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Home My WebLink About198-129CAUTION: 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: Withdraw Sundry #322-214 - Trading Bay Unit D-26RD PTD: 198-129 Date:Monday, May 1, 2023 1:08:04 PM Hi James, This sundry is already processed but needs to be withdrawn. Thanks From: Juanita Lovett <jlovett@hilcorp.com> Sent: Monday, May 1, 2023 11:24 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: Withdraw Sundry #322-214 - Trading Bay Unit D-26RD PTD: 198-129 Bryan, Please withdraw the above-mentioned sundry. The project will not be completed at this time. Scope of work was to pull the patch and reset an extended patch to repair the tubing. Regards, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com 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. 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Allowable Surface Pressure:~1,200 psi gas-lift ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dŚĞͲϮϲƌĚǁĂƐůĂƐƚǁŽƌŬĞĚŽǀĞƌŝŶϭϵϵϴ͘/ƚŝƐĂŐĂƐůŝĨƚĞĚ͕ŶŽĨůŽǁǁĞůůĐŽŵƉůĞƚĞĚŝŶƚŚĞ'ƌĂǇůŝŶŐ͘/ƚĐƵƌƌĞŶƚůǇ ŚĂƐĂƚƵďŝŶŐƉĂƚĐŚƐƉĂŶŶŝŶŐĂůĞĂŬďĞƚǁĞĞŶϮ͕ϲϮϳ͛ͲϮ͕ϳϬϳ͛ƚŽƌĞƉĂŝƌdǆ/͘dŚŝƐƉƌŽĐĞĚƵƌĞǁŝůůƉƵůůƚŚĞƉĂƚĐŚĂŶĚ ƌĞƐĞƚĂŶĞǆƚĞŶĚĞĚƉĂƚĐŚƚŽƌĞƉĂŝƌƚŚĞƚƵďŝŶŐ͘ WƌŽĐĞĚƵƌĞ͗ ϭ͘ D/Zh^ůŝĐŬͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϭ͕ϱϬϬƉƐŝŚŝŐŚ͕ϮϱϬƉƐŝůŽǁ͘ Ϯ͘ Z/,ǁŝƚŚƐůŝĐŬͲůŝŶĞĂŶĚƉƵůůƚŚĞƉĂƚĐŚ ϯ͘ Z/,ǁŝƚŚƚďŐƉĂƚĐŚĨƌŽŵцϮϲϬϬʹцϮϳϮϬ͛D;ĂŚŽůĞĨŝŶĚĞƌ͕ĐĂůŝƉĞƌŽƌ>>ǁŝůůďĞƌƵŶƉƌŝŽƌƚŽ ƌƵŶŶŝŶŐƚŚĞƉĂƚĐŚƚŽĚĞƚĞƌŵŝŶĞĂĐƚƵĂůĚĞƉƚŚͿ ϰ͘ ZƐůŝĐŬͲůŝŶĞ ϱ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ ŽůůǇsĂƌĚĞŶWůĂƚĨŽƌŵ tĞůů͗ͲϮϲZ ŽŵƉůĞƚĞĚ͗ϴͬϬϵͬϭϵϵϴ hƉĚĂƚĞĚďǇ͗:>>ϬϯͬϬϱͬϮϭ ^,Dd/ Dy,K>E'>сϰϯ͘ϮϱqΛϯ͕ϴϬϬ͛ Z<сϰϬ͘ϱ͛ 'Ͳϰ 'Ͳϯ 'ͲϮ dK Λ ϭϭ͕Ϭϰϴ͛ dD ϯ ϱ ϲ ϭ Ϯ ; ďĂŶĚ ,ĞŵůŽĐŬ EĞǁ͗dϭϭ͕ϱϬϬ͛ tŚŝƉ ^ƚŽĐŬΛ ϭϬ͕ϳϯϬ͛ ϰ WĂƚĐŚϮ͕ϲϮϳ͛ʹ Ϯ͕ϳϬϳ͛^>D ϭϬͬϭϯͬϬϵ͗ ϯ͘ϳϱ͟'Z ƚĂŐŐĞĚƵƉĂƚ ϭϬ͕ϭϰϵ͛͘ ^/E'd/> ^ŝǌĞ td 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϮϬ͟ ϵϰ ,ͲϰϬ ϭϵ͘ϭϮϰ ^ƵƌĨĂĐĞ ϲϳϯ͛ ϭϯͲϯͬϴ͟ ϲϭ :Ͳϱϱ ^ĞĂů>ŽĐŬ ϭϮ͘ϱϭ ^ƵƌĨĂĐĞ ϯ͕ϯϬϲ͛ ϵͲϱͬϴ͟ϰϬ Θϰϳ EͲϴϬ ΘWͲϭϭϬ d ϴ͘ϳϱϱ ^ƵƌĨĂĐĞ ϭϬ͕Ϯϯϵ͛ ϳ͟ Ϯϵ EͲϴϬ yͲ>ŝŶĞ ϲ͘ϭϴϰ ϭϬ͕ϬϴϮ ϭϭ͕ϵϲϵ͛ EŽƚĞ͗dŽƉŽĨǁŝŶĚŽǁŝŶϳ͟ΛϭϬ͕ϳϰϮ͛ dh/E'd/> ϰͲϭͬϮ͟ ϭϮ͘ϲ >ͲϴϬ dΘ ϯ͘ϵϱ ^ƵƌĨĂĐĞ ϭϬ͕ϭϰϵ͛ ϮͲϳͬϴ͟^> ϲ͘ϰ >ͲϴϬ ^d> Ϯ͘ϰϰϭ ϭϬ͕ϬϱϬ ϭϭ͕ϰϵϳ͛ :t>Zzd/> EK͘ ĞƉƚŚ;DͿ ĞƉƚŚ;dsͿ / K /ƚĞŵ ϭ ϰϬ͘ϱϬ͛ ϰϬΖ Ͳ Ͳ /t͕ϭϭ͟ǆϰ͕͟ϱD͕^ŝŶŐůĞdƵďŝŶŐ,ĂŶŐĞƌ Ϯ ϰϭ͘ϳϱ͛ ϰϮΖ ϯ͘ϵϱ ϰ͘ϱ ϰͲϭͬϮ͟ƵƚƚƌĞƐƐdƵďŝŶŐDŽĚŝĨŝĞĚ ϯ ϯϬϮ͛ ϯϬϮΖ ϯ͘ϴϭϯ ϱ͘ϯϯ ĂŵĐŽdZWͲϰ^^^s;ϯ͘ϴϭϯ/͘͘Ϳ͕ ϰ Ϯ͕Ϯϰϭ͛ Ϯ͕ϮϭϵΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϰ͕ϭϮϱ͛ ϯ͕ϳϱϲΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϱ͕ϳϲϳ͛ ϱ͕ϬϬϭΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϲ͕ϴϵϲ͛ ϱ͕ϴϲϴΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϳ͕ϳϰϲ͛ ϲ͕ϱϰϯΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϴ͕ϰϴϮ͛ ϳ͕ϭϭϴΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϴ͕ϵϵϳ͛ ϳ͕ϱϭϵΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϵ͕ϰϳϳ͛ ϳ͕ϵϬϮΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϵ͕ϵϵϲ͛ ϴ͕ϯϭϳΖ ϯ͘ϴϳϱ ϱ͘ϵϲϴ ĂŶŝĞůƐ͕ϰͲϭͬϮ͟Ϯ'>D͕ϭͲϭͬϮ͕͟Z< ϱ ϭϬ͕Ϭϭϱ͛ ϴ͕ϯϯϯΖ ϯ͘ϵϱ ϰ͘ϱ ϰͲϭͬϮ͟ƵƚƚƌĞƐƐdƵďŝŶŐDŽĚŝĨŝĞĚ͕ϭͲ:Ŷƚ ϭϬ͕Ϭϱϭ͛ ϴ͕ϯϲϭΖ ϰ ϱ͘Ϯϱ ĂŬĞƌ^ĞĂů>ŽĐĂƚŽƌĨͬWZ ϭϬ͕ϬϱϮ͛ ϴ͕ϯϲϮΖ ϰ͘ϳϱ ϴ͘Ϯϲϱ ĂŬĞƌWZtͬ^ĐŽŽƉηϲϴϯͲϭϵͲϰϳϭϱ ϭϬ͕ϬϳϮ͛ ϴ͕ϯϳϴΖ ϯ͘ϵϱ ϰ͘ϱ ϰͲϭͬϮ͟ƵƚƚƌĞƐƐdƵďŝŶŐDŽĚŝĨŝĞĚ͕ϭͲ:ŶƚнϮƉƵƉƐ ϲ ϭϬ͕ϭϭϭ͛ ϴ͕ϰϬϵΖ ϰ ĂŬĞƌ^>ͲϯWĂĐŬĞƌǁͬdŽƉ>ĂƚĐŚΘDK ϳ ϭϬ͕ϭϯϮ͛ ϴ͕ϰϮϲΖ ϯ͘ϴϭϯ KƚŝƐyͲEŝƉƉůĞǁŝƚŚϯ͘ϴϭϯ͟WŽůŝƐŚŽƌĞ ϴ ϭϬ͕ϭϰϵ͛ ϴ͕ϰϯϵΖ Ϯ͘ϵϵϮ ϲ͘Ϭϯ tŝƌĞ>ŝŶĞZĞͲĞŶƚƌǇ'ƵŝĚĞ ϵ ϭϬ͕Ϭϱϭ͛ ϴ͕ϯϲϭΖ Ϯ͘ϯϳϮ ϯ͘ϳϱ >ŝŶĞƌƐĐŽŽƉ,ĞĂĚǁŝƚŚϰͲϭͬϮ͟EŽŵ'^WƌŽĨŝůĞ ϭϬ ϭϬ͕Ϭϱϲ͛ ϴ͕ϯϲϱΖ Ϯ͘ϰϰϭ Ϯ͘ϴϳϱ ϰϱ:ŽŝŶƚƐϮͲϳͬϴ͟ϲ͘ϰη>ŝŶĞƌǁŝƚŚ^d>ĐŽŶŶĞĐƚŝŽŶ͘ϭϲΛ ϯͬϴ͟,W&ƉĞƌĨŽƌĂƚĞĚůŝŶĞƌ ϭϭ ϭϭ͕ϰϴϴ͛ ϴ͕ϵϱϯΖ ϭ͘ϲ Ϯ͘ϴϳϱ WĂĐŬŽĨĨ^Ƶď͘ ϭϮ ϭϭ͕ϰϵϲ͛ ϴ͕ϵϱϮΖ Ϭ Ϯ͘ϴϳϱ dĂƉĞƌĞĚƵůůĞƚŶŽƐĞŐƵŝĚĞƐŚŽĞ ϳ ϴ ϵ ϭϬ ϭϭ ϭϮ WZ&KZd/KEd/> ŽŶĞ dŽƉ;DͿ ƚŵ;DͿ dŽƉ;dsͿ ƚŵ;dsͿ ŵƚ ƐƉĨ ^ƚĂƚƵƐ ĂƚĞ 'ͲϮ ϭϬ͕ϲϲϴΖ ϭϬ͕ϲϴϴΖ ϴ͕ϴϱϮΖ ϴ͕ϴϲϴΖ ϮϬΖ KƉĞŶ ϭϭͬϭϲͬϮϬϭϱ 'Ͳϯ ϭϬ͕ϲϵϯΖ ϭϬ͕ϳϬϵΖ ϴ͕ϴϳϮΖ ϴ͕ϴϴϰΖ ϭϲΖ KƉĞŶ ϭϭͬϭϲͬϮϬϭϱ 'Ͳϯ ϭϬ͕ϳϰϬΖ ϭϬ͕ϳϲϱΖ ϴ͕ϵϬϵΖ ϴ͕ϵϮϴΖ ϮϱΖ KƉĞŶ ϯͬϮϯͬϭϵϵϳ 'Ͳϰ ϭϬ͕ϳϴϲΖ ϭϬ͕ϴϲϬΖ ϴ͕ϵϰϯΖ ϴ͕ϵϴϳΖ ϳϰΖ ϭϮ KƉĞŶ ϯͬϮϯͬϭϵϵϳ Ͳϭ ϭϭ͕ϮϭϬΖ ϭϭ͕ϮϳϯΖ Eͬ Eͬ ϲϯΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ ͲϮ ϭϭ͕ϮϳϯΖ ϭϭ͕ϯϬϲΖ Eͬ Eͬ ϯϯΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ Ͳϯ ϭϭ͕ϯϵϬΖ ϭϭ͕ϰϯϱΖ Eͬ Eͬ ϰϱΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ Ͳϰ ϭϭ͕ϰϲϴΖ ϭϭ͕ϲϭϱΖ Eͬ Eͬ ϭϰϳΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ Ͳϱ ϭϭ͕ϲϰϮΖ ϭϭ͕ϳϱϬΖ Eͬ Eͬ ϭϬϴΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ Ͳϲ ϭϭ͕ϴϮϲΖ ϭϭ͕ϴϱϴΖ Eͬ Eͬ ϯϮΖ ϭϮ ďŶǁͬĞŵĞŶƚ ϯͬϮϯͬϭϵϵϳ ϰͬϯͬϭϮ͗ZĞŵŽǀĞ ĨŝƐŚĨƌŽŵϮ͘ϴϳϱ ůŝŶĞƌΛϭϬ͕ϲϵϲ͛ ϬϯͬϬϰͬϮϭ͗>ŽƐƚϮǁŚĞĞůƐ ĨƌŽŵƌŽůůĞƌƐƚĞŵЬ͟ǆϭ͘ϴ͟ ΕϭϬ͕ϲϱϲ͛͘ ŽůůǇsĂƌĚĞŶWůĂƚĨŽƌŵ tĞůů͗ͲϮϲZ ŽŵƉůĞƚĞĚ͗ϴͬϬϵͬϭϵϵϴ hƉĚĂƚĞĚďǇ͗:>>ϬϰͬϭϱͬϮϭ WZKWK^ Dy,K>E'>сϰϯ͘ϮϱqΛϯ͕ϴϬϬ͛ Z<сϰϬ͘ϱ͛ 'Ͳϰ 'Ͳϯ 'ͲϮ dK Λ ϭϭ͕Ϭϰϴ͛ dD ϯ ϱ ϲ ϭ Ϯ ; 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Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Remove & Reinstall Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,500 feet N/A feet true vertical 8,950 feet N/A feet Effective Depth measured 10,149 feet 10,111 feet true vertical 8,439 feet 8,409 feet Perforation depth Measured depth 10,668 - 10,860 feet True Vertical depth 8,852 - 8,987 feet 4-1/2" 12.6# / L-80 10,149 MD 8,439 TVD Tubing (size, grade, measured and true vertical depth)2-7/8" SL 6.4# / L-80 11,497 MD 8,952 TVD 10,111 (MD) 302 (MD) Packers and SSSV (type, measured and true vertical depth)SALB-3 Pkr 8,409 (TVD) TRDP-4A SSSV 302 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Collapse 520psi Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 1,530psi 3,090psi 907 777-8376 5,750psi 673 3,150 8,511 8,912 673 3,306 Conductor Surface 7,020psi 3,090psi 20" 13-3/8" 10,239 Size 480 Production Casing Structural Liner 1,887 Length Intermediate N/A Junk 5. Permit to Drill Number: 92 McArthur River Field / Middle Kenai G Oil PoolN/A measured 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15 Gas-Mcf 498 N/A Oil-Bbl 51 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-330 194 Authorized Signature with date: Authorized Name: 76 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-129 50-733-20260-01-00 Plugs ADL0018729 Trading Bay Unit D-26RD measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 13 Representative Daily Average Production or Injection Data 20873 Casing Pressure 7" 10,239 MD 673 3,306 11,969 TVD measured true vertical Packer 9-5/8" Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:22 pm, Oct 28, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.10.28 12:34:01 -08'00' Dan Marlowe (1267) RBDMS HEW 10/28/2020 gls 11/23/20 DSR-10/28/2020 Remove & Reinstall Patch Dolly Varden Platform Well: D-26RD Completed: 8/09/1998 Updated by: JLL 10/26/20 SCHEMATIC MAX HOLE ANGLE = 43.25q @ 3,800’ RKB = 40.5’ G-4 G-3 G-2 TOC @ 11,048’ CTM 10/22/93 3 5 6 1 2 X Aband Hemlock New: TD 11,500’Whip Stock@ 10,730’ 4 Patch 2,627’– 2,707’ SLM 10/13/09: 3.75” GR tagged up at 10,149’. CASING DETAIL Size WT Grade Conn ID Top Btm 20” 94 H-40 19.124 Surface 673’ 13-3/8” 61 J-55 Seal Lock 12.51 Surface 3,306’ 9-5/8”40 &47 N-80 &P-110 BTC 8.755 Surface 10,239’ 7” 29 N-80 X-Line 6.184 10,082 11,969’ Note: Top of window in 7” @ 10,742’ TUBING DETAIL 4-1/2” 12.6 L-80 BT & C AB 3.95 Surface 10,149’ 2-7/8” SL 6.4 L-80 STL 2.441 10,050 11,497’ JEWELRY DETAIL NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50’ 40' - - CIW, 11” x 4”, 5M, DCB Single Tubing Hanger 2 41.75’ 42' 3.95 4.5 4-1/2” Buttress Tubing AB Modified 3 302’ 302' 3.813 5.33 Camco TRDP-4A SSSV (3.813 I.D.), 4 2,241’ 2,219' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 4,125’ 3,756' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5,767’ 5,001' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 6,896’ 5,868' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 7,746’ 6,543' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,482’ 7,118' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,997’ 7,519' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,477’ 7,902' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,996’ 8,317' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5 10,015’ 8,333' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt 10,051’ 8,361' 4 5.25 Baker Seal Locator f/ PBR 10,052’ 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 10,072’ 8,378' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt + 2 pups 6 10,111’ 8,409' 4 Baker SALB-3 Packer w/ Top Latch & MOE 7 10,132’ 8,426' 3.813 Otis X-Nipple with 3.813” Polish Bore 8 10,149’ 8,439' 2.992 6.03 Wire Line Re-entry Guide 9 10,051’ 8,361' 2.372 3.75 Liner scoop Head with 4-1/2” Nom GS Profile 10 10,056’ 8,365' 2.441 2.875 45 Joints 2-7/8” 6.4# Liner with STL connection. 16 @ 3/8” HPF perforated liner 11 11,488’ 8,953' 1.6 2.875 Packoff Sub. 12 11,496’ 8,952' 0 2.875 Tapered Bullet nose guide shoe 7 8 9 10 11 12 PERFORATION DETAIL Zon e Top(MD) Btm(MD) Top(TVD) Btm(TVD) Am t sp f Status Date G-2 10,668' 10,688' 8,852' 8,868' 20' Open 11/16/2015 G-3 10,693' 10,709' 8,872' 8,884' 16' Open 11/16/2015 G-3 10,740' 10,765' 8,909' 8,928' 25' Open 3/23/1997 G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/ Cement 3/23/1997 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/ Cement 3/23/1997 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/ Cement 3/23/1997 B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/ Cement 3/23/1997 B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/ Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/ Cement 3/23/1997 4/3/12: Remove fish from 2.875 liner @ 10,696’ Patch 2,627’– 2,707’ SLM Rig Start Date End Date Slickline 10/9/20 10/10/20 10/09/20 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20260-01 198-129 Well Name D-26RD 10/10/20 - Saturday Arrive on Dolly. Rig up on well. PT to 2000 psi. Rih w/ 3' X 1.5" Stem w/ bull nose on bottom to 5000' kb, pooh. Rih w/ Tandem Tri-gauges to 5000' kb, make 5' bottom hole stop, pooh. Ooh w/ tools, lay down for the night. Download data. Rig up on well. PT to 2000 psi -GOOD. Rih w/ 4 1/2 Gs to 2633' kb, latch AA-stop, spang up 20X, pooh, ooh w/ stop. Rih w/ 4 1/2 Gs to 2636' kb, latch top patch, pooh, ooh w/ patch/ packoff. Take off packoff and put on receptacle. Rih w/ 4 1/2 Gs w/ Spacer pipe (6.5' total length zeroed @ gs) to 2637' kb, set spacer, pooh. Rih w/ 4 1/2 Gs w/ top spacer pipe w/ DD packoff (total length 11' 9") zeroed @ packoff element to 2628' kb, set patch, pooh. Ooh no patch. Rih w/ 4 1/2 Gs w/ AA- stop (zeroed @ GS) to 2627' kb, set stop, pooh, ooh no stop. OOH w/ tools. Rig down off well. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): McArthur River Field / Middle Kenai G Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,500'N/A Casing Collapse Structural Conductor 520 psi Surface 1,540 psi Intermediate Production 3,090 psi Liner 7,020 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Remove & Reinstall Patch N/A 8,950' 11,496' 8,952' ~1200psi 1,887' 7" 8,511'9-5/8" 11,969' 8,912' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8/26/2020 4-1/2" & 2-7/8" S/L Daniel E. Marlowe SALB-3 Pkr & TRDP-4A SSSV 10,239' Perforation Depth MD (ft): 10,668 - 10,860 10,239' 10,111 (MD) 8,409 (TVD) & 302 (MD) 302 (TVD) Tubing Grade:Tubing MD (ft): 8,852 - 8,987 Perforation Depth TVD (ft): 20" 13-3/8" 673' 3,306' 673' 3,150' 673' 3,306' 12.6# L-80 & 6.4# L-80 TVD Burst 10,149 & 11,497 5,750 psi 8,160 psi Tubing Size: MD 1,530 psi 3,090 psi 198-129 50-733-20260-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC Trading Bay Unit D-26RD COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:25 pm, Aug 10, 2020 320-330 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.10 13:19:10 -08'00' Dan Marlowe (1267) DLB 08/10/2020 X DSR-8/10/2020 NA DLB all Patch OIL 10-404 gls 8/24/20dts 8/24/2020 8/24/2020Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2020.08.24 14:23:55 -08'00' RBDMS HEW 8/26/2020 Well Work Prognosis Well: D-26rd Well Name:Trading Bay Unit D-26rd API Number: 50-733-20260-01 Current Status:Gas-Lift Producer Leg:NE Corner (A-1) Estimated Start Date:8/26/2020 Rig:N/A Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:198-129 