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9.1.2022 By Anne Prysunka at 1:30 pm, Sep 01, 2022 By Anne Prysunka at 1:34 pm, Aug 23, 2022 5HJJ-DPHV% 2*& )URP %URRNV3KRHEH/ 2*& 6HQW 7XHVGD\$XJXVW 30 7R 7RP.DYDQDJK & &F 5HJJ-DPHV% 2*& 6XEMHFW 5( &'5LQLWLDOWHVWRQ3 $WWDFKPHQWV 1DERUV&'5$& [OV[ dŽŵ͕ /ŵĂĚĞĂŵŝŶŽƌƌĞǀŝƐŝŽŶ͕ĂĚĚŝŶŐ͞Ϭ͟ƚŽƚŚĞďůĂŶŬŽŶƚƌŽů^LJƐƚĞŵZĞƐƉŽŶƐĞdŝŵĞĨŝĞůĚƐ͘WůĞĂƐĞƵƉĚĂƚĞLJŽƵƌĐŽƉLJ͘ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůLJƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗dŽŵ<ĂǀĂŶĂŐŚͲ;ͿфdŽŵ͘<ĂǀĂŶĂŐŚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗&ƌŝĚĂLJ͕ƵŐƵƐƚϭϵ͕ϮϬϮϮϭϭ͗ϭϴWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂLJфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂLJΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ůĂƐŬĂE^Ͳd^DфůĂƐŬĂE^ͲdͲ^DΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗ZϮŝŶŝƚŝĂůƚĞƐƚŽŶWϭͲϮϯ ,ĞƌĞŝƐŽƵƌŝŶŝƚŝĂůƚĞƐƚŽŶWϭͲϮϯ͘ dŚĂŶŬLJŽƵ͕ dŽŵ dŽŵ<ĂǀĂŶĂŐŚ dƌŝůůƐŝƚĞDĂŶĂŐĞƌʹZϮ ZŝŐϵϬϳϲϳϬϯϬϵϳ ĞůůϵϬϳϴϰϭϮϰϭϬ ,ϰϭϲϵ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CDR2AC DATE: 8/19/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1961240 Sundry #321-586 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250 /3500 Annular:250 / 3500 Valves:250 / 3500 MASP:2870 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7-1/16" GK P Pit Level Indicators PP #1 Rams 1 Blind / Shear P Flow Indicator PP #2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector PP #3 Rams 1 3.0" Pipe / Slip P H2S Gas Detector PP #4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)2925 P Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2300 P Check Valve 0NA200 psi Attained (sec)16 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)38 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 1880 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 5 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 3 P Inside Reel valves 1P #3 Rams 2 P #4 Rams 2 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 08/17/22 17:22 Waived By Test Start Date/Time:8/18/2022 19:30 (date) (time)Witness Test Finish Date/Time:8/19/2022 1:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors R. Coyne / W. Williams Hilcorp M. Igtanloc / T. Kavanagh PBU P1-23 Test Pressure (psi): Robert.Coyne@Nabors.com AlaskaNS-CTD-DSM@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0819_BOP_Nabors_CDR2AC_PBU_P1-23 9 9 9 9999 9 9 9 9 9 -5HJJ 5HJJ-DPHV% 2*& )URP 'DQLHO6FDUSHOOD 'DQLHO6FDUSHOOD#KLOFRUSFRP! 6HQW 6XQGD\$XJXVW 30 7R 5HJJ-DPHV% 2*& '2$$2*&&3UXGKRH%D\ %URRNV3KRHEH/ 2*& &F 1LFN)UD]LHU & $UYHOO%DVV & 6XEMHFW 7KXQGHUELUG5LJ:HHNO\%23(7HVW/ $WWDFKPHQWV 7KXQGHUELUG5LJ[OV[ ůů͕ ƚƚĂĐŚĞĚŝƐƚŚĞKW ƚĞƐƚŽŶĐĞƌŝŐŐĞĚƵƉŽŶWdDWϭͲϮϯ dŚĂŶŬLJŽƵ͕ 'DQLHO6FDUSHOOD +LOFRUS1RUWK6ORSH//&$ODVND_6U:HOO6LWH6XSHUYLVRU_3%8:HOOV7HDP FHOO_ RIILFH_+_DOW Anthony Knowles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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:Thunderbird 1 DATE: 8/7/22 Rig Rep.: Rig Phone: 907-444-7218 Operator: Op. Phone:907-444-7218 Rep.: E-Mail Well Name: PTD #11961240 Sundry #322-236 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2915 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5" VBR P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1400 P Quantity Test Result 200 psi Attained (sec)19 P No. Valves 8P Full Pressure Attained (sec)143 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 0NA Nitgn. Bottles # & psi (Avg.): 3@2200 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:4.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/6/2022 05:45 Waived By Test Start Date/Time:8/7/2022 14:15 (date) (time)Witness Test Finish Date/Time:8/7/2022 18:45 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Lou Laubenstein Hilcorp Tested with fresh water. Closing times: Annular: 25 sec Pipe Rams: 8sec Blinds:7sec HCR: 3sec Brandon Stiffler/Josh Noel Hilcorp North Slope, LLC Nick Frazier/Daniel Scarpella PBU P1-23 Test Pressure (psi): pbrwowss@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0807_BOP_Hilcorp_Thunderbird1_PBU_P1-23 9 9 9 9 9 9 999 9 9 9 -5HJJ Closing times: Annular: 25 sec Pipe Rams: 8sec Blinds:7sec HCR: 3sec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'DWH $33529('%< 7+($2*&&&200,66,21(5 3703 +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. $'/ &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU 1RQH &U &U 6WUXFWXUDO %DNHU63HUP3DFNHU 1R6669,QVWDOOHG 1R6669,QVWDOOHG 'DWH %R<RUN 2SHUDWLRQV0DQDJHU /HVOLH5HDYLV OUHDYLV#KLOFRUSFRP 358'+2(%$<370&,17<5(2,/ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& &RPP &RPP6U3HW(QJ 6U3HW*HR 6U5HV(QJ )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Samantha Carlisle at 2:51 pm, Apr 26, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1 FQ %R<RUN RX 8VHUV 'DWH %R<RUN %23(WHVWWRSVL$QQXODUWRSVL 6)' 0*5-81 -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.06.14 12:15:19 -08'00' RBDMS JSB 062822 5:2 :HOO 3 37' $3, tĞůůEĂŵĞ͗WϭͲϮϯ W/EƵŵďĞƌ͗50-029-22690-00 ƵƌƌĞŶƚ^ƚĂƚƵƐ͗WƌŽĚƵĐĞƌʹEŽŶͲKƉĞƌĂďůĞ ZŝŐ͗dŚƵŶĚĞƌďŝƌĚ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϯYϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϰͲϭϬĚĂLJƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛Ě͍ϭϬͲϰϬϯ͕ϭϬͲϰϬϰ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗d ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝ 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If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P1-23 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 196-124 50-029-22690-00-00 ADL 028297 & 034622 13432 Conductor Surface Intermediate Production Liner 9204 80 4008 13392 12978 20" 9-5/8" 7" 8922 34 - 114 34 - 4043 31 - 13423 2870 34 - 114 34 - 3660 31 - 9198 13041 470 3090 5410 / 7020 None 1490 5750 7240 / 8160 12935 - 13240 4-1/2" 12.6#13Cr80 29 - 127108895 - 9086 Structural 4-1/2" Baker S-3 Perm Packer No SSSV Installed 12654 / 8719 No SSSV Installed Date: Monty Myers Drilling Manager Trevor Hyatt trevor.hyatt@hilcorp.com 777-8396 PRUDHOE BAY, PT MCINTYRE OIL February 1, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. Set Whipstock / Mill Window By Samantha Carlisle at 12:45 pm, Nov 15, 2021 321-586 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.11.15 11:36:03 -09'00' Monty M Myers DSR-11/15/21 10-407 BOPE test to 3500 psi. Variance to 20 AAC 25.036 c.(4).(C) a fire wall to shield accumulators and primary controls if approved if accumulator and controls remain greater than 70' from wellhead. MGR22NOV22 SFD 11/17/2021dts 11/23/2021 11/23/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.23 14:13:25 -09'00' RBDMS HEW 11/24/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 15, 2021 Re: PBU P1-23 Sundry Request Sundry approval is requested to set a whipstock and mill the window in P1-23 pre-rig as part of the drilling and completion of the proposed P1-23L1 CTD lateral. Proposed plan for P1-23L1 Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, MIT, and caliper log. E-line will then set a 4-1/2"x7" flow through whipstock and mill XN nipple. Service Coil will mill the XN-nipple (if not done with E- line) and mill a single string window in the 7” casing (if scheduling needs arise, the rig will mill the window). See P1-23L1 PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If scheduling needs arise, the rig will mill a single string 3.80" window + 10' of formation. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-7/8” L-80 slotted liner. This completion will NOT abandon the parent Kuparuk perfs. Pre-Rig Work - (Estimated to start in February 2022): 1. Slickline: Dummy WS drift and Caliper a. Drift past whipstock setting location b. Caliper past whipstock setting location 2. Fullbore: CMIT-TxIA to 3,000 psi and MIT-T to 3,000 psi 3. E-line: Set 4-1/2”x7” whipstock and Mill XN a. Top of whipstock set at 12,945’ MD (top of window – 5’ down from top of whipstock) b. Oriented 170° LOHS c. Mill XN-nipple at 12,693’ MD to 3.80” ID 4. Service Coil: Mill Window a. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,870 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 7” Casing 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference PBU P1-23L1 PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,870psi a. 24 hour notice for AOGCC witness BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run Slotted Liner 5. Freeze Protect and RDMO Sundry 321-586 ppp completion will NOT abandon the parent Kuparuk perfs. p Top of whipstock set at 12,945’ MD PTD 221-096 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: x PBU P1-pad is an H2S pad. o The highest recorded H2S well on the pad was from P1-20 (850 ppm) in 2011. o Last recorded H2S on P1-23 was 80 ppm in 2021 Reservoir Pressure: x The maximum reservoir pressure is expected to be 3,750 psi at 8,800’ TVD (8.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,870psi. x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 Coiled Tubing BOPs Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee STATE OF ALASKA �`in '',::"D eASKA OIL AND GAS CONSERVATION COMMIS ,£ k e REPORT OF SUNDRY WELL OPERATIOI 1. Operations Performed t N [ 9 ^u E ti Abandon ❑ Plug Perforations ❑ Fracture Stimulate LO Pull Tubing 0 Operations shutdown ^ ___..0 - Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Ap }pfe r r�m ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: '"6LJ�.�1<./ 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 196-124 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-22690-00-00 7. Property Designation(Lease Number): ADL 28297&0034622 8. Well Name and Number: PBU P1-23 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PT MCINTYRE OIL 11.Present Well Condition Summary: Total Depth: measured 13432 feet Plugs measured None feet true vertical 9204 feet Junk measured 13041 feet Effective Depth: measured 12978 feet Packer measured 12654 feet true vertical 8922 feet Packer true vertical 8719 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 4008 9-5/8" 34-4042 34-3659 5750 3090 Intermediate Production 13392 7" 31-13423 31-9198 7240/8160 5410/7020 Liner Perforation Depth: Measured depth: 12935-13240 feet SCANNED True vertical depth: 8895-9086 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 29-12710 29-8753 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 12654 8719 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12935'-12945' Treatment descriptions including volumes used and final pressure: See Attachment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 183 681 1486 1761 568 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations a Exploratory ❑ Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 �A\L3\ 16.Well Status after work: Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data RI GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-396 Authorized Name: Lastufka,Joseph N Contact Name: Wages,David Authorized Title: ation and Controller Contact Email: David.Wagesabp.com Authorized Signature: ✓` Date: t'z(D/!t> Contact Phone: 907.564.5669 Form 10-404 Revised 04/2017 ()k./ 3 512.0)g V TL 3/16//Cf trp pt�t f L_ / /��� REDMMfS Le!.? 2 9 2018 Submit Original Only • • Daily Report of Well Operations P1-23 ACTIVITYDATE SUMMARY T/I/O = 500/2200/150 TEMP = 125* PPPOT-T (PASS) PPPOT-IC (PASS) Pre Frac PPPOT-T: Stung into test void, 250 psi on void, bled void to 0 psi. Monitored for 10 min, no change in pressure. Pump through void, good returns of fluid. Pressure void to 5,000 psi for 30 min test. Lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to void to 0 psi, R/D test equipment. PPPOT-IC: Stung into test void, 50 psi on void, bled void to 0 psi. Monitored for 10 min, no change in test void pressure. Pump through void, good returns of fluid. Pressure test void to 3,500 psi for 30 min test. Lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled 12/3/2017 void to 0 psi. ****WELL FLOWING UPON ARRIVAL**** (Fracturing) DRIFTED W/ 10' x 3-3/8" DUMMY GUN, 2-1/2" S-BAILER TO TD @ 13,145' SLM (No issues) 12/15/2017 ****CONT JOB ON 12/16/17**** ****CONT. JOB FROM 12/15/17**** (Fracturing) DRIFTED W/3.805" G-RING, 4-1/2" BRUSH, 3.50" G-RING TO XN-NIP @ 12,680' SLM / 12,698' MD LRS FP FLOWLINE W/—7 BBLS 60/40 METH (See LRS log) SET 4-1/2"WHIDDON CATCHER @ 12,674' SLM / 12,698' MD PULLED STA#5 INT-OGLV FROM 12,577' SLM / 12,589' MD PULLED STA#4 INT-LGLV FROM 11,142' SLM/ 11,158' MD PULLED STA#3 INT-LGLV FROM 9,457' SLM/9,482' MD ****JOB INCOMPLETE, RDMO DUE TO WEATHER**** **NOTE : 4-1/2" WHIDDON CATCHER LEFT IN HOLE / GLM's#5, #4  LEFT AS 12/16/2017 OPEN POCKETS T/I/0=2050/2020/20 (LRS Unit 42 -Assist Slickline: Freeze Protect Flowline). Pumped 12/16/2017 8 bbls 60/40 meth down FL. Notify DSO, SLB on well upon departure. T/I/0=2200/2300/20 Temp=SI (LRS Unit 72 -Assist Slickline: Load &Test) Pumped 5 bbls 60/40 meth and 240 bbls crude down IA for load. SL ine to set Sta#5 ***Job Cont to 12/19/2017 12-20-2017 WSR*** ****CONT. JOB FROM 12/16/17****(Fracturing) PULLED STA#2 INT-LGLV FROM 7,785' SLM/7,797' MD PULLED STA# 1 INT-LGLV FROM 4,732' SLM/4,478' MD SET STA's#1, 2, 3, 4 INT-DGLV's LRS LOADED IA W/—240 BBLS CRUDE (See LRS log) 12/19/2017 ****CONT JOB ON 12/20/17**** ****CONT. JOB FROM 12/19/17**** (Fracturing) SET STA#5 INT-DGLV(12,589') PULLED 4-1/2" WHIDDON CATCHER FROM 12,674' SLM (Empty) RAN 4-1/2" BRUSH, 3.70" G-RING TO XN NIPPLE @ 12,698' MD LRS LOADED TBG W/300 BBLS CRUDE (See LRS log) MADE 2 ATTEMPTS TO SET 4-1/2" PXN-PLUG BODY (Left in sta#1 glm @ 4,730' slm) 12/20/2017 RECOVERED 4-1/2" PXN- PLUG BODY FROM STA#1 @ 4,730' SLM (3rd attempt) ***Job cont from 12-19-2017 WSR*** Pumped 2 bbls crude down IA to pressure up after SLine set Sta#5. Bled IA to 12 psi. Got back 3 bbls. Loaded Tbg w/300 bbls crude, Freeze 12/20/2017 protected FL w/8 bbls 60/40. S-Line set Plug. ***Job Cont to 12-21-2017 WSR*** • Daily Report of Well Operations P1-23 ***CONT. JOB FROM 12/20/17***(Fracturing) SET 4-1/2" PX PLUG IN X-NIPPLE AT 12,687' MD. LRS PERFORMED PASSING MIT-T TO 4000# 12/21/2017 ***CONT ON 12-22-17 WSR*** ***Job Cont from 12-20-2017 WSR** MIT-T 4310 psi PASSED Max applied = 4500, Target pressure =4000 Pumped 5.44 bbls crude down Tbg. to reach target Pressure on 2 failing MIT-T attempts. Bled Tbg and IA pressure down. Got—4 bbls from Tbg. Pumped 5 bbls crude down Tbg for MIT-T. Tbg lost 124 psi in 1st 15 mins and 51 psi in 2nd 15 mins for a total of 175 psi in 30 min test PASS. Bled Tbg to 20 psi and got back —4.5 bbls. 12/21/2017 ***Job Cont to 12-22-2017 WSR*** ***CONT FROM 12-21-17 WSR***(fracturing) LRS PERFORMED PASSING MIT-IA TO 4000# PULLED PRONG FROM PX-PLUG BODY @ 12,687' MD. ATTEMPT TO PULL PLUG BODY FROM X-NIPPLE @ 12,687' MD.(unable to latch) BAILED SAND/SCALE FROM PLUG BODY W/ 10' x 2.25" & 10' x 2.50" BAILERS @12,687' MD. (recovered —1/2 gallon) PULLED PX-PLUG BODY FROM X-NIPPLE @ 12,687' MD.(full of scale) 12/22/2017 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** ***Job Cont from 12-21-2017 WSR*** MIT-IA to 4432 psi PASSED Target pressure = 4000 psi Max pressure =4500 psi Pumped 8 bbls crude down IA to pressure up IA to 4494 psi. IA lost 46 psi in 1st 15 mins and 16 psi in 2nd 15 mins for a total of 62 psi loss during 30 min test. Bled IA to xx psi and got back —x bbls. SLine in control of well per LRS 12/22/2017 departure. FWHP's=0/40/30 IA,OA=OTG 12/26/2017 ***Place Card Holder for sale of product(Sand/Chemicals) to be used on well*** T/I/O = 920/400/20. Temp = SI. TBG & IA FLs (E-line req). ALP = 660 psi, SI @ CV. TBG FL© 500' (8 bbls), IA FL @ 40' (1 bbl). 12/29/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 08:45 ***WELL S/I ON ARRIVAL*** (SLB ELINE IBP) INITIAL T/I/O = 840/275/0 PSI. MIRU, LPT/HPT= PASS. RIH W/ PEH-EF (1.20" FN)/XO-GO/3.38" BAKER IBP. OAL = 31.5', OAW= 300 LBS, MAX OD = 3.38". TIE INTO SLB PERFORATION RECORD DATED: 29-SEP-2016. SET IBP AT 12985'. CCL TO MID ELEMENT=23.8'. CCL STOP DEPTH = 12961.2'. HAD TO WORK TENSION TO PULL OFF THE PLUG. WELL LEFT S/I ON ARRIVAL. FINAL T/I/O = 800/50/0 12/30/2017 ***JOB COMPLETE ON 30-DECEMBER-2017*** Job Scope: Fracture Treatment- Rig-up Set tree saver. PT connection to 4300 psi. Test cups to WHP (850 psi) pass. Tie in IA line to PRV and OT tank. Test IA PRV's - Left 3200 psi and Right 3400 psi. Rig-up frac equipment. 2250 bbls 105f FW hauled to 5 tanks, water sample to lab for testing. ***Cont on WSR 1/1/18**** 12/31/2017 Job Scope: Fracture treatment- Rig-Up day 2 Complete rig-up 1/1/2018 ***Cont on WSR 1/2/18*** 1/1/2018 T/I/O=SI Assist Frac as directed (FRACTURING) Heat 90 bbls DSL to 90*for Frac. • • Daily Report of Well Operations P1-23 Job Scope: Fracture Treatment Kuparuk Sands InterACT Publishing ***Cont. from WSR 1/1/18 *** ***R/U in place upon arrival*** LRS hold 2700 psi on IA, IA pop-off= 3000 psi. OA= open bleed. Global kickout= 6000 psi Troubleshoot Ice in pump discharge line, electrical issues with pump control signal, Blender POD alternator Perform Passing PT all check valves, lines, and pumps, blow down, S/D to start Frac 1/2/2018 tomorrow. 1/2/2018 WHP: Temp = S/I WHP: 950/40/0 Temp= S/I. Assist SLB with frac/Hold backside pressure. Pumped 3.16 bbls dsl down IA to reach 2000 psi as per WSL. Punped an additional 1.2 bbls down IA to reach 2700 psi. Bled IAP back to 100 psi. Bled to return tank. Pumped a total of 11 BBLS of DSL down IA to hold backside pressure for the Frac. Bled IA down to 1800 psi PER WSL. RDMO: FWHP= FRAC/1800/0 1/3/2018 VALVES = FRAC Job Scope: Fracture Treatment Kuparuk (InterAct Publishing) Injectivity test w/diesel. Tbg to pressure to 4800 psi to pump into formation. Injectivity 3500 psi @ 2 bpm after breaking circulation. Discuss possiibility of the IBP failing. Pre IBP injectivity was 3 bpm @ 2000 psi. Confident IBP in place. Pump data frac w/90 bbl scour stage .5 ppa. 694 bbls total. Note 400 psi improvement w/scour stage.Analyze data frac. Pumped 400 bbl pad and 46,500 lbs sand in 8 stages ( 1 - 8 ppa)Avg treating pressure 4300 psi @ 33 bpm. Screened out w/8 ppg at surface and 3 ppa at perfs. tripped out @ 5500 psi. Sand from surface to perfs in 28 lb cross-linked gel. Estimated top of sand completely settled is 8000' but a sand bridge could be expected anywhere below surface. 1/3/2018 Sqz 1 bbl diesel freeze protect into well. Put parachute and heaters on tree. RD for the Job Scope - Rig down tree sver and frac equipment Cont from WSR 1/3/18 (no activity on 1/4/18 due to frac crew change-out) PJSM, establish roster and muster areas. Pull tree saver and rig down frac equipment. ***Job Complete**** 1/5/2018 LRS Unit 70 - Heat UR w/290 bbls 1% kcl w/Safelube to 140* ***Continued on 01-10-18 1/9/2018 WSR*** CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP MIRU. BOPs function tested upon initial rig up. Make up and RIH with 2.25" DJN BHA. 1/9/2018 ***Job in Progress*** CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP MIRU. BOPS function tested upon initial rig up. Make up and RIH with 2.25" DJN BHA. Bust through a couple bridges/possible ice to 1943'. Choke completely plugged off. POOH, swap chokes. Change to 2.3" JSN. RIH. Begin cleaning out at 1800'. 1/9/2018 ***Job in Progress*** CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP MIRU. BOPs function tested upon initial rig up. Make up and RIH with 2.25" DJN BHA. Bust through a couple bridges/possible ice to 1943'. Choke completely plugged off. POOH, swap chokes. Change to 2.3" JSN. RIH. Begin cleaning out at 1800'. 1/9/2018 ***Job in Progress*** • • Daily Report of Well Operations P1-23 CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Clean out down to 2070', Chase all gel OOH, RIH dry, tag at 2070 again, resume cleaning 1/10/2018 out. Clean out down to 12921CTMD. Cannot jet off. Pump 50bbl gel pill and chase out at CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP 1/10/2018 Clean out down to 2070', Chase all gel OOH, RIH dry, tag at 2070 again, resume cleaning ***Continued from 01-09-18 WSR*** LRS unit 70- Heat UR w/290 bbls 1% kcl w/ 1/10/2018 Safelube to 140* CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Clean out down to 2070', Chase all gel OOH, RIH dry, tag at 2070 again, resume cleaning out. Clean out down to 12921CTMD. Cannot jet off. Pump 50bbl gel pill and chase out at 50%. Got significant solids/sand back from —2000' to surface. Made decision to RBIH with a BDJSN to perform one final, large gel sweep off bottom due to concerns of residual carbolite being left in hole and causing issues with hydraulic centralizer that is being run on JDC fishing BHA. When tagged up depth was -56 which makes sense why the final tag was 58' shallow. MU 2" Ball drop JSN for final gel sweep/cleanout pass. RIH tag IBP 1/10/2018 12,981 CTM. CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Clean out down to 2070', Chase all gel OOH, RIH dry, tag at 2070 again, resume cleaning out. Clean out down to 12921CTMD. Cannot jet off. Pump 50bbl gel pill and chase out at 50%. Got significant solids/sand back from —2000' to surface. Made decision to RBIH with a BDJSN to perform one final, large gel sweep off bottom due to concerns of residual carbolite being left in hole and causing issues with hydraulic centralizer that is being run on JDC fishing BHA. When tagged up depth was-56 which makes sense why the final tag was 58' shallow. MU 2" Ball drop JSN for final gel sweep/cleanout pass. RIH tag IBP 1/10/2018 12,981 CTM. CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Continue rih w/2" BDJSN. Tag IBP 12, 981'. Lead with gel, load ball. Nozzle plugged off close to when ball/gel hit, surged several times, no go. FP all surface lines, pump 60/40 CTBS while pooh. Found nozzle packed with gel/goo/carbolite. Pump cold gel out to tanks. Cut pipe for chrome mgmt, change packoffs. MU BDJSN bha, 7/8" ball preloaded. 