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HomeMy WebLinkAbout169-0321. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,124' N/A Casing Collapse Structural Conductor Surface 1,970psi Intermediate Production 3,080psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman, Operations Engineer Contact Email:eric.dickerman@hilcorp.com Contact Phone: 907-564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Attached Schematic 8,097' 6,618' Length See Attached Schematic See Attached Schematic 6,884' 6,618' 5,632' 16" N Cook Inlet Unit A-05CO 68A Same 6,861'7" ~249psi North Cook Inlet Tertiary System Gas Size 385' November 26, 2025 4-1/2" 385' 30" 8,097' Perforation Depth MD (ft): See Attached Schematic 3,350psi 643'643' 2,571' 643' 2,571' MD 385' 10-3/4" 12.75# / J-55 TVD Burst 6,452' 4,080psi 2,382' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 169-032 50-883-20025-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 AOGCC USE ONLY Tubing Grade: 12.6# / J-5 Tubing MD (ft): 311'Perforation Depth TVD (ft): Subsequent Form Required: Operations Manager Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 4-1/2" PRESENT WELL CONDITION SUMMARY m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.11.12 05:45:46 - 09'00' Dan Marlowe (1267) 325-693 By Grace Christianson at 9:27 am, Nov 12, 2025 SFD 11/13/2025 Perforate DSR-11/13/25 *Service coil BOPE pressure test to 3000 psi. 48 hour notice to AOGCC. MGR12NOV2025 10-404 JLC 11/13/2025 11/13/25 Fill Clean Out and Perforate Well: North Cook Inlet Unit A-05 Well Name: NCIU A-05 API Number: 50-883-20025-00 Current Status: Online, Gas Well Leg: Leg #3 (SE corner) Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 169-032 First Call Engineer: Eric Dickerman (907) 564-4061 Second Call Engineer: Casey Morse (907) 777-8322 Maximum Expected BHP: 700 psi at 4,512’ TVD – 0.16 psi/ft - based on BHP from nearby wells NOTE: Shut in BHP survey 8/12/2012 showed 450 psi at 4,512’ TVD Max. Potential Surface Pressure: 249 psi MPSP - 0.1 psi/ft gas grad. to surface Field/Pool: North Cook Inlet Unit, Tertiary System Gas Pool Brief Well Summary: NCIU A-05 was initially drilled in 1969 and completed in the Sterling and Beluga Formations of the Tertiary System Gas Pool. In July 1981, the Beluga interval was isolated and the well produced from the Sterling interval only. In August 1994 the well was worked over and the Sterling and half of the Beluga intervals were re- perforated. A cement retainer was set and isolated lower Beluga intervals. A coiled tubing cleanout was performed in June 2006 with moderate success. The well was worked over in December 2007 to replace a failed subsurface safety valve landing nipple and add gas lift mandrels. Recently, the well’s production decline rate has steepened. The most recent slickline tag was at 5,783’ on 9/19/2023 putting approximately 670’ of perforations below the top of fill. Objective: Coiled tubing fill cleanout to return well to production. Test production after cleanout. Add eline perforations. Wellbore information: Well is completed with a wireline retrievable subsurface safety valve. North Cook Inlet Unit, Tertiary System Gas Pool top = Top of Sterling sands, at 3,662’ md / 3,263’ tvd. North Cook Inlet Unit, Tertiary System Gas Pool Bottom = Base of Beluga sands (below TD). Sterling intervals are currently isolated behind sliding sleeves and have tested to be higher watercut. 9/19/23 Slickline bailed fill from 5,479’ down to 5,783’ over two days. 9/30/23 Eline completed perforating the Beluga A, B, C, and D intervals. Fill Clean Out and Perforate Well: North Cook Inlet Unit A-05 Coiled Tubing Cleanout: 1. MIRU Fox Offshore Coiled Tubing Unit #9 and pressure control equipment. 2. Pressure test BOP and PCE to 250 psi low / 3,000 psi high. a. Provide AOGCC with 48hr witness notification for BOP test. 3. MU cleanout BHA. Dry tag top of fill, then begin cleaning out to CIBP at 6,618’. a. Working fluid will be 6% KCl (8.6 ppg). b. Take returns to surface from the coiled tubing backside. c. Add foam and nitrogen as necessary to carry solids to surface. 4. RDMO CTU. Eline Perforate: 5. MIRU Eline. 6. Pressure test PCE and treating iron to 250 psi low / 3,000 psi high. 7. Perforate the infill target intervals per the perf table below. All perforations are within the North Cook Inlet Unit, Tertiary gas pool. Sand Interval Perforation Top (MD) Perforation Bottom (MD) Perforation Interval Footage (ft.) Beluga_Aa 5218 5231 13 Beluga_Ab 5248 5255 7 Beluga_Ac 5286 5301 15 Beluga_Ad 5303 5312 9 Beluga_Ba 5324 5341 17 Beluga_Bb 5355 5361 6 Beluga_Bc 5365 5371 6 Beluga_Bd 5434 5450 16 Beluga_Be 5454 5457 3 Beluga_Bf 5479 5483 4 Beluga_Ca 5558 5571 13 Beluga_Cb 5592 5600 8 Beluga_Da 5707 5715 8 Beluga_Db 5730 5738 8 Beluga_Dc 5746 5754 8 Beluga_Dd 5769 5778 9 Beluga_De 5782 5792 10 Beluga_Ea 5821 5835 14 Beluga_Eb 5839 5855 16 Beluga_Ec 5886 5894 8 Beluga_Ed 5922 5933 11 Fill Clean Out and Perforate Well: North Cook Inlet Unit A-05 Beluga_Ee 5958 5965 7 Beluga_Ef 5974 5981 7 Beluga_Eg 5992 6012 20 Beluga_Fa 6040 6047 7 Beluga_Fb 6067 6072 5 Beluga_Fc 6108 6117 9 Beluga_Ga 6162 6173 11 Beluga_Gb 6179 6190 11 Beluga_Gc 6195 6206 11 Beluga_Ha 6239 6243 4 Beluga_Hb 6266 6282 16 Beluga_Hc 6336 6343 7 Beluga_Hd 6346 6356 10 Beluga_He 6399 6403 4 Beluga_Ia 6435 6445 10 Beluga_Ib 6476 6483 7 8. RDMO Eline. Attachments: 1. Correlation log 2. Current Wellbore Schematic 3. Proposed Wellbore Schematic 4. CT BOP Drawing 5. Nitrogen procedure Fill Clean Out and Perforate Well: North Cook Inlet Unit A-05 Correlation Log: Updated By: JLL 10/27/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PBTD:6,618’ TD:8,124’ 30” RKB: 39.4 7” 3 4 5 6 7 8 9 10 11 12 13 10-3/4” B-2 / B-6 16” 1 2 15 16 A-2 E-4 / E-9 D-1 / D-3 F-4 / F-8 H-3 / H-8 G-1 / G-5 K-2 / K-5 / L-2 / N-1 / N-5 / P-2 P-3 / P-5 / R-3 C-1 14 C I 8.2 C I 10.0 C I 11.0 C I 6.2 C I 5.0 C I 1.0 C I 2.0 C I 3.0 C I 6.0 D-4 / D-5 X XN Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM 30” Conductor Welded 29.000 Surf 385’ 16” 65# H-40 Welded 15.250 Surf 643’ 10-3/4”45.5# & 51#J-55 BTC 9.794 Surf 2,571’ 7” 26# J-55 BTC 6.366 Surf 79’ 23# J-55 BTC 6.366 79’ 7,127’ 26# J-55 BTC 6.366 7,127’ 8,097’ Tubing Detail 4-1/2” 12.6# J-5 IBT Mod 3.958 Surf 311’ 4-1/2” 12.75# J-55 8rd Mod 3.958 305’ 6,452’ Jewelry Details No Depth MD Depth TVD ID OD Item 39.4’ 39.4’ 4.500 FMC Tubing Hanger 1 270’ 270’ 3.813 Halliburton XXO SVLN w/ FXE X-Lock WRDP (ID 2.12) 2 1,770’ 1,726’ Camco KBG-2 GLM 3,351’ 3,013’ Camco KBG-2 GLM 4,277’ 3,751’ Camco KBG-2 Orifice 3 4,333’ 3,795’ 3.860 Upper Body PBR Assembly - Ratch latch seal assembly 4,339’ 3,799’ 4.000 Halliburton VSR Packer 4 4,377’ 3,830’ 3.813 Halliburton X Nipple 5 4,660’ 4,058’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/22/2003) 6 4,696’ 4,087’ 3.930 No-Go Seal Assembly 4,698’ 4,089’ 4.000 Halliburton TWR Packer 4,703’ 4,093’ 4.276 Millout Extension 7 4,804’ 4,175’ 3.930 No-Go Seal Assembly 4,807’ 4,177’ 4.000 Halliburton TWR Packer 4,810’ 4,180’ 4.276 Millout Extension 8 4,864’ 4,223’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/23/2003) 9 4,869’ 4,227’ 3.930 No-Go Seal Assembly 4,870’ 4,228’ 4.000 Halliburton TWR Packer 4,874’ 4,232’ 4.276 Millout Extension 10 4,975’ 4,313’ 3.930 No-Go Seal Assembly 4,976’ 4,314’ 4.000 Halliburton TWR Packer 4,980’ 4,318’ 4.276 Millout Extension 11 5,208’ 4,503’ 3.813 Halliburton XD Sliding Sleeve (Closed) 12 5,212’ 4,506’ 3.930 No-Go Seal Assembly 5,213’ 4,507’ 4.000 Halliburton TWR Packer 5,217’ 4,510’ 4.276 Millout Extension 13 5,818’ 4,994’ 3.813 Halliburton XA SSD Sliding Sleeve (Open 5/24/2003) 14 6,450’ 5,497’ 3.725 Halliburton XN Nipple 15 6,451’ 5,498’ 3.933 Wireline Re-Entry Guide 6,452’ 5,499’ End of tubing assembly 16 6,618’ 5,632’ CIBP Updated By: JLL 10/27/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI 1.0 4,450’ 4,515’ 3,889’ 3,941’ 65' 08/07/1994 Open CI 2.0 4,535’ 4,610’ 3,957’ 4,018’ 75' 08/07/1994 Open CI 3.0 4,630’ 4,650’ 4,034’ 4,051’ 20' 08/07/1994 Open CI 5.0 4,770’ 4,785’ 4,147’ 4,160’ 15' 05/08/1969 Open CI 6.0 4,832’ 4,862’ 4,197’ 4,222’ 30' 08/07/1994 Open CI 6.2 4,890’ 4,915’ 4,244’ 4,265’ 25' 05/08/1969 Open CI 8.2 5,042’ 5,052’ 4,368’ 4,376’ 10' 08/07/1994 Open CI 10.0 5,129’ 5,144’ 4,438’ 4,450’ 15' 08/01/1994 Open CI 11.0 5,196’ 5,206’ 4,493’ 4,501’ 10' 08/07/1994 Open A-2 5,220’ 5,230’ 4,513’ 4,521’ 10' 08/07/1994 Open Ab 5,248’ 5,254’ 4,536’ 4,540’ 6’ 09/29/2023 Open Ac 5,290’ 5,300’ 4,570’ 4,578’ 10’ 09/29/2023 Open Ad 5,303’ 5,312’ 4,580’ 4,587’ 9’ 09/29/2023 Open Ba 5,324’ 5,341’ 4,597’ 4,611’ 17’ 09/29/2023 Open B-2 5,357’ 5,361’ 4,624’ 4,627’ 4' 08/07/1994 Open Bc 5,434’ 5,451’ 4,686’ 4,700’ 17’ 09/30/2023 Open B-5.5 5,454’ 5,456’ 4,703’ 4,704’ 2' 08/07/1994 Open B-6 5,479’ 5,483’ 4,723’ 4,726’ 4' 08/07/1994 Open C-1 5,561’ 5,571’ 4,790’ 4,798’ 10' 08/07/1994 Open Cb 5,592’ 5,600’ 4,814’ 4,820’ 8’ 09/28/2023 Open D-1 5,709’ 5,714’ 4,907’ 4,911’ 5' 08/07/1994 Open Db 5,730’ 5,737’ 4,924’ 4,930’ 7’ 09/28/2023 Open Dc 5,746’ 5,754 4,937’ 4,943’ 8’ 09/28/2023 Open D-2.5 5,773’ 5,778’ 4,958’ 4,962’ 5' 08/07/1994 Open D-3 5,782’ 5,792’ 4,966’ 4,973’ 10' 08/07/1994 Open D-4 5,825’ 5,835’ 5,000’ 5,008’ 10' 08/07/1994 Open D-5 5,840’ 5,855’ 5,012’ 5,024’ 15' 08/07/1994 Open E-4 5,922’ 5,932’ 5,077’ 5,085’ 10' 08/07/1994 Open E-9 6,000’ 6,010’ 5,139’ 5,147’ 10' 08/07/1994 Open F-4 6,111’ 6,116’ 5,227’ 5,231’ 5' 08/07/1994 Open F-7 6,163’ 6,173’ 5,269’ 5,277’ 10' 08/07/1994 Open F-8 6,180’ 6,190’ 5,284’ 5,292’ 10' 08/07/1994 Open G-1 6,196’ 6,206’ 5,296’ 5,304’ 10' 08/07/1994 Open G-5 6,267’ 6,282’ 5,352’ 5,364’ 15' 08/07/1994 Open H-3 6,346’ 6,356’ 5,415’ 5,423’ 10' 08/07/1994 Open H-8 6,435’ 6,445’ 5,489’ 5,497’ 10' 08/07/1994 Open K-2 6,680’ 6,685’ 5,681’ 5,685’ 5' 1994 Isolated K-5 6,752’ 6,762’ 5,739’ 5,747’ 10' 1994 Isolated L-2 6,784’ 6,789’ 5,765’ 5,769’ 5' 1994 Isolated N-1 7,024’ 7,032’ 5,961’ 5,967’ 8' 1994 Isolated N-5 7,095’ 7,110’ 6,020’ 6,032’ 15' 1994 Isolated P-2 7,286’ 7,296’ 6,178’ 6,186’ 10' 1994 Isolated P-3 7,316’ 7,321’ 6,203’ 6,207’ 5' 1994 Isolated P-5 7,374’ 7,384’ 6,251’ 6,259’ 10' 1994 Isolated R-3 7,526’ 7,536’ 6,378’ 6,386’ 10' 1994 Isolated Updated By: JLL 10/27/23 PROPOSED SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PBTD:6,618’ TD:8,124’ 30” RKB: 39.4 7” 3 4 5 6 7 8 9 10 11 12 13 10-3/4” B-2 / B-6 16” 1 2 15 16 A-2 E-4 / E-9 D-1 / D-3 F-4 / F-8 H-3 / H-8 G-1 / G-5 K-2 / K-5 / L-2 / N-1 / N-5 / P-2 P-3 / P-5 / R-3 C-1 14 C I 8.2 C I 10.0 C I 11.0 C I 6.2 C I 5.0 C I 1.0 C I 2.0 C I 3.0 C I 6.0 D-4 / D-5 X XN Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM 30” Conductor Welded 29.000 Surf 385’ 16” 65# H-40 Welded 15.250 Surf 643’ 10-3/4”45.5# & 51#J-55 BTC 9.794 Surf 2,571’ 7” 26# J-55 BTC 6.366 Surf 79’ 23# J-55 BTC 6.366 79’ 7,127’ 26# J-55 BTC 6.366 7,127’ 8,097’ Tubing Detail 4-1/2” 12.6# J-5 IBT Mod 3.958 Surf 311’ 4-1/2” 12.75# J-55 8rd Mod 3.958 305’ 6,452’ Jewelry Details No Depth MD Depth TVD ID OD Item 39.4’ 39.4’ 4.500 FMC Tubing Hanger 1 270’ 270’ 3.813 Halliburton XXO SVLN w/ FXE X-Lock WRDP (ID 2.12) 2 1,770’ 1,726’ Camco KBG-2 GLM 3,351’ 3,013’ Camco KBG-2 GLM 4,277’ 3,751’ Camco KBG-2 Orifice 3 4,333’ 3,795’ 3.860 Upper Body PBR Assembly - Ratch latch seal assembly 4,339’ 3,799’ 4.000 Halliburton VSR Packer 4 4,377’ 3,830’ 3.813 Halliburton X Nipple 5 4,660’ 4,058’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/22/2003) 6 4,696’ 4,087’ 3.930 No-Go Seal Assembly 4,698’ 4,089’ 4.000 Halliburton TWR Packer 4,703’ 4,093’ 4.276 Millout Extension 7 4,804’ 4,175’ 3.930 No-Go Seal Assembly 4,807’ 4,177’ 4.000 Halliburton TWR Packer 4,810’ 4,180’ 4.276 Millout Extension 8 4,864’ 4,223’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/23/2003) 9 4,869’ 4,227’ 3.930 No-Go Seal Assembly 4,870’ 4,228’ 4.000 Halliburton TWR Packer 4,874’ 4,232’ 4.276 Millout Extension 10 4,975’ 4,313’ 3.930 No-Go Seal Assembly 4,976’ 4,314’ 4.000 Halliburton TWR Packer 4,980’ 4,318’ 4.276 Millout Extension 11 5,208’ 4,503’ 3.813 Halliburton XD Sliding Sleeve (Closed) 12 5,212’ 4,506’ 3.930 No-Go Seal Assembly 5,213’ 4,507’ 4.000 Halliburton TWR Packer 5,217’ 4,510’ 4.276 Millout Extension 13 5,818’ 4,994’ 3.813 Halliburton XA SSD Sliding Sleeve (Open 5/24/2003) 14 6,450’ 5,497’ 3.725 Halliburton XN Nipple 15 6,451’ 5,498’ 3.933 Wireline Re-Entry Guide 6,452’ 5,499’ End of tubing assembly 16 6,618’ 5,632’ CIBP Updated By: JLL 10/27/23 PROPOSED SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status CI 1.0 4,450’ 4,515’ 3,889’ 3,941’ 65' 08/07/1994 Open CI 2.0 4,535’ 4,610’ 3,957’ 4,018’ 75' 08/07/1994 Open CI 3.0 4,630’ 4,650’ 4,034’ 4,051’ 20' 08/07/1994 Open CI 5.0 4,770’ 4,785’ 4,147’ 4,160’ 15' 05/08/1969 Open CI 6.0 4,832’ 4,862’ 4,197’ 4,222’ 30' 08/07/1994 Open CI 6.2 4,890’ 4,915’ 4,244’ 4,265’ 25' 05/08/1969 Open CI 8.2 5,042’ 5,052’ 4,368’ 4,376’ 10' 08/07/1994 Open CI 10.0 5,129’ 5,144’ 4,438’ 4,450’ 15' 08/01/1994 Open CI 11.0 5,196’ 5,206’ 4,493’ 4,501’ 10' 08/07/1994 Open Aa 5,218’ 5,231’ A-2 5,220’ 5,230’ 4,513’ 4,521’ 10' 08/07/1994 Open Ab 5,248’ 5,254’ 4,536’ 4,540’ 6’ 09/29/2023 Open Ac1 5,286’ 5,301’ Ac 5,290’ 5,300’ 4,570’ 4,578’ 10’ 09/29/2023 Open Ad 5,303’ 5,312’ 4,580’ 4,587’ 9’ 09/29/2023 Open Ba 5,324’ 5,341’ 4,597’ 4,611’ 17’ 09/29/2023 Open Bb 5,355’ 5,361’ B-2 5,357’ 5,361’ 4,624’ 4,627’ 4' 08/07/1994 Open Bc 5,434’ 5,451’ 4,686’ 4,700’ 17’ 09/30/2023 Open B-5.5 5,454’ 5,456’ 4,703’ 4,704’ 2' 08/07/1994 Open B-6 5,479’ 5,483’ 4,723’ 4,726’ 4' 08/07/1994 Open Ca 5,558’ 5,571’ C-1 5,561’ 5,571’ 4,790’ 4,798’ 10' 08/07/1994 Open Cb 5,592’ 5,600’ 4,814’ 4,820’ 8’ 09/28/2023 Open Da 5,707’ 5,715’ D-1 5,709’ 5,714’ 4,907’ 4,911’ 5' 08/07/1994 Open Db 5,730’ 5,737’ 4,924’ 4,930’ 7’ 09/28/2023 Open Db1 5,730’ 5,738’ Dc 5,746’ 5,754 4,937’ 4,943’ 8’ 09/28/2023 Open Dd 5,769’ 5,778’ D-2.5 5,773’ 5,778’ 4,958’ 4,962’ 5' 08/07/1994 Open D-3 5,782’ 5,792’ 4,966’ 4,973’ 10' 08/07/1994 Open Ea 5,821’ 5,835’ Eb 5,839’ 5,855’ Ec 5,886’ 5,894’ Ed 5,922’ 5,933’ Ee 5,958’ 5,965’ Ef 5,974’ 5,981’ Eg 5,992’ 6,012’ D-4 5,825’ 5,835’ 5,000’ 5,008’ 10' 08/07/1994 Open D-5 5,840’ 5,855’ 5,012’ 5,024’ 15' 08/07/1994 Open E-4 5,922’ 5,932’ 5,077’ 5,085’ 10' 08/07/1994 Open E-9 6,000’ 6,010’ 5,139’ 5,147’ 10' 08/07/1994 Open F-4 6,111’ 6,116’ 5,227’ 5,231’ 5' 08/07/1994 Open Ga 6,162’ 6,173’ F-7 6,163’ 6,173’ 5,269’ 5,277’ 10' 08/07/1994 Open Gb 6,179’ 6,190’ F-8 6,180’ 6,190’ 5,284’ 5,292’ 10' 08/07/1994 Open Gc 6,195’ 6,206’ G-1 6,196’ 6,206’ 5,296’ 5,304’ 10' 08/07/1994 Open Ha 6,239’ 6,243’ Hb 6,266’ 6,282’ G-5 6,267’ 6,282’ 5,352’ 5,364’ 15' 08/07/1994 Open Hc 6,336’ 6,343’ H-3 6,346’ 6,356’ 5,415’ 5,423’ 10' 08/07/1994 Open He 6,399’ 6,403’ H-8 6,435’ 6,445’ 5,489’ 5,497’ 10' 08/07/1994 Open Ib 6,476’ 6,483’ K-2 6,680’ 6,685’ 5,681’ 5,685’ 5' 1994 Isolated K-5 6,752’ 6,762’ 5,739’ 5,747’ 10' 1994 Isolated L-2 6,784’ 6,789’ 5,765’ 5,769’ 5' 1994 Isolated N-1 7,024’ 7,032’ 5,961’ 5,967’ 8' 1994 Isolated N-5 7,095’ 7,110’ 6,020’ 6,032’ 15' 1994 Isolated P-2 7,286’ 7,296’ 6,178’ 6,186’ 10' 1994 Isolated P-3 7,316’ 7,321’ 6,203’ 6,207’ 5' 1994 Isolated P-5 7,374’ 7,384’ 6,251’ 6,259’ 10' 1994 Isolated R-3 7,526’ 7,536’ 6,378’ 6,386’ 10' 1994 Isolated KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,124 feet 6,618 feet true vertical 6,884 feet N/A feet Effective Depth measured 6,618 feet See schematic feet true vertical 5,632 feet See schematic feet Perforation depth Measured depth 4,450 - 6,445 feet True Vertical depth 3,889 - 5,497 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" J-55 6,452 (MD) 5,499 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Tertiary System Gas 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,080psi 3,350psi 4,080psi 2,571 2,382 Burst Collapse 1,970psi measured TVD Production Liner 8,097 Casing Structural 6,8618,097 643 2,571 643Conductor Surface Intermediate 30" 16" 10-3/4" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-032 50-883-20025-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0017589 North Cook Inlet / Tertiary System Gas N Cook Inlet Unit A-05 Plugs Junk measured Length 385 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 385 N/A 387 Size 385 643 0 1224759 0 1080 57 323-515 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 2540 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:07 am, Nov 01, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.10.31 15:11:06 - 08'00' Dan Marlowe (1267) Updated By: JLL 10/27/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PBTD:6,618’ TD:8,124’ 30” RKB: 39.4 7” 3 4 5 6 7 8 9 10 11 12 13 10-3/4” B-2 / B-6 16” 1 2 15 16 A-2 E-4 / E-9 D-1 / D-3 F-4 / F-8 H-3 / H-8 G-1 / G-5 K-2 / K-5 / L-2 / N-1 / N-5 / P-2 P-3 / P-5 / R-3 C-1 14 C I 8.2 C I 10.0 C I 11.0 C I 6.2 C I 5.0 C I 1.0 C I 2.0 C I 3.0 C I 6.0 D-4 / D-5 X XN Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM 30” Conductor Welded 29.000 Surf 385’ 16” 65# H-40 Welded 15.250 Surf 643’ 10-3/4”45.5# & 51#J-55 BTC 9.794 Surf 2,571’ 7” 26# J-55 BTC 6.366 Surf 79’ 23# J-55 BTC 6.366 79’ 7,127’ 26# J-55 BTC 6.366 7,127’ 8,097’ Tubing Detail 4-1/2” 12.6# J-5 IBT Mod 3.958 Surf 311’ 4-1/2” 12.75# J-55 8rd Mod 3.958 305’ 6,452’ Jewelry Details No Depth MD Depth TVD ID OD Item 39.4’ 39.4’ 4.500 FMC Tubing Hanger 1 270’ 270’ 3.813 Halliburton XXO SVLN w/ FXE X-Lock WRDP (ID 2.12) 2 1,770’ 1,726’ Camco KBG-2 GLM 3,351’ 3,013’ Camco KBG-2 GLM 4,277’ 3,751’ Camco KBG-2 Orifice 3 4,333’ 3,795’ 3.860 Upper Body PBR Assembly - Ratch latch seal assembly 4,339’ 3,799’ 4.000 Halliburton VSR Packer 4 4,377’ 3,830’ 3.813 Halliburton X Nipple 5 4,660’ 4,058’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/22/2003) 6 4,696’ 4,087’ 3.930 No-Go Seal Assembly 4,698’ 4,089’ 4.000 Halliburton TWR Packer 4,703’ 4,093’ 4.276 Millout Extension 7 4,804’ 4,175’ 3.930 No-Go Seal Assembly 4,807’ 4,177’ 4.000 Halliburton TWR Packer 4,810’ 4,180’ 4.276 Millout Extension 8 4,864’ 4,223’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/23/2003) 9 4,869’ 4,227’ 3.930 No-Go Seal Assembly 4,870’ 4,228’ 4.000 Halliburton TWR Packer 4,874’ 4,232’ 4.276 Millout Extension 10 4,975’ 4,313’ 3.930 No-Go Seal Assembly 4,976’ 4,314’ 4.000 Halliburton TWR Packer 4,980’ 4,318’ 4.276 Millout Extension 11 5,208’ 4,503’ 3.813 Halliburton XD Sliding Sleeve (Closed) 12 5,212’ 4,506’ 3.930 No-Go Seal Assembly 5,213’ 4,507’ 4.000 Halliburton TWR Packer 5,217’ 4,510’ 4.276 Millout Extension 13 5,818’ 4,994’ 3.813 Halliburton XA SSD Sliding Sleeve (Open 5/24/2003) 14 6,450’ 5,497’ 3.725 Halliburton XN Nipple 15 6,451’ 5,498’ 3.933 Wireline Re-Entry Guide 6,452’ 5,499’ End of tubing assembly 16 6,618’ 5,632’ CIBP Updated By: JLL 10/27/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI 1.0 4,450’ 4,515’ 3,889’ 3,941’ 65' 08/07/1994 Open CI 2.0 4,535’ 4,610’ 3,957’ 4,018’ 75' 08/07/1994 Open CI 3.0 4,630’ 4,650’ 4,034’ 4,051’ 20' 08/07/1994 Open CI 5.0 4,770’ 4,785’ 4,147’ 4,160’ 15' 05/08/1969 Open CI 6.0 4,832’ 4,862’ 4,197’ 4,222’ 30' 08/07/1994 Open CI 6.2 4,890’ 4,915’ 4,244’ 4,265’ 25' 05/08/1969 Open CI 8.2 5,042’ 5,052’ 4,368’ 4,376’ 10' 08/07/1994 Open CI 10.0 5,129’ 5,144’ 4,438’ 4,450’ 15' 08/01/1994 Open CI 11.0 5,196’ 5,206’ 4,493’ 4,501’ 10' 08/07/1994 Open A-2 5,220’ 5,230’ 4,513’ 4,521’ 10' 08/07/1994 Open Ab 5,248’ 5,254’ 4,536’ 4,540’ 6’ 09/29/2023 Open Ac 5,290’ 5,300’ 4,570’ 4,578’ 10’ 09/29/2023 Open Ad 5,303’ 5,312’ 4,580’ 4,587’ 9’ 09/29/2023 Open Ba 5,324’ 5,341’ 4,597’ 4,611’ 17’ 09/29/2023 Open B-2 5,357’ 5,361’ 4,624’ 4,627’ 4' 08/07/1994 Open Bc 5,434’ 5,451’ 4,686’ 4,700’ 17’ 09/30/2023 Open B-5.5 5,454’ 5,456’ 4,703’ 4,704’ 2' 08/07/1994 Open B-6 5,479’ 5,483’ 4,723’ 4,726’ 4' 08/07/1994 Open C-1 5,561’ 5,571’ 4,790’ 4,798’ 10' 08/07/1994 Open Cb 5,592’ 5,600’ 4,814’ 4,820’ 8’ 09/28/2023 Open D-1 5,709’ 5,714’ 4,907’ 4,911’ 5' 08/07/1994 Open Db 5,730’ 5,737’ 4,924’ 4,930’ 7’ 09/28/2023 Open Dc 5,746’ 5,754 4,937’ 4,943’ 8’ 09/28/2023 Open D-2.5 5,773’ 5,778’ 4,958’ 4,962’ 5' 08/07/1994 Open D-3 5,782’ 5,792’ 4,966’ 4,973’ 10' 08/07/1994 Open D-4 5,825’ 5,835’ 5,000’ 5,008’ 10' 08/07/1994 Open D-5 5,840’ 5,855’ 5,012’ 5,024’ 15' 08/07/1994 Open E-4 5,922’ 5,932’ 5,077’ 5,085’ 10' 08/07/1994 Open E-9 6,000’ 6,010’ 5,139’ 5,147’ 10' 08/07/1994 Open F-4 6,111’ 6,116’ 5,227’ 5,231’ 5' 08/07/1994 Open F-7 6,163’ 6,173’ 5,269’ 5,277’ 10' 08/07/1994 Open