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8384 Cell: 907-570-1801 Current Bottom Hole Pressure:~2,188 psi @ 8,919’ TVD 0.417 psi/ft Mid-Perf Maximum Expected BHP:~2,188 psi @ 8,919’ TVD 0.417 psi/ft Mid-Perf Max. Allowable Surface Pressure:~1,200 psi gas-lift Brief Well Summary The D-26rd was last worked over in 1998. It is a gas lifted, no flow well completed in the Grayling. It currently has a tubing patch spanning a leak between 2,628’-2,707’ to repair TxIA. This procedure will pull the patch and reset an extended patch to repair the tubing. Procedure: 1. MIRU Slick-line, PT lubricator to 1,500 psi high, 250 psi low. 2. RIH with slick-line and pull the patch 3. RIH with tbg patch from ±2600 – ±2720’ MD (a hole finder, caliper or LDL will be run prior to running the patch to determine actual depth) 4. RD slick-line 5. Turn well over to production Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Dolly Varden Platform Well: D-26RD Completed: 8/09/1998 Updated by: JLL 12/03/15 SCHEMATIC MAX HOLE ANGLE = 43.25q @ 3,800’ RKB = 40.5’ G-4 G-3 G-2 TOC @ 11,048’ CTM 10/22/93 3 5 6 1 2 X Aband Hemlock New: TD 11,500’Whip Stock@ 10,730’ 4 2,628’– 2,707’ Patch 10/13/09: 3.75” GR tagged up at 10,149’. CASING DETAIL Size WT Grade Conn ID Top Btm 20” 94 H-40 19.124 Surface 673’ 13-3/8” 61 J-55 Seal Lock 12.51 Surface 3,306’ 9-5/8”40 &47 N-80 &P-110 BTC 8.755 Surface 10,239’ 7” 29 N-80 X-Line 6.184 10,082 11,969’ Note: Top of window in 7” @ 10,742’ TUBING DETAIL 4-1/2” 12.6 L-80 BT & C AB 3.95 Surface 10,149’ 2-7/8” SL 6.4 L-80 STL 2.441 10,050 11,497’ JEWELRY DETAIL NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50’ 40' - - CIW, 11” x 4”, 5M, DCB Single Tubing Hanger 2 41.75’ 42' 3.95 4.5 4-1/2” Buttress Tubing AB Modified 3 302’ 302' 3.813 5.33 Camco TRDP-4A SSSV (3.813 I.D.), 4 2,241’ 2,219' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 4,125’ 3,756' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5,767’ 5,001' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 6,896’ 5,868' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 7,746’ 6,543' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,482’ 7,118' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,997’ 7,519' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,477’ 7,902' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,996’ 8,317' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5 10,015’ 8,333' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt 10,051’ 8,361' 4 5.25 Baker Seal Locator f/ PBR 10,052’ 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 10,072’ 8,378' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt + 2 pups 6 10,111’ 8,409' 4 Baker SALB-3 Packer w/ Top Latch & MOE 7 10,132’ 8,426' 3.813 Otis X-Nipple with 3.813” Polish Bore 8 10,149’ 8,439' 2.992 6.03 Wire Line Re-entry Guide 9 10,051’ 8,361' 2.372 3.75 Liner scoop Head with 4-1/2” Nom GS Profile 10 10,056’ 8,365' 2.441 2.875 45 Joints 2-7/8” 6.4# Liner with STL connection. 16 @ 3/8” HPF perforated liner 11 11,488’ 8,953' 1.6 2.875 Packoff Sub. 12 11,496’ 8,952' 0 2.875 Tapered Bullet nose guide shoe 7 8 9 10 11 12 PERFORATION DETAIL Zon e Top(MD) Btm(MD) Top(TVD) Btm(TVD) Am t sp f Status Date G-2 10,668' 10,688' 8,852' 8,868' 20' Open 11/16/2015 G-3 10,693' 10,709' 8,872' 8,884' 16' Open 11/16/2015 G-3 10,740' 10,765' 8,909' 8,928' 25' Open 3/23/1997 G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/ Cement 3/23/1997 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/ Cement 3/23/1997 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/ Cement 3/23/1997 B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/ Cement 3/23/1997 B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/ Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/ Cement 3/23/1997 4/3/12: Remove fish from 2.875 liner @ 10,696’ pull and reset patch Dolly Varden Platform Well: D-26RD Completed: 8/09/1998 Updated by: JLL 08/10/20 PROPOSED MAX HOLE ANGLE = 43.25q @ 3,800’ RKB = 40.5’ G-4 G-3 G-2 TOC @ 11,048’ CTM 10/22/93 3 5 6 1 2 X Aband Hemlock New: TD 11,500’Whip Stock@ 10,730’ 4 ±2,600’– ±2,720’ Patch 10/13/09: 3.75” GR tagged up at 10,149’. CASING DETAIL Size WT Grade Conn ID Top Btm 20” 94 H-40 19.124 Surface 673’ 13-3/8” 61 J-55 Seal Lock 12.51 Surface 3,306’ 9-5/8”40 &47 N-80 &P-110 BTC 8.755 Surface 10,239’ 7” 29 N-80 X-Line 6.184 10,082 11,969’ Note: Top of window in 7” @ 10,742’ TUBING DETAIL 4-1/2” 12.6 L-80 BT & C AB 3.95 Surface 10,149’ 2-7/8” SL 6.4 L-80 STL 2.441 10,050 11,497’ JEWELRY DETAIL NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50’ 40' - - CIW, 11” x 4”, 5M, DCB Single Tubing Hanger 2 41.75’ 42' 3.95 4.5 4-1/2” Buttress Tubing AB Modified 3 302’ 302' 3.813 5.33 Camco TRDP-4A SSSV (3.813 I.D.), 4 2,241’ 2,219' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 4,125’ 3,756' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5,767’ 5,001' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 6,896’ 5,868' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 7,746’ 6,543' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,482’ 7,118' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 8,997’ 7,519' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,477’ 7,902' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 9,996’ 8,317' 3.875 5.968 Daniels, 4-1/2” 2A GLM , 1-1/2”, RK 5 10,015’ 8,333' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt 10,051’ 8,361' 4 5.25 Baker Seal Locator f/ PBR 10,052’ 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 10,072’ 8,378' 3.95 4.5 4-1/2” Buttress Tubing AB Modified, 1- Jnt + 2 pups 6 10,111’ 8,409' 4 Baker SALB-3 Packer w/ Top Latch & MOE 7 10,132’ 8,426' 3.813 Otis X-Nipple with 3.813” Polish Bore 8 10,149’ 8,439' 2.992 6.03 Wire Line Re-entry Guide 9 10,051’ 8,361' 2.372 3.75 Liner scoop Head with 4-1/2” Nom GS Profile 10 10,056’ 8,365' 2.441 2.875 45 Joints 2-7/8” 6.4# Liner with STL connection. 