1/11/2018 RIH. CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Continue rih w/2" BDJSN. Tag IBP 12,981'. Lead with gel, load ball. Nozzle plugged off close to when ball/gel hit, surged several times, no go. FP all surface lines, pump 60/40 CTBS while pooh. Found nozzle packed with gel/goo/carbolite. Pump cold gel out to tanks. Cut pipe for chrome mgmt, change packoffs. MU JSN. RIH w/2.3" JSN tagged top of IBP jetting with power vis leaving 2 bbls on top for any fall out of propant. POOH chasing at 50% (2.5 bpm/80fpm)(chrome tbg). RIH w/ BOT Hydraulic overshot/hyd centralizer, had to jet a little bit to get on fish, latched IBP, picked up and let IBP relax for 30min before PUH into TTL. Weights were heavy until we got IBP out of perf at 12935'. FP well well with 30bbl 60/40 before pull into TTL. No overpull seen when pull into TTL. 1/11/2018 Smooth pulling in tbg. • Daily Report of Well Operations P1-23 CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Continue rih w/2" BDJSN. Tag IBP 12,981'. Lead with gel, load ball. Nozzle plugged off close to when ball/gel hit, surged several times, no go. FP all surface lines, pump 60/40 CTBS while pooh. Found nozzle packed with gel/goo/carbolite. Pump cold gel out to tanks. Cut pipe for chrome mgmt, change packoffs. MU BDJSN bha, 7/8" ball preloaded. RIH w/2.3" JSN tagged top of IBP jetting with power vis leaving 2 bbls on top for any fall 1/11/2018 out of propant. POOH chasing at 50% (2.5 bpm/80fpm)(chrome tbg) ***Job in progress*** CTU 9 1.75" CT Job Objective: Post Frac FCO & Pull IBP Pop off well. Retreive IBP fish, all rubber elements and stiffener ring have been left downhole. RDMO. 1/12/2018 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (Fracturing) TAG HARD BOTTOM AT 13,041' SLM W/4-1/2" BRUSH, WIRE GRAB (Recovered 1 -6" sealing element). CURRENTLY POOH W/4-1/2" BRUSH, 3.50" WIRE GRAB FROM 13,041' SLM.. 1/13/2018 ***JOB IN PROGRESS, CONTINUED ON 1/14/18 WSR*** ***CONTINUED FROM 1/13/18 WSR*** (Fracturing) TAG HARD BTM @ 13,041' SLM W/4-1/2" BRUSH, WIRE GRAB (Recovered second 6" sealing element). SET 4-1/2" SLIP STOP CATCHER SUB AT 7,848' SLM PULL INT-DGLV'S FROM ST#2 (7,797' MD) & ST#1 (4,748' MD) SET INT-LGLV AT ST#1 (4,748' MD) & INT-OGLV AT ST#2 (7,797' MD). PULL EMPTY 4-1/2" SLIP STOP C-SUB FROM 7,848' SLM ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 1/14/2018 NOTE: STIFFENER RING FROM 3-3/8" BAKER IBP PULLED 1/12/18 LEFT IN HOLE. ! ! 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Z • • Schlumberger FracCAT Treatment Report Well :P1-23 Field :Point McIntyre Formation :Kuparuk C County :North Slope State :Alaska Prepared for Client :BP Exploration Alaska Client Rep :David Wages Date Prepared :January 3,2018 Prepared by Name :Michael Hyatt Division :Schlumberger Phone :907 227 9897 Pressure(All Zones) Initial Wellhead Pressure(psi) 868 Maximum Treating Pressure(psi) 5675 Surface Shut in Pressure(psi) 3836 Average Treating Pressure(psi) 4102 DataFRAC ISIP(psi) 2495 Maximum Rate(bpm) 33.4 Final ISIP(psi) Screenout Average Rate(bpm) 23.4 Maximum Prop Con(ppa) 8.1 Average Prop Con(ppa) 1.34 Treatment Totals(All Zones as per FracCAT) Total Slurry Pumped(Water+Adds+Proppant)(bbl) 1499.1 Total CarboLite 16/20 Proppant(lbs) 48100 Total YF128FIexD Past Wellhead(bbl) 980.62 Total CarboBond Lite(lbs) 15560 Total WF128 Past Wellhead(bbl) 466 Total 20/40 River Sand(lbs) 1000 Freeze Protect(bbl) 1.5 Total 16/30 Sand 800 Total Clean Fluid(bbl) 1448.12 Total Proppant Pumped(lbs.) 65460 Total Proppant in Formation(lbs.) 9502 Total Chemical Additives Invoiced Past WH Invoiced Past WH J957(mgal) 41.2 41 M002(Ib) 64 63 J604(gal) 94 93 M275(gal) 30 19 J891 (Ib) 395 392 J218(lb) 0 0 F103(gal) 60 59 J475(Ib) 385 381 L071(gal) 116 115 J134(lb) 40 0 L065(gal) 66 65 Freeze Protect(bbl) 0 1.5 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • • Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country United States Section 1 : Executive Summary Equipment and materials were mobilized and rigged up on P1-23 location between December 30, 2017 and January 2, 2018.After setbacks due to equipment issues, it was only possibly to pressure test lines on January 2, 2018. On January 3, 2018, we pumped the DataFRAC and propped fracture treatment for BP Exploration Alaska, with the treatment prematurely terminated due to a screenout with 2.6ppa at the perforations. On January 3rd, the crew arrived on location at 5:30, proceeded to fire up all of the equipment, and prepare the site for the upcoming job. At 7:45, we began the prime up and performed a pressure tests to verify that there were no leaks in the surface iron. At 8:20 we conducted a pre job safety meeting and it concluded at 8:55. After a short delay waiting for LRS to line out their equipment, we started to pump our injection test. At 11:30, after pumping 6 bbl of fluid, the well pressured out. Initially, the BP representatives on location thought the bridge plug failed and the decision was made to rig down and clear the location for Wireline and Slickline. BP's engineers had a conference call and made the determination that the bridge plug had held and the pressure signature was instead the formation breakdown. The conclusion was to proceed with the Calibration Test. The new design called for all of the River Sand and 800 pounds of the 16/30 to be pumped on the scour step. The remaining 200 pounds of 16/30 were left in buckets on location for potential Slickline operations. At 13:15, the crew started rigging the equipment back up. At 15:00 we performed a pressure test and held a safety meeting to discuss the Calibration Test. After the safety meeting, we completed the rigup, re-generated the POD Blender's road engine (to prevent it going into regen mode during the frac treatment) and we proceeded to pump the DataFRAC. At 17:37, we pumped the Calibration Test and it was completed at 18:40. After analyzing the data, we proceeded to start the main treatment at 20:00. At about 1,500 bbl of slurry pumped we screened out with 8ppa on surface and 2.6ppa on formation.We pumped a total of 48,000 lb of prop and about 9,500 lb into formation. • • Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 2: Post Job Treatment Plots Pressure Test BP Exploration Alaska — Treating Pressure P1-23 — Slurry Rate 01-02-2018 8000 10 7000 Pump Check Valves were monitored during r ---- -B 6000 prime-up and the low-pressure tests. 5 -7 5000 $ • s w 4000 •� a ~ 3000 2000 - -- - -2 1000--- 1 -. - - -_- 1:1 -4 iwliLAI+��kr till - -0 14.3757 14:437 15:11:17 15.2757 15:44:37 Time-hh:mm.s ©Schlumberger 1994-2016 Schlumberger —Injectivity Test PRC BP Exploration Alaska — 6H Pressuree Pressure 1 Y P1-23 — Slurry Rate 01-03-2018 - lean Fluid Rate — Pro C BH Propon Con 10000 • , , , 10 -15 -14 9000- - -.. -.-. -9 -13 8000- -------- -8 712 -11 7000--— _. _ -__._____—_-- 7 -10 a n 6000--"- — 8 p -9 El 5 O Z. 5000 • 5 t7 § 13 4000 •4411— i q v -5 v Fri n 5 3000 - ---- -3 -4 2000 2 -3 1000-- if - I 72 ;1 0r• 1 1 -. . . 0 0 11:1722 11:34:02 11:50:42 12:07.22 12:24:02 Time-hh:mm:s ©Schlumberger 1994-2016 Schlumberger 0 0 Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States DataFRAC Plot BP Exploration Alaska Gel Concentration P1-23 01-02-2018 — L071 concentration — F103 Concentration 30 , 10 15 — L065 Concentration J — U028 Concentration -14 a - J604 Concentration -13 2511 — Breaker Concentration a -12 - o -7 i -11 20 i -10 _ E illiAltililio000,00,116, -e 9 _be W 15 P 5 -7 I.D Bj -4 8 0 3 ca 'I1 2 -3 5 2 -1 -1 0 t 0 0 17:42:41 17:59:21 18:18:01 18.32.41 18:49:21 Time-hh:mm.s ©Schlumberger 1994-2016 Schlumberger BP Exploration Alaska — BH Presssureessure Main Treatment PRC P1-23 — Slurry Rate 01-03-2018 ?ace Prop Con BH Prop Con 10000 . 40 -15 -14 9000 — - -13 8000- _. - _. - -12 -11 7000 -10 T 80009 n -8 'v 5000 J I 20 . ab 7 i 4000 1 -8 > 5 3000—— - -10 4 2000 -3 -2 1000- 19:44:41 19:57:11 20339.41 20:22.11 20.34 4' Time-hh:mm:a ©Schlumberger 1994.2016 Schlumberger • • Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Clean quid Rate Main Treatment Additive Plot BP Exploration Alaska - Gel Concentration P1-23 — L071 Concentration 01-02-2018 — F103 Concentration 10 -15 — L065 Concentration — U028 Concentrationg -14 — J604 Concentration .13 � +—� Breaker Concentration 8 r -12 30- ,) I c -11 7 G 1 10 Li 1 I -e — g = 8 w 20- I 5 g i -7 9,' -4 ' 1 6 oi -3 a 10- csg 4 _2 -3 3 -2 _1 e- -0 -0 19'.44'.41 19:57:11 20:09:41 2022'.11 20:34:41 Tlme-khmm:a ©Schlumberger 1994-2016 Schlumberger • • SchluiNherger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 3: DataFRAC, Designed Pump Schedule Designed Pump Schedule Ramp Slurry Pump Fluid Prop Step Step Name Volume Pump Rate Time Fluid Name Volume Prop Name Prop Cone Mass # (bbl) (bbl/min) (min) (gal) (PPA) (Ib) 1 Breakdown 40.0 20.0 2.0 WF128 1680 0.0 0 2 Scour 49.0 40.0 1.2 WF128 2058 Sand 0.5 1,800 3 Displacement 50.0 40.0 1.3 WF128 2100 0.0 0 4 Calibration 100.0 20.0 5.0 YF128FIexD 4200 0.0 0 5 Displacement 202.0 20.0 10.1 WF128 8484 0.0 0 Designed Ramp Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 441.0 19.6 18522 0 0 0 Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 4: DataFRAC, As Measured Pump Schedule As Measured Pump Schedule Step Slurry Slurry Pump Time Fluid Prop Prop Prop # Step Name Volume Rate (min) Fluid Name Volume Proppant Name Conc Conc Mass (bbl) (bbl/min) (gall (PPA) (PPA) (Ib) 1 Breakdown 116.4 14.4 9.2 WF128 4874 0.0 0.0 0 2 Scour 98.7 19.6 5.0 WF128 4086 Sand 16/30 0.7 0.3 1,800 3 Displacement 50.0 22.3 2.2 WF128 2094 0.1 0.0 4 Calibration 226.5 28.4 8.0 YF128FIexD 9510 0.0 0.0 0 5 Displacement 202.8 28.7 7.1 WF128 8518 0.0 0.0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Breakdown 14.4 19.9 4670 4899 2434 2 Scour 19.6 19.8 4432 4821 4142 3 Displacement 22.3 26.4 4564 4846 4285 4 Calibration 28.4 29.0 4684 4914 4446 5 Displacement 28.7 29.1 4579 4667 1055 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (lb) 694.3 31.6 29081 1800 Average Treating Pressure: 4606 psi Maximum Treating Pressure: 4914 psi Minimum Treating Pressure: 1055 psi Average Injection Rate: 24.5 bbl/min Maximum Injection Rate: 29.1 bbl/min Average Horsepower: 2767.6 hhp Maximum Horsepower: 3433.0 hhp Maximum Prop Concentration: 0.7 PPA • 0 Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 5: DataFRAC, Job Messages Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) Ibbl) (bbl/min) (PPA) 1 Reset Executed Steps 0 0 0.0 0.0 0.0 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 14:55:25 The 5 Pump Check Valves are Tested 231 119 0.0 0.0 0.0 4 15:06:16 Good Low PT 291 119 0.0 0.0 0.0 5 15:10:11 Main Line Check Valve Test Complete 2221 118 0.0 0.0 0.0 6 15:29:46 High PT Complete 7213 118 0.0 0.0 0.0 7 15:34:54 Global Trip and Pump Trips Tested 70 115 0.0 0.0 0.0 8 _ 7:46:04 Priming Up 194 123 0.0 5.1 0.0 9 9:16:13 Interact test 962 41 0.0 0.0 0.0 10 9:16:25 Test 962 41 0.0 0.0 0.0 11 9:31:39 Start Breakdown Automatically 961 133 0.0 0.0 0.0 12 9:31:39 Start Diagnostic Automatically 961 133 0.0 0.0 0.0 13 9:31:39 Start FracCat Automatically 961 133 0.0 0.0 0.0 14 9:31:55 Started Pumping 961 133 0.0 0.0 0.0 15 9:32:15 Activated Extend Stage 962 133 0.0 0.0 0.0 16 9:34:08 Wellhead Open 962 140 0.0 0.0 0.0 17 9:55:05 Bleeding Pressure down 2355 1893 6.3 0.0 0.0 18 10:59:31 Deactivated Extend Stage 57 1708 156.0 0.0 0.0 19 11:13:42 Priming Pump 1 47 1707 156.0 0.0 0.0 20 11:27:31 Wellhead Open 663 1703 156.0 0.0 0.0 21 11:28:23 Reset Executed Steps 680 1705 156.0 1.0 0.0 22 11:28:23 Reset All Totals 680 1705 156.0 1.0 0.0 23 11:28:23 Restart Treatment 680 1705 156.0 1.0 0.0 24 11:28:23 Start Breakdown Automatically 680 1705 156.0 1.0 0.0 25 11:28:23 Started Pumping 680 1705 156.0 1.0 0.0 26 11:30:41 Activated Extend Stage 2617 2696 4.3 2.0 0.0 27 11:37:34 Deactivated Extend Stage 2419 2563 10.0 0.0 0.0 28 11:38:08 Wellhead Shut 2373 2552 10.0 0.0 0.0 29 11:42:39 Pressure bled off 51 2484 10.0 0.0 0.0 30 14:41:11 Priming up 72 -22 10.0 4.9 0.0 31 15:02:36 Good Low PT 5608 -22 10.0 0.0 0.0 32 15:02:48 Pump Trips and Global Trip Tested 5801 -22 10.0 0.2 0.0 33 15:53:57 Good High PT 1296 -22 10.0 0.0 0.0 34 15:54:03 PJSM Complete 1296 -22 10.0 0.0 0.0 35 17:34:11 Finished Regen on the POD 876 1886 10.0 0.0 0.0 36 17:38:05 Wellhead Open 870 1885 10.0 0.0 0.0 37 _ 17:43:00 Started Pumping 3432 2646 10.0 0.9 0.0 38 17:43:25 Activated Extend Stage 3413 2660 10.3 0.9 0.0 39 17:49:42 Reset Executed Steps 3037 2635 20.8 0.0 0.0 40 17:49:42 Reset All Totals 3037 2635 20.8 0.0 0.0 41 17:49:42 Restart Treatment 3037 2635 20.8 0.0 0.0 42 17:49:42 Deactivated Extend Stage 3037 2635 20.8 0.0 0.0 43 17:49:42 Start Breakdown Automatically 3037 2635 20.8 0.0 0.0 44 17:49:42 Started Pumping 3037 2635 20.8 0.0 0.0 45 17:49:51 Activated Extend Stage 2971 2623 0.0 0.0 0.0 46 17:54:49 Priming LAS add hose 2490 2671 0.0 0.0 0.0 47 18:05:01 Deactivated Extend Stage 4814 2741 116.4 19.6 0.0 • • Schlumberger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 48 18:05:01 Start Scour Manually 4814 2741 116.4 19.6 0.0 49 18:05:01 Started Pumping Prop 4814 2741 116.4 19.6 0.0 50 18:05:04 Activated Extend Stage 4798 2739 117.4 _ 19.7 0.0 51 18:08:52 Stage at Perfs:Breakdown 4185 2722 191.9 19.7 0.3 52 18:09:56 Stage at Perfs:Breakdown 4280 2738 212.8 _ 19.6 0.2 53 18:10:03 Deactivated Extend Stage 4293 2734 215.1 19.6 0.1 54 18:10:03 Start Displacement Manually 4293 2734 215.1 19.6 0.1 55 18:10:43 Stopped Pumping Prop 4400 2722 228.2 20.1 0.0 56 18:12:18 Start Calibration Automatically 4840 2723 265.3 26.7 0.0 57 18:14:11 Activated Extend Stage 4909 2713 317.6 28.6 0.0 58 18:14:35 Stage at Perfs:Scour 4868 2710 329.0 28.7 0.0 59 18:18:02 Stage at Perfs:Displacement 4500 2740 427.8 _ 28.7 0.0 60 18:18:34 440 XL 4470 2728 443.1 28.7 0.0 61 18:19:47 Stage at Perfs:Calibration 4450 2699 478.1 28.7 0.0 62 18:20:15 Deactivated Extend Stage 4447 2692 491.5 28.7 0.0 63 18:20:15 Start Displacement Manually 4447 2692 491.5 28.7 0.0 64 18:20:18 Activated Extend Stage 4442 2694 493.0 28.7 0.0 • • Schlumber'■ger Client:BP Exploration Alaska lR�, Well:P1-23 Formation:Kuparuk C District Prudhoe Bay Country:United States Section 6: Main Treatment, Designed Pump Schedule Designed Pump Schedule Ramp Slurry Pump Fluid Prop Step Step Volume Pump Rate Time Fluid Name Volume Prop Name Prop Conc Mass # Name (bbl) (bbl/min) (min) (gal) (PRA) (Ib) 1 PAD 400.0 40.0 10.0 YF128FIexD 16800 0.0 0 2 1.0 PPA 50.0 40.0 1.3 YF128FIexD 2012 CarboLite 16/20 1.0 2012 3 1.0 PPA 38.0 40.0 1.0 YF128FIexD 1529 CarboLite 16/20 1.0 1529 4 2.0 PPA 36.2 40.0 0.9 YF128FIexD 1428 CarboLite 16/20 2.0 2142 5 3.0 PPA 36.6 40.0 0.9 YF128FIexD 1386 CarboLite 16/20 3.0 3465 6 4.0 PPA 36.9 40.0 0.9 YF128FIexD 1344 CarboLite 16/20 4.0 4704 7 5.0 PPA 37.1 40.0 0.9 YF128FIexD 1302 CarboLite 16/20 5.0 5859 8 6.0 PPA 37.3 40.0 0.9 YF128FIexD 1264 CarboLite 16/20 6.0 6952 9 7.0 PPA 37.4 40.0 0.9 YF128FIexD 1222 CarboLite 16/20 7.0 7941 10 8.0 PPA 37.4 40.0 0.9 YF128FIexD 1182 CarboLite 16/20 8.0 8866 11 8.0 PPA 50.0 40.0 1.3 YF128FIexD 1544 16/20 CarboBond Lite 8.0 12349 12 9.0 PPA 50.0 40.0 1.3 YF128FIexD 1494 16/20 CarboBond Lite 9.0 13448 13 10.0 PPA 50.8 40.0 1.3 YF128FIexD 1470 16/20 CarboBond Lite 10.0 14700 14 11.0 PPA 50.8 40.0 1.3 YF128FIexD 1428 16/20 CarboBond Lite 11.0 15708 15 12.0 PPA 100.0 40.0 2.5 YF128FIexD 2726 16/20 CarboBond Lite 12.0 32715 16 Flush 165.0 40.0 4.1 WF128 6930 0.0 0 17 FP 33.0 40.0 0.8 Freeze Protect 1386 0.0 0 Designed Ramp Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 1246.6 31.2 46447 63660 • 0 Schlumberger Client BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 7: Main Treatment, As Measured Pump Schedule As Measured Pump Schedule Ste Ste Slurry Slurry Pump Fluid MaxrProp Prop p p Volume Rate Time Fluid Name Volume Proppant Name p Conc Mass # Name (bbl) (bbl/min) (min) (gal) PPA) (PPA) (lb) 1 PAD 34.5 15.7 2.9 YF128FIexD 1433 0.0 0.0 0 2 PAD 400.0 32.2 12.5 YF128FIexD 16792 0.0 0.0 0 3 1.0 PPA 50.0 32.6 1.5 YF128FIexD 2022 CarboLite 16/20 1.1 0.9 2400 4 1.0 PPA 38.0 32.4 1.2 YF128FIexD 1529 CarboLite 16/20 1.1 1.0 2086 5 2.0 PPA 36.2 32.5 1.1 YF128FIexD 1439 CarboLite 16/20 1.8 1.3 2547 6 3.0 PPA 36.6 32.3 1.1 YF128FIexD 1397 CarboLite 16/20 _ 2.6 2.3 4363 [7 4.0 PPA 36.9 32.3 1.1 YF128FIexD 1352 CarboLite 16/20 3.8 3.3 6115 8 5.0 PPA 37.1 32.3 1.2 YF128FIexD 1310 CarboLite 16/20 4.8 4.3 7706 9 6.0 PPA 37.3 32.1 1.2 YF128FIexD 1271 CarboLite 16/20 _ 5.9 5.3 9201 10 7.0 PPA 37.4 32.6 1.1 YF128FIexD 1228 CarboLite 16/20 6.9 6.3 10601 11 8.0 PPA 37.4 32.1 1.2 YF128FIexD 1190 CarboLite 16/20 7.8 7.3 11845 12 8.0 PPA 23.3 20.5 3.5 YF128FIexD 776 16/20 CarboBond Lite 14.3 6.4 6796 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 15.7 22.5 3988 4321 1057 2 PAD 32.2 33.3 4852 4957 4323 3 1.0 PPA 32.6 32.9 4847 4902 4793 4 1.0 PPA 32.4 32.6 4764 4795 4733 5 2.0 PPA 32.5 32.6 4702 4733 4665 6 3.0 PPA 32.3 32.5 4609 4665 4545 7 4.0 PPA 32.3 32.5 4471 4539 4412 8 5.0 PPA 32.3 32.5 4324 4409 4227 9 6.0 PPA 32.1 32.5 4219 4263 4181 10 7.0 PPA 32.6 33.0 4182 4194 4167 11 8.0 PPA 32.1 32.5 4271 4494 4140 12 8.0 PPA 20.5 30.8 4243 5192 0 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 804.8 29.5 31739 63,660 Average Treating Pressure: 4645 psi Maximum Treating Pressure: 5675 psi Minimum Treating Pressure: 0 psi Average Injection Rate: 31.2 bbl/min Maximum Injection Rate: 33.3 bbl/min Average Horsepower: 3573.7 hhp Maximum Horsepower: 4003.8 hhp Maximum Prop Concentration: 8.08 ppa • • Scb1unibePger Client:BP Exploration Alaska Well:P1-23 Formation:Kuparuk C District Prudhoe Bay Country:United States Section 8: Main Treatment, Job Messages Message Log Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. # Time Pressure Pressure (psi) (psi) (bbl) (bbl/min) (PPA) 1 19:53:29 Deactivated Extend Stage 1060 2832 694.3 0.0 0.0 2 19:53:29 Start PAD Manually 1060 2832 694.3 0.0 0.0 3 19:53:29 Start Propped Frac Manually 1060 2832 694.3 0.0 0.0 4 19:54:53 Start Pumping 1057 2835 0.0 0.0 0.0 5 19:56:23 Stage at Perfs:Displacement 4008 2700 9.8 12.6 0.0 6 19:57:45 Start PAD Manually 4394 2624 34.5 22.5 0.0 7 20:03:30 Stage at Perfs:PAD 4920 2884 212.9 33.0 0.0 8 20:04:33 Stage at Perfs:PAD 4918 2860 247.5 32.7 0.0 9 20:10:14 Start 1.0 PPA Automatically 4902 2876 434.6 32.9 0.0 10 20:10:14 Started Pumping Prop 4902 2876 434.6 32.9 0.0 11 20:11:46 Start 1.0 PPA Automatically 4795 2800 484.5 32.4 1.1 12 20:12:57 Start 2.0 PPA Automatically 4734 2814 522.9 32.4 1.0 13 20:14:04 Start 3.0 PPA Automatically 4668 2824 559.2 32.5 1.9 14 20:15:12 Start 4.0 PPA Automatically 4537 2826 595.7 31.9 2.8 15 20:16:20 Start 5.0 PPA Automatically 4406 2808 632.3 32.2 3.9 16 20:16:48 Stage at Perfs:PAD 4329 2804 647.3 32.3 4.3 17 20:17:29 Start 6.0 PPA Automatically 4186 2785 669.4 32.1 4.8 18 20:18:21 Stage at Perfs:1.0 PPA 4221 2771 697.1 32.5 5.6 19 20:18:39 Start 7.0 PPA Automatically 4183 2764 706.9 32.7 6.0 20 20:19:32 Stage at Perfs:1.0 PPA 4204 2745 735.7 32.3 6.5 21 20:19:48 Start 8.0 PPA Automatically 4164 2732 744.3 32.2 6.9 22 20:20:40 Stage at Perfs:2.0 PPA 4370 2781 772.2 32.2 7.5 23 20:20:58 Start 8.0 PPA Automatically 4546 2808 781.6 30.1 7.6 24 20:21:59 Stopped Pumping Prop 4979 2908 800.9 11.8 2.2 25 20:26:59 Shutting the well 2111 2764 801.8 0.0 0.0 26 20:29:36 Cleaning lines out to the tank 7 2771 801.8 0.0 0.0 27 20:59:21 Wellhead Open 2091 2911 803.3 0.0 0.0 28 21:00:24 Started Pumping 2095 2871 803.3 0.0 0.0 29 21:00:31 Activated Extend Stage 2094 2869 803.3 0.0 0.0 30 21:07:29 Bleeding WH Pressure to 3500psi 4378 2800 804.8 0.0 0.0 31 21:14:03 Deactivated Extend Stage 4193 2815 804.8 0.0 0.0 32 21:18:07 Wellhead Shut 3853 2812 804.8 0.0 0.0 TREE_ VVELL ACT_UAATTOR= BAKERC w P 1 -2 Tit HANGERHFMC GEN 5 @ 30'MD.•.CSG KB.EDEV= 43.1 RIF ELEV= 43.1' BE ELEV= 12.08' KOP= 1737 Max Angle= 58°@}8295' 2096' —14-1/2"CAMCO BAL-O-SV LN,ID=3.812" Datum MD- 12856' Datum TVD= 8800'SS 9-518"CSG,40#,L-80,ID=8.835" H 4043' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE Minimum ID =3.725" @ 12698' ( 1 4748 4080 55 KBG 2-LS DONS INT 16 01(14!18 2 7797 5867 52 KBG-2-LS SO INT 20 01!14(18 4-1/2" HES XN NIPPLE 3 9482 6832 54 KBG-2-LS DMY INT 0 12/20/17 4 11158 7821 54 KBG-2-LS DMY INT 0 12/20/17 5 12589 8680 53 KBG-2-LS DMY INT 0 12/20/17 7"CSG,26#.L-80,ID=6.276" H 12450' 12654' H 7"BKR S-3 PERM PKR,D=1875" 12687' —I4-1/2"HES X NIP,D=3.813" 12698' —14-1/2"HES XN NIP,ID=1725" 4-1/2"TBG,12.6#,13-CR,.0152 bpf,ID=3-958" H 12709' I---' 12709' —14-1/2"WLEG,ID=3.858" 12693' H ELMD TT LOGGED 08/19/96 PERFORATION SUMMARY REF LOG:DIFL ON 08/05/96 ANGLE AT TOP TU U:50°@ 12935' — Note:Refer to Production DB for historical perf data _ SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 12935-12945 0 07/23/03 2-1/2" 6 12994-13054 0 09/29/16 — 3-3/8" 6 12994-13074 0 08/19/96 — 2-7/8" 6 13115-13135 0 08/10/11 2-7/8" 6 13140-13180 0 07/23/03 2-7/8" 6 13220-13240 0 07/22/03 — 13041'SLM —FISH:STFFBVER RING FROM EP LH-I DH(01/11/18) PBTD —j 13337' 11111111.1 ►111111111111 7"CSG,29#,13-CR,D=6.184" H 13423' i1A1&A1A•A1A•A+A1Aii4 DATE REV BY COMMENTS DATE REV BY COI?v1VTS POINT MCINTY RE UNIT 08/11/96 ORIGINAL COMPLETION 01/17/18 CJNIJMD GLV CIO(01/14/18) WEIL: P1-23 08/12/01 RNITP CORRECTIONS 01/29/18 DS/JMD ADJUS IID FISH DE 7TH&RECOVERED ELEMENT PERMIT No:`1961240 08/16/17 JNUJMD ADDED REF/BF ELEV&FIXED 7"CSG DEPTH AR No: 50-029-22690-00 12/28/17 RCB/JMD GLV CIO(12/20/17) SEC 16,T12N,R14E,4869.21'FEL&578.82'FNL 01/03/18 MS/JMD SET 03P(12/30/17) 01/17/18 JTGJMD PULLED IBP&SET FISH BP Exploration(Alaska) • • �wP I 1/7,4.4.4. THE STATE Alaska Oil and Gas 71, O T K ® Conservation Commission s - _ } —_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov David Wages Well Interventions Engineer swim 0 62017, BP Exploration (Alaska), Inc. ' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PBU P 1-23 Permit to Drill Number: 196-124 Sundry Number: 317-396 Dear Mr. Wages: 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, Hollis S. French Chair DATED this 2)day of September, 2017. REID S Lv OCT — 3 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI�,,, APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ®' Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 196-124 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-22690-00-00 ' 7. If perforating: 8. Well Name and NRECEIVED What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes H No 0 PBU P1-23 • 9. Property Designation(Lease Number): AE ji_ 7 P rb 9 ) 10. Field/Pools: ADL 028297&034622 PRUDHOE BAY,PT MCINTYRE OIL• 11. PRESENT WELL CONDITION SUMMARY A0000 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 13432 • 9204 . 