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193-103
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-06 PRUDHOE BAY UN PTM P2-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 P2-06 50-029-22388-00-00 193-103-0 N SPT 8593 1931030 2500 179 2756 2600 2552 164 166 168 160 OTHER P Josh Hunt 6/21/2025 This is the Initial MIT-T required by Sundry # 325-097. To be tested to 2500 psi. This is the second attempt after bleeding some gas from the well. This test was a passing test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P2-06 Inspection Date: Tubing OA Packer Depth 145 162 162 159IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622102449 BBL Pumped:0.2 BBL Returned:0.2 Thursday, July 24, 2025 Page 1 of 1 1-Oil producer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-06 PRUDHOE BAY UN PTM P2-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 P2-06 50-029-22388-00-00 193-103-0 N SPT 8593 1931030 2500 155 2738 2505 152 160 165 OTHER F Josh Hunt 6/21/2025 This is the Initial MIT-T required by Sundry # 325-097. To be tested to 2500 psi. This test failed immediately after the 15 minute mark due to dropping under the 2500 psi minimum. At this time they bled the well back and noticed a loss of 0.7 bbls of diesel, gas was also present. I will attach this report to the second test which did pass. Also noted here is the increase in IA & OA pressure after the initial pressure build, only 8 psi on the IA and 5 psi on the OA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P2-06 Inspection Date: Tubing OA Packer Depth 77 149 157IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622101100 BBL Pumped:1.3 BBL Returned:0.6 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P2-06 PRUDHOE BAY UN PTM P2-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 P2-06 50-029-22388-00-00 193-103-0 N SPT 8593 1931030 2500 252 470 545 541 166 472 473 470 OTHER P Josh Hunt 6/21/2025 This is the initial MIT-IA required by Sundry # 325-097 to be tested to 2500 psi. This was a passing test however, there was a 75 lb increase in the tubing pressure over the first 15 minutes of this test. Although this was a passing test I do believe there is still slight communication between the tubing and IA on this well. It could possibly be thermal but I do not usually see that much of an increase of tubing pressure in these situations. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN PTM P2-06 Inspection Date: Tubing OA Packer Depth 142 2745 2684 2665IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622103255 BBL Pumped:3.3 BBL Returned:3.3 Thursday, July 24, 2025 Page 1 of 1 1-Oil producer 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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 T40716PBUP2-06 50029223880000 193103 6/19/2025 HALLIBURTON Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' 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: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' PBU P2-06 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-103 50-029-22388-00-00 12103 9232 26 4342 12036 12010 20" 10-3/4" 7-5/8" 9177 54 - 80 52 - 4394 51 - 12087 54 - 80 52 - 3666 51 - 9223 11449, 11685, Unknown None 5210 8160 11600 - 11830 3-1/2" 9.2# 13Cr80 49 - 11429 8931 - 9073 4-1/2" Baker SABL-3 Packer 11395, 8796 11103, 11395 8593, 8796 Dave Bjork for Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY, PT MCINTYRE OIL ADL 0034622 49 - 8819 7-5/8" x 3-1/2" IA from 9594 - 11072'MD Squeezed 48.5 bbls of 15.8 ppg Class G cement into IA through retainer @ 11057' MD to 2215 psi 115 148 4260 3553 854 714 1536 1631 339 385 325-097 PT MCINTYRE OIL 3-1/2" Baker S-3 Packer 11103, 8593 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3-1/2" CAMCO TRDP-4A SSSV 2207, 2093 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.07.21 10:09:38 - 08'00' David Bjork (3888) By Grace Christianson at 12:24 pm, Jul 21, 2025 RBDMS JSB 072525 DSR-7/21/25JJL 8/12/25 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P2-06 IA Cement Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-103 50-029-22388-00-00 ADL 0034622 12103 Conductor Surface Intermediate Production Liner 9232 26 4342 12036 11128 20" 10-3/4" 7-5/8" 8611 54 - 80 52 - 4394 51 - 12087 2250 54 - 80 52 - 3666 51 - 9223 11685 , unknown 2480 7020 11128 5210 8160 11600 - 11830 3-1/2" 9.2# 13Cr80 49 - 114298931 - 9073 Structural 7-5/8" Baker SABBL-3 , 11375 , 8783 3-1/2" Baker S-3 , 11103 , 8593 3-1/2" CAMCO TRDP-4A , 2207 , 2093 Date: Bo York Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907) 903-5990 PRUDHOE BAY 3/5/2025 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-097 By Gavin Gluyas at 9:02 am, Feb 21, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.02.21 07:18:14 - 09'00' Bo York (1248) * AOGCC Witnessed MIT-T and MIT-IA to 2500 psi post-cemented IA initially and every 2 years thereafter. * CBL identifying cement quality and TOC in IA. SFD 2/26/2025 DSR-2/24/25 X JJL 2/25/25 10-404 *&: 2/26/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.26 09:32:33 -09'00' RBDMS JSB 022625 P2-06: IA Cement Page 1 of 10 Well Name:P2-06 API Number:50-029-22388-00 Current Status:Shut in Well / Not Operable – PC Leak Permit to Drill Number:193103 Estimated Start Date:March 5, 2025 Rig:SL/EL/CT Regulatory Contact:Carie Janowski Estimated Duration:5 Days First Call Engineer:Michael Hibbert Cell Number:907-903-5990 Second Call Engineer:Jerry Lau Cell Number:907-360-6233 Brief Well Summary: P2-06 was drilled and completed in 1995 with 150’ of perforations and gas lifted with moderate results. The well was fracture stimulated with a 37k frac in mid-1995 with good results. Production improved from ~1000 bopd to 3000 bopd. After a shut-in period the well was POP’d in 1997 with degraded productivity. A pressure build up indicated no frac seen in communication with the wellbore (well appeared unstimulated). A refrac was pumped in the fall of 1998 with 134k pounds. The frac propagated into water and the stimulation was a failure. A WSO gel squeeze was performed but the well remained uncompetitive. The well was made non operable in Oct 1999 due to a failed SSSV. A tubing swap RWO was executed in April 2000, but the well almost immediately went nonoperable due to the tubing chem cut penetrated the PC at 10,646’ with a LLR of 7 gpm at 3,000 psi. The well passed a MIT-T to 3,294 psi on 8/2/24. The well was POP’d UE from 6/7/24-7/30/24 for economic evaluation. The well produced at 190-350 IOR. Objective: The objective of the IA Cement job is to restore production casing integrity. Cement will be circulated down CT and up the IA through a cement retainer/open GLM. Cement column length in the IA is planned to be ~1400’ MD. The proposed TOC in the IA is ~9,700’ MD (7,513’ TVD). Projected TOC will be 3,848’ TVD below the SC shoe at 3,665’ TVD and 2,383’ TVD deeper than the estimated top of UG4 formation at 5,130’ TVD (per AOGCC 736 - Rule 2 TOC must be at least 1,500’ TVD below the casing shoe and no shallower than 500’ MD above the UG4 formation top). The Proposed TOC would leave 1400’ of cement above the packer. Current Bottom Hole PSI:3499 psi on 5/13/24 Max. Anticipated Surface PSI:2,250 psi – stacked out with lift gas Last Shut-in WHP:1450 psi – 8/1/24 Min. ID: 2.812” @ 2,007’ – SSSV – Min ID on WBS is in the tubing tail that was cut and dropped into the liner Max. Deviation:55 @ 11,949’ MD H2S Concentration:64 PPM – 7/14/24 Well Integrity Information: Tbg: Passed MIT-T to 3,294 psi on 8/2/24. IA: PC leak @ 10,646’. Failed CMIT with LLR of 7 gpm @ 3000 psi. MIT-OA: No test PPPOT-T: 1/2/2001 – 5,000 psi (passed) P2-06: IA Cement Page 2 of 10 PPPOT-IC: 1/28/10 – 3,500 psi (passed) Well Completion Information: Wellhead: FMC, Size = 13-5/8” Tree: CIW, RWP = 5000 psi, 4-1/16” SVLN: 3-1/2” CAMCO TRDP-4A, ID = 2.812” @ 2007’ GLM: 6 Stations, 3 live valves in #1, #2 and #3 and a SO in #4. Stations #5 and #6 are dummied Production Pkr: 7-5/8” x 3-1/2” Baker S-3 Existing Casing/Tubing Program: String Pipe #/ft Grade Connection Top Bottom ID Surface Csg.10 ¾”45.5 NT-80 BTC 0 4,394’9.953” Prod. Csg.7 5/8”29.7 13CR80 0 12,087’6.875” Tbg.3-1/2”9.2 13CR80 NSCT/BTC 0 11,429’2.992” Wellwork Procedure: Slickline/Fullbore: 1. Run flapper checker to SSSV and verify open. 2. Drift for upcoming EL step (NS 3.5” CBP is 2.73” OD), so drift with ~2.75” down to 11,100’ min. 3. Pull live GLVs and dummy stations #1-#4. 4. MIT-T to 3000 psi. 5. Pull GLV#6 and leave open. 6. Pull PX plug from 11,128’ 7. Drift and tag to ~11,685’, pump a HOT B&F to cleanup any tags/tight spots in 3-1/2” tubing if needed. Drift for upcoming EL work - confirm that 2.73” OD drift will make it to 11,100’ at a minimum, but preferably out the tubing tail. 8. RDMO. E-Line/ Fullbore: 1. Set 3.5” CBP @11,090’ in 10’ pup below GLM #6. 2. RU to take returns from IA to tank or flow line. 3. RU fullbore to circulate tubing and IA for upcoming IA cement. 4. Pump the following down the tubing taking returns from the IA at a minimum rate of ~3 bpm (max WHP of 2500 psi) a. 140 bbls of diesel b. 100 bbls of water/surfactant wash c. 180 bbls of inhibited 1% KCL (order packer fluid from MI or Halliburton) d. 54 bbls of diesel 5. After circulating in the final amounts above close in IA and complete a CMIT-TxIA and confirm a LLR of 7 gpm at 3000 psi 6. RDMO Coil: *Note design adequate thickening time based on CT size with consideration of placing cmt in IA P2-06: IA Cement Page 3 of 10 1. RU CT with ability to measure returns from the IA. This will help track TOC. 2. Pressure test coil connector and CT to 4500 psi in anticipation of potential high circulating pressures during cement job if using 1.5” CT. Preferably pump cmt job with 1.75” or 2” CT. 3. MU 3.5” alpha 1-trip cement retainer. RIH. 4. Tag CBP at 11,090’. Pull up 30’ and set retainer in first full joint of 3-1/2” tubing above GLM #6 @ 11,060’. Call OE to discuss this retainer set depth if needed. 5. Establish circulation down the coil tubing and up the IA to tanks. Verify 1:1 returns. Verify acceptable return rate before mixing cement. Verify CTBS is shut in. Monitor WH pressure throughout job. 6. Pump cement schedule: a. Spacer – 5 bbls b. 15.8 ppg Class G Cement – 49 bbls pumpable c. Spacer – 5 bbls d. Displacement – Based on coil volume. 7. Keep track of returns from the IA. Note bbls returned to indicate cmt losses through leaking production casing (known LLR of 7 gpm @ 3000 psi). 8. With 1.5 bbl left in CT stop taking returns from IA and attempt to down squeeze ~0.5 bbls through leaking production casing leak. Ensure sufficient thickening time remains. Max pressure 2500 psi. 9. With ~0.5 bbl left in CT shutdown and pull-release from the retainer. Note WH pressure after un-stinging to verify retainer/check is holding. 10. While holding a minimum of the final WH pressure on the CTBS lay in remaining ~0.5 bbl of cmt on top of the retainer. 11. POOH while pumping pipe displacement. 12. Wait on cement. 13. Mill retainer, cement, andCBP and push into liner. 14. RDMO. Slickline and Fullbore: Wait on Cement ~10 days 1. Memory CBL log across packer to TOC to confirm TOC in IA. a. CBL to be sent to AOGCC. 2. Set 3-1/2” plug in X nipple @ 11,128’. 3. MIT-T & MIT-IA to 2,750 psi max applied, 2,500psi target. AOGCC to witness. a. Provide 24hr AOGCC notice for witness. 4. If MITs pass pull 3-1/2” plug from 11,128’. 5. Set Gas Lift Valves as per GL Engineer. 6. Turn well over to Operations. Well Integrity/DHD: 1. Reclassify well as Operable after passing MITs and AOGCC approval. 2. Flag well as falling under CO 736. 3. Update integrity management system to include an AOGCC witnessed CMIT-TxIA and MIT-T to 2,750 psi max applied, 2,500 psi target every two years. Attachments: 1. Current wellbore schematic 2. Proposed wellbore schematic P2-06: IA Cement Page 4 of 10 3. P&A proposed schematic 4. Tie in log 5. Sundry change form P2-06: IA Cement Page 5 of 10 Wellbore Schematic: P2-06: IA Cement Page 6 of 10 Proposed Wellbore Schematic: IA Cement – Designed TOC 9,700’ MD P2-06: IA Cement Page 7 of 10 Proposed P&A Schematic Reservoir Cement Plug Surface Cement Plug P2-06: IA Cement Page 8 of 10 Tie in log:Yellow Jacket Tubing Cut Record 5-May-2024 P2-06: IA Cement Page 9 of 10 ~11,060’ - 3.5” Retainer ~11,090’ - 3.5” CBP 11,072’ – Open Pocket GLM P2-06: IA Cement Page 10 of 10 Sundry change form: Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU P2-06 Cut Tbg Tail Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-103 50-029-22388-00-00 12103 Conductor Surface Intermediate Production Liner 9232 26 4342 12036 11128 20" 10-3/4" 7-5/8" 8611 54 - 80 52 - 4394 51 - 12087 54 - 80 52 - 3666 51 - 9223 11685 , unknown 2480 7020 11128 5210 8160 11600 - 11830 3-1/2" 9.2# 13Cr80 49 - 11443 8931 - 9073 Structural 7-5/8" Baker SABBL-3 , 11375 , 8783 3-1/2" CAMCO TRDP-4A , 2207 , 2093 11375 , 11103 8783 , 8593 Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907) 564-4891 PRUDHOE BAY, PT MCINTYRE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034622 49 - 8829 0 115 0 4260 0 854 0 0 0 339 N/A 13b. Pools active after work:PT MCINTYRE OIL 3-1/2" Baker S-3 , 11103 , 8593 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:31 am, Aug 26, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.08.23 19:47:26 - 08'00' Bo York (1248) DSR-8/26/24WCB 10-3-2024 RBDMS JSB 090324 ACTIVITYDATE SUMMARY 4/23/2024 ***WELL S/I ON ON ARRIVAL*** TAGGED SSSV @ 2007' MD w/ 2.87 CENT RAN FLAPPER CHECKER w/ 2.78'' PINS (good) ***WSR CONT ON 4-24-24*** 4/24/2024 ***WSR CONT FROM 4-23-24*** DRIFT w/ 2.50'' CENT, 2' x 1-3/4'' STEM, 23' x 2.5'' BAILER DRIFT (oal 25') DRIFT CLEANLY TO 11430' SLM LOC X-NIP @ 11425' SLM / 11426' MD & 11375' SLM / 11377' MD **JOB COMPLETE, WELL LEFT S/I*** 5/5/2024 *** WELL S/I ON ARRIVAL*** (WELLTEC TBG CUT) RIG UP YJ ELINE. PT PCE 300 PSI LOW / 3000 PSI HIGH RIH CH 1.435" / 2.375" WELLTEC CUTTER TO 11442' CORRELATED TO TBG PIPE TALLY DATED 01/22/1994 CUT THE TUBING AT 11429.2', CCL TO CUTTING BLADE = 18.0', CCL STOP AT 11411.2' PRE CUT T/I/OA 2250/0/250 PSI, POST CUT T/I/O/= 250/0/250, WELLTEC VERIFIES TATTLETAIL ON SURFACE 4.77" RDMO YELLOWJACKET ELINE JOB COMPLETE ***WELL S/I ON DEPARTURE**** 5/13/2024 *** WELL S/I ON ARRIVAL *** SBHPS STOPS @ 11,332' MD (8,700' TVD), 11,188'MD (8,600' TVD), 11,048' MD (8,500' TVD) FOUND TUBING TAIL @ 11,685' SLM SET X-CATCHER IN X-NIPPLE @ 11,128' MD PULLED RK, DUMMY FROM ST#4 @ 9,443' MD *** CONTINUE WSR ONTO 5/14/24 *** 5/14/2024 *** CONTINUED WSR FROM 5/13/24 *** PULLED RK, DUMMY VALVE FROM ST#3 @ 8,238' MD PULLED RK, DUMMY VALVE FROM ST#2 @ 7,376' MD PULLED RK, DUMMY VALVE FROM ST#1 @ 4,906' MD SET RK, 16/64" PORT TRO-2,303psi DOME VALVE IN ST#1 @ 4,906' MD SET RK, 16/64" PORT TRO-2,284psi DOME VALVE IN ST#2 @ 7,376' MD SET RK, 16/64" PORT TRO-2,249psi DOME VALVE IN ST#3 @ 8,238' MD SET RK, 24/64" PORT SCREEN ORFICE VALVE IN ST#4 @ 9,443' MD PULLED X-CATCHER FROM X-NIPPLE @ 11,128' MD *** WELL FLOWING ON DEPARTURE *** 6/4/2024 (TFS unit 1 assist Well testers with opening SSSV) Travel to location, Spot in unit ****WSR Continued on 6-5-2024******* 6/4/2024 T/I/O = SSV/90/220. Temp = SI. IA FL (under eval). No AL or flowline. IA FL = 1380' (47 bbls). OA FL @ surface. LRS welltesters in control of well upon departure. 13:30 6/4/2024 LRS Test Unit 6, Begin WSR on 6/4/24, Rate Verification, Unit Move, RIg Up, Pt, Standby, Continue WSR on 6/5/24 Daily Report of Well Operations PBU P2-06 RIH CH 1.435" / 2.375" WELLTEC CUTTER TO 11442' CORRELATED TO TBG PIPE TALLY DATED 01/22/1994 CUT THE TUBING AT 11429.2', () FOUND TUBING TAIL @ 11,685' SLM Daily Report of Well Operations PBU P2-06 6/5/2024 *****WSR Contiinued from 6-4-2024****** T/I/O 100/100/200 (TFS unit 1 Assist LRS well testing) Pumped 30 bbls of Crude down the TBG to open SSSV for LRS well testing. Well left in Well testing control Final WHPS 300/100/200 6/5/2024 LRS Test Unit 6, Begin WSR on 6/4/24, Rate Verification, Cont Standby, POP FLow Well, SI, Begin SB, Continue WSR on 6/6/24 6/6/2024 T/I/O = 260/1480/350. Temp= SI. IA FL (under eval). No flowline. PBGL SI @ CV, 2300 psi. IA FL @ 6105' (1271' above sta# 2, 207 bbls). LRS well testers in control of well upon departure. 16:15 6/6/2024 LRS Test Unit 6, continue WSR from on 6/5/24, Rate Verification, Standby, POP Well,, Continue WSR on 6/724. 6/6/2024 T/I/O= 100/1450/NA. LRS 72 Assist Well Test (WELLWORK). Pumped 22 bbls of crude into the TBG to open SSSV. Final T/I/O= 1450/1450/NA. 6/7/2024 LRS Test Unit 6, continue WSR from 6/6/24, Rate Verification, Continue to flow Well,, Continue WSR on 6/8/24. 6/7/2024 T/I/O = 450/1400/510. Temp = LRS. IA FL. Temporary GL online. IA FL @ 9443' (sta # 4 SO, 321 bbls). LRS in control of well upon departure. 17:30 6/8/2024 LRS Test Unit 6, continue WSR from 6/7/24, Rate Verification, Continue to flow Well, 6 Hr PB WT,, Continue WSR on 6/9/24. 6/8/2024 T/I/O = 480/1440/510. Temp = LRS. IA FL (under eval). PBGL = 1440, online. IA FL @ 9443' (sta # 4 SO, 321 bbls). LRS well testers in control of well upon departure. 6/9/2024 LRS Test Unit 6, continue WSR from 6/8/24, Rate Verification, Continue to flow Well, 12 Hr PBWT, Continue WSR on 6/10/24. 6/10/2024 LRS Test Unit 6, continue WSR from 6/9/24, Rate Verification, Continue to flow Well, 12 Hr PBWT, Continue WSR on 6/11/24. 6/10/2024 T/I/O = 440/1540/270. Temp = 65°. IA FL (under eval). Temporary CNG gas lift RU from P2-08 GLT = 1440, online. IA FL @ 9443' (sta # 4 SO, 321 bbls). LRS well testers in control of well upon departure. SV, SSV, MV = O. WV = C. IA, OA = OTG. 6/11/2024 LRS Test Unit 6, continue WSR from 6/10/24, Rate Verification, Continue to flow Well, , Continue WSR on 6/12/24. 6/11/2024 T/I/O = 440/1540/270. Temp = 65°. IA FL (under eval). Temporary CNG gas lift RU from P2-08 GLT = 1440, online. IA FL @ 9443' (sta # 4 SO, 321 bbls). LRS well testers in control of well upon departure. 13:15 6/12/2024 T/I/O = 440/1600/390. Temp = 68°. IA FL. PBGL online. IA FL @ 9443' (sta # 4 SO, 321 bbls). LRS in control of well upon departure. 14:30 6/12/2024 T/I/O = 470/1570/290. Temp = 54°. IA FL. PBGL online. IA FL @ 9443' (sta # 4 SO). LRS in control of valves upon departure. 6/12/2024 LRS Test Unit 6, continue WSR from 6/11/24, Rate Verification, Continue to flow Well, End WSR on 6/12/24 6/14/2024 T/I/O = 390/1450/340. Temp = 66°. IA FL. PBGL online. Flowline disconnected. 3" Hardline installed for temporary flowline. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 20:00 Daily Report of Well Operations PBU P2-06 6/16/2024 T/I/O = 390/1490/350. Temp = 66°. IA FL. PBGL online. Flowline disconnected. 3" Hardline installed for temporary flowline. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 20:00 6/21/2024 T/I/O = 390/1490/300. Temp = 71°. IA FL. PBGL online. Flowline disconnected. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 20:30 6/25/2024 T/I/O = 380/1460/310. Temp = 72°. IA FL. PBGL online. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 23:00 7/1/2024 T/I/O = 400/1370/280. Temp = 71°. IA FL (every 5 days, OE request). PBGL online. Flowline disconnected. 3" Hardline installed for temporary flowline. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 17:00 7/7/2024 T/I/O = 400/1510/270. Temp = 70°. IA FL (Every 5 days per OE). PBGL online. Flowline disconnected. 3" hardline temporary flowline to P2-08. IA FL @ 9443' (sta # 4 SO). WV = C. SV, SSV, MV = O. IA, OA = OTG. 17:15 7/12/2024 T/I/O = 350/2390/130. Temp = SI. IA FL (Every 5 days per OE). PBGL online. Flowline disconnected. 3" hardline temporary flowline to P2-08. IA FL @ 9443' (sta # 4 SO, 321 bbls). WV = C. SV, SSV, MV = O. IA, OA = OTG. 17:30 7/17/2024 T/I/O = 390/2390/300. Temp = 71*. IA FL (Every 5 days per OE). PBGL online = 2020 psi (source well P2-08). Flowline and S-riser removed. 3" hardline temporary flowline to P2-08. IA FL @ 9443' ( sta#4 SO, 321 bbls). WV = C. SV, SSV, MV = O. IA & OA = OTG. 09:30. 7/22/2024 T/I/O = 390/1430/210. Temp = 68°. IA FL (Every 5 days per OE). PBGL online = 2350 psi (source well P2-08). Flowline and S-riser removed. 3" hardline temporary flowline to P2-08. IA FL @ 9443' ( sta # 4 SO, 321 bbls). WV = C. SV, SSV, MV = O. IA & OA = OTG. 20:00 7/27/2024 T/I/O = 450/1600/440. Temp = 67°. IA FL (Every 5 days per OE). PBGL online = 2100 psi (source well P2-08). Flowline and S-riser removed. 