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Home My WebLink About185-036By Samantha Carlisle at 10:36 am, Aug 19, 2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 10, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-09 MILNE PT UNIT C-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/10/2022 C-09 50-029-21299-00-00 185-036-0 G SPT 6834 1850360 1708 2298 2302 2301 2299 INITAL P Guy Cook 5/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-09 Inspection Date: Tubing OA Packer Depth 780 3038 2964 2947IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220509164304 BBL Pumped:2.6 BBL Returned:2.5 Friday, June 10, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 6XQGU\FRQYHUWWR:$*LQMHFWRUIURP2LOSURGXFHU James B. Regg Digitally signed by James B. Regg Date: 2022.06.10 14:53:49 -08'00' Hilcorp Alaska, LLC David Haakinson, Milne Point Operations Manager 3800 Centerpoint Dr, Suite 400 Anchorage, Alaska 99503 05/18/2022 Chairman Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Safety Valve System Pilot Setpoint Error for Milne Point well C-09 (PTD# 185-036), Hilcorp Alaska, LLC. Dear Chairman Price, Please see below for information regarding the C-09 (PTD# 185-036) safety valve system low pressure pilot setpoint error incident on 05/10/2022. Event Summary: Milne Point, Kuparuk well C-09 was a gas lifted producer, originally drilled in 1998. On 03/02/2022, the well was approved under Sundry # 322-060 to be converted to a water alternating gas (WAG) injector. The well was placed on gas injection the morning of 5/6/2022. On 05/10/2022, state witnessed testing of the safety valve system (SVS) on C- 09 failed to actuate the low-pressure pilot (LPP) and close the surface safety valve (SSV). Upon investigation, it was found that the LPP sensor setpoint was incorrectly set in the production automation system for the current injection pressure. The LPP setpoint was corrected and C-09 passed waived witness SVS testing on 05/16/2022. Investigation Details: Recent timeline of events leading to discovery of the incorrect LPP setpoint on C-09 on 05/10/2022: o 03/02/2022: Sundry approval to convert C-09 to WAG injection. o 05/05/2022: Functional check-out (FCO) of conversion to WAG injection, pilot setpoint set to 2500 psi. o 05/06/2020: C-09 placed on gas injection. o 05/10/2022: C-09 AOGCC witnessed SVS testing, LPP failed to trip. o 05/10/2022: C-09 LPP setpoint found to be incorrect. Setpoint changed and transmitter successfully function tested. o 05/12/2022: C-09 brought on injection with AOGCC approval and SSV was function tested. o 05/16/2022: C-09 AOGCC waived witness SVS testing passed. The SVS LPP on well C-09 is an electronic pressure sensor/transmitter that is set in the production automation control system by the automation tech at the request of the pad operator. When the flowline pressure drops below the sensor setpoint value, hydraulic pressure is dumped from the SVS, closing the SSV. Control logic within the automation system requires the tubing injection pressure to be above the LPP actuation pressure to initially arm the system such that when the tubing injection pressure falls below the actuation pressure the SVS hydraulic pressure is dumped. If the well is brought on injection and the tubing injection pressure never goes higher than the LPP actuation pressure setpoint, the system does not arm itself, and does not flag in the control automation system as an error. This start-up condition override is required to get the SSV open when the pressure is initially below normal operating conditions. Per 20 AAC 25.265(h)(10) the system actuation pressure must be greater than 50% of the injection tubing pressure for C-09. Well tie-in changes occurred from 03/25/2022 - 05/05/2022 as part of work to convert C-09 from a producer to a WAG injector under Sundry # 322-060. Initial target gas injection pressure into C-09 was planned to be 3200 psi; based on this the LPP was set to 2500psi on 05/05/2022. Functional checkout of the SVS was completed on 05/05/2022, including a successful function test of the LPP sensor/ transmitter and actuation of the SSV while the well was shut in at the wing valve. On 05/06/2022, C-09 was placed on gas injection with the injection rate choked back more than By Samantha Carlisle at 2:52 pm, May 19, 2022 initially planned due to engineering requests to reduce the gas injection rate. Due to injection being choked back, tubing injection pressure was ~2,300psi and the LPP setpoint in the automation system remained at 2500psi as set in the FCO. The LPP setpoint change requirement was overlooked by the pad operators. On 05/10/2022, during AOGCC witnessed SVS testing of C-09, the LPP failed to trip. The LPP did not trip even though the LPP actuation setpoint (2500psi) was above the tubing injection pressure (2300psi). This was due to control logic which did not arm the transmitter to dump the SVS system hydraulic pressure because the tubing injection pressure never initially exceeded the LPP actuation setpoint. No alarms were present in the production control system to flag on the scenario where the pilot set point was above the injection pressure. After failure of the test the well was shut in. Upon troubleshooting, it was discovered that the LPP setpoint was at 2500psi in the automation system with the well injecting at ~2300psi. The LPP actuation pressure was reset to 1800psi, and the pressure transmitter was function tested successfully on 05/10/2022. C-09 was placed on gas injection on 05/12/2022 and successfully passed AOGCC waived witness SVS testing on 05/16/2022 Timeframe the SVS LPP was incorrectly set: 05/06-05/10/2022= 4 days- SVS LPP incorrectly set while the well was flowing. Root cause of the incident: x Field Operator failed to correctly set the C-09 LPP setpoint when the tubing injection pressure was changed to ~2300psi from the initially planned pressure of 3200psi. x LPP actuation setpoint error did not flag in the automations control system due to specific scenario logic not being present. Contributing factors of the incident: x LPP was functionally tested on shut in well. Well operating conditions were different, and the wellhead injection pressure was lower than prescribed on setup of LPP setpoints. Actions to prevent recurrence: x Update MPU production control pad operating limit screen pilot setpoint to flag pilots on wells with setpoints that have not reached their limits and become functional. Completed at MPU. Reviewing applicability for other North Slope assets. x Expand MPU automation logic to automatically shut in SSV on wells if the pilot setpoint pressure conditions have not been met after one hour. This logic already exists on MPU ESP producers and will be completed for the remainder of wells. Completed at MPU. Reviewing applicability for other North Slope assets. x On all North Slope conversions, rig workovers and new drill wells, SSV will be functionally tested after bringing the well online to ensure operating conditions are within the preset limits input during the functional check-out process. x Safety Bulletin about incident to be distributed across the Hilcorp Alaska assets and reviewed with Hilcorp North Slope pad operators and production control by 05/25/2022. If you have any questions, please call me at 907-777-8343 or Oliver Sternicki at 907-564-4891. Sincerely, David Haakinson Milne Point Operations Manager Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.05.19 11:52:32 -08'00' David Haakinson (3533) Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-09 (PTD 185-036) Leak Point Survey 4/17/2022 Please include current contact information if different from above. PTD:185-036 T36559 Kayla Junke Digitally signed by Kayla Junke Date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+LOFRUS$ODVND//& 0,/1(3781,7& 0,/1(32,17.83$58.5,9(52,/ &2' /HQJWK 6L]H /16&7 79' %XUVW 0' SVL SVL SVL 3HUIRUDWLRQ'HSWK0'IW 6HH6FKHPDWLF 6HH6FKHPDWLF ([W&DVLQJ3NU[+(6717 [%DNHU3HUPDQG1$0'79'0'79' 0'79'DQG1$ U\ 6WDWX )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO Taylor wellman for David Haakinson By Samantha Carlisle at 2:45 pm, Feb 09, 2022 'LJLWDOO\VLJQHGE\7D\ORU :HOOPDQ '1FQ 7D\ORU:HOOPDQ RX 8VHUV 'DWH 7D\ORU:HOOPDQ '/% $2*&&WRZLWQHVV&0,77[,$WRSVLSULRUWRLQMHFWLRQ ; '650*5)(% GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.02 14:57:52 -09'00' RBDMS SJC 030322 ŽŶǀĞƌƐŝŽŶ tĞůů͗DWhͲϬϵ ĂƚĞ͗ϬϮͬϳͬϮϮ tĞůůEĂŵĞ͗DWhͲϬϵ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϭϮϵϵͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/KŝůtĞůů WĂĚ͗ͲWĂĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗DĂƌĐŚϭϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍zĞƐ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗dŽŵ&ŽƵƚƐ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϱͲϬϯϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ƌŝĂŶ'ůĂƐŚĞĞŶ ϵϬϳͲϱϰϱͲϭϭϰϰ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗dĞĚ<ƌĂŵĞƌ ϵϬϳͲϳϳϳͲϴϰϮϬ &EƵŵďĞƌ͗yyyyyyy :ŽďdǇƉĞ͗ŽŶǀĞƌƚƚŽt'/ŶũĞĐƚŽƌ &XUUHQW%RWWRP+ROH3UHVVXUH 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ƚŚĂƚĨŽƵŶĚƌŽƵŐŚůǇϭ͕ϬϬϬ͛ŽĨŶĞƚƉĂǇŝŶƚŚĞ<ƵƉĂƌƵŬϯĂŶĚϮ͘ͲϬϵŚĂƐƚŚĞ<ƵƉĂƌƵŬϯĂŶĚϮƐĂŶĚƐ ŽƉĞŶƚŽƉƌŽĚƵĐƚŝŽŶ͘ͲϬϵŝƐůŽĐĂƚĞĚΕϮ͕ϬϬϬ͛ƚŽƚŚĞƐŽƵƚŚĞĂƐƚŽĨ>ͲϬϲĂŶĚŝƐŝĚĞĂůůǇůŽĐĂƚĞĚƚŽƉƌŽǀŝĚĞ ŝŶũĞĐƚŝŽŶƐƵƉƉŽƌƚƚŽƚŚŝƐŶĞǁĚƌŝůů͘ŽŶǀĞƌƚŝŶŐͲϬϵƚŽĂŶŝŶũĞĐƚŽƌǁŽƵůĚŝŵƉƌŽǀĞŽǀĞƌĂůůƐǁĞĞƉ ĞĨĨŝĐŝĞŶĐǇŽĨƚŚĞŚǇĚƌĂƵůŝĐƵŶŝƚĂŶĚŝŶĐƌĞĂƐĞƌĞĐŽǀĞƌǇƐŝŐŶŝĨŝĐĂŶƚůǇ͘ THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-09 Permit to Drill Number: 185-036 Sundry Number: 319-029 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner /-� DATED thisye day f January, 2019. RBDMS']3FPR n 12019 RECEIVED STATE OF ALASKA JAN 2 4 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /4o�C� 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: Convert to Jet Pump ❑v 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q ' Stratigraphic ❑ Service ❑ 185-036 3. Address: 3800 Centerpoint Dr, Suite 1400 S. API Number: Anchorage Alaska 99503 50-029-21299-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MILNE PT UNIT C-09 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0047434 MILNE POINT! KUPARUK RIVER OIL ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,881' 7,303' 10,725' 7,213' 2,700 10,772' 10,725' (Fill) Casing Length Size MD TVD Burst Collapse Conductor 103' 13-3/8" 103' 103' 1,730psi 740psi Surface 6,603' 9-5/8" 6,603' 4,693' 3,520psi 2,020psi Production 10,870' 7" 10,670' 7,297' 7,240psi 5,41 Ops! Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" 9.2# / L-80 / TC -II 10,204' See Schematic See Schematic 3-1/2" 9.3# / L-80 / NSCT 10,307' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Ext. Casing Pkr, 7" x 3.5" HES TNT & 7"x3.5" Baker Perm and N/A 1,807MD/ 1,745TVD, 10,90MD/ 6,834TVD & 10,270MD/ 6,945TVD and N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/5/2019 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: 8 orhola 0 hilcor .com Contact Phone: 777-8412 Authorized Signature: Date: 1/22/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (�]7 1. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ (.� Spacing Exception Required? Yes El% No d Subsequent Form Required: I c) — I O APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 0 RBDMSSV�FFR 0 12019 /s��" 'V Submit Form and \ Form 10-403 Revised 4/2017 Approved application is valid fgr'r a �# tr�� t a�o�oprovaL t Attachments in Duplicate U IU]mry Alaska, LU Well Prognosis Well: MPU C-09 Date:01/22/2019 Well Name: MPU C-09 API Number: 50-029-21299-00 Current Status: Oil Well Pad: C -Pad Estimated Start Date: February 5t^, 2019 Rig: Wireline Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-036 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Current Bottom Hole Pressure: 3,400 psi @ 7,000' ND (SBH PS 12/31/2013 / 9.34 ppg EMW) Maximum Expected BHP: 3,400 psi @ 7,000' ND (No new perfs being added) MPSP: 2,700 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU C-09 was drilled and completed in March 1985 as a gaslifted Kuparuk producer completed with straddle packers across the Kuparuk C -1/B-6 sands and the A-2 sand open at the bottom of the well. The A-2 was fracture stimulated and the A-3 was perforated thru-tubing. A workover in October 1994 pulled the completion, added perfs in the B-6 and A-3, re-fracture stimulated the well and an ESP completion was ran in the well. The ESP was replaced in July 1995 w/ Nabors 4E5, February 1998 w/ Nabors 5S, converted to Gaslift in May 1999 w/ Nabors 4E5, A gas leak in the casing head was discovered on August 5, 2008. A rig workover with Doyon 14 in January 2014 cut and pulled the 3-1/2" tubing, cut and pulled the 1,807' of 7", ran new 7" with an external casing packer and cemented to surface. A new gaslift completion was set tying into the existing permanent packer. Notes Regarding Wellbore Condition • 7" casing tested to 3,500 psi for 30 minutes 01/28/2014. • Well has a history of gas slugging that affects plant operations. • All GLMs will be dummied off. - Objective: The purpose of this work is to install a reverse circulating thru-tubing jet pump in the existing 3-1/2" / completion. Brief Procedure: Slickline Procedure: 1. MIRU Slickline and PCE (Press Control Equip) PT lubricator to 3,500 psi Hi 250 Low. 2. RIH w/ 2.70" drift and tag PBTD. 3. RIH w/ bailers and recover any fill. Bail fill if above 10,680' MD. 4. RIH w/ brushes and brush planned packer setting depths of 9,401' MD and 9,419' MD. 5. RIH and set catcher sub in XN profile at 10,295' MD. 6. RIH and pull OGLV from Station #1 at 9,407' MD. 0 Hil.ru Alaska. M 7. RIH and set DGLV in Station #1 at 9,407' MD. A 8. RIH and pull LGLVs in Stations #247. 9. RIH and set DGLVs in Stations #2-#7. J 10. RU Pump Truck and pressure test annulus to test annulus to 3,500 psi for 30 min and chart. 30 min and chart. 11. RIH and pull DGLV from Station #1 at 9,407' MD. 12. RIH and set Circulating Valve in Station #1 at 9,407' MD. 13. RIH and pull catcher sub in XN profile at 10,295' MD. 14. RD Slickline and PCE. Eline Procedure: 15. RU E -line. Test lubricator to 250/3,500 psi. Well Prognosis Well: MPU C-09 Date:01/22/2019 16. MU lower packer assembly. 17. RIH at maximum running speed of 150 ft/min to a setting depth of+/- 9,418' MD. 18. Record PU and SO weights. Correlate depths using GR/CCL across GLM at 9.407' MD. . 19. Set packer at+/- 9,418' MD. Confirm set and POOH. a. Correlate to tie-in log 4/01/1985 DIL. 20. RD E -line. Slickline Procedure: 21. MIRU Slickline and PCE (Press Control Equip) PT lubricator to 3,500 psi Hi 250 Low. 22. MU snap latch to upper packer/ jet pump assembly. a. Snap Latch/Spacer/Jet Pump/Spacer/Upper Packer (Bottom to Top). 23. RIH at maximum running speed of 150 ft/min to a setting depth of+/- 9,398' MD. 24. Record PU and SO weights. Enter packer bore at 9,418' and snap into packer (100 Ibs to snap in). 25. Pull to confirm snap latch is engaged (1,200 lbs to snap out). 26. Once confirmed snap latch is set, set upper packer. 27. Tag to confirm packer is set. POOH. 28. RD Slickline and PCE. 29. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic K Hile .p Alaeke, LLC Initial KB Elev.: 5Y (Alaska United#3) TD= 10,88T (ND) /TD= 7,30(TVD) PBTD=10,725' (ND) / PBiD=7,213'(TVD) SCHEMATIC Milne Point Unit Well: MP C-09 Last Completed: 1/27/2014 PTD: 185-036 TREE & WELLHEAD Tree 4 -1/6" -API 5K Wellhead 11" x 5K SLX 7" CIW Sliplock w/ SA -SRL 4-1/2" 7" 12.6lb TC -II Top & Bottom CIW 4" BPV Profile OPEN HOLE/ CEMENT DETAIL 9-5/8" 2,600 sx Permafrost E & 275sx Class "G" in a 12-1/4" Hole 9-5/8" x 7" 358 sx bbls, Class "G" 7" 1 271 sx Class "G" in 8-1/2" Hole CASING DETAIL WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 61' @ 6,212' Hole Angle thru perforations= 52° Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48#/H-40/N/A N/A" Surface 103' N/A 9-5/8" Surface 36#/K-55/Btrs. 8.681" Surface 6,603' 0.0773 7" Production 26#/L-80/Btrs. 6.276" Surface 10,870' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.2#/1--80/TC-II 2.992" Surface 10,204' 0.0087 3-1/2" Tubing 9.3#/L-80/TC-II 2.992" li 10,197 10,307' 0.0087 JEWELRY DETAIL No Depth Item 1 1,807' 7" External Casing Packer 2 2,045' 3-1/2"XNipple I13=2.813 W/ Tubing WHC/O - Doyon 16 - 1/29/2014 GLM Detail -3-1/2" x1-1/2" MMG w/ RK Latches 3 2,270' ST 7: Port= 16, Dev.= 38, VLV= Dome, TVD= 2,120', 11/1/2015 4 4,437' ST 6: Port= 16, Dev, 55, VLV= Dome, TVD= 3,491', 11/1/2015 5 5,801' ST 5:Port=16,Dev.=55,VLV= Dome, TVD= 4,278', 11/1/2015 6 6,839' sT 4: Pon= 16, Dev, =58, VLV= Dome, TVD= 4,816', 11/1/2015 7 7,780' ST 3: Port= 16, Dev, =52, VLV= Dome, TVD= 5,376', 11/1/2015 8 8,661' ST 2: Port= 16, Dev, 51, VLV= Dome, TVD= 5,891', 11/1/2015 9 9,407' STI: Port= 36, Dev, SO, VLV= S/0, TVD= 6,407', 12/29/2018 30 10,059' 3-1/2"X Nipple, ID= 2.813 Ti- 10,090' 7" x 3-1/2" Vam Top HES TNT Packer, ID= 2.949" 12 10,126' 3-1/2" X Nipple w/ RHC -M, ID= 2.813 131218 10/94 & 7/95 7"x3-1/2" Unique Machine Overshot -Btm@10,204' 14 10,270' 7" x 3-1/2" Baker Perm Packer 15 30,29S' 3-1/2" XN Nipple, MIN ID= 2.750 16 10,306' WLEG - Bottom @10,307 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status Size W/ Tubing WHC/O - Doyon 16 - 1/29/2014 10,392' 10,406' 7,018' 7,026' 14 10/94 & 7/95 Open 5"& 3.S" 10,454' 10,464' 7,055' 7,060' 10 10/94 & 7/95 Open 5"& 3.5" Kuparuk 10,498' 10,502' 7,081' 7,083' 4 10/94 & 719S Open 5"& 3.5" 10,609' 10,629' 7,146' 7,158' 20 10/94 & 7/95 Open 5"& 3.5" 10,646' 10,680' 7,167' 7,187' 34 10/94 & 7/95 Open 5"& 3.5" Ref Log: DIL 4/1/1985 STIMULATION SUMMARY 7/4/98-A-2 Frac Sand 72M# of 16/2015P 10/30/98-'C' Sand 27M#20/40 & 168M# of 16/20 Carbolite behind pipe GENERALWELLINFO API: 50-029-21299-00-00 Drilled and Completed by AUDI #3-4-8-1985 RWO ESP -10/17/1994 RWO ESP Nabors 5-S - 2/20/1998 RWO ESP Nabors 4ES - 5/15/1999 RWO W/ Tubing WHC/O - Doyon 16 - 1/29/2014 Revised By: TDF 1/10/2018 Milne Point Unit Well: MPC -09 PROPOSED Last Completed: Proposed HilcorP Aluke. LLC PTD: 185-036 Initial KB Elev.: 52' (Alaska United #3) r,5 TREE & WELLHEAD Tree 4-1/6"-AP15K Wellhead 11"x5KSLX7"CIWSliplockw/SA-SRL4-1/2" 9-5/8"x7" 358 sx bbls, Class "G" 12.6lb TC -11 Top & Bottom ClVV 4" BPV Profile OPEN HOLE/CEMENT DETAIL WELL INCLINATION DETAIL 9-5/8" 2,600 sx Permafrost E & 275$x Class "G" in a 12-1/4" Hole KOP @ 500' 9-5/8"x7" 358 sx bbls, Class "G" Max Hole Angle =61°@6,212' 7" 271 sx Class "G"in 8-1/2" Hole Hole Angle thru perforations= 52' CASING DETAIL 48#/H-40/N/A TD=10.881' (MD)/TD=7,303 MM) PBTD =10,725' (MD) / PBTD = 7,21T(TVD) Size Type Wt/ Grade/ Conn ID I Top I Btm BPF 13-3/8" Conduaor 48#/H-40/N/A N/A" I Surface 103' N/A 9-5/8" Surface 36#/K-55/Btrs. 8.681" Surface 6,603' 0.0773 7" Production 26#/L-80/Btrs. 6.276" Surface 10,870' 0.0383 TUBING DETAIL 3-1/2" Tubing 9.2#/L-80/TC-II 2.992" Surface 10,204' 0.0087 3-1/2" Tubing 9.3#/L-80/TC-II 2.992" 10,197 10,307' 0.0087 JEWELRY DETAIL No Depth Item 1 1,807' 7" External Casing Packer 2 2,045' 3-1/2"X Nipple ID=2.813 KUP C3 GLM Detail - 3-1/2" x 1-1/2" MMG w/ RK Latches 3 2,270' ST 7: Port= 16, Dev.= 38, VLV= Dome, TVD= 2,120', 11/1/2015 4 4,437' ST 6: Port= 16, Dev.