13337 9145 None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 4008 9-5/8" 34-4042 34-3659 5750 3090 Intermediate Production 13392 7" 31-13423 31-9198 7240/8160 5410/7020 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12935-13240 8895-9086 4-1/2"12.6# 13Cr80 29-12710 Packers and SSSV Type: 4-112"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 12654/8719 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: September 30,2017 15. Well Status after proposed work: Oil II WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages,David be deviated from without prior written approval. Contact Email: David.Wages@bp.com Authorized Name: Wages,David Contact Phone: 907.564.5669 Authorized Title: Well Intervrentions,Engineer Authorized Signature: :i\---, // Date: {�1 ( 11 tt�� z; COMMISSION USE O LY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 (7-37Q Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No f 0 Spacing Exception Required? Yes 0 No I2 Subsequent Form Required: / Approved by: gi)1".— COMMISSIONER APPROVED BYTHECOMMISSION Date: 1 I I l'q YTZ 9/1g//7- 0)14 911312,017 ORIGINAL -i' c'q-- 90. x,1 ....... -�e. Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBD!J!S ,., OCT - 3 2017 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS Before me, the undersigned authority, y g on this day personally appeared �,LAC �.ti �' , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration(Alaska) Inc. ("BPXA")and I am familiar with the Application for Sundry Approvals to stimulate the P1-23 Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On May 23rd, 2017,the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 15th day of August,2017. 677 / (Signature) STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at Alkcite,t-w-.),-- e) Alas �. on the /S4 day of 6.(Ayfj , 20f7 . Signature of Officer Sail of Alaska �7` ' Ll biIC Notary Public i - �, l ogle L.Jordheim Title of Officer My Convoission : 3.20.20 • • Date: August 15, 2016 Subject: P1-23 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: AOGC Commission Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of p 9 p well P1-23. P1-23 was frac'd in 1998 with good production rates. However, decline was much faster than anticipated. It is believed that connectivity to the frac has been lost as several wellbore cleanouts ' have been performed to remove frac sand from the well. WC remains favourable and reservoir pressure is sufficient to support a re-frac. The goal of the re-frac is to increase total fluid rate which will address the slugging issues the well is currently experiencing. tiJ4 We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh— water aquifers and a plan for basewater sampling. We are also requesting that the requirements in section 20 AAC 25.283, a, 10 be met by pressure tests of the tubulars on the well to be stimulated and by investigation into the mechanical condition of the wells within '/z mile of the wellplan within the producing interval. Please direct questions or comments to David Wages • • Affidavit of Notification (20 AAC 25.283,a, 1) Partners notified 5/23/2017: ConocoPhillips ExxonMobil Chevron Department of Natural Resources • • Plat Identifying Wells(20 AAC 25.283,a,2,A-C) and Faults(20 AAC 25.283,a, 11) 3 e..rxu s,v�u e.nw a.uw P2.11. vP{�N 4. i' , 40 . ,•+ I. ..474, r 40 0,0 r. d",$ 2 `' 'dam y r i10. Maf • . r� 0o • s. -,.vFMo4, ''''"ft, t N i . 4P .4444s. :/ t '` - 3 r ` i { e°n ' i pr -f fa IIVIIP''' i ; = ,� ♦' y V '� UP • 4 r P ° 3 `� r-41fp fie'4► ,476 nomJ 'l. • 'die '"� "" • • '�/ 7 • ri7.44,4, 4,-,,,,, w f f r 41, le FAMMPOI lei r40,b , " .fir, `�.�,'-\ 1$r/*iF i Red lines indicate approximate length and location of the frac. Producers within 1/z mile of L-200a: P2-55 • P1-01 • P2-24 - P1-24 . P1-21 • P1-11 . Per the plat above, there are no water wells within 1/2 mile of the subject well. The above map shows 1 primary fault of concern: Fault #1. The remaining faults are well away from stimulation chemicals and/or not in the direction that the induced fractures are predicted to travel. Per the frac modelling, historical data, and post frac analysis of past jobs we are expecting a half-length of about 150' which is well short of the distance to faults 2 and 3. In order to reach fault 1, the frac half- length would have to be over 500 feet long. If any indication of connection to a fault is seen, pumping operations will shut down at a safe point to do so. Exemption for Freshwater Aquifers(20 AAC 25.283,a,3-4) Well P1-23 is in the East Operating Area of Prudhoe Bay. Per Area Injection Order No.4 dated July 11, 1986 where ARCO (BP) Alaska requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Eastern Operating Area of the Prudhoe Bay Unit for purposes of enhanced hydrocarbon recovery and the disposal of non-hazardous oil field waste fluids. Finding #5 specifies that: "Within the Project Area, injection into, though, or above fresh water aquifer or underground source of drinking water will not occur." To • • comply with this finding, the operator must confirm integrity of the well that will be injected in per the injection order and the integrity of wells within 'h mile radius per 20 AAC 25.283. These requirements will be met and proven in this document, thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283,a,5-6) Well P1-23 was spudded on 7/24/1996. A 30" hole was drilled to 80' where 20" 94#, H-40 was set and cemented with 260 sx of Arctic set cement A 12-1/4" hole was drilled to 4043' where 9-5/8" 40#, L-80 Surface casing was set and cemented with 1310 sx of CS III, 405 sx Class G. An 8-1/2" hole was drilled to 13,513' where 7" 26#, L-80 was set and cemented with 258 sx of Class 7 G. PBTD: 13,337' -re 10/6/1996, the well was frac'd with —163k#of proppant. Screened out at 12ppa • 1110 Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8) TREE= AELLFEAD CON SAFETY NOTE:CHROME 4.10'1BGa7'CSG. ACTUATOR= BAKER C P 1 -2 3 -,„„,G HANGER:FMC GEN 5 Q 311'MO, REF MEV- 43.1' BF 13EV 110 KOP= 1737 _ Ma Angle 58'0 8290 2055' r-14-112'CAMCO BA L-0 9Y LN D='3 812 1 Dan.) 12856 Datum TYE>= 6800'55 19-5f8'CSG,404,L-60,D-6.635' 4043• GAS LFT MOORE S .._ STI 1t3 TVD DPv. NF ? VLV-LATER PORT_. DATE Mfllmllm ID=3 725- 12898' �; 1 1 1 '4748 MOO 55 i KBGZLSi DOME MT /6 maii6' 2 7797 5887 52 KBG2-LS,DOeE NT 16 09'2868 4 112"HES XN NIPPLE 3 9182 6832 54 I KSG-2-LS1 Don& NT 16 0028/16 4 11158 7821 54 KBG-2-LS;DONE NT 16 0928/16 5 12589 861301 53 ;KB6.2-LS i SO NT 22 0928/16 lrcsG,ter.L-90 D=6_2rel.J-1/_1245©'--] \ / CZ' L 12564• HT 81165-3 R8301 WA.D*^3E73'� 1255T 4-1YFESXNP D- I r { 1211141" hES TCN PP,D=3.725' I [4.1/2- 12,04,TBG, 13-CR.0182 apt, 3.968' 1270Y' —� 12708' H4-12'%LEI%Er*a-ex' 1213' �am)n L• tri*awl—1 FE FORAT13Ns1.aa4 RY o,..•�.~..•," ' REF LOG:DEL ON O43A16/95 ANGLEAT TOP PERE:NY 0 12935' We.Refer to Roductian OB for tsmrcal Pert data SIZE SPF NTIRVAL Opru9gx CATE 2-746' 6 12935-12945 0 0723/03 2-1/2' 6 12994-13354 0 09.29116 3318• 6 12994-13374 0 0019196 2-748' 6 13115-13115 0 001641 2-7/8' 6 13140-13180 0 O7R3103 2.7M' 6 13220.13240 0 0722/03 r "FBTo ]�`"ia3sr:] �i44'� 4114 041410,,14/414/14 F e 29Y.13.c17 0 6.184} 1/342]•,,.. 41•1�14a1,'+ DATE FEV BY c228S.H•4fsDLAIE FEV 3Y 1 COMMENTS .....�...�„„..�,.,. ,.PONT M3.R1'FEE Llfr 01/11!86 ORDINAL COMPLETION 10104116 G B/.AD SET FLO TI-RU SLR w!GAUGES AEI'P1-23 08112101 1441P CORRECTUNS 1110/116 ZV/JMD FULL FLA TFRU-SET X LOC](w433 DEV&GA R3214tTNe: 1961240 01112/16 GE/AC/SET 4-1/Z PJ(R.11G(01 1110016 JUJUS) RLLEt XLOCX w 1B3 Ela!&GAUGES(11/016 AR N7'50-029-22690-00 0929/16 JTC�Jr()RIL(3)PA PLl1G(091231 00101%JNJ.M)A[IETJ l /BF ELEV 8(i0(ID%'CSG 0!3'EH SEC 16,71214 R14E 4869.21'FEL&575-87 FNL 0929116 J16/.11117 OLV 60(0972016) 1472411E 6(R'JB.A[SEIES 10929/16) .1,._m„.v,...........,s...,..�.....a,.,.........�........,, ..,......,....._...aM BP Exploration(Alaska) Name/Size Weight Grade ID Burst,psi Collapse,psi 9-5/8” Surface Casing 40# L-80 8.835 5750 3090 7" Production Casing 29# 13Cr-80 6.6.184" 8160 7020 4-1/2" Production Tbg 12.6# 13Cr-85 3.958" 8960 7810 • Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 5,000psi , Tubing head adaptor: 11" 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11" 5,000psi w/2-1/16" side outlets Casing Spool: 11" 5,000psi w/2-1/16" side outlets Geological Frac Information (20 AAC 25.283,a,9) MD TVDss TVDss TVD Frac Lithological Formation MD Top Bottom top bottom Thickness Gradient Desc. HRZ 12649 12895 -8671 -8824.38 153.38 0.7 Shale TKUP 12895 12895 -8824.38 -8824.38 0 0.67 Sandstone UC4 12895 12936 -8824.38 -8850.42 26.04 0.67 Sandstone UC2-3 12936 12990 -8850.42 -8884.63 34.21 0.63 Sandstone UC1 12990 13055 -8884.63 -8925.68 41.05 0.64 Sandstone UB4 13055 13182.67 -8925.68 -9004.93 79.25 0.65 Sandstone UA1-4 13182.67 13261 -9004.93 -9053.38 48.45 0.67 Sandstone LC4 13261 13320 -9053.38 -9089.71 36.33 0.68 Sandstone LC3 13320 13413 -9089.71 -9146.98 57.27 0.68 Sandstone TKNG 13413 -9146.98 0.68 Sandstone • • Mechanical Information of nearby wells(20 AAC 25.283,a, 10) Well Name Casing Type Casing Size Casing Depth Mole Size Vol cmt TOC est..ria TOC TOC Top of pay interval Zonal Isolation? Comments Inches Feet Inches Cu Ft MDFeet NDssFeet TVDssFeet P2-55 pc Production Casing 4.625 _ 552 o mem umec 202 1 23.33 8892 ves ✓ P;ug bumped and he:d.CrDC ps.. 12-55 p'. Production Liner 7 3341 5.5 527 Vs:u^tetr c 11443 5624 5892 Yes 11-21 pc Production Casing 7 12471 5.3 ..2.75 is's umetrc 3782 6652 8725 Yes ^"... P1-24 p. Production Lner 2.875-14750 3.25 1 No cement N/A NA 8725 No / n:one 5 detrack,cement,sc.at'.on not required. P1-01 pc Production Cas:ng 4;625 13245 12.23 1457.5 Volumetric 9761 6386 8804 Yes P1-01 p Production Linen 7 14124 6.5 385.25'.e umetr'c 11785 7513 8844 Yes Fu..,cemented.netcement returns at diner hanger P1-21 pc Production Casing 7.625 11513 9.875 667 Volurnetr.c 9122 732E 8672 Yes P2-24 pc Production Casing 120831 8S 296.7 V'olumetrC 11199 7353 5780 Yes P1-11 pc Production Casting 9.625 12272 12.25 440 Valumetr c 11191 5:21 8725 Yes P1-11 pS Product on L nor q.5 253 Vo u met-c 11377 iii-7 5725 Yes =u:5 cemented ,net.corer;returns a: net hanger Summary Hydraulic Fracture Program (20 AAC 25.283,a, 12) (Detailed program included) Hydraulic fracture treatment schedule stage 1: Fresh MP 1 PRIVVOtuWE PROPPART CLEAR WINE theses. Fiber PURR TIME STEP STAGE AVERAGE COMMENTS TM RATE - 1 STAGE COW STAGE CW STAR GW SUE GROSS CM Breaker CO.,. STAGE CBE a roA (1661) :moi ,11e: 1141) I844 (LOS) fins) 10011 3064 911114) 1006849 MO Mt .___.1 1 AD YF728FIeaD 40 1%5 501 7350 21168 0 2000 0 175 504 #0 00-04122 001235 _-_ 2112 801 __. 1212__ _._ i s I 0.5 RAT W12aFin0 40 50 554 2100 23260 1027 3 027 rums a 49 =53 8.0 00:01.15 001150 2111 .__ 5 1121 1222. 2222._ 211- 2212-_ __2122_ 2222._. 042 B - 1 PAD W128FlnA 40 175 729 7350 30618 0 3027 175 728 8.0 1111. 00:0412 00'1[12 2111_ 2112._ 1112 .. __ 2211 2113 __. 212. 1121_ 1191_ ..._.__T 1 1 FLAT 161286414 40 _ 50 7A 2100 32718 2011 5078 lruzoGimbel. d8 776t0 00-Ot-16 00142/ 2222. 1111 2221. 2222... -2222._ 1122.. 2111 a a ... 1 4410 Y6728Fin10 40 ... 38 817 1575 34293 1508 6547._.16120 c bet4. 36 812 -_-8A 0000 56._-00'1013 --- _ .__�. 2112 1112_ 1221 1211 2122. _1122 i 0 a 2 °_._ TF12118100D p 38 054 1575 35860 2894 9,440 10120 r...6.0.0. 34 846 8A 0000 Se 0021.79 i _.. 2122 2212 -_ 1222 m I 3 ME► 1F728FlexD M 38 � 1575 37443 4177 13672 181zncb esu 33 879 8A 00 0056 0022153 _. ._ -__ 1212 __. II 1 4 RAMP.._ YF128F4oO 40 2222 38 979 1575 39018 5353 1B 964 30126 c bour. 2222.. 911 8_e 30 00.56 032311 _- 12 1 5 86047 YF128F4rA 40 38 967 1575 40593 6448 25413 30x20 Gerbil,. 31 942 -_.-10 0 2212 00.60 56 0024-07-1 2111. 2222. 1121 ,, 1222._ 2121_ u t � 6 RAW 1612434x0 4D ..8 100E 1575.... 42168 7468__..32,881..,,,-.ran 30 971 10.0 4456 002503�� 2222 _-_ _......- 01 ....._.. 5 _-i 14 1 7 RAID 161286414 40 ;6 1042 1575 43743 817$ 41298 1srz6 ca,botne 29 1800 10.0 00 W36 042559 o. 221 2222__- 1212_ 1111_ 1111_ __- __. __ Is 2 $ °�.._. YF12�1e14 N ... 38 1074 1575 45318 93� 50604 !sizes c.rboul. � 1028 10.0 0056 002fi55 ._- .,b --r 16 / .....___._8 f1AT 1612864x0 40 __- .18 7124... 2100 47418 12408_.... 63012 _....._.t6r2o 4rboBoh4 2222..37 1065 _-..%.D 2222 000115.....-_002010 a --_ ... 91 t 9 FLAT YF128FlexD 40 .... 50 1179 2100 49518 13517-'- 76.530 16120 C.,ba8.rrd 36 1100 14.0 00 01 15 002415 1212.__ 22222111_ -._ 22111212 2111 __._. 1122- 10 b 1 10 FLAT 1772864x( N SB 1129 2100 51618 74559 91,088 1sr2oc b.eorre 36 Tl� 189 0001 75 003140 { 11111122. 2121._ 2212 6912-._1121 __. 11212221._ is t f 1 FLAT 1672864x( 40 50 1279 7100 53718 14518 106625 1&20 carb.B.M 34 7169 10-0 0101:15 B0 3155 1121_ 1221.__ 2222. 1211 1251 m_r I 12 FLAT 1612864x0 40 100 1379 2122 .4200 57918 3292+ 134.547...1812oc b a ed --- 1231 184 000210 003025 1212 2222 1162_ 1121 2221__- 2121 1222 2222_.. 11120_203 1112 w 2121! 2222 FLUX VYF728 40 166 1545 2222 H52 64870 1395aT %6 1400 CO 00 NM 003033 .. .--__ ... 2121_-_61 ?a I RUSK 2222-_ F1eREe�oeac(. 15 __.33___. 1578 1408 WZ/6 -1112.. 139,547 33 7133 1222 00 1213 004046 I _-_ 1211... 1570 ._ 1121___ TOTALS _.. -_ 2221 .2111.._.. __. 130547 1433 MIRK The wellbore penetrates that reservoir at an inclination of -50 degrees at an azimuth of 350 degrees. The induced fractures are expected to propagate at 30 degrees west of north. Maximum Anticipated Treating Pressure: 4500 psi Maximum Allowable Treating Pressure: 5000 psi Surface pressure is calculated based on a closure pressure of -0.64 psi/ft or 5500 psi, this combined with the anticipated net pressure to be built, hydrostatics and the friction gives a maximum surface pressure of 4500 psi at the time of flush. Anticipated half length: 1 50' Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values, the above half length is calculated. Anticipated height growth: 90' The above frac dimensions were calculated using modeling software. The frac height is primarily based on closure pressure differences between the confining shale layers and the unconfined sandstone reservoir. Average confining layer stress is anticipated to be --0.7 psi/ft. Prior to fracturing operations, service coil will plug back to prevent a re-frac of old perforations. The target perforations are from 12,935'-12,945' • • Pressure Test Information (20 AAC 25.283,a,7) Per the drilling program, the both the tubing and the IA will be pressure tested. The IA will be tested to 4000 psi and the tubing will be tested to 4000 psi. The wellhead will be tested to 5000 psi, a tree saver will not be required. PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 5000 psi Stagger Pump Kickouts between: 4500 psi and 4750 psi (90%to 95% of MATP) Global Kickout: 4750 psi (95%of MATP) IA pop-off set pressure: 3000 psi (<75%of MIT-IA) Treating line test pressure: 6000 psi 50,000# 16-20 Carbolite, 90,000# 16-20 Sand Requirement CarboBOND, 3000#20-40 or 16-30 sand Minimum Water Requirement 1800 bbls(pump schedule: 1400 bbls) IA Hold Pressure 2700 psi (IA pop-off @ 3000 psi) OA Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r P1-23 Rig Up Inner Annulus Line6J/ Dessitometer 06 tes8 eD yu 1:"LApr'"'" caaaol Buu�T • • a3isssle •. ` I PLP i L - J • • Chemical Disclosure (20 AAC 25.283,a, 12) Client. BP I pioretfon Alaska Schlumberger Weit. P1-23 Basun/fiekl: Prudhoe Bay State Alaska County/Parish: North Dope Borough Case: 63427677_7055755 Disclosure Type Pm-Job Well Completed Date Prepared_ 8/10/2017 2.50 PM Report ID. RPT-501B5 fluid Name&Volume Additive Additive Description CoEce^rrar a Volume F112 5o1'1actart I Gal/1000Gal 6C,2 Gal • --- =r e - -- -- :Gal _.. -- -. _ Sal 53.-- -- YF128Flea[D:WF1.28 58,300 Gal .__ 1 - - .-- - '.i. - .- - 2 _ . 1- - 51275 _-.. --_ --_ -- .-. 1 - . -- S522-1620 _-_ aarse•^ - •-c-- 5526-1520 , e._ aa+ie- -- :- =45:.._._1.• mrol:WO rat,.rra.,r,.P.11,mo,a.vm.:47s e.suemtoetaw y.o..r..a.sa in.Alter-:_:_._ CAS Number Chemical Name Mass Frac-man - Water 1IL:al-g Mi, 'ate Supplied tty Client/' -77% 66402.684 : --.cl mares..chemicals -22% 64742-47-8 e- :;.-- ro reared6dut <1% 9000-30.0 <1% 14808447 _L,_ <1% 67-48-1 2�N.rd.. -- ., : - _ <1% 1319-33-1 _ - - <01% 7727-54-0 C- - :_ - .-.. _ _ <0.1% 107-21-1 _- _-_ : :- <0.1% 1310-73-2 ... - -= t 0.1 25038-72-6 Yr�Bide _ ..e-- -. ere:apoirtmer <0.1>,__-.� ..w 1303.96.4 ._.._. ._._.T.._.._.,..... _.A.. _ Sc:.. - - -3ecahyarate <.0.1% 31726-348 PallRoay-i - he mega-hydroxy- <0.01% 68153-340 = -._.- - - _ <001% 110-17-8 . --_- _u::.c <001% 91053-39-3 :-s :- e. <ot% 68131-39-5 Ai:'-: _. - <001% 7631-4(-9 - .. _ , --- <0.001% 14807.966 - -_:_ - _- <0001% 10377-60-3 --_, . :._ <0. 01% 61789-77-3 <01101% 26172-55-4 <1131101% 7786-30-3 _ .- < % $40 ..—.. <omi% 595585-15-2 _ .-_ <0001% 125005-87-0 ,-_.... _ r=-:.._ _.. <0.001% 67-63-0 _.-. =r,ca: -r- <00001% 2682-20-4 ...2-methyl2h-nothia:o1-3-care <00001% 14464.46-1 Ctstabalite <00001% • • Wellwork Procedure Request To: D. Scarpella/A. Bass: Boss-men Date: 8/15/2017 R. Mielke/C. Olsen: Coil and Well Testing Supt. VER1 L. Seymour/ R. Burnett: Well Support Supt. AFE: XXX From: David Wages IOR: XXX Est. Cost: XXX Subject: P1-23 - Pre/Post Frac Procedure Please perform the following steps 1. W Install TWC, test tree to 5000 psi, PPPOT/service wellhead 2 S Drift, Install plug/catcher in XN, Pull LGLVs, Install Dummy valves 2-5, load IA, dummy station 1, MIT-T, MIT-IA, pull plug/catcher 2. F Assist SL MITs 3. E Install IBP 4. S Place sand plug 5. F Hydraulic Fracture Treatment 5. CP Contingent FCO 6. S D&T, Install GLVs 7. C Post frac FCO 8. T Post frac flowback Current Status: Operable Minimum ID: 3.725" at @ 12698' MD. 4-1/2" XN-Nipple Max Deviation: -55 deg at 4300'- 13,432' MD Tbg Tail Deviation: 52 deg at 12,900-13,432' MD Last TD Tag: 9/23/2016: SL 35' x 2-7/8" dummy drift Last Downhole Op: 11/7/2016, SL pull SLB DHSI tool and gauges from X-nipple @ 12,660' SBHP/SBHT: 4019 psi @ 8800' Latest H2S: 70 ppm, 4/2/2017 Program Contacts Contact Phone -Work Phone - Mobile Interventions Engineer David Wages 907-564-5669 713-380-9836 Pad Engineer Katie Burton 907-564-5554 907-360-6002 Pad Engineer Lea Duong 907-564-4840 720-951-7238 Pagel 1 of 8 • . Well Summary: P1-23 has been shut-in since 2012, and was SI prior to this from 2005-2011, due to slug flow which is unmanageable at the plant and on pad. It will flow Obbls for 20 minutes then upwards of 10,000bpd rates for-20 minutes. It is considered operationally challenging and has spent little of the last 10 years online due to this flow regime. The well was brought back online fall 2016 with the purpose of testing the current WC and evaluating pressure data to evaluate for a frac, it has been online since. Despite this, the current production is already at risk of getting SI due to this behavior- based on historical treatment of the well and on-time. The frac is anticipated to help stabilize flow outside the slugging regime which not only protects current production but also enhances production. History: 11/2016: SL pull DHSIT and gauges from X-nipple @ 12,660' 10/2016: SL set DHSIT and gauges 10/2016: Testers obtain well tests to confirm WC 9/2016: E-line — perforate @ 6 spf fr. 12,994'-13,054' 9/2016: SL-install LGLVs for well test 9/2015: MIT-IA to 3974 psi 9/2016: MIT-T to 4500 psi 9/2016: SL-circ in diesel Objectives: • Frac and pop P1-23 1.1 Critical Issues: Latest MIT-T: 9/24/2016 to 4500 psi for pre-frac screening Latest MIT-IA: 9/25/2016 to 3974 psi for pre-frac screening Latest Caliper: 3/5/2015, tubing OK. 1.2 Pressure Prediction: Reservoir Pressure Latest BHP survey in P1-23 was 3/2015 and came in at 4019 psi at 8800' Page j 2 of 8 i • Procedure 1. Wellhead- PPPOT/service wellhead a. Have Wellhead crew service the wellhead and tree. b. Install TWC c. Pressure test tree to 5000 psi high i. The tree is the weak point in the system during the frac and will determine our max treating pressure d. Pull TWC 2. Slickline- Drift, Install plug in XN, Pull LGLVs, Install Dummy valves, Circ 9.8# brine w/ freeze protect, install dummy in sta 1, pull plug a. Drift to deviation for 3-3/8" IBP b. Install plug in XN profile at 7640' c. Pull LGLVs d. Install Dummy valves in stations 2-4. e. Circ Inhibited Brine, freeze protect with crude or diesel to 2500' in the tubing and IA. i. Total volume (tbg+IA) is 411 bbls to station 1 is 412 bbls ii. Freeze protect volume to 2500' is 82 bbls (tbg+IA) iii. Lead with crude/diesel spear f. Dummy Sta 1 g. MIT-T to 4000 psi target i. Max Applied pressure: 4500 psi ii. Do not hold pressure on the IA during MIT-T h. MIT-IA to 4000 psi target i. Max Applied pressure: 4500 psi ii. Do not hold pressure on the tubing during MIT-IA NOTE: It is OK for final pressure to drop slightly below the target pressure if MIT criteria is met. The frac crew can reduce Max treating pressure if necessary. If it does, please note in AWGRs and advise Special Projects i. Pull XN plug Fullbore-Assist SL with circ and MITs 3. E-line- Install IBP a. RU E-line b. Install 3.380" IBP @ 12,985' i. - 10' above perforations from 12,994'-13,054' ii. Max differential is 6500 psi, sand plug is required as max expected differential is 1000 psi. 4. Slickline- Dump bail sand plug Page 13 of 8 • a. Dump bail 20-30' of sand on top of the IBP i. 7" 29# casing requires 22.2# sand/ft to fill. ii. Total sand requirement should be 440#-660# sand (plan on 500-600#s dumped) iii. Note that the frac crew can place this plug if necessary 5. Special Projects- Hydraulic fracture treatment NOTE: If Slickline did not dump bail sand, the frac crew will place the sand volume during the injection test/DataFrac. a. Frac well per pump schedule Pressure testing Maximum Allowable Treating Pressure: 5000 psi (or WH test pressure) Stagger Pump Kickouts between: 4500 psi and 4750 psi (90% to 95% of MATP) Global Kickout 4750 psi (95% of MATP) IA pop-off set pressure 3000 psi (75% of MIT-IA) Treating Line Test Pressure 6000 psi 50,000# 16-20 Carbolite, 90,000# 16-20 Sand Requirement CarboBOND, 3000# 20-40 or 16-30 sand Minimum Water Requirement 1800 bbls (pump schedule: 1400 bbls) IA Hold Pressure 2700 psi (IA pop-off @ 3000 psi) OA Monitor and maintain open to atmosphere 6. Pending Coil- Contingent FCO a. See Appendix A - CT Screenout FCO Procedure b. Pull IBP 7. Slickline- D&T, Install Generic LGLVs a. D&T b. Install Generic LGLVs i. This step can be moved to after the post frac FCO/millout if sand top is expected to be above the sleeve or if a hard screenout occurred. 