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C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-23_16019-KRU_1A-28_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16019 KRU 1A-28 50-029-22126-00 VIVID Leak Detect Log 23-Jan-25 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 ______________________________ _____________________________________ 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 191-002 T40076 2/12/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.12 14:55:21 -09'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2025-01-09_16019_KRU_1A-28_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16019 KRU 1A-28 50-029-22126-00 VIVID Leak Detect Log 09-Jan-25 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 ______________________________ _____________________________________ 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 191-002 T40051 2/6/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.06 08:41:16 -09'00' OF w�'‘� /7 s THE STATE • Alaska Oil and Gas e� ceA of/� //fj �` • Conservation Commission _ KA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h Main: 907.279.1433 (4%.1k SSP Fax: 907.276.7542 www.aogcc.alaska.gov July 1, 2016 Mr. Patrick Wolfe North Slope Integrated Operations and Project Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH 16-018 SCA,NNED DEC 16 20161 Notice of Violation Rescinded Dear Mr. Wolfe: On June 14, 2016, the Alaska Oil and Gas Conservation Commission (AOGCC) issued a notice of violation to ConocoPhillips Alaska Inc. (CPAI) for failing to test the well safety valve system on Kuparuk River Unit (KRU) 1A-28 (PTD 1910020). AOGCC also increased the well safety valve system testing frequency for KRU 1A-pad in response to a component failure rate exceeding 10 percent. Thank you for your quick response which updates the investigation findings provided earlier. In the June 22, 2016 response, CPAI notes that additional review shows that the proper sized low pressure pilot was installed on KRU 1A-28 after well work was completed in August 2015, and the well safety valve system was successfully tested when production was recommenced. AOGCC well records confirm the post-workover test occurred on October 24, 2016. CPAI notes that a discrepancy between the actual set point of the low pressure pilot and CPAI's "IP21" data system was found during the investigation and corrected. Several other corrective actions have been identified and implemented as a result of the investigation. We applaud CPAI for its thorough investigation and implementing actions identified as "opportunities for improvement". The notice of violation for failure to test the well safety valve system on KRU 1A-28 is rescinded. The safety valve systems associated with wells located on KRU 1A-pad must be tested at intervals not exceeding 90 days as instructed in AOGCC's letter dated June 14, 2016. Please direct any questions regarding this decision to Jim Regg at 907-793-1236. Sincerely, Cathy . Foerster Chair, Commissioner Docket Number:OTH 16-018 41111 July 1,2016 Page 2 of 2 cc: P. Brooks AQGCC Inspectors NSK 69—Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • Patrick J.Wolfe Manager North Slope Integrated Operations &Projects ConocoPhil lips 700 G Street,, ATO 1226 Anchorage,AK 99501 Alaska, Inc. Phone 907 265 6202 patrick.j.wolfe@cop.com June22,2016 RECEIVED JUN 23 ?' Mr. Daniel T.Seamount,Jr. AOGCC Commissioner Alaska Oil and Gas Conservation Commission 333 W.7"'Avenue Anchorage,Alaska 99501 Re: Docket Number OTH-6-018 Response to AOGCC inquiry about the 1A-28 LPP Possible Compliance Issue Dear Commissioner Seamount, On June 2,2016 an AOGCC witnessed pad test was performed on DS-1A and the pad had a failure rate of 13.6%(11 wells,22 components,3 failures). During the investigation of the pad failure, it was discovered that there was a discrepancy between the pilot set point recorded in our IP21 system and the tag on the pilot which led us to believe that the LPP was changed and not tested since we didn't have a record of the pilot being changed. We self disclosed this information to Jim Regg on 6/6/16 via email.In a letter received June 16, 2016, the AOGCC requested COPA to provide the Commission with an explanation of how this event happened and what has been or will be done in the future to prevent recurrence. COPA provides the following description of events that led to the pilot information being incorrect, as revealed by our incident investigation,and steps being taken to prevent recurrence. Description of incident: A State witnessed SVS pad test was performed on DS-1A on 6/2/16. The pad failed the pad test with a failure rate of 13.6%(11 wells, 22 components,3 failures). An incident investigation into the pad failure was started the next day. As part of the investigation it was discovered that the pilot setpoint recorded in 1P21 for well 1A-28 was 85 psi and the tag on the pilot at the wellhead was for a 60 psi pilot. This led COPA to believe that a regulatory out of compliance incident might have occurred when an undocumented pilot change occurred. Notification of a possible nonconformance was reported to Jim Regg on 6/6/16. Findings An investigation into the possible nonconformance was completed on 6/11/16. The investigation identified that a 60 psi pilot was installed after the rig workover in August 2015 but the IP21 set point was not updated with the new pilot setting. Post workover, 1A-28 was brought back online on 10/21/15 and • • Mr. Daniel T.Seamount,Jr. Commissioner Alaska Oil and Gas Conservation Commission June 22, 2016 Page 2 the SVS system successfully tested on 10/24/15. Therefore,we concluded that an undocumented pilot change did not occur and no SVS tests were missed. We did have an incorrect pilot setting recorded in our IP21 system and recorded the wrong pilot setting on the state testing forms for the 10/24/15, 12/13/15 and 6/2/16 tests. The investigation revealed the following sequence of events: • August 2015- POP crew reassembled the well after the August 2015 RWO and did not have the previous LPP to install. They requested a pilot with the 60 psi setting listed on the P&ID from the PSV shop and installed it on the well, but did not update IP21 with the correct pilot setpoint and installation date. • October 21,2015-The well was brought online • October 24, 2015 -The wellhead SVS was MISC tested and the pilot tripped at 73 psi, which is consistent with a new pilot set point of 60 psi that has an actual trip pressure of 69 psi(15%above set point). A new 85 psi pilot would be expected to trip above 97 psi. The State test report identified the pilot as an 85 psi pilot,which we now know was in error. The set point recorded on the test report was taken directly from IP21, which was not updated when the 60 psi pilot was installed. • December 13, 2015 - DS1A pad test was completed and 1A-28 LPP passed with a 51 psi trip pressure. Test report indicates an 85 psi set point for the LPP. This is still incorrect since the IP21 data discrepancy had not yet been discovered. • March 13, 2016- Pad LPP PM completed and 1A-28 tripped at 58 psi. SVS Tech log book makes note about a 60 psi pilot on 1A-28. No follow-up on the actual pilot setpoint in IP21 was initiated at this time. • June 2, 2016- LPP on 1A-28 failed to trip at the required pressure during the pad test(actual 43 psi, required 46 psi). Total failure rate for the pad was greater than 10%, thus triggering an internal LCA of the failures. • June 2, 2016 - LPP on 1A-28 replaced by SVS Tech with an 85 psi LPP and retested per State of Alaska SVS requirements. Test witnessed by State Inspector. • June 5, 2016 - LCA of the pad failures incorrectly identified that the LPP on 1A-28 had been changed sometime between the December 2015 pad test and the March 2016 pilot PM and had not been recorded properly or tested per Alaska requirements. Investigation of this situation initiated. • June 6,2016- State of Alaska notified by Scott Fahrney of the possible non-conformance. • June 10, 2016 - The 60 psi pilot removed from 1A-28 was in the PSV shop and the PSV Shop calibration seal had an "August 2015" date. Identification of the August 2015 calibration date results in the linkage to the RWO post rig work. • June 11, 2016 - Determination made that the LPP on 1A-28 was installed in August 2015 and tested per State requirements within 5 days after the well POP,and therefore was in compliance. Error in documentation led to the false conclusion otherwise. • • Mr. Daniel T.Seamount,Jr. Commissioner Alaska Oil and Gas Conservation Commission June 22,2016 Page 3 As part of the follow up action items we did compare the set point marked on the pilot to the settings on IP21 and did find one other well, 1Y-29, to have a discrepancy between the tag and the IP21 set point. This discrepancy was also traced back to a rig workover performed on the well. Review of our procedures related to these activities identified some opportunities for improvement. The corrective actions identified in the investigation are summarized below. 1. Compare the 1P21 setpoint to the pilot setpoint for all wells. CPF1 Complete. CPF2 and CPF3 in progress. 2. Add the comparison of the IP21 setpoint and the pilot setpoint to the 6 month LPP PM. Complete. 3. Update the GKA SVS Operating Procedure to clarify which work groups are allowed to change LPP's. Due 9/30/16. 4. Investigate replacing the setpoint on the P&ID with a reference to setting the LPP per AOGCC regulations. Due 12/31/16. ConocoPhillips takes regulatory compliance very seriously and has systems and personnel in place dedicated for that purpose and will take every care to prevent reoccurrence. Sincerely, Patrick Wolfe Manager North Slope Integrated Operations & Projects ConocoPhillips Alaska, Inc. PW:db y of 77 •• • �w��\I%%y , THE STATE Alaska Oil and Gas pf Conservation am}€ - - � : 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ® *'`' _ Main: 907.279.1433 ALAS Fax 907.276.7542 www.aogcc.alaska.gov June 14, 2016 Mr. Patrick Wolfe North Slope Integrated Operations and Project Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Subject: Docket Number: OTH-16-018 Notice of Violation Failure to Test KRU 1A-pad Dear Mr. Wolfe: The Alaska Oil and Gas Conservation Commission (AOGCC) witnessed safety valve systems (SVS) performance tests at Kuparuk River Unit (KRU) 1A-pad on June 2, 2016 and identified a failure rate of 13.6 percent (11 wells, 22 components, 3 failures). The AOGCC's SVS test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. A copy of the AOGCC-witnessed Safety Valve System Test Report is attached. Exacerbating this situation is ConocoPhillips Alaska Inc. (CPAI)'s inability to substantiate the required testing of the low pressure pilot on KRU 1 A-28 (PTD 1910020) after the device was replaced and the well placed back in service sometime between December 15, 2015 and March 13, 2016.1 The low pressure pilot failed its initial performance test on June 2, 2016 then passed the required test that same day after the device was replaced — both tests were witnessed by an AOGCC Inspector. Failure to performance-test the SVS device is a violation of AOGCC Well Safety Valve System regulations 20 AAC 25.265(b) and 25.265(h)(2). Not later than June 24, 2016, CPAI is requested to provide a copy of its investigative findings for this noncompliance, which should include: - A timeline from initiating event (reason for changing the low pressure pilot) through the passing test on June 2, 2016; - identification of the root cause for the missed SVS component test; and - a description of the process and verification steps that have been or will be implemented to prevent recurrence (i.e., ensure the required performance test is completed and documented after replacing a SVS component). 'June 6,2016 email from CPAI's NSK Fieldwide Operations Superintendent • Docket Number:OTH 16-018• June 14,2016 Page 2 of 2 Effective immediately and until an acceptable level of performance is achieved, the safety valve systems (SVS) associated with wells located on Kuparuk River Unit 1A-pad must be tested at intervals not exceeding 90 days (next test is due September 2016). When testing is scheduled, ConocoPhillips Alaska Inc. (CPAI) must notify the Alaska Oil and Gas Conservation Commission(AOGCC) at least 24 hours in advance for an opportunity to witness the SVS tests. The AOGCC reserves the right to pursue additional enforcement action in connection with the failure to test the low pressure pilot on KRU 1A-28. Should you have any questions regarding the contents of this letter or our decision to place Kuparuk River Unit 1A-pad wells on a 90 day safety valve system test interval,please contact Jim Regg at 907-793-1236. Sincerely, A Daniel T. Seamount, Jr Commissioner Attachment cc: P. Brooks AOGCC Inspectors NSK 69—Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • 'Regg, James B (DOA) From: NSK Fieldwide Operations Supt <n2072@conocophillips.com> Sent: Monday, June 06, 2016 11:24 AM 6i6( F(� To: Regg,James B (DOA) Subject: 1A-28 Low Pressure Pilot Missed Test (corrected) Attachments: SVS KRU 1A 06-02-16.xlsx Jim, Last week the DS1A pad at Kuparuk had a greater than 10%failure rate during the pad test. In our investigation of these failures to help with our program improvement,we discovered that the pilot for 1A-28 had been changed out sometime between December 15, 2015 and March 13, 2016, and had not been performance tested per AOGCCsesluirements. No record of a pilot change was found in our logs or our IP21 control system as is required by our internal policies and procedures. A correct entry into our IP21 system would have triggered a WeIITRAK alert to test the system within 5 days, but without such an entry, no alert was generated. Our SVS Testing crew was not notified by any other means to test the system for this well either. The SVS system for this well passed the required State test on June 2"d and was witnessed by Jeff Jones. See attached for the test summary form for the pad. ConocoPhillips takes this breach in our systems very seriously and will take steps to reinforce our internal policies and procedures, which include the proper data entry and notifications when wellhead SVS system components are repaired or replaced. We recognize the need and the requirement to performance test repaired/replaced SVS components within the required time frames and will strive to ensure that this does not happen again. Please call if you have any questions. Scott Fahrney/Larry Baker NSK Fieldwide Operations Superintendent (907) 659-7042 1 • 0 o a w x ›" X N O O 0 y cnaod Ci pU r. 01 v o rn CD 0o v, oo 4 .o 0, o cr. s .o � cn N 00 C r, & G+ d V t ••-17 C 00 A glo .O 'r .yam \ g a w N '14, ,4 il V �� C. q 0 4 (I ..a ¢ �.4 <<4<4 , ¢ Q ¢ d , d � � � . , ? � � CD 0 � 0303 � 330333303tA � 00 � 0 (7000 � 0 oC :? `n w ," �i, y C 01 M O N N N N 0 Q 4' 6. ---� N o N O --., CI a .0 0 0 0 0 0 0 0 O r 03 C6 ti V "' L 4 co i N d fy o •E o • Qv0, ` 4. ^C N N Co) a 4.2 70 (/,1 H V \ ❑ o O 7 .. M N N 6,• = 0 0 „.. cu o P. a v, P. P. P. P. a. P. P. a. 3 ,{',Hz E c7 F" U b -0 VI VI U• Ur) d am 0. -, V i c cci v, 6> N t nO O a. a. P. P. M P. P. P. P. P. M y C • . 0 •a v F U rt 04 m o C V'1 O N •�t 00 N 00 N O O. 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' STATE OF ALASKA ALIIIIA OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing p' Operations Shutdown r Performed: SuspendPerforate p r r Other Stimulate r Alter Casing 17 Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r' Other: Cement OA j✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 191-002 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22126-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25652,25647 KRU 1A-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10025 feet Plugs(measured) none true vertical 6499 feet Junk(measured) none Effective Depth measured 9916 feet Packer(measured) 9119,9246, 9416 true vertical 6435 feet (true vertical) 5982,6056,6152 Casing Length Size MD TVD Burst Collapse CONDUCTOR 40 16 80 80 SURFACE 5417 9.625 5452 3883 PRODUCTION 9971 7 10006 6488 OCT 12 2015 Perforation depth: Measured depth: 9330-9390, 9619-9633, 9649-9712 True Vertical Depth: 6104-6138,6266-6274,6283-6318 AO3CC V VVV Tubing(size,grade,MD,and TVD) 3.5", L-80, 9112' MD/5978 TVD and 3.5"x 2.875", L-80, 9204 MD/6030 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 9119 MD and 5982 TVD PACKER-BAKER HB RETRIEVABLE PACKER @ 9246 MD and 6056 TVD PACKER-TIW SS PERMANENT PACKER @ 9416 MD and 6152 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-359 Contact Diana Guzman @ 265-6318 Email Diana.Guzman(a conocophillips.com Printed Name Dia a Guzman Title Sr. Wells Engineer SignaturePhone:265-6318 Date a_ . ...} _ Is 1 utacu.-J/4„ /71., vn- 3/p/1 Form 10-404 Revised 5/2015 4 3%q0. )GRBDMS OCT 13 2015 Submit Original Only KUP PROD • 1A-28 ConocoPhillips it Well Attributes Max Angle&MD TD Ala$ea Inc Wellbore APl/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ...,,,,.4..." 500292212600 KUPARUK RIVER UNIT PROD 57.27 5,100.00 10,025.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-28,9/23/201545736 PM SSSV:NIPPLE Last WO: 8/10/2003 34.81 1/21/1991 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 9,749.0 9/19/2015 Rev Reason:Re-Set Plug.Set Catcher,GLV C/0 haggea 6/26/2013 HANGER',31.0 1 -oh `' ., It Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread . CONDUCTOR 16 15.060 39.7 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'WtlLen(I...Grade Top Thread SURFACE 9 5/8 8.921 35.0 5,452.3 3,882.4 36.00 J-55 'BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ✓✓A.CONDUCTOR;39.7-80.0Aa .xn.1✓'s TIE-BACK-WO 2015 7 6.276 35.0 2,071.7 1,869.5 26.00•L-80 Hydril 563 , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 2,068.5 10,005.5 6,487.8 26.00 J-55 BTC Tubing Strings Tub n9 Description (String Ma...I ID(in) (Top(ftKB)31 Set Depth(fL.f Set Depth(TVD)(...I Wt(Ib/ft) (Grade Top Connection TUBING-W02015 31/2 2.992 310 9,11211 5,978.3 9.30 L-80 EUE Brd Mod :,1 Completion Details fl) Nominal ID • Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.0 31.0 0.10 HANGER McEVOY GEN IV TUBING HANGER 2.950 TIE-BACK-WO 2915;35.0- • E; 9,099.4 5,971.0 54.53 LOCATOR BAKER GBH-22 LOCATOR SUB 2.980 2.071.7 9,100.3 5,971.5 54.53 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.900 Tubing Description I String Ma...l ID(in) I Top(ftKB) I Set Depth(ft...Set Depth(TVD)(...I We(Ib/ft) (Grade (Top Connection GAS LIFT;3,259.5 - TUBING-WO 2003 31/2 2.992 9,1053 9,207.31 6,033.1 9.30 L-80 EUE MOD al Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inti(3 Item Des Com (in) 1 9,105.3' 5,974.4 54.56 PBR BAKER 80-40 PBR 3.000 9,119.0 5,982.3 54.65 PACKER BAKER FHL PACKER 3.000 SURFACE;35.0-5,4S2.3-4 9.1942 6,025.6 55.11 NIPPLE CAMCO DS NIPPLE 2.812 9,201.3 6,029.7 55.15'OVERSHOT UNIQUE POORBOY OVERSHOT 3.750 Tubing Description String Ma...ID(in) Top(ftKB) -Set Depth(ft..f Set Depth(TVD)(...I Wt(Ib/ft) Grade Top Connection GAS LIFT;5,472.6 = TUBING-ORIGINAL 31/2 2.992 9,204.4 9,502.8 6,200.1 9.30 L-80 BTC-MOD 3.5 x2875" 11. Completion Details Nominal ID GAS LIFT;7,103.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) IIP9,232.7 6,047.7 55.04 PBR BAKER PBR w/10'STROKE 3.980 9,246.4' 6,055.5' 54.99 PACKER BAKER HB RETRIEVABLE PACKER 2.870 9,305.0 6,089.2' 54.86 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 GAS LIFT;8,303.9 GAS LIFT;9,014.2 9,402.8 6,144.7 56.04 SLEEVE-O CAMCO CB-1 SLIDING SLEEVE;OPENED 6/15/01 2.812 9,413.5- 6,150.6 56.10 SEAL ASSY TIW LOCATOR SEAL ASSEMBLY 3.011 9,416.5 6,152.3 56.12 PACKER TIW SS PERMANENT PACKER 4.000 9,420.2- 6,154.3 56.14 SBE TIW SEAL BORE EXTENSION 4.000 9,424.5 6,156.7 56.16'XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,#6.5,J-55,EUE- 2.875 MOD LOCATOR;9,099.4 i 9,490.3 6,193.2 56.51 NIPPLE 'CAMCO D NIPPLE NO GO 2.250 9,502.0 6,199.7 56.54 SOS ,BAKER SHEAR OUT SUB 2.441 SEAL ASSY;9,100.3 - PBR;9,105.3 Perforations&Slots PACKER;9,119.0 '' I Shot Dens Top(ND) Bim(TVD) (shots/f NIPPLE;9,194 2 'X' Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date t) Type Com 9,330.0 9,370.0 6,103.5 6,126.2 C-4,C-3,C-2, 6/5/1991 10.0 IPERF HLS 4.5"Casing Gun 1A-28 OVERSHOT;9,201.3 ;•' 9,370.0 9,390.0 6,126.2 6,137.5 C-2,C-1,1A- 6/5/1991 5.0 IPERF HLS 4.5"Casing Gun 28 PBR;9,232.7 9,619.0 9,633.0 6,265.3 6,273.2 A-5,1A-28 6/5/1991 4.0 IPERF HLS 4.5"Casing Gun PACKER;9,246.4 --' -- 9,649.0 9,712.0 6,282.3 6,318.0 A-4,1A-28 6/5/1991 4.0 IPERF HLS 4.5"Casing Gun Mandrel Inserts t III I. St PRODUCTION;9,2904 alt on Top(ND) Valve Latch Port Size TRO Run R N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 3,259.5 2,596.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,283.0 9117/2015 IPERF;9,330.0-9,370.0- 2 5,472.6 3,893.6 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,259.0 9/17/2015 (PERF;9,370.0-9,390.03 7,103.7 4,806.2 CAMCO MMG 11/2'GAS LIFT GLV RKP 0.188 1,261.0 9/16/2015 DCR1 4 4 8,303.9 5,506.0 CAMCO MMG 1 1/2,GAS LIFT OV RK 0.250 0.0 9/16/2015 5 9,014.2 5,921.4 CAMCO KBMG 1 GAS LIFT DMY 'BK 0.000 0.0 9/11/2015 SLEEVE-0;9,402.8 6 9,290.4 6,080.8 MERLA TGPDC 11/2 PROD DMY RK 0.000 0.0 6/14/1996 Close d SEAL ASSY;9413.5 sr" Notes:General&Safety End Date Annotation PACKER;9,416.5 12/2/2010 NOTE:View Schematic w/Alaska Schernatio9.0 SBE;9,420.2 Ti NIPPLE;9,490.3 I. SOS;9,502.0 IPERF;9,619.0-9,633.0 IPERF;9,649.0-9,712.0- er I PRODUCTION;2,068.5- r 10,005.5 Time Log & Summary ConocoF'hillips WeMview Web Reporting Report Well Name: 1A-28 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 8/26/2015 4:00:00 PM Rig Release: 9/12/2015 5:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/26/2015 24 hr Summary Release rig from 1A-02 at 05:00 hrs 8/26/2015. Move pits and sub structure to 1A-28 and rig up. Accpet rig at 16:00 hours 8/26/2015. Rig up lines and lubricator. Pull BPV. Test lines prior to displacing well. 05:00 12:00 7.00 0 0 MIRU MOVE MOB P Move rig off of well 1A-02 and move to 1A-28. Pre cellar, set rig mats, lay herculte and hang tree in cellar. Spot rig over well and position rig mats under beams 12:00 12:30 0.50 0 0 MIRU MOVE SFTY P Pre-job safety meeting on spotting mud pits against substructure with truckers. 12:30 13:30 1.00 0 0 MIRU MOVE RURD P Spot pits next to substructure. Set mats. Lay herculite. Check connections 13:30 16:00 2.50 0 0 MIRU MOVE RURD P Rig up berms around cellar and pits. Set mats for cuttings tank and LEPD tank. Lay herculite and build berms around tanks. Work on rig up checklist. Bring on 590 bbl seawater to the pits. Remove A-leg brace. Accept rig at 16:00 hours 8/26/2015 16:00 19:30 3.50 0 0 MIRU WELCTL RURD P Rig up second kill line to circulating manifold. M/U flange on wing blalve. Install working valve on IA. R/U hoses to kill well with seawater. Rig up hardline to open top tank. Bled 40 psi on OA to bleed trailer. Pickup lubricator and wellhead equipment 19:30 20:00 0.50 0 0 MIRU WELCTL SFTY P Pre-job safety meetin on pulling BPV 20:00 23:00 3.00 0 0 MIRU WELCTL MPSP P Pickup lubricator and rig up hydraulic lines. Attempt to make up lubricator on tree. Pull tree over with come-alongs and make up lubricator. Pull BPV. Tubing pressure=900 psi, Casing pressure= 1100 psi. 23:00 23:15 0.25 0 0 MIRU WELCTL SFTY P Pre-job safety meeting on pressure testing lines. 23:15 00:00 0.75 0 0 MIRU WELCTL SEQP P Pressure test lines to 500 psi/3000 psi 38/27/2015 Displace well with 320 bbl seawater. Circulate bottoms up through gas buster. Set BPV. Nipple down Xmas tree and nipple up BOPE. Test BOPE to 500/3000 psi. Bob Noble,AOGCC inspector,waived witnessing the test. Pulled BPV and made up landing joint to tubing hanger. Backed out locking screws and pulled tubing hanger to the rig floor. Circulated 320 bbl seawater. Blew down top drive and prepare to lay down tubing. Page 1 of 23 • Time Logs • • Date From 'To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 MIRU WELCTL KLWL P Bleed pressure off tubing and IA. Circulate 320 bbl seawater down tubing taking returns out IA. ICP= 220 psi, FCP=278 psi. SI well and tubing pressure build to 30 psi and IA pressure built to 25 psi. 03:00 04:00 1.00 0 0 MIRU WELCTL RURD ' P Rig up to circulate through 2nd choke through gasbuster 04:00 05:30 1.50 0 0 MIRU WELCTL KLWL P CBU through gasbuster at 3 bpm. ICP=311 psi. FCP=294 psi. 05:30 06:30 1.00 0 0 MIRU WELCTL OWFF P Rig down line from tree and observe well for flow 06:30 07:15 0.75 0 0 MIRU WELCTL RURD P Continue rigging down lines and prepping cellar. Pick up T-bar and BPV w/test dart 07:15 08:15 1.00 0 0 MIRU WHDBO MPSP P Set BPV w/test dart. Test from below to 500 psi. Close IA 08:15 10:30 2.25 0 0 MIRU WHDBO NUND P Nipple down Xmas tree and tubing head adapter 10:30 12:00 1.50 0 0 MIRU WHDBO NUND P Remove bolts from tubing head. Clean wellhead and hanger threads. Function LDS. Inspect hanger and tubing head 12:00 12:15 0.25 0 0 MIRU WHDBO SFTY P Safety meeting on nippling up BOPE 12:15 15:00 2.75 0 0 MIRU WHDBO NUND P Nipple up BOPE. Make up 11"-5M x 13-3/8"-5M DSA. Set stack on DSA. Torque up studs and nuts. Install turnbuckles. Install riser and air up boots. Straighten stack with turnbuckles. Calibrate and test gas alarms 15:00 15:30 0.50 0 0 MIRU WHDBO BOPE P Perform body test on BOPE to check all flanges-good test 15:30 20:00 4.50 0 0 MIRU WHDBO BOPE P Test all BOPE components to 250/3000 psi. Test annular, upper pipe rams with 3-1/2"and 4"test joints. Bob Noble,AOGCC,waived witnessing BOPE test 20:00 20:30 0.50 0 0 MIRU WHDBO RURD P Blow down choke/kill lines and choke manifold. R/U casing tongs. Install mouse hole. L/D test joint. 