16 @ 3/8” HPF perforated liner 11 11,488’ 8,953' 1.6 2.875 Packoff Sub. 12 11,496’ 8,952' 0 2.875 Tapered Bullet nose guide shoe 7 8 9 10 11 12 PERFORATION DETAIL Zon e Top(MD) Btm(MD) Top(TVD) Btm(TVD) Am t sp f Status Date G-2 10,668' 10,688' 8,852' 8,868' 20' Open 11/16/2015 G-3 10,693' 10,709' 8,872' 8,884' 16' Open 11/16/2015 G-3 10,740' 10,765' 8,909' 8,928' 25' Open 3/23/1997 G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/ Cement 3/23/1997 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/ Cement 3/23/1997 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/ Cement 3/23/1997 B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/ Cement 3/23/1997 B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/ Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/ Cement 3/23/1997 4/3/12: Remove fish from 2.875 liner @ 10,696’ POF 77,,, • ce,1 t//j; THE STATE Alaska Oil and Gas F�►,►-s�� of® Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r Main: 907.279.1433 OF ALAS1 Fax: 907.276.7542 www.aogcc.alaska.gov December 8, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification scow AUG 1 4 2016 Trading Bay Unit D-26RD PTD 1981290 Dear Mr. Golis: On December 5, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-26RD located on the Dolly Varden Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit D-26RD prior to the test. The well performance was monitored for approximately four hours with alternating shut in and open flow periods. The resulting gas flow rate at the end of each flow monitoring period was below the regulatory limit; no liquids were produced during the test. The passing no-flow test means TBU D-26RD may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-26RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM ION - REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubinill Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casindil Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Cl Re-enter Susp Wel❑ Other: Remove/Reinstall Patch 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 Exploratory ❑ 198-129 a 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20260-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 ' Trading Bay Unit D-26RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): , 3 7 Z N/A McArthur River Field/Middle Kenai G Oil Pool 11. Present Well Condition Summary: AO3e Total Depth measured 11,500 a feet Plugs measured N/A feet �1r�'VV true vertical 8,950 ' feet Junk measured N/A feet Effective Depth measured 11,496 feet Packer measured 10,111 feet true vertical 8,952 feet true vertical 8,409 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 673' 20" 673' 673' 1,530 psi 520 psi Surface 3,306' 13-3/8" 3,306' 3,150' 3,090 psi 1,540 psi Intermediate Production 10,239' 9-5/8" 10,239' 8,511' 5,750 psi 3,090 psi Liner 1,887' 7" 11,969' 8,912' 8,160 psi 7,020 psi Perforation depth Measured depth 10,688-10,860 feet True Vertical depth 8,852-8,987 feet 4-1/2" 12.6#/L-80 10,149'(MD) 8,439'(TVD) Tubing(size,grade,measured and true vertical depth) 2-7/8"SL 6.4#/L-80 11,497'(MD) 8,952'(TVD) Packers and SSSV(type,measured and true vertical depth) SALB-3 Pkr 10,111'(MD)8,409'(TVD) TRDP-4A SSSV 302'(MD)302'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/ASC FEB 0 9 2016 Treatment descriptions including volumes used and final pressure: �a ��Q N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 58 57 415 972 228 Subsequent to operation: 58 58 331 646 166 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development El n Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data Cl GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ u SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-668 Contact Dan Marlowe(907)283-1329 Email dmarloweahilcorp.com Printed Name Stan W.Golis' Title Operations Manager Signature '"T 1"4......w1 6 0--(. _ Phone (907)777-8356 Date . . Form 10-404 Revised 5/2015 j. (2,..44.___ RBDMSVEC 1 1 2015 Submit Original Only Dolly Varden Platform SCHEMATIC Well: D-26RD _ H Ililcorp Alaska,LLC Completed: 8/09/1998 CASING DETAIL RKB = 40.5' Size WT Grade Conn ID Top Btm 1 20" 94 H-40 19.124 Surface 673' 2 13-3/8" 61 1-55 Seal Lock 12.51 Surface 3,306' 9-5/8" 40 N &47 &p gOp BTC 8.755 Surface 10,239' 7" 29 N-80 X-Line 6.184 10,082 11,969' Note:Top of window in 7"@ 10,742' BTC TUBING DETAIL 4-1/2" 12.6 L-80 BT&CAB 3.95 Surface 10,149' 2-7/8"SL 6.4 L-80 STL 2.441 10,050 11,497' JEWELRY DETAIL I NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50' 40' - - CIW,11"x 4",5M,DCB Single Tubing Hanger 2 41.75' 42' 3.95 4.5 4-1/2"Buttress Tubing AB Modified 2,628'-2,707' 3 302' 302' 3.813 5.33 Camco TRDP-4A SSSV(3.8131.0.), Patch 2,241' 2,219' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4,125' 3,756' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 5,767' 5,001' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 6,896' _ 5,868' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 7,746' 6,543' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 8,482' 7,118' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 8,997' 7,519' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK al 9,477' 7,902' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,996' 8,317' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 10,015' 8,333' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt 5 10,051' 8,361' 4 5.25 Baker Seal Locator f/PBR 10,052' 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 111 10,072' 8,378' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt+2 pups 6 10,111' 8,409' 4 Baker SALB-3 Packer w/Top Latch&MOE 7 10,132' 8,426' 3.813 Otis X-Nipple with 3.813"Polish Bore 8 10,149' 8,439' 10,051' 8,361' 2.992 6.03 Wire Line Re-entry Guide 9 2.372 3.75 Liner scoop Head with 4-1/2"Nom GS Profile 10 10,056' 8,365' 2.441 2.875 45 Joints 2-7/8"6.4#Liner with STL connection. 16 @ 53/8"HPF perforated liner 11 11,488' 8,953' 1.6 2.875 Packoff Sub. . 