8. Coil- Pull IBP a. Ensure the well is flowing while performing FCO i. Reservoir gradient (0.45 psi/ft) should allow for returns while FCO. b. If unable to pull the IBP during the post frac FCO due to losses, pull while the well is flowing. 9. Flowback a. See Appendix B - Test Separator Additional Flowback Procedure Page 14 of 8 • • Appendix A - CT Screenout FCO/Millout Procedure i. This is a generic FCO/millout procedure for a post screenout FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the event. ii. The objective of this procedure is to get the well cleaned to continue frac operations or to prep the well for POP. iii. Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure b. MIRU CT c. MU BHA. d. RIH down to estimated sand top and begin cleaning out with slick 1% KCL. e. Continue down to —12835' CTMD. At this point we are 100' above the uppermost perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the sleeve. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. f. Slowly continue to clean out until returns fall off to —80%. If returns are still good even after the nozzle is past the sleeve (not likely but possible), continue to clean out to IBP i. If returns are too low, it may be necessary to pull the IBP after LGLVs are installed. g. Once IBP is clear of sand, RIH and pull IBP. h. FP to 2500'. i. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. j. RDMO. Page 15 of 8 • • Appendix B - Test Separator Additional Flowback Procedure 1. MIRU ASRC. RU equipment to in a manner that allows CT to RU if an additional FCO is necessary. 2. POP the well to ASRC at minimum choke. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, increase the production rate to 1000 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, allow well to flow to 1500 BLPD. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 500 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 6. Once at FOC, stabilize the well for 4 hrs. Obtain a 3 hr purge, 8 hr welltest. Page 1 6 of 8 TREE= • ACTUATOR WELLHEAD= CTw P 1 _2 3 HANGER: FMC GEN 330'M D w CSG. ACTUATOTOR= BAKER C KB.REV= 43.1' REF ELB/= 43.1' BE T3.EV= 12.08' KOP= 1737' MiX Angle= 58"@ 8295' 2096' --I4-1/2"CAMCO BAL-O-SVLN,D=3.812" Datum MD= 12856' L�tum TVD= 8800'SS 9-5/8"CSG,40#,L-80,D=8.835" H 4043' GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" @ 12698' 1 4748 4080 55 KBG-2-LS DOME NT 16 09/28/16 -1/2" HES XN NIPPLE 2 7797 5867 52 IBG-2-LS DOME NT 16 09/28/16 3 9482 6832 54 KBG-2-LS DOME NT 16 09128/16 4 11158 7821 54 KBG-2-LS DOME NT 16 09/28/16 -rn C. / ). ,Z J --- 5 12589 8680 53 KBG-2-LS SO NT 22 09/28/16 r CSG,26#.L-80,D=6.276" --{ 12450' r/ �--I 12654' H7"BKR S-3 PERM PKR,D=3.875" ' 12687' H4-1/2"HES X MP,D=3.813" 12698' H4-1/2"HES XN MP,ID=3.725" 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958" H 12709' --I 12709' H4-1/2"YVLEG,D=3.858' 12693' --I H.MD TT LOGGED 08/19/96 1 Z`P35f PERFORATION SUMMARY FEF LOG:DIEL ON 08/05/96 ANGLE AT TOP F'lRF:50'@ 12935' _ Note:Refer to A oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 12935-12945 0 07/23/03 2-1/2' 6 12994-13054 0 09/29/16 _ 3-3/8" 6 12994-13074 0 08/19/96 2-7/8' 6 13115-13135 0 08/10/11 2-7/8" 6 13140-13180 0 07/23/03 I 13 — 3 4-0 . pexi,' 2-7/8" 6 13220-13240 0 07/22/03 — I 'i" — 37.2.o 4c. mac . 12,130 — — >L‘1a PBTD H 13337' 7"CSG,29#,13-CR D=6.184" H 13423' 1 '''''''''•� DATE REV BY COMvB'ffS DATE REV BY COMMENTS PONE MCNTY RE UNIT 08/11/96 ORIGINAL COMPLETION 10/04/16 GJB/JT4D SET FLO TI-RU St1B w/GAUGES VVELL: P1-23 08/12/01 R4Y9P CORRECTIONS 11/03/16 ZV/JMD RLL FLO TI-RU-SET X LOCK w/EO DEV&GA PERMIT No: 1961240 01/12/16 GE/J1/13 SET 4-1/2"PX RUG(01/08/ 11/08/16 JUJM) RJLLTB)X LOCK w/EQ DEV&GAUCCS(11/6/16 AR No: 50-029-22690-00 09/29/16 JTG/JMD FULLED PX RUG(09/23/16 08/16/17 JNUJM)ADDED REF/BF ELEV&FIXED 7"CSG DEPTH SEC 16,T12N,R14E 4869.21'FR&578.82'FNL 09/29/16 JTG/JMD GLV GO(09/28/16) 10/03/16 MRDIJNO ADFE RFS(09/29/16) BP Exploration(Alaska) • • TubeMove Analysis: ,- 1 _ !oo Y c V r S • • •'o-, �...... ♦► i m . 1 • pR a .(;:y•r4 1•t 12 v. m :..i. i --� t V ' �yo v 1 -. 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Q C • .� �L N 3 o0 lID Lim al t74 ro - O c0 Z L Q = a M M m 00 N N Ln a 2 N V C0 Q 0 s a ra L L. L a V V 0 • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, September 26, 2017 6:53 AM To: Davies, Stephen F(DOA) Subject: RE: P1-23 Faults Steve, Below is the answer to question 3 from our eolo ist/Peto h list: 3. How confident is CPAI in the location of the fault? Medium confidence.Was it mapped using 3D seismic data? Yes. What is the spacing of the lines(bin size)in this area?Pt. McIntyre:82.5 ft x 82.5 ft Can you provide an estimate of possible position error for this fault(uncertainty ellipse dimensions)?300-350ft of positional uncertainty of fault placement. From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent:Tuesday, September 19, 2017 6:19 PM To: Wages, David Subject: RE: P1-23 Faults David, I have a couple of additional questions due to the proximity of the proposed fracturing perforations and the nearby fault: 1. What is the distance(in feet)from the proposed fracturing perforations to the fault that lies to the west? 2. How confident is CPAI in the location of those proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth?(See http://petrowiki.org/Directional survey errors) 3. How confident is CPAI in the location of the fault? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault(uncertainty ellipse dimentions)? 4. I see two predominant trends in the faults on BP's map for P1-23, north and northwest. What is the basis for CPAI's belief that the induced fractures will trend 30 degrees west of north? 5. What are CPAI's contingency plans should there be indications that the induced fracture(s) has(have) encountered a naturally occurring fault or fracture zone during pumping operations? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Friday, September 22, 2017 1:04 PM To: Davies, Stephen F (DOA) Subject: RE: P1-23 Faults To answer your questions: 1. Approx 1300' 2. 107.2' in the major axis and 18.8' in the minor axis. Minor axis is azi 9.37 deg. 3. Working on that answer... 4. Borehole breakout data along with tiltmeter data obtained on the slope are the basis for the direction of the fracs. Combine that information with investigation into the fracs performed since the implementation of the new hydraulic fracturing regulations which suggest that we have not frac'd into a fault (as indicated by a sudden, unexpected drop in pressure) means that our fracs are indeed growing in the general direction expected. 5. Per the sundry packet, if a sudden, unexpected drop in treating pressure is seen, pumping operations will cease. Anything else, please let me know, David Wages From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, September 19, 2017 6:19 PM To: Wages, David Subject: RE: P1-23 Faults David, I have a couple of additional questions due to the proximity of the proposed fracturing perforations and the nearby fault: 1. What is the distance (in feet) from the proposed fracturing perforations to the fault that lies to the west? 2. How confident is CPAI in the location of those proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth? (See http://petrowiki.org/Directional survey errors) 3. How confident is CPAI in the location of the fault? Was it mapped using 3D seismic data? What is the spacing of the lines (bin size) in this area? Can you provide an estimate of possible position error for this fault (uncertainty ellipse dimentions)? 4. I see two predominant trends in the faults on BP's map for P1-23, north and northwest. What is the basis for CPAI's belief that the induced fractures will trend 30 degrees west of north? 5. What are CPAI's contingency plans should there be indications that the induced fracture(s) has(have) encountered a naturally occurring fault or fracture zone during pumping operations? Thanks, Steve Davies AOGCC 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 1 you are an unintended recipient of thise-mail, please delete it,without first saving or fording it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Monday, September 18, 2017 3:43 PM To: Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject: FW: P1-23 Faults Steve, Please see below a fault map showing fault magnitude, please advise if you need anything else. From: King, Sarah Sent: Monday, September 18, 2017 1:57 PM To: Wages, David Cc: Swanson, Mark; Fishter, Kristin (E)0XONMOBIL) Subject: RE: P1-23 Faults Hello, Here is a map with more details about the faults we were discussing last week. Please let me know if there is anything else that you need. Sarah King 2 • • NOTE: SHOWING Al. P s. Well does not 4:oss fault.The well ��. „'° is drilled in the ft•twall of the ,, , NeN ^, fault. P240 4$0,16 ,If x r, et 0 # �'®kt co' eioW k atilt s &t s a . „fpa Max throw in 0. ,�.up ru i a A22 `''mo oy " 910tr wa x e srxi LittA $SS`001.19 9 1 �n ' 'a '0 d ,,, �1 tO t 44...S ;Ai fig° ',ice-" ,,,,,a, {a , D T. id..� IMGs # F 40, 4 - ePi , ° ._ ,+ ' T a r " ro t , or .49 e,• a , i it" .,"*a9y a r 1#it lft P1-1 p i" a a. 20 " .„,,,414100. d .,.�ti*Go 't6j �' a ,' " '''' - I f t4i, - - ." 1 1 0 4 9 P I- f 2 sraaf►l0 1 y9.>,,, SADI tee,<,. _,�.a ,`. �- ,__m—. ._.--...,.._ .. ...............c..._.... ........... .. e .1,k I ..... ..».m_._.,a. {811!" 0 {{ 670100 From: King, Sarah Sent: Thursday, September 14, 2017 11:30 To: Wages, David 3 • • Cc: Swanson, Mark Subject: P1-23 Faults Hello! I am looking into the faults around P1-23.The fault running N/S has been identified, however the E-W fault(s) are not as obvious to find. I am looking into it, but will probably have to get back to you next week. Thanks, Sarah King GPMA Geologist Cube 5748 W:(907)564-4841 C:(970)274-9398 4 Guhl, Meredith D (DOA) etico91 From: Guhl, Meredith D (DOA) Sent: Tuesday, September 19, 2017 8:54 AM To: Davies, Stephen F (DOA) Subject: RE: PTU P1-23 logs (Permit 196-124) Steve, I filed this with the other data in T24691 and imported it into RBDMS and Geographix. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhi(a)alaska.gov. From: Davies,Stephen F(DOA) Sent: Friday,September 15, 2017 3:35 PM SCANNED , , i;v To:Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: FW: PTU P1-23 logs(Permit 196-124) Meredith, Please add this to the DigLogs digital well log files for PBU P1-23(Permit 196-124). Thanks, Steve D. 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Wednesday, September 13, 2017 1:50 PM 1 . • • To: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Cc: Hecker, Dodie<Dodie.Stinson@bp.com> Subject: FW: P1-23 logs Steve, Please see attached the logs for P1-23, working on the map now. From: Hecker, Dodie Sent: Wednesday, September 13, 2017 1:42 PM To: Wages, David Subject: RE: P1-23 logs Hi Dave, Attached is the .las for the raw logs for P1-23. Thanks, Dodie From: Wages, David Sent: Wednesday, September 13, 2017 1:26 PM To: Hecker, Dodie Subject: FW: P1-23 logs Hey Dodie, Could you point me in the right direction? Looking for maps and logs per Steve's request below. Thanks! From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, September 13, 2017 1:03 PM To: Wages, David Subject: FW: P1-23 logs Hi David, I finally got the time to get back to reviewing this sundry application. The fault map that you sent on 9/8 is for a 1.5 mile radius around well P1-20 rather than well P1-23. My original questions and request were: 1. The map that displays faulting within 1/2 mile of the P1-23 well does not contain a scale, and the direction and amount of vertical displacement for those faults is not marked. Could BP please provide that information? How far does Fault 1 lie from the planned fracture interval in P1-23? 2. I'm reviewing BP's application to fracture stimulate PBU P1-23, and I noticed that the AOGCC's digital data file for this well is corrupt—it will not load into my geoscience workstation, and Schlumberger's Toolbox software cannot open it. Could BP please provide a copy of this digital data file to the AOGCC? A file in LAS format would be best, but we can open .LIS, .TAP,or.DLIS format files. The PDF file of the log helps, but I would like to replace the corrupt digital data file.Just standard well log curves: gamma ray, resistivity, neutron,density,sonic, caliper, and SP (if you have it). I don't want BP's interpretative logs.The digital data file that you sent on 8/29 were for well P1-20 rather than well P1-23 2 • • Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Friday,September 8, 2017 8:33 AM To: Davies, Stephen F(DOA)<steve.davies@alaska.gov> Subject: FW: P1-23 logs Steve, Does the attached work? Please also see the fault map included. Thanks, David From:Wages, David [mailto:David.Wages@bp.com] Sent:Tuesday,August 29,2017 1:00 PM To: Davies, Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124,Sundry 317-396)- Data Request Apologies, P1-20 will be headed your way soon From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Tuesday, August 29, 2017 9:15 AM To: Wages, David Subject: FW: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request David, I just noticed that the file name is P1-20,and there is no log name or log_ID in the header for the electronic file. The well information that I need is for P1-23. Is this the correct file but just miss-labeled, or an incorrect file? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Tuesday,August 29,2017 8:16 AM 3 • • • To: Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396)- Data Request Steve, Please see attached the well logs as requested. Our geologist is working on the fault information. Thanks From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, August 28, 2017 3:42 PM To: Wages, David Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Just standard well log curves: gamma ray, resistivity, neutron, density,sonic, caliper,and SP(if you have it). I don't want BP's interpretative logs. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Monday,August 28, 2017 3:39 PM To: Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396)- Data Request Steve, could you please specify which logs you'd like? Is just gamma ray fine?Or do you need RHOB, porosity.. do you want our interpretations of permeability? I ask because I quite simply don't know what you typically use or if there is certain confidential information that we are not required to send. I will ask around the office but a short list from you would help. Thanks, David From: Davies, Stephen F (DOA) [mailto:steve.davies@ alaska.gov] Sent: Monday, August 28, 2017 3:35 PM To: Wages, David Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Thanks David, it's our digital well log file that is corrupt. We have the directional survey data. Thanks, Steve Davies 4 AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Monday,August 28,2017 2:26 PM To: Davies, Stephen F(DOA)<steve.davies@alaska.gov> Cc:Guhl, Meredith D (DOA)<meredith.guhl@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124,Sundry 317-396)- Data Request Steve, Are you looking for logs?Surveys? Please advise what exactly you'd like and I can do my best to get it headed your way. Thanks, David From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, August 28, 2017 12:52 PM To: Wages, David Cc: Guhl, Meredith D (DOA) Subject: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request David, I'm reviewing BP's application to fracture stimulate PBU P1-23, and I noticed that the AOGCC's digital data file for this well is corrupt—it will not load into my geoscience workstation, and Schlumberger's Toolbox software cannot open it. Could BP please provide a copy of this digital data file to the AOGCC? A file in LAS format would be best, but we can open .LIS, .TAP, or.DLIS format files. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 5 • • Wallace, Chris D (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, September 19, 2017 12:08 PM To: Wallace, Chris D (DOA) Subject: RE: PBU P1-23 (PTD#1961240, Sundry#317-396) -Application to Fracture Stimulate - Request for Additional Information Chris, This is a standard frac down jointed tubing, no coil involved unless we need to do a cleanout. When we sent in L-200a's sundry(216-250) I included that request.The purpose of the request is clarify which wells we are looking into detail for the wells within 1/2 mile.The justification being that we are pressure testing the tubulars and verifying cement tops,this should provide the safety margin required from the top of the fractured interval to surface. We then investigate all wells within%2 mile of the wellpath that is in the fractured interval.This provides the safety insurance for the wells For the top of cement we have a temp log giving a cement top at 12,280' MD which correlates to 8449',top of Kuparuk per Geologic Frac Information is at 8824'. Please advise if you need anything else! David From:Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Tuesday, September 19, 2017 9:26 AM To: Wages, David Subject: PBU P1-23 (PTD #1961240, Sundry #317-396) -Application to Fracture Stimulate - Request for Additional Information David, We are progressing the application but I have a few questions. Am I correct in assuming this will be a straight tubing frac without coil ? Or is it down the coil/tubing annulus similar to L-200A frac? There is mention of a waiver request from 25.283(a)(10) and pressure testing of tubulars. What exactly is this request and why is it a new request for this well? Also, we cannot find BPXA interpretation of the cement tops for P1-23. Please provide with method determined etc and in future add this to 25.283(a)(5) or (6). Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax),chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, September 13, 2017 1:03 PM To: david.wages@bp.com Subject: FW: P1-23 logs Attachments: P1-23_sundry.pdf; P1-20_1.5mile_radius.pptx Hi David, I finally got the time to get back to reviewing this sundry application. The fault map that you sent on 9/8 is for a 1.5 mile radius around well P1-20 rather than well P1-23. My original questions and request were: 1. The map that displays faulting within%2 mile of the P1-23 well does not contain a scale, and the direction and amount of vertical displacement for those faults is not marked. Could BP please provide that information? How far does Fault 1 lie from the planned fracture interval in P1-23? 2. I'm reviewing BP's application to fracture stimulate PBU P1-23, and I noticed that the AOGCC's digital data file for this well is corrupt—it will not load into my geoscience workstation, and Schlumberger's Toolbox software cannot open it. Could BP please provide a copy of this digital data file to the AOGCC? A file in LAS format would be best, but we can open .LIS, .TAP, or.DLIS format files. The PDF file of the log helps, but I would like to replace the corrupt digital data file.Just standard well log curves: gamma ray, resistivity, neutron, density, sonic, caliper, and SP (if you have it). I don't want BP's interpretative logs.The digital data file that you sent on 8/29 were for well P1-20 rather than well P1-23 Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesc alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Friday, September 8, 2017 8:33 AM To: Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject: FW: P1-23 logs Steve, Does the attached work? Please also see the fault map included. Thanks, David From: Wages, David [mailto:David.Wages@bp.com] Sent:Tuesday, August 29, 2017 1:00 PM 1 • • To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Apologies, P1-20 will be headed your way soon From: Davies, Stephen F (DOA) [mailto:steve.davies@ alaska.gov] Sent: Tuesday, August 29, 2017 9:15 AM To: Wages, David Subject: FW: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request David, I just noticed that the file name is P1-20, and there is no log name or log_ID in the header for the electronic file. The well information that I need is for P1-23. Is this the correct file but just miss-labeled, or an incorrect file? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent:Tuesday,August 29, 2017 8:16 AM To: Davies, Stephen F(DOA) <steve.daviesPalaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396)- Data Request Steve, Please see attached the well logs as requested. Our geologist is working on the fault information. Thanks From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 28, 2017 3:42 PM To: Wages, David Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Just standard well log curves: gamma ray, resistivity, neutron, density, sonic, caliper, and SP (if you have it). I don't want BP's interpretative logs. Thanks, Steve Davies AOGCC 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 2 • • 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Wages, David [mailto:David.Wages@bp.com] Sent: Monday, August 28, 2017 3:39 PM To: Davies, Stephen F(DOA)<steve.davies@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396)- Data Request Steve, could you please specify which logs you'd like? Is just gamma ray fine?Or do you need RHOB, porosity.. do you want our interpretations of permeability? I ask because I quite simply don't know what you typically use or if there is certain confidential information that we are not required to send. I will ask around the office but a short list from you would help. Thanks, David From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Monday, August 28, 2017 3:35 PM To: Wages, David Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Thanks David, it's our digital well log file that is corrupt. We have the directional survey data. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Monday, August 28, 2017 2:26 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Guhl, Meredith D (DOA) <meredith.guhlPalaska.gov> Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396)- Data Request Steve, Are you looking for logs? Surveys? Please advise what exactly you'd like and I can do my best to get it headed your way. Thanks, David From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 28, 2017 12:52 PM 3 • To: Wages, David Cc: Guhl, Meredith D (DOA) Subject: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request David, I'm reviewing BP's application to fracture stimulate PBU P1-23, and I noticed that the AOGCC's digital data file for this g well is corrupt—it will not load into my geoscience workstation, and Schlumberger's Toolbox software cannot open it. Could BP please provide a copy of this digital data file to the AOGCC? A file in LAS format would be best, but we can open .LIS, .TAP, or.DLIS format files. Thank you for your help. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 4 • Davies, Stephen F (DOA) From: Davies, Stephen F(DOA) Sent: Monday, August 28, 2017 5:45 PM To: david.wages@bp.com Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) -Another Request David, The map that displays faulting within 1/2 mile of the P1-23 well does not contain a scale,and the direction and amount of vertical displacement for those faults is not marked. Could BP please provide that information? How far does Fault 1 lie from the planned fracture interval in P1-23? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@ialaska.gov. 1 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday,August 28, 2017 3:35 PM To: Wages, David Subject: RE: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request Thanks David, it's our digital well log file that is corrupt. We have the directional survey data. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Monday,August 28, 2017 2:26 PM To: Davies, Stephen F(DOA)<steve.davies@alaska.gov> Cc:Guhl, Meredith D (DOA)<meredith.guhl@alaska.gov> Subject: RE: PBU P1-23 (Permit 196-124,Sundry 317-396)- Data Request Steve, Are you looking for logs?Surveys? Please advise what exactly you'd like and I can do my best to get it headed your way. Thanks, David From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, August 28, 2017 12:52 PM To: Wages, David Cc: Guhl, Meredith.D (DOA) Subject: PBU P1-23 (Permit 196-124, Sundry 317-396) - Data Request David, I'm reviewing BP's application to fracture stimulate PBU P1-23, and I noticed that the AOGCC's digital data file for this well is corrupt—it will not load into my geoscience workstation, and Schlumberger's Toolbox software cannot open it. Could BP please provide a copy of this digital data file to the AOGCC? A file in LAS format would be best, but we can open .LIS, .TAP,or.DLIS format files. Thank you for your help. 1 • • Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, September 26, 2017 3:11 PM To: Wages, David Subject: RE: P1-23 Faults David, If I sketch the nearby fault in on my map using wells P1-01, P1-11, P1-21 and P1-24 as proportional guides,and then plot circles representing BP's estimated uncertainty of the fault location (about 300' radius) atop the fault trace, I get the map, below. It looks as if the distance from the fracturing perfs to the fault is more on the order of 250'than 1,300'that you estimate in answer 1, below. The regional stress direction reported by BP indicates the fractures should be induced along a direction that is about 30 degrees west of north, but due to the uncertainty of the fault position,the northern fracture wing could very well approach the fault closely. Accordingly,caution is strongly advised during BP's fracturing operation. Thanks, Steve Davies AOGCC 1 • • N''''''''''..... \\ \\\,,,..„....„ ......N.\\ .' 13800 600 13400 P#1 -0 1 13200 ••. 13000 ''f : 12800 i • . 12600 1 a +M 12400 13200 1220+ 13000 1 ,100 `-_ 12800 `` 12600 1800 12400 \ ,.-.. 11600 \ P1 -P , 4oa 12200 '1;14tt 12000 " 11200 ill200 f 11 01800 �1, `�1,� ��00 12800 "'`12600 1140010400 P1 -24 \ 12400 v__ 11200 10200 10000 Q _12200- ` 11000 98( 13000 - - 10800 f 12000 .+ —12800 ` 118045 1 0600 12 . . •i. • I Mins- i i 12600 — 10400 801.'P,.. 4�40a ,� , 11640 20, 00 . 114040200 13600 40 _ `y, ' 1120f�0000 300' 800 -12000 . 11800 \ 110 00 11600 r 1 — 1 '- 108000 11400 ---106M0Q 11200 11400--- 104@§00 11200-- 1020 —t1Q00 iinnn 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.com] Sent: Friday,September 22, 2017 1:04 PM To: Davies,Stephen F (DOA)<steve.davies@alaska.gov> Subject: RE: P1-23 Faults To answer your questions: 1. Approx 1300' 2. 107.2' in the major axis and 18.8' in the minor axis. Minor axis is azi 9.37 deg. 2 S • 3. Working on that answer... 4. Borehole breakout data along with tiltmeter data obtained on the slope are the basis for the direction of the fracs. Combine that information with investigation into the fracs performed since the implementation of the new hydraulic fracturing regulations which suggest that we have not frac'd into a fault(as indicated by a sudden, unexpected drop in pressure) means that our fracs are indeed growing in the general direction expected. 5. Per the sundry packet, if a sudden, unexpected drop in treating pressure is seen, pumping operations will cease. Anything else, please let me know, David Wages From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.00v] Sent:Tuesday, September 19, 2017 6:19 PM To: Wages, David Subject: RE: P1-23 Faults David, I have a couple of additional questions due to the proximity of the proposed fracturing perforations and the nearby fault: 1. What is the distance(in feet)from the proposed fracturing perforations to the fault that lies to the west? 2. How confident is CPAI in the location of those proposed fracturing perforations? What are the dimensions of the 2D ellipse of uncertainty in the directional survey data at this depth?(See http://petrowiki.org/Directional survey errors) 3. How confident is CPAI in the location of the fault? Was it mapped using 3D seismic data? What is the spacing of the lines(bin size)in this area? Can you provide an estimate of possible position error for this fault(uncertainty ellipse dimentions)? 4. I see two predominant trends in the faults on BP's map for P1-23,north and northwest. What is the basis for CPAI's belief that the induced fractures will trend 30 degrees west of north? 5. What are CPAI's contingency plans should there be indications that the induced fracture(s)has(have) encountered a naturally occurring fault or fracture zone during pumping operations? Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From:Wages, David [mailto:David.Wages@bp.coml Sent: Monday,September 18, 2017 3:43 PM To:Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject:FW: P1-23 Faults Steve, Please see below a fault map showing fault magnitude, please advise if you need anything else. 3 From: King, Sarah Sent: Monday, September 18, 2017 1:57 PM To: Wages, David Cc: Swanson, Mark; Fishter, Kristin (EXXONMOBIL) Subject: RE: P1-23 Faults Hello, Here is a map with more details about the faults we were discussing last week. Please let me know if there is anything else that you need. Sarah King 4 • • NOTE: SHOWING AL n • P2411 +F - 111* 4 • " Well does not , oss fault.The well ,., 0.4" is drilled in the f..twall of the "`�. 40 fault. r ', i°yD,,o ow,„to ba/o w ii„ fault T \5 lb .70 Max throw in Ku, aruk ' . ,,,,,„,14."*. hroly n Ku ii i Lott.%re,.. -.: .,,, , 4; 01,fra, _ 4034 • me a ,,e= • �, a-.s*/(/? .Q., 1f p -,00....." ' Inas. 1wMrn ' T+ S 0r1- offt• P1.2le .1 a }° I _ .. ii go - corn -c , Mn , �► c i If r� d © h CZ ...,, fir_ by ..,2000 NW 1 . Iwo tRE.a. Y C` iV 1�\ ..11600 MD -Is -"7t d 4... i M y A `�if - nes MO +t3 f '{� �0 ...fiat rD P1-21 .A'� °°MO ry Gt 2�.1 lino 100 �"r6rp .b � ,.` ib tt000 VD "4.40 '�� 46 t '147 $0•Dg MD j ,MIM 1� zMO. 1~ C2: Sit"fie?pr* 3 1021/1103 MO ' 4Iii $ IK7 -a 416 From: King, Sarah Sent: Thursday, September 14, 2017 11:30 To: Wages, David 5 Cc: Swanson, Mark Subject: P1-23 Faults Hello! I am looking into the faults around P1-23.The fault running N/S has been identified, however the E-W fault(s)are not as obvious to find. I am looking into it, but will probably have to get back to you next week. Thanks, Sarah King GPMA Geologist Cube 5748 W:(907)564-4841 C:(970)274-9398 6 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy ~incent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /s/ STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIOP REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 151 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ " 196 -1240 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 22690 -00 -00 8. Property Designation (Lease Number) : ` 9. Well Name and Number: ADLO- 034622 — P1 -23 10. Field /Pool(s): .. PRUDHOE BAY FIELD / PT MCINTYRE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13432 feet Plugs (measured) None feet true vertical 9203.68 feet Junk (measured) None feet Effective Depth measured 13337 feet Packer (measured) 12654 feet true vertical 9145.23 feet (true vertical) 8719 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 40 - 120 40 - 120 Surface 4004' 9- 5/8 "40# L -80 39 - 4043 39 - 3660 5750 3090 Production 11475' 7" 29# 13CR80 38 - 11513 38 - 8033 8160 7020 Production Liner Liner �• Perforation depth: Measured depth: SEE ATTACHED - Ara,t ,trio J E P C . 7 0 )'r — True Vertical depth: _ — .z. Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 37 - 12709 37 - 8753 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 12654 8719 ECE Wow+ 12. Stimulation or cement squeeze summary: -\UG 3 0 ?OP Intervals treated (measured): Mask' a 011 & Gas C+». Ga missiion Treatment descriptions including volumes used and final pressure: Ant 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 479 467 347 692 Subsequent to operation: 470 484 489 589 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IS ` Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . Kg Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na , - . Lastufk -w t Title Petrotechnical Data Technologist Signatu Milt Phone 564 -4091 Date 8/29/2011 i EIDMS AUG 31 2011 ,�j t I l ' Form 10 -404 Revised 10/2010 Submit Original n y P1 -23 196 -124 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P1 -23 8/19/96 PER 12,994. 13,074. 8,932.36 8,982.51 P1 -23 2/20/00 FIL 13,067. 13,337. 8,978.14 9,145.23 P1 -23 7/19/03 FCO 13,067. 13,300. 8,978.14 9,122.46 P1 -23 7/23/03 APF 12,935. 12,945. 8,894.98 8,901.33 P1 -23 7/23/03 APF 13,140. 13,180. 9,023.64 9,048.49 P1 -23 7/23/03 APF 13,220. 13,240. 9,073.23 9,085.55 P1 -23 8/10/11 APF 13,115. 13,135. 9,008.07 9,020.53 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 411 1 • P1-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/9/2011:***WELL FLOWING UPON ARRIVAL***(E-LINE PERFORA TING RECORD) INITIAL T/I/0 = 600/1050/900 SIGN PERMIT WITH DSO, SPOT EQUIPMENT, REBUILD HEAD, BEGIN LUBRICATOR PRESSURE TEST 1***JOB CONTINUED ON FOLLOWING DAY*** ' 8/10/2011 ***JOB CONTINUED FROM PREVIOUS DAY***(E-LINE PERFORATING RECORD) PERFORATED WELL WITH 20 FEET OF 2-7/8" PJ OMEGA 2906 HMX PERFORATION INTERVAL = 13115-13135 !GUN DATA: PENETRATION = 36", ENTRANCE HOLE = 0.34", 60 DEG PHASING, SPF FINAL T/I/0 = 750/1325/900 ***JOB COMPLETE***(WELL LEFT SHUT IN UPON DEPARTURE) FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL TREE = W • ELLHEAD= CIW SAFETY.: CHROME4 -1/2" TBG& 7" CSG. ACTUATOR = BAKER C p 1 _2 3 TUBING HANGER: FMC GEN 5 @ 30' MD. KB. ELEV = 43.1' • BF. ELEV= KOP = 1737' Max Angle = 58 @ 8295' [mil [ ' I Datum MD = 12856' 2096' I — 4 -1/2" CAMCO BAL -O -SVLN, ID = 3.812" Datum TVD= 8800'SS WRDP (CAMCO BTDP-1) 9 -5/8" CSG, 40 #, L -80, ID = 8.835" H 4043' I — i GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4748 4080 55 KBG -2 -LS DOME NT 16 Minimum ID = 3.725" @ 12698' 2 7797 5867 52 KBG -2 -LS S/O INT 12 09/14/03 4 -1/2" HES XN NIPPLE 3 9482 6832 54 KBG -2 -LS S/O INT 20 03/27/03 4 11158 7821 54 KBG -2 -LS DMY INT - 5 12589 8680 53 KBG -2 -LS DMY NT - I 7" CSG. 26 #. L -80, ID = 6.276" H 12450' I.--N E 1t 12654' H 7" BKR S -3 PERM PKR, ID = 3.875" I 1 1 1 12687' H 4 -1/2" HES X NIP, ID = 3.813" 1 1 I 12698' 1 - 1 4 -1/2" HES XN NIP, ID = 3.725" 1 1 4 -1/2" TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" I--I 12709' I 1 I 12709' H 4 -1/2" WLEG, ID = 3.858" 12693' H ELMD TT LOGGED 08/19/96 1 1 PERFORATION SUMMARY I REF LOG: DIFL ON 08/05/96 ANGLE AT TOP PERF: 50° @ 12935' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 12935 - 12945 0 07/23/03 3 -3/8" 6 12994 - 13074 0 08/19/96 2 -7/8" 6 13115 - 13135 0 08/10/11 " 2 -7/8" 6 13140 - 13180 0 07/23/03 I 2 -7/8" 6 13220 - 13240 0 07/22/03 1 I PBTD 1-I 13337' t j y 1' • ∎ • 1 ∎ � • � • 1 • 1 ! *00...4. �� 1 i �� 7" CSG, 29 #, 13 -C R, ID = 6.184" I J ( 11513' ' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS POINT MCINTYRE UNIT 08/11/96 ORIGINAL COMPLETION WELL: P1 -23 08/12/01 RN/TP CORRECTIONS PERMIT No: 1961240 03/28/03 JCM/TLH GLV UPDATE API No: 50- 029 - 22690 -00 7/22 -23/03 TG /KAK ADPERFS SEC 16, T12N, R14E, 4869.21' FEL & 578.82' FNL 09/14/03 JCM/TLP GLV C/0 I 08/15/11 TTR/ PJC PERFORATIONS (08/10/11) BP Exploration (Alaska) C BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 by ~'~~ ~-ra~- .,~ , ~ ~,~ Subject: Corrosion Inhibitor Treatments of GPMA P1 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA P1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al P1-01 1900270 50029220180000 NA 0.2 NA 1.70 7/6/2009 P1-02A 2020650 50029217790100 NA 0.1 NA 0.90 7/8/2009 P1-03 1890130 50029219120000 Cemented to flutes NA 0 NA 0.00 P1-04 1930630 50029223660000 NA 0.2 NA 1.70 7/8/2009 P1-05 1930870 50029223780000 NA 0.2 NA 1.70 7/18/2009 P1-os 1961370 50029226950000 Sealed conductor NA NA NA NA P1-07A 2040370 50029219960100 SC Leak NA NA NA NA P1-OSA 2021990 50029223840100 NA 1.2 NA 6.50 7/8/2009 P1-09 1961540 50029227040000 NA 14.5 NA 141.10 7/9/2009 P1-11 1920860 50029222840000 NA 0.2 NA 1.70 7/7/2009 P1-12 1910130 500292213aoooo NA 0.6 NA s.so 7n/2oos P1-13 1930740 50029223720000 NA 1.5 NA 10.20 7/6/2009 P1-14 1930160 50029223380000 NA 1.5 NA 10.20 7/6/2009 P1-16 1930340 50029223490000 NA 0.7 NA 6.80 7/6/2009 P1-17 1930510 50029223580000 NA 1.7 NA 11.90 7/7/2009 P1-18A 2020760 50029229530100 NA 1.8 NA 8.50 7/7/2009 P1-20 1920940 50029222880000 NA 0.6 NA 3.40 9/12/2009 P1-21 1930590 50029223630000 NA 0.6 NA 5.10 7/7/2009 P1-23 1961240 50029226900000 NA 1.6 NA 13.60 7/7/2009 P1-24 1961490 50029227030000 NA 10 NA 107.10 12/13/2009 P1-25 1890410 50029219370000 Sealed conductor NA NA NA NA P1-G1 1921130 50029222980000 NA 0.2 NA 1.70 7/6/2009 II"~ STATE OF ALASKA j~ ALAS ~ OIL AND GAS CONSERVATION C ,,,vlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonF~ Suspend[~ Operation Shutdown~-'~ Perforate, Variance[~ Annuar Disposal[~ After Casin~] RepairWellr'-~ Plu~ Perforationsl-'~ Stimulated Time ExtensionD OtherE] Change Approved Program[~ Pull Tubing[~ Perforate New Pool[~ Re-enter Suspended Wellr-~ ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [~ ExploratoryF~ 196-124 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic ~] Service, 50-029-22690-00-00 7. KB Elevation (ft): 9. Well Name and Number: 45.00 P1-23 8. Property Designation: 10. Field/Pool(s): ADL 034622 Prudhoe Bay Field ! Point Mclntyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 13432 feet true vertical 9204 feet Plugs (measured) Effective Depth measured 13423 feet Junk (measured) true vertical 9198 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 120' 120' 40K 520 Surface 4003' 9-5/8" 4043' 3660' 80K 6280 Production 13383' 7" 13423' 9198' 80K 7020 Perforation depth: Measured depth: Open Perle 12935'-12945', 12994'-13074', 13140'-13180', 13220'-13240'. True vertical depth: Open Perle 8895'-8901', 8932'-8983', 9024'-9048', 9073'-9086' , · Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# 13-CR TBG @ 12709'. Packers & SSSV (type & measured depth) 7"x4-1/2" Baker S-3 PERM PKR @ 12654'. 4-1/2" Camco BAL-O SVLN @ 2096'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Avera.qe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 390 215 585 761 Subsequent to operation: 538 306 787 766 14. Attachments: 15. Well Class after proposed work: Exploratoryr-1 DevelopmentE~ Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: oilr'-] Gasr"l WAGI-'I GINJr-] WINJB WDSPLI--I Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name,~ ~_;. ,~2/)DeWar/ne R. Schnorr Title Techical Assistant Signature ~'~~~~~ Phone 907/564-5174 Date Sept24,20_03 lt its . l. Form 10-404 Revised 2/2003 P1-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/03/2003 07/19/2003 07/22/2003 07/22/2003 07/23/2003 PERFORATING: DRIFT/TAG HYDRATE / ICE PLUG: FILL CLEAN OUT PERFORATING: PERFORATING PERFORATING: HOT OIL TREATMENT PERFORATING: PERFORATING 09/17/2003 TESTEVENT --- BOPD: 649, BWPD: 679, MCFPD: 4,388, AL RATE: 4,162 07/03/03 EVENT SUMMARY DRIFT W/2 7/8" DUMMY GUN / TEL / SB TO 13,046' CORRECTED TO ELM (NO SAMPLE) - NOTIFY DSO OF WELL STATUS **WELL LEFT SHUT IN** 07/19/O3 FCO; MIRU DS CTU #9. WELL IS SHUT-IN. OPEN WELL TO FLOW. RIH WITH 3.0" JSN. CLEAN OUT TO 13300' CTMD USING FLOPRO SWEEPS TO THE TAIL (40 BBLS TOTAL). FREEZE PROTECT WELL TO 2500' WITH 50/50 METHANOL. LEAVE WELL SHUT-IN FOR E-LINE TO ADD PERFS. NOTIFY DSO OF WELL STATUS. RDMO. <<< JOB COMPLETED >>> O7/22/O3 PERFORATE 13420 - 13440' MD WITH 2 7/8" HSD, 2906 POWERJETS @ 6 SPF. DEPTHS REF TO ATLAS DIL LOG 8/5/96. RAN INTO A BRIDGE @ 1684'. SUSPECT HYDRATES, SO PUMPED 13 BBLS METHANOL BEFORE WHP DROPPED AND GUN STARTED TO FALL. TAGGED TD @ 13284'. WHP BEFORE AND AFTER PERF - 500 PSI. RETURN ON 7/23/03 TO PERF REMAINING 50'. <<< LEFT WELL SHUT IN >>> 07/22/03 ASSIST E-LINE WITH HYDRATE/ICE PLUG. 07/23/03 PERFORATE 13142'-13182' AND 12937'-12947'. CORRELATE TO SWS PERF RECORD 8/19/1996. LOG FROM TD **13281'** to 12550'. WELL SHUT IN UPON. CHARGE DATA: 2906 PJ 6 SPF, 27.1" PENE, 0.36" EH, 15 GMS. 09/22/03 TESTEVENT --- BOPD: 649, BWPD: 679, MCFPD: 4,388, AL RATE: 4,162 FLUIDS PUMPED BBLS 3 PUMPED DIESEL FOR PRESSURE TEST. (3 TESTS) 50 DIESEL 90 50/50 METHANOL WATER 35 METHANOL 820 1% EXTRA SLICK KCL WATER 40 FLOPRO 1038 TOTAL Page 1 P1-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 07/18/2003 THE FOLLOWING INTERVALS WERE PERFORATED WITH 2-7/8" 2906PJ POWERJET GUN, LOADED AT 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 12937' - 12947' 13142'- 13182' 13420' - 13440' Page 2 STATE OF ALASKA ALASK :'~IL AND GAS CONSERVATION COMMI[ .)N REPOR! OF SUNDRY WELL OPERATIONS · Operations performed: Operation shutdown __ Stimulate.L~ Plugging__ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address 100360, Anchorage, AK 99510 P.O. Box 4. Location of well at surface 3905' FNL, 949' FEL, Sec. 16, T12N, R14E At top of production interval At effective depth At total depth 578' FNL, 4869' FEL, Sec. 10, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KB 45 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P1-23 9. Permit number/approval number 96-124 / 10. APl number 500292269000 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 80' 20" Surface 4043' 9 5/8" Intermediate Liner 12450' 7" 13432 feet Plugs (measured) 9204 feet 13423 feet 9204 feet Cemented Junk (measured) 260 sx Arcticset 1152 sx CS III, 759 sx Class 'G' & 250 sx CS III 258 sx Class 'G' None. None. Measureddepth Truevedicaldepth 80' 80' 4043' 3660' 12450-13423' 8597-9198' Perforation depth: measured 12994-13074' true vertical 8887-8937' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 13CR @ 0-12709' MD Packers and SSSV (type and measured depth) 3 7/8 x 7 PKR @ 12654' MD, 3 4/5 x 4 1/2 WRSSSV @ 2096' MD RECEIVED JUL 22 1999 Alaska 0ii & Gas Cons. Commission Anchorage 13. stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. ORIGINAL 14. Oil-Bbl Prior to well operation n/a Subsequent to operation 1619 Representative Daily Average Production or Iniection Data Water-Bbl 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certiflj that the foj~goi.~s true' and S 'gned ,~-~-~~~~'" ~~ Gas-Mcf Casing Pressure n/a n/a n/a 1164 631 770 Tubing Pressure n/a 1339 I 16. Status of well classification as: Oil~ Gas Suspended __ correct to the best of my knowledge. ..,.-, Title ~/'~" ~ 1 A./[~,,_.. Date Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P1-23 Data Frac 10/6/96 1 RU frac equipment. Pressured up backside to 3500 psi. Held pre-job safety meeting 2 Screen out w/12# at perfs, (12994-13074' MD). Prop pumped was 213,759#, Prop in perfs is 163,434#. Prop in pipe is 54,731 (estimated sand top at 2,000'). Average psi is 3200. Frac gradient is .72. 