F-8 6,180’ 6,190’ 5,284’ 5,292’ 10' 08/07/1994 Open G-1 6,196’ 6,206’ 5,296’ 5,304’ 10' 08/07/1994 Open G-5 6,267’ 6,282’ 5,352’ 5,364’ 15' 08/07/1994 Open H-3 6,346’ 6,356’ 5,415’ 5,423’ 10' 08/07/1994 Open H-8 6,435’ 6,445’ 5,489’ 5,497’ 10' 08/07/1994 Open K-2 6,680’ 6,685’ 5,681’ 5,685’ 5' 1994 Isolated K-5 6,752’ 6,762’ 5,739’ 5,747’ 10' 1994 Isolated L-2 6,784’ 6,789’ 5,765’ 5,769’ 5' 1994 Isolated N-1 7,024’ 7,032’ 5,961’ 5,967’ 8' 1994 Isolated N-5 7,095’ 7,110’ 6,020’ 6,032’ 15' 1994 Isolated P-2 7,286’ 7,296’ 6,178’ 6,186’ 10' 1994 Isolated P-3 7,316’ 7,321’ 6,203’ 6,207’ 5' 1994 Isolated P-5 7,374’ 7,384’ 6,251’ 6,259’ 10' 1994 Isolated R-3 7,526’ 7,536’ 6,378’ 6,386’ 10' 1994 Isolated Rig Start Date End Date Eline 9/27/23 10/3/23 09/28/2023 - Thursday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCIU A-05 50-883-20025-00-00 169-032 09/18/2023 - Wednesday Meet at PWL shop, load up tools, head to OSK. Arrive on platform, permit, JSA, TGSM. Rig up slickline. P/T to 2500 PSI, good. RIH W/ 4 1/2 GS and 5' prong, latch SSSV at 274' KB, POOH W/ SSSV. 09/27/2023 - Wednesday AK E-Line arrive OSK. Weigh equipment. Depart to Tyonek. Arrive Tyonek. PJSM & permit. Spot equipment & MIRU. Re- head. Stab on riser & night cap. PT riser only 250 / 2500 PSI. Reconfigure 6 of the 8 guns available to match run sheet. Clean area. SDFN. AK E-Line PJSM & permit. Complete rig up on well. PT 250 / 2500 PSI. Test good. RIH w/ 2-3/8 x 8 Gun ONE to shoot Beluga Dc sands at 5746 to 5754. CCL to TS = 15.2 / CCL to be at 5730.8 to place TS at 5746. Well had been pinched back from 4mm rate to 1.6mm. Tie in pass. Send log to town. Town approved. Prod Op brought well rate up to 4Mil while E-Line Op watching weight. Position Gun ONE. Fire gun and pick up hole to 5250 and stand by while taking 15 min readings. PSI stayed flat at 160. POOH. OOH. L/D Gun ONE. Perf gun & tool string covered in water and muddy sand. P/U Gun TWO. RIH w/ 2-3/8 x 7 Gun TWO to shoot Beluga Db sands at 5730 to 5737. CCL to TS = 18 / CCL to be at 5712 to place TS at 5730. At 2700 in hole, lost signal to tools DH. Found connector on side of drum transmitting to computers had parted. Called for new parts & prepped unit for repairs. New parts installed. Test run 100. All good. Re-install covers. Resume Gun TWO. Position Gun TWO. Fire Gun Two. Small bobble on wt. ind. POOH. Start PSI 120 / 5 Min 120 / 10 Min 122 / 15 Min 122. OOH. L/D Gun TWO. Perf gun & tool string covered in water and muddy sand. P/U Gun THREE. RIH w/ 2-3/8 x 8 Gun THREE to shoot Beluga Cb sands at 5592 to 5600. CCL to TS = 17 / CCL to be at 5575 to place TS at 5592. Well stayed on 4mm rate. Tie in pass. Send log to town. Town approved. Position Gun THREE. Fire Gun THREE. POOH. PSI unchanged at 122 for 15 minutes. OOH. L/D Gun THREE. Night cap well. Prep tools for morning. SDFN. P/U Gun TWO. RIH w/ 2-3/8 x 7 Gun TWO to shoot Beluga Db sands at 5730 to 5737. CCL to TS = 18 / CCL to be at 5712 covers. Resume Gun TWO. Position Gun TWO. Fire Gun Two. Small bobble on wt. ind. POOH. Start PSI 120 / 5 Min 120 / 10 Min 122 / 15 Min 122. OOH. L/D Gun TWO. Perf gun & tool string covered in water and muddy sand. P/U Gun THREE. RIH w/ 2-3/8 x 8 Gun THREE to shoot Beluga Cb sands at 5592 to 5600. CCL to TS = 17 / CCL to be at 5575 to AK E-Line PJSM & permit. Complete rig up on well. PT 250 / 2500 PSI. Test good. RIH w/ 2-3/8 x 8 Gun ONE to shoot Beluga Dc sands at 5746 to 5754. CCL to TS = 15.2 / CCL to be at 5730.8 to place TS at 5746. Well had been pinched Rig Start Date End Date Eline 9/27/23 10/3/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCIU A-05 50-883-20025-00-00 169-032 AK E-Line PJSM & permit. Rig back on well and prep Gun FOUR. RIH w/ 2-3/8 x 17 Gun FOUR to shoot Beluga Bc sands at 5434 to 5451. CCL to TS = 16 / CCL to be at 5418 to place TS at 5434. CCL & gamma ray. Well pinched back from 6mm to 3.5mm rate. Tie in pass. Send log to town. Town approved. Fire Gun Four. POOH. Start PSI: 156 / 5 Min 160 / 10 Min 161 / 15 Min 161. OOH. L/D Gun FOUR. Perf gun & tool string covered in water and muddy sand. RDMO AK E- Line. 09/30/2023 - Saturday 09/29/2023- Friday AK E-Line PJSM & permit. Call in and instructions received from town. Rig back up on well. RIH w/ proposed Gun FOUR 2.75 x 17. CCL needed to be at 5423 to place TS at 5434 Bc zone. We sat down 8 high and were not able to reach Bc zone w/ 2.75 gun. Rate at 1.5mm. Consult w/ town. This current 2.75 x 17 gun will be used to shoot at Gun FIVE Ba zone which can be reached. A 2-3/8 x 17 gun will be built on the beach to be used later on the Bc zone. Made tie in pass at Ba zone 5324 to 5341 w/ 2.75 x 17 Gun FIVE. CCL to TS = 11 / CCL depth to be at 5313 to place TS at 5324. Sent log to town for approval. Town approved. Positioned Gun FIVE. Prod Op brought rate up to 4.0mm. Fired Gun FIVE. POOH. Start PSI: 150 / 5 Min 145 / 10 Min 143 / 15 Min 146. OOH. L/D Gun FIVE. Perf gun & tool string covered in water and muddy sand. Having issues w/ gamma ray working. Trouble shooting. We have one gamma ray functional. Town is good w/ CCL only to shoot Guns SIX Ab zone, SEVEN Ac zone & EIGHT Ab zone but they especially want gamma ray for FOUR Bc zone. Plan forward is to save working gamma ray for Gun FOUR Bc zone and use CCL only on remaining shots. RIH w/ 2.75 x 9 Gun SIX to shoot Beluga Ad sands at 5303 to 5312. CCL to TS = 8.9 / CCL to be at 5294.1 to place TS at 5303. CCL only. No gamma ray. Well stayed on 3.7mm rate. Tie in pass. Send log to town. Town approved. Position and fire Gun SIX. POOH. PSI remained flat at 150 for 15 minutes. OOH. L/D Gun SIX. Perf gun & tool string covered in water and muddy sand. P/U Gun SEVEN. RIH w/ 2.75 x 10 Gun SEVEN to shoot Beluga Ac sands at 5290 to 5300. CCL to TS = 11.9 / CCL to be at 5278.1 to place TS at 5290. CCL only. No gamma ray. Tie in pass. Send log to town. Town approved. Position and fire Gun SEVEN. POOH. PSI remained flat at 152 for 15 minutes. OOH. L/D Gun SEVEN. Perf gun & tool string covered in water and muddy sand. P/U Gun EIGHT. RIH w/ 2.75 x 6+A1 Gun EIGHT to shoot Beluga Ab sands at 5248 to 5254. CCL to TS = 10.6 / CCL to be at 5237.4 to place TS at 5248. CCL only. No gamma ray. Tie in pass. Send log to town. Town approved. Position and fire Gun EIGHT. POOH. PSI remained flat at 154 for 15 minutes. OOH. L/D Gun EIGHT. Perf gun & tool string covered in water and muddy sand. Lay down lubricator. Night cap well. Prep tools for morning. SDFN. Plan forward: A replacement 2-3/8 x 17 Gun FOUR is being loaded on the beach to perforate 5434 to 5451 Bc zone and will be at platform later tonight via boat & ran tomorrow. muddy sand. P/U Gun SEVEN. RIH w/ 2.75 x 10 Gun SEVEN to shoot Beluga Ac sands at 5290 to 5300. CCL to TS = 11.9 / string covered in water and muddy sand. P/U Gun EIGHT. RIH w/ 2.75 x 6+A1 Gun EIGHT to shoot Beluga Ab sands at 5248 to 5254. CCL to TS = 10.6 / CCL to be at 5237.4 to place TS at 5248. CCL only. No gamma ray. Tie in pass. Send log 2.75 x 9 Gun SIX to shoot Beluga Ad sands at 5303 to 5312. CCL to TS = 8.9 / CCL to be at 5294.1 to place TS at 5303. AK E-Line PJSM & permit. Rig back on well and prep Gun FOUR. RIH w/ 2-3/8 x 17 Gun FOUR to shoot Beluga Bc sands at 5434 to 5451. CCL to TS = 16 / CCL to be at 5418 to place TS at 5434. CCL & gamma ray. Well pinched back from at Ba zone 5324 to 5341 w/ 2.75 x 17 Gun FIVE. CCL to TS = 11 / CCL depth to be at 5313 to place TS at 5324. Sent log to Rig Start Date End Date Eline 9/27/23 10/3/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCIU A-05 50-883-20025-00-00 169-032 RIG UP W/L - PT LUB 150/1500 PSI DIESEL - GOOD - DUMP FLUID DOWN HOLE - SHUT IN WELL RIH W/ 3.9" BRAIDED LINE BRUSH - HAND SPANG DOWN HOLE TO 274'KB WT BRUSH SSSV NIPPLE - POOH - REDRESS AND REBUILD SSSV (REPLACE ALL PACKING) RIH W/ 4 1/2 XLINE RT W/ 5' PRONG W/ SSSV TO 250'KB - PURGE CONTROL LINE - GO TO 274'KB WT TO SET VALVE - CAN NOT PRESSURE UP ON CONTROL LINE - SHEAR OFF - POOH. RIH W/ 4 1/2 GS W/ 5' PRONG TO 274'KB WT LATCH SSSV - 12 OIL JAR LICKS UP TO 1500 LBS COME FREE - POOH - OOH W/ SSSV PACKED W/ BLACK GREASEY SAND ADD 2" X 5' STEM - RIH W/ 3.9" BRAIDED LINE BRUSH - BEGIN PUMPING DIESEL - TO 274'KB BRUSH SSSV NIPPLE WHILE PUMPING DIESEL - (60 GAL AWAY) POOH. RIH W/ 4 1/2 XLINE W/ 5' PRONG W/ SSSV TO 250'KB PURGE CONTROL LINE - CONTINUE IN HOLE TO 274'KB WT - PRESSURE UP ON CONTROL LINE - GOOD - SHEAR OFF - NO PRESSURE LOSS POOH - STANDBY FOR FUNCTION AND CLOSURE TEST TESTS IS GOOD - RIG DOWN W/L - CLEAN AREA. Wellwork extension for SSSV reset granted by Bryan McLellan on 9/29/23. SSSV needed to be reset by 10/8/23. Complete. 10/03/2023 - Tuesday Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/25/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231025 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 241-23 50283201910000 223061 9/27/2023 AK E-LINE CBL BRU 241-23 50283201910000 223061 10/4/2023 AK E-LINE GPT/Plug/Perf GP ST 18742 37 50733203940000 187109 9/30/2023 AK E-LINE Plug IRU 41-01 50283200880000 192109 9/22/2023 AK E-LINE Perf/GPT LRU C-02 50283201900000 223057 9/28/2023 AK E-LINE Perf LRU C-02 50283201900000 223057 9/25/2023 AK E-LINE Perf/GPT MPU K-13 50029226550000 196040 10/1/2023 AK E-LINE GPT/Plug/Perf NCI A-05 50883200250000 169032 9/27/2023 AK E-LINE Perf Please include current contact information if different from above. T38097 T38097 T38098 T38099 T38100 T38100 T38101 T38102 10/25/2023 NCI A-05 50883200250000 169032 9/27/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.25 11:33:48 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,124 N/A Casing Collapse Structural Conductor Surface 1,970psi Intermediate Production 3,080psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Karson Kozub Contact Email:kkozub@hilcorp.com Contact Phone:907-570-1801 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See schematic See schematic CO 68A Operations Manager 8,097' Perforation Depth MD (ft): 4,450 - 6,445 8,097' 3,889 - 5,497 4-1/2" 6,861'7" 385' 30" 16" 10-3/4" 643' 2,571' MD 3,350psi 643' 2,382' 643' 2,571' Length Size Proposed Pools: 385' 385' J-55 TVD Burst 6452 4,080psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 169-032 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-883-20025-00-00 Hilcorp Alaska, LLC AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 9/25/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY N Cook Inlet Unit A-05 North Cook Inlet Tertiary System Gas Same 6,884 6,618 5,632 1,871psi 6,618 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:33 pm, Sep 11, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.09.11 14:09:06 - 08'00' Dan Marlowe (1267) 323-515 SFD 9/12/2023 DSR-9/12/23BJM 9/14/23 10-404 *&:JLC 9/14/2023 09/15/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.15 07:45:43 -08'00' RBDMS JSB 091523 Perf add Well: NCIU A-05 Well Name:NCIU A-05 API Number:50-883-20025-00-00 Current Status:Online Gas Producer Permit to Drill Number:169-032 First Call Engineer:Karson Kozub (907) 570-1801 (c)Leg 3 (SE corner) Second Call Engineer:Ryan Rupert (907) 301-1736 (c) Maximum Expected BHP:2,420 psi @ 5,502’ TVD 0.44psi/ft to deepest proposed Max. Potential Surface Pressure: 1,871 psi Using 0.1 psi/ft gradient per 20 ACC 25.280(b)(4) Brief Well Summary NCIU A-05 is a Tyonek platform gas producer open in several sands currently. There are bypassed sands still available to perforate between the existing perforations. The goal of this project is to add infill gas sand perfs. All proposed perfs remain within the Tertiary System Gas Pool Pertinent wellbore information: - SSSV: WL retrievable - Inclination 37 degrees max above PBTD Pre-Sundry work: - Slickline pull SSSV - Slickline runs as needed to evaluate wellbore E-Line Perf procedure 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250psi low / 2500psi high 3. RIH and perforate Beluga sands from ±5,213’ – ±6,449’ MD (±4,507’ – ±5,502’ TVD) per RE/Geo a. * other E-line logs may be run as needed to evaluate wellbore 4. RDMO EL NOTE: WL-SSSV will need to be pulled, and reinstalled. It must be tested within 14 days of the well being returned to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic All proposed perfs remain within the Tertiary System Gas Pool Updated By: JLL 09/08/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PBTD: 6,618’ TD:8,124’ 30” RKB: 39.4 7” 3 4 5 6 7 8 9 10 11 12 13 10-3/4” B-2 / B-6 16” 1 2 15 16 A-2 E-4 / E-9 D-1 / D-3 F-4 / F-8 H-3 / H-8 G-1 / G-5 K-2 / K-5 / L-2 / N-1 / N-5 / P-2 P-3 / P-5 / R-3 C-1 14 C I 8.2 C I 10.0 C I 11.0 C I 6.2 C I 5.0 C I 1.0 C I 2.0 C I 3.0 C I 6.0 D-4 / D-5 X XN Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM 30” Conductor Welded 29.000 Surf 385’ 16” 65# H-40 Welded 15.250 Surf 643’ 10-3/4”45.5# & 51#J-55 BTC 9.794 Surf 2,571’ 7” 26# J-55 BTC 6.366 Surf 79’ 23# J-55 BTC 6.366 79’ 7,127’ 26# J-55 BTC 6.366 7,127’ 8,097’ Tubing Detail 4-1/2” 12.6# J-55 IBT Mod 3.958 Surf 311’ 4-1/2” 12.75# J-55 8rd Mod 3.958 305’ 6,452’ Jewelry Details No Depth MD Depth TVD ID OD Item 39.4’ 39.4’ 4.500 FMC Tubing Hanger 1 270’ 270’ 3.813 Halliburton XXO SVLN w/ FXE X-Lock WRDP (ID 2.12) 2 1,770’ 1,726’ Camco KBG-2 GLM 3,351’ 3,013’ Camco KBG-2 GLM 4,277’ 3,751’ Camco KBG-2 Orifice 3 4,333’ 3,795’ 3.860 Upper Body PBR Assembly - Ratch latch seal assembly 4,339’ 3,799’ 4.000 Halliburton VSR Packer 4 4,377’ 3,830’ 3.813 Halliburton X Nipple 5 4,660’ 4,058’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/22/2003) 6 4,696’ 4,087’ 3.930 No-Go Seal Assembly 4,698’ 4,089’ 4.000 Halliburton TWR Packer 4,703’ 4,093’ 4.276 Millout Extension 7 4,804’ 4,175’ 3.930 No-Go Seal Assembly 4,807’ 4,177’ 4.000 Halliburton TWR Packer 4,810’ 4,180’ 4.276 Millout Extension 8 4,864’ 4,223’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/23/2003) 9 4,869’ 4,227’ 3.930 No-Go Seal Assembly 4,870’ 4,228’ 4.000 Halliburton TWR Packer 4,874’ 4,232’ 4.276 Millout Extension 10 4,975’ 4,313’ 3.930 No-Go Seal Assembly 4,976’ 4,314’ 4.000 Halliburton TWR Packer 4,980’ 4,318’ 4.276 Millout Extension 11 5,208’ 4,503’ 3.813 Halliburton XD Sliding Sleeve (Closed) 12 5,212’ 4,506’ 3.930 No-Go Seal Assembly 5,213’ 4,507’ 4.000 Halliburton TWR Packer 5,217’ 4,510’ 4.276 Millout Extension 13 5,818’ 4,994’ 3.813 Halliburton XA SSD Sliding Sleeve (Open 5/24/2003) 14 6,450’ 5,497’ 3.725 Halliburton XN Nipple 15 6,451’ 5,498’ 3.933 Wireline Re-Entry Guide 6,452’ 5,499’ End of tubing assembly 16 6,618’ 5,632’ CIBP Updated By: JLL 09/08/23 SCHEMATIC North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI 1.0 4,450’ 4,515’ 3,889’ 3,941’ 65' 08/07/1994 Open CI 2.0 4,535’ 4,610’ 3,957’ 4,018’ 75' 08/07/1994 Open CI 3.0 4,630’ 4,650’ 4,034’ 4,051’ 20' 08/07/1994 Open CI 5.0 4,770’ 4,785’ 4,147’ 4,160’ 15' 05/08/1969 Open CI 6.0 4,832’ 4,862’ 4,197’ 4,222’ 30' 08/07/1994 Open CI 6.2 4,890’ 4,915’ 4,244’ 4,265’ 25' 05/08/1969 Open CI 8.2 5,042’ 5,052’ 4,368’ 4,376’ 10' 08/07/1994 Open CI 10.0 5,129’ 5,144’ 4,438’ 4,450’ 15' 08/01/1994 Open CI 11.0 5,196’ 5,206’ 4,493’ 4,501’ 10' 08/07/1994 Open A-2 5,220’ 5,230’ 4,513’ 4,521’ 10' 08/07/1994 Open B-2 5,357’ 5,361’ 4,624’ 4,627’ 4' 08/07/1994 Open B-5.5 5,454’ 5,456’ 4,703’ 4,704’ 2' 08/07/1994 Open B-6 5,479’ 5,483’ 4,723’ 4,726’ 4' 08/07/1994 Open C-1 5,561’ 5,571’ 4,790’ 4,798’ 10' 08/07/1994 Open D-1 5,709’ 5,714’ 4,907’ 4,911’ 5' 08/07/1994 Open D-2.5 5,773’ 5,778’ 4,958’ 4,962’ 5' 08/07/1994 Open D-3 5,782’ 5,792’ 4,966’ 4,973’ 10' 08/07/1994 Open D-4 5,825’ 5,835’ 5,000’ 5,008’ 10' 08/07/1994 Open D-5 5,840’ 5,855’ 5,012’ 5,024’ 15' 08/07/1994 Open E-4 5,922’ 5,932’ 5,077’ 5,085’ 10' 08/07/1994 Open E-9 6,000’ 6,010’ 5,139’ 5,147’ 10' 08/07/1994 Open F-4 6,111’ 6,116’ 5,227’ 5,231’ 5' 08/07/1994 Open F-7 6,163’ 6,173’ 5,269’ 5,277’ 10' 08/07/1994 Open F-8 6,180’ 6,190’ 5,284’ 5,292’ 10' 08/07/1994 Open G-1 6,196’ 6,206’ 5,296’ 5,304’ 10' 08/07/1994 Open G-5 6,267’ 6,282’ 5,352’ 5,364’ 15' 08/07/1994 Open H-3 6,346’ 6,356’ 5,415’ 5,423’ 10' 08/07/1994 Open H-8 6,435’ 6,445’ 5,489’ 5,497’ 10' 08/07/1994 Open K-2 6,680’ 6,685’ 5,681’ 5,685’ 5' 1994 Isolated K-5 6,752’ 6,762’ 5,739’ 5,747’ 10' 1994 Isolated L-2 6,784’ 6,789’ 5,765’ 5,769’ 5' 1994 Isolated N-1 7,024’ 7,032’ 5,961’ 5,967’ 8' 1994 Isolated N-5 7,095’ 7,110’ 6,020’ 6,032’ 15' 1994 Isolated P-2 7,286’ 7,296’ 6,178’ 6,186’ 10' 1994 Isolated P-3 7,316’ 7,321’ 6,203’ 6,207’ 5' 1994 Isolated P-5 7,374’ 7,384’ 6,251’ 6,259’ 10' 1994 Isolated R-3 7,526’ 7,536’ 6,378’ 6,386’ 10' 1994 Isolated Updated By: JLL 09/08/23 PROPOSED North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PBTD: 6,618’ TD: 8,124’ 30” RKB: 39.4 7” 3 4 5 6 7 8 9 10 11 12 13 10-3/4” B-2 / B-6 16” 1 2 15 16 A-2 E-4 / E-9 D-1 / D-3 F-4 / F-8 H-3 / H-8 G-1 / G-5 K-2 / K-5 / L-2 / N-1 / N-5 / P-2 P-3 / P-5 / R-3 C-1 14 C I 8.2 C I 10.0 C I 11.0 C I 6.2 C I 5.0 C I 1.0 C I 2.0 C I 3.0 C I 6.0 D-4 / D-5 X XN Casing Detail SIZE WT GRADE CONN MIN ID TOP BTM 30” Conductor Welded 29.000 Surf 385’ 16” 65# H-40 Welded 15.250 Surf 643’ 10-3/4”45.5# & 51#J-55 BTC 9.794 Surf 2,571’ 7” 26# J-55 BTC 6.366 Surf 79’ 23# J-55 BTC 6.366 79’ 7,127’ 26# J-55 BTC 6.366 7,127’ 8,097’ Tubing Detail 4-1/2” 12.6# J-5 IBT Mod 3.958 Surf 311’ 4-1/2” 12.75# J-55 8rd Mod 3.958 305’ 6,452’ Jewelry Details No Depth MD Depth TVD ID OD Item 39.4’ 39.4’ 4.500 FMC Tubing Hanger 1 270’ 270’ 3.813 Halliburton XXO SVLN w/ FXE X-Lock WRDP (ID 2.12) 2 1,770’ 1,726’ Camco KBG-2 GLM 3,351’ 3,013’ Camco KBG-2 GLM 4,277’ 3,751’ Camco KBG-2 Orifice 3 4,333’ 3,795’ 3.860 Upper Body PBR Assembly - Ratch latch seal assembly 4,339’ 3,799’ 4.000 Halliburton VSR Packer 4 4,377’ 3,830’ 3.813 Halliburton X Nipple 5 4,660’ 4,058’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/22/2003) 6 4,696’ 4,087’ 3.930 No-Go Seal Assembly 4,698’ 4,089’ 4.000 Halliburton TWR Packer 4,703’ 4,093’ 4.276 Millout Extension 7 4,804’ 4,175’ 3.930 No-Go Seal Assembly 4,807’ 4,177’ 4.000 Halliburton TWR Packer 4,810’ 4,180’ 4.276 Millout Extension 8 4,864’ 4,223’ 3.813 Halliburton XD Sliding Sleeve (Closed 5/23/2003) 9 4,869’ 4,227’ 3.930 No-Go Seal Assembly 4,870’ 4,228’ 4.000 Halliburton TWR Packer 4,874’ 4,232’ 4.276 Millout Extension 10 4,975’ 4,313’ 3.930 No-Go Seal Assembly 4,976’ 4,314’ 4.000 Halliburton TWR Packer 4,980’ 4,318’ 4.276 Millout Extension 11 5,208’ 4,503’ 3.813 Halliburton XD Sliding Sleeve (Closed) 12 5,212’ 4,506’ 3.930 No-Go Seal Assembly 5,213’ 4,507’ 4.000 Halliburton TWR Packer 5,217’ 4,510’ 4.276 Millout Extension 13 5,818’ 4,994’ 3.813 Halliburton XA SSD Sliding Sleeve (Open 5/24/2003) 14 6,450’ 5,497’ 3.725 Halliburton XN Nipple 15 6,451’ 5,498’ 3.933 Wireline Re-Entry Guide 6,452’ 5,499’ End of tubing assembly 16 6,618’ 5,632’ CIBP Updated By: JLL 09/08/23 PROPOSED North Cook Inlet Unit Tyonek Platform Well: A-05 PTD: 169-032 API: 50-883-20025-00 Completed: 12/21/2007 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI 1.0 4,450’ 4,515’ 3,889’ 3,941’ 65' 08/07/1994 Open CI 2.0 4,535’ 4,610’ 3,957’ 4,018’ 75' 08/07/1994 Open CI 3.0 4,630’ 4,650’ 4,034’ 4,051’ 20' 08/07/1994 Open CI 5.0 4,770’ 4,785’ 4,147’ 4,160’ 15' 05/08/1969 Open CI 6.0 4,832’ 4,862’ 4,197’ 4,222’ 30' 08/07/1994 Open CI 6.2 4,890’ 4,915’ 4,244’ 4,265’ 25' 05/08/1969 Open CI 8.2 5,042’ 5,052’ 4,368’ 4,376’ 10' 08/07/1994 Open CI 10.0 5,129’ 5,144’ 4,438’ 4,450’ 15' 08/01/1994 Open CI 11.0 5,196’ 5,206’ 4,493’ 4,501’ 10' 08/07/1994 Open Beluga ±5,213’ ±6,449’ ±4,507’ ±5,502’ ±1,236’ Future Proposed A-2 5,220’ 5,230’ 4,513’ 4,521’ 10' 08/07/1994 Open B-2 5,357’ 5,361’ 4,624’ 4,627’ 4' 08/07/1994 Open B-5.5 5,454’ 5,456’ 4,703’ 4,704’ 2' 08/07/1994 Open B-6 5,479’ 5,483’ 4,723’ 4,726’ 4' 08/07/1994 Open C-1 5,561’ 5,571’ 4,790’ 4,798’ 10' 08/07/1994 Open D-1 5,709’ 5,714’ 4,907’ 4,911’ 5' 08/07/1994 Open D-2.5 5,773’ 5,778’ 4,958’ 4,962’ 5' 08/07/1994 Open D-3 5,782’ 5,792’ 4,966’ 4,973’ 10' 08/07/1994 Open D-4 5,825’ 5,835’ 5,000’ 5,008’ 10' 08/07/1994 Open D-5 5,840’ 5,855’ 5,012’ 5,024’ 15' 08/07/1994 Open E-4 5,922’ 5,932’ 5,077’ 5,085’ 10' 08/07/1994 Open E-9 6,000’ 6,010’ 5,139’ 5,147’ 10' 08/07/1994 Open F-4 6,111’ 6,116’ 5,227’ 5,231’ 5' 08/07/1994 Open F-7 6,163’ 6,173’ 5,269’ 5,277’ 10' 08/07/1994 Open F-8 6,180’ 6,190’ 5,284’ 5,292’ 10' 08/07/1994 Open G-1 6,196’ 6,206’ 5,296’ 5,304’ 10' 08/07/1994 Open G-5 6,267’ 6,282’ 5,352’ 5,364’ 15' 08/07/1994 Open H-3 6,346’ 6,356’ 5,415’ 5,423’ 10' 08/07/1994 Open H-8 6,435’ 6,445’ 5,489’ 5,497’ 10' 08/07/1994 Open K-2 6,680’ 6,685’ 5,681’ 5,685’ 5' 1994 Isolated K-5 6,752’ 6,762’ 5,739’ 5,747’ 10' 1994 Isolated L-2 6,784’ 6,789’ 5,765’ 5,769’ 5' 1994 Isolated N-1 7,024’ 7,032’ 5,961’ 5,967’ 8' 1994 Isolated N-5 7,095’ 7,110’ 6,020’ 6,032’ 15' 1994 Isolated P-2 7,286’ 7,296’ 6,178’ 6,186’ 10' 1994 Isolated P-3 7,316’ 7,321’ 6,203’ 6,207’ 5' 1994 Isolated P-5 7,374’ 7,384’ 6,251’ 6,259’ 10' 1994 Isolated R-3 7,526’ 7,536’ 6,378’ 6,386’ 10' 1994 Isolated f~Ml"~IU~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION i~ECEfVED MAR 0 7 2008 REPORT OF SUNDRY WELL OPERAT~~ & Gas Cons, Commission 1. Operations Performed: Abandon ^ Repair Well 0 Plug Pertorations ^ Stimulate ^ Otl>~tpfa~ Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^~ Exploratory ^ ~ 169-032 ! ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: - P. O. Box 100360, Anchora e, Alaska 99510 50-883-20025-00 7. KB Elevation (ft): ' 9. Well Name and Number RKB 116 , NC.1 V Dl~l A-05 8. Property Designation: 10. Field/Pool(s): ADL 17589 ~ \ North Cook Inlet /Tertiary Gas 11. Present Well Condition Summary: Total Depth measured 8124' ~ feet true vertical 6884'' feet Plugs (measured) 6618' Effective Depth measured 6760' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural Structural 30" 385' 385' Conductor 16" 643' 643' Surface 10-3/4" 2571' 2373' Production 7" 8097' 6856' Perforation depth: Measured depth: 4450'-7536' ~~N ApR ~. ~ 2008 true vertical depth: Tubing (size, grade, and measured depth) 4.5", J-55, 6452' MD. Packers &SSSV (type & measured depth) Halliburton VSR pkr, 5 Halliburton TWR pkrs @ 4342', 4700', 4806', 4869', 4976', 5213' SSSV @ 286' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na 11000 0 -- 150 Subsequent to operation na 11000 0 -- 150 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^ GasO WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 307-372 Contact Jim E 's @ 265-1544 Printed Name i nis Title Wells Group Engineer , Signature `. ,.,-" • ~--- Phone: 265-1544 ~ ~ ~ ~ Date P ared b haro Allsu -Drake 263-4612 l" ~ 6 p Form 10-40 R vised 04/2006 v ~.~ ( Submit Original Only ConocoPhillips Weilviea Web Reporting Well Name: NCI A-05 Job Type: RECOMPLETION Time Log Summary 12/13/2007 00:01 03:01 3.00 MIRU MOVE I SKID Skid rig CUDD #136 over well 03:01 05:01 2.00 COMPZ MOVE OTHR RU PWS, PT Lub. 05:01 06:01 1.00 MIRU MOVE OTHR RIH and pull SSSV 06:01 07:31 1.50 MIRU MOVE OTHR Attempt to set PX plug in X profile @ 4380 RKB, unable to locate profile. POOH 07:31 09:01 1.50 MIRU MOVE OTHR RIH and reattempt set with no success, still unable to locate profile. POOH 09:01 10:31 1.50 MIRU MOVE OTHR RIH and locate SSSV profile, RIH in the control position. Still not able to locate X profile. 10:31 14:31 4.00 RIH w/ BL brush and pumped 10 bbls of KCL to brush and flush X nipple. 14:31 16:01 1.50 RIH with plug in the control position, still not able to locate X profile. 16:01 18:01 2.00 RIH and set plug body in XD sliding sleeve 4663' RKB. POOH 18:01 22:01 4.00 RIH with prong, bullhead 71 Bbls. 6% KCI and set prong. PT tubing to 1000 psi. Bleed to zero and monitor well. 22:01 23:01 1.00 RIH with catcher 23:01 00:01 1.00 RD Pollard 12/14/2007 00:00 01:00 1.00 MIRU MOVE OTHR RD Pollard. 01:00 02:30 1.50 MIRU MOVE OTHR Fluid pack and PT IA to 2200 psi for 30 min. 02:30 10:30 8.00 MIRU MOVE WOP NP Waiting on FMC hand on 0730 chopper. 10:30 13:30 3.00 MIRU MOVE OTHR Bled down tubing and IA to 0 psi, stung into TTP and bled to 0 psi. 13:30 15:30 2.00 MIRU MOVE OTHR Set BPV in tubing hanger. Unable to set properly and then unable to pull. Call out SL to pull BPV and set plug in tubin 15:30 20:00 4.50 MIRU WELCT WOLG NP Wait on Polard to arrive at platform 20:00 22:00 2.00 MIRU WELCT OTHR RU pollard SL 22:00 23:00 1.00 MIRU WELCT OTHR Pull BPV with 2.5" GS 23:00 00:00 1.00 MIRU WELCTI OTHR RIH with slipstop and set at 30' i Time Logs _. __ __ Date From _ To _D_ur S De th E. De th Phase Code Subcode T CdM 12/15/2007 00:00 06:00 6.00 MIRU WELC OTHR _ RIH with D&D packer and set on top of sli sto at 29', set slipstop on top of D&D. PT D&D 06:00 12:00 6.00 MIRU WELC NUND Nipple down tree 12:00 18:00 6.00 MIRU WELC NUND NU BOP 18:00 20:00 2.00 MIRU WELCT EQRP Change rams in BOP 20:00 00:00 4.00 MIRU WELC BOPE Be in testin BOP. Leak at BOP ram bonnet. 12/16/2007 00:00 08:00 8.00 MIRU WELC BOPE P Testing BOP 08:00 17:00 9.00 COMPZ RPCOh OTHR P Completed BOP test. RU to disposal well, set u A-3 for flowback. 17:00 23:00 6.00 COMPZ RPCOti SLKL P RU SL, shear Kobe and pulled upper slip stop. Unable to pull D&D after four attem ts. 23:00 00:00 1.00 COMPZ RPCOh SLKL P RD SL. Prep to pull tubing 12/17/2007 00:00 01:30 1.50 COMPZ RPCO OTHR RU to pull tubing and circulate well 01:30 08:30 7.00 COMPZ RPCOh CIRC Pulled 70000#, approx. 10' up weight dropped to 62000#, pulled up 15' and reverse circulate. 2100 psi @ 1.6 bpm. Surface to surface volume is 140 Bbls. 08:30 10:30 2.00 COMPZ RPCOA CIRC Well looks as if flow had stopped, attempt to break joint of tubing and fluids spilled out causing a 40 gallon s ill. 10:30 13:30 3.00 COMPZ RPCOh SFTY Clean spill fluids, secure well to circulate .Attend safet stand down. 13:30 16:00 2.50 COMPZ RPCO CIRC Circulate 160 bbls down tubing string takin returns u the IA of 6% KCL. 16:00 16:30 0.50 COMPZ RPCOh PULD Start pulling tubing, lay down first stand and ull sli -sto left b Pollard. 16:30 17:00 0.50 COMPZ RPCOh PULD Pulled out XXO SVLN and sent in with Pollard for testing as to why it would not seal. 17:00 00:00 7.00 COMPZ RPCOh TRIP Continued pulling tubing 12/18/2007 00:00 06:00 6.00 COMPZ RPCO WOEO NP Tally jewelry and clean up deck, prepare to run tubing in hole, waiting for boat with GLMs 06:00 21:30 15.50 COMPZ RPCOh RCST Trip in hole with production tubing 21:30 23:00 1.50 COMPZ RPCOh RCST PU SVLN, Continue RIH with control line 23:00 00:00 1.00 COMPZ RPCO RCST PU landing joints, total of 80.83', MU stand i e hose. 12/19/2007 00:00 01:30 1.50 COMPZ RPCOh HOSO Continue with space out, pumped at min rate while stabbing over, 500 psi holding steady. Bleed off and PUH to up weight of 58000. PU 2' and mark i e. gage ~ o#~ r ~ Time Logs - _ _ - - - Date _ From To Dur__ S. Depth E. D~th Phase Code Subcode T COM 12/19/2007 01:30 04:00 2.50 COMPZ RPCOti HOSO Lay down 4.23' pup joint to get on depth. Install hanger, make up control line and PT. 04:00 12:00 8.00 COMPZ RPCOti CIRC Land tubing and confirm depths, PU 10' and reverse circulate IA. Frozen lines bein delt with. 12:00 13:00 1.00 COMPZ RPCOh CIRC Reverse in 70 Bbls. 6%KCI with 1% by volume ConQor 303 A corrosion inhibitor. 13:00 16:00 3.00 COMPZ RPCO HOSO Land tubing, PT tubing and hanger, monitorin IA. La down landin 'oints 16:00 18:00 2.00 COMPZ RPCO NUND Set BPV 18:00 22:30 4.50 COMPZ RPCOh NUND Nipple down BOP stack 22:30 00:00 1.50 COMPZ RPCO NUND Nipple up tree 12/20/2007 00:00 03:30 3.50 COMPZ RPCOh NUND Nipple up tree, test control line. 03:30 05:30 2.00 COMPZ RPCOh NUND PT tubing to 2500 psi for 30 min. PT .~ IA to 2500 for 30 min. PT Tree to 05:30 17:30 12.00 COMPZ RPCOh SLKL RU SL, pull dummy SSSV, pull dumm GLV, install GLV, 17:30 19:00 1.50 COMPZ RPCO SFTY Safety stand down 19:00 22:00 3.00 COMPZ RPCOti OTHR RU to displace KCI to PTS 22:00 22:30 0.50 COMPZ RPCO SFEQ PT PTS flow line 22:30 00:00 1.50 COMPZ RPCOh OTHR Displacing KCI from IA and tubing to PTS 12/21/2007 00:00 04:00 4.00 COMPZ RPCOh OTHR Displacing KCI from tubing and IA with lift as. 715 si 04:00 12:00 8.00 COMPZ RPCO WOEQ X Leaking casing valve, bled down IA and decided to install new casing valves before resumin as lift 12:00 18:00 6.00 COMPZ RPCO NUND Install new 2 1/16" casing valves on IA, PT to 2500 si 18:00 21:00 3.00 COMPZ RPCOti OTHR Resume gaslifting well to displace well bore fluids. 21:00 00:00 3.00 COMPZ RPCOh WOEL NP Shut down attempts to gaslift well due to lattorm roduction roblems 12/22/2007 00:00 09:00 9.00 COMPZ RPCO WOEL NP Waiting on production to startup a ain. 09:00 10:00 1.00 COMPZ RPCOh SLKL RD PTS and RU SL 10:00 15:00 5.00 COMPZ RPCO SLKL Change out GLV Sta. #1 & #2 15:00 16:00 1.00 COMPZ RPCO SLKL RD Pollard SL and re-rig PTS 16:00 22:00 6.00 COMPZ RPCOM1 OTHR Displace fluid with lift gas, for real this time. 22:00 23:00 1.00 COMPZ RPCO SLKL Straight gas after flowing back about 140 Bbls. water, RD PTS, RU SL 23:00 00:00 1.00 COMPZ RPCO SLKL RIH to pull catcher. Tagged up at 4563'. POOH ~® Paq~ 3 oaf ~ r ~ Time Logs _ _ Date From To Dur S De th E, Depth Phase Code Subcode T COM 12/22/2007 COMPZ RPCOh SLKL RIH with 3" bailer to 4562', worked down to 4567'. POOH. Bailer full of scale i e do a mixture. 12/23/2007 00:00 06:00 6.00 COMPZ RPCOh SLKL Bailing fill from 4571' to 45 06:00 12:00 6.00 COMPZ RPCOh SLKL NP Shut down SL crew for rest 12:00 20:30 8.50 COMPZ RPCOh SLKL Relief crew on platform. Back to bailin . 20:30 21:30 1.00 COMPZ RPCOti SLKL NP Bailer stuck at 4627'. Jars still work but no spangs. Pull 1650 and start bleedin WHP down from 320 si. 21:30 23:00 1.50 COMPZ RPCOh SLKL Pulled free, POOH, slip and cut wire. 23:00 00:00 1.00 COMPZ RPCO SLKL RIH to resume bailing 12/24/2007 00:00 01:00 1.00 COMPZ RPCOh SLKL Still bailing fill, sticky. Ran 3.80" ua a rin down to 4623'. 3" bailer 01:00 14:00 13.00 COMPZ RPCOh SLKL Bailed down 4629' SLMD, Attempt to pull catcher sub . Pulled up hole 29' and to ed u ,lost catcher. 14:00 16:30 2.50 COMPZ RPCOh SLKL RIH with 2-3/8" pump bailer, 3 runs 16:30 17:12 0.70 COMPZ RPCOti SLKL RIH and pull catcher sub 17:12 18:12 1.00 COMPZ RPCOh SLKL Attempt to pull prong, can't get latched u 18:12 20:00 1.80 COMPZ RPCOI~ SLKL Made two runs with 2.-3/8" pump bailer. 20:00 21:30 1.50 COMPZ RPCOh SLKL Latch up on prong and jarred free 21:30 00:00 2.50 COMPZ RPCOh SLKL RIH with 2-3/8" bailer, 12/25/2007 00:00 01:00 1.00 COMPZ RPCOh SLKL P Pull PX plug from 4664'. 01:00 02:30 1.50 COMPZ RPCOti SLKL P Set SSSV @ 285.7'. Apply hydraulic ressure. Test ood, POOH. 02:30 03:30 1.00 COMPZ RPCOh SLKL P RD SL. Shut SSSV, bleed down WHP to 150 psi from 540. slowly buids u to 540 over twent minutes./ 03:30 05:30 2.00 COMPZ RPCOh SLKL P Test SSSV failed, pull SSSV. 05:30 07:30 2.00 COMPZ RPCOh SLKL P Inspect SSSV and it appears to be in ood sha e. 07:30 09:30 2.00 COMPZ RPCOh SLKL P Re run SSSV, still won't hold. Turn well over to roduction 09:30 12:00 2.50 COMPZ RPCO SLKL P RDMO F~age 4 n# ~ • • C011000P~l1~~IP5 NCIU WELL A-5 Completion Diagram APlttsot383zoozsoo d Gas Producer FMC OCT RKBArill Deck: i Sin /e Comp. FMC 6" 3M 4 1/2" 8rd X 4 1/2" IBT RKB-THF: 39.4 } XXO 271' Annulus Fluid: 6 % KCL wlr w/ corrosion inhibitor RKB-SL : 116 So SVLN . ~. TOC: 2612' from CBL datetl 05/06/69 WATER DEP7H: 120' RKB-ML OD To Bottom YVf Grede Conn. Buret Coll Tenan CASING & TUBING 16" ~ 643' ~_ 30 " 41' 385' 16 " 41' 643' 65# H-40 10 3/4 " 41' 2571' 15.5# 8 51# JSS B78C 3350 1970 531 n GLM #1 @ 1770' 7 " 39' 79' 26# JSS B78C 4660 4080 327 7" 79' 7127' 23# J-55 B78C 4080 3080 288 ' 10 314" @ 2571' ? " 7117 809?' 26# J-55 B78C 4660 4080 327 r.u J-55 187 Mod 4730 4960 134 TOC @ 2612' CBL ' ~ ~ - ~ J-55 8rd Mod x730 a9EO 13a I I No. To Len th Deaerl Ion ID OD 4s i' GLM #2 @ 3352' PRODUCTION TUBING STRING & JEWELRY i - l ~.. _:: .. .,. ~ Lu ~ ~IS ~ ..::._ . - fi l 50 270.30 2 42 XXO SVLN Halliburton 3.813 5.528 ~~ l an. ~.-r+ ~.~ ~ ~ ~ . ~ - r1.ut Tubm ~ -:t ~ 43 l ~~ GLM #3 @ d27T 47 1769 83 6 86 Camco KBG-2 GLM w/ GLV 3.956 6.250 an ~. ... .::.., ....; .. .. ,!:~d Tubing ~ ed •I'BR- 4333' Ill 45 3351.73 6.86 Camco KBG-2 GLM wr GLV 3.958 6.250 ~ as 1:rt Tubui ~ 43 4276.68 6.89 Camco KBG-2 GLM w/ OV 3.958 6.250 ae ''~ ' Halliburton VSR packer ~ 4342' ai .>::t Mod 7ubmg 41 tipace Uul 76 •x• 4380' 40 4333.25 9.13 Upper PBR Assembly 3.850 5.956 Cook Inlet Sands 1st 38 4339.50 6.48 7" 261b Halliburton VSR Packer 4.000 5.875 4450-4515 CI 1.0 't7 ' I 4535-4610 CI 2.0 36 4377.44 1.44 HaIliGlrton "X" Nipple 3.813 5.560 I 4630-4650 CI30 nt'. - :~~f Tun~r~ - 3a ~ l2.' H.il ... - ~.. CLOSED (5'22:03) :.E'_'. ...... .. i i.i Ling 3t Halliburton TWR pecker ~ 4700' 31 4698.66 d.19 7" 261b Halliburton TWR Packer 4.000 5.875 4770-4785 CI 5.0 - - r.1: -~:t,. ,u _,7 2a Halliblxton TWR packer @ 4806' 26 4806.73 4.19 7" 261b Halliburton TWR Packer 4.000 5.875 4 C?ii 4832-4862 C16.0 2a - ~ 55'"~. ' ..xo_ an ~~'. r,7 as > .. .. °.v,.' T~.b ~~g '.t slys C lo,ed 22 4864.39 4.23 H:,C :, SI.•eve CLOSED 5!23/03' 3.813 ak6n 62 Pi'~~ +ar ail ' 20 Halliburton TWR packer ~ 4869' 20 4869.74 4.19 7" 261b Halliburton TWR Packer 4.000 5.875 r~+,:i '_27ti 4890-4515 CI 6.2 r. ~~~ .'. -t te:::. - v ua 1~ a ' „~L, ~ n„..n t5 HaIlLurton TWR packer @ 4976' 15 4976.32 4.19 7" 261b Halliburton TWR Packer 4.000 5.875 'a 5042 -5052 CI 8.2 5129-5144 CI 10.0 ~i, 5196-521)6 CI17.0 11 CLOSED 1.81 3 n xo.. I ' Closed 9 5213.00 4.19 7" 261b Halliburton 7WR Packer 4.000 5.875 a Halliburton TWR packer ~ 5213' ? Beluga Sands - - - - ' ''• ~ _ 5 5817.69 4.22 Halliburton 4 112" XA SSD Sleeve OPEN (Si24l03) 3.873 5.560 5220-5230 a-2 41 '. ~'.7 ttt :.'.5 L IE ".ri A4. ~t 'r, itri~ig .1 t::' ? 947 • 5357 - 5361 D-2 ~.1 l 3 6449.89 1.49 Halliburton 4 1!2" "XN" Ni pie 3.725 5.530 l i • 5454 - 545fi b-5.5 ~ vs's ' • 5479-5483 I>•6 1 6452.12 Asg nntbl End of T ng 5561 - 5571 c-1 I. We// Nisto „I' ~~,I -~. 15818• Open Bu a 5907 °xN~~ 6450' 5709 - 5714 d-1 5773 - 5778 d-2.5 5782 - 5792 d-3 5825 -5835 tl-0 5840 - 5855 d-5 5922 - 5932 e4 6000 -6010 e-9 6111 - 6116 f-0 6163 - 6173 f-7 6180-6190 f5 6196 - 6206 g-1 6267 - 6282 g-5 6346 - 6356 h-3 6435 -6445 h5 ' ' August 1969 -Well completed in Cook Inlet 1-3,5,6,8,10,11 8 Beluga a-r July 1981 -Producing from Cook Inlet only, isolate Beluga. August 1994 WO - Repedorate Beluga a-2 to hA 5220'5445' Repedorate Cook Inlet 1.0, 2.0, 3.0. 6.0, 8.2, 10.0, 8 11 0 DST #1 Beluga a-r Flow 9.5 MMCFD, 100 BW PD. 5650 CI, 192 psi FTP CI 11.0, 10.0811.0, and 8.2,10.0,811.0 tested gas no water. CI fi.0 woultl not flow. Set cement retainer at 6618' to abantlon Beluga k-r, DST # 9 Beluga a-h :Flow 8.7 MMCFD, 159 BW PD, 195 psi FTP. Well completed in Beluga a-h :Test 9.8 MMCFD, 44 BW PD. 910 psi FTP. NEW PERFS 1994 October 1999 -Top of Fill 6120' W LM June 4, 2001-Tag fill@6100'WLM May 10, 2002 -Tag fill @6129' W LM, ran caliper (tbg goe d). May 12, 2003 -Tag fill @ 5818' W LM, open sleeve @ d664' May 1 d-15, 2003 -Open sleeve @ 4664' & 4864' May 16, 2003 -Reset SSSV @ 271' May 22, 2003 -Bail fill to 5815'; close sleeve @4664' RKB. May 23, 2003 -Close sleeve @ 4864'; bail fill to 5831' May 24, 2003 -Open sleeve @5818' RKB t SSSV @271' 513 V03 31 2003 T fill 5805' 5/29103 FCO 5/30/03 R M 29 ro s7sa CIBP @ 6618 (8/ 94) 6680 -6685 k-2 6752 - 6762 k-5 6784 - 6789 I-2 7024 - 7032 n-1 7095 - 7110 n-5 I~li~' 7286-7296 p-2 ' 7316 - 7327 p-3 r /374 - 73!54 p-5 7526 - 7536 r-3 . , on . . ese ay . - ag @ May 11, 2005 -Tag fill @ 5702' RKB during SBHP Survey June 2006 -Tag fill @ 5560' K8. Run MPLT survey. CCT FCO to 6492' CTMD. Sept 17, 2006 -Tag fill @ 5961' KB for BHP surrey. Set & pull plugs for tree replacement. May 12. 2007 -Tag fill @ 5907' RKB for SBHP survey. Dec 2007 - RW O pulled Ibg from PBR, replaced failed SVLN 8 added GLM's U ated :1 21612 0 0 7 B :Jim Ennis 7" .~; 80]7' PBTD-. 6760' TD = 8.124' Well: North Cook Inlet Unit No. A-05 PTD# 169-032 Location. Lower Cook Inlet, Alaska Field: Cook Inlet Unit JJE Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting : Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 332,102.26 2.09 NCI A-02 2,586,722.85 332,108.29 2,586,721.16 332,111.27 3.43 - ---- NCI A-03 2,586,728.60 332,106.22 2,586,728.31 - 332,109.43 3.22 NCI A-04 2,586,719.62 332,105.09 2,586,718.58 332,108.09 3.18 _ NCI A-05 2,586,725.55 332,110.17 _ 2,586,725.14 __ 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 NCI A-10A 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 NCI A-11 2,586,670.23 332,039.14 2,586,677.01 332,041.75 7.27 - - NCI A-12 2,586,722.73 _ - 331,947.80 - 2,586,723.59 331,994.15 46.36 NCI A-13 2,586,734.88 331,993.50 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03P61 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 C] ~~~N~ APR 0 ~ 2000 / (O~ ~~ REV DATE BY CK APP ESCRIPTION REV DATE BY CK P DESCRIPTION I 2/29/08 SAS {(W,Q MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 g = ~ 36 31 T 12 N 31 32 $; e Y F a°~ 1 6 ~ y~i T II N 6 5 .,~ »o N s. ro'IS' ~ SE . 6 1206' SCALE: I"=1320' -6 - ~ ~ o 1 6 6 5 12 7 ~ g GENERAL NOTES: ~~~~ OF ~'I/ ,1,/ < ~~~~~~~~ ~ • 1. SEE SHEET 3 FOR COORDINATE TABLE '~`5~-~,• ~' '~P •'~~~ i 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ~ : ~ VERTICAL SURVEY DATA ~ 49th ': 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~ """"""""""""""""""""'""" j VALUES ~ ~ . . ~ ................................. . ....~ i ~ ~ KENNETH W. AYERS ;' ~o~ • ~ ; : . ~• ~ ',~ LS-8535 ~,' ~,~i SURVEYOR'S CERTIFICATE „~,..~ „ ~'P~::~i ~1~,, ARo 1 HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED ~ F AND ~~~~ ; ~=~~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY ME OR UNDER MY DIRECT SUPERVISION AND THAT AL DONE BY L LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & nssoctaTES, iNC. FEBRUARY 28, 2008. SURVEYORS ENGINEERS PLANNERS ~ PHONE: 19071 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORT" C°OK INLET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. 08-005 AS BUILT 02/27/08 DRAWING N0: ~8~~5 AS BU~L_T PART: 1 OE 3 REV: 1 r~ REV DATE BY CK APP DESCRIPTION REV DATE BY C P DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUO LINE ELEV., SHT.3 ~ ~; ~ ~~ ~ y~~ ~ Ap 99 rw as ~O s. ro'u' 9EG 6 aliS ~^ `` ` ~ ~ ~~ ~o •s~, SCALE: 1"=30' a 9 AA~ O ESD 600 -50 ESD 600-51 Ala 7 I p •91 AB A•A• B3 : •p5 • A3~ A6 AI2 BI : ••A5 A4 A2 WELL HOUSE 2 Opp A'° zp 05 LEGEND: p 3 • A ~ WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE) GENERAL NOTES: 1. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE NO. 4, AND IT WAS NOT & assoc[nTes, [rrc. S AS BUILT SURVEYORS ENGINEERS PWNNERS v PHONE: (907) 272-5451 AREA: MODULE: UNIT: ConocoPhilli s NORT" C°OK INEET p TYONEK P~ATEORM Alaska, Inc. WEEE CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 08- 005 AS BUILT 2 of 3 1 i~-. • • .~ ~~ SARAH PAL/N, GOVERNOR CO~L+Y,tR Aj~=O n ~~+ I~ 333 W. 7th AVENUE, SUITE 100 -7L .ii l.~~ll•••~~~~~•iiiiii----777 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Group Engineer ConocoPhillips Alaska, Inc ~~,'~~ DEe ~ ~ ZQ07 PO Box 100360 Anchorage, AK 99510 Re: North Cook Inlet Field, Tertiary Gas Pool, NCI A-05 ~' Sundry Number: 307-372 f„ ~ ~3 I, ~(/~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~y of December, 2007 Encl. Sincerely, • _ • ~~ ~~ ~ ~2 ~ Z~ Z~t' STATE OF ALASKA ~t~ a ~~,~ ~. ~+ ~~~~ t ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA+Lgk~ ~`~ ~` ~~~ ~°"~~ COmmisslon 20 AAC 25.280 Anchorage .___ . 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ ' Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q ` Exploratory ^ 169-032 3. Address: Stratigraphic ^ Service ^ 6. API Number: f P. O. Box 100360, Anchorage, Alaska 99510 50-883-20025-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ NCI A-05 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~IE fCl~~, ~'%G~ ADL 17589 ~ RKB 116' Cook Inlet / B r ool ~-s j. ~L•e 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8124' ~ 6884' 5907' 6618' Casing Length Size MD ND Burst Collapse Structural 30" 385' 385' Conductor 16" 643' 643' Surface 10-3l4" 2571' 2373' Production 7~~ 8097 6856' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4450'-7536' 4.5" J-55 6452' Packers and SSSV Type: Packers and SSSV MD (ft) Halliburton VSR pkr, 5 Halliburton TWR pkrs @ 4342', 4700', 4806', 4869', 4976', 5213' SSSV @ 271' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed O erations Pro ram p g ^ BOP Sketch Q Exploratory ^ ~ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat December 13, 2007 Oil ^ Gas ~ ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed Nam Ennis Title: Wells Group Engin er Signature s Phone 265-1544 Date ! ~ ~x (~~ Commission Use Onl Snry um r Conditions of approva : Notify Commission so that a representative may witness ~ ~~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~5~©~~ ~~'~ t e ~~ Subsequent Form Required: ~~ ~ ~~? ~~~ ~~~- ~ ~ 2~~~ APPROVED BY /~~, Approved by: C E THE COMMISSION ~~ r Date: Form 10-403 Revised 06/2006 i~®~~ ybmit in Duplicate ,[~/Z'/~'°% i2~t7 r • • NCIU A #5 Change SVLN Sundry Procedure Pre-riq Work: 1. MIRU Pollard slickline. Pull SSSV. Set 3.813" `PX' plug in nipple @ 4380' KB. Blow down tbg pressure to zero. RD slickline. 