to Drill, Well 1 D-1 OSA ( Revision No.1 Saved: 10-0ct-O1 13. Proposed Dri Iii ng Prog ram........................ .............................................................. 5 Requirements of 20 AAC 25.005 (c)(13) ...... ... ........... .... ...... .............. .... ..... ................... ........................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) .................................................."............................................6 15. Attachments........................................................................ ..................................... 6 Attachment 1 Directional Plan (6 pages) ............................................................................................... 6 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................ 6 Attachment 3 Well Schematics (2 pages).............................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) B;;ch well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 2!i.O40(b). For a well with multiple Itllell bram:'hes; each Lm:md¡ must sim¡/ar~v be identified by a unique name and API number by adding a sìJlfix to the name designated for the well by the operatvr and to the number as5igned to the well by the commis:siol7. The well for which this Application is submitted will be designated as 1D-105A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to On!1 must be accompanied by each of the following item~ except fbr an item already on file with the corrJ/n/'ision and Identified in the applicFJ!7Ón: (2) a plat identifying the property and the property's owners' and showing (A)the coordinate:; of the proposed lo(;õtïÒn of the well at the surf..7ce/ at the top of each o[lfective IÓrmation and at total depth referenced to governmental section/ine5: (8) the coordinates of the proposï:xf location or the well at the surfÚa~ referenced to the state plane coordinate sy!:i1;em for this state as maintained by th(; National Geodetic Swvey 1Ì1 the National Oceanic and Atmosphetic Admini'itration/ (C) the proposed depth of" the well at the top of" each objective formation and at total depth; Location at Surface I 134' FSL, 595' FEL, Section 14, T11N, R10E, UM NGS Coordinates RKB Elevation 100,8' AMSL Northings: 5,959,798.99 Eastings: 560,490.57 Pad Elevation 70.5' AMSL Location at Top of Productive Interval West Sak "D" Sand NGS Coordinates Northings: 5,962,853 2218' FNL, 1357' FWL, Section 13, T11N, R10E, UM Eastings: 562,494 Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 5545 3789 3688 Location at Total De th NGS Coordinates Northings: 5,966,942 Eastings: 563,135 and (0) other ¡/7formation required by 20 MC 25.050(bì: Page 2 of 6 Printed: 1 O-Oct-O 1 ( ( Ap,t 'ion for Permit to Drill, Well 1 D-1 05A ~ Revision No.1 Saved: 10-0ct-O1 Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally de¡dateft the application for a Permit to Dnll (Form 10-401) must (1) include a pla( drawn to a suitable scale, showing the path of the proposed wellbore, including all adþcent 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 thc; opertltors 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 (8) 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 items, except for an item already on file with the commis-sion and identified in the application: (3) a diagram and description ot"the bIowoutpreven/iofJ equipment (BOPE) as' required by 20 AAC 25~035~ 20 AAC25.0J6, or 20 AAC 25.037, as applicable,. Please reference BOP schematics on file for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application lor a PermIt to Dn/I must be accompanied by each of the fbllowlÍ79 Items, except fÒr an item already on ¡lie with the commi'ision and identIfied in the application: (4) information on dn/l1i79 hazards, includliïg (A) the maxtinum downhole pres-:":,ì.Jf'e that may be enaìlJntere{,t criteria used to deÜmmi7e it~ and maJ<'linum potent¡;;¡1 surt~](:e pres:'ilJ((? based on a methane gradient~. The expected reservoir pressures in the West Sak D sand in lD-l05A is 1620 psi at a TVD of 3698 (.44 psi/ft). This pressure was obtained from lD-l07. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1220 psi, calculated thusly: MPSP =(3698 ft)(0.44 - 0.11 psi/ft) =1220 psi (B) data on potentia/gas zone5~' The well bore is not expected to penetrate any gas zones. and (q data conc(:?min9 potential causes' ot"holø problems such as abnormally geo'pressured strata/ lost Cïir;ulation zones, and zones that have a propensity for dlfférential sticking; Please see Attachment 2: Drilling Hazards Summary, 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 (ollowing items, exa:pt (or an item already on file with the commi-;sion and identified liï the application: (5) a desaipÜo/ï of the procedure for conduc:ting formation integrity tests~ as requked under 20 AAC 25:030(1); A whipstock will be set to mill a window in the 7 5/8" casing in the K-13 shale above the West Sak D- Sand, A formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. Page 3 of 6 Printed: 1 O-Oct-O 1 I" ( API."" tion for Permit to Drill, Well 1 0-1 05A ~. Revision No.1 Saved: 10-0ct-O1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dr/II must be accompanied by each of the following items/ except for an item already 017 file with the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 2S0JO/ and a description of any slotted liner:, pre-' perforated liner.- or screen to be installed; CsgfTbg 00 in 4 screen 6-3/4" Grade L-80 Connection HSLHT Length ft 4668 Top MOfTVO ft 5150/ 3557 atm MOfTVO ft 9818/ 3799 Cement Pro ram Screens - Inflate ECP with cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application far a Permit to Dnll must be accompanied by each of the lÖllowing ¡[em5~ except fÒr an item already on file with the commiS..<:,ion and identified in the application: (7) a diagram and description oftl7e divelter sys1:em as required by 20 AAC25:0J5~ unk':..:; this requkementis waived by the commission under 20 AAC 25:035(/7)(2); ~ \ \ ~ , ~ \ ùft "" ~bt. ~d ~(t '- \ A diverter system will not be used while drilling the West Sak "0" lateral. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An applk:ation for a Permit to Drill must be accompanied by each of the following item.