3 RD 10/7/96 4 RU equipment FCO (post frac) to 13300' MD. Well cleaning up before rupturing coil tubing at 7840'. SD pump and was able to spool damaged section on reel. Kept well head pressure down. OOH and secure well and coil. 6 RD 10/9/96 7 RU and RIH w/4-1/2" GS to -3' SLM, POOH, OOH Tools covered w/ice 8 RD 10/26/96 9 RU and RIH w/CT 10 FCO'd Frac sand to PBTD @ 13317' CTM, left well FP'd and ready for post fac w/I work. RD Well' P1-23 WRSSSV-- PKR -- NIP -- NIP -- Perf -- GPMA WEB Date' 4/16/99 P1:~23 :: i :: APl: 5002922690~)-0 Well Type: PROD Angle @ TS: deg @ SSSV Type: CAT I - SSSV Annular Fluid: AL GAS T Reference DIFL Log: Last Tag: 13100' SLMD-CORR Last Tag Date: 5/16/98 Orig Compltn: 8/11/96 Last W/O: Ref Log Date: 8/5/96 TD: 13423 ftKB Max Hole 58 deg @ 8295 Anqle: Angle @ TD: 52 deg @ 13432 Rev Reason: RAN SSSV Last Update: 10/1/98 :Safety: Notes Date Note 8/8/96 Minimum ID: 3.725" OTIS XN NIPPLE AT 12698' MD Genemt Notes Date Note 8/8/96 Well Status: ACTIVE 8/8/96 Tubing Hanger: FMC GEN 5 @ 30' MD Last Tag Depth @ 13432 Top Of Fluid Depth @ 12878 Other: (plugs, :equip., etc.)- JEWELRY Depth TVD Type Description 2096 2082 WRSSSV 4-1/2" CAMCO BAL-O-SVLN, ID=3.812" - w/SSSV ( ran 9/25/98) 12654 8719 PKR BAKER 7" S-3 PERMANENT PACKER, ID=3.875" 12687 8739 NIP HES 'X' NIPPLE, ID = 3.813" 12698 8746 NIP HES 'XN' NIPPLE, ID = 3.725" 12709 8753 TT TUBING TAIL WI WIRELINE ENTRY GUIDE, ID=3.858"; 12693' ELMD ID 3.812 3.875 3.000 4.000 3.858 Casing :Strings, All Size Weight Grade Top Btm Feet Description 9.625 40.00 L-80 0 4043 4043 SUR. CASING 7.000 26.00 L-80 0 12450 12450 PROD. CASING 7.000 29.00 13CR 12450 13423 973 PROD. CASING TUbing:strings - All ~Size Weight Grade Top Btm Feet Description 4.500 12.60 13CR 0 12709 12709 TUBING Gas Lift Mandrels/Valves I Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4748 4080(BG-2-L,~ CA BK-1 1.0 BTM 0.250 2475 7/11/98 INT 2 7797 5867(BG-2-L,~ CA BK-1 1.0 BTM 0.250 2513 7/12/98 INT 3 9482 6832(BG-2-L,~ CA DK-1 1.0 BTM 0.000 0 7/11/98 INT 4 11158 7821(BG-2-L,~ CA DKO-2 1.0 BTM 0.313 0 7/11/98 INT 5 12589 8680(BG-2-L,~ CA DK-1 1.0 BTM 0.000 0 5/17/98 GLM INT perforations summary Interval TVD Zone Status FeetSPF Date Type Comment 12994 - 8932 - 8982 80 6 8/19/96 IPERF INITIAL PERFS 13074 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATrN: Sherrie NO. 11352 Company: Alaska Oil & Gas Cons Comm Attn- Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/21/98 Field: Point Mclntyre Floppy Well Job # Log Description Date BL RF Sepia Disk P1-17 (-~'~. o~----t PRODUCTiON LOG 980701 I I ..... P 1 - 17 ~ DIGITAL FLOW ENTRY LOG 980701 I 1 P1-20 ~ ~ c-I 'PRODUCTiON PROFILE 980421 I 1 P1-23 ~. I ~1 . PRODUCTION PROFILE 980526 I 1 P 1-23 qf DEFT LOG 980526 I 1 PM 2-09 ~ ©C~ L~ CEMENT EVALUATION LOG 980611 I 1 P2-10 ~'~. ~,~ RFT 980523 I 1 P2-10 -~-' CEMENT EVALUATION LOG 98061 7 I 1 P2-19 C~. ©-7ol CEMENT EVALUATION LOG 980414 I 1 P2-37 ~.~ -. ~Q~.~ PRODUCTiON PROFILE 980504 I 1 P2-37 ,-c/ DEFT LOG 980504 I 1 -44 Ct(,¢ ~ ~ CEMENT EVALUATION LOG 980413 I 1 ",-- -44 ~ PRODUCTiON PROFILE 98041 5 I 1 P2-44~- PRODUCTION PROFILE W/DEFT 9 8061 5 I 1 P2-45A (~'.~ I~-Ic~ PRODUCTiON PROFILE 980423 I 1 P2-45 A j~ DEFT LOG 980423 -- ~ ' , SIGNED: I~.'-__~ ~ ~/,~_.~.~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 07/21/98 PERMIT DATA T DATA PLUS RUN RECVD 96-124 DIR SRVY ~HB 0-13432 06~20/97 96-124 MWD SRVY R HB 0-13242 06~2o~97 96-124 PROD-FBS/TEMP/ ~/PRES/CFM 11182-14093 FINAL o9118197 10-407 ~R~ COMPLETION DATE DAILY WELL OPS R P/z[k/[~/ TO %/)~ /~/ Are dry ditch samples required? yes ~___~And received? Was the well cored? yes ~_~Analysis & description received? Are well tests required? yes ~ ...... Received? Well is in compliance Initial COMMEN,TS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [--I Gas I--I Suspended E~ Abandoned [--I Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-124 96-146 ~3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~, 50-029-22690 !4. Location of well at surface ~ 9. Unit or Lease Name 1370' NSL, 951' WEL, SEC. 16, T12N, R14E, U~?~i'~!'~.! ~!!~ Point Mclntyre Attop of productive interval~/~ '~~~-'~ 10. Well Number 4350' NSL, 447' EWL, SEC. 10, T12N, R14E, uM,~_ ~ P1-23 At total depth I~.,.~.,-'~;..~ :~::~'~ - 11. Field and Pool 4696' NSL, 338' EWL, SEC. 10, T12N, R14E, UI~I ~/"' ..... ~ ..... Point Mclntyre !5. Elevation in feet (indicate KB, DF, etc.) 16. Lea§¢e"-Db§-i~h'a(ion and Serial No. KBE = 45'I ADL 034622 12. Date Spudded7/24/96 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re 16' N°' °f C°mpleti°ns8/5/96 8/19/96 N/A MSL One 17. Total13432Depth (M D+TVD)9203 FTI I18. Plug13345Back Depth 9150(M D+TVD)FTiI19. [~YesDirecti°nal SurveyF_lNo,I20. Depth where SSSV2096, MDset,121' Thickness1800, (Approx.)Cf Permafrost .22. Type Electric or Other Logs Run MWD, DIFL/GR/Z-DEN/NEU, GR/CCL/TEMP 23. CASING, LINER AND CEMENTING RECORD CASING SE"I-f lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 38' 110' 30" 260 SX Arcticset (Approx.) 9-5/8" 40# L-80 35' 4043' 12-1/4" 1310 sx Cold Set III, 404 sx Class 'G' 7" 26#/29# L-80/13CR 33' 13423' 8-1/2" 270 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13CR 12710' 12654' MD TVD MD TVD 12994'-13074' 8932'-8982' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 0RISJN L Freeze protect with 56 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) October 31, 1996I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .jIjf,! 20 1997 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Kuparuk River 12878' 8859' Zone UC1 12986' 8927' Zone UB2 13054' 8970' Zone UB1 13074' 8982' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that t :)regoing ue a ect to the best of my knowledge Signed d/" ~ J '~'k ' Steve Shultz _ Title Senior Drilling Engineer Date P1-23 96-146 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. 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. IT£M 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 cementing and the location of the cementing tool. |TEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 22 Jul 96 23 Jul 96 24 Jul 96 25 Jul 96 26 Jul 96 27 Jul 96 28 Jul 96 Progress Report Pt Mac 1 Well P1-23 Page 1 Rig Doyon 14 Date 18 June 97 00:00-06:00 06:00-06:00 06:00-13:00 13:00-19:00 19:00-20:30 20:30-21:00 21:00-00:00 00:00-01:30 01:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-09:30 09:30-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-11:30 11:30-12:30 12:30-13:00 13:00-17:00 17:00-18:30 18:30-18:45 18:45-19:30 19:30-19:45 19:45-21:00 21:00-22:00 22:00-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-11:30 11:30-12:00 12:00-14:00 14:00-19:00 19:00-19:30 19:30-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-03:30 03:30-04:00 04:00-04:30 04:30-05:00 05:00-06:00 Duration 6hr 24 hr 7hr 6hr 1-1/2 hr 1/2 hr 3hr 1-1/2 hr 1/2 hr 2hr lhr lhr 24 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 17-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 2hr 1-1/2 hr 1-1/2 hr lhr 1/2hr 4hr 1-1/2 hr 1/4 hr 3/4 hr 1/4 hr 1-1/4 hr lhr 2hr 5hr lhr 1/2hr 5hr 1/2hr 2hr 5hr 1/2 hr 2-1/2 hr lhr lhr 1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2hr lhr Activity Rig moved 0.00 % Rig moved 90.00 % Rig moved 100.00 % Rigged up Divertor Rigged up Kelly Tested Divertor Made up BHA no. 1 Rigged up Divertor Held safety meeting Circulated at 90.0 ft Drilled cement to 120.0 ft Drilled to 216.0 ft Drilled to 2355.0 ft Drilled to 2510.0 ft (cont...) Circulated at 2510.0 ft Pulled out of hole to 1073.0 ft R.I.H. to 2510.0 ft Drilled to 4055.0 ft Circulated at 4055.0 ft Pulled out of hole to 1073.0 ft R.I.H. to 3000.0 ft R.I.H. to 4055.0 ft (cont...) Circulated at 4055.0 ft Pulled out of hole to 200.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 4043.0 ft (9-5/8in OD) Circulated at 4043.0 ft Pumped 70.000 bbl spacers - volume (null) Mixed and pumped slurry - 448.000 bbl Mixed and pumped slurry - 82.000 bbl Displaced slurry - 300.000 bbl Cleared Bell nipple Rigged down Divertor Rigged up BOP stack Installed Casing spool Installed Casing spool (cont...) Rigged up BOP stack Tested BOP stack Retrieved BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 2 R.I.H. to 2000.0 ft Serviced Block line R.I.H. to 3963.0 ft Circulated at 3963.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float shoe Circulated at 4065.0 ft Performed formation integrity test} ~3 Circulated at 4065.0 ft Drilled to 4189.0 ft Facility Date/Time 29 Jul 96 30 Jul 96 31 Jul 96 01 Aug 96 02 Aug 96 03 Aug 96 04 Aug 96 05 Aug 96 06 Aug 96 Pt Mac 1 Progress Report Well P1-23 Rig Doyon 14 Page 2 Date 18 June 97 06:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-06:00 06:00-15:00 15:00-16:00 16:00-19:00 19:00-21:00 21:00-21:30 21:30-22:00 22:00-23:30 23:30-01:00 01:00-02:00 02:00-06:00 06:00-06:00 06:00-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-06:00 06:00-06:00 06:00-03:00 03:00-04:00 04:00-06:00 06:00-07:30 07:30-08:30 08:30-11:30 11:30-12:30 12:30-15:00 15:00-06:00 06:00-09:30 09:30-10:30 10:30-15:30 15:30-17:00 17:00-17:30 17:30-22:00 22:00-22:30 22:30-23:30 23:30-01:00 01:00-02:00 02:00-06:00 06:00-06:15 06:15-06:30 06:30-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-14:30 14:30-19:30 19:30-20:30 20:30-05:00 05:00-05:30 05:30-06:00 Duration 10hr 1/2 hr lhr 1/2hr 12 hr 9hr lhr 3hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 4hr 24 hr 8-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 13hr 24 hr 21 hr lhr 2hr 1-1/2 hr lhr 3hr lhr 2-1/2 hr 15 hr 3-1/2 hr lhr 5hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr lhr 1-1/2 hr lhr 4hr 1/4 hr 1/4 hr 4hr lhr lhr 1/2hr 1-1/2 hr 5hr lhr 8-1/2 hr 1/2 hr 1/2 hr Activity Drilled to 5277.0 ft (cont...) Circulated at 5277.0 ft Pulled out of hole to 4000.0 ft R.I.H. to 5277.0 ft Drilled to 6176.0 ft Drilled to 7081.0 ft (cont...) Circulated at 7081.0 ft Pulled out of hole to 200.0 ft Pulled BHA Retrieved Wear bushing Made up BHA no. 3 R.I.H. to 4000.0 ft Serviced Block line R.I.H. to 7081.0 ft Drilled to 7341.0 ft Drilled to 8867.0 ft (cont...) Drilled to 9022.0 ft (cont...) Circulated at 9022.0 ft Pulled out of hole to 6200.0 ft R.I.H. to 9022.0 ft Drilled to 9708.0 ft Drilled to 11390.0 ft (cont...) Drilled to 12633.0 ft (cont...) Circulated at 12633.0 ft Pulled out of hole to 8900.0 ft Pulled out of hole to 4040.0 ft (cont...) Flow check R.I.H. to 12633.0 ft Circulated at 12633.0 ft Circulated at 12633.0 ft Drilled to 13235.0 ft Drilled to 13331.0 ft (cont...) Circulated at 13331.0 ft Pulled out of hole to 1088.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 4 R.I.H. to 4000.0 ft Serviced Block line R.I.H. to 13000.0 ft R.I.H. to 13255.0 ft (cont...) Reamed to 13331.0 ft Drilled to 13432.0 ft Circulated at 13432.0 ft Pulled out of hole to 12012.0 ft R.I.H. to 13432.0 ft Circulated at 13432.0 ft Pulled out of hole to 1088.0 ft Pulled BHA Conducted electric cable operations Made up BHA no. 5 R.I.H. to 1500.0 ft Facility Date/Time 07 Aug 96 08 Aug 96 09 Aug 96 10 Aug 96 Progress Report Pt Mac 1 Well P1-23 Page 3 Rig Doyon 14 Date 18 June 97 06:00-11:00 11:00-15:00 15:00-22:30 22:30-23:30 23:30-00:00 00:00-01:00 01:00-01:30 01:30-06:00 06:00-15:00 15:00-17:30 17:30-17:45 17:45-18:30 18:30-20:00 20:00-22:30 22:30-23:00 23:00-01:30 01:30-02:00 02:00-03:00 03:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-07:30 07:30-08:00 08:00-15:00 15:00-18:00 18:00-20:00 20:00-21:30 21:30-22:30 22:30-23:00 23:00-23:30 23:30-00:00 00:00-02:00 02:00-06:00 06:00-08:30 08:30-09:00 09:00-09:15 09:15-11:30 11:30-00:00 00:00-01:00 O1:00-05:00 05:00-06:00 06:00-07:30 07:30-09:30 09:30-10:30 10:30~11:30 11:30-13:30 13:30-14:30 14:30-15:30 15:30-16:30 16:30-18:00 18:00-21:00 21:00-21:30 21:30-22:00 Duration 5hr 4hr 7-1/2 hr 1/2 hr lhr 1/2 hr 4-1/2 hr 9hr 2-1/2 hr 1/4 hr 3/4 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr lhr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 7hr 3hr 2hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 2hr 4hr 2-1/2 hr 1/2 hr 1/4 hr 2-1/4 hr 12-1/2 hr lhr 4hr lhr 1-1/2 hr 2hr lhr 2hr lhr lhr lhr 1-1/2 hr 3hr 1/2 hr 1/2 hr Activity R.I.H. to 1500.0 ft (cont...) Circulated at 13432.0 ft Laid down 12400.0 ft of 5in OD drill pipe Pulled BHA Retrieved Wear bushing Rigged up Casing handling equipment Held safety meeting Ran Casing to 7in (4000.0 ft OD) Ran Casing to 13423.0 ft (7in OD) (cont...) Circulated at 13423.0 ft Held safety meeting Mixed and pumped slurry - 54.000 bbl Displaced slurry - 512.500 bbl Rigged down Casing handling equipment Installed Seal assembly Conduct braided cable operations - 7/32 size cable Serviced Bottom ram Serviced Top ram Serviced Kelly Tested All rams Installed B ore protector Serviced Handling equipment Serviced Handling equipment (cont...) Made up BHA no. 6 Singled in drill pipe to 10000.0 ft Repaired Drillstring handling equipment Singled in drill pipe to 13179.0 ft Drilled cement to 13240.0 ft Reverse circulated at 13240.0 ft Drilled cement to 13337.0 ft Reverse circulated at 13337.0 ft Tested Casing - Via annulus and string Reverse circulated at 13337.0 ft Laid down 6300.0 ft of 3-1/2in OD drill pipe Laid down 6787.0 ft of 3-1/2in OD drill pipe (cont...) Removed Bore protector Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 10600.0 ft (4-1/2in OD) Rigged up sub-surface equipment - SCSSSV control line Ran Tubing to 12680.0 ft (4-1/2in OD) Rigged up sub-surface equipment - Hanger assembly Rigged up sub-surface equipment - Hanger assembly (cont...) Circulated at 12709.0 ft Set packer at 12653.0 ft with 4000.0 psi Rigged down Tubing handling equipment Rigged down All functions Installed Adapter spool Installed Xmas tree Removed Hanger plug Tested Permanent packer - Via annulus and string Circulated at 7797,0 ft Freeze protect well - 56.000 bbl of Diesel Rigged up High pressure lines ,~SSAGE CENTF~ ; 6-18-97 ; 15:25 ; ARCO PBOC~ 907 5645194;# 2/ 2 EL Well Work Log i , Date Deaoription DS-Well FI~P/ITP psi ,IA PSI' ' OA P~l [SITP IMih ID SSSV nipple 7o0 psi 400 .psi - 1,,000 psiI 3.7.25¢~12098 CAMCO BAL-O SVLN sSSV'lnlormation Tubular er C~81ng Problema PB'~ 4 1/2' / 7" Diesel (Recov.) Diesel (non Recov) AFE'~t- CC~ J(C~ass Activity " ' Time ' ..L°g En~." . _ _ -' .. 08:00 SINS.ON LOCATION ... 82~. <G. JOHNS.Q.N! . . ~ ~ :40 T~[ ~N,O. ~NDUCT~O..~ [0~. DA'r£D ~, auNO~¢¢L .'[JE ~N PASS .... . . 14:00 PERFORATE 13054' TO 13074' 15:30 [AT.SURFA(~'.E, ALL SHOTS FIRED, SURFACE Pi~..ESS= 800 PSI _ . 16:00 ~RIH wmq 30' 3 ~8' 6 SPF PERF GUN 17:40 CFRFOR^TED 130~4'T0 130~4' i 9:00. AT SURFA,CE, ALL S_H.O.T$ FIRED, sURfAcE_ . _ PRE,~. 800 PSI . . 19;$0 RIH WITH 30' 3 $/8' $ SPF PF~IF GUN - -- ........ - - i i ill i ii iiii .... · i, 23:30 ._ PERFORATED 12994' TO 130~4'_ .................. 12:30 AT SURFACE, ALL SHOTS FIRED, BEGIN RIO DOWN .. .11 i _ _ .. ....... 01:00 LF~VE kOOATION ~ · · ....... , ..... · ...... i i i ii i i i i l · ~ _ .... . . _ .· i i i, · · · · .... ii ...... _ · _ _ · i i ii ii i Resu~tS':'~umm-ry .... ~utdr~ '~oh,obla~ti¥$ listed in dob'mqu~t -'e...g._'~_~ll~,.GOC. plo_Ih channel8,-~t¢, .... , . · " ' .... "'P~'~omti~g .Intel .{8 'delhi} .. 'Gun':l~. {in~®r~.more'lines ·-,_ ~ .... Top (ft), Bottom _ _~F ,_ Gram./EHD/'I'TP Pha,~ing orient OIBlU Zqne Ad/Reperf 12994 13074 6 21/.44/18.34 60 I=I:NI U UC1 ,OB2. INITIAL , ,! , ~ , ! ,, · 1 Ill BOPD:' FIITP:! ' MD: ,. , m ! -. Tot. Gaa: GOI:E BWPD: .W.C (%1: . Press: ........ GL, Gae: Choke' °' Temp; ...... Signed ~'~ i-::: i: Ji "iPSgd No. o f ~O. "(.I G CI&~O& ffCI . .. P 1 - 23_Directional_Su rv. API500292269000 Survey Type: MEASURED WHILE DRILLING Company: HALLIBURTON Survey Date: 08/05/1996 00:00:00 Survey Top: 110' MD Survey Btm: 13,242' MD Kickoff Depth: Max. Dogleg: 4.5°/100, @ 4,187' MD Avg. Angle below KOP: Max. Angle: 57.8° @ 8,295' MD MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 0 0.00 110 110.00 183 182.89 272 271.93 365 364.51 453 453.23 545 544.55 634 634.23 725 724.61 816 815.83 907 906.70 996 995.71 1,089 1,088.76 1,183 1,182.56 1,276 1,275.38 1,368 1,367.62 1,461 1,460.07 1,553 1,551.57 1,646 1,643.38 1,737 1,733.90 1,831 1,825.98 1,925 1,917.14 2,018 2,006.90 2,111 2,096.79 2,205 2,186.45 2,296 2,273.61 2,390 2,361.61 2,483 2,448.78 2,577 2,535.04 2,672 2,621.89 2,765 2,705.72 2,855 2,785.00 2,948 2,865.01 3,041 2,943.66 3,134 3,020.36 3,224 3, 092.12 3,317 3,164.51 3,410 3,234.16 3,505 3,303.74 3,597 3,370.06 3,690 3,435.05 -43.10 66.90 139.79 228.83 321.41 410.13 501.45 591.13 681.51 772.73 863.60 952.61 1,045.66 1,139.46 1,232.28 1.324.52 1 ~416.97 1,508.47 1.600.28 1.690.80 1,782.88 1.874.04 1.963.80 2,053.69 2,143.35 2,230.51 2,318.51 2,405.68 2,491.94 2,578.79 2,662.62 2,741.90 2,821.91 2,900.56 2,977.26 3,049.02 3,121.41 3,191.06 3,260.64 3,326.96 3,391.95 0.00 0.00 0.0 674,107.3 5,994,497.0 0.00 0.00 0.0 67~,, 107.3 5,994,497.0 0.12 271.45 0.2 674,107.2 5,994,497.0 0.12 202.39 0.2 674,107.1 5,994,497.0 0.13 141.97 0.1 674,107.2 5,994,496.8 0.10 134.13 0.0 674,107.3 5,994,496.7 0.28 137.27 0.2 674,107.5 5,994,496.4 0.41 154.79 0.2 674,107.8 5,994,496.0 0.03 261.95 0.5 674,107.9 5,994,495.7 0.03 303.40 0.0 674,107.9 5,994,495.7 0.32 304.40 0.3 674,107.6 5,994,495.9 0.76 344.26 0.6 674,107.2 5,994,496.6 1.69 357.64 1.0 674,107.0 5,994,498.5 3.22 353.77 1.6 674,106.5 5,994,502.5 4.27 354.38 1.1 674,105.8 5,994,508.5 5.19 355.77 1.0 674,105.0 5,994,516.1 6.38 356.67 1.3 674,104.1 5,994,525.5 6.67 354.48 0.4 674,103.1 5,994,535.9 7.40 357.46 0.9 674,102.0 5,994,547.1 9.52 1.66 2.4 674,101.7 5,994,560.6 11.33 2.48 1.9 674,101.9 5,994,577.5 15.13 3.30 4.06 674,102.5 5,994,599.0 15.95 6.20 1.2 674,104.0 5,994,623.9 16.32 7.33 0.5 674,106.5 5,994,649.7 16.40 10.52 1.0 674,110.0 5,994,675.8 18.52 11.28 2.3 674,114.5 5,994,702.9 20.50 10.41 2.1 674,119.6 5,994,733.6 22.06 13.01 2.0 674,125.8 5,994,767.0 23.15 13.28 1.2 674,133.1 5,994,802.1 24.97 9.52 2.5 674,139.9 5,994,840.3 27.58 9.04 2.8 674,145.6 5,994,881.3 29.42 10.93 2.3 674,152.1 5,994,923.8 31.58 14.19 2.9 674,161.3 5,994,970.0 33.36 14.27 1.9 674,172.5 5,995,018.8 35.54 14.22 2.3 674,184.2 5,995,070.1 37.83 13.16 2.7 674,195.7 5,995,122.3 40.31 15.02 2.9 674,208.7 5,995,179.6 42.24 13.73 2.3 674,222.4 5,995,239.2 43.65 14.66 1.6 674,236.9 5,995,302.3 44.44 14.86 0.9 674,251.7 ~5,995,364.7 46.68 14.11 2.5 674,266.8 Page 1 of 4 P1-23_Directional_Surv. MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 3,783 3,497.09 3,453.99 49.90 14.03 3.5 674,282.2 5,995,497.1 3,878 3,556.50 3,513.40 52.03 14.06 2.3 674,298.3 5,995,568.6 3,968 3,612.88 3,569.78 51.30 15.23 1.3 674,314.7 5,995,638.0 3,997 3,630.60 3,587.50 50.86 14.88 1.8 674,319.9 5,995,659.3 4,095 3,693.59 3,650.49 49.63 15.39 1.3 674,338.0 5,995,732.9 4,187 3,750.91 3,707.81 53.11 18.15 4.46 674,357.1 5,995,802.0 4,281 3,806.84 3,763.74 54.20 18.72 1.3 674,379.4 5,995,874.6 4,378 3,863.24 3,820.14 54.18 18.39 0.3 674,402.6 5,995,949.3 4,467 3,915.85 3,872.75 53.72 19.32 1.0 674,424.3 5,996,018.2 4,562 3,971.57 3,928.47 54.09 14.42 4.21 674,444.8 5,996,091.8 4,654 4,025.74 3,982.64 54.30 15.53 1.0 674,462.5 5,996,164.7 4,747 4,079.63 4,036.53 54.74 15.85 0.6 674,481.2 5,996,238.0 4,840 4,133.44 4,090.34 54.72 15.35 0.4 674,500.0 5,996,311.7 4,933 4,186.62 4,143.52 55.21 15.44 0.5 674,518.4 5,996,385.3 5,026 4,240.68 4,197.58 53.56 15.82 1.8 674,537.0 5,996,458.4 5,121 4,296.88 4,253.78 53.79 15.74 0.3 674,556.1 5,996,532.4 5,214 4,352.10 4,309.00 53.80 15.44 0.3 674,574.7 5,996,605.5 5,306 4,406.22 4,363.12 54.22 15.84 0.6 674,593.1 5,996,677.8 5,400 4,461.01 4,417.91 54.08 15.64 0.2 674,612.0 5,996,751.2 5,494 4,515.87 4,472.77 54.49 17.08 1.3 674,631.7 5,996,824.9 5,587 4,570.04 4,526.94 54.64 16.95 0.2 674,652.3 5,996,898.2 5,679 4,622.14 4,579.04 55.83 13.70 3.2 674,670.4 5,996,971.0 5,772 4,676.09 4,632.99 54.01 13.58 1.9 674,686.8 5,997,046.0 5,866 4,730.99 4,687.89 54.01 13.29 0.3 674,702.7 5,997,119.9 5,959 4,785.68 4,742.58 54.27 13.29 0.3 674, 718.3 5,997,194.0 6,051 4,839.22 4,796.12 54.41 13.52 0.3 674,733.9 5,997,266.9 6,144 4,893.06 4,849.96 54.67 13.29 0.4 674,749.7 5,997,340.9 6,238 4,947.32 4,904.22 54.77 13.89 0.5 674,766.0 5,997,415.8 6,332 5,001.56 4,958.46 54.76 14.15 0.2 674,782.9 5,997,490.7 6,424 5,054.90 5,011.80 54.72 13.12 0.9 674,799.0 5,997,564.4 6,519 5,109.08 5,065.98 55.20 12.58 0.7 674,814.4 5,997,640.1 6,613 5,162.95 5,119.85 55.06 12.33 0.3 674,829.3 5,997,716.0 6,707 5,216.90 5,173.80 54.78 11.93 0.5 674,843.7 5,997,791.4 6,799 5,270.04 5,226.94 54.88 11.40 0.5 674,857.2 5,997,865.6 6,892 5,324.08 5,280.98 54.14 11.79 0.9 674,870.7 5,997,940.2 6,986 5,378.94 5,335.84 54.21 10.85 0.8 674,883.9 5,998,015.1 7,077 5,432.72 5,389.62 53.89 10.83 0.4 674,896.1 5,998,088.2 7,173 5,489.36 5,446.26 53.22 12.49 1.6 674,909.9 5,998,163.7 7,266 5,545.33 5,502.23 52.85 13.10 0.7 674,924.6 5,998,236.6 7,360 5,601.51 5,558.41 53.78 13.58 1.1 674,940.3 5,998,310.3 7,455 5,657.71 5,614.61 53.50 12.73 0.8 674,956.0 5,998,385.0 7,549 5,714.55 5,671.45 52.63 13.10 1.0 674,971.2 5,998,459.1 7,642 5,771.68 5,728.58 51.71 14.22 1.4 674,986.9 5,998,531.0 7,735 5,829.09 5,785.99 51.83 14.71 0.4 675,003.4 5,998,602.0 7,828 5,886.20 5,843.10 52.03 15.01 0.3 675,020.5 5,998,672.8 7,922 5,944.09 5,900.99 52.31 15.40 0.4 675,038.3 5,998,745.2 8,014 5,998.98 5,955.88 54.35 14.18 2.5 675,055.5 5,998,816.9 8,109 6,053.40 6,010.30 56.06 12.33 2.4 675,071.6 5,998,893.5 8,203 6,104.82 6,061.72 57.06 12.09 1.1 675,086.3 5,998,970.0 8,295 6,154.29 6,111.19 57.82 11.82 0.9 675,100.6 5,999,046.1 8,387 6,203.96 6,160.86 56.90 10.93 1.3 675,114.1 5,999,122.5 Page 2 of 4 P 1-23_Directional_Surv. XLa MD TVD SS INCLINE AZIMUTH DOGLEG ASP × ASP Y 8,480 6,256.21 6,213.11 55.07 11.57 2.0 675,127.5 8,574 6,309.99 6,266.89 55.15 11.63 O. 1 675,141.2 8,667 6,363.03 6,319.93 55.06 12.13 0.5 675,155.1 8,761 6,416.65 6,373.55 55.74 12.06 0.7 675,169.7 8,855 6,468.85 6,425.75 56.19 11.23 0.9 675,183.5 8,946 6,520.14 6,477.04 55.15 11.93 1.3 675,196.8 9,041 6,574.39 6,531.29 55.73 11.21 0.9 675,210.8 9,135 6,627.77 6,584.67 55.17 10.66 0.8 675,223.8 9,229 6,682.24 6,639.14 53.70 11.37 1.7 675,236.6 