2. Load tbg w/ 2 micron filtered 6% KCL water. PT tbg & plug to 1000 psi. Load & PT IA to 2500 psi w/ methanol or diesel. 3. Set BPV. Riq Work: 1. Verify sundry approval to perform workover has been received. 2. MIRU Cudd #136. Paint line on tree, tbg head adapter and tbg head. Take photo of tree position for reference at end of workover. ND tree. Install blanking plug in hanger lift threads. NUBOP, 7", 5M w/ 4.5" pipe rams. Function test BOP's and PT to 250/2500 psi. Pull blacking plug. Pull BPV. (Note: 24 hr advance notification to AOGCC required prior to testing BOPE.) MASP is (572)-(4153' TVD)(0.01 psi/ft}=530 psi based on SBHP obtained 5/12/07. 4. Unland tbg hanger. Attempt to pull tbg from HES PBR. If unsuccessful @ 80% tbg yield (158M#), rig up E-line and chemical cut tbg in middle of first full joint above packer. POOH w/ 4.5" tbg, spooling SSSV control line as necessary. No equipment shall leave platform until surveyed for NORM. 5. If PBR pulled OK, go to step #6. If tbg was chemical cut, single in w/ wash shoe, overshot w/ grapple, DC's and jars on production tubing. Reverse circ down to `VSR' pkr and engage fish. Pull and/or jar as necessary to remove PBR stem. POOH, lay down fishing tools. 6. RIH w/ PBR seal stem, same 4.5" production tubing, three KBG-2 GLM's and 3.813" `XXO' SVLN. 7. Locate PBR. Circ well & spot corrosion inhibited (1 % by volume Baker Petrolite CRW-132) 2 micron filtered 6% KCL water & 300' freeze protect fluid in IA. Space-out, land tbg hanger w/ landing joint perforated below upper pipe rams. Close upper pipe rams. PT tbg & hanger 2500 psi. Bleed off pressure. Open upper pipe rams. 8. Install BPV. NDBOP. Install tbg hanger hold down plate. RILDS. NUWH. Pull BPV. RU chart recorder to tbg & IA. PT tbg 2500 psi for 30 minutes. Bleed off tbg pressure. PT IA 2500 psi for 30 minutes. Install tree test plug (TTP) and test tree to 3000 psi. Pull TTP. Install BPV. RDMO. Post Riq Work 1. RU slickline. Install GL design. 2. RU PTS. Using low GL rate, displace water from IA and unload water from well. 3. Retrieve `PX' plug from 3.813" `X' nipple @ 4380' KB. 4. Install `FXE' SSSV in SVLN and test. RD slickline. Jim Ennis Page 1 12/11/2007 ~ '~ °,ry~~~ ~~I ~~' ~,~ it ~~~ _, ~, 1 ~.~~ ~, ~:_ 1~' ~~nc~ ~`c-~~~. ~r~r ~. ~-1 ~'~ ~" ~1'. I ~~la~~~~ ~ 1~~~1 d a5 SVLN I I~~~16'8~643' 10 314" @ 2571' as "Pa R" 4333' TOC @ 2612' CBL ao Halliburton VSR packer @ 4342' ae "x•' 4380' Cook Inlet Sands ~: 4450 - 4515 CI 1.0 ~: 4535-4610 CI 2.0 4630 - 4650 CI 3.0 76 "Xn" Closed 77 I:I: Halliburton TWR packer ~ 4700' :~ 4770 - 4785 CI 5.0 sfi Halliburton TWR packer ~ 4806' ~: 4832 - 4862 CI 6.0 zz °xo° Closed so Halliburton TWR packer @4869' 4890 - 4915 CI 6.2 is Halliburton TWR packer @ 4976' ~: 5042 - 5052 CI 8.2 ~: 5129 - 5144 CI 10.0 ~: 5196 - 5206 CI 11.0 tt °xo° Closed s Halliburton TWR packer ~ 5213' Beluga Sands ~: 5220 - 5230 a-2 5357 - 5361 b-2 ' 5454 -5456 b-5.5 ' 5479 -5483 b-6 5561 - 5571 c-1 ~: 5709 - 5714 d-1 ~: 5773 - 5778 d-2.5 5782 - 5792 d-3 s € °xn° :5818' Open = 5825 - 5835 d-0 5840 - 5855 d-5 5922 - 5932 e-4 ~ 5907' = 6000-6010 a-9 6111-6116 f~ 6163-6173 f-7 6180-6190 f-8 6196 - 6206 g-1 6267 - 6282 g-5 6346 - 6356 h-3 s "xN•' 6450' = 6435 - 6445 h~ T CIBP ~ 6618' (Sf94) :~ 6680 - 6685 k-2 ~: 6752 - 6762 k-5 ~: 6784 - 6789 I-2 :~ 7024 - 7032 n-1 :~ 7095 - 7110 n-5 ~: 7286 - 7296 p-2 ~: 7316 - 7321 p-3 :~ 7374 - 7384 p-5 :~ 7526 - 7536 r-3 PBTD 6760' 7" @ 8097' TD ~=~~8,124'~ ~~~ • • COnoCOPhillips NCIU WELL A-5 Completion Diagram ADI# 508832002500 Gas Producer FMC OCT RKB-Drill Deck: Single Comp. FMC 6" 3M 4 112" 8rd X 4 1/2" BTSC RKB-THF: 39.4 Annulus Fluid: salt water with 3 bbl methanol RKB-SL : 116 TOC: 2612' from CBL dated 05106/69 WATER DEPTH: 120' RKB-ML 48 39 SO :'31 OS 4 1; '.~ 12JL Ic J-55 BTC MOD Tu 45 270.95 2.45 Halliburton XXO SVLN ~4 - 32 u4 4 v2° 12 ~ 5 Ib J-55 BTC MOD Tu 4627 5 ~ 4 112" 12. i8 Ib 755 EU -MOD Tul 42 4333.25 9.13 U er PBR Assembl 1 R2 Ra:G'I I_atc;li Seal F~sseribl 40 4342.70 6.48 7" 26 Ib Halliburton VSR Packer ... 31 :I> -I "_" i2 ~ J-55 E. I LI 'L Tul 38 4380.64 1.44 Halliburton "X" Ni le 37 4382.05 281 `~0 ~ 1 ~' Ib J-55 EU -MOU Tul 36 4663.58 4.23 Halliburton 4 112" XD Sleeve 35 4867 81 31 43 4 Vim' 12.i51b J-55 EU -MOD Tul 34 4C=t, 24 2 62 No vo Seal Assembly 26 4818 27 0 6 4 1/2"'12751b Tubin Ada for 25 481 ~ 87 31.?2 4 112" 1275 Ib J-55 EU -MOD Tub 24 48ti0.19 R 06 4 112" 12 ~51b EU Pu Jt. 23 4G58 27 6 (~ 4 '.;2" 12751b EU Pup Ji 22 4864.39 4.23 Halliburton 4 112" XD Sleeve ?1 g8rg C2 No ~so Seal Assenib, 20 4869.74 4.19 7" 26 Ib Halliburton TWR Packer a soo 3.813 5.528 _ 4~ 4~ 3.850 6.956 5r 4.000 5.875 4 ~o 3 930 5 500 4.000 5.875 4 276 5 C00 3 956 v 562 3.992 1 4.500 15 4976.32 4.19 7" 26 Ib Halliburton TWR Packer 4.000 5.875 '14 49>>U.~~1 8.5".7 Mill~~,ii->:ICi~s~i~~ii 5000 13 4" ;' ins C ~~. I.. - 950 12 ~0 . i~ 11 5207.65 4.23 Halliburton 4112" xD Slee4'e CLOSED 3.813 5,560 1C ., < J. Lo _.~ I. -., r,. 3930 ~- 9 5213.00 4.19 7" 26 Ib Halliburton TWR Packer 4.000 5.875 8 1`r ;d8 111Lut E;aeiisun 4276 JOG 7 _;=6.57 ~ 4 '~, ':~~~ 12 751b Tubirn.. 1f ;Y.o~, 3 956 - g< 6 _, 1 ' %2" 12 '5 Ib 755 EU -MOD Tubinrl 3 992 d ' 5 5817.67 4.22 Halliburfon 4 112" XA SSD Sleeve OPEN (5124103) 3.813 4 t:1 b i 1/:"' 12J51b J-55 EU -MOD Tubin; 3 992 4 3 6449.89 1.49 Halliburton 4 1/2" "XN Nf le 3 725 5.530 - t `~ li,"CIVVIL Re-e nU .~~ude ~ X33 ~I 645Z 12 End of Tubin Assembl . ...................................................................... .............. Well His'to August 1969 -Well completed in Cook Inlet 1-3,5,6,8,10,11 & Beluga a-r. July 1981 -Producing from Cook Inlet only, isolate Beluga. August 1994 WO - Reperforate Beluga a-2 to h-8 5220'-6445' Reperforate Cook Inlet 1.0, 2.0, 3.0, 6.0, 8.2, 10.0, & 11.0 DST #1 Beluga a-r :Flow 9.5 MMCFD, 100 BWPD, 5650 CI, 192 psi FTP CI 11.0, 10.0&11.0, and 8.2,10.0,&11.0 tested gas no water. CI 6.0 would not flow. Set cement retainer at 6618' to abandon Beluga k-r, DST # 9 Beluga a-h :Flow 8.7 MMCFD, 159 BWPD, 195 psi FTP. Well completed in Beluga a-h :Test 9.8 MMCFD, 44 BWPD, 910 psi FTP. NEW PERFS 1994 October 1999 -Top of Fill 6120' WLM June 4, 2001 -Tag fill @ 6100' WLM May 10, 2002 - Tag f ll @6129' WLM, ran caliper (tbg good). May 12, 2003 - Tag f ll @ 5818' WLM, open sleeve @ 4664' May 14-15, 2003 -Open sleeve @ 4664' & 4864' May 16, 2003 -Reset SSSV @ 271' May 22, 2003 -Bail fill to 5815'; close sleeve @ 4664' RKB. May 23, 2003 -Close sleeve @ 4864'; bail fill to 5831' May 24, 2003 -Open sleeve @ 5818' RKB May 29-31, 2003 -Tag fill @ 5805' on 5/29/03. FCO 5/30/03. Reset SSSV @271' 5/31/03. May 11, 2005 -Tag fill @ 5702' RKB during SBHP Survey June 2006 -Tag fill @ 5560' KB. Run MPLT survey. CCT FCO to 6492' CTMD. Sept 17, 2006 -Tag fill @ 5961' KB for 8HP survey. Set 8 pull plugs for tree replacement. May 12, 2007 - Tag f ll @ 5907' RKB for SBHP survey. NCIU A #5 (PTD# 169-032) i Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophitlips.com] Sent: Tuesday, December 11, 2007 5:20 PM To: Maunder, Thomas E (DOA) Cc: Braden, John C Subject: NCIU A #5 (PTD# 169-032) Attachments: NCIU A #5 Change SVLN sundry procedure.doc; A-05 wellbore diagram 12-6-07.xts Tom, Page 1 of 1 We've got 1-1.5 days of post rig work remaining on A #3. Rather than wait to repair A #5 after A #4's workover, we'd prefer to replace A #5 SVLN next. I'll have a 403 submitted tomorrow morning for this work. I've attached a copy of the procedure &wellbore diagram for your use. BTW, A #3 gravel packed nicely yesterday and the wellhead was back on and tested this afternoon. «NCIU A #5 Change SVLN sundry procedure.doc» «A-05 wellbore diagram 12-6-07.x1s» Jim Ennis j j.ennis@conocophiUips.com (907)265-1544 (4Y) (907}632-7281 (C} From: Braden, John C Sent; Tuesday, December 11, 2007 1:20 t~M To: 'tom.maunder@aiaska.gov` Cc: NSK Problem Well Supv; NSK Problem Welt Supv; Tyanek Supervisor; Clark, Lindsey L; Ennis, J J; Cawvey, Von Subject: North Cook Inlet Unit A-5 Tom- NCIU A-5 has a sick SSSV. It needs to be replaced. There is a rig on location that can perform the work. I am in the process of writing an AFE to replace the SSSV. The valve will be replaced as soon as practical, but may be mare than 14 days. The well has a functioning surface safety valve. It was Last tested and passed on 11/8/07. We would like to continue to flow the welt unfit the workover. Please let me know what other information you may need or #arms t need to fill out. Sincerely, John C. Braden Cook Inlet Development ConocoPhillips Alaska, Inc. (9Q7) 263-4536 phone (907) 265-1441 fax john.c.braden@conocophillips.com 12/12/2007 Memow Multi-Finger Caliper Log Results Summaw Company: PHILLIPS Well: Log Date: May t2, 2002 Field: Log No.: 4679 State: Run No.: 1 APl No.: Pipe1 Desc.: 4.5" 12.6 lb. J-55 Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: NCIU A-5 North Cook Inlet Unit Alaska N/A 4,321 Ft. (MD) 6,108 Ft. (MD) Inspection Type' Corrosive & Mechanical Damage Inspection COMMENTS · This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 4.5" tubing logged is in good to fair condition. The caliper recordings indicate penetrations from 20% to 40% wall thickness recorded throughout the interval logged. The damage appears in the form of General Corrosion. No areas of significant cross-sectional wall loss are recorded throughout the logged interval. Deposits restrict the minimum measured ID to 3.34" in joint 165. The distribution of penetrations is illustrated in the Body Region Analysis Page of this report. The field engineer reported erratic slick line pulling speed and many tool hang-ups during the log run. This resulted in several intervals of minimal recorded data where the tool experienced excessive acceleration upon pulling loose from the hang-ups. The joint count numbering is an approximation based on the average joint length and the log start depth. TUBING - MAXIMUM RECORDED WALL PENETRATIONS · Corrosion (40%) Jt. 155 @ 4,735 Ft. (MD) Corrosion (37%) Jt. 161 @ 4,965 Ft. (MD) Corrosion (35%) Jt. 185 @ 5,751 Ft. (MD) Corrosion (31%) Jt. 145 @ 4,401 Ft. (MD) Corrosion (30%) Jt. 143 @ 4,330 Ft. (MD) TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No areas of significant cross-sectional metal loss (> 3%) are recorded throughout the interval logged. TUBING - MAXIMUM RECORDED ID RESTRICTIONS · Deposits Min. I.D. = 3.34" Jt. 165 @ 5,096 Ft. (MD) Deposits Min. I.D. = 3.35" Jt. 186 @ 5,764 Ft. (MD) Deposits Min. I.D. = 3.35" Jt. 161 @ 4,948 Ft. (MD) Deposits Min. I.D. = 3.36" Jt. 160 @ 4,928 Ft. (MD) Deposits Min. I.D. = 3.39" Jt. 143 @ 4,329 Ft. (MD) Field Engineer' S. Adcock Analyst: M. Lawrence Witness: N/A I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax' (907) 659-2314 Well: NCIU A-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA PDS Report Ove Body Region Analysis Survey Date: May 12, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread 4.5 ins 12.6 ppf. J-55 Nom. ID Nom. Upset Upper len. Lower len. 3.958 ins 4.5 ins 1.2 ins 1.2 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 'it 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 79) pene. 47 5 10 17 0 0 loss 67 12 0 0 0 0 Damage Configuration ( body ) isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 27) 0 25 0 2 0 Damage Profile (% wall) penetration body ,mm metal loss body 0 50 143 156 164 ~ 180 Bottom of Survey = 197 1 O0 Analysis Overview page 2 I I I I i ! I I I ! ] ] i ! ! I I Well: Field: Company: Country: NCIU Ao5 North Cook Inlet Unit PHILLIPS USA PDS Caliper Statisitical Evaluation Report Survey Date: May 12, 2002 Tool: MFC40 No. 00432 Tool Size: 2.75 inches Tubing I.D.: 3.958 inches 0.24 0.19 0.14 0.09 10 0.04 0.1 Percent Probability of Hole 20 50 1 O0 Average Rank 10 Standard Deviation of 0.009 100 Maximum Probable Penetration* 0.115 inches (42.6 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% * Derived from data with average rank value less than or equal to 26. PDS Caliper Minimum Diameter Profile Well: NCIU A-5 Survey Date: May 12, 2002 Field: North Cook Inlet Unit Tool: MFC40 No. 00432 Company: PHILLIPS Tool Size: 2.75 inches Country: USA Tubing I.D.: 3.958 inches Minimum Measured Diameters (In.) 2.75 2.85 2.95 3.05 3.15 3.25 3.35 3.45 3.55 3.65 3.75 3.85 3.95 { I IIII ii mm mm mm mm mm mm mm mm 143 143 144 146 148 150 152 153 154 154 156 157 157 158 158 159 159 161 161 162 164 166 168 168 168 170 172 174 176 178 180 182 184 186 187 189 191 193 195 197 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body ~ 0.271 ins Upset -~ 0.271 ins Nominal ID: 3.958 ins Well: NCIU A-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA Survey Date: May 12, 2002 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Bd@Up Body Loss Cplng [3ody ID Comments (% wall) inches inches inches % % inches inches inches 0 50 __1_ 143 0 0 .08 30 2 .13 .45 3.39 Corrosion. Deposits. 143.1 0 0 0 0 0 0 0 3.85 PBR 143.2 0 0 0 0 0 0 0 4.00 PACKER 144 0 0 .08 30 2 .20 .44 3.40 Corrosion. Deposits. [] · · 144.1 0 0 0 0 0 0 0 3.81 X Nip 145 0 0 .08 31 2 .16 .36 3.44 Corrosion. Deposits. 146 0 .02 [ .04 15 1 .09 .25 3.68 Shallow corrosion. Deposits. 147 0 0I .05 17 1 .08 .29 3.60 Shallow corrosion. Deposits. ·· 148 0 0 .05 18 1 0 .21 3.68 Shallow corrosion. Deposits. --- []l 149 0 0 .05 17 1 .17 .25 3.70 Shallow corrosion. Deposits. __ [][] 150 0 0 .03 10 1 0 .22 3.73 Deposits. 151 0 0 .06 21 1 .09 .31 3.52 Corrosion. Deposits. 152 0 0 .05 19 1 .11 .32 3.47 !Shallow corrosion. Deposits. __ 153 0 .03 .08 28 I .34 .26 3.62 'Corrosion. Deposits. 153.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Open) 154 0 0 .07 25 I .22 .48 3.41 Corrosion. Deposits. 154.1 0 0 0 0 0 0 0 3.93 NO GO SEAL 154.2 0 0 0 0 0 0 0 4.00 PACKER -- 154.3 0 0 0 0 0 0 0 4.28 MIL/OUT EXT 155 0 0 .11 40 2 .07 .47 3.41 Corrosion. Deposits. 156 0 0 .04 14 I .12 .32 3.53 Shallow corrosion. Deposits. ----· I 157 0 0 .06 21 1 .14 .32 3.59 Corrosion. Deposits. 157.1 0 0 0 0 0 0 0 3.93 NO GO SEAL 157.2 0 0 0 0 0 0 0 4.00 PACKER 157.3 0 0 0 0 0 0 0 4.28 MILLOUT EXT 158 0 0 .08 28 3 .08 .39 3.53 Corrosion ring with heavy deposits. 158.1 0 0 0 0 0 .28 .16 3.77 PUP Lt. Deposits. 158.2 0 0 0 0 0 .07 .10 3.83 PUP Lt. Deposits. 158.3 0 0 0 0 0 0 0 3.81 SLDNG SLV (Open) 158.4 0 0 0 0 0 0 0 3.93 NO GO SEAL 158.5 0 0 0 0 0 0 0 4.00 PACKER 158.6 0 0 0 0 0 0 0 4.28 MILLOUT EXT 159 0 .03 .04 16 I .29 .36 3.50 Shallow corrosion. Deposits. __ [] 160 0 0 .06 21 1 .32 .39 3.36 Corrosion. Deposits. [] · 161 0 0 0.10 37 2 .16 .52 3.35 Corrosion. Deposits. 161.1 0 0 0 0 0 0 3.93 NO GO SEAL 161.2 0 0 0 0 0 0 0 4.00 PACKER 161.3 0 0 0 0 0 0 0 4.28 MILLOUT EXT 162 0 0 .06 21 2 .26 .39 3.49 Corrosion ring with heavy deposits. 163 0 .03 .05 19 2 .25 .42 3.51 i Shallow corrosion. Deposits. 164 0 0 .05 20 2 .18 .40 3.47 Corrosion. Deposits. __ [] · 165 0 0 .07 24 2 .15 .46 3.34 Corrosion. Deposits. [] · I 166 0 .04 .06 22 3 .16 .31 3.48 Corrosion. Deposits. 167 0 0 .06 21 I .16 .32 3.53 Corrosion. Deposits. ----- []· 168 0 0 .06 21 I .07 .35 3.47 Corrosion. Deposits. _ 168.1 0 0 0 0 0 0 0 3.81 SLDNG SLV (Open) 168.2 0 0 0 0 0 0 0 3.93 NO GO SEAL 168.3 0 0 0 0 0 0 0 4.00 PACKER 168.4~ 0 0 0 0 0 0 0 4.28 MILLOUT EXT 169 0 0 0 0 0 .08 .33 3.61 Deposits. 100 Pipe Tabulations page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Well: NCIU ^-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA Survey Date: May 12, 2002 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage Profile No. Upset Bd@Up Body Loss Cplng Body ID Comments (% wall) inches inches inches % % inches inches inches 170 0 0 0 0 0' .07 .14 3.78 Lt. Deposits. -- 171 0 0 0 0 0 .15 .31 3.61 Deposits..._ 172 0 0 0 0 0 .07 .12 3.81 Lt. Deposits. 173 0 0 0 0 0 .07 .08 3.85 Lt. Deposits. 174 0 0 0 0 0 .09 .19 3.75 Lt. Deposits. 175 0 0 0 0 0 .10 .15 3.79 Lt. Deposits. 176 0 0 0 0 0 .06 .07 3.86 Lt. Deposits. 177 0 0 .01 3 0 .07 .08 3.86 Lt. Deposits. 178 0 0 0 0 0 .05 .07 3.85 Lt. Deposits. 179 0 0 0 0 0 .08 .07 3.85 Lt. Deposits. __ 180 0 0 0 0 0 .09 .08 3.85 Lt. Deposits. 181 0 0 0 0 0 .08 .14 3.78 Lt. Deposits. 182 0 0 0 0 0 .12 .28 3.65 Deposits. 183 0 0 .02 8 0 .06 .07 3.84 Lt. Deposits. 184 0 0 0 0 0 .18 .19 3.73 Lt. Deposits. 185 0 .04 .09 35 3 .42 .40 3.48 Corrosion. Deposits. 186' 0 0 .05 18 I .28 .49 3.35 Shallow corrosion. Deposits. ~1· 187 0 0 0 0 0 .11 .29 3.63 Deposits. 787.1 0 I 0 0 0 0 0 0 3.81 SLDNG SLV (Open) 188 0t 0 0 0 0 .17 .13 3.77 Lt. Deposits. 189 0 0 .03 10 0 .11 .12 3.79 Lt. Deposits. [] 190 0 0 .03 10 0 .08 .09 3.83 Lt. Deposits. [] 191 0 0 0 0 0 .07 .08 3.82 Lt. Deposits. 192 0 0 .00 1 0 .07 .08 3.81 Lt. Deposits. 193 0 0 0 0 0 .08 .09 3.82 Lt. Deposits. 194 0 0 0 0 0 .09 .12 3.77 Lt. Deposits. 195 0 0 0 0 0 .10 .13 3.78 Lt. Deposits. 196 0 0 0 0 0 .11 .10 3.80 LL Deposits. 197 0 0 0 0 0 .09 t .09 3.81 Lt. Deposits. _ _ Damage classification scheme Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 65% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference. General - damage depth range exceeds 1 * pipe IDand/or extends more than 20% of circumference. Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.333 feet. Pipe Tabulations page 2 I ] I I } ! ! i I I } I ! i I i I ] PDS Report Cross Sections Well: NCIU A-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA Tubing: 4.5 ins 12.6 ppf J-55 Survey Date: May 12, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint Tool speed -- 52 Nominal ID -- 3.958 Nominal OD-- 4.500 Remaining wall area = 99 % Tool deviation = 81 ° 155 at depth 4734.84 ft ? / Finger 28 Penetration = 0.108 ins Corrosion 0.11 ins: 40% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ! ! i I I ! ! ! I I ] i ~ I I ! } I I PDS Report Cross Sections Well: NCIU A-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA Tubing: 4.5 ins 12.6 ppf J-55 Survey Date: May 12, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint 161 Tool speed -- 142 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area -- 99 % Tool deviation = 31 ° at depth 4964.48 ft Finger 9 Penetration -- 0.099 ins Corrosion 0.10 ins = 37% Wall Penetration HIGH SIDE-- UP Cross Sections page 2 } ! ! ! ! ! ! I } ! ! ! ) ! I ! } } ! PDS Report Cross Sections Well: NCIU A-5 Field: North Cook Inlet Unit Company: PHILLIPS Country: USA Tubing: 4.5 ins 12.6 ppf J-55 Survey Date: May 12, 2002 Tool Type: MFC40 No. 00432 Tool Size: 2.75 No. of Fingers: 40 Analyst: M. Lawrence Cross Section for Joint Tool speed = 57 Nominal ID -- 3.958 Nominal OD -- 4.500 Remaining wall area = 100 % Tool deviation -- 66 ° 165 at depth 5095.75 ft Finger 31 Projection :-0.456 ins Deposits Minimum I.D. = 3.34 HIGH SIDE = UP Cross Sections page 3 I I I ! I ! I I I I I I ! I I I I ! ! PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset-- 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 143 4305.02 27,07 3.958 3.881 3.958 4.500 143.1 4332.09 8.03 3.850 3.850 3.850 4.500 )bt 143.2 4340.12 7.97 4.000 4.000 4.000 4.500 )acker 144 4348.09 29.98 3.958 3.831 3.958 4.500 -- 144.1 4378.07 2.30 3.813 3.813 3.813 4.500 x nip. 145 4380.37 28.96 3.958 3.862 3.958 4.500 146 4409.33 33.70 3.958 3.932 3.958 4.500 -- 147 4443.03._~ 28.54 3.958 3.889 3.958 4.500 148 4471.57 37.18 3.958 3.915 3.958 4.500 149 4508.75 19.84 3.958 3.923 3.958 4.500 150 4528.59 34.54 3.958 3.940 3.958 4.500 151 4563.13 29.65 3.958 3.858 3.958 4.500 152 4592.78 35.51 3.958 3.874 3.958 4.500 153 4628.29 31.90 3.958 3.908 3.958 4.500 153.1 4660.19 6.89 3.813 3.813 3.813 4.500 _sldn~slv_ 154 4667.08 28.44 3.958 3.811 3.958 4.500 154.1- 4695.52 4.52 3.930 3.930 3.930 4.500 no go seal 154.2 47'00.04 2.29 4.000 --4.000 4.000 4.500- )acker 154.3 4702.33 - 6--~1 4.27-i--~- 4.276 4.276- 4.500 millout ext-- 155 4708.44 28.97 3.958 3.822 3.958 4.500 156 4737.41 35.63 3.958 3.864 3.958 4.500 157 4773.04 25.76 3.958__. 