~ except (or an item already on file with the cormm:s:':./()n and Idel7titÎé~d in the applic,.1tion.' (8) a dtil/ing Iluid prograrn including a diagram and de,';;criptio/ï of the dlillinr;¡ fluid .sY'!;tern as required by 20 AAC 2.5.033; Drilling will be done with a BaradrilN mud system having the following properties over the listed intervals: Sidtrack interval /K-13 shale only) D sand lateral Initial Value Final Value Initial Value Final Value Density (ppg) 9.0-9.1 9.0-9.1 8.9-9.0 8.9-9.0 Funnel Viscosity (seconds) 40-55 40-55 45-60 45-60 Yield Point 20-27 20-27 18-25 18-25 (cP) Plastic Viscostiy (lb/l00 sf) 11-19 11-19 8-14 8-14 Tau 0 4-7 4-7 4-7 4-7 Chlorides 13-15K 13-15K 13-15K 13-15K pH 8-9 8-9 8-8.5 8-8.5 API filtrate <6 <6 <6 <6 **HTHP filtrate <10 <10 <10 <10 MDT <11 <11 <2.5 <2.5 ***Solids ppb <12 <12 <12 <12 ** HTHP to be run at 80° F *** The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25,033. Please see "Diagram of Mud System, Nordic 3", placed on file with the Commission. Page 4 of 6 Printed: 1 O-Oct-O 1 ( APt 'ion for Permit to Drill, Well 1 D-105A ~ Revision No.1 Saved: 10-0ct-O1 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (e)(9) An application for a Permit to Dnll must be accompanied by each of the following item~ except for an item already on file with the commis..c;jon and Identified in the application: (9) for an exploratory or stratigraphic test welt a tabulation setting out t/7e depths of predicted abnormally geo.-pressured strata as required by 20 AAC 25.033(f)/" Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) An application for a Permit to Offll must be accompanied by each of the following itern~ except for an item already on file witt¡ tile commission and Identified in the application: (10) for an explarato/Y 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. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (e)(11) An application tor a Penmt to Olill must be accompanied by each of'the following ¡tems~ except for an item already 0/7 tHe with tile commission and identifìed i/7 the application: (11) for a well drilled fmm an offshore platform, mobile bottomfollnded structure/ jack-up rig or floating drilling ve.':;:5e¿ an analy::;i5 of seabed conditions as reqlJiœd by 20 AA C 25: 06.1 (b)/ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (e)(12) An application for a Permit to On!1 must be accompanied by each of the IÒllowing item5~ except for an item already on file with tfle commi5:sion and identified IiI the application: (.t2) evidence 5170Wli1g that the reqU/i"ements ol20 AAC 25. 025 {Bondti1g}have been met. Evidence of bonding for Phillips Alaska, Inc, is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (e)(13) An application for a Permit to Drill must be accompanied by each of the tollowing item::,~ ('?xcept for an item alr'!:?aL1von file wIth the commLsion and ¡dentitied in the application: The proposed drilling program is listed below. Please refer also to Well Schematics. 1. MIRU Nordic 3. Lay hard line to tree. Pull BPV and VR plug. 2. Circulate well to seawater. Verify well is dead , 3, Set BPV. ND tree. NU and test BOP. ~SCC ~~ \ 4, Screw in landing joint. Pull tubing hanger to rig floor. Pooh laying down all tubing, jewelry, ESP and cable. 5. PU casing scraper on DP and run through BP setting depth. 6. RU Eline and set Cement Retainer at 5229' MD. Test plug and casing to 3000 psi. 7. RIH with DP and sting into cement retainer. Squeeze 15 bbls cement below retainer. TOH, 8. PU Baker 7-5/8" window master bottom trip whipstock, TIH, orient and set whipstock wI MWD. Shear off whipstock bolt and mill window and 20' formation. Perform LOT. POOH and LD milling assembly. 9, Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud. 10. Continue to directionally drill to TD of D sand lateral as per directional plan. 11. POOH and lay down MWD, LWD and PWD tools. Page 5 of 6 Printed: 10-0ct-O1 .~( ( APt 'ion for Permit to Drill, Well 1 D-1 05A , Revision No.1 Saved: 10-0ct-O1 12. RIH with 6-3/411 hole opener and ream entire open hole. 13. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. POOH and lay down hole opener assembly. 14. RIH with whipstock retrieval tool and casing scaper assembly to whipstock. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH. 15. PU 411 Liner with liner hanger, ECP/s and excluder screen and 2-7/811 inner wash string. 16. RIH, and land and set hanger, 17. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out excess cement and POOH. 18, Pick up lateral diverter tool and RIH and set in hook hanger. 19. RIH with cup tool assembly and spot 80/0 Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. POOH, laying down Drill pipe as needed. 20. Make up lateral diverter retrieving tool and RIH on 4-1/211 completion tubing, Once at diverter, run dummy ESP through tubing string on wireline. Retrieve diverter, and POOH, standing back tubing. 21. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 22. Land tubing with ESP +/- 60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 23. Set BPV and move off, 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applk:atlon for a Permit to 0/711 mastc be accompanied by each of" tile fbllowing items~ except fix an Item a/ready on tlle with the commi5'sion and identlfìed in the applkf.1tion: (14) a general description of"l1ow the operator plans to dls,'/.")ose Ordfilling mud and Clittli7gS and a statement of" whether the operator Intends to request authorization under 20 MC 25. 080 fÓr an annular dispo:.,clJ operation 1/7 the we//./ Waste fluids generated during the drilling process will be disposed by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations, 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematics Page 6 of 6 Printed: 10-0ct-a1 ( ( lD-l0SA Drilling Hazards Summary 6-3/4" Open Hole / 4" Liner In1;erval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener, Decreased mud wei ht Reduced um rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets, Pu m in out Low Low Moderate 1D-105A Drilling Hazards Summary prepared by Todd Mushovic 10/09/01 ZXP Lil)er Top Packer f/7 5/8" Vv / ø ~ ¿~ /1,( f',?øFiU:f:. 75/8" x 5 1/2" CMC Liner Hanger . Casing Sub w/5 1/2" BTC box x 41/2" IBT pin .1 r&íï8 B'ULu Baker Oil Tools Date: Oct. 4, 2001 Revision 2 ( Phillips Alaska Inc. 1 D-1 05 ? /ZD P oS¿:; 0 ;.;-------- JIlt .-. 