3" hardline temporary flowline to P2-08. IA FL @ 9443' (sta # 4 SO, 321 bbls). WV = C. SV, SSV, MV = O. IA & OA = OTG. 17:00 8/1/2024 T/I/O= 1400/1550/0 Assist S-Line (L&T) Pumped 11 bbls crude to assist SLine in getting down ****Job Continues to 8-2-2024**** 8/1/2024 ***WELL S/I ON ARRIVAL*** RAN 2.84" NO-GO CENTRALIZER TO TAG SSSV NIPPLE @ 2007' MD RAN 2.84" WITH FLAPPER CHECKER PRONG TO SSSV NIPPLE ****CONTINUED ON 08/02/2024 WSR*** 8/2/2024 T/I/O = 698/1533/vac LRS 46 - Assist Slickline (WELLWORK) Pumped 63 bbls of 190* Crude down TBG to assist SL w/ B&F. MIT-T to 3062 psi **PASSED** Pumped 1.5 bbls of Crude down TBG to reach 3294 psi. 1st 15-minute loss of 166 psi, 2nd 15- minute loss of 66 psi, for a total loss of 232 psi. Bled back ~0.2 bbls. SL in control of well upon departure. FWHPs= 480/1525/0 Daily Report of Well Operations PBU P2-06 8/2/2024 ****Job Continues from 8-01-2024**** Pumped 61 bbls Crude to assist SL 8/2/2024 ***CONTINUED FROM 08/01/2024 WSR*** ATTEMPTED BRUSH AND FLUSH W/ T-BIRD UNIT, UNABLE TO WORK THROUGH PARAFFIN AT SSSV AT 2007' MD. SWAP TO LRS HOT TRUCK. BRUSH AND FLUSH TUBING (HOT) DOWN TO X NIPPLE AT 11,128' MD. ATTEMPT TO BRUSH DEEPER, BUT UNABLE TO PASS OVERSHOT AT 11,148' MD SET 2.81" PX PLUG BODY (4 x 3 1/16" ports, =23" lih) IN X-NIP @11,128' MD SET P PRONG (=97" oal), IN PX PLUG BODY @11,128' MD LRS PERFORM PASSING MIT-T TO 3,000 PSI ***WELL S/I ON DEPARTURE*** CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki Subject:NOT OPERABLE: Producer P2-06 (PTD #193103) Shut in post economic evaluation flowback Date:Thursday, August 1, 2024 2:29:03 PM Mr. Regg, Producer P2-06 (PTD #193103) has been shut in and slickline is arriving today to set a tubing plug for secure following 60 day economic evaluation flowback. The well is now classified as NOT OPERABLE and will remain shut in until well integrity is restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, June 3, 2024 12:32 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer P2-06 (PTD #193103) 60 days production evaluation Mr. Regg, Producer P2-06 (PTD #193103) has a known PC leak at 10464’ MD. The well passed an MIT-T on 08/11/23 and AOGCC has granted approval to produce the well with gas lift for up to 60 days to evaluate economics for repair. The well is now classified as UNDER EVALUATION and can be put on production. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Rixse, Melvin G (OGC) To:Oliver Sternicki Subject:20230815 1641 APPROVAL Flow under eval - P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Date:Tuesday, August 15, 2023 4:42:52 PM Oliver, Hilcorp is approved to place P2-06 on gas lift production for 60 days to evaluate production. Steady state annular gas injection pressure combined with liquid level hydrostatic head in the IA is to remain below formation fracture pressure at the PC leak at 10,464’ MD. IA fluid level shots will be taken once gas lift pressure is stable, every 2 days for the first 10 days and then weekly thereafter. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, August 15, 2023 12:09 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Mel, Gas lift header pressure is 2450 psi. Surface AL pressure on the well is expected to be 1620 psi with the well flowing. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Tuesday, August 15, 2023 10:31 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Oliver, What is your GL header pressure? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, August 14, 2023 4:37 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Mel, The pressure exerted on the leak is estimated to be 2,331 psi. Based on our gas lift modelling, the bottomhole pressure in the IA at the orifice while operating is expected to be 2,014 psi. The additional hydrostatic pressure of the Seawater in the IA between the orifice and the PC leak is estimated at 317psi. The PC leak at 10,464’ (8,054’TVDss) is in the Coleville. Based on the Pore Pressure Fracture Gradient reports for Pt McIntyre, the minimum fracture EMW is 13ppg or 5,444psi at 8,054’ TVDss. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, August 14, 2023 2:07 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Oliver, Please describe the exerted pressure at the PC leak in the IA when the well would be on gas lift. Please provide the formation fracture pressure at the PC leak. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, August 14, 2023 1:20 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: P2-06 (PTD# 193103) request to POP under eval with PC leak for up to 60 days Mel, P2-06 (PTD# 193103) is currently a not operable producer that was shut-in in late 1999. At that time a RWO was planned to repair a broken SSSV and prep the well for a coil sidetrack due to it being uncompetitive. The tubing was chem cut and replaced on 4/29/2000. When attempting to pressure test the new completion it was discovered that the tubing cut inadvertently damaged the PC at 10464’ MD, resulting in a failing MIT-IA (7 gpm @3000 psi). The PC leak depth of 10464’ MD was confirmed with an LDL on 5/29/2000. On 8/11/2023 the well passed a non-witnessed MIT-T to 2827 psi and failed a CMIT-TxIA to 2800 psi with a LLR of ~7 gpm. Hilcorp requests permission to place the well online, under evaluation for up to 60 days to measure production flow rates to justify economics for repair of the PC leak. The well is expected to require gas lift to flow. IA fluid level shots will be taken once gas lift pressure is stable, every 2 days for the first 10 days and then weekly thereafter to ensure IA fluid level is not being depressed to the PC leak depth at 10464’ MD. IA pressure will be maintained below MOASP. Regards Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 &LAMED AUG 0 7 2012 Alaska Oil and Gas Conservation Commission 3 333 West 7 Avenue l G I 3 Anchorage, Alaska 99501 6- Subj1 ect: Corrosion Inhibitor Treatments of GPMA PM -2 I Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, L - 77 11/11 "" --/"7-) Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM -2 Date: 04/362012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cemeent pumped cement off date inhibftor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2-03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 -r P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 10.20 6/15/2009 P2 -25 1971110 50029227760000 1,8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2-31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2-33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2 -35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2 -41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2 -46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2-47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 P2-51A Spacing exception Page 1 of 1 • Schwartz, Guy L (DOA) PZ—o` From: Schwartz, Guy L (DOA) ! • /13- (O 3 Sent: Wednesday, February 29, 2012 9:34 AM +1 To: 'Strait, David R' Cc: Warner, Ross L (warnerrl @BP.com); Huber, Kenneth J; Roby, David S (DOA) Subject: RE: P2 -51A Spacing exception (PTD 212 -017) Dave, I discussed the situation with the Commissioner Foerster and she agrees as long as P2 -06 is incapable of flow and there are no plans to produce it you don't need a spacing exemption for P2 -51A. As long as the tubing tail plug stays in place you are in compliance with the spacing rules for Pt McIntyre Pool , the casing leak really doesn't qualify the well as incapable of flow but the plug does by our definition. P2 -06 may be one of the wells that should go in the "suspended" category if you have no plans to flow it again. I noticed on the P2 -06 wellsketch that the wrong PTD is shown .. should be 193 -103 . It appears a sidetrack was planned at one time and PTD approved for this well but never done (P2 -06A ... PTD 200- 029) Regards, Guy Schwartz *Algtittat AR (1 2, Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Strait, David R [mailto:David.Strait @bp.com] Sent: Wednesday, February 29, 2012 8:47 AM To: Schwartz, Guy L (DOA) Cc: Warner, Ross L (warnerrl @BP.com); Huber, Kenneth 3 Subject: P2 -51A Spacing exception Guy, ZMe (BP) are trying to determine if a spacing exception is needed for the proposed P2 -51A well. The ;;roposed TD lies 64' within the same 1/4 1/4 section as the perfs in the P2 -06 well (see attached map). However, the P2 -06 has been off production since 1999 due to a casing leak and is considered inoperable due to the leak. Further, there is a plug in the tubing at 11,442 which renders the well incapable of flow (see attached well schematic). Is a spacing exception needed for this well? Thanks, Dave Strait Pt. McIntyre geologist 564 -4365 «P2Wells_SpacingException.ZIP» «P2- 06.pdf» 2/29/2012 TREE = 4-1/16" CAW SAFETY OTES: WELL REQUIRES A SSSV. 7 -5/8" WELLHEAD = FMC • P2 CSG TBG ARE 13- CHROME TEMP LOG OF ACTUATOR = BAKER C 05/29/0 OUND LEAK IN 7 -5/8" CSG @ 10464'. KB. ELEV = 53.50' CHROME CSG AND TBG. BF. ELEV = NA - KOP = 1000' Max Angle = 54 @ 12000' I 69' I---I 4 -1/2" X 3 -1/2" TBG XO, ID = 3.958" I Datum MD = 11481' Datum TVD = 8800' SS 2007' — I 3 -1/2" CAMCO TRDP SSSVN, ID = 2.812" I GAS LIFT MANDRELS 4-1/2" TBG, 12.6 #, 13CR -80, .0152bpf, ID= 3.958 "I --I 69' S T MD TVD DEV TYPE VLV LTCH PORT DATE 1 4906 4031 44 FMHO DMY RK 0 04/29/00 t I 2 7376 5812 44 TGPDX DMY RK 0 04/29/00 10 -3/4" CSG, 45.5#, NT -80, ID = 9.953" I 4394' 1 3 8238 6423 43 TGPDX DMY RK 0 04/29/00 4 9443 7316 41 TGPDX DMY RK 0 04/29/00 5 10339 8009 37 TGPDX DMY RK 0 04/29/00 Minimum ID = 2.750" @ 11442' 6 11072 8571 44 TGPDX DMY RK 0 04/29/00 PARKER SWN NIPPLE Z Z 11 103 ' --I 7 -5/8" X 3 -1/2" BKR S -3 PKR, ID = 3.875' I I 3 -1/2" TUBING STUB (04/27/00) I--1 11134' I 1 1 i 11128' H 3-1/2" HES X NIP, ID = 2.813" 1 I 3 -1/2" TBG, 9.2 #, 13- CR -80, .0087bpf, ID = 2.992" H 11140' 1 -" 1-_-1 11148' I---I UNIQUE OVERSHOT, ID = 2.905" I I 7 -5/8" CSG, 29.7 #, NT95HS, ID = 6.875" HI 11279' I X X TUBING PUNCH (04/17/00) H 11338' - 11342' I D 1 11377' -I 3-1/2" PARKER SWS NIP, ID = 2.813" I Z g 11395' H 7 -5/8" X 3 -1/2" BKR SABL3 PKR, ID = 3.906" I 1 1 1 11426' H 3 -1/2" PARKER SWS NIP, ID = 2.813" I 11442' HI 3 -1/2" PXN PLUG (04/14/00) I 11442' H 3 -1/2" PARKER SWN NIP, ID = 2.75" I I 3 -1/2" TBG, 9.2 #, 13- CR -80, .0087bpf, ID = 2.992" I—I 11462' I- -/ I 11463' I-I 3 -1/2" WLEG, ID = 2.992" I 11443' I-I ELMD TT LOGGED 01/31/94 I PERFORATION SUMMARY REF LOG: ZDL /GR of 08/17/93 ANGLE AT TOP PERF: 50° @ 11600' Note: Refer to Production DB for historical perf data — SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 4 11600- 11630 0 04/14/00 2-1/8" 6 11600 - 11660 0 04/14/00 2 -1/8" 6 11670 - 11690 0 04/14/00 2 -1/8" 6 11688 - 11700 0 04/14/00 CAUTION: " MISC FISH IN HOLE ". ON 2 -1/8" 6 11700 - 11730 0 04/14/00 — 06/20/99 A 1 -1/2" GLV WAS FOUND 2-1/8" 6 11750 - 11809 0 04/14/00 MISSING FROM STATION # 5. ON 04/28/00 2-1/8" 6 11809 11830 0 04/14/00 DURING RWO, 10 CUTTER BLADES FROM WASHOVER ASSY WERE LEFT IN THE r HOLE ( EACH BLADE IS 2" X 1/2" X 1/8 "). EXACT DEPTH UNKNOWN ? I PBTD H 12010' rvirvtryr�♦ I �������1�1�1�1�1�1���1 7 -5/8" CSG, 29.7 #, 13CR80, ID = 6.875 I-I 12087' DATE REV BY COMMENTS DATE REV BY COMMENTS POINT MCINTYRE UNIT 08/21/93 ORIGINAL COMPLETION 10/31/01 WB /TP SURF LOC CORRECTIONS WELL: P2 -06 04/29/00 RWO 03/19/10 JLW /SV CSG CORRECTION PERMIT No: 2Q0 0290 f• i 3 - 16 3 11/20/00 SIS -IsI CONVERTED TO CANVAS 03/19/10 SV CORRECTIONS API No: 50- 029 - 22388 -00 02/22/01 SIS -MD FINAL 02/18/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 11, TI2N, RI4E 29' FSL & 1046' FWL 10/05/01 CH/KAK CORRECTIONS BP Exploration (Alaska) SEC. 03, T12N, R14E, UM l r3- (o ff • Below 12,898' and 1/4 SEC. 03 P2 -51 A_WP6 c • P2 -06 114114 SEC. 03 P2 -06 Perfs OS/11 /OS ~~~fu~~~~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Weil Jnh S 3' X63 1 - ~~P ~~ 1 nn r)nsrrinfinn flafa RI NO. 4745 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Cnlnr en P2-13 11978463 STATIC PRESS & TEMP 06/03/08 1 12-05A 11963097 MEM PROD PROFILE ~ 06/01/08 1 P2-06 12014018 PRESS & TEMP LOG 06/03/08 1 1 N-14A 12017297 LDL Aj -Ill 06/10/08 1 1 K-12A 11966245 SCMT - a O6/O6/OS 1 1 06-15 11966256 USIT - / 3 06/07/08 1 1 A-13 12031481 USIT %~ - G 06/06/08 1 1 P2-45B 40016680 OH MWD/LWD EDIT '~ - ( ~f ~ 03/13/08 2 1 r~.GnaG r~~.nwvYYLGV\iG nGa,r Clr'1 di .711a1V11VU NIVU rlGl VI'71VIIVl7 VIVG GVYT tHGrl 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~t 900 E. Benson Blvd. ~~,~~~~~ J~IV ~ ~ 2008 Anchorage, Alaska 99508 Date Delivered: ;; ,,, l~ .,c. Alaska Data & Consulting Services 2525 Gambell Street, Su' 400 Anchorage, AK 99503- 38 ATTN: Beth Received by: • • ON OR BEF ORE FW: P2-06 LDL Results Subject: FW: P2-06 LDL Results Date: Mon, 12 Jun 2000 19:24:51 -0500 From: "Stone, Dan M (ARCO)" <StoneDM~BP.com> To: '"AOGCC-Tom Maunder'" <tom_maunder@admin.state.ak. us> Tom J Walker 05/30/2000 08:57 AM To: PRB Problem WelIs/AAI/ARCO cc: CraneLR@BP. com, John W Groth/AAI/ARCO@ARCO, John L Hand/AAI/ARCO, Anthony D Jackson/AAI/ARCO@ARCO, Michael Kasecky/AAI/ARCO@ARCO, Gavinkidd@hotmail. com, Gordon Kidd/AAI/ARCO, Tim J Nelson/AAI/ARCO@ARCO, Leslie B Senden/AAI/ARCO@ARCO, StoneDIV~BP. com Subject: P2-06 LDL Results (Document link not converted) Thanks Jerry. Glad it all went well. The leak depth is within one foot of a chemical cut we made on 4/19 at 10465'. I guess we can say we cut/damaged more than just the tubing. We did get a good MIT to 3000 psi on 4/26 but the casing could have been damaged and let go when we tested the IA on 4/29. Thoughts on that? Any ideas on a fix would be helpful. I guess we could fill up the backside with cement but that would place +/- '/000' over the packer. Has that been done before? Thanks sir, Tom 05/30/2000 07:33 AM PRB Problem Wells PRB Problem Wells PRB Problem Wells 05/30/2000 07:33 AM 05/30/2000 07:33 AM To: Tom J Walker/AAI/ARCO@ARCO, Tim J Nelson/AAI/ARCO@ARCO, Johnny 0 Golden/AAI/ARCO, Anthony D Jackson/AAI/ARCO@ARCO cc: Subject: P2-06 LDL Tom: Our plan appeared to ~,ork on P2-06; the LDL was successful in finding the IA x formation leak @ 10464' md. It took a little longer than t4e had planned but the log results look good. A copy of the log should be in the mail. Call if you have any questions. Jerry Dethlefs, 5102 1 ~f 2 6/13/00 8:38 AM .... -- STATE OF ALASKA -~- ALASKA _AND GAS CONSERVATION COMIV, 'ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. [] Development KBE = 53.50' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Point Mclntyre P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 5247' SNL, 4234' WEL, SEC. 11, T12N, R14E, UM P2-06 At top of productive interval 9. Permit Number / Approval No. 193-103 300-053 3975' SNL, 1238' WEL, SEC. 03, T12N, R14E, UM 10. APl Number At effective depth 50-029-22388-00 3837' SNL, 1386' WEL, SEC. 03, T12N, R14E, UM 11. Field and Pool At total depth Point Mclntyre 3615' SNL, 1446' WEL, SEC. 03, T12N, R14E, UM 12. Present well condition summary Total depth: measured 12103 feet Plugs (measured) Tagged fill at 11820' (06/99) true vertical 9232 feet Effective depth: measured 11820 feet Junk (measured) true vertical 9067 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 280 cu ft Arcticset (Approx.) 80' 80' Surface 4343' 10-3/4" 2821 cu ft PF 'E', 406 cuft Class 'G' 4394' 3666' Intermediate Production 12035' 7-5/8" 600 cuft Class 'G' 12087' 9223' Liner ~:~- ........... Perforation depth: measured 11600'- 11730', 11750'- 11830' ,? . , · ~., __.,! .,~, ;- .... ,-. , ; true vertical 8931' - 9013', 9025' - 9073' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, 130r to 11147'; 3-1/2", 9.2#, 130r80 to 11443' Packers and SSSV (type and measured depth) 7-5/8" Baker SABL-3 packer at 11375'; 3-1/2" Baker S-3 packer at 11103'; 3-1/2" Camco TRDP-4A SSSV at 2007' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~/"~~ Title TechnicalAssistantlll Date Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate~~ Form 10-404 Rev. 06/15/88 Progress Report Facility Pt Mac 2 Well P2-06 Page 1 Rig Nabors 9ES Date 31 May 00 Date/Time 19 Apr O0 19:00-06:00 19:00-06:00 19:00-06:00 20Apr 00 06:00-17:00 06:00-09:00 09:00 09:00-12:00 12:00 12:00-13:00 13:00 13:00-14:00 14:00 14:00-17:00 17:00 17:00-21:30 17:00-20:15 20:15 20:15-20:30 20:30 20:30-21:30 21:30 21:30-22:30 21:30-22:30 22:30 Duration llhr llhr llhr llhr 3hr 3hr lhr lhr 3hr 4-1/2 hr 3-1/4 hr 1/4 hr lhr lhr lhr Activity Move rig Rig waited · Production facilities Removed snow from around well and cellar area. Rig waited · Production facilities Waited on removal of flow line and well houses (from P2-06 and nearby wells) and setting BPV. Held Pre-spud meetings and weekly safety meetings with both crews. Reviewed Nabors procedures for applicable upcoming operations. Cleaned and serived rig. Move rig (cont...) Rig waited · Production facilities (cont...) Waited on removal of flow line and well houses (from P2-06 and nearby wells) and setting BPV. Held Pre-spud meetings and weekly safety meetings with both crews. Reviewed Nabors procedures for applicable upcoming operations. Cleaned and serived rig. Resumed operations Rig moved 30.00 % Blow down pits and move same, shop and sub base (derrick up) off of well P2-54. Tight pad and high winds hampering move. Rig off station Installed Additional services Lay mats, herculite. Equipment work completed Rig moved 80.00 % Spot and level sub base At well location - Re-spud location Rig moved 100.00 % Build berms, close up cellar, lay safety matting. At well location - Re-spud location · **ACCEPTED RIG 17:00 HRS, APRIL 20, 2000*** Wellhead work Rigged up Surface lines Install secondary annulus valve, and to tree for circulation take on 200 bbls 9.9 ppg NaC1 brine. Equipment work completed Tested High pressure lines Pressure test completed successfully - 2200.000 psi Bleed down well Inner annulus pressure 1150 psi, tubing pressure 550 psi. Bleed tubing through choke / gas buster to 150 psi, annulus fell to 1050. Begin bleeding ann. /~~~7/8~ugh choke, opened al oWi~began (~. _ -~ witnessed crude oil discharge fr/gas buster. Began precautionary measures Roughly 3/4 gallon of crude mist resulted in +/- ) ~ 12-ft radius spray onto snow on pad. Fluid system Cleared Mud/gas separator Cleaned affected area with shovels, put snow in slop tank for disposal to Pad 3 (class 1 waste). Rigged up bleed trailer directly from well head. Equipment work completed Progress Report Facility Pt Mac 2 Well P2-06 Page 2 Rig Nabors 9ES Date 31 May 00 Date/Time 22:30-06:00 22:30-06:00 22:30-06:00 21 Apr 00 06:00-07:30 06:00-07:30 07:30 07:30-11:30 07:30-11:30 11:30 11:30-16:30 11:30-12:30 12:30 12:30-14:00 14:00 14:00-16:30 16:30 16:30-19:30 16:30-19:30 19:30 19:30-21:30 19:30-21:30 21:30 21:30-06:00 21:30-22:30 22:30 22:30-23:30 23:30 Duration 7-1/2 hr 7-1/2 hr 7-1/2 hr 1-1/2 hr 1-1/2 hr 4hr 4hr 5hr lhr 1-1/2 hr 2-1/2 hr 3hr 3hr 2hr 2hr 8-1/2 hr lhr lhr Activity Wellhead Bleed work down well Bled gas through bleed trailer: 175 psi on annulus @ 06:00 hrs, 75 psi tubing. Bleed down well Continue bleed down well to bleed trailer until 100 psi an annulus. Switch to choke and bleed remainder through gas buster. Final tubing and annulus pressure = 0. Wellhead work (cont...) Bleed down well (cont...) Continue bleed down well to bleed trailer until 100 psi an annulus. Switch to choke and bleed remainder through gas buster. Final tubing and annulus pressure = 0. Completed operations Fluid system Circulated at 10507.5 ft Pump away 128 bbls 9.9 ppg brine before returns, continue circulating 2-3 bpm one full well volume. Monitor well - static. Hole displaced with Brine - 100.00 % displaced Wellhead work Installed Hanger plug Blow down lines, install TWC and test to 500 psi from annulus. Equipment work completed Removed Xmas tree ND tree and adapter flange. Inspect tubing hanger running threads (goog) and cycle LDS. Terminate control line. Equipment work completed Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Test BOPs 250 / 3500. Change out bonnet seal - bottom gate. Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug RU DSM lubricator, attempt to pull TWC - could not latch due to sand in profile. PU single joint of DP and flush TWC profile. Rig up and pull TWC. Equipment work completed Pull Tubing, 3-1/2in O.D. Installed Tubing retrieval string Make up landing joint XO on DP joint. RU casing tools and Camco control line spooling unit. Completed operations Removed Tubing hanger Pull tubing hanger, observe well, fill 7.5 bbls, laydown LJ and tubing hanger. Equipment work completed Progress Report Facility Pt Mac 2 Well P2-06 Page 3 Rig Nabors 9ES Date 31 May 00 Date/Time 23:30-00:00 22Apr 00 00:00 00:00-03:30 03:30 03:30-04:00 04:00 04:00-06:00 04:00-06:00 06:00-15:00 06:00-14:30 14:30 14:30-15:00 15:00 15:00-06:00 15:00-16:00 16:00 16:00-19:00 19:00 19:00-03:00 23 Apr 00 03:00 03:00-05:15 05:15 05:15-06:00 05:15-06:00 06:00-12:00 06:00-10:00 10:00 Duration 1/2 hr 3-1/2 hr 1/2 hr 2hr 2hr 9hr 8-1/2 hr 1/2 hr 15hr lhr 3hr 8hr 2-1/4 hr 3/4 hr 3/4 hr 6hr 4hr Activity Flow check Well U-tubing, install safety valve, pump dry job. Observed well static Laid down 2400.0 ft of Tubing Spool control line and lay down 86 joints R2, 3-1/2" 9.2 g/ft, 13-Cr Fox tubing. Stopped: At sub-assembly Retrieved SCSSSV Lay down SSSV and RD Camco. Recovered 39 stainless steel bands. Retrieved 71.5 ft from SCSSSV Laid down Tubing of 900.0 ft Continue laying down 3-1/2" tubing with single joint compensator. Laid down Tubing of 900.0 ft Continue laying down 3-1/2" tubing. Recovered 330 joints 3-1/2" 9.2g/ft, 13-Cr Fox + 5 GLMs + 1 SSSV + 19.48' cut joint. Clean chemical cut, no evidence of corrosion. Pull Tubing, 3-1/2in O.D. (cont...) Laid down 10465.0 ft of Tubing (cont...) Continue laying down 3-1/2" tubing. Recovered 330 joints 3-1/2" 9.2g/ft, 13-Cr Fox + 5 GLMs + 1 SSSV + 19.48' cut joint. Clean chemical cut, no evidence of corrosion. 