3.901 3.958 i 4.500- 157.1 4798.80 3.09 3.930 3.930 3.930 4.500 ~no go seal- 157.2 4801.89 5,09 4.000 4.000 4.000 4.500 ~acker 157.3 4806.98 10.65 4.276 4.276 4.276 4.500 ~illout ext 158 4817.63 26.39 3.958 3.901 3.958 4.500 158.1 4844.02 9.59 3.958 3.927 3.958 4.500 ~up 158.2 4853.61 7.84 3.958 3.933 3.958 4.500 ~up 158.3 4861.45 6.30 3.813 3.813 3.813 4.500 ~ldng sly 158.4 4867.75 2.02 3.93~-- 3.930 3.930 4.500 mo go seal 158.5 4869.77 2.18 4.000 4.000 4.000 4.500 )acker 158.6 4871.95 5.56 4.276 4.276 4.276 4.500 ~niliout ext 159 4877.51 31.81 3.958 3.852 3.958 4.500 160 4909.32 31.90 3.958 3.814 3.958 4.500 j161 4941.22 30.49 3.958 ~__ 3.765 3.958 4.500 Well: Field: Company: Country: Survey Date: NCIU A-5 North Cook Inlet Unit PHILLIPS USA May 12, 2002 Joint Depth Length Modal Mean Nominal Nominal Type No. ID ID ID OD feet feet inches inches inches inches 161.1 4971.71 2.33 3.930 3.930 3.930 4.500 no go seal 161.2 4974.04 3.61 4.000 4.000 4.000 4.500 ~acker 161.3 4977.65 8.30 4.276 4.276 4.276 4.500 mi,out ext 162 4985.95 29.52 3.958 3.834 3.958[ 4.500 163 5015.47 31.59 3.958 3.858 --3.958'--"-L- 4.509 164 5047.06 33.24 3.958 3.829 3.958 4.500 -- 165 5080.30 23.76 3.958 3.828 3.958 4.500 166 5104.06 34.89 3.958 3.906 3.958 4.500 167 5138.95 30.90 3.958 3.924 3.958 4.500 168 5169.85 30.47 3.958 3.933 3.958 4.500 168.1 5200.32 2.31 3.813 3.813 3.813 4.500 ~ldng_s_l..v____ 168.2 5202.63 3.65 3.930 3.930 3.930 4.500 no go seal 168.3 5206.28 2.63 4.000 4.000 4.000 4.500 )acker 168.4 5208.91 9.17 4.276 4.276 4.276 4.500 rnillout ext 169 5218.08 33.14 3.958 3.894 3.958 4.500 170 5251.22 28.59 3.958 3.915 3.958 4.500 171 5279.81 29.00 3.958 3.902 3.958 4.500 _1_-~_'-' 5308.81 34.69 3.958 ......... 3.907 ...... -3.958 4.500 173 5343.50 31.24 3.958 3.919 3.958 4.500 174 5374.74 29.~9 3.958 3.914 3.958 4.500 175 5404.43 29.54 3.958 3.901 3.958 4.500 -- 176 5433,97 33.88 3.958 3.915 3.958 4.500 -- 177 5467.85 31.50 3.958 3.915 3.958 4.500 -- 178 5499.35 31.01 3.958 3.911 3.958 4.500 179 5530.36 30.68 3.958 3.920 3.958 4.500 180 5561.04 32.83 3.958 3.917 3.958 4.500 181 5593.87 30.61 3.958 3.916 3.958 4.500 182 5624.48 28.61 3.958 3.903 3.958 4.500 -- 183 5653.09 34.40 3.958 3.915 3.958 4.500 184 5687.49 34.06 3.958 3.898 3.958 4.500 185 5721.55 33.03 3.958 3.877 3.958 4.500 186 5754.58 19.83 3.958 3.820 3.958 4.500 187 5774.41 35.80 3.958 3.904 3.958 4.500 187.1 j 5810.21 6.36 3.813 3.813 3.813 4.500 ~ldng sly -~88t 5816.57 32.31 3.958 3.875 3.958 4.500 __ Joint Tally page 1 ! I I ! ! ! ! ! PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf J-55 Wall thickness: Body = 0.271 ins Upset-- 0.271 ins Nominal ID: 3.958 ins 5'~-i'i~F-J Type _~.5g_o_[_ ............. 4.500 J_ _4.500_4 4.50g_J,- _4.5004 Well: Field: Company: Country: Survey Date: NCIU A-5 North Cook Inlet Unit PHILLIPS USA May 12, 2002 Joint Tally page 2 STATE OF ALASKA : ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS. 1. Operations performed: Operation Shutdown__ Pull Tubing =X= 2. Name of Operator: Phillips Petroleum Co. 3. Address: P.O. Box 1967 Houston, Texas 77251-1967 4. Location of well at surface: 1253' FNL & 1091' FWL At top of productive interval: 160' FSL & 1550' FWL At effective depth: 160' FSL & 1550' FWL At total depth: 1872' FSL & 1886' FWL Alter Casin, Stimulate~ Plugging ~ Repair Well 5. Type of Well Development X Exploratory Stratigraphic Service Leg 3, Slot 6 PPCo. Tyonek Platform Perforate X Other 6. Datum elevation (DF or RKB) RKB 116 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number Sec6-T11N-R9W 4450' MD Sec 31 - T12N - R9W 4450' MD Sec 31 - T12N - R9W 6760' MD Sec 31 - T12N- R9W North Cooklnlet, Ak. 3880' TVD 3880' TVD 5736' TVD A-05 9. Permit Number / Approval Number 69-32 94-235 ' 10. APl Number 50-283-20025 11. Field / Pool Cook Inlet / Beluga 12. Present well condition summary: Total Depth: measured true vertical Effective Depth: measured true vertical 6,760 feet Plugs (measUred) PBTD 6,760' 5,736 feet 4,450 feet 3,880 feet Junk (measured) ORIGINAL Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30 " Driven 385 385 10 3/4" 765 sx CI "G" 2,571 2,373 7" 1352 sx CI"G 8,097 6,856 Perforation Depth: measured 4450' - 7536' true vertical 3880' - 6381' Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) 4 1/2" 12.6 Ib/ft J-55 Mod-BT&C Tubing 39 - 305' 4 1/2" 12.75 Ib/ft J-55 Mod 8rd Tubing 305 - 6452' Halliburton "XXO" SVLN at 271', Halliburton "VSR" packer at 4342' Halliburton "TWR" packers at 4700', 4800', 4869' 4~ F~3~ ,~ I" r~ 13. Stimulation or cement squeeze summary: Intervals treated (measured): JAN 2 7 1995 Treatment description including volumes used and final pressure: ' A!as~ Dil & Gas Cons. C0mmis -,-L Anchor -' 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Prior to well operation: 0 8000 Water-Bbl Casing Pressure Tubing Pressure 49.82 165 922 06/12/94 Subsequent to operation 0 15. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations X 14400 7.84 280 966 12/03/94 16. Status of Well Classification as: Oil Gas X Suspended Service 15. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed ~' d 2~ Title Principle Engineer Form 10-404 Rev. 06/15/88 Date 19-Jan-95 SUBMIT IN DUPLICATE PHILLIPS PETROLEUM DAILY REPORT SUMMARY PAGE: 1 WELLtNorth Cook Inlet Unit No. a-$ FIELD:COOK INLET NORTH CNTY/STATE:TYONEK OFFSHORE/ALASKA RIG:Pool Arctic Alaska/Pool Arctic Alaska AFE$:P-V194 AUTH COST:$1,339,800 DATE DEPTH RPT NO leg OPERATIONS SUGARY DAILY COST CUId COST 08/01/94 8,097 1 8.6 SKID RIG OVER NCIU A-5.R/U UTILITIES.SHUT IN NELL.BLEED & $8,7~0 S8,720 BLIND ALL LINES.R/U & TEST LUBRICATOR.PREPARE TO PUHP KILL FLUID. ~8/02/94 8,097 2 8.6 KILL NELL/PULL SSSV '& SET PLUG/SET BPV/ND TREE/gU BOPS & S36,603 ' $45,323 RISERS. INITIAL BOP TEST.R/U TO PULL PLUG. ~8/03/94 8,097 3 '8.6 RU WL PULL PLUG/ATTEMPT PULL TBG. STUCK/RU gL RUN FREE PT $44,966 $90,289 CHEMICAL CUT TBG~659/goRK FREE/CBU/POOH LAYING DOWN TUBING 08/0~/94 8,097 4 8.~ TIH W/WASHPIPE/WASHOVER 4659-4687/CBU/POOH/TIH W/OVERSHOT/ $48,285 $138,574 dAR ON FISH WITH NO SUCCESS/POOH/RIH & gASHOVER PACKER/CHASE PACKER TO 5336'/ClRC HIGH VISC SUEEP (~8/05/94 8,097 '5 8.6 POOH WITH WASHOVER ASSEMBLY/MAKE UNSUCCESSFUL OVERSHOT RUN/ $48,440 $187,0~3 ...... RIH & DRESS OFF TOP OF FISH/POOH WITH FISH-FULL RECOVERY/ BIT & SCRAPER RUN/gASH & REAH SAW 08/06/94 8,097 6 8.5 FINISHED REAHING SAND FROM HOLE/CIRCULATED HOLE CLEAN/POOH/ S39,929 $226,942 RIH WITH BELUGA GUNS & TEST TOOLS/CORRELATE GUNS IN PLACE WITH SCHLUHBERGER/RU TEST TREE & LINES.TO TEST SEPERATOR 08/07/94 8,097 7 8.5 PERFORATE & SURGE BELUGA ZONES/KILL WELL/POOH/BIT & SCRAPER/ $38,851 $265,793 RIH WITH GUNS & TEST TOOLS TO PERFORATE COOK INLET/CORRELATE WITH SCHLUNBERGER/NU TEST TREE & LINES/PERFORATE COOK INLET §~/08/94 8,097 " ~ 8.5 FINISHED SURGING COOK INLET AFTER PERFORATING/KILLED WELL/ $280,892 " 'S546,685 CIRC/POOH WITH GUNS/BIT & SCRAPER RUN/ClRC OUT GAS/POOH/ gU DST ASSEMBLY #1/JET WELL IN W/NITROGEN ~8/09/94 8,097 9 8.5 FINISHED FLOWING BELUGA FOR CLEAN UP/KILLED 1dELL/CIRCULATED S55,596 $602,280 OUT GAS/POOH/TEST BOP'S/ 08/10/94 8,097 10 8.5 BOP TEST/BIT & SCRAPER RUN/ISOLATED BELUGA WITH EZSV/POOH/ $61,267 S663,547 RIH WITH DST #2/TEST COOK INLET # 11/PULL PACKER UP HOLE AND TEST COOK INLET # lO/PULL UP HOLE & TEST COOK INLET # 8 08/11/94 8,097 11 8.5 DRILL STEM TESTED COOK INLET 7, 8, 10, & 11/SET EZSV ABOVE S51,509 S715,056 Cl # 7/BEGAN TESTING COOK INLET # 6 08/12/94 08/13/94 ~/14/94 8,097 12 8.5 ABORTED TEST ON COOK INLET #6/POOH/DRILL OUT EZSV'S/MAKE $67,269 $782,324 SCRAPER RuN/POOH 8,097 13 8.5 ISOLATE LC~ER BELUGA PERFS WITH EZSV/RIH WITH DST ASSEMBLY S32,449 S814,r?3 & JET IN WITH NITROGEN & RETEST BELUGA PERFS/ . 8,097 14 8.6 FINISHED W/DST # 9/KILLED WELL/POOH/BIT & SCRAPER RUN/gU & $99,4~8 $914,210 RIH WITH PERMANENT PACKER ASSEMBLY # I & # 2 08/15/94 08/16/94 58/17/94 8,097 15 8.5 CONTINUE WITH COHPLETION BY SETTING PACKER ASSEMBLIES # 3, S32,316 $946,526 # 4, # 5, & # 6/CONTINUE PU & RIH WITH PROOUCTION TUBING/ 8,097 16 8.5 FINISHED RUNNING COMPLETION/PUMPED PACKER FLUID/ND BOP'S/NU 'S235,192 $1,181,718 TREE & FLO~LINE & TEST/RU RISER & COIL TUBING/KICK OFF ~ELL (BELUGA) FOR PROOUCTION 8,097 17 8.5 FLC)WlNG WELL FOR CLEANUP BEFORE TURNING INTO PRODUCTION. S142,399 $1,324,117 08/18/94 8,097 18 8.5 FLCR/ WELL FOR CLEANUP BEFORE TURNING OVER TO PRODUCTION. $37,88~ Sl,362,001 TURN NELL OVER TO PRODUCTION AND PREPARE TO SKID RIG. 10/30/94 8,097 19 8.5 TIH W/GUAGE RING & SHIFTING TOOL CHECKING SLEEVES. ALL $2,.100 $1,36~,101 SLEEVES gERE IN CORRECT POSITION. BELUGA ZONE PROOUCING. TURN NELL TO PROOUCTION FLC~ING. DAYSUM.RP1 12/07/94 RECEIVED dAN 2 ? 19B5 Ataska Oil & Gas Cons. Commission Anchor[ ~ ,., Dd~ l!ucl lOlUI ~lOOD :pp!,4 e~l~lV 'lOlUI ~tooD ~omO~l :uo!leooq P~I 'TI ~qmo*oN ] ~0-V 'oN )!u~ l~lUI ~oo~ quoN :IP~ ....~'f wql ~L'~[ ~ 9'~T - ,,~/[ P :1~ S~[ poppe oq ~ ~ ~Z - ggGz GS~ - O~ ~ ~ j O~Z - G~Z t~Z9 - 60Z9  ,JeMO3,, ~L~'  6gzg - Pgzg - Egzg - Egzg 0~9 - OEES ,jeddR. pelm~ed-ea ~ o~ 3ON ~le~ ~ed EgEg - Z~g 9 ~6~ - ~g~ Z-lO ~g ' ~ ~g E~ - E~ g-lO ~9 ' ~9 9gZ~ ' 0~ g-lO ~Z~9 - ~9~9 ~gP ' ~g~ grid ('m°O G~S YO~8 SU~S ~3q~ ~00~ &lq~ g~%Jo PU3 ~1'~9 [ 0~S'~ ~'~ olddlN ,,~ .... ~/l P u~qHl~H 6VI 68'6~P9 00~'~ ~'E ~qn& QO~- ~H g~-r ql ~'~[ ,,~/[ ~ ~VE6g ~'~ 9 ~gg'g 996'~ ~old~v ~qn& ql ~'~[ .~/[ ~ 09'0 ~9'E~ 000'~ 9fZT uo!~ 3no[l!~ gV9 6I'~I~ g~8'~ 000't ~o~OSd ~& uo~nqHleH ql 9~ ,,f 6['~ 00'El~g ,, 0%'g 0E6'~ ~lq~ leOS °D ON ~9'~ gg'II~g 0I 00g't ~'~ ~u!qn& QO~- ~ gg-r q[ gL'~I .~/[ ~ I0'0~ ~%'g 996'E zold~v ~qn& ql g~'~I .~/[ ~ 09'0 ~0'~g6~ 000'~ 9fg't uo!~H 3noll~ Eg'9 l~'0g6~ gfg'~ 000'~ ~R~d ~ u~qHlsH q[ 9~ ,,~ 6['~ 09~'g 0E6'E ~lq~ leOS °D oN ~9'~ 0~'g~6~ 9I 00~'t ~'E ~qn& QO~- RH ~-{ q[ gU~[ ,,~/[ ~ ~I'~6 000'~ 9f~'~ uo!~ 3nolH~ 1~'9 0%'~ 0E6'E ~lq~ leOS OD ON ~9'~ 00g't ~'E '~ d~ ~ ql gf'~I ,,~/[ ~ ~I'9 00g'~ ~'~ '3r d~ ~ q[ ~'~1 ,,~/[ ~!~ g0'g 6I'0~g~ ~%'g 996'~ ~3d~v g~qn& ql ~'~I .~/I ~ 09'0 ~'glg~ 000'g 9f~'~ uo!~ lnol[~ gE'~ ~6'0Ig~ ~8'~ 000't ~R°Sd ~& u°~qHleH q[ 9~ ,,~ 6I'~ 0%'g 0E6'E ~lq~ leOS OD ON ~9'~ Ig'g08~ 6~ ~9S'~ 9~6'~ z~d~v ~qn& q[ g~'~I ,,~/[ ~ I9'0 000'g 9~'~ uo!~H InolH~ 8V9 ~'~0~ 09g'g 0~6'E ~lq~ lSOS OD ON ~9'~ ~'~9~ .... 09g'g ~Ig'~ oAOOlS ~ ,,~/I ~ uo~qHISH E~'~ 00g'~ ~'~ ~qu& QO~- ~H gg-f q[ ~'~[ ,,~/[ ~ 9VIE gfg'~ 000'~ ~Ogd ~SA u~qHlgH q[ 9~ ,,~ 8~'9 , 8g~'g ~I8'~ N~S O~ u~qHleH gp'~ ~6'0Lg ~H ~qn% 0~'0 0V6~ aoDeAOl~ 0t'6E 00'0 8t I I I :guile ~ulqn~ ~E 080~ 099~ D~8 ~g-f Wql 9~ ~60'g ~ZI'~ ,, g8~ 080~ 08~ D~ gg-f wq[ ~ L~I'L 6L . L L~ 08~ 09~ D~&~ gg-f Wql 9E 6L 6E . L 0~H Wql g9 ~P9 IP .9I gee 1~ ,, Og ,, :gUl~ UOl~np~d ~'glI : ~ IOUgqlam Iqq ¢ ql~ aam~ 3~ :p!nl~ mlnu~ , ,og/_g GJ. Bd g£gz - g~gL ~ 0 I. I./. - g60/. ~ ~gO/. ' t~:Ol ~ 6glo ' Vg/.9 ~ ~9L9 ' ~9Lg ~ Gg99 - 0999 ~ ,gl. gg ~ dSlO spues e§nleE! ,Cg~:g I~ Je)loed L-lO 90~g ' 96 gg Og'lO l~gg ' 6~,Lg ~ ~'10 ~gOg - ~:POg ~Z6~)Je~oed /.-lO GL6P - 06gV ~ ,69gv 0 JmlOed g-lO ~ - ~ggg' ~ ,g0gt t~ Je~toed 9-10 ggzP ' OZ./.V spue~®lUlHOOO Je~loed ~SA oo~v~OH CC: ~ PHII. LIpS PET*ROLE NORTH AMERICA EXPLORATION AND PRODucTION COMPANy BELLAiRE TEXA 6330 WEST LOr~.,'~_ S LL)ING ORIGINAL Alaska Oil & Gas C . 3001 Porc ,~; .... °nservatlon Commission AnchorageU,''''~ Unve Alaska 99501 August 18, 1994 North Cook Inlet U . Phillips , ...... nit A-0 - A, . Tyu,eK Pla.~__ . 5 -orth Cook Inlet, ~;a°sr~a A" Re: North Cook Inlet Unit A-5 Workover Program Enclosed are three copies of t · co.pies of the pro o he revise . . ynlt. The revisi~_sed Wellbore S d.Ap_Phcation . p~ rOduction ;,.,_ ~, requested a c..hematic for the f_o. r Sundry A _ . n d'o~:Over . PProval Workov Pproval~ andle exces * _ ed Whlle Dri _ to Setaci __ er of the ~ n~ · form l O-4no . Water' .s..ive amOun II.Stem Tes · B_P at ~,61 · .: -,-va Well o I.n_the future · .._ ts of Produc...~ .. ting the Belu~- - 8 (W, thout ~._ n the North p,.,. , r..~ the CIBp u _ , it.,a antici "" water at t _ ~ rormatio . _"~,-ent) to is """~ inlet interval _ "n. cemente(/ w;,, _.?ated that incr,=o~he present tir,- ,).n.: The platforr, :_ o/ate the war,, -., an(/recover ~^ '_" altow a relati~,,.-."°~u Water ha ;.~'.~- vvnen the w '"_~a.not equi '~' "'~ gas res,, .... -~'¥ Strai . n.dhng equi e..!ls begin t PPed to ---~,a at tha ,;~._ghtforwar(/w ~_..pment Will be r ~,..-~ m. ake more t -,-e. or/(uver n ,~ _ e,~u~reo to '~-open the If You have any questions COncerning this Workover ,,,wer Beluga Paul R. Dean at (713) 669-3502. or need any additional information please contact V. Ft. Chamberlain (~ M. L. Jones (r) p . J.F. Mitchell · R Dean Central files R~g~rds, D. C. Gill, Manager Drilling and Production Engineering RECEIVED AU(; 2 6 1994 Alaska 0il & Gas Cons. Commission Anchorage ~' ~STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation Shutdown Alter Casing .__Repair Well Plugging .~ Time Extension Chan~e Approved pro,ram X Pull Tubin~l Variance 2. Name of Operator: I 5. Type of Well Phillips Petroleum Co. I Development X 3. Address: Exploraton/ 6330 W. Loop South Stratigraphic Bellairer Texas 77401 Service 4. Location of well at surface: Leg 3, Slot 6 PPCo. Tyonek Platform 1253' FNL & 1091' FWL Sec 6 - T11N - R9W North Cook Inlet, Ak. At top of productive interval: 4450' MD 3880' TVD 160' FSL & 1550' FWL Sec 31 - T12N - R9W At effective depth: 4450' MD 3880' TVD 160' FSL & 1550' FWL Sec 31 - T12N - R9W Attotal depth: 8124' MD 6879' TVD 2524' FSL & 2243' FWL Sec 31 - T12N - R9W 12. Present well condition summary: Total Depth: Plugs (measured) measured 8,124 feet true vertical 6,879 feet Reenter Suspended Well ~ Stimulate Perforate Other (add perfs! 6. Datum elevation (DF or RKB) RKB 116 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number A-05 9. Permit Number / Approval Number 69 -32 94 - 144 10. APl Number 50-283-20025 11. Field / Pool Cook Inlet/Beluga Set ClBP at 6618' to shut off water production from lower Beluga intervals Effective Depth: measured 4,450 feet Junk (measured) true vertical 3,880 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth True Vertical Depth 30" Driven 385 385 10 3/4" 765 sx CI "G" 2,571 2,373 7" 1352 sx CI "G" ..o,, RE( EIVE.D Perforation Depth: measured 4450'-7536, 2 G 1994 true vertical 3880' - 6381' Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade and measured depth) 4" 10.9 Ib/ft J-55 BT&C & 3 1/2" 9.2 Ib/ff J-55 BT&C set at 4,721' Packers and SSSV ( type and measured depth) Otis "RH" retr. packer @ 4,404'; Otis "WB" permanent packer @ 4687'. Otis Wireline Retrievable SSSV ~ 285.58'. 13. Attachments: Description Summary of Proposal __ Detailed Operations Program m BOP Sketch __ 14. Estimated Date for Commencing Operations: 16. If PropOsal waS Verbally Approved: Oil Gas __ R. Crandall August 10, 1994 Name of Approver Date Approved Service 17.1 hereby ca,art, he f~ true and correct to the best of my knowledge: Signed,,,~'"~~ D.C.. Gill Title Drlcj. & Prod. Encjr. Manacjer FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so Representative may witness Plug Integrity BOP Test Location Clearance Mechanical IntegrityTest Subsequent Form Required 10 - ~0~ 15. Status of Well Classification as: Suspendedm IApproval No ..... Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By David W. Johnston Commissioner Date SUBMIT IN TRIPLI(~ATE' Approved Copy Returned PBTD 8059' TD 385 643 10 3/4" @ 2571 TOC @ 2612 Howco VSR packer Cook Inle~ Sands 4450 - 4515 C1-1 4535 - 4810 Cl-2 4830 - 4650 Cl-3 Packer @ 4702' 4770 - 4785 CI-5 Packer @ 4805' 4832 - 4862 CI-6 Packer @ 4871' 4896 - 4915 CI-7 Packer @ 4984' 5042 - 5052 CI-8 5129 - 5144 C1-10 5196 - 52O6 C1-11 Packer @ 5210' Beluga Sands 5220 - 5230 *~5357 - 5361 **5454 - 5456 *~-o479 - 5483 5561 - 5571 5709 - 5714 5773 - 5778 5782 - 5792 6111 - 6116 6163 - 6173 6180 - 6190 6196 - 6206 6267 - 5282 6346 - 6356 ClBP @ 6618' 6680-6685 6752 - 6752 6784 - 6789 7024 - 7032 7095 - 7110 7286 - 7296 7316 - 7321 7374 - 7384 7526 - 7536 7' @ 8097' PROPOSED WELL COMPL' ~N DIAGRAM ~ ..... e OD' FMC OCT I R~B-Drill Deck: Annulus FlUid: salt water with 3 bbl methanol [ RKB-SL: 116.00 TOC: 2612' from CBL dated 05/06/69 WATER DEPTH: 120[ RKB-ML: Production Casing: "I 41 2,571 [ 45.5 & 51 lb/lq 3-55 BT&C 3350 1970 531 39 79 [ 26 lb/ft / J-55 BT&C 4660 4O80 1 327. 79 7,1271 23 lb/ft [ J-55 BT&C 4080 3080 288 " 7,127 8~097 [ 26 lb/ft / J-55 BT&C 4660 4080 327. . Tubing String: . 4 1/2. I 39 1 310 1 12.6 lb/ft J-55 Mod BT&CI 4730 1 4980 1 134 41/2 [3,01 7,540112.751b/ft J-SS ModSrd[ 47301 4980[ 134 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~i.~iii!~!~!:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ?RODUCTION TUBING STRING -0.00 40.23 Elevation 40,23 2.00 250.27 325.00 292.50 2.50 295.00 30.00 2.00 327.00 4327.00 1.00 4328.00 30.00 4358.00 3.00 4361.00 7.00 4368.00 30.00 4398.00 1.00 4399,00 270.00 4669.00 4672.00 30.00 4702.00 10.00 4712.00 90.00 4802.00 3.00 4805.00 4815.00 4865.00 4871.00 4981.00 4984.00 4994.00 5207.00 5210.00 5220.00 5796.00 5800.00 .6{~$.00 6450.00 10.00 50.00 10.00 100.00 10.00 210.00 10.00 576.00 648.00 FMC / OCT 6" 3M 4 1/2" 8rd x 4" BT&C Tubing Hat 4 1/2" 12.6 ib/ft J-55 Mod BT&C Tubing Halliburton 4 1/2" WLRSV Safety Valve Nipple 4 1/2" 12.6 lb/ft J-55 Mod BT&C Tubing 4 1/2" BT&C x 4 1/2" EUE X-OVER 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "X" Nipple 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton Ratch-Latch Seal Unit Halliburton VSR packer & tubing adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "X" Nipple ~ 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "XD" Sliding Sleeve 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton AWR Packer & Tubing Adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton "No-Go" Seal Unit Halliburton AWR Packer & Tubing Adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "XD" Sliding Sleeve Halliburton "No-Go" Seal Unit Halliburton AWR Packer & Tubing Adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton "No-Go" Seal Unit Halliburton AWR Packer & Tubing Adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "XD" Sliding Sleeve Halliburton "No-Go" Seal Unit Halliburton AWR Packer & Tubing Adapter 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "XD" Sliding Sleeve 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing Halliburton 4 1/2" "XN" Nipple End of Tubing 3.958 3.958 2.992 3.958 3.958 3.958 3.813 3.958 3.958 3.880 3.958 3.813 3.958 3.813 3.958 3.958 3.900 4.00 3.958 3.813 3.900 4.~ 3.958 3.958 3.813 3.958 3.813 3.958 3.725 PRODUCTION PERFORATION INTERVALS COOK INLET SANDS BELUGA SAND (cont.) 'Middle' C1-1 4450 - 4515 8000 - 6010 CI-2 4535 - 4810 6111 - 6116 CI-3 4&30 - 4650 6163 - 6173 CI-5 4770 - 4785 6180 - 6190 C1-6 4832 - 4862 6196 - 6206 CI-7 4890 - 4915 6287 - 6282 CI-8 5042 - 5052 6346 - 8356 C1-10 5129 - 5144 6435 - 8445 C1-11 5196 - 5206 8680 - 8885 BELUGA SAND Reds Below Not To Be Re-Perforated 'Upper' 6752 - 6762 ECEIYED .,, .,- 5220-5230 5357 - 5361 - 5454 - 5456 5478-5483 /~UG 6991-7001 5561-5571 2 6 1994''°w'r' 5709 - 5714 7095 - 7110 7288 - 7296 5782~;73 _- 57~n~ Alaska 0JJ &..Gas Cons. Cor/iffij$sjorl 7318 - 7321 5626 - ~ ~ncnora~le 7374 - 7384 5840 - 5855 7528 - 7536 5922 - 5932 NOTE: ** denotes new perforations to be added PBTD: 8,059' [ Supv: Well: North Cook Inlet Unit No. A-05 Location: Lower Cook Inleh Alaska ]Tbg Wt: 4 1/2" - 12.6 & 12.75 Ib/ft J-55 July 28, 1994 Field: Cook Inlet Unit PRD,, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' David J~ Chairma. l~ Blair Wondzell, ~ P. I. Supervisor e/~lt~. FROM: Bobby Foste~'~' SUBJECT: Petroleum Inspector DATE: August 9, 1994 FILE NO: AX81HIBD.doc BOPE Test - PooI-Artic 429 Phillips - NCI - A-5 PTD # 69-0032- 94-144. Tyonek Platform Monday, Au.qust 8,. 1.. 994:. I traveled this date to Phillip's Tyonek Platform and stood by to witness the upcoming BOPE Test. Tuesday, August 9,1994: The testing of the choke manifold began at 1:45AM and was concluded at 2:30AM and no failures were found. The Stack test begeo at 3:30AM and was concluded at 5:15AM and no failures were found. The rig was very clean and all equipment seemed to be in good working order. The platform was clean and excess equipment, due to the rig working over the well, was arranged in a very orderly manner on the deck and in the well room. Summary: i witnessed the BOPE test o Pool rig 429 working over Phillips Petroleum's Tyonek Platform well A-5 - Test time 2.5 hours - no failures. Attachment: AX81HIBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Workover: X Approval # 94-0144 Pool - Attic Rig No. 429 PTD # Phillips -Petroleum Rep.: A-5 Rig Rep.: Set @ 8097' Location: Sec. . 69-0032 DATE: 8/9/94 Rig Ph.