4 1/2" IBT handling pup it. 4 1/2" IBT Tubing as needed ~ I Lift sub wI 4 112" IBT box x 4 1/2" BTC Pi~ 4 1/2" Ind. Coupling w/4 1/2" BTC b x P ~ Spacer pup it. w/4 1/2" BTC b x P 4 1/2" HMCV w/4 1/2" BTC box x pin Spacer pup jt. wI 4 1/2" BTC b x p 4 1/2" Pup it. w/4 1/2" BTC b x P 4 1/2" Ind. Coupling w/4 1/2" BTC b x P 4 1/2" Pup it. wI 4 1/2" BTC b x p Payzone pkr. w/4 1/2" BTC b x b Pup it. w/4 1/2" BTC pin x 4 1/2" SLHT pin 1 it. 30' 4 1/2" SLHT box x pin CMD Sliding Sleeve 3.43" wI 4 1/2" SLHT box x pin 1 it. 30' 4 1/2" SLHT box x pin Casing sub w/4 1/2"SLHT box x 4" SLHT pin 4" Excluder Screen & Blank pipe s~ Þ- as needed wI 4" SLHT box x pin 1 it. 4" SLHT box x pin 30' ~ Casing sub, wI 4" SLHT box x 5" SLHT pin . V-Set Shoe wI 5" SLHT box ~ ODD . (' .... .. ... Drill Pipe to surface Plug Landing Collar Rotating Dog Sub .... HR Running Tool 2 3/8" Swivel Sub 2 7/8" Tubing w/2 7/8" Hydril 511 .... Inflation Tool 2 7/8" Tubing w/2 7/8" Hydril 511 4"CUpS facing down Ball Seat, fl 29/32" ball - . '- r&ií8 BAKER H UGIE5 Baker Oil Tools Date: Oct. 4, 2001 Revision 2 ZXP Liner Top Packer f/7 5/8" 7 5/8" x 5 1/2" CMC Liner Hanger Casing Sub w/5 1/2" BTC box x 4 1/2" IBTpin ( Phillips Alaska Inc. ( 1 D-1 05 Acid Wash p£o f c> <; EO -_:...:------- ~ 4 1/2" IBT handling pup jt. 4 1/2" IBT Tubing as needed ~ ~ Uft sub wi 4 1/2" IBT box x 4 1/2" BTC pi~ 4 1/2" Ind: Coupling wI 4 1/2" BTC b x P -----. Spacer pup jt. w/4 1/2" BTC b x P 4 1/2" HMCV w/4 1/2" BTC box x pin 4 1/2" Pup jt. wI 4 1/2" BTC b x p 4 1/2" Ind. Coupling wI 4 1/2" BTC b x p 4 1/2" Pupjt. w/4 1/2" BTC b x p Payzone pkr. w/4 1/2" BTC b x b Pup jt. w/4 1/2" BTC pin x 4 1/2" SLHT pin 1 jt. 3D' 4 1/2" SLHT box x pin CMD Sliding Sleeve 3.43" wI 4 1/2" SLHT box x pin 1 jt. 3D' 4 1/2" SLHT box x pin Casing sub wI 4 1/2" SLHT box x 4" SLHT pin 4" Excluder Screen & Blank pipe s~ ~ as needed wI 4" SLHT box x pin Spacer pup jt. wI 4 1/2" BTC b x P þo 000 1 jt. 4" SLHT box x pin 3D' ~ Casing sub, wI 4" SLHT box x 5" SLHT pin V-Set Shoe wI 5" SLHT box . .... 3 1/2" IF Drill Pipe x-a to Workstring 2 7/8" Tubing w/2 7/8" Hydril 511 .... Acid Cup Tool CMD Shifting Tool " . ... . - ). -. P -- I C> 01- W t tV Doì.J S-z,( 0 :JvrT ~'7 e. Gd tJ ~ 2fi I'M/) "~i. BAKER IIUGIIES Baker Oil Tools (' ( (" Phillips Alaska Inc. 1 D-1 05 Pr2-0 P oc;t;; D SCH¿fv\ftTIC [, f-Ì ¿ ¡¿ ~-- 0 S~\,JD HEEL @J: {;l154 I M D !: 3~} :5 ¡'It) () ---- ,,' Date: 9/29/01 - b'lt ö()€~ HoLE 1i) @:l:. tfß1B MO ;t. 3'tttq '11;-0 ðel6.{f-jÂL Co~LEnD~ PW668Ð ß6¡v6~TJ-l c.f"lT {LT~ @ c:; ~ .(,~ I t"" ~ Well # 1 D-105A, West Sak Horizontal Sidetrack Planned Completion Schematic Tubing String Details ("" \ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Tree Assembly, Vetco Gray Gen II Tubing Hanger, 3-1/2", Vetco Gray ESP Power Cable Penetrator Heat Trace Penetrator Tubing Head Assembly, Vetco Gray (1) Joint Tubing (x) Pup Joints Tubing, as required to spaceout 16" Conductor: +/- 121' MD Connector, Field Attachable, Power Cable Connector, Field Attachable, Heat Trace Power Cable, Centrilift, (x) Joints Tubing (1) Gas Lift Mandrel, CAMCO 3-1/2" x 1-1/2" Model MMG, with dummy valve installed. Tubing String: 3-11211,9.3#, L-80 (3) Joints Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup Joint Tubing, 10 ft length (1) Pup Joint Tubing, 10ft length (1) Through Tubing Conveyed Electric Submersible Pump (TTCESP) Assembly, Centrilift, consisting of: Top of Window: +/- 5,210' MD 13,597' TVD (1) Slotted Nipple, Centrilift, 3-1/2" (1) Crossover, Centrilift, 3-1/2", (1) Tandem Seal Section, Centrilift (1) ESP Assembly, Centrilift (1) Motor, Centrilift, (1) Gauge, Phoenix, Model, MS-1 Gauge (1) Centralizer, Motor, Centrilift, Cement retainer set at +1- 5229' MD ------------ ------------ ------------ ------------ ------------ ----------- ----------- ----------- ----------- ---- D-Sand Lateral 6-3/4" Open Hole TD: +/- 9818' MD /3,799' TVD Old completion squeezed beneath cement retainer set at +1- 5229' MD 7-5/8" Shoe: 6077' MD T JM 10/9/01 WEST SAK (1 D-1 05) (Frac-Packed Producer) Current Completion 7-5/811 Marker Joint (+/- 50' Above Top Perforation) Drillers TD @ 6093' MD {'" ¡;, ARCa Alaska, Inc. CuRf-£Jl 3-1/211 Vetco-Gray Tubing Hanger wI 2-7/811 L-80 EUE 8rd Mod Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 2-7/811 6.5# L-80 EUE 8rd Mod Spaceout Pups as Required for Heat Trace. 1611 62.5# H-40 @ 121' MD Stage Tool @ 2245' MD Raychem Heat Trace @ +1- 2265' MD Directional KOP = 381' 2-7/811 6.5# L-80 EUE 8rd Mod Tubing to Surface (as required). Max Angle = 57 Deg @ 2154' MD Avg Angle Thru W.Sak = +/- 21 Deg 5' Handling Pup 2-7/811 6.5# L-80 EUE 8rd Mod Tubing. 2-7/811 X 111 Camco 'KBMM' GLM @ +1-5189' MD wI Shear Circulating Valve. (pinned for 3000 psi Tbg I Csg differential) 5' Handling Pup 2-7/811 6.5# L-80 EUE 8rd Mod Tubing. 1 Joint 2-7/811 6.5# L-80 EUE 8rd Mod Tubing. 6' Pup Joint 2-7/811 6.5# L-80 EUE 8rd Mod Tubing. (BOT double box coupling on top providing the port for the Baker Sentry Gauge) 8' Handling Pup 2-7/811 6.5# L-80 EUE 8rd Mod Tubing Centrilift ESP (components as listed below) wI bottom set @+I- 5286' MD. Centrilift Discharge FPHVDIS. Centrilift Upper Tandem Pump 142FC925 Cehtrilift Lower Tandem Pump wI Intake 9FCNPSH Centrilift Seal Section: GSFT DB HL PFS Centrilift Motor: 57 HP KMH 1315/26 Baker SC-1 Gravel Pack Packer @ 5299' MD D-Sand Perfs: 12 SPF 5382' - 5420' Frac and Pack wI Carbolite Baker FB-1 Sump Packer @ 5422' MD Tubing Stub @ 5424' MD Baker Isolation Packer @ 5427' MD B I A4-Sand Perfs: 12 SPF 5454' - 5520' Frac and Pack wI Carbolite Baker Isolation packer @ 5526' MD A3-Sand Perfs: 12 SPF 5550' - 5600' Frac and Pack wI Carbolite Baker Isolation Packer @ 5606' MD A2-Sand Perfs: 12 SPF 5630' - 5710' Frac and Pack wI Carbolite Baker FB-1 Sump Packer @ 5714' MD PBTD @ 5861' WL (Top of Sump Packer Stuck and Set) 7-5/811 29.7# L-80 BTCMod @ 6077' MD MAC 10/8/99 Kuparuk River Unit North Slope, A/~{$l{fl~ Kuparuk 1 D~}iS~f1IJ-¡lfl~tÐ5A 1 "..(:"'.&:llt.,:.. ~í.~71': :.,~,: ...- 1",¿'rV":ifiI ItI .", j .u~ -ÍliYis~~1J ôð~i~/2Ó01 .~,. . -- . -- - ---- -- . . . . -- . . -- n - . -- . -- -- - - - ... . . - . -- - - _n- - .. -- . . ... - - -. -- - -- -- __un S1I:rJPOSAL REPORT . . 9 October, 2001 Your Ref: per Prelim Plan ver #O.B Surface Coordinates: 5959798.99 N, 560490.57 E (700 18' 02.6368" N, 149030' 36.2633" W) Surface Coordinates relative to Project H Reference: 959798.99 N, 60490.57 E (Grid) Surface Coordinates relative to Well: 105.255, 5.58 E (True) Kelly Bushing: 1 00. 80ft above Mean Sea Level -~~ Proposal Ref: pro9648 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 5200.00 22.928 30.787 3496.54 3597.34 5212.00 5230.00 5300.00 5387.68 5400.00 5420.14 5500.00 5545.41 24.670 24.670 38.924 56.788 59.281 63.356 79.512 88.700 32.719 32.719 34.007 34.806 34.867 34.960 35.277 35.440 5600.00.. 88.700'- -'35.440 5700.00- 5800.00::: 5900.00:. 6000.00 . 6100.00 6200.00 6300.00 6365.41 6400.00 6500.00 ... .. . -. .. . . ..~.70(r-~ ..35.440. ,ð87lQØ- 35.440 88.700 ...35.440 88.700 35.440 88.700 35.440 88.700 88.700 88.700 88.784 89.036 35.440 35.440 35.440 33.331 27.235 3507.52 3523.88 3583.22 3641.81 3608.32 3624.68 3684.02 3742.61 Sperry-Sun Drilling Services Proposal Report for 1D-105A (wp02) Your Ref: per Prelim Plan ver #0.8 Revised: 9 October, 2001 Local Coordinates Northings Eastings (ft) (ft) 2821.71 N 2825.82 N 2832.14 N . . 2~~i~ N 29f6.'2'ON . .... . . .. - .. - .. . . . 3648.33 .~7 4SlT13g _..