330 joints laid out Rigged down Tubing handling equipment Equipment work completed BHA run no. 1 Serviced Top drive Change out top drive sub and service top drive. Equipment work completed Made up BHA no. 1 Set wear ring, make up outside cutter BHA. BHA no. 1 made up R.I.H. to 10489.5 ft Wash down from 10,430'. PUW = 220, SOW = 130, RTW = 169. At Top offish: 10489.5 ft Cut Tubing at 10533.5 ft Wash down to 10,543', position cutter at 10,491' and cut tubing. Torque and weight indications of making neaarly a full cut before torqueing up and possibly damaging cutters. Picked up indicating latching the fish & breaking free the final uncut part. Completed operations Pulled out of hole to 10242.5 ft Pump dry job, POH. Pulled out of hole to 10242.5 ft Continue POH w./BHA gl (outside cutter). BHA run no. 1 (cont...) Pulled out of hole to 317.5 ft (cont...) Continue POH w./BHA gl (outside cutter). At BHA Facility Pt Mac 2 Progress Report Well P2-06 Page 4 Rig Nabors 9ES Date 31 May 00 Date/Time 10:00-12:00 12:00 12:00-04:00 12:00-13:30 13:30 13:30-14:00 14:00 14:00-14:30 14:30 14:30-18:00 18:00 18:00-21:00 21:00 21:00-02:00 24 Apr 00 02:00 02:00-04:00 04:00 04:00-06:00 04:00-04:45 04:45 04:45-06:00 06:00-08:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-19:30 08:00-10:00 10:00 Duration 2hr 16hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3hr 5hr 2hr 2hr 3/4 hr 1-1/4 hr 2hr 1-1/2 hr 1/2 hr 11-1/2 hr 2hr Activity Pulled BHA Knives gone from cutter, no fish BHA Laid out BHA run no. 2 Made up BHA no. 2 Reposition cutter to cut one joint deeper. Leave off collars and fishing jar. Change mill shoe for cut lip guide. Bumper sub would not make up completely. Lay out same and call out replacement. Jars failed - Change operation Serviced Top drive Equipment work completed Made up BHA no. 2 Continue make up BHA #2 w/new bumper sub. BHA no. 2 made up R.I.H. to 10489.5 ft At Top of fish: 10489.5 ft Cut Tubing at 10562.5 ft Wash over fish to 10,527'. Pick up and cut tubing w/50 rpm. Completed operations Pulled out of hole to 172.5 ft At BHA Pulled BHA Lay down BHA and 73.9' of tubing fish. Cut from BHA #1 nearly complete. No evidence of internal obstruction. BHA Laid out BHA run no. 3 Made up BHA no. 3 Overshot w/3-1/2" grapple. BHA no. 3 made up R.I.H. to 4042.5 ft Continue RIH w/overshot fishing BHA #3. BHA run no. 3 (cont...) R.I.H. to 10522.5 ft (cont...) Continue RIH w/overshot fishing BHA #3. At Top of fish: 10563.5 ft Fished at 10563.5 ft PUW = 200 SOW = 135 RWT= 165 Tag and swallow 5' offish @ 10,521'. Hang off same in slips with 10K over PUW. Latched fish Electric wireline work Rigged up Wireline units Pick up stuffing box and jt of 5" HWDP for lubricator, hang sheive from top drive. Hold safety meeting, establish radio silence, ready 2-3/8" chemical cutter (Schlumberger). Equipment work completed Facility Date/Time 25 Apr 00 Pt Mac 2 Progress Report Well P2-06 Page 5 Rig Nabors 9ES Date 31 May 00 10:00-18:30 18:30 18:30-19:30 19:30 19:30-04:30 19:30-20:30 20:30 20:30-02:30 02:30 02:30-04:30 04:30 04:30-06:00 04:30-05:00 05:00 05:00-06:00 06:00-11:30 06:00-07:00 07:00 07:00-08:00 08:00 08:00-11:00 11:00 11:00-11:30 11:30 11:30-18:15 11:30-12:45 12:45 12:45-16:45 16:45 Duration 8-1/2 hr lhr 9hr lhr 6hr 2hr 1-1/2 hr 1/2 hr lhr 5-1/2 hr lhr lhr 3hr 1/2 hr 6-3/4 hr 1-1/4 hr 4hr Activity Conducted electric cable operations RIH through DP to top offish at 10,521. Could not work into fish. POH w/wireline, change centralizer configuration (crescent marks on bottom of cutter appear as cut stub impression). Attempt second pass without success. POH w/wireline. Run completed but Chemical cutter hung up at 10563.5 ft Note: Attempted to pump tools downhole, workstring held 1500 psi before stuffing box leaked. Rigged down Wireline units POH w/cutter, RD Schlumberger. Equipment work completed BHA run no. 3 Fished at 10563.5 ft Perform blind back-off. Fish came free Pulled out of hole to 62.5 ft Monitor well, blow down top drive, POH. Fish at surface Laid down fish RU tubing handling equipment. Lay down 13 full joints plus cut stub (422' total). No indication of damage to top of stub. New top of fish: 10,943' (box up). No obstructions inside of recovered fish. Partial fish recovered BHA run no. 4 Made up BHA no. 4 Overshot w/4" grapple. B HA no. 4 made up R.I.H. to 1042.5 ft BHA run no. 4 (cont...) R.I.H. to 4242.5 ft Stopped · To service drilling equipment Serviced Block line Line slipped and cut Slip and cut 75 ft drilline. R.I.H. to 10985.5 ft At Top of fish · 10985.5 ft Fished at 10985.5 ft Latched fish Up weight 206 klbs, down weight 142 klbs. Rotating weight 170 klbs. Engage fishand hangoff with 10 klbs up weight. Electric wireline work Rigged up Wireline units Equipment work completed R/U stuffing box. Hold PJSM. Hold radio silence and make ready 2.375" chemical cutter Conducted electric cable operations Completed misrun with Chemical cutter to 10986.5 ft RIH. Unable to work thru TOF. POOH. Observe crescent marks on bottom of cutter similiar to those seen on previous runs except indicating smaller Facility Date/Time 26 Apr 00 Pt Mac 2 Progress Report Well P2-06 Page 6 Rig Nabors 9ES Date 31 May 00 16:45-18:15 18:15 18:15-02:30 18:15-19:30 19:30 19:30-21:00 21:00 21:00-21:15 21:15 21:15-02:00 02:00 02:00-02:30 02:30 02:30-03:00 02:30-03:00 03:00 03:00-06:00 03:00-03:30 03:30 03:30-06:00 06:00-14:00 06:00-07:30 07:30 07:30-09:00 09:00 09:00-13:30 13:30 13:30-14:00 14:00 14:00-19:30 14:00-15:30 15:30 15:30-19:00 19:00 19:00-19:30 19:30 Duration 1-1/2 hr 8-1/4 hr 1-1/4 hr 1-1/2 hr 1/4 hr 4-3/4 hr 1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 2-1/2 hr 8hr 1-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr Activity Rigged down Wireline units Equipment work completed BHA run no. 4 Fished at 10985.5 ft Fish came free Attempt to back out Kanchor taking RH torque to 10 klbs max- NO go. Conduct blind back-off w/x 8 LH wraps. Circulated at 10985.5 ft Hole swept with slug - 100.00 % hole volume Sweep hole w/25 bbl hi vis pill @ 9 BPM/1700 psi. How check Observed well static Pulled out of hole to 142.5 ft At BHA Pulled BHA BHA Laid out L/D BHA- No fish. Perform integrity test Tested Casing Pressure test completed successfully - 3000.000 psi Pressure Test Casing- Good test. BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up Make up Scraper assembly w/overshot- no grapple inserted. R.I.H. to 4042.5 ft BHA run no. 5 (cont...) R.I.H. to 10943.0 ft At Top of fish: 10943.0 ft Circulated at 10943.0 ft Obtained bottoms up (100% annulus volume) Up weight 200 klbs, down weight 143 klbs. Carfeully wash down and tag TOF on depth. Swallow 5 ft. TOF clear. Work scraper and CBU @ 9 BPM/1450 psi. Pulled out of hole to 5.0 ft At BHA Pulled BHA BHA Laid out Laid out scaper and fishing jars, bumper sub. BHA run no. 6 Made up BHA no. 6 BHA no. 6 made up M/U 176 ft washpipe and 5.7/8" external cutter assembly R.I.H. to 10943.0 ft At Top offish: 10943.0 ft Washed over string at 11028.0 ft Observed loss of 5.00 klb string weight Carefull run washpipe over Top of 3.1/2" fish @ 10,943. Observe resistance @ 11,028' ( Collar @ 11,033'). 85 ft from TOF. Progress Report Facility Pt Mac 2 Well P2-06 Page 7 Rig Nabors 9ES Date 31 May 00 Date/Time 19:30-23:00 19:30-23:00 23:00 23:00-06:00 23:00-00:00 27 Apr 00 00:00 00:00-01:30 01:30 01:30-03:00 03:00 03:00-06:00 06:00-11:00 06:00-07:30 07:30 07:30-09:00 09:00 09:00-10:30 10:30 Duration 3-1/2 hr 3-1/2 hr 7hr lhr 1-1/2 hr 1-1/2 hr 3hr 5hr 1-1/2 hr 1-1/2 hr 1-1/2 hr Activity Slickline wireline work Conducted slickline operations on Slickline equipment - Tool run Completed run with Drift from -0.0 ft to 10956.0 ft RFLI and run 1.3/4" Bailer and 1.1/2" toolstring. Hit Obstruction @ 10,956'. Work several times- no go. POOH and recover - 2 lbs of Frac sand- proppant from bailer- no other marks. BHA run no. 6 Washed over string at 11134.0 ft Completed operations Lightly wash down to 11,134'@ 4 BPM/550 psi- observe each collar. Cut Tubing at 11134.0 ft Completed operations Increase pump to 9 BPM/1450 psi and make cut. Up weight 197, down 143, Rotating 168 klbs. Circulated at 11134.0 ft Obtained clean returns - 120.00 % hole volume Sweep hole w/25 bbl Hi-vis pill until shakers clean. Observe approximately 3 bbls Frac Sand recovered. Pulled out of hole to 6000.0 ft Flowcheck. POOH. BHA run no. 6 (cont...) Pulled out of hole to 100.0 ft At BHA Laid down fish Complete fish recovered With washpipe in rotary R/U and Lay down 6 joints of 3.1/2" Tubing and 2.20 ft cut off. TOF @ 11,130'. Total length recovered= 186.58'. Pulled BHA BHA Laid out Pull BHA and lay out same. Clear rigfloor. 10:30-11:00 11:00 11:00-03:00 11:00-12:00 12:00 12:00-16:00 16:00 16hr lhr 4hr 16:00-17:00 17:00 lhr 17:00-18:30 18:30 1-1/2 hr Six Cutter knifes lost- probably on oustide of fish. Serviced Top drive Equipment work completed BHA run no. 7 Made up BHA no. 7 BHA no. 7 made up Make up 7.5/8" scraper and overshot assembly. R.I.H. to 11130.0 ft At Top offish · 11130.0 ft RIH and wash carefully over fish f/11,052'. Scraper depth @ 11,126'. Circulated at 11130.0 ft Obtained clean returns - 120.00 % hole volume Sweep hole w/25 bbl Hi-vis pill moving pipe periodically. Observe - 1 bbl frac sand back. Reverse circulated at 11130.0 ft Obtained clean returns - 100.00 % hole volume Shut Hydril and reverse circulate wellbore @ 6 BPM/ ,~-,n _~: ,-. ........... o .... ,, ......~-:~,_ 8 ft 7.Jk/ 1./31. ,,,.~lL/all l~,.,tllllli3, OWOII~JW kJll 11~11 Z , Progress Report Facility Pt Mac 2 Well P2-06 Page 8 Rig Nabors 9ES Date 31 May 00 Date/Time Duration Activity 28 Apr 00 18:30-20:00 20:00 20:00-21:00 21:00 21:00-02:30 02:30 02:30-03:00 03:00 03:00-06:00 03:00-04:45 04:45 04:45-05:00 05:00 05:00-06:00 06:00-04:30 06:00-20:30 20:30 20:30-21:30 21:30 21:30-01:30 29 Apr 00 01:30 01:30-03:30 03:30 03:30-04:00 04:00 04:00-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:30 06:00-06:30 06:30 06:30-11:00 06:30-09:30 09:30 1-1/2 hr lhr 5-1/2 hr 1/2 hr 3hr 1-3/4 hr 22-1/2 hr 14-1/2 hr lhr 4hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 3hr Laid down 3000.0 ft of 4in OD drill pipe Stopped · To service drilling equipment Serviced Block line Line slipped and cut Laid down 8000.0 ft of 4in OD drill pipe At BHA Pulled BHA BHA Laid out Run Gas lift completion, 3-1/2in O.D. Rigged up Completion string handling equipment Equipment work completed Pull Waear ring. Clear rigfloor and R/U Chrome Handling Equipment. Held safety meeting Completed operations Ran Tubing to 200.0 ft (3-1/2in OD) M/U Tailpipe assembly and RIH Chrome completion. Run Gas lift completion, 3-1/2in O.D. (cont...) Ran Tubing to 9130.0 fl (3-1/2in OD) Stopped · At sub-assembly Installed SCSSSV Equipment work completed PFU Camco SSSV and install same. Function Test Flapper Valve and test control line to 5000 psi/15 minutes. Ran Tubing to 11140.0 ft (3-1/2in OD) Observed 3.00 klb resistance Run remainder of 3.1/2" Tubulars. Wash down carefully- good indications of o/shot over fish and observe no go- 10 fl deeper than drill pipe tally. Space out tubulars Completed operations Pull back and L/O 3 joints and space out picking up 3 x 3.1/2" Chrome pups. Installed Tubing hanger Equipment work completed M/U Tubing Hanger. Test control line ports to 5000 psi. Install TWC and M/U Landing Joint. Ran Tubing to 11140.0 ft (3-1/2in OD) Hanger landed Land Hanger. RILDS and test from below to 500 psi- good. 350 x 3.1/2" Chrome joints run, 1 x 4.1/2" Chrome Jr, 3 x 3.1/2" Chr pup joints. 6 x GLM's, 1 x SSSV, 38 stainless bands. BOP/riser operations - BOP stack Rigged up BOP stack N/D BOPE BOP/riser operations - BOP stack (cont...) Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed IlIDLO. II Z-~.'qLJ-I./L~JI CIIIU Allg./g.~ Lk/~LIII~ UUI. IJ LU ~/UUU }Jbl. Facility Date/Time Progress Report Pt Mac 2 Well P2-06 Page 9 Rig Nabors 9ES Date 31 May 00 Duration Activity 09:30-11:00 11:00 11:00-16:00 11:00-15:00 15:00 15:00-16:00 16:00 16:00-19:00 16:00-17:15 17:15 17:15-19:00 19:00 19:00-21:00 19:00-21:00 21:00 1-1/2 hr 5hr 4hr lhr 3hr 1-1/4 hr 1-3/4 hr 2hr 2hr Retrieved Hanger plug Equipment work completed R/U DSM and pull TWC. R/U hoses to tree and test same to 3500 psi. Fluid system Freeze protect well - 100.000 bbl of Diesel Completed operations Reverse circulate wellbore to 290 bbls seawater followed by 210 bbls inhibited brine followed by 100 bbls of Diesel Freeze Protect. Freeze protect well - 100.000 bbl of Diesel Completed operations Allow tubing/annulus to U-tube. Run Gas lift completion, 3-1/2in O.D. Functioned Pe-rihanent packer Equipment work completed Pressure up tubing to 3500 psi to set packer. Observe leak via open annulus valve- lost 280 psi/30 minutes. Suspect GLM?.Leak ratio 8%. Tested Permanent packer Suspended pressure test on Casing, observed leak Attempt to pressure up Annulus while monitoring tubing w/1000 psi on tubing. Failure. Annulus leaking off @ 100 psi/minute with no change in tubing pressure. Repeat and troubleshoot- suspect casing parted when set packer. Loose 8 bbls.. Wellhead work - Installed Hanger plug Equipment work completed Rig Down HVB&R and clear all lines Install BPV. Rig Released @ 2100 hrs to M17A on 29 April 2000 .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~/'~ APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_,~i'~:. Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ ,~.,~ Plugging _X Time extension _ Stimulate Change approved program _ ~E; Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development _X RKB 51.6 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Point Mclntyre Unit 4. Location of well at surface ~' / V"' 8. Well number 5247' FNL, 4234' FEL, Sec. 11, T12N, R14E, UM (asp's 681281, 5998606) P2-06 At top of productive interval 9. Permit number / approval number 3975' FNL, 1238' FEL, SEC. 3, T12N, R14E, UM (asp's 678829, 6005104) 193-103V''' At effective depth 10. APl number 33837' FNL, 1386' FEL, SEC. 3, T12N, R 14E, U M (asp's 678678, 6005238) 50-029-22388 At total depth 11. Field / Pool 3716' FNL, 1420' FEL, Sec. 3, T12N, R14E, UM (asp's678642, 6005358) Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 11975 feet Plugs (measured) Tagged PBTD @ 11820' MD on 6/13/1999. true vertical 9159 feet Effective depth: measured 11820 feet Junk (measured) true vertical 9067 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 280 cubic ft AS 80' 80' Surface 4343' 10-3/4" 2821 cu It PFE & 406 cuft G 4394' 3666' Production 12035' 7-5/8" 600 cubic ft Glass G 12087' 9223' Perforation depth: truemeasuredvertical 8931'11600'- 11730'; 11750'- 11830'._ 9013'; 9025' - 9073'. 0/~/~,~/~[~4~ RECEIVED~¥lp~ 0 '~ '~ Anchorage Tubing (size, grade, and measured depth 4-1/2", 12.6#, 9cR80 Tbg @ 38' MD; 3-1/2", 9.2#, 13CR80 Tbg @ 11443' MD. i Packers & SSSV (type & measured depth) 7-5/8" X 4" BAKER SABL-3 PACKER @ 11375' MD. 3-1/2" CAMCO TRDP-4A-SSA SSSV @ 2400' MD. 13. Attachments Description summary of proposal __X ~ .. Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: March 7, 2000 16. If proposal was verbally approved Oil __X Gas__ Suspended _ Name of approver Date approved Service 17. I hereby cerfihj that the foregoing is true and correct to the best of my knowledge. Questions? Call Stephen Ward @ 265-1305. Signed Title: AAI Coil Tubing Drilling Supervisor Date ~'-~- /~'~ ~ ~ Bruce E. Smith, P.E. Prepared b~, Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integdly ~ BOP Test ~, Location clearance __ I Appr°val n°~,~ "' ~ Mechanical Integrity Test__ Subsequent form required lo- ORIGINAL SIGNED BY Robert N. Christenson Approved by' order of the Commission .Co_rj~issioner Date ¢-'~ "~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE P2-06 Intended P&A Procedure Ob. iective: P&A existing interval in preparation for CT sidetracking operations. Intended Procedure · RU SL. Tag bottom. · RU coiled tubing unit and tag bottom. Pump 20 bbls Class 'G', 17 ppg neat cement. Clean cement top to -11570' md in 7-5/8" casing(KOP in 7-5/8" for CTU drilling at 11600'md). · WOC, Tag top of cement. · Mill window in 7-5/8" casing at - 11600' md. RECEIVED f¥1AR O 1 2000 Alaska Oil.& Gas Cons. Anchora,qe February 23, 2000 P2-06A Proposed CT Sidetrack Horizontal Z 3-1/2" Tubing 12" Camco TRDP-4A SSSV@ 2192' 10-3/4" Casing shoe @ 4394' 6- 3-1/2" OTIS TGPDX GLM's 3-1/2"SWS Nip @ 11356' Packer @ 11375' 3-1/2"SWS Nip @ 11406' 3-1/2"SWN Nip @ 11422' 3-1/2"TT @ 11443' TOC in 7-5/8" 11500' Top of 2-3/8" Liner in 3-1/2" Tbg 2-3/8" liner Initial Perfs Window cut in 7-5/8" at -11600 - 11605' Current perforations cement squeezed 3" Open hole RECEIVED 1,3,,~,R O 1 2000 A[~sk~ 0il & G.~s "-.r" .,,,, ,..,-...' ........... " TD @ - 12620' Well' P2-06 GPMA WEB Date: 1110100 XO-- TRSSSV~ NIP -- PKR -- NIP -- Perf -- Perf -- Perf -- Perf -- APl: 500292238800 SSSV Type: CAT I - SSSV Annular Fluid: LIFT GAS Reference ZDL/GR Log: Last Tag: 11800' SLM CORR Last Tag Date: 6/13/99 Well Type: PROD Orig Compltn: 8/21193 Last W/O: Ref Log Date: 8/17193 TD: 12087 ftKB Max Hole 55 deg @ 11975 Angle: Angle @ TS: deg @ Angle ~} TD: 55 deg @ 11975 Rev Reason: tagged ice at 430' on 12/28199 Last Update: 1/5/00 Date Note 1/22194 Minimum ID: 2.760" PARKER SWN NIPPLE ~ 11422' MD Date Note 1/22/94 Well Status: ACTIVE 1/22194 Tubing Hanger: 4 112D FMC NSH @ 34' MD Last Tag Depth @ 12103 ) Of Fluid Depth. (~ .1 !573 Depth Description 11830 FISH - GLV Depth 38 2400 11356 11375 11406 11422 11443 Comment 1-1/2" OGLV discovered missing f/sta ~ 6/20/99 j~ELR¥ :.: :.: .: TVD Type Description ID 38 XO 4.5" x 3.5" 2.990 2247 TRSSSV 3-1/2" CAMCO TRDP-4A-SSA SSSV, ID=2.812", Damaged 6119/99 2.810 (will not close) 8770 NIP 3-112" PARKER SWS NIPPLE, ID=2.8125" 2.810 8783 PKR 7-5~8" x 4" BAKER SABL-3 PACKER 3.000 8804 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 2.810 8815 NIP 3-1/2" PARKER SWN NIPPLE, ID=2.76" (WHIDDON C-SUB SET 2.760 6-13-99) 8829 TT 6.000 TUBING TAIL, WLEG ( 11443' ELMD) Size Weight Grade Top Btm Feet Description 10.750 45.50 NT80 0 4394 4394 SUR. CASING 7.625 29.70 NT95HS 0 11279 11279 PROD. CASING 7.625 29.70 13CR 11279 12087 808 PROD. CASING Size Weight Grade Top Btm Feet Description 4.500 12.60 9CR80 0 38 38 TUBING 3.500 9.20 13CR80 38 11443 11405 TUBING ~G~ i!EiffilM~hdt~l~al~e~ i ~. i i i:. ~ :i: ?::~::: : !~ :. . MD TVD Man Man VMfr Mfr Type 1 4867 4003 OTIS TGPDX CA GLV 2 7347 5791 OTIS TGPDX CA OV 3 8212 6405 OTIS TGPDX CA DMY 4 9407 7289 OTIS TGPDX OT DMY 5 10305 7982 OTIS TGPDX CA DMY 6 11337 8757 OTIS TGPDX OT DMY VType VOD Latch Port TRO Date Vlv Run Comment 1.5 TG 0.250 2559 6/28/99 1.5 TG 0.375 0 6~28/99 1.5 TG 0.000 0 6121/99 1.5 TG 0.000 0 1.5 TG 0.000 0 6/28/99 1.5 TG 0.000 0 Interval TVD 11600- 8931-8950 11630 11630- 8950-8969 11660 11660- 8969-8975 11670 11670- 8975-9013 11730 11750- 9025-9061 11809 11809- 9061-9073 11830 Zone Status Feet SPF Date Type Comment 30 102/22/98 RPERF REPERF, 2-1/2" GUNS, ORIENTED 30 6 7/26/94 APERF ADDPERFS 10 61/30/94 60 6 7/26/94 APERF ADDPERFS 59 6 7/26194 APERF ADDPERFS 2161/31/94 RECEIVED Perf -- 6 5 4 COILED TUB],NG UNIT 80P EOU] PHENT 1. 5000 PSI 7" WELLHEAD CONNE~OR £LAhG[ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS ~. :~)OC) PS1 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX . 4 3 RECEIVED i NIREL]NE BOP EOUIPMENT _ i 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WlRELIN[ RAIDS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS~ 4 1/6" FLOW TUBE PACK-Orr STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5247' FNL, 4234' FEL, Sec. 11, T12N, R14E, UM At top of productive interval 1303' FSL, 1238' FEL, Sec. 03, T12N, R14E, UM At effective depth At total depth 3716' FNL, 1420' FEL, Sec. 3, T12N, R14E, UM 5. Type of Well: Development~X Exploratory__ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Point Mclntyre Unit 8. Well number P2-06 9. Permit number / approval number 93-1 O3 10. APl number 50-029-22388 11. Field / Pool Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Surface 4354' 10-3/4" Production 11242' 7-5/8" Production 808' 7-5/8" 12103 feet Plugs (measured) 9232 feet 11820 feet Junk (measured) 9067 feet Cemented 280 cubic ft Arcticset 2821' cuft PFE & 406 cuft G 600 cubic ft Class G Tagged TOS @ 11820' MD (6/13/1999) Measured Depth TrueverticalDepth 80' 80' 4394' 3666' 11279' 8717' 12087' 9223' Perforation depth: measured 11600' - 11730'; 11750' - 11830'. true vertical 8931' - 9013'; 9025' - 9073'. Tubing (size, grade, and measured depth) 4-1/2"12.6#, 9CR80 Tbg @ 38' MD; 3-1/2"9.2#, 13CR80 Tbg @ 11443' MD. Packers & SSSV (type & measured depth) 7-5/8" X 4" BAKER SABL-3 PACKER @ 11376' MD. 3-1/2" CAMCO TRDP-4A-SSA SSSV @ 2401' MD. ORIGINAL 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 50 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 124 2130 206 117 633 Casing Pressure Tubing Pressure 1106 758 15, Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil .__X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedErin Oba ~ /~ . ~ Title ARCO EngineeringSupervisor Prepared by Paul Rauf 263-4990 .~' Form 10-404 Rev 06/15/88 o SUBMIT IN DUPLICATE P2-06 DESCRIPTION OF WORK COMPLETED FB MARCIT GEL SQUEEZE FOR WATER SHUTOFF Date Event Summary 6/08/1999: 6/12/1999: 6/13/1999: 6/14/1999 - 6/18/1999: 6/21/1999: 6/22/1999: Performed injectitivy test w/110 bbls Crude - 1 bpm @ 3000 psi. RIH & tagged frac sand @ 11561' MD. RIH & FCO'd f/11561' - 11900' MD. Displaced well to Crude. Performed injectivity test: 4 bpm @ 2100 psi 3 bpm @ 1900 psi 2 bpm @ 1750 psi 1 bpm @ 1625 psi RIH & tagged TOS @ 11820' MD. Left wire/toolstring in hole as fish. Attempted to fish wire - unsuccessful. Successuflly fished 6600' of wire & 22' toolstring from wellbore. MITIA to 3000 psi - passed. Performed a Fullbore Marcit Gel Squeeze for Water Shutoff as follows: MIRU. PT'd to 4000 psi. Pumped the Gel treatment through the perforation intervals located @: 11600' - 11730' MD 11750' - 11830' MD Pumped: (a) 500 bbls 1% KCL Water cool down stage @ 3-5 bpm, followed by (b) 500 bbls 1% KCL Water w/3000 ppm polymer @ 5.6 bpm, followed by (c) 1000 bbls 1% KCL Water w/4500 ppm polymer & chrome acetate @ 5.3 bpm, followed by (d) 1600 bbls 1% KCL Water w/6000 ppm polymer & chrome acetate @ 4.7 bpm, followed by (e) 470 bbls 1% KCL Water w/7500 ppm polymer & chrome acetate @ 4.7 bpm, followed by (f) 12 bbls 1% KCL Water spacer, followed by (g) 200 bbls Crude flush, followed by (h) shutdown. Final treating press was 2400 psi. RD. Returned well to production & obtained a valid welltest. RECEIVED Alaska Oit & Gas Cons. Commission STATE OF ALASKA - "~ ALASK/' .... "AND GAS CONSERVATION COMMIS" .... 