20:30 21:00 0.50 0 0 COMPZ RPCOM MPSP P Pull BPV w/test dart 21:00 21:30 0.50 0 0 COMPZ RPCOM PULL P Make landing joint into tubing hanger. Make up top drive. Set down 10 kips. BOLDS. Pull tubing hanger to the rig floor. Max pull 175 kips. P/U = 103 kips 21:30 00:00 2.50 0 0 COMPZ RPCOM CIRC P Circulate surface to surface. @ 7 bpm. Concurrent operation-prep floor for laying down tubing. Pick up tubing tongs. Monitor well for 10 minutes. Circulate additional 1500 strokes. SPR w/pump#1 @ 2 bpm =30 psi, @ 3bpm =90 psi w/pump #2@2bpm=20 psi @3bpm =80 psi. Lay down hanger and blow down top drive Page 2 of 23 9 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08/28/2015 24 hr Summary POOH and lay down 3-1/2"completion string. Rig up digital slickline and Dutch riser. Make up 6.151"gauge ring,junk basket and wire brush and RIH to 9060'WLM. POOH. Make up gauge ring and SCMT and RIH to 1000' POOH to check tool memory. Reprogram tool. RIH with gauge ring and SCMT to 5550'WLM and POOH logging to determine TOC. 00:00 07:15 7.25 9,169 1,717 COMPZ RPCOM PULL P POOH laying down 3-1/2 L-80 EUE 8rd TBG from 9,169-ft to 6371'80K Up Wt 62k Dn wt to seal assembly 07:15 07:30 0.25 1,717 1,717 COMPZ RPCOM WAIT T Wait on parts to repair 3-1/2"tubing elevators supplied by casing crew 07:30 09:30 2.00 1,717 0 COMPZ RPCOM PULL P POOH laying down 3-1/2 L-80 EUE 8rd TBG from 1717'to seal assembly 50K Up Wt 48k Dn wt 09:30 10:30 1.00 0 0 COMPZ RPCOM RURD P Rig down tubing equipment. Drain stack and clear rig floor 10:30 11:15 0.75 0 0 PROD1 WELLPF SLKL P Rig up Dutch riser 11:15 15:00 3.75 0 0 PROD1 WELLPF SLKL P Rig up digital slickline and tools. Test Dutch riser to 1000 psi 15:00 18:00 3.00 0 0 PROD1 WELLPF SLKL P RIH with junk basket,wire brush and 6.120"gauge ring on digital slickline to 9060'WLM. POOH 18:00 19:00 1.00 0 0 PROD1 WELLPF SLKL P Rig up 6.120"gauge ring and SCMT 19:00 19:30 0.50 0 0 PROD1 WELLPF SLKL P RIH with gauge ring and SCMT to 1000'. POOH to check memory 19:30 22:30 3.00 0 0 PROD1 WELLPF SLKL T Reprogram SCMT tools 22:30 23:00 0.50 0 5,550 PROD1 WELLPF SLKL P RIH with SCMT and gauge ring to 5550' 23:00 00:00 1.00 5,550 0 PROD1 WELLPF SLKL P POOH recording with SCMT on digital slickline from 5550'to 4470' 08/29/2015 Run SCMT on digital slickline from 4470'to surface. TOC @ 2134'. Left centralizer arm from SCMT in hole. Run gauge ring and junk basket to 9105'and POOH. RIH with 3-1/2"gauge ring and spear to catcher sub at 9190'and latch catcher sub. POOH and recovered 7 small pieces of metal. RIH with catcher sub and attempt to set at 9172'without success. POOH and redress setting tool. RIH and set catcher sub at 9172'. Make up 6.12"gauge ring and junk basket and RIH to 3000'. POOH with no recovery. Make up Baker 47BS 7"26-29#WSRBP and RIH. Set WSRBP @ 2650'SLM. POOH. Make up tandem dump bailer and RIH. Dump one sack of sand on top of WSRBP. POOH. Make up 7"chemical cutter and RIH. Correlate 00:00 03:00 3.00 0 0 PROD1 WELLPF SLKL P Continue to POOH recording with SCMT on digital slickline from 4,470 to surface. Field Estimate on TOC is 2,134-ft Lost.25 x.25 x10 inch centralizer arm and wheel from centralizer. 03:00 08:00 5.00 0 0 PROD1 WELLPF SLKL T RU and RIH w/6.12"Gauge ring/ Junk Basket from surface to 9,105-ft (Top of PBR). POOH and recovered nothing. 08:00 10:15 2.25 0 0 PROD1 WELLPF SLKL T MU and RIH w/2.71 GS spear to RIH and recover 2.71"x 10-ft Junk catcher to 9,190-ft, engage and POOH. Recovered 7 dime size Pcs of metal-shear pin remnants from PBR. Page 3 of 23 Time Logs • • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 14:30 4.25 0 0 PROD1 WELLPF SLKL T Re pin running tool and RIH w/3.5" GS w/10'-2.71"Catcher sub(125" Catcher sub)Set Catcher @ 9172' SLM, POOH. Didn't shear off and leave catcher sub. Re-pin lighter and RIH w/3.5"GS w/10'-2.71"Catcher sub(125"Catcher sub)Set Catcher @ 9172' SLM, POOH. Catcher sub in place. 14:30 15:00 0.50 0 0 PROD1 WELLPF SLKL T Make up and RIH w/6.12"Gauge ring/Junk Basket from surface to 3,000-ft(500-ft past setting depth of WRP). POOH and recovered nothing. 15:00 18:00 3.00 0 0 PROD1 WELLPF SLKL P PU, MU and RIH w/Baker 4762 7" 26-29# (WSRBP)to 2,650-ft WLM. POOH 18:00 19:30 1.50 0 0 PROD1 WELLPF SLKL P Lay down RBP setting tool and make up dump bailer. Fill bailer with 1 bag of sand. 19:30 20:30 1.00 0 0 PROD1 WELLPF SLKL P RIH and with tandem dump bailer and dump sand on top of RBP at 2650' 20:30 21:00 0.50 0 0 PROD1 WELLPF SLKL P POOH with tandem dump bailer and lay down. 21:00 23:00 2.00 0 0 PROD1 CSGRC'SLKL P Pick up 7"chemical cutter and test 23:00 00:00 1.00 0 0 PROD1 CSGRC'SLKL P RIH with 7"chemical cutter. Correlate 08/30/2015 Run in the hole with chemical cutter. Cut 7"casing at 2-76'WLM from SCMT run on 8/28/2015. POOH. Circulate 10 bbl seawater through cut at 1 bpm @ 300 psi. Rig down digital slickline and Dutch riser. RIH with 4"drillpipe to 2572'. Close pipe rams and displace OA with 260 bbl hot seawater(145 F). Dump 16 sacks of sand on top of RBP @ 2650'. Wait for sand to fall and tag top of sand at 2598'. POOH. Test lower pipe rams and annular with 7"test joint to 250 psi/3000 psi. Nipple down BOPE and rig up Hydratight. 00:00 03:00 3.00 0 0 PROD1 CSGRC'SLKL P Continue to RIH with 7"chemical cutter. Correlate @ 2,076-ft and cut casing-POOH and close Blind rams 03:00 03:30 0.50 0 0 PROD1 CSGRC'CIRC P Circulate thru cut @ 2,076-ft at 1 bpm @ 300 psi for 10 bbls.taking returns to Open top tank. 03:30 05:15 1.75 0 0 PROD1 CSGRC'SLKL P RD Digital Slick line unit and Dutch riser. 05:15 05:30 0.25 0 0 PROD1 CSGRC'RURD P RU to RIH w/4"Drill pipe 05:30 08:30 3.00 0 2,572 PROD1 CSGRC'PULD P P/U 4" 15.7#DP to 2,572-ft, Up wt- 75k, Dn wt-62k. 08:30 12:00 3.50 2,572 2,572 PROD1 CSGRC'CIRC P Circulate 280 bbls of 145° Fresh water thru cut to open top tank at 1.5 bpm 460 psi to 2 bpm @ 780 psi. recovered 260 bbls at the tank. Blow down lines and re connect OA to cuttings box. 12:00 17:00 5.00 2,572 2,572 PROD1 CSGRC'OTHR P Dump 16 sacks of sand in drillpipe. 17:00 17:30 0.50 2,572 2,572 PROD1 CSGRC'WAIT P Wait on sand to settle. 17:30 18:30 1.00 2,572 0 PROD1 CSGRC'TRIP P Pick up single and tag sand at 2598'. POOH racking drillpipe in derrick Page4of23 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:30 1.00 0 0 PROD1 CSGRC'BOPE P `Make up 7"test joint and set test plug. 19:30 20:30 1.00 0 0 PROD1 CSGRC'BOPE P Test annular and lower pipe rams with 7"test joint to 250/3000 psi. 20:30 22:00 1.50 0 0 PROD1 CSGRC'BOPE P Perform annular accumulator test with Axon 22:00 23:30 1.50 0 0 PROD1 CSGRC'NUND P Nipple down BOP stack and set on stump. Pull mousehole and flow riser 23:30 00:00 0.50 0 0 PROD1 CSGRC'RURD P Rig up Hydratight 08/31/2015 Grow casing 21"with hydratight system. Remove tubing head. Spear casing and pull slips. Release spear. Nipple up BOPE. Spear casing and pull casing free with 200 kips. Circulate 80 bbl water taking returns from OA to tiger tank. Release spear and lay down. POOH laying dow 49 joints of 7"casing. Clear rig floor 00:00 03:45 3.75 0 0 PROD1 CSGRC'NUND P Rig up hydratight equipment and release tubing head. Casing grew 21". Maximum(load on hydratight jacks=300 kips 03:45 04:15 0.50 0 0 PROD1 CSGRC'NUND P Pull packoff and attempt to pull casing slips 04:15 05:00 0.75 0 0 PROD1 CSGRC'BHAH P Make up 7"spear 05:00 05:30 0.50 0 0 PROD1 CSGRC'NUND P Engage top of 7"casing and pull 100kips. Pull slips. Slack off and release spear 05:30 09:00 3.50 0 0 PROD1 CSGRC'NUND P Clear cellar of tree and tubing spool 09:00 10:00 1.00 0 0 PROD1 CSGRC'NUND P Nipple up DSA and Spacer spool 10:00 15:00 5.00 0 0 PROD1 CSGRC'NUND P Nipple up BOPE. Confirm elevations. Make up flanges 15:00 15:30 0.50 0 0 PROD1 CSGRC'FISH P Spear casing and fill hole. Check for leaks 15:30 16:00 0.50 0 0 PROD1 CSGRC'CIRC P Ciriculate at 2 bpm, 35 spm, 420 psi taking returns to pits. Pull casing free with 200 kips indicated. 16:00 17:00 1.00 0 0 PROD1 CSGRC'CIRC P Ciriculate 80 bbl at 5 bpm, 87 spm, 258 psi. Work pipe 5'. P/U =205 kips, S/O=50 kips. Monitor well for 10 minutes.Total losses= 12 bbl 17:00 18:00 1.00 2,076 2,050 PROD1 CSGRC'PULL P Pull casing to the floor and release spear. Lay down spear 18:00 23:00 5.00 2,050 0 PROD1 CSGRC'PULL P Rig up elevators and lay down 49 joints of 7"casing. Tight spots @ 1950', 1859', 1735', 1534', 1319', 908', 745', 542', Top cut-off joint= 35.47'. Bottom cut joint=32.44'of 42.88-ft= 10.44-ft stub of original tally jt#186. Recovered 9 centralizers 23:00 00:00 1.00 0 0 PROD1 CSGRC'RURD P Rig down casing tongs and clear floor. Swap elevators 09/01/2015 Shell test the BOP stack and found spacer spool flange leaking. ND, change out API ring, NU Flange. Pressure test flange breaks to 250/3000 psi(good test). RIH with 7"dress off assembly could not get past 123' RKB, TOOH,and lay down dress off assembly. RIH with 8-3/4"string mill and work tight spots at 111', 123', 335'-341', and 360' RKB then continue down to tag on casing stub at 2068' RKB. Attempt to run dress off assembly but unable to get past 335' RKB. RIH with tandem string mill assembly(8-1/2"x 8-3/4")and work tight spots at 111', 123', and 335'-349' RKB. Page 5 of 23 Time Logs 411• Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 0 0 PROD1 CSGRC'BOPE P RU on fresh water and set 11" McEvoy Test plug test flange break for Post break of TBG Spool and Slip removal. 01:00 02:00 1.00 0 0 PROD1 CSGRC'BOPE T Shell test and found spacer spool flange leaking. 02:00 03:45 1.75 0 0 PROD1 CSGRC'BOPE T ND and change out API ring, NU Flange. Fill stack and observe for leaks. 03:45 04:45 1.00 0 0 PROD1 CSGRC'BOPE P Close Blind rams and pressure test flange breaks at 250/3,000 psi. - Good test 04:45 05:00 0.25 0 0 PROD1 CSGRC'BOPE P RD testing equipment and blow down lines. 05:00 05:30 0.50 0 0 PROD1 CSGRC'RURD P PJSM. PU wear ring running tool, install wear ring, and lay down wear ring running tool. 05:30 07:00 1.50 0 0 PROD1 CSGRC'BHAH P PU and MU BHA#2- 7"dress off assembly with 8-3/4"string mill. PU 1 stand of DP and could not get past 123'. Lay down BHA#2. 07:00 07:15 0.25 0 30 PROD1 CSGRC'BHAH T PU and MU BHA#3-Cleanout assembly with 8-3/4"string mill. 07:15 11:30 4.25 30 410 PROD1 CSGRC'REAM T TIH and at 111' RKB with 3K down. Establish parameters: PU=40K, SO=38K, Rotating weight=38K, 60 RPM, Free torque=500 ft-lbs, 5 BPM=50 psi. Ream from 105'to 125'with 500-3000 ft-lbs of torque. Back ream up to 100', SO, and slide through area with 5K down. Work tights spots at 111', 123', 335'-341', and 360' RKB. 11:30 14:00 2.50 410 2,068 PROD1 CSGRC'TRIP T Blow down TD and TIH from 410'to 2028'. Tag casing stub at 2068'with 5K down. 14:00 15:30 1.50 2,068 30 PROD1 CSGRC'TRIP T TOOH with BHA#3 15:30 16:00 0.50 30 0 PROD1 CSGRC'BHAH T Lay down BHA#3-Cleanout assembly with 8-3/4"string mill. 16:00 16:30 0.50 0 38 PROD1 CSGRC'BHAH T PU and MU BHA#4-7"Dress Off Assembly with 8-3/4"string mill 16:30 17:00 0.50 38 116 PROD1 CSGRC'TRIP T TIH to 108'and tag with 3K. Work through tight spot to 116'and set down 15K but unable to work past. 17:00 17:30 0.50 116 38 PROD1 CSGRC'TRIP T TOOH with BHA#4. 17:30 18:00 0.50 38 0 PROD1 CSGRC'BHAH T Lay down BHA#4-7"Dress Off Assembly with 8-3/4"string mill. 18:00 18:15 0.25 0 31 PROD1 CSGRC'BHAH T PU and MU BHA#5-7"Dress Off Assembly. 18:15 19:00 0.75 31 335 PROD1 CSGRC'TRIP T TIH with BHA#5 and work down through tight spot with slight rotation and 3-5K down but unable to get past 335'RKB. 19:00 19:30 0.50 335 31 PROD1 CSGRC'TRIP T TOOH with BHA#5. Page 6 of 23 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 31 0 PROD1 CSGRC'BHAH T Lay down BHA#5-7"Dress Off Assembly. Clean and clear the rig floor. 20:00 21:00 1.00 0 45 PROD1 CSGRC'BHAH T Bring string mill to the rig floor. PU and MU BHA#6-Tandem String Mills with flex joint(8-1/2"x 8-3/4"). 21:00 00:00 3.00 45 349 PROD1 CSGRC'REAM T Establish parameters: PU=40K, SO=40K, Rotating weight=40K, 60 RPM, Free torque=600 ft-lbs, 8 BPM= 100 psi. Ream from 118'to 138'RKB with 2500 ft-lbs of torque. Work area four until able to slide through with minimal rotation. Continue to 337'tag with 3K down and work tight spot to 349'. 09/02/2015 Ream tight spots from 320'to 425' RKB,TOOH, and lay down tandem string mill with flex joint. PU, MU, TIH with tandem string mills without flex joint and ream tight spots from 111'to 425' RKB. TOOH and lay down tandem string mill assembly. PU/MU 7"dress off assembly, repair top drive handler, and TIH to top of 7" casing stub at 2068' RKB. Dress off 6"of 7"casing, pump 20 bbl of hi-visc sweep,TOOH, and lay down dress off assembly. PU, MU, and TIH with cleanout assembly to 2101' RKB. Pump a bottoms up,TOOH, and lay down cleanout assembly(recovered 10 lbs of metal debris). 00:00 00:30 0.50 349 425 PROD1 CSGRC'REAM T PU from 349'to 320'and ream from 425' RKB with 1000-2500 ft-lbs of torque. PU=44K, SO=44K, Rotating weight=43K, 60 RPM, 5 BPM=38 psi. 00:30 01:00 0.50 425 45 PROD1 CSGRC'TRIP T TOOH with BHA#6-Tandem String Mills with flex joint(8-1/2"x 8-3/4"). 01:00 01:15 0.25 45 0 PROD1 CSGRC'BHAH T Lay down BHA#6. Mills sting in gauge. 01:15 01:30 0.25 0 36 PROD1 CSGRC'BHAH T PU and MU BHA#7-Tandem String Mills(8-1/2"x 8-3/4"). 01:30 04:45 3.25 36 425 PROD1 CSGRC'REAM T Ream tight spots from 111'to 425' RKB at 5 BPM =35 psi, 80 RPM with 2-3K ft-lbs torque. 04:45 06:00 1.25 425 36 PROD1 CSGRC'REAM T POOH reaming tight spots from 425' to 111' RKB. Parameters: 5 bpm @ 35 psi, RPM's=80 w/2-3k torque 44K up wt, 44K do wt and 44K ROT wt 06:00 06:15 0.25 36 0 PROD1 CSGRC'BHAH T Lay down BHA#7-Tandem String Mills(8-1/2"x 8-3/4"). 06:15 06:30 0.25 0 226 PROD1 CSGRC'BHAH T PU, MU and TIH w/BHA#8-8-3/8" Dress off assembly to 226-ft then top drive handler failed 06:30 07:00 0.50 226 226 PROD1 CSGRC'SVRG T Inspect pipe handler to determine failure. Recorded in the IADC as.5 hrs service time. 07:00 10:00 3.00 226 226 PROD1 CSGRC'RGRP T Remove pin and cylinder from pipe handler and inspect threads, replace handler pin re-install. Recorded in IADC as code 8. 10:00 12:00 2.00 226 2,030 PROD1 CSGRC'TRIP T Continue to trip in the hole working thru tight spots from 226-ft to 2,030-ft. Up wt=67K, Dn wt=60K Page 7 of 23 Time Logs . • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 2,030 2,067 PROD1 CSGRC'MILL P Obtain Parameters: 7.5 bpm =300 psi,WOM=7K, 60 RPM, 5-7K torque, Up wt=66, Dn wt=62K and ROT wt=65K. Wash over 7"casing stub at 2068' RKB and dress off 7" casing stub 6"at 50-60 RPM with 3-4K torque. 14:00 15:00 1.00 2,067 2,067 PROD1 CSGRC'CIRC P Pump a 20 bbl hi-visc sweep at 8 BPM(circulated two bottoms up) 15:00 16:30 1.50 2,067 226 PROD1 CSGRC'TRIP P TOOH with BHA#8. 16:30 18:00 1.50 226 0 PROD1 CSGRC'BHAH P Lay down BHA#8 18:00 19:30 1.50 0 0 PROD1 CSGRC'BHAH P Clean and clear the floor of all fishing tools and PU string magnet. 19:30 20:00 0.50 0 30 PROD1 CSGRC'BHAH P PU and MU BHA#9-Cleanout assembly with string magnet. 20:00 21:00 1.00 30 2,101 PROD1 CSGRC'TRIP P TIH with BHA#9 to 2101' RKB with the mule shoe(string magnet at 2066' RKB). PU=60K, SO=58K, Rotating weight=60K. 21:00 21:30 0.50 2,101 2,066 PROD1 CSGRC'CIRC P PU to 2066' RKB and circulate bottoms up at 8 BPM =255 psi 21:30 22:30 1.00 2,066 30 PROD1 CSGRC'TRIP P TOOH with BHA#9 22:30 23:30 1.00 30 0 PROD1 CSGRC'BHAH P Lay down BHA#9(recovered 10 lbs of metal debris). Clean and clear the floor. 23:30 00:00 0.50 0 0 PROD1 CSGRC'RURD P MU wear ring pulling tool, pull the wear ring, and lay down wear ring pulling tool. 09/03/2015 PU and MU casing patch and HMCV assembly. RIH with 7",26#, L-80, Hydril 563 casing to 338' RKB using the top drive to assist in the hole due to tight spots in the 9-5/8"surface casing. On joint#7 a sheared cap screw was found on the rig floor that was determined to have come off the top drive gripper box die block. Replace gripper box die block and replace HT-40 quill. Tested the new HT-40 quill to 250/3000 psi. Continue to RIH with 3 joints of casing using top drive to assist in the hole due to tight spots in 9-5/8"surface casing to 462' RKB. Continue to RIH from 462'to 2020' RKB on elevators and tagged fill. Wash down to casing stub at 2068' RKB and attempted to engage casing patch but were unsuccessful. POOH laying down 7"casing. Lay down HMCV and casing patch. 00:00 02:00 2.00 0 0 PROD1 CASINGWWWWH P PJSM. MU BOP stack washing tool with string magnet and wash out the BOP stack. Clean off magnet, lay down BOP stack washing tool, and lay down magnet. Blow down the top drive. 02:00 02:30 0.50 0 0 PROD1 CASING RURD P RU Weatherford power tong and 7" casing elevators. Bring centralizers to the rig floor. 02:30 02:45 0.25 0 0 PROD1 CASING SFTY P PJSM on running 7"casing. Page 8 of 23 4111 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 05:30 2.75 0 338 PROD1 CASING PUTB P PU and MU casing patch and HMCV assembly and RIH with 7", 26#, L-80, Hydril 563 casing to 338' RKB using the top drive to assist in the hole due to tight spots in the 9-5/8"surface casing. On joint#7 a sheared cap screw was found on the rig floor that was determined to have come off the top drive. 05:30 05:45 0.25 338 338 PROD1 CASING SFTY T Drops inspection on the top drive, found the Dutchman was from the die block on the gripper box. 05:45 06:15 0.50 338 338 PROD1 CASING SVRG T Inspect the top drive die block for the gripper box and found that the HT-40 quill was damaged. 06:15 08:45 2.50 338 338 PROD1 CASING RGRP T Replace gripper box die block and replace HT-40 quill. Tested the new HT-40 quill to 250/3000 psi. 08:45 09:15 0.50 338 462 PROD1 CASING PUTB P Continue to RIH with 3 joints of casing using top drive to assist in the hole do to tight spots in 9-5/8" surface casing to 462' RKB. 09:15 13:00 3.75 462 2,020 PROD1 CASING PUTB P Change over to 7"casing elevators and continue to RIH from 462'to 2020' RKB on elevators and tagged fill. 13:00 13:30 0.50 2,020 2,054 PROD1 CASING WASH P MU the top drive, stage the pumps up to 5 BPM=45 psi, and wash down to 2054' RKB(PU=90K, SO= 70K). 13:30 14:30 1.00 2,054 2,054 PROD1 CASING CIRC P Circulate bottoms up at 8 BPM = 106 psi. 14:30 15:30 1.00 2,054 2,065 PROD1 CASING PUTB P Continue to RIH with 7"casing to 2065' RKB. 15:30 17:00 1.50 2,065 2,065 PROD1 CASING CIRC P Make a hi-visc pill and spot it on the back side of the 7"casing. 17:00 17:30 0.50 2,065 2,068 PROD1 CASING PUTB P Work the 7"casing down to 2068' RKB pumping at 0.5 BPM and rotating at 10 RPM. Made several attempts to get over the casing stub but were unsuccessful. 17:30 18:00 0.50 2,068 2,068 PROD1 CASING SFTY T PJSM on laying down 7"casing. 18:00 19:30 1.50 2,068 1,868 PROD1 CASING PULL T Change elevator to 7"casing and POOH laying down 7"casing to 1868' RKB. Well is swabbing due to hi-visc pill on the backside of the 7" casing. 19:30 20:00 0.50 1,868 1,868 PROD1 CASING CIRC T Circulate a bottoms up to remove the pill from the hole at 5 BPM =30 psi. 20:00 00:00 4.00 1,868 0 PROD1 CASING PULL T Continue POOH laying down 7" casing. Lay down HMCV and casing patch. Clean and clear the floor. Page 9 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/04/2015 24 hr Summary Conduct weekly BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's(upper pipe rams)with 3-1/2"and 4"test joint;test 7"solid body rams(lower pipe rams)with 7"test joint; test annular to 250/3000 with 3-1/2",4", and 7"test joints; conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 9/3/15 at 07:15 hours and an extension to the BOPE test time was granted by AOGCC Victoria Loepp via email on 9/3/15 at 11:05 hours. PU, MU, and TIH with cleanout assembly to 2039' RKB. Slip and cut 91'of drilling line(14 wraps). 00:00 02:00 2.00 0 0 PROD1 WHDBO RURD P RU BOPE testing equipment. RU 3-1/2"test joint,4" HT-40 TIW, and Dart Valve. Install the test plug. Line up the choke, purge the lines, fill the stack with fresh water, grease the chokes, and grease the HCRs. 02:00 03:45 1.75 0 0 PROD1 WHDBO RURD P Attempt to shell test BOP stack, leaking grease fitting on the choke, fix, and still leaking. Trouble shoot and determine the test plug is leaking. 03:45 04:30 0.75 0 0 PROD1 WHDBO RURD T Pull the test plug, redress the test plug, and install the test plug. Fill the stack with fresh water and purge the lines. Shell test the BOP stack (good test). Page 10 of 23 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 13:30 9.00 0 0 PROD1 WHDBO BOPE P Conduct weekly BOPE test to 250/3000 psi: test 2-7/8"x 5"VBR's (upper pipe rams)with 3-1/2"and 4" test joint;test 7"solid body rams (lower pipe rams)with 7"test joint; test annular to 250/3000 with 3-1/2", 4", and 7"test joints; conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 9/3/15 at 07:15 hours and an extension to the BOPE test time was granted by AOGCC Victoria Loepp via email on 9/3/15 at 11:05 hours. Tests: #1) Blinds, Kill Demco, Chokes 1, 2, 3, & 16(Passed) #2) HCR Kill, Chokes 4,5, &6 (Passed) #3)Manual Kill, Chokes 7, 8, &9 (Passed) #4)Manual Choke, Hydraulic Choke, Blinds(Passed) #5)Blinds, Chokes 12, 13, & 14 (Passed) #6)Blinds, Chokes 10& 11 (Passed) #7)Annular with 3-1/2"test joint, 3-1/2" EUE TIW, HCR Kill, Choke 15 (Passed) #8)Annular with 3-1/2"test joint, Dart Valve, HCR Kill (Passed) #9) Upper Pipe rams with 3-1/2"test joint, Manual Choke(Passed) #10)Annular with 7"test joint, 4" HT-40 TIW(Passed) #11) Lower Pipe rams with 7"test joint(Passed) #12)Annular with 4"test joint, HCR Kill, Upper IBOP, Outer Test Spool (Passed) #13)Upper Pipe rams with 3-1/2" test joint, HCR Kill, LWCV, Inner Test Spool(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2900 psi Accumulator Pressure After Closer= 1750 psi Pressure Gain of 200 psi =33 seconds Full System= 130 Seconds Average N2(6 Bottles)=2033 psi Page 11 of 23 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 0 0 PROD1 WHDBO RURD P RD BOP Test equipment, Install wear ring, RILDS, along with clear and clean rig floor. 14:30 17:30 3.00 0 40 PROD1 CASING BHAH T Bring cleanout tools to the rig floor. PU and MU BHA#10-inner and outer cleanout assembly. 17:30 19:00 1.50 40 335 PROD1 CASING TRIP T TIH working past tight spots from 111'to hard tag at 335' RKB. 19:00 20:00 1.00 335 441 PROD1 CASING PULD T Lay down stand#4, PU a single joint of DP,work past tight spot rotating at 10 RMP with 15K down, and PU remaining 2 singles from the pipe shed to rebuild stand#4. 20:00 21:00 1.00 441 2,039 PROD1 CASING TRIP T Continue to TIH on elevators from 441'to 2039' RKB. 21:00 23:00 2.00 2,039 2,039 PROD1 CASING SLPC P PJSM. Slip and cut 91'of drilling line (14 wraps). 23:00 23:30 0.50 2,039 2,039 PROD1 CASING SVRG P Servie the top drive and draw works. 23:30 00:00 0.50 2,039 2,039 PROD1 CASING RURD T PJSM. RU blower hose to the top drive. 39/05/2015 Continue to TIH with cleanout assembly to top of casing stub at 2068.5' RKB. Wash/mill over casing stub down to 2072' RKB,weight dropped off, and wash down to 2077.5'. Back ream off 7"casing,shut down rotary/pumps, and slide over 7"casing to 2077.5' RKB. Circulate the well over to hi-visc seawater and TOOH while pumping each stand to avoid swabbing. RIH with casing patch/HMCV working past tight spot to 502' RKB and continue RIH to 2067' RKB on elevators. Pump a casing volume to clear the 7"casing of the hi-visc seawater. Engage the casing patch onto the 7"casing stub and PT to 500 psi for 5 minutes(good test). Break the bolts on the BOPE stack, lift the stack, and install the 7"casing slips. 00:00 00:15 0.25 2,039 2,069 PROD1 CASING TRIP T Continue to TIH with BHA#10-inner and outer cleanout assembly to top of casing stub at 2068.5' RKB. PU = 68K, SO=62K, rotating weight= 65K, 30 RPM,torque= 1200 ft-lbs, 5 BPM= 100 psi 00:15 02:00 1.75 2,069 2,078 PROD1 CASING WASH T Wash over casing stub at 30 RPM, 5 BPM = 100 psi unable to slide over stub. Wash/mill over 7"casing from 2069'to 2072' RKB at 30-60 RPM, torque 1200-6000 ft-lbs, 5 BPM, and 2-7K down. Weight dropped off at 2072' RKB shut down rotary and wash down to 2077.5' RKB. Back ream off 7"casing, shut down rotary/pumps, and slide over casing down to 2077.5' RKB with 2-3K drag. 02:00 02:30 0.50 2,076 2,076 PROD1 CASING CIRC T PU 2'and circulate at bottoms up at 5 BPM= 137 psi. 02:30 03:00 0.50 2,076 2,076 PROD1 CASING CIRC T Circulate the well over to hi-visc seawater at 5 BPM =230 psi. 03:00 08:30 5.50 2,076 40 PROD1 CASING PMPO T TOOH with BHA#10; pumping out of the hole each stand with hi-visc seawater. 08:30 10:00 1.50 40 0 PROD1 CASING BHAH T Lay down BHA#10-inner and outer cleanout assembly. Clean and clear the floor. Page 12 of 23 Time Logs • 1 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 0 0 PROD1 CASING RURD T PU and MU wear ring pulling tool, pull wear ring, and lay down wear ring pulling tool. 11:00 12:00 1.00 0 0 PROD1 CASING RURD T PJSM. RU Weatherford power tong, MU crossovers, and change elevator from 4"drill pipe to 7"casing. 12:00 13:30 1.50 0 121 PROD1 CASING PUTB T PU and MU casing patch and HMCV assembly and RIH with 7", 26#, L-80, Hydril 563 casing to 121' RKB and tagged tight spot. 13:30 14:00 0.50 121 121 PROD1 CASING RURD T Change elevator to 4"DP and MU crossover to TD. 14:00 15:30 1.50 121 502 PROD1 CASING PUTB T Continue RIH with 7", 26#, L-80, Hydril 563 casing to 502' RKB using the top drive to assist in the hole due to tight spots in the 9-5/8"surface casing. 