# 776-6074 Marc Babineaux Darrell Green 6 T. 11N R. 9E Meridian S Test: Initial ~ Weekly X Other Test MISC. INSPECTIONS: Quan. Pressure Location Gen,: OK Well Sign OK I 300\3000 ...... Housekeeping: OK (Gen) Drl. Rig OK 1 Reserve Pit NV~ 1 1 BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves Check Valve Test Pressure 300\3000 300\3000 30O\300O 300\~000 300\3000 300~3000 2 300~000 FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly / IBOP Ball Type Inside BOP P/F P CHOKE MANIFOLD: P No. Valves 17 P No. Flanges 48 P Manual Chokes 1 P Hydraulic Chokes 2 'p P N~A MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X ,, Flow Indicator X X Gas Detectors X X 300~3000 300\3000 300\3000 P/F P P ,,, , P Test Pressure 300\3000 300\3000 P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2000 3,000 I P minutes 31 sec. ,,, minutes 58 sec. ye..s Remote: yes Psig. Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 daYs. Notify the Inspector and follow with Written or Faxed verification to Ithe AOGCC Commission Office at: Fax No. 276'7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test. Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Bobby D. Foster FI-021L (Rev. 7/19) AX81HIBD.XLS PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 EXPLORATION AND PRODUCTION GROUP COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING June 2, 1994 North Cook Inlet Unit "A-05" Phillips Tyonek Platform "A" North Cook Inlet, Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: North Cook Inlet Unit A-5 Workover Program Attached are three copies of the Application for Sundry Approvals, form 10-403, and three copies of the tentative workover program for the workover of the A-Q~'well on the North Cook Inlet Unit. Included in the program are the BOP schematic and the well control policy for the workover. If you have any questions concerning this workover or need any additional information please contact Paul R. Dean at (713) 669-3502. D. C. Gill, Manager Drilling and Production Engineering CC: A. R. Lyons M. L. Jones (r) P,~R. Dean J.F. Mitchell Central files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend,, Alter Casing Repair Well Pro ram Chan 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellairel Texas 77401 4. Location of well at surface: Leg 3, 1253' FNL & 1091' FWL Sec 6 - T11N - R9W At top of productive interval: 4450' MD 160' FSL & 1550' FWL Sec31 - T12N - R9W At effective depth: 4450' MD 160' FSL & 1550' FWL Sec 31 - T12N - R9W At total depth: 8124' MD 2524' FSL & 2243' FWL Sec 31 - T12N - R9W 12. Present well condition summary: Total Depth: Operation Shutdown.. Plugging Time Extension Pull Tubin Varianoe I5. Type of Well Development Exploratory Stratigraphic Service Slot 6 PPCo. Tyonek Platform North Cook Inlet, Ak. 3880' TVD 3880''1'VD 6879' 'I'VD measUred 8,124 feet Plugs (measured) true vertical 6,879 feet Effective Depth: measured 4,450 feet Junk (measured) true vertical 3,880 feet Casing: Structural Conductor Surface Intermediate Production Liner Length Size Cemented Measured Depth 30" Driven 385 Reenter Suspended Well Stimulate Perforate Other 6. Datum elevation (DF or RKB) RKB 116 7. Unit or Property Name North Cook Inlet Unit Feet 8. Well Number A-0 9. Permit Number / Approval Number 10. APl Number 50-283-20025 11. Field / Pool Cook Inlet/Beluga R ECEI ,' 'D ,JUN -6 uil & Gas Cons, 385 10 3/4" 765 sx CI "G" 2,571 2,373 7" 1352 sx CI "G" 8,097 6,856 Perforation Depth: measured 4450' - 7536' true vertical 3880'- 6381' Tubing (size, grade and measured depth) 4" 10.9 Ib/ft J-55 BT&C & 3 1/2" 9.2 Ib/ft J-55 BT&C set at 4,721' Packers and SSSV ( type and measured depth) Otis "RH" retr. packer @ 4,404'; Otis "WB" permanent packer @ 4687'. Otis Wireline Retrievable SSSV ~ 285.58'. 13. Attachments: Description SUmmary of Proposal ~ Detailed Operations Program __ BOP Sketch X~ 14. Estimated Date for Commencing Operations: June 27~ 1994 16. If Proposal was Verbally Approved: 15. Status of Well Classification as: Oil Gas X Suspended Name of Approver Date Approved Service 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge: Si~lned ~_~-~ D.C. Gill Title Drl~.&Prod. En~r. Manager Date FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so Representative may witness I Approv~al N.~o~. Plug Integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent Form Required 10 - Approved by Order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By Dayj{I W, .lnhn.~tnn Commissioner Date (-,~?/S ¥ Approved Copy SUBMIT IN TRIPLICATE Returned June 2, 1994 Houston, Texas North Cook Inlet Unit "A"-5 North Cook Inlet Unit Tyonek County, Alaska Tentative Procedure le · · · · · Skid rig over No. 5 slot in Leg 3. Kill well with 8.5 lb/gal KCl water / XanVis polymer. Fill tubing and annulus with 2 % kcl water. Bleed off pressures and monitor same. Close SSSV. Install BPV, remove XMAS tree, NU and test 13 5/8" 10M BOP equipment. Utilize a 16 3/4" 5M x 13 5/8" 10M DSA (FMC Unihead with 16 3/4" 5M BX Clamp Hub). Test the BOP equipment as per the attached "Well Control" program. Rig up to pull tubing. Release Otis "RH" packer (4,404'). -Pull 4" tubing, SSSV and retrievable packer with tailpipe and seal assembly from the "WB" packer at 4,687'. Circulate out any gas from below the packer. Inspect all tubulars for "NORM" contamination. TIH with packer milling assembly. Mill over packer slips and recover Otis "WB" permanent packer. POOH. TIH with 6 1/8" bit and casing scraper for 7" 23 and 26 lb/ft casing. Clean out casing to PBTD of 8059'. Circulate hole clean and POOH. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing and new Beluga Sands as follows: 5220' - 5230' ** 5357' - 5361' ** 5454' - 5456' ** 5479' - 5483' 5561' - 5571' 5709' - 5714' 5773' - 5778' 5782' - 5792' 5825' - 5835' 5840' - 5855' 5922' - 5932' 6001' - 6010' 6111' - 6116' 6163' - 6173' 6180' - 6190' ** 6196' - 6206' 6267' - 6282' 6346' - 6356' 6435' - 6445' 6680' - 6685' 6784' 6789' _ ** 7024' - 7032' 7095' - 7110' 7286' - 7296' 7316' - 7321' 7374' - 7384' 7526' - 7536' New perforations · Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. 8. Unload well and flow for initial clean-up. 9. Kill well and POOH with perforating assembly. 10. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well is stable. 11. If significant volumes of water and/or sand is produced during Step No. 8, TIH with DST tools and isolate intervals to check for water production. Squeeze any interval that indicates it is water productive. 12. Make up and TIH with tubing conveyed perforating assembly to reperforate the existing Cook Inlet Sands as follows: 4450' - 4515' 4535' - 4610' 4630' - 4650' 4770' - 4785' 4832' - 4862' 4890' - 4915' 5042' - 5052' 5129' - 5144' 5196' - 5206' 13. Use Gamma Ray log to correlate guns on depth. Set packer and pressure up on tubing with nitrogen to fire guns. 14. Unload well and flow for initial clean-up. 15. Kill well and POOH with perforating assembly. 16. TIH with bit and scraper and clean out well to PBTD. Circulate out gas until well is stable. 17. If significant volumes of water and/or sand is produced during Step No. 14, TIH with DST tools and isolate intervals to check for water production. Squeeze any interval that indicates it is water productive. 18. TIH with Halliburton 7" retrievable "VSR" packer with 4 1/2" tailpipe equipped as per the proposed wellbore schematic. Set packer at 4,350' with sliding sleeves at 4,417' and 6,000'. 19. Make up Halliburton packer seal assembly onto the 4 1/2" tubing. TIH with 4 1/2" tubing and SCSSV landing nipple. Land seal assembly into isolation packer. Test annulus, then pull out of seal assembly and circulate 70/30 methanol / KCl packer fluid into annulus. Space out tubing. 20. Close SCSSV, install BPV, ND BOP equipment and NU and test 7 1/16" x 4 1/2" Xmas Tree. Remove BPV's. 21. Use coiled tubing (if necessary) and nitrogen to lower fluid level and get well kicked off. Unload well and allow clean up through the production testing equipment. Release workover rig to next well. NOTE: BHP at 3880 TVD is approx 1400 psi (7.0 lb/gal equivalent), somewhat less than the 8.5 lb/gal equivalent which will be used to kill the well during the recompletic~5,\ ~~rVED ii - 6 1994 & Gas Cons. COrirlllil~JDff Anchorage , SECTION WELL CONTROL PROCEDURES This well is a category 3 well, as defined in Phillips Completion Workover and Well Control Policy. As such two barriers must be in place during nipple up and nipple down operations. For all other operations, two barriers, e.g. the BOP's, fluid column, etc. must be in place in order to conduct simultaneous operations. The BOP equipment is 10000 psi WP Class 4 as per Phillips Well Control manual. The bottom set of rams should be 5" pipe rams, the middle set will be blind rams and the top set should be variable rams. Although the BOP is rated to 10000 psi, the riser and the wellhead are rated to 5000 psi. The BOP and choke manifold should be stump tested to 3000 psi. The BOP should be tested to 3000 psi upon nipple up and to 1500 psi on a weekly basis. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early enough for them to witness the test if they desire. The maximum surface pressure for the well is 1080 psi. This pressure was obtained during the welltest of February 10, 1994. The well can be killed and stability maintained with 8.5 lb/gal fluid. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. This well produces from a series of very permeable sands. A small decrease in pressure at the perforations can result in very large flowrates. It is vital that good well control practices be followed during the course of this workover. Trip speed while POOH should be kept relatively slow to avoid any tendency to swab. Before any trip is made swab and surge calculations should be made based on the properties of the fluid in the hole. DO NOT exceed the running speed determined by the calculations. A detailed trip book comparing measured fill up requirements to the calculated requirements should be maintained for each trip. The cause for any discrepency between the actual and required fill up volume must be determined before continuing with the trip. ~AINTAINING CONTROL OF THE WELL IS OF THE UPMOST IMPORT~NCE, TRIP SPEED IS SECOND&RY. Three perforated intervals are isolated between the Otis "RH" retrievable and the "WD" permanent packer, and there are 31 different intervals below the "WD" that are effectively commingled at the present time and cannot be isolated. Ail of the zones presently perforated in this well can be killed with water. As a precautionary measure, a line should be ran from the annulus valves on the tubing head to supply workover fluid, drillwater, or seawater. This line can be used to supply workover fluid as discussed above or as a last resort can be used to kill the well with drillwater or seawater. Pumping drillwater or seawater through the annulus valves should be considered only in an emergency situation as these fluids could result in formation damage. RECEIVED UUN _ 6 ~las~ ~ &~C~or~. .~s Cons. Co~mission NCIU A-"7 RISER AND BOP ARRANGEMENT ! I 6M ANNULAR PREVENTER 1OM VARIABLE BORE PIPE RAMS 1OM BLIND RAMS DRILLING SPOOL 3 1/2' 1OM PIPE RAMS RISER 13 6/8' 'IOM X 13 6/8' 6M ADAPTER 13 6/8' 6M X 16 3/4' 6M CLAMP RISER 16 3/4" 6M X 16 3/4' 6M i UNIHEAD 16' 8RD X 16 3/4' 6M CLAMP HUB J PBTD 8O59' 10 3/4' ~D 2571 TOC @ 2612 Otis RH packer @ 4404' 4450 - 4515 4535 - 4510 4630 - 4650 Otis WB packer @ 4687' Cook Inlet Sands 4770 - 4785 4632 - 4562 4890 - 4915 5042 - 5052 5129 - 5144 5196 - 5206 Beluga Sands 5220 - 5230 5561 - 5571 5709 - 5714 5773 - 5778 5782 - 5792 5825 - 5635 5840 - 5855 5922 - 5932 6000 - 6010 6111 - 6116 6163 - 6173 6180 - 6190 6196 - 6206 6267 - 6282 6435 - 6445 6680 - 6685 6752 - 6762 6784 - 6789 6991 - 7001 7095 - 7110 7286 - 7296 7316 - 7321 7374 - 7384 7526 - 7536 7" @ 8097' /~XISTING WELL COMPLETION DIA(~RY~, , I'~rOD) FMC OCT FMC 6'3M 4 l/Z'8rdX 4 1/2' BT&C Annulus Fluid: salt water with 3 bbl methanol REB-SL: 116.00 2612' from CBL dated 05/07169 Production Casing: 41 385 41 643 65 ib/ft H-40 41 45_5 & 51 J-SS 39 79 26 lb/ft J-55 J-55 WATER DEFTH: ]20 ]~JI-M].,: BT&C 3350 BT&C 4660 BT&C 408O BT&C 4660 1970 79 J-55 4080 39 10.9 lb/ft J-55 BT&C ] 5150 5730 9.3 lb/ft J-55 BT&C[ 5700 6440 PRODUCTION TUBING STRING 0.00 40-23 Elevation 402.3 1.00 ' OCT 6" 3M 4 1/2" 8rd x 4" BT&C Tubin 3.958 24425 J-55 BT&C Tubing 3.476 4.00 Otis 3 1/2" NO Ball Valve Nipple and SCSSV 2.760 3334 4" 10.9 lb/ft J-55 BT&C Tubing 3.476 CAMCO 3 1/2" GLM 2.991 4066.95 J-55 BT&C Tubin 3.476 1.13 4" BT&C x 3 1/2" X-OVER 2.992 Otis 3 ]/2" "X" Nipple 2.75 KBM 3 1/2" GLM 2.99 289.48 32Zg2 325.82 4392.77 4393.90 4395.13 4396.90 4402.02 3 1/2" 93 Ib/ft J-55 BT&C Tubing 2.992 2.750 4403.75 8.00 Otis 7" x 3" "RH" Hydraulic Set Retrievable Packer 2.900 4411.75 239.45 3 1/2" 931b/ft J-55 BT&CTubing 2.992 4651.20 3.00 "XO" Sleeve 2.75 4654.20 30.00 3 1/2" 9-3 Ib/ft J-55 BT&CTubing 2.992 4684.20 2.80 2.750 10,19 Otis 7" x 4" "WB" Permanent Packer 4697.19 10.80 31/2" 4707.99 1.00 4708.99 10.80 4719.79 1.21 4721.00 End of Tubing J-55 BT&C Tubin 2.992 2.750 J-55 BT&C Tubin 2.992 2.635 NOTE: Tailpipe and "Q" Nipple cut with Dia-Log at 4,714'. May not have dropped off~ PRODUCTION PERFORATION INTERVALS COOK INLET SANDS BELUGA SAND (cont.) C1-1 Cl-2 Cl-3 Cl-5 Cl-6 Cl-7 Cl-8 C1-10 C1-11 4450-4515 4535 -4510 4630-4550 ~70 - 4785 4832-4862 4890-4915 5042-5052 5129- 5144 5196- 5206 BELUGA SAND 5561-5571 5709- 5714 5773-5778 5782-5792 5825 -5835 5922-5932 "Middle" 6000 - 6010 6111 - 6116 6163 - 6173 6180 - 6190 6196 - 6206 6267 - 6282 6435 - 6445 6680 - 6685 6752 - 6762 6784 - 6789 6991 - 7001 7095 - 7110 7258 - 7296 7316 - 7321 7374 - 7384 7526 - 7536 Well: North Cook Inlet Unit No. A-05 ITbgWt: 4" - 10.9 lb/ft 1994 TD = 124' Field: Cook Inlet Unit 385 643 10 3/4" @ 2571 TOC@ 2612 ,/'~ PROPOSED WELL COMPLET~'~N DIAGRAM Bi FMC OCT I RKB-Drill Deck: ~-- 6" 3M 4 1/2" 8rd X 4 1/2" BT&C RKB-TH1~ 39.40 Annulus Fluid: salt wate. r with 3 bbl methanol I RKB-SL: 116.00 TOC: 2612' from CBL dated 05/06/69 WATER DEPTH: 120~ RKB-ML: i::i::i ?:::iii:-B 6~i::i:: ::::ii[ ?::: ii:. ii ::::::::::::::::::::: ::::::::::::::::::::::: ?::: i::i:::.G:t~ad~i~i i!: il::ii::ii:::::: i::::!::~fifii:,iiii ::::::::i::i[i :.i i:.ii :: i:::::::: B :~ i::i:: i::::::i ii t::i:: ::i?:::::i::::i:: i ii~:[i [ii::i:::: i i::ii:::: Production Casing: 30" 41 385 16" 41 643 65 ib/ft! H-40 10 3/4" 41 45.5 & 51 ~b/f~ J-55 7" 39 79 26 ib/ft 7" 79 23 ]b/ft / 7 26 Ib/ft / 39 310 BT&C 3350 1970 Tubin J-55 BT&C 4660 4080 J-55 BT&C 4080 3080 J-55 BT&C 4660 4080 12.75 lb/ft J-55 4730 4980 :ii:iii:.ii!i!ii?:.!ii :iiiiiiD~iption:: '::i: : :::::::?:::::::::??/:::: PRODUCTION TUBING STRING TD 124' Howco VSR packer @ 4350' Cook Inlet Sands 4450 - 4515 45.35 - 4610 4630-4650 4770 - 4785 48,32-4862 4890 - 4915 5042 - 5052 5129 - 5144 5196 - 5206 .... Beluga Sands **5357 - 5361 **5454 - 5456 **5479 - 5483 5561 - 5571 5709 - 5714 5773 - 5778 5782 - 5792 5922-5932 6000 - 6010 6111 - 6116 6163 - 6173 6180 - 6190 6196 - 6206 6267 - 6252 6435 - 6445 6752 - 6762 6784 - 6789 6991 - 7001 **7024 - 7032 7095 - 7110 7286 - 7296 7316 - 7321 7374 - 7384 7529- 7536 7" @ S0@7' 0.00 40.23 Elevation 40.23 42.23 275.73 278.23 2.00 FMC / OCT 6" 3M 4 1/2" 8rd x 4" BT&C Tubin 233.50 4 1/2" 12.6 lb/ft J-55 Mod BT&C Tubing 2.50 Halliburton 4 1/2" WLRSV 30.00 4 1/2" 12.6 Ib/ft J-55 Mod BT&C Tubing 308.23 1.77 4 1/2" BT&C x 4 1/2" EUE X-OVER 3.958 3.958 2.992 3.958 3.958 310.00 4000.00 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing 4310.00 3.958 4311.00 4341.00 1.00 Halliburton 4 1/2""X" Nipple 30.00 4 1/2" 12.75 Ib/ft J-55 Mod EUE 8rd Tubing 3.813 3.958 8 4349.00 8.00 Halliburton Upper Seal-Bore Assembly 1.00 Halliburton Ratch-Latch Seal Unit 3.958 3.958 7 4350.00 6 4357.00 7.00 Halliburton VSR packer & tubing adapter 60.00 4 1/2" 12.75 Ib/ft J-55 Mod EUE 8rd Tubing 5 4417.00 3.00 Halliburton 4 1/2 .... XA" Sliding Sleeve 4 4420.00 1580.00 4 1/2" 12.75 lb/ft J-55 Mod EUE 8rd Tubing 3 6000.00 3.00 Halliburton 4 1/2 .... XD" Sliding Sleeve 2 6003.00 1536.00 4 1/2" 12.75 Ib/ft J-55 Mod EUE 8rd Tubing 7539.00 1.00 Halliburton 4 1/2""XN" Nipple 7540.00 End of Tubing 3.880 3.958 3.813 3.958 3.813 3.958 3.725 PRODUCTION PERFORATION IbrFERVALS COOK INLET SANDS Gl- 1 Cl-2 CI-3 CI-5 Cl-6 Cl-7 CI-8 Gl- 10 C1-11 "Uppe~ "Middle" BELUGA SAND (cont.) 4450 - 4515 6000 - 6010 45.35 - 4610 6111 - 6116 : 4630 - 4650 ~ 6163 - 6173 4770 - 4785 ¥, 6180 - 4832 - 4862 ~" ~ 6196 - 48,90 - 4915 '~ ~. '~, 6267 - 6282 >.-. 5042 - 5052 :'~3 '"'-- r'11 6346 - 6358 5129 - 5144 ~?-" !¢~i,~ -'Z ~' 6435 - 6445 5196 - 5206 '~:~!' ~"~ ~ rw~i 6752 - 6762 BELUGA S ~.~ ~754 - 670o 'Z,=~ * 6991 - 7001 I ~ r~12' ** 7024 - 70~. ,5220 - 5230 "kt~ ~ "Lower" 5.357 - 5.381 5454 - 5456 7095 - 7110 5479 - 5483 7286 - 72~6 5581 - 5571 7316 - 7321 5709 - 5714. 7374 - 7384 5773 - 577~ 7526 - 7536 5782 - 5792 5825 - 5835. 5840 - .5855. NOTE: ** denotes new perforations 5922 - 5932 to bc added PBTD: 8,059' ] Supv: Well: North Cook Inlet Unit No. A-05 Location: Lower Cook Inlet Alaska I Tbg Wt: 4 1/2" - 12.6 & 12.75 Ib/ft J-55 June 01 ~ 1994 Field: Cook Inlet Unit PRD DEPAR~]~NTOFNA~URAL~ Division of Oil andGasCcnservaticn DirectorO~ K. Gitbreth,~~~Jr~ I{oyle H. Hamilton . (/~%ef Petroleum En~vt' ~ June I, 1978 Harold R. Hav&~ins Rewitn~ss subsurface safety valve (SSSV) and surface safety ~ralves (SSV) plus high and l~v pilots, Phillips Platform North Cook Inlet _~n_day, May 19, 1978 - I left ~chorage to Kenai at 8:00 AM by AAI, arriving -in K~ a~ 8:30 A~ I walked to F~ai air service where I was to get a d~opper rid~ to Phillips platfonn. Purpose of trip to r~vitness safety valves that failed last test cn 4/20/78. I arri%~d c~ the platform at 12-:10 I~4. I mst Bob Gamble, the supervisor for Phillips platform. Bel~v are the results of the tests: Pilot Well No. Flc~ PSI_ Test PSI SSSV SSV A-6 1400 900 C~K OK OK OK. A-11 1375 875 OK . 1500 1000 OK fTK OK ~ 1400 900 OK OK OK In ~: I rewitnessed the above indicated safety valves plus high and iow pilots that failed in previous tests c~ the Phillips platform. Retests ~m-re satisfactory.. Atta~t A-~'- a Oil and-Gas Conservation Comm:.--:,.ee ! Field Inspection Report Drlg. Permit No. Weli/Platfm Sec__T__R__, Opera tom .P//~X/.~'"?~?Za_.x_~,~R. epresented by~/? J~/4~?Lt? Name & Number.~/)/ Satisfactory Type Inspection Yes No 'Item ( ) Location,General () () () () () () () () 9<) ()' of) () () () () () () () () () 1. Wel'l Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig. O~ Safety Valve Tests 5. Surface-No. Wells ~_~" 6. Subsurface-No. Wells - ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser ~ , , 9. BS&W , , , lO. Gr. Bbls. ( ) Final Abandonment Satisfactory TYpe Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15. "C~'~inq set 0 ( ) ( ) 16. ?esl fluid-( )wtr.-----~ )mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- psig ( ) ( ) 18. N2 btls. , I,__, psig. ( ) ( ) 19. Remote Controls .( ) ( ) 20. Drillin~ spool- "outlets ( ) (.) 21. Kill Line-( ) Check valve ( ) (). 22. Choke Flowline ( )HCR.. valve ( ) ( ) 23. Choke Manifold ,No. valvs flas ( ) ( ) 24. Chokes-( )Remote( )Pos.(-]~-dj . ( ) ( ) 25. Test Pluo-( )Wellhd( )csq( )none ( ) ( ) 26. Annular Preventer, ...psia ( ) ( ) 27. Blind Rams, psia ( ) ( ) l l. P&A Marker ( ) ( ) 28. Pipe.Rams ~.psiq ( ) ( ) lZ. Water welt-( )capped( )Plugged ( ) ( ) 29 Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve ~sia ( ) ( ) la. Pad leveled ( ) ( ) 31 Safety F. loor valvesL'('~B'V ( )Dart Total inspection observation time hrs/days Total number leaks and/or equiP, failures Remarks _/~L-~'X'~Zi)- ~,.~ ~/~z.~-~ '~/~/~ ~z,~ ~~z~ ~ _ /l~'~a Oil and 'Gas Coqservation ComF ..ae Field Inspection Report Drlg. Permit No._ ..... ' ' Well/Platfm Sec T__R__ Opera tor~~/)o~ ~z~AZ~_~X_~R. epresented by~./~.~O~,~_-~ Name & Number~/j~~,- Z Satisfactory Type Inspection Yes No Item ( ) Location,General ( ) ( ) 1. ~'!ell Sign ( ) ( ) 2. General Housekeepine ( ) ( ) ~,. Reserve Pit-( )open( )filled Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15. "c'a'sinq set ~ ( ) ( ) 16. TesL fluid-( )wtr.------~ )mud ( ) oil ( ) ( ) 17. Master Hyd. Control Sys.- psig () () ~) ( ) () () () () () () () () () () 4. Rig. (/V~ Safety Valve Tests 5. Surface-No. ~ells ~ 6. Subsurface-No. Wells / - ( ) Well Test Data 7. Well Nos. , , , 8. Hrs obser , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment ll. P&A Marker ( ) ( ) 18. ~!2 btls. , __,__, ?sig. ( ) ( ) 19'. Remote Controls ( ) .