= 55, VLV= Dome, ND= 3,491', 11/1/2015 5 5,801' ST 5: Port= 16, Dev, =55, VLV= Dome, TVD= 4,278', 11/1/2015 6 6,839' ST4: Port= 16, Dev, 58, VLV= Dome, TVD= 4,816', 11/1/2015 7 7,780' ST 3: Port= 16, Dev.=52, VLV= Dome, TVD= 5,376', 11/1/2015 8 8,661' ST 2: Port= 16, Dev.=51, VLV= Dome, ND= 5,891', 11/1/2015 9 9,398' 3-1/2" Paragon 11 Packer 10 9,407' ST 1: Port= 16, Dev.=50, VLV=S/O, ND= 6,407', 12/29/2018 11 9,408' Top of Jet Pump 12 9,418' 3-1/2" HP Paragon Il Packer 13 10,059' 3-1/2" X Nipple, ID= 2.813 14 10,090' 7" x 3-1/2" Vam Top HES TNT Packer, ID= 2.949" IS 10,126' 3-1/2" X Nipple w/ RHC -M, M=2.813 16 10,189' 7"x3-1/2" Unique Machine Overshot - Btm @ 10,204' 17 10,270' 7" x 3-1/2" Baker Perm Packer 18 10,295' 3-1/2" XN Nipple, MIN D= 2.750 19 10,306' WLEG-Bottom @10,307 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status Size KUP C3 10,392' 10,406' 7,018' 7,026' 14 10/94&7/95 Open 5"&3.5" KUP B6 10,454' 10,464' 7,055' 7,060' 10 10/94 & 7/95 Open 5"& 3.5" KUP 86 10,498' 10,502' 7,081' 7,083' 4 10/94&7/95 Open 5"&3.5" KUP A3 10,609' 10,629' 7,146' 7,158' 20 10/94&7/95 Open 5"&3.5" KUP A2 10,646' 10,680' 7,167' 7,187' 34 1 10/94&7/95 Open 5"&3.5" Ref Log: DIL 4/1/1985 STIMULATION SUMMARY 7/4/98 -A-2 Frac Sand 72M# of 16/20 ISP 10/10/98 -'C' Sand 27M# 20/40 & 168M# of 16/20 Carbolite behind pipe GENERAL WELL INFO API: 50-029-21299-00-00 Drilled and Completed by AUDI #3-4-8-1985 RWO ESP -10/17/1994 RWO ESP Nabors 5-5-2/20/1998 RWO ESP Nabors 4ES-5/15/1999 RWO w/ Tubing WH C/O - Doyon 16 -1/29/2014 Revised By: STP 1/22/2019 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Monday, January 28, 2019 3:29 PM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL] C-09 Jet pump Conversion (PTD 185-036) Guy, The circulation valve has a check valve that will prevent flow from entering the annulus. This same setup is currently in use on MPU C -05A (PTD 184-243). Stan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, January 28, 2019 1:00 PM To: Stan Porhola <sporhola@hilcorp.com> Subject: [EXTERNAL] C-09 Jet pump Conversion (PTD 185-036) Sta n, Does the circulation valve installed on step 12 have a check as part of the assembly? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ( or (Guv schwortz@alaska.aov(. w\��\��s THE STATE r Alaska Oil and Gas ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF" mrmm� P Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 David Bjork Engineering Team Leader WOW FEB 2 L BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk River Oil Pool, MPC-09 Sundry Number: 313-635 Dear Mr. Bjork: 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, f---;64-71-t----- Cathy P oerster Chair DATED this 20 day of December, 2013. Encl. . 4 • STATE OF ALASKA n - E C E I V D • ALASKA OIL AND GAS CONSERVATION COMMISSION o�•� DEC Q 2013 APPLICATION FOR SUNDRY APPROVAL ‘.1,1\°‘' ti 20 AAC 25.280 OTT tZ 14(3 1. Type of Request: A.OG C ❑Abandon ❑Plug for Redrill ❑Perforate New Pool ®Repair Well . ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate IS Pull Tubing .❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ®Alter Casing .❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 185-036 3. Address: ®Development. 1:1 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21299-00-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPC-09 Will planned perforations r equ it e a Spac in g Exception? 0 Yes El No 9. Property Designatior 10. Field/Pool(s): ADL 047434 - Milne Point/Kuparuk River Oil • 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): 10881' • 7303' ' '10772' 7240' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 103' 13-3/8" 103' 103' 1740 750 Surface 6603' 9-5/8" 6603' 4693' 3520 2020 Intermediate - Production 10870 7" 10870' 7297' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10392'- 10680' ' 7018'-7187' 3-1/2",9.3# L-80 10307' Packers and SSSV Type: 7"x 3-1/2"Baker S-3 Packer Packers and SSSV 10270'/6945' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: • ®Description Summary of Proposal IN BOP Sketch • ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: January 15,2014 , IS Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jimmy Smith,564-5616 Printed Name: David Bjork Title: Engineering Team Leader Email: James.Smith7 @bp.com Signature: ��/#_./ Phone: 564-5683 Date: /a/)l/s ��r' Commission Use Only _ /, Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?,v3_/4:S S I ❑Plug Integrity lirBOP Test 0 Mechanical Integrity Test 0 Location Clearance HBL)MS i ::3 I 2u Other: o!" jc J)' -to 3 500 13 5/ Spacing Exception Required? ❑Yes No Subsequent Form Required: (�c� APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: /2 - 20 —/3 Form 10-403 Revised 0/2012 Approved i orr r arr'` fo�i 1 m nths from the date of approval Submit In Duplicate • bp Sundry Request for casing repair Well: MPC-09 0 Date: 12/03/2013 Engineer: Jimmy Smith MASP: 3250 psi Well Type: Producer Estimated Start date: January 15th, 2014 History: MPC-09 was drilled and completed 04/1985. The well was fractured in the A2 sand in 07/1985 and completed as a gas lifted well. A gas leak in the casing head was discovered 8/5/08. After investigating other possibilities, it was determined a casing cut and pull rig workover was the only option to return this well back to production. Scope of Work: Pull 3-1/2" L-80 gas lift completion from cut, USIT log 7" casing to determine top of cement in 7"x 9-5/8"annulus, Cut and pull 7"casing, Cut off wellhead and install landing ring, Run and fully cement new 7"casing, Install new slip lock wellhead, Run new 3-1/2" L-80 gas lift completion. Pre Rig Prep Work: S 1 Pull XN plug from XN nipple @ 10,295' MD. S 2 Obtain 30-day SBHPS. S 3 Set PXN plug in XN nipple at 10,295' MD. Bail 10' of sluggits, set 3-1/2" Junk Catcher. V 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage(check one at a time). PPPOT-T& IC. F 5 MIT-T to 3500 psi and MIT-IA to 3500 psi, MIT-OA to 2,000 psi. E 6 Jet cut tubing at the top of the first full joint above the packer F 7 Circulate well through the cut with 11.1 ppg brine and diesel freeze protect to 2000' MD. Post cut CMIT-TxIA to 1,000 psi. ✓ 8 Prep annular valves, set a BPV O 9 Remove the wellhouse&flow line. Level the pad as needed for the rig. Line Cellar. Proposed RWO Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 7/8" x 5"VBRs, blind shears, mud cross' and 2-7/8" x 5"VBR's). Test the VBR's and annular to 3,500 psi. 2. Pull and lay down 3-1/2" gas lift completion to the jet cut. 3. RU E-line. Run USIT from 6500' MD to surface in the 7" casing to determine TOC in the 7"x 9-5/8" 1 annulus. Run both an acoustic and a 3-4 arm mechanical caliper with the USIT to check the well for any signs of subsurface subsidence./Set cut depth to—150' above the TOC. Y 9 P 4. Run RTTS to test lower barrier(if MIT-IA fails during the prerig testing). 5. Set 7" RBP and 50' of sand —100' below logged TOC. Pressure test RBP to 3,500 psi. Change upper BOP rams to 7"fixed and test to 3500 psi. 6. Mechanically cut 7" casing, circulate out arctic pack, and pull casing to surface. 7. Run 9-5/8" scraper and dress 7" casing stub. 8. Split the BOP stack and cut off 9-5/8"starting head. Install landing ring. 9. Run and cement 7"tie-back casing to surface with —190 bbls of 15.8 ppg class G cement. 10. Install 7" x 9-5/8" hanger and 7" sliplock wellhead. Nipple up and test BOP equipment, changing upper rams to 2-7/8" x 5"VBRs. 11. Drill out shoetract and run a RCJB to cleanout the wellbore. Test the casing to 3,500 psi. 12. Recover RBP. 13. Run a 7" scraper and dress 3-1/2" tubing stub. 14. Run new 3-1/2" L-80 gas lift completion with 7"x 3-1/2" HES TNT packer. 15. Set the packer and MIT-T& MIT-IA to 3500 psi. 16. ND BOPE. NU and test tree. Freeze protect to 2000' MD. 17. Seta BPV and RDMO. Post ri Work ✓ 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Run GL Design S 3 Pull junk catcher, bail sluggits, pull PXN plug - Tree: 3-1/8"-5M FMC MPU C-09 Orig. DF tiev.=52'(AUDI 3) Wellhead: 11" x 7"5M FMC Orig.GL Elev.=17'(AUDI 3) NSCT,w/3.5"FMC tubing hanger CIW 3.5"H BPV profile. 20" 91.1 ppf, H-40 115' 1 1 HES 3.5"X-Nipple(2.813"id) 1,992' KOP @ 500' Max. hole angle=61 deg @ Camco glm.kbmm.w/bk latch 6212' # and tvd dg Hole angle thru'perfs=52 deg 8 2,097' 1,982' 7 2,406' 2,296' i . 6 4,373' 3,448' 9 5/8",36 ppf,J-55 6604' , 5 5,993' 4,373' Btrc. 4 7,305' 5,067' 3 8,363' 5,717' 2 9,239' 6,276' 1 9,643' 6,536' 3 3-1/2",9.3#, L-80 8rd.eue I (drift ID=2.992",cap.=.0087 bpf) 7"26 ppf, L-80, Btrc.prod.casing (drift ID=6.151",cap.=0.0383 bpf) Stimulation Summary 07/04/98-'A-2'Sand frac-72 M#of 16/20 ISP --Y4 10/10/98-'C'Sand-27 M#20/40 and 40 168 M#of 16/20 Carbolite behind pipe. HES 3.5"X-Nipple(2.813"id) 10,227' Perforation Summary 7x 3.5"Baker Perm >"pkr. 10,270' Ref log: 4/1/85 DIL Size SPF Interval (TVD) HES 3.5"XN-Nipple(2.750"id) 10,295' * 6&24 10392'-10502' (7022'-7087') - WLEG 10,307' * 12&2410608'-10680' (7150'-7191') ; If *Intervals originally perforated at 12 spf w/5"guns. Reperfed at 6 spf w/3-3/8"guns 10/94. Perfed a third / t L. ! ime at 6 spf w/3-3/8"big hole guns 7/95. 7"float collar(PBTD) 10772' 4 Ilk 7"float shoe 10870' DATE REV.BY COMMENTS MILNE POINT UNIT 4/8/85 DBR Drilled and completed WELL C-09 10/17/94 DBR RWO/5/29/95 RWO remove GP scrn. API NO: 50-029-21299 02/22/98 M.Linder RWO Nabors 5-S 05/15/99 MDO RWO ESP to GLM Nabors 4 ES BP EXPLORATION (AK) Tree: 16"API 5K M P U C-09 Orig. C .v. =52' (AUDI 3) Wellhead:11"5K SL x 7"CIW Sliplo ' Orig. GL Elev. =17' (AUDI 3) :L 4-1/2" 12.6 lb TC-Il Top & PROPOSED CIW W 4 4"H BPV profile 20" 91.1 ppf, H-40 115' I I HES 3.5"X-Nipple(2.813"id)-2100' 7"csg,26#L-80 VAMTOP HC, ID=6.276"-X,XXX' KOP @ 500' Max. hole angle=61 deg @ 7"ES CEMENTER,X,XXX' 6212' -7"EXTERNAL CSG PKR,X,XXX' Hole angle thru'perfs=52 deg L Camco glm.kbmm.w/bk latch 9 5/8", 36 ppf,J-55 6604' # and tvd dg Btrc. 8 7 6 5 4 3 2 3-1/2", 9.2#, L-80 TCII 1 (drift ID=2.992",cap. =.0087 bpf) 7"26 ppf, L-80, Btrc. prod. casing (drift ID=6.151",cap.=0.0383 bpf) Stimulation Summary I 3-1/2"HES X NIPPLE, ID=2.813' Po. 7"x 3-1/2"HES TNT PKR, 07/04/98-'A-2' Sand frac-72 M#of ID=X,XXX"-10,113' 16/20 ISP I I 10/10/98-'C' Sand-27 M#20/40 and 3-1/2"HES X NIPPLE, ID=2.813" 168 M#of 16/20 Carbolite behind pipe. 7"x 3-1/2"UNIQUE OVERSHOT- 3-1/2"TUBING STUB(12/XX/13)-—10.231' —10,231' i Perforation Summary 7x 3.5"Baker Perm pkr. 10,270' Ref log:4/1/85 DIL Size SPF Interval (TVD) HES 3.5"XN-Nipple(2.750"id) 10,295' 6&24 10392'-10502' (7022'-7087') WLEG 10,307' * 12&24 10608'-10680' (7150'-7191') 0 *Intervals originally perforated at 12 spf w/5"guns. Reperfed at 6 spf w/3-3/8"guns 10/94. Perfed a third time at 6 spf w/3-3/8"big hole guns 7/95 7"float collar(PBTD) 10772' Ilk 7"float shoe 10870' DATE - REV.BY COMMENTS MILNE POINT UNIT 4/8/85 DBR Drilled and completed WELL C-09 10/17/94 DBR RWO/5/29/95 RWO remove GP scrn. API NO: 50-029-21299 02/22/98 M.Linder RWO Nabors 5-S 05/15/99 MDO RWO ESP to GLM Nabors 4 ES BP EXPLORATION (AK) CAMERON APP .e wig U•U 4-1/16 API 5000 Tree Assembly With 9. �i Actuated Valve in Upper Master Position ®O' i N E ' ,0 \ \ r,Or � O ii ! r °' ,% En ow fla * 1 ISI MI Ia Ill / 2-05---&N 'A0\ �.DO! / Tubing Hanger Type �,- SA-SRL 11" Bowl, 4-1/2" 12.6 lb. TC-II Top & Btm. Tubing Head Adapter �� ` 4" Type "H" BPV. 11" 5K Bottom x 4-1/16" API 5K Top, Two = %` Two '/4" NPT CCL Preps. CCL preps. PN 2247222-05-01 — and Metal Seal Neck ""' - 0 „ QllIg PN 2031940-15-01 i � Slip Lock Casing Head Type SL. 7" -- MI) _ I MI I , \` j� Slip Lock BTM x 11" API 5K FLG /7 ,© o ! : I _: F / ,o ,,\\ 8 Top With (1) 2-1/16 API 5K �'' I " 1i Companion Flange and . - Bull Plugs Min Bore 6.34" _ PN 2236000-72 -a 7" Casing 4111 /2"Tubing x 3-1/2" Tubing it r S gN gf •. °•L, ffi w rc pc • cn r _ ao VD D Oo CO m o wo m Z K DU 4^ d ,Orc Ell J 2 Z 2a a ¢ wZ ° I ° z < o cn 01 O w w ¢ w r CI_ § a PL. � °• N w D a i - X le ix m P- 0 6x o z • F-1 ig trA UJ gt N ,■.■.■_ Lax _♦�I -§< : 8 S ,, o ._ ' D w U a .O ■ a¢ ¢m N • ii,- I Z 0 r. gSA $; W 1.QO5 ce ce ° g a4 a asn Zz _. 2 O t O Is 6 a N ° a V N ° - V ? � 2O °a X o_t.1 LA.g.- N•g a m3 N m J0 o ° $ a O o ° o o o oo Ln a N III ■ o .n m Z ° O J m w W m °m ,. w ° w 1 O N .4 Z O O $ a ce z z LL z Kx . w I o 4iiiIiiirt . YCC ■ mg w cn III 111 V\J 0/111* o E z - L) s a 1 U o\ m 3 CC \n osi2~ioa NO.4763 Alaska Data & Consulting Services , Com an State of Alaska 2525 Gambell Street, Suite 400 r~,„, t ~ ~ ~v~~ Ry~,~ ~UL p Y• Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 3 / _ ~~~~fl wou In{. ~ ~ ,... ~.._ ~i N-04A 11962603 PRODUCTION PROFILE -' ,~'"..- "-°',i._ ~'d~~"" `~-=~ 06/23/08 1 1 L2-06 11999020 PRODUCTION PROFILE .,~,"°.. a ;--~,,,~ 06/15/08 1 1 L3-31 12005214 MEMORY SBHP a,,. ~~ ~~ r,"~"~~ ~~~y 06/11/08 1 1 C-02 11982437 PRODUCTION PROFILE ; ° ~" , •°- f c~ +'.,r- ~° .".`~''' ' 06/20/08 1 1 E-39A 12066529 SCMT ,=,7g~F -r ~`,'~ ~~, -~~ :='"F;? 06/19/08 1 1 MPC-09 12005215 MEM PROD PROFILE 9~~ -M Y`"C~ 6'~"~~:?, ~ ` ~~ 06/12/08 1 1 W-31 12014027 LDL ~ ~rt'`bf ~ ~° ~-~ `~ ~ ~ ~' ~") 06/15/08 1 1 02-04A 11962602 USIT t%~` ~ ~ - ,~ ~ * pr ar-f ~^ ~p 06/22/08 1 1 02-04A 12086662 USIT ?' ~~ ~ ~ .-- ~ r-~ ~~ ~ gam, ^~i ~_~ . 06/20/08 1 1 r~.ur~.~c rw new vrVGV\ac nc~. Clr 1 ~~ JIV~IVIIVL7 NIVU nCl UFIIVIIVta VIVO liVYr CHGr7 1 V: BP Exploration (Alaska) Ina -- Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services ,^ 2525 Gambell Street, Suite 40Q~! Anchorage, AK 99,503-2838 q' ATTN: Beth ;~ I _ Received by: , ,. _ `-_. _ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, O~'~\~ Commissioner Tom Maunder, ~/'~~ P. I. Supervisor~'~ DATE: May 19, 2001 FROM' John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19, .2001' I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the ^OGCC Policy Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I .requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells #4,6 & 14 were shut in for repairs. ~UMMAR¥: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6 failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL i I I 11 i ii i SVS MPU C Pad 5-19-01jc Alas,.a Oil and Gas Conservation Commis~ a Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: John Crisp_ Submitted By: John Crisp Date: Field/Unit/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI ,,,Trip ,Code Code Code,, , Passed GASor cYCLE,, C-01 18114~0 'i'40 ':i00 110 P P OIL C-02 1821940 C-03 ........1820500 140 ' "1013 .... 95 P ~ ........ OIL C-04 1821260 140 100 110 P 4 oIL C-05A' ' 1842430 " 140 100 '100 P P ............. 0I~' c-06 1842410 "4500 ' 2'000 1950 i~ 4 'WAG C-07 "' 1~i'50020 ' 'i40 "i00 '" 95 'i~ 4 ......... OIL C-08 '~' 1850i40 '4300'" 2006"' 1900 " P ~ WAG C-09 " 1850360 ...... 140 i00 .... 105 P' 'P OiL C'13 1850670 C-14 "1850880 '" 1~6 100 100 F ~4 OIL! C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C'22A' '' 1951980' 140 100 "9~ P' ' P ........ 0IL C-23 1960160 C-25A '1960210 4300 2000 1'900 P ' 4 ............ wAG C-26 1952060 C-28 1960290. C-36 1980010 C-39 1972480 C-40 2002130 ' 'C-10 1850150 " 4300 2000. 1850 'P P .... wAG Wells: _ 12 Components: 24 Failures: 6 Failure Rate: 25.00°~] o0 oar Remarks: RJF 1/16/01 Page 1 ofl SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: NOvember 18, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grima:~, ~ ~. SUBJECT: Petroleum Inspector SVS tests BPX C-pad Milne Point Unit Kuparuk River Field Saturday, November 18, 2000; I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field. This was the three-month test for this pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse Inspections; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad t 1-18-00 LG.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi: LPS 140 Date: 11/18/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed ~AS or CYCLE C-01 1811430 140 100 120 P P OIL iC-02 1821940 C-03 1820500 140 100 105 P P OIL C'-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 C-07 1850020' ' 140 100 110 P P' oil d-08 1850140' . , C-09 1850360 140 100 80 P P OIL C-13 1850670 C-14 1850880 140 100 105 P P "0IL , , C-15 1851030 C-17 1852630 .,.. C-20 1890150 C-21 1940800 C-22A 1951980 140 100 110 P P OIL C-23 1960160 C-25~" 1960210 4000 2000 2000 P "'4 WAGi ,, C-26 1952060 C-28 1960290 4000 2000 2000 P P WAG C-36 1980010 c-39 1972480 c-19i 1852960 4000! 200~ 2000 P 4 .... WAG Wells: 11 comPonents: 22 Failures: 3 Failure Rate: 13.6%~] 90 Day Remarks: C-03 has gas leak on Tubing Spool adapter, Develop plan for repair and report back. 11/20/00 Page 1 of 1 V0kl trl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU- Dan Seamount, Commissioner ,~///~~ Blair Wondzell, P. I. SupervisOr · FROM: Jeff Jones~, ~,~ ./-- SUBJECT: Petroleum I DATE: July 12, 2000 Safety Valve Tests Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9.wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad,' 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi' LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE C-01 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 .................... 1850140 , ~~ 1850360 i 40 100 120 P 4 OIL C-13 1850670 C- 14 1:850880 140 100 100 P P OIL C-15 1851030 iC,17 1852630 iC-20 1890150 C'-21 1940800 C-22A 1951980 140 100 95 p P Oil~ C-23 .1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 . C-28 1960290 4000 2000 2000 P 43 WAG C236 1980010 ,.. C-39 1972480 C-02 1821940 4000 1900 p P WAG C-06 1842410 4000~ 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[] 90 oar Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V 1 v7irqm.xls STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [~ Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4166' SNL, 2428' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 3620' SNL, 1091' WEL, Sec. 4, T13N, R10E, UM At effective depth 1925' NSL, 1248' WEL, Sec. 4, T13N, R10E, UM At total depth 3279' NSL, 1294' WEL, Sec. 4, T13N, R10E, UM Stimulate I--] Plugging [] Perforate Alter Casing [~ Repair Well [~ Other Convert to Gas Lift Type of well: [~ Development [] Exploratory I--] Stratigraphic I--t Service 6. Datum Elevation (DF or KB) KBE - 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-09 9. Permit Number / Approval No. 85-36 10. APl'Number 50-029-21299 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 10881' true vertical 7308' Effective depth: measured 10772' true vertical 7245' Casing Length Structural Conductor 80' Surface 6267' Intermediate Production 10836' Liner feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 16" To surface 9-5/8" 2600 sx PF 'E', 275 sx Class 'G' 7" 271 sx Class 'G' MD TVD 115' 115' 6603' 4549' 10870' 7301' Perforation depth: measured true vertical 10392'-10502', 10608'-10680' 7022'-7087', 7150'-7191' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 10307' Packers and SSSV (type and measured depth) Baker '3' packer at 10270' ?~i3.