15:30 16:00 0.50 502 502 PROD1 CASING RURD T Change elevators to 7"casing and MU crossover to TIW. 16:00 18:45 2.75 502 2,067 PROD1 CASING PUTB T Continue to RIH from 502'to 2050' RKB on elevators. MU 20'landing pup(PU =90K, SO=70K, Rotating weight=75K,free torque=2-3K, 10 RPM)and wash down 2067'to ensure there is no fill. Shut down the rotary and pumps. 18:45 19:00 0.25 2,067 2,067 PROD1 CASING CIRC T Pump a casing volume(80 bbls) to clear the 7"casing of the hi-visc seawater at 4.5 BPM= 170 psi. 19:00 19:30 0.50 2,067 2,072 PROD1 CASING FISH P Engage casing patch onto 7"casing stub, set down 20K, and saw indicating shear. PU 5'no over pull, rotate down, set down 15K, shut down the rotary, set down 30K, PU 20K over pull, set down 35K, and PU 75K over pull. PT the 7"casing to 500 psi for 5 minutes(good test). 19:30 21:00 1.50 2,072 2,072 PROD1 CASING RURD P Break out 7"crossover, displace out the seawater in the 7"casing with one stand of DP, and change elevators to 7"casing. Blow down the top drive and kill lines. Pull the mouse hole. 21:00 22:30 1.50 2,072 2,072 PROD1 CASING NUND P Break the bolts on the BOPE and spacer spool. Lift riser and lift BOPE stack. 22:30 00:00 1.50 2,072 2,072 PROD1 CASING NUND P Install 7"casing slips. 09/06/2015 IC LDS are packed with sand from the well bore. Back out each gland nut, clean the port, and reinstall each gland nut. RILDS. IC LDS at 12:00 o'clock and 3:00 o'clock are seized. Cut the 7"casing with Wachs cutter. Set the BOPE on the stump, NU new tubing head, and PT void to 250/3000 psi(good test). NU DSA, NU BOPE, and wash the BOPE stack. Open up all ram doors, inspect cavities/rams, and close all ram doors. Close the annular on the 4"test joint and shell test the BOPE stack to 250/3000 psi(good test). Pull the test plug and install the wear ring. Page 13 of 23 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 2,072 2,072 PROD1 CASING NUND T RILDS. IC LDS are packed with sand from the well bore. Back out each gland nut, clean the port, and reinstall each gland nut. RILDS. IC LDS at 12:00 o'clock and 3:00 o'clock are seized. 03:00 04:00 1.00 2,072 0 PROD1 CASING CUTP P RU the Wachs cutter, cut the 7" casing, and RD the Wachs cutter. Cut joint 6.88'. 04:00 06:00 2.00 0 0 PROD1 CASING NUND P Pull cut joint out of the BOPE stack and set the BOPE stack back on the stump. 06:00 07:00 1.00 0 0 PROD1 CASING NUND P NU new tubing head. 07:00 07:30 0.50 0 0 PROD1 CASING PRTS P PT the void to 250/3000 psi for 10 minutes. 07:30 08:30 1.00 0 0 PROD1 CASING NUND P NU DSA. 08:30 09:30 1.00 0 0 PROD1 CASING WAIT T Nabors did not have an API ring for their BOP stack. Cameron had to run to the warehouse for a new API ring. 09:30 12:00 2.50 0 0 PROD1 CASING NUND P NU the BOPE stack and get new RKB's. 12:00 14:30 2.50 0 0 PROD1 CASING NUND P Adjust turn buckles on the BOPE stack, install the riser,fill the air boot, and install the mouse hole. Double check all the BOP stack bolts. 14:30 15:30 1.00 0 0 PROD1 CASING WWWH P PU and MU BOPE stack washing tool,wash the BOPE stack, and lay down the BOPE stack washing tool. Blown down the TD, choke, and kill. 15:30 22:00 6.50 0 0 PROD1 CASING RURD P Post milling operations inspection: Open up all ram doors, inspect cavities/rams, and close all ram doors. 22:00 22:30 0.50 0 0 PROD1 CASING BOPE P PJSM. MU 4"test joint with 4" HT-40 TIW. Fill the stack with fresh water. 22:30 23:00 0.50 0 0 PROD1 CASING BOPE P Close the annular on the 4"test joint and shell test the BOPE stack to 250/3000 psi (good test). 23:00 23:30 0.50 0 0 PROD1 CASING BOPE P RU BOPE testing equipment, break out 4"TIW, pull test plug, and lay down test joint. Drain the stack. 23:30 00:00 0.50 0 0 PROD1 CEMEN-RURD P PU wear ring running tool, nstall wear ring, lay down wear ring running tool, and RU to run 4"DP. Page 14 of 23 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/07/2015 24 hr Summary PU, MU, and TIH with cement inner string assembly. Snap in and out of indicating profile to verify tool depth. Pump 10 bbl cement retardant pill, pump dart assembly to seat, small dart sheared at 800 psi but still had circulation. Troubleshoot to determine if dart seated properly. TOOH with cement inner string assembly and found ITTS had been sheared open. Get new dart assembly and ITTS. PU, MU, and TIH with cement inner string assembly. Pump 15 bbl cement retardant pill, pump dart assembly to seat, small dart sheared at 950 psi and no communication to the IA. Quickly bring the pump up to shear the rupture disk in the HMCV (sheared at 2000 psi), continue to circulate the hi-visc seawater out of the 7"x 9-5/8"annulus. Pump cement job;got cement to surface after 98 bbls of PressureNet, closed the OA but max squeeze pressure observed was 120 psi, and pump the remaining 29 bbls of PressureNet. PU and close the HMCV at 30K over pull. Watch for flow back(none observed)and pressure up to shear the ITTS(sheared at 3100 psi). Close the annular, and reverse circulated until returns were clean. RD cementing equipment and TOOH with cement inner string assembly to 1090' RKB at midnight. 00:00 00:45 0.75 0 42 PROD1 CEMEN-BHAH P PJSM. PU and MU cement inner string and crossover pup. 00:45 01:00 0.25 42 42 PROD1 CEMEN-RURD P Remove blower hose. 01:00 04:00 3.00 42 2,034 PROD1 CEMEN"TRIP P TIH with cement inner string from 432;to 2036' RKB locate indicator sub at 2065', PU, pull 15K over to snap out, pass back through to verify cementing tool depth at 2065', and lay down a single. 04:00 04:15 0.25 2,034 2,034 PROD1 CEMEN CIRC P Pump 10 bbls cement retardant pill at 3 BPM= 145 psi and chase with 6 bbls to clear the surface lines 04:15 06:00 1.75 2,034 2,065 PROD1 CEMEN RURD P PU a single joint of DP,drop dart, and RU to circulating equipment. 06:00 07:30 1.50 2,065 2,065 PROD1 CEMEN-CIRC T Locate indicator sub to patch cement tools on depth at 2065' RKB, circulate the dart to seat at 2 BPM= 93 psi, saw large dart latch and small dart shear off at 800 psi but still had circulation up the IA. Troubleshoot to determine if dart is seated properly. 07:30 08:00 0.50 2,065 2,065 PROD1 CEMEN RURD T Blow down lines and RD circulating equipment. 08:00 08:30 0.50 2,065 2,074 PROD1 CEMEN RURD T PU and MU 9' DP pup. RU circulating equipment. 08:30 08:45 0.25 2,074 2,074 PROD1 CEMEN CIRC T Bring the pumps up to 7 BPM=477 psi but still have circulation up the IA. 08:45 09:15 0.50 2,074 2,034 PROD1 CEMEN RURD T RD circulating equipment, lay down 9' DP pup, lay down single, and blow down lines. 09:15 11:30 2.25 2,034 37 PROD1 CEMEN TRIP T TOOH with cement inner string. 11:30 13:00 1.50 37 0 PROD1 CEMEN BHAH T Lay down cement inner string. Break out double plug catcher and ITTS(ITTS was sheared open) 13:00 15:00 2.00 0 0 PROD1 CEMEN-WAIT T Wait for new dart assembly and ITTS to arrive from Deadhorse. 15:00 15:30 0.50 0 37 PROD1 CEMEN-BHAH T PU and MU cement inner string, double plug catch, and ITTS. 15:30 17:00 1.50 37 2,035 PROD1 CEMEN-TRIPT TIH with cement inner string to 2035' RKB Page 15 of 23 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 2,035 2,010 PROD1 CEMEN-CIRC T MU head pin, pump 15 bbls of cement retardant pill at 3 BPM = 115 psi, break out head pin, drop dart assembly, MU head pin, and PU to 2010' RKB. 17:30 18:30 1.00 2,010 2,035 PROD1 CEMEN-CIRC T Pump dart assembly down the DP at 1.5 BPM =41 psi, after 200 strokes slow pump rate to 0.5 BPM=26 psi, land dart assembly, continue to increase pressure to shear small dart at 950 psi, pressure dropped, bring pressure back to 1000 psi and hold to ensure cup are holding. SO back to 2035' RKB. 18:30 19:00 0.50 2,035 2,068 PROD1 CEMEN RURD P PU single and RIH to 2065' RKB, MU head pin, RU cement manifold, RU cementing/circulating line, and place cement inner string into position for cement job. 19:00 19:30 0.50 2,068 2,068 PROD1 CEMEN SFTY P PJSM with all third party involved in the cement job. 19:30 20:00 0.50 2,068 2,068 PROD1 CEMEN CIRC P Quickly bring the pump up to shear the rupture disk in the HMCV (sheared at 2000 psi), continue to circulate the hi-visc seawater out of the 7"x 9-5/8"annulus at 4 BPM out to the open top tank with 70 bbls of seawater. 20:00 20:30 0.50 2,068 2,068 PROD1 CEMEN'SEQP P Fill the line with fresh water and PT the cement line to 4500 psi (good test). 20:30 21:30 1.00 2,068 2,068 PROD1 CEMEN-CMNT P Pump cement job: pump 10 bbls of 15..7#AS1 neat cement, 98 bbls of 15.7#PressureNet cement, cement to surface, close the OA, attempt to squeeze(max squeeze pressure observed 120 psi), 29 bbls of 15.7# PressureNet cement, 15 bbls of 15.7#AS1 neat cement, and 19 bbls of fresh water. Shut down pumps. 21:30 22:30 1.00 2,068 2,060 PROD1 CEMEN-CIRC P PU and close the HMCV at 30K over pull. Watch for flow back(none observed)and pressure up to shear the ITTS(sheared at 3100 psi). Close the annular, and reverse circulate down the secondary kill taking returns up the DP at 5 BPM= 500 psi until returns are clean. 22:30 23:30 1.00 2,060 2,060 PROD1 CEMEN-RURD P RD cement manifold on the rig floor and in the cellar. Blow down all lines. 23:30 00:00 0.50 2,060 1,090 PROD1 CEMEN TRIP P TOOH with cement inner string from 2060'to 1090' RKB at midnight. Page 16 of 23 Time Logs • • Date__, From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/08/2015 24 hr Summary Continue to TOOH with cement inner string and lay down. PU, MU, and TIH with 5-3/4" RCJB but unable to get past 2067' RKB(casing patch);TOOH. PU, MU, and TIH with 6-1/8"rock bit but unable to get past 2068' RKB(casing patch); TOOH. PU, MU, and TIH with smooth OD tapered mill assembly unable to get past 2069' RKB(casing patch); TOOH(wear pattern on the base of the smooth 6"OD of the tapered mill). PU, MU, and TIH with smooth OD string mill assembly. Mill through tight spot from 2068'-2070' RKB, PU, slide through tight spot with 8K drag to 2083' RKB, and TOOH. 00:00 01:00 1.00 1,090 37 PROD1 CEMEN.TRIP P Crew change. PJSM. Continue to TOOH with cement inner string from 1090'to 37' RKB. 01:00 01:30 0.50 37 0 PROD1 CEMEN-BHAH P Lay down cement inner string assembly 01:30 02:00 0.50 0 0 PROD1 WELLPF BHAH P Load jars and bumper sub in the pipe shed. Bring RCJB and extensions to the rig floor for cleanout BHA. 02:00 03:00 1.00 0 224 PROD1 WELLPF BHAH P PU and MU BHA#11 -5-3/4"RCJB assembly with six 4-3/4" DCs. 03:00 04:30 1.50 224 2,054 PROD1 WELLPF TRIP P TIH with BHA#11 to 2054' RKB. 04:30 05:15 0.75 2,054 2,067 PROD1 WELLPF WASH T Tag cement stringer below HMCV at 2054' RKB, bring the pump up to 5 BPM=241 psi, and was through HMCV. Continue to wash down to hard tag at 2067' RKB(casing patch). Attempt to rotate through but unable to. 05:15 06:30 1.25 2,067 224 PROD1 WELLPF TRIP T TOOH with BHA#11. 06:30 06:45 0.25 224 0 PROD1 WELLPF BHAH T Lay down BHA#11 -5-3/4" RCJB assembly. 06:45 07:30 0.75 0 218 PROD1 WELLPF BHAH T PU and MU BHA#12-6-1/8"Rock Bit assembly. 07:30 08:45 1.25 218 2,057 PROD1 WELLPF TRIP T TIH with BHA#12-6-1/8"Rock Bit to 2057' RKB. 08:45 09:00 0.25 2,057 2,068 PROD1 WELLPF WASH T RU blower hose,wash down to 2068' RKB at 10 BPM=776 psi, but unable to get through casing patch. 09:00 09:30 0.50 2,068 2,068 PROD1 WELLPF RURD T Remove blower hose and blow down the TD. 09:30 10:30 1.00 2,068 218 PROD1 WELLPF TRIP T TOOH with BHA#12 from 2068'to 218' RKB. 10:30 11:30 1.00 218 0 PROD1 WELLPF BHAH T Lay down BHA#12-6-1/8" Rock Bit. 11:30 12:30 1.00 0 0 PROD1 WELLPF BHAH T Bring tapered mill and 6-1/8"smooth OD string mill to the rig floor. 12:30 13:30 1.00 0 225 PROD1 WELLPF BHAH T PU and MU BHA#13-Smooth OD Tapered Mill Assembly. 13:30 14:30 1.00 225 2,033 PROD1 WELLPF TRIP T TIH with BHA#13 to 2033' 14:30 15:00 0.50 2,033 2,069 PROD1 WELLPF PRTS T Attempt to pressure test casing, lost 400 psi in 5 minutes. Page 17 of 23 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 2,069 2,069 PROD1 WELLPF MILL T PU stand#20. Obtain parameters: PU=70K, SO=65K, rotating weight =65K, free torque= 1200 ft-lbs, 5 BPM=245 psi. Wash down to 2069' RKB, set down 5K, rotate at 60 RPM,and attempt to mill through obstruction but kept stalling out. Attempted several times without success. 16:30 17:30 1.00 2,069 225 PROD1 WELLPF TRIP T TOOH with BHA#13 17:30 18:30 1.00 225 0 PROD1 WELLPF BHAH T Lay down BHA#13-Smooth OD Tapered Mill Assembly. Wear pattern on the base of the smooth 6" OD of the tapered mill. 18:30 19:30 1.00 0 0 PROD1 WELLPF PRTS T Purge the lines to ensure no air is in the system. PT the 7"casing to 2500 psi: Test#1 -lost 200 psi in 5 minutes Test#2-bumped back to 2500 psi and lost 100 psi in 5 minutes. Test#3-bleed the pressure to 2000 psi and bring back up to 2500 psi and lost 200 psi in 5 minutest. 19:30 20:00 0.50 0 212 PROD1 WELLPF BHAH T PU and MU BHA#14-Smooth OD String Mill Assembly. 20:00 21:00 1.00 212 2,020 PROD1 WELLPF TRIP T TIH with BHA#14 to 2020' RKB. 21:00 22:30 1.50 2,020 2,083 PROD1 WELLPF MILL T Establish parameters: PU=70K, SO=65K, rotating weight=67K, free torque= 1400 ft-lbs, 5.5 BPM= 235 psi. Wash down to tag at 2071' RKB bull nose depth(string mill at 2068' RKB). Mill through tight spot from 2068'-2070'(string mill depth) at 80 RPM,torque= 1400-7500 ft-lbs several time. PU above tight spot and slide through with 8K drag to 2083' RKB(bull nose depth), and back ream through. 22:30 23:00 0.50 2,083 212 PROD1 WELLPF TRIP T TOOH with BHA#14 23:00 00:00 1.00 212 0 PROD1 WELLPF BHAH T Lay down BHA#14-Smooth OD String Mill Assembly. Clean and clear the floor. 39/09/2015 PU, MU, and TIH with RCJB assembly. Work through tight spot at 2068' RKB and tag fill at 2598' RKB(90' above top of the sand). Wash down to 2512'but were unable to make it any deeper. TOOH and RCJB was packed off with cement. PU, MU, and TIH with 6-1/8"bladed junk mill assembly to 2512' RKB. Wash fill from 2512'to 2598' RKB, pump hi-visc sweep, and TOOH. PU, MU, and TIH with RCJB assembly to tag at 2599'. Wash from 2599'to 2618' RKB, circulate bottoms up, and TOOH. RCJB pack with sand/metal debris and a baseball sized rock. PU, MU, and TIH with RCJB assembly to 698' RKB at midnight. 00:00 01:00 1.00 0 223 PROD1 WELLPF BHAH T PU and MU BHA#15-5-3/4"RCJB assembly. 01:00 02:15 1.25 223 2,068 PROD1 WELLPF TRIP T TIH with BHA#15 to 2068'work through tight spot at 20 RPM, torque =2000-4000 ft-lbs. Page 18 of 23 Time Logs 41) Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 02:15 03:00 I 0.75 2,068 2,508 PROD1 WELLPF;TRIP P Continue to TOOH to tag at 2508' RKB with 5K down. Tagged 90'high; top of sand at 2598' RKB. Drop ball for RCJB. 03:00 04:00 1.00 2,508 2,512 PROD1 WELLPF WASH P Wash down from 2508' RKB at 10 BPM = 1600 psi, 60 RPM, and torque= 1500-3500 ft-lbs. Cleanout down to 2512 and stopped making progress. Attempted several times but unable to work past 2512' RKB. 04:00 05:15 1.25 2,512 223 PROD1 WELLPF TRIP T Blow down the TD and TOOH with BHA#15. 05:15 06:45 1.50 223 0 PROD1 WELLPF BHAH T Lay down BHA#15-5-3/4" RCJB assembly. RCJB packed off with cement. 06:45 07:30 0.75 0 228 PROD1 WELLPF BHAH T PU and MU BHA#16-6-1/8"Bladed Junk Mill Assembly. 07:30 09:30 2.00 228 2,512 PROD1 WELLPF TRIP T TIH with BHA#16 to tag at 2512' RKB with 5K down. 09:30 10:15 0.75 2,512 2,598 PROD1 WELLPF WASH T PU and obtain parameters: PU = 75K, SO=65K, rotating weight= 70K, 50 RPM, free torque= 1400 ft-lbs,6 BPM =375 psi. Wash fill from 2512'to 2598' RKB. 10:15 11:00 0.75 2,598 2,598 PROD1 WELLPF CIRC T Pump 40 bbl hi-visc sweep at 8 BPM =650 psi. At bottoms up shakers loaded with sand, circulate clean, shut down pumps and blow down TD 11:00 11:15 0.25 2,598 2,600 PROD1 WELLPF WASH T SO with no pumps or rotary and tag at 2600' RKB. Attempt to wash but unable to make any progress. 11:15 11:30 0.25 2,600 2,600 PROD1 WELLPF RURD T RU to PT the 7"casing. 11:30 12:15 0.75 2,600 2,600 PROD1 WELLPF PRTS T PT the 7"casing to 2500 psi for 30 minutes(good test). 12:15 12:30 0.25 2,600 2,600 PROD1 WELLPF RURD T RD pressure testing equipment 12:30 13:30 1.00 2,600 228 PROD1 WELLPF TRIP T TOOH with BHA#16. 13:30 14:30 1.00 228 0 PROD1 WELLPF BHAH T Clean out magnet(recovered about 25 lbs of metal)and lay down BHA #16-6-1/8" Bladed Junk Mill Assembly. 14:30 15:30 1.00 0 0 PROD1 WELLPF BHAH T Send Baker fishing tools outside. Clean and clear the floor. 15:30 16:30 1.00 0 0 PROD1 WELLPF RGRP T Replace the high drum clutch on the draw works. 16:30 17:00 0.50 0 0 PROD1 WELLPF PRTS T Close the blinds and PT the 7" casing to 2500 psi for 15 minutes (good test). 17:00 18:00 1.00 0 223 PROD1 WELLPF BHAH T PU and MU BHA#17-5-3/4" RCJB assembly. 18:00 19:00 1.00 223 2,507 PROD1 WELLPF TRIP T TIH with BHA#17 to 2507' RKB Page 19 of 23 410 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:30 1.50 2,507 2,618 PROD1 WELLPF WASH P Establish parameters: PU =77K, SO=65K, rotating weight=68K, 10 BPM = 1625 psi, 60 RPM, free torque= 1700 ft-lbs. TIH and tag sand at 2599' RKB. Wash from 2599'to 2618' RKB with 2-10K down and torque 1700-3000 ft-lbs 20:30 21:30 1.00 2,618 223 PROD1 WELLPF TRIP P TOOH with BHA#17. 21:30 23:00 1.50 223 0 PROD1 WELLPF BHAH P Clean out magnet(recovered about 10 lbs of metal)and lay down BHA #17-5-3/4" RCJB assembly. RCJB pack with sand/metal debris and a baseball sized rock. 23:00 23:30 0.50 0 223 PROD1 WELLPF BHAH P PU and MU BHA#18-5-3/4"RCJB assembly. 23:30 00:00 0.50 223 698 PROD1 WELLPF TRIP P TIH with BHA#18 to 698'RKB at midnight. 09/10/2015 Continue to TIH with RCJB to 2618' RKB,wash down to 2637' RKB, and TOOH. PU, MU,and TIH with RBP retrieving tool to 2641' RKB, release the RBP, and allowed elements to relax. Circulated bottoms up and seen a small amount of gas at surface. Slip and cut 59'of drilling line. Replaced the quick release on the master drum clutch and installed a new air line. POOH with RBP laying down DP and lay down RBP retrieving head with RBP. Pull wear ring, flush the stack, RU to run completion, and RIH with 3-1/2"GL completion to 3278' RKB at midnight. 00:00 01:00 1.00 698 2,618 PROD1 WELLPF TRIP P Continue to TIH with BHA#18- 5-3/4" RCJB assembly from 698'to 2618'RKB 01:00 01:15 0.25 2,618 2,637 PROD1 WELLPF WASH P Establish parameters: PU=77K, SO=65K, rotating weight=68K, 10 BPM= 1625 psi, 30 RPM,free torque= 1700 ft-lbs. Wash down with no weight down or torque from 2618'to 2637' RKB. 01:15 02:00 0.75 2,637 2,637 PROD1 WELLPF CIRC P Circulate bottoms up at 10 BPM = 1700 psi. At bottoms up shakers loaded with sand, circulate clean, shut down pumps and blow down TD. 02:00 03:30 1.50 2,637 223 PROD1 WELLPF TRIP P TOOH with BHA$18 03:30 05:00 1.50 223 0 PROD1 WELLPF BHAH P Lay down BHA#18-5-3/4" RCJB assembly and send tools outside. Clean and clear the floor. 05:00 05:30 0.50 0 187 PROD1 WELLPF BHAH P PU and MU BHA#19-RBP Retrieving Head. 05:30 06:45 1.25 187 2,599 PROD1 WELLPF TRIP P TIH with BHA#19 to 2599' RKB 06:45 07:00 0.25 2,599 2,651 PROD1 WELLPF MPSP P Circulate down at 3 BPM, latch onto RBP at 2641' RKB, release RBP, and allow elements to relax. SO 10' to verify RBP is free. 07:00 08:00 1.00 2,651 2,651 PROD1 WELLPF CIRC P Circulate bottoms up at 3 BPM = 225 psi. At bottoms up small amount of gas seen and circulate until clean. Blow down the top drive. 08:00 10:00 2.00 2,651 2,651 PROD1 WELLPF SLPC P Slip and cut 59'of drilling line. Inspect and adjust brakes. 10:00 10:30 0.50 2,651 2,651 PROD1 WELLPF SVRG P Service the top drive. Page 20 of 23J Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 2,651 2,281 PROD1 WELLPF PULD P POOH with BHA#19 and RBP to 2281' RKB laying down DP . 12:00 13:30 1.50 2,281 2,281 PROD1 WELLPF RGRP T Replace the quick release on the master drum clutch and install new air line. 13:30 15:30 2.00 2,281 187 PROD1 WELLPF PULD P Continue to POOH laying down DP. 15:30 17:00 1.50 187 0 PROD1 WELLPF BHAH P Lay down six 4-3/4" DCs and RBP retrieving head with RBP. 17:00 17:30 0.50 0 0 PROD1 WELLPF RURD P MU wear ring pulling tool, pull wear ring, and lay down wear ring pulling tool. Wear ring had metal debris around it while pulling. 17:30 18:30 1.00 0 0 COMPZ RPCOM RURD P Bring Weatherford power tong, elevators, and slips to the rig floor. RU Weatherford power tongs and elevators. 18:30 19:00 0.50 0 0 COMPZ RPCOM WWWH P PU and MU BOPE stack washing tool,wash the tubing hanger seal area/BOPE stack, and lay down BOPE stack washing tool. 19:00 19:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running completion. 19:15 00:00 4.75 0 3,278 COMPZ RPCOM PUTB P PU and MU seal assembly and RIH with gas lift completion on 3-1/2", 9.3#, L-80, EUE 8rd Mod tubing to 3278' RKB at midnight. 09/11/2015 Continue to RIH with 3-1/2"tubing to the top of the PBR at 9105' RKB,engage seal assembly, locate out, and space out. MU tubing hanger, pump 280 bbls of corrosion inhibited seawater, land the tubing hanger, and RILDS. PT the tubing to 3000 psi for 10 minutes(good test/charted), bleed the tubing to 1500 psi, and PT the IA to 2500 psi for 30 minutes(good test/charted). Quickly bleed the pressure off the tubing to shear the SOV. Install the 3"'H' BPV per Cameron and pressure up on the IA to 1000 psi to test the BPV from below in the direction of flow(good test). RU super sucker and clean under the rotary table, pipe racks, skate sump, and EZ torque sump. ND the BOPE and set back on the stump. NU the tubing head adapter and NU the tree. 00:00 06:45 6.75 3,278 9,105 COMPZ RPCOM PUTB P Continue RIH with gas lift completion on 3-1/2", 9.3#, L-80, EUE 8rd Mod tubing from 3278'to top of the PBR 9105 RKB. 06:45 07:15 0.50 9,105 9,085 COMPZ RPCOM HOSO P Engage the seal assembly, locate out, and space out with 8.13'pup joint 07:15 07:30 0.25 9,085 9,089 COMPZ RPCOM THGR P PU and MU tubing hanger with landing joint. 07:30 08:00 0.50 9,089 9,104 COMPZ RPCOM HOSO P Roll the charge pump, engage the seal assembly, shut down the pump, and PU until the pressure drops+1' to space out for pumping corrosion inhibitor. 08:00 08:30 0.50 9,104 9,104 COMPZ RPCOM WAIT T Attempt to pump corrosion inhibited seawater off vac truck but the vac truck had a motor failure. Wait for mechanic to fix the motor. SimOps: RD Weatherford power tongs and elevators. Clean and clear the floor. Page 21 of 23 • Time Logs- • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:30 2.00 9,104 9,104 COMPZ RPCOM CRIH P Circulate 280 bbls of corrosion inhibited seawater from vac truck at 3.5 BPM =234 psi followed by 42 bbls of seawater at 3.5 BPM=225 psi. 10:30 11:00 0.50 9,104 0 COMPZ RPCOM THGR P Drain the BOP stack, land the tubing hanger, and RILDS. 11:00 11:15 0.25 0 0 COMPZ RPCOM RURD P Lay down the landing joint and RU pressure testing equipment. 11:15 13:15 2.00 0 0 COMPZ RPCOM PRTS P PT the tubing to 3000 psi for 10 minutes(good test/charted), bleed the tubing to 1500 psi, and PT the IA to 2500 psi for 30 minutes(good test/charted). Quickly bleed the pressure off the tubing to shear the SOV. 13:15 14:00 0.75 0 0 COMPZ WHDBO MPSP P Install the 3"'H' BPV per Cameron and pressure up on the IA to 1000 psi to test the BPV from below in the direction of flow(good test). 14:00 15:30 1.50 0 0 COMPZ WHDBO OTHR P RD pressure testing equipment. Send Weatherford tubing handling equipment,wear ring, test plugs, running/pulling tools, and thread protectors off the rig floor. 15:30 20:45 5.25 0 0 COMPZ WHDBO OTHR P RU super sucker and clean under the rotary table, pipe racks,skate sump, and EZ torque sump. Grease the linkage on the rotary table. 20:45 22:45 2.00 0 0 COMPZ WHDBO NUND P Remove the turnbuckles, ND the BOPE stack, and set back on the stump. ND the DSA 22:45 00:00 1.25 0 0 COMPZ WHDBO NUND P Install tree test dart, NU tubing head adapter, and NU tree.Tree orientation verified by 1A DSO. 09/12/2015 PT the tubing hanger void to 250/5000 psi(good test). Finished tightening the bolts of the tree. PT the tree to 250/5000 psi (good test). Pull BPV/tree test dart. Freeze protect the well by pumping 80 bbls of diesel down the IA and taking returns up the tubing. Place the tubing and IA in communication; allow to u-tube and equalize. Install 3"'H' BPV and RD lubricator. Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Release rig Nabors 9ES at 17:00 hrs on 9-12-15. 00:00 00:30 0.50 0 0 COMPZ WHDBO THGR P PT the tubing hanger void to 250/5000 psi(good test). 00:30 01:30 1.00 0 0 COMPZ WHDBO NUND P Finished tightening the bolts of the tree 01:30 03:00 1.50 0 0 COMPZ WHDBO NUND P RU to test the tree and fill the tree with diesel. 03:00 04:30 1.50 0 0 COMPZ WHDBO PRTS P PT the tree to 250/5000 psi(good test). 04:30 05:30 1.00 0 0 COMPZ WHDBO OTHR P RD tree testing equipment. Drain the diesel out of the tree to the wing valve. 05:30 06:00 0.50 0 0 COMPZ WHDBO MPSP P Pull BPV/tree test dart. 06:00 07:00 1.00 0 0 COMPZ WHDBO FRZP P RU LRS to pump down the IA and RU to take returns out the tubing. Page 22 of 23 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 0 0 COMPZ WHDBO FRZP P Freeze protect the well by pumping 80 bbls of diesel down the IA and taking returns up the tubing. 08:00 09:00 1.00 0 0 COMPZ WHDBO FRZP P RD LRS and RU to u-tube. 09:00 13:00 4.00 0 0 COMPZ WHDBO FRZP P Place the tubing and IA in communication; allow to u-tube and equalize. 13:00 13:45 0.75 0 0 COMPZ WHDBO FRZP P RD down lines for u-tube. 13:45 15:45 2.00 0 0 COMPZ WHDBO MPSP T Attempt to RU lubricator but the tree is at an angle due to the subsidence at the well head. Use come along to straighten the tree. RU the lubricator, attempted to PT, but the o-ring got cut during RU. Replace o-ring and PT(good test). 