~924.78 N 3658.00 .;~~;lQ8~@O~::_:"2939.27 N 3683~~4:;""~~. 37~.2t4 3000.98 N 3688~O'O,.378g;aO 3037.78 N . -. 3689.24 3691.51 3693.78 3696.04 3698.31 3700.58 3702.85 3705.12 3706.60 3707.36 3709.27 3790.04 3792.31 3794.58 3796.84 3799.11 3801.38 3803.65 3805.92 3807.40 3808.16 3810.07 3082.25 N 3163.70 N 3245.15 N 3326.60 N 3408.05 N 3489.50 N 3570.95 N 3652.40 N 3705.68 N 3734.22 N 3820.52 N 1878.79 E Global Coordinates. Northings . Eastings .. (ft).-(ftl ... 596263§.?3 N . . .. -. -. ... .... . . . - .. - .. ... ... . - ..... . .. .)1~f1~E.gŽ~Æsg9.87 N J885.40E . .5962646.22 N :1905.70 E 1942.34 E 1948.31 E 1958.43 E 2001 .84 E 2027.95 E 2059.60 E 2117.57 E 2175.54 E 2233.51 E 2291.48 E 2349.45 E 2407.42 E 2465.39 E 2503.30 E 2522.83 E 2573.23 E 5962677.06 N 5962730.74 N 5962739.36 N 5962753.93 N 5962815.99 N 5962853.00 N 5962897.72 N 5962979.63 N 5963061 .55 N 5963143.46 N 5963225.38 N 5963307.29 N 5963389.21 N 5963471.12 N 5963524.70 N 5963553.40 N 5963640.10 N 562346:59 E Dogleg Rate e/10Oft) Vertical Section 2821.71 562349.10 E 15.900 2825.82 562353.11 E 0.000 2832.14 562373.17 E 20.385 2862.82 562409.37 E 20.385 2916.20 562415.27 E 562425.27 E 562468.18 E 562494.00 E 562525.29 E 562582.60 E 562639.91 E 562697.22 E 562754.54 E 562811.85 E 562869.16 E 562926.47 E 562963.96 E 562983.26 E 563032.96 E 20.235 20.235 20.235 20.235 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 6.100 6.100 2924.78 2939.27 3000.98 3037.78 3082.25 3163.70 3245.15 3326.60 3408.05 3489.50 3570.95 3652.40 3705.68 3734.22 3820.52 . North Slope, Alaska Kuparuk 1 D Comment Top of Whipstock (7-5/8" Csg) 15.900/10Oft: 5200.ooft MD, 3597.34f TVD--..., 7-5/8" Casing Begin Rathole @ 24.67° (6-3/4" Hole): 5212.00ft MD, 3608.32ft TVD Begin Dir @ 20.39°/10Oft : 5230.00ft MD, 3624.68ft TVD Decrease DLS to 20.24°/100ft: 5387.68ft MD, 3742.61ftTVD Top West Sak 'Do 'D-Sand' Plane pt, Start Sail @ 88.7° ir & 35.44° Az: 5545.41ft MD, 3788.8Oft TVD Target - D Sand 'Plane' Pt., Current Target .- Begin Dir @ 6.1°/lOOft: 6365.41ft M[ 3807.4Oft TVD 9 October, 2001 - 16:53 Page 2 of 6 Dril/Quest 2.00.09.003 Kuparuk River Unit Measured Depth (ft) 6574.42 6600.00 6700.00 6800.00 6900.00 6945.90 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 Sub-5ea Vertical Incl. Azim. Depth Depth (ft) (ft) 89.231 22.699 3710.39 3811.19 89.301 21.168 3710.72 3811.52 89.580 15.181 3711.70 3812.50 89.864 9.195 3712.18 3812.98 90.149 3.209 3712.17 3812.97 90.279 0.461 3712.00 3812.80 90.279 90.279 90.279 90.279 90.279 90.279 90.279 90.279 90.279 .'. 7900.OQ~_n~O.279 :~g:~l~.....,:~:~}:.L; 8200.00-~ 90.279 8300.00' .90.279 8400.00 8500.00 8600.00 8700.00 8800.00 90.279 90.279 90.279 90.279 90.279 0.461 0.461 0.461 0.461 0.461 0.461 O.~.. ([461 ,.. 0.4ß1 -- . .. ..,.0.461... .. . . ..0.461 0.461 0.461 0.461 0.461 0.461 0.461 0.461 0.461 3711.74 3711 .25 3710.76 3710.27 .. ~Z09.!9 Ë~709~~9. .:~g08.81' 37Q8.32 3707.84 3707.35 3706.86 3706.37 3705.89 3705.40 3704.91 3704.42 3703.94 3703.45 3702.96 3812.54 381 ~O5:., 381 t~§6~. . :~11~W "'0 . . . m n n . . n . .... . u ._u _m .- - u u m . . ).3810:59 ~::;3810.1 0 .'.- 3809.61 3809.12 3808.64 Sperry-Sun Drilling Services Proposal Report for 1D-105A (wp02) Your Ref: per Prelim Plan ver #0.8 Revised: 9 October, 2001 Local Coordinates Northings Eastings (ft) (ft) 3887.96 N 2604.63 E Global Coordinate~ Northings i:astingsu (ft) - (ft) ... 5963701.79 N _u - - -.- - - -. -. . .. . 3911.68 N 261~.18 E...-.:A~~K31.5~tN 4006.65 N 2645;p6 Ej: 'c~t!6~?6.80N 41 04.35 NJ~'~gß.p6~~~ Eu- 5@.3924.67 N 4203.72 N<- 261'7.29~E.;'; .;)964024.12 N . --. u .-. . u- u - u . . .. . . . . -. - - . -.. . . . -. . u- u -.-- .-. 424p,"58 Nt~'_~.2678.73 E m.'. -.- . .'.'-. u. .. n. -. -. . -- n - - . -.- - . ;.;~3.6.9J~ -c:J~~p8 N .7,'4503.68 N :<"4603.67 N 4703.67 N 4803.66 N 4903.66 N 5003.65 N 5103.65 N 5203.65 N 5303.64 N 5403.64 N 5503.63 N 5603.63 N 5703.62 N 5803.62 N 5903.61 N 6003.61 N 6103.61 N 2679.16 E 2679.97 E 2680.77 E 2681.58 E 2682.38 E 2683.19 E 2683.99 E 2684.80 E 2685.60 E 2686.41 E 2687.21 E 2688.02 E 2688.82 E 2689.63 E 2690.43 E 2691.24 E 2692.04 E 2692.85 E 2693.65 E 5964070.00 N 5964124.10 N 5964224.10 N 5964324.10 N 5964424.10 N 5964524.10 N 5964624.10 N 5964724.10 N 5964824.10 N 5964924.09 N 5965024.09 N 5965124.09 N 5965224.09 N 5965324.09 N 5965424.09 N 5965524.09 N 5965624.09 N 5965724.09 N 5965824.08 N 5965924.08 N -563063.82 E 563073.18 E 563103.59 E 563123.90 E 563133.90 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E North Slope, Alaska Kuparuk 1 D Dogleg Vertical Rate Section Comment CO/100ft) 6.100 3887.96 Decrease DLS to 6.0°/1000 : 6574.421 MD, 3811.1911 TVD 5.993 3911.68 ~, , 5.993 4006.65 5.993 4104.35 5.993 4203.72 5.993 4249.58 'Heel'Target: 6945.90ft MD, 3812.8Ot TVD Target - 1 D1 05a (Heel), Current Targe 0.000 4303.69 0.000 4403.68 0.000 4503.68 0.000 4603.67 0.000 4703.67 0.000 4803.66 0.000 4903.66 0.000 5003.65 0.000 5103.65 0.000 5203.65 0.000 5303.64 0.000 5403.64 ~. , 0.000 5503.63 0.000 5603.63 0.000 5703.62 0.000 5803.62 0.000 5903.61 0.000 6003.61 0.000 6103.61 3808.15 3807.66 3807.17 3806.69 3806.20 3805.71 3805.22 3804.74 3804.25 3803.76 9 October, 2001- 16:53 Page 3 of 6 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Proposal Report for 1D-105A (wp02) Your Ref: per Prelim Plan ver #0.8 Revised: 9 October, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (It) (ft) 8900.00 90.279 0.461 3702.47 3803.27 9000.00 90.279 0.461 3701.99 3802.79 9100.00 90.279 0.461 3701.50 3802.30 9200.00 90.279 0.461 3701.01 3801.81 9300.00 90.279 0.461 3700.52 3801.32 9400.00 90.279 0.461 3700.04 3800.84 9500.00 90.279 0.461 3699.55 3800.35 9600.00 90.279 0.461 3699.06 3799.86 9700.00 90.279 0.461 3698.57 3799.37 9800.00 90.279 0.461 3698.09 3798.89 9817.93 90.279 0.461 3698.00 Local Coordinates Northings Eastings (ft) (ft) 6203.60 N 6303.60 N 6403.59 N 6503.59 N 6603.58 N 670?58 N 68~1?7 N 6~~5Z N :1~Ö3~SPìJ 7tO3.5ŠN 21.49 N Global Coordinates Northings . I;astings (ft) ..{ft} .. 2694.46 E 5966Q?4.p8 N 2695.26 E 5~124:Öa N 269?07 E .:~{i96f)224.cmN 26gp~87 J;.~.. ...§96~?4.08N . .~469t.a:e Eu.> 59ßQ424.08 N ... m .. u .- - ~8.48;IB .2699.29 E 5g7oo.09 E ..'.2700.90 E 2701.70 E 2701.85 E .5966524.08 N 5966624.07 N 5966724.07 N 5966824.07 N 5966924.07 N 5966942.00 N . .. .. All data is in Feet (US) unless oth~§~.st~~. DifE!êíibhs and coordinates are relative to True North. Vertical depths are relative to R~= 1~$f.ASL. Northings and Eastings are relative to 134' FSL & 595' FEL. . .....u .... - ..... . . - --- . . . . -- - u --- -- u.. un.. The Dogleg~yerity iSJ.O Dem~.pi:J(100 feet (US). Vertical SectiC>JiisJroml~'f$L &5~S' FEL and calculated along an Azimuth of 0.0000 (True). .. - u -.. . --. - .