12 11,496' 8,952' 0 2.875 Tapered Bullet nose guide shoe 6 PERFORATION DETAIL !' I• Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Status Date 10/13/09' G-2 10,668' 10,688' 8,852' 8,868' 20' Open 11/16/2015 3.75"GR L , G-3 10,693' 10,709' 8,872' 8,884' 16' Open 11/16/2015 tagged up at G-3 10,740' 10,765' 8,909' 8,928' 25' Open 3/23/1997 10,149'. G-4 10,786' 10,860' 8,943' 8,98T 74' 12 Open 3/23/1997 ------_, X 7 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/Cement 3/23/1997 4/3/12: 8 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/Cement 3/23/1997 Remove fish 9 / G-2 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/Cement 3/23/1997 B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/Cement 3/23/1997 from 2.875 liner B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/Cement 3/23/1997 @ 10,696' G-3 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/Cement 3/23/1997 -4 Whip ' I I Stock@j Aband I I I I I I I I I I I I I I I I New: TD 11,500' 10,730' ` Hemlock 10 11 12 MAX HOLE ANGLE=43.25°@ 3,800' TOC @ ,iptv .*` 11,048' fit: ., CTM 10/22/93 -4 Updated by:JLL 12/03/15 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-26RD E-Line 50-733-20260-01 198-129 11/15/15 11/17/15 Daily Operations: 11/15/2015-Sunday PICK UP TOOLS,TRAVEL TO LOCATION. COMPLETE -JSA- PERMIT-SAFETY MEETING. RIG UP SLICKLINE - PRESSURE TEST TO 1500PSI -GOOD. RIH W/2" GAUGE RING TO 10,703'KB- POOH. RIH WI 2" DD BAILER TO 10,703'KB-WORK TO 10,708'KB- POOH OOH WI EMPTY. RIH WI SAME TO 10,740'KB. WORK TOOLS. FALL TO 10,780'KB-COULD NOT PASS. MAKE SEVRAL PASSES FROM 10,700'KB TO 10,780'KB. WILL NOT PASS 10,780'KB FROM WHAT LOOKS LIKE DEVIATION. POOH. OOH WI 1/2 CUP SAND. RIH WI 20' X 2 1/8 SPENT DUMMY GUNS TO 10,730'KB, TAG. WORK SPANGS TO GET FREE. TAG 3 TIMES. CAN'T PASS. POOH. DISCUSS WI CO. REP. RIH WI 3.75" G. RING TO 2,644'KB, TAG. POOH. RIH WI 4 1/2 GS TO SAME. LATCH AND PULL. POOH OOH W/A STOP. RIG OFF. 11/16/2015 - Monday JSA& work permit. Rig up unit, lub &guns. Arm gun. Pick gun 1 and pressure test lub to 1500 psi. RIH with 16' of 2 1/8" strip gun. Perf depth 10,693' to 10,709', 9' from CCL to top shot (CCL depth 10,684'). Ran correlation pass (perfl pass5). Sent log in. Log into position, perforate (gun did not fire). POOH. Checked out gun and tool string. Line was shorted out. Cut 1,200' off unit. Line checked good. Rigged up grease head and reheaded. Pick gun 1 connect to wellhead. RIH with 16' of 2 1/8" strip gun. Perf depth 10,693' to 10,709' -9'from CCL to top shot (CCL depth 10,684'). Ran correlation pass (perfl pass8). Sent log in. Log into position fire gun (perfl pass9). POOH. No changes in tubing pressure.Arm up gun 2 - RIH with 20' of 2 1/8" strip gun. Perf depth 10,668' to 10,688' -9' from CCL to top shot (CCL depth 10,659'). Ran (1 correlation pass (perf2 pass2). Sent log in. Log into position fire gun (perf2 pass3). POOH. No changes in tubing pressure. Rigged down and cleaned up waiting on flight. 11/17/2015-Tuesday MORNING SAFETY MEETING, JSA. STAND BY FOR PRODUCTION CREW CHANGE OUT. MOVE OUT ELINE. MOVE IN SLICKLINE. RIG UP. PRESSURE TEST LUB AND WLV TO 1500PSI -GOOD. RIH W/3" B/L BRUSH TO 2,644' KB. BRUSH PACKOFF RECEPTICLE. POOH. RIH W/4 1/2 GS W/ 10.85' SPACER (STINGER HAS 3.1" PACKING)TO 2,636'KB (TOP)SET SPACER. POOH. RIH WI SAME W/ DD PACKOFF W/SPACER AND STINGER ( 8.4') TO 2,628'KB (TOP) SET. POOH. RIH WI SAME W/A-STOP TO 2,628'KB(TOP) SET. POOH. RIH WI SAME W/ DD PACKOFF WI SPACER AND STINGER ( 8.4')TO 2,628'KB (TOP) SET. POOH. RIH WI SAME WI A-STOP TO 2,628'KB(TOP) SET. POOH. RIG DOWN.TURN OVER TO PRODUCTION. • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg , kZI 11L DATE: 12/5/15 P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test - Petroleum Inspector TBU D-26RD ' Hilcorp Alaska LLC - PTD 1981290 12/5/15: On arrival to the Trading Bay Unit Dolly Varden platform I met with Hilcorp's lead operator Jon Loomis. We went over how I would like to do the no-flow. He told me that this was a gas lifted well and that they had been bleeding it for over 24 hours. We then went down to the well room and looked over how he had the well rigged up. Everything looked good except they didn't have a pressure gauge on the IA. I ask if they could please install one and they did it right away. I then started my No-Flow test and it went as follows. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:20 0/0/146 0 0 Shut well in. - 11:00 6/0/146 - 0 0 S/I 11:30 10/0/146 4 • 0 Opened, bled to 0 in 15 sec, S/I 12:00 5/0/146 0 0 S/I 12:30 9/0/146 0 0 S/I 13:00 15/0/146 - 0 0 S/I 13:30 21/0/146 0 - 0 S/I • 14:00 26/0/146 - 6 0 - Opened, Bled to 0 psi in 1 min. 1 Pressures are T/IA/OA Summary: Trading Bay Unit D-26RD met the criteria for a no flow determination. Attachments: none SCANNED SEP 1 5 2016 2015-1205_No-Flow_TBUD-26RD_bn.docx Page 1 of 1 • t',‘"\ F r�� • I//7„ THE STATE Alaska Oil and Gas ��— ofA LAsKA Conservafi®n Commission - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA,tiLAsY'P Fax: 907.276.7542 www.aogcc.alaska.gov Dan Marlowe SC-04E Operations Engineer I� Hilcorp Alaska, LLC " J 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU D-26RD Sundry Number: 315-668 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, "" Cathy P oerster 01€- Chair DATED this 4ay of October, 2015 Encl. ReNtinI T z9as • RECEIVED • STATE OF ALASKA OCT i 201 OA L ALASKA OIL AND GAS CONSERVATION COMMISSION S ,I l$ APPLICATION FOR SUNDRY APPROVALS11 2O AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate 0 . Other Stimulate [I Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well [i Re-enter Susp Well ❑ Other.Remove/Reinstall Patch I]i 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development El • 198-129' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20260-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A/ Will planned perforations require a spacing exception? Yes ❑ No CI / Trading Bay Unit D-26RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 . McArthur River Field/Middle Kenai G Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,500 8,950 11,496 8,952 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 673' 20" 673' 673' 1,530 psi 520 psi Surface 3,306' 13-3/8" 3,306' 3,150' 3,090 psi 1,540 psi Intermediate Production 10,239' 9-5/8" 10,239' 8,511' 5,750 psi 3,090 psi Liner 1,887' 7" 11,969' 8,912' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,668-10,860 8,852-8,987 4-1/2"&2-7/8"SL 12.6#L-80&6.4#L-80 10,149&11,497 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SALB-3 Pkr&TRDP-4A SSSV • 10,111'(MD)8,409'(ND)&302'(MD)302'(ND) 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/10/2015 OIL CI . WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowefthilcorp.com Printed Name Dan Marlowe Title Operations Engineer Ste Signatµr� ,moi ��- Phone (907)283-1329 Date 10 /2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316- (4_ce_ Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS1(9CT 2 9 2015 Spacing Exception Required? Yes 0 No IV' Subsequent Form Required: /0 "Yc) ( / , APPROVED BY _ Approved by: l`�` COMMISSIONER THE COMMISSION Date: i _ 20 . /5 / 43-�'-15 PKb #46- /1 !0/ 615 Form 10-4' Revised 5/2015 ®p I vif �C ti /S�faiifor 12 months from the date of approval.1 Submit nForm and Attachments in Duplicate • • Well Work Prognosis Well: D-26rd Haeorp,ua.ka.Lu: Date: 10/27/15 Well Name: Trading Bay Unit D-26rd API Number: 50-733-20260-01 Current Status: Gas-Lift Producer Leg: NE Corner(A-1) Estimated Start Date: 11/10/15 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 198-129 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell:985-867-0665 Current Bottom Hole Pressure: -2,188 psi @ 8,919' TVD 0.417 psi/ft Mid-Pert Maximum Expected BHP: -2,188 psi @ 8,919' TVD 0.417 psi/ft Mid-Pert Max.Allowable Surface Pressure: -1,200 psi gas-lift Brief Well Summary The D-26rd is a gas-lifted oil well completed in the G zone. This project will re-perf the G-2 & G-3 sands./ Procedure: 1. MIRU Slick-line, PT lubricator to 1,500 psi. 2. RIH with slick-line and pull the patch. 3. MIRU E-line, PT lubricator to 1,500 psi. 4. RU e-line guns and perforate per program. Record tubing pressures before and after each perforating run. 5. RD E-line 6. MIRU Slick-line, PT lubricator to 1,500 psi. 7. RIH with slick-line and reset the patch from ±2,636' to ±2,707'. 8. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Dolly Varden Platform . 14 SCHEMATIC Well: D-26RD llileorp Alaska,LLC Completed: 8/09/1998 CASING DETAIL RKB = 40.5' Size WT Grade Conn ID Top Btm I 1 20" 94 H-4019.124 Surface 673' 2 13-3/8" _ 61 40 J-55 Seal Lock 12.51 Surface 3,306' 9-5/8" &47 &P-8010 29 N-80 BTC 8.755 Surface 10,239' 7" X-Line 6.184 10,082 11,969' Note:Top of window in 7"@ 10,742' 3 TUBING DETAIL 4-1/2" 12.6 L-80 BT&C AB 3.95 Surface 10,149' 2-7/8"SL 6.4 L-80 STL 2.441 10,050 11,497' IJEWELRY DETAIL I1 I NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50' 40' - - CIW,11"x 4",5M,DCB Single Tubing Hanger 2 41.75' 42' 3.95 4.5 4-1/2"Buttress Tubing AB Modified 4 4/5/12:2,646'- 3 302' 302' 3.813 , 5.33 Camco TRDP-4A SSSV(3.813 I.D.), 2,707'Patch. 2,241' 2,219' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4,125' 3,756' 3.875 5.968 Daniels,4-1/2"2A GLM,1 1/2",RK 5,767' 5,001' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK �� I 6,896' 5,868' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 7,746' 6,543' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 8,482' 7,118' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 8,997' _ 7,519' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK g 9,477' 7,902' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 101 9,996' 8,317' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 10,015' 8,333' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-int 5 10,051' 8,361' 4 5.25 Baker Seal Locator f/PBR 10,052' 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 10,072' 8,378' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-int+2 pups 6 10,111' 8,409' 4 Baker SALE-3 Packer w/Top Latch&MOE 7 10,132' 8,426' 3.813 Otis X-Nipple with 3.813"Polish Bore 8 10,149' 8,439' 2.992 6.03 Wire Line Re-entry Guide 9 10,051' 8,361' 2.372 3.75 Liner scoop Head with 4-1/2"Nom GS Profile 10 10,056' 8,365' 2.441 2.875 45 Joints 2-7/8"6.4#Liner with STL connection. 16 @ 53/8"HPF perforated liner 41, / 11 11,488' 8,953' 1.6 2.875 Packoff Sub. . 12 11,496' 8,952' 0 2.875 Tapered Bullet nose guide shoe PERFORATION DETAIL 0 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Spf Status Date II ii 10/13/09: 1 : G-2 10,668' 10,688' 8,852' 8,868' 20' 12 Open 3/23/1997 3.75"GR , G-3 10,693' 10,709' 8,872' 8,884' 16' 12 Open 3/23/1997 tagged up at G-3 10,740' 10,765' 8,909' 8,928' 25' 12 Open 3/23/1997 10,149'. G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 1. X 7 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/Cement 3/23/1997 8 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/Cement 3/23/1997 4/3/12: 9 G 2 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/Cement 3/23/1997_ Remove fish B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/Cement 3/23/1997 from 2.875 liner @ 10,696' I G-3 B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/Cement 3/23/1997 -4 Whip - 1I Stock@ I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 New: TD 11,500' 10,730' Aband _ 10 11 12 Hemlock _ MAX HOLE ANGLE=43.25°@ 3,800' TOC @ 11,048' . Cq CTM 10/22/93 L Revised By:TDF 11/12/2012 1110 Dolly Varden Platform . iii PROPOSED Well: D-26RD Flilcora Alaska,LLC Completed: 8/09/1998 CASING DETAIL RKB = 40.5' Size WT Grade Conn ID Top Btm W 1 20" 94 H-40 19.124 Surface 673' 2 13-3/8" 61 J-55 Seal Lock 12.51 Surface 3,306' N- 9-5/8" &47 &P-8010 BTC 8.755 Surface 10,239' • 7" 29 N-80 X-Line 6.184 10,082 11,969' Note:Top of window in 7"@ 10,742' 3 TUBING DETAIL 