15:45 16:30 0.75 0 0 COMPZ WHDBO MPSP P Install 3"'H' BPV and RD lubricator 16:30 17:00 0.50 0 0 DEMOB MOVE RURD P Secure tree and cellar. Install valves and gauges. Clean and clear the cellar. Final well pressures: Tubing=0 psi, IA=0 psi, and OA=0 psi. Release rig Nabors 9ES at 17:00 hrs on 9-12-15 Page 23 of 23 Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Thursday, September 03, 2015 11:01 AM To: Loepp,Victoria T (DOA) Subject: RE: KRU 1A-28 - PTD# 191-002 - Sundry# 315-359 - BOPE Test Waiver Request Attachments: BWM BOP performance (CPAI) 8-18-15.pdf; BOPE Between Well Maintenance Objective - Doyonl4l 7-25-15.pdf Follow Up Flag: Follow up Flag Status: Flagged Couple things bug me about this request; couple things support granting request: - They need to get out of the mind-set that they are ok starting a BOPE test by midnight on the due date - Should have tested before starting to run the 7" casing patch to be in compliance (operators should be looking for opportunities to test rather than ways to get around the regulatory requirement) - Recent BOPE test performance has been ok; last AOGCC witness was 7/23—initial test after rig finished summer maintenance - Nabors 9ES is part of their BOP Between Wells Maintenance (BWM) Program which is showing some positive results regarding BOPE reliability/performance—this is a strong justification for granting the extension. Granting request until next trip to surface would be appropriate. I've attached the BOP BWM program summary which may explain the reason for the uptick in requests for extensions; CPAI's goal is to get AOGCC approval for 14day BOPE test interval (vs. 7day currently)for workovers—see last page of 8/18/15 attachment. Jim Regg SCNKHf° MAR 0 8 2.Q16, Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Thursday, September 03, 2015 10:34 AM To: Regg, James B (DOA) Subject: FW: KRU 1A-28 - PTD# 191-002 - Sundry# 315-359 - BOPE Test Waiver Request Jim, How do you like to handle these BOP test timing waivers? Do you want to review or the inspectors review or would you like me to review and handle or all three?We're getting more requests lately. Thanx, 1 OF Tye (...i....:„ e THE STATE Alaska Oil and Gas 1�, of 11ASKA Conservation Commission -, - - __4- iii _- 333 West Seventh Avenue u GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 OFALAS1'� q Fax: 907.276.7542 JUL 0 +y! 2„V:: www.aogcc.alaska.gov aogcc.alaska.gov Diana Guzman S�14NEp Sr. Wells Engineer 1 ----60--10°' ConocoPhillips Alaska, Inc. f P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-28 Sundry Number: 315-359 Dear Ms. Guzman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 /, Daniel T. Seamount, Jr. Commissioner DATED this l G day of June, 2015 Encl. STATE OF ALASKA ' .SKA OIL AND GAS CONSERVATION COMMISSION (6\��� " APPLICATION FOR SUNDRY APPROVALS ‘7a' 20 AAC 25.280 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing p' • Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing , Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well ry . Re-enter Susp Well r Other G 0.4411 C7f r- 2 Operator Name 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. • Exploratory r Development ps J 191-002 • 3 AddressStratigraphic r Service r 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-22126-00 ' 7.If perforating, What 8 Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r KRU 1A-28 9 Property Designation(Lease Number) 4416 10 Field/Pool(s) ADL 256a56S q j i 611;)_ Kuparuk River Field/Kuparuk River Oil Pool• 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 10025 - 6499 • 9916' • 6435' 9194' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 40 16 80' 80' SURFACE 5417 9.625 5452' 3883' " PRODUCTION 9971 7 10006' 6488' • - l I L A 0!9,71 CC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size: Tubing Grade Tubing MD(ft) 9330-9390,9619-9633,9649-9712• 6104-6138,6266-6274,6283-6318 3.5 L-80 9207 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=9119 TVD=5982• PACKER-BAKER HB RETRIEVABLE PACKER MD=9246 TVD=6056 • PACKER-TIW SS PERMANENT PACKER MD=9416 TVD=6152 NIPPLE-CAMCO DS NIPPLE MD=554 TVD=553 12 Attachments: Description Summary of Proposal [ 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r 14 Estimated Date for Commencing Operations 15 Well Status after proposed work 8/5/2015 OIL P • WINJ r WDSPL E Suspended r 16 Verbal Approval Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact. Diana Guzman @ 265-6318 Email Diana Guzman@conocophillips corn Printed Name Diana Guzman Title Sr. Wells Engineer Signature /,'X,t dpi r-------, Phone.265-6318 Date „lb ne, 10/ 20(S Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 31S—' 5-4:t Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other. j3 p tc5f to 3000 psi (A4p5P /S z6 E'¢ p5t !thr)V/a1- pr-CVCv77r - t-r5f • -0 Z57- C psi - Spacing Exception Required? Yes ❑ No L Subsequent Form Required /0 — 4 Cit. - APPROVED BY /1L J] Approved by COMMISSIONER THE COMMISSION Date -25 YTL 6//5---//5"" Approved application is valid for 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015 <� IIt lis Attac is in Duplicate ORIGINAL ,.�6� � RBDMJUN 252015 • ConocoPhillips ,. R . � a Alaska - P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AO CC June 10,2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover the Kuparuk Well IA- 28(PTD: 191-002). Well 1A-28 was originally drilled and completed as a Kuparuk A and C sand producer in 1991. A Leak Detection Log performed in March 2003 indicated a suspected upper packer leak. As a result 1A-28 was shut in. A rig workover was performed on July 2003 to stack a packer above the existing upper selective packer. Well 1A-28 continued to produce until September 2011 when it was shut-in due to a failed combo MIT and a failed mechanical integrity test for the outer annulus(MIT-OA)on February 2011.A Leak Detection Log ran on April 2011 confirmed the tubing by inner (TxIA) annulus communication at GLM #3. Follow up diagnostics concerning the failed MIT- OA were performed on November 2011 and confirmed that surface leak around 300ft. A gyro survey logged on December 2011 confirmed that the annular communication in well 1A-28 was due to subsidence related damage induced by sinusoidal buckling from 350ft to surface. Prior to being shut-in on September 2011, well 1A-28 was producing 171 BOPD. The purpose of this workover is to pull the existing gas lift completion, cut and pull the 7"production casing above the top of cement, tie in and cement a new 7" production casing from the back off, and run a new 3 '/2" gas lift completion. If you have any questions or require any further information, please contact me at 907-265-6318 or Diana.Guzman@conocophillips.com. Sincerely, Diana Guzm n Wells Engineer CPAI Drilling and Wells i KUP 1A-28 ConocoPhillips $ Well Attributes Max Angle&MD TD • Alaska,Inc, Wellbore APW WI Field Name Well Status Incl(°) MD(RKB) Act Btm(RKB) ...Fumes500292212600 KU PARUK RIVER UNIT PROD 57.27 5,100.00 10,025.0 .,,, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •• WelICanfq:-1A-28 6/26/20136:59:46AM SSSV:NIPPLE 120 9/13/2010 Last WO: 8/10/2003 34.81 1/21/1991 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,757.0 2/2/2011 Rev Reason:Re-Set PIug,Set Catcher,GLV C/0 haggea 6/26/2013 ""Idli` 1�ii ill l .i ' �'7E'sK 91Q(I II O�i�li4,n HANGER,31 9 fix' CasOr ing 0000rrpton Strings String 0... String ID...Top MKS) Set Depth(f...Set Depth(ND)..String WE..String...String � I ring Top Thrd CONDUCTOR 16 15.060 39.7 80.0 80.0 65.00 H-40 WELDED `*111E ,:A: 'U Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 35.0 5,452.3 3,882.5 36.00 J-55 BTC I Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd PRODUCTION 7 6.276 35.0 10,005.5 6,487.8 26.00 J-55 BTC CONDUCTOR, 40-80 Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 3 1/2 3.500 31.0 9,207.3 6,031.4 9.30 L-80 EUE MOD NIPPLE,554 1 ,._ Completion Details IIK Top Depth' (ND) Top Incl Nomi... Top(RKB) (RKB) (°) Item Description Comment ID(In) GAS LIFT, `= 31.0 31.0 0.44 HANGER CAMERON TUBING HANGER 4.500 3,336 33.9 33.9 0.44 XO Reducing CROSSOVER 4.5x3.5" 3.500 messe 554.1 553.1 8.14 NIPPLE CAMCO DS NIPPLE 2.875 9,105.4 5,975.3 55.48 PBR BAKER 80-40 PBR 3.000 I 9,119.1 5,983.0 55.43 PACKER BAKER FHL PACKER 3.000 9,194.2 6,025.6 55.17 NIPPLE CAMCO DS NIPPLE 2.812 SURFACE. A 9,201.3 6,027.7 53.59 OVERSHOT UNIQUE POORBOY OVERSHOT 3.750 355.452 Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd TUBING Original 312 2.992 9,204.4 9,502.7 6,200.1 9.30 L-80 BTC-MOD GAS LIFT, 3.5x2.875, 5,667 r. I Completion Details al Top Depth (ND) Top Incl Nomi... Top(RKB) (RKB) (1 Rem Description Comment ID(in) GAS 72T - ";�, 9,232.7 6,046.7 53.97 PBR BAKER PBR w/10'STROKE 3.000 9,246.4 6,054.9 54.14 PACKER BAKER HB RETRIEVABLE PACKER 2.870 .1 9,304.9 9,304.9 6,089.2 54.86 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 9,402.8 6,146.5 57.64 SLEEVE-0 CAMCO CB-1 SLIDING SLEEVE;OPENED 6/15/01 2.812 GASLIFT, 9,363 - 9,413.5 6,152.1 57.52 SEAL ASSY TIW LOCATOR SEAL ASSEMBLY 3.011 9,416.4 6,153.7 57.49 PACKER TIW SS PERMANENT PACKER 4.000 --"` 9,420.1 6,155.6 57.45 SBE TIW SEAL BORE EXTENSION 4.000 11111 GAS LIFT, 9,424.4 6,157.9 57.40 XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,#6.5,J-55,EUE-MOD 2.875 lir 8055 9,490.3 6,193.2 56.67 NIPPLE CAMCO D NIPPLE NO GO 2250 lir El 9,502.0 6,199.7 56.54 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl PBR,9,105 - Top(RKB) (RKB) (°) Description Comment Run Date ID(in) PACKER,9,119 9,190.0 6,023.2 55.19 CATCHER 10"-2.71"CATCHER SUB 6/18/2013 0.000 9,194.2 6,025.6 55.17 PLUG 2.81"CA-2 PLUG 6/18/2013 0.000 CATCHER, 9.1901 'INII.I PLUG,9,19/ Perforations&Slots NIPPLE,9.194' W Shot III Top(ND) Btm(TVD) Dens Top(RKB)Bbtl(RKB) (RKB) (RKB) Zone Date Oh- TypeComment OVERSHOT, 9,330.0 9,370.0 6,103.5 6,126.2 C-4,C-3,C-2, 6/5/1991 10.0 IPERF HLS 4.5"Casing Gun 9,201lENMINK 1A-28 9,370.0 9,390.0 6,126.2 6,137.5 C-2,C-1,1A-28 6/5/1991 5.0 IPERF HLS 4.5"Casing Gun PER.9.233 F I 9,619.0 9,633.0 6,265.7 6,273.5 A-5,1A-28 6/5/1991 4.0 IPERF HLS 4.5"Casing Gun PACKER.9.246 !-M 9,649.0 9,712.0 6,282.5 6,318.0 A-4,1A-28 6/5/1991 4.0 IPERF HLS 4.5"Casing Gun lir Notes:General&Safety End Date Annotation PRODUCTION. Ir 9,290 12/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF. _ - 9,330-9,370 IPERF. 9,370.9,390 Ilt SLEEVE-O, 9,403 SEAL ASSY, 9,413 PACKER,9,410 CallI SBE,9,420 Mandrel Details NIPPLE,9,490W. I Top Depth Top Poi S... (ND) Inst OD Valve Latch Sloe TRO Run N...Top(RKB) (11KB) (°) Make Model (in) Sets Type Type (in) (psi) Run Date Com... SOS.9502 - 1 3,338.0 2,647.5 50.02 CAMCO KBUG-M 1 GAS LIFT DMY BK-5 0.000 0.0 222011 2 5,666.8 4,000.3 56.97 CAMCO KBUG-M 1 GAS LIFT DMY BK-5 0.000 0.0 222011 3 7,279.2 4,907.3 54.79 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 9222012 Ext pk9 RF, 9,619PE5.633 4 8,382.9 5,552.5 54.05 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 8/10/2003 (PERF, 5 9,054.5 5,944.8 54.25 CAMCO KBUG-M 1 GAS LIFT OPEN 0.000 0.0 6/18/2013 9,640-9.712 r 6 9,290.4 6,080.8 54.68 MERLA TGPDC 1 12 PROD DMY 'RK 0.000 0.0 6/14/1996 Closed PRODUCTION, 3510,006 TD.10,025 . , . L 11 , 1A-28 ConocoPhillips Proposed Completion Subsidence RWO 4- Cemented OA from TOC-Surface 41 Casing-7"26#, L-80 TC-II @ - 2,000'MD/1,825'TVD Casing-9-5/8"36#,J-55 BTC @ 5,452' MD/3,883'TVD Gas Lift Mandrels: Type MD TVD MMG, 1" 3,340 2,650 MMG, 1" 5,665 4,000 MMG, 1" 7,280 4,900 MMG, 1" 8,830 5,550 MMG, 1" 9,055 5,995 MMG, 1" 9,290 6,080 1 " II- 4 PBR @ 9,105 MD/5,975'TVD -r Baker FHL Packer @ 9,119'MD/5,983'TVD 4 2.812" DS-Nipple @ 9,194'MD/6,026'TVD I4-- Over Shot/Tubing Stub @ 9,201' MD/6,028'TVD PBR @ 9,233' MD/6,057'TVD I- J Baker HB Permanent Packer @ 9,247'MD/6,055'TVD liii C-4,C-3,C-2,C-1 Pert @ 9,330,-9,390' . Carbide Blast Rings @ 9,305 MD/6,089'TVD -41- Camco Sliding Sleeve(Open)@ 9,403'MD/6,147'TVD I. -ill-- TIW Seal Assembly @ 9,414'MD/6,152'TVD I J -4- TIW SS Permanent Packer @ 9,416'MD/6,154'TVD CCE F TIW Seal Bore Extension @ 9,420'MD/6,156'TVD Tubing-3-1/2'9.3#, L-80,8rd EUE ► a a 4- 2.25" D-Nipple @ 9,490'MD/6,193'TVD 4- 2.441"Shear Out Sub @ 9,502'MD/6,200'TVD A-5 @ 9,619'-9,633' -► Ii A-4 @ 9,649'-9,712' -I.' G Casing-7"26#, L-80 @ 11,924' Date: June 10,20151 Drawn By:Diana Guzman 1A-28 Rig Workover Subsidence Repair (PTD #: 191-002) Current Status: This well is currently shut in and awaiting pre-RWO well work. Scope of Work: • Pull and replace the existing gas lift completion, • Cut and pull the 7"production casing above the top of cement. • Tie in and cement a new 7"production casing. General Well info: Well Type: Producer MASP: 2684 psi using 0.1 psi/ft gradient(Most recent SBHP=3310 psi on 06/18/13) Reservoir Pressure/TVD: 3310 psi/6265' TVD(10.2 ppg)on 06/18/13 Wellhead type/pressure rating: McEvoy Gen IV/7%i6"5M Top x 11"3M Bottom BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: CMIT—TxIA passed April 26,2015 TxIA DDT passed April 22,2015 TIFL failed January 28,2011 MIT-OA failed February 19,2005 Earliest Estimated Start Date: August 5,2015 Production Engineer: David Lloyd Lagerlef/David Haakinson Workover Engineer: Diana Guzman Work: 265-6318 E-mail:Diana.Guzman@conocophillips.com Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE and test to 3,000 psig. ./ 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 3 'h"tubing. a. If tubing will not pull free,RU E-line: Cut the tubing. 6. RIH on DP and 7' casing scraper to the PBR. POOH 7. RU E-line. RIH with CAST-M to locate TOC.RIH and fire string shot. POOH 8. Set 7"RBP below TOC.PT/DDT the RBP.Dump sand. POOH with DP. 9. Cut the 7"casing above TOC. 10. Monitor OA for flow.ND BOPE. Remove tubing head.NU the BOPE to the casing head. 11. Spear casing and PU. 12. Reverse circulate out the Arctic Pack from the OA with heated diesel. 13. POOH laying down the 7"casing. 14. Set the test plug in the casing head. Shell test the BOPE. 15. RIH with 9%"casing scraper to the cut 7"casing. POOH with DP. 16. Gauge the 9%"casing for the ES cementer with tandem string mills. POOH with DP. 17. Dummy drift the ES cementer. POOH with DP. 18. Backoff the top 7"casing joint. POOH with DP. 19. Engage spear on casing stub to retrieve fish. POOH with DP. 20. Run new 7"casing. PT the 7"casing. NU cement head. 21. RU SLB cementers. Close pipe rams and open the annulus valve. Pressure up the casing to open the ES cementer. Cement the 7"casing to surface. 22. PT the cement plug. Bleed production casing pressure to zero. ND cement head. WOC. 1A-28 Rig Workover Subsidence Repair (PTD #: 191-002) 23. ND BOPE. Land 7" casing in the slips. Cut excess casing off. Install packoff. NU new tubing head and BOPE. Install BPV and blanking plug. Shell test BOPE. Pull BPV. 24. Mill up cement,closing plug,and ES cementer. POOH with DP. 25. PT the casing. Record test on chart for 30 minutes. 26. Mill remaining debris from the top of the sand. POOH with DP. 27. RIH with wash string and circulate sand out from on top of the RBP. POOH with DP. 28. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. 29. Run new 3 'h"gas lift completion. 30. Sting into PBR. Space out for subsidence,mark the pipe,and POOH two joints. Space out with pups. 31. MU tubin$,kanger. Swap the well over to corrosion inhibited seawater. Land the hanger and RILDS. 32. PT tubing.Pressure test the IA. ✓ 33. Bleed T and IA. Shear the SOV.Bleed tubing and IA pressures to zero. Monitor for flow. 34. Pull landing joint. Install TWC. Pressure test IA to test TWC from below. 35. ND BOP stack,NU tree. PT tree and tubing hanger packoffs. 36. Remove TWC. 37. Freeze protect w/diesel. Set BPV. 38. RDMO. Proposed Post-Rig Work: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull catcher and plug. Run new gas lift design. Set up for production 4. Handoff to operations to put back on production. ,DTv r`7/— OZLoepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday,June 05,2015 3:17 PM To: 'Guzman, Diana' Subject RE: 1A-28(PTD 191-002) Sundry If the work starts within a week of the expiration,then that will be fine to continue, however any longer, would like an updated sundry. From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Friday,June 05, 2015 3:04 PM To: Loepp, Victoria T(DOA) Subject: RE: 1A-28(PTD 191-002) Sundry Good afternoon Victoria, Well 1A-28 has been shut in since 2011 and its RWO plan is still the same: • Pull and replace the existing gas lift completion. • Cut and pull the 7" production casing above the TOC. • Tie in and cement a new 7" production casing. The only thing that has changed since I submitted the sundry last year are more current TIFL/MIT Results performed in 2015 vs 2013: 04/26/2015 (PRE-RWO) : BPV TEST PASSED TO 1015 PSI, DDT-TXIA PASSED. 04/22/2015 (PRE RWO): CMIT-T X IA(PASSED)TO 2500 PSI,T X IA DDT(IN PROGRESS). 04/21/2015 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, FUNCTION TESTED T&IC LDS (T LDS ARE STIFF, IC GOOD). Please let me know if you have any other questions. Sincerely, Diana Guzman Senior Wells Engineer SCANNED - U s L U 13 ConocoPhillips Alaska Inc Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,June 05, 2015 1:35 PM To: Guzman, Diana Subject: [EXTERNAL]RE: 1A-28(PTD 191-002) Sundry 1 Has anything changed? From: Guzman, Diana [mailto:Diana.Guzman@conocophillips.com] Sent: Wednesday,June 03, 2015 4:45 PM To: Loepp, Victoria T(DOA) Subject: 1A-28 (PTD 191-002) Sundry Good afternoon Victoria, A sundry for 1A-28(PTD 191-002)was submitted and approved last year(August 5, 2014).The workover schedule changed and now it's scheduled for August 8, 2015. Do you want me to submit a new sundry application?Or is there an extension process for the current sundry? Please let me know how you would like me to proceed. Thank you for your time. Sincerely, Diana Guzman Senior Wells Engineer ConocoPhillips Alaska Inc. Drilling&Wells 700 G Street(ATO-1502) Anchorage,AK 99501 Main:907-265-6318 Cell:305-332-6332 Fax:918-662-1893 2 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / q/- ~)~,~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Gmyscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .n· Logs 'of various kinds . [] Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell n TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si THE STATE Alaska OF Tk °f ALASKA Conservation CommiCommission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Jacob Voss sumo) NOV` 3 2013 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-28 Sundry Number: 313-368 Dear Mr. Voss: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this l day of August, 2013. Encl. STATE OF ALASKA •k /t J '' '\ AleA OIL AND GAS CONSERVATION COM•ION� APPLICATION FOR SUNDRY APPROVALS o Z113 20 AAC 25.280 p-rs g f/ I 1.Type of Request: Abandon r Plug for Redrill Perforate New Pool Repair well Ch `r,.' • Fk•gram Suspend p Plug Perforations �""° Perforate '� Rill Tubing `. Time Extension Operational Shutdown ( Re-enter Susp.Well Stimulate Alter casing , Other: t 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inca Development r;,-,-., Exploratory 191-002' 3.Address: Stratigraphic Service 6.API Number: ` P.O. Box 100360,Anchorage,Alaska 99510 50-029-22126-000 7.If perforating, ha4V 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1A-281 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 256524 Kuparuk River Field/Kuparuk River Oil Pool, 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10025 6499 9916' 6435' 9194' none Casing Length Size MD TVD Burst i Collapse CONDUCTOR 40 16 80' 80' SURFACE 5417 9.625 5452' 3883' PRODUCTION 9971 7 10006' 6488' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9330-9390,9619-9633,9649-9712 i 6104-6138,6266-6274,6283-63181 3.5 L-80 9207 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=9119 TVD=5982v PACKER-BAKER HB RETRIEVABLE PACKER MD=9246 TVD=60551 PACKER-TIW SS PERMANENT PACKER MD=9416 TVD=6152 NIPPLE-CAMCO DS NIPPLE MD=554 TVD-553 12.Attachments: Description Summary of Proposal IV 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch Exploratory F Stratigraphic Development 0 Service f 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/8/2013 Oil i✓ • Gas 3 WDSPL r Suspended 16.Verbal Approval: Date: VVINJ 1 GINJ )— WAG F Abandoned F Commission Representative: GSTOR F SPLUG F 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jacob Voss @ 265-6935 Email: Jake.Voss(aconocophillips.com Printed Name J ob Voss Title: Wells Engineer Signature f Phone:265-6935 Date 7/(.$7-3 Commission Use Only Sundry Number: " 1(/]ll Conditions of approval: Notify Commission sio(�'" so that a representative may witness llll//// �J Plug Integrity F BOP Test Mechanical Integrity Test r Location Clearance F , �/ Other: /� UP t taf rzSS e-t v G JJ 5 ( �? / v t Yl cf / htc,c) ByP .1-z 5 pr -55Lrt' /1 ,-. , tral fa GGO ps OY7 CLS�h RBDMS AUG - 2 2013 Spacing Exception Required? Yes ❑ No d/ Sbs eq uent Form Required: `r _ 4-e/) 1 / / APPROVED BY -�_�� Approved by ;� l�✓ ,A „{,e Ili' 0 MI ONER - TH OM ,ISSION Date: 8 Form 10-403(Revise.10/2012) !L Submit Form and Attachments in Duplicate 1 ,\9 7J3// 13 roi ft 1AI ///�� ��`t' • • July 15,2013 nEr EI V Commissioner Dan Seamount i/ State of Alaska a 2013 Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Ai 06 CC Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 1A-28(PTD: 191-002). Well 1A-28 was originally completed in 1991 as a Kuparuk A& C sand producer with a selective packer for the C-sand. The well has produced as a Kuparuk A and C sand producer until the well was shut in due to a suspected upper packer leak in February 2003. On July 30, 2003, a rig workover was performed on well 1A-28 to stack a packer above the upper selective packer. The well continued to produce until September 2011 due to TxIA communication discovered by a failed TIFL on 1/28/2011. On 2/5/2011 the well failed a MITxT. On 2/19/2011 the well failed as MITOA. On 4/4/2011, a leak detect log found a tubinglak in gas lift mandrel #3 (7,279' RKB). A surface leak around 300' RKB was confirmed on 11/14/2011. The objective of this workover is to pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement,tie in and cement a new 7"TC-II threaded production casing from the back off,and run a new 3 '/2"gas lift completion. If you have any questions or require any further information,please contact me at 265-6935 or Jake.Voss@conocophillips.com. Sincer , Jacob Voss Wells Engineer CPAI Drilling and Wells • • 1A-28 Rig Workover, Subsidence Repair (PTD #: 191-002) Current Status: The well is currently shut in awaiting RWO operations It has leaks in the tubing and surface casing. Scope of Work: Pull the existing gas lift completion, cut and pull the 7" production casing above the top of cement, tie in and cement a new 7" TC-II threaded production casing from the back off, and run a new 3 1/2" gas lift completion. General Well info: MASP: 2,484 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A, C-Sands— 3,110 psi /6,265' TVD (9.6 ppg EMW+ 125 psi Safety factor= 10ppg KWF) measured 6/18/2013 via SBHP (Dual Panex Gauges.) Wellhead type/pressure rating: McEvoy Gen IV, 7 1/16" 5M Top x 11" 3M Bottom BOP Configuration: Annular/7" Pipe Rams/ Blind Rams/ Mud Cross/Variable Pipe Ram MIT results: CMIT TxIA/DDT— Passed 9/23/2013/6/22/13 TIFL— Failed 1/28/2011 MITOA— Failed 2/19/2011 Well Type: Producer Estimated Start Date: August 8, 2013 Production Engineers: David Lagerlef/ Dana Glessner RWO Engineer: Jacob Voss Work: 265-6935 Cell: 832-499-9085 Email: Jake.Voss(p�conocophillips.com) • • Proposed Procedure: Pre-Rig Work: 1. Set BPV within 24 hours prior to rig arrival. RU,Test, Pull Tbq,and 7" Csg Evaluation 1. MIRU, Pull BPV. Circulate 10 ppg brine to kill well. 2. Install BPV. ND tree. 3. Install the blanking plug. NU BOPE. Test BOPE to 250/3,500 psi. 4. Pull the blanking plug. Pull the BPV. - 5. BOLDS, un-land tubing hanger, and pull to the floor. 6. POOH laying down tubing. Note: If tbg does not come free of PBR, RU HES E-Line and cut tbg in 1st full jt above PBR 7. MU and TIH w/7" csg scraper assembly on DP to the PBR. POOH standing back DP. LD csg scraper assembly. 8. RU E-Line. Log w/CAST-M. Locate TOC. RIH and fire string shot in first collar above TOC. POOH. RDMO E-line. 7" Csg Replacement 1. MU 7" RBP and set 500' below TOC. PT to 3000 psi and DDT the RBP. Dump sand, POOH w/DP 2. Monitor OA for flow. ND BOPE. Remove tubing head. Spear the 7" csg and re-land in tension. Cut off excess csg growth. NU the BOPE to the csg head. Note: BOPE is now acting as a diverter due to a surface csg leak at— 300 ft MD. BOPE will be pressure tested once the 7" csg has been removed. 3. MU and TIH w/Baker MSC. Cut the 7" casing above TOC. 4. Reverse circulate out the Arctic Pack from the OA with heated diesel. POOH with DP. 5. C/out lower BOPE pipe rams to 7" solid body. Function test rams on 7"test jt. Note: BOPE is now acting as a diverter due to a surface csg leak at— 300 ft MD. BOPE will be pressure tested once the 7"csg has been removed. 