'N REPORT oF SUNDRY WELL OPERATluNS 1. Operations performed: Operation shutdown__ Stimulate ~ Plugging__ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5247' FNL, 4234' FEL, Sec. 11, T12N, R14E At top of production interval 1294' FSL, 1293' FEL, Sec. 3, T12N, R14E At effective depth At total depth 3716' FNL, 1419' FEL, Sec. 3, T12N, R14E 5. Type of Well: Development ~. Exploratory __ Stratigraphic _ Service __ Datum elevation (DF or KB) KB 51 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P2-06 9. Permit number/approval number 93-103 / 10. APl number 500292238800 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Conductor 80' Surface 4394' Intermediate 11279' Liner 11975 feet Plugs (measured) None. 9159 feet 11880 feet Junk (measured) None. 9103 feet Size Cemented Measured depth 20" 280 CU ft Arcticset 80' 10 2821 cu ft PF 'E' & 4394' 406 cuft 'G' 7 5/8" 60 cuft Class G 11279' True vertical depth 80' 3666' 8717' Perforation depth: measured 11600-11630', 11630-11660', 11660-11670', 11670-11730', 11750-11809', 11809-11830' true vertical 8880-8899', 8899-8918', 8918-8924', 8924-8961', 8973-9009', 9009-9022' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 9CR80 @ 0-38' MD, 3 1/2 in. 9.2# 13CR80 @ 38-11463' MD Packers and SSSV (type and measured depth) 3 X 7 5/8 PKR @ 11375' MD, 2 4/5 x 4 1/2 TRSSSV @ 2400' MD JUL 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. AlaskaSjt & Gas ~;u;is. 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation 304 2735 377 Subsequent to operation 551 2605 1433 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Casing Pressure Status of well classification as: Oil~x Gas __Suspended and correct to the best of my knowledge. Title Tubing Pressure 703 1219 Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-06 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE STIMULATION TREATMENT Date Event Summary 07-19-1998 07-27-1998 Performed Hydraulic Refracture Treatment to stimulate perforations at: 11600' - 11631' MD CTU placed temporary sand plug in casing in preparation for job. Top of sand plug at 11632' MD to isolate perforations below that depth. The job was performed in the following stages. a) MIRU. b) Pumped Breakdown Treatment of 50# Cross-Linked Gel to maximum wellhead treating pressure of 4470 psig. c) Pumped Scour Stage of 1979# 20/40 Carbolite Proppant. d) Pumped Data Frac w/50# Cross-Linked Gel into perforations. e) Determined ISIP = 2580 psig. f) Pumped Hydraulic Propped Fracture Treatment into perforations with average treating pressure of 5400 psig. g) Placed 1721# 20/40 Carbolite and 125733# 16/20 Carbolite into the formation. h) Frac did not screen out. i) RDMO. CTU cleaned out temporary sand plug to 11880' MD. Well put on production. Well-P2-06 TRSSSV-- NIP -- PKR -- NIP -- 3ATCHER -- SUB NIP -- Perf · Per[ -- Per[ GPMA WEB Date: 4/13/99 Angle @ TS: deg @ Angle @ TD: 55 deg @ 11975 Rev Reason: JET ICE PLUG Last Update: 11/1/98 APl: 500292238800 SSSV Type: CAT I - SSSV Annular Fluid: LIFT GAS Reference ZDL/GR Log: Last Tag: 11880 SLM CORR Last Tag Date: 7/29/98 Well Type: PROD ©dg Compltn: 8/21/93 Last W/O: Ref Log Date: 8/17/93 TD: 12087 ftKB Max Hole 55 deg @ 11975 Angle: Date Note 1/22/94 Minimum ID: 2.760" PARKER SWN NIPPLE (~ 11422' MD Gene~! Notes ::: : I ID 2.812 2.813 3.000 0.000 2.813 2.760 6.000 Date Note 1/22/94 Well Status: ACTIVE 1/22/94 Tubing Hanger: 4 1/2U FMC NSH @ 34' MD Last Tag Depth @ 12103 Top Of Fluid Depth (~ 11573 IEWELRY Depth 'I'VD Type Description 2400 2247 TRSSSV 3-1/2" CAMCO TRDP-4A-SSA SSSV, ID=2.812" 11356 8770 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 11375 8783 PKR 7-5/8" x 4" BAKER SABL-3 PACKER 11406 8804 CATCHER SUB 11406 8804 NIP 3-112" PARKER SWS NIPPLE, ID=2.8125" 11422 8815 NIP 3-1/2" PARKER SWN NIPPLE, ID=2.76" 11443 8829 'IT TUBING TAIL, WLEG (11443'ELMD) ' S,:AII: : : J Size Weight Grade Top Btm Feet Description 10.750 45.50 NT80 0 4394 4394 SUR. CASING 7.625 29.70 NT95HS 0 11279 11279 PROD. CASING 7.625 29.70 13CR 11279 12087 808 PROD. CASING S,All' ::: [ Size Weight Grade Top Btm Feet Description 4.500 12.60 9CR80 0 38 38 TUBING 3.500 9.20 13CR80 38 11463 11425 TUBING Lift MandrelsNaives I Stn MD TVD Man Man VMfr VType rOD Latch Port TRO Date VIv Mfr Type Run Comment 1 4867 4003 OTIS TGPD× CA GLV 1.5 TG 0.250 2375 9/19/98 2 7347 5791 OTIS TGPDX CA DV 1.5 TG 0.000 0 9/19/98 3 8212 6405 OTIS TGPDX CA GLV 1.5 TG 0.250 2368 9/19/98 4 9407 7289 OTIS TGPDX OT DV 1.5 TG 0.000 0 5 10305 7982 OTIS TGPDX CA ORIFICE 1.5 TG 0.188 0 8/6/98 6 11337 8757 OTIS TGPDX OT DV 1.5 TG 0.000 0 Perfo~:tions summary Interval TVD 11600- 8931-8950 11630 11630- 8950-8969 11660 11660- 8969-8975 11670 11670- 8975-9013 11730 11750- 9025-9061 11809 11809- 9061-9073 11830 Zone Status Feet SPF Date Type Comment 30 10 2/22/98 RPERF REPERF, 2-1/2" GUNS, ORIENTED 30 6 7/26/94 APERF ADDPERFS 10 61/30/94 60 6 7/26/94 APERF ADDPERFS 59 6 7/26/94 APERF ADDPERFS 21 61/31/94 Per[ · Per[ · Per[ · STATE OF ALASKA ALASKA '--'~. AND GAS CONSERVATION COMMIS,C'--N REPORT oF SUNDRY WELL OPERATI~JNS · Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~.~ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5247' FNL, 4234' FEL, Sec. 11, T12N, R14E At top of production interval 1294' FSL, 1293' FEL, Sec. 3, T12N, R14E At effective depth At total depth 3716' FNL, 1419' FEL, Sec. 3, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KB 51 feet 7. Unit or Property name POINT MCINTYRE UNIT 8. Well number P2-06 9. Permit number/approval number 93-103 / 10. APl number 500292238800 11. Field/Pool Point Mclntyre 12. Present well condition summary , Total Depth: measurea: 11975 feet Plugs (measured) None. true vertical: 9159 feet Effective Depth: measured: 11880 feet Junk (measured) None. true vertical: 9103 feet Casing Length Size Cemented Measured depth Conductor 80' 20" 280 CU ft Arcticset 80' Surface 4394' 10 2821 cu ft PF 'E' & 4394' 406 cu ft 'G' Intermediate 11279' 7 5/8" 60 CUft Class G 11279' Liner True vertical depth 80' 3666' 8717' Perforation depth: measured 11600-11630', 11630-11660', 11660-11670', 11670-11730', 11750-11809', 11809-11830' true vertical 8880-8899', 8899-8918', 8918-8924', 8924-8961', 8973-9009', 9009-9022' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 9CR80 @ 0-38' MD, 3 1/2 in. 9.2# 13CR80 @ 38-11463' MD, Packers and SSSV (type and measured depth) 3 x 7 5/8 PKR @ 11375' MD, 2 4/5 x 4 1/2 TRSSSV @ 2400' MD RECEIVED ,1111 2_'2_ 19~9 3. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OEiGii iAL ~,,ka 0ii & Gas Cons. C0mmissi0n Anchorage 14. Oil-Bbl Gas-Mcf Prior to well operation 290 3137 Subsequent to operation 481 2694 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Iniection Data Water-Bbl 337 492 Casing Pressure Tubing Pressure 755 772 I16. Status of well classification as: Oil~x Gas __Suspended __Service 17. I hereby ~.,~t the forego~,gJs/~ and correct to the best of my knowledge. S igne ../~.,.~-~'Y,. Title Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-06 DESCRIPTION OF WORK COMPLETED REPERFORATIONS Date Event Summary 02-22-1998 RIH 2 1/2" HSD gun and reperforated the following: 11600' - 11630' MD All shots at 10 SPF, 180 deg phasing and oriented at 172 deg ccw. Well: P2-06 TRSSSV-- PKR -- NIP -- 3ATCHER -- SUB NIP -- Perf - Perf -- Perf - Pen' - Perf - Perf · GPMA WEB Date: 4/13/99 APl: 500292238800 SSSV Type: CAT I- SSSV Annular Fluid: LIFT GAS Reference ZDL/GR Log: Last Tag: 11880 SLM CORR Last Tag Date: 7129198 Well Type: PROD Grig Compltn: 8/21/93 Last W/O: Ref Log Date: 8117193 TD: 12087 ftKB Angle @ TS: deg @ Angle @ TD: 55 deg @ 11975 Rev Reason: JET ICE PLUG Last Update: 11/1/98 Max Hole 55 deg @ 11975 Angle: :Safe~:NoteS' :::::: ::~ : I Date Note 1/22/94 Minimum ID: 2.760" PARKER SWN NIPPLE @ 11422' MD Gene~tNOteS:: :;.: :; :: :: ID 2.812 2.813 3.000 0.000 2.813 2.760 6.000 Date Note 1/22/94 Well Status: ACTIVE 1/22/94 Tubing Hanger: 4 1/2D FMC NSH @ 34' MD Last Tag Depth @ 12103 Top Of Fluid Depth (~ 11573 Other(Plugs;equip, etc,) ' JEWELRY Depth TVD Type Description 2400 2247 TRSSSV 3-1/2" CAMCO TRDP-4A-SSA SSSV, ID=2.812" 11356 8770 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 11375 8783 PKR 7-5/8" x 4" BAKER SABL-3 PACKER 11406 8804 CATCHER SUB 11406 8804 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 11422 8815 NIP 3-1/2" PARKER SWN NIPPLE, ID=2.76" 11443 8829 TT TUBING TAIL, WLEG ( 11443' ELMD) casing strings ~Aii ::: : Size Weight Grade Top Btm Feet Description 10.750 45.50 NT80 0 4394 4394 SUP. CASING 7.625 29.70 NT95HS 0 11279 11279 PROD. CASING 7.625 29.70 13CR 11279 12087 808 PROD. CASING ITubing stringS~:, Al! : : Size Weight Grade Top Btm Feet Description 4.500 12.60 9CR80 0 38 38 TUBING 3.500 9.20 13CR80 38 11463 11425 TUBING Gas Lift MandrelsNalVes Stn MD 'FVD Man Man VMfr VType rOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 4867 4003 OTIS TGPDX CA GLV 1.5 TG 0.250 2375 9/19/98 2 7347 5791 OTIS TGPD× CA DV 1.5 TG 0.000 0 9/19/98 3 8212 6405 OTIS TGPDX CA GLV 1.5 TG 0.250 2368 9/19/98 4 9407 7289 OTIS TGPDX OT DV 1.5 TG 0.000 0 5 10305 7982 OTIS TGPDX CA ORIFICE 1.5 TG 0.188 0 8/6/98 6 11337 8757 OTIS TGPDX OT DV 1.5 TG 0.000 0 PerOrations summary Interval 'FVD 11600- 8931-8950 11630 11630- 8950-8969 11660 11660- 8969-8975 11670 11670- 8975- 9013 11730 11750- 9025-9061 11809 11809- 9061-9073 11830 Zone Status FeetSPF Date Type Comment 30 10 2/22/98 RPERF REPERF, 2-1/2" GUNS, ORIENTED 30 6 7/26/94 APERF ADDPERFS 10 6 1/30/94 60 6 7/26194 APERF ADDPERFS 59 6 7/26/94 APERF ADDPERFS 21 6 1/31/94 STATE OF ALASKA ALASKA'"~'".AND GAS CONSERVATION COMMIS,~ .... XI REPORT SUNDRY WELL OPERATIUNS 1. Operations performed: Operation shutdown __ Stimulate X Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5247' FNL, 4234' FEL, Sec. 11, T12N, R14E At top of production interval 1294' FSL, 1293' FEL, Sec. 3, T12N, R14E At effective depth At total depth 3716' FNL, 1419' FEL, Sec. 3, T12N, R14E 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ Datum elevation (DF or KB) KB 51 feet 7. Unit or Properly name POINT MCINTYRE UNIT 8. Well number P2-06 9. Permit number/approval number 93-103 / 10. APl number 500292238800 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 80' 20" Surface 4394' 10 Intermediate Liner 11975 feet Plugs (measured) 9159 feet 11880 feet 9103 feet Cemented Junk (measured) None. None. Measured depth 280 CUft Arcticset 80' 2821 cuft PF 'E' & 4394' 406 cuft 'G' 11279' 7 5/8" 60 cuft Class G 11279' True vertical depth 80' 3666' 8717' Perforation depth: measured 11600-11630', 11630-11660', 11660-11670', 11670-11730', 11750-11809', 11809-11830' true vertical 8880-8899', 8899-8918', 8918-8924', 8924-8961 ', 8973-9009', 9009-9022' Tubing (size, grade, and measured depth) 4 1/2 in. 12.6# 9CR80 @ 0-38' MD, 3 1/2 in. 9.2# 13CR80 @ 38-11463' MD Packers and SSSV (type and measured depth) 3 X 7 5/8 PKR @ 11375' MD, 2 4/5 x 4 1/2 TRSSSV @ 2400' MD RECEIVED -JUL 22 !13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. ORIGINAL Alaska 0ii & Gas 6o~s. ~;ommissio Anchorage Prior to well operation Subsequent to operation Representative DailyAveraqeProductionorlniection Data Oil-Bbl Gas-Mcf Water-Bbl CasingPressure 1044 3745 3 3380 4221 51 Tubing Pressure 678 692 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas __ Suspended __ 17. I hereby certify that the fo_j. egoir)g .is true and correct to the best of my knowledge. Signed , Title Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE .h. P2-06 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE STIMULATION TREATMENT Date Event Summary 10-22-1995 Performed Hydraulic Fracture Treatment to stimulate the perforations at: 11600'-11730' MD 11750'-11830' MD The job was performed in the following stages: a) MIRU. b) Pumped Data Frac w/100# Cross-Linked Gel into perforations. c) Determined ISIP = 2580 psig. d) Pumped Hydraulic Propped Fracture Treatment into perforations with average treating pressure of 5200 psig. e) Placed 2500# 20/40 Carbolite, 19000# 16/20 Carbolite and 4800# 12/18 Carbolite into the formation. f) Frac screened out while pumping 14 ppg stage. g) RDMO. Well' P2-06 TRSSSV -- NIP -- PKR -- NIP -- 3ATCHER -- SUB NIP -- Perf · Perf -- Perf · Perf · Perf · Perf · GPMA WEB Date: 4/'13/99 P2-06::..::: : APl: 500292238800 SSSV Type: CAT I - SSSV Annular Fluid: LIFT GAS Reference ZDL/GR Log: Last Tag: 11880 SLM CORR Last Tag Date: 7/29/98 Well Type: PROD Orig Compltn: 8/21/93 Last W/O: Ref Log Date: 8/17/93 TD: 12087 ftKB Max Hole 55 deg @ 11975 Anqle: Angle @ TS: deg @ Angle @ TD: 55 deg @ 11975 Rev Reason: JET ICE PLUG Last Update: 11/1/98 Safety NOtes : Date Note 1/22/94 Minimum ID: 2.760" PARKER SWN NIPPLE @ 11422' MD General NOtes Date Note 1/22/94 Well Status: ACTIVE 1/22/94 Tubing Hanger: 4 1/2~] FMC NSH @ 34' MD Last Tag Depth @ 12103 Top Of Fluid Depth @ 11573 Other (plugs, iequip., etc.)- JEWELRY Depth 'rVD Type Description 2400 2247 TRSSSV 3-1/2" CAMCO TRDP-4A-SSA SSSV, ID=2.812" 11356 8770 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 11375 8783 PKR 7-5/8" x 4" BAKER SABL-3 PACKER 11406 8804 CATCHER SUB 11406 8804 NIP 3-1/2" PARKER SWS NIPPLE, ID=2.8125" 11422 8815 NIP 3-1/2" PARKER SWN NIPPLE, ID=2.76" 11443 8829 TT TUBING TAIL, WLEG ( 11443' ELMD) Casing Strings - All ID 2.812 2.813 3.000 0.000 2.813 2.760 6.000 Size Weight Grade Top Btm Feet Description 10.750 45.50 NT80 0 4394 4394 SUR. CASING 7.625 29.70 NT95HS 0 11279 11279 PROD. CASING 7.625 29.70 13CR 11279 12087 808 PROD. CASING TUbing :strings - All Size Weight Grade Top Btm Feet Description 4.500 12.60 9CR80 0 38 38 TUBING 3.500 9.20 13CR80 38 11463 11425 TUBING Gas Lift Mandrels/Valves Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date VIv Mfr Type Run Comment 1 4867 4003 OTIS TGPDX CA GLV 1.5 TG 0.250 2375 9/19/98 2 7347 5791 OTIS TGPDX CA DV 1.5 TG 0.000 0 9/19/98 3 8212 6405 OTIS TGPDX CA GLV 1.5 TG 0.250 2368 9/19/98 4 9407 7289 OTIS TGPDX OT DV 1.5 TG 0.000 0 5 10305 7982 OTIS TGPDX CA ORIFICE 1.5 TG 0.188 0 8/6/98 6 11337 8757 OTIS TGPD× OT DV 1.5 TG 0.000 0 PerforatiOns summary Interval TVD 11600- 8931-8950 11630 11630- 8950-8969 11660 11660- 8969-8975 11670 11670- 8975-9013 11730 11750- 9025-9061 11809 11809- 9061- 9073 11830 Zone Status FeetSPF Date Type Comment 30 10 2/22/98 RPERF REPERF, 2-1/2" GUNS, ORIENTED 30 6 7/26/94 APERF ADDPERFS 10 6 1/30/94 60 6 7/26/94 APERF ADDPERFS 59 6 7/26/94 APERF ADDPERFS 21 6 1/31/94 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 __ Suspended _ Operation Shutdown__ Repair well __ Plugging __ Pull tubing __ Variance __ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 5249' FNL, 4236' FEL, Sec. 11, T 12N, R 14E At top of production interval 1294' FSL, 1293' FEL, Sec. 3, T12N, R14E At effective depth At total depth 3718' FNL, 1421' FEL, Sec. 3, T 12N, R 14E ORIGINAL Re-enter suspended well__ Time extension __ Stimulate X__ Perforate Other 3. Datum elevation (DF or KB) 8800 7. Unit or Property name Prudhoe Bay Unit 8. Well number P2-06 9. Permit number 93-103 0. APl number 500292238800 11. Field/Pool Point Mclntyre 12. Present well condition summary Total Depth: measured' true vertical' 11,975 feet 9,1 58.51 feet Plugs (measured) None. feet Effective Depth: measu red: true vertical: Casing L e n g t h Size Conductor 80' 20", 4394' 10.75", Surface Intermediate 12087' 7.875", feet Junk (measured) None. feet Cemented Measured depth 280 cu ft Arcticset 80' 2821 cu ft PF "E"/406 cu 4395' ft "G" 60 cu ft Class "G" 12087' True vertical depth 80' 3664' 9219' Liner Perforation depth: measured 11,600 - 11,830' true vertical 8,926 - 9,069' Tubing (size, grade, and measured depth) 3.5", 9.2#, 13CR80, 11,463' MD Packers and SSSV (type and measured depth) 4"x7.625" Baker SABL# packer @ 11,395' MD, 0CT 'i9 1995 Alaska 0il .& Gas Cons. Commission ~chorage 3.5" Camco 'q'RDP-4A-SSA" SSSV @ 2,400' MD 13. Attachments Description summary of proposal __X Please refer to the attached 14. Estimated date for commencing operation October 24, 1995 16. If proposal was verbally approved Name of approver 17. I hereby ce.CJ~ that the foregoing Signed Detailed operation program __ BOP sketch -- I 15. Status of well classification as: Oil × Gas Date approved Service is true and correct to the best of my knowledge. Title Suspended Sr. Operations Engineer Date October 17, 1995 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP test Location clearance -- Mechanical Integrity Test Subsequent for [e~uired 10- -- original ~gnea ~y Approved bv order of the Commission 0avid W. Johnston · . Approved CopLAppr°va~l'~ "-/ Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Point McIntyre P2-06 Stimulation Procedure . , . RU pumping equipment. Pressure test annulus to 3500 psi. Pressure test surface equipment to 7000 psi. Perform data frac on Kuparuk 11,600 - 11,830' MD with 106 bbls of 2% KCL and 100 bbls of 40 pptg gelled water. Hydraulically fracture Kuparuk 11,600- 11,830' down 3 1/2" production tubing with the following fluids. Maximum treating pressure is 7,000 psig. 385 bbls 40 pptg gelled water. 79,544 lbs proppant. RD stimulation company. Estimated Static BHP = 4,250 psig at 8,800' ss. _,~.~ Oit .&, Gas Cons. Commissioo ~chorage WIRELINE BOP EQUIPI"IENT ii I 5000 PS1 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 WIRELINE RAMS 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSi 4 1/6" FLOW TUBE PACK OFF Oil & Gas Cons. Commissior~ Anchorage PE RNIT DATA ~..dl¥~eual Well AOGCC T~, ' ~ ~ ~-oiogicai Materials ~nv~n~or~ T DATA_PLUS rage: I Date~ 10/13/95 RUN DATE_RECVD 93-103 5811 93-103 5811 93-103 5814 93--10.3 5814 93--].03 407 :,3-103 93~!03 DAILY WELl_. OP SUR~fEY SURVEY 93-!03 BHP 93-103 93-!03 DLL/GR/SP GCT 93-103 PERF 93-103 PERF 93~103 93-103 93-i03 S S TVD STAT/?RE~£S/TEMP/ ZD L / CNL/GR./CAL Fi[iNA. I, MWD 93- 103 SURVEY OH~CDR/CDN,8384-11976.5 1i400~ii786, LDWG OH-DLL~ii400-11786 COMP DATE~ 8/27/93 8/u5/9s TO 8/21/e3 0.00-!1840 0-12000, GCT ~1~00-11786 11400-11756 40~!1949 11270-11985 11480-11750 I1400-11786 11245-11985 11400-1175q 0-11955, GCT 10/14/93 ~I/19/'93 10/14/93 '11/19/93 11/01/93 11/01/93 ~i/0i/93 04/19/94 11/'19/93 ii/19/~'~ u.~/I~/94 04/19/94 09/29/94 11/19/93 04/19/94 11/19/93 i1/i9'~ 0~/19/94 P~ RH T.T' DA?A T DATA_PLUS Paga ~ 2 'nat~. i0/i3/ ......... . ............ ..~ ~. s no And received? yes iio ~ ~ sts requ~rec~-~ Ye~; no Recelv~,d© ~ In ~ "- ' ye S ii O 93 ~-. 1 O3 93 ..... 103 9 3 '-' i 0 3 93 ..... i 03 93 i03 <? ..... 93 ~ i 0 3 ~-:., ::, 103 93 '- 'i 03 93 .... i 03 93 "' 103 g~: '" i 03 9,~': ...... i 03 9 .::3" J03 93 '" 'i 03 · :.q 3 "' 10 :' 93 ~ i 03 581 i !:58i i !5814 ..., (., 4 07 D,&IL.Y ~,,',/ELL O S II F~ V r: Y S U R V E Y ~::, Hi'-' ,'i/,' , F' D u .... ' a R / S G C 'T P E R F' F' E R F :3 S T V D '".u-l-~,8384- "Y 1 i 9 "? 8 ,:, C L';' N / C D R f T ~...'?I'",, "" C D R/'; (? D N ~ <:,~' 3.8. ,!!. ~' i i 9.. 76 . ~'!400'-11786.~ LDWG .__ T ()H--DI...[..~ i ia. 00 ..... I '1788 ~OHP D,.~Tx..: 8/"27/9,) . . "93 ~"8/0B/'9:3 TO 8/'2i/ i2000., ,3CT 1..S00--1'i786 i400--i'1788 1270 .... 11985 .~>~"i a s o I i 7 $ o ~-i1~.00-..I1788 / -~-' '~ . /' F'/{_~.~ ""~+'::,'.-~ I 198,5 S I,~,I/I-.-'RESS TEk1 11.-..: ...... L..L. I 'ia-0C-.' i 1759 r, 0 ...... 1 i q 5 ~x ,3 C (_~-~,?'x A N AD R ..Z._ L i.. I ' .j Q,. t,, // 'J {}/' 9 .,,c:. I}/-",-.. i'1!; F;~ i:; C V D 'ii)/" 'i ~' ' 9q . . '.: / J ,~.. I i/"i9/i993 /' 'J 1.~-/ 'J 9 q "':' I i),/ ,... ,,, 'i// I 9/ 'i 993 i/0 i / i 993 i /~ ('1i // 'i 9 9 7 '1 i/01/'i993 ()/!/' 1 i// r.) 3/' 04/' i 9//'l 994 09/' 29/' 'l 9..:-::.,"" 4- I 'i/"i9/'J!::93 [) .!~ / 'l ,9/'i 994. i i/ i '" / .:.,, i q q 3 , ,' ,:. ,~.. 'i 'i,/"i9/ ifi93 06,,' 'i9/'i9g/! 'i0//i;h./'i993 dr'y ,:';:!~'!:cn sarnp'Jes the. v,;ei I coi-"ed? We i 'i -i s ,"' O H H E J':..! T S ARCO Alaska Inc. Date: Greater Point McIntyre Engineering September 29, 1994 Subject: Transmittal Number 745 From: ARCO Alaska, Inc. To: Bob Crandall 4/e. ~001 PorcupMe Drive ~chorage, ~ 99~01 ~~ F~. ~e follow~g Greater PoMt Mc~tyre Area data are enclosed. ~ms information is confidential ~d your cooperation M maMta~g confidentiality is appreciated: Well Name Data Description L3-01 ....Tubing Puncher Record ~ ~DR-Final ~ ~. C~R-Very E~ced Resistivity -Gamma Ray '~, ~rue Vertical Depth CDR-F~al ~~jection Profile Log (Press-Temp-SP~-GR) ~1 ~jection Profile Log (Press-Temp-SP~-GR) Perfora~on Record 23/~" Phased E~ 6 SPF -07 f~~~g Record wi~ GR/CCL Jewel~ Log Perfo~a~on Record 3-3/s" HSD 4lB ~ 6 SPF _~2-18/ Perfora~g Record wi~ GR/CCL Jewe~ Log ~2-18 . Static Pressure Survey-Press-Temp ~2-21 Perfora~on Record 3-~/8' HSD 41B ~ 6 SPF Tr~~al Nmber: 745 Page: Run # Date Run Company 1 9/6/94 Schlumberger 1-12 3/6/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 8/23/94 Schlumberger 8/23/94 Schlumberger 7/27/94 Schlumberger 7/27/94 Schlumberger 7/21/94 Schlumberger 7/25/94 Schlumberger 7/25/94 Schlumberger 7/22/94 Schlumberger STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SLISPENDED [] ,ABAN~ED [] SERVICE [] 2. Name{' of Operator 7, Permil Number ARCO Alaska, Inc. 93-103 3, Address 9. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22388 4. Location of well at surface 9. Unit or Lease Name 30' NSL, 1046' EWL, SEC. 11, T12N, R14E 'i ?,'.~'~i~;i.