- - - - . . - .. . n -- -- -. u Based upon MirJil1lum9urV~!Jre type calculations, at a Measured Depth of 9817.93ft., The Bottom HgJe Displacement is 7616.80ft., in the Direction of 20.7760 (True). . . >563135.00 E 56.aps.oo E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E 563135.00 E Dogleg Rate e/10Oft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Vertical Section 6203.60 6303.60 6403.59 6503.59 6603.58 6703.58 6803.57 6903.57 7003.57 7103.56 7121.49 9 October, 2001 - 16:53 Page 4 of 6 . North Slope, Alaska Kuparuk 1 D Comment ---., Proposed BHL (Toe') : 9817.93ft MD, 3798.8Oft TVD 4-1/2" Liner Target -1 D105a (Toe), Current Target -- -.. --- DrillQuest 2.00.09.003 Kuparuk River Unit Comments Measured Depth {It} 5200.00 5212.00 5230.00 5387.68 5545.41 . 6365.41 6574.42 6945.90 9817.93 Formation Tops Sperry-Sun Drilling Services Proposal Report for 1D-105A (wpO2) Your Ref: per Prelim Plan ver #0.8 Revised: 9 October, 2001 Station Coordinates TVD Northings Eastings (It) (It) {It} Comment 3597.34 3608.32 3624.68 3742.61 3788.80 3807.40 3811.19 3812.80 3798.80 2821.71 N 2825.82 N 2832.14 N 2916.21 N 3037.78 N 3705.68 N 3887.96 N 4249.59 N 7121.49 N Formati on Plane.. ..<. ~... (Below Well Origin) ..=- "M~asiJred Sub-Sea Dip-:tlip Djt.. ~.Depth (ft) Des:Ü' 'Dèg.". {It} . 3658.0Œ.o-.Ooo"O.461 . ....-:d;. . 5420.14 1878.79 E 1881.34 E 1885.40 E 1942.34 E 2027.95 E . u .. . .. . . -. - . . . . u .. ..... .. m. u . . Top of Whipstock;('Z;-5/8'tÇsSJl'lp.99f:/100ft: 5200.00ft MD, 3597.34ft TVD Begin RattJ9!~;~,,24rf)7°\@ígf4~;1:i9le): 5212.000 MD, 3608.32ft TVD Begin Qí~@ 2q~~ottJQOff~1f)?$O:OOO MD, 3624.68ft TVD pecreaSEÌJ~)!:-.§Jô'20.24~t~Ööft: 5387.68ft MD, 3742.61ft TVD ~:tfil-Sand' PR¥Jê pt, Start'Sail @ 88.7° inc & 35.44° Az: 5545.41ft MD, 3788.80ft TVD . . - . .. . -. . u . u n . ... .. d -. -. 2503.30 E -\B.eg¡.1J Dir @-6.1°/100ft: 6365.41ft MD, 3807.400 TVD 26°<1~~'B: DeÇr~e DLS to 6.0°/1000: 6574.42ft MD, 3811.100 TVD .. f67~1?3JE)";.{t;:!eeli Target: 6945.900 MD, 3812.800 TVD .2701.85- E .; Proposed BHL ('Toe') : 9817.93ft MD, 3798.8Oft TVD file Penetration Point Vertical Sub-Sea Depth Depth Northings Eastings (It) (It) {It} (ft) Formation Name 3758.80 2939.27 N 1958.43 E Top West Sak 'D' 3658.00 9 October, 2001 - 16:53 Page 5 of 6 . North Slope, Alaska Kuparuk 1 D ~--d. -~ DrillQuest 2.00.09.003 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> 5000.00 <Surface> 3417.43 Targets associated with this we/Jpath Target Name 1D105a (Heel) 1 D10Sa (Toe) D såfld ~PJåne' To Measured Vertical Depth Depth (ft) (ft) 5200.00 9817.93 3597.34 3798.80 Sperry-Sun Drilling Services Proposal Report for 10-1 05A (wp02) Your Ref: per Prelim Plan ver #0.8 Revised: 9 October, 2001 . North Slope, Alaska Kuparuk 1 D Casing Detail ~ , --', 7 -5/8" Casing 4-1/2" Liner Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 3812.80 4249.58 N 2678.73 E Point Current Target Mean Sea Level/Global Coordinates: 3712.00 5964070.00 N 563135.00 E Geographical Coordinates: 700 18' 44.4304" N 149029' 18.1160" W 3798.80 7121.49 N 2701 .85 E Point Current Target Mean Sea Level/Global Coordinates: 3698.00 5966942.00 N 563135.00 E Geographical Coordinates: 700 19' 12.6780" N 149029' 17.4112" W 3788.80 3037.78 N 2027.95 E Point Current Target Mean Sea Level/Global Coordinates: 3688.00 5962853.00 N 562494.00 E ~ Geographical Coordinates: 70018132.5133" N 149029' 37.1108" W ---- ---- - - -- 9 October, 2001 - 16:53 Page 6 of 6 DrillQuest 2.00.09.003 iUips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 D Pad 1 Current Well Properties 1D-105A Well: Horizontal Coordinates: Ref. Global Coordinates. Ref. Well. Ref. Geographical Coordinates: RKB Elevation North Reference' Units: 5959798.99 N, 560490.57 E 105.25 S, 5.58 E 70" 18' 02.6368" N, 149" 30' 36.2633" W (134' FSL & 595' FEL, SEC. 14-T1 100.80ft above Mean Sea Level True North Feet (US) Top 01 Whipstock (7-5/8" Csg) 15.90'/1O0ft : 5200.00ft MD, 3597.34ft TVD Begin Rathoie @ 24.67' (6-314" Hoie): 5212.00ft MD, 3608.32ft TVD Begin Dir @ 20.39"/100tt: 5230.0011 MD, 3624.68tt TVD iõ >:: 1!=. .c ã. OJ 0 ëõ (,) to OJ > OJ :0 ~ Scale: 1inch = 10001t Eastings 3500 i 4500 7500 7500 3000.88 ;; c. ¿ « Ii) 0 6 6500 6500 3803.80 5500 5500 W0673 3S09.55 Cj) 0> C :.e t 0 Z 4500 3500 4500 3500 Dir @ 6.1'/100ft: 6365.4111 MD, 3807.40ft TVD 2500 Decrease DLS to 20.24'/10011: 5387.68ft MD, 3742.611t TVD Begin Dir @ 20.39'/100ft: 5230.00ft MD, 3624.68ft TVD Begin Rathole @ 24.67" (6-3/4" Hole): 5212.0011 MD, 360B.32ft TVD Top of Whipstock (7-5/B" Csg) 15.90'/1O0ft : 5200.00ft MD, 3597.341t TVD 2500 1500 3500 4500 2500 4.1/2' 6250 7250 6750 ...-..... '. . Phillips Alaska, Inc. 1 D-105A (wpO2) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS v.s. Comment (1t) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/1001t) (ft) 5200.00 22.93 30.79 3496.54 3597.34 2821.71 N 1878.79 E 5962635.73 N 562346.59 E 0.00 2821.71 Top of Whipstock (7-5/811 Csg) 5212.00 24.67 32.72 3507.52 3608.32 2825.82 N 1881.34 E 5962639.87 N 562349.10 E 15.90 2825.82 Begin Rathole (6-3/4" Hole) 5230.00 24.67 32.72 3523.88 3624.68 2832.14 N 1885.40 E 5962646.22 N 562353.11 E 0.00 2832.14 Begin Dir 5387.68 56.79 34.81 3641.81 3742.61 2916.20 N 1942.34 E 5962730.74 N 562409.37 E 20.39 2916.20 Decrease DLS 5501.96 79.91 35.28 3683.69 3784.49 3002.56 N 2002.95 E 5962817.58 N 562469.29 E 20.24 3002.56 Top West Sak 'D' 5545.41 88.70 35.44 3688.00 37§.8.80 3037.78 N 2027.95 E 5962853.00 N 562494.00 E 20.24 3037.78 'D-Sand' Heel ...(Start Sail) 6365.41 . 88.70 35.44 3706.60 3807.40 3705.68 N 2503.30 E 5963524.70 N 562963.96 E 0.00 3705.68 Begin Dir 6574.42 89.23 22.70 3710.39 3811.19 3887.96 N 2604.63 E 5963707.79 N 563063.82 E 6.10 3887.96 Decrease DLS 6945.90 90.28 0.46 3712.00 3812.80 4249.58 N 2678.73 E 5964070.00 N 563135.00 E 5.99 4249.58 'End of Turnl Target (Start Sail) 9817.93 90.28 0.46 3698.00 3798.80 7121.49 N 2701.85 E 5966942.00 N 563135.00 E 0.00 7121.49 Proposed BHL (Toe') I ---- " ( (- Sperry-Sun Anticollision Report Company: Phillips Alaska Inc. Date: 10/0912001 Time: 16:36:46 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1 D Pad Co-ordiDate(NE) Reference: Well: 10-105, True North Reference Well: 1D-1O5 Vertical (TVD) Reference: 1D-1O5@ 100.8' RKB 100.8 Reference WeUpath: Plan: 10-105A Db: Orade GLOBAL SCAN APPLIED: AU wellpatbs within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MO Interval: 50.00 ft Error Model: ISCWSA Ellipse Deptb Range: 5200.00 to 9826.97 ft Scan Metbod: T rav Cylinder North Maximum Radius: 1179.67 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Well path Date: 09/20/2001 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 100.80 