6. Spear the 7" csg and POOH laying down the 7" csg. 7. Set the test plug in the casing head. C/out lower BOPE pipe rams to VBRs. PT BOPE w/3-1/2" test jt to 250/3,000 psi. (limited by 3,000 psi casing head). Pull Test Plug 8. RIH with 9%" csg scraper to the 7" csg stub. Circ clean and POOH with DP. 5 9. Gauge the 9%" csg for the ES cementer with tandem string mills. POOH with DP. 10. Dummy drift the ES cementer. POOH with DP. 11. RIH with back off tool and back off the 7" csg stub. POOH with DP. 12. RIH w/spear and engage casing stub to retrieve fish. POOH with DP. 13. Set the test plug in the casing head. C/out lower BOPE pipe rams to 7" solid body. Function test rams on 7"test jt. 14. Run new 7"casing. PT the 7" casing to 2500 psi. 15. RU SLB cementers. Close pipe rams and open the annulus valve. Pressure up the casing to open the ES cementer. Cement the 7" casing to surface. 16. WOC. ND BOPE and land 7" on slips. Cut 7" csg and install packoff. NU tbg head and 11" 5M BOPE w/VBRs in bottom cavity. PT csg packoff to 3500 psi. PT break below tbg head to 3500 psi. Install test plug in tbg head and PT BOPE to 250/3500 psi for 30 min and record on chart. 17. RIH w/cement milling assembly and mill up cement, closing plug, and ES cementer. POOH with DP. 18. PT the csg to 250/2500 psi for 30 min and record on chart. ✓� 19. Mill remaining debris from the top of the sand. POOH with DP. 20. RIH with wash string and circulate sand out from on top of the RBP. POOH with DP. 21. RIH with RBP retrieving assembly. Retrieve RBP. POOH laying down DP. • . Run 3-1/2" Gas Lift Completion 1. Run new 3-1/2" gas lift completion. 2. Load tbg and IA w/diesel. Stab seal assembly into PBR and space out. 3. PT tubing to 3000 psi and IA to 2500 psi 30 min each and record on chart. 4. Install TWC. Pressure test IA to test TWC from below. 5. ND BOP stack, NU tree. PT tree and tubing hanger packoffs to 250/5,000 psi. 6. Remove TWC. Freeze protect well. Set BPV. 7. RDMO. Proposed Post-Riq Work: MIRU HES Slickline 1. Pull BPV. 2. Pull SOB from GLM and run GLD 3. Pull catcher. 4. Handoff to operations. T 1A-28 ConocoPhiIIips Subsidence RWO ■ i ■ DS Nipple, 2.875" @ 500' MD/500'TVD -411-- Cemented OA from TOC-Surface ( � iii Casing-7"26#, L-80 TC-II @-2,000' MD/1,825'TVD - Casing-9-5/8" 36#, J-55 BTC 1 - @ 5,452' MD/3,883'TVD C ., Gas Lift Mandrels: Tvae MD TVD MMG, 1" 3,340 2,650 MMG, 1" 5,665 4,000 MMG, 1" 7,280 4,900 I MMG, 1" 8,830 5,550 MMG, 1" 9,055 5,995 MMG, 1" 9,290 6,080 i PBR @ 9,105 MD/5,975'TVD -4-- Baker FHL Packer @ 9,119' MD/5,983'TVD •iif-- 2812" DS Nipple @ 9,194' MD/6,026'TVD f I Over Shot/Tubing Stub @ 9,201' MD/6,028'TVD �1 -4---- PBR @ 9,233' MD/6,057'TVD - f-- Baker HB Permanent Packer @ 9,247' MD/6,055'TVD nill L. 1E C 4, C 3, C 2, C 1 Pert @ 9,330, 9,390' _1111- Carbide Blast Rings @ 9,305' MD/6,089'TVD r: ttttt .;_: 4 Camco Sliding Sleeve(Open)@ 9,403' MD/6,147'TVD I 4 TIW Seal Assembly @ 9,414' MD/6,152'TVD . - 4 TIW SS Permanent Packer @ 9,416' MD/6,154'TVD TIW Seal Bore Extension @ 9,420' MD/6,156'TVD Tubing-3-Y2" 9.3#, L-80, 8rd EUE ► �- 2.25" D Nipple @ 9,490' MD/6,193'TVD 4 2.441" Shear Out Sub @ 9,502' MD/6,200'TVD A-5 @ 9,619'-9,633' -► A-4 @ 9,649'-9,712' -1/". Ai Casing-7"26#, L-80 @ 11,924' Date: July 10,2013 I Drawn By:Jacob Voss i KUP IA-28 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,If1c. Wellbore API/OW] Field Name Well Status Inc!(°) MD(ftKB) Act Btm(FMB) �,,�p 14� 500292212600 KUPARUK RIVER UNIT PROD 57.27 5,100.00 10,025.0 - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -- SSSV:NIPPLE 120 9/13/2010 Last WO: 8/10/2003 34.81 1/21/1991 Well Genfi9:-1A-28 2/28/20131'23.00 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,757.0 2/2/2011 Rev Reason:WELL REVIEW osborl 2/28/2013 HANGER,31 - Casing Strings IN Casing Description String 0... String ID...Top(FMB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.060 39.7 80.0 80.0 65.00 H-40 WELDED Y Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 11 9 SURFACE 95/8 8.921 35.0 5,452.3 3,882.5 36.00 J-55 BTC 1 I Casing Descrlption String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.0 10,005.5 6,487.8 26.00 J-55 BTC coNDUCTao80 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd TUBING 13 1/2 I 3.500 31.0 I 9,207.3 I 6,031.4 I 9.30 L-80 EUE MOD NIPPLE.554 ilL, Completion Details aill Top Depth (ND) Top Inc! Nomi... illi Top(ttKB) MKS) C) Item Description Comment ID(in) GAS LIFT 32 W, 31.0 31.0 0.44 HANGER CAMERON TUBING HANGER 4.500 33.9 33.9 0.44 XO Reducing CROSSOVER 4.5x3.5" 3.500 ® 554.1 553.1 8.14 NIPPLE CAMCO DS NIPPLE 2.875 I 9,105.4 5,975.3 55.48 PBR BAKER 80-40 PBR 3.000 9,119.1 5,983.0 55.43 PACKER BAKER FHL PACKER 3.000 9,194.2 6,025.6 55.17 NIPPLE CAMCO DS NIPPLE 2.812 SURFACE, 9,201.3 6,027.7 53.59 OVERSHOT UNIQUE POORBOY OVERSHOT 3.750 35-5,452 Tubing Description String 0... String ID...Top(RKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd I. TUBING Original 3 1/2 2.992 9,204.4 9,502.7 6,200.1 9.30 L-80 BTC-MOD GAS LIFT. 3.5x2.875" 5,667 in Completion Details IIIII Top Depth (WD) Top Incl Nomi... Top(RKB) (RKB) Cl Item Description Comment ID(in) GAS LIFT, F - 9,232.7 6,046.7 53.97 PBR BAKER PBR w/10'STROKE 3.000 zz7s P 9,246.4 6,054.9 54.14 PACKER BAKER HE RETRIEVABLE PACKER 2.870 - 9,304.9 6,089.2 54.86 BLAST RINGS CARBIDE BLAST RINGS(3) 2.992 MI 9,402.8 6,146.5 57.64 SLEEVE-O CAMCO CB-1 SLIDING SLEEVE;OPENED 6/15/01 2.812 GAS LIFT, 9,413.5 6,152.1 57.52 SEALASSY TIW LOCATOR SEAL ASSEMBLY 3.011 8,383 MI 9,416.4 6,153.7 57.49 PACKER TIW SS PERMANENT PACKER 4.000 El 9,420.1 6,155.6 57.45 SBE TIW SEAL BORE EXTENSION 4.000 III 9,424.4 6,157.9 57.40 XO Reducing CROSSOVER 3.5 x 2.875,ID 2.441,#6.5,J-55,EUE-MOD 2.875 GAS LIFT 9,490.3 6,193.2 56.67 NIPPLE CAMCO D NIPPLE NO GO 2.250 9,055 Int 9,502.0 6,199.7 56.54 SOS BAKER SHEAR OUT SUB 2.441 MI Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) alli Top Depth Mil (ND) Top Inc! Top(MKS) )RKB) )) Description Comment Run Date ID(in) PBR.9.105 9,194.2 6,025.6 55.17 PLUG 2.81"CA-2 PLUG 9/23/2012 0.000 PACKER,9.119 ® Perforations&Slots PLUG.9,794 t�7; Shot NIPPLE,9,194 Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(FEB) IRKS) (ftKB) Zone Date (sh... Type Comment OVERSHOT, I 9,330.0 9,370.0 6,103.5 6,126.2 C-4,C-3,C-2, 6/5/1991 10.0 IPERF HLS 4.5"Casing Gun 1A-28 9,201 Ili 1 9,370.0 9,390.0 6,126.2 6,137.5 C-2,C-1,1A-28 6/5/1991 5.0 IPERF HLS 4.5"Casing Gun PBR,9.233 M= 9,619.0 9,633.0 6,265.7 6,273.5 A-5,1A-28 6/5/1991 4.0 IPERF HLS4.5"Casing Gun PACKER,9,246 _ 9,649.0 9,712.0 6,282.5 6,318.0 A-4,1A-28 6/5/1991 4.0 IPERF HLS 4.5"Casing Gun ink Notes:General&Safety End Date Annotation PRODUCTION, 12/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 9,290 IPERF, 9,330-9,370 IPERF, 9,370-9,390 ....._ SLEEVE-O, . 9,403 I SEAL ASSY, 9,413 PACKER,9,416 SBE,9.420 •_ U III Mandrel Details NIPPLE.9.490 1.d. Top Depth Top Port M S... (ND) Ind OD Valve Latch Size TRO Run N...Top(ftKB) (RKB) I°) Make Model (in) Sery Type Type (In) (psi) Run Date Corn... SOS.9,502 1 3,338.0 2,647.5 50.02 CAMCO KBUG-M 1 GAS LIFT DMY BK-5 0.000 0.0 2/2/2011 2 5,666.8 4,000.3 56.97 CAMCO KBUG-M 1 GAS LIFT DMY BK-5 0.000 0.0 2/2/2011 3 7,279.2 4,907.3 54.79 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 9/22/2012 Ext 2kg 9.61 IPERF. 4 8,382.9 5,552.5 54.05 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 8/10/2003 IPERF, 5 9,054.5 5,944.8 54.25 CAMCO KBUG-M 1 GAS LIFT DMY BK 0.000 0.0 8/12/2003 9sas-x,712 �. 6 9,290.4 6,080.8 54.68 MERLA TGPDC 1 1/2 PROD DMY RK 0.000 0.0 6/14/1996 Closed PRODUCTION, 35-10.006N TD,10.025 4. • WELL LOG C.,...N11111W3S TRANSMITTAL pa PROAc1ivE DiAgNOSric SERVICES, INC. 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 Anchorage, AK 99518 874 MA E Fax: (907) 245 -8952 2 3 201 19 ( -ooh 3()9 1) Leak Detection - WLD 04-Apr-11 14,28 EDE ' • REdrIVE 2) APR 1 2011 Signed : C Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PH0NE: (907)245 -8951 FAx: (907)245$8952 C:\Documents and Settings \Diane Williams \Desktop \CPAI_Transmit.docx • • WELL LOIN TRANSMITTAL PROACTVE DIAGNOSTIC SERVICES, INC. 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 )f,il 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 08- Feb-11 1A-28 1 Report / EDE 50 -029- 22126 -00 2) lg / —bd FEB RECEIVED 2011 Signed : ( � k Date : Print Name:' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 Fax: (907)245 - 88952 E -MAIL : pdsanchoraae(Wmemorvloa.com WEBSITE : wwW.memorvloq.COm C:\Documents and Settings\Diane Williams \Desktop \Transmit_Conoco.docx 1 s • Memory Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1A -28 Log Date: February 8, 2011 Field: Kuparuk 1 Log No.: SO # 10258302 ZX70 State: Alaska Run No.: 1 API No.: 50-029-22126-00 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvil.: 9,190 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to the Tubing Tally Record. This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and liner logged appear to be in good condition with respect to 1 corrosive and mechanical damage, with a maximum recorded wall penetration of 22% wall thickness and no other significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions recorded. This summary report is interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: 1 Isolated Pitting ( 22 %) Pup Jt. 230.3 @ 7,288 Ft. (MD) No other significant wall penetrations (> 16 %) are recorded throughout the interval logged. 1 MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall Toss (> 9 %) are recorded throughout the tubing and liner logged. 1 MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. 1 1 I Field Engineer: D. Schwarzenberger Analyst: J. Thompson Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431 -7100 Fax: (281) 431 -7125 E -mail: PDS©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 1 -vba oj-9-6-6 1 • • 1 PDS Report Overview J61 Body Region Analysis I Well: 1A -28 Survey Date: February 8, 2011 Field: Kuparuk Tool Type: UW MFC 24 No 10000429 Hal Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE MOD Analyst: J. Thompson Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) 400 IIIMI Penetration body IMO Metal Toss body 0 50 100 1 _ 1 300 = 1 200 1 100 49 =, 0 I 0 to 20 to 40 to over 20% 40% 85% 85% 99 -, Number of joints analysed (total = 303) GLM 1 __ I 302 1 0 0 147 1 Damage Configuration ( body ) 40 M GLM 2 I 30 195 -:1 —.. 20 I .4 ' 10 GLM 3 243 0 I Isolated Geneva! Line Other Hole/ G 4 Pitting Corrosion Corrosion Damage Pos. He GLM 5 287 I Number of joints damaged (total = 40) 40 0 0 0 0 Bottom of Survey = 289 1 1 1 1 1 • • Correlation of Recorded Damage to Borehole Profile I Pipe 1 3.5 in (38.5 - 9163.3') Well: 1A-28 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: February 8, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 39 25 809 I 50 1591 75 2367 1 GLM 1 100 3147 I 125 4 3945 150 4725 1 . _ _ -..sill GEM 2 :- 175 5507 .S 200 •I 6307 a 1 'o a 0 GLM 3 225 __ i 7088 1 250 7878 GLM 4 - -�_ 275 = 8680 1 GLM 5 _� 289 9163 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 i Bottom of Survey = 289 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 EUE MOD WeIE: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 39 0 0.03 11 7 2.92 Lt. Deposits. 1.1 70 0 0.02 7 1 2.94 Pup 1.2 80 0 0.02 8 3 2.95 Pup 2 88 0 0.03 10 5 2.93 Lt. Deposits. • 3 119 0 0.03 12 4 2.94 • I 4 150 0 0.02 9 6 2.94 ■ 5 182 0 0.03 11 6 2.93 Lt. Deposits. ■ 6 213 0 0.03 10 4 2.94 • 7 245 0 0.02 9 6 2.94 ■ I 8 276 0 0.03 10 5 2.94 9 307 0 0.02 9 5 2.95 10 339 0 0.02 9 4 2.95 • 11 369 0 0.03 11 5 2.93 ■ I 12 400 0 0.02 9 4 2.93 13 432 0 0.02 9 5 2.93 14 463 0 0.02 9 4 2.94 • 15 494 0 0.03 11 6 2.94 , ■ I 16 526 0 0.03 11 6 2.92 Lt. Deposits. 16.1 557 0 0 0 0 2.87 XN Nipple 17 559 0 0.03 10 4 2.94 ■ 18 590 0 0.03 10 5 2.93 Lt. Deposits. • 19 621 0 0.03 13 7 2.94 Shallow Pitting. 1 I 20 653 0 0.03 11 5 2.94 ■ 21 684 0 0.02 9 5 2.94 ■ 22 715 0 0.02 9 5 2.94 • 23 747 0 0.03 10 6 2.93 Lt. Deposits. ■ I 24 778 0 0.02 9 5 2.94 ■ 25 809 0 0.03 11 6 2.94 • ■ 26 841 0 0.03 10 5 2.94 ■ 27 871 0 0.03 11 5 2.92 Lt. Deposits. • I 28 903 0 0.03 10 5 2.93 ■ 29 934 0 0.02 9 5 2.93 Lt. Deposits. ■ 30 965 0 0.03 10 6 2.93 Lt. Deposits. • 31 997 0 0.03 11 5 2.93 Lt. Deposits. • 32 1028 0 0.03 11 4 2.94 • I 33 1059 0 0.03 11 5 2.94 ■ 34 1091 0 0.04 14 6 2.91 Shallow Pitting. Lt. Deposits. ■ 35 1122 0 0.02 9 5 2.94 • 36 , 1153 0 0.03 10 6 2.94 ■ I 37 1185 0 0.03 10 5 2.93 • 38 1216 0 0.03 11 6 2.94 ■ 39 1247 0 0.02 9 5 2.94 ■ 40 1278 0 0.03 10 4 2.95 ■ I 41 1310 0 0.03 11 6 2.93 Lt. Deposits. ■ 42 1341 0 0.03 10 5 2.94 43 1373 0 0.02 8 5 2.95 44 1403 0 0.02 9 6 2.93 ■ 45 1434 0 0.03 11 6 2.93 Lt. Deposits. ■ I 46 1465 47 1497 0 0.03 10 6 2.94 0 0.03 11 6 2.94 rat I Metal Loss ion Body 1 Page 1 Penet 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %, (Ins.) 0 50 100 I 48 1528 0 0.02 9 5 2.93 Lt. Deposits. ■ 49 1559 0 0.03 10 7 2.93 50 1591 0 0.02 8 5 2.95 i 51 1622 0 0.02 9 5 2.91 Lt. Deposits. 52 1654 0 0.02 9 6 2.94 I 53 1684 0 0.04 14 5 2.94 Shallow Line of Pits. 11 54 1714 0 0.03 10 6 2.94 1 55 1745 0 0.02 9 6 2.93 Lt. Deposits. ■ 56 1775 0 0.03 11 6 2.95 ■ I 57 1807 0 0.03 13 6 2.93 Shallow Pitting. Lt. Deposits. ■ 58 1838 0 0.03 11 7 2.94 1 59 1870 0 0.02 9 6 2.94 ■ 60 1901 0 0.03 11 5 2.94 • I 61 1932 0 0.03 13 7 2.92 Shallow Pitting. Lt. Deposits. 62 1964 0 0.02 9 6 2.93 Lt. Deposits. 63 1995 0 0.02 7 2 2.94 64 2026 0.04 0.04 15 6 2.93 Shallow Pitting. Lt. Deposits. I 65 2055 0 0.02 8 2 2.95 66 2086 0 0.03 11 5 2.94 ■ 67 2118 0.18 0.03 10 5 2.93 ■ 68 2150 0 0.03 11 5 2.95 69 2180 0 0.02 8 3 2.94 3 I 70 2211 71 2242 0 0.02 8 2 2.96 0 0.02 9 4 2.94 72 2274 0 0.02 9 3 2.95 73 2306 0 0.03 10 4 2.94 I 74 2336 0 0.02 9 3 2.93 75 2367 0 0.03 10 3 2.95 • 76 2398 0 0.02 9 6 2.94 ■ 77 2430 0.04 0.03 12 6 2.94 78 2461 0 0.02 8 3 2.94 79 2493 0.04 0.02 9 3 2.95 • 80 2523 0 0.03 13 4 2.93 Shallow Pitting. ■ 81 2555 0.03 0.02 9 2 2.94 ■ 82 2586 0 0.03 10 6 2.94 I 83 2616 0 0.02 9 2 2.95 84 2648 0.04 0.02 7 2 2.95 85 2679 0 0.03 13 6 2.93 Shallow Pitting. Lt. Deposits. ■ 86 2710 0.03 0.03 10 6 2.94 ■ I 87 2741 0 0.03 10 3 2.92 Lt. Deposits. • 88 2773 0 0.03 11 3 2.93 Lt. Deposits. 89 2804 0 0.02 9 3 2.96 90 2836 0 0.02 9 1 2.96 • I 91 2866 0 0.02 9 4 2.93 92 2898 0 0.02 8 2 2.95 93 2928 0 0.03 11 6 2.94 ■ 94 2960 0 0.03 10 5 2.92 Lt. Deposits. 95 2991 0 0.02 9 2 2.91 Lt. Deposits. 96 3022 0 0.04 15 7 2.91 Shallow Line of Pits. Lt. Deposits. 97 3054 0 0.03 12 6 2.92 Shallow Pitting. Lt. Deposits. Penetration Body I Metal Loss Body 1 Page 2 1 1 • • PDS REPORT JOINT TABULATION SHEET , i Pipe: 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A-28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Mct,il Min. Damage Profile No. (Ft.) U % pset Body I oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 98 3085 0 0.03 10 6 2.94 ■ 99 3116 0 0.03 11 4 2.92 Lt. Deposits. • ■ 100 3147 0 0.02 9 2 2.93 Lt. Deposits. as 101 3178 () 0.03 10 5 2.93 Lt. Deposits. 102 3209 0 0.02. 9 4 2.91 Lt. Deposits. II 103 3241 0.03 0.03 11 3 2.91 Lt. Deposits. ■ 104 3272 0 0.02 9 2 2.93 Lt. Deposits. 105 3303 0 0.02 9 6 2.91 Lt. Deposits. 105.1 3335 0 0.02 8 2 2.89 Pup Lt. Deposits. I 105.2 3341 0 0 0 0 2.85 GLM 1 (Latch @ 2:00) 105.3 3348 0 0.02 8 2 2.89 Pup Lt. Deposits. 106 3354 0 0.02 9 6 2.93 107 3385 0 0.02 8 2 2.93 Lt. Deposits. I 108 3416 0 0.02 9 6 2.92 Lt. Deposits. II 3447 0 0.03 10 4 2.93 Lt. Deposits. • ■ 110 3479 0 0.02 9 2 2.92 Lt. Deposits. ■ 111 3509 0.03 0.03 10 4 2.93 • 112 3540 0 0.03 12 6 2.93 Lt. Deposits. ■ I 113 3572 0 0.03 13 7 2.92 Shallow Pitting. Lt. Deposits. ■ 114 3603 0.03 0.03 10 4 2.93 Lt. Deposits. , 115 3633 0.05 0.02 8 13 2.92 Lt. Deposits. 116 3665 0 0.03 13 6 2.92 Shallow Pitting. Lt. Deposits. I 117 3695 0.03 0.02 8 2 2.93 Lt. Deposits. 118 3726 0 0.03 13 6 2.93 Shallow Pitting. Lt. Deposits. ■ 119 3758 0 0.02 9 2 2.92 Lt. Deposits. IN 120 3789 0 0.03 12 6 2.92 Shallow Pitting. Lt. Deposits. I 121 3821 0 0.02 8 2 2.93 Lt. Deposits. 122 3852 0 0.02 8 3 2.94 123 3883 0 0.03 11 5 2.92 Lt. Deposits. ■ 124 3914 0 0.03 12 4 2.94 Shallow Pitting. I 125 3945 126 3976 0 0.02 7 2 2.93 Lt. Deposits. 0 0.02 9 5 2.90 Lt. Deposits. 127 4008 0.03 0.02 9 2 2.94 ■ s 128 4038 0.03 0.02 9 2 2.94 129 4069 0 0.04 14 7 . 2.92 Shallow Pitting. Lt. Deposits. 1 I 130 4101 0 0.02 9 2 2.92 Lt. Deposits. is 131 4132 0.03 0.03 10 3 2.92 Lt. Deposits. • 132 4163 0 0.03 10 2 2.92 Lt. Deposits. ■ 133 4194 0 0.02 9 4 2.90 Lt. Deposits. • P 134 4226 0 0.03 12 6 2.93 Lt. Deposits. 135 4257 0 0.02 8 2 2.93 Lt. Deposits. 136 4288 0 0.03 11 2 2.93 Lt. Deposits. ■ 137 4320 0 0.02 9 6 2.92 Lt. Deposits. I 138 4351 0 0.02 7 4 2.95 139 4382 0 0.01 5 1 2.94 140 4414 0.03 0.02 9 5 2.93 Lt. Deposits. 141 4445 0 0.03 10 5 2.94 142 4477 0 0.02 7 2 2.94 I 143 4507 0 0.03 12 6 2.94 Shallow Pitting. 144 4539 0 0.02 7 4 2.94 ration Body I Metal Loss Body Page 3 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4571 (.) 0.02 9 1 2.95 J 146 4600 0 0.03 10 5 2.94 147 4632 0 0.02 8 2 2.92 Lt. Deposits. 148 4663 0.0 i 0.03 12 6 2.96 Shallow Pitting e 149 4694 0 0.02 9 2 2.93 Lt. Deposits. ■ 150 4725 0 0.03 11 7 2.93 Lt. Deposits. J 151 4757 0 0.02 8 2 2.93 Lt. Deposits. 152 4788 0 0.03 12 7 2.91 Shallow Pitting. Lt. Deposits. 153 4820 0 0.02 9 3 2.94 il I 154 4851 0 0.02 9 2 2.93 Lt. Deposits. ■ 155 4882 0 0.03 11 6 2.92 Lt. Deposits. 1 156 4914 0.03 0.03 12 5 2.94 157 4945 0 0.02 7 2 2.94 I 158 4976 0 0.02 9 4 2.94 159 5006 0 0.03 10 6 2.94 160 5038 0 0.02 9 5 2.93 Lt. Deposits. 161 5069 0.04 0.02 9 5 2.92 Lt. Deposits. I 162 5099 0 0.02 9 5 2.93 Lt. Deposits. 163 5131 0 0.02 6 2 2.94 164 5162 0 0.03 12 6 2.92 Lt. Deposits. 165 5194 0 0.01 6 2 2.94 166 5225 0 0.03 11 7 2.94 I 167 5256 0 0.01 6 2 2.87 Lt. Deposits. 168 5287 0 0.03 11 6 2.90 Lt. Deposits. 169 5319 0 0.02 7 2 2.93 Lt. Deposits. 170 5350 0 0.01 6 2 2.93 Lt. Deposits. I 171 5381 0 0.02 9 5 2.91 Lt. Deposits. 172 5413 (1 0.03 11 6 2.94 173 5445 0 0.02 7 4 2.93 174 5476 0 0.01 6 2 2.93 I 175 5507 0 0.01 6 1 2.93 176 5538 0 0.02 7 2 2.94 177 5570 0 0.02 7 4 2.92 Lt. Deposits. 178 5600 0 0.03 11 6 2.92 Lt. Deposits. ■ 179 5632 0 0.02 9 4 2.93 179.1 5662 0 0.02 7 2 2.90 Pup Lt. Deposits. 179.2 5667 0 0 0 0 2.86 GLM 2 (Latch CP 3:00) 179.3 5676 0 0.01 5 2 2.89 Pup Lt. Deposits. 180 5681 0 0.03 10 6 2.94 i I 181 5712 0 0.02 , 9 6 2.93 Lt. Deposits. u 182 5744 0 0.02 9 3 2.93 183 5775 0 0.01 6 2 2.92 Lt. Deposits. 184 5807 0 0.02 8 4 2.90 Lt. Deposits. 185 5838 0 0.02 9 6 2.93 Lt. Deposits. I 186 5868 0 0.04 14 7 2.91 Shallow Pitting. Lt. Deposits. 187 5900 0 0.02 , 9 2 2.93 Lt. Deposits. 188 5932 0 0.03 11 7 2.93 Lt. Deposits. I 189 5963 0 0.02 7 2 2.93 190 5994 0 0.03 10 6 2.95 191 6026 0 0.02 7 2 2.91 Lt. Deposits. Penetration I Metal Loss Body Page 4 Penetra 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: : 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 8, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 192 6056 0 0.03 11 6 2.93 Lt. Deposits. 193 6088 0 0.02 7 1 2.94 194 6119 (1 0.01 6 1 2.94 195 6150 0 0.02 8 4 2.91 Lt. Deposits. 196 6182 0 0.01 6 2 2.94 ' 197 6213 198 6244 0 0.02 7 2 2.94 0 0.03 10 b 2.92 Lt. Deposits. ■ 199 6276 0 0.02 9 5 2.94 200 6307 0 0.02 7 2 2.94 I 201 6338 0 0.02 7 2 2.94 202 6369 0 0.02 7 4 2.93 203 6399 0 0.03 10 5 2.94 204 6430 0 0.02 8 5 2.90 Lt. Deposits. I 205 6463 0.03 0.02 8 4 2.92 Lt. Deposits. 206 6494 0 0.02 9 6 2.94 ■ 207 6525 0 0.03 10 3 2.94 1 208 6557 0 0.01 6 2 2.92 Lt. Deposits. I 209 6587 0 0.02 9 5 2.91 Lt. Deposits. 210 6618 0 0.03 10 4 2.93 ■ 211 6648 0.03 0.03 13 8 2.91 Shallow Pitting. Lt. Deposits. i 212 6680 0 0.03 10 6 2.93 1 213 6711 0 0.03 11 7 2.94 1 I 214 6742 0 0.03 11 7 2.93 215 6774 0 0.03 10 4 2.91 Lt. Deposits. i 216 6805 0 0.02 7 3 2.93 Lt. Deposits. 217 6835 0 0.03 11 5 2.92 Lt. Deposits. ■ I 218 6867 0 0.02 9 6 2.93 Lt. Deposits. 219 6899 0 0.02 8 6 2.92 Lt. Deposits. 220 6931 0 0.02 8 4 2.93 Lt. Deposits. 221 6961 0.03 0.04 16 5 2.90 Shallow Line of Pits. Lt. Deposits. il I 222 6993 0.03 0.03 10 2 2.93 Lt. Deposits. 223 7025 0 0.02 7 2 2.94 224 7056 0 0.02 6 4 2.91 Lt. Deposits. 225 7088 0 0.01 6 2 2.93 226 7118 0 0.02 7 2 2.94 I 227 7148 0 0.02 7 4 2.90 Lt. Deposits. 228 7181 (1 0.02 7 1 2.94 229 7211 0 0.03 12 6 2.94 Shallow Pitting. ■ 230 7243 0 0.02 9 6 2.91 Lt. Deposits. ■ I 230.1 7274 0 0.02 9 2 2.86 Pup Lt. Deposits. 230.2 7280 0 0 0 0 2.85 GLM 3 (Latch @ 2:00) 230.3 7287 0 0.06 22 4 2.87 Pup Isolated Pitting. Lt. Deposits. • 231 7293 0 0.03 11 6 2.92 Lt. Deposits. ■ I 232 7324 0 0.04 15 5 2.88 Shallow Line of Pits. Lt. Deposits. • 233 7356 0 0.03 11 5 2.89 Lt. Deposits. • ■ 234 7386 0 0.03 11 6 2.90 Lt. Deposits. ■ 235 7417 0 0.03 11 6 2.91 Lt. Deposits. I 236 7447 0 0.02 8 5 2.91 Lt. Deposits. 237 7477 0 0.03 13 7 2.88 Shallow Pitting. Lt. Deposits. 238 7506 0 0.03 11 5 2.90 Lt. Deposits. t Body I Metal Loss ion Body 1 Page 5 Penetra 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 239 7538 0 0.03 13 5 2.90 Shallow Pitting. Lt. Deposits. Ii 7569 0 0.03 10 6 2.89 Lt. Deposits. ■ 241 7598 0 0.03 11 6 2.91 Lt. Deposits. ■ 242 7628 0 0.03 11 5 2.90 Lt. Deposits. 243 7660 0 0.02 8 5 2.90 Lt. Deposits. I 244 7691 0.03 0.03 10 4 2.91 Lt. Deposits. 245 7722 0 0.02 8 4 2.87 Lt. Deposits. 246 7754 0 0.03 12 5 2.90 Shallow Pitting. Lt. Deposits. • 247 7784 0 0.03 10 5 2.90 Lt. Deposits. ■ I 248 7815 0 0.02 9 4 2.91 Lt. Deposits. • 249 7847 0 0.03 10 3 2.91 Lt. Deposits. ■ 250 7878 0 0.03 12 7 2.91 Shallow Pitting. Lt. Deposits. 1 251 7910 0 0.03 12 6 2.92 Shallow Pitting. Lt. Deposits. ■ I 252 7941 0 0.03 12 8 2.92 Lt. Deposits. i 253 7972 0 0.03 12 3 2.91 Lt. Deposits. • 254 8004 0 0.03 13 7 2.91 Shallow Pitting. Lt. Deposits. t 255 8035 0 0.02 9 3 2.92 Lt. Deposits. • ' 256 8066 0 0.03 11 5 2.90 Lt. Deposits. ■ 257 8097 0 0.03 11 5 2.90 U. Deposits. iii 258 8129 0 0.03 12 8 2.91 Shallow Pitting. Lt. Deposits. 1 259 8161 0 0.03 10 4 2.90 Lt. Deposits. • 1 260 8192 0 0.03 11 4 2.90 Lt. Deposits. II 261 8222 () 0.03 13 7 2.88 Shallow Pitting. Lt. Deposits. 262 8253 0 0.03 12 8 2.88 Lt. Deposits. i 263 8285 0 0.03 13 4 2.89 Shallow Pitting. Lt. Deposits. ■ 264 8315 0 0.03 10 6 2.90 Lt. Deposits. ■ I 265 8346 0 0.03 10 4 2.93 Lt. Deposits. 265.1 8378 0 0.01 5 2 2.89 Pup Lt. Deposits. 265.2 8383 0 0 0 0 2.86 GLM 4 (Latch @ 9:00) 265.3 8391 0 0.02 7 4 2.87 Pup Lt. Deposits. I 266 8396 0 0.03 10 4 2.90 Lt. Deposits. • 267 8428 0.04 0.03 12 7 2.92 Lt. Deposits. ■ 268 8459 0 0.02 9 2 2.93 Lt. Deposits. • 269 8491 0 0.03 11 6 2.92 Lt. Deposits. 270 8523 0 0.02 8 3 2.91 Lt. Deposits. I 271 8555 0 0.02 9 3 2.90 Lt. Deposits. 272 8585 0 0.03 12 5 2.91 Lt. Deposits. 273 8618 0 0.02 9 5 2.91 Lt. Deposits. 274 8648 0 0.03 13 7 2.89 Shallow Pitting. Lt. Deposits. I 275 8680 0 0.02 9 4 2.90 Lt. Deposits. 276 8711 0 0.03 13 6 2.91 Shallow Pitting. Lt. Deposits. ■ 277 8743 0.04 0.04 15 9 2.86 Shallow Pitting. Lt. Deposits. i 278 8774 0 0.03 11 (i 2.90 Lt. Deposits. ■ I 279 8803 0 0.03 122 2.88 Lt. Deposits. • 280 8835 0 0.03 12 9 2.89 Lt. Deposits. 281 8866 0 0.02 9 4 2.90 Lt. Deposits. • 282 8897 0 0.03 12 5 2.89 Shallow Pitting. Lt. Deposits. • I 283 8927 0.04 0.03 13 0 2.88 Shallow Pitting. Lt. Deposits. ■ 284 8958 0 0.03 12 7 2.85 Lt. Deposits. 285 8988 0 0.03 12 9 2.86 Shallow Pitting. Lt. Deposits. Penetration Body I ..= Metal Loss Body Page 6 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE MOD Well: 1A -28 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: February 8, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 286 9017 0.04 0.02 8 3 2.90 Lt. Deposits. 286.1 9048 0 0.03 10 6 2.86 Pup Lt. Deposits. 286.2 9055 0 0 0 0 2.85 GLM 5 (Latch @ 3:00) 286.3 9061 0 0.01 6 2 2.87 Pup Lt. Deposits. 287 9067 0 0.03 10 4 2.89 Lt. Deposits. I 287.1 9098 0 0.02 9 2 2.89 Pup Lt. Deposits. 287.2 9105 0 0 0 0 2.92 PBR 287.3 9115 0 0 0 0 2.86 Packer 287.4 9126 0 0.02 9 3 2.87 Pup Lt. Deposits. I 288 9132 289 9163 0 0.03 10 3 2.91 Lt. Deposits. 0 0.02 9 2 2.91 Lt. Deposits. I Penetrat Body Metal Loss ion Body 1 1 1 1 1 1 1 1 1 Page 7 1 1 1 • • 1 PDS Report Cross Sections I Well: 1A -28 Survey Date: February 8, 2011 Field: Kuparuk Tool Type: UW MFC 24 No 10000429 Hal Company: ConocoPhillips Alaska Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 EUE MOD Analyst: J. Thompson 1 1 Cross Section for Joint 230.3 at depth 7288.1 70 ft Tool speed = 61 Nominal ID = 2.992 I Nominal OD = 3.5 __ Remaining wall area = 96% --0' Tool deviation = 53° i I / 1 1 1 1 1 _, I Finger = 19 Penetration = 0.056 ins Isolated Pitting 0.55 ins = 22% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 I (" KUP 1A -28 ConocoPhillips Il ' - 4 - n ttr yes Angle SMD TD 'dv'BNbor, ARNJ'WI � gNtl 1YMa plied Statue I ErI(t hcl t °) NO (tie. B' Frirt Ast eh (rtK Edit CuiPaP�1:Fe 500292212600 KUPARIJK RIVER UNIT PROD 57.27 5,100.0 10,025. Comnent 'Edit Mtf t l mb Ed t Annottion la" Doi 9/10/200Y - KB•GIV 3,t(It) Rig Release Edit SSSV: NIPPLE 100 8!6120 Las[ W0: 8110200 34 121119 ••. ','xTieT T.,� pnnoytlon Depth MK B) Bid Calf fin Annotation Lo.l Mod ... 