~-'.':~;;.j.~.' Point Mclnt. vre At Top Producing Interval .~-~,~.~.,, ..... ~ 10. Well Number 1303' NSL, 1238' WEL, SEC. 3, T12N, R14E 11. Field and Pool At Total Depth ~. · .... Point Mclntyre 1707'NSL, 1349' WEL, SEC. 3, T12N, R14E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 51.6' ! ADL 34622 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 8/6/93 8/18/93 1/30/94I N/A feat MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I0. Depth where SSSV set I1. Thickness of Permafros t 12103' MD/9232' TVD 12010' MD/9177' TVD YeS [] NO [] 2400' feet MD 1750' (Approx.) 22. Type Electric or Other Logs Run C D L/C N L/D L I_/ML L/G R/M WD 23, CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 280 cu ft Arcticset (Approx.) 10-3/4" 45.5# NT-80 40' 4394' 13-1/2" 2821cu ft PF"E"/406 cu ft "G" 7-5/8" 29. 7# NT95HS 36' 11278' 9-7/8" 7-5/8" 29. 7# 13CR80 11278' 12087' 9-7/8" 600 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI Gun Diameter2-1/8", 6 spt 3-1/2", 13CR80 11463' 11395' MD TVD 11660'-11670' 8966'-8972' 11809'- 11830' 8973'-9069' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED !27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/4/94 I FIowing Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZF_ IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOC_.-~3 MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. HRZ 11453' 8831' Kalubik 11493' 8858' Kuparuk 11574' 8910' 31. LIST OF A'I-rACHMENTS 32. I hereby certify t. hat the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Drillina Enaineer Suoervisor Date d-'i'~ ~ f~'__ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Ir~,~,~ jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". BP/AA! SHARED SERVICE DALLY OPERATIONS PAGE: 1 WELL: P2-06 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 08/05/93 08:00 SPUD: RELEASE: 08/21/93 02:30 OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 08/05/93 (1) RIG MAINTENANCE MW: 0.0 VIS: 0 TD: 0'(0) MOVE RIG. N/U DIVERTOR. RIG MAINTENANCE. 08/O6/93 (2) TEST DIVERTER. MW: 8.5 VIS: 0 TD: 110'(110) MOVE RIG. RIG ACCEPTED @ 2O:O0 HRS, 8/5/93. PAJ BHA. TEST DIVERTER. 08/07/93 ( 3) DRILLED TO 2105' MW: 8.5 VIS: 0 TD: 2105'(1995) BHA RUN NO. 1. SET VECO CU~-FINGS TANK. DRILLED TO 2105'. P/U BHA WHILE DRILLING. TAG BOTTOM @ 50' DRILLED & SURVEYED FROM 50' TO 2105'. BEGAN KICK OFF @ 450. 08/08/93 (4) R.I.H. TO 4410' MW: 8.5 VIS: 0 TD: 4410'(2305) BHA RUN NO. 1. DRILLED TO 2840'. DRILLED & SURVEYED FROM 2105' TO 2840' STARTED SCHEDULED WIPER TRIP: DUE TO FOTTAGE DRILLED. CIRC AT 2840'. OBTAINED BOTTOMS UP (100 ANNULUS VOLUME). POOH TO 0.00'. AT 20.000 IN CASING SHOE. R.I.H. TO 2840' ON BOTTON HIT TIGHT SPOT @ 1920'. CIRC THRU, CONTINUE RIH DRILLED TO 4410'. REACHED PLANNED END OF RUN - SECTION / WELL T.D. CIRC AT 4410'. POOH TO 2800' SHORT TRIP TO 2800'. AT TOP OF CHECK TRIP INTERVAL R.I.H. TO 4410' 08/09/93 ( 5) N/D BOPE. MW: 9.5 VIS: 49 TD: 4410'( 0) RIH. CBU. POOH. RIH W/10-3/4" CSG TO 4395'. CMT CSG W/ 415 BBLS CMT. BUMP PLUG W/2000 PSI. N/D DIVERTER. TOP JOB W/42 BBLS CMT. N/U BOPE. 08/10/93 ( TD: 4860'( 6) DRLG. MW: 9.0 VIS: 39 450) N/U BOPE. TEST BOPE. M/U BHA. RIH. CIRC. TEST CSG. OK. DRLG CMT, FC, FS, 10' NEW HOLE. LOT (12.24 PPG EMW). DRLG TO 4860'. 08/11/93 ( 7) DRLG. MW: 9.5 VIS: 37 TD: 6927'(2067) DRLG TO 5622'. CBU. SHORT TRIP TO SHOE. DRLG TO 6642'. CBU. SHORT TRIP TO 5610'. DRLG TO 6927'. 08/12/93 (8) DRLG. MW: 9.5 VIS: 71 TD: 7860'(933) DRLG TO 7046'. CBU. POOH. CHANGE BHA, BIT. RIH. CIRC. DRLG TO 7860'. WELL · P2-06 OPERATION: RIG · POOL 7 PAGE: 2 08/13/93 ( 9) DRLG. MW: 9.5 VIS: 50 TD: 8514'( 654) CBU. SHORT TRIP TO SHOE. DRLG TO 8454'. CBU. POOH. CHANGE BIT. RIH. DRLG TO 8514'. 08/14/93 (10) DRILLING TD: 9841'(1327) DRLD TO 9841. MW: 9.5 VIS: 66 08/15/93 ( 11 ) POH MW: 9.7 VIS: 57 TD:10347'(506) CIRO, POH. REAMED. PULL BHA, LD MWD. SERV BOP. MU BHA #5, RIH. REAM. DRLD TO 10347. POH, CIRC, PUMP DRY JOB, POH. 08/16/93 (12) DRILLING MW: 9.9 VIS: 54 TD:11382'(1035) POH, DOWN LOAD LOG TOOL. SERV B©PE. MU BHA #6, RIH & TEST MWD. RIH. FILL PIPE. RIH. REAM. DRLD TO 11382. 08/17/93 (13) POOH TO 220' AT BHA MW: 9.9 VIS: 0 TD:11975'( 593) BHA RUN NO. 6. DRILLED TO 11479'. CIRC AT 11479'. OBTAINED CLEAN RETURNS - 120.00 3677775767OLE VOLUME. CIRC HI VlSC SWEEP AROUND. POOH TO 10450'. AT TOP OF CHECK TRIP INTERVAL. R.I.H. TO 11479'. ON BOTTON. DRILLED TO 11975'. ROP DROPPED FROM 50.0 FT/HR TO 2.0 FT/HR - BIT QUIT. POOH TO 220.00 FT. AT BHA 08/18/93 (14) CIRC AT 12103' TD:12103'(128) MW: 9.9 VIS: 0 08/19/93 (15) RAN CASING TO 9000' MW: 9.9 VIS: 0 TD:12103'( 0) CIRC. POOH. MIPPLE UP TOP RAM. RIGGED UP TOP RAM. RAN CASING TO 9000'. 08/20/93 (16) N/U BOPE. MW:10.3 WBM TD:12103 RIH W/7-5/8" CSG. CIRC. PUMP 554 BBLS CMT. BUMP PLUG. PB: 0 TEST CSG. OK. TEST BOPE. RIH TO 2300'. DISP HOLE W/ DIESEL. POOH. L/D DP. N/D BOPE. NAJ BOPE. 08/21/93 (17) RIG RELEASED. MW:10.3 WBM TD:12103 N/U BOPE. RIH W/RI-I'S. SET@ 89'. N/D BOPE. N/U BOPE. PB: 0 L/D DP. N/D BOPE. N/U DUMMY TREE. RIG RELEASED @ 02:30 HRS, 8/21/93. SIGNATURE: DATE: (drilling superintendent) COMPANY ARCO ALASKA INC. FIELD P2-06 WELL POINT MCINTYRE COUNTRY USA RUN ONE DATE LOGGED 7-JAN-1994 REFERENCE 94058 All interpretations are opinions based on inferences from electrical or ot~er measurements and we cannot and do not guarantee 1fie accuracy or correcth~ess of an¥interpretations, and we sha not, except in the case of gross or wilfull negl gence on our part. be liable or responsible for any loss, costs, damaQes or expenses incurred or sustained by anyone result ng from any interpretation. _made by a..n...v of ,o. ur officers, age. ri. rs or empioy.ees.. Thee ,se in, te, rpretations are also subject to our L~eneral/erms algol L;or~31fions as set out ~n our current pr ce ~:~cneoule. WELL' P2-06 (30'FSL & 1045'FWL, SEC.11, T'-~', R14E) · ..... 'ORIZONTAL PROJECTION NORTH 12000 10000 8000 6000 4000 2000 -2000 ~u~ -4000 REF 94058 SCALE = 1 / 2000 IN/IT i' ! ! ! !'i-'!" !'!"! ! ~ ~ ~'! ~ ~ ! i i i i i . . i , . ~ , . , i .... i i ..... i ! ! i -i i }--i -i---i---?-i '} i , ~ i i ~ i. i i i i : ~-~ i i ! 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I ...... ~'~':";'i .... 5-!"i";'5'"'"'! !'"7'i'i'I'''?''!'~ ..... .... 5":-]"5'~'~0o0: : ..... ] ....... :' I[ i:ii i--i ~-i!' i~: !i,i ,ili:.:' :i: ~ooo :. , _!, .......... i- :;-: .-~-.!,--: "i"i"i"~ '"~ "~ ..... !'"5"!"! !''' '~ ''': ............ I ! ~ , . . . "~'~' } .... i"i '!'¥'i~'i . t ..... : .... ! . ~ i ! !..i ........ i.i..! t -~ -~-; .--.-: i .: : . ' i ........... !"t'! ! : ; ! ' ! : ' ' ' ' I ; ;:-;!-'!--;-!--i--'i--!-!i'-!--i;:':"i:";::: ':i: ..... . .. ........... ! ..... :...; ......... :: .............. !..i ....... !..-i-.-,.-: ...... i...i ....... " ~' ~; .... - .... I · . --; ..... : ...... ; .... : .... ;"77 '': .... : :':'i ................. ' :.,5:- !;--!---:---!--~--,---;-.;--;;-! ~':-5---; ' ; '' : I r -8000 -6000 ~4000 -2000 0 2000 4000 5000 8000 WEST ~ELL' P2-06 (30'FSL & 1045'FWL, SEC.11,T12'-'-"~14E) ~'VERTICAL PROdECTZON l~JO.O -4000 -2000 0 Cl' 2000 4000 6000 8000 10000 .: .... i ..... ;...i-..i .... ;...i...L-.i ..... i...i...i..,i .... ;,..~...L.,i ...... i..4.-.L..~ .... L-.;.--L..i ..... ;...i.i.-.;...i,.:...L~ .... : ...... L.,~ .... : ..... ~..: ...... ~..LL; .... ~...;.-.L..; ........... : ..... ; ..... .: ;: .:;. :.:: ::.; ::: :..: ;;.: :::. .::: ;..: :;. .;: : .. :::: :::: -::: ::.: :.:: :::: :;:: ::-: :.: :.:: :::: :::- ::. · :~: .:~..~..:. ~..~.~.L.L.~.~ :~: ~- -::- :- -::. ~:~.~ ...~.~.:...:,~.~eo]e~.~ ..... :...:.. .... · -h--h--~ .... h..~..~..L.[.~.~.~.~.,[~i~.,.; .. 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':' ' 12000 340.0 PROJECTION ON VERTICAL PLANE 160.0 - 340.0 ~CALED IN VERTICAL OEPI'I-IS HOf::~IZ SCALE = 1 / 2000 IN/I=T BP/AAI SHARED SERVICE WELL: P2-06 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: DAILY OPERATIONS PAGE: 1 ACCEPT: 01/21/94 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 14 01/22/94 (1) TD:12103 PB:12010 RUNNING COMPLETION MW: 0.0 ND, NU BOPE & TEST. RIH, DISPLC W/SW. MU STORM PKR & SET. ND BOPE. LD PKR. RU & RUN TBG. RIG ACPTD 1-21-94 @ 0600 HRS. 01/23/94 ( 2) TD:12103 PB:12010 MOVE RIG MW: 0.0 CONT TO RUN COMPLETION. ND, NU TREE. PUMP DIESEL, SET PKR. CLEAN PITS. RELEASE RIG 1-23-94 @ 0300 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED r~UIDANCE $ UB.S URFA CE DIRECTIONAL SURVEY [~]ONTINUOUS F~'IOOL RECEIVED Company Well Name Field/Location . ARCO ALASKA, INC. P2-06 (30'FSL & 1045'Fla., SEC.11, T12N, R14E) POINT HCINTYRE, NORTH SLOPE, ALASKA Job Reference No. 94O58 Logaed By: SCi*il, IARTZ - Date · 7-JAN- 1994 Computed By:, SINES . SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE' 7-JAN-1994 ENGINEER' SCHWARTZ METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 19 DEG SB MIN WEST COMPUTATION DATE' 16-FEB-94 PAGE I ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 7-JAN-1994 KELLY BUSHING ELEVATION' 53.50 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI~JTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMU-~ FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 3O0 O0 400 O0 5OO O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 400 O0 499 98 599 92 699 65 798 83 897 71 -53 50 46 50 146 50 246 50 346 50 446 48 546 42 646 15 745 33 844 21 0 0 N 0 0 E 0 10 N 13 27 E 0 12 N27 5 E 0 8 N 1 10 E 0 45 N 1 35 E I 32 N 5 17W 2 34 N 6 14 W 5 55 N 7 58 W 8 10 N 9 49 W 9 i N 9 3'1W 0 O0 0 O8 0 28 0 51 1 15 2 88 6 14 '13 07 25 63 40 27 0 O0 0 01 0 O0 0 O0 0 01 0 01 0 02 0 O4 0 01 0 01 000N 0 09 N 0 36N 0 63N 1 33N 3 14N 647 N 13 55 N 26 13 N 40 81 N 0.00 E 0.01 E 0.'17 E 0.24 E O.3O E 0.21 E 0.19 W 0.97 W 3.14 W 5.60 W 1 3 6 13 26 41 0 O0 N 0 0 E 0 09 N 4 57 E 0 40 N 24 36 E 0 68 N 2O 43 E 36 N 12 46 E 15 N 3 46 E 47 N I 4O W 59 N 4 6 W 32 N 6 51 W 19 N 7 48 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 996.25 O0 1094 14 1040 O0 1190 O0 1286 O0 1381 O0 1476 O0 1569 O0 1661 O0 1752 O0 1842 87 1137 41 1232 41 1327 23 1422 68 1516 87 1608 96 1699 31 1788 942 75 10 38 64 13 8 37 15 58 91 18 7 91 18 6 73 19 18 18 22 8 37 23 27 46 25 20 81 28 30 N 9 32W N 10.36 W N 16 3W N 22 31 W N 21 56 W N 18 25W N 17 32W N 18 OW N 2O 23 W N 23 59 W 56 99 77 05 102 20 131 69 162 89 194 62 230 16 268 87 310 11 354 94 0 02 0 04 0 O3 0 01 0 01 0 03 0 O2 0 O2 0 02 0 O5 57 55 N 77 65 N 102 29 N 130 03 N 158 86 N 188 65 N 222 52 N 259 43 N 298 41N 339 848W 11 17 27 39 5O 61 73 86 93 N 103 58 18 N 8 23 W 91W 78 73 W 103 74 W 132 76 W 163 71W 195 55 W 23O 31W 269 80 W 310 80 W 355 56 N 8 43 W 82 N '9 50 W 96 N 12 3 W 76 N 14 3 W 34 N 15 3 W 87 N 15 28 W 59 N 15 47 W 77 N 16 13 W 42 N 16 59 W 2000 O0 1927 37 1873 87 34 42 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2008 02 1954 O0 2087 82 2034 O0 2168 11 2114 O0 2246 86 2193 O0 2321 16 2267 O0 2393 69 2340 O0 2465.05 2411 O0 2536.28 2482 O0 2609.99 2556 52 37 10 32 36 46 61 36 47 36 40 1 66 43 5 lg 43 55 55 45 2 78 43 30 49 41 49 N 24 20 W N 23 22 W N 21 38 W N 21 59 W N 24 51W N 24 44 W N 23 51W N 25 44 W N 25 26 W N 23 42 W 407 25 466 21 526 42 586 O1 647 48 714 14 782 79 852 61 922 43 989.77 0 O5 0 O1 0 O1 0 O3 0 O6 0 01 0 01 0 02 0 O3 0 O2 387 71 N 125 48 W 407.51 N 17 56 W 441 497 552 609 670 732 796 859 921 75 N 149 41N 172 94 N 194 35 N 218 05 N 247 81N 275 52 N 304 69 N 335 12 N 363 39 W 466.33 N 18 41W 50 W 526.47 N 19 8 W 17 W 586 04 N 19 21 W 94 W 647 49 N 19 46 W 09 W 714 15 N 20 15 W 36 W 782 84 N 20 36 W 47 W 852 73 N 20 55 W 06 W 922 68 N 21 18 W 18 W 990 13 N 21 31W 3000.00 2684.48 2630.98 42 13 3100.00 2756.91 2703.41 44 45 3200.00 2827.36 2773.86 45 32 3300 O0 2897.25 2843 75 45 50 3400 O0 2966.39 2912 89 46 49 3500 O0 3034.27 2980 77 47 25 3600 O0 3102.40 3048 90 46 36 3700 O0 3171.92 3118 42 45 23 3800 O0 3242.51 3189 O1 44 SO 3900 O0 3313.72 3260 22 44 32 N 22 31W 1056 40 N 22 55 W 1125 25 N 22 17 W 1196 14 N 21 44 W 1267 62 N 22 59 W 1339 82 N 25 27 W 1413 O0 N 24 43 W 1485 go N 23 49 W 1557 58 N 23 0 W 1628 28 N 22 27 W 1698.41 0 O2 0 O2 0 01 0 01 0 04 0 01 0 01 0 01 0 01 0 O0 982 58 N 389 16 W 1056 83 N 21 36 W 1046 1111 1177 1244 1311 1377 1443 1508 1573 11N 415 64 N 443 96 N 469 95 N 496 68 N 527 98 N 558 51N 588 52 N 616 30 N 643 90 W 1125 15 W 1196 92 W 1268 96 W 1340 59 W 1413 61W 1486 14 W 1558 25 W 1629 33 W 1699 76 N 21 41W 71 N 21 44 W 23 N 21 45 W 47 N 21 46 W 81 N 21 55 W 90 N 22 4 W 73 N 22 lO W 54 N 22 13 W 74 N 22 14 W COMPUTATION DATE' 16-FEB-94 PAGE 2 ARCO ALASKA INC. P2-06 POINT MCTNTYRE NORTH SLOPE, ALASKA DATE OF sUrVEY, 7-JAN-1994 KELLY BUSHING ELEVATION' 53.50 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMLrrH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIaUTH FEET DEG/IO0 FEET FEET FEET DEG aiM 4000 O0 3384 76 3331 26 44 57 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3455 O0 3527 O0 3598 O0 3670 O0 3740 O0 3812 O0 3884 O0 3955 O0 4026 67 3402 19 3473 64 3545 11 3616 86 3687 70 3759 33 3830 32 3901 78 3973 17 44 32 69 44 19 14 44 19 61 44 46 36 44 47 20 43 48 83 44 45 82 44 37 28 44 5 N 22 5 W 1768 74 N 21 42 W 1839 N 21 19 W 1909 N 21 3 W 1979 N 21 6 W 2048 N 21 3 W 2119 N 21 10 W 2189 N 21 33 W 2258 N 21 32 W 2329 N 21 27 W 2399 21 08 02 96 61 16 91 32 25 0 O0 0 O1 0 O0 0 O1 0 01 0 02 0 O1 0 O1 0 O0 0 O1 1638 43 N 669 99 W 1770 13 N 22 14 W 1703 1768 1834 1899 1965 2O30 2095 2160 2225 86 N 696 89 N 721 13 N 747 42 N 772 36 N 797 26 N 822 24 N 848 75 N 873 85 N 899 29 W 1840 90 W 1910 15 W 1980 27 W 2050 67 W 2121 68 W 2190 11W 2260 98 W 2330 59 W 2400 64 N 22 14 W 53 N 22 12 W 47 N 22 10 W 41 N 22 8 W 06 N 22 5 W 61 N 22 3 W 38 N 22 2 W 81 N 22 ! W 77 N 22 0 W 5000 O0 4099 07 4045.57 43 18 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4~72 O0 4245 O0 4318 O0 4391 O0 4465 O0 4538 O0 4611 O0 4683 O0 4756 11 4118.61 43 1 23 4191.73 43 0 52 4265.02 42 48 98 4338.48 42 46 31 4411.81 42 52 52 4485.02 43 4 35 4557.85 43 20 84 4630.34 43 48 O0 4702.50 43 53 N 21 3O W 2468 32 N 21 36 W 2536 N 21 45 W 2604 N 21 41W 2672 N 21 38 W 2740 N 21 43 W 2808 N 21 52 W 2876 N 21 56 W 2945 N 21 41W 3013 N 21 36 W 3083 60 79 78 60 57 66 13 99 19 0 01 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 0 O0 2290 15 N 924 88 W 2469 86 N 21 59 W 2353 2417 2480 2543 2606 2669 2733 2797 2861 69 N 949 09 N 975 30 N 1000 36 N 1025 55 N 1050 81N 1075 37 N 1101 34 N 1126 69 N 1152 94 W 2538 12 W 2606 28 W 2674 31W 2742 41W 2810 70 W 2878 28 W 2946 85 W 3015 38 W 3085 16 N 21 59 W 37 N 21 58 W 40 N 21 58 W 25 N 21 57 W 25 N 21 57 W 37 N 21 57 W 88 N 21 57 W 77 N 21 56 W O1 N 21 56 W 6000 O0 4827 98 4774 48 44 3 6100 6200 6300 6400 6500 66OO 6700 6800 6900 O0 4899 O0 4971 O0 5042 O0 5113 O0 5185 O0 5256 O0 5328 O0 5399 O0 5470 68 4846 20 4917 51 4989 76 5060 27 5131 88 5203 30 5274 59 5346 76 5417 18 44 18 70 44 25 O1 44 37 26 44 27 77 44 17 38 44 19 80 44 31 09 44 35 26 44 41 N 21 27 W 3152 58 N 21 1W 3222 N 20 57 W 3292 N 2O 49 W 3362 N 20 51W 3432 N 20 59 W 3502 N 20 56 W 3572 N 20 59 W 3642 N 2O 59 W 3712 N 2O 31W 3782 27 15 25 41 3O 09 07 2O 43 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 2926 25 N 1177 87 W 3154.42 N 21 56 W 2991 3056 3122 3187 3252 3318 3383 3448 3514 23 N 1203 51N 1228 01N 1253 59 N 1278 89 N 1302 07 N 1327 44 N 1352 91N 1378 6O N 1402 12 W 3224.12 N 21 55 W 10 W 3294 O0 N 21 53 W og W 3364 10 N 21 52 W 03 W 3434 26 N 21 51 W 98 W 3504 14 N 21 50 W 95 W 3573 94 N 21 49 W 96 W 3643 92 N 21 48 W 10 W 3714 05 N 21 47 W 98 W 3784 28 N 21 46 W 7000 O0 5541 92 5488 42 44 32 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5613 O0 5684 O0 5756 O0 5829 O0 5901 O0 5973 O0 6043 O0 6113 O0 6182 21 5559 82 5631 87 5703 03 5775 29 5847 15 5919 42 5989 10 6059 58 6129 71 44 30 32 44 6 37 43 47 53 43 47 79 43 43 65 44 39 92 45 47 60 45 55 08 46 1 N 20 15 W 3852 69 N 20 19 W 3922 N 20 11W 3992 N 19 49 W 4061 N 19 31W 4131 N 19 6 W 4200 N 19 35 W 4269 N 20 36 W 4340 N 20 10 W 4412 N 19 31W 4484 82 61 96 18 31 84 99 71 62 0 O0 0 O1 0 O0 0 O0 0 O0 0 O0 0 O3 0 O0 0 O1 0 O0 3580 48 N 1427 40 W 3854 52 N 21 44 W 3646 27 N 1451 3711 74 N 1475 3776 91N 1499 3842 10 N 1522 3907 33 N 1545 3973 05 N 1568 4039.77 N 1593 4106.97 N 1618 4174.65 N 1642 70 W 3924 88 W 3994 58 W 4063 88 W 4132 75 W 4201 49 W 4271 2O W 4342 25 W 4414 57 W 4486 63 N 21 43 W 40 N 21 41W 72 N 21 39 W 90 N 21 37 W 98 N 21 35 W 45 N 21 33 W 58 N 21 31W 29 N 21 30 W 18 N 21 29 W COMPUTATION DATE' 16-FEB-94 PaGE 3 ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 7-JAN-1994 KELLY BUSHING ELEVATION- 53.50 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 6251.95 6198.45 46 7 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6322.61 6269.11 43 24 OD 6395.84 6342,34 42 46 O0 6469.20 6415.70 42 55 O0 6542.30 6488.80 43 7 O0 6615,78 6562.28 42 29 O0 6689.45 6635.95 42 36 O0 6763.01 6709.51 42 40 OO 6836.57 6783.07 42 31 O0 6910.25 6856.75 42 38 N 19 32 W 4556 65 N 20 27 W 4627 N 20 55 W 4695 N 20 50 W 4763 N 20 46 W 4831 N 19 28 W 4899 N 19 44 W 4967 N 19 44 W 5034 N 19 21W 5102 N 19 9 W 5170 40 48 43 66 49 lO 85 59 19 0 O1 0 03 0 O0 0 O0 0 O1 0 O0 0 O0 0 O0 0 01 0 O0 4242.57 N 1666 58 W 4558 17 N 21 27 W 4309.15 N 1690 4372.77 N 1714 4436.29 N 1738 4500.05 N 1763 4563.81 N 1786 4627.51 N 1809 4691.27 N 1831 4755.11N 1854 4818.96 N 1876 49 W 4628 74 W 4696 93 W 4764 22 W 4833 37 W 4900 04 W 4968 95 W 5036 59 W 5103 84 W 5171 88 N 21 25 W 96 N 21 25 W 93 N 21 24 W 16 N 21 24 W 97 N 21 23 W 55 N 21 21W 27 N 21 20 W 98 N 21 18 W 54 N 21 17 W 9000 O0 6983 69 6930.19 42 56 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7056 O0 7131 O0 7207 O0 7283 O0 7359 O0 7436 O0 7513 O0 7589 O0 7665 95 7003.45 42 24 97 7078.47 40 56 52 7154 02 40 48 37 7229 87 40 38 44 7305 94 40 14 08 7382 58 39 38 15 7459 65 40 10 21 7535 71 40 22 65 7612 15 39 59 N 19 19 W 5238 05 N 19 18 W 5306 12 N 19 10 W 5372 22 N 19 7 W 5437 73 N 18 43 W 5502 N 17 57 W 5567 N 17 6 W 5631 N 16 52 W 5695 N 16 38 W 5760 N 15 49 W 5824 89 77 96 58 4O 73 0.01 0.03 0. O0 0.01 0. O0 0.01 0.01 0.02 0.01 0.01 4883 04 N 1899 18 W 5239.37 N 21 15 W 4947 5009 5071 5133 5194 5256 5317 5379 5441 28 N 1921 70 N 1943 58 N 1964 24 N 1986 85 N 2006 09 N 2025 11N 2044 22 N 2063 15 N 2081 69 W 5307.40 N 21 14 W 48 W 5373.47 N 21 12 W 98 W 5438.94 N 21 11 W 08 W 5504 06 N 21 9 W 51W 5568 89 N 21 7 W 92 W 5633 O1 N 21 5 W 26 W 5696 55 N 21 2 W 16 W 5761 30 N 20 59 W 08 W 5825 55 N 20 56 W 10000 O0 7742 70 7689.20 39 16 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 7820 O0 7898 O0 7977 O0 8056 O0 8135 O0 8214 O0 8291 O0 8368 O0 8444 36 7766.86 38 46 65 7845.15 38 11 65 7924.15 37 31 96 8003 46 37 40 85 8082 35 38 9 12 8160 62 38 51 71 8238 21 39 21 50 8315 O0 40 24 06 8390 56 41 20 N 15 41W 5888 29 N 15 58 W 5951 12 N 16 11 W 6013 20 N 16 5 W 6074 37 N 15 56 W 6135 14 N 16 2 W 6196 44 N 16 21W 6258 54 N 16 23 W 6321 50 N 16 26 W 6385 43 N 16 23 W 6450.81 0 O0 0 O1 0 O1 0 O0 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 5502 51N 2098.32 W 5889 02 N 20 52 W 5563 12 N 2115.51W 5951 5622 90 N 2132.76 W 6013 5681 79 N 2149 79 W 6074 5740 35 N 2166 57 W 6135 5799 43 N 2183 48 W 6196 5859.20 N 2200 81 W 6258 5919.73 N 2218 59 W 6321 5981.18 N 2236 68 W 6385 6044,01 N 2255 20 W 6451 78 N 20 49 W 78 N 20 46 W 90 N 20 43 W 61 N 20 41 W 85 N 20 38 W 9O N 2O 35 W 81 N 20 33 W 70 N 20 30 W O5 N 2O 28 W 11000 O0 8518 48 8464 98 42 34 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 8591 O0 8662 O0 8731 O0 8799 O0 8866 O0 8931 O0 8994 O0 9055 O0 9114 13 8537 22 8608 86 8678 87 8746 24 8812 18 8877 25 8940 28 9001 91 9061 63 44 11 72 45 13 36 46 28 37 47 47 74 49 4 68 50 9 75 51 43 78 52 57 41 53 50 N 16 18 W 6517.46 N 16 16 W 6586 03 N 16 22 W 6656 N 16 13 W 6727 N 16 13 W 6800 N 16 3 W 6875 N 15 51W 6951 N 15 36 W 7028 N 15 26 W 7107 N 15 8 W 7187.81 21 82 97 60 46 84 81 0 O2 0 O1 0 O1 0 O1 0 O1 0 02 0 O1 0 02 0 O1 0 02 6108 11 N 2273 97 W 6517 66 N 20 25 W 6174 6241 6310 6380 6452 6525 6600 6676 6754 07 N 2293 57 N 2312 44 N 2333 84 N 2353 68 N 2374 81N 2395 52 N 2416 86 N 2437 3O N 2458 21W 6586 19 N 20 23 W 96 W 6656 35 N 20 20 W 10 W 6727 93 N 20 17 W 55 W 6801 05 N 20 15 W 35 W 6875 66 N 20 12 W 21W 6951.49 N 20 9 W 18 W 7028,86 N 20 6 W 34 W 7107.81 N 20 3 W 47 W 7187.81 N 20 0 W COMPUTATION DATE: 16-FEB-94 PAGE 4 ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 7-JAN-1994 KELLY BUSHING ELEVATION: 63.50 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG 12000.00 9173.01 9119.51 54 44 N 15 4 W 7268.90 0.00 6832.89 N 2479.62 W 7268.90 N 19 57 W COMPUTATION DATE: 16-FEB-94 PAGE ARCO ALASKA INC. P2-06 POINT MC INTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 7-JAN-1994 KELLY BUSHING ELEVATION: 53.50 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET Of MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED YERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLFFH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IOO FEET FEET FEET DEG MIN 0. O0 0 O0 1000.00 996 2000.00 i927 3000.00 2684 4000.00 3384 5000.00 4099 6O00.00 4827 7000.00 5541 8000.00 6251 9000.00 6983 25 942.75 10 38 N 9 32 W 56 37 1873.87 34 42 N 24 20 W 407 48 2630 98 42 13 N 22 31 W 1056 76 3331 26 44 57 N 22 5 W 1768 07 4045 57 43 18 N 21 30 W 2468 98 4774 48 44 3 N 21 27 W 3152 92 5488 42 44 32 N 20 15 W 3852 95 6198 45 46 7 N 19 32 W 4556 69 6930 19 42 56 N 19 19 W 5238 0 O0 -53.50 0 0 N 0 0 E 0 O0 99 25 4O 74 32 58 69 65 O5 0 02 57 0 05 387 0 02 982 0 O0 1638 0 O1 2290 0 O0 2926 0 O0 3580 0 01 4242 0 O1 4883 55 N 8.48 W 58 71N 125.48 W 407 58 N 389.16 W 1056 43 N 669 99 W 1770 15 N 924 88 W 2469 25 N 1177 87 W 3154 48 N 1427 40 W 3854 57 N 1666 58 W 4558 04 N 1899 