5200.00 1D-105 MWD MWD - Standard 5200.00 9826.97 Planned: 1 D-1 05A (wp02) V1 MWD MWD - Standard Casing Points MD TVD Diameter Høle Size Name .ft ft in in 5200.00 3597.34 7.625 9.875 75/8" 9826.97 3798.85 4.500 6.125 41/2" Summary < . Offset Wellpatb. > . Site. . . \Veil...' . ... Wellpath ' Kuparuk 1C Pad 1 C-02 1C-02 V1 Out of range Kuparuk 1C Pad 1C-133 1C-133 V6 Out of range Kuparuk 1C Pad 1 C-26 1 C-26 VO 9810.54 4700.00 1041.41 350.59 698.24 Pass: Major Risk Kuparuk 1C Pad Plan 1C-137 (Y14) 1C-137 (Y-14) VO Pia Out of range Kuparuk 1 D Pad 1 D-01 1 D-01 V9 Out of range Kuparuk 1D Pad 1 D-02 1 D-02 V9 5290.69 5300.00 856.32 247.96 636.03 Pass: Major Risk Kuparuk 1D Pad 10-03 1 D-03 V5 Out of range Kuparuk 1 D Pad 10-101 1D-101 V1 Out of range Kuparuk 10 Pad 1D-102 1D-102 PB1 V9 Out of range Kuparuk 1 D Pad 1D-102 1D-102 PB2 V1 Out of range Kuparuk 1 D Pad 1D-102 1D-102 PB3 V1 Out of range Kuparuk 1 D Pad 1D-102 1D-102 V1 Out of range Kuparuk 1 D Pad 1D-102 1D-102L1 V1 Out of range Kuparuk 10 Pad 1D-103 WPs 1D-104 WPs V2 Plan: PI Out of range Kuparuk 1D Pad 1D-104 WPs 1D-104 WPs V1 Plan: PI Out of range Kuparuk 1 D Pad 1D-105 1D-105 V2 5200.00 5200.00 0.00 0.84 -0.73 FAIL: No Errors Kuparuk 1 D Pad 1D-106 1D-106 V2 Out of range Kuparuk 1 D Pad 1D-107 1D-107 V6 5200.00 5600.00 1115.60 273.66 848.50 Pass: Major Risk Kuparuk 1 D Pad 1D-108 1D-108 V3 Out of range Kuparuk 1 D Pad 1D-109 1D-109V2 Out of range Kuparuk 10 Pad 1D-110 1D-110 V2 Out of range Kuparuk 10 Pad 1D-110 1D-110A VO Out of range Kuparuk 1 D Pad 1D-110 1D-110A WPs V8 Plan: 1 Out of range Kuparuk 1 D Pad 1D-111 1D-111 V2 Out of range Kuparuk 1 D Pad 1D-112 1D-112 V2 Out of range Kuparuk 1 D Pad 1D-113 1D-113 V2 Out of range Kuparuk 10 Pad 1D-114 1D-114 V2 Out of range Kuparuk 1 D Pad 1D-115 1D-115 V2 Out of range Kuparuk 1 D Pad 1D-116 1D-116 V2 Out of range Kuparuk 1 D Pad 1D-117 1D-117 V2 Out of range Kuparuk 10 Pad 1D-118 1D-118 V2 Out of range Kuparuk 1 D Pad 1D-12 1D-12 V2 Out of range Kuparuk 10 Pad 1 D-140 1D-140 L 1 VO Plan: 1D- Out of range Kuparuk 1 D Pad 1 D-140 1D-140 PB1 V4 Plan: 1D Out of range Kuparuk 1 D Pad 1 D-140 1D-140 VO Out of range Kuparuk 1 D Pad 1 D-141 1D-141 VO Out of range Kuparuk 10 Pad 1D-141 1D-141 WPs V4 Plan: 1D Out of range Kuparuk 1 D Pad 1D-141 1D-141L 1 VO Out of range Kuparuk 1 D Pad 1D-141 1D-141L 1PB1 VO Out of range Kuparuk 1 D Pad 1D-141 1 D-141 L2PB2 VO Out of range Kuparuk 1 D Pad 1D-141 1D-141PB1 VO Out of range Kuparuk 1 D Pad 1 D-14 1 D-14 V2 Out of range Kuparuk 10 Pad Plan 1D-19 (C12) 1D-19 (C-12) VO Plan: Out of range Will DI'TAIIS ANTI-COLLISION SE'ITINGS N"m, ""~",d' ",' +N/S +UW Nmllm" 1"1\"",, ID-IO' 13L17 'm490..'7 N/A -59,1S6 "'5979899 70"'02"'7N 149 "n6263W twpO2) 1213 0 From ColDur 0 5000 5500 6000 6500 7000 7500 SOOO S500 9000 9500 1000 750 500 250 0 250 500 750 1000 1213 180 Travel1ing Cylinder Azimuth (TFO+AZl) [deg] vs Centre to Centre Separation [500tì/in] COMI',"Y SIIRVI'), PROGOAM ISp'" I'm "'1"" T" Sm"y/P"" ,]!niXJ 98 Ins P,""","IDII"AI""O"VI ToMD 5000 5500 6000 6500 7000 7500 SOOO S500 9000 9500 10000 From Colour 0 5000 5500 6000 6500 7000 7500 SOOO S500 9000 ~OO 0.0 0 5.0 ]5,0 90 Œ7 5.0 -15.0 0,0 Travel1ing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15ft/in] SICT10N OETAIIS See TVD +NI-S MD I",' A" 1"",1 MWO To 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 WI'LIPArI! DII.\IL' PI", II)O)5A """",W""p"," ¡¡"",MD 1D105 om "'" IMD,""'; II)-lOS@ liXJ,WOKIl Im&m O,i,¡" +NI-S On"" +El-W 51"""'1' I'm",TVO 211.76 O.lX! LEGIN1~) lUX) pO"ID-IO'A"'l/02)(ID-IOS/PJ",II)I()5A) C',"'ee' By'BertG"'f D,," lO/09ntJOI ,,"-W OL,I' VSee T'"gd !!)I(iS"(!!,,O PHILLI( 3 Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 (" October 10, 2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: 1 D-105A Surface Location: Target Location: Bottom Hole Location: 134' FSL,595'FEL,Sec. 14,T11N, R10E 2218'FNL,1357'FWL,Sec.13,T11N,R10E 1976' FSL,2112'FWL, Sec. 12,T11N,R10E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well 1 D-1 05A. The well will be sidetracked and completed using Nordic 3. Please refer to the diverter and BOP schematics previously filed with the Commission for blowout prevention information as required under 20 AAC 25.005(c)(3). Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1 D, or hauled to an approved Prudhoe or GKA Class II disposal well. We would greatly appreciate your immediate attention to this permit as our drilling schedule has changed and requires us to move to this well this week. Several wells on the schedule have been eliminated and we have had to push forward the operations on 1 D-1 05A. Therefore, we are asking you to expedite processing of this permit by October 12, 2001. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974. Sincerely, ef RECEIVED Chuck Mallary Drilling Engineering Supervisor OCT 1 0 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ( (' I J i \ American Express8 Cash Advance Draft 167 DATE 0/&>&'",. ¡P, 2eo 107--40111111 ~ SUCC>.C)O PAY TO THE ORDER OF DOLLARS ..----. Issued by Integrated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand junction - Downtown. NA Grand junction. Colorado PERIOD ENDING tD -lOS A- I: . 0 2 . 0 0 .... 0 0 I: :l 5 III 0 . 7 5 0 0 0 5 :l b III 0 . b 7 .. ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELL NAME kf?¿.( /» -. /Ocs-Â- CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL / EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DI~OSAL ( i A NO ANNULAR DISPOSAL <-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. .. . ANNULUS <-J YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. IC R LL WELL PERMIT CHECKLIST COMPANY ~ WELL NAME / D -/05,L) PROGRAM: exp - dev -.-L redrll FIELD & POOL '-Ie 0/56 INIT CLASS -:::-\/' 0/ L- GEOL AREA ADMINISTRATION 1, Pennit fee attached. . . . . . . . . . . . . , . . . . , . . .. ,,- Y N 2, Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available'in drilling unit.. . . . . . . . , . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . , , . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . , . . . 11. Pennit can be issued without conservation order. . . . . . . . 12. Pennit can.be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . ~ i: ~a;~;~~i~E~;~,:~'~~~~~~ i ~~d ~g: ': ': : : cf ~~ ~ :::~~~: ~~ ~:~ ~\( 17. GMT vol adequate to ,tie-in long string to surf csg. . . . . . . . Y ~.." ~ \ - , , ~ I 1::-1' b .. \ - ~... 18. CMTwillcoveraliknownproductivehorizons. . . . .', . . .. ' W ~tt..ft.~r) ,E)""'O~'bt" ,~,-~ ~~ 19. Casing designs adequate for C. T. B & permafrost. . . . . . . ' N T ~~: ~~e~~I~~~~~ ~~f;~~:~d~n~~t ¡'~e~ ~pp;o~~d: : : . ~ .!,~~ ~ ~ ~ ~~~ ~~ ~ ~ 22. Adequate wellbore separation proposed.. . . . . . . . . . .. , N ....