010 DEAR _ Last Tag:9LM 9,757.0 221 n Rev Reason: TAG, GLV C /0. Set Plug/Catcher Imosbor 217 IAIOEII, 31 Casing Strings Cann° Gelenpton Siring OD.. String ID... Top 11/ B) Set Depth (1._ set Depth(TvD)... String Wt.. String... String Tope I/ 44411114{4 {1 {1141, ' CONDUCTOR 16 15.060 39.7 80.0 80.0 65.00 H40 WELDED (' Casing Delerlptian SMng OD.. String 10 ... Top (tth; B) Set Depth if_ Set Depth fTv O)... String Wt. String._ String Tap Tll SURFACE 9518 5.921 35.0 5,452.3 3,882.5 36.00 J-55 BTC Calmg Delcnpti0n Siang OD.. Stang ID... Top jTH(B) Set Dept it.. Set Depth it String Yet- Stang... Sting Top 111 PRODUCTION 7 6.151 35.0 10,005.5 6,487.8 26.00 J-55 ETC COYPU O� Tibltl Strings I/ Tubing D[ tertption Bang OD..lettnng ID... Top iltl1B/ eetCcptr1 it_ eet De T:D)... Ilttn7WL.. S8ing.. StnnOTapnl TUBII .1 3 12 3.500 31.0 9, 207.3 6,031.4 9 .30 L20 EUE M NIP- LE, 05* Completion DetatlS Top DepO) Top 11201 Top 62 Horn I... i ttK8) j1MK61 i'1 Rem N.M. Comment IGlini G+..3 31.0 31.0 0.44 HANGER CAMERON TUBING HANGER 4.500 I 339 33.9 0.44 XO Reducing CROSSOVER 4.523.5" 3.500 554.1 553.1 8.14 NIPPLE CAMCO DS NIPPLE 2875 9,105.4 5,975.3 55.48 PBR BAKER 80-00 PBR 3.000 9,119.1 5,983.0 55.43 PACKER BAKERFHLPACKER 3.000 ' DUPE. +L 9,1942 6,025.6 55.17 NIPPLE CAMCO DS NIPPLE 2.812 E, CARPAL E, 9,201.3 6,027.7 53.59 OVERSHOT UNIQUE POORBOY OVERSHOT 3.750 Tubing De .rrlpaon Sting OD.. Sting ID... Top (ItKB) Set Depth (1.. Set Depth (TVD)... ailing Wt.. Sting.,. Sting Top lllE[ TUBING Original 312 2.992 9,204.4 9,502.5 6,200.1 9.30 680 BTC -tId[r IA wo 1 . 26 7 ; I 3.582375" Completion Details IEda ' Top Depth Top iflD) Top Intl NORIL„ i ttK:B) ittIB/ i °i item toecap ID(In) ` 'i� -r ^e � 9,232.7 6,046.7 53.97 PBR BAKER PBR wt 10 STROKE 3.000 9,246.4 6,054.9 54.14 PACKER BAKER HB RETRIEVABLE PACKER 2.870 IIMMOMI ' 9,304.9 6,089.2 54.86 BLAST RINGS CARBIDE BLAST RINGS 2.992 81 9,442.8 6,146.5 57.64 SLEEVE -0 CAMCO CB-1 SLIDING SLEEVE; OPENED 6/15/01 2.812 9,413.5 6,152.1 57.52 SEALRSSY TIW LOCATOR SEALASSEMBLY 3.011 miem 9,416.4 6,153.7 57.48 PACKER TIW SS PERMANENT PACKER 4.000 ■ 9,420.1 6,155.6 57.45 SBE TIW SEAL BORE EXTENSION 4.000 i 4166/7, 9,424.4 6,157.9 57.40 X0 Reducing CROSSOVER 3 .5o2.875,1D2.141,96.5,J-55,EUE -MOD 2.875 9.055 9,490.3 6,193.2 56.67 NIPPLE CAMCO D NIPPLE NO GO 2.230 9,502.0 6,199.7 56.54506 BAKER SHEAR OUT SUB 2.441 Other ki Hole (4UIetine retrievable plugs, valves, puns, fish, etc.) 'Edit Tap Dept) I -11,92101 Top (Tv D) Top ) hel I i jith:Bl oB ,crlpllon �Umment tun Dote IDiln) "!ALE " • 9 ,1920 6,024.4 55.18 CATCHER AVA CATCHER 222011 0.000 9.119 ;[;eil; ^,.`,e 9,1942 6,025.6 55.17 PLUG 2.81 "CA2 PLUG 222011 0.000 CATCHER, P LUG, 9,194 Perforations 8 Slots It 0E1 ■1P • LE, 9.194 P-1.. [ SIIOt Bea Top (ND) Beni (ND) Dent r Top (ttK8) (MB) (tt681 MK Ell one Date IA-- TIP. C0mment OVEP 9 ( 1 � 9,330.0 9,370.0 6,103.5 6,126.2 C-4, C-3, C-2, 6/5/1991 10.0 IPERF HLS 4.5" Casing Gun f �' 1-226 9,370.0 9,390.0 6,128.2 6,137.5 C-2, C -1, 1A -28 615/1991 5.0 IPERF HLS 4.5" Casing Gun PIP..213 P,.ceEP 9,619.0 9,633.0 6,265.7 6,273.5 AS, 1.0-28 6/5/1991 4.0 IPERF HLS 4.5" Casing Gun s246 9,649.0 9,712.0 6,252.5 6,318.0 A4, 1.0,28 6/5/1991 4.0 IPERF HLS 4.5" Casing Gun Notes: General & Safety IEda PRODUCTION, B10 02t6 I Annotation 9" .' 1222010 NOTE: Mew Schematic w1.Jaska Schematic9.0 go'. EP', -. 9,P_D9, _ I IP EPf, 9,3rD9290 I OLEEVE0, 9 . . 'AO DEAL1L9 1 1', 9 ,.13 PACKER, 9,E OBE, 9,03 ) Mik Mandrel Details Edit IIPPLE,9,.90 liwlit. Top Depth Port U Top (TJO) Top O0 Lekn Slat Too Run Sin (ttK B) MB) helj•1 moo Model 110 . 1 SON Val ve Ttpe 7` (In 't (pelt RUn Data Dom... 330.9.502. i 3,338.0 2,647.5 50.02 CAM... KBUG 1 GAS LIFT DMY BK5 0.000 0.0 2/2/2011 2 5,666.5 4,000.3 56.97 CAM... KBUG 1 GAS LIFT DMY BKS 0.000 0.0 222011 3 7,2792 4,9073 54.79 GAM._ KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 2/52011 Ext... i 9419 IP 05 EPF, 11 ' - 4 8,2029 5,552.5 54.05 CAM... KBUG 1 GAS LIFT DMY 131( 0.000 0.0 6/(0/2003 5 9,054.5 5,944.8 54.25 CAM... KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/122003 IP EPf, 6 9,290.4 6,080.8 54.68 MERIA TGPDC 1 1/2 PROD DMY RK 0.000 00 6/14/1996 Clo... 94.9'9,71: 1 PROP UCTOI, 35-10=6'N TO, 10.025 1 • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 2- ° Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were performed between June 23, 2008 and August 24, 2008. The corrosion inhibitor/sealant was pumped on August 27, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, 1~ i~%~~ M.J. oveland ConocoPhillips Well Integrity Projects Supervisor *,;,..ftV~ SAP 200$ ~~ R ~ V ~' V i.~ 4/ SEP 0 2 2008 Afaska ~~_ & Gas Cons. Commission Anchorage • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 8/27/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-23 191-Ob9 12" na 12" na 6.80 8/27/2008 1A-24 200-1'81 6" na 6" na 2.55 8/27/2008 1A-28 191-002 8" na 8" na 1.70 8/27/2008 1 B-13 194-055 24" na 24" na 8.50 8/27/2008 1 B-15a 204-256 SF na SF na 8.50 8/27/2008 1 B-16 194-037 21' 8" 4.00 25" 8/24/2008 6.80 8/27/2008 1 B-17 194-045 6' 5" 1.00 28" 8/24/2008 5.10 8/27/2008 1 D-134 198-111 SF na SF na 2.55 8/27/2008 1 D-135 197-184 SF na SF na 1.70 8/27/2008 1 D-141 a 208-016 16' 1.40 3' 6/23/2008 9.35 8/27/2008 a v Schiumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description 08/06/08 N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 A-22 12097412 GLS 1 -CR) ~O ~' 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23/08 1 1 1A-22 12097413 PROD PROFILE ~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE - 07/24/08 1 1 1A-25 11996648 PROD PROFILE i 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26!08 1 1 1E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE 07/28/08 1 1 3J-10 12097408 SBHP SURVEY - 07/20/08 1 1 3M-28 12097411 SBHP SURVEY C .~ Q 07/21/08 1 1 1 L-15 11982443 PROD PROFILE '~ 07/06/08 1 1 30-08A 12080407 SBHP SURVEY ~~°. ipj~} - tg3 ~ (p~-(o 07/26/08 1 1 30-09 12080406 SBHP SURVEY /(®~~ 07/26/08 1 1 1L-24 11978468 PRODUCTION PROFILE f 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE • ~( ~ (p 07/29/08 1 1 30-ti 12100430 SBHP SURVEY -p~ 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 iH--~. `!f 12100434 INJECTION PROFILE UZ.C. / '3 {0 08/03/08 1 1 UGNU DS2-OBI 11996650 TEMPERATURE LOG j 07/27/08 1 1 2X-14 12100432 LDL a 08!01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 1 H-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~ Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPhilli ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 March 16, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 A-28 (APD # 191-002) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 A-28. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )/{J1~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED APR - 2 2004 Alaska on & Gas Cons. Commission Anchorage Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360. Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 31' 1. Operations Performed: Abandon Alter Casing STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 Suspend 0 Operation Shutdown 0 0 Repair Well 0 Plug Perforations 0 0 Pull Tubing 0 Perforate New Pool 0 4. Current Well Status: Development 0 Stratigraphic 0 5. Permit to Drill Number: 191-002/ 6. API Number: 50-029-22126-00 Perforate 0 Variance 0 Annular Disp. 0 Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 Exploratory 0 Service 0 9. Well Name and Number: 1A-28 8. Property Designation: ADL 25652, ALK 2578 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: 10. FieldlPool(s): Kuparuk River Field / Kuparuk Oil Pool measured 10025' 6499' feet feet true vertical Plugs (measured) Junk (measured) measured feet 9796' true vertical feet Length Size Collapse MD TVD Burst 80' 5382' 9969' 16" 9-5/8" 115' 5413' 10006' 115' 3861' 6488' 7" Measured depth: 9330'-9390',9619'-9633',9649'-9712' RECE IVED APR - 2 2004 Ataska on & Gas CUllS. CommisSion Anchorage true vertical depth: 6103'-6137',6265'-6273',6282'-6318' Tubing (size, grade, and measured depth) 3.5" /2-7/8", L-80 / J-55, 9409' /9503' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; Baker'HB'; TIW '55' pkr= 9119'; 9246'; 9416' SSSV= Cameo landing nipple nipple @ 554' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A .... 8FL AI' 0 C) 10°' 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl SI 495 CasinQ Pressure TubinQ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 3278 1351 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: oil0 GasD WAG 0 WDSPLD 270 Service 0 GINJD WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney NI J ¡I¿~ Wells Group Team leader Date dZz/o4 Preoared by Sharon AI/suo-Drake 263-4612 O~'G\NAL Title Phone Form 10-404 Revised 2/2003 . SUBMIT IN DUPLICATE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1A-28 1A-28 WORKOVER/RECOMP Nabors3SCompanyM@conoco Nabors 3S Start: 7/30/2003 Rig Release: 8/7/2003 Rig Number: Spud Date: 1/10/1991 End: 8/7/2003 Group: 7/30/2003 03:00 - 22:00 22:00 - 00:00 19.00 MOVE MOVE MOVE 2.00 WELCTL NUND DECOMP 7/31/2003 00:00 - 04:00 4.00 WELCTL NUND DECOMP 04:00 - 05:00 1.00 WELCTLCIRC DECOMP 05:00 - 06:00 1.00 WELCTL NUND DECOMP 06:00 - 08:00 2.00 WELCTL NUND DECOMP 08:00 - 11 :30 3.50 WELCTL NUND DECOMP 11 :30 - 12:00 0.50 WELCTL NUND DECOMP 12:00 - 14:00 2.00 WELCTL BOPE DECOMP 14:00 - 18:00 4.00 WELCTL BOPE DECOMP 18:00 -19:30 1.50 FISH RURD DECOMP 19:30 - 20:00 0.50 FISH SFTY DECOMP 20:00 - 21 :00 1.00 FISH RURD DECOMP 21 :00 - 22:00 1.00 FISH FISH DECOMP 22:00 - 22:30 0.50 FISH PULL DECOMP 22:30 - 23:00 0.50 FISH PULL DECOMP 23:00 - 00:00 1.00 WELCTL CIRC DECOMP 8/1/2003 00:00 - 02:00 2.00 WELCTL CIRC DECOMP 02:00 - 03:00 1.00 FISH PULD DECOMP 03:00 - 04:00 1.00 FISH RURD DECOMP 04:00 - 06:00 2.00 FISH PULL DECOMP 06:00 - 09:00 3.00 FISH PULL DECOMP 09:00 - 12:00 3.00 FISH PULL DECOMP Moving rig from 1 A-08 to 1 A-28 Accept rig. PJSM on ND & NU. Check well for pressure. Tubing & 4" x 7" annulus on vacuum. 7" X 9-5/8" annulus at 225 psi. RU kill line to 4" X 7" annulus to fill. Clean debris out of pits & prepare to put 150 Bbls of 9.6 ppg brine in pits (140 bbls used brine, 10 bbls new). Clean pits. Service choke manifold valves. Load 155 Bbls of 9.6 ppg brine into pits. RU lines to fill and circulate well. Tubing & IA on vacuum, OA 225 psi. PJSM. Pull BPV. Pump into tubing, until getting returns from annulus. Took 12 Bbls to fill well. Observe well - static. Set BPV. Blow down & rig down circulating lines. Nipple down tree. Attempted to screw 4" DSS-HTC crossover into hanger, made up about 2 turns and would go no further. Threads were corroded, as well as hanger neck. Hanger neck had been plastic packed, sometime past, and does not seal in tubing head adapter. THA also corroded. Cannot use 4" landing joint to test BOP's or to pull hanger, due to insufficient threads in hanger. Order test joint and doughnut to test BOP's, located at Nabors 4ES. Order fishing spear to pull hanger. Nipple up DSA & 13-5/8",5 Ksi BOP stack while waiting on fishing tools and test joint / doughnut. Pull BPV. Set 2-way check. PJSM. Ran in 3.5" test joint w/ doughnut to begin test on BOP stack - rigging up lines for same. Fill stack & choke lines. Begin pressure test on BOP stack - Test VBR's, blinds and Hydril (3000 psi) along with choke manifold to 250 psi & 4000 psi - state witness was waived by Lou Grimaldi. PJSM. Pull two way check. RU tools on floor to pull tubing. Bring in Baker spear and joint of 3-1/2" drillpipe. RU Camco spooling unit Took 30 minutes for rig walk through with fire Captain and 9 fire crew members for familiarization with rig and ingress/egresslrescue routes. Continued RU to spear & pull tubing. MU 4" spear with packoff. Work spear into 4" tubing below hanger and engage spear. BOLDS Pull tubing hanger to rig floor. Pulled free at 100K#, PU weight 80K#. Fill annulus with 5.5 Bbls. Fluids out of balance, flowing back out of tubing. RU circulating line to tubing and start circulating tubing and annulus volume to balance out fluid. Circulating 152 SPM, 2.7 BPM. 450 psi. Monitor OA pressure while circulating, 250 psi. Continue circulating one hole volume at 152 SPM, 2.7 BPM, 450 psi to 400 psi. No fluid loss while circulating. Monitor well, tubing and annulus static - well balanced. Break out and LD spear. LD joint of 3-1/2" drillpipe. RD DP tongs. LD 4" tubing hanger. Well static. RU tools & power tongs to pull 4" tubing. POOH LD 4", 11 #, J55, DSS-HTC Tubing, spooling up control line. Approx. 22 jts out at 0600, recovering about 1/2 of 55 control line bands. Pulled SSSV with control line birdnested with multiple wraps and bands around top of SSSV - lost a total of 7 bands downhole- continue pulling 4" tubing. Pulling @ approx. 17 joints an hour speed - 90 total joints pulled at Printed: 8/15/2003 12:40:38 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 A-28 1 A-28 WORKOVER/RECOMP , Nabors3SCompanyM@conoco Nabors 3S Start: 7/30/2003 Rig Release: 8/7/2003 Rig Number: Spud Date: 1/10/1991 End: 8/7/2003 Group: 8/1/2003 09:00 - 12:00 12:00 - 18:30 18:30 - 22:30 8/2/2003 22:30 - 00:00 00:00 - 01 :30 01 :30 - 12:30 3.00 FISH 6.50 FISH PULL DECOMP PULL DECOMP 4.00 FISH PULL DECOMP 1.50 FISH PULL DECOMP 1.50 FISH PULL DECOMP 11.00 CMPL TN PULD CMPL TN 12:30 - 13:30 1.00 CMPL TN RUNT CMPL TN 13:30 - 00:00 10.50 CMPL TN RUNT CMPL TN 8/3/2003 00:00 - 06:00 6.00 CMPL TN RUNT CMPL TN 06:00 - 12:00 6.00 CMPL TN PCKR CMPL TN 12:00 - 13:00 1.00 FISH PULL CMPL TN 12:00 - Pipe is in good shape with schmoo or parrafin on the outside. Continue pulling 3.5" pipe - appears to be free of corrosion - gas lift mandrels look good extemally. 175 total joints pulled @ 1830 hours. Continue POOH with 3-1/2" tubing. Light pitting/corrosion on GLM #2, between joints #142 & #143. Started seeing corrosion and pitting on couplings (only), starting below the crossover to 3-1/2", pipe bodies look good. Coupling corrosion got progressively worse. Coupling on jt #153 had noticeably deeper pits, on #187 parts of the top shoulder of the coupling were eaten away. GLM #3, between jts #194 & #195 had some scale build-up and more noticeable pitting/corrosion. There was a marked increase in scale on the pipe below there, especially around the couplings, more couplings with top shoulders partially eaten away. GLM #4, between jts #227 & #228 has deep pits and corrosion, especially at the top, corrosion has eaten through the top of the GLM exposing some of the pin end threads on the joint above it. Coupling on top of jt #227 has severe pitting and parts of top shoulder eaten away. Jts #228 & #229, below that GLM have scale, but scale is minimal to nil below there. Couplings continue to show pitting, though less severe. GLM #5, between jts #243 & #244 has minimal pitting, small amount of scale below pocket on bottom end of mandrel. Couplings continue to show some pitting, much less to no scale on pipe. GLM #6, between jts. #266 & #267 looks good, with little or no pitting. Recovered 12.98' stub from Jt #267, chemical cut left a small burr on opposite sides, but was otherwise clean. Cut is 3-1/2" OD, 4" OD on small burrs, Baker's 6" OD overshot will swallow the stub OK & should push aside the burrs on it easily. Unload 3-1/2" & 4" tubing and jewelry from pipe shed. Unload 3-1/2" & 4" tubing and jewelry from pipe shed. Break out bundles of new 3-1/2" tubing. Load tubing into shed & tally. Drift tubing: Jts #1-#226 to 2.867", Jts #227-#300 to 2.91", space out pups to 2.91". assured nipples were correct and checked GLM's for proper valves. Note: About 0800 hrs, another KRU Fire Crew came out to become familiar with rig, ingress, egress, and practiced a rescue. PJSM on completion safety and procedures - bring initial jewelry and BHA to rig floor. RU power tongs & rig floor for running tubing. RIH with completion as designed - well fluid level stable and tubing displacement volumes are correct during pipe running. 61 joints run @ 1800 hrs. 140 joints run @ 2230 hrs. 180 joints run @ 2400 hrs. Continue running 3-1/2", 9.3#, L-80, Mod-EUE tubing & jewelry. 281 joints run, about 10 left to run. Ran 8 more joints to #289 (approx. two joints above the stub to be overshot) - Driller picked up to check pipe weight and packer appeared to hang up - Driller continued to pull to 90k (string weight approx. 65k) with Baker rep. present and PBR appeared to shear - FHL packer appeared to be stuck or had set itself. Attempted to slack off slowly and sat down. Made many attempts at picking up and setting down to move packer - packer moved approx. 12' down during one slackoff. Attempted to reverse circulate but casing pressured up to 500 psi - Pulled out of PBR and reverse circulated well 400 bbls at 3 bpm rate. Returns dirty during bottoms up but no large corrosion or scale pieces. Made a final attempt at pushing packer downhole after circulating - able to sting into PBR but unable to move packer downhole Check torque rotation pressure while down on bottom - Gas lift Printed: 8/15/2003 12:40:38 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 A-28 1 A-28 WORKOVERIRECOMP Nabors3SCompanyM@conoco Nabors 3S Start: 7/30/2003 Rig Release: 8n /2003 Rig Number: Spud Date: 1/10/1991 End: 8n/2003 Group: 8/3/2003 12:00 - 13:00 1.00 FISH PULL CMPL TN mandrels stil on string caused slight excessive torque @ 1800 ft-Ib. 13:00 - 22:30 9.50 FISH PULL CMPL TN Start out of hole pulling doubles leaving pipe standing in derrick. POOH 143 stands & 1 single. LD GLMs and Baker seal assembly. Some scrapes on upper trash seal from brass shear pins on PBR, otherwise seal assembly looks good. Hole took proper fill on trip out. 22:30 - 00:00 1.50 FISH PULD CMPL TN RU floor to PU fishing tools. Bring fishing tools to rig floor & load 6 - 4-3/4" drill collars into pipe shed. Strap and caliper fishing tools & DCs. 8/4/2003 00:00 - 02:00 2.00 FISH PULD CMPL TN PU fishing tools. MU oil jar, bumper sub, & spear with 4" grapple on 4-3/4" DC. RIH, PU 6, 4-3/4" Drill Collars. MU crossover & 1 stand of 3-1/2" tubing. 02:00 - 07:00 5.00 FISH TRIP CMPLTN RIH with first stand. Break circulation to flush DC and fishing tool string. RIH with fishing assembly on 3-1/2" tubing from derrick. 07:00 - 10:00 3.00 FISH TRIP CMPL TN Continue running fishing assb. to 8993'. 10:00 -13:00 3.00 FISH CIRC CMPL TN Circulate 80 bbls 9.6# down tubing to assure spear was clear - well unbalanced - continue circulation all the way around to balance well 322 total bbls surface to surface. 165SPM, 2.9 BPM, 450 psi. 13:00 - 16:30 3.50 FISH JAR CMPL TN Latch fish @ 9034' (Nabors RT) with Baker internal spear - starting jarring @ 100K# and worked up to 140K# - 22 total licks to finally free packer. Started moving packer fish uphole - lost well balance and had to pump 18 bbl 9.8# heavy pill to rebalance well. Packer didn't appear to be set. Possibly stuck in junk. POOH with fish standing back doubles in derrick. String weight before fish 65K. String weight while POOH with fish 72K. 16:30 - 00:00 7.50 FISH PULL CMPL TN POOH with fish, standing back 3-1/2" tubing. Got to DCs @ 2400 hrs. 8/5/2003 00:00 - 03:00 3.00 FISH PULL CMPL TN POH, stand back DCs. LD spear with PBRlFHL Packer & pup. Stand back 2 joints tubing. LD nipple, pup, and Guide/Overshot. Recovered all of fish. No significant junk marks on PBRlPkr or poor boy overshot. Found two pieces 2" & 3" long, of mashed control line from SSSV caught between packer mandrel and top of packer body. 2 pieces of tubing 3-1/2" & 5" long, beside neck of RHC plug in 2.812" DS Nipple. Recovered an 18" piece of 1/4" SS tubing from inside Poor Boy overshot. 03:00 - 04:00 1.00 FISH PULD CMPL TN Bring 7" casing scraper, 2 boot baskets, and dressing mill tools to rig floor. Strap and caliper cleanout tools. 04:00 - 05:00 1.00 RIGMNT RSRV CMPL TN Service rig. Grease drivelines. 05:00 - 06:30 1.50 FISH PULD CMPL TN PU & MU 7" casing scraper, 2 boot baskets, & 3-1/2" stub dressing mill assy on bumper sub and oil jars. 06:30 - 17:00 10.50 FISH TRIP CMPL TN RIH with DCs. Continue RIH with 3-1/2" tubing. Change out seal rings on breaks. LD jt #17 (bad pin). Replace with jt #290. Continue RIH w/ 3-1/2" tubing. Change out seal rings on breaks. Trip in hole to 9014' RKB. 17:00 - 17:15 0.25 FISH RURD CMPL TN RU to circulate the long way down over fish. 17:15 - 23:00 5.75 FISH WASH CMPLTN Begin circulating down 7 stands above top of fish at 2 bpm. 9125' set down 3000 Ibs. Increase pump rate to 3 bpm and work past with no problem. Set down 5K-7K# at 9139', worked and washed through, 3.3 BPM, 500 psi. Tagged up at 9192' and again at 9197', top of stub and 5' over stub. Not able to rotate on or above stub at 2200 ft-Ib. With mill above stub. able to get some rotation at 2400 ft-Ib. but not over stub. Worked dressing mill up and down over stub 15 to 20 times to clean off burrs and verify position, ciculating at 166 SPM, 3 BPM. 75K# Up Wt, 40K# Down Wt. 23:00 - 00:00 1.00 FISH WASH CMPLTN Switch lines around and reverse circulate to clean hole. Reversed 1 + tubing volume about l' above stub, 166 SPM, 3 BPM, 350 psi. No Printed: 8/15/2003 12:40'38 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 A-28 1 A-28 WORKOVER/RECOMP Nabors3SCompanyM@conoco Nabors 3S Start: 7/30/2003 Rig Release: 8/7/2003 Rig Number: Spud Date: 1/10/1991 End: 8/7/2003 Group: 8/5/2003 8/6/2003 23:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 07:00 07:00 - 17:30 17:30 - 18:00 18:00 - 00:00 8nt2003 00:00 - 07:30 07:30 - 09:00 09:00 - 13:00 1.00 FISH 2.50 FISH WASH CMPLTN WASH CMPLTN 1.00 FISH WASH CMPLTN 3.50 FISH TRIP CMPL TN 10.50 FISH TRIP CMPLTN 0.50 CMPL TN RUNT CMPL TN 6.00 CMPL TN RUNT CMPL TN 7.50 CMPL TN RUNT CMPL TN 1.50 CMPLTN CIRC CMPLTN 4.00 CMPL TN PCKR CMPL TN significant change in returns at bottoms up. Slide down with mill about l' over stub, reversed out another 1+ tubing volume, 166 SPM, 3 BPM, 300 psi, no change over shaker. Slide down to about 3-1/2' over stub and reverse out the remainder of a full circulation, 166 SPM, 3 BPM, 300 psi, no change over shaker. Slack off and set down 5K# on stub, top at 9192', dressing mill at 9197'. Reverse out 1+ tubing volume, 166 SPM, 3 BPM, 450 psi (150 psi increase). No change at shaker. PU 30' above stub and sit w/o circulating for 45 minutes. Drop back down over stub w/o pump. Slid over stub and tagged at 9197', OK, no fill. Drain possum belly and found same full of .sand" (Ground up scale, pipe dope, crude, etc.), no pieces of metal. Clean out possum belly and flow line. Depths are Nabors 3S RT (add 10' for Doyon 14 RKB). LD 6 joints picked up for cleanout. LD single to get on new break for stands. POOH 10 stands. Pump slug. Drop drift in pipe. Continue POOH. POOH to stand #12. Drift stopped here. Pull drift. Drop 2.867" drift through stand #12 down through tubing string. Continue POOH with tubing. 2.867" rabbit recovered on top of XO above drill collars. LD DC's and fishing tools. Recovered 2 control line bands, sand, and scale in junk baskets. Decide to run completion. Clear rig floor. RU to run tubing and jewelry. PU Guide/Poor Boy Overshot with pup and 2.812" DS Nipple with redressed RHC plug in place. RIH on 2 joints (1st stand) of 3-1/2" tubing. PU & MU pup, PBR/FHL Packer, pup assy. Cleaned & Baker Lok'd all connections. (Assemblies pre-done at shop). MU 1 jt tbg. PU & MU KBUG-M GLM assy w/1" DCK-2 shear valve (2500 psi annular shear) with BEK latch. RIH with tubing stands from derrick, installing KBUG-M GLM assemblies (1" dummies, BK latch) as planned. Installing new seal rings. 