4-1/2" 12.6 L-80 BT&CAB 3.95 Surface 10,149' 2-7/8"SL 6.4 L-80 STL 2.441 10,050 11,497' t ^' r JEWELRY DETAIL / 1 NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50' 40' - - CIW,11"x 4",5M,DCB Single Tubing Hanger 2 41.75' 42' 3.95 4.5 4-1/2"Buttress Tubing AB Modified ±2,636'-±2,707 3 302' 302' 3.813 5.33 Camco TRDP-4A SSSV(3.813 I.D.), Patch 2,241' 2,219' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4,125' 3,756' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 5,767' 5,001' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK lit,', 6,896' 5,868' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 7,746' 6,543' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 8,482' 7,118' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 8,997 7,519' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,477' 7,902' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,996' 8,317' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 10,015' 8,333' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt 5 10,051' 8,361' 4 5.25 Baker Seal Locator f/PBR 10,052' 8,362' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 11 10,072' 8,378' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-int+2 pups 6 10,111' 8,409' 4 Baker SALB-3 Packer w/Top Latch&MOE " 11' 7 10,132' 8,426' 3.813 Otis X-Nipple with 3.813"Polish Bore 8 10,149' 8,439' 2.992 6.03 Wire Line Re-entry Guide 9 10,051' 8,361' 2.372 3.75 Liner scoop Head with 4-1/2"Nom GS Profile II 10 10,056' 8,365' 2.441 2.875 45 Joints 2-7/8"6.4#Liner with STL connection. 16 @ 5 3/8"HPF perforated liner \ 11 11 11,488' 8,953' 1.6 2.875 Packoff Sub. 12 11,496' 8,952' 0 2.875 Tapered Bullet nose guide shoe 6 * PERFORATION DETAIL L Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt sPf Status Date G-2 ±10,668' ±10,688' ±8,852' ±8,868' ±20' Open/Re-perf Future 10/13/09: 3.75"GR / \ G-3 ±10,693' ±10,709' ±8,872' ±8,884' ±16' Open/Re-Perf Future tagged up at G-3 ±10,740' ±10,765' ±8,909' ±8,928' ±25' Open/Re-Perf Future 10,149'. G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 -------y X 7 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/Cement 3/23/1997 8 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/Cement 3/23/1997 4/3/12: 9 G-2 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/Cement 3/23/1997 Remove fish from 2.875 liner x B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/Cement 3/23/1997 @ 10,696' 4" G-332' B-5 11,642' 11,750' N/A N/A 12 Abn w/Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/Cement 3/23/1997 -4 Whip 1 1 I 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 1 _ Stock@ 11 1 1 I 1 1 1 1 1 1 1 1 I 1 1 New: TD 11,500' 10,730' Aband 10 11 12 Hemlock - ff .Yt MAX HOLE ANGLE=43.25°@ 3,800' TOC @ ,, .%:''* -""°s°,,, 11,048' „gip. cfr "'tom CTM 10/22/93 - .e G Updated by:JLL 10/23/15 • 0 • DECEIVED STATE OF ALASKA OCT 21 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION gAPPLICATION FOR SUNDRY APPROVALS pi 2Q AAC 25.28D 1.Type of Request: Abandor ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Sus pend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ • Re-enter Susp Well ❑ Other Remove/Reinstall Patch I]' 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 2 198-129 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic El Service II6.API Number: Anchorage,AK 99503 50-733-20260-01 ' 7. If perforating: 8.Well Name and I}itata,Yror: Clhat Regulation or Conservation Order governs well spacing in this pool? N/A \k�26 Will planned perforations require a spacing exception? Yes No ❑ / Trading a n -26RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 o McArthur River Field/Middle Kenai G Oil Pool`\ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): 0Ags(measured): Junk(measured): 11,500 , 8,950 11,496 B(k�c 'v/A N/A Casing Length Size MD , iVD Burst Collapse Structural Conductor 673' 20" 673' `, 673' 1,530 psi 520 psi Surface 3,306' 13-3/8" 3,306' • - 3,150' 3,090 psi 1,540 psi Intermediate Production 10,239' 9-5/8" 10,239'x, 8,5 ' 5,750 psi 3,090 psi Liner 1,887' 7" 11,969' : • 2' 8,160 psi 7,020 psi ak , Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: j - t_. Grade: Tubing MD(ft): 10,668-10,860 • 8,746-8,987 4-1/2"&2-7/8" i..#L-80&6.4#L-80 10,149&11,497 Packers and SSSV Type: acker a SSW AD(ft)and TVD(ft): SALB-3 Pkr&TRDP-4A SSSV 10,111' D)8,409'(TVD)&302'(MD)302'(TVD) 12.Attachments: Description Summary of Proposal3.Well ss after proposed work: Detailed Operations Program E.] BOP Sketch CI kN.- s- •pl.ra ry ❑ Stratigraphic❑ Development LI ' Service ❑ 14.Estimated Date for • S tus after proposed work: Commencing Operations: 11/4/2015 0 0 ' WINJ ❑ WDSPL ❑ VVV Suspended ❑ 16.Verbal Approval: Date: A eAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: I GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe anhilcorp.com Printed Name �j Dan Marlowe J Title Operations Engineer Signature '�/ •�Z� •- r' Phone (907)283-1329 Date 10/21/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3f5 -4.43 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCgg°a 2Q15 RBDMS Spacing Exception Required? Yes CI No 1 Subsequent Form Required: 10 `L f C t ,OCT 2 9 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (266 4,G4 '---! slid SubForm ane Form 10-403 Revised 5/2015 OrG4i for 12 months from the date of approval. Attachmentss in Duplicate • • 11 Well Work Prognosis Well: D-26rd Hilrnrp:11a.ka.LLC Date: 10/21/15 Well Name: Trading Bay Unit D-26rd API Number: 50-733-20260-01 Current Status: Gas-Lift Producer Leg: NE Corner(A-1) Estimated Start Date: 11/04/15 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 198-129 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell:907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current Bottom Hole Pressure: -2,188 psi @ 8,919' TVD 0.417 psi/ft Mid-Pert Maximum Expected BHP: -2,188 psi @ 8,919'TVD 0.417 psi/ft Mid-Perf Max.Allowable Surface Pressure: -1,200 psi gas-lift Brief Well Summary The D-26rd was last worked over in 1998. It currently has a tubing patch spanning a leak between 2,646'-2,707'. A gas-lift survey ran 10/13/15 shows it to be leaking right above the patch at^'2,640'.This procedure will pull the top A-stop and add an additional ±10' spacer to the patch and reset the pack-off. / Procedure: 1. MIRU Slick-line, PT lubricator to 1,500 psi. 2. RIH with slick-line and pull the A-stop at 2,646'. 