~[~a 0ii ~ GaS L;0lb~ ~;0~.Fi~i: ~;I: ~ ^nchora~; 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments ~ Copies of Logs and Surveys run ~ Daily Report of Well Operations 6. Status of well classifications as: [~ Oil [--I Gas [-~ Suspended Service 17. I hereby certify that the.f, eregoing i,s itrue~an~d ~correct to the best of my knowledge Signed ,,y"~ ~ ,.k l,- /J ~.,',~ Terrie Hubble / ~~J~ Title Technical Assistant III Prepared By Name/Number: Date ~'~,,O.?f Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt C Pad Well MPC-09 Page 1 Rig Nabors 4ES Date 20 May 99 Date/Time 11 May 99 12 May 99 13 May 99 14 May 99 15 May 99 16 May 99 12:00-01:00 01:00-06:00 06:00-10:00 10:00-16:30 16:30-18:00 18:00-01:00 01:00-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-14:30 14:30-20:00 20:00-01:30 01:30-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-19:00 19:00-03:30 03:30-06:00 06:00-07:00 07:00-17:00 17:00-18:00 18:00-20:00 20:00-22:30 22:30-00:30 00:30-01:00 Duration 13hr 5 hr 4 hr 6-1/2 hr 1-1/2 hr 7 hr 3 hr 1 hr 1 hr 2 hr 6-1/2 hr 5-1/2 hr 5-1/2 hr 4-1/2 hr 1/2 hr 3 hr 2 hr 7-1/2 hr 8-1/2 hr 2-1/2 hr 1 hr 10hr 1 hr 2 hr 2-1/2 hr 2 hr 1/2 hr Activity Rig moved 100.00 % Fill pits with Brine Circulated closed in well at 10680.0 ft Circulated closed in well at 10630.0 ft Rigged down Xmas tree Installed BOP stack Tested BOP stack Retrieved Hanger plug Rigged up Tubing handling equipment Removed Tubing hanger Pulled Tubing in stands to 7125.0 ft Laid down 3038.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 8500.0 ft (3-1/2in OD) Held safety meeting Ran Tubing to 10483.0 ft (3-1/2in OD) Reverse circulated at 10717.0 ft Reverse circulated at 10717.0 ft Laid down 10717.0 ft of Tubing Rigged up sub-surface equipment - Completion equipment Held safety meeting Ran Tubing to 10307.0 ft (3-1/2in OD) Serviced Tubing hanger Rigged down BOP stack Installed Xmas tree Functioned Permanent packer Installed Hanger plug Re: Milne Point, C-09 Subject: Re: Milne Point, C-09 Date: Thu, 13 May 1999 15:27:37-0800 From: Blair Wondzell <Blair Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: "Kissinger, Matt D" <KissinMD~BP.com> Matt, I agree that a 10-403 is not needed in this case. We'll accept this E-mail as adequaate notification. Good Luck, Blair Wondzell Senior Petroleum Engineer "Kissinger, Matt D" wrote: Blair Wondzell I am inquiring as to whether or not we need to file a 10-403 for a rig workover project we are undertaking. Similar to our many ESP changeouts, the plan for MPC-09 is to pull the current ESP completion and replace it with a standard gas lift completion (complete with packer). The fact that the new completion will be a gas lift completion is the only variance from our standard rig workover/ESP changeouts which do not need a 10-403. If you do need this form, I will send it immediately. Thanks, Matt Kissinger Milne Point C & L Pad Surveillance Engineer Western North Slope Asset BP Exploration (Alaska) (907) 564-5654 1 of 1 5/13/99 3:28 PM ~ALASKA~ .jeared rvices rilling BP Exploration / Arco To: Alaska Oil & Gas Conservation Commission Date: February 26, 1999 From: Subject: Terrie Hubble Technical Assistant Miscellaneous Surveys Enclosed, in duplicate, are a number of directional surveys that I have come across while clearing out Ms. Campoamor's desk. I have verified that these surveys do not affect the previously calculated TVD's and below surface locations of these wells, so it was not necessary to correct the 10-407's. They are simply being submitted for your records. If they are duplicates, please discard them. Thank you. /tlh Endicott MPI 1-09A/L-21 Milne Point MPC-09 Milne Point MPF-21 Milne Point MPF-37 Milne Point MPF-45 Milne Point MPF-69 Milne Point MPF-79 Permit #97-29 Permit #85-36 Permit #96-135 Permit #96-25 Permit #95-58 Permit #95-125 Permit #97-180 gyro/data B.P. EXPLORATION C PAD, WELL NO. MPC-09 MILNE POINT FIELD, ALASKA Gyro Multishot Survey in 3.5" tubing Survey date: 19 June, 1995 Job number: AK0695G273 ORIGINAL SR273,DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 June 30, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re: C Pad, Well No. MPC-09 Milne Point Field, Alaska Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #MPC-09 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER · AK0695G273 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR273.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR273.DOC gyro/data DISCUSSION JOB NUMBER' AK0695G273 Tool 080 was run in MPC-09 on ATLAS 7/32" Wireline inside 3.5" tubing. The survey was run without problems. SR273.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0695G273 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- TIM ANDERSON TOM STODDARD OPERATIONS ENGINEER SR273.DOC gyro/data 2. SURVEY DETAILS SR273.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0695G273 CLIENT: B.P. EXPLORATION RIG: ATLAS LOCATION: MILNE POINT WELL: MPC-09 LATITUDE: 70.455 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 19-June, 1995 MULTISHOT DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE EVELATION 52.0 asl 10025' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100' UTM CO-ORDINATES: TARGET DIRECTION: 324.5 GRID CORRECTION: CALCULATION METHOD: SURVEYOR: MINIMUM CURVATURE STODDARD SR273.DOC gyro/data 3. OUTRUN SURVEY LISTING SR273,DOC A Gyro da t a D i re c t i ona i Survey for B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, 3 1/2" TUBING Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0695G273 Run Date: 19-Jun-95 08:14:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.460000 deg. N Sub-sea Correction from Vertical Reference: 52 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 324.500 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273 3 1/2" TUBING ALASKA MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -52.0 0.00 0.0 0.0 ALL MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 52 FEET. 0.0 - 10025.0 FEET; GYRO SURVEY RUN IN 3 1/2" TUBING. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .21 66.22 100.0 -.0 48.0 .21 200.0 .05 66.63 200.0 -.1 148.0 .16 300.0 .23 355.88 300.0 .1 248.0 .22 400.0 .17 350.34 400.0 .4 348.0 .06 500.0 .36 36.60 500.0 .6 448.0 .27 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 00.0 .24 323.16 600.0 .9 548.0 .37 00.0 2.05 305.41 700.0 2.8 648.0 1.82 00.0 4.81 310.26 799.8 8.6 747.8 2.78 00.0 7.79 317.39 899.2 19.4 847.2 3.07 00.0 11.97 320.23 997.7 36.4 945.7 4.21 00.0 14.08 322.62 1095.1 58.9 1043.1 2.18 00.0 16.33 323.90 1191.6 85.2 1139.6 2.28 00.0 19.33 325.44 1286.8 115.8 1234.8 3.04 00.0 21.67 319.93 1380.4 150.7 1328.4 3.03 00.0 23.63 317.28 1472.7 189.0 1420.7 2.22 00.0 26.28 318.42 1563.4 230.9 1511.4 2.69 00.0 28.41 317.90 1652.2 276.6 1600.2 2.14 00.0 31.02 321.66 1739.1 326.0 1687.1 3.21 00.0 34.65 320.19 1823.1 380.1 1771.1 3.72 00.0 36.51 321.04 1904.4 438.1 1852.4 1.92 .2 .4 .6 .8 1.3 1.7 2.9 8.6 19.6 36.7 59.2 85.4 115.9 150.9 189.4 231.5 277.4 326.9 381.1 439.3 66.2 66.3 46.3 26.2 24.7 20.8 340.2 319.0 316.6 317.8 319.2 320.5 321.6 321.8 321.1 320.5 320.2 320.1 320.2 320.3 .07 N .16 N .38 N .73 N 1.14 N 1.55 N 2.75 N 6.50 N 14.20 N 27.16 N 44.80 N 65.83 N 90.83 N 118.60 N 147.45 N 178.74 N 212.95 N 250.82 N 292.88 N 337.86 N .17 E .37 E .40 E .36 E .52 E .59 E .99 W 5.65 W 13.44 W 24.66 W 38.68 ~ 54.35 L 72 · 03 W 93.31 W 118.79 W 147.09 W 177.73 W 209.67 W 243.87 W 280.79 W A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273 3 1/2" TUBING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. H O R I Z O N T A L COORDINATES feet 2100.0 36.86 323.14 1984.6 2200.0 37.16 325.22 2064.4 2300.0 38.71 326.32 2143.3 2400.0 41.46 326.40 2219.8 2500.0 44.78 326.36 2292.8 497.8 1932.6 558.0 2012.4 619.5 2091.3 683.8 2167.8 752.1 2240.8 1.31 499.0 320.5 1.29 559.1 320.9 1.69 620.4 321.4 2.75 684.5 321.8 3.32 752.7 322.3 384.99 N 317.49 W 433.81 N 352.71 W 484.64 N 387.28 ~' 538.25 N 422.95 W 595.17 N 460.79 W 2600.0 46.86 326.86 2362.5 2700.0 46.57 327.18 2431.0 2800.0 46.79 327.99 2499.6 2900.0 47.43 326.45 2567.7 3000.0 50.64 326.90 2633.2 823.8 2310.5 896.5 2379.0 969.2 2447.6 1042.3 2515.7 1117.8 2581.2 2.11 824.2 322.6 .38 896.8 323.0 .63 969.4 323.3 1.30 1042.5 323.6 3.23 1117.9 323.8 655.05 N 500.26 W 716.11 N 539.89 W 777.52 N 578.89 W 839.11 N 618.56 W 902.20 N 660.04 W 3100.0 53.08 323.62 2695.0 3200.0 53.48 323.77 2754.8 3300.0 53.32 324.51 2814~4 3400.0 53.18 325.76 2874.3 3500.0 53.36 325.14 2934.1 1196.4 2643.0 1276.5 2702.8 1356.8 2762.4 1436.9 2822.3 1517.1 2882.1 3.55 1196.5 323.9 .41 1276.6 323.9 .61 1356.9 323.9 1.02 1437.0 324.0 .53 1517.1 324.1 966.79 N 1031.39 N 1096.45 N 1162.19 N 1228.21 N 704.87 W 752.33 W 799.36 W 845.16 W 890.61 W 3600.© 52.90 324.87 2994.1 3700.0 52.69 326.64 3054.5 3800.0 52.60 326.39 3115.2 3900.0 52.32 327.09 3176.1 4000.0 53.08 324.50 3236.7 1597.1 2942.1 1676.7 3002.5 1756.1 3063.2 1835.4 3124.1 1914.9 3184.7 .50 1597.1 324.1 1.43 1676.7 324.2 .21 1756.1 324.3 .62 1835.4 324.4 2.20 1914.9 324.4 1293.74 N 1359.57 N 1425.87 N 1492.17 N 1557.94 N 936.49 981.31 1025.16 W 1068.64 W 1113.36 W 4100.0 53.76 325.79 3296.3 4200.0 55.17 323.34 3354.5 4300.0 55.11 325.48 3411.6 4400.0 54.88 324.81 3469.0 4500.0 54.95 325.15 3526.5 1995.2 3244.3 2076.5 3302.5 2158.6 3359.6 2240.5 3417.0 2322.3 3474.5 1.24 1995.2 324.5 2.44 2076.5 324.5 1.76 2158.6 324.5 .60 2240.5 324.5 .29 2322.3 324.5 1623.84 N 1690.13 N 1756.85 N 1824.07 N 1891.09 N 1159.25 W 1206.43 W 1254.18 W 1300.99 W 1347.94 W A Gyroda t a D i re c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273 3 1/2" TUBING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 55.02 323.89 3583.9 4700.0 54.81 325.05 3641.3 4800.0 54.56 325.31 3699.1 4900.0 54.62 325.24 3757.1 5000.0 54.60 326.30 3815.0 2404.2 3531.9 2486.0 3589.3 2567.6 3647.1 2649.1 3705.1 2730.6 3763.0 1.03 2404.2 324.5 .97 2486.0 324.5 .33 2567.6 324.5. .08 2649.1 324.6 .87 2730.6 324.6 1957.78 N 2024.37 N 2091.36 N 2158.35 N 2225.75 N 1395.47 W 1443.03 1489.62 1536.06 W 1581.92 W 5100.0 54.70 326.31 3872.8 5200.0 54.85 326.23 3930.5 5300.0 54.87 326.54 3988.1 5400.0 54.58 327.94 4045.8 5500.0 54.44 328.10 4103.9 2812.2 3820.8 2893.8 3878.5 2975.5 3936.1 3057.1 3993.8 3138.4 4051.9 .10 2812.2 324.6 .16 2893.8 324.7 .25 2975.6 324.7 1.18 3057.1 324.8 .19 3138.4 324.9 2293.61 N 2361.55 N 2429.64 N 2498.30 N 2567.36 N 1627.17 W 1672.54 W 1717.81 W 1761.99 W 1805.11 W 5600.0 55.25 331.18 4161.5 5700.0 54.32 328.71 4219.1 5800.0 54.68 325.36 4277.2 5900.0 56.05 321.42 4334.0 6000.0 58.04 321.35 4388.4 6100.0 60.20 321.05 4439.8 6150.0 60.30 321.92 4464.6 6200.0 60.00 322.62 4489.5 6250.0 59.65 321.45 4514.6 6300.0 59.52 324.09 4539.9 3219.8 4109.5 3301.1 4167.1 3382.4 4225.2 3464.6 4282.0 3548.4 4336.4 3634.1 4387.8 3677.5 4412.6 3720.8 4437.5 3764.0 4462.6 3807.1 4487.9 2.64 3219.9 325.0 2.22 3301.3 325.1 2.75 3382.6 325.2 3.52 3464.9 325.1 1.99 3548.6 325.0 2.18 3634.2 325.0 1.52 3677.6 324.9 1.36 3720.9 324.9 2.14 3764.0 324.9 4.56 3807.1 324.8 2637.90 N 2708.61 N 2776.90 N 2842.91 N 2908.47 N 2975.35 N 3009.31 N 3043.61 N 3077.69 N 3112.02 N 1846.42 W 1887.33 W 1931.62 W 1980.69 W 2033.06 W 2086.83 T~ 2113.86 ¼ 2140.40 W 2166.99 W 2193.08 W 6350.0 59.88 321.72 4565.1 6400.0 59.72 322.03 4590.3 6450.0 59.80 323.30 4615.5 6500.0 59.90 322.51 4640.6 6600.0 59.33 324.70 4691.2 3850.2 4513.1 3893.4 4538.3 3936.6 4563.5 3979.8 4588.6 4066.0 4639.2 4.15 3850.3 324.8 .62 3893.4 324.8 2.19 3936.6 324.7 1.38 3979.8 324.7 1.97 4066.0 324.7 3146.44 N 3180.44 N 3214.78 N 3249.27 N 3318.69 N 2219.11 W 2245.79 W 2271.99 W 2298.07 W 2349.26 W A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273 3 1/2" TUBING ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 6700.0 59.00 321.58 4742.4 6800.0 57.97 322.38 4794.7 6900.0 57.02 321.57 4848.5 7000.0 56.31 322.90 4903.4 7100.0 54.79 322.17 4960.0 7200.0 53.22 324.57 5018.8 7300.0 51.97 323.58 5079.5 7400.0 51.45 323.80 5141.5 7500.0 51.90 323.76 5203.5 7600.0 51.88 324.55 5265.2 7700.0 51.89 325.68 5326.9 7800.0 52.10 324.09 5388.5 7900.0 52.18 324.13 5449.9 8000.0 52.50 324.64 5511.0 8100.0 51.90 322.83 5572.3 8200.0 51.29 321.46 5634.4 8300.0 51.67 320.90 5696.7 8400.0 52.03 319.46 5758.5 8500.0 51.32 320.06 5820.5 8600.0 50.55 321.31 5883.5 8700.0 50.89 320.09 5946.8 8800.0 51.14 320.62 6009.8 8900.0 49.52 323.28 6073.6 9000.0 48.49 323.85 6139.2 9100.0 48.46 325.90 6205.5 4151.8 4690.4 4237.0 4742.7 4321.3 4796.5 4404.7 4851.4 4487.1 4908.0 4568.0 4966.8 4647.4 5027.5 4725.9 5089.5 4804.4 5151.5 4883.0 5213.2 4961.7 5274.9 5040.5 5336.5 5119.4 5397.9 5198.6 5459.0 5277.6 5520.3 5355.9 5582.4 5434.0 5644.7 5512.4 5706.5 5590.6 5768.5 5668.1 5831.5 5745.3 5894.8 5822.8 5957.8 5899.7 6021.6 5975.2 6087.2 6050.0 6153.5 2.70 4151.9 324.7 1.24 4237.0 324.6 1.17 4321.3 324.6 1.32 4404.7 324.5 1.64 4487.1 324.5 2.49 4568.0 324.5 1.48 4647.4 324.5 .55 4725.9 324.4 .45 4804.4 324.4 .62 4883.0 324.4 .88 4961.7 324.4 1.27 5040.5 324.4 .09 5119.4 324.4 .52 5198.6 324.4 1.55 5277.6 324.4 1.24 5355.9 324.4 .58 5434.0 324.4 1.19 5512.4 324.3 .85 5590.7 324.2 1.24 5668.1 324.2 1.00 5745.4 324.1 .48 5823.0 324.1 2.61 5899.9 324.1 1.11 5975.3 324.1 1.54 6050.2 324.1 3387.38 N 2400.76 W 3454.53 N 2453.26 W~ 3520.96 N 2505.21 ~ 3587.00 N 2556.38 W 3652.46 N 2606.53 W 3717.36 N 3781.69 N 3844.93 N 3908.22 N 3972.00 N 4036.54 N 4100.98 N 4164.94 N 4229.29 N 4292.99 N 4354.86 N 4415.82 N 4476.21 N 4536.10 N 4596.16 N 4656.05 N 4715.91 N 4776.50 N 4837.21 N 4898.44 N 2654.80 W 2701.41 W 2747.88 W 2794.24 W 2840.31 W 2885.30 W 2930.63 W 2976.91 W 3023.01 W 3069.75 W 3117.83 W~ 3166.88 L 3217.23 W 3267.90 W 3317.10 W 3366.12 W 3415.71 W 3463.16 W 3508.00 W 3551.07 W A Gyrodat a D i r e c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273 3 1/2" TUBING ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. 9200.0 48.89 326.33 6271.5 9300.0 49.34 325.64 6337.0 9400.0 49.61 326.00 6402.0 9500.0 50.01 329.92 6466.5 9600.0 50.85 328.80 6530.2 6125.1 6219.5 .53 6125.2 324.1 6200.7 6285.0 .69 6200.8 324.1 6276.6 6350.0 .38 6276.8 324.1 6352.9 6414.5 3.02 6353.0 324.2 6429.7 6478.2 1.21 6429.7 324.2 9700.0 51.28 330.14 6593.1 9800.0 51.79 329.25 6655.3 9900.0 52.16 329.53 6716.9 10000.0 51.65 330.99 6778.6 10025.0 51.62 331.29 6794.1 6507.2 6541.1 1.13 6507.2 324.3 6585.1 6603.3 .86 6585.2 324.4 6663.6 6664.9 .43 6663.6 324.4 6741.9 6726.6 1.25 6741.9 324.5 6761.4 6742.1 .95 6761.4 324.5 Final Station Closure: Distance: 6761.39 ft Az: 324.51 deg. Page 5 HORIZONTAL COORDINATES feet 4960.79 N 3592.93 W 5023.45 N 3635.23 W~ 5086.33 N 3677.93 ~ 5151.07 N 3718.43 W 5217.38 N 3757.72 W 5284.38 N 3797.23 W 5351.98 N 3836.74 W 5419.78 N 3876.85 W 5488.11 N 3915.89 W 5505.27 N 3925.35 W A Gyro da t a D i r e c t i ona I Survey for B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, 3 1/2" TUBING Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0695G273SS Run Date: 19-Jun-95 08:14:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.460000 deg. N Sub-sea Correction from Vertical Reference: 52 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 324.500 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey B.P. EXPLOPJtTION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273SS 3 1/2" TUBING ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. -52.0 0.00 0.00 0.0 0.0 0.00 0.0 0.0 ALL MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 52 FEET. 0.0 - 10025.0 FEET; GYRO SURVEY RUN IN 3 1/2" TUBING. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .13 66.43 152.0 -.1 .18 200.0 .14 217.04 252.0 .0 .19 300.0 .20 353.00 352.0 .2 .13 400.0 .27 14.39 452.0 .5 .17 500.0 .30 185.62 552.0 .8 .33 600.0 1.18 313.93 652.0 1.9 1.13 700.0 3.49 307.94 752.0 5.8 2.32 800.0 6.38 314.01 852.0 14.2 2.93 900.0 10.03 318.91 952.0 28.5 3.68 1000.0 13.15 321.57 1052.0 49.0 3.08 1100.0 15.41 323.38 1152.0 74.4 2.24 1200.0 18.24 324.88 1252.0 104.6 2.76 1300.0 20.96 321.60 1352.0 140.1 3.03 1400.0 23.19 317.87 1452.0 180.4 2.40 1500.0 25.95 318.27 1552.0 225.7 2.63 1600.0 28.40 317.90 1652.0 276.5 2.14 1700.0 31.58 321.43 1752.0 334.3 3.29 1800.0 35.32 320.49 1852.0 400.7 3.08 1900.0 36.72 322.29 1952.0 473.5 1.56 2000.0 37.12 324.90 2052.0 548.6 1.29 .4 66.2 .6 55.9 .8 35.9 1.3 25.4 1.7 22.7 2.9 359.7 8.6 329.2 19.6 317.7 36.7 317.2 59.2 318.6 85.4 319.9 115.9 321.2 150.9 321.7 189.4 321.3 231.5 320.6 277.4 320.2 381.1 320.1 439.3 320.2 499.0 320.4 559.1 320.8 .12 N .27 E .28 N .39 E .56 N .38 E .94 N .44 E 1.35 N .56 E 2.18 N .80 W 4.71 N 3.42 W 10.55 N 9.74 W 21.15 N 19.46 W 37.00 N 32.48 W 57.21 N 47.93 W 81.70 N 65.57 W 110.17 N 86.85 W 140.97 N 113.07 W 174.82 N 143.54 W 212.88 N 177.66 W 257.30 N 214.95 W 308.89 N 257.01 W 365.85 N 302.58 W 426.21 N 347.23 W A Gyro da t a D i re c t i ona i Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273SS 3 1/2" TUBING ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG S EVE R I TY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 39.03 326.33 2152.0 2200.0 42.93 326.38 2252.0 2300.0 46.55 326.78 2352.0 2400.0 46.63 327.42 2452.0 2500.0 47.28 326.80 2552.0 626.8 714.0 813.0 918.7 1025.5 1.81 3.00 2.29 .46 1.14 684.5 321.4 752.7 322.0 824.2 322.6 969.4 323.1 1042.5 323.5 490.74 N 391.34 W 563.37 N 439.65 W 646.07 N 494.34 W 734.89 N 551.82 W 824.91 N 609.41 W 2600.0 51.38 325.90 2652.0 2700.0 53.46 323.76 2752.0 2800.0 53.24 325.30 2852.0 2900.0 53.22 325.06 2952.0 3000.0 52.69 326.57 3052.0 1141.7 1272.8 1407.1 1541.0 1673.4 3.33 .56 .87 .52 1.39 1196.5 323.8 1276.6 323.9 1437.0 323.9 1597.1 324.1 1676.7 324.2 921.81. N 1028.36 N 1137.74 N 1247.80 N 1356.82 N 673.65 W 750.11 W 828.13 W 904.33 W 979.43 W 3100.0 52.43 326.82 3152.0 3200.0 53.26 324.83 3252.0 3300.0 55.11 323.45 3352.0 3400.0 54.95 325.01 3452.0 3500.0 54.98 324.59 3552.0 1804.0 1935.4 2073.1 2216.2 2358.8 .46 1.95 2.39 .94 .62 1835.4 324.3 1995.2 324.5 2076.5 324.5 2240.5 324.5 2404.2 324.5 1465.90 N 1574.81 N 1687.32 N 1804.16 N 1920.76 N 1051.41 W 1125.10 W 1204.43 W 1287.12 W 1369.09 W 3600.0 54.77 325.09 3652.0 3700.0 54.62 325.24 3752.0 3800.0 54.67 326.30 3852.0 3900.0 54.86 326.34 3952.0 4000.0 54.57 327.96 4052.0 2501.1 2642.0 2782.8 2924.3 3065.7 .85 .11 .37 .20 1.08 2567.6 324.5 2649..1 324.6 2812.2 324.6 2975.6 324.7 3138.4 324.8 2036.74 N 2152.48 N 2269.17 N 2386.97 N 2505.65 N 1451.63 W 1531.99 W 1610.87 W 1689.44 W 1766.58 W 4100.0 55.12 330.67 4152.0 4200.0 54.52 326.81 4252.0 4300.0 56.71 321.40 4352.0 4400.0 60.25 321.48 4452.0 4500.0 59.69 322.96 4552.0 3206.4 3347.1 3492.3 3655.5 3827.7 2.24 2.52 3.01 1.85 4.36 3219.9 325.0 3382.6 325.2 3548.6 325.1 3677.6 324.9 3850.3 324.8 2626.32 N 2747.26 N 2864.54 N 2992.10 N 3128.51 N 1839.64 W 1912.40 W 1997.97 W 2100.16 W 2205.55 W A Gyrodata Directional Survey B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, Job Number: AK0695G273SS 3 1/2" TUBING ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 59.77 323.00 4652.0 4700.0 58.81 321.72 4752.0 4800.0 56.97 321.65 4852.0 4900.0 55.00 322.28 4952.0 5000.0 52.54 324.03 5052.0 3999.2 1.52 4066.0 324.7 4167.4 2.43 4237.0 324.7 4326.6 1.18 4404.7 324.6 4475.5 1.60 4487.1 324.5 4611.5 1.94 4647.4 324.5 3264.93 N 3399.66 N 3525.21 N 3643.22 N 3752.56 N 2309.62 W 2410.35 W 2508.50 W 2599.45 W 2680.30 W 5100.0 51.52 323.80 5152.0 5200.0 51.88 324.38 5252.0 5300.0 51.97 325.03 5352.0 5400.0 52.19 324.14 5452.0 5500.0 52.10 323.43 5552.0 4739.2 .53 4804.4 324.4 4866.2 .58 4883.0 324.4 4993.8 1.04 5040.5 324.4 5122.2 .10 5198.6 324.4 5251.4 1.20 5277.6 324.4 3855.67 N 3958.35 N 4062.76 N 4167.14 N 4271.89 N 2755.75 W 2830.44 W 2903.74 W 2978.49 W 3054.27 W 5600.0 51.40 321.30 5652.0 5700.0 51.99 319.62 5752.0 5800.0 50.93 320.68 5852.0 5900.0 50.91 320.14 5952.0 6000.0 50.07 322.38 6052.0 5377.9 1.05 5434.0 324.4 5504.2 1.12 5512.4 324.3 5629.3 1.04 5668.1 324.2 5751.6 .96 5823.0 324.1 5873.7 1.89 5899.9 324.1 4372.06 N 4469.87 N 4566.11 N 4660.96 N 4756.00 N 3131.67 W 3211.94 W 3292.49 W 3370.19 W 3447.11 W 6100.0 48.49 324.24 6152.0 6200.0 48.76 326.20 6252.0 6300.0 49.40 325.73 6352.0 6400.0 49.92 329.04 6452.0 6500.0 51.00 329.26 6552.0 5989.6 1.19 6050.2 324.1 6102.9 .83 6125.2 324.1 6218.2 .62 6276.8 324.1 6335.7 2.43 6353.0 324.2 6456.5 1.18 6507.2 324.3 4849.04 N 4942.35 N 5037.98 N 5136.51 N 5240.61 N 3516.31 W 3580.55 W 3645.09 W 3709.32 W 3771.42 W 6600.0 51.76 329.30 6652.0 6700.0 51.87 330.36 6752.0 6742.1 51.62 331.29 6794.1 6581.1 .87 6585.2 324.4 6708.2 .90 6741.9 324.5 6761.4 .95 6761.4 324.5 5348.44 N 5458.69 N 5505.27 N 3834.67 W 3899.08 W 3925.35 W Final Station Closure: Distance: 6761.39 ft Az: 324.51 deg. gyro/data 4. QUALITY CONTROL SR273.