9,322 6,737.49 6,694.39 53.58 11.96 0.5 675,250.0 9,416 6,792.95 6,749.85 53.98 12.28 0.5 675,264.2 9,509 6,847.40 6,804.30 54.43 11.52 0.8 675,278.1 9,602 6,902.12 6,859.02 53.66 11.83 0.9 675,291.6 9,697 6,958.62 6,915.52 53.08 11.72 0.6 675,305.4 9,793 7,015.91 6,972.81 53.69 11.27 0.7 675,319.0 9,886 7,070.49 7,027.39 54.09 11.38 0.4 675,331.9 9,979 7,124.85 7,081.75 54.49 11.18 0.5 675,345.0 10,073 7,180.13 7,137.03 53.29 11.22 1.3 675,358.0 10,165 7,235.54 7,192.44 53.21 11.73 0.5 675,371.0 10,258 7,291.18 7,248.08 53.38 11.80 0.2 675,384.6 10,352 7,347.10 7,304.00 53.77 12.01 0.5 675,398.5 10,445 7,401.34 7,358.24 54.34 9.77 2.1 675,410.9 10,538 7,455.61 7,412.51 54.53 9.39 0.4 675,421.8 10,630 7,508.99 7,465.89 54.72 8.24 1.0 675,431.5 10,723 7,562.72 7,519.62 54.67 8.00 0.2 675,440.5 10,816 7,616.78 7,573.68 54.30 6.46 1.4 675,448.3 10,911 7,672.61 7,629.51 53.10 5.39 1.6 675,454.4 11,004 7,728.71 7,685.61 52.90 6.13 0.7 675,460.1 11,097 7,784.48 7,741.38 53.36 2.46 3.2 675,463.9 11,191 7,840.47 7,797.37 53.49 1.87 0.5 675,465.0 11,285 7,896.70 7,853.60 53.37 0.41 1.3 675,464.8 11,378 7,952.00 7,908.90 53.26 359.65 0.7 675,463.1 11,472 8,008.62 7,965.52 53.03 358.55 1.0 675,460.1 11,566 8,065.20 8,022.10 52.96 357.90 0.6 675,456.1 11,659 8,121.12 8,078.02 53.10 357.57 0.3 675,451.4 11,753 8,177.19 8,134.09 53.47 356.97 0.7 675,446.1 11,846 8,232.31 8,189.21 53.50 357.17 0.2 675,440.5 11,939 8,287.70 8,244.60 53.74 357.10 0.3 675,435.0 12,030 8,341.67 8,298.57 53.73 355.61 1.3 675,428.7 12,123 8,397.46 8,354.36 52.56 354.40 1.6 675,420.5 12,217 8,454.95 8,411.85 52.00 353.60 0.9 675,411.0 12,310 8,512.08 8,468.98 52.28 353.15 0.5 675,400.8 12,404 8,568.79 8,525.69 53.00 353.38 0.8 675,390.4 12,496 8,624.06 8,580.96 53.36 353.36 0.4 675,380.1 12,590 8,680.90 8,637.80 52.67 351.63 1.6 675,368.5 12,683 8,737.14 8,694.04 52.84 350.40 1.1 675,355.3 12,778 8,795.37 8,752.27 51.23 350.10 1.7 675,341.0 12,870 8,853.64 8,810.54 50.32 351.42 1.5 675,327.8 12,878 8,858.68 8,815.58 50.35 351.40 0.4 675,326.8 12,962 8,912.13 8,869.03 50.64 351.19 0.4 675,315.5 13,054 8,970.12 8,927.02 51.35 351.02 0.8 675,302.8 Page 3 of 4 5,999,198.8 5,999,274.6 5,999,349.4 5,999,425.8 5,999,501.8 5,999,575.7 5,999,653.2 5,999,729.7 5,999,804.7 5,999,878.6 5,999,953.0 6,000,027.2 6,000,101.4 6, 000,176.1 6,000,252.0 6,000,325.7 6,000,400.2 6,000,474.9 6,00O, 547.9 6,000,621.3 6,000,695.8 6,000,769.5 6,000,844.6 6,000,919.2 6,000,994.5 6,001,069.8 6,001,145.6 6,001,219.8 6,001.294.0 6,001.369.5 6,001,445.3 6,001,519.5 6,001,595.0 6,001,669.9 6,001,744.1 6,001,819.1 6,001,893.3 6,001,968.3 6,002,041.6 6,002,115.5 6, 002,189.2 6,002,262.0 6,002,335.6 6,002,408.7 6,002,483.3 6,002,556.0 6,002,629.3 6,002,699.4 6,002,705.4 P1-23_Directional_Surv.XL MD TVD SS INCLINE AZIMUTH DOGLEG ASP X ASP Y 13,149 9,028.98 8,985.88 51.52 350.55 0.4 675,289.3 6,002,912.3 13,242 9,086.78 9,043.68 52.03 350.73 0.6 675,275.6 6,002,984.4 Page 4 of 4 Halliburton Energy Services - Drilling Systems PSL Survey Report Stav~ Rzt'ctcnce: WELLHEAD Rcferonoe World Coordinates: Lal. 70.23.26 N- Long, 148.35.0! W Refere. na: GRID Syslcm: Alaska Stata Plane Zone: Alaska 4 Rafcre, n~ GRID Coordinates: (fi): 5994495.12 lq 674106.94 E No" ligned To: TRUE NORTH Page 1 Job No: 00256 Date: 815/96 Time: 1:45 pm Wellpath ID: PI~23MWD Date Creal~; 7/24/96 Last Revisit: 8/5/96 ,-., _._ ___-_' .... BPX - Shared SeMces Drilling Alaska .~ate; Plau~: Zone4 Pt Mac: Phil PI-23 AS Built pl-23mwd Mea~ Inci Drift Subs~a (ii) (degJ) (dug.) 0.00 0.00' 0.00 43.10 0.00 BHA#I / 1.500 B.H. { 12 1/4" HOLE ) ,d'l ( 00 0.00 0,00 -66.90 II0.LO · . .,,,=89 0.12 2'71.45 -139.79 182.89 271.93 0.12 202,39 -228.83 271.93 364.51 0.13 141.9'/ -321.41 364.51 453.23 0.10 134.13 -410.13 453,23 544.55 0.28 137.17 634.23 0.41 154.79 724.61 0.03 261.95 Vertical 815.83 0.03 303.40 906.70 0,32 304.40 995.71 0.'/6 344.26 Colh~ TOTAL (n) (n) 0.00 0.00 0.00 N 0.00 E 0.00 110.00 0.00N 0.LO B .0.01 72.89 0.00N 0,08W .0.11 89.04 0.08 $ 0,21W -0.28 92.58 0.25 S 0,189/ · 0,39 88,72 0.39 S O.06W ,501.45 544,55 -0.58 91,32 0,61 S 0,1SE -591.13 634,23 -0.98 89.68 1,06 S 0.43 -681.51 724,61 -I.25 90.38 1.35 S 0.55E -772.73 815.83 -!,25 91.22 1,34 S 0,51 -863.60 906.70 -!, 13 90,87 !,19 S 0.28 -952.60 995.70 -0.49 89,01 0.48 S 0.0~M 1088.78 1.69 357,64 ,1045.65 1088.75 1.42 93,0q 1.49N 0,31W Dia. Din gorlhing Easting (ii) (deg.) (fl) 0.0~ .0.00 5994495.12 674106,94 0,0(~ 0,00 5994495.12 674106,94 ~0~271.45 5994495.12 6~4106,86 '~22~248.22 5994495,04 674106,74 031~214.88 5994494.87 674106.77 ~39~188.76 5994494.74 674106,89 ~62~166.21. 5994494.52 674107.10 1.14~157.69 5994494~8 ~7410'/.40 1.46~157.94 599449~,78 67¢107.52 1.44~159,41 5994493.79 674107.47 1.22~166.93 599449~.94 674107.24 0A9~190.58 5994494.64 674106,86 1.5~34~.09 5994496.60 6~4106.59 0.00 0,16 0.1'5 0.14 0.04 022o '0.19 0.46 O.02 0.32 0.62 Oleg) 0.0 0,0 0.1 0.3 0.4 0.4 0.6 0.8 1,2 -. 1.2 1.5 2.0 3.0 Survey Tool BPHM.PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD 'BPHM-PBD BPttM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD HallibUrton Energy Services- Drilling Systems PSL Survey Report ?ag~ 2 Dale: 8/5/96 Wellpah ID: ?I-23MWD Mea~ lacl Dri~ Subsea (ft} (deg.) idcg.) (i~) 1182.67 1275.69 1365.25 1461,17 1553.27 ~5.78 1830,93 1924.59 3.22 353,7/ 4.27 354.38 5.19 355.77 6.38 356.67 6.6'/ 354.48 7.40 357.46 9.52 !.66 11,33 2.48 15, I3 3 30 2017,76 15,95 6.20 2111,34 16.32 733 2204.78 16.40 10.52 2296.16 18.52 11.28 2389.52 20,50 10.41 2483,07 22,06 13.01 2576.51 2671.62 2765.12 ! .,~55.33 2948.19 3041.42 23.15 13.28 24.9q 9.52 27.58 9.04 29.42 10.93 31.58 14.19 33.36 14.27 3134.44 35.54 14.22 3223.93 37.83 13,16 3317.17 40.31 15.02 3409,85 42.24 13//3 3504.91 43,65 14.66 3597.17 44,44 14.86 3690,00 46.68 14.11 3783.26 49,90 14.03 3877,59 52,03 14,06 -1139,45 -1232,27 -1324,51 -1416,% -1508.46 -1600,28 -1690.80 -1782.88 -1874,03 -1963,80 -2053,69 -2143,35 -2230.52 -2318.51 -2405,68 -2491.94 -2578.79 -2662.62 -2741 -2821,91 -2900.56 -2977.2'/ .3049.03 .3121.41 -3191.06 -3260.65 -3326,96 -3391.96 -3454.00 -3513.40 1182.55 1275.37 1367.61 1460.06 1551.56 1643.38 1733 1825,98 1917.13 2006.90 209639 2186.45 2273.62 23~1,61 2445.78 2535.04 2621.89 2705.72 2785.00 2865.01 2943.66 3020.37 3092.13 3164.51 3234.16 3303.75 3370.06 3435,06 3497,10 3556.50 Vc~ (~) 5,32 11.19 18.60 27.74 37,9I 48.95 62.23 39,05 100.36 125,25 151.23 177,54 204.94 236.10 270.01 305,83 344,55 385,94 428.97 475.99 525,83 578.23 631.51 690.03 750,90 815.39 879.21 945,18 1014.52 1087.51 Course T O T A L Ck,'mc GRID Cooxdimlc~ Length Rcctangula~ Ottsc~s Dist. Dk. ~ Fasting (i~) (n} (i~) (~) (~g.) (fl) 93.89 5.49N 0.66W 5.53(~353,18 5994500.60 674106.15 93.02 11.53N 1,28W 11,61~353,67 599450/5.63 674105.39 92,56 19.14N 1.939/ 19,24~354.26 5994514.21 674104.57 92.92 28.48N 2.54W 28.60~354,91 5994523.54 6/4103.74 92.10 38.92N 3.35W 39.06~355.08 5994533.95 674102.69 92.51 50.22N 4.13W 50.39(~355.30 5994545,23 674101,64 91,52 63.67N 4,17W 63,81~356.25 5994558.68 674101.2~ 93.63 80.60N 3.55W 80,61~357,4 8 5994575.62 674101,52 93~66 IOI.OON 2.45W 102.03(~358.63 5994597.04 674102.12 93.17 126.87N · 0.36W 126.87~.359.84 5994621.~ 674103.62 93.58 152.69N 2.70E 152.72~ 1.01 5994647.1B 674106.09 93.44 178.68N 6.79E 178,81@ 2.18 5994673.91 674109:56 .91.38 205.6ON 11.98E 205.9.~ 3.34 5994700.94 674114.13 93.36' Z:36.23N ' .17.g4E 236,90~ 4,32 5994731,69 674119.27 93.55 269.46N 24.75E 270,$~(~ 5.25 5994765,07 674125.41 93.44 304.43N 3Z92E 306.20~ 6.17 5994800.Zl .674132.76 95.11 342.43N 40.54 E ]44,82~ 6.75 5994838.38 674139.49 93.50 383.28N 47.20E 386.17~ 7.02 599457937 674145.20 90.21 '425.66N 54j69E 429,1¢:,~ 7.32 5994~1.91 674151.69 92.86 471.63N 64.97 E 476.09~ 7.84 5994~68.11 674160.91 93,23 520.15N ~.28E $25.1~ 8.45 5995016,90 674172.07 93.02 571.15N 90,22E 578,23~ 8.98 59950~.18 674185.83 g9.49 623.09N 152.56 E 631.5~ 9.37 5995120.40 67419525 93.24 680,07N 117.19E 6~0.09~ 9.78 5995177.69 67420825 92.68 TJg.29N 132.36 E 751.05~ 10.15 5995237.25 674222.03 95.06 ~02.07N 148.24B {15.64~ 10.47 5995300.38 674236.45 92.26 [64.10N 164.58E g79.63(~ 10.78 5995362.76 674251.34 92.83 928.2?N 181.15E 945,78~ 11.04 599542730 674266.41 93.26 995.79N 198.08 E 1015.30~ 11.25 5995495.19 674281.75 94.33 1066.87N 215.56E 1088.49~ 11.44 5995566.66 674297.87 DLS (dgtl0Oit) !.64 1.13 !,00 1.28 0.41 0.88 2.41 1.94 4.06 1.21 0.52 0,97 2.33 2.14 1.95 1.17 '2,50 2.80 2.27 2.93 1.91 2.34 2.65 2.94 2.28 1.63 0.87 2.48 3.45 2.26 4.6 5.6 6.5 7.7 8,1 8.9 11.1 12.9 16.7 17.9. 18.4 19,3 21,4 23.4 25.2 263 28.7 31,3 33.4 3~,! 3719 40.0 42.4 4Y2 47.3 48.8 '49.6 51.9 55.1 57.3 Survey Tool BPHM-PBD BPHM-PBD BPEM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BH-IM-PBD BPHM-PBD 'BH-IM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BI~M-PBD BPttM.PBD 'BPHM-PBD BPHM-PBD BPttlvI-PBD BPHIVI-PBD BPHM-PBD BHtM.PBD 'BPHM-PBD BPHM-PBD 'BPHM-PBD BPHM-PBD BPHlVI-PBD BPHM.PBD DPHM-PBD BPHM.PBD BPHM-PBD Halliburton Energy Services- Drilling Systems PSL Survey Report Page 3 Dat~: 8/5/96 Wdlpath ID'. PI-23MWD 3968.49 51.30 15.23-3569.79 3996.70 5036 14.88 -3587.51 BI-IA #2 / 1.25· a.H. { 8 1/2' HOLE } 4095.20 49.63 15.39 -3650.50 3612.89 3630.61 3693.60 Vertical 1158,46 i 180.29 1255.58 Couts~ T O T A L Closure GRI) Coordimlcs Length ~~~ ~i~ ~. ~g ~g (~) (fl) (~) (a) (dg.) ~) (~) ~.~ IDs. gsN 233,88E 1159,6~ 11,63 5~.~ 674314,27 ~.21 1157.05N 239.58E 1181.5~ 11,70 5~.36 674319.48 98,50 1230.14N 259.35 E 1257.1~ !1.91 5995730.90 674337,53 DL$ 1.29 1.83 1.31 CU~, Dogie§ 58.4 59,0 60.'3 Sm~ Tool BPI~-PBD BPHM-PBD BPHM-PBD 4187,02 4~'' 40 4467.18 4561.72 4654.32 53.11 18.15 -3707.82 54.20 18.72 -3763.75 54.18 18.39 -3820.15 53.72 19,32 -3872.76 54.09 14.42 -3928.47 54.30 15.53 -3982.65 3750.92 3806.85 3863.25 3915.86 3971.57 4025.75 1326.62 1401.62 1478.70 1549.91 1625.54 1700.24 4747,17 54.74 15,85 -4036.54 4079.64 1775.33 484035 54.72 15,35 -4090,35 4133.45 1850.90 4932.98 55.21. 15.44 -4143,52 4186.62 1926,28 53.~ 15,82 .4197,59 53,79 15,74 -4253,79 53,lO 15,44 .4'309,00 54.D. 15.84 '.4363.13 54.08 15.64 -4417.92 54.19 17.08 .4472.77 54.~4 16,95 -4526.94 55.13 13,70 .4579.04 54.81 13.58 .4632.99 54.01 13.29 -4687,89 54.27 13.29 -4742.58 54.41 13.52 4796.12 5120.70 5214.18 5306.28 5399,83 5557.23 5678.58 5772.46 5865,88 5959.24 6051.08 4240.69 4296.89 4352.10 4406.23 4461.02 4515.87 4570.04 4622.14 467639 4730.99 4755.68 4839.22 4893.06 4947.32 5001.56 6143.89 6237,83 6331.84 54.67 13.29 .4849.96 54.77 13.89 .4904.22 5~.76 14.15 .4958.46 2001.25 2077,16 2152.09 2226,11 2301.41 2377.08 2452,46 2527,04 2603.61 2678.97 2754.42 2828.82 2904.20 2980.64 3057.13 6424.23 54.72 13.12 -5011.79 5054.89 3132.32 6518.59 55.10 12.58 -5065.97 5109.07 3209.41 91,82 1298.79N 280.08E 1328.64~ 12.17 5995.800.00 674356.66 94.38 1370.90N 304.12 E 1404.2~ 12.51 5995872.65' 674379.O1 96.39 1445.01N 328,99E 1481.99~ 12.83 5995947.31 674402.14 89,39 1513.40N 352,35E 1553.8~ 13,11 5996016.23 674423.89 94,54 1516.47N 374.50E 1630.0'i~ 13.28 59960~.79 674444,33 ~2,60 1659.02N 393,90E 1705.14~ 13.36' 5996162.77 674462.04 92,85 1731.$[N 414,35E 1780.6~ 13.46 5996236.OI 674480.78 93.18 1805.0gN 434.81E 1856.71@ 13.54 590,6309.74 674499.:52 92.63 1878.21N 454,95E 1932,5~} 13,62 .5996383.30 674517,94 92,84 19~0.8~)N 475.28E 2007,95~ 13.69 5996456.44 674536,57 94.88 .2024.45N 496,06 E 2084,34~ 13,77 59965~.46 674555,63 93.48 2097.10N 516.34 E 2159 73~ 13,83 59~:dY3.56 674574,20 92.10 2168.86N. 536A3E 2234,22~ 13.89 5996675.77 674592,60 93.55 2241.85N 557.00E 2310.0!~ 13,95 5996749.21 674611,'46 93,97 2315.05N 578.49E 2386,23~ 14,03 59%~22.89 674631.24 93.43 23S/.84N . 600.76E 2462,2(~ 14,12 .59~%.17 674651.80 91,35 2460.21N 620.58E 2537,27~ 14,16 59%96&~ 674669,92 93.88 2534.~6N 638.70E 2614,0~]} '14.14 5997044.03 674686.29 93.42 2608,38N 656.26 E 2689,6'~ 14,12 5997117.93 674702.12 93,36 26~2.02N 673.65 E 2765,33~ 14.10 5997191.95 674717.79 91,84 2754,60N 690.95 E 2839,94~ 14.08 5997264.92 674733,39 92.81 2828.14N 708.48E 2915.53~ 14.06 599'/338.84 674749.19 93,94 2902.68N 726,50E 2992.21@ 14,05 5997411.78 674765.46 94,01 2977,18N 745,10E 3069.0(~ 14,05 59974:88.68 674782.31 92:39 3050.49N 762.88 E 3144.44~ 14.04 599'/56239 674798.38 9436 3.125.81N 780,06 E 3221.61~ 14.01 5997638.09 674813,79 4.46 1.25 0.28 0.99 4.21 1.00 '0.55 0.44 0.53 1,81 0.25 0,26 0.58 0.23 1;32 0.20 3.20 1.94 0.25 0.28 0.25 0.35 . 0.53 0.23 0.91 0.69 64.3 65.5 65.8 66.7 70.7 71,6 72.1 72,5 73.0 74.7 74.9 75,2 75,7 75.9 77,1 77.3 80,2 82,1 82,3 82,6 82.8 83.1 ~3,6 83.8 84.7 85.3 BPRM-?BD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPttM-PBD BPHM-PBD BPHM-PBD neJ~-~V BPItM.PBD BPHM-PBD BPHM-PBD BPNM-PBD .~HM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPItM-PBD BPIiM-PBD BPHM.PBD BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Survey Report Page 4 Da~¢: 8/5/96 ID: PI-23MWD (fl) 6612.81 6706.69 6798.95 Ind (d~) 55.06 Dr~ Dh'. (d~,) Subsea Depth 12.33 -5119.84 11.93 -5173.79 11.40 -5226.93 5162.94 5216.89 5270.03 Vertical 3286.57 3363.28 3438.62 Course T O T A L Closure C. dl]D Coord/nales Length Rectangular Offscis Dia. Din No.hlng ~ (~) (fl) (it) (l~) (deg.) (fl) 94.22 3201.30N 796.73 E 3298.95~} 13.98 5~97713.93 67482&69 93.~ 3276.41N 812.88E 3375.74~ 13.93 5997789.40 674843.07 92.26 3350.27N 828.13 E 3451.10~ 13.88 59978~3.59 674856.59 DIS (d~/lO0n) 0.26 0.46 0.48 Dogl~ (~) 85.6 g6,0 86.4 Suney Tool BFHM-PBD BPHM-PBD BPHM-PBD 6892.04 6985.77 7r' '8 "I~HA #3 ! !° 7172.73 7265,81 73.59.8.5 7454.65 7549.24 7642.39 7735.17 7827.78 7922.16 54.14 54.21 53.~ ~,~t { 53.22 52.~5 53.78 53.50 52.63 51.71 51.83 52.03 52.31 11.79 -5280.98 10.85 .5335.84 10,83 -5389.62 8 1/2' HOLE ) 12.49 -5446.27 13,10 -5502.24 13.58 -5558.42 12.73 -5614.62 13.10 -5671.46 14.22 -5728.59 1431 -5786.01 15.01 -5M3A! 15.40 -5901.00 5324.08 5378.94 5432.72 5489.37 5545,34 5601.52 5657.72 5714.56 5771.69 5829.1 ! 5886.21 5944.10 3514.34 3590.27 3664.39 3741.01 3815.22 3890.41 3966.56 4041.99 4115.32 4187.87 .4260,39 4334.50 93.09 3424.52N 843.36E 3526.83(~ 13.84 5997938.17 674870.08 93.73 34~9.03N 855.28E 3602.76~_,13.78 5998013.01 674883.25 91,61 3571,87N 872.22 E 3676,8~ 13.72 5998086,1.5 674895.49 95.35 3646,99N $87,T2E 3753,49~ 13,68 5998161.60 674909,22 93,08 3719,51N 904.19E 3827.$3~ 13.66 5998234,49 674923.99 94.04 3792.89N 921.59E 3903.24~ 13.66 5998308.25 674939.67 94.80 3867.22N 938.97E 3!rlg. Sg~ 13.65 5998382.97 674955.30 94.59 3940.92N 955.{6 E 4055.11~. 13:63 5?9M57.03 674970.46 93.15 4012.41N 973.23E 4128.7~ 13.63 5998528.90 674986.15 92.78 4082.98N 991.44E 4201.6~ 13.65 5998599.88 675002.70' 92.61 4!53.45N IOI0.14E 4274.52~ 13.67 5998670.76 675019.74 94.38 4225.38N 1029.69E 4349.04~ 13.70. 5998743.13 675007~60 0.87 0.82 0.35 i.57 0.66 1.07 0.78 0.9'/ 1.37 0.43 0.33 0.44 87.3 88,0 88,3 89.8 ~0,4 91.5 92.2 93.1 94.4 '94.8 95.1 '95.5 BPHM-PBD BPItM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BI~-PBD BPHM-PBD BPHM-PBD BPIIM.PBD BPHM-PBD BPHM-FBD 8014.07 8109.43 8294.68 8386.77 8480,17 8574.19 8666.91 8761.34 8854,61 8945.56 9041.20 9135,32 9228.97 54.35 56.e6 57.~6 57.82 %.90 55.O7 55.15 55.116 55.'/4 56.19 .55.15 55.73 55.17 .53../0 14.18 12.33 12,09 11,82 10,93 11.57 11.63 12,13 12.06 11,23 11,93 11,21 10.66 11,37 -5955.89 -6010.30 406133 -6111.20 -6160.87 -6213.12 -6266.90 .6319.94 .6373.56 -6425.77 -6477.06 -653131 -6584.69 -6639,16 5998.99 6053.40 6104.83 6154.30 6203.97 6256.22 6310,00 6363,04 6416.66 6468,87 6520.16 6574.41 6627.79 6682.26 4407,84 4485.93 4563,68 4641,06 4718.54 4795.89 4872.93 4948.89 5026.50 5103.71 5178,74 5257.43 5334.90 5411.03 91.91 42%.66N 1048.50E 442Z74~ 13.71 95.36 4372.88N 1066.44. E 4501.04~ 13.71 93.32 4448,99N I082,90E 4578,8~ 13,68 91,93 4524,79N 1098,95E 4656,33~ 13,65 91,09 4600.81N 1114.25 E 4733.81~1 13.61 93.40 4676.73N 1129.35E 4811,16~ 13.58 94.02 4752.28N 1144.86E 488&24~ 13.54 92.72 4826.70N 1160.51E 4964.25{} 13.52 94,43 4902,70N 11'/6.801] 5041.96~ 1~.50 93,27 497&40N 1192.40E 5119.21~ 13.47 90.95 ~51.98N 1207,47E 5194;2"~ 13,44 95.64 5129.14N 1213.27E 5272.99(~113.41 94,12 5205.25N 1237.97 E 5350.44~ 13.38 93.6.5 5280.03N 1252.52E 5426,,,,V:1~ 13.34 5998814,82 675054.73 5998891;43 6750~,88 59~967,90 675085.56 5999044,05 6750~.83 5999120.40 675113.34 5999196.66 67512635 5999272,54 675140.38 5999347.30 675154.29 5999423.66 675168.79 5999499.70 675182.61 5999573.61 675195.95 599965L i I 675209.94 5999727.55 6752D...~5 5999802;64 675235,65 2.46 2.40 1.09 0,86 1,29 2.04 0.10 0.45 0.72. 0.88 i.31 0.87 0.77 1.69 97.8 100.1 101.1 101.9 103.1 105.0 105.1 105.5 106.2 107.0 108.2 109.0 109,7 111,3 BPBM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BI~i-PBD BPHM.PBD BPHM-PBD BPIiM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD Halliburton Energy Services - Drilling Systems PSL SurveY Report Page 5 Dale: 8/$/96 Wcllpalh ID:. P 1-23MWI) %22.16 9416,02 9509.12 Incl (~g.) 53.58 53.98 54.43 Drift Dir. (~g.) 11.96 12.28 11,52 Suhsea .6694.41 -6749.87 -6804,32 6'/37.51 6792.97 6847.42 Vertical Section (~) 5486.O0 5561.61 5637.02 Coum T O T A L Closure GRID Cooadinales Lcnglh R~~ DM' Dir. NoO. hi~ Easting (fi) (fl) (fl) (l~) (&g,) (fi) (f~) 93.19 5353.52N 1267.70E 5501.5'~ 13.32 5999876.46 675249,09 93.86 5427.56N 1283.59E 5577.2'~ 13.31 5999950.84 675263.25 93.I0 55OI.45}q 1299.16E 5652.'/'~ 13:29 6000025.011 675277.08 DIS 0.53 0.51 0.82 Dogies 111.8 112.3 113.0 Surv~ To~I BPHM.PBD BPHM-PBD BPHM-PBD 9602.31 53.66 11.83 -6859,04 9697.01 53.08 11.72 -6915.54 e % 53.69 11.17 .6972.83 '" 91185,67 54.09 11.38 -7027,41 9978.81 54.49 11.18 -7081.77 10072,61 53.29 11.22 -7137.05 10165,21 10251].30 10352,47 10444,86 10538,17 1O630.37 53.21 53.38 53.77 54,34 54.53 54.72 11.73 Il,g0 12.01 9.77 9.39 8.24 -7192.45 -7248,09 -7304.01 0358.25 -7412.52 0465.90 6902.14 6958.64 7015.93 7070.51 712437 7180.15 7235.55' 7291.19 7347.11 740135 7455.62 75O9.00 5712,38 5788 29 5865,31 5940,07 6015,63 6091.36 6165.48 6240.03 63 ! 5.71 639O .46 6466.35 6541.53 93,19 5575.32N 1314.43E 5728.1'~ 13.27 6000099,28 675290,61 94.70 5649.72N 1329.94E 5804.14~ 13.25 6000174.02 675304,37 %.05 5725.27N 1345.30E 5881.20~ 13.22 6000249.90 675317.95 92.61 5798.63N 1359.99E 5955.98~ 13,20 6000325.58 675330.92 93.14 5872.80N 1374,79E 6031,5'~ 13.18 6000398.07 675343:97 93.80 5947,13N 1389.50E 610'~.30~ 13.15 6000472.73 675356.94 92.60 6019.85N 1404~26E .6181,46~ 13.13 6000545.76 675369,99 93.09 6092.91N 1419,48E 62.%.08~ 13.11 6000619.16 675383.45 94.17 6167.05N 1435.11E 6331.83~ 13.10 6000693,64 675397,37 92.39 6240.50N 1449.24E 6406.5'~ 13.07 6000767.39 67540937 93.31 '.611534N 1461.87E 6482.33~ 13.03 6000842.51 675420.64 92.20 6389.63N 1473.39E 6557.3~ 12,98 6000917.04 675430.41 0.87 0.62 0.44 0.46 1.28 0.45 0,19 0.45 0:39 1.04 ! 13.8 114.4 115.1 !15.6 !.16.~3 117.2 117.6 117.8 118.2 120.1 ,120.5 121.4 BPHIVf-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPH1VI.~D BPHM.PBD BPHM.PBD BPHM-PBD ~HM-PBD B?HM-PBD BPitM-PRD BPItM-PBD 10723,34 10816.39 10910,70 .31(,...~.92 11096,85 1119O.81 1285.18 1377.75 1472.15 54.67 54,30 53.10 52.9O 53.36 53.49 53.37 53,26 53.03 gDO 6.46 5.39 6.13 2.46 1.87 0.41 359,65 358.55 -'7519.63 4573.68 ,7629.52 4685.62 -'/741.39 -7'797.38 -71L53,60 .7908.91 -7965.53 7562.73 7616.78 7672.62 '/'/28.72 7'/84.49 784O.48 7896.70 7952.01 8O08.63 6617.39 6693.09 6768.99 6843,31 6917.38 6992,30 7067.38 7140.70 7215.11 92.97 6464.74N 1484.11E 6632.9Q~ 12.93 6000992.38 675439,36 93:05 6539.87N 1493,64E 6708.2'~ 12.87 6001067,71 675447,13 94.31 6615ATN 1501.49E 6783.72~ 12.79 66o1143.47 675453.21 93,22 668934N 1508.96E 6857.62~' 12.71 6001217.69 675458,94 92.93 6763.65N 1514.52E 6931.1f~ 12,62 6001291.91 675462 76 93,96 6839.06N 1517.]7E 7005.3f:~ 12.51 6001367.35 675463,85 94,37 6914,83N 1518.88E '/079,68~ 12.39 6001443.13 675463.58 92.57 6989.06N 1515,92E 7152,21~ 12,26 6001517.34 675461.88 94.40 70643914 1517.73 E 7225.7l~ 12.12 6001592.82 675458.93 0.12 1.40 !,57 0.67 3.20 0.52 1.25 0,67 0,96 121,6 I22,9 124.4 125.0 128.0 128.5 129.7 130,3 131.2 BPHM-PBD BPHM-PBD BPIiM-PBD BPHkI-PBD BPHM-PBD BPHM-PBD BPHlVI-PBD BPHM-PBD BPHIVI-PBD 11566.15 !1659.14 11752.92 52.% 53.10 53.47 357.90 357.57 356.97 -8022. ! 1 4078.O3 -8134.09 8065.21 8121.13 8177.19 7288.85 7361.71 7435.31 94.00 7139~2N 1515.41E 7298.6'~ 11.98 6001667.77 675454.86 92.99 721335N 1512.47E 7370.70~ 1.1,84 6001741.91 675450.19 93.78 7288.94N 1508,89E 7443,4~ 11.70 6O01816.89 675444,85 0,56 0.32 0.65 131,7 132,0 132,6 BPHlVI-PBD BPHM-PBD BPHM-PBD 11845.55 11938.93 12030.17 53.50 53.74 53.73 357.17 357.10 355.61 -8189.21 -8244.60 -8298.57 8232.31 8287.70 8341.67 7508.14 7581.72 7653.49 92.63 7363.2914 1505.08E 1515,54~ 11.55 6001891.12 675439.31 93.38 743838N 1501.33 E 75118.38~ 11,41 6001966.09 675433.80 91.24 7511.79N 1496.65E 7659.44~ 11.27 6002039.37 675427,41 0.18 0.26 132 132,8 133,0 134,2 BPHlVl-PBD BPHM-PBD BPHM-PBD ., Halliburton 'Energy Services - Drilling Systems PSL Survey Report Page 6 Date: 8/5/96 Wellpath ID: P 1-231VlWD Mea.~ lad DriP. Subsca TVD Vertical Coursc TO T A L Depth Dir. Depth Scclion Leagl~ Rcctangular Oflbcls (fl) (deg.) (deg.) (fl) (ii) (fi) (fi) (fi) (fl) Ck)su~ GRID Cooniina~ Dis1. Db, NortEng Eastin~ (fi) (deg.) (fi) (fi} 12123,18 52.56 354.40 -8354.36 8397.46 '7725,70 93,01 ·7585,93N 1490.18E . 7730.91@ I1.11 12217,I4 52.00 353.60 -8411.84 8454.94 7797,49 93,96 7659184N 1482,4[E 7801.9'~ 10.95 12310.22 52.2g 353,15 .846~.97 8512.O7 7868.25 93.08 7732.84N 1473.93E 7872.06~ 10,79 12403,6'7 53.(}0 35338 4525.68 g56~.'/8 7939.74 93.45 '/806,61N 1465.22E 7942.92~ 10.63 12495,90 53.36 353.36 -8580.95 8624.05 8010.84 92.23 7879,94N 1456.70E 8013.4(:~ 10.47 12~o038 52.67 351,63 .8637,79 8680.89 8083.20 94.48 7954,76N 1446.84E 8088.2'~ 10.31 '"J'i2683,30~ 52.84 350.40 .8694,03 8737.13 8153.54 92.92 g027.82N 1435.29E 8155,12~ 10.14 12777,96 51.23 350.10 -8752.26 879536 8224.21 94.66 $101.37N 1422.66E 8225.34~ 9,96 12870,10 50.32 351.42 -8810.53 8853.63 8291.99 92.14 8171.82N 1411,19E 82,92.7'~ 9,80 12962.02 50.64 351.19 .8869,02 8912.12 8359.54 91.92 8241.91N 1400,47E 8360.05~ 9.64 13054,16 51.35 351.02 -8927.02 8970.12 8427.67 92,14 8312,65N 1389.40E 8427,96~ 9,49 13148.58 51.52 350.55 4985.88 ~2:~.98 8497.'