( ) 20. Drilling spool-__"outlets' ( ) (.) 21. Kill Line-( ) C~eck valve ( ) ( ) 22. Choke Flowline ( )HCR valve ( ) ( )' 23. Choke Manifold No. valvs flms __ ( ) ( ) 24. Chokes.'-( )Remote( )Pos.(-~dj. ( ) ( ) 25. Test Pluo-( )Wellhd( )cs.q( )none ( ) ( ) 26. Annular Preventer, ~si~ ( ) ( ) 27. Blind R. ams, osi~ ( ) ( ) 28. Pipe-Rams ..?siq ( ) ( ) lZ. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve Dsi~ ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves--L-(- '--~BV ( )Dart Total inspection observation time hrs/days Total number leaks and/or equiP, failures Remarks ??~-~._1'~'X' ~? ~z.~ ~/~ ~4,~9 ~/~'/~7~ ~ cc:,2~: ~ot~t~ ~n~-~s or ~hen ready~~nspected b~~/y/~ Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports, in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) OIL r-I GAs g-J WELL L.--I WELLES. bi OTHER 2. NAME OF OPERATOR Phillips Petrole~m Company. 3. ADDRESS OF OPERATOR P.0. Drawer 66 / Kenai~ Alaska 99611 4. LOCATION OF WELL Atsurface Leg 3, Slot 6, 1253' FNL, 1091' FWL, Sec. 6, TllN, RgW., S.M. BHL 2524' FSL~ 2243' FWL~ Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 116' from MLLW 14. $1~ T12N~ R9W. ~ S.M. CheCk ApproPriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE ~0-28~-20025 6. LEASE DESIGNATION ANO SERIAL NO. ADL-17589 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME NCIU 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Ngr~h ~ook Inlet '11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) See Item 4 BHL 12. PERMIT NO. 69-32 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) ~,] ~ RTl 0!?- SUBSEQUENT REPORT OF-' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 1. Rig up. Kill well with 10.0 ppg mud. Remove tree. and 12" 3000# WP double gate preventor and Hydril. 2. Pull 4" tbg and retrievable packer. 3. Clean out to 8059 PBTD. Install 12"-3000# WP riser Test BOP and riser. . Run combination 4 "x 3 1/2" tubing string with Otis subsurface safety valve set about 285' RKB and Otis retrievable packer set about 4400' MD RKB, and tubing set 7536' MD RKB. 5. Install tree and displace mud with water. Set hydraulic packer. 6. Clean up well and c~nduct 4 Point BPT. 7. Utilize as a producer commingled in Cook Inlet and Beluga pays. Estimated start of operations is 8/24/75. 16. I hereby certify that the for e and correct ] SIGNED"' ~_' ~ . TITLE Sr. Petro2eum ~,n~Sneer . DATE ,- ~..~-~ 1~. ~. ~orver ~ Test packoff. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side PHILLIPS PETROLEUM COMPANY 515 "D" Street Anchorage, Alaska. 99501 Date - mi .lJ ~"J-"" ,L ~J' Trmnsmitted herewith are .the following f.rom the subject well: Sepi_~ .Blu,e Line .BHC"-Sonic/Caliper Log 2" 5" .BHC .Sonic Log.. 2" BHC.-'Sonic/G~.mma Ray Log 2" BHC Sonic/Caliper' 2" Gamma Ray-Log 2" 5" Collar Log 2" 5" Cement Bond Lo'g Continuous Dipmeter Log 5" 60" Direction 'Survey Dual Induction-Laterolog 2" 5" Formation Density_Log_ 2" 5" Gamma Ray Log ~ 2" 5" Gamma Ray-Neutron .Log 2" .5" Induction-Electrical Log 2" 5" Neutron Log 2" 5" Proximity-Microlog/ 2" 5" Caliper Log Completion Reports. · . . /:. . Receipt Acknowledge~ by. .............. Date: PLEASE RETURN ONE SIGNED COPY TO THE LE~.?ERHEAD ADDRESS / STATE OF ALASKA - : ~' (See other In- 0~(~ structions on £" /O gO l ~i~ ! : reverse side)i ~' API N~CAL ; o L AND GAS CONSERVATION5 ~~ITTEE ~ ~ ~- ~'~ ro, ~ ~ ~ 1°~ ~I~50-283-2002~W~ · , ~_ .~[L~QH.~LET!Q_N__QR~REC~PL,~~_~~~ AND ---- .' . l ~17589 la. TYPE OF WELL: 01L ~ g,S ~ ~ ~'~l ~ :e ~ }b. TYPE OF COMPLE~ON: ~-'":~:~ " ~: '" J FILE ~. NAME 0F OPERATOR ' ~ ~--- =-¢ .~ .-~- ~ · - 5 D Street, ~chorage, ~$~ 99501~ ,~ ~ : i ,: ~o. ~. LOCATION O~ wELL {~eport location c~earl~ and in accordance wtt~.~$~e r~qutre~ents)* " ' '~ :' 11. ~., T[~ R., M., ' '. Seo~ 3i, T~N~, R~ 18~ T~ D~..~ & TVD~9. PLUG ~ MD & ~. m ~L'i'~ ~L., ]:. I [ 21. :-~: }- ',NTERV2LS~RILLED ~_ ............ '!_ P~ _._ I ~w~Y* ~ ""~ { soT,R, ~ooL~' -.' ' '1- ' CXabe ~OOL8 · ~' ~~?' ~~'~ 6~' ~ Single ~ ~:~; J ',. 1~ ],: : ~el~a ~d8 5220' ~(&505' ~) to 7536' (63alt ~) " - . · J-~ Yes ~ .CASING RECORD (Report all set in CASING SIZE DEPTH SET (1V/D) HOLE SI~.E ~' SIZE ~...~ (MD) SACKS C~VI~* SIZE (Interval, size and LINER TOP ( 1VLD y; OP~.~N TO . usi~ :~, ' : ~; ~ ~ODU~'I'ION -' ;' """" pump~g--~ize and type of p~p) , " iWELL STA~S (~odue~ or DATE FIRST ~ODUC~ON [ ~O~CTION METHOD (Flowh~g~:~as lift, ~+_ ~a,~ad va+. [ ~ .:.::; Flow ~: ,~ ,-. '-' ."'-- , ~ I snuf-m) - , '- ..... '~ ~ ~ " .~_ ' J' .:, Shut-in: · ~hut-L. ,, ~ -}[ ~' ' !- ~:~ .o ot~eal ~eE Hi~oT, ~eaze .Record. ~Bl~d T,~ ne ~d Sep~ a ~s. . i hereby cert~ th~ the ~ore~p~g and ~aened information 1~ ~omplete and correct a~ determined from all:available recoras ' ~ Distr - INSTRUCTIONS - General: lhis form is designed_}t:or submitting a complete end correct well completion report and log all.,types of 'lands and leases in Alaska. - '~ It--ll 16: Indicate which elevaa~n is used as reference (where not otherwise.shown) for deP(h measure ment~ given in c~he~..spaces on this form and in any attachments. Items 20, and '22:~::']'f this well is completed for,'~eparate production from more thah one interval zon~ (multiple c0mplefi~'n), so s,ate in item 20~ ahd2in i~em ~2 show *he p, cducing ~p~erval, ~ interval~ lop~s), bo.o'mls) and na~e {s) {~ an~) {or:~ ~he inlerval reported in i~em 30, Submi~ a separate re.fl (pa~e) on fh[~ fO.~, adequately~idenfified, for each adgi~ional ime~val ~o ~ seper~ely prod0'c~,~shoo;- ing the a~i'tion~[ data pertinent to such ~nterVal. o ~26: "~Cks Cement": Attached suppl~t~ records for this well should show the details of any,mul- tiple stnge cementing and the ..IoC.tian of~-th'S,ce, ment~ng tool. " '~*~m ~8: Submit a separate completion re.ri on ~his form for each interval to ~ separably produ~, (~ in~ruction for i*em~ 20 and 22 above). ?. - . ). ~'Y Ol~ ,~I.I~ATION TI~'I~ INCLUDINC; INT~V*~ ~D. ~U~ DA~* ~ ~OV~:OF OIL. G~. . [/) '~ ...... ~ ' ' 35. G~GIC MARK~ .~ . WA~ AND MUD- ~ ~ , ' i.,, ri , . '.'~ ,.'"' I , , ~ : .. . .. ,, - ~ok~I~e~: S~ds ~50' -3779' ~ o B. el~a ~' ,- ~ ~ 5209' -~395 ' S~',.ATTAC~D CHRONO~GIC~ ~ HI~% - ---"- '- ; 0 ' '" J -" : j ~ : . ~-~' ,. .". :_ , ~ . .. . ~ ..... , ~ ~ ~ .-.~ . .- , . . ~, .... . ., . :O : . '.,. ,.:~ ', :. ' ; -i ,. '' '.' ' .':."~ , ,,~ · ~ i ~ : .'~ ~ ,,,.; ~4 ' :., '.' . .... '~.. L" : ...... .. ,., . , . - '.. : ,) p DAT~:~ A~ACII BRIEF 'D~CRIPI~ONS OF LITHOLO~Y ..POHosiT~,~FRAC~R~ APP~ DI~S ',, ';~, ~ .~ .'A~D DETECt'ED SIIOWS O~ OIL, G~ o~gWA~. ' ~ " ' " '. ; . ' ' ' ' ~ J '~ ' .k ' ',:' . ~ · . ~. ~ .'~ ~ '". ~ ~2' . , ,. t ~ .,; ': . ..,.. . ~ , ;...~ .;.: c~_,.".~'" .' .) . . ~ " "' '- ' ~,'3 : : - -.- .. , ..... ,'., ..~ ,,.., ~ : - ,. , : ~~]' .... .. ~. '.:'::~ . :_ ', c ~_ ,.: ~_ " :. ~, :7~ · i'~ n '~ ',- ' ~'~ : -'- ~'. ' . : I", $ , . . ' ~ " ~.- ~q ; , ;'~'~ , , 'J " ,. CHRONOLOGICAL .WELL HISTORY WELL #A-~ ATTACHMENT &-16-69 ~-17-69 ~-18-69 Spud 15" hole. Drld 15" hole and reamed to 22" to 670'. Set 16" csg @ 6~3' & cemented w/~50 sx Class "G" cement mixed w/200 bbls prehydrated Gel Water, tailed in w/125 sx Class "G" cement w/ 15 bbls 2% cc water. &-19~22-69 &-23/2&-69 ~-25/30-69 5- /5 9 5-8-69 5-9 31-69 Drld 15" hole to 2625' twisted off, WIH w/overshot, caught fish, started out of hole, hole tight, worked pipe out, reamed hole. Set lO-3/&" casing at 2571'. Cemented w/6&O sx Class "G" cement w/8#/bbl prehydrated Gel salt water, tailed in w/125 sx Neat cement w/2% cc salt water. Drld 9-5/8" hole to 7218'. Drld 9-5/8" hole to 812&'. Ran IES, FDC, GR and SNP logs. Ran 7" OD casing and set at 8,096.97' and cemented w/502 sx Type "G" cement mxd w/122 bbls prehydrated 10% Diacel "D" wtr & 2% cc. 2nd stage cemented w/850 sx Type "G" cement mxd w/lO5 bbls 2% cc wtr. Squeezed leak in casing below RTTS tool at 512~' w/Il0 sx Neat cement uu .s cc. Perforated following intervals w/A" no plug gun, ~ shots/ft., .50" holes, IES & SNP Measurements: ~50'-&515', ~535'-~610', &630'-&650', ~770'- ~785', ~832'-~862', ~890'-~915', 50~2'-5052', 5129'-5144', 5196'-5206', 5220'-5230', 5561'-5571', 5709'-5714', 5773'-5778', 5782'-5792', 5825'- 5835', 58&O'-5855', 5922'-5932', 6000'-6010', 6111'-6116', 6163'-6173', 6180'-6190', 6196'-6206', 6267'-6282', 63~6'-6356', 6~35'-6~45', 6680'- 6685', 6752'-6762', 678&'-6789', 6991'-7001', 7095'-7110', 7286'-7296', 7316 ' -7321', 737~' -738&', 7526 ' -7536 '. Ran 3½" and &" comb tbg string set @ ~689'. Ran g-pt tests, perf's ~770'- 7536'. #1 - F ~ hfs on 3/~" .chk, FTP 1760 PSI, Temp 70°F,^FARO 25,986 MCFD. #2 - F 2-3/~ hrs on 5/8" chk, FTP 1920 PSI, Temp 73VF, FARO 19,57& MCFD. #3 - F 3 hrs on ½" chk, FTP 19~2 PSI, TemPo72°F, FARO 12,351 MCFD. #& - F 1½ hrs on 3/8" chk, FTP 1996 PSI, Temp 72 F, FARO 6,885 MCFD. WOR to pull tbg for leak. Pulled tubing, no indication of leak. Reran tubing & tested, O.K. 6-5/10-69 Attempted to set plug in KBMMandrel, could not. Lost dummy in tubing. Otis bailed sand and Baroid to A615'. 6-11/12-69 Bailed Baroid and water to A582'. (co,r, o) #A'-5. PAGE 2 6-13-69 Pumped SW in annulus and out thru Mandrel. Recovered muddy water for 15 minutes, then cleared up. Started injecting gas into annulus. Blew water from annulus and tubing for 15 minutes. Tubing pressure llOO PSI. 6-5%-69 WIH w/drive bailer, hit bridge 4531'. Drove bailer to 4626'. WIH w/Star bit, drove thru bridge and dropped to 4668'. 6-15-69 Pumped SW in annulus thru Mandrel at 4391'. Circulated until cleaned up. Opened XO sleeve at 4650'. Opened gas on annulus and kicked well off. WIH w/Sand bailer and cleaned out sand and Barite to 4690'. 6-16/17-69 Injected water in annulus, retrieved dummy from X-nipple at 4707'. Tried to reset in Mandrel at 4391', dropped, fished out, attempted to set dummy, did not set. Attempted to retrieve dummy, no recovery. 6-18/26-69 Bailed mud and water to 4707'. 6-27-69 WIH & recovered X-plug & dummy. Set dummy in Mandrel @ 4395'. While attempting to set dummy, dummy dropped off & fell to 'Q' nipple @ 4719'. 6-28/30-69 Made 3 runs w/retrieving tool, no recovery. Temporarily suspended. Fished junk out of hole. Trying to complete well. 7-10/31-69 Temporarily suspended. Wait on wireline unit. Temporarily suspended. Pulled plug for X-nipple at 4707', cut off pup joint above 'Q' nipple at 471g'. Opened XO sleeve at 4651'. Set ball valve at 285'. Clean up thru flare. SI. Wait on potential test. 8-15-69 SIP 2064 PSIG. Ran 4-pt test as follows: #1 - Flwd 1¼ hrs on 3/4" chk, FTP 1674 PSI, Temp 59°, FARO 25,930 MCFD. #2 - Flwd 1 hr on 5/8" chk, FTP 1904 PSI, Temp 62°, FARO 20,560 MCFD. #3 - Flwd 1 h~ on ½" chk, FTP 1995 PSI, Temp 63°, FARO 13,360 MCFD. #4 - Flwd 1 hr on 3/8" chk, FTP 2030 PSI, Temp 62°, FARO 7,340 MCFD. Completed as NG well in Cook Inlet & Beluga Sands. Perf's 4450' - 7536'. North Cook Inlet Field. ATTACHMENT #2 PHILLIPS PETROLEUM COMPANY N.C.I.Unit #A-5 North Cook Inlet Field Cook Inlet, Alaska 3085 - 3550 3550- /.,d.~ - &.380 /~30- 5210 5210- 5665 5665 - 6200 6200- 7&O0 7&O0- 812A SAMPLE DESCRIPTION Sand- ned gy, f-rog, ang-subang, mod srtd, abndt blk and grm grains, some red and brn grains Sand- meal gy, rog, ang-subang, abndt blk, gm, and red grains; w/clyst, sltst, and coal stringers Sand- mod gy, rog, ang-subang, pred. qtz w/abndt blk grains Clyst - gy, mod hd, sli carb; w/some thin coal beds Sand- mod gy, f-cg, poorly srtd, ang-subang, pred. qtz w/abndt blk grains, some gm, bm, and red grains; some gy, carb clyst and thin coal beds Clyst - gy, slty, soft, sli carb; w/thin coal and sand stringers Interbedded clyst and sand; clyst - gy and tan, soft to hd; sand -mod gy, f-rog, ang-subang, pred. qtz w/abndt gy smoky qtz, tr colored grains Clyst - gy, slty, soft to mod hd; w/thin sltst, ss, and coal stringers Sltst -ned gy, clayey to sandy, mod hd to hard, calc; w/gy c!yst and talc ss stringers 'Clyde R. Seewald June &, 1969 ATTACHME~ #3 PERFORATING AND SQUEEZE RECORb Well. A-5 5-8-69 . '7 She of Casf~ng 11 11 !1 I! . II 11 Il II N. I! II I! II II .~ .. To 4450' 4535' ;~630' 47?0' 4832' 4890' Peri'orating From & Si 4610' '4650,~ 4862 4915 Feet Perforated 65' 75' 20' 30' 25' 5042' 5129' 5196' 5220' 5561' 5709' 57?3' 5782' 5825' 5840" 592~' 6000' 6111'. 6163'-- 6180' 6196' 6267' .63Z+6, 6435' 6680' 6752' 67~' 6991' 7095 ' 7286 ' 7316' 7374'. 7526 ' 5052'~ 5144'/ 5206',~ 5230 5571'~/ - 5714,z' 5778'~ 58356/ - . 5855'~ 5932'¢' 6010,/ .611&., /.~ 6173'~ 6190"~ 6206'~. 6282,~ 6356'~ 6445, 6762'~/ 6789'*~ 7110'~ 7296' 732 ,' 7384'/ 7536' ~O! 15' 10'- 10' 10'. 10' 10! !5"' 10' 10' 5' 10' 10' 10' 15' 10' 10' 5' 10' 5' 10, !~' 10' 5' 10' 10' No..o~ S,"ze o~ Holes Holes 260 3OO 6o 120 100 40 60 40 &O &o 20 20 60 20- &O 60' 4o 20 ~0 2O 4O 6O 20 II- II II I! I! 11 11 II II GUn D;emeler ..~ II II 11 Il 11 !1 II Il II II II Il Il_ " il !1 Gun ! . Per,'oraflng Company ! ! ~? I! " II ~{ II II II · * !! Schl~:?oergez II I! II l Il II Il I! · Il Il REPORT of SUB-SURFACE DIRECTIONAL SURVEY PHILLIPS PETROLEUM COMPANY PLATFORM COMPANY IiAii A-5 NAME NORTH COOK INLET LOCATION JOB NUMBER TYPE OF SURVEY DATE AM4-1069 SING LE SHOT APRIL SURVEY BY ANCHORAGE 1969 WELL COMPLETION REPORT PHILLIPS PETROLEUM A-5 PREPARED FOR EASTMAN SURVEY CO. BY SCS 05/06/69 · PAGE TANGENTIAL ME~HOD MEASURED COURSE - - D E V I A T I 0 N - C 0 U R S E DEPTH LENGTH ANGLE DIRECTION AMOUNT V.DEPTH LATITUDE DEPARTURE . . ORIGIN LOCATED AT MD : 0.00, TVD = . ?.100' 125. 150. 175. 200. 22.5, 250. ~'275. 300. )25. 356. 39~, 425' 455,~ 485. 512. 544. 58~. 640. 710, 800, 840. 870. 901. 43. 0 O' N 0 E 32. 0 10' N 11 E 25. 0 15' N 27 E 25. 0 15' N 15 E 25. 0 10' N 16 E 25. 0 10' N 17 E 25. 0 10' N 81 W 25. 0 15' S 37 E 25. '0 30' S 44 E 25, 0 30' S ~4 E 25. 0 40' S 84 E 25. 0 40' S 70 E 0.00, LATITUDE = 31. .38. 30, 30. 27. 32. 40. 56. 70. 40. 30. 31. 50' S 82 E 55' S 79 E 55' 'S 53 E 50' S 69 E 15' N 34 W 15' N 65 W 40' S 69 E 5' S 65 E 30' S 57 E 20' S 56 E 40' S 57 E 15' N 75 E 30' N 60 E 45' N 52 E 933, ~ ~ 32' ' 5 30' N 30 E '" 963. 30. 6 30' N 25 E lOtg, ~ 56. 8'~'0' N 20 E 1078, 59° g 30' N 17 E 1169, 91. 11 45' N 16 E 0.00 43.00 O.Og 31.99 0.10 24.99 0.10 24.99 0.07 24..99 0.07 24.99 0.07 24.99 0.10 24.99 0.21 24.99 0.21 24.99 0.29 24.99 0.29 24.99 0.45 30.99 0.60 37.99 0.49 30.99 0.43 29.99 0.65 29.99 0.11 26.99 0.93 31.98 2.15 39.94 2.44 55.94 2.84 69.94 2.61 89.96 1.57 39.96 1.83 29.94 2.56 30.89 3.06 31.85 3,39 29.80 7.79 55.45 9.73 58.19 18.53 89.09 V.DEPTH T O T A t .... LATITUDE DEPARTURE 1.30, DEPARTURE = 5.10 0.00 N 0.00 E 43.00 1.30 N 0.09 N 0.01 E 74.99 1.39 N 0.09 N 0.04 E 99.99 1.48 N 0.10 N 0.02 E 124.99 1.59 N 0.06 N 0.02 E 149.99 1.66 N 0.06 N 0.02 E 174.99 1.73 N 0.01 N 0.07 W 199.99 1.74 N 0.06 S 0.06 E 224.99 1.65 N 0.15 S 0.15 E 249,99 1.50 N 0.15 S 0.15 E 274.99 1.34 N 0.03 S 0.28 E 2gg.gg 1.3I N 0.09 S 0.27 E 324.99 1.21 N 0.06 S 0.44 E 355.99 1.15 N O.11 S 0.59 E 393.98 1.03 N 0.29 S 0.39 E 424.98 0.73 N 0.15 S 0.40 E 454.97 0.58 N 0.54 N 0.36 W 484.97 1.12 N 0.04 N 0.10 W 511.97 1.17 N 0.33 S 0.86 E 543.95 0.83 N 0.90 S 1.94 E 583.89 0,07 S 1.33 S 2.04 E 639.84 1.40 S 1.59 S 2.36 E 709.78 2.99 S 1.42 S 2.19 E 799.75 4.41 S 0.40 N 1.51 E 839.71 4.01 S 0.91 N 1.58 E 869.66 3.09 S 1.58 N 2.02 E 900.55 1.51 S 2.65 N 1.53 E 932.40 1.13 N 3.07 N 1.43 E 962.21 4.21 N 7.32 N 2.66 E I017.67 II.54 N g,3i N 2.84 E 1075.86 20.85 N 17.81 N 5.10 E 1164.95 38.66 N 5.10 E 5.11 E 5.16 E 5. lg E 5.21 E 5.23 E 5.16 E 5-23 E 5.38 E 5,53 E : 5-82 E 6.09 E 6.54 E 7.13 E 7.53 E 7,94 E 7.57 E 7.47 E 8.33 E 10.28 E 12.33 E 14.70 E 16.89 E 18.41 E 19.99 E 22,02 E 23.55 E 24.99 E 27.65 E )0.50 E 35.61 E WELL COMPLETION REPORT PHILLIPS PETROLEUM A-5 PREPARED FOR EASTMAN SURVEY CO. BY SCS 05/06/69 MEASURED COURSE - - D E V I A T I 0 N .... C 0 U R S E - - - DEPTH LENGTH ANGLE DIRECTION AMOUNT V.OEPTH LATITUDE DEPARTURE 1264. 1356. 144'7. 1540. 1635. 1728. 1822. 1914. 1975. 2071. 2165. 2257. 2351. 2445. 2539. 2625. 2681. 2742. 2836, 29)0. )054. 3241. 342~. a6o8, 3702. 3858. 3930. 4055, 4241. 4427. 4645. 95. 14 30' N 15 E 92. 17 O' N 15 E 91. 19 45' N 12 E 93. 23 O' N 10 E 95. 25 15' N 9 E 93. 27 O' N 10 E 94. 30 15' q 10 E 92. 33 15' N 10 E 61, 35 15' N IO E 96. 35 45' N 10 E 94. )5 45' N 11 E 92. 36 15' N II E 94. 36 45' N II E 94. 36 45' N 11 E 94. 36 15' N 13 E 86. 36 15' N 12 E 56. 35 45' N 11 E 6I. 35 45' N IO E 94. 36 15' N 12 E 94. 36 15' N 12 E 124. 36 O' N 11 E 187, 36 O' N 11 E 183. 36 O' N It E 184. 37 15' N 11 E 94. 37 15' N 11 E 156. 37 30' N 12 E 72. 37 45' N I1E 125. 37 30' N 14 E 186, 37 30' N 14 E 186. 36 30' N 12 E 218. 36 O' N 13 E 23.78 91.97 26.89 87.98 30.75 85.64 36.33 85.60 40.52 85.92 42.22 82.86 47.35 81.20 50.44 76.93 35.20 49.81 56.08 77.91 54.91 76.28 54.40 74.19 56.24 75.31 56.24 75.31 55.58 75.B0 50.85 69.35 32.7i 45.44 35.63 49.50 55.58 75.80 55.58 75.80 72.88 100.31 109.91 151.28 107.56 148.05 111.37 146.46 56.89 74.82 94.96 123.76 44.07 56.92 76.09 99.16 113,22 147,56 110,63 149.51 128.13 176.36 PAGE "~, · TANGENT[AL NETH[ - - - T 0 T A L V.DEPTH LATITUDE DEPARTU~ 22.97 N 6.15 E 1256.92 61.64 N 41.76 E 25.98 N 6.96 E 1344.90 87.62 N 48.72 E 30.07 N 6.39 E 1430.55 117.70 N 55.12 E 35.78 N 6.31E 1516.16 153.48 N 61.43 E 40.02 N 6.33 E 1602.08 193.51N 67,77 E 41.57 N 7.33 E 1684,95 235.09 N 75.10 E 46.63 N 8.22 E 1766.15 281.72 N 83.32 E 49.67 N 8.75 E 1843.08 331.40 N g2.08 E 34.67 N 6.11E 1892.90 366.07 N 98.19 E 55.23 N 9.73 E 1970.81 421.31N 107.93 El i 53.91N 10.47 E 2047.10 475.22 N 118.41E 53.40 N 10.38 E 2121.29 528.62 N 128.79 E 55.20 N 10.73 E 2196.61 583.83 N 139.52 E 55.20 N 10.73 E 2271.93 639.04 N 150.26 E 54.15 N 12.50 E 2347.73 693.19 N 162.76 E 49.74 N 10.57 E 2417.09 742.94 N 173.33 E 32.11N 6.24 E 2462.54 775.05 N 179.58 E 35.09 N 6.18 E 2512.04 BIO.15 N 185.76 E 54.36 N 11.55 E 2587.85 864.52 N 197.32 E 54.36 N 11.55 E 2663.65 918.89 N 208.88 E 71.54 N 13.gO E 2763.97 990.43 N 222.78 E 197.89 N 20.97 E 2915.26 1098.33 N 243.76 E 105.58 N 20.52 E 3063.31 1203.92 N 264.28 E 109.32 N 21.25 E 3209.77 1313.25 N 285.53 E 55.85 N 10.85 E 3284.60 1369.10 N 296.39 E 92.89 N 19.74 E 3408.36 1461.99 N 316.13 E 43.26 N 8.41 E 3465.29 1505.26 N 324.54 E 73.83 N 18.40 E 3564.46 1579.10 N 342.95 E 109.86 N 27.39 E 3712.02 1688.96 N ~70.35 E 108.2l N 23.00 E 3861.54 1797.18 N 393.35 E 124.85 N 28.82 E 4037.90 1922.03 N 422.17 E WELL COMPLETION REPORT PHILLIPS PETROLEUM A-5 PREPARED FOR EASTMAN SU[;~VEY CO. BY SCS 05/06/69 PAGE TANGENTIAL ME~HOD MEASURED COURSE - - D E V I A T I 0 N - C 0 U R S E DEPTH LENGTH ANGLE DIRECTION AMOUNT V.DEPTH LATITUDE DEPARTURE T 0 T A L V.DEPTH LATITUDE DEPARTURE 4863. 218. 36 O' N 14 E 128.13 176.36 124.33 N 30.99 E 5113, 250. 35 30' N 14 E 145.17 203.52 140.86 N 35.12 E 5237. 124. 35 15' N 14 E ?1.56 101,26 69.44 N 17.31E 5489. 252. 36 15' N 16 E 149.01 203.22 143.23 N 41.07 E 5737. 248. 37 15' N 16 E 150.11 197,40 144.29 N 41.37 E 5989. 252. 37 15' N 18 E 152.53 200,59 145.06 N 47.13 E 6175. 186. 37 15' N 19 E 112.58 148.05 106.45 N 36.65 E 6424. 249. 37 15' N 20 E 150.T1 198,20 141.62 N 5t.54 E 6673. 249. 36 45' N 21 E 148.98 199.51 139.08 N 53.39 E 6921, 248. 35 O' N 23 E 142.24 203.14 130.93 N 55.58 E 7168. 247. 34 O' N 25 E 138.12 204.7? 125.17 N 58.3? E 7387. 219. 33 45' N 29 E 121.66 182.09 106.41N 58.98 E 7574. 187. 32 43' N 30 E 101.07 157,33 87.52 N 50.53 E 7700. 126. 32 O' N 30 E 66.76 106.85 57.82 N 33.38 E 7876. 176. 32 O' N 31E 93.26 149.25 79.94 N 49.03 E 8124. 248. 