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MILNE POINT NUMBER MPU C-09, Location: C PAD, MILNE POINT FIELD, 3 1/2" TUBING ALASKA Job Number : AK0695G273 / AK0695G273 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 1000.0 11.24 11.97 -.735 318.41 2000.0 36.49 36.51 -.018 321.53 2800.0 46°79 46.79 -.000 327.99 3000.0 50o10 50.64- -.543 324.81 9900.0 52o12 52.16 -.031 330.30 10025.0 51.60 51.62 -.019 331.39 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.2243 deg. Average Azimuth Difference = -.1763 deg. OUTRUN Az 318.88 322.25 327.07 325.74 330.24 331.29 Delta -.472 -.723 .915 -.938 .060 .100 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0695G273 TOOL NUMBER: O8O MAXIMUM GYRO TEMPERATURE: 75.0c MAXIMUM AMBIENT TEMPERATURE: 38.0 c MAXIMUM INCLINATION: 60.3 AVERAGE AZIMUTH: 324.5 WIRELINE REZERO VALUE: 0' correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 12 MAY 1995 CALIBRATION USED FOR FINAL SURVEY: 12 MAY 1995 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] · -0.0 .24 0.0 USED CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 10025 51.62 331.29 6794.1 5505.30 N 3925.30W FINAL SURVEY 10025 51.62 331.29 6794.1 5505,27 N 3925,35W SR273.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0695G273 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ff 1 2 3 4 5 2800 46.79 46.79 46.79 46.79 46.79 AZIMUTH M.D. ft 1 2 3 4 5 2800 327.99 327.99 327.99 327.99 327.99 SR273.DOC gym/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR273.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0695G273 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0094 DATA SECTION A0025 POWER SECTION A0052 BACKUP TOOL No. 136 GYRO SECTION A0099 DATA SECTION A0029 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055 A0079 A0071 A0122 A0032 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32" RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL: MAXIMUM O.D.: TOTAL WEIGHT OF TOOL: 31.5 feet 2.25 INCHES 240Lbs SR273.DOC gyro CHRONOLOGICAL REPORT JOB NUMBER: AK0695G273 6/19/95 O4OO 0730 0800 0945 1115 1225 1300 1430 1545 1730 2100 6/20/95 0500 0800 1600 FINISH MPE-22 LEAVE FOR C PAD. MU TOOL, WO CAP FOR WELL HEAD. PU TOOL, RIH 10025' TOOL SET DOWN. 6450' 4000' LD TOOL RD ATLAS AND BD TOOL. RETURN ATLAS, CHECK TOOL, POST RUN CAL CHECK. PROCESS SURVEY. RETURN MILNE POINT CAMP. SUBMIT SURVEY. ATLAS. CHARTER TO ANCHORAGE. SR273.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: r-IOperation Shutdown I--IStimulate I-'] Plugging [] Perforate [~ Pull Tubing I--]Alter Casing I--] Repair Well [~ Other ESP Changeout 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4166' SNL, 2428' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 3620' SNL, 1091' WEL, Sec. 4, T13N, R10E, UM At effective depth 1925' NSL, 1248' WEL, Sec. 4, T13N, R10E, UM At total depth 3279' NSL, 1294' WEL, Sec. 4, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-09 9. Permit Number / Approval No. 85-36 10. APl Number 50- 029-21299 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10881' feet Plugs (measured) 7308' feet 10772' feet Junk (measured) 7245' feet Length Size Cemented 80' 16" To surface 6568' 9 5/8" 2600 sx "E"/275 sx "G" 10836' 7" 271 sx Class "G" ORIGINAL MD 115' 6603' 10870' TVD 115' 4549' 7301' Perforation depth: measured 10392'- 10408', 10454'- 10502, 10608'- 10680' true vertical (subsea)6970' o 6980', 7007' - 7035', 7080' - 7140' Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 to 9855', 2 7/8" 6.5 ppf, L-80 at 10082' Packers and SSV (type and measured depth) None RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure / R2 4 1998 ,l~ka 0ii & Gas Cons. Commission Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: IX] Oil [] Gas I--I Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of Signed · - ~ Title ?:~;~ ,,, , Prepared By Name/Number: Date '~-~/'~/~? ,. ~ ~ubmit In Duplicate~p Form 10-404 Rev. 06/15/88 Facility Date/Time 14 Feb 98 15 Feb 98 16 Feb 98 17 Feb 98 18 Feb 98 19 Feb 98 20 Feb 98 Progress Report M Pt C Pad Well MPC-09 Page 1 Rig Nabors 5S Date 05 March 98 06:00-16:30 16:30-17:30 17:30-18:30 18:30-19:00 19:00-20:30 20:30-06:00 06:00-06:15 06:15-09:30 09:30-10:30 10:30-15:00 15:00-19:30 19:30-20:30 20:30-22:00 22:00-01:30 01:30-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-08:00 08:00-08:15 08:15-11:30 11:30-18:00 18:00-18:15 18:15-00:30 00:30-02:00 02:00-06:00 06:00-06:15 06:15-09:00 09:00-13:00 13:00-18:00 18:00-18:15 18:15-01:30 O1:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-12:00 12:00-12:30 12:30-15:30 15:30-19:30 19:30-20:00 20:00-21:00 21:00-22:30 22:30-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-16:30 16:30-18:00 18:00-18:30 18:30-02:30 02:30-05:00 Duration 10-1/2 hr lhr 1 hr 1/2 hr 1-1/2 hr 9-1/2 hr 1/4 hr 3-1/4 hr 1 hr 4-1/2 hr 4-1/2 hr lhr 1-1/2 hr 3-1/2 hr 3-1/2 hr lhr 1/4 hr 3/4 hr lhr 1/4hr 3-1/4 hr 6-1/2 hr 1/4 hr 6-1/4 hr 1-1/2 hr 4 hr 1/4 hr 2-3/4 hr 4 hr 5 hr 1/4 hr 7-1/4 hr 4-1/2 hr 1/2 hr 3 hr 1 hr 1-1/2 hr 1/2 hr 3 hr 4 hr 1/2 hr lhr 1-1/2 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 5-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 1/2 hr 8 hr 2-1/2 hr Activity Rig moved 100.00 % Rigged up Drillfloor / Derrick Held safety meeting Rigged up High pressure lines Circulated at 10052.0 ft Bleed down well Held safety meeting Circulated at 10052.0 ft Removed Xmas tree Installed BOP stack Tested All rams Investigated pressure change Circulated at 10052.0 ft Circulated at 10052.0 ft Circulated at 10052.0 ft Removed Tubing hanger Held safety meeting Pulled Tubing in stands to 10100.0 ft Installed Rig services Flow check Circulated at 10052.0 ft Pulled Tubing in stands to 10100.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 1800.0 ft (3-1/2in OD) Flow check Held safety meeting Bullhead well Ran Tubing in stands to 7160.0 ft Held safety meeting Ran Tubing in stands to 10571.0 ft Reverse circulated at 10602.0 ft Circulated at 10602.0 ft Monitor wellbore pressures Monitor wellbore pressures Circulated at 10602.0 ft Held safety meeting Circulated at 10693.0 ft Reverse circulated at 10693.0 ft Circulated at 10400.0 ft Pulled Tubing in stands to 9960.0 ft Pulled Tubing in stands to 4000.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Held safety meeting Rigged up sub-surface equipment - ESP Ran Tubing in stands to 1000.0 ft Held safety meeting Ran Tubing in stands to 7800.0 ft Rigged up sub-surface equipment - ESP Facility Date/Time Progress Report M Pt C Pad Well MPC-09 Rig Nabors 5S Page Date 05:00-06:00 06:00-06:30 06:30-09:30 09:30-11'30 11:30-12:30 12:30-14:30 14:30-17:00 17:00-22:00 Duration 1 hr 1/2 hr 3 hr 2 hr lhr 2 hr 2-1/2 hr 5 hr Activity Ran Tubing in stands to 8500.0 ft Held safety meeting Ran Tubing in stands to 10138.0 ft Installed ESP Ran Tubing on landing string to 10138.0 ft Removed BOP stack Installed Xmas tree Displace treatment 2 05 March 98 .SENT BY :BPX-i~ff'OC ; 3-2§-~17 ; 5:22 ; BPX-~ILI~E UOl~'l'~ · Memorandum To.' Blair Wondzell/AOGCC · oam: 3/28197 Jerry Bixbyl MPU Well Ops Sublect: _A.p_p_!!CatiOn for Sundry C-09 Annular Vent Attached you will find our application for Sundry approval and two drawings for our proposed annular vent system, The sole intent is to bleed IA gas into the production tree and down the flow line, Figure #1 will be the most common used with Figure #2 used if room permits in our well houses. Every effort will be made to put the Actuated valve as close as possible to the manual annulus valve. This will be basically the same system we had proposed for well E-11 before the ESP failed. We will invite all inspectors out to take a look at the syslem when it is installed. Thanks again for your help and consideration in this matter. Jerry L. Bixby MPU Well OPS Coordinator ORIGINAL RECEIVED Ala.,~a 011 & ~ Cons. C~mmi~lon A~choraoe .$F_,NT BY :BP×-~IPOC ;8-28-97; BP EXPLORATION (ALASKA) PRODUCTION ENGINEERING PRUDHOE BAY, ALASKA FAX # (',907) 659-4655 5:21 ; BPX-MILNEPOINT~ Message No, 907 276 7542;~ 1/ 0 TO: LOCATION: TEI,ECOPY. -- RECEIVED Anchorage FROM: LOCATION: PAGES TO FOLLOW_'..__ DATE: TIME: (excluding this cover) OPERATOR:_ COMMENTS:_ SECURITY CLASSIFICATION (BP America Guidelines) .~.-~ Non-Classified _ ~ Secret Confidential ..... Private IF YOU DO NOT RECEIVE ALL PAGES, OR HAVE ANY PROBLEMS, PLEASE CALL ONE OF THE FOLLOWING NUMBERS' (907) 659-4654 (907) 659-4660 "BPA NET" 621-4654/4660 SENT BY: BPX-I~OC ; 3-28-D7 ; 5: 22 ; ut'X-~l I LNE FO 1 INT.+ , ,~ ~/~ I r~ <71" · " ALA~-~--.OIL AND GAS CONSERVATION COMMISSIO' APPLICA', .,.)N FOR SUNDRY APPhOVALS 1. Type of Request: Aba,don Suspend Opetal~on Shutdown __ Re-snter suspended well ........ Al{er casing __ Repair well Plugging Time extension Stimulate Change approved program Pull tub(no __ Variance ~ Perforate ~ Other,,,,~.._ 2. Name of Operator BP Exl)loratton (Alaska) Inc. 3. Address P. O. Box 196612. Anchoraue. Alaska 99519-6612 4. Location of well at surface 4166' FNL, 2428' FEL, Sec. 70, T13N, RIOE At top of productive interval At effective depth At total depth 2001' FSL. 1294' FEL $EC4. T13N, RIOE, 5. Type of Welt: Dovolopment F[ Exploratory stratloraphic ...... Service 6. Datum elevation (DF or KB) 52' 7. Unit or Property name Miine Point Unit 8. Well number C-09 9. Permit number 85-36 10. APl number 50- 029-21299 11. Field/Pool KuDaruk River Pool feet 12. Present well condition summary Total depth; measured true vertical Effective depth; measured truc vortical 10,881' teat Plugs (measured) 7,307 feet 10,734 teat Junk (measured) 7,225' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured 115' 13 3/8 115' 6.604' 9 5/8 2600 SX Tvl)e "E" / 6,604' 10870 7" 271 Sx Class "(3" 10,870 measured 10,392.10,408 10,454-10,502 10,608. 10,680 ORIGINAL True vertical depth BKB 115 4, 699' 7,300' true vertical 7,022.7,031 7,059- 7,087 7~ 150- 7,191 , Tubing (size, grade, and measured depth)3 1/2 9,2# L-80 Butt at 10,098' RECEIVED Packers and $8SV (type and measured depth)no packer orsssv AI~I~EII 0Il & Gal ~O.l. ~mmlallon 13. Attachments Description summary of proposal X Detailed operations program ...... '"~OP sketch __ 14, Estimated date for commencing operation 16. If proposal was verbally approved I Oil × Gas Name of approver Date approved Service ........ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Slglled {j~ .......... Title ~{~/..~, / ~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 15. Status gl well classification as: Suspended~ Plug integrity . BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- 7~.~P c~,,'/-.k ~'~V Original Signed 'By Approved by order of the Commission David ~., Johnston Form 10-403 Rev 06/15/88 ~o ~ cJ/A,,,r"ffO,4" Date ~'/~77 J^ppro'~a, No. ~)q _., ~L~:] Commissioner sU'~'MIT ,N Ti~P~.ICATE SENT BY:BPX-MPOC ; 3-28-97 ; 5:22 ; BPX-MILNE POINT~ 907276 7542;# 3/ 5 ProposEÍ- annular vent:Fi4~re #1 Notes: The hydraulic control pressure for the SSV would be tapped to supply pressure to the annular vent actuator. Both actuators would then trip simultaneously if needed closing In the well. 2° welded pipe ~ ~J"'I:'INl"".."""'~"""-'"."1 ~-"',W'I~'-""""'- Annular vent actuator Check valve ~ 'I" ,', ", ",:,: '" " r, ,18: (~ '1';'-' ',:,,; ',:,':,: ',;', :'r:: ,'; ;:, ¡¡.ii: I"'¡¡¡¡¡¡"""""~" ,.",'" !!I,ll",,' '.."'" :;":,,,. ;"":,::::...::,,, ,..,':,'.... ..'..'r,'.. ,.'" '". 'M8t¡' ,,',1,'1, ,.,1,. / ssv :;, , ~i'l~ ~ll"'t ' " " C.) ':li8¡,< Il¡¡!8!:i" ,':,~it:': ::iil::?:" ',' "'"",,.'.:,',,;:,' <:¡II.r.:' :::!:;~ilk:::, ;1" ~;i " r'1 Ii 'J ,,¡, ~œ RECEIVED M~R 28 ,g9r Alaska Oil & Gas Cons. COmmission Anchorage 9072767542;# 4/ 5 BPX-MILNE POINT~ 5:22 ; ; 3-28-97 ; SENT BY:BPX-MPOC " ,,- ( Proposed da~nular vent:Figure #2 Notes: The hydraulic control pressure for the SSV would be tapped to supply pressure to the annular vent actuator. Both actuators would then trip simultaneously If needed closing in the well. Check valve - 2" welded pipe -~ ""':=1: 1:",',',",",I':.',:,.','~,",::i::""""',. " :::::',:","'",,'.'.." :".'",,:,..~,,' "c""" ..' ,..,,' """""""',' """"""""',"']'" """"'ml""" " ,.,. ]il.lii,: ;11 ¡: / ssv r ' ::'¡ >' -, '" ¥ :",'..<1!"""""...!'1!1~~ ..' ' . ~1¡I"jI"""'.""""""""'I l.., ../J 11): t ii,".,:,' ..::.¡¡, 1 , '.....t", ':""""",','"',..,",41."",,,) .. I, /1 ::1!8;; i~.K,:' ::,!liii8'&:: ,;:¡[_mi~:',' ::))1' "W:: ',.',':,~,,:,:,I . \'i: ',",'::',',:: 'Pet 1': ,'" ~i ".. ' ,..'..,' :n "i~': ,1.. " I ':, :i. =III..., , ' :' ;. ..'", -- ':)"'" Annular vent actuator "~ RECEIVED MM{ 28 1q:f 1 Alaska 011& Gas Cons. Commission , Anchorage MEMORANDIr. M _State of Alaska Alaska Oil and Gas C~, ~ervation Commission TO: David J?h~ Chairm~n ~ DATE: July 15, 1995 THRU: Blair Wondzell, ~.~2,.~ FILE NO: P. I. Supervisor 7/~,/ef' FROM: Jerry Herring,~'""~ SUBJECT: Petroleum lnspectbr aw9kglcd.doc BOPE Test, Nabors 4ES BPX, Milne Point Unit Well MPU C-09, PTD 85-0036 Tuesday, July 11, 1995: i traveled to BPX's Miine Point Unit to witness a BOPE test on Nabors 4ES completing a workover on well C-09. The BOPE test report is attached for reference. I arrived at 8:00 PM as requested by the rig personnel. The test finally got underway at 2:00 AM in the morning. Because the rig had been taken out of service for a month for maintenance, the BOP stack had to be completed rebuilt from ground up. Many leaks on the stack were repaired until the stack finally was able to hold the 5,000 PSlG test pressure. All of the valves on the choke manifold had to be greased before the valves would hold the test pressure. In all, there were at least 10 separate failures and the test did not end until 2:00 PM making this a very long test. I was exhausted by the end of the test. Overall, the rig was in excellent condition sporting a new paint job. Several other changes were completed on the rig improving the layout for the floor hands. Both crews worked hard to get the BOP equipment operating correctly and I am glad I was there to verify the adequacy of the test. Summary: ! witnessed a BOPE test on Nabors 4ES completing a workover on MPU C-09. The test lasted 12 hours and there were 10 failures. Attachment: aw9kglcd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: Drlg Contractor: Nabors Alaska Drilling Operator: BPX Well Name: MPU C-09 Casing Size: 7" Set @ Test: Initial X Weekly X DATE: 7/12/95 Rig No. 4ES PTD # 85-36 Rig Ph.# 659-6476 Rep.: Gene Cooper Rig Rep.' Gene Sweatt 10870' Location: Sec. 10 T. 13N R. IOE Meridian UM Other Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD # n/a Standing Orders Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. O.__K Test BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Pressure P/F I 250/3000 P 1 250 / 5000 F / P n/a 250/5000 n/a 1 250 / 5000 F / P I 250 / 5000 P 2 250 / 5000 P I 250 / 5000 P n/a n/a n/a MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F n/a n/a n/a n/a n/a n/a 1 250 / 5000 P I 250 / 5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 10 250 / 5000 F 26 250 / 5000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,950 J P 1,900 P 0 minutes 38 sec. 2 minutes 20 sec. OK Remote: OK (4) BOTTLES 2200 AVE. Psig. Number of Failures 10 Test Time 12.oo Hours Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The rig was down for maintenance and the BOP stack was completely rebuilt. There were man)/leaks on the stack. All were repaired and the stack finally tested good. Several valves on the choke manifold leaked. Choke manifold was serviced with grease and finally tested good. Rig had been freshly painted and looked good. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: j)~, ~ AW9KGLCD.XLS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 July 1995 Transmittal of Data ECC #: 6282.02 Sent by: PRIORITY MAIL Data: PFC/PERF Dear Sir/Madam, Reference: MPC-09 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wir~ chorage,AK 99518 r FAX ~_907)563-7803 Received bY~ ~/ ~~ ~ate: RECEIVED ..... dUL 4 .,_.,_ n~, & ao~ P. rmg. CO[~ITIJssJo~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: MPF-01___ . 1 PLS/STATIC FNL BL+RF a' 1 PFC/PERF FINAL BL+RF MPF-01/' 1 GR/CCL FINAL BL+RF ECC No. Run # 1 6282.01 Run # 1 6456.01 Run # 1 Run # 1 6456.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Received by~~ ~~ - Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI3dlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing X Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 4166' SNL, 2428' WEL, SEC. 10, T13N, RIOE At top of productive interval 3620' SNL, 1091' WEL, SEC. 4, T13N, RIOE At effective depth At total depth 3279' SNL, 1294' WEL, SEC. 4, T13N, RIOE 6. Datum elevation (DF or KB) KBE = 52' 7. Unit or Property name Mi/ne Point Unit feet 8. Well number MPC-09 9. Permit number/approval number 85-36/94-262 10. APl number 50- O29-21299 11. Field/Pool Kuparuk River 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 6267' 10836' measured true vertical 10881 feet 7308 feet 10772 feet 7245 feet Size Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 16" 9-5/8" To Surface 115' 115' 2600 sx "E"/275 sx "G" 6303' 4549' 7" 271 sx Class "G" 10870' 7301' 10656'- 10680', 10632'- 10656', 10608'- 10632', 10470'- 10500', 10446'- 10470', 10416'- 10446', 10392'-10416' 7126'-7140', 7112'-7126', 7098'-7112', 7016'-7034', 7002'-7016', 6984'-7002', 6970'-6984' (Subsea) Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 10187' MD Packers and SSSV (type and measured depth) Camco TRDP-4A SSSV @ 529' MD; HES DHR Packer @ 559' MD; Baker 'FB- 1' Packer w/ screen assembly @ 10264'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure l~OV - 4 0il & Gas Cons. Commission Anch0rc 14. Reoresentative Daily Avera(]e Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of ~ell Operations x 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certif~a],a~e,,f~/egOing is true~nd correct to the best of my knowledge. Signed ,~ ~--~~' ~'~'~_. TitleDrillin~lEn~lineerSupervisor Service Form 10-404 Rev 0~/15/88 MP C-09 09/25/94 10,870' FINISH MODIFICATION ON CHOKE MANIFOLD. ADDED VALVE DOWNSTREAM OF EACH CHOKE, TO ENABLE CHOKE ISOLATION. REBUILD STUFFING BOS ON DRAWWORKS. STANDBY WHILE MP PRODUCTION FINISHES WIRELINE PREP ON C-09. 