/9 94.42 8385.$2N 1377.5~E 849"/,9'~ 9.33 13242,95 52.04 350.73 .9044,26 9087,36 8568.16 94.37 8458.68N 1365.52E 8568.1~ 9.17 BHA ~ / PACKED ASSElVIBLY { 8 I/2" HOLE } 13330.06 52.11 349.47 4097.80 9140.90 8633.16 8731 8826;37N 135:LTOB 8633.16~ 9.02 13417,92 53.16 350.22 .9151.12 9194.22 8699.12 87.86 8595,10N 1341.40E 8699,14~ 8.87 PROJECTED 'fO T.D. 13432,00 53.16 350.22 .9159.57 9202.67 8709.79 14,08 8606.21N 1339.4gE 8709.82~ 8.85 .. 6002113.33 675419.21 6002187.04 675409.72 6002259,81 675399.54 6002333,35 675389.11 6002406,46 675378.88 6002481.02 675367.29 6002553.79 675354.04 6002627,01 6/5339.69 6002697,17 675326.59 6002766.99 675314.24 6002837.44 675301.52 6002910.01 675288.01 6002982.86 675274.25 6003050.25 675260,r/ 6003118,67 6'75246.96 6003129,73 675244.79 DL$ Cum. (dg/IOOfl) {dcg) Sun~ Tool 1.63 13~.8 BPHIVI.PBD 0,90 136,6 BPRM-PBD 0,49 137.1 BPHM-PBD 0.79 137.8 BPIilVI-PBD 0.39 138.2 BPltM-PBD 1,63 139.7 BPHM-PBD 1107 140;7 BPHM-PBD 1.72 '142.3 BPHM-PBD 1,49 143.7 BPHM-PBD 0.40 144.1 BPttM-PBD 038 144.8 BPttbLPBI) 0.43 145.2 BPHM-PBD 0.57 145.7 BPHM-PBD 1,14 146.7 BPHM-PBD 1,37 147,9 BPHM. PBD 0.00 147.9 BPI-Rvf.PBD -" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. [] Development Plan RTE - 74' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Point Mclntyre P.O. Box 196612, Anchorage, Alaska 99519-6612 []Service 4. Location of well at surface 8. Well Number P1-23 1370' NSL, 951' WEL, SEC. 16, T12N, R14E 9. Permit Number At top of productive interval 96-124 1099' SNL, 506' EWL, SEC. 10, T12N, R14E 10. APl Number At effective depth 50-029-22690 11. Field and Pool At total depth Point Mclntyre 628' SNL, 424' EWL, SEC. 10, T12N, R14E 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner ADJUSTMENT TO Hole: 12-1/4", Casing: 9-5/8", Wt: 40#, Grade: L-80, Coupling: BTC, Length: 3976', Top 10-401, MD: 41', Top TVD: 41', Bottom MD: 4017', Bottom TVD: 3623', Cement: 1310 sx Surface Casin~: CS II1~ 405 sx 'G'~ 250 sx CS II ,- There Are No Other Chan.qes~ At This Time .o Perforation depth: measured true vertical RECr---:iVED Tubing (size, grade, and measured depth) JUL Packers and SSSV (type and measured depth) ~?,~s "'" Commission Alaska 0il & O...:m,. 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sk~'~'~t]ul*''- 14. Estimated date for commencing operation 15. Status of well classifications as: July 24, 1996 16. If proposal was verbally approved [] Oil [] Gas [] Suspended Blair Wondzell 07/19/96 Service Name of approver Date approved Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number Terrie Hubble, 564-4628 17. I hereby certify that ~ng i~~ct to tho best of my knowledge Signed SteveShultz Title Senior Drilling Engineer Date ¢~L) - ~'--~Commission Use Only Conditions of Approval: Notify Commission so representative may witness I Approval No. Plug integrity __ BOP Test __ Location clearance __ Mechanical Integ?~/Oqj'est Subsequent form required 10-~ ~'o 7 .,.,~o,~e6 '-'~' Approved by order of the ComCn'~ss~'~t ~..~~ Original Signuu 5; Commissioner Form 10-403 Rev. 06/15/88..~i'~"~~ David W, J01~nst0n Submit In Triplicate,~, BP EXPLOR.airlON To: B. Wondzell Date: July 22, 1996 A~ From: J. Smith SSD Subject: Surface Casing Depth Correction Per our verbal agreement on Friday, July 19,1996, SSD has corrected a sand naming error on the permit for the P1-23 well (permit number 96-124) in Point Mclntyre. The change places surface casing on that well at a depth of 4017'MD and 3623'TVD (10' TVD into the SV4 sand) instead of the incorrect values of 5596'MD and 4553'TVD. This change has produced a revision to the amount of cement required to bring cement to surface. We plan to pump 250% excess cement in the permafrost and 30% excess for remaining intervals on the surface hole. There are no changes to the 7" longstring, tubing or directional plan on the well. Sincerely, Smith SSD Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION July 18, 1996 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz, Sr Drlg Engr ARCO Alaska inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Pt Mclntyre P1-23 ARCO Alaska, Inc. 96-124 1370'NSL, 951'WEL, Sec 16, T12N, R14E, UM 628'SNL, 424'EWL, Sec 10, T12N, R14E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J~hnston Chairman ~ BY ORDER OF THE COMMISSION slh/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type Of Well [] Exploratory [] Stratigrapl~ic T(~st [] Development Oil [] Re-Entry [] DeepenI [] Service [] D..ev. el.0pment Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 74' Point Mclntyre 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034622 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1370' NSL, 951' WEL, SEC. 16, T12N, R14E Point Mclntyre At top of productive interval 8. Well Number Number U-630610 1099' SNL, 506' EWL, SEC. 10, T12N, R14E P1-23 Attotal depth 9. APl~roximate spud date' Amount $200,000.00 628' SNL, 424' EWL, SEC. 10, T12N, R14E 07/22/96 12. Distance to neares;~ p'rop~rty line"1 i'3. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD arid TVD) ADL 028297, 4652'! No Close Approach 2560 13422' MD / 9189' TVD 16. To be completed for deviated wells i17, Anticipated pressure {see 2o AAC 25.035 (e)(2)} Kick Off Depth 1000' Maximum Hole Angle 54° Maximum surface 3516 psig, At total depth (TVD) 8844' / 4400 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arcticset (Approx.) i2'-1/4" 9-5/8" '40# L-80 ..... Btc 5555' 41' 41' 5596' 4553' 1152 sx CS III, 759sx'G',25OsxCSII 8-1/2" 7" 26# L-80 Btc Mod 13381' 41' 41' 13422' 9189' 258 sx Class 'G' ......... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ~C~'IVED Production Liner JUL 1 6 1996 Alaska 0il & 0as Cons. Perforation depth: measured true vertical 20. Attachm'ents [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter sketch [] Ddliing Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , Contact Engineer Name/Number: Jim Smith, 564-5026 Prepared By Name/Number Kathy Campoamor, 564-5122 21. I hereby certify that the fore_going is true and, co'rrect to the best of my knowledge Signed ~ L.~(X~ ..... SteveShuitz ~ Title Senior Drilling Engineer Date ' ' ~ Commission Use Only ' ' ' , Permit Number I APINumber [ ApprovalDate I Seecoverletter ~"-.-//.2_.,¢,Z 50- 02_ ~--- ~ ~----~' ~'~:::~ .,/ ,- ) ~ ~ ~ for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes '~ No Hydrogen Sulfide Measures ~l~['yes [] No Directional Survey Required ~Yes [] No RequiredWorking01~l'¢t~/r~j'e~,J~~.~ []2M; []3M; ~5M; EI10M; []15M Other: David W. Johnston by order of Approved By Commissioner the commission Date[ Form 10-401 Rev. 12-01-85 Submit In Triplicate I WellName: IP1-23 Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 1370' FSL, 951' FEL, Sec. 16, T12N, R14E UM Target Location: 1099' FNL, 506' FWL, Sec. 10, T12N, R14E UM Bottom Hole Location: 628' FNL, 424' FWL, Sec. 10, T12N, R14E UM I AFENumber: 12C0102 [ I EstimatedStartDate: 17/22/96 MD: I 13422' I Well Design (conventional, slimhole, etc.): [ Rig: [Doyon#14 Operating days to complete: ] 25 IT VD: 19189'rkb I IKBs: I74' [ slimhole longstring ] Objective: I Kupamk Sand Formation M:arkers: Formation Tops MD TVD(BKB) Base Permafrost 1859 1853 K-15 6376 5013 West Sak 9474 6838 9.5 ppg minimum mud weight required K-10 12278 8509 K-5 12337 8544 HRZ 12640 8724 Kalubik 12724 8774 Kupamk 12830 8837 10.0 ppg minimum mud weight required TD 13422 9189 Evaluation Program: ISURFACE PRODUCTION CASED HOLE LOGS Anadrill directional MWD only None GR-RES-DEN-NEUT from approx. 500' TVD above Kupamk to TD Well Plan Summary RECEIVED JUl._ '1 G '~99G Alaska 09 & q'-'"'./:,~ns C.~.,,mmissior, Page 1 Mud Program: Special design considerations lAn open hole displacement to +/- 10 ppg Xanvis polymer/3% KC1 water based mud will be performed above the reservoir. Surface Mud Properties: [ SPUD DENSITY Marsh Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 8.7 300 40-60 30-60 60-80 9-10 15-25 9.5 150 30-40 20-30 40-60 9-10 < 15 Production Mud Properties: I LSND initially, 3% KC1 in Kupamk DENSITY Plastic Yield Point 10 Sec Gel 10 min Gel pH Fluid Loss (PPG) Viscosity 9.8 8-15 25-30 5-15 10-20 9-10 5-10 10.4 8-15 25-30 8-12 <25 9-9.5 4-10 <15 HTHP Directional'. IKOP: I 1000' MD Maximum Hole Angle: [ 54° @ azimuth = 350° Close Approach Well: I None Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Con Length Top Btm Tbg O.D. n MDfrVD MD/TVD 30" 20" 94g H-40 WLD 80' GL 80/80 12-1/4" 9 5/8" 40.0# L-80 BTC 5555' 41'/41' 5596'/4553' 8 1/2" 7" 26.0# L-80 BTC 13381' 41'/41' 13422'/9189' Mod TBG 4.5" 12.6# 13CR80 NSCT 13,000' 41'/41' 13000'/8926' Cement Data: Casing/Liner 9-5/8" ,, Lead: SxsFWt/Yield 1152/12.2/1.92 ** 100% excess lead none Tail: Sxs/Wt/Yield 759/15.8/1.15 **30% excess tail 213/15.8/1.14 Comments Cold Set III & Class "O TOC-11922' +/- (500'TVD above Kupamk Top Out Job (if necessary) 250/14.95/0.96 Top Out--CSII Name Contacts Office Home Pager James E. Smith Adrian Clark Drilling Eng. Drilling Supt. 564-5026 564-4720 345-8660 275-4015 Well Plan Summary Page 2 Drilling Hazards/Risks The original reservoir pressure is 4350 psi at 8800' ss. Abnormally '/ pressured formation are not expected in this well. There is the remote possibility that a pressure of 4400 psig could be encountered. Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe. This has caused stuck pipe incidents and bit/BHA bailing Gumbo problems. ROP's in this section are typically very fast and care must be taken to ensure the hole does not become overloaded with cuttings. Sufficient pump rates must be achieved at all times to ensure the hole will be cleaned. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, B OPE and mud fluid system schematics on file with AOGCC. o o . o o . o , P1-23 Operations Summary MIRU drilling rig. NU and function test diverter. Spud well and drill 12-14" hole to 1000' md. Kick off and build angle to 54° on 350° azimuth by 3825'. Hold angle to 5596' md surface hole TD (4553' TVD). Set 9-5/8" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOP's and test same to 5000 psi. Note AOGCC witness or waiver on the morning report. PFLI 8 1/2" BHA, drill ew hole and perform LOT. Drill ahead and hold 54° to 13422' mdtd. Displace mud to 10 ppg 3% KC1 before top of Kuparuk. If LWD logs were not obtained while drilling run wireline open hole logs. Make a cleanout run. POH and stand back drill pipe. Run 7" L-80 casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 4-1/2" tubing and completion assembly. ND BOP and NU tree assembly. Test tree assembly to 5000 psi. Displace tubing to diesel, freeze protect the annulus. Set packer, test tubing. Test annulus. Secure well, release rig. Well Plan Summary Page 3 Sheet1 Cement Calculations I , Well # Pt Mac 1-23 Hole Size: ! 12.25 Casing Size: I 9.625 Casing I.D.: 8.681 Hole Angle: I 5 4 Lead Excess: 2 i Tail Excess: 1.3 , Lead Ft3/sackt 1.92 ~ Tail Ft3/sack; / 1.15 Casing Shoe: I 5596 Tail TVD lengt! 750i i t , Surface Lead CS III (BJ) I Cement Lengths ' Hole Size: 12.25 Hole Angle: 54 Casing Size: 9.625 TVD Length' 750 Cement Lengtl 3531.780836 ~ Depth of Shoe: 5596 Excess: ! 2 Measured Length' 2064 Cubic Feet: ! 2211.099444 Barrels: ~ 340648 i 393.4 , _ Cubic feet/sk: 1.92 Sacks: I 11 52, , Surface Tail G + 2% CaCL Shoe Volume Excess: 1.3 Length' 8 0 Cubic Feet: 840.0085221 ID: 8.681 Barrels: 149.4677085 Volume: I 32.8652291 Cubic feet/sk:l 1.15 ~Barrels: ~ 5.847905534 _, Sacks: I 730 Cubic feet/sk: 1.15 I Sacks: 28.57846009 I iTotal Lead: I 393 Bbls , 1 1 5 2 Sacks ! TOP JOB if Required _ Total Tail: i 1 55 Bbls 250sx CSII i 7 5 9 S~cks I Cement Calculations for 7" Long String Cement: G + FI33 + CD32, mix at 15.8ppg, 1.14ft3/sx, TOC 500' above Kuparuk Hole Size: 8.5 Cement Shoe Volume: 1.56 bbls 9 5/8" Csg ID: 8.681 I .7.78 ft3 _ 9 5/8" Shoe' 5596 I 6.77 sx Casing Size: i 7 Open Hole Volume: 33.83 bbls Casing ID ! 6.276 i 190 ft3 Casing Shoe: i 13422 i 165 sx Cement Lengt~ 1500 plus 50% excess: 258 sx Page 1 VERI'/CAL VI~ S~L£ 500 ft, / DIV]SEN TYD I~; I~LLI~ V~T[F~_ ~CTII~ I~D ~ELLI~AD (100 e o MD TIEIN BPX- §h~Ped Se~vlces D~i[tlng ALask~ State PI;ne: Zone4 Pt M~c', PHI Pl-83 As-BuiVc P~-83 ~p3 -500 0 5[]0 I $500 [][XiO 31X]O 3500 4U(]3 4500 55U0 6000 6500 71XIO 7500 VERTICN_ SEUTII~ PLA~: g,Oi Hi] lnc Azi. TVD N/S TIE ~ O O, O0 5.00 0 0 N 0 E ~ / ~TART lDO0 0.~ 5,DO iUCO O N O E ~ I{UILD ~ IJDO/IOO Pt S'I'A~ [}- i]l~_O 1300 3,00 5.~ i3CO B N ! E R i.50/IBO S'I'/~RT IF BUILI] 161]0 7.50 5,DO iSc,'g 35 N 3 E Buse P~n 11~ 1~,67 5.1X) !1~ BO N Z E ~q) iF BULl] lgCO i3,50 5/X) 11~3 93 N 8 E ST/~RT II:' BL~O0 i3,50 5.gO 8{B5 i5~ N 14 [ PSOtiOg r( g474 ,53.~ 14.58 6838 5437N I353 E l.OI]/i~ r~ K-lO K-5 i~C~O 5Ek~ 3So, go 8ogt 7503 N 1544 E 1~8 ~ ~ ~ 7~N 1517 E l~Y ~ ~,~ ~ ~N I~E i~D ~ ~,~ 87~4 7~4 N 14~ E 1~24 ~ ~,~ B~4 ~10 N 14~ E l~O ~ ~,~ g~ ~4N i~E ID Ik, p~fO 1~ I pt.--~j {,Ip3 g-tD4~ ~a~ ~ J P'~uOSED ~L TVD 9iBg. lO MD 134Ei.69 VS BG~9.33 NFS' 8E6~.43 N E/W i3~Z.~ E :D :D JUL tl iT~ N~t ~v~ t4s __E~ . C~dX __ ~d ~L-i T~-.~-H: i ~-y~ ~ ~ N ~440 r- G.~=j353' NNF~U_~[AN FEASIBII.11Y STUDY plan tm for ~lbil;'l~ RECEIVED A/ask~q Oil E Gas Cons. CoF~missi°'" Survey Re. feeac~: WBLLHEAD Rd~eace World Coofdh{~..,: Iai. 70.2326 N- Long, 148.35,01 W Rd~,,c~ GRID Sys~,',.' Ahska Sia. Ylauo 7,on~: Alaska 4 l~f~ao~ OR ID Coo~dina~: {IO: 599449M2N 674106.94 E No~ All.od To: TRIIBEO[llt Vmical Soc~io~ Rdea etx:e.: WI~.I _HEAD Go{ute Pafg,~moe: WELLHEAD Halliburton Energy Services. Drilling Systems PSL , l'roposal Report VeStal g~ion ?hao: 9.01 deg. Paso I {h~oid No: Dale', 7/I, 1/96 ]'iz~: 10:Zl ID: ~ 1-~ Wp3 WELLPLAN FEASlBitlTY STUDY, It ha~ not ye~ be~n c~ttifltdl BPX "~d Servic~ PI Mac'~: FMI Pi-23 As-l}uill kit~m-~{ In~i Drift ~ TVD Courso TOTAL GRIDCoonfmales Clmma~ Ve. st{~ Bttild Walk DL.q Gum. Bx~Totai MaxHot MiaHot Di.r. Vm D~h Dir. ~ Lu~h R~ulzr Ofls~ Noztbia8 F,~fi~ Di~. Dh. $oclioa Rate lh~ Dogkg R~augulax Coot& ikror Ea~ Max Ea Error 01) (d,~g.) (d~) 0~) 0t) (ii) (ii) (ii) (ii) (t0 (fl) (deg.) (fl) (dg/lOOit) (dg/10Of0 (dg/10Oft) (dM) (ii) ~) 0t) (fl) (dog.) (ft) 0,00 0,00 0.03 -43.10 0.00 0.00 0.00N 0.00E 5994495,12674106.94 0.(K~ 0,00 O,00 0,0O 0,00, 0,00 0,0 0,00N 0,00B 030 0,00 0.00 0.00 MWD KOP/START OF BUILD ~ I.O0de~100 It I000,00 0,00 0.03 956.90 I000.00 100020 0,00N O.00E 5994495.126'/41~94 0,(t~ 0,00 0,00 0.01) 0,~0 it00 0.0 0.00N 0,00E 2.02 2,02 0,00 1.44 BPIIM-PBD 1100.00 1.00 5.03 105639 1099.99 10030 O.87N O.08E 5994496,03674106.99 0.8?4} 5.00 0.87 1.00 O.00 1,00 1,0 0,87N O,~E 2.02 2,0l 275.~ 1,59 B?HM-?I~D 1200.00 2,00 $.03 115636 1i99.96 lO0.~0 3.48N O.30E 5994498,61 67410?.16 3,_4~ 5.00 3,48 1.00 0~00 1,00 2,0 3,48N O,3lE 2.03 2,02 275,00 i,74 BPHM-PBD START OFBU[LD @ i.{O&g/100 it i300,00 3,00 $.03 1256.76 I299.86 100.00 7.82N O.68E 5994502,9667410'/.44 ?,8518 5,00 7,83 LO0 O,00 1,00 3.0 7,82N 0.69[} 2.06 2,03 275,0D t.89 B?HM-?BD i400.00 4,50 5.1301356.55 I399.65 100.~0 14.34N [.25E 59945~9,4~67410/.{$ 14,3~ 5,00 14,36 1.50 O.00 1.50 4.5 14.34N 123E 2.13 2.04 275,00 2.03 15~oO 6,00 5.O0 1456.12 1499.22 i00.O0 23ASN 2.O5E 5994518,6267410~.44 23,54~ 5.00 23,48 i.50 O.00 1.50 6,0 23,45N 2.06E 2.27 2.06 275,00 LIS B?HM-?BD ST. )F BU[LD @ ZOO d~flaO ii 160o330 7,50 $.00 1555.43 1598,53 i~.O0 35.16N 3.04E 5994530,35 674109. D 35,3f~g 5,00 35,2! {.50 O.00 1.50 7.5 35,16N 3.10[} 2.51 2,09 275,00 2.33 1700,00 9,51) 5.03 165432 1697.42 100.~0 49.89N 436E 5994545.(}9674111}.14 50,O~ 5,00 49,95 2.00 0,00 2.00 93 49,88N 4.40E 2.89 2,14 275,00 2.48 BPHM-PBD 1800,00 11,50 5.O0 1752.~ 1795.74 100.[}0 68.04N 5.95E 5994563.28674111.3D 61,3C~ 5.00 68.13 7.00 O.00 2,00 11,5 68,03N 6,0lB 3.42 2,21 275,00 2.63 BPHM-?BD 1858,66 1Z,67 $.00 18IO.00 1853,10 58.66 8~.27N 7.0ZE 59945'i5,53 674112,09 80.55~ 5,00 80,3{{ 2.00 O,00 2,00 12.7 80.27N 7,09B 3.79 2,26 275,00 2.72 BPHM-?BD ENI) OFBUILD i900,O0 i3,50 5.00 185027 i{193.37 41.34 89.60N 7.84E 5994584,88 674112.69 89,94~ 5,00 89,72 7..00 0.00 2.00 133 89.59N ?,92B 4,08 2,31 275,00 2.78 BPttM-PBD Zl00,O0 1351) 5.00 204~74 2OB?,84 Z00.00 i3&IIN II.91E 5~94631,47674115.67 136,63~ 5,00 136.30 O.00 0.00 0,00 135 136,10N 12,05B 5.55 2.57 275,00 3,08 BPHM-?BD START OF CUXVE ~ 2,50 deg/i~ § 2Y.00.00 13.Y) 5.00 2141..98 2185,08 I00.00 15937}< 13.94E 5994654.76674117. i? 159.9'/g 5.00 159.58 O.00 0.00 0.00 133 159.35N 14. lIE 6.32 2,73 275,00 323 BPHM-PBD 2300,00 15.95 6.88 2238.69 2281,79 100.00 184,~N 16.61E $~94680.O9 674119.24 155.3~ 5.14 IM,97 2.45 1.88 2,50 16,0 184,62N 16,83B 7.23 2,92 275,26 338 BPHM-?BD 2403.00 111.4l 8.;26 233432 237732 100.00 215,93N 20.52E 5994709,46674122.47 214,918 5.48 Z14,50 7.4? 1.3~) 230 18.5 213,89N 20,84E 8.30 3,16 275,68 3.54 BPHM-PBD ZS00,00 20,89 9.33 2428.38 2471.48 100.00 247,16N 25.69E 5~94742.80 674126.16 24~,5C~ 5,93 248.14 2.47 1.07 2.50 21.0 247,11N 26.12B 9.51 3,43 176,17 3,70 BPHM-I~D 2600,0{)2337 IO. 192521.00 2564,10 100.00 28419N 32.09E 5994780,O76741~L41} 286.1C~ 6,44 285,81 2.48 0.~5 2,50 23.5 284.21N 32.(7)1] 10.87 3.75 276.70 3.87 BPHM-PBD 2700.00 2536 10.{18 2611.91 2655.01 100.00 325,24N 3932E 5994821,11 674139.07 327,65~ 6,96 327,44 2.48 0.70 2.50 26.0 325,11N 40.53E 12.38 4,11) 277,23 4,O5 BPHM-PBD JUL 11 ~96 10:4?AM ALASKA HALLIBURT©M DRILLIM~ WELLPLAN FEASIBILITY STUDY, This p~an iB los' 'fe.~ibilify pugpO~l~ Halliburton Energy Services- Drilling Systems PSL Proposal Repofl Pa§o 3 Da~: '/t!1/96 Wellpa~ ID: f!43 Wpl ~ ~I Drift Subs~ I'VD Co~o TOTAL. GlflDC. ootdin~ ~ Ve~ical 13~ld Walk DLS (3nm Bxpr. aedTotal Ma~Ho~ MiaHor Dir. Vat ~yTool l)~h Oir. DepSt ~ lO.a~gularOgset~ N~ Eu~g Di~t. Dk, $~ioa I~ llato Doglcg R~uCoo~ls ~ror Faor M~F~r ~ (~) (~) (~q.) (~t) (fi) (~) (~) . (~) (f0 (it) (f0 (d~,.) (~) (dg/100it) (~dt~) (d~0Ofl) O~ (~) ~) (~) (n) 8~g,) 11901,95 53,33 352,1t 8243,00 8286.10 !00.00 7360.65N 156638E 6001~89.92 675500.62 7525.439 12.01 '/515.11 0,08 -1,24 I.~0 ~/2.17341,94N 163~,38E 2'/5.28 50.63 282,0.~; 62.44 BPH~.?BD 12110L95 $].47.350,94 8302,65 8345,75 lO0.00 7440.~N ISS4.601t 6001969.00675456.99 7600.710 It.S0 7591.67 0,09 -1,~ 1.00 73.1 74ZI.23N l(OJ.~)l~ 277,95 51.11 281,vl 63,12 BPi~I-PBD END OF CURVE 12079,92 53,5~) 350,00 11347,$18390,9~ 75.96 750{).221'/ 154430E6002028,93 675475A9 765./.6(~g 11.64 764~).5t 0,10 -124 ID0 73.9 748133N 1615,37F.. 2'/9,99 51.48 231,67 63,64 I~PI1M-PBD g-10 1227&49 53.50 3~.00 M66,00 ~509.10 19838 7657,42N 1516.78E 6UO2115A3675444.11 71~06.2L@11.20 7800,46 0.00 0,00 0,00 73.9 7635.29N 1556,311~ 2~53Z 52,44 231.25 65,00 BPHM-P~D 12317,3353.5~ 350,00 8501.00 ~544, t0 5~,lgl ./704,00N 1508.57E 6002231.80675434,82 7~50.32@ Il.08 7845,18 0.00 0,00 0,00 ?3,9 7684.81N 1577,70B 2a6.90 52,72 281.1Z 65.40 BP}tM-PBD 12639,9453.50 350.00 8681.00 $~24,10 3~61 7943,56N 1~66.32E 6002470.29 675387,01 80~7.77@ 10.46 8075,17 0.0~ 0.00 0.00 73,9 7924,011¢ ~533,42E 295,06 54.18 280,51 67,46 BPHM. PBD 12724.00 53.50 350.00 8731.00 $774,10 84.06 IOI0.11N 145439B 6002536.53 6/53~3.73 8141,11@ 10,29 8137.0~ 0.0D 0.00 0.O0 73.9 7990,45N lSZl,llg 29./34 54.59 280,:35 68,03 I~PHM-PBD 128B.92 5L50 350,00 8794.00 $837.10 !~.91 109~.95N 1439.811t 60{R620.006/5357.00 8221.02@ 10,09 8219.56 0,00 0.00 0.00 73.9 1074,17N 1505.6213 3~0.21 ~5.10 280,14 6B,,/5 BPHM-PBD CASING POINT OD ='/ia, ID =6.2a in, W~ight = 26~lh/E 13421.60 53.50 350.00 9145.95 9189,05 591.68 156Z.36N 1357.21E 6003086.31 675263,53 1f)69.2~ 9,01 8669.26 0.00 0.00 0.00 7:L9 ~562.36N 1357,2113 030 0,00 0.00 0,00 BPHM-PBD 13421.69 53,50 350.00 9146,00 9J~9.10 0.09 S56Z.43N 1357.20E 6003086,31 6'/5263.52 1(f~9.33~ 9,01 8669.33 0.00 0,00 0.00 73.9 g541.94N 1419,02E 316,29 57.99 279.08 TL79 BPItM-PBD · WELL PER'lIT CHECKLIST GEOL AREA/ '/~"~ UNIT# ///~'¢/~'(-~ ON/OFF SHORE AD M IN ISTRATION 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number ................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drlg unit boundary ..... N 6. Well located proper distance from other wells ......... N 7. Sufficient acreage available in drilling unit ........... N 8. If deviated, is wellbore plat included .............. N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............ N 11. Permit can be issued without conservation order ...... N 12. Permit can be issued without administralJve approval .... N 13. Can permit be approved before 15-day wait ......... N ENGINEERING APPR%.~L...... D~¢.¢=, GEOLOGY 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ......... .f,.)~ N 16. CMT vol adequate to circulate on conductor & surf csg .... d~ N 17. CMT vol adequate to tie-in long string to surf csg ....... 18. CMT will cover all known productive hodzons ......... (~ N 19. Casing designs adequate for C, T, B & permafrost. ..... ~,, N 20. Adequate tankage or reserve pit ................ LY_M N 21. If a re-drill, has a 10-403 for abndnmnt been approved... 22. Adequate wellbore separation proposed ............ (~N 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... 25. BOPEs adequate ........................ ,,.z,, N 26. BOPE press rating adequate; test to .~-~)~_ psig.i~N 27. Choke manifold complies w/APl RP-53 (May 84) ....... f,~Y_~N 28. Work will occur without operation shutdown ......... .,..~ N 29. Is presence of H2S gas probable .............. ~ N ,,/ 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~' ,,¢' / ,,~ 31. Data presented on potential overpressure zones ....... Y/,N' /~.,,/.~~ , 32. Seismic analysis of shallow gas zones ............. /v/ N ' 33. Seabed condition survey (if off-shore) ........... //Y N 34. Contact name/phone for weekly proq. ress reports .... /'... Y N [~ror~/ only] " REMARKS GEOLOGY: ENGINEERING: COMMISSION: BEW ~ 7'//t[8 DWJ~ JDH %Tf-,=F-~' JUN Comments/Instructions: t::::::2 O o I--3 HOW/I~ - A:~FORMS'~eklist rev 4¢96