60 stands of tubing in hole at 2400 hrs. RIH with 3-1/2" tubing and jewelry. Ran 142 stands & 2 singles (286 jts), plus jewelry. PU & run 5 more joints. Drifted stands and joints above 2.875" DS nipple to 2.91" (all other to 2.867"). Check weights: 68K# PU, 38K# SO. Circulating with charge pump, tagged top of stub. Took 2K# - 3K# weight sliding over top of stub, then slid on freely. Swallowed 4+ ft. and bottomed out on stub inside overshot barrel, set down 10K# to verify. PU to up weight, plus l' to put pipe in tension and overshot barrel l' from bottoming out on stub. Circulating with charge pump throughout. RU to circulate corrosion inhibited 9.6# brine. Pump 15 bbls brine mixed with 12.5 gals Baker CRW 132 corrosion inhibitor. Displace with 80 bbls 9.6# brine. Drop ball and rod. Wait 25 min for ball and rod to get to RHC plug. Pressure up on well. Packer shifted at 1800 psi. Walk pressure up to 2500 psi and hold for 10 min. Set packer with mid element at 9123' RKB. Bleed pressure down to 1000 psi. Pull up on tubing to 90K. PBR sheared with 30K over string weight (pressure helped with about 13K force). Pull up 67K up weight. Slack off 38K down weight. Set down on PBR. PU to neutral. Figure space out for seal assembly to be stroked up 3' from bottom of PBR. Lay down 3 joints tubing. PU 1-8' pup and 1-10' pup. PU 1 joint tubing. MU 4" DSS-HTC box x 3-1/2" 8rd pin XO. MU Cameron tubing hanger with 4" J-55 DSS-HTC pin x pin pup joint. Printed: 8/15/2003 12:40:38 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1A-28 1A-28 WORKOVERIRECOMP Nabors3SCompanyM@conoco Nabors 3S Start: 7/30/2003 Rig Release: 8/7/2003 Rig Number: Spud Date: 1/10/1991 End: 8/7/2003 Group: 8/7/2003 09:00 - 13:00 13:00 - 14:30 4.00 CMPL TN PCKR CMPL TN 1.50 CMPL TN DEQT CMPL TN 14:30 - 18:00 3.50 WELCTL NUND CMPL TN 18:00 - 19:00 1.00 CMPL TN SEQT CMPLTN 19:00 - 21:00 2.00 WELLSA PLGM CMPL TN 21 :00 - 00:00 3.00 MOVE RURD CMPL TN MU 3-1/2" IF box x 4" DSS-HTC pin XO. MU 3-112" IF landing joint. Drain BOP stack. RIH 21.3' and land hanger. Run in lock down screws. Pressure test tubing to 2500 psi for 15 min. Monitor IA. No returns. Good test. Bleed off tubing to 1500 psi. Pressure test 3-1/2" x 7" annulus to 2500 psi for 15 min. Tubing pressure stayed at 1500 psi. Chart both tests. Bleed down tubing pressure and shear SOV. Pump down tubing taking returns up IA to ensure SOV is sheared. Dry rod 2-way check in through BOP stack. Set 2-way check in BPV profile. ND BOP stack. NU tree. Pressure test tubing packoff to 5000 psi. Held good. Pressure test tree to 250 psi low and 5000 psi high. Held good. RU lubricator & pull2-way check valve. Set BPV. Load brine from pits into vacuum truck and haul to storage. Clean pits, possum belly, flowline, and pipe shed sumps with super sucker. Unload extra tubing from pipe shed. Clean up pipe shed and rig. Release rig @ 2400 hrs, 8/7/03. (Moving to 1 R-14). Printed: 8/15/2003 12'40,38 PM ~ ConocoPhillips Alaska, Inc. 1A.28 TUBING (0-9409, OD:3.500, ID:2.992) PBR (9233-9234, OD:3.500) PKR (9246-9247, OD:6.156) Perf (9330-9370) SLEEVE-O (9403-9408, OD:3.500) PUP (9408-9416, OD:3.500) NIP (9490-9491, OD:2.875) TUBING (9416-9503, OD:2.875, ID:2.441) Perf (9619-9633) Perf (9649-9712) ~~ Reference Log: 31' RKB Last Tag: 9795 Last Tag Date: 2/13/2003 Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 SUR. CASING 9.625 0 5413 3861 36.00 J-55 PROD. CASING 7.000 0 10006 6488 26.00 J-55 Tubing String - TUBING (3.5" TUBING DEPTH INCLUDES NEW & ORIGINAL TUBING) Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 9409 6148 9.30 L-80 8rdEUEABMOD 2.875 9416 9503 6200 6.50 J-55 EUE-MOD Perforations Summary Interval TVD 9330 - 9370 6103 - 6126 9370-9390 6126-6137 9619 - 9633 6265 - 6273 9649 - 9712 6282 - 6318 Gas LIft MandrelsNalves St MD TVD Man Man Type V Mfr V Type V 00 Latch Port TRO Mfr 1 3338 2647 Cameo KBUG-M 2 5667 4000 Cameo KBUG-M 3 7279 4907 Cameo KBUG-M 4 8383 5553 Cameo KBUG-M 5 9055 5945 Cameo KBUG-M Production MandrelsNalves St I MD I TVD I Man I Man Type I V 7 9290 6081 M~~a TGPDC Other (plugs, equip., etc.) . JEWELRY Depth TVD Type 554 553 NIPPLE 9105 5974 PBR 9119 5982 PACKER 9194 6025 NIP 9201 6029 Overshot 9211 6035 TBG SUB 9233 6048 PBR 9246 6055 PKR 9403 6145 SLEEVE-O 9408 6148 PUP 9416 6152 PKR 9490 6193 NIP 9503 6200 SOS 9504 6201 TTL General Notes Date I Note 8/17/2003 UNABLE TO PASS 9227' RKB - TRIED 9/15, 9/16, 9/17/03 API: 500292212600 SSSV Type: NIPPLE Well Type: PROD Orig 1/21/1991 Completion: Last W/O: 8/10/2003 Annular Fluid: Ref Log Date: TD: 10025 ftKB Max Hole Angle: 57 deg @ 5100 Zone Status C-4,C-3,C-2 C-2,C-1 A-5 A-4 Ft SPF Date 40 10 6/5/1991 20 5 6/5/1991 14 4 6/5/1991 63 4 6/5/1991 GLV GLV OV DMY DMY 1.0 1.0 1.0 1.0 1.0 KRU 1A-28 Angle @ TS: 55 deg @ 9328 Angle @ TD: 54 deg @ 10025 Rev Reason: TAG, Pull WRP, Set OV Last Update: 3/19/2004 Type IPERF IPERF IPERF IPERF Comment HLS 4.5" Casing Gun HLS 4.5" Casing Gun HLS 4.5" Casing Gun HLS 4.5" Casing Gun BK BK BK BK BEK Date Run 0.125 1259 8/13/2003 0.188 1310 8/13/2003 0.313 0 3/11/2004 0.000 0 8/10/2003 0.000 0 8/10/2003 Vlv Cmnt V OD I Latch I Port I TRO I Date I Vlv Run Cmnt 1.5 RK 0.000 0 6/14/1996 Closed Description CAMCO 'DS' LANDING NIPPLE SET 8/10/2003 BAKER 80-40 PBR - SET 8/10/2003 BAKER FHL PACKER SET 8/10/2003 CAMCO 'OS' NIPPLE SET 8/10/2003 UNIQUE POOR BOY OVERSHOT SET 8/10/2003 Baker w/ 10' Stroke Baker 'HB' Cameo; CB-1 SLIDING SLEEVE opened 6/15/01 PUP/LOCATOR TO TOP OF PACKER TIW'SS' Cameo 'D' Nipple NO GO Cameo ID 2.875 3.000 3.000 2.812 3.750 2.992 3.000 2.875 2.812 2.992 4.000 2.250 2.441 2.441 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2 200,________0_0 P M E E L E W A T ERIA L U N D E THIS MARKER_ R C:LORI~MFILM.IX)C ~-~-~, STATE OF ALASKA A! ,A OIL AND GAS CONSERVATION CC SSION 0 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well O,L I~1 ~^s F-I SUS.E.OED I--'1 ^BANOO. ED r-i S~RV.:E ED 2 Name of Operator 7 Permit Number ARCO Alaska, Inc ~--u~- 91 - 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22126 4 Location of well at surface 9 Unit or Lease Name 587' FSL, 309' FWL, SEC 5, T11N, R10E, UM ~'~~ ~~~ KUPARUK RIVER AtTop Producing Interval . I _.., 5~TE . ~ 10 Well Number 161' FNL, 2342' FEL, SEC 17, T11N, R10E, UM--.,~ ~ J -'~'~ ~ ~:/ 1A-28 At Tota~ Depth j V~J~IED ] . FiadandPoo~ .... 6.991FNL, 2143' FEL, SEC 17, T11N, R10E, UM L.___~'~~ , KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 102', PAD 67'J ADL 25652, ALK 2578 12 Date Spudded1/10/91. 13 Date T.D.R.chedl/19/91. 14 O.t. Comp., Susp. er Aband.6./91: , J 15 Water Depth, if offshoreNA feet MSL J16 N°' °f c°mpleti°nsl 17 Total Depth (MD+'rVD) ' 18 Plug Back Depth (MD+'FVD) 19 Directional Survey 20 Depth where SSS~/set 21 Thickness of permafrost 0,025' MD,-6499' TVD 9916' MD, 6435' TVD YES [~ NO D 1769' feet MD 1500' APPROX 1 · 22 Type ElectriC or ~)~er Logs'Rb. DI L/SFL/ML/CET/CBL/GYRO 23 CASING, LINER AND'CEMENTING RECORD SETTING DEPTH MD ' ' CASING SIZE WT. PER FT. GRADE TOP BOT]'(]VI HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 16" 62.5# H-,ID SURF 115' 24" 222 SX ASI 9-5/8" 36# J-55 SURF 5413' 12-1/4" 1268 SX ASIII, 507 SX CLASS G ....... 7" 26~ J-55 SURF 10,005' 8-1/2' 300 SX CLASS G TAIL , · 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD1 PACKER SET (MD) 4", 3-1/2', 2-7/8" 9503' 9246', 9416' 9330"9370' W/ 4-1/2" CSG GUN @ 10 SPF MD 6103'-6126'TVD ........ 9370'-9390' W/4-1/2" CSG GUN @ 5 SPF MD 6126'-6137" TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, FTC 9619'-9633' W/4-1/2" CSQ GUN @ 4 PF MD 626.5'-6273' TVD DEPTH INTERVAL IMD) AMOUNT & KIND OF MATERIAL USED 9649'-971Z W/4-1/2" CSG GUN @ 4 SPF MD 6282'-6318' TVD, · , , , 27 PR~,, UCTION TEST Date First Production'lM~th°d of Operation (Flowing, gas lift, etc.) I ,, , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-MCF WATER-BBL CHOKE SIZE I GAs'OIL RATIO I ~_ TEST PERIOD ~Flow Tubing Casing Pressure CALCULATED OIL-BilL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) press. 24-HOUR RATE ~- O i\, F D ' ' "Brief description of lithology, porosity, fractures, apparent dip~ and presence Of oil, gas or water. Submit cor~bhl~.~,' '-- ' ' "" -- AUG 0'~ 1991 . Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 ~EDON REVERSESlDE ~ -.. GEOLOGIC M~ , ~S ~ ,.., ,..;ATION TESTS " NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 9326' 6101' NA KUPARUK C BoTroM 9394' 6140' KUPARUK A TOP 9601' 6255' (UPARUK A BOTTOM 9818' 6378' , 31. LIST OF ^'I-rACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~ . Title AREA DRILLING ENGINEER Date 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 only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB. etc.). Item 23: Attached supplementaI records fOr this well should show the details of any multiple stage cement- ing and the location of the cementing tool. .. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI': 1A-28 . NORTH SLOPE KUPARUK RIVER UNIT ADL 25652 ALK 2578 50-029-22126 90-02 AK 5598 55.252072 SPUD: 01/10/91 RELEASE: 01/21/91 OPERATION: DRILLING RIG: DOYON 14 01/11-/91 ( 1) TD: 1657' (1657) SUPV:JMM 01/12/91 (2) TD: 4322' (2665) SUPV:JMM 01/13/91 (3) TD: 5435' (1113) SUPV:JMM 01/14/91 (4) TD: 5435'( SUPV:JMM o) 01/15/91 (5) TD: 6475'(1040) SUPV:JMM 01/16/91 (6) TD: 8575' (2100) SUPV: JMM DRILLING AT 1657 MW: 9.2 VIS: 63 MOVE RIG FROM 1A-26 TO 1A-28. ACCEPT RIG AT 1A-28 AT 10:00 1/10/91. NU DIVERTER, MU BHA, TEST DIVERTER, SPUD AT 14:00 HRS. KO AT 300' AND NAVIDRILL TO 1657' · DAILY:S75,413 CUM:$75,413 ETD:S75,413 EFC:$1,960,000 DRILLING AT 4322'. MW: 9.5 VIS: 57 DRILL FROM 1657' TO 1876' POOH FOR SPERRY MWD TOOL FAILURE. RIH AND'DRILL F~OM 1876' TO 4322' DAILY:S68,226 CUM:$143,639 ETD:$143,63~ EFC:$1,960,000 , POOH TO CHANGE BHA MW: 9.8 VIS: 60 DRILL FROM 4322' TO 5435', CASING POINT. CBU, WIPER TRIP, HOLE TIGHT AT 1680' -2230'. HIT BRIDGE AT 1925', ATTEMPT TO ROTATE BY OBSTRUCTION, POOH FOR HOLE OPENER. RIH WITH HOLE OPENER, HIT BRIDGE AT 2035', WASH AND REAM TO 2233', UNABLE TO WORK BELOW 2233' POOH TO CHANGE BHA. DAILY:S53,435 CU~:$197,074 ETD:S197,074 EFC:$1,960,000 NU CSG HEAD 9-5/8"@ 5332' MW:10.0 VIS: 47 LD HOLE OPENER, PU BIT AND NAVIDRILL MOTOR. RIH AND TAG BRIDGE AT 2233', WASH AND REAM TO 2429', CONT RIH TO 5435' TD, CIRC AND COND MUD, POOH. RUN 128 JTS 9-5/8" J-55 BTC 36# CASING, CIRC AND COND MUD. PUMP 80 BBLS WATER, 438 BBL LEAD CEMENT AT 12.1 PPG, 104 BBL TAIL CMENT AT 15.8 PPG. DISPLACE WITH 412 BBL WATER, BUMP PLUG AT 2500 PSI, FLOATS OK. ND BOPE, PERFORM TOP JOB WITH 150 SX CLASS G CEMENT. INSTALL CASING HEAD. DAILY:S174,506 CUM:$371,580 ETD:S371,580 EFC:$1,960,000 DRILLING AT 6475 9-5/8"@ 5332' MW: 9.6 VIS: 38 MAKE UP STARTING HEAD, NU BOPE, TEST BOPE. MU TURBINE AND DBS BIT. RIH DRILL OUT FLOAT COLLAR, TEST CASING TO 2000 PSI, DRILL OUT SHOE AND 10' OF FORMATION PERFORM FORMATION INTEGRITY TEST TO 12.0 PPG EMW. DRILL FROM 5445' TO 5794', POOH FOR SPERRY MWD TOOL FAILURE.METAL FILINGS OBSTRUCTED IMPELLERS OF PULSER MU BHA AND RIH, DRILL FROM 5794' TO 6475'. DAILY $162,525 C~M:$534,105 ETD:S534,105 EFC:$1,960,000 DRILLING AT 8575 9-5/8"@ 5332' MW: 9.7 VIS: 41 DRILL FROM 6475' TO 8575'. DAILY:S58,309 CUM:$592,414 ETD:S592,414' EFC:$1,960,000 WELL: 1A-28 OPERATION: DRILLING RIG: DOYON 14 PAGE: 2 01/17/91 ( 7) TD: 9320' ( 745) SUPV:JMM 01/18/91 (8) TD: 9760' ( 440) SUPV:JMM 01/19/91 (9) TD: .9913' ( 153) SUPV:JMM 01/20/91 (10) TD:10025' ( 112) SUPV:JMM 01/21/91 (11) TD:10025' ( SUPV:JMM 0) DRILLING AT 9320, 9-5/8"@ 5332' MW:ll.0 VIS: 44 DRILL FROM 8575' TO 8973'. POOH AND CHANGE BHA TO A ROTARY ASSY. PERFORM FORMATION INTEGRITY TEST TO 11.5 PPG EMW. RIH AND REAM FROM 8923' TO 8973'. DRILL FROM 8973' TO 9320'. DAILY:S87,431 CUM:$679,845 ETD:S679,845 EFC:$1,960,000 'DRILLING AT 9760' 9-5/8"@ 5332' MW:ll.0 VIS: 43 DRILL FROM 9320 TO 9731'. ROP VERY POOR AT BOTTOM. POOH, BIT TEETH SEVERELY WORN. RIH WITH NEW BIT, DRILL FROM 9731' TO 9760'. DAILY:S64,230 CUM:$744,075 ETD:S744,075 EFC:$1,960,000 LOGGING MAD PASS 9-5/8"@ 5332' MW:ll.0 VIS: 41 DRILL FROM 9760' TO 9913' TD. WIPER TRIP AND POOH FOR LOGS. WAIT ON LOGGING UNIT DUE TO ROAD BLOCKED BY BROKE DOWN AUDI RIG. RIH WITH SPERRY RLL LOGS WHILE WAITING EOR WIRELINE. MAKE MAD PASS FROM 8976 TO 9588". LOGGING UNIT ARRRIVE ON LOCATION AT 0100 HRS. DAILY:S53,809 CUM:$797,884 ETD:S797,884 EFC:$1,960,000 POOH LDDP 7"@10006' MW:ll.1 VIS: 42 FINISH MAD LOGGING PASS FROM 9588' TO 9913'_ POOH AND UNLOAD LOG. RIH AND DRILL FROM 9913' TO 10025', POOH LDDP. DAILY:S63,309 CUM:$861,193 ETD:S861,193 EFC:$1,960,000 PREPARE TO MOVE RIG 7"@10006' MW:ll.0 VIS: 0 FINISH POOH LDDDP. RUN 236 JTS 26# 7" J-55 BTC CASING TO 10006'. LOST RETURNS AT 210 JTS, RU DOWELL, PARTIAL RETURNS WHILE CIRCULATING UNTIL LOST ALL RETURNS AT 1700 STROKES. PUMP 10 BBL PRE-FLUSH, 35 BBL 12 PPG SPACER, 62 BBL 15.8 PPG C CEMENT (300 SX), DISPLACE WITH 380 BBL 11.0 PPG BRINE. BUMP PLUG TO 3000 PSI, FLOATS OK. RECIP PIPE 30' THRUOUT JOB, BEGAIN REGAINING RETURNS AT. 350 BBL INTO DISPLACEMENT. ND BOPE, WELL FLOWED BACK 30 BBLS/HR DECREASING AFTER 1.5 HRS. SET CASING SLIPS WITH 175K TENSION. NU TREE, TEST TO 3000 PSI. PREPARING TO MOVE TO 1A-27. DAILY:S430,196 CUM:$1,291,389 ETD:S1,291,389 EFC:$1,960,000 DATE: ARCO ALASKA INC.~-~-~- DAILY OPERATIONS~-~-~ PAGE: 1 WELL: BOROUGH: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1A-28 NORTH SLOPE KUPARUK RIVER UNIT ADL 25652 ALK 2578 50-029-22126 90-02 AK5598 55.252072 ACCEPT: 06/05/91 RELEASE: 06/07/91 OPERATION: COMPLETION RIG: NORDIC 06/05/91 (12) TD:10025 PB: 9918 SUPV:GB 06/06/91 (13) TD:10025 PB: 9918 SUPV:GB/WM 06/07/91 (14) TD:10025 PB: 9918 SUPV:GB/WM 06/08/91 (15) TD:10025 PB: 9918 SUPV:GB/WM TESTING BOPE 7"@10006' MW:ll.0 NaCl/Br MOVE RIG TO 1A-28. ND DHT AND NU BOP STACK. TEST BOPE. DAILY:S16,346 CUM:$1,307,735 ETD:S1,307,735 EFC:$1,960,00 PERFORATING 7"@10006' MW:ll.0 NaCl/Br RU HLS AND MADE 5 PERF GUN RUNS. DAILY:S30,147 CUM:$1,337,882 ETD:S1,337,882 EFC:$1,960,000 RUNNING COMPLETION 'ASS' Y 7"@10006' MW:ll.0 NaCl/Br MADE PERF RUNS 6 THROUGH 9. RAN PERMANENT PACKER ASS'Y ON WL. RUN 4" X 3-1/2" COMPLETION ASS'Y. RR @ 1830 HRS 07-JUN-91 7"@10006' MW:ll.0 NaCl/Br FINISH RUNNING 4" X 3-1/2" SELECTIVE SINGLE COMPLETION. STING INTO PERMANENT PACKER AND SPACE OUT. SET RETRIEVABLE PACKER, SHEAR PBR, TESTED SSSV. ND BOP STACK AND NU TREE. TEST SAME. OK. FREEZE PROTECT WELL AND RR @ 1830 HRS 07-JUN-91. DAILY:S359,380 CUM:$1,728,936 ETD:S1,728,936 EFC:$1,960,00 DATE: DS 1H f 18 lg WClNITY MAP NOTES: 1. BASIS OF LOCATION AND ELEVATION IS D.S. MONUMENTATION PER LOUNSBURY & ASSOCIATES. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. 3. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. 4. LOCATED WITHIN PROTRACTED SECTION 5, T 11 N, R 10 E, UMIA T MERIDIAN, ALASKA. NO. Y X 17L 5971370.96 540180.24 18A 5971251.02 540180.20 19H 5971205.06 540180.24 20M 5971179.05 540180.17 21O 5971155.00 540180.25 22B 59711,30.99 540180.19 251 5971011.10 540180.26 24F 5970915.06 540180.25 25C 5970819.08 540180.28 26J 5970723.13 540180.21 27E 5970699.09 540180.20 28D 5970675. t0 540180.27 LAT. LONG. F.S.L. F.W.L. O.G. PAD 70' 19'57. 794' 149· 40'~.6.654' 1285' 315' 59.6' 67.0' 70'19'56.614" 149'40'26.654" 1165' ,.314' 6!.0' 66.5' 70'19'56.143" 149'40'26.660" 1115' 314' 61.7' 66.8' 70'19'55.906' 149'40'26.666' 1091' ,:714' 62.0' 67.0' 70' 19'55.670' 149'40'26.667' 1067' 514' 62.4' 66.9' 70'19'55.454" 149' 40'26.67,.'7' 1043' 515' 62.8' 67.0' 70' 19'54.255' 149' 40'26.689' 92,.3' 312' 63.8' 66.,.7' 70' 19'55.310" 149' 40'26. 705" 827' 511' 64. O' 66.7' 70'19'52.366' 149' 40'26.719' 731' ,:711' 65.$' 67.0' 70'19'51.422' 149'40'26.736" 635' 310' 62.7' 67.2' 70'19'51.186' 149'40'26.740' 611' 310' 62.5' 67. J' 587' 309' 62.4' 67.2' 70 ' 19 50. 9 ,,~, ~,4~' ~ 26. 742' . ~II~V~'~ ~~I~A~ ~eeeeeeeeeeeeeee. eeeeee ~eee REGI~RED AND LICENSED TO PRAC~CE LAND SUR~NG IN ~ STA ~ OF ALASKA f :~'%. LS-8035 .. '~ suRlY OON[ BY ~E OR UNDER ~Y O~RECT '~~.'""~ SUPER~SION, AND ~AT ALL DIMENSIONS AND O~ER DETAILS ARE CORRECT AS OF OCTOBER 23, ~990. 10/30/90 Change F.N.L. to F.S.L. Date Description ARCO ALASKA, INC. DWG// NSDK- 1A OO-CEA-D1AX-610 7 D10 .ARCO Alaska,Inc. DRILL SITE 1-A WEll CONDUCTORS #17-#2B AS-BUI£ LOUNSBURY & ASSOC. 0~. OCS A J..':,' TOP SL~PVS'? Job }~umber: AKOi91G208 ra~,-,,~ ation ..... MINIMUM CURVATDRE Az~mLt~h~ are Re!atlva ~ TRUE N~RTH Vmrtic.~.i Section Calculated from t4mll Head Lmcation CiosuP~ CalcL~].atmd from Well H~ad Location N~.~=~,=~ ....... ~-,o,- r~-,,~ from Loca. i Horizontal Refmremc8 ICROFILHED ,::,-.n ALASi:':A~ TNC., DEPTH 200, 600, 0 9.17 80!), 0 i 7~ 24 000, O 20. % 200.0 23; 59 400,0', 2,5.08 150010 27.9.5 ~ .,.,r,.,'., n 33,3i 1700, :) ~.~.,?'-~ 16 ~' 8-":)(L 0 40.21 ® Directional Survey nc, fi ~ofi N nO E ~: ....... ~ ............. :u 9895 M,D. ALL~u,,'~,,o":"~v ~.~,,=,...,~,,~rOm~n[N~T;~ REFERENCED TO~,,~o,:~L~:"mmA' R,K,B.. . !%22 ~cm.n .,, N ,08 E ~.~. ~. ,~0 , i85.10 30(L0 .08 S' .20 E 14.3,57 499.5 10.46 S 6.55 E i40.56 696.7 36.72 S 26.74 E i39.17 793.2 56.57 S 43.54 E 159..40 888.4 7%88 S 63.60 E 142~57 i075.3 i35.06 S I08.12 E !45.79 1167.5 165.86 S !31.04 E 155~12 1548.~ 241.50 S 172.!8 E ~ ~ ~,~ , 0.~£~ -~. ~.i~ i65.!i .~-.~.~n~ ~ 386,75 S ~,.,z?'° ~ ~64.0! 1684.,! 446.31S 236.20 i6i, 81 ...... 511,6~, S 256.~-~ i57.8i 1824~4 580.9! ~ 281.94 1~' 92 J886 ~ 652.93 S .~,~, ~8 156.37 i94.7.5 725.99 S 343.53 156.70 2007.5 ~oo ~ S 575. !5&87 2067~i 87L~5 S 407,04 VERT S~ , E~ION ft .0 .I ~2 · , 44..- ~ 69.0 98:3 150.7 !66.4 204.6 245.7 289,~~ 441,7 505.0 570,7 644.8 722.8 802.4 882.3 962.7 Page DOS-LEG o-cV~t:;,TTY deg/ 3,78 4,34 2,44. !,71 !.62 .:--:, 08 1,67 4..!! 5.58 5.54 2, i7 ARCO ~L~Si::'~,. NORTH SLOPE BOROUGH~ ALASKA A Gyrodata DEPTH DEPTH ft :-' dmn 25~J~0 ~ ~]~ 54I: 72 157.87 2125, 4 2~'->9, -'.') 54~ 58 15L 99 2 i 8.3, -3 ~on~-~ n ~ ~ 160,13 2365, 6 3000:0 49,52 !61,42 2429,5 :< r,.-', ~"? ~.:', '-.-,n ~ ~.c 7,-... 2493.9 -~:-~:.~'~ r: 4% 80 :, -An ~ 2558, 2 3300,0 ::o :7 '."'A: :~ 2623, i 3500~0 3600.0 3700,0 3800~0 3900,0 51, i0 50, 35 51.76 52.~i 52,18 54,91 54=97 55~0! 5.3,51 55,20 56,46 4:00,0 4200,0 4400,0 4500,0 4600,0 4700,0 4800,0 4900,0 159, 34 i59,24 158.- 77 !59..22 160, i7 i60.73 i60,94. !6!, 43. D i~:~c t i ona ! Survey 28i3~2 2876,0 2998,3 3!16,2 3176,2 3235, i 3409,5 3467,9 3525~0 HOR i ZONTAL r..:OOR~!NATES feet 948, ii S ~o 28 !023, 70 S 468, 92 E 1098~68 S 49~.94 E ~246.''~ 554. . i 318,67 S 579, 65 ~<,¥ ....S 605.09 i462.78 S 63t, 18 ~=..~. 74 q A~-' 04 i607, i0 S 68!.9! ~-~' 43 S 736.41 E ~l~ . 1825~25 S 763, 72 E i899.07 S 79i,87 E 1973,13 S 820, 00 E zu~8. <':A S 849,2'! E 2'~23,=~ . ~ S 87~,~7 E i ....24 S oa: 66: 2273,72 S 936,47 E ~:~:" 17 S ~5 86 E VERT ft 043,9 Ii25,4 12(&2 i440,3 !5!6,6 i593.1 1669, i i7~5,8 1823,5 !900,9 1978,6 2057.5 2217,1 2298,2 2378.2 24.59.0 2622.2 2702.~ 2783,8 2865,7 2948,7 SEVERITY d~:." !00' 1,16. 1.4-5 i. 70 1.49 2,36 1,48 ~77 2, i. 6 ~74 i,62 A 9yrodata ~r r,.c- .'-' ~4r~ A7 TMUTM VFRT DEPTH DEPTH dSq , ~ ~-'"'":" 0 5% 26 !59.75 5655,8 5100~ 0 57,27 159.8! 36B9,9 ~xO'~ 0 ~: 07 ~i.n ~n 3798,5 , . ~ ~ O~ ~ ,~ ~ -. ~.~ ~ . ,-, -- -' - TC, LT 5700:0 56.92 !59.48 40!8. ~ i-v,...', t ..... 89 158, 35 ~. .... 3 ..... o, ,._.'.,,: ,~ 44L):'. 2 6500.0 56, ~.~. .-:-~,.~--'....', 0 55,94 6700.0 55, 6800.0 6900= 0 54.65 7000.0 54,60 7 i. 0,:.'! = 0 54. 74 72C3C:'.. 0 54,80 %100= ':) 54, 79 7400, 0 54, 78 !54.62 !54,12 i54,07 i55, ii D i r ~c t iona ~ S,._'.r'~'/ 4462,3 4517.9 4574..0 4630.7 4688,2 474~! 4919,3 4977,0 HORIZONTAL i'* feet 28!3.47 S 'i131,i6 E ~o~ ~, q i!60,23 E 2971,~ S 1189,05 E 5050.55 S !2i7,52 E 5!29.54 S 1244..54 E 5208,2! S .~,~,58~ E 5286.90 S !299,60 E 3565,41 S 1528.47 E 3444,05 S i ..... z,, E 3522.5! S 1385,32 E 3600.15 S 14!4,47 E 367%20 S i444,8! E 3754,28 S 14.75.29 E ~83i,4i S !506,!7 E 3908,62 S i557,49 E 3985.85 S !569,05 E ,..6 ....... ~ 1602,34, ~ r 4136.9~ S i637,43 E a2'i~,~=~ S i67%95 E 42~4,83 S 1708,/? ~ 4358.05 S i744,66 E 4431.01 S ~ =~ 4503.88 S !~18,06 E 4576.7~ S ~ ..... E 4649,61 o ~? nn ~ V~;,T 3032.0 3,11~.0 3199,9 5367.! 3450,5 3533,7 3617.2 J700.9 3784.! 5867,0 394% 8 41i=, --, 4199,0 44.48, 3 4612.2 4693.6 4856,5 4938.0 5019.5 DOG-LES SEVERITY ,05 .34 ,77 _,~ .26 ,22 ~56 , .2, U ,,~ .,, 2.04 ,50 .46 ,28 ~t DEPTH DEPTH 7500,0 7700, 0 54,84 7':,'Fx'}, 0 5.3,73 ~,'. ...... u ~3,7i 8200.0 53,85 8300, 0 53, 7~ ~..P4f'.,O,.... 0 54, ~..,.~ '..2. '.,- %': ".,. ~7.90, C': 54,56 8800:0 54, 43 00,"~£', A q& ! 7 ._ 9500,0 56, 56 960(:.', (: 55, 45 9895,0 54,29 !,52, 9.5 ! 52,75 i 52,26 152,3i 252,01 i5!.76 i5i ~':' 150.58 i 5(.'-, 07 !49.94 156.93 157, iB i58, i2 i60,65 5034,6 5150, i 5208. i 52~6,8 5326,2 5385,5 5444,5 5503,7 5~ 562i,! 5679,6 5738,0 597i,3 6028,9 608&3 6!98,6 6254~5 6311,2 6368,3 6423,3 Z a ~.iT A L feet ~ .... ~ ~ ~928,87 ,,. "&= 90 ~7e5,27 S ~%¢, E 4867, e~ ~ ~OF, X ~6 E 4940,41S 204o ~ r .,~/ 50~2,24 S 2077,54 E 5083,5L S 2!i5.08 E ~s~ 64 o ~57 ~= E ~o~A oo ~ 2228,74 E 5357,97 S 2267,57 E 5509.22 S 2~47,00 E 5579,54 S 2387~6(: E 7 ' ] ':~: t. ' ' ' : . : ' ':', S2 S 251 O, 51 E 5860,66 S 2550,46 E 6008.3! S 2620,84 E ~084,20 S 2652.74 E 6i60~83 S 2685, i4 E 6313.~ ~ 2748,77 ~ 6390,20~c _.7777.6g. E 6464.,18 S 2800.57 E VERT f~ 510i.0 526.5.8. 534% ! 5~.~m 7 JL.,,~, 7 5586, i 5666.4 5746.8 5827, 2 5907, 7 , 63!0.3 S472. b 6720.0 6802, 9 ~B85,2 5967,3 7044. ~ DOS-LES om.¢CRTTY dea/ i 22 · , ?... 2, S7 2, '::)0 1,24 1.14 5,8! ARCO ALASKA~ ~TNC~ A Gyrsdata Survey Station Ciosu~e: 7044.8 feet 155~5756 de?ees HORIZONTAL COORDINATES feet VERT DOS-LEG SEVERITY T V D' ARco ALASKA, ']:NC. " ~_ A-2B APT'50-029-22~26 VERTICAL SECTION VIEH Section at: S 22.80 E TVD Scale' ! inch = ~300 feet Dep Scale · ! inch = ~300 feet )raun .... '05/02/9~. SPear Land D~ne£tionaJ Onillin9 ~ ,, Marker Ident~ftcatton B) 9 5/8' CASING C) PBTD D) 71 CASING TD ND TVD SECTN INCLN 0 0 0 0.00 5413 386! 337B 56.36 99~6 6435 706! 54.29 !0006 6488 7t34 54.29 !0025 6499 7~49 54.29 <KB> 78OO 0 i300 2600 3900 5200 6500 Sect ~o,,n,,,,, Departure , /V t21 36( AI~"~0 A'LASKA, Marker Identification MD N/S A) KB 0 0 N 0 E B) 9 5/8' CASING 54t3 3t39 S t248 E C) PB3D 99t6 648t S 2805 E D) 7' CASING 10006 6551 S 2824 E E] TD 10025 6566 S 2828 E TNd'. ~A-28 APZ50-02§-22~26 PLAN VIEH CLOSURE ..... ' 7t49 ft $ 23.30 E DECLZNAIION.' 0.00 E SCALE · ! inch: 1200 ~eet DRANN · 05/02/9! SPear Land Directional D?Jl l. Jng 3600 2400 t200 0 t200 2400 <- NEST ' EAST -> 3600 GREAT LAND DIRECTIONAL DRILLING, INC. for GyroData'Incorporated 05/02/91 llient .... : ARCO ALASKA, INC. 'ield ..... : KUPARUK RIVER UNIT tell ...... : 1A-28 API50-029-22126 ;ection at: S,22.80,E :ngineer..: MIKE BUSH Computation...: RADIUS OF CURVATURE Survey Date...: 01/26/91 RKB Elevation.: 102.00 ft Reference ..... : 0191G208 INTERPOLATED MARKERS REPORT Surface Location: 587 FSL 309 FWL S5 TllN R10E MARKER IDENTIFICATION KB 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUKA PBTD 7" CASING EXTRAPOLATED TD MEAS INCLN DEPTH ANGLE o o.0o 5413 56.36 9326 55.12 9394 55.95 9601 55.45 9818 54.84 9916 54.29 10006 54.29 10025 54.29 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -102 3861 3759 6101 5999 6140 6038 6255 6153 0 N 0.00 E 3378 S 18.62 E 6576 S 22.82 E 6632 S 22.77 E 6804 S 22.81 E :~0 N 0 E 3139 S 1248 E 6028 S 2629 E 6079 S 2651 E 6238 S 2718 E 6378 6276 6435 6333 6488 6386 6499 6397 6982 S 18.52 E 7061 S 14.99 E 7134 S 14.99 E 7149 S 14.99 E 6404 S 2783 E 6481 S 2805 E 6551 S 2824 E 6566 S 2828 E ~REAT LAND DIRECTIONAL DRILLING, INC. ~lient .... : ARCO ALASKA, INC. Wield ..... : KUPARUK RIVER UNIT lell ...... : 1A-28 API50-029-22126 ~ection at: S,22.80,E ~ngineer..: MIKE BUSH 05/02/91 Computation....' RADIUS OF CURVATURE Survey Date...: 01/26/91 RKB Elevation.: 102.00 ft Reference ..... : 0191G208 MEAS INCLN DEPTH ANGLE 100 0.32 200 0.14 300 0.96 400 3.13 500 6.93 RECORD OF SURVEY VERTICAL-DEPTHS' SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 100.0. -2.0 -0.2 N 17.22 E 0.3 N 0.1 E 200.0 98.0 -0.5 N 18.48 E 0.6 N 0.2 E 300.0 198.0 -0.2 S 3.10 W 0.5 N 0.9 E 399.9 297.9 3.3 S 30.82 E 2.9 S 1.7 E 499.5 397.5 11.9 S 36.43. E 10.2 S 6.6 E CLOSURE DL DISTNCE BEARING /100 0.3 N 17.22 E 0.32 0.7 N 17.59 E 0.18 1.0 N 58.48 E 0.82 3.4 S 30.45 E 2.17 12.1 S 32.74 E 3.80 600 9.17 700 12.91 800 17.24 .900 18.59 1000 20.96 598.5 496.5 25.5 S 36.71 E 21.4 S 14.9 E 696.7 594.7 44.0 S 39.44 E 36.5 S 26.7 E 793.2 691.2 68.8 S 40.83 E 56.4 S 43.5 E 888.3 786.3 98.1 S 40.60 E 79.7 S 63.5 E 982.4 880.4 130.4 S 38.92 E 105.7 S 85.2 E 26.1 S 34.79 E 2.24 45.2 $ 36.18 E 3.74 71.2 S 37.62 E 4.33 101.9 S 38.55 E 1.35 135.7 S 38.85 E 2.38 1100 22.57 1200 23.59 1300 25.59 1400 26.08 1500 27.96 1075.3 973.3 166.2 S 37.43 E 134.8 S 108.1 E 1167.3 1065.3 204.4 S 34.21 E 166.6 S 131.0 E 1258.2 1156.2 245.5 S 28.55 E 202.1 S 152.7 E 1348.2 1246.2 289.0 .S 24.88 E 241.1 S 172.3 E 1437.3 1335.3 334.4 S 20.72 E 282.9 S 189.9 E 172.8 S 38.71 E 1.62 212.0 S 38.17 E 1.14 253.3 S 37.06 E 2.26 296.3 S 35.55 E 0.86 340.7 S 33.86 E 2.09 1600 33.31 1700 36.16 1800 40.21 1900 45.58 2000 50.26 1523.3 1421.3 385.1 S 14.88 E 331.4 S 205.4 E 1605.5 1503.5 441.5 S 14.89 E 386.5 S 220.1 E 1684.1 1582.1 502.8 S 15.99 E 446.0 S 236.5 E 1757.3 1655.3 570.5 S 18.19 E 511.1 S 256.5 E 1824.3 1722.3 644.7 S 22.19 E 580.7 S 282.1 E 389.9 S 31.79 E 5.63 444.7 S 29.65 E 2.85 504.9 S 27.93 E 4.08 571.8 $ 26.65 E 5.49 645.6 S 25.91 E 5.24 2100 52.32 1886.9 1784.9 722.7 S 23.08 E 652.7 S 312.1 E 723.5 S 25.56 E 2.13 'Survey Codes: 7/GYRO '1A28 B1.21) .A-28 API50-029-22126 Page 2 05/02/91 MEAS INCLN DEPTH ANGLE 2200 53.16 2300 53.00 2400 53.89 2500 54.72 2600 54.58 2700 53.16 2800 51.74 2900 51.06 3000 49.52 3100 50.20 3200 49.80 3300 49.37 3400 51.07 3500 51.10 3.600 50.35 3700 51.76 3800 52.61 3900 52.18 4000 54.91 4100 53.51 4200 52.82 4300 54.97 4400 55.01 4500 54.09 4600 53.51 4700 55.13 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RECORD OF SURVEY 1947.4 1845.4 802.3 2007.5 1905.5 882.2 2067.0 1965.0 962.5 2125.4 2023.4 1043.7 2183.2 2081.2 1125.3 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD S 23.63 E 725.8 S 343.7 E S 23.30 E 799.1 S 375.5 E S 23.13 E 872.9 S 407.2 E S 22.13 E 947.9 S 438.4 E S 22.01 E 1023.5 S 469.1 E 2242.2 2140.2 1206.1 S 21.61 E 2303.1 · 2201.1 1285.3 S 20.43 E 2365.5 2263.5 1363.4 S 19.87 E 2429.4 2327.4 1440.1 S 18.58 E 2493.9 2391.9 1516.5 S 20.30 E 2558,.1 2456.1 1593.0 S 19.52 E 2623.0 2521.0 1668.9 S 18.59 E 2687.0 2585.0 1745.7 S 20.72 E 2749.8 2647.8 1823.4 S 20.66 E 2813.1 2711.1 1900.8 S 20.20 E 2875.9 2773.9 1978.5 S 20.91 E 2937.3 2835.3 2057.4 S 20.84 E 2998.3 2896.3 2136.6 S 20.76 E 3057.7 2955.7 2217.0 S 21.82 E 3116.2 3014.2 2298.1 S 21.23 E 3176.1 3074.1 2378.1 3235.0 3133.0 2458.8 3292.4 3190.4 2540.7 3350.4 3248.4 2622.1 3409.5 3307.5 2702.7 1098.5 S 499.1 E 1172.5 S 527.5 E 1245.9 S 554.5 E 1318.5 S 579.8 E 1390.6 S 605.2 E 1462.6 S 631.3 E 1534.6 S 656.2 E 1606.9 S 682.0 E 1679.7 S 709.5 E 1752.3 S 736.5 E 3467.8 3365.8 2783.7 1825.1 S 763.8 E 1898.9 S 792.0 E 1973.0 S 820.1 E 2047.9 S 849.3 E 2123.3 S 879.1 E S 20.78 E 2198.1 S 907.8 E S 20.99 E 2273.5 S 936.6 E S 21.06 E 2350.0 S 966.0 E S 19.83 E 2426.3 S 994.4 E S 19.27 E 2502.4 S 1021.4 E S 19.06 E 2579.1 S 1048.1 E CLOSURE DISTNCE BEARING 803.1 S 25.34 E 883.0 S 25.17 E 963.2 S 25.00 E 1044.4 S 24.82 E 1125.9 S 24.62 E 1206.5 S 24.43 E 1285.7 S 24.22 E 1363.7 S 23.99 E 1440.3 S 23.73 E 1516.6 S 23.52 E 1593.0 S 23.34 E 1669.0 S 23.15 E 1745.7 S 22.99 E 1823.4 S 22.90 E 1900.8 S 22.80 E 1978.5 S 22.71 E 2057.4 S 22.64 E 2136.6 S 22.57 E 2217.0 S 22.52 E 2298.1 S 22.49 E 2378.1 S 22.44 E 2458.9 S 22.39 E 2540.8 S 22.34 E 2622.2 S 22.28 E 2702.8 S 22.20 E 2783.9 S 22.11 E DL /lOO 0.91 0.26 0.90 1.06 0.16 1.44 1.60 0.76 1.71 1.22 0.61 0.69 2.13 0.05 0.80 1.48 0.85 0.43 2.82 1.45 0.75 2.15 0.06 1.22 0.68 1.63 'Survey Codes: 7/GYRO A-28 API50-029-221~.