~ ~\~ ~ -.:..- -~~~~ 23. If diverter required. does it meet regulations. . . . . . . . . . y N ~b... 24. Drilling ,fluid program schematic & equip list adequate. . . . . N DATE ~~: ~g~~spr~~:~:~.;e:~¿~~~~~~;nt~si t~ . . . . ~rou' ~sig: ~ -~~~~ t~~'\~~~ ~ \d~ 0 ?~ \ ~ . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work. will occur without operation shutdbwn. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (f9 30. Pennit can be issued w/o hydrogen sulfide measures. . . . ,. çpy 31. Data presented on potential overpressure zones. . . . . .. /'. ~ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . .~. . , . ok Y N APRB DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N < ;'61) /0' /1 ¡ 6/ 34. Contact name/phone for weekly progress reports [~ ratery only] Y N ANNULAR DISPOSAL35. With proper cementing records. this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; . . (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N ~ ENGINEERING: UIC/Annular COMMISSION: ~ WM ~ 8~pc2{ I) J [} I < If:;)(, JM .. J A~Ef) DATE iD' /L D ¡ ENGINEERING GEOLOGY APPR Y N Y N DATE c:\msoffice\wordian\diana\checklist (rev. 11/011100) serv wellbore seg _ann. disposal para req- 0 I It ON/OFF SHORE () n UNIT# .5U-Y"'f.:t.'-c-- ~d ..,t.(f röc/v::"-h-v<- ~,it!.-rv.1:./ /~-(' 'i ~'~ /9DL OZ:S-cfSb ,-¡'v /OCAÞ--d?1".. ADL ð2Sb '/9, ,4b Com me ntsllnstructions: c 0 Z ( 0 -I ~ :;0 - -I m - z -I :r: - en » :;0 j' ,I' '" \. m » ~,<" 't ~' Well History File APPENDIX Information of detailed nature that is not , particularty gennane 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 Drilling Service~ LIS Scan Utilit.y $Revision: ~-) ~: LisLib $Revision: 4 $ Thu Feb 1417:59:50 2002 Reel Header Service name.... .........LISTPE Date.....................02,1CJ2/1':; Ori,;]in...................STS Reel Name................UNKNOI\JN Continuation Number......O1 Previous Reel Name.......UNKNOWN Conunents.................STS LIS Tape Header Service name.............LISTPE Date.....................02/02/H Ot-igin...................STS Tape Name................LJNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER. Kuparuk River Unit MWD/MAD LOGS # WELL NÞME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-ll1'72 J. SACK R. BOWIE II SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD If Writing Library. Scientific Technical Services Wr-i ting Library. Scientific Technical Services ID-I05A 500292284301 PHILLIPS Alaska, Inc. Sperry Sun H-FEB-02 MWD RUN 3 AK-MM-11l72 ,J. ~3ACK R. BOWIE MWD RUN 4 AK-MM-11l72 J. SACK R. BOViII E ,I D 14 UN 10E 134 595 0 .00 100.80 70.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 5205.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY FOR SETTING WHIPSTOCK AND IS NOT PRESENTED. aO/-aù~ ~: i( 3. !'-1WD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GÞlv[!VIA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (Eí^JR4) . 4. RESISTIVITY DATA PRESENTED FROM 7450' MD, 3818' TVD, TO 8584' MD, 3830' TVD WAS OBTAINED DURING A 1'-1ADPASS AFTER Hì"JD RUN 400 DUE TO TOOL DAMAGE ON MWD RUN 300. 5. MWD DATA IS PDC PER THE GKA GEOSIENCE GROUP (E-MAIL FROJ'.1 D. SCHWARTZ OF PHILLIPS }\LASKA, INC. DATED 01/04/02). DATA NOT SHIFTED TO PARENT WELL THIS WELL KICKS OFF FROM 10-105 AT 5205' MD, 3602' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 2 - 4 REPRESENT WELL, ID-105A WITH API # 50-029-22843-01. THIS WELL REACHED A TOTAL DEPTH OF 9820' MD, 3830' TVD. SROP = SMOOTHED RATE OF PENETH.ATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SI-IALLC)[ì'J S PJ..\CTNG ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACINC3 ) SEDP'" SMOOTHED PHl\SE SHIE'T DEHIVED RESISTIVITY ( DEEP SPACING) Sf'XE = SMOO'I'HED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.OO1 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......O2/02/14 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR ROP FET 1 clipped curves; all bit runs merged. .5000 S1:AW[' DE P1'H 5200.0 5200.0 5200.0 5200.0 5205.0 5240.5 5240.5 S'I'OP DEP'I'I-I 977 3.5 9773.5 9773.5 9773.5 9766. ~) 9B20.0 9773.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIF~[' DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD BIT RUN NO 2 MERGE TOP 5200.0 MERGE BASE 6130.0 .j" ( l 4 Ó031.0 8577.5 :::630. (I 9820.0 ìVí\^lD !'-TI-;'D 3 ~; - RE,HARI<S: HERGED HAIN PASS. .:;; rl Data format Specification Record Data Record Type..................O Data Specificati,=,n Block Type..... 0 Lc";J,::¡in<::¡ Direction.................Dc,wrl 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 OHM.M 4 1 68 12 4 RPS MWD OHM.M 4 1 68 16 5 RPM M\i\TD OHMM 4 1 68 20 6 RPD MWD OI-lM.M 4 1 68 24 7 FET MWD I-IR 4 1 68 28 8 Fir.'st: Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5200 9820 7510 9241 5200 9820 ROP M.WD FT/I-! 2.61 1855.75 165.833 9160 5240.5 9820 GR M.WD API 36.56 118.72 69. :)804 9124 5205 9766.5 RPX M\i\TD OHM.M 0.39 12'HL 27 23.4767 9148 5200 9773.5 RPS MWD OHM.M 0.71 1;278.51 40.8~)58 9148 5200 9773.5 RPM. Mt\fD OHMM. 0.84 2000 46.9994 9148 5200 9773.5 RPD MWD OHMM 1. 25 2000 b9.6% 914 f3 5200 9773.5 fET M.WD HR 0.15 67.85 15.124 9067 5240.5 9773.5 First Reading For Entire File..........5200 Last Reading For Entire File...........9820 File Trailer Service name.............STSLIB.O01 Service Sub Level Name... Version Number...........l.O.O Date of Generation.. .....02/02/14 Maximum Physical Record..65535 Fi1e'I'ype................l,O 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.......O2/02/14 Maximum Physical Record..65535 File Type................LO Previous File Name.......S'I'SLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 2 header data for each bit run in separate files. "" ¿ ( DE PTH I NCREHEI\J1' : .500Cì '. FIJÆ SUivUvIARY VENQOR TOOL CODE RPD RPM RPS RPX GR ST.~RT DE PT:i 5200.0 5200.0 5200.0 5200.0 5205.0 5240.5 5240.5 STOP DEPTH 6087.5 6087.5 6087.5 6087.5 6080.5 6130.0 ROP FET 6087.5 (. ..,' Ii LOG HEADER DATA DATE LOGGED: SOFTIÑARE SURFACE SOFTWARE VERSION: DOWNHOl,E SOFTWARE VERSION: DAT,1\ TYPE (MEMORY OR REAl,-TIME): 'I'D DRIl.l,ER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGl,E,: i,f TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUA.L GA.MMA RAY ELECTFWMAG. RESIS. 4 II BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): ¡VIUD PH: MUD CHLORID.ES (PPM): FLUID LOSS (C3): RESISTIVITY (OH¡VIM) AT TEMPERATURE (DEGF) MUD AT ME1\SURED TEMPERATURE (M'r): MUD 1\'1' MAX CI!7!,.CULATINC; TERMPERl\TURE: MUD FILTRATE AT ¡ver: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: ¡VIA'l'TUX DENSITY: HOJÆ CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if 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 Name Service Order DEPT ,{ , 20-0CT-O1 Insite 4.05.5 66.16 Mernory 6130.0 26.3 90.8 TOOL NUI'1BER PBO2225HAGR4 PB02225HAGR4 6.750 Water 9.00 45.0 8.8 14100 4.4 Based .370 .294 .280 .390 64.0 82.4 64.0 64.