18 W 5239 0 O0 N 0.00 E 0 O0 N 0 0 E 18 N 8 23 W 51 N 17 56 W 83 N 21 36 W 13 N 22 14 W 86 N 21 59 W 42 N 21 56 W 52 N 21 44 W 17 N 21 27 W 37 N 21 15 W 10000.00 7742.70 7689.20 39 16 N 15 41W 5888.29 11000.00 8518.48 8464.98 42 34 N 16 18 W 6517.46 12000.00 9173.01 9119.51 54 44 N 15 4 W 7268.90 0.00 5502.51 N 2098.32 W 5889.02 N 20 52 W 0.02 6108.11 N 2273.97 W 6517.66 N 20 25 W 0.00 6832.89 N 2479.62 W 7268.90 N 19 57 W COMPUTATION DATE' 16-FEB-94 PAGE 6 ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 7-JAN-1994 KELLY BUSHING ELEVATION' 53.50 FT ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARI'URE SECTION SEVERITY NORTH/SOU-rH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 53 50 153 50 253 50 353 50 453 51 553 55 653 67 754 24 855 26 0 O0 53 50 153 50 253 50 353 50 453 50 553 5O 653 50 753 50 853 50 -53 50 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 8 S 19 31E 0 10 N 34 3 E 0 10 N 13 40 E 0 23 N 9 6 E 0 59 N 3 35 W I 53 N 7 34 W 4 8 N 5 43 W 7 35 N 10 12 W 8 36 N 9 3O W 0 O0 0 02 0 19 0 41 0 71 I 91 4 43 9 12 19 42 33 55 0 O0 0 02 0 O0 0 O0 0 O1 0 01 0 O1 0 O4 0 02 0 01 0 O0 N 0 03 N 0 24 N 0 52 N 085N 2 13N 4 72N 9 53 N 19 93 N 34 07 N 0 O0 E O02E 0 09 E 0 23 E 0 26E 0 27 E 0 02 E 049W 2 04W 4 47W 000 N 0 OE 0 0 0 0 2 4 9 20 34 03 N 37 42 E 25 N 20 48 E 57 N 23 30 E 89 N 17 1E 15 N 7 16 E 72 N 0 17 E 54 N 2 58 W 03 N 5 50 W 36 N 7 29 W 956 55 1058 1161 1265 1370 1475 1582 1690 1800 1912 953 50 50 1000 50 1100 50 1200 50 1300 50 1400 5O 1500 50 1600 50 1700 50 1800 37 1053 21 1153 41 1253 63 1353 95 1453 54 1553 88 1653 60 1753 82 1853 900 O0 9 52 O0 11 56 O0 15 3 O0 17 32 O0 18 12 O0 18 46 O0 21 49 O0 23 19 O0 25 20 O0 29 14 N 9 49 W N 9,34 W N 13 45 W N 21 17 W N 22 41W N 19 13 W N 17 32 W N 17 54 W N 20 24 W N 24 13 W 49 38 68 19 91 87 121 05 153 186 223 265 310 361 75 79 61 26 37 18 0 02 0 03 0 O3 0 O3 0 O1 0 02 0 02 0 O1 0 02 0 O6 49 93 N 68 80 N 92 27 N 120 17 N 150 39 N 181 23 N 216 27 N 256 O0 N 298 65 N 345 7 18W 10 15 23 36 48 59 72 86 64 N 106 50.44 N 8 11W 35 W 69.57 N 8 33 W 07 W 93.49 N '9 17 W 73 W 122.49 N 11 10 W 29 W 154 71 N 13 34 W 17 W 187 53 N 14 53 W 58 W 224 32 N 15 24 W 20 W 265 98 N 15 45 W 89 W 311 03 N 16 13 W 36 W 361 64 N 17 6 W 2032 03 1953 50 1900.00 35 57 2157 2281 2408 2544 2683 2823 2958 3095 3237 07 2053 78 2153 79 2253 41 2353 65 2453 65 2553 33 2653 22 2753 34 2853 50 2000.00 37 6 50 2100.00 36 35 50 2200.00 40 28 50 2300.00 43 28 50 2400.00 44 54 50 2500.00 42 52 50 2600.00 41 48 50 2700.00 44 40 50 2800.00 45 37 N 24 4 W N 22 28 W 500 N 21 26 W 575 N 24 53 W 653 N 24 19 W 744 N 25 23 W 841 N 25 3 W 938 N 22 43 W 1028 N 22 56 W 1121 N 22 3 W 1222 425 72 65 13 21 48 10 58 56 90 79 0 03 0 O1 0 02 0 06 0 O1 0 03 0 03 0 O1 0 02 0 O0 404 60 N 133 07 W 425 92 N 18 12 W 473 542 614 697 786 874 956 1043 1136 51N 162 83 N 190 56 N 221 73 N 259 10 N 299 36 N 341 84 N 378 02 N 414 84 W 500 15 W 575 36 W 653 72 W 744 45 W 841 99 W 938 45 W 1028 59 W 1122 34 N 453.21 W 1223 73 N 18 59 W 17 N 19 18 W 21 N 19 49 W 50 N 20 25 W 20 N 20 51W 86 N 21 22 W 96 N 21 35 W 40 N 21 41W 38 N 21 45 W 3381 20 2953 50 2900 O0 46 34 3528 3673 3815 3955 4096 4236 4376 4517 4656 38 3053 73 3153 49 3253 89 3353 96 3453 81 3553 66 3653 75 3753 50 3000 50 3100 50 3200 50 3300 SO 3400 5O 350O 5O 36OO 50 3700 74 3853.50 3800 O0 47 15 O0 45 38 O0 44 44 O0 44 45 O0 44 33 O0 44 24 O0 44 31 O0 44 28 O0 44 18 N 22 17 W 1326 15 N 25 15 W 1433 78 N 24 2 W 1538 89 N 22 53 W 1639 18 N 22 15 W 1737 65 N 21 43 W 1837 08 N 21 12 W 1934.81 N 21 4 W 2032.56 N 21 3 W 2132.08 N 21 25 W 2228.58 0 03 0 O1 0 O1 0 O1 0 O1 0 O1 0, O0 0.01 0.03 0.01 1232 33 N 491.67 W 1326 79 N 21 45 W 1330 1426 39 N 580 1518 57 N 620 1609 62 N 658 1701 88 N 695 1792 88 N 731 1884.12 N 766 1976.99 N 802 2067.01N 837 55 N 536 53 W 1434 55 W 1540 51W 1640 26 W 1739 51W 1838 22 W 1936 37 W 2034 15 W 2133 65 N 21 58 W O1 N 22 9 W 46 N 22 14 W O1 N 22 15 W 51 N 22 14 W 26 N 22 11W O1 N 22 8 W 53 N 22 5 W 00 W 2230.04 N 22 3 W COMPUTATION DATE' 16-FEB-94 PAGE 7 ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF surveY: 7-JAN-1994 KELLY BUSHING ELEVATION' 53.50 ET ENGINEER' SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG 4797.44 3953 50 3900.00 44 37 4937.11 4053 5074.55 4153 5211.30 4253 5347 62 4353 5483 89 4453 5620 53 4553 5758 04 4653 5896 54 4753 6035 54 4853 50 4000.00 43 48 50 4100.00 43 1 50 4200.00 42 58 50 4300.00 42 41 50 4400.00 42 53 50 4500.00 43 10 50 4600.00 43 35 50 4700.00 43 52 50 4800.00 44 10 N 21 32 W 2327 52 N 21 28 W 2425 O0 N 21 33 W 2519 25 N 21 44 W 2612 48 N 21 4O W 2705 N 21 42 W 2797 N 21 54 W 2890 N 21 45 W 2985 N 21 37 W 3080 N 21 19 W 3177 08 61 68 02 79 3O 0 O0 0 O1 0 O0 0 O0 0 O0 0 O0 0 01 0 01 0 O0 0 O0 2159 07 N 873.32 W 2329 O1 N 22 1W 2249 2337 2424 2510 2596 2682 2770 2859 2949 82 N 909.01W 2426 55 N 943.56 W 2520 24 N 977.97 W 2614 33 N 1012.21W 2706 37 N 1046.36 W 2799 83 N 1080.93 W 2892 41 N 1116.12 W 2986 46 N 1151.50 W 3082 29 N 1186.89 W 3179 52 N 22 0 W 80 N 21 59 W 07 N 21 58 W 71 N 21 58 W 28 N 21 57 W 40 N 21 57 W 79 N 21 57 W 61 N 21 56 W 15 N 21 55 W 6175 23 4953 50 4900 O0 44 22 6315 6455 6595 6735 6875 7016 7156 7295 7433 44 5053 61 5153 28 5253 34 5353 73 5453 24 5553 33 5653 33 5753 87 5853 50 500O 50 5100 50 5200 5O 5300 50 5400 50 5500 50 5600 50 5700 50 5800 O0 44 38 O0 44 18 O0 44 18 O0 44 32 O0 44 39 O0 44 31 O0 44 14 O0 43 47 O0 43 44 N 20 56 W 3274 82 N 20 49 W 3373 N 20 56 W 3471 N 20 56 W 3568 N 21 1W 3666 N 2O 39 W 3765 N 20 15 W 3864 N 2O 17 W 3962 N 19 50 W 4058 N 19 25 W 4154 10 30 79 85 37 08 19 73 61 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 3040 32 N 1221 91 W 3276 67 N 21 54 W 3132 3223 3314 3406 3498 3591 3683 3773 3864 15 N 1256 94 N 1291 99 N 1326 58 N 1361 62 N 1396 17 N 1431 19 N 1465 88 N 1498 19 N 1530 94 W 3374 89 W 3473 77 W 3570 84 W 3668 99 W 3767 34 W 3865 36 W 3963 48 W 4060 69 W 4156 95 N 21 52 W 15 N 21 50 W 64 N 21 49 W 70 N 21 47 W 22 N 21 46 W 91 N 21 44 W 99 N 21 42 W 49 N 21 39 W 31 N 21 37 W 7572.47 5953 50 5900.00 44 13 7714.46 6053 7858.12 6153 8OO2 24 6253 8142 32 6353 8278 58 6453 8415 31 6553 8551 18 6653 8687 07 6753 8822 96 6853 50 6000.00 45 47 50 6100.00 46 1 50 6200 O0 46 6 50 6300 O0 42 48 50 6400 O0 42 52 50 6500 O0 42 59 50 6600 O0 42 32 50 6700 O0 42 39 50 6800 O0 42 30 N 19 4 W 425O 56 N 20 35 W 4351 N 19 41W 4454 N 19 32 W 4558 N 21 3 W 4656 N 20 50 W 4748 N 20 3O W 4842 N 19 35 W 4934 N 19 46 W 5026 N 19 16 W 5118 35 49 26 31 85 10 07 O9 10 0 02 0 O0 0 O0 0 O1 0 O0 0 O0 0 02 0 O0 0 O0 0 O0 3954 86 N 1562 10 W 4252.18 N 21 33 W 4049 4146 4244 4336 4422 4509 4596 4683 4769 47 N 1596 84 W 4352.95 N 21 31W 26 N 1632 47 W 4456:06 N 21 29 W 09 N 1667 12 W 4559.77 N 21 27 W 19 N 1700 73 W 4657.79 N 21 25 W 66 N 1733 75 W 4750.35 N 21 24 W 83 N 1766.87 W 4843.60 N 21 24 W 40 N 1797.93 W 4935.53 N 21 22 W 02 N 1829.00 W 5027.51 N 21 20 W 76 N 1859.71 W 5119.48 N 21 18 W 8958 83 6953 50 6900 O0 42 44 9095 9228 9360 9492 9622 9753 9884 10013 10142 N 19 15 W 5210 07 34 7053 50 7153 64 7253 22 7353 57 7453 02 7553 14 7653 94 7753 42 7853 50 7000 50 7100 50 7200 50 7300 50 7400 50 7500 50 7600 50 7700 50 7800 O0 42 31 N 19 18 W 5302 O0 40 58 N 19 10 W 5390 O0 40 37 N 18 50 W 5477 O0 40 16 N 18 0 W 5562 O0 39 24 'N 16 48 W 5646 O0 40 40 N 17 5 W 5729 O0 40 3 N 15 52 W 5814 O0 39 13 N 15 44 W 5897 O0 38 30 N 16 6 W 5977 98 9O 27 75 29 92 56 O9 55 0 O0 0 02 0 O0 0 O0 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 4856 62 N 1889 94 W 5211 40 N 21 16 W 4944 5027 5108 5190 5269 5350 5431 5511 5588 32 N 1920 34 N 1949 98 N 1977 07 N 2004 82 N 2030 O1N 2054 34 N 2078 O1N 2100 58 N 2122 65 W 5304 61W 5392 84 W 5478 96 W 5563 08 W 5647 31W 5730 29 W 5815 71W 5897 82 W 5978 26 N 21 14 W 14 N 21 12 W 46 N 21 10 W 88 N 21 7 W 32 N 21 4 W 86 N 21 0 W 39 N 20 56 W 81 N 20 52 W 17 N 20 48 W COMPUTATION DATE: 16-FEB-94 PAGE 8 ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKa DATE OF SURVEY: 7-JAN-1994 KELLY BUSHING ELEVATION: 53.50 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 10269.53 7953 50 7900 O0 37 39 N 16 8 W 6055 84 10395.63 8053 10522.47 8153 10650 66 8253 10780 33 8353 10912 61 8453 11047 84 8553 11187 63 8653 11331 S5 8753 11480 57 8853 50 8000 50 8100 50 8200 50 8300 50 8400 50 8500 50 8600 50 8700 50 8800 O0 37 39 N 15 56 W 6132 O0 38 17 N 16 5 W 6210 O0 39 7 N 16 23 W 6290 O0 40 9 N 16 26 W 6372 O0 41 27 N 16 22 W 6459 O0 43 22 N 16 16 W 6549 O0 45 4 N 16 22 W 6647 O0 46 53 N 16 12 W 6750 O0 48 54 N 16 7 W 6860 0 O1 5663 94 N 2144 64 W 6056 38 N 20 44 W 48 0 31 0 35 0 73 0 15 0 98 0 45 0 74 0 97 0 O1 5737 O1 5812 O0 5889 O1 5968 O1 6O52 02 6139 O1 6233 O1 6332 02 6438 79 N 2165 79 N 2187 79 N 2209 98 N 2233 03 N 2257 39 N 2283 14 N 2310 50 N 2339 59 N 2370 84 W 6132 32 W 6210 79 W 6290 08 W 6373 55 W 6459 11W 6550 49 W 6647 51W 6750 30 W 6861 95 N 20 41W 71 N 20 37 W 69 N 20 34 W 02 N 20 31W 38 N 20 27 W 17 N 20 24 W 59 N 20 20 W 84 N 20 17 W 04 N 20 13 W 11635.02 8953.50 8900.00 50 40 N 15 42 W 6978.37 11797.05 9053.50 9000.00 52 55 N 15 26 W 7105.46 11966.20 9153.50 9100.00 54 44 N 15 4 W 7241.40 12000.00 9173.01 9119.51 54 44 N 15 4 W 7268.90 0,02 6551.78 N 2402.55 W 6978.40 N 20 8 W 0.01 6674.59 N 2436.71 W 7105.47 N 20 3 W 0.00 6806.24 N 2472.45 W 7241.40 N 19 58 W 0.00 6832.89 N 2479.62 W 7268.90 N 19 57 W ARCO ALASKA INC. P2-06 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER GCT LAST READING TD COMPUTATION DATE: 16-FEB-94 PAGE 9 DATE OF SURVEY: 7-JAN-1994 KELLY BUSHING ELEVATION: 53.50 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 30' FSL & 1045' FWL, SECll T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11949.30 9143.74 '9090.24 6792.91N 2468.87 W 12000.00 9173.01 9119.51 6832.89 N 2479.62 W ARCO ALASKA INC. P2-06 POINT MCZNTYRE NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: [6-FEB-94 PAGE 10 DATE OF SURVEY: 7-JAN-J994 KELLY BUSHING ELEVATION: S3.50 FT ENGINEER: SCHWARTZ ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 30' FSL & [045' FWL, SEC[[ T[2N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOL/TH EAST/WEST 12000.00 9173.01 9119.51 6832.89 N 2479.62 W FINAL WELL LOCATION AT ID: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12000.00 9173.01 9119.51 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7268.90 N 19 57 W ~P:~'~.~ WELL ~ ~TI~ 2 ~IC D~ZLINATi~ 30.09 DA~: ~-A~-~ ~.L ~B:: 0 WB, LL ~ LOr...ATI~: L~T(,N/-$)- TIE. IN POIh~(TIP): TRUe. V~ DEPTH 0,00 I~Li.~TtGN AZIMS%H 0,00 ~TI!~JDE(N/-S) D~A,R'T~ (F.#'-W) 0,00 D~'(£/-W) 340,26 F~E ND~ 2 ~L~ CALCLILAI]~ ?~ STA?I~ ~!~lrflH LA. IlilJDE ~IC)N I~LN. K/-S ft deg aec ft 0,00 0,00 D.~{~ 0.00 0,26 0,29 3i,2~ 0.35 0.62 0,42 22.~3 0.~2 0,~ 0,14 26.94 1,24 1.17 0,38 1.~1 1.47 DEF'~E DI~'I.ACEMENT at ~IgLrfH DLS U-W deg/ ft ft deg lOOft 0.00 0.00 0,00 0,00 0.21 0.41 31.29 0.44 0.93 2~,32 0.16 0.62 l.~ 26,74 0.31 0,~ 1.61 24,~2 0,48 449,1i 507,3B 568.11 62?°77 ~t,57 835,i? 10i8,~ ii10.~ 1203,44 1293,32 14, 7,6,.. 1570.5i 58,6 449.10 58.3 507,36 ~,7 568,04 61,7 629,60 59,2 668.5? 62.6 83.6 833.52 92.7 9~,05 ~1,1 1014,62 91.1 1103,57 93,4 1193.80 &?.? 1279,55 94.3 90.0 1454,37 92,9 154t,35 1.75 0.85 4.54 2,11 2.90 1,54 355.31 3.32 5.13 2.99 3.77 5,72 8.49 3,69 35~.51 9.31 13,10 5.56 ~2.50 14,~ 20.3:3 7,98 ~1.37 21.~ ~,02 8,4'/ ~3,52 ~,21 ~,16 9,43 ~9.59 47,47 62.34 11.45 3~3.23 63,79 81,63 13.52 ~.53 83.27 105,52 16.40 ~5.0~ 1~,77 132,42 18.52 337.£7 132.22 162,08 18,18 3YP.27 159.77 190.72 18.97 344.03 166.99 223,24 22.11 ~3,64 218.26 0.70 2.22 16.30 0.81 0.68 3.3~ 11.56 1.21 0.73 5.76 7.2~ 2.43 0,79 9,34 4.8.3 1,24 0.36 14.~ 1.47 3.26 -0.69 21.37 358.16 3.87 -2.25 33.29 356.12 0.70 -4.40 47.67 354.71 1.23 -6,81 ~,15 ~3,91 2,33 -9.63 83,~ 353.40 2.36 -14.82 107.81 352.!0 3.42 -23.60 134.31 349.88 3.52 -34.59 163.49 347.79 0.76 -43,59 192,00 346,B6 1.90 -52,66 224,55 346.44 3,39 1661.~.4 1752.%~ 1844.31 t937.53 91.0 16~,3~ 91.4 17~,%~ 91,4 1791.48 ?3.2 1873.3i 92.0 1949,92 258,20 23.I5 E~4.31 2~1,95 295.07 24,51 3~!,72 2~7.2~ 334,31 26,38 33~.~8 324,19 378.86 30.83 335,92 429.59 ~.,31 336.~5 411.~2 -62.33 259.55 346.10 1.17 -73.14 296.4i 345.72 1.88 -~.36 335.49 345.08 2.42 -103,54 379,75 34~,18 5.03 -1~.97 43K).17 343.~5 5,97 2122.~ 2213.64 2307.13 Z~96.62 24~9,42 25B0,97 2673,96 2763,6B 2856,01 29YJ,25 92.8 2024.07 91.3 2096.95 93,5 2171.90 69.5 2241.94 92.8 23tl.43 91.6 2376.03 9'3,0 2444,64 69.7 2508,~ 92.3 2575.~ 94.2 2645.43 485,27 37.58 337,72 ~.33 540.30 36,56 [~.40 514.57 596,17 36,~ 337,69 5~,59 651,72 40,08 335.52 617,66 713.00 42,94 335,40 673.60 775.62 43.72 336.~, 730.85 840.24 44.80 333.85 7~9.64 902.96 44.69 333.18 846.17 9~,15 42,27 335.9~ 903,52 1029.05 41.64 337.$'7 961,50 -145.59 485,~ 342,56. 1.53 -165,73 540,60 342.15 1.58 -186.18 596.39 ~1,81 1.14 -208,31 651.84 341.36. 3,8~ -233,85 713.04 340,85 3,09 -259.70 7~,62 340,44 0,96 -287,20 840,25 34C,,01 1,97 -315.35 903,02 ~3'~.% 0.56. -342.64 966,31 339,23 3.34 -367.29 10~,26 3L'~'. 09 I ;-:038.58 3t33,25 ~7.0~ ~!9,86 3413.~, 8~..3 2710.~. 94.7 2778.07 ~.6 2~43.82 92.6 2908.56 93.5 ~72.94 1088.77 43,53 337,8? 1016,88. 1154,98 45,33 33~.C1 1078.31 12~.34 45.94 ~9.44 1~2.49 13~.,08 47.02 33.6.6~ 1265,~' -3,89,75 1089.02 339.03 2.14 -414.63 1155.26 338.97 1.90 -439,47 1222.14 ~6,,~ 0.44 -4~$.41 1268.69 33~.~ 0.~ -468,65 1356.47 336,89 2.31 D~PA~TLI~ DISPLACEiI~7 at ~/-W ft ft -515.~ 1422.79 -544.33 14~J.38 -571../,6 1~7.31 -597.51 16~,B7 -622+74 1688,8~ ~ZIMUTH dec 336,74 336,46 d_~/ lOOft 1,67 0.~ 1,64 0.46. 1,12 3966,93 40C~B.M 4151.10 424.5.,37 43~,43 4426.3! 4517.40 ~13.~ 470~.59 4798.~ 91.5 3358.61 91,7 ~23.~ 92.5 3489,61 ~,3 3557,78 5'3.1 3624,10 84,9 3685,S6 91.1 3750,40 96,3 ~.19,87 94.9 3807,83 89.5 3951.32 1752,15 44,82 EOB.Z8 16~,59 1816.77 44+8.3 338.91 1699,88 1~1.57 44.17 339+Z~ 1750+43 1948.12 44,¢~. 3~,73 1M2,79 2013,39. 44,62 339.~6 1874,01 2074,79 45,32 340.03 193!,65 2138,77 43,93 34.0.21 lV?1,82 2205,41 43.69 339,5~ 20~.~ 2271,&8 44,88 339.50 2116,49 2334,69 44,69 338.96 2175,41 -646,3? 1753.11 338.36 -&69,73 1817,75 338.38 -692.81 1882.55 338.41 -716,08 1949,10 336.45 -738,73 2014,36.' 33~.49 -759.89 ~75.74 336,53 -7B1.65 21~'.70 3~.. ~,, -~4.~ 22(~6.~ 336,61 -827,72 2272.59 338.M -8~.07 ~,~ 0,74 0.10 0,79 0,41 0,18 0,86 1,54 0,52 1,26 0,47 48?3,45 4987._~ 5079.12 5175.12 526.6,94 95.4 ~19.50 94,1 4;.387,45 91.6 4154.21 96,0 4224,37 91,8 425'1,58 240io41 44,08 339.~ 2237,84 2466,43 43+39 339,¢9 2"~8,77 2529,16 43,05 339.C? 235'7,45 2594,67 43.04 338.75 2418.59 2657,20 42,85 ~8,78 2476,90 -873,66 2402,33 338,67 -896,36. 2467,35 336,70 -918,56 ~,0~ 338,71 -942.13 2595,61 336,72 -9M,79 26.58,17 338,72 0.~ 0.75 0.47 0.24 0.20 5361 5453,65 5.545.07 5733.00 94.3 4360.8.4 92.4 4428,66 91,4 ~.~ 93.8 4564.19 94,1 4632,65 2721.21 42,65 338.93 253~,61 2783,93 42,90 2~.02 2595,18 2846.15 42,91 338,86 2653,25 2910,19 43,20 ~?.~ ~13,14 2974,75 43.46 ~.89 2,,'73.51 -987,89 2722,19 336,72 -I010,40 27~,93 338,73 -1032,76 2847,16 336,73 -I0b'5,49 2911,21 33~.,74 -1078.3~ 2'975,78 336.75 0,24 0,28 0,12 0,61 0,57 5824,55 5920.44 6012,06 6103,66 6197,83 91.5 4698,95 ~,9 4768,15 91.6 4834,03 91,6 4999,69 94.2 4967,04 3037.88 43.74 ..~.E2 2832,55 3104,25 43,87 3~,85 2894,82 3167,91 44,18 339.2_5 2954+48 3231,78 44,24 340,14 9014,38 3297,60 44.45 340.46 3076,35 -1100,74 3038,91 33~,76 -1123,73 3105,28 336,78 -1145,96 3168,94 -1168,15 3232,81 335,82 -1190,~ 3298,61 33~).B5 0,63 0,21 0,57 0,~ 0,34 6292,02 6.3P_..3,56 6473.~. 6569,16 6E.62+26 94.2 5334.17 91.5 50~,48 ~.0 5163,8~. 95.6 5232.37 93,1 5298,98 3363,67 44.63 3.40,28 3138.56 3427.81 44.34 340.35 3198,97 34~,69 44.29 339,65 3258.10 35'57.37 44,18 ~0,93 3320,91 3622,43 44,47 340,19 3382,26 -1212,51 3364,65 -1234,11 3428,77 ~J.,~ -1255.51 3491 ,~ -1277,90 3558.30 33~..95 -129~,55 3,.A23,~ 336,9~. 0,24 0,32 0,39 0,79 0,64 6758,16 6850,43 6945,47 7132,14 95.9 5367.39 92,3 5433.17 95.0 5500.78 93.5 93,1 _%34.04 3689,EJ 44,52 qj9.44 34~5,34 3754,33 44,53 340,54 32~.,13 ~.21,12 44,77 3~0.43 O Z . -,~) ~51,M 44.I9 340.53 -1322.75 36?0,53 339,00 -1344.89 3~5.22 339.01 -1~.7.19 3821.%' -1389,15 3~.---', ~ -1410.85 3~i,67 339.39' 0,5~ 0,84 0.26 0,37 0,26 · I~EASLI~t~D IHTE~RV~ ~I~L DETH DBr~lt~ ft ft ft 7224,60 92.5 5700,44 73!8,26 7412,~2 93,9 ~35,53 ~4,~6 ~,8 5~2,65 ~9~,33 91,4 59~,20 *'~*.********~* ANADRILL ~x~.~.****~. SUFdJ~ CALCULAT!gNS ~x~*******~* CI~LA~~ AF~ MEqHOI)**~.***** TAF,~ET 5TATI~ AZtMLrlI~ ~TITUDE S~TION INCLN. N/-S ft deg d~ ft 4016,18 44,01 340.~2 3~3,03 4081.21 43.95 341,17 3~14,54 4146,21 43,75 ~1.~1 3876,2I 4210,32 43,65 342,]4 3937,20 4273,95 44,67 341 ~2~ 3997,62 DIS deg/ lOOft 0.35 0.21 0.50 0,27 1.31 7690,40 ~83,72 7873.15 7~65,01 8155,15 8246.O6 8340,96 ~36,32 8531,19 94.1 6034,45 93.3 6099,43 89,4 6161,57 91,9 6225.30 95,9 6292,78 94.3 6361.05 ~.9 6427.77 94,9 64W.~ ~,4 6567.24 94,9 6637,15 4340,73 45,79 340.1~ 4060,&6 4407,72 45,96 340.10 4123,66 4472,01 -45o~ 341,41 4184,37 4538,16 46.16 341.52 4247,10 4606,27 44,37 341,24 4311,66 4671,25 42,80 ~3.00 4372,96 47~,99 42,75 340,06 4430.98 4797,60 43,06 340.29 4491.76 4862.41 ~..58 341o69 4~3.04 4926,52 42,48 341.49 ~13,89 -1535,74 4341,36.. 339,28 -1556,49 4408.35 33'7.30 -1579.68 4472,62 339,32 -1600,72 4538.74 33~,35 -1622,46 46O6,82 339,38 -1644.01 4671.76 33~.40 -1665,10 4733,51 339,40 -1667.01 4798.12 33~.41 -1708,13 466.2,91 ~9,44 -1728,38 492_7,00 33~,46 1.43 0,20 1.05 0,21 1.88 1.90 0.07 0.36. 1,12 0,17 8625,~ 8716,84 88!1.03 8904,28 8998,~ ?3.9 6706,37 91.8 6774,02 94,2 6843,51 93.3 6912,33 94,4 6981,73 4989.90 42,48 341.18 4673.5 5051,92 42,56 341.43 4732.70 5115,48 42,3.6 341,84 4793,05 5178,38 42,53 342.~' 4852,96 5242,32 42,81 342,06 4913,91 -1748.66 4~0,35 339,49 -1768.54 5(7J2,35 33~.51 -1788.58 5115,89 339,~ -1807,84 5178,76 339,57 -1827,31 5242,67 339,60 0.22 0,20 0.37 0,51 0,44 9094.65 9185,20 9274,48 9369,32 9462,32 96.0 7052,3~ ?0,6 7120,12 89.3 7187,73 74,8 7259,69 93,0 7330.51 5307.24 42,36 342.00 4'.7'/5.69 5367.2~ 40.7? 342,55 5032.92 5425.56 40.78 341.~ 508a,46 5487,32 40,5! 342,21 5147,23 5547.53 40.29 343.06 5204.75 -1847.35 5307,56 33'7.63 -1865,64 5367,5~ 339,6~ -1883.44 5425.85 339,69 -15112,47 5487,~, 339,72 -1920,45 5547,75 339.75 0.47 1.78 0.48 0.35 0.~ 9557.42 9651.54 9743.71 9871,02 99..~,72 10060.54 10152.34 10245,77 1033~,35 10~34.63 95,1 7403,27 94,1 7475,93 92,2 7546,60 127,3 7643,39 ?3,7 7715,37 95.8 7789.65 91,8 7661.29 93.4 7934,82 ?3,6 95,3 8084,29 5608,67 39,88 344,11 52.x.3,49 5668,33 39,04 344.~ 5321,10 5727o~ 40,-93 344.2~ 5378,10 5609,60 40.19 345.18 5457.87 .5869.55 37+42 345.3'? 5515.88 5729.~ 38.~3 345.37 5574,47 5987,04 38.44 :'M4,L~ 5629,93 6044.52 37,74 344,10 5685.46 6101.46 37.46 345,12 5740,52 6159,55 38.03 ~5.74 5796.97 -1937,76 5606,~ 339.79 -1953.87 5668,49 33v.84 -1969,75 5727,47 33f;',8,8 -1991.59 5809,88 33V.95 -2006.83 5669,61 340.01 -2022,11 5929,89 -2036,86 5987,O6 340,11 -2052.30 6044,54 340.15 -2067,45 6101,47 340.19 -2082.12 6159.55 340.24 0.83 0.97 1.97 0.71 0,84 0,49 0.66 0.89 0.73 0.72 10528.37 10622,60 lnT~ :,. f).q 108~,39 ~.7 8157,91 94,2 8231.32 91.4 6~32.~) 94,4 &374.09 F3,2 8444.26 6217,36 38,46 344.97 5853,12 6276.25 39,19 344.E0 5910.13 5 n~ 0 Z 63~3,98 3~,51 ~,45,~.~ 5.~...17 63~4.64 40,89 ~5.37 60.25,20 6455.81 41,50 345.3~ 60~,63 -2096,80 6217,~ 340,29 -2112.31 6276.26 340.33 -2127.03 E~3.~ 340,~ -2142.12 6394.67 34C.43 -2157.62 ~ ~:,85 34{',4~ 0.68 O.B1 1.00 1.52 0.65 Cons. (..orr ~n)sstu'~ ~ I~¥AL ~ICAL 1~.6~ 94.0 ~513.~ 110~.22 94,6 85~2,43 11181.45 91~2 ~7.12 112~.89 96.4 8714.28 11373.~ 96.1 6~9.71 11466.20 94.3 8842.52 11561.52 93.2 6903.35 11655.50 94.1 8963.12 117~.82 91.2 ~19.38 11840.80 94.0 9075.93 PROJ~Zll~SLgt~W 119~.~ 1~.2 91~,~ SURVEY CALCb~A?IO~S ************* CIRCUIaS~: ARC I~I~)OD,~~ P2-O6IF3 T~E~G~ b'YATION AZI~ I.ATIIT)DE ~ARYURti DISPLACI~II~f a~ AZIMUTH SL°TID~ INCLhh ~-S ft deg d~q ft ft it dec 6518.66 42.81 L:M4. g6 6145.60 -2173.82 6518.73 340,52 6563.67 44.40 3q4.f9 6208.58 -2190.78 6563.76 340.56 6647.77 45.28 ~5.~ 6270.~ -2207.31 &M7.89 340.61 6716.71 46.44 345.44 6837.70 -2224.83 6716.B7 340.66 6786.84 47.73 344.45 6405.67 -2243.12 6787.0~ 340.70 64b-7.00 46.74 344..47 6473.42 -2261.96 6857.24 340.74 6927.49 49J32 344.00 6541.43 -2281.16 6927.77 340.78 6999.92 . 51.26 344.64 ~i1.34 -2300.713 7000.25 340.B! 7071.55 52.61 3d4.53 ~,59 -~19,~ 7071,~ ~0,85 7146.38 53,40 3~5.00 6753+01 -2339.61 7146.81 340.B9 7~3.75 53.40 345.¢0 6857.08 -2367.49 7254.213 340.95 U~/ lOOft 1.45 1.~ 0,99 1.21 1,53 1.07 1.22 1.62 1.