09/26/94 10,870' STANDBY WHILE MP PRODUCTION FINISHED WIRELINE PREP ON C-09. LAY HERCULITE AND MATS. SPOT SUB, PITS, AND PIPE SHED. RAISE AND SCOPE DERRICK. ATTEMPT TO PULL BPV. BLED GAS. PULL BPV. RU HARD-LINE TO TREE AND TIGER TANK. TAKEN ON 130 DEGREE SOURCE WATER. RU CAMCO. TEST LUBRICATOR. RIH, LATCH AND PULL EQ PRONG @1914' WLM. RIH, LATCH AND PULL PLUG. TEST HARD-LINE. PRESSURE UP AND PUMP OPEN SSSV. FILL TBG W/60 BBL'S SOURCE H20. CIRC. ACCEPT RIG @2200 HR'S ON 09/24/94. 09/27/94 10,870' FINISH CIRC WELL TO SOURCE H20. RIH AND SET PLUG IN SSSV PROFILE @1914' WLM. POH AND RD CAMCO. SET TWC. NIPPLE DOWN TREE AND ADAPTER FLANGE. NIPPLE UP BOPE, RISER AND FLOW LINE. RU TO TEST BOPE. NO TEST ON LOWER FLANGE. TIGHTEN UP. NO TEST. ND GRAY LOCK FLANGE. TIGHTEN ADAPTER FLANGE. RE TORQUE GRAY LOCK. GRAY LOCK CLAMP HITTING STUDS ON ADAPTER FLANGE. ND FLANGE. GRIND DOWN STUDS. MAKE UP GRAY LOCK. NU FLOW NIPPLE. TEST BOPE. HAD TO FABRICATE TEST JT TO TEST PIPE RAMS. NECK ON HANGER EXTENDED TOO CLOSE TO PIPE RAMS. RD TEST JT. PULL TWC. RU LANDING JT. RU CAMCO. 09/28/94 10,870' WO XO'S TO RIG UP CAMCO. FINISH RU CAMCO AND LUBRICATOR. TEST LUBRICATOR, OK. RIH AND PULL EQ PRONG. POH. RIH AND PULL PLUG @ 1914' WLM. POH RD CAMCO. RU AND CIRC PROD H20 AROUND. SOME OIL AND GAS CUT. BOLDS. PULL HANGER TO FLOOR. SEAL ASSEMBLY APPEARED TO ALREADY BE SHEARED. LD HANGER. PUMP OPEN SSSV. POH W/3.5" TBG. SLM AND DRIFT TBG IN DERRICK. ClRC TO CHECK SSSV. CIRC SMALL AMOUNT CRUDE AND GAS OUT. LD SSSV. POH W/ 3.5" TBG. LD GLM'S. RECEIVED NOV -'4 1994 A!;~ska Oil & Gas Cons. Commission Anchor~ 09/29/94 10,870' FINISH POH W/3.5" TBG. SLM & DRIFT. LD GLM'S. STRAP, CALIPER & PU FISHING TOOL ASSEMBLY #1. SET WEAR BUSHING. RIH W/FTA #1, PICKING UP 3.5" DP. DRIFT DP. SERVICE RIG. FINISH RIH TO 10200'. CIRC ONE FULL CIRC. STING INTO PBR W/SPEAR. ClRC OUT OIL AND GAS BUBBLE. OPEN BAG AND CIRC. POH. DRAGGING 5-35K OVER ST WT. 09/30/94 10,870' POH. PULLING PIPE @ 3 MIN/STD TO KEEP HOLE FROM SWABBING. LD FISH AND TOOLS. RECOVERED EVERYTHING FROM TOP PACKER TO LOWER SEAL ASSEMBLY. BLAST JTS UNCUT, BUT COATED WITH WHAT APPEARED TO BE HARDENED ASPHALTINE AND FORMATION SAND. PU FTA #2. RIH W/FTA #2. SLIP 62' DRILLING LINE. FINISH RIH TO 10506'. CBU. MILL ON PACKER F/10512.5-10514.5'. LOSING CIRCULATION REPEATEDLY WHILE MILLING. ACTS LIKE PACKER MILL IS PACKING OFF ON THE PACKER ELEMENTS, FORCING FLUID DOWN HOLE TO LOWER PERFS. BEING FORCED TO MILL A LITTLE, THEN PULL UP TO CIRC CLEAR. QUIT MAKING HOLE AFTER 2'. START CBU & WO XANVIS SWEEP. PUMPING XANVIS/LITHIUM HYPO CHLORITE SWEEP. 10/01/94 10,870' FINISH CIRC XANVIS SWEEP AROUND. HOLE UNLOADED RUBBER AND METAL. SPOT 20 BBL XANVIS PILL ON BOTTOM. CONTINUE MILL ON PKR F/10514.5-10516'. PACKER BROKE LOOSE. PUSH DOWN HOLE TO 10536' RKB. CBU. POH W/FTA #2. DID NOT RECOVER FISH. LEFT PRT IN HOLE. MU FTA #3 AND RIH. SLIP AND CUT DRLG LINE. FINISH RIH. TAG FISH @10524'. VERIFY TOP OF FISH W/PUMP PRESS. WORK W/SPEAR ON BOTTOM TO GET GOOD BITE. CBU. CIRC OUT GAS. POH W/FTA #3. APPEAR TO BE DRAGGING FISH. 10/02/94 10,870' SERVICE RIG. FINISH POH W/FTA #3. NO FISH. SPEAR SHOWED MARKS ON GRAPPLE WHERE IT HAD BEEN ALL THE WAY IN. GRAPPLE WAS IN THE RELEASE POSITION. SUSPECT IT RELEASED WHEN USING JARS ON BOTTOM. GRAPPLE WAS 4.179". INSTALL 4.320" GRAPPLE ON SPEAR. RIH W/FTA #4, TO 10514'. CBU. CIRC GAS OUT. WORK W. SPEAR @ 10524'. SEEING PUMP PRESS INCREASE WHEN WORKING ON BOTTOM. POH SLOW W/FTA #4. NO FISH. MARKS ON BULL NOSE, RETAINER RING & LOWER LEVEL ON GRAPPLE. GRAPPLE HAD NOT BEEN IN FISH. LD SPEAR, & PU OVERSHOT & FTA #5. OVERSHOT DRESSED W/3 1/8" SPIRAL GRAPPLE. RIH W/FTA #5 TO 10493'. CBU. CIRC GAS OUT. a!a~ka Oil a Gas Con~. Commission Anchor~. 10/03/94 10,870' ATTEMPT TO WORK OVERSHOT INTO FISH @ 10524'. NO GOOD INDICATIONS. SLIP 42' DRLG LINE. ADJUST BRAKES. POH W/FTA #5. APPEARS THAT OVERSHOT GUIDE HAD BEEN INTO FISH +/- 6". 3 1/8" GRAPPLE WAS BROKEN. PU PIN TAP. RIH W/FTA #6. CBU. LESS GAS THAN PREVIOUS TRIPS. WORK W/PIN TAP ON FISH @10524'. PUMP PRESSURE INDICATION OF WHETHER WE WERE PULLING OUT OF FISH, OR PULLING FISH. POH W/FTA #6. NO FISH. OF 9.5" TAP AREA, 7.5" SHOWED CLEAR INDICATION OF BEING IN FISH. 2" SHOWED CLEAN. STOP AREA ABOVE THREADS WAS WORN CLEAN. APPEAR TO HAVE TAPPED through A RESTRICTION. PU PIN TAP. START RIH. 10/04/94 10,870' SERVICE RIG. RIH W/FTA #7. CUT 106' AND SLIP 64' DRLG LINE. FINISH RIH. CBU. CIRC GAS OUT. LOCATE INTO FISH @ 10524' W/PUMP PRESSURE. WORK TAP INTO FISH AND WORK WITH SAME. START TRYING TO WORK FISH FREE. BLED OFF JARS. STRAIGHT PULLED IN 3-5K INCREMENTS. WORKING FROM STRING WT, UP TO 80K OVER. PULLED LOOSE. UNABLE TO TELL IF PULLED FISH LOOSE, OR PULLED OUT OF FISH. CIRC HOLE. POH W/FTA #7. LD PIN TAP. PIN TAP HAD BEEN +/- 6.5" INTO FISH. PU BURN SHOE AND EXTENSIONS. RIH W/FTA #8. CBU. CIRC GAS OUT. BURNING OVER FISH. 10/05/94 10,870' FINISH BURN OVER FISH F/10524-10526.5'. PUMP 45 BBL XANVIS/LITHIUM SWEEP AROUND. POH W/FTA #8. MILL 50% WORN. CONFIRMED MILL HAD BEEN +/- 2.5' OVER FISH. PU 4.75" GRAPPLE IN FTA #9. START RIH. CBU. CIRC OUT GAS. WELL MAKING CONSIDERABLE CRUDE. WORK GRAPPLE ONTO FISH @ 10526'. STAGED UP JARRING IN SAME INCREMENTS. SLIPPED OFF. GOT BACK O FISH. UNABLE TO STAY ON FISH. CIRC. SKIM OFF OF PITS. POH W/FTA #9. 10/06/94 10,870' LUB RIG. POH W/3 1/2" DP & LAY DOWN BHA #9. WAIT ON FISHING TOOLS. MAKE UP BHA #10 & RIH WITH SAME SLOWLY, TO TOP OF PKR @10524'. CBU. MILL OVER PKR, MILL OUT EXTENSION W/6 1/8" X 5 1/4" WASH OVER SHOE & 1 JT WASH PIPE F/10524-10530'. FISH FELL FREE CHASE DOWN HOLE 20'. CIRC BOTTOMS UP. RECEIVED NOV -4 lgga. A!aska 0il & Gas Con,~. Commission Anchor; 10/07/94 10,870' CIRC BOTTOMS UP & RAISE WT TO 8.6 MONITOR WELL. POH W/BHA #10, 5 STANDS. CONT POH AND LAY DOWN BHA #10. MAKE UP FTA #11. RIH W/ FTA #11 TO 10550'. CIRC BOTTOMS UP. PUSH FISH F/10550 - 10673' & LATCH SAME W/OVERSHOT 4 5/8" GRAPPLE. WORK FISH TO ASSURE GOOD CATCH. CIRC BOTTOMS UP TO REMOVE OIL & GAS F/SUMP HOLE THAT WAS PUMPED UP HOLE WHILE LATCHING FISH. POH W/FTA #11. 10/08/g4 10,870' LUB RIG. CUT AND SLIP 84' DRLG LINE. POH W/BHA #11 LAY DOWN SAME. REC PACKER MANDREL & MILL OUT EXT REC PKR SLIPS ON TOP OF FISH IN OVERSHOT. MU BHA #12 & RIH TO 10783' WITH CSG SCRAPER SPACED AT 10360'. CIRC BOTTOMS UP UNTIL GAS AND OIL INFLUX OUT AND RETURNS CLEAN. POH AND LAY DOWN BHA #12. INSTALL TEST PLUG AND TEST BOP. TESTING CHOKE MANIFOLD. 10/09/94 10,870' CONT TESTING BOP AND CHOKE MANIFOLD & KOOMEY TEST. PULL TEST PLUG. INSTALL WEAR RING. RIG UP SHOOTING FLG ON ANNULAR AND TEST LUBRICATOR. RIH W/ATLAS GR/CCL AND GUN TIE IN TO DUAL INDICATIONS/SFL-GR. PERFORATE. RIG DOWN ATLAS AND SHOOTING FLANGE. INSTALL BELL NIPPLE. RIH W/31 STD DP. CIRC DP VOLUME & MONITOR WELL. CONT RIH WITH DP, 106 STANDS. WELL FLOWED WHILE LOGGING. 10/10/94 10,870' CONT RIH TO 10703'. CIRC AND COND BRINE. RU BJ. TEST BJ LINE. PULL 10 STDS. REVERSE CIRC TBG VOLUME. RIH TAD SD @ 10579'. PULL 5 STDS, WAIT ON CARBOLITE TO FALL. WAIT ON SD WHILE OBSERVING WELL U-TUBING OUT TUBING. ATTEMPT TO RIH TO TAG SD PLUG. BRINE FLOWING OUT DP. DECISION TO CIRC. WELLBORE TO MORE STABLE. REV CIRC DP VOLUME AND OBSERVE WELL. RIH TAG CARBOLITE @ 10568'. POH W/DP. SLIP DRLG LINE. CONT POH. PICK UP BAKER MODEL C-1 FULL BORE PKR AND RIH AND SET @ 570'. RU BJ FRAC EQUIP. TEST SURFACE LINES & PERFORM FRAC. RECEIVED Gas Cong. Commission Anchor;. 10/11/94 10,870' CONT FRAC AND RIG DOWN BJ. RU CIRC. HEAD AND MONITOR PSI. RECORD DP PRESSURE ON CHART. START BLEEDING VOLUME OFF IN STAGES BLEED TO 0. OPEN ANNULUS AND DP & OBSERVE WELL NO FLOE. UNSEAT & POH W/BAKER C-1 PKR. LAY DOWN SAME. MU BIT & RIH TO 9566'. TAG FRAC SD. LAY DOWN 37 JTS DP AND RIH WITH 12 STD OUT OF DERRICK. WASH FRAC F/9566-9634'. RETURNS WERE HIGHLY VISCOUS. PULL BACK TO 9507'. MIX PH-6 TO BREAK DOWN CROSS LINKED GEL & DIS. OUT OF HOLE IN VAV TRUCK. WASH OUT FRAC F/ 9560-9919'. 10/12/94 10,870' WASH OUT FRAC SAND F/9920 - 10135'. REVERSE CIRC FRAC SAND OUT F/10135-10574'. CIRC AND WASH FRAC SAND CONVENTIONALLY. PUMP 40 BBL XANVIS SWEEP W/BREAKER CONV AND ATTEMPT TO REVERSE CIRC 35 BBL XANVIS SWEEP W/BREAKER PLUGGING OFF. PUMP 35 BBL SWEEP CONV SHUT WELL IN AND GO THROUGH CHOKE AND GAS BUSTER DUE TO GAS INFLUX KICKING BRINE OVER NIPPLE NO SHUT IN PSI TO READ. OPEN ANNULAR WHEN INFLUX BY AND CONTINUE TO CIRC SWEEP. REVERSE CIRC. 10/13/94 10,870' REVERSE CIRC. MIX AND PUMP 40 BBL'S XANVIS SWEEP, DISPLACE WELL TO CLEAN FILTERED BRINE. CLOSE IN WELL AND MONITOR. DRILL PIPE 200 AND ANNULUS 100. CLEAN PIT TRIP TANK AND FLOW LINE SHAKER BELLY AND TROUGHS OF CARBOLITE. FILL TRIP TANK. CIRCA COMPLETE HOLE VOLUME + THROUGH CHOKE TO DETERMINE ACTUAL WELL PROBLEM. HAD SOME GAS AND OIL INFLUX TO SURFACE. CIRC. WELL WOULD NOT FLOW. DISPLACE WELL TO 9.1 PPG THROUGH CHOKE. HAD A 17 BBL'S OIL INFLUX GAIN. MONITOR DP AND ANNULUS. NOT RECORDABLE ALTHOUGH WELL BORE HAS OIL AND GAS INFLUX WORKING OUT AND WILL FLOW IF LEFT OPEN. DISPLACE 9.1 PPG BRINE WITH 9.3 PPG AND THROUGH CHOKE WHILE CIRC. MONITOR WELL DP AND ANNULUS. WELL BORE STABLE. POH W/10 STDS AND STD IN DERRICK HOLE TOOK CALCULATED FILL. MONITOR WELL. WELL BORE STABLE. LAYING DOWN 3 1/2" DP. RECEIVED NOV - 4 '1994. 0il & Gas Con~. Commission Anchor;_ . 10/14/94 10,870' LUB RIG. LAY DOWN 3 1/2" DRILL PIPE. PUMP 40 BBL XANVIS PILL, FILL TRIP TANK W/9.3 PPG BRINE. CONTINUE LAY DOWN DRILL PIPE AND DRILL COLLARS F/DERRICK. NIPPLE DOWN FLOW NIPPLE AND NIPPLE UP SHOOTING FLANGE. RIG ATLAS AND TEST LUBRICATOR. RIH W/6.0" GAUGE RING AND JUNK BASKET TP 10386' WLM, POH. RIH W/BAKER MODEL F-1 PKR AND SCREEN ASSY TO 6535', UNABLE TO GET DOWN HOLE. POH AND INSPECT SCREEN ASSY. NO VISIBLE MARKS THAT WOULD INDICATE PROBLEM. RE-RUN PACKER AND SCREEN ASSY TO 6535'. ATTEMPT TO USE DIFFERENT LINE SPEEDS. NO RESULTS POH AND GRIND STABILIZER AT BOTTOM OF SCREEN. RE-RUN PKR AND SCREEN ASSY TO 6535'. NO RESULTS POH W/SAME RE-RUNNING GAUGE RING JUNK BASKET TO VERIFY. 10/15/94 10,870' CONTINUE RIH WITH 6.0" GAUGE RING AND JB TO 7500', NO PROBLEM AT 6500'. RIG DOWN WESTER AND RIG DOWN SHOOTING FLG AND RIG UP NIPPLE. MU BAKER F-1 PKR ON TBG AND RIH W/SAME TO 10264'. DROP 1 7/16" SETTING BALL. CIRC DN. SET PKR. PICK UP AND SHEAR OFF WITH 25K OVER TD PU WT 10264'. CIRC BOTTOMS UP. TOOK 2 BBL GAIN W/OIL INFLUX AND CIRC INFLUX OUT THROUGH CHOKE. OPEN BAG AND OBSERVE WELL. NO FLOW AND POH W/TBG. CUT DRLG LINE. CONTINUE POH W/TBG AND SETTING TOOL. RIG UP TO RUN ESP AND PICK UP SAME. 10/16/94 10,870' MU CENTRALIFT ESP PUMP ASSY. RIH WITH ESP COMPLETION ON 3.5" 9.2# L-80 BUTT TBG. PU HES DHR PKR RETR PKR PERFORM ESP SPLICE. PU CAMCO TRSSSV AND HOOK CONTROL LINE AND TEST. RIH W/ESP COMP ASSY. PU LANDING JT AND TBG HGR STB PENETRATOR AND PERFORM ESP SPLICE INSTALL SSSV LINE THROUGH HGR. 10/17/94 10,870' LAND HANGER 3 1/2" COMPLETION STRING W/ESP RILDS-RD LANDING JT. SET TWO WAY CHECK. ND BOP. BRIDGE CRANE DN - REPAIR SAME. SET BACK BOP. NU ADAPTER FLANGE AND TREE. TEST ADAPTER AND HGR. PUMP OPEN SSSV LINE. TEST TREE. PULL 2-WAY CHECK. RIG UP TO DISPLACE PUMP 70 BBL 60/40 METHANOL DOWN ANNULUS. ALLOW TO U-TUBE TO TBG. PUMP 10 BBL METHANOL DOWN TBG. DROP SETTING BALL. PICK UP LUBRICATOR SET BPV. SECURE TREE. RELEASED RIG @ 2400 HR'S 10/16/94. RF.,C£1¥£D ~OV -'4 1994 Gas Con~. Commission ^nchor; : LARRY GRANT Attn. ALAS.KA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPC-e9 DESCRIPTION 1 PFC/GR/PERF FINAL BL 1 PFC/GR/PERF RF SEPIA 1 CCL/PERF FINAL BL 1 CCL/PERF RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6282.00 6283.00 P1 las Wi~=linc ~_rvic__ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received b ""~$~a Oil & ~a~ Co,~s MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~, DATE: Chairm~n..~ October 5, 1994 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM' Lou Grimaldi, ~,~.- SUBJECT: Petroleum Inspector QW9JIEBD.DOC Rig BOPE inspection Nabors 4-ES BPX well # C-9 Milne Point Unit PTD #.,,94--2~'- Wednesday, October 5, 1994: I traveled to BPX C pad in the Milne Point Unit to make a Rig BOPE inspection on Nabors rig 4-ES. The rig was pulling tubing when I arrived. Bob Finkbinder (Nabors Toolpusher) accompanied me on my tour of the rig. I found all BOPE equipment to be in place with the exception of the methane detection system. The equipment had been installed since my last visit but was malfunctioning and was sent to Eagle enterprises to be repaired. Bob informed me that turnaround time was approximately 48-72 more hours. Access to the rig was fair considering the small size of the pad..The location surrounding the rig was clean and orderly. SUMMARY: I made a Rig/BOPE inspection on Nabors 4-ES. One non- compliance noted, No methane detection system. - Attachments: QW9JIEBD.XLS cc: Marry Lemon (Prudhoe Bay drilling) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drilling Workover Drig Contr: Operator: Location: Nabors BPX Section 10 T. 13N X Cmpl. UlC Well Name C-9 Rig No. 4ES Rep. Rep. Tom Anglin R. 10E M. U DATE: 9/5/94 PTD# 94-26-2 Bob Finkbinder Rig Ph.# 659-2233 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses ect.) IN COMPLIANCE IN COMPLIANCE REMARKS: Methane detectors down for repairs INSPECTION ITEMS MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors H2S & methane) Hydraulic choke panel Choke manifold INSPECTION ITEMS (E.) MISC. EQUIPMENT Flare/vent line All turns targeted (downstream choke lines) Reserve pit tankage Personnel protective equip, avail. Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK 9/27/94 Kill Sheet Current? Distribution: odg - Well File ¢ - Oper./Rig c - Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) Louis R Grimaldi QW9JIEBD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X Change approved program __ Pull tubing x Variance__ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4166' SNL, 2428' WEL, SEC. 10, T13N, RIOE 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) KBE = 52' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPC-09 '~-'~, H, At top of productive interval 9. Permit number 3620' SNL, 1091' WEL, SEC. 4, T13N, RIOE At effective depth At total depth 3279' SNL, 1294' WEL, SEC. 4, T13N, RIOE 12. Present well condition summary Total depth: measured 10881 feet true vertical 7308 feet Effective depth: measured 10772 feet true vertical 7245 feet Plugs (measured) Junk (measured) 85-36 10. APl number 50- 029-21299 11. Field/Pool Kuparuk River Casing Length Structural Conductor 80' Surface 6267' Intermediate Production 10836' Liner Perforation depth: Size 16" 9 -5/8" Cemented Measured depth True vertical depth To Surface 115' 115' 2600 sx "E"/275 sx "G" 6303' 4549' 7" 271 SX Class "G" 10870' 7301' Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 10573'MD measured 10646'-10680', 10609'-10629', 10454'-10464', 10498'-10502', 1o392,.1o4o6,[ E E i V E true vertical 7172'-7191', 7150'-7163', 7059'-7065', 7085'-7087', 7022'-7030' · E..P 2 2 1994 ,~ ~Ka utt& Gas Cons. C0mmi Anch0r~ Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV @ 1917'MD; BOT 'HB' retrievable packer @ 10249'; BO T'2-B' packer @ 10550' MD 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 9/24/94 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby certify/t~at the foregoing is true and correct to the best of my knowledge. Signed ,/~~') ~ 15. Status of well classification as: Gas Suspended Title Drilling Engineer Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test__ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10- Original Signea By Approved by order of the Commission David W, J0hn,~t~n Form 10-403 Rev 06/15/88 IApproval No. ~, Commissioner ~pproved Copy Returned ~ion Date ~f~- ~f~ ? SUBMIT IN TRIPLICATE ~, -. MP C-09 RW("~'AND FRAC SUNDRY INFORE~, ,'ION Objective: The objective of this workover is to pull the existing gas lift tubing and staddle packers completion from the well, add additional perforations, perform a fracture treatment on the Kuparuk interval, set a packer/tailpipe assembly with screen, and recomplete the well with the existing 3.5" tubing and an ESP. Scope:, 1. Pre- rig: Obtain a static pressure survey and bullhead to kill the well. Cut tubing deep with chemical or jet cutter. Install BPV. Remove wellhouse and flowline. 2. MIRU Nabors 4ES workover rig. Circulate as necessary to ensure the well is killed. Pull existing 3.5" L-80 BTC tubing and the straddle packers completion. 3. Perform wireline conveyed perforations at Kuparuk sands. 4. Perform sandback to isolate Kuparuk "A" and "B" zones and fracture stimulate Kuparuk "C" sand interval. Cleanout wellbore to PBTD. Run 7" packer / tailpipe assembly with 20', 20 gage screen in the tailpipe and set it 50' above the top perfs. Rerun 3.5" tubing with an ESP, GLMs, SSSV and tubing packer. Freeze protect the well before setting the tubing packer. RDMO Nabors 4ES. Put well on production. . o o . Timing: Nabors 4ES will be making a pad to pad move from E-06 to C-09 on approximately 9/24/94. The workover should take approximately 8 days rig time. DH, September 21, 1994, 6:49 PM RECEIVED S£P 2 2 i994 Alaska Oil & Gas Cons. Con'lmission .Anchor~.~ WELL No. COMPLETION MILNE POINT C-9 SKETCH APl No.: 50-029-21299 PERMIT No.: 85-56 COMPLETED: 4/8/85 L/.,ST WORKOVER: N/A NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB-SL = 52' KDB-OL = 35' 2. MAX. /_ = 60.5' @ 6212' MD 3. K.O.P. = 500' 4. SLANT HOLE: YES " 5. MIN. /_ = 48.5' @ 9000' 6. TREE TYPE: FMC 3 1/8", APl 5000# 'VClTH 3 1/2" 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE 10.573 (2.750" ID) 8. COMPLETION FLUID: 10.2 PPG NaCI-NaBr 9. FRACTURE STIMULATION: 7-4-85 LK-2 72,000 LBS 16-20 P~RFORATION DATA 12 SRF, 120' PHASING. 5" GUNS (ALL DEPTHS FROM OiL LOC 4-1-85) MIDDLE KUP 10,392'-10.406' MD 7.022'- 7.030' i"VD L-8 10,454'-10.464' MD 7,059'- 7,065' TVD L-9 10,498'-10.50,2' -MD - 7.085'-7.087' TVD LK-2 10,646'-t0.680' MD 7.172'-7.191' TVO 4 SPF. 180' PHASING. 2 5/8' GUNS (ALL DEPTHS FROM OIL LOC; 4-1-85) LK-1 10,609' 10.629' ;',40 7.150'- 7,163' TVD FMC TUBING HANGER w/ 3 1/2" 'H' BPV PROFILE ~3 1/2", 9.2# L-80 BUTTRESS TUBING (2.992' I.D.. 2.867" DRIFT) ~ 1917' CAMCO TRDP-IA-SSA-SSSV (2.812" ID) ~ 2228' GLM ~ 5268' 0LM ~ 4275' OLM ~ 5317' GLM ~ 6223' GLM CAMCO ~ 7164" OLM ~ KBUG OLM ~9563'CLM ~ !;~P 22 1994 ~ 10,195' GLM / -.: ,~,a ,,,, ~, Gas Cons. Comrr Anchor~e BOT...PBR, SEAL ASSEMBLY (3.00" ID) ~ 10.249' BOT 'HB' PACKER (2.89" ID) 10,287' CAMCO 'W-I' SELECTIVE NIPPLE (2.812' ID) 10.521' CAMCO 'MMG-2' GAS LIFT MANDREL 2,92' ID. 1.5" VALVES 10,361' CAMCO 'MMC-2' CAS LIFT MANDREL 2.92' ID, 1,5' VALVES 10,402' BLAST JOINT (19.95' TOTAL LENGTH, 4.50' OD. 3.00' ID) 10,462' BLAST JOINT (19.85' TO:FAL LENGTH, 4.50' OD. 3.00' ~D) 10,507' BLAST JOINT (9.75' TOTAL LENGTH, 4.50' OD. zoo' ~D) 10,549' BOT LOCATOR, SEAL ASSEMBLY (3.00' ID) 10,,550' BOT '2-B' PERMANENT PACKER (,5.875' OD, 4.25' ID) W~TH MILLOUT EXTENSION, (5.00' OD. 4.408' ~0) 10.573' CAMCO 'D' NIPPLE (2.750' ID) 10.581' TUBING TAIL 10,725' TAG FILL E-LINE 6-19-91 10,772' PBTD 10,870' 7' 2~# L-S0 BTRS (6.276" ID. 6.151' DRIFT) CONOCO INC. ANCHORAGE DIVISION APPROVED BY: HDS DATE: 03/16/92 DRAFTED BY: SJN CAD FILE: wCOC9 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (10,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-13-85: ACCEPT RIG. NU diverter & diverter lines, mix spud mud. Strap BHA, PU BHA (function test diverter). Clean out ice 55'-103'. Orient Mach I, service MWD, orient MWD. Drld. from 103' to 590'. Unable to build angle w/new Mach I design. POOH from 590' to 0', LD 9½" Mach I, PU 8" Mach III and 2° bent sub, orient w/MWD. RIH from 0' to 590', survey and orient. Drld from 590' to 650'. 