~ % MEAS INCLN VERTICAL-DEPTHS DEPTH ANGLE BKB SUB-SEA RECORD OF SURVEY SECTION DIRECTION RELATIVE-COORDINATES DISTNCE BEARING FROM-WELL-HEAD Page 3 CLOSURE DiSTNCE BEARING 05/02/91 DL /lOO 4800 55.20 3524.9 3422.9 4900 56.46 3581.1 3479.1 5000 57.26 3635.7 3533.7 5100 57.27 3689.8 3587.8 5200 57.03 3744.1 3642.1 2865.6 S 18.57 E 2656.8 S 1074.5 E 2948.2 S 20.40 E 2734.8 S 1102.1 E 3031.8 S 20.25 E 2813.3 S 1131.2 E 3115.9 S 20.19 E 2892.2 S 1160.3 E 3199.8 S 19.91 E 2971.2 S 1189.1 E 2865.9 S 22.02 E 2948.5 S 21.95 E 3032.2 S 21.90 E 3116.3 S 21.86 E 3200.3 S 21.81 E 0.34 1.79 0.81 0.04 0.31 5300 57.07 3798.5 3696.5 5400 56.32 3853.4. 3751.4 5500 56.67 3908.6 3806.6 5600 56.62 3963.6 3861.6 5700 56.92 4018.4 3916.4 3283.6 S 19.50 E 3050.2 S 1217.4 E 3284.1 S 21.76 E 3367.0 S 18.51 E 3129.2 S 1244.6 E 3367.6 S 21.69 E 3450.2 S 19.34 E 3208.0 S 1271.7 E 3450.9 S 21.62 E 3533.6 S 19.86 E 3286.7 S 1299.7 E 3534.4 S 21.57 E 3617.1 S 20.52 E 3365.2 S 1328.5 E 3618.0 S 21.54 E 0.29 1.02 0.68 0.37 0.55 5800 56.78 4073.0 3971.0 5900 56.14 4128.3 4026.3 6000 55.92 4184.2 4082.2 6100 55.89 4240.2 4138.2 6200 56.07 4296.2 4194.2 3700.8 S 19.61 E 3443.9 S 1357.3 E 3784.0 S 19.83 E 3522.3 S 1385.4 E 3866.8 S 21.33 E 3600.0 S 1414.5 E 3949.6 S 21.65 E 3677.0 S 1444.9 E 4032.5 S 21.50 E 3754.1 S 1475.4 E 3701.7 S 21.51 E 3785.0 S 21.47 E 3867.9 S 21.45 E 3950.7 S 21.45 E 4033.6 S 21.45 E 0.65 0.66 1.05 0.22 0.21 6300 56.29 4351.8 4249.8 6400 56.57 4407.1 4305.1 6500 56.52 4462.2 4360.2 6600 55.94 4517.8 4415.8 6700 55.81 4573.9 .4471.9 4115.6 S 22.13 E 3831.2 S 1506.2 E 4198.9 S 22.03 E 3908.5 S 1537.6 E 4282.3 S 22.43 E 3985.7 S 1569.1 E 4365.4 S 24.79 E 4061.8 S 1602.4 E 4448.1 S 25.38 E 4136.8 S 1637.5 E 4116.7 S 21.46 E 0.49 4200.0 S 21.47 E 0.29 4283.4 S 21.49 E 0.28 4366.5 S 21.53 E 1.72 4449.1 S 21.59 E 0.42 6800 55.11 4630.6 4528.6 6900 54.65 4688.2 4586.2 7000 54.60 4746.1 4644.1 7100 54.74 4803.9 4701.9 7200 54.80 4861.6 4759.6 7300 54.79 4919.2 4817.2 4530.4 S 25.88 E 4211.1 S 1673.1 E 4612.1 S 25.93 E 4284.7 S 1708.9 E 4693.5 S 26.27 E 4357.9 S 1744.7 E 4774.9 S 26.89 E 4430.8 S 1781.2 E 4856.4 S 26.81 E 4503.7 S 1818.1 E 4937.9 S 27.01 E 4576.6 S 1855.1 E 4531.3 S 21.67 E 4612.9 S 21.74 E 4694.2 S 21.82 E 4775.5 S 21.90 E 4856.9 S 21.98 E 4938.3 S 22.06 E 0.78 0.46 0.23 0.44 0.08 0.13 Survey Codes: 7/GYRO .A-28 API50-029-22126 Page 4 05/02/91 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 7400 54.78 7500 54.79 7600 54.65 7700 54.84 7800 54.30 7900 53.73 8000 53.52 8100 53.71 8200 53.85 8300 53.71 8400 54.12 8500 54.17 8600 54.23 8700 54.36 8800 54.43 8900 54.17 9000 54.22 9100 54.53 9200 55.15 9300 54.80 9400 56.03 9500 56.56 9600 55.45 9700 55.45 9800 54.97 9895 54.29 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 4976.9 4874.9 5019.4 S 26.78 E 4649.4 S 1892.1 E 5034.5 4932.5 5100.9 S 26.89 E 4722.3 S 1929.0 E 5092.3 4990.3 5182.3 S 27.05 E 4795.1 S 1966.0 E 5150.0 5048.0 5263.7 S 27.25 E 4867.8 S 2003.2 E 5208.0 5106.0 5344.9 S 27.10 E 4940.3 S 2040.5 E 5266.8 5164.8 5425.6 S 27.74 E 5012.1 S 2077.7 E 5326.1 5224.1 5505.8 S 27.69 E 5083.4 S 2115.2 E 5385.4 5283.4 5586.0 S 28.14 E 5154.5 S 2152.9 E 5444.5 5342.5 5666.3 S 27.99 E 5225.7 S 2190.8 E 5503.6 5401.6 5746.7 S 28.24 E 5296.8 S 2228.8 E 5562.5 5460.5 5827.1 S 28.88 E 5367.8 S 2267.5 E 5621.0 5519.0 5907.6 S 29.42 E 5438.6 S 2306.9 E 5679.5 5577.5 5988.1 S 29.93 E 5509.1 S 2347.1 E 5737.9 5635.9 6068.7 S 30.06 E 5579.4 S 2387.7 E 5796.1 5694.1 6149.3 S 30.49 E 5649.6 S 2428.7 E 5854.5 5752.5 6229.8 S 30.44 E 5719.6 S 2469.9 E 5913.0 5811.0 6310.2 S 30.05 E 5789.7 S 2510.7 E 5971.2 5869.2 6391.0 S 28.66 E 5860.5 S 2550.6 E 6028.8 5926.8 6472.5 S 25.23 E 5933.4 S 2587.6 E 6086.2 5984.2 6554.4 S 22.84 E 6008.2 S 2620.9 E 6143.0 6041.0 6636.7 S 22.77 E 6084.1 S 2652.9 E 6198.4 6096.4 6719.9 S 23.07 E 6160.7 S 2685.3 E 6254.4 6152.4 6802.8 S 22.82 E 6237.0 S 2717.6 E 6311.1 6209.1 6885.2 S 21.88 E 6313.2 S 2748.9 E 6368.1 6266.1 6967.2 S 19.35 E 6390.1 S 2777.8 E 6423.1 6321.1 7044.3 S 14.99 E 6464.1 S 2800.7 E CLOSURE DL DiSTNCE BEARING /100 5019.7 S 22.14 E 0.15 5101.1 S 22.22 E 0.07 5182.5 S 22.29 E 0.18 5263.9 S 22.37 E 0.23 5345.1 S 22.44 E 0.55 5425.7 S 22.51 E 0.71 5505.9 S 22.59 E 0.21 5586.0 S 22.67 E 0.35 5666.3 S 22.74 E 0.17 5746.7 S 22.82 E 0.21 5827.1 S 22.90 E 0.59 5907.7 S 22.98 E 0.36 5988.2 S 23.07 E 0.34 6068.8 S 23.17 E 0.16 6149.5 S 23.26 E 0.29 6230.1 S 23.35 E 0.26 6310.6 S 23.44 E 0.26 6391.5 S 23.52 E 0.97 6473.1 S 23.56 E 2.39 6555.0 S 23.57 E 1.63 6637.3 S 23.56 E 1.23 6720.5 S 23.55 E 0.57 6803.4 S 23.54 E 1.12 6885.7 S 23.53 E 0.64 6967.7 S 23.49 E 1.76 7044.7 S 23.42 E 3.11 Survey Codes: 7/GYRO 1A-28 API50-029-22126 Page 5 05/02/91 RECORD OF SURVEY MEAS INCLN VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DEPTH /~NGLE BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD DiSTNCE BE3~ING /100 10025 54.29 6499.0 6397.0 7148.9 S 14.99 E 6566.0 S 2828.0 E 7149.1 S 23.30 E 0.00 Survey Codes: X/EXTRAPOLATED 1A-28 API50-029-22126 Page 6 05/02/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 100 202 0.16 200 302 1.00 300 402 3.21 400 502 6.99 500 604 9.30 TVD BKB 202 302 402 502 602 600 705 13.15 702 700 809 17.36 802 800 914 18.93 902 900 1021 21.30 1002 1000 1129 22.86 1102 1100 1238 24.35 1202 1200 1349 25.83 1302 1300 1460 27.21 1402 1400 1575 31.95 1502 1500. 1696 36.03 1602 1600 1824 41.48 1702 1700 1966 48.65 1802 1800 2125 52.53 1902 1900 2291 53.01 2002 2000 2460 54.38 2102 2100 2632 54.12 2202 2200 2798 51.76 2302 2300 2957 50.17 2402 2400 3113 50.15 2502 2500 3268 49.51 2602 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 S 14.57 W 0~65 N 0.21 E 0 0 S 2.42 W 0.49 N 0.85 E 0 0 S 30.93 E 2-99 S 1.76 E 0 0 S 36.43 E 10.43 S 6.73 E 2 1 S 36.80 E 21.88 S 15.23 E 3 2 S 39.51 E 37.46 S 27.49 E 7 4 S 40.81 E 58.46 S 45.25 E 12 5 S 40.36 E 83.22 S 66.54 E 19 7 S 38.61 E 111.59 S 89.89 E 27 8 S 36.50 E 143.78 S 114.80 E 36 9 S 32.06 E 179.55 S 139.45 E 47 11 S 26.77 E 220.81 S 162.46 E 58 12 S 22.38 E 265.77 S 183.07 E 73 15 S 16.36 E 318.27 S 201.71 E 94 21 S 14.89 E 384.00 S 219.41 E 122 28 S 16.51 E 460.92 S 240.85 E 164 42 S 20.82 E 556.42 S 272.57 E 223 59 S 23.22 E 670.82 S 319.88 E 289 66 S 23.33 E 792.46 S 372.66 E 358 69 S 22.53. E 917.54 S 425.97 E 430 73 S 21.88 E 1047.77 S 478.87 E 496 66 S 20.45 E 1171.14 S 527.03 E 555 59 S 19.13 E 1287.74 S 569.29 E 611 55 S 20.20 E 1399.72 S 608.60 E 666 55 S 18.89 E 1511.35 S 648.29 E 2600 3424 51.07 2702 722 56 S 20.70 E 1624.34 S 688.60 E A-28 API50-029-22126 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/02/91 UBSEA MEAS INCLN EPTH DEPTH ANGLE TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES BKB DIFF CRRT BEARING FROM WELL HEAD 2700 3583 50.48 2802 781 59 S 20.28 E 1739.68 S 2800 3742 52.12 2902 840 60 S 20.88 E 1856.17 S 2900 3906 52.34 3002 904 64 S 20.82 E 1977.46 S 3000 4076 53.84 3102 974 70 S 21.37 E 2105.39 S 3100 4243 53.75 3202 1041 67 S 20.87 E 2230.50 S 3200 4417 54.85 3302 1115 73 S 20.85 E 2362.75 S 3300 4587 53.58 34.02 1185 71 S 19.34 E 2492.82 S 3400 4760 55.17 3502 1258 72 S 18.77 E 2625.56 S 3500 4938 56.76 3602 1336 78 S 20.34 E 2764.54 S 3600 5123 57.21 3702 1421 84 S 20.13 E 2910.00 S 3700 5307 57.02 3802 1505 84 S 19.43 E 3055.30 S 3800 5488 56.63 3902 1586 82 S 19.24 E 3198.63 S 3900 5670 56.83 4002 1668 82 S 20.32 E 3341.76 S 4000 5853 56.44 4102 1751 83 S 19.72 E 3485.27 S 4100 6032 55.91 4202 1830 79 S 21.43 E 3624.53 S 4200 6210 56.09 4302 1908 79 S 21.56 E 3762.18 S 4300 6391 56.54 4402 1989 80 S 22.04 E 3901.27 S 4400 6572 56.10 4502 2070 81 S 24.12 E 4040.46 S 4500 6750 55.46 4602 2148 78 S 25.63 E 4173.86 S 4600 6924 54.63 4702 2222 74 S 26.01 E 4302.20 S 4700 7097 54.73 4802 2295 73 S 26.87 E 4428.47 S 4800 7270 54.79 4902 2368 73 S 26.95 E 4554.84 S 4900 7444 54.78 5002 2442 73 S 26.83 E 4681.21 S 5000 7617 54.68 5102 2515 73 S 27.08 E 4807.28 S 5100 7790 54.35 5202 2588 73 S 27.11 E 4932.82 S 731.89 E 775.70 E 821.83 E 872.08 E. 920.11 E 970.84 E 1018.07 E 1064.00 E 1113.19 E 1166.82 E 1219.22 E 1268.36 E 1319.80 E 1372.06 E 1424.16 E 1478.55 E 1534.65 E 1592.68 E 1655.18 E 1717.41 E 1780.04 E 1844.05 E 1908.12 E 1972.20 E 2036.65 E 5200 7959 53.60 5302 2657 70 S 27.71 E 5054.50 S 2100.02 E LA-28 API50-029-22126 Page 8 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 05/02/91 ~UBSEA MEAS INCLN TVD )EPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5300 8128 53.75 5402 2726 69 S 28.10 E 5174.47 S 5400 8297 53.71 5502 2795 69 S 28.23 E 5294.97 S 5500 8467 54.15 5602 2865 70 S 29.24 E 5415.63 S 5600 8638 54.28 5702 2936 71 S 29.98 E 5536.13 S 5700 8810 54.40 5802 3008 72 S 30.48 E 5656.72 S 5800 8981 54.21 5902 3079 71 S 30.12 E 5776.51 S 5900 9153 54.86 6002 3151 72 S 26.83 E 5899.00 S 6000 9328 55.14 6102 3226 74 S 22.82 E 6028.96 S 6100 9506 56.49 6202 3304 79 S 23.05 E 6165.64 S 6200 9684 55.45 6302 3382 78 S 22.03 E 6301.00 S 6300 9859 54.55 6402 2163.53 E 2227.82 E 2294.04 E 2362.69 E 2432.86 E 2503.08 E 2570.79 E 2629.69 E 2687.36 E 2743.97 E 3457 75 S 16.65 E 6435.67 S 2792.62 E LA-28 API50-029-22126 Page 9 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 05/02/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 20.96 982 880 130 S 38.92 E 106 S 2000 50.26 1824 1722 645 S 22.19 E 581 S 3000 49.52 2429 2327 1440 S 18.58 E 1318 S 4000 54.91 3058 2956 2217 S 21.82 E 2048 S 5000 57.26 3636 3534 3032 S 20.25 E 2813 S DL/ 100 85 E 136 S 38.85 E 2.4 282 E 646 S 25.91 E 5.2 580 E 1440 S 23.73 E 1.7 849 E 2217 S 22.52 E 2.8 1131 E 3032 S 21.90 E 0.8 6000 55.92 4184 4082 3867 S 21.33 E 3600 S 7000 54.60 4746 4644 4693 S 26.27 E 4358 S 8000 53.52 5326 5224 5506 S 27.69 E 5083 S 9000 54.22 5913 5811 6310 S 30.05 E 5790 S 10000 54.29 6484 6382 7129 S 14.99 E 6546 S 1415 E 3868 S 21.45 E 1.1 1745 E 4694 S 21.82 E 0.2 2115 E 5506 S 22.59 E 0.2 2511 E 6311 S 23.44 E 0.3 2823 E 7129 S 23.32 E 0.0 AOGCC GEOLOGICAL idATEi:UALS INVENTOFIY LIST COMPLETION DATE check off or list data ~S' it i'~ re~iv'~d..list receiVed da'te for 407. if not required list as NFl 407 l* ~;/'7 ~C:ll drii'iin~' i~istory 'v/'" s"rv,ey I, ,~,~"~eli te~tS" /',~e"aesc,ip"o4 ~ cored inte'rvais , ,C,o,re ,analysis , , ,1~, ~ dry ditch intervals digital data .................... . ......... q77t--i ~,',,',, ' ........ i I i i ii i J i i i iii ii iiiiilll i iii ii i ii J ii [i i i i i i ii i~ i i i iI i iI i iiii i jl i I ii i II i i i i i i ,, , LoG ~PE ~N · INTEFiYALS- SCALE NO. ~ (to the nearest foot~ ,, [InchllO0'] - , '" ,,, ......... .... ' ........... I iJiJi J i iiiiJi iiii i i i i i ii ii i ]1 I iiiii Ii I iJJt t /i iii uJ i ii i i I i L J Il IIII III I IIIII II I I ...... ~ ........ ~ ~ ~ ....... ~~ ~~ ..... 12) ~ ~ ,, ,,, ,,,u , , , ,,~,,,, , , ~ t ,.. ~ ,, , ,,. , ,,, ~ ,,~ ' . ~ ~ '"'~" ' L ~ ,. t , .. , ~, , , , , ~ , ~ , H ..... i jl i i iii i i ii illll iii i i ii i I .J i i i ii iii i Hi i iJJ, i ~t . L IIjjI I I .~81 , , ,,,1,, , I I II I i i I iiiii i ~1 i ' ARCO Alaska, Inc. Date: May 31 1991 Transmittal #: 8116 ~ [---~0 1L-14 1L-14 1L-14 O, 0-15[ .,.'1A-1 7 ~I-0~._.1A-22.~ ~l1-0c~ -,4 A- 2 Ol t-01--"-,1 A- 2 8,,,~ '~1. A- 23//~ '~1 "'.t A- 28" ~.3G-19 RETURN TO: ' ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the folloWing items. signed copy of this transmittal. Cement Bond Log Geochemical Log Cement Evaluation Log Acoustic Cement Bond Log After Squeeze Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Please acknowledge receipt and return one 5-12-91 5300-6327 5-12-91 5100-6330 5-12-91 5300-6349 4-24-91 4800-8400 3-2-91 4981-7880 3-2-91 5276-7379 1 -25-91 7000-9914 3-26-91 5400-7984 3-3-91 5330-7380 3-2-91 5625-7860 1-25-91 7000-9894 3-26-91 5000-7958 Receipt Drilling Acknowledge :~--~~~. State of Date- TO: THRU: FROM: MEMORANoUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION .f~~? ~' DATE: Lonnie C. Sm February 14, 1991 Commis s ioner ~ FILE NO: DA214-1 TELEPHONE NO: Petro leur~/~ec tor SUBJECT: BOP Walk-Thru Insp AAI KRU 1A-28 Permit No. 91-02 Kuparuk Rv Field ~ Jan. ~ 1991: Lou Grimaldi and I traveled this date from Conoco's MPU to AAI's KRU 1A-28 well to conduct a BOPE/RIG walk-thru inspection on Doyon Rig No. 14. We conducted a thorough inspection of the BOP stack and related equipment and found all items to be in compliance. Attached. is an AOGCC BOPE/RIG walk-thru inspection form. In summary: Louis Grimaldi and I conducted a BOPE/RIG walk- thru inspection of AAI's KRU IA-28 well. on Doyon Rig No. 14. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 ,:NT BY'Xerox Tetecopier ?020 6594510;¢ 2 1. () ~.() ~.() 6.() 7.() () P I VE. RT ER ( ) (i Y/~ l~ne corm & enchored ( ) (-l~ bifurcated & dwn wind ( ) (~ 90" sargeted turn~ ( ) (~vlvs~ auto &stmultaneou& ( ) (~annu')ar pack-off (~condition STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COMMI SS ION BOPE Walk-Thru Inspection Report DATE, /" //~' "'~// ....... Permit # ~/~/ 11. ~2. (~' () BOP STACK wellhead flg wkg pre~ stack wkg press annul ar preventer p~pe ram~ b] t nd rams chke/ki 11 I f ne ~z 90° turn~ targeted (chke &ktll l n) HCR vtvs (chka & kill) manual vlvs (chke & kill) connections (flgd, whd~ clmpd) drl t~pool flow n~pple flow monitor control lines fire protected oprt,q pre&& pres(~ gauges sufficient vtvs regulator' bypass ~-way vlv~ (actuators) blind handln nnwr drtl I er control panel r~mot;o control panel (if apple) 9. RECORDS ( ) nitrogen power ~ource (back-up) ( ) condition (leak~, ho¢os, ere) b~e of last BOP in~pec~t<,n; Re~ulting fatlure~: Failures not corrected & why: Date cor'recttor)~ will be ~ompleted: D, p.~ fail p/__~, MUD SYSTEM 1. (~. ( ) ( ) pit level floats installed 2, (~ ( ) ( ) flow rate sen~or~ 3 (~ ( ) ( ) mud 9a~ ~eparator ~, (~ ( ) ( ) dega~er 5 (~i.~ ( ) ( ) separator bypass 7,{~ ( ) ( ) ohk~ In conn 8. ( ) ( ) trip t4nk pass f,.~,! 1,, n/_..Ea 1.(v¢ () 2. if () ~.( (> ~,(v¢x () s.(~ () 6( () () ( ) RIG FLOOR floor vlvs (dots vlv, ball vlv) kelly & floor vlv wreneheB (flow monitor flow rate Indicator) drtller'~ con~ole (pit level tndtcators~ gauge~) kill nheet up-to-date gas ~etection monitor~ (H S & m~than~) hyUr chke panel F. pa~_~_ fail n/~ MtSO EQUIPMENT 3. ('~ ( ) ( ) 90~ turn~ targeted ~.() () S.<) () 6, (~,r' () Date of Im~t BOP tmSt; (dwn strm choke lng) reserve ptt tankage personnel protective equip avail nll drl ~tte ~m. iprv~ t~atned 2for prooedurem H S probe~ ri~ housekeeping 6,OO13 (rev 01/17191 Inupeotor ARCO Alaska, Inc. Date: January 25, 1991 Transmittal #: 7993 RETURN TO:. ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. '"~1A-26 -..1 A-26 '-,.1A-26 ~-1 A-26 "'-,,1 A- 26 '---1A-26 -~..1 A-26 '~-1 A-26 'X, 1A-28 ",. 1A-28 Formation Test Log High Resolution Induction DFL 5"/100' High Resolution Induction DFL 2"/100' High Resolution Induction DFL Raw X and Raw R Microiog Spectral Density Dual Spaced Neutron Raw Data Spectral Density Dual Spaced Neutron Porosity Spectral Density Dual Spaced Neutron High Resolution Pass Dual Gamma Ray-Compensated Neutron Porosity-Simultaneous Formation Density Dual Gamma Ray-Electromagnetic Receipt Please acknowledge receipt 1 -8-91 1 -7-91 1-7-91 1-17-91 I -7-91 I -7-91 I -7-91 1-7-91 1-19-91 1-19-91 Wave Resistivity,~. ~i~.. _... i'~A t~, Acknowledged: - - - '~v:' -' -"J-l- ~ ~tm~'~ ~- ~ ........ D 4632-8250 0-8124 0-8124 0-8124 0-8090 0-8091 0-8091 0-8091 8994-9915 8994-9915 ate: .......... DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) RECEIVED d A I~l ?_ 9 19 ¢ 1 {.~,)no. Commission Alaska Oil & fS~.s "~" Anchorage ARCO Alaska, Inc.,, Date: January 25, 1991 Transmittal #: 7992 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are 'the following items. one signed copy of this transmittal. 1A-26 1A-26 1A-28 Receipt Please acknowledge receipt and return LIS Tape and Listing I - 8 - 9 1 LIS Tape and Listing I - 7 - 9 1 LIS Tape and Listi.ngA. I - 2 2 - 9 1 Acknowledged: AK RB910103~- c.~--~.-7 ~' Date: DISTRIBUTION: Lynn Goettinger State of Alaska · . ~'~ RECEIVED JAN 2 9 t991 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION January 4, 1991 WALTER ]. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 P H O N E: (907) 279-1433 TELECOPY NO: (907) 276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re.' Kuparuk River Unit 1A-28 ARCO Alaska, Inc. Permit No. 91-02 Sur. Loc. 587'FSL, 309'FWL, Sec. 5, T11N, R10E, UM Btmhole Loc. 599'FNL, 2252'FEL, Sec. 17, T11N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf / Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc]. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51~ PERMIT TO DRILL 2O AAC 25.OO5 ! la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory...._ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service ~ Development Gas ~ Single Zone ~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 102'. Pad 67' Gl. feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25652 ALK 2578 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 587' FSL, 309' FWL, Sec. 5, T11N, R10E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 105' FNL, 2460' FEL, Sec. 17, T11N, R10E, UM 16-28 #U630610 At total depth 9. Approximate spud date Amount 599' FNL, 2252' FEL, Sec 17, T11N, R10E, UM 10-JAN-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) !property line 1A-8 9841' MD 599' @ TD feet 15' at 720' MD feet 2469 6443' TVD leet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300' feet Maximum hole an~le 54° Maximum surface 2290 ps~ At total depth (TVD) 3690 psi~l @ 6443' 18. Casing program Selling Deplh size Specification Top Bottom Quantity of cement Hole Casin~l Wet,Iht Grade Couplin~ Len~lth IVE) TVD IVD TVD {include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 5469' 35' 35' 5504' 3867 2290 Cu. Ft. AS III & HF-ERW 580 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MO[ 5469' 35' 35' 5504' 3867' 260 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 4337' 5504' 3867'i 9841' 6443' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth Structural Conductor Cu. R. Surface Cu. R. Intermediate ~J[-\[~ - 2 Production Liner Alaska 0il & Gas Cons. Perforation depth: measured nch0rage. true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch X Drilling program ~ Drilling fluid program X~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned /'/~~/~ ~.~~ CommissionTitle useAreaonlyDrillin~ Encjineer Date //~'~/~;;;~/ ?~/- O,~ 50- O~? - ~-, ~'- ~' ,,~,,~ U//U~/91 other requirements Conditions of approval Samples required .._Y e s ,~ N o Mud Icg required~ Y e s ~ N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~.Yes ~ N o Required working pressure for BOPE ~2M; ~ 3 M'~ 5M' ~ 1 0M' ~ 1 5 M Approved b Commissioner the commission Date ! Form 10-401 Rev. -89 ~ Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD lA PAD , . . . . . al . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. DRILLING FLUID PROGRAM (1A-28) Spud to 9-5/8" Drill out to surface casino weiaht uo -- _ Density 8.6-10.0 8.6-9.6 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-4 0 4- 8 APl Filtrate 1 0-1 2 8- 1 0 pH 9- 1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drillina Fluid System: Triple Tandem Shale Shaker (2) Mud Cleaners Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators NoteS: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2290 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1A-28 will be 1A-8. As designed, the minimum distance between the two wells would be 15' at 720' MD. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. ARCO ALASKA, Inc. Pad lA, Nell Not 28 prOposed Kupaeuk Field, Noeth Slope, Alaska ~ ! 000 _ 2000 _ 3000. 4000 _ 5000 _ sooo. ?000 ,, 0 RKB ELEVATION, 102' KOP TVD-300 TMD-300 DEP'O 9 BUILD 3 OEO 15 PER I00 FT 21 27 33 ae B/ PERMAFROST TVD-1502 TMD-1600 OEP-426 45 si EOC ?VD-1836 TMD-208$ DEP-?75 T/ UONU SNDS TVD-2642 TMD-3442 DEP-1867 AVERAGE ANGLE 53 DEG 34 HI N T/ ~ SAK SNDS TVD-3227 TMD-4426 DEP-2659 B/ W SAK SNDS TVD-3667 THO-516? OEP-3255 9 5/8' CSG PT TVD-3867 TMD-5504 DEP-3526 K-lO TVD-4052 THD-5815 DEP-3776 K-$ TVD-5082 THO-?550 DEP-51?I TARGET - T/ ZONE C TVD=604? TMD=9174 DEP=6478 .T/ ZONE A TVD-6213 TMD=9454 DEP=6?03 B/ KUP SNDS ?VD-6324 ?MD-9641 DEP-6854 TD / LOG PT TVD-6443 ?MD-9841 DEP-?015 I 1000 I I I I 2000 3000 4000 $000 VERT I CAL ' SECT l ON I 6O00 I 7000 I 8000 HORIZONTAL PROJECTI ON SCALE I IN. - I000 FEET Z 1000 _ I 000 _ 2000 _ ~ooo _ 4000 5000 _ 6000 . 7000 _ ARCO ALASKA, Ino. ,^...,, .o. Kuperuk Field. NorthSl°pe, Almokm 000 0 I WEST-EAST 1000 2000 I I SURFACE LOCArlO#. SSF' FSL, 300' F~L SEC. 5, TII#, RIOE ~000 I S 22 DEG 48 HI N E 6478' [TO TARGET) TARGET TVDI604F Tfll)-OIF4 DEP-64F8 SOUTH SOFa EAST 2511 TAROET LOCATION, lOS' FILL. 2460' FEL SEC. IF. TIIN. RIOE TO LOCATION, 590' FNL. 2252' FEL SEC. IF. TIIN. RIOE Alaska Oil a ass Cons. Anchorage 700 650 I00 150 200 250 300 I I I I , ,,I I 600 I I 550 I 500 I 450 I I I 400 _ j 350 ..~/ I I 300 I I 250 I I I 200. ! ! ?00 ! / / / / ! / 500 ! ! ! ! · 1300 ! 21 O0 1 ?00 · I I ! ! 900 350 400 450 500 ,, I I I I / ! / / '~ I100 ~0 17001 I I t 1300 15eO I I I 1900 I I I ! I I J 1500 I I I ! I I00 300 ?00 \ \ 1500 I ~$00 502? \~r' I t I I~oo I I ! o0 I ?oo~ { soo 0 \ 900 1 o0 I0o \ \ \ ~o ?00 I I I I I 300 \ \ \ 2100 x 100 150 200 250 ~00 ~50 400 450 500 700 650 600 550 5OO 450 4OO 35O 300 250 t200 K~PARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 5 I 4 I I 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION , . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"-2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 ,6 , 13 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 5 4 BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3(X)0 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS ITEM (l) Fee 1. APPROVE DATE (2) (2 thru 8) Admin ~p/ ~ 9. (9 Thru 13) 10. (10 and 13) 12. 13. Case /~,~ /-3-f? (14 thru 22) 14. 15. (5) BOPE ,, (23 thru 28) Company ~./p~_ ~ ........ LeaSeyEs & WellNoNO. _ _~/3/- Z 3' ~.. ......... ~f~d~{ //~ -_,~ ~ Is the permit fee attached .......................................... "'~ -- ,, , · ~ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well td be located in a defined pool ............................. 3, Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-daywait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~. . Are necessary diagrams and descriptions of diverter and BOPE attached. ~z~ ,, - Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. '" ~ (6) OTHER /~>0,,.(2~ th (6) Add: .,'~. C~. ,'~/" / /'3- ~. " _ Geology: Eng~e~g: DW3 ~ LCS~BEW ~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented mm mm~ mm ~ Additional requirements ............................................. ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 91/01/22 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 91/01/22 ORIGIN OF DATA: 1A28 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 1A28.RPT SERVICE NAME: RLL VERSION #: V 3.26 DATE: 91/01/22 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 1A-28// API#: 50-029-22126// DATE: 19-JAN-90 LOCATION: 587' FNL, 309' FEL, SEC. 5, TWP. llN, RANGE 10E, KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA// RIG: DOYON 14// CO. REP.: McCAULEY// SSDS ENG.: GALVIN & WANG. COMMENTS ***> ALL MEASUREMENTS MADE AFTER DRILLING. TOOLS WERE NOT DOWN HOLE FOR MWD RUN. NEUTRON AND DENSITY DATA ARE CALIPER CORRECTED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR MAD OHMM 0 0 0 0 1 4 0 1 68 RATE MAD FT/H 0 0 0 0 1 4 0 1 68 CAL INCH 0 0 0 0 1 4 0 1 68 RHOB MAD G/C3 0 0 0 0 1 4 0 1 68 DDN MAD PPF 0 0 0 0 1 4 0 1 68 NFO MAD CTS 0 0 0 0 1 4 0 1 68 NFl MAD CTS 0 0 0 0 1 4 0 1 68 NN0 MAD CTS 0 0 0 0 1 4 0 1 68 NN1 MAD CTS 0 0 0 0 1 4 0 1 68 DDD MAD PPF 0 0 0 0 1 4 0 1 68 GRC MAD API 0 0 0 0 1 4 0 1 68 NPSC MAD P . U . 0 0 0 0 1 4 0 1 68 RHOB MAD G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT EWR RATE CAL RHOB DDN NFO NFl NN0 NN1 DDD GRC NPSC RHOB MAD MAD MAD MAD MAD MAD MAD MAD MAD MAD MAD MAD FT OHMM FT/H INCH G/C3 PPF CTS CTS CTS CTS PPF API P.U. G/C3 68 68 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR RATE CAL RHOB DDN NF0 NFl NN0 NN1 DDD GRC NPSC RHOB 8850.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8900.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9000.000 519.000 2.345 133.333 9.124 2.265 1.639 2344.000 2312.000 1.493 117.618 47.656 9100.000 531.000 469.000 2.371 9200.000 445.000 2.774 131.083 8.921 2.240 1.235 508.000 2360.000 2400.000 1.190 110.431 45.208 2.345 9300.000 503.000 2.472 119.531 8.894 2.278 1.695 469.000 2280.000 2216.000 1.333 110.848 51.567 2.385 9400.000 535.000 3.074 139.108 8.789 2.224 1.527 2488.000 2440.000 1.515 120.378 43.353 9500.000 555.000 5.537 160.802 8.840 2.182 1.099 2616.000 2536.000 2.041 80.584 39.730 497.000 2.328 9600.000 493.000 4.978 179.464 8.813 2616.000 2672.000 -999.250 9700.000 551.000 527.000 2.284 9800.000 527.000 2.190 1.342 555.000 91.427 37.195 2.292 9900.000 -999.250 3.299 127.865 9.148 2.284 1.124 535.000 2696.000 2600.000 1.149 92.314 40.181 2.391 10.463 133.333 8.771 2.292 1.725 2712.000 2632.000 1.389 88.490 36.009 3.531 148.308 8.892 2.214 1.695 2408.000 2520.000 1.538 100.097 45.055 527.000 2.400 -999.250 149.854 -999.250 -999.250 -999.250 -999.250 ** 123 DATA RECORDS ** 1024 ** FILE TRAILER** 493.000 2.318 ********** END OF FILE (EOF # 2) ********** FILE NAME: 1A28.RPT SERVICE NAME: RLL VERSION #: V 3.26 DATE: 91/01/22 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: FROM 8850.00 TO 9950.00 FT -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** TAPE TRAILER** SERVICE NAME: RLL DATE: 91/01/22 ORIGIN OF DATA: 1A28 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 91/01/22 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********