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 KOP 'JR KF':': KPS f.!~'JD020 MWD020 MìÑDO:20 Mí~DO 2 0 !'1\IiJD020 HìÑD020 MìÑD020 RF'!'1 RPD FET { FT/H API OHM1'1 OHMM OHH1'1 OHMM HR 4 4 4 4 .1 4 ,1 ( 1 1 1 1 1 1 1 68 4 ') 68 68 68 68 8 .:; 4 5 12 16 20 6 68 ,~, -'"' 6::: ::: ::: ::: First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5200 6130 5665 1861 5200 6130 Rap MWD020 FT/H 2.61 399.51 73.8816 1780 5240.5 6130 GR MWD020 API 36.56 118.72 72.3208 ]752 5205 6080.5 RPX MWD020 OHMM 0.39 1278.27 27.1831 1776 5200 6087.5 RPS MWD020 OHMM 0.71 1278.51 47.8301 1776 5200 6087.5 RPH H~'VDO 2 0 OHMH 0.84 2000 46.6778 1776 5200 6087.:) RPD MWD020 OHHM 1.25 2000 70.6091 1776 5200 6087.5 FET MWD020 HR 0.41 3.06 1. 5217 9 1695 5240.5 6087.5 First Reading For Entire File. ...,. ....5200 Last Reading For Entire £'ile...........6130 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.. .....02/02/14 Haximum Physical Record..65535 File'rype................LO Next File Name...........STSLIB.003 Physj.cal EOF File Header Service name............. STSLIB. 003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/14 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR F'ET RPD RPM RPS RPX ROP 3 header data for each bit run in separate files. 3 .5000 $ START DEPTH 6081. 0 6088.0 6088.0 6088.0 6088.0 6088.0 6130.5 t~ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOf"l'WARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 8577.0 8584.0 8584.0 8584.0 8584.0 8584.0 8630.0 22-0CT-0l Insite 4.05.5 66.16 Memory 8630.0 it T?OTTOM LOG INTERVAL (fT): BIT ROTATING SPEED (RPM): ~!OLE INCLINATION (DEG I'll N I HU]'! .I\NGLE: rLA.XIIv¡UM l\NGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (fT): Ji BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): HUD VISCOSITY (S): HUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) tvlUD AT MEASURED TEtvlPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATUR£:: tvlUD FILTRATE AT MT: tvlOD CAKE AT MT: 1/ NEUTRON TOOL tvlATRIX: Ml-\TRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REtvlARKS: $ # 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 Spec.ification Bloc:1<. sub-type... 0 ( 85.1 91. :::: TOOL NUI'IBER PB02225HAGRej PB02225HAGR4 6.750 Water- 9.40 47.0 9.0 16800 4.3 Based .240 .186 .280 .280 68.0 89.6 68.0 62.0 Name Service Order Uni.ts Size Nsam Rep Code Offset Channel DEPT E'T 4 1 68 0 1 ROP MWD030 FT!H 4 1. 68 4 2 GR MWD030 f\PI 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMtvl 4 1. 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHHM. 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last .Name Service Unit Min Max Mean N;;:~am Reading Reading DEPT FT 6081 8630 7355.5 :)099 6081 8630 ROP MWD030 FT/H 5.29 1197.22 184.265 5000 6130.5 8630 GR MWD030 API 47.4 lCH.78 68.7289 4993 6081 8577 RPX MWD030 OHMM 8.21 61.43 21.3472 4993 6088 8584 RPS MWD030 OHtvlM 15.01 192.18 39.6792 4993 6088 8584 RPtvl MWD030 OHMtvl 16.83 135.26 46.0683 4993 6088 8584 RPD MWD030 OI-lMM 23.92 181.07 59.2139 4993 6088 8584 FET MWD030 HR 0.15 67.85 26.0656 4993 6088 8584 ( First Reading For Entire File..........608l Last Reading For Entire File...........S63C Fi.le Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......O2/O2/14 Maximum Physical Record..65535 File Type................LC> Next File Name...........STSLIB.OO4 Physical EOF File Header Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/14 Maximum Physical Record..65535 File Type............. ...LO Previous File Name.... ...STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 4 ( header data for each bit run in separate files. 4 .5000 START DEPTH 8577.5 8584.5 8584.5 8584.5 8584.5 RPD RPM RPS RPX FE '1' ROP $ 8584.5 8630.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURF'.ACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM J~OG INTERVAL (F"I'): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9766. !:) 9773.5 9773.5 9773.5 9773.5 9773.5 9820.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOT'l'OM) TOOL TYPE DUAL GAMMA RAY ELEC'T'ROMAG. RESIS. 4 # BOREHOLE AND Cl-\SING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: 24-0CT-Ol Insite 4.05.5 66.16 Memory 9820.0 86.9 92.0 TOOL NUMBER PB02222HAGR4 PB02222HAGR4 6.750 Water Based 9.50 47.0 8.7 --( :( :; '~ ìViUD CHLORIDES (PHI): FUnD LOSS (C3): RESISTIVITY (OHMM) l\T TEHPER}\TURE', (DEGF MUD AT MEASURED TEMPERATURE (NT): MUD .1\1' Mi\/: CIRCULATING TERMPER}\TUí-\(: MUD FILTR.J\TE Þ.T HT: 1'-1UD CAKE AT MT: 15ljO( 4. ::: .270 .:232 71J. '. 8:~. 4 70.0 70.0 .240 .300 4 NEUTRON TOOL ¡"IATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): » TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: ,. y ff Data Format Specification Record Data Record Type..................O Data Specì.fication Block Type.....O Loggì.ng 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 Serv.ice Order Units Size Nsam Rep Code Offset Channel DEPT F1' 4 1 68 0 1 ROP MWDO40 FT/H 4 1 68 4 2 GR MWDO40 API 4 1 68 8 3 RPX MWD040 OI-IMM <1 1 68 12 4 RPS MWDO40 OHMM 4 1 fif3 16 5 RPM MWDO40 OHMM 4 1 68 20 (') RPD MWDO40 OHMM 4 I 68 24 7 FE1' MWDO40 HR 4 1 6ß 28 8 F:Lrst Last Name Service Unit Min Max Mean N::¡am Reading Reading DEPT FT 8577.5 9f320 9198.75 2486 8577..5 9820 ROP MWDO40 fT/H 8.21 1855.75 195.882 23tJO 8630.5 9820 GR MWDO40 API 47.11 97.67 69.3495 2379 8577.5 9766.5 RPX MWDO40 OrIMM 7.83 59.32 25.1792 2379 8584.5 9773.5 RPS MWD040 OHMM 13.57 92.94 38.1189 2379 8584.5 9773.5 RP¡V¡ MWD040 OHMM 17.13 104.86 49.1936 2379 8584.5 9773.5 H.PD M1iIiDO 40 OHMM 19.'72 lCH. 613 52. 5~)n 2379 8584.5 9773.5 FE '1' MHD040 HR 0.15 27.14 1.05111 2379 8584.5 9773. .5 First Reading For Entire Fi1e..........8577.5 Last Reading For Entire File...........9820 File Trailer Service name.............S1'SLIB.OO4 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/14 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO5 Physi.cal EOF Tape Trailer Service name.. """" ...LISTPE Date.....................02/02/14 ( :;c.i'Jin...................STS Tape Narne................UNKNOWN :ontinuation Nurnber......Ol ~ext Tape Name...........UNKNOWN Comments.... ... ..... '" ..STS LIS Writing Library. Reel Trailer Service name............. LISTFE Date.....................O2/02/l4 Origin...................STS Reel Narne................UNK'NOWN Continuation Number. .....01 Next Reel Name...... .....UNKNOWN Comrnents.................STS LIS Il'Jri tinq Library. Physical EOr Physj_cal EOr End Of LIS File :( Scientific Technical Services Scientific Technical Services