03-14: Drld. & surveyed from 2300' to 2951'. Dropped survey. POOH from 2951' to surface. Change BHA, LD 2 stabilizers, PU 9½" Navidrill, make up bit, orient Navidrill w/MWD, orient MWD, test MWD. RIH from surface to 2263T (tight spot 2186'-2233'). Work through tight spot from 2263'-2414'. Wash & ream from 2414' to 2552'. RIH from 2552' to 2750', take MWD check survey. Drld., surveyed & oriented from 2951' to 3820'. 03-15: Drld from 3820' to 4268'. Having false MWD readings, ran wireline survey. Drld. from 4268' to 4484'. Ran wireline survey, showed false MWD reading. Drld. from 4484' to 4608'. POOH from 4608' to 2808', at 2908' hole tight and started swabbing hole, POOH working pipe from 2908' to 2294' Ream from 2294' to 2491' LD 5 jts DP · , · POOH from 2491' to surface. Change electronics in MWD, make up bit, orient MWD. RIH from surface to 2598', couldn't work below 2598'. (Looked like making new hole?) Ream from 2598' to 2825'. Ran survey, still questionable, drld. or reamed to 2918', ran survey. Drilling new hole. Circ. and WOO, orient mud motor. Drld. from 2918' to 2970'. 03-16: Drld., surveyed, and oriented from 2970' to 5360'. 03-17: Drld. from 5360' to 6163', DP torqued up and stuck pipe. Work stuck pipe while pumping high visc. pill, pull up to 360,000#. Work stuck pipe while pumping high visc. pill and rigging up to spot diesel. Work stuck pipe and spot 60 bbls diesel, 16 bbls outside and 44 inside. Work stuck pipe, moving ½ bbl diesel around DC every 15 minutes, have moved up hole 6", jars not working properly, they will go off at 150,000 one time, then after adding right-hand torque they will go off at 250-300,000. Then have to add left-hand torque to get to set. 03-18: Work stuck DP, 50,000# to 360,000#, jars not working, moved dish up hole 6" (total of 1' since starting). Circ. out diesel, pumped 2 hi-visc sweeps (very little recovery). Removed suction valve on one liner since jars not working, work pipe till. RD Kelly hose, wash pipe packing and goose neck. RIH w/string shot to 20' (300 grains), couldn't back-off Kelly, run shots #2 @ 20' (300 grains). Backed-off Kelly. RIH w/homemade 3-prong fish hook on ½" tbg. Retrieved DP screen from top of fish. PU jt of HWDP. Screw into top Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (lO,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-18 (cont'd.): of fish and torque up. Work torque out of DP & RIH w/free it, worked pipe and found jars to be free and 1st DC 50% free. Bottom of jars @ 5972'. RIH w/600 grain shot, attempted to back off at 5972' w/rounds torque, didn't back-off. RIH w/ 300 grain shot, attempted to back-off at 5972' w/7 rounds torque. Didn't back-off, POOH w/2nd shot. 03-19: POOH w/2nd shot, backed out jt of HWDP at surface (came loose from 2nd shot). PU Kelly, torqued up Kelly and worked DP. Backed off at 5938' w/6½ rounds of torque and 700 grain shot. Left 4½" IF box looking up. POOH w/wireline. RD Gearhart. POOH laying down 19.50# E DP (10 its bent). Stand back 48 jts HWDP and found communication between conductor and cellar. WO Halliburton to cement backside. Cement backside of 13 3/8" conductor w/163 sks of Permafrost "C" cement @ 15.6 ppg down 50' of 2" tbg. Cement in place. WO cement, NU Kelly hose, gooseneck, & swivel packing strap 25.60# G DP. Cmt 100'. Drlg line and WO cement. WO cement, PU make up and stand back 2 standard 8" collars. WO cement and make up fishing tools. RIH w/fishing tools and DC. pu 2 jts DP, POOH w/DC & fishing tools (still have communication around 13 3/8" conductor). WO Halliburton to do 2nd conductor job. 03-20: WO Halliburton, RIH w/1 std. DP, cemented 13 3/8" conductor annulus w/222 sks of Permafrost "C" cmt. mixed @ 16-18 ppg. WOC. RIH w/bit and drlg 50' cement from 90' to 140'. POOH. PU fishing tools. RIH. Circ. @ 2150'. RIH to 3425', Hit bridge @ 3425'. Attempt to circ. & unplug pipe, unable to unplug pipe. POOH w/fishing tools (wet string) unplug 70' of gravel packed fishing tools. PU bit & BHA # 5. 03-21: Make up BHA. Clean gravel out of connection. TIH to 1300'. Bit plugged. TOOH. Break off bit. Circ. through drill collars. PU bit. TIH. Brk. circ. each 10 stands. TIH to 2180'. TIH to 2597'. Break circ. Circ. btms up. Wash and rotate from 2707' to 2863'. Unable to RIH w/o rotating. Wash and rotate from 2863' to 3392'. Unable to RIH w/o rotating. TIH from 3392' to 3467'. Wash and rotate from 3467' to 3958'. Unable to RIH w/o rotating. TIH from 3958' to 4612'. Circ. @ 4612' btms up. Wash and rotate from 4612' to 5330'. Trying to pack off @ 5330'. Wash and rotate from 5330' to 5935'. Unable to RIH w/o rotating. Tag top of fish @ 5935'. -2- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (10,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-22: Circ. & clean hole @ top of fish & pump pill. Trip out. Tight spots from 3069' to 2510' & 2120' to 1900'. Pull pipe slowly to prevent swabbing. LD fishing tools that were stood back in derrick. TIH. PU DP to cmt., plug back. Brk. circ. @ 2200'. DP plugged @ 5980'. Clear DP & RU cmt. head. Set 220'± of cmt. plug, 16.2 ppg, 46 bbls. 237 sks cmt. Class G w/2% CaC1 & 1% CFR-2. Displace w/rig pumps. Cmt. in place. POH 10 stds & circ. btms. up & POH laying down extra DP. PU BHA to test & polish plug. RIH SLM. Fill pipe @ 3694'. Frozen stand pipe. Rig crew thawing. 03-23: Thaw frozen stand pipe. Trip from 3694' to 5465'. Wash from 5465' to 5668' (tag top of plug). Drill from 5668' to 5696' (polish top of plug). Circ. & trip from 5696' to surface (LD steel BHA). Make up BHA & orient and test, service MWD & test w/mud. Trip from surface to 5696'. Orient & drlg from 5696' to 5705' (side wall sticking 25,000 lbs. drag). Drlg w/Navidrill from 5705' to 5795'. 03-24: Drlg w/Navidrill from 5795' to 5888'. Trip from 5888' for BHA change & change BHA. Trip to 5625'. Tight spot & 2521'. Ream from 5625' to 5888' (ream out Navidrill run). Drlg from 5888' to 6109' & wire line survey. Trip from 6109'. BHA change (too rapid build). Trip to 6109'. Tight spot 2540'-2910'. No fill. Drlg. from 6109' to 6206'. 03-25: Drlg from 6206' to 6626'. Reaming each connection & wireline surveys, short tripping from 6626' to 5650'. No excessive drag. Circ. btms up. Pump down survey - dropped. POH from 6626'. Strap out. Tight hole @ 2410'-2790'. Tight hole from 1091' to 667'. Retrieve survey. Stand BHA in derrick. RU csg. crew. Run csg. 9 5/8", K-55 36# btrs. 03-26: Run csg. 9 5/8" 36# K-55 btrs, 167 jts to 6603'. Lost no returns while running @ 45 sec. per joint drop (float shoe @ 6603'; float collar @ 6523'). Picked up landing jnt & broke circ. RU Halliburton. Circ. inside volume & outside volume +; no loss of returns (loaded head & tested surface lines to 3000 psi). Pump 40 bbls Sepeolite spacer 11 ppg followed by 912 bbls 12.3 ppg Permafrost "E" cmt. @ 7 bbl/min; 56 bbls of 15.8 ppg Class G cmt. w/3% salt & 1% CFR-2 @ 4 bbl/min. Dropped top plug. Pumped 5 bbl H 0 & displaced with 499 bbls 9.4+ ppg drilling mud. Bumped plug to 25~ psi. Cmt in place. Floats held. Cmt. returns to surface (cmt. set up @ HGR & 100 bbls excess was forced into formation @ 1500 psi until job was complete. LD landing jnt & RD Halliburton. ND diverter system. NU speed head FMC. NU 13 5/8 5000 BOP's. RU to test BOPE & test BOP's. -3- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (10,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 03-27: Test BOPE, upper rams, blind rams, BTM rams, stack & valves, HCR's, choke manifold, Kelly cocks, floor valve, inside BOP to 500 & 5000 psi. Test hydril to 350 & 3500 psi, functional test accumulate. Install wear ring. LD 12 1/4 BHA & PU 8 1/2 BHA & test MWD w/fluid. Cut drlg line. TIH w/DP. LD 26# pipe (picked up for f~shing job). Pick up 19.5# pipe & strap. Wash & clean out to 6520' (top of plug). Test csg. to 1500 psi - test OK. Drlg. cmt. & float equipment & work through shoe. Drlg. from 6626' to 6690'. Circ. hole clean & pull formation. Competency test to 12.0 ppg @ 4700± TVD - 6690' M.D. Drlg from 6690' to 7000'. 03-38: Drlg from 7000' M.D. to 7382' MLD. POH. Change BHA. Orient Navidrill & MWD. RIH to 7382'. No fill. Drlg from 7382' to 8190'. 03-29: Drlg. & surveys from 8190' to 9371' w/navigational control. 03-30: Drlg from 9371' to 10,240'. 03-31: Drlg. from 10,240' to 10,669'. Repair rotary chain (pull 2 stds. recip, pipe & circ. interm, until repairs completed). Drlg from 10,669' to 10,696' (increasing torque, penetration slowed). Pump pill. Survey & POH from 10,696' - SLM. 04-01: POOH for bit change. Change BHA. LD Navidrill, MWD. PU conv. assby. RIH. Cut drlg line & break in bit and ream from 10,620' to 10,696'. Drill from 10,696' to 10,881'. Circ. for short trip. Short trip from 10,881' to 10,470'. Circ. hole clean & drop survey @ 10,840' 54° N24.5W. POH for logs from 10,881' to surface & retrieve survey. RU Shclumberger for open hole logs & RIH w/logs. 04-02: Logging w/Schlumberger. DIL from 10,864' to 6607'. LDT from 10,834' to 9600'. CNL from 10,813' to 9600'. CAL from 10,834' to 6607' & RD loggers. TIH slowly. Lost returns @ 3590'. Re-establish circ. @ 150 psi 1 1/2 bbls/min. Brought rate up to 7.0 bbls/min. No loss. Broke circ. @ 6553'. No loss. Lost returns @ 8053'. Broke circ. and re-establish normal rate slowly - 7 bbls/min. Broke circ. @ 8990'. Broke circ. @ 9920'. Trip in to 10,860'. Wash to bottom @ 10,881'. No increase in drag on trip in. Unable to pick up without pack off problems & extra drag. Laye one jnt down & washed pipe & picked up rate on pump to 70 bbls/min. Cleaned up hole & thinnned mud. Short trip from 10,881' to 9900'. Hole pulling tight. 04-03: Short trip from 10,881' to 9900'. Tight from 10,737' to 10,587'. Circ. btms up & mix pill. POH, laying down DP. Prepared to 'ream to btm if tight. LD 26 jnts. Tight from 10,520' to 10,350'. Pulled to 10,055'. Ream from 10,160' to 10,881' until each jnt worked freely. Circ. hole clean & pump pill for trip. POH, LD DP, pulling slow through tight area. No extra drag. Continue to LD DP & B~A.~ ~.- -4- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (10,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 04-03 (cont'd): Change rams to 7" & pull wear ring. RU csg crew & run 7" 26# L-80 btrs. 04-04: Finished running 7" 26# L-80 btrs. Csg. (total 275 its) shoe @ 10,870'. FC @ 10,790', ECP #1 @ 10,586', ECP #2 @ 10,560', Marker jt @ 10,298'. Full returns. Circ. 7" csg., make up Halliburton cmt head. Circ. & WO defoamer for spacer. Pump 50 bbls of Dowell 3000 spacer, 271 sks of Class "G" w/l% CFR-2 & 0.3% Halad-24. Dropped plug. Displaced w/435 bbls of 10.2 ppg BR-CL. Bumped plug to 3500 psi, inflated pkrs. Csg. wouldn't hold pressure. Full returns. Take on brine, back out landing it, RD csg crew. RU Dresser & PU tools. RIH, tool malfunctioned. POOH w/wireline. Running GR-CCL and gyro. 04-05: Finished running GR-CCL and gyro from 10,700' to 0'. Pressured up on csg, failed to test. RIH w/BP. Failed to set, POOH w/BP, firing head wet, RIH w/BP set @ 10,772'. POOH w/wireline. RD Dresser. RU tbg. tools, test csg to 2500#, bled to 1300#, hold for 15 min. Test 3 1/2" rams to 3000 psi. Test hydril to 2000 psi. PU Vann guns, pker & test tools. Run 300 jts of 3 1/4" 9.5# tbg. RU Dresser, RIH w/GR-CCL log. Found tbg 4' high. POOH, RD Dresser, set pkr @ 10,330'. Pressure up back side to 2000 psi. Opened LPR valve, dropped bar, perforated. 672 shotes total. Perforated w/200' of water cushion, flow well 20 min. 04-06: Opened APR valve, reversed out 35 bbls of oil & gas. POOH w/tbg, after releasing pkr. Well started heading brine & gas. Shut-in w/no pressure, bled off gas. Monitor well (filling hole as gas migrated to surface) and mixed brine. RIH w/tbg. Circ. btms up (gas and oil). POOH to last stand. Monitor well until gas started to die down. LD Halliburton tools and Vann guns. RU Dresser. Run junk basket and bauge ring from 0' to 10,557'. POOH w/GR. Had to work GR down from 9500' to 10,557' (setting down & pulling tight) (GR 6.125"). PU BOT pkr (2-B). RIH set pkr @ 10,537'. POOH, RD Dresser. 04-07: RIH w/seal assembly, blast joints, BOT PKR & PBR, gas lift mandrels and 269 jts 3 1/2" 9.2# L-80 btrs. Work on SCR and restart engines. RIH w/SSSV & control line. Test control line to 5000 handling. RIH w/60 jts of 3 1/2" 7.2#, L-80. Taking 1 1/2 bbls of brine per hour to keep the hole full. Attempt to stab-in lower pkr w/seal assembly, working and rotating the pipe. RU Camco to POOH w/control line. Mix brine, clean jts (trip and suction) take on 80 bbls of brine. POOH w/44 jts tbg and control line. -5- K~paruk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.9- CONFIDENTIAL (10,881'-Kuparuk River) AFE 10-61-1105 API No. 50-029-21299. Ak. Permit No. 85-36. Elevation: 52' KB. Location: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, Umiat Meridian 04-08: Cut drlg line. POOH w/3 1/2" tbg, GLM, PKR and seal assembly. LD bullet nose seal assembly, make up mule shoe and install two centralizers on tbg. RIH w/29 jts of 3 1/2", 9.2#, L-80 btrs. tbg to 10,549.73 (bottom pkr tbg. depth). Ran communication test (no communication). Dropped ball, set top pkr @ 10,233.65 w/2900#. Sheared. Shear out sub, PU 40,000# sheared PBR. PU and space out tbg, NU control line and install tbg. hanger. Dispose of fluid in suction pit. Pumped 100 bbls diesel down tbg. Circ. 10 bbls into annulus, landed tbg, tested backside to 1500#. LD landing jt and ND. 04-09: Lay down landing joint, install BPV. Change rams, ND flow line and bell nipple. ND BOP's, dispose of fluid in mud tanks, clean oil out of mud tanks. NU tree, test bottom ring gasket to 5000#, tested tbg hanger seals to 5000#. Did not test tree, could not bleed off. Will test tree after rig moves off. Pumped out cellar and RELEASE RIG. -6- Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 5, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Production Profile Logs for Wells B-10; B-Ii; C-9; C-13; C-14; C-15; C-16 · Included with this cover letter are the logs and related pressure data for production profile work completed at Milne Point prior to shutdown. This information is submitted to the State as per Rule 9 of the Kuparuk River Field Rules. If you should have any questions or comments, please contact Mr. Don Girdler at 564-7637. Division Manager DRG/vv Oil & Gas Co,s. Commission Anchgrage Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Mi!ne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Miine Point Unit. There are 19 ac:ive and 5 inactive production wells at Milne Point. ACTIVE: B-3, B-'^, B-.o, , ~.~. ~ B-9 B-10, B-il, B-13, B-15, B-16, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, ~_~_., ~_o~. C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. t~. ~ ?~' . [' ?~L~' ACTIVE: B-8, B-12, B-14, B-l.7, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. ~ ~ = you have any questions on the shutdow-m procedure please contact Don Girdler at 564-7637. Yours very truly, /~v ~sion Manager ',,.,,; "' STATE OF ALASKA ~ ALASK. .)IL AND GAS CONSERVATION COMM ,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well © Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~-J Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 4166' FNL, 2428' FEL, Sec. At top of productive interval 3620' FNL, 1091' FEL, Sec. At effective depth N/A At total depth 3279' FNL, 1294' FEL, Sec. 10, T13N, R10E, U.M. 4, T13N, R10E, U.M. 4, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 59' KB 6. Unit or Property name Milne Point Unit 7. Well number C-9 8. Permit number 85-36 9. APl number 50-- 029-21299 10. Pool Kuparuk River feet 11. Present well condition summary Total depth: measured true vertical 10811 feet Plugs (measured) 7308 feet Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80 ' 16" To Surface 115 ' 115 ' Surface 6267' 9 5/8" 2875 Sxs 6303' 4549' Intermediate Production 10836' 7" 271 Sxs 10870' 7301' Liner Perforation depth: measured 10646'-80'; 10609'-29'; 10454'-64'; 10498'-502'; 10392'-406' true vertical 7172'-91'; 7150'-63'; 7059'-65'; 7085'-87'; 7022'-30' Tubing (size, grade and measured depth) 3~"2 , L-80, 10573' Packers andSSSV(typeand measured~e~tl~)SCSSV @ 1917'; Ret. Pkr. @ 10249'; Perm. Pkr. @ 10550 12.Attachments Description summary of proposal ,~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver 15. I hereby_cruCify that the foregoing is true and correct to the best of my knowledge Commission Use Only Date Conditions of approval Notify commission so representative may witness ! Approval No. [] Plug integrity [] BOP Test [] Location clearance 7/~ Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in'triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201C Street, Suite 200, Anchorage, Alaska 4. Location of Well 4166' 99503 FNL, 2428' FEL, Sec. 10, T13N, RiOE, U.M. 7. Permit No. 85-36 8. APl Number 50- 029-21299 9. Unit or Lease Name Milne Point Unit 10. Well Number C-9 11. Field and Pool Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I 47434 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-2-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge, The space be~d~f'for Commission use - Conditions ~f//APproval, if any: Date By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-$0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ; /' SIMF "N LAGOON SCALE IN ~,LES CO N OCO MILN£ POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO.ORDINATE:S ARE ,.~NF' 4. ALL GEODETIC POSITIONS AR[ BASED ON N.A.D. 19Z7. OFFSETS TO SECTION LINES ARE COMPUTED BASED -ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. LOCATED WITHIN SECT. 10, T 13 N, RIOE, ULM.,AK. LOCATION IN SECTION STATE PLANE CO-BROS. GEODETIC POSITION ~ R 0 ~ S' [ m ~ N EASTINGS LATITUDE LONGITUDE 0ATE ~ BOOK !___c-I I ,fSS' 22,e' ====--'= 6,029,4~0.20 I . ~8,2o~.~? ~29'27.868"~. 14~31'27. O~S"W' ~ 6.1,8~ J.B.S. 22-8S f229' ~sg' ' C ~ I 1395'. 2326' 6,0~,677.~ ~ 6 ~ 665', 2289 6 ,028,947. e0 ~8,17~. 18 ~°29'~ .929~ 149o51' 28.~7"W. I " " " 0°29'24 055~ 149°~m' 2~ ~Rn"~~ . C-9 Ill 4' 2428' 6 ,029 ,39, ~ f 558 ,03, 82 ~o , - j o . - ...... I ~'~ ' · C'10 I 894' 2~60' 6,029, '76.48 ~ 558, 101 82 ; 70°2~' ........ J ---=-- - ' ' J ' . CERTIFICATE OF SURVEYOR aEG~STE~D AND LICENSED TO LOC~T,O. Su~v[t -*o~ ~. ~Y Su~6,vlSlOti ~'aD T.