32 30' N 32 E 133.25 209.16 113.00 N 70.61E 4214,27 2046.36 N 4417.80 2t87.23 N 4519.06 2256.67 N 4722.29 2399.91 N 4919.70 2544.20 N 5120.29 2689.27 N 5268.34 2795.72 N 5466.55 2937.35 N 5666.06 3076.44 N 5869.21 3207.38 N 453.17 E 488.29 E 505.6I E 546.68 E 588.06 E 635.19 E 671.85 E 723.40 E 776.79 E 832.37 E 6073.98 3332.56 N 890.74 E 6256.07 3438.97 N 949.73 E 6413.4I 3526.50 N 1000.26 E 6520.26 3584.33 N 1033.65 E 6669.52 3664.27 N 108[.68 E 6878.68 3777.27 N 1152.29 E CLOSURE 3949.13 N I6- 58' E VE~TIC_AL ~EETION PHILLIP~ PETR~LELI~ , TVF__) = 6878. ' HDRIZDNTAL VIEW SCALE ~ , I -- PHILLIPS PETR~~ A-5 P~~ F~ CO. I lV~rm No. P--4 STATE OF ALASKA svB~rr IN DU~LZCA~'~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF :DRILLING AND WOR'KOVER OPERATIONS TRM ,~~-- OKG , '5. AP1 NUA{ERICAL CODE KLV : ,../~ Ali ~0-283-2002~ HWK ~. LEASE DESIGNATION AND SElq~.NO. F ' ~- r ADL-17589 -- 7. IF INDI^~, ^LOTrEE · 2. NAME OF OP]gRATOR Pb!l_l ~ ps Petrele-~ Co_mpan7 3. ADDRESS OF OPE~ATOR 515 "D" Street, A_nchera~e, A~~ 99501 4. LOCATION OF W Surface: Leg 3, Slot 6, 1253~ FNL, 1091' FWL, Sec. 6, TllN, Rgw' S.M., North Ceek Inlet,' Platform "Tyenek" TMp ef Pa~: 160' FSL, 1550' ~, Sec. 31, T~, Rgw, S.M. 8. LTNIT,FARA{ OR LEASE NAME North Coek Inlet Unit 9. %VELL NO. 10. FIELD A.ND POOL, OR WILDCAT , North Ceek Inlet 11. SEC., T., R., 1~{., (BOTTOM HOL~ os,mCTr¢~ Sec. 31~ T12N~ Rgw~ S.M. 12. PEP, A'IIT NO. 69-32 13. REPORT TOTAL DEPTH AT END oF MONTH, CI-LA. NGES IN HOLE SIZE, CASING A/%]D cEIVIENTING JOBS INCLUDING DEPTH SET ~ VOLU1VIES USED, PERFORATIONS. TESTS ANT) RESULTS, FISI-I/NG JOBS, JLrNK IN HOLE A_ND SIDE-T'PL~CKED HOLE AND ANY OTHER SIGNIFICANT C'I-IANGES IN HOLI~ CONDITIONS. 8-15-69 Completed as commingled gas well. Temporarily suspended. ~ed plug for X-Nipple at &707', cut off pup Joint above 'Q' Nipple at &714'. Opened XO sleeve at ~651'. Set ball valve at 285'. 8-9/11-69 Clea~ up thru flare. 8-15-69 SI. Wait on p~tential test. SIP 206& PSIG. Ran &-pt test as f~llows: #1- Flwd ~ hfs en 3/&" chk, FTP 167~ PSI, Temp 59e, FARO 25,930 MCFD. #2 - Flwd 1 hr on 5/8" chk, FTP 190~ PSI, Temp 62°, FARO 20,560 MCFD. #3 - Flwd 1 hr on ½" chk, FTP 1995 PSI, Temp 63~, FARO 13,360 MOFD. #&- Flwd 1 hr en 3/8" chk, FTP 2030 PSI, Temp 62°, FARO 7,3&0 MCFD. DIVISION OF 011. AND GAS ANCI'IOI~.~E 14. 27. /~TE--Report on t,is f0r~s required for each calendar monLh, regardle,, of the status of operation% and mu,,. file~ in duplicate the Division of Mi,es A Minerals bM the 15th o{ t~e succeeding mo.th, unless othe~ise directed. Form N'o. G-1 RE¥1 ~I[D : JAN. STATE OF ALASKA sum~rr ~ ovm. zc,vr~ OIL AND GAS CONSERVATION COMMIT'TEE GAS WELL OPEN FLOW POTENTIAL TEST RFPORT 4-P01NT TEST Test Initia! . []~ Annual ~ Special Field ('ounty [ Location I P~od uein~ ~hru / ' Re;en'oir T~G.! CSG. T~mp~r~ture Temperature..., .-', ~ ~,~.~ Test Date _/~_ ' .<L_> ._. i ~,Vell No. T/Pay Produdr,~ t ":t' Interva! kcz-~:z;,'_., r /_~;:3'g Pipeli.~-'Conneetion /-:/.',Z../,:~... /~,'~.=. .... , . , ~Iultiple Completion (D~al or Triple) /' g(L,Set @ I Oas arav!ty I ~v~:. rrocl. I GL I C.~,-L~m,!~ Ib'drocarbon .. [ (Separator) I Length (L) ] ~-~-~., ,~l Ratio Mcr per Bbl. · ~ - ., ~ . , , , .__ Type Taps ' · ,. , ~ ,~.~ .. _ . : ~., ~, ~ ~__.  Type production from e~ch zone Gravity of Liquid (Apl) OBSERVED DATA. Flow Data I. ,, , of Fioxv (Line) ) Hours Size 2. 4. Coe~i- cient (24 Hr.) (Choke) Size Press. psig ,.:¥n .0 t FLO\V CALCULATIONS Diff. h ~v Pressure psJ~ Flow Temp. Factor t Tubing Press. psig'.,/ ._.?) ,.,. :, ...; Gravity Factor F PRESSI:RE CALCULATIONS Casing Press. psig Flowing Temp. °F Compress. Factor F DY f/ / / Rate of Flow Q MCF/D / ~,: - , ..' ...- '~ . > ,.%'-r' ,% .- / ../' ~'~ '<:'"" '" '"~' ' ~" '" """ ;;".' " CER~'I/FICATE: i. the undersized, state ~at I am the :' ," '.L :' of ~e" ' ' : .. (company), ~d ~at I am author~ed by said company to make t~is report; and that this report was pr~;~.~ . ............ ~ ," . pared ~der my supe~ision ~d direction ~d that the facts stated merem areitrue, co=ect ~d complete ~e be=t of my ~owledge. /%-?/ "/~ /' /:/' .. c.?" :. ~::"' '," '- } // Si~ature . - DM~~L~~ Forlu I~-----12 STATE OF ALASKA OIL AND GAS CONSERVATION COMM[ITTEE RESERVOIR ~. RESSUBE REPORT %cc Instrt c,mns on l~c;.'(:rse Side Lease . ._ ]bate Tested Shut-In l :Pressur~ Test Del)th Bomb T-:st Dicta B.}I. T e mp. Observed Pressure Prod. Test (Bbls. ])er Day) Oil. Water . Designate type of report by "X". ,., CERTIFICATE: I, the u'nderslg,te,l, state that I am the '2 of tile (cOmpany), and that I am authorized by said company, to :make ~his report; and that this report was _prepared under m7 supervision .nd direction and tky the~ae't':'"';'t'hed tl. ere,,, .re true, correct and complete to thc best of my knowledge. ~ ~ ] - :/' .../::..2::,:~.: ......... :::::::::::::::::::::::::::::::: ............................................. / Signature ~ - / 1 i Ii~uia i XVt. of Liquid ' q.. ~ I Liquid l,e;'el [G-"aa,ent [Column XVt. of Ca:;ing' (;' ~.'.. S 1~' r e .'-.- S!l r e Col%lmr,_ t,]/.,/,~:2 LOO^t~ITt~IMIc 46 7'400 KEUFFEiL & tT$%[:R CO, o~, ~J co tu o Form No. P--4 REV. STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE AP1 NUA{ERICAL CODE T~ -- OKG -~~ KLV ... MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPE~,ATOR ~11t9~ Pe%rele~ Company 3, ADDRESS OF OPERATOR ~1~ "9" ~ree%, Am~herage, Alaska . 99~1 4. LOCATiON OF WELL ~_~j&~: ~g 3, alet 6, ~53' FI~, ~91' lng, see. 6, To~ ~f ?ar: ~0' ?~, 15~' ~, ~e. 31, ~, R~, S.M. 9. WELL NO, ~l-~ 10. ~-lJ~t.,D A.ND POOL, OR WILDCAT Ner~h ~mk 11. SEC.. T.. R.. M., ('BO~'~FOM HOLE OmmCTrVFJ See. 31, ~, RgW, S.~. 6~-32 12. PEI~/IIT NO. 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING A~-D CEMEN'IqNG JOBS INCLUDING DEPTH SET AN~ VOLLrM]~ USED, PERFORATIONS, TESTS ANT) RESULTS. FISHING JOB~. JLrNK IN HOLE A~D SIDE-TRACKED HOLE ANT) A_NY OTHER SIGNIFICANT CI4_.A.N~ES IN HOL~ CONT)ITIONS. 7-31 7-10/31-~ Fished J,ak e~% ef hole. Tr~ te ~e~le~e well. ,, T~rari~ suspended. Wait en wireline 14I ' ' cO ' " s~ ~L~ mn~. ar.. 1~_~_ DA~ A~ust 1~, 1~69 , // - . /6 .... , tile~ //NOTE--Report on this for~ is required for each calendar month, regardless of the status of operations, an~ must in duplicate ~th//the Division of Mines & Minerals bY the 15th of the succeeding month, unless othe~ise directed. Form No. P--4 REV. 9-30-6~ STATE O,F ALASKA SUBMIT ~ DEPLICATE OIL AND GAS CONSERVATION COMMITTEE ~VIONTHLY REPORT O,F ~DRILLING AND WORKOVER OPERATIONS WELL WELL __ 2.NAME OF OP~TOR 3.)~DREss OF OP~TOR - ' , 515 "~" S~ree%~ ~e~e_~ ~-~ 99~1 4.LOCA~O~ OF ~ R~' S.M., ~e~ O~k ~et, ~tfe~ ~Te~ ef ~y: ~' ~, 1~ ~' ~o. 31, ~, R~, S.M. 7. IF INDIAN, ALOi l~ OR TRIBE NASIE 8. U/~'IT FA3~M OR LEASE NA-AIE u.R''E 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Sec. 31, T12N; R~I, $.M. ~. PEPd~IT NO. REPORT TOTAL DEPTH AT: END OF MONTH, CH-A/WG~S IN I-IOLE SI~E, CASING ~ CElV[ENTING JOBS INCLUD*IN~ DEPTH SET A3~ VOL~ USED, PERFORATIONS, TESTS ANT) RESULTS, FISHING JOB~, JUNK LN HOLE A_ND SIDE.T]~ACKED HOLE AD ANY 'OTHER SIGNIFICA/XTT CPLAiWI~ES IN HOg ~DNT)!TIONS. 6-~0-69 Tem~e~ Suspen4e~. Palled t=bing, ne ~ica%ie~ of leak. Reran t~bing and tested, O.K. A%%e~ed te se% ~l~g ia ~ Fmnd~i, ceal~ ae~ Lest d~ i~ %ubing. ~is ~iled sand and Bareid ~led Bareid and wa~er %e &582'. 5-/3--69 P~aped ~ im ann~s and eat thra ~drel. Recevered m~ddy wa~er for 15 mi~es, ~hen cleared ~p. Started injecting gas into aam~l~s. ~lew water fre~ anm~lus and ~ub~g fer 15 minu~es. ~bimg ~ressare ~ .~. 6-/4-69 w/drive ~ailer, hit bridge ~531'. 9reve bailer %e ~26'. ~IH w/ S%ar ~i%, dreve thru bridge am~ drepped te ~65'. 6-1~-69 l~mped ~ in annulus %hru Ma~rel at ~391'. Oiro~lated u~til cleaned up. O~ned X0 sleeve at M)~O'. O~ned gas on anmulus and kicked well elf. ~[H w/~md bailer and cleaned cut smad a~d Barite te Injected water in ama, lus, retrieved dammy frem x-nipple at Tried te reset in ~rel at ~391', drepped, fishe~ eut, attempted te set d~, ~id net set. Attempted te retrieve du~ay, ne recevery. Bailed m~t ama ~ater ~o ~707'. 6-27-69 WI~ & recovered X-plag & dm~r. Set d~ in Mandrel $ &395'. While at%em~t~ to set d~, dmm~ drepped ~ff &-fell te 'Q' nipple · /+719' · 6-2~/3049/~ l~u,~ 3 runs w/re%ri.~ t(~l, ~? recovery, Teap~rarily suspended. ~4. ! hereby certii~ tl'J~h~ foregoin~ is true~~=~ct .. ~ [ ! - ,,, - ..... !1~ . wi~tbe Division of Mines & Mi.era~FT$£h~¥~the s,,cceedi.g mc.th..nless otherwise directed. Form No. P--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATIO'N COMMITTEE MONTHLY REPORT O'F DRI. LLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Phi 1~ ps Petreleum Oempar~ 3. AD~ESS OF OPERJ%TOR SUBMIT IN DUPLICATE 515 nD" Strget; A-c~_ara_~e: A.~lnal~a 99~1 4. DCA~ON OF W~ $~face: ~g 3, $1et 6, ~53-' F~,~ 1091' ~, ~c. 6, T~, R~, S.M. Ne~h C~k I~et, P~tfe~ "~nek". Tep ef Pay: 160' F~, 15~' ~' ~c. 31, T~, R~, $.M. AP1 NUA~ER/CAL CODE OKG AP1 50-283-20025 REL LEASE DES'.G~ATION A.~"D $~IA~ NO. ADL-,,'I 7,58c~ FILE , 17. IF INDIAN, ALOTfE~ OR TRIBE NAME 8. UNIT,FA.RM OR LEASE NAME Nerth Oeek Inlet Unit 9. WELL NO. #1-5 10. FIELD A_ND POOL. OR WILDCAT Nerth ~eek Inlet 11. SEC., T., R., M., (RO"CrOM HOI.,E OBJECTZV~ Sec. 31, T12N, R~, $.M.' 12. PERMIT N'O. 69-32 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANG~ IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DI~PTH SET AN~ VOLUMES USED. PERFOP, ATIONS, TESTS A_N'D RESULTS. FISHING JOBS. JUATK IN HOLE A_ND SIDE-TPLACKED HOLE AND A~Y OTHER SIGNIFICANT CI-IAN,~ES IN HOL~ CONDITIONS. 5-31-69 PBTD ~59' WOR te p~ %bg for leak Dri~ 9-5/8" hole te 812~', Ran IES, FDO, G-R and SNP legs Rau 7" O.D. cas~ and set at 8,096.97' and cemented w/502 sx T~ "~. cement mm~ w/122 bbls prehydrated 10% Diacel "D" wtr & 2% ¢~. ~ stage cemented w/850 sx Type "G" cement nmi w/lO5 bbls 2% cc wtr. Squeezed leak i~ cas~ belew RTTS reel at 5123+' w/llO sx Neat cement w/15~ bbls 2% cc. ~-69 Perferated fellewiug intervals w/&" ne Plug gan, & abets/ft., .58" heles, ~ & SNP Measurements: ~.5~'-~515', &535'-~10', ~630'-~5~', &770'-4~785', ~832'-~862', ~890'-4+915', 50~2'-5052', 5~9'-51~A' 5773'-5778' 6267'-6282 t 6784'-6789' 737& '-738& ' , 5196'-5206', 5220'-5230', 5561'-5571', 5709'-571A', , 5782'-~', 5825'-5835', 58&0'-5855', 5922'-5932r, , 6~'-6116', 6163'-6173', &180'-61~0', 6196'-$206', , 63~6'-6356', 6k35'-6~5', 6680J-6685', 6752'-6762', , 699i'-7~1', 7095'-711~', 72~6'-7296', 7316'-7321', · 7526"-7536'. Ran 3~" and &" cemb tbg str~ set Ran &-pt. tests, perf's &770'-753$'. #i-F & hfs en 3/&" chk, ~ 1760 PSI, Temp TOFF, FARO 2~,986 MCFD. #2-F 2-3/& hrs en 5/8'.c~,~ FTP 1920 PSI, Temp 73 F, FARO 19,57~ MCFD. #3-F 3 _hrs en chk, FTP 19~2 PSI, Temp 72CF, FARO 12,351 ~CFD. #&-F hfs en 3/8" c~, FTP 1996 ~, Temp 72CF, FARO 6,885 HCFD. WOR te ~ tbg fer leak. ~'~,-,) ~'~.. ,~-'~~ ~i,t. Office ~r. o~ ~,me ~, ~969 //0TE~Report on tills form is rbq~red for each Calendar month, regardless of the status of operations, an~ mu~t ~ file~l io duplicate wit~tbe Division of Mines & Minerals bM the 15th of the succeedin~ month, unless otherwise directed. FILE ANCI.,i~BAGE Form No. 1:--4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS HWK~ REL 2. NAME OF OPgRATOR Phillips Petroleum Company 3. ADbRESS OF OPEAIATOR 515 "D" Street~ Ancharage, Alaska 99501 FILE ~, 4. LOCATION OF WELL Surface: Leg 3, Slot 6, 1253' FNL, 1091' FWL, Sec. 6, TllN, R9W, S.M. North Cook Inlet, Platform "Tyonek". Top of Pay: 160' FSL, 1550' FWL, Sec. 31, T12N, Rgw, S.M. AP1 NUAIERICA/. ~ODE API 50-283-20025 LEASE DESIGNATION AND SEEIAL NO. ADL-17589 7. IF INDIA]q, ALOTT'EE OR TRIBE NAME 8, UNIT,FA/RA~ OR LEASE NA~ME North Cook Inlet Unit 9. 'WELL NO. 10. FIFJ~D A-ND POOL, OR %VILDCAT .. 5Tn~+.h ~.nnk Tnlet 11. SEC., T., R., M.. (BO'I~OM HOLE oB,rF, crn~ Sec. 31, T12N, R9W, S.M. PEP.MIT NO. 69-32 13. REPORT TOTAL DEPTH AT END oF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CKMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AiTD RESULTS. FISH/NG JOB~, JLrNK IN HOL4g A~ND SIDE-TIR-%CKED HOLE AND A~NY OTHER SIGNIFICA/XTT CHA_N~F~ IN HOL~ CONDITIONS. g-30-69 TD 7218, Drill 9-5/8" hole 4-16-69 Spud 15" hole g-17-69 Drill !5" hole and ream to 22" to 670' 4-18-69 Set 16" csg at 6L~3' and cemented w/g50 sx Class "G" cement mZxed w/2OO prehydrated Gel water, tailed in w/125 sx Class "G" cement w/15 bbls 2% cc water. g-19/22-69 Drill 15" hole to 2625' twisted off, %~IH w/overshot, caught fish, started out of hole, hole tight, worked pipe out, reamed hole. 4.+-23/2&-69 Set 10-3/h" casing at 2571'. Cemented w/640 sx Class "G" cement w/8#/bbl prehydrated Gel salt water, tailed in w/!25 sx Neat cement w/2% cc salt water. 4-25-69 Drill 9-5/8" hole to 7218'. RECEIVED MAY ? t96.ct DIVISION OF OIL AND GAS ANCHORAGE · S~G~m ~ /~. ~)=TL~ District Office Mgr DA~ ~y 6, 1969 ' ~' 'F -- ........ ~0TE--Repon on %~is form is reqUi~ed for each calendar moath, regardless of the status ol opera%io~s, aha must '~ filee in d~plicate with the Division of ~i,es & ~i,erals bF the 15%h of De succeeding mo,th, unless othe~ise directed. PHILLIPS PETROLEUM COMPANY ANCHORAGE, ALASKA 99'~0i ~ 515 "D" STREET EXPLORATION AND PRODUCTION DEPARTMENT April 22, 1969 Mr. F. J. Keenan Director, Division of Lands State of Alaska Department of Natural Resources 3~ 6th Avenue ~nchorage, Alaska Re: Spud New Well- NCIU ;~A-5 ~ Dear Sir: This is to notify you that the subject well was spudded on State Leas~. ADL-17589 at 11:50 A.M., ~-16-69. The surface location of this well is at 1253' FNL, 1091' FWL, Sec. 6, TllN, RgW, S.M. We plan to drill this well directionally to a bottom hole location of 2550' FSL, 2330' Y~L, Sec. 51, T12N, Rgw, S.M. Very truly yours, PHILLIPS PETROLEUM COMPANY ~ohn B. Gipson, ~ District Office Manager JBG: jo cc: Mr. T. R. Marshall, Jr. (1) Division of Mines & Minerals Department of Natural Resources Stabe of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 .LB OKG ~ KLV -.-~'--"~"'- HW~ ~ REL FILE ~!¥1510N OF o11. AND GAS OKG ~ at 12~' F~~, 1091' ~, See. 6, TI~, Xc~, $.a. DIVISION OF 01[ AND GAS ANcHo~/~GF' FORM SA- I B /~. MEMORANDUM State of Alaska FROM: DATE SUBJECT: FORM SA- I B _ MEMORANDUM TO: r- State of Alaska FROM: SUBJECT~ Form P~I REV. 9'30-6? ' SUBMIT IN TRIPL1 g (Other instructions o,. reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION ,COIMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1R. TYPE OF WORK DRILL [] DEEPEN I--I PLUG BACK I-] b. TYPE OF WELL SINGLE ~-] MULTIPLE ~_~ OIL [-~ OAS ~ OTHER ZONE ZONE WELL WELL 2. NAME OF OPERATOR philips Petreleum 3. ADDRESS O~F OPERATOR 515 "D" Street, Ancherage, Alaska 99501 4. LOCATION O~F WELL Atsurface ~g 3, Slet 6, 1253' FNL, 1091' I~'L, Sec. 6, TllN, RgW, S.M. Ne~h ~k I~et, P~tfe~ ,~nek". At pro~sedprod, zone 160' ~, 15~' ~, ~c. 31,-~, R~, S.M. 13. DISTANCE IN MILES AND DIRECTION FXOM~NEAREST TOWN OR.POST O~'~'ACE* . 10.5 mql_a_ -'~_~ ef-Tyenek,.-A~~ . - ~. ~D ~O~A=O~: H~~ ~ate ~de ~ Bi-1 TYPE ' Surety and/or No. 15. DISTANCE FROM PROPOSED~ ' ' ~ v ' .~ .' - ]16. NO. OF A~ IN LEASE LOCATION TO NEAREST PROP~TY OR LEASE L~E~-~.-_ ~- (Also tO nearest drig unit, i~ any) 18. DISTANCE FROM PROPOSED LOCA~ON~ '' ' " ~ 9~ PROPOS~'D~r~ ' TO N~A~EST W~LL DmLL~N~, COM~L~mD., OR APPLI~ FOR, ~. ' '' ' ~1. E~V~WIONS (Show whether D~, ~T, G~, etc.) 23. - -' ' - ' ' ' 'PROPOSED CASING A~qD cEMENTII~G~ROGRAM 6. LEASE D]~2~IGNATION ~ ~tAIAL NO. L IF INDIAN,' .,a~I.&,OTTEE OR 'I~J. Bg N.P~KE 8. UNIT~ FARM[ OR LEASE NA-ME Ner~h Ceek Inlet Unit 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT l,l®~q~h ~ek Inlet 11. SEC.., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T12N~ RgW~ 1~.. [7~ NO. ACRES ASSIGNED TO THiS WELL 20. ROTARY OR CABLE TOOLS Re%arT ,.2~-~APPROX, DATE WORK WILL START~ .-2o.-69 SIZE OF HOLE SIZE OF C~SING :~wEIGHTpER-FOO~' GRADry' ' <' SETTING~DEpTH '" ' ' ' QUANTIT' OF CEMENT ~,, ~ ~., ~ ~ N-~ 6~ ~ Cire~te ~e' '~face 1. Deviatien re~d:te_reach ~-fre~ permanentptatfer~. 2. There ar~ ne~e~feete~ o~era~ors. · ~ ~. ~ ~l~cifieat±e~ attached. k. Intervals of imtere~ ~ be perferate~ amd may be stimmuta~ed. * Refer to ~ate ef. ~oh,, ~S~ ~1 & ,~s 0emservatie~ ~ew~%tee, ~nservatien 0r~er #~, dated 6-8-67 aha #68, ~ated 12-7-68. IN ABOVE S~p~f'E DESCRIBE PROPOSED. PROG~A.M[: If propo.~.l is.to dee~n or p~g ~k: give ~ on presen~ p~du~ive ~ ~d propo~ r~ pr~du~ive ~e. If pro.~ m to ~fll or d~n ~e~_o~lly, g~ve pe~meno ~a~ on ~bs~ace ~t~ ~d meas~ ~d ~ue ver~ ~p~. Give blowout/eventer progr~. hereby c~rtif~at t~ Forego~ is ~d ~rre~ DAE .lp~ 3, 969 :~ Di~riot Office ~r. sp or S~te office u~) (This CONDITIONS OF APPROVAL, IF ANY: SA1ViPLES AND COP~ CHIPS RF~UIR~D [DIRECTIONAL *See lnmucfi°ns On Reveme SiJe ~PROV~DA~ April Il, 1969 DX~eeto~ Div. of 0il & Cas nA~ April 11, 1969 · iiii - i i i i iii111 ........ ii i i i ii i .401. /8 ~',.,¢5 ' ~ A-4 (RB.H.L.) -12 7 ~2 ! pROPOSED B.H.L. N,C.I, Un. No. A-5~ (2560'FSL & ~'330*FWi. of 8ea. ~1-19N-~W ~.M. ) 5 8 GRID .1:~ 18 Il Il Il Ill Il I I I Il ........... Illllllll ..... Illlllll Il I I PHILLIPS PETROLEUM COMPANY 515 "D" STR£ET ANCHORAGE ,ALASKA PLAT OF NORTH COOK INLET UNIT TYONEK PLATFORM . DRWi Ni'iiN* ~' P°Welll ij ii I $CALE: I". 2000' · Leg 4~ - .- North Cook Inlet Unit A-5~ Leg !. "~' .N.C.,. Un. ~ . · . _ · ' .... ' ~ ~+' ~ PHILLIPS PETROLEUM COMPANY , 515 "D' STREET ANCHORAGE,ALASKA NORTH COOK. INLET TYONEK PLATFORM COOK INLET1 ALASKA NOTE: Using PLATFORM NORTH, Slot No.! will be the furthest platform North slot in platform North- west quadrant of any legl Slots are numbered I thru 8 in a counter-clock-wise direction. ~L~J~FORM LOCATION; Sec. 6'llN-BW I DAT~="' 4 -3"69 ])RW__N? N: ~,. p.ow.i! ........ ~ .,. I NOT YO SCA.I.E..,.', · HOOm'P ( i HYDRIL GK ] ! 1' SERIES 1500 · · ~.i~---. - ] CHOKE MANIFOLD ',~--x2~_~,,~, ~o~. ~.~~= ' e~n .'.... . ~--.._~.. - ." . / onL6 . / RAN~-TNPE BOP SERIES 1500 ~ ' ~ . '? ~ · . ., , NOTE: 'Double Preventers are used with flanged side outlets for choke manifold ,, and fillup line co~mections. · FOR N,C.I.U. DOUBLE PREVENTERS PLATFO R M G 4" SERIES 1500 VALVE G 2" SERIES 1500 VALVE G 2" MUD PRESSURE GAUGE ON 4"X ~'X2' SERIES 1500 STEEL TEE 4" SERIES 1500 X 2" SERIES 1500 STEEL CROSS G £"SERIES 1500 poSITIVE CHOKE G 2" SERIES 1500 ADJUSTABLE CHOKE PHILLiPS PETROLEUMuu,~,i."""'°"'i.~NY PRODUCTION DEPARTMENT 5000 PSI WORI(ING PRESSURE BLOV'/OUT , R~:.VENTER HOOK-UP (SERIES 1500 FLANG,.:.-S OR BETTER) t, ~' 56 31 6 975' I 6 12 7 LEG Ng. I LAT. 61° 04' 36.38" LONG.150° 56' 55.65" Y= 2,586,731 X= :551,995 FROM NW. COR. ~250' SOUTH I~ 975' EAST. '~'~'~ N 31 32 TilN 6 5 mm mmm mm m mmmmmmm m m m m mm .o _ . SCA~E ' I"= 1,000' LEG N° 3 LAT. 61u - 6 LEG N°. 4 LEG N°.2 LAT. 61° 04' 56.89" LAT. 61° 04' 35.83" LONG. 150° 56' .54.25" LONG. 1500 56' 54,77'~ Y: 2~586,781 Y= 2,586,674 . ' X=' 352,063 X: 532,036 FROM N.W. COR. FROM N.W. COR.. 1,198' SOUTH I& 1,505' SOUTH I~ · .I,045' EAST. ' 1,018' EAST. NOTE: Plot amended 7AUG 68' to show revised leg numbering', · · 04' 36.54" LONG. 150° 56' 53.59" Y:2,586,724 X= 332,105 FROM N.W. COR. 1,254' SOUTH ~ i,085'. EAST. CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision and that ail dimensions and other details are correct. SUR~V~YOR ~ · NOTE . The location of the platform legs was accomplished by using tria ngu lotion stations BE LUGA,TERRACE,and TYONEK which are all U.S,C.t~G.S. stations. AIl coordinates are Alaska State Plane, Zone 4. NORTH COOK I NLETUNIT PLATFORM FO. PHILLIPS PETROLEUM CO "DATE: 2i JUNE 68 - ~SCALE: I"="lO'O0' - - .'FB. II574 Pp. 11-15 ~,.---ic,,~--icc,.. J.'HG; I ".. Ii~574 F.M. LI NDSEY ~ ASSOC. Land L~ Hydrographic Surveyors ~50~ W. NOR1H~ ~NLIGH~ ~L~,ti ~NARD~ 80X ~ 061 AL, A~KA :- _::. CHECK-LIST FOR NEW ~LL PERMITS l® e 17. 18. Is well to be located in a defined pool .............. , ............ ,..~ Do statewide rules apply ............................................. lat attached : Is a survey p ..,.....,....,....,..,.,....,.., e ' · Is w 11 located proper distance from property line oooo..ooo°oo ...... Remarks Is well located proper distance from other wells .............. ,...,. . Is sufficient undedicated acreage available in this pool ..... , ...... Is well to be deviated ................... , .......................... Is operator the only affected party .,,., ..... ,., .... ,.., .... ,.., .... , approved before day wait Can permit be ten- ..., .... ,..,,..,o, ...... ,. Does operator have a bond in force ......... , ..... , .......... ° ....... Is conductor string provided . g .,, . . . Is enough cement used to circulate°2~°22~2~2~2~ 2*nll i~222 iiiiiiiii'~ --__ Will surface csg° internal burst equal .5 psi/fro to next string W£11 Cement tie-in surface & intermediate or production strings o .... ~ , Will ali casing give adequate safety in collapse and tension .... °'" _ __v --- Will cement cover all possible productive horizons ..... , .......... oo Will. surface casing cover all fresh water zones ...... ~ .............. /~_, Does BOPE have sufficient pressure rating ..o ......... ,o, ..... ,...,., Can this permit be approved immediately ......... ,. o,...,.., ..... ,....___ Approval Recommended: :0 i . '/ Tno~.~,:~, R ::~.:shal, 1, Jr Karl L. VonderAhe Ha'::?"~, i? K.ug].er ?:~ ~,?' Robert E. L rso