~ 0.94 0.01 Date: Subject: From: To: .... , ARCO Alaska Inc. Great~ Point Mclntyre Engineering April 19, 1994 Transmittal Number ARCO Alaska, Inc. Bob CrandalJ AOGCC 3001 Porcupine Drive Anchorage, AK 99501 720 The following Greater Point Mclntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: NK-26 FINAL DISKETTE: MWD w/Sub-Surface 3-17-94 qq'~o~ Directional Survey This information is confidential Pl-17 "/FINAL LOG: Production Profile 1 3-%94 93- P1-21 --FINAL LOG: Perf Record 3 3/8" HSD - 6 SPF 1 2/5/94 P2-06 P2-06 P2-06 P2-12i P2-121 P2-15 P2-15 P2-15 ~'/~AL LOG: Perforation Record 2 1/8" Phased Enerjet ~AL LOG: Static Pressure Survey Press-Temp-Gr/CCL FINALDISKE~: GCT -Surface w/SuJ Directional Survey 4" ~( ~'/'F/NAL LOG: Perf Record 3 3/8" HIII, 6 SPF 'VFINAL LOG: Static Pressure Survey Press-Temp-Gr/CCL ~AL TAPE: DIFL/CN/ZDL/GR w/LIS Vet Anadrill Schlumberger S~hlumberger I 1/29/94 Schlumberger 1 1/29/94 Schlumberger 1 3-5-94 Atlas ~/FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) INAL LOG: Borehole Profile 1 3-5-94 Atlas 1 3-5-94 Atlas Wireline '//FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper 1 3-5-94 Atlas P2-15 1 1-7-94 Schlumberger 1 1/31/94 Schlumberger I 1/30/94 Schlumberger Well Name P2-15 P2-15 P2-15 P2-15 P2-15 P2-161 P2-23 qq.'52- P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 Data Description "lff'INAL LOG: Dual Induction Focused Log GR/SP FINAL DISKETTE: MWD Survey w/LIS Yer x'~NAL LOG: Cement Evaluation (CET-GR) FINAL LOG: Cement Bond Log (CBT-GR) *'FINAL DISKETTE: GCT w/Sub-surface Directional Survey LIS Vet FINAL LOG: Perforat/ng Depth Control Powered Gun GR ~2WAL LOG: Perforation Record 3 3/8"HJ II, 6 SPF ~'/FINAL DISKETTE;~MWD Survey w/LIS Vet V'FINAL TAPE: DIFL/CN/ZDL/GR w/LIS Ver 1 '/FINAL LOG: Borehote Profile v/FINAL LOG: Sub-Sea Vertical Depth (Directional Drillers Data) //FINAL LOG: Z-Dens/log Comp NEUTRON GR/Caliper '/'FINAL LOG: Dual Induction Focused Log GR/SP "~INAL DISKETTE:c, MW~ Survey w/LIS Vet MSINAL DISKETTE: Electronic Multi-shot Survey w/LIS Vet · v~FINAL LOG: Cement Evaluation Log (CET-GR) Run # 1 Date Run 3-5-94 3-9-94 3-26-94 3-26-94 3-26-94 1/26/94 1/27/94 3-23-94 2/12/94 2-12-94 2-12-94 2-12-94 2-12-94 2-10-94 2-10-94 3-25-94 Company Atlas Sperry Sun Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Sperry-Sun ATLAS Atlas Atlas Atlas Atlas Sperry-Sun Sperry Sun Schlumberger Transmittal Number: 720 Page: Well Name P2-29 P2-29 P2-30 q-2._,-,q5 P2-30 P2-30 Data Description 'V(~AL LOG: Cement Bond Log (CBT-GR) V/FINAL DISKETTE: _Sub_-S~lrface Directional Survey (GCT) ',/FINAL TAPE: CH Edit 3 Pass CNT-G with Average Pass w/Ver List //FINAL TAPE: CH Edit TDTP 3 Passes and Average w/Vet List LOC.. ' //FINAL LOG: TDTP Depth Corrected Run # Date Run 3-25-94 3-20-94 1-8-94 1-8-94 12-8-93 Company Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P2-31 qq- P2-31 P2-31 P2-31 P2-31 P2-31 P2-42 P2-42 P2-42 P2-42 FINAL DISKETTE: MW w/Sub-Surface Directional Survey ~- ~/ ~eI~rAL~~TTE: Electronic MultiShot w/LIS W/FINAL LOG: Sub Sea VD (Multi-shot Directional Survey) V/FINAL LOG: Dual Laterolog/GR/SP FINALLOG: Borehole Profile i~TNAL LOG: Z-Densilog / Comp Neutron / GR/Caliper :~AL LOG: Dual Induction Focused Log/GR/SP '~FINAL LOG: Formation Multi-Tester/GR ~FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) V/FINAL LOG: Z-Densilog/Compensated Neutron/GR/Caliper /FINAL LOG: Borehole Profile 04-08-94 4-10-94 4-10-94 4-10-94 4-10-94 4-10-94 1/9/94 1/9/94 1/9/94 1/9/94 1/9/94 Sperry Sun Sper?y Sun Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Atlas Atlas Atlas Atlas Transmittal Number: 720 Page: 3 Well Name Data Description P2-42 ~'FINAL DISKETTE: M~D Survey w/LIS Vet P2-51 v//FJ~AL LOG: TDTP Depth Corrected P2-51 M~tNAL TAPE: CH Edit 3 Pass TDTP w/Average Pass w/Vet List / P2-51 I~INAL TAPE: CI-I Edit 3 Pass CNTG and Average w/Vet List P2-57 V~FINAL LOG: 2.5" CNT-~>Depth Corrected P2-57 FINAL TAPE: CH Edit 2.5 CNT-D 3 passes w/Average w/Ver List Run # Date Run Company 1/8/94 Sperry-Sun 1-11-94 1-11-94 Schlumberger Schlumberger 1-11-94 Schlumberger 11-t4-93 11-14-93 Schlumberger Schlumberger Please sign .~ ..... . and return to: Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal Number. 720 Page: 4 Date: Subject: From: To: ARCO Alaska Inc. Greater Point McIntyre Engineering March 7, 1994 Transmittal Number 703 ARCO Alaska, Inc. Bob Crandall AOGCC 3001 Prokupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. and your cooperation in maintaining confidentiality is appreciated: ,~b,~//~ 1-05 ST1 -~ J P1-05 ' / /ST1 xxP1-05 ~/ST1 Pl-08 tS'08 1-08 T1 ¢~~1-11 q ?".~'bPl_l2 q~"'q~P1-20 q P1-2i P2-06 This information is confidential Final Log: CDR__D_g_~ery Emhanced Resis~vi~ L~th Corrected___. Final Log: C~DR LWD/Depth Corr_!ggected ~) 7/8-9/93 Schlumberger/ ~zq qo-- ~ 3g~o 5 7/8-9/93 Schlumberger / t~.~so - t%%0o ~ + 5' Final Log: CDN LWD/Depth Corrected ~ t-ok 0o ~ \ %~o FINAL Log: DC~p_.g2_~Very Enhance__~d Ro.~i.~tivity (~ 7/8-9/93 Schlumberger / ~ 7/18-28/93 Schlumberger st & FINAL Log: ~rue Vertical Depth~ZDR ~ 7/18-28/93 Schlumberger st Tape: ~ Edit~5~~Only in 5 bit runs w/Verification Listing 7/24/% Schlumberger Tape: ~ Edit ~n 2 ST bit (~ runs (with original Well) LDWG Format -hct~O~ 7/18/93 Schlumberger Pro__ducti~: FBS/TEMP/PR E.g.q./GRADIO/~HI J'M i2/ii/93 Schlumberger P_rod. ction L~g: S/GRADIO 12/11/93 Schlumberger Log: P_r_oduction Log FB.B_SS / Te mp/Press./_ Gradio/HUM LOG:Production Log F~S/TEMP/PRESS/Gradio/'HUM Final Log: GYRO Directional Survey (GC_.~_) ~215 12/12/93 citgo -- l o~ oO $" 12/12/93 Schlumberger Schlumberger 1/7/94 Schlumberger Well Name 'P2-30 P2-30 P2-30 P242 P2-42 P242 P2-42 p~2P2-S 1 -51 Data Description FINAL LOG:~Compensated Neutron Log (Dual Porosity - CNT-G) Run # Date Run ~ 1/8/94 l ~Ob~- ~o~ 2~ FINAL LOG: Dual Burst TDT-P (~ 1/8/94 I ,o~-o0 -- ~ O(o 2.0 ~'~ 1/17/94 "FINAL LOG: Perf Record 3 3/8 .... HJII, 6SPF"__(~qq$O..tOCoKo "FINAL LOG: Perf Record 270'3 3/8 .... 6 SPF" Tape:~,Wr./CN/Z~: 7500-10564 w/lis verification FINAL LOG: V~ement Bond Log (CBT-GR) v' FINAL LOG: Cement Evaluation Log (CET-GR) Company, Schlumberger Schlumberger Schlumberger 1/16-17/94 Schlumberger ~"Compensated Neutron Log (Dual Porosity- CNT-G) 'If)ual Burst TDT-P Log 1/9/94 Atlas 1/15/94 Schlumberger 1/15/94 Schlumberger 1/11/94 Schlumberger 1/11/94 Schlumberger Please sign '"- ARCO Alaska, Inc. P.O. Box 100360 /laff/,~.. ,~ Anchorage, Alaska 99510-0360 ~°°hou/~*' PLEASE SIGN ONE COPY AND RETURN Transmittal Number: 703 Page: 2 INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/18/1993 PAGE: 1 93-103 SURVEY-MWD 93-103 407 93-103 DAILY WELL OP 93-103 SURVEY 93-103 5811 93-103 5814 ANADRILL COMP DATE: 8/27/93 8/05/93 TO 8/21/93 0.00-11840 8384-11976,CDN/CDR 11400-11786, LDWG SUMMARY Are well tests required? Was well cored? Yes No Yes No If yes, was the core analysis & description received? Are dry ditch samples required? Yes No Yes No WELL IS IN COMPLIANCE. INITIAL COMMENTS: Date: Subject From: October 13, 1993 Transmittal #359 ARCO Alaska Inc. ARCO Alaska, Inc. t-sburne/Point McIntyre EngineerL .. To: Bob Crandall A~C 3001 Porcupine Drive Anchorage, AK 99501 The following Point McIntyre data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title P1-04 Completio Record, Perforation HSD 6 sfp 33/8'' P1-05 Perfora~g Record 3%e" HSD 41B P1~5 Peffora~ng Record ~s/a" ~D 41B P1-05 Perfora~g Record 3%e"~D 41B P1-05 Perforating .Record 3%e"~SD 41B P1~5 Perfora~g Record 3%e" ~D 41B ~ H ~X ~8 ~e~a~ed ~o~aQon Pl~8 En~r~g Parameters ~ ~"! ~- icao' Pl~8 Press~e Data Log-MD l"~ ~ - ~7~' Run # 'Run Date Company 1 8/19/93 Schlumberger. 1~ z~'0~ '8/23/93 Schlumberger 1 ~'~ 8/30/93 Schlumberger 160~i-~8/31/93 Schlumberger 1~,~ ,.~9/01/93 Schlumberger 1 ,,.~9/02/93 Schlumberger 7119-24193 7119-24/93 7119-24193 7119-24/93 Exlog Exlog Exlog .(BPI-(BS'~' Integrated Formation Log ~.2"~, ~Yf/o--~o'~' . Pl-CSS~-Integrated Formation Log 4~)2'~ ~,~O--%76o~ . -(BS~ Engineering Parameters ~~"~ ~?O-. leqco' . St~I Pressure Data Log-MD ~ ~lz5 -- Z?~5' - 7/25-31/93 7/25-31/93 7/25-31/93 7/25-31/93 Exlog Exlog Exlog Exlog IPI-13 Pl-13 Pl-13 Pl-13 Integrated Formation Log -t~ 2", ~c~ - ! I eo5 _ Integrated Formation Log ~-~-"~ (~40-77q5 Engineering Parameters 2/~]~:z'~, co, cO.- 11 coo Pressure Data Log -MD ~" co~ -- ~,-~ ~ - 6/1-11/93 6/1-11/93 6/1-11/93 6/1-11/93 Exlog Exlog Exlog Exlog Pl-17 Pl-17 P1-17 Pl-17 Integrated Formation Log -~_ 2'i, 7~0-iog~Z - Integrated Formation Log-~).2 ~ ~ ~c)53z Engineering P~et~s ~ ~", 7~- ~~ Press~e Data Log-MD ~" 4112-16193 4/12-16/93 4112-16193 4112-16193 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN Date: Subject: From: ARCO Alaska, Inc. sbume/Point McIntyre Engineering November 17, 1993 Transmittal #361 ARCO Alaska Inc. To: Bob Crandall AOC~C 3001 Porcupine Drive Anchorage, AK 99501 Enclosed are sepias for the following Point McIntyre logs. These sepias were erroneously omitted from Transmittal #359, sent 10/13/93. This information is confidential and your cooperation in maintaining confidentiality is appreciated. Log Well Title Run # Run Date Company 1 sepia · P!-04 Completion Record, Per£oradon HSD 6 s~ 33/8'' 1 8/19/93 Schlumberger P1-05 /Perforating Record 3%s" HSD 4lB I-~ TI RDX 1 P1-05 v/Perforating Record 3%8" HSD 4lB I-~ TI RDX 1 P1-05 ,w'Perforating-Record 3%8" HSD 41B I-II TI RDX 1 P1-05 vlSerforating Record 33/8" HSD 4lB I-ti TI RDX 1 P1-05 v, Perforating Record 33/8" HSD 4lB I-ti II RDX 1 8/23/93 8/30/93. 8/31/93 9/01/93 9/02/93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P1-08 ,,/integrated Formation Log-MD P1-08 ,/'Integrated Formation Log -TVD P1-08 ,,/'Engineering Parameters -MD P1-08 ,/Pressure Data Log-MD 7/1%24/93 7/1%24/93 7/1%24/93 7/1%24/93 Exlog Exlog Exlog Exlog ~,/P1-08ST1 Integrated Formation Log-MD V'P1-08STI_ Integrated Formation Log-TVD v/P1-08STi Engineering Parameters -MD /I~-CSST1 Pressure Data Log-MD · 7/25-31/93 7/25-31/93 7/25-31/93 7/25--31/93 Exlog Exlog Exlog Exlog Pl-13 ',/Integrated Formation Log -MD Pl-13 v' Integrated Formation Log -TVD P1-13 v'Engineering Parameters -MD Pl-13 v/pressure Data Log-MD' - 6/1-11/93 - 6/1-11/93 - 6/1-11/93 - 6/1-11/93 Exlog Exlog Exlog Exlog Pl-17 v/Integrated Formation Log-MD P1-17 v/Integrated Formation Log-TVD P1-17 v/ Engineering Parameters -MD Pl-17 ,,/Pressure Data Log-MD - 4/12-16/93 - 4/12-16/93 - 4/12-16/93 - 4/12-16/93 Exlog Exlog Exlog Exlog PLEASE SIGN ONE COPY AND RETURN , ransmittal ~359 (AC)GCC) "- Page 2 %-6't m-os P1-05 P1-08 · ~'~ ~Pl_08 ~%--'7q IPl-13 P2-06 ~qS-[07 P2-06 P2-06 Log Well Title 1 blue line Run # Run Date Company P1-21 Integrated Formation Log ~~- 4/30-5/5/93 Exlog ~TtO-- lt%2.5'j P1-21 Integrated Formation Log ~~" '- 4/30-5/5/93 Exlog ~o- P1-21 Engineering Parameters ~ - 4/30-5/5/93 Exlog ~"; ~:~--- P1-21 Pressure Data Log -MD"'" - 4/30-5/5/93 Exlog ~" ~ -- ? 'P2-06 Z-Densflog/Cmpnstd NEUTRON/GR/C~per ~'> '~'~"~ t~4oo 8/17/93 Atlas P2-06 Dual Laterolog/Gamma Ray/SP ' 1 8/17/93 Atlas ~*'5'~ liqoc- P2-06 Sub-Sea Vertical Depth (Single Shot Data)~1 8/17/93 Atlas ~P2-06 Borehole Profile 1 8/17/93 Atlas ~1 I ~-)." ~ tq0o- ltq~o ',,.~ 5,~ ~ ~t40~ - t~95~~ l oo7_ 0-.9/13/931o5~ Atlas P2-16 Z-Densflog/Cmpnstd NEUTRON / GR/ Caliper /7 m --~ P2-16 Dual Induction Focused Log/Gamma Ray 1 9/13/93 Atlas ,-~ ;P2-16 Sub-Sea Vertical Depth (Multi Shot Data) 1 9/13/93 Atlas P2-16 Borehole Profile 1 9/13/93 Atlas P2-46 Z-Densflog/Cmpnstd NEUTRON/Gl/Caliper a~'{, Z~27-/9~3.~' Atlas P2-46 Dual Induction Focused Log/Gamma Ray 1 9/27/93 Atlas P2-46 Sub-Sea Vertical Depth (Directional Drlg Data) ~ 1 9/27/93 Atlas P2-46 Borehole Profile 1 9/27/93 Atlas ~-> I+a", ~o- Diskette/Tape (w/ver;_~icafion Hst~g) We],] Title Run # Run Date Company ~!-0~ CC'[' dJs~ette-Comp[ete Cal¢.,/ ! 7/28/93 S¢~umberger P!-05 GCT ~skette-Complete Cal¢.v' ! 8/_1.2/.9_3 S¢~[umber§er CDN/CD[ in 3 Bi~ Rtms (O__~.~ Ed.it)v' q~t~tt~S5 ~5&i~ 6/27/93 Schlumber§er ;Final MWD w/l[st~-~ "/' - 7/~3/93 Schlumberger CD[/CR'O~y in 5 BJt ~u~ (OH Fffit)'~5615/~W"lq3~O 7/24/93 S¢~umberger Dual ~op ~esis/De~[W/Neut-ron/C[ w/]ist~g 5-7 6/6/93 Baker Hughes Final MWD w/Listing + ~ - 6/07/93 Baker Hughes Final MWD w/Lisfing'r'~ - 4/16/93 Baker Hughes Final MWD w/Listing*~ - 4/16/93 Baker Hughes Final MWD w/Listing ~-~ ~' - 8/17/93 Baker Hughes CDN/CDR in 3 Bit Runs (O__.~ Edit)~.~t[/% ~q-liq7/~, 51 8/17/93 Schlumberger DLL/CN/ZDL/GR in LDWG Format w/Listing 1 8/17/93 Arias PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Page 2 Log Well Title 1 sepia P1-21 v/Integrated Formation Log -MD P1-21 V' .Integrated Formation Log -TVD P1-21 V'Engineering Parameters-MD P1-21 ,/Pressure Data Log-MD P2-06 v"Z-Densilog/Cmpnstd NEU71~ON/GR/Caliper 1 P2-06 ,/Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 v/Borehole Profile 1 P2-16 P2-16 P2-16 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper v?/~Pual Induction Focused Log/Gamma Ray ub-Sea Vertical Depth (Multi Shot Data) ~/Borehole Profile P246 P2-46 P2-g6 P2-g6 7'Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 V'Dual Induction Focused Log/Gamma Ray 1 ,/Sub-Sea Vertical Depth (Directional Drlg Data) 1 dBorehole Profile 1 Run # Run Date Company - 4/30-5/5/93 - 4/30-5/5/93 - 4/3O-5/5/93 - 4/30-5/5/93 8/17/93 8/17/93 8/17/93 8/17/93 9/13/93 9/13/93 9/13/93 9/13/93 9/27/93 9/27/93 9/27/93 9/27/93 Exlog Exlog Exlog Exlog Atlas Arias Atlas Atlas Atlas Atlas Arias Atlas Atlas Atlas Atlas Atlas Please and return to' Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. 'P.O, BOX 100360 ' Anchorage, Alaska 99510-0360 Transmittal #361 R'ECEIVED NOV 79 1993 'Alaska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #361 (AOGCC) Page 2 Log Well Title 1 sepia P1-21 .,/Integrated Formation Log -MD P1-21 V' Integrated Formation Log -TVD P1-21 7Engineering Parameters -MD P1-21 /Pressure Data Log-MD Run # Run Date - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 - 4/30-5/5/93 P2-06 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-06 ,/'Dual Laterolog/Gamma Ray/SP 1 P2-06 ,/Sub-Sea Vertical Depth (Single Shot Data) 1 P2-06 7Borehole Profile I 8/17/93 8/17/93 8/17/93 8/17/93 P2-16 v/Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 P2-16 v'Dual Induction Focused Log/Gamma Ray 1 P2-16 ,/Sub-Sea Vertical Depth (Multi Shot Data) 1 P2-16 7'Borehole Profile I 9/13/93 9/13/93 9/13/93 9/13/93 P2-46 P2-46 P2-46 P2-46 J~Z-Densilog/Cmpnstd NEUTRON/GR/Caliper 1 v/Dual Induction Focused Log/Gamma Ray 1 ./Sub-Sea Vertical Depth (Directional Drlg Data) 1 JBorehole Profile I 9/27/93 9/27/93 9/27/93 9/27/93 Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 Anchorage, Alaska 99510-0360 Company Exlog Exlog Exlog Exlog Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Transmittal #361 RECEIVED Naska Oil & Gas Cons. Commission Anchorage PLEASE SIGN ONE COPY AND RETURN Transmittal #359 (AOGCC) Page 3 Report Well P1-04 P1-05 P1-08 P1-13 P1-17 P1-21 Title Sub-Surface Directional Survey (2 copies)v' Sub-Surface Directional Survey (2 copies) Final Well Report ~" Final Well Report Final Well Report Final Well Reportv, Date 7/28/93 8/12/93 7/1%8/1/93 6/1-11/93 4/12-16/93 4/30-5/5/93 Company Schlumberger Schlumberger Exlog Ex, log Exlog Exlog Please and return to: Laura S. Lahrson, ATO-409 ARCO Alaska, Inc. P.O. BOX 100360 ' Anchorage, Alaska 99510-0360 Please note: The Exlog blueline logs are located within the Final Well Report binders. Transmittal #359 PLEASE SIGN ONE COPY AND RETURN ALASKA OIL AND GAS CONSERVATION COMMISSION July 23, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anc~horage, AK 99519-6612 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Re: Point McIntyre P2-06 ARCO Alaska, Inc. Permit No: 93-103 Sur. Loc. 29'NSL, 1046'EWL, Sec. 11, T12N, R14E, UM Btmhole Loc. 1557'NSL, 1387'WEL, Sec. 3, T12N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you. from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman~ BY ORDER OF THE COMMISSION dlf/Enclosures co: Department of Fish & Game, Habitat Section w/o encl. Department of Environme'ntal Conservation w/o encl. ~,?,~ pdnted on recycled [')apP. r [~ y (~. Q STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 Ila. Type of work Drill [] Redrill l-Il lb. Type of well. Exploratory F'] Stratigraphic Test [] Development Oil [] ' Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 53.5 feet Point Mclntyre 3. Address ~6. Property Designation ?. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 34622 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(,,,e 20 AAC 25.02,5) 29' NSL, 1046' EWL, SEC. 11, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 1294' NSL, 1293' WEL, SEC. 3, T12N, R14E P2-06 U-630610 At total depth 9. Approximate spud date Amount 1557' NSL, 1387' WEL, SEC. 3, T12N, R14E 8/1/93 $200,000.00 12. Distance to nearest 113. Distance to nearest well 14. Number of acres in property15. Proposed depth(MDa,dTVO) e~ line prop L365548-1387' feet P2-30402'@350'MD feet 2560 11987'MD/9196' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 2S.O3S (e)(2)) Kickoff depth soo'feet Maximum hole angle 44 o Maximum surface 3330 pslg At total depth (TVD) 8800'/4390 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casi,ng Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" 20" 91.5# H-40' Weld 80' Surface 80' 80' 280 cu ft 13-1/2" 10-3/4" 45.5# NTaOS ' B TC 4338' 41' 41' 4379' 3700' 2824 cu ft "E"/406 cu ft "G"/235 cu ft "C" 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11339' 41' 41' 11380' 8758' 9-7/8" 7-5/8" 29. 7# 13CR NSCC 607' 11380' 8758' 11987' 9196' 623 cu ft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ..~, ~;~ Conductor Surface Intermediate Production j Li L. 1. 5 Liner ?4.iask,~. 0il & Gas Cons. C0rcn~.issio~ Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certiffy J~hat t,b,e fore_ge¢L~ ~~n<'g is true and correct to the best of my knowledge (/'-'-'"~'~' Title Drilling Engineer Supervisor Date '~"- Signed - L./' Commission Use Only Permit Number IAPI number IApproval date See cover letter ¢ ,.~ -'//O,~ 150'°'~- '?-- ~-- -~ E'~' j ~,~'-~,? ~.-~,-~ for other requirements Conditions of approval Samples required [] Yes J~] No Mud Icg required []Yes 1~ No Hydrogen sulfide measures [] Yes [] 1'4o Directional survey required J~ Yes [] No Other:Required working pres~u.ret_.,r~gina.!for BCPEo~¢._,..neE~ 2~y; F'I3M; FISM; F-Il 0M', 1--]15M; Johnstone by order of Approved by David W. Commissioner [ne commission Date -- Form 10-401 Rev. 12-1-85 Submit in trip WELL PLAN SUMMARY WELL NAME: P2-O6/F3 WELL TYPE' AFE NUMBER' Slimhole, Iongstring AFC #2C INITIAL COMPLETION: Producer SURFACE LOCATION' 29'FSL, 1046'FWL, SEC11, T12N, R14E TARGET LOCATION' 1294'FSL, 1293'FEL, SEC3, T12N, R14E BOTTOM HOLE LOCATION' 1557'FSL, 1387'FEL, SEC3, T12N, R14E TOTAL DEPTH' 11987' md / 9196' tvd brt CONTRACTOR: POOL 7 ELEVATION' RTE-SS- 53.5' RTE-GL: 41' GL-SS: 12.5' DIRECTIONAL INFORMATION' Typ. build and hold, target=8905' tvd brt, departure=6955'. KOP' 500' Angle/dir.' 44°/N20°W Build Rate' 2/100'md MUD PROGRAM: Surface hole = typical spud mud. Production hole (9-7/8")=3% KCL water. FORMATION MARKERS' TVDss MD WEST SAK 6850 881 4 K-10,K-5,HRZ 8790 . .~ 11500 KALUBIK 8820 ~ -- 11540 TARGET (KUPARUK) 8851 11 584 TD 9142 11987 MILUVEACH BELOW TD CASING PROGRAM: Hole (;::~ g wt Grcde ¢onn Length TOp Btm 30" 20" 91.5 H-40 WELD 80 GL 80 " 13-1/2" 10-3/4" 45.5# NT-80S BTC 4338 41 4379(365Otvdss) 9-7/8" 7-5/8" 29.7# NT95HS NSCC 11339 41 11380 9-7/8" 7-5/8" 29.7# 13CR NSCC 11380 607 11987 · . LOGGING PROGRAM: Open Hole Logs: Surface NONE Final Mud Logs: NONE MWD: GR/Resistivity/Neutron/Density. Top of K-10 to TD Wireline: NONE Case(;l H01e Loqs' Cement bond Icg and gyro after rig release. COMPLETION: To be completed at a later date. I ~lask~ 0il & Gas Cons. Corr~rOssiO° Anchorage MEM Page 3 7/12/93 MUD PROGRAM SURFACE AND SHALLOW INTERMEDIATE MUD PROPERTIES: TYPICAL Density Marsh Yield 10 sec 10 min pH Fluid (ppg) Viscosity Point gel gel Loss Spud @.7 300 40-60 30-60 60-80 9-10 15-25 Change 9.8 50 20-40 15-20 20-30 9-10 10-20 over FINAL HOLE MUD PROPERTIES: 3% KCL Density PV YP 10 sec 10 rain pH Fluid (ppg) gel gel Loss Change 9.5 8-15 25-30 5-15 10-20 9-10 10-15 over TD 10,0 15-30 25-30 8-12 <25 9-9.5 4-15 <15HTHP NOTE: ADJUST YP FOR HOLE CLEANING. MAINTAIN MINIMUM YP 25 FROM SURFACE CASING SHOE TO TD. Aiask~ Oil & Gas Cons. 'Anchorage MEM Page 5 7/1 2/93 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P2-06 Cement Volumes Surface String 4379 10 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1301 (2824 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 11 987 7 5/8 29.7 1O584 9 7/8 1.9 LEAD Yield · 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 519 Cf bbls I I I (o Cu. Ft.) (623 Cu. Ft.) Aiask~, Oil & Gas Cons. Corr~rnissio~ Anchorage · , . , . , . . . MIRU drilling rig. P2-06 Operations Summary Spud well and drill 13-1/2" hole to 4379' md/3700' tvd building angle to 44 degrees. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7~8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 11987' md / 9196'.tvd. Log with MWD. Set 7 5/8" L-80 and chrome casing and cement same, displacing with seawater. Test casing to 3500 psi for 30 minutes. Run 3-1/2" chrome tubing completion and tree. Displace tubing to diesel and freeze protect well with 2000' of diesel in annulus. Release rig. Run cased hole logs: cement bond log, gyro. :~Jask~ 0il & Gas Cons. Cori~rnission Ancholage _C~-GING DESIGN SPECIFICAT*~NS SURFACE CASING 10-3/4" 45.5#/FT, NT80LHE, BTC BURST COLLAPSE PBYS # TJYS # NT80LH E 551 0 3390 1 040000 1 063000 I · m · Burst Pressure The burst rating is based on shutting the well in on a gas kick with pressure equivalent to the leak-off at the surface casing shoe: Burst Pressure = 14 ppg (LOT) @ 3500' tvd = 2548 psi, Safety Factor = 2.16 Collapse Pressure The scenario for collapse rating is based on having lost circulation such that the fluid level drops below the surface casing shoe and there is 9.5 ppg mud in the annulus: Collapse pressure = 9.5 * 3500 * .052 = 1729 psi Saftey Factor -- 1.96 Tension Tension is based on full string weight in mud. A maximum casing length of 5000' is assumed, and a vertical hole is assumed (for worst case scenario): Tension = 45.5 * 5000 * .85 = 193375 Cf Saftey Factor (pipe body) = 5.38 Saftey Factor (joint) = 5.50 7-5/8", NT95HS (0-8200' tvd+-) 1 3CR80 (8200'+--TD) PRODUCTION CASING 29.7 -Cf/FT, NT95HS, 13CR80 BURST COLLAPSE 8180 7200 6890 4790 NSCC PBYS # 811000 683000 TJYS Cf 813OO0 721 000 I · 1 · Burst Pressure The worst case scenario is a tubing leak at reservoir pressure at the surface (with the NT95HS grade) with no annulus backup. Maximum shut-in.tubing pressure= burst pressure= 4360- (.15 * 8810') = 3038 psi Saftey FaCtor- 8180 /3038 -- 2.69 Collapse Pressure Assume the casing is evacuated to gas lift gas with 10.0 ppg mud in the annulus (worst case on bottom with 13CR80 grade): Collapse pressure= 8750"10.5'.052 = 4777 psi Saftey Factor - 4790 / 4777 = 1.01 Tension Based on a full string weight in 10 ppg mud. A maximum casing length of 16000' is assumed as a worst case scenario (at surface with NT Tension = 29.7'16000'.85= 403920 #. Saftey Factor = 811000 / 403920 = 2.01 Safley Factor (jo/nO 2.01 Alaska 0il & Gas Cons. Commission Anchorage TRUE Prudhoe ]3a~ Drillin~ ~ Poin[ McIn[~re, Alaska f~ Well' P2-06 File:~ P~-O6wp ~{~ ! , , ! n,,. t ~ tx~-~ 30.12 deg, E~st Dectinat;on 05/14/1993 HALL IBURT~ DRILLING SYSTEMS 1,15 om CRITICAL POINT DATA MD TIE IN 0 START DF BUILD 489 8 8.00 DEG/IO0 FT END OF BUILD 8677 WEST SAK 8814 K-10, K-5, HRZ 11499 KALUBIK 11541 TARGET - 11584 KUPARUK TOTAL DEPTH 11987 Inc Az I 0,00 0.00 O. O0 O. O0 TVD North East 0 0 0 489 0 0 43,75 340.26 2470 43.75 340.86 6904 43.75 340.26 8844 43.75 340.26 8874 43,75 340.86 8904 43,75 340.86 9196 749 -269 4743 -1702 6491 -2329 6518 -2339 6546 -2349 6808 -2443 HORIZONTAL VIEW SCALE 100o ft. / DIVISION SURVEY REF: WE[LLHEAD 000 BHL DATA [ TI/D 9195.741 MD 11987.03l VS 7833.46[ North 6808.35l East -2443.23[ Da~e Ptotted : 5/14/93 Created By Checked By : Approved By Da~e , VERTICAL VIEW SCALE 1000 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 489 1000 2000 0.00' ~ 0 MD TIE IN 489 MD START DF BUILD 8 2.00 DEG/IO0 FT 0.00' 8 4.00' 8 689 MD 8 00' 8 889 MD 12 00' 8 1089 MD 16 00' 8 1289 MD 20.00' 8 1489 MD 24 00' ~ 1689 HD 28 00' @ 1889 MD 32 00' 8 2089 MD 36.00' 8 8289 MD 40.00' 8 2489 MD 43.75' @ 2677 MD END OF BUILD 795 10.750 OD, 8 4379 MD, 3700 TVD 5~~ . 690~ I 1 3000 2000 I 000 000 000 5000 600'0 '~I i 5 ! 41ask.~ Uil &. Gas Cons, Comm. issio,", 5039 43.75' 8 8814 MD WEST SAK 80( 6896 .... 6955 71647233 11 9 5 KUPARUK loooo.. I I I I I I I I 0 1000 2000 3000 4000 5000 6000 7000 BO00 VERTICAL SECTION PLANE: 340.26' Prudhoe Point Well' Bay Di illing McIn[yre, Alaska P2-06 File: P2-06wp SCALE~00 ft. / DIVISION su~v~F: ~~ HALLIBURTON DRILLING SYSTEMS 05/14/1993 1,80 on HD Ina Azl TVD North East TIE IN 0 O.O0 O.O0 0 0 0 START OF BUILD 489 0.00 0.00 489 0 0 8 2.00 OEO/lO0 FT END DF BUILD 2677 43.75 340.26 8470 749 -269 WEST SAK 88[4 43.75 340.26 6904 4743-1708 K-Ia, K-5, HRZ11499 43.75340.26 8844 649l-8329 KALUBIK 11541 43.75340.86 8874 6518-8339 TARGET - 11584 43.75340.86 8904 6546-8349 KUPARUK TOTAL DEPTH [1987 43.75340.86 9196 6808 -2443 --5400 --4600 ~00 000 --8800 ~oo O0 ,8-30GC O0 Dote Piotted Created By Checked By Approved By Date 5/14/93 BHL DATA TVD glg5.74[ MD 11987.03[ VS 7233.46[ North 6808.35 East -2443.23 3000 8800 1400 600 CRITICAL POINT DATA rd ~00 ooo ,---'PRUDHOE BAY DRILLING ',OUP 20" DIVERTER SCHEMA J IC POOL 7 FILL UP LINE FLOWLINE 20" 2000 PSi DIVERTER · 1' 10" BALL VALVE 10" BALL VALVE CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVEP, TER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS COND:TIONS REQUIRE THE USE OF T?'{.E SECOND DiVERTER LINE. THE SECOND VENT LI/'4E.CAN BE REMOTELY OPENED TO ACHIEVE DOWNWIND DIVERSIO,".,'. THIS IS A VAR',AI".:CE FROM 20AAC25.035. J ),dj ~ /'-h'DRIL 15 5/8"-5000PSi OK ANNULAR BOP LATCHED HEAD CONNECTION'"1 5/8"-10,000PS1 HUB BOTTOM HYDRIL 1,7 5/8"- 10, O00?S{ MPL RAM BOP HUB CONNECTIONS 4 1/16"- ~ O, O00PSI SIDE OLFFLETS HYDRIL 13 5/8'- 10, O00PSI MPL RAM BOP HUB CONNECTIONS 4 I/I~"-10, O00?SI SIDE OUTLETS CHOKE WING t/.~NUAL HCR LYNN INTERNATIONAL ~ 7/~ 6"- ~ o, ooo~sl CHECK VALVE KILL WING McEVOY 4 1/16"- ~ 0 TYPE E ~ATE VALVE 5/~'-~o, ooo~sl HUB X FLANGE ADAPTOR BLOW-OLFF PREVENTER STACK PAA RIG 7 ~cEVO¥ 5 1/16"- 10, O00PSI TYPE E GATE VALVE HYDRIL 15 5/8'-10,O00PSI MPL RAM BOP HUB CONNECTIONS 4 1/16"-10,000PSi SIDE OUTI_E-FS ' Gas 6ons. 6ornrniss~O~ Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER d. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 8, 1993 Peter Goebel Land Department ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Application for spacing .exceptions - Pt Mclntyre wells P2-06 and P2-12 Dear Peter: As we discussed today, I am returning your June 23 correspondence requesting exception to the provisions of 20 AAC 25.055 for the subject wells. The issuance of pool rules for the Pt. Mclntyre oil field on July 2, 1993 negates the need for exceptions to statewide regulations in this area. Let me know if any other concerns arise. Robert P Crandall Sr Petr Geologist encl ARCO Alaska, Inc. Post Office Box 1,. ,60 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 23, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 SR E]~[II~ ENG'AS~'¢-'I - ', -..q QEOL ~-'. E OL ASSTI ':'rAT TECHI · "'FA'," TEC'q ~ Re: Request for Exception to the Provisions of 20 AAC 25.055 (drilling units and well space) Pt. Mclntyre Development Wells P2-06 and P2-12 Prudhoe Bay, Alaska Dear Chairman Johnston: ARCO Alaska, Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling and completion of ARCO's Pt. Mclntyre Development Wells P2-06 and P2-12. The P2-06 Well will be drilled as a directional hole within 250' of the following locations: · Surface Location: 29'FSL, 1046'FWL, Sec 11, T12N, R14E, UM; · Target Location: 1294'FSL, 1293'FEL, Sec 3, T12N,R14E, UM; · Bottom Hole: 1557'FSL, 1387'FEL, Sec 3, T12N, R14E, UM. The P2-12 Well will be drilled as a directional hole within 250' of the following locations: · Surface Location: 6'FNL, 1129'FWL, Sec 14, T12N, R14E, UM; · Target Location' 133'FNL, 2138'FWL, Sec 11, T12N, R14E, UM; · Bottom Hole: 67'FSL, 2177'FWL, Sec 2, T12N, R14E, UM. A plat showing the location of the P2-06 and P2-12 Wells, leasehold ownership, and all other completed and drilling wells in the area is attached as Exhibit 1. The names and addresses of all owners and operators of the governmental quarter sections directly and diagonally offsetting the proposed drilling unit for the P2-06 and P2-12 Wells are set forth in Exhibit 2. Included in Exhibit 3 is the verification required by the referenced provisions, a copy of the notice sent to the owners and operators listed in Exhibit 2, and the date such notice was mailed. If you have any questions or require any additional information, please contact the undersigned at (907) 265-6281. Peter L. Goebel Landman :jls Attachments RECEIVED d UN 2 3 1993 Alaska 011 & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Company I s~ a?aa u~a~a' ADL 312809 T15N ADL 377054 I T12N AM-EXXON %~~ EXXON o~ ~ "/ BPX 3-31-77 ~~ 3-31-77 ~z ~qo , ,,/ 11-30-95 (COND) ~~ ADL 34622 ~ ' / ADL 365548 ALK 3054 ~ .~r ~o~. z ~ P2-12'7 ADL_~6a~ ....... ~~ _ 4 _ _,~ ....... L_ . ~ ~J vr xQ~ ~ ~~ , ~ ~/g~~ ~ 3-31-77 ~ 9-30-75 ~-~ ', k~ 2 ~5 ADL 34624~ ADL 28~90 k [ M~ aa~ ~ ~ ALK ~308~ Y/ ,/ kocefion Exceptions o aero' szgo'~, ADL ~8~97 = ~~ q ,/ ,, for Well; ~ ~ ' ]~ ,~ P2-06, P2-12 SCALE IN FEET k k "~ a~. ~ AK95 011101 DO3 Exhibit 2 Pt. Mcintyre Development Well Request for Spacing Exception P2-06 and P2-12 Workinq Interest Owners Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn: Mr. David E. Steingraeber BP Exploration (Alaska)Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attn: Terry J. Obeney Royalty Owners State of Alaska Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn: James E. Eason, Director Overriding Royalty Owners Not Applicable REEEIVED J UN 2 ;~ 1993 Alaska 0il & L~as Cons, (;omm~ssioll Anchorage EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) Request of ARCO Alaska, Inc. for ) an Exception to the Provisions ) of 20 AAC 25.055 for Pt. Mclntyre ) Development Wells P2-06 and P2-12 ) ) VERIFICATION OF FACTS AND AFFIDAVIT OF PETER L. GOEBEL STATE OF ALASKA THIRD JUDICIAL DISTRICT SS. Peter L. Goebel, being first duly sworn, upon oath, deposes and states as follows' 1. My name is Peter L. Goebel. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Landman for the well operator, ARCO Alaska, Inc. 3. I am acquainted with the facts associated with the drilling of Pt. Mclntyre Development Wells P2-06 and P2-12. 4. I have reviewed the application submitted for the exception to 20 ACC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit I and it correctly portrays pertinent and required data. 6. Pursuant to 20 AAC 25.055 (b), ARCO Alaska, Inc. ("ARCO"), the well operator, prepared a Notice of Request for Exception to the Provision of 20 AAC 25.055. A copy of this notice is attached hereto. 7. On June 23, 1993 pursuant to 20 AAC 25.055 (b), ARCO sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed locations of ARCO's Pt. Mcintyre Development Wells P2-06 and P2-12. These names and addresses are set forth on Exhibit 2 attached to ARCO's Request for Exception to Provisions of 20 AAC 25.055 dated June 23, 1993. Subscribed and sworn to on June 23~¢,./,/~-~ ~,~.~~ Peter L. Goebel STATE OF ALASKA ) ) SS. THIRD JUDICIAL DISTRICT ) RECEIVED ,IUN 2 ~ 199~ .~,laska 0il & ~as Cons. Oom~issi°° Anchorage The foregoing instrument was acknowledged before me on June 23, 1993, by Peter L. Goebel. OFFICIAL SEAL STATE OF ALASKA Janis L. Shaw NOTARY PUBLIC My Comm. ,Expires. At:h'il 2, .1...997 Notary Public, State of AI~'-- My Commission Expires: ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 23, 1993 BP Exploration (Alaska) Inc. P.O. Box196612 Anchorage, AK 99519-6612 Attn: Terry J. Obeney Exxon Corporation P.O. Box 2180 Houston, TX 77252-2180 Attn: David Steingreaber Department of Natural Resources Division of Oil and Gas P.O. Box 107034 Anchorage, AK 99516 Attn: James E. Eason, Director Re: Notice of Request for Exception to the Provisions of 20 ACC 25.055 Pt. Mclntyre Development Wells P2-06 and P2-12 Prudhoe Bay, Alaska Pursuant to the provisions of 20 AAC 25.055 (b), ARCO Alaska, Inc. (ARCO) hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission (AOGCC) for an exception to the well spacing requirements of 20 AAC 25.055 for the drilling of the Pt. Mclntyre Development Wells P2-06 and P2-12. ARCO's request if approved, will permit the drilling and completion of the Pt. Mclntyre Development Wells P2-06 and P2-12 as a directional hole within 250' of the following locations: · Sudace Location: 29'FSL, 1046'FWL, Sec 11, T12N, R14E, UM; · Target Location: 1294'FSL, 1293'FEL, Sec 3, T12N,R14E, UM; · Bottom Hole: 1557'FSL, 1387'FEL, Sec 3, T12N, R14E, UM. P2-12 · Sudace Location: 6'FNL, 1129'FWL, Sec 14, T12N, R14E, UM; · Target Location: 133'FNL, 2138'FWL, Sec 11, T12N, R14E, UM; · Bottom Hole: 67'FSL, 2177'FWL, Sec 2, T12N, R14E, UM. A plat showing the location of the subject wells, leasehold ownership, and all other completed and drilling wells in the area is attached as Exhibit 1. Should you have any questions, please call the undersigned at (907) 265-6281. Peter L. Goebel Landman RECEIVED :jls J UN 2 3 199 Alaska 0il & Gas Cons. 00mmissio~ Anchorage ARCO Ala]ka, Inc. I~, · Subsldl·ry of Aflaatl¢ Richfield Co,~pa~y ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE [2 ~hru ~ ' ' 2. 3. 4. 5. 6. .~ ~" -., [10 S 13] 12. (4) Casg [14 thru 22]~ 15. [23 thru 28] (5) BOPE Company YES Is permit fee attached ............................................... /( Is well to be located in a defined pool .............................. L Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... ~ Is sufficient undndicated acreage available in this pool ............. ~ 16. 17. 18. 19. 20. 21. 22 23. 24. 25. 26. 27. 28. Lease & Well NO Is well to be deviated & is wellbore plat included ................... 'L Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... _L Is a conservation order needed ...... ~-- Is administrative approval needed Is lease ntrnber appropriate .......................................... L Does well have a unique name & nLrnber ................................ ~ .. Is conductor string provided ......................................... ~L Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. ..~.' Is well to be kicked off from an existing wellbore ................... ..~ Is old wellbore abandonment procedure included on 10-403 ............. ~.' Is adequate well bore separation proposed ............................. ~+~-' ... Is a diverter system required .............. ~ ......................... -~ Is drilling fluid program schematic & list of equipment adequate ..... ...... Are necessary diagrams & descriptions of diverter & BOPE attached Does BOPE have sufficient pressure rating -- test to~-oz~r~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... N/~ Is presence of H2S gas probable ...................................... REMARKS (6) Other ~_~ [29 thru 31] [32] (8) Addl 29. 30. 31. 32. 33. geo 1 ogy: en9 i nee r [ng: DW BEW ~----~H .~[1 ~' TA , rev 6/93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ngrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA -' ~ SHORE , ,, Additional remarks' UM X MERIDIAN: SM WELL TYPE' Exp'~-:z~"~ Inj Red ri 11 Rev 0 --I ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER POINT MCINTYRE UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN1 6019.00 BRAD ESARY ALONZO/PEAK REMARKS: P2 - 06 500292238800 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 24-AUG-93 RUN2 RUN3 30 11 12N 14E 1045 53.50 OPEN HOLE 12.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 4313.0 9.875 11975.0 24:00 16-AUG-93. DLL/CN/ZDL/GR CIRCULATION STOPPED: HOLE CONDITIONS VERY STICKY RUNNING IN HOLE. COULD NOT GO BELOW 11800'. NO REPEAT PASS ATTEMPTED. NEUTRON WAS RECORDED ON A SANDSTONE MATRIX. A CALIPER CORRECTION WAS APPLIED. CHISM FILTERING WAS NOT ACTIVE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth shifted and clipped curves; (including cased hole). DEPTH INCREMENT: 0.5000 FILE S~RY LDWG TOOL CODE GR DLL 2435 SDN $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH STOP DEPTH 11400.0 11734.5 11400.0 11786.0 11400.0 11741.0 11400.0 11759.0 GR (MEASURED DEPTH) BASELINE DEPTH LL3 11393.0 11393.0 11435.5 11436.0 11437.0 11457.5 11456.5 11458.5 11458.5 11459.0 11458.0 11462.0 11461.5 11462.0 11496.5 11496.0 11496.0 11499.0 11498.5 11498.5 11502.0 11501.0 11502.0 11505.5 11506.0 11505.5 11506.0 11506.5 11529.0 11528.5 11528.5 11553.0 11553.5 11553.5 11552.0 11552.0 11561.5 11559.5 11559.5 11579.5 11578.5 11578.5 11580.0 11578.0 11586.0 11586.0 11588.0 11586.5 11586.5 11596.0 11593.5 11595.0 11609.0 11609.0 11615.5 11615.5 11619.5 11619.0 11623.0 11622.5 11623.5 11623.0 11623.0 11625.5 11625.0 11624.5 11624.5 11644.5 11643.0 11645.0 11644.0 11644.0 11654.0 11655.0 11668.0 11668.5 11667.5 11667.5 11672.0 11672.5 11698.0 11698.0 11698.0 11709.0 11709.0 11709.0 11719.0 11719.0 11793.0 11793.0 11793.0 11793.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. EQUIVALENT UNSHIFTED DEPTH NPHI RHOB 11393.0 11393.0 11436.0 11436.0 PASS NO. MERGE TOP all runs merged MERGE BASE GR DLL 2435 SDN $ REMARKS: CN WN FN COUN STAT 11400.0 11734.5 11400.0 11786.0 11400.0 11741.0 11400.0 11759.0 MAIN PASS. LLD, MTEM, SP, TENS, & TEND WERE SHIFTED WITH LL3. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. $ : ARCO ALASKA INCORPORATED : P2 - 06 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 2 LL3 DLL 68 1 OHMM 3 LLD DLL 68 1 OHMM 4 SP DLL 68 1 MV 5 MTEM DLL 68 1 DEGF 6 TEND DLL 68 1 LB 7 TENS DLL 68 1 LB 8 NPHI 2435 68 1 PU-S 9 FUCT 2435 68 1 CPS 10 NUCT 2435 68 1 CPS 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 1 IN 4 57 515 01 6 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 56 * DATA RECORD (TYPE~ 0) Total Data Records: 51 966 BYTES * Tape File Start Depth = 11793.000000 Tape File End Depth = 11393.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1~016 datums Tape Subfile: 2 172 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is typ'e: LIS ~ ,~ ~ FILE HEADER IQ ~ ~ ~ ~ ~' '~ ~ ~ -,~ FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 1 0.2500 VENDOR TOOL CODE START DEPTH GR 11393.0 DLL 11393.0 2435 ZDL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 11393.0 11393.0 STOP DEPTH 11738.0 11790.0 11745.0 11762.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN PCM ZDL KNJT TEMP PCM KNJT MIS DLL FTS FTS $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 17-AUG-93 FSYS REV. J001 VER. 1.1 2400 16-AUG-93 1116 17-AUG-93 11975.0 11800.0 11400.0 11786.0 1200.0 TOOL NUMBER 3974XA 3517NA 1309XA 2435XA 3508EA 2222EA/MA 3921NA 2806XA 3506XA 3921NA 3967NA 1229EA/MA 9.875 4313.0 0.0 KCL POLY 10.05 51.0 MUD PH: FLUID LOSS~ (C3)~: MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 9.4 6.0 170.0 0.200 0.085 0.209 0.000 0.399 0.000 68.0 170.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN) : 8.5 REMARKS: MAIN PASS. DUE TO HOLE CONDITIONS THIS WAS THE ONLY PASS RECORDED. CNC LOGGING PARAMETERS: SANDSTONE MATRIX BOREHOLE CORRECTION = CALIPER CHISM FILTERING NOT ACTIVE. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : P2 - 06 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Name Tool Code Samples Units GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 17 CAL ZDL 68 1 IN 4 * DATA RECORD (TYPE# 0) Total Data Records: 115 1014 BYTES * 68 4 24 115 90 Tape File Start Depth = 11793.000000 Tape File End Depth = 11393.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28819 datums Tape Subfile: 3 202 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is typ~: LIS 93/ 8/24 01 **** REEL TRAILER **** 93/ 8/25 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 25 AUG 93 2:05p Elapsed execution time = 14.72 seconds. SYSTEM RETURN CODE = 0 * ALASKA COi~P[JTIMG CM::iTf]R * , ****************************** ****************************** q~.p5 RECEIVED :chlu~.~erqer AlasKa r'onput~nq Center PAGEI P2-O6/F'3 ('0292 o 5 .... , 23880 ~RCO AI.,t~SKA, INC. SCHbII?BERGER ~.:ELI, SKRVICES 21-SEP-93 ]ST r'" o '. k I "G 12~ 3 {? !. O45 53.50 53.50 12,50 **~*****~* ~9~ 2 ********** ,317 TO ~EU 12~ 6- v , GII'TO OE~'.~ ~22.71' ~G~; RP TO F, IT: 64.93, ~t)S RP TP BIT: i. 29 ~,TT 'lC: ~ES ~1 76' ~IT TJ GR 72.1~' ... ~:.; I: V .... 347 0 11976 PAGEI ~.., ~~ .... , .. '.. r'-epth shifted ar:~d c]..j, pped curves; all bit runs merged, 0.5000 9¢32 ['~-6':':F'l,'!i",:;r''' ('i,[.?¥E FC:R 5i'i~TFTS: ,IS '!ar:'.-e t,'eriiicatioa !~J. sti~a ~C~lUr~:b, ercer !~las~a ~'o,'.."~;t',tl~ Center PAGE= !J77~,5 11712.0 !!697,0 t!6~7.5 11674,5 i1&65,5 !.~6~'~,5 ~!65~,5 11.655.5 1!6,~5.n 1!632,5 !16~'~.~ !!61.4.'~ 1!6C5.5 11596°5 1158~,5 1!5~9.9 11580°0 1156~,0 11553,0 11540.0 !t. 530,0 11519°0 11503.o !1492.0 IIa84,{~ 1!.476,0 ~ !.462.0 !!455,5 1on,o ~ti fOOL alt p[.]~ ~!{)o uERGE TUP NERGE B~$E 2 9832,0 103~0.0 3 10340.0 11964.5 OPE~,~ ~ObE ~,~I~FJLI~ GR OF 17-AUG-93. :~.b!.~ 9T~,~E~ CURVES k~[;::~;~'E ('~!ED WI:TH T~{E GR S~!FT. ~,JO DRIL[,It~G DATA WAS C(.~[.,LE:CTED OVEP PIT ~1.}'~ ~i (MAD ONLY). BIT R!T !;~!~:,~ ~3 ~:~'[~ 9RIbLItlG P!SSES !~.~CLUI)E CD9 Ai~iD CDN DATa FPO? 9839' TO 11964.5'. LIS Fr*i~!~AT !'>!NT?:N ;Ch].,.~r,'ber::er ,~,las~ra ¢o:P,~tj.r,g Cente) ! 4 6a 0000000000 1 4 68 0000000000 I .4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 6~ 0000000000 I 4 68 0000000000 ! 4 68 0000000000 1. 4 68 0000000000 1 4 68 0000000000 ~ 4 68 0000000000 I 4 68 0000000000 1, 4 68 0000000000 i 4 6~ 0000000000 -999.250 -999,250 -999.250 2,972 3. 401 241,750 ['.;FpT!..~ i:'.;CRFi~ENT O, 5000 ......................... ;155 r<,-p 9680.0 0832.0 ClikVk: $~4IFT DATA ru~s ~eroed uslnq earliest ...... ----EOUIVAbE:~,!T LINSHIFTED DEPTii----- ..... 11719,0 117!2.0 ~1687.5 I!665.5 11654.5 11645.O 1 1 5 g 0,0 ~1553,0 1152~,5 1!.519.0 89 I 0 0 mmmmmmmmmm L~ 0 E ~£6"g mmmmmm#mmmmmmmmmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmm~ammm 0000000000 89 ~ I ~ ~ 0 O0 00o 0000000000 89 ~ I [ ~ o O0 OeO 0000000000 89 ~ ~ [ ~ 0 O0 OtiO 0(> 0000000000 89 ~ ~ '[ ~ 0 oO <)(),,) O0 0000000000 89 ~ [ [ g C, OO 00~ 0000000000 89 ~ [ I ~ 0 O0 0~0 0000000000 89 ~ [ [ ~ n O0 000 OOOO000000 89 ~ I [ g J O0 000 0000000000 89 ~ i t g r~ O0 060 0000000000 89 ~ .~ ~ E (:: O0 000 0000000000 89 ~ i [ ~ 0 O0 000 0000000000 89 ~ i [ ~ ~, O0 00<> 0000000000 89 ~ [ [ ~ 0 O0 OuO 000000o000 89 ~ ~ I ~ 9 oO 000 O0 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm iIiI I i I i I I Ill I I i I I iIii I I I Ifil I ~il m II II. I t /Il I i I I III III I I III d '4 T d 'V I d V I d ? ~ D I A ~ 1.~ c..,. & I !., I't A :d .4 nu'i~sTq uol;'3~t:~:~OA ouei SI, ~'6E86 ~II~I~i~it :3D~d ~L~'6 60E'O q~:O0 E66¥-dqW-E~ tls 22-SgP-1903 (}9:56 10 i) F PT F q~ (:, n .. 0 I 4 68 0000000 _ (';~ 1,-,! (;~pI 99 ()cO O0 O ] 1 1 4 68 0000000000 -999. 250 88.2,71 Curves and to~'? header data ~or each blt:: run in separate [iles.: DE:P??{ i: ~.} ~ R [~? :~4 '~; i~ T: 0,5000 vE~,.[>gR T991, CO0~ START DI".:PT~ STOP i;.~EPTH C?>~ 961 '57 10346,5 , 0 '~L 0 0 ' '[ EO&'O 00°o~ ~LA'6 $ ~ ' L [96 :~DYd 99 of., 60 E66 $ u; £ elep 0~Z'666- 0~'666- 0g~'666- 0S~'666- ~,~' i' ~I ' i ,i~ II~II ImII II i Ii Iii i 1-1 i I I I IIImIIIl i ~ lIII ii IIII ~ i i i ~ i I II III IIii~ #i I i II I i i i i~ I~ I~ iii Iii~ i 9~:6t) E66[-d~9-dZ ~t~u'.[~s".~,~ uo!~eo~I~A aueu SI, 2~-5LP-1993 PAGE: 14 ? . ® 11977.0 8191.0 9.875 4313.0 n.5o2 2.65 9,875 i29' 65.0 72.0 9S:60 £66I-d39-dg Is ~a.r.~e Verification bistJ, nq PAGE: 16 250 DPFI.LW3 -999 250 DRHO.LN3 ~5n T'~b 1.,~:3 -999 250 ~TR.b~3 -~.~5o ~f~PE:. L,*~ 3 1~.642 GR. [.,w~ -qS'9.~50 Thb. LW3 -999.~50 T~BD.L~3 -999.250 -999,250 -999,250 -999.250 -999.,250 -999,250 -999,250 -999,250 **** FILE mRA] !,,ER **** ~ D~TV : 93/0q/~2 FT [.,F TYPE:: L~ST FILE : P 2 - 06 / t;' 3, P2-O6IF3, 50-029-22388-00 50-029-22388-00