~T ALL a~O OT"E~ OETGIL~ ~RE COH~ECT 'C' PA D Surveyed for CONOCO SCALE ' I SHEEr : 4 ,-. ,oo. , o, E~G~NEEH'S ......... COulaENTS : Cons?'L%mmissio c o) Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are the Sundry Notices for the Milne Point C-3, C-7, C-8, and C-9 wells. Conoco intends to stimulate the above referenced wells. If you have any questions, please call Don Girdler at 564-7637. Very ~ruly yours, ~ R. J. Francis Manager-Engineering DRG/vv cc: MP C-3, C-7, C-8, C-9 Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. CONOCO, ]:NC. 85-36 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21299 4. Location of Well 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB J A.DL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point C-9 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well is proposed for a 12-3 mud acid stimulation treatment to improve the productivity from the Middle Kuparuk formation. The 12-3 mud acid treatment has been successful on the Middle Kuparuk formation in offset wells. Alaska 0il & Gus C..':~ ~:. ",,, 't ,~.o, , (,( ,,,1 .... ,,,h)l 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~. ~, ~/';~:~. /"'~/~,) Title Sr. Production The space below for Commission use Engineer Date 10-28-85 Conditions of APproval, if any: ORIGINAL SIGNED BY IOH~!IE C. SMITII Approved by. COMMISSIONER Approved C~ov R~turn~d By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76(X) August. 28, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr, Chatterton: On August 19, 1985, we sent you the "Well Completion" forms #10-407 for Conoco's Mtlne Point Unit wells No. C-7, C-9, C-II, C-12, C-13, C-14, C-15, and C-16. On these forms, the true vertical depths at TD were inadvertently left off. The following data should be added to the submitted forms: WELL NO. TD (MEASURED DEPTH) TD (TRUE VERTICAL DEPTH) C-7 9,940' 7,429' C-9 10,881' 7,308' C-11 8,990' 7,527' C-13 8,270' 7,313' We regret any inconvenience this may have caused you. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, R. J. Francis Manager - Engineering John R. Kemp Conoco Inc. Manager of Alaskan Operations 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-ii, C-12, C-13, C-14, C-15, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R Kemp~ ~laskan Operations KJS 5/vv RECEIVED AUG 2 0 1985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA .... ALASKA t..~ AND GAS CONSERVATION CO,..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED~[~ ABANDONED [] SERVICE [] ...... 2. Name of Operator 7. Permit Number Conoco Inc. 85-36 ,., 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-21299 4. Location of well at surface 9. Unit or Lease Name 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 3620' FNL, 1091' FEL, Sec. 4, T13N, R10E, U.M. C No. 9 At Total Depth 11. Field and Pool 3279' FNL, 1294' FEL, Sec. 4, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 52' KB ADL 47434 . 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 3-12-85 4-1-85 4-8-85 N/A feet MSt 1 17. Total Depth (MD+TVD) 'iS.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thicl~ness of Permafrost 10,881' ~?~ 10,772(7245' TVD) YES]~ No i--II 1917 feetMD 1800+ 22. Type Electric or Other Logs Run D IL-LDT-CNL-CAL-GR-CCL-Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 0' 103' Plug 46 bbls Class G ~ ' 163sx Permafrost C,2~.2sx Permafrost 9 5/8" 36# K-55 0' 6303' 12¼" 2600 sx Permafrost E 275 sx Class G 7~'~' 26# L-80 0' 10870' 82" - ~. 271 sx Class G 24. Perforations Open to ProductiOn (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10392'-10406' (Middle Kup) 12 spf,120°phasJn~ 3~".9.2# ~L-80 10.573' 10;249' 10.550' 10498'-10502' (L-9) 12spf,120° phasing 26. ACID, FRACTURE, CEMENTSQOEEZE, ETC. 10454'-10464' (L-8) 12spf,120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10646'-10680' (LK-2) 12spf,120° phasing 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGASJOILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cDr'r) Press. 24-HOUR RATE 28. CDR E DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ECEI,V[D Alaska 0il & Gas C0ns~ O0mmiss 0 Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KA 4,890' 3,760' MA 5,386' 4,046' NA 5,869' 4,324' OA 6,170' 4,483' T/Kup. Interval 10,153' 6,877' Middle Kuparuk 10,392 ' 7,022 ' Laminated Zone 10,407 ' 7,031 ' Lower Kuparuk 10,608' 7,150' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ), ~ Title PI~J. ~/1~'/I,(" Date ~-'~, ,1~=~' .__ 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 supplemental 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 Eastman/ Whipstock l A PETROLANE COMPANY DIRECTIONAL CONOCO, INC. COMPANY "' ....; :' '~:':: : ...... ':'"'Pad C, Well Number: WELL NAME · Milne Point, North Slope, Alaska LOCATI ON JOB NUMBER A0485G0211 TYPE OF SURVEY Gyro Multi-ShO~Ec~i\/.~!D DATE 04 -APR- 85 SURVEY BY B JAHN OFFICE Anchorage, Alaska Eastm. an (907) 349-4617 Whtpstock ~. o. Box 4-1970/Anchorage, Alaska 99509-1970 A PETREZANE COMPANY Date: April 23, 1985 Conoco, Inc. : ............. 3201 C. Street ........ S~ite 200 Anchorage, Alaska ....... 995.03 · Well Number: Pad C, Well No: 9 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 04-APR-85 Method of Computation:' Radius of Curvature' Surveyor: B JAHN Job Number: A0485G0211 Atten: Mr. Dan RobertsOn Dear Mr. Robertson: We are enclosing the original' and one copy of the Gyro Multi- Shot survey run on the above mentioned well. To date, the following distribution has been-accomplished: A. 1 copy delivered to drilling for in-house distribution. B. 9 copies noted for oil company representa'tives. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock:'and look forward tO'being of service in the future. TOM J ....... District Technical CoordinatOr cc/file cc: L.A. Dinges - Offshore Exploration Conoco O.G. Kiel- P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco William Van Alen- Alaska Oil and Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Eng~.~trom - Chevron U.S.A., Inc. Concord Office Dale Bossert -Champlin Petroleum Co. C.E. Seery, Jr. - Reading and Bates Petroleum Co. Neil Buttram - Cities S~rvice Oil and Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide CONOCO, INC PAD C:, WELL NO: ~ GMS ._lOB NO: AO485G0211 MILNE F'T., NORTH SLOPE, ALASKA GMS, 0-10700 MD, ~:;URVEYOR: B dAHN, DATE RUN: 04,APR-85 GYRO NO: 2':.'-,1, CAMERA NO: 07'.~¢, ':~¢0 BEG A/U NO: 1566 FORES I GHT: .=,._ 1 47 1 .-'F.,'W VERTICAL SECTION CALCULATED IN PLANE L-iF F'ROF'OSAI.. DIRECTION: N ::""::2: BEG. 5 MIN. W RECORI] OF SURVEY RADIU:_=; OF CURVATURE METHOD _ Eastman / f':r-~NOCO, INC · ' . .; .... :.; i...'. COMPUTATION .. F'RGE i',!0. F'AF'I C:.~ WELL Nl_-I." '.P GMS dOB NO: AO4:::5G0211 I l..::.!j~lf?7:i?: .ll '" TIME DATE M I LNE F'T , NriRTH '._:;LOF'E, AI.A'.S;KA 12" 16: 36 .-,,-, ' -' . . . , TRUE · MEA:=:UREf"I DRIFT i')EPTH FEET I]RIFT COURSE VERTICAL VERTICAL SI_IBSEA R E C T A N G U L A R C L 0 S U R E I]OF:;LE AN~]LE~ DIREF:TION I...ENG'FH I]EF'TH SECTION TVD C 0 0 R I: I N A T E S DI.:.,TAN...E'-' P DIRECTION SEVERI D M I: M FEET FEET FEET FEET FEET FEET D M I]G/10( Dim 100. 200. :':: C)C). 400. 0 0 0 0 O. 0. O0 O. O0 -52. O0 0:2:0 S 4.2 0 W 100. 100.00 -0.11 48.00 0 4.5 S 6 0 W 1 O0. 1 '.:¢'P. ':.-'¢'F* -0.70 147. ':?'P 0 :.7:0 S 41 0 E 100. 2'.-79. '.-79 - 1.72 247. '.-79 0 :.7::0 ::~_ 8:':: o. E 100. ._'::':,'-'?..., 9:::. _ -'-:,...., 4/.,_ :.7:47. '-?:::. _ 50¢). 600. 7¢)0. 8(:)0. 90¢). 1000. 1200. 1 :.7:00. 1400· 0 4._": N 76 0 E 0 :.7:¢) N 1'2 0 E 1 0 N :_::4. 0 W 4 1= I',! ='-' --' .-'.,:. 0 W 7 15 I',1 42 0 W 10 45 N 41 0 W 1:'-': 45 N :2:7 0 W 16 0 I',.I :3:3 0 W l:E: 45 N :'::7 0 W 21 :.7.:0 N 40 0 W 1 C)0. 499.9:5: -3, 00 447.98 100, 599.97 -2.77 54.7 · 97 100. 699.96 -1.59 647.96 100. 799.84 2.91 747.84 100. 899.33 12.62 847.33 100. 998.08 2:--,:. 09 946.08 100. 1095.79 49.19 1043· 79 100. 11':72.44 74.78 1140.44 10¢). 1287.87 104.55 12:'::5.87 100. 1381.75 13:::. 80 13'29.75 21.22 N. 37.70 N 58.07 N ¢:1.76 N 108.68 iq ':' 6.5 ~' 4:3 c, 1 E 1.91. o'-' : 2.14 E · 0.6/:, :--: 1.90 E ~..:.,_-, N 1 21 W 9.F,O N o ~.lo W · _ . ' m_~ # ,_ 1~ ~',,~ '--'mm 0., W '--"-' 24 W 47 '-"/, W 66. C)4 W ~ o7 46 W z., :37 ._,':' 48 2:.7: I.': 2.01 S 7C) 59 E 2, 94 N 24 t7 W 12.77 N 41 54 W 28.41 N 41 4.1 W 49.61 N 4C) 32 W 75.25 Iq 39 30 W 105. ii i) N 38 56 W 139.50 N :3:3 4'.-? 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N :=: :=: ~_ :=: W 1. 1 C, 0.50 PRO._IECTED TO 10740-10:3::31 1¢)740. 54 4..5 N 31 0 W 10 ::::=-: 1 Pi 0' ..... 4 45 N :=':1 W 4- 0. 7 2 2 6.16 7:315. :2:7 717 4.. 16 6, .)/=,,:,. 7 5 N 4 ('). :::_/-,_. 21 W 7:316 .21 N ._,':'._,':' 5'7 W 141. 73c)7.5:2: 74:':'.c). 44 7'255.5:2: /=. 167.4.5 N 4145.52 W 74:-:-: 1.21 N :3:=: 54 W /~ . ~... '(_) (.) 0.00 FINAL C:LO:E;URE - DIRECTION: D I .C;TANCE: N :':::=d I]EGS 54 MINS 27 SEC:S W' 74:=:1.21 FEET - Eastman Whipstock l A F~:TRt'}~.,ANE OOMPANY CONOCO, INC F'A[~ C, WELL NO: 'F~ GMS ._lOB NO: AO485G0211 MILNE PT., NORTH SLOPE, ALASKA GMF-~, 0-1070('~ MD, SURVEYOR: B dAHN~ DATE RUN~' 04-APR-85 GYRO NO: 271, CAMERA PlO: 079, 90 BEG A/U NO: 1566 FF~RES I Gl-IT:..,c'.:;... 1 47 19W ], · . RECORD OF INTERPOLATED SURVEY Eastman/ F:nNnC~"'~, I iqF': I::'AD F:, I/¢F'LL I',10: 9 61"i:.=..; I"ITLNE P¥,,, NOR-I"H SLFiF'E, ALASKA MEASI_IRED F~EF'TH FEET TRUE VERT I CAI_ DEPTH FEET ,_lOB NO: A04:::5GO'211 SI_lB'..:: E A VER'T' I CAI... DEF'TH FEET R E C T A N G LI L A R r": n 0 R D I N A T E._, '=' FEET COMPUTAT I ON T I ME DATE -),-, ._ 12: 18: (..=. 23--AF"R ..... C L 0._. '=' LI R E D I.=.TAN _.E II I R EC'I" I ON FEET D P'i PAGE NO. 100.00 '.'200.01 :2:00.01 400.02 500.02 600.0:3 700.04 800. 1/:., 700.68 1001. ? 6 100. O0 200.00 :_--:0 c~. o c~ 40o. 00 500,. 0 ¢7 600.00 700.00 800.00 900.00 1000.00 4:_=:. O0 14:3.00 24:3.00 34, :'::. 00 44.8.00 548.00 648.0('7 748.00 84:3.00 948. (70 0.32 S 0.29 W 1.:_--:0 S 0.73 W 2.31 S 0.41 W ,.:' 72 S 0..'34 E 2.65 :E.: 1.4:3 E ..... :, 2.14 E O' / ~ c- . . . ,-,.'",,... 1,90 E .,...'":' 69 N 1 ,.,...-.":'"' W '::.'.~ '::"i'"' N ,=,'-' 60. 1,4 · . ... ,.~ . 21.54 N 19.15 W 0.44 S 42 0 W 1,49 ._,':' 2e. 11 W 2.:>'.:5 S 10 2 W 2.74 S 7 1:.']: E :3.01 8 .' :.,:~ ._.c, 18 E · -I I-I -- · -..:.7 ':' 48 ":":' 2.01 S 71 0 E 2.95 N 24. 24 W 12.87 N 41 54- W 28, ',--..: 2 N 41:3',:: W 110.4 '-'= - . .", ._! 1z.'-' 07. o.. :.3 1:2:12.93 14-19.7 4 · J .-' c,. 1100. O0 120 (]7.00 1300. O0 1400.00 1500. O0 1048. O0 1148. (.'70 1248.00 1348.00 144,8.00 38.59 N 32.92 W 59.94 N 49.31 W 85.24 N 68.:$:1 W 114.26 N ~92.48 W 14._,,._4 Iq 121 14 W 50,7:2: lq 40 2:3 W 77.6 :? N 3'ii:' ',T::/_.. W 109 54. N ':":' ~'i = .............. , W 14-/.00 N 38 59 W 1::.:9.36 N :i.:9 4.6 W 16 :'::'?. 3 (] 175',2.6,4 1 :::69.24 19'? 0.43 '2114.. 75: 2240.07 2:2: A 7. '? 9 ' 2502.26 2645.9:-: 2791.71 1600.00 1700.00 1800.00 1900. O0 2000.00 · .- 100.00 2200.00 2:30 n. 0('~ 24-C) 0.00 .-' ._,t.)(.). 0 0 1548.00 1648. O0 174 :ii:. 00 1848. O0 1'P48.00 204:-=:. 00 2148.00 2248. OQ 2:2:4 ¢, ,:,. 00 2448.00 180.46 N 153.92 W 220.57 N 188.99 W 266.42 N 2:7::7.46 W 31:3.94 N 271.24 W :j:7:--:. 18 N :315.26 W 441.46 N 356.52 W 50'?. 55 Ix! .397. '? :.--.: W 586.29 N 44.4.09 W 674.89 N 496.99 W 7,_"'.6.3:9 N 550.54 W 2:2:7. 18 N 40 28 W :2'? 0,, 4. 6hi 4,n, .:,'-'._, '= W 350,32 Iq 4() 29 W 418.68 N 40 '2::: W 4.92 3:5 N ':'"-" z~.,..-./ W . . ...~...- , . 567.45 N :38 55 W 64.6.5..5-; N 37 .59 W 7..:,.::,. 4.9 N :'::7 9 W 8:38.13 N :36 22 W 94:3.,_._,/-,":' N ._-,'-'._,':"- 42 t.,..t 29:--:9. 17 :30?5. ?0 :326:3.05 :2:4:30.29 2597.14 2 600. (170 2700.00 2800.00 '.P'?(') 0. C) 0 :3000. o 0 254:--:. 0(] · --* /. J-'l ..::,'", 4,:,. 2748.00 2:348.00 294 :'-":. 0 (.'7 ,:,._,;. 1 ::: N /-, c76.44- W 96c:,,75 N 671.4.5 W 107:3.20 N 744.21 W 11:::/'_-.. 1:_:: N 81/_-.. 4-3 W 12 c./:E:. 27 N '-'"-' .... -7~'.7 W · .-, ,.:, ,:-, ~ . 051.64 Ix! :35 1:3 W 172.1:3 Iq 34 57 W 1305,,99 N :_--:4 44 W 4:39.95 Iq :134 22 W 573.4/_, N :34 24 W Eastman/ k Whipstock A ,~_'TROIANE COMPANY F:ONF~CO, I I',.IC F'AI] C, WELL.. NO: 9 GMS; MILNE PT,, NnRTH SLOPE, ALASKA ,_lOB NO: A ]4,=,._,L',OZ 1 I TRUE SLIBSEA MEASURED VERT I CAI.. VERT l CAL. DEPTH DEPTH DEPTH FEET FEET FEE]' :3762.2(i) 3100. O0 3048. O0 :z:,.?; '.76./-..,5 3200.00 .2:14 ::.3.00 4092.45 3:300.00 :3248.00 42,'_'-,4.48 3400.00 334F,:. O0 4.43'..7;. 25 3500.00 344.'8. c)0 /[613.55 3600.00 3548.00 4- 786...':,'-' ~'-':3700 .00 :'::/., 48.00 , -- ." · .,k...-- .... '--'-- ~--I 4 9 ~i'-? '.--' ~:; :':: F.:c') ¢), 0 (') ..:, 7 4. ,:,. 0 0 51:32.0::: 3700.00 3848.00 5305.67 4000.00 3'748.00 '.5479, 2:3 4100.00 4048.00 ':':"~._ ,_,._ .-' ./- ~'-' /.:,/.:, 4200. (')0 4.14-:E:, 00 .-,~ ,'..:,"" 2/-,_. O. 9. 4 :":: 00.. (') (') 4248, ()0 /.,006.62 4400.00 4:2:48.00 6204.2I 450c). 00 4448.00 6404. 16 4600.00 4548. O0 /-,AA2 '-'= .... .... .,:.._, 4. 700 () 0 ,,I-/., 4 L.::. 00 /:,7'F,'6.4:2: 480C). 00 4748, 00 6 '? :-':: 1.6 :s: 4-'? 00.00 4 ::-: 4:3. (:)0 71.57 ...../-F, .,--]000 00 4948.00 7:32:3.79 5100.00 504:E:. O0 748.5 · :2:2 5 :-7' 00. 00 5 i 4 F':. 00 7/.,47.66 5300.00 5248. £)0 7810.09 54 C)0.0 CZ) 5:34' 8.00 7'.;',' 72. '.-.-,' 3 .:'=;',.'50 c). C~ ¢) 544 :'::. A 0 ::: 1 :z: 5.77 5/.,00.00 554 :E:. 00 82'?/.,. 5',}:: 5700. 00 5/.,48. 00 :B45S. 21 58C)0.00 57;1-F:. C~0 :E: 617. :31 5':-? 00 · 00 5:348· 00 :::', 775. 77 /., 000. 00 594 :E':. 00 R E C T A N G U L A R C ID 0 R D I N A T E S FEET 1408.64 N '760.13 W 1518.88 hi 10:z:0.06 W 1/.,29.'?:3 N 1101.87 W 174.6.4-2 N 1179.47 W 1864.89 N 1'260.1.5 W 1982.80 N 1340.64 W 20'.:..)?¢. '.".-)3 N 1420.01 W 2216.15 N 14.98.90 W 23:~:3.72 N 1576.65 W .,::.4.._,.",, .-:,o / F,'-' . _ = .... N 1: .... _-,.0::: W 2573.3'? N 1728.53 W 2/-,':* 4 1 '-' N 1 ,:, ) ~. 6'? W . .- . -.D 2812.41 N 1:::80.5'? W 2F;32.4-3 N 1.F;7C). '?'.--; W ::":06:::. i ' · :,Z~. 7.08 N.- ~-' :[ 77.._,':'~-.., W ""'-' '= :,._, N 77 W ..:,..:, 40 · / '= 2'":' .,_ . .5/.. 3-4.80.52 hi 2:'::75,0'F; W 3/_..,08.13 N 24.,'.:,4,,/:,'? W · 2:727 ':;.=, hi ..... · -'... -~._,. 91 W :38::.:7.40 N 2620.::.,'6 W 3'.')42.42 N 2/.,'72.01 W 404:'--:. 44 N ..'7o.-, . .-,='-'~. W 4154.55 N 2,'.Z',:2:5.10 W 4261.0'? hi 2'70/.,.76 W 4:]:66.15 N'2980.96 W - 44,..!:16.':7/'.;~ N :3056.40 W 45/..,8.15 N 31:2:5:.13 W 4665, 84 N :":::..-.' O'F,', 0'.-.-~ W 476:3. ¢) ]. N :--::.2 :'-': 4.. 3 ¢:, W I I I COMPUTAT I ON T I ME ELATE 12: 1,...':' .' 03 23-AF'R '-' '~' PAGE NO. '":; C: L 0._,° U R E 'D I.:.TAN_.E D I RECT I ON FEE'/ D M 1704.73 N 34 17 W 1835.22 N .2:4 9 W 1967.4:3 N 34. 4 W 2107.4.0 N :'.::4 2 W 2250.7:'-: N :34 3 W .,:.. ........, 4.9 N ..:,'-'4 4 W 2534.9:2: N 34 4 W 2/.,75.45 N 34. 4 W 2:.2,1/.,. 3'? N :34 :3 W 2'? 58.25 N :--::B5:ii!: W 3100.03 Iq 3:3 53 W 324 .1.61 N .2:::: 4.'7 W 338:3.24 N 3:3 4-6 W ,:,...,..:',..:,. 26 N .2::3 54 W :370:3.40 N :34 :3 W 387/.,.:37 N :34 10 W 404.7.:30 N :34 1: W 4.21:.-::.6'7 N 34 19 W ,,~, 1."**~ · .~ ,' 4.'-,/., :. ~':'; N :"": 420 W 4514..2:4 N .2:4 20 W 4646, '? 9 N 3.4 ',--.': 0 W 477:3, :::4 hi :2: 4. 2 (-) W 4901.7:2: N :']4 I'? W ~ (] % cl . .... · -...72 bt :3 -!. 19 W · _, 15:-.]. 2:3 N 3'1- 18 .bi F,' .';,,:, 6 7.1. N :34- 19 W 5412· 54- N 3:4 2:-: W = [ "~1 I:Jl :"~: /'1 Ix[ .'2:,i- 27 W ._1 ._1 ._~ ..~ · - - 5/.,62. ::39 N 34 31 W · .,/,- .... ./.. 1 I'q .2:-I- :35 W - Eastman / CONOCO, INC PAD C:, WELL NO: ~.~ GMS MILNE PT.., NORTH SLOF'E, ALASKA MEASI_IRED I]EPTH FEET TRUE VERTICAl_ DEPTH FEET 6100. O0 6200.00 6:2:00.00 640A. 00 /",500.00 6600, 00 6700. O0 6:2:00.00 6'.~00.00 7000.00 052.'2.'. 67 06?4.71 0867. '? 5 7100. O0 7200.00 7:300. O0 dOB NO: AO48560211 SUBSEA VERTICAL DEPTH FEET 604:_=:. O0 6148.00 624 :':-:. 00 6348. ()0 64.48, 00 6548.00 6648.00 674-8.00 6:--:4::::. 00 6'.:..'4 ::::-:. 00 7048. O0 7148.00 724. 8. C~ 0 R E C T A N G U L A R COORDINATES FEET 485'.-.-,'. 52 N 3354.32 W 4 .'.....:,.._ ._, N 1 :::, 27 W 5048.'?~2 N 34-:.'-';:2. 1'~ W 5147.::::':: N :3545.68 W · '=., ...'-' -~" ".).~, ._,~: ._~'-' Iq ._-,'-' ,_..,' ,..)"' '7....,._"2' ,..~ W 5355.25 N 3670,44 W 546:3,5'?¢ N 3735.54 W 5574.05 N 375)'.~¢.':.75 W 5/_-.86, 27 N :3862.80 W ~ I::.I(') (') .-, .-:, .-, c~ .':, ,::, · .:,.-N 12 W .... ~ . u ."~' .' ",-, u 5'?~L17' 85 N 3'''7''';'6' 17 W 6037'07 N 4067' 1'7 W 6158'32 N 4140'03 W COMF'LITA'F I ON T I ME DATE I 2 : I :2:: 03 23-APR'-E:5 CLOSURE D I STANCE D I RECT I ON FEET D M 5?/04.77 N 34 37 W 6018.48 N 34 37 W 6133.2'P Iq 34:36 W 6250,:::';~ N :34 :'::4 W 6:2:67. th] 0 N :2:4 30 W 647.)2.37 N 34~_. '?/- W 6618.54 N :34 22 W 6746.08 N 34 17 W 6874.22 N :::4 11 W 7005.2:::: Iq :2:4 6 W 7140.75 ,N 34 2 W 727'F~ 2':~'~ N ..... ' ~ :-':: . . .':..:, _ W 7420. '"'/ .~'=' .:,..-, 1'4 :.93 .... , W PAGE NO. Eastman Whipstock ~ t: .. .... ~ ' ' ' .r ~ · , ;.' ,'~j, ' , I ' ; ' ~ ' ' * ' .'" j~L-I~:r ' ;.'.iPAD C. ~ELL 'NO~ ,'~HILNE PT,, NORTH SLOPE , EASTHAN WHIPSTOCK,' ,. ,. , r , ¢. "=~"" ~'"* "'; ' · , : ':"i-r":- 'FINAL ~".~t7.':".* '.., ,- DEPTH 10881 :'T%r ...... NORTH ;..'f ~. - CLOSURE :..~..~'. , . · .. , ~ ' ' , : ' ..... ~ i . .... -,~ '~ ...... "'~' :"~':,-?~ ::~. ':-(':!':~::FX~-':'?.",t' ~:~ : SOALE :.DEPTH ~I~DIOATOR, TVD ~ - " "b . 'f- ~ ~ '~ ~ f ~~- : , ~ ; ' t ~ ~. ,, ;, i.. ' "::"~. ~ , "~"'1 ,-~...,~.4:, ,4..~ · F.t.: .... f..f ~??~"::':" J"i::~f!':"i~'i' '~ ", '" ' ': ~' '" ' '~.-: ",: : ~ ~ ~..~ ' ',.~ ~ .... ~ :!- ' ' ~ ".~'. ~ ' -; ~"~'~' , '~ ': , .' ~ ~ : ~ ~ . . , - ; : .. · ,'" , < i ..... ~' ' ',' ' 'I ' ~,'{ l.i~.~ ' , ~.-~ ~ ' ~ ' ' ~" ::~l'~.. , ,-- t ~ ~':/ ~t~'I ~ , · .~-~-, · CONOCO.' INC ....:-'.[ ..,-, r-.,.-~ :,.T~. i' '~"~'~ ' ' : i '~ ~'"':" .... .~ ..... ~ PAD C. WELL NO~ .9 , OHS .~ "~:,~ , .~, MILNE PT..~ NORTH SLOPE.t ALASKA ... ~-,-.~ · ~ .... f.~:-~.?-~ :-' .-.t,'~.,. ..... ~ '~"~ .... !'~"F' '~'""t,' :.~"': .... · ( ~. ~ · , ~ L,,,'.. . · ~ ~ ' ~ ; ~ ~, · ~ ',~ , ' , ~, ;~ ,. ~ ,. ' ~ . , , . . 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' · ,"" ~ "~ ~ , - , ' ; .... ~ l' ,, ,~; . 4'*'; "~.'' ' ~ ' : ' · ' ' , "~ ' ''.' : ': ~ , . . . '"',,~r~' f'"~:*.~ e.'~:'~ ~ : '"i ' I'-'''; !'''''~ ~'' ', ~,. ~ : , : f....'it ; i '. ..;. Suggested form to ~e-inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: ~-6~' ~~ Date Required Date Received Remarks Com~n Report ~/~ Well His tory--S._,/ Core Ch~ps Core Descr~ptSon Registered Survey P~ Inclination Survey Directional Survey Production Test Reports Log Run , Digitized Data STATE OF ALASKA ' ~' ALASKA~-' L AND GAS CONSERVATION Cr~"MISSION ~ ' ONTHI. Y REPORT ,IF DRILLING AND WORKOVER OPERATIONS./ -' 1. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. Conoco Tnc, 85-36 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21299 4. Location of Well at surface 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 52 ' KB ADL 47434 · · For the Month of July ,19 85 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 9 11. Field and Pool Kuparuk River Field Kuparuk River 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Pumped frac treatment into Lower Kup Formation. Attempted to flow frac sand, produced oil, gas, and broken frac gel. Depth at end of month: 10,881' MD Footage drilled: 0' 13. Casing or liner run and quantities of cement, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run GR-CCL- pressure temp.- Spinner tool from TD 16. DST data, perforating data, shows of H2S, miscellaneous data NONE. Well suspended. Completion report to follow. K L IVI:U \UG 1985 Alaska 0il & Gas Corm. C0mmissio. Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ~' ALASKA ,_ ,L AND GAS CONSERVATION CC,~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-36 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50D29-21299 4. Location of Well SURFACE: 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number C-9 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate ' [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-9 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completion flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-9 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. 14. I hereb~y__g_c~tify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~, z Title The space below for Commission use Conditions of Approval, if any: II!I!t111[ !]1i' /:I~I~IE ~. SMITH Approved by Date By Order of COMMISSIONER the Commission Date 6-17-85 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 Hay 29, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Monthly Report of Drilling and Workover Operations on wells No. B?7, B-8, C-9, C-ll, and C-13. If you have any questions, please call Lynn Alexander at 564-7609. Very truly yours, · Ma°nhn eR Ke~P~~- ~laskan Operations LA/vv le£CEI iI£D ,. :5 1 AI I:. L)i- ALASKA ALASKA OJ,L AND GAS CONSERVATION CO'~MISSION (~ IaONTHLY REPORT' F DRILLING AND WOR..OVER OPERATIONS Workover operation [--~ 7. Permit No. 85-36 1. Drilling wel~:: :2. Name of operator Conoco Inc. 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21299 4. Location of Well at surface 4166' FNL, 2428'FEL, 5. Elevation in fe~ findhT, ate KB, DF, em.) 52'KB Section 10, T13N, RiOE, U.M. 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 9 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. May · 19, 85 12. Deflth at end of month, foot-age driite~i, fishing jobs, directional drilling problems, spud date, remarks None. 13. CasJ~j m ~ine~ run an~ cluan~ities of csma~t. ~esults of pressure tests None. 14. Corir~g ~es~ne anti b~ief descii)tion None. 15. Lcgs run and c~epth where run None. 16. DST data. perforating data, shows of H2S, miscellaneous data None. Well suspended. Completion report to follow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~~ J- f~ ~"2-~,,. TITLE ~.¢~/'/,/,f ~'. A J, ~'"~,) ~", DATE ~ / ~//~¢-.~' NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ~ ~ ~ ~ r- [Jr-/~LA:SKA MONTHL¥ ALASKA OIL AND GAS CONSERVATION MISSION REPOR1 )F DRILLING AND WOh., OVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator Conoco Inc. Address 3201 C Street, Suite 200, Anchorage, AK 99503 Location of Well at surface 4166 ' FNL, 2428' FEL, Section 10, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 47434 52' KB 7. Permit No. 85-36 8. APl Number 50-029-21299 9. Unit or Lease Name Mi lne Point Unit 10. Well No. C No. 9 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of April ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Ream tight spot 10,160' - 10,881' 13. Casing or liner run and quantities of cement, results of pressur9 tests Size Wt. Grade From To 7" 26# L-80 O' 10,870' Cement 271 sks. Class G. Full returns. 14. Coring resume and brief description None 15. Logs run and depth where run Run 1 DIL Neutron-GR LDT-CNL-GR 6607'-10,864' 4600'- 6,584' 9700'-10,834' 1 6. DST data, perforating data, shows of H2S, miscellaneous data .. 10,392' - 10,406'3 10~498' - 10,502'~ ' 10,454' - 10,464'~ 12JSPF 10,-646' - 10,680~7 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Rev. 7-1-80 Submit in duplicate Conoco~ lnc. 3201 "C" Street, Suite 200 Anchorage, Alaska · 99503 -" ti n -DAN ROBERTSON~- ~,rren o : .................. SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEASE: REPLY TO 0 ~ SCHLUMBERGER OFIr~IHORE SERVICES W. International Airport Rd. horage, Alaska 09502 ATTN' HOLLY BURGAN PAGE 1 of 2 Gentlemen: Enclosed are2 Blprints of the 2"&5"DIL, LDT/CNL; NEUTRON/GR (in cas'.~) Company Conoco Inc. , Well MPU C-9 , Field Kuparuk , County North Slope State Alaska Additional prints are being sent to: 1 BL prints & 1 RFolded Sepia Conoco, Inc. Offshore Exploration-E.W.A. Div. P.O. Box 4444 Houston, TX 772~52 AT. TN: L.A. Din§es C/O Randy Altobelli 1 BL nrints & 1 RFolded Sepia Conodo, Inc. P.E.S. Reservnir Sec. Offshore Bui~-ding P.O. Box 2197 Houston, TX 77252 ATTN' O.G. Kiel 1 BL prints Conoco, Inc. P.R.D. Reservoir-Sec. P.O. Box 1267 Ponca City, OK ~ 74603 ATTN' H.E. Gilliland - 6356 RW ~1 BL ,prints & 1 RFolded Sepia Chevron U.S.A.~ Inc. P.O. Box 8200 Concord, CA 94524 ATTN: Dave Engstrom C/O Louis Klonsky 1 BL nrints & 1 RFolded Sepia Champ~lin Petroleum Co. P.O,, Box 1257 Englewood, CO 80150 ATTN- Dale Bossert 1 Bk.prints & 1 RFolded Sepia Reading & Bates Petroleum Co. 3200 Mid Continent Tower Tulsa, OK 74103 ATTN' C. E. Seery, Jr. 1 BL prints & 2 RFolded Sepia Chevron U.S.A., Inc. P.O. Box 107.839 Anchorage, AK 99510 ATTN' J.L. Weaver 1BL prints & 1RFolded Sepia Cities Service Oil & Gas Corp. P.O. Box 939 Bakersfield, CA 93302 ATTN' Nell Buttram C/O Jim Ouinn The film is returned to Conoco Anchorage Office We appreciate the privilege of serving you. Recei~ by;~ Da t e' Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Art Huffman DISTRICT MANAGER CONOCO, INC. 3201 "C" STREET ANCHORAGE; ALASKA 99503 SCHLUMBERGER~ OFFSHORE SERVICES ~ A Division of Schlumberger Limited HOUSTON, TEXAS 77001 PLEASE REPLY TO 9 May 85 SC.LU..E.GE. OF~S.O.~SE.V,CES 500 W.INTERNATIONAL AIRPORT RD. //iNCHORAGE ;ALASKA 99502 ~:Z ATTN: Holly Burgan Attention: DAN ROBERTSON PAGE 2of 2 Gentlemen: Enclosed are 2BL prints of the Company CONOCO ~ INC. Field KUPARUK ~ A/d'ditional prints are B~i~ent to: iBL Prints &IRF ALASKA OIL & GAS CONSERVATION COMMISSION \ 3110 PORCUPINE DRIVE ANCHORAGE; ALASKA 99501 ~ATTN' WILLIAM VAN ALF~/: 2"&5"DIL, , Well. LDT/CNL; NEUTRON ( in casing ) on: MPU C-9 ., ., County_ NORTH SLOPE State ALASKA __prints prints ___prints __prints __prints The film is We appreciate the privilege of serving you. SOS--1565 -A __prints prints " L.L'iVED Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Art Huffman DISTRICT MANAGER ADDITIONAL TAPES TO: CITIES SERVICE: BAKERSFIEL~CA READING & BATES: TULSA,OK CHAMPLIN: ENGLEWOOD, CO CHE~ON USA:ANCHO~GE ALAS~ OIL&GAS:ANCHO~cHLUMBERGER OFFSHORE SERVICES CONOCO :ANCHORAGE 5oo w. INTERNATIONAL AIRPORT RO~ CONOCO:PONCA CITY,OK ANCHORAGE, ALAS~ 99502 COMPANY ' ~~/ff~ ATTENTION' ~~.*~2~/~~ N_° 000513' L-~COMPUTING CENTER PRINT CENTER WELL NAME SERVICES NO. OF BOXES JOB NO. ADD' L TAPES · !~ WELL NAME ' · I-~I/L/S s~v~c~s .,~Jz'-'c7o2 4'4 9-,S - a~'e~ - ,/~?,.s-- / ~ z~ ~ NO. OF BOXES: JOB NO. : ADD'L TAPES : WELL NAME : SERVICES : WELL NAME : SERVICES : NO. OF BOXES: JOB NO. : ADD'L TAPES : NO. OF BOXES: JOB NO. : ADD'L TAPES : WELL NAME : SERVICES : WELL NAME : SERVICES : NO. OF BOXES: JOB .NO. : ADD'L TAPES : SCHLUMBERGER COURIER NO. OF BOXES: JOB NO. : ADD'L TAPES : DATE DELIVERED Alaska Oil & Gas Cons. Commission Anchorao~ STATE OF ALASKA ON NTHLY REPORT OF DRILLING AND WORKOVER OPERATI · Drilling well I-~ Workover operation [] 2. Name of operator 7. Permit No. Conoco ]]nc 85-36 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 5o_029-21299 9. Unit or Lease Name Milne Point Unit 4. Location of Well at surface 4166'FNL, 2428'FEL, SectionlO, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52'KBI ADL 47434 10. Well No. CNo. 9 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. March ,19 85 12. Depth at end of month, footage drilled, fishing'jobs, directional drilling problems, spud date, remarks Spud 3/11/85 10,881' TD 13. Casing or liner run and quantities of cement, results of pressure tests Si ze Wt Grade From To Cement 95/8" 36# K-55 0' 6---~03' 912 bbls. 12.3 ppg, Permafrost E cmt., 56 bbls. 15.8 ppg. class G cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run Dual Induction-SFL-GR Compensated Neutron-Li th.0-DensSf. Y-,GR- GR-Neutron (in casing) 6607'-10864' 9590' - 10834' 4600'-6584' 16. DST data, perforating data, shows of H2S, miscellaneous data 3/18/85 - Had communication between conductor and cellar, cemented with 163 sks, Perma- frost C cmt, repeated on 3/19 with 222sks, Permafrost. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /)~/,/'~$~--~'~-crt~ TITLE J"~,~-,,,'¢~ /:;~,~ ~]. p"'~,~r. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate ~,~/ T-1 -RF/ b~rch 8, 1985 Dan Girdler Comoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit C-9 Conoco Inc. Permit No. 85-36 Sur. Loc. 4166' FNL, 2428' FEL, Sec. 10, T13N, R10E, UM. Btmhole Loc. 2084' FSL, 1220' FEL, Sec. 4, T13N, R10E, UM. Dear' 14r. Girdler: Enclosed is the approved application for permit to drill the above referenced well. if coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to co~encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. T. . ~ o aid us in schedulzn~ fle. ld work, please notify this office 24 hours prior to commencing znstallation of the blowout prevention Mr. Dan Girdler Milne Point Unit-C-9 -2- March 8, 1985 equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, f/i"( ?'?~ " ' ::~. ' ' Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION lc Enclosure C¢: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery John FI. Kemp Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 March 5, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point C-9. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Don Girdler at 564-7637. Very truly yours, John R. ~mp . Manager of Alaskan Operations DRG/vv cc: MP C-9 Correpondence File RECEIVED i', :,'"':.' ', ...... "':~ .,:i 3 Ataska Oil & Gas Cons. Commission ~ Anchorage STATE OF ALASKA ALASKA .)IL AND GAS CONSERVATION C,~MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL E~: REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE j~ STRATIGRAPHIC L~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 4. Location of well at surface 4166', FNL, 2428' FEL, Sec 10, T13N, R10E, U.M. At top of proposed producing interval 1900', FSL, 1100', FEL, Sec 4, T13N, R10E, U.M. At total depth 2084', FSL, 1220', FEL, Sec 4, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) [ 6. Lease designation and serial no. RKB 52' Pad 17' ~ 47434 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 ~ 1~ of Deadhorse miles 3061' @ Sur"~ feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11,100 1vD 7614' 'i'rV~e~t 2,560' 20. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 53°0 (see 20AAC25.035(c) (2) 19. If deviated (see 20 AAC 25.050) 9. Unit or lease name ~' "~ ~_.. D 10. Well number .~ ~_O~~ ~ C No. 9~ 11. Field and p~0i ?¢i:~i'*i '~ ~0,~*,% N~s~~ 0i~ & G~s O0ns. o0mm~ss ~ch0rage Kupa~ ~ver Amount $200,000.00 1 5. Distance to nearest drilling or completed · C-7 well //¢¢) ~ feet 18. Approximate spud date 03/10/85 3230 psig@_80°F Surface .... _3800 psig@7;350 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE H_o_!e.. I Casing Weight 36 26 CASING AND LINER H-40Grade Co~g I Lengths0 * K-55 .6267 SETTING DEPTH MD TOP TVD 35' I 35' 33' I 33' 32' , 32' M D BOTTOM TV D 115'! 115 6300' 4539 10,850 7460 QUANTITY OF CEMENT (include stage data) +100 cf _+3200 cf ~ _+250 cf (MT 22. Describe proposed program: Conoco Inc. proposes d.rilling the subject well as a water injection well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a ~ m~d weight in' ~urface hole of 9.0 ppg to a maxJman of 9.~ ppg. Mud weight at T.D. will be 10.2 ppg. A 20", 2000 psi diverter will be insta]3ed on the 13 3/8" conductor for drillJmg the surface hole. A 13 3/8", 5000 psi RSRRA MDPE stack will be used on the surface casing. Presst~ tests will be performed as per State Regulations. ~ downhole pressure is based on initial reservoir pressure. Mmx/nmm surface pressure ~_~sed on an unexpanded gas bubble, temperature taken into account. The closest we//bore is C No. 7 which is ~h~' southeast of C-9 on the surface. The proposed path of C-9 wJ]l cross over the C-7 well at 1200' +_ M.D. At this point ~t~,.. e C-7 well depth is approximately 1550'. Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing ~.~ test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. '23. I her~"~rtify that the foregoi~9~is true and correct to the best of my knowledge S I G N E D ~;;~ TIT L E Production Engineer The space below for Commission use DATE 03/05/85 CONDITIONS OF APPROVAL Samples required I--IVES [~NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud Icg required []YES E~JO Approval date Directional Survey required APl number ~YES []NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 8, 1985 by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-9 Conoco, Inc. 3201 "C" Street, Ste. 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM Ae The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Be The 9-5/8" surface casing will be cemented with 1500± sacks of Permafrost "E" cement followed by 200± sacks of Class "G" cement. A top job will be done if cement Js not circulated to the surface. Ce The 7" production casing w~ll be cemented in two stages. The primary cementing job will consist of 250± sacks of Class "G" cement pumped around the casing shoe (estimated 1200'± of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of 200± sacks of permafrost type "~" cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0 ' -4500 ' (TVD) Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at 1700±. 4500'-TD Predominantly shale until the Kuparuk Sands - expected at 7000' subsea TVD. III. FORMATION EVALUATION Ao Wireline logs for the 8~" hole from T.D. to ±1000' above the Kuparuk interval will include: Dual Induction Laterolog; Sypherical]y Focused Log; Litho Density; CNL with GR-caliper. IV. DRILLING FLUIDS A high viscosity gel-fresh water (non-dispersed) mud system 0'-1000' V. Low solids non-dispersed gel-water mud system 1000' ~Surf. Csg. Pt. Low solids lightly dispersed mud system 6300' -T.D. DIRECTIONAL PROGRAM The well will be drilled to a proposed K0P of 500' then build angle in a north 33° west direction. The closest that the C-9 wi]_] come to anoth~wellbore is from surface to KOP± where the proposed C-9 will be ~' northwest of the existing C-7 well and 120' southeast of the C-2 well.. An MWD tool is to be run while drilling for surveying purposes. Proposed ho].e angle is 52.7°. cOuoco.*'Iuc, .......... :: PAD C, WELL NOt 9 REVISED PROPOSAL MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. ...... WEST-EAST 6000 5000 4000 3000 2000 1000 0 7000 t t i t I t ..... 6000 _ .. . . 5000 4000 , .... :3000 _ _._2000 _ ..... 1000 _ 1000 . '1000 ! ' TARGET LOCATIONt ' , . · . ...................................................1900' FSL. I100' FEL SEC. 4, TI3N. RtOE . . 1ARGET TVD-? 150 -. TMD-t 0~74 DEPm?240 NORTH 6O66 Ir~ST 3952 N 33 DEG 5 HI N 7240' (TO TARGET) . . . · Alaska Oil & ~as Cons. L;o~m'n~ssior~ Anchorage, SURFACE LOCATIONt 1114' FSL (4166' FNL) 2428' FEL (2852' Ft/I.) SEC. 10, Tt3N, RtOE PAD C. WELL NO, 9 R~v,,ISED PROPOSAL IIIL.NE PT.. NORTH SLO' · ALASKA EAST,MAN WHIPSTOCK. INC. 0 1000 2OOO 3000 4000 5000 6000 7000 8000 _ 0 SURFACE KOP TVD=500 TtlD=500 DEP=O $ 10 15 20 BU[LD 2 I/2 DEG 25 PER ! O0 FT SO EOB TVD=2323 TIED=2608 DEP~903 Alaska Oil & (~as Cons. ComrnJssior~ Anchorage _.. 9 5/8' CSG PT - TVD-4560 T~ID=6300 DEP-3840 AVERAGE ANGLE 52 DEG 42 HI N ~IID KUPARUK TVD=ZOIO TIeD=lO343 DEP=701i6 TARGET (LOWER KUP) TVD=7150 TlflD=10574 DEP=; "TENTATIVE' TD TVD=Z317 TMD=10850 DEP=7460 I 1000 I I I I I' 2000 3000 4000 5000 6000 VERTICAL SECTION 7000 1700 _ 1600_ 1 500 _ 1400_ 1300_ 1200_ 1100_ 1000. NORTH 900 ......... 800 7OO 2900 2800 2700 2600 2500 24OO I 1913 '9 37'6 1631 CONOCO. INC PAD C, WELL NO, 9 REVISED PROPOSAL MILNE PT., NORTH SLOPE, ALASKA EASTMAN WHISPTOCK"- INC]- ............ NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 154.7 23OO I 12?$ 2200 ! '61 g: CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Li~e~~_ Flow IAnnular Preventer Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. 2" - 5000 Side Outlets 3" - 5000 Side Outlets' 13 5/8" - 5000 13 5/8" - 5000 3" - 5000 Side Outlets 13 5/8" - 5000 11" - 5000 Alaska Oil & ~uias Co~s, Commission Anchorage CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ~ ~ Flow Line Fill-up Line ~ ,'~0" 2000 ps~ ! Annular ! ~ Preventer ~c~ ~ ~''' ', ~CR Valve'.. , Dtillin , I Valve ~ ] 2000 psi ~ ~ ~ 3tverter Quick ~ . ~ ~ Connect Assembly ~,:-:::~ - - - l'.'.~. . ~ .:..~ ~ ~ ~0. ~., . ..; .~ - _ _ _ '...1'" ~ Saver Sub ~ i'.f ... Assembly . .~ · [ ~ [... , .. ~ ~ Starting ~. [ ~ Head ~ !" '. I 5~-/ I.". "~l /casing I l' ' ~- · ~---.'.' --;7-i]-7-:-''.'-7-','.'- · -' 1. Relief lines.from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 ALASKA UNITED DRILLING RIG NO. 3 ,BUTTERFLY. VALVE CLOSF. D CLOSED Flow path Solids removal DEGASSING FLOW PATH Flowline (in) & pass shaker screens Shaker discharge into sand trap (ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed) Degasser discharge into ditch Overflow returns to degasser suction (underflow butterfly closed) Switch desander suction out of degasser tank Desilter suction (Normal) Cleaned mud to treatment pit Underflow from treatment to suction pit Gravity-flooded suction ALASKA UNITED RIG NO. 3 DRILLING CHOKE · MAN IFOLD' LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6"x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type Choke (2) Type 10,000 psi w/ (2) Manual (1) Automatic CAPACITIES ACTIVE SYSTEM I Sand trap 6 bbl I Degasser tank 56 bbl I Desander suction 54 bbl I Desilter suction 55 bbl I De$ilter discharge 66 bbl SUBTOTAL Mud Tank NO. I I Common 2 Suction Mud Tank No. 2 Receiving Discharge Mud Tank No. 3 SUBTOTAL ACTIVE SYSTEM TOTAL TRIP TANK SURFACE VOLUME GRAND TOTAL JCalculaJed 4' below tank topi 237 38bbl 122 bbl 18'1 bbl 184 bbl 240 bbl 768 bbl 1005 bbl 150 bbl 1155 bbl (2) HCR valves CHECK LIST FOR NEW WELL Pi~RMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2/thru 8) (3) Adm±n ~ {~- ~-~ 9. ~(¢ thru 12) 10. (10 and 1~): 12. YES NO l. Is the permit fee attached .......................................... / well to be located in a defined pool ............................. 2, Is 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 ................................. 3. Can permit be approved before ten-day wait Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~_~-~_~. Is administrative approval needed ................................... Is the lease number appropriate ..................................... REMARKS .~<77','.''I ":' f 7, (13 thru 21)" 13. 14. 15. 16. 17. 18. 19. 20. 21. Is conductor string provided ........................................ 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 surface casing protect fresh water zones ....................... 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 ............................ (22 thru' 2'6) (6) Add: //z]'-/]/ Geo lo gy.~f~ngineeri, ng: WVA~L JKT~''~ tlJH ~L ~' . rev: 10/29/84 6. CKLT ~,' ~:. :,.~.':.. L ~:: ': ~.~,"~, '%~,.,.:::~ ,~v,~,~:~,~,,,,..~,~,~~~.~,. ,. 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... ~Y~ Are necessary diagrams of diverter and BOP equipment attached ....... ~, Does BOPE have sufficient pressure rating - Test to ~ ~-JZ> psig Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. f~ Additional requirements.. ............................................ ~z?~ Additional Remarks: ,~/~Z/- ~,.,-? ~UIfA ~ //D~~ ~-~ ~~ ~RF~C~ - INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. 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