3. RIH with ±10' Spacer. 4. RIH with A-stop. 5. RD slick-line Attachments: 1. Current Well Schematic 2. Proposed Well Schematic Dolly Varden Platform • Ii SCHEMATIC Well: D-26RD Hilcorp Alaska,LLC Completed: 8/09/1998 CASING DETAIL RKB = 40.5' Size WT Grade Conn ID Top Btm - 1 20" 94 H-40 19.124 Surface 673' 2 13-3/8" 61 1-55 Seal Lock 12.51 Surface 3,306' 9-5/8" 8447 &P-8010 BTC 8.755 Surface 10,239' 7" 29 N-80 X-Line 6.184 10,082 11,969' Note:Top of window in 7"@ 10,742' 3 TUBING DETAIL 4-1/2" 12.6 L-80 BT&C AB 3.95 Surface 10,149' 2-7/8"SL 6.4 L-80 STL 2.441 10,050 11,497' JEWELRY DETAIL /1 1 NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50' - - CIW,11"x 4",5M,DCB Single Tubing Hanger S 11 2 41.75' 3.95 4.5 4-1/2"Buttress Tubing AB Modified 4/5/12:2,646'- 3 302' 3.813 5.33 Camco TRDP-4A SSSV(3.813 I.D.), 2,707'Patch. 2,241' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4,125' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 5,767' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 1k 6,896' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 7,7 ' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 8,482' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 8,997' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,477' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,996' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK ''.s, 10,01546' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt 5 10,051' 4 5.25 Baker Seal Locator f/PBR 10,052' 4.75 8.265 Baker PBR W/Scoop #683-19 4715 10,072' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-int+2 pups 6 10,111' 4 Baker SALB-3 Packer w/Top Latch&MOE 7 10,132' 3.813 Otis X-Nipple with 3.813"Polish Bore 8 10,149' 2.992 6.03 Wire Line Re-entry Guide 9 10,051' 2.372 3.75 Liner scoop Head with 4-1/2"Nom GS Profile 10 10,056' 2.441 2.875 45 Joints 2-7/8"6.4#Liner with STL connection. 16 @ 5 3/8"HPF perforated liner 11 11,488' 1.6 2.875 Packoff Sub. � 12 11,496' 0 2.875 Tapered Bullet nose guide shoe 6 0 ,! PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Status Date • 10/13/09: ' •• G-2 10,668' 10,688' 8,746' 8,762' 20' 12 Open 3/23/1997 3.75"GR Q , \ G-3 10,693' 10,709' 8,872' 8,884' 16' 12 Open 3/23/1997 tagged up at G-3 10,740' 10,765' 8,909' 8,928' 25' 12 Open 3/23/1997 10,149'. G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 -may \ 7 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/Cement 3/23/1997 8 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/Cement 3/23/1997 4/3/12: 9 G 2 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/Cement 3/23/1997 Remove fish B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/Cement 3/23/1997 from 2.865 liner B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/Cement 3/23/1997 @ 10,696' G 3 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/Cement 3/23/1997 -4 Whip 1 Stock@ 1 1 _L 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 New: TD 11,500' 10,730' Aband 10 11 12 Hemlock TOC @ CSS MAX HOLE ANGLE=43.25° @ 3,800' •p"", 11048' - ? ,P, CTM 10/22/93 "' .. r L Revised By:TDF 11/12/2012 , 14 H . * Dolly Varden Platform PROPOSED Well: D-26RD Hilcorp Alaska,LLC Completed: 8/09/1998 CASING DETAIL RKB = 40.5' Size WT Grade Conn ID Top Btm - 1 20" 94 H-40 19.124 Surface 673' 2 13 3/8" 61 J 55 Seal Lock 12.51 Surface 3,306' N- 9-5/8" &47 &P-8010 BTC 8.755 Surface 10,239' 7" 29 N-80 X-Line 6.184 10,082 11,969' Note:Top of window in 7"@ 10,742' 1 3 TUBING DETAIL 4-1/2" 12.6 L-80 BT&CAB 3.95 Surface 10,149' 2-7/8"SL 6.4 L-80 STL 2.441 10,050 11,497' L. JEWELRY DETAIL NO. Depth(MD) Depth(TVD) ID OD Item 1 40.50' - CIW,11"x 4",5M,DCB Single Tubing Hanger L 2 41.75' 3.95 4.5 4-1/2"Buttress Tubing AB Modified ±2,636'-±2,7073 302' 3.813 5.33 Camco TRDP-4A SSSV(3.813 I.D.), Patch 2,241' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4,125' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 5,767' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK I ' 6,896' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 7,746' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 8,482' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 4 8,997' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,477' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 9,996' 3.875 5.968 Daniels,4-1/2"2A GLM,1-1/2",RK 10,015' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt 5 10,051' 4 5.25 Baker Seal Locator f/PBR 10,052' 4.75 8.265 Baker PBR W/Scoop #683-19-4715 10,072' 3.95 4.5 4-1/2"Buttress Tubing AB Modified,1-Jnt+2 pups 6 10,111' 4 Baker SALB-3 Packer w/Top Latch&MOE 7 10,132' 3.813 Otis X-Nipple with 3.813"Polish Bore 8 10,149' 2.992 6.03 Wire Line Re-entry Guide L_ 9 10,051' 2.372 3.75 Liner scoop Head with 4-1/2"Nom GS Profile 45 Joints 2-7/8"6.4#Liner with STL connection. 16 @ 5 10 10,056' 2.441 2.875 3/8"HPF perforated liner k \ 11 11,488' 1.6 2.875 Packoff Sub. 12 11,496' 0 2.875 Tapered Bullet nose guide shoe I 6 PERFORATION DETAIL L I Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Status Date 10/13/09: I • G-2 10,668' 10,688' 8,746' 8,762' 20' 12 Open 3/23/1997 3.75"GR L \ G-3 10,693' 10,709' 8,872' 8,884' 16' 12 Open 3/23/1997 tagged up at G-3 10,740' 10,765' 8,909' 8,928' 25' 12 Open 3/23/1997 10,149'. G-4 10,786' 10,860' 8,943' 8,987' 74' 12 Open 3/23/1997 • 7 B-1 11,210' 11,273' N/A N/A 63' 12 Abn w/Cement 3/23/1997 4/3/12: 8 B-2 11,273' 11,306' N/A N/A 33' 12 Abn w/Cement 3/23/1997 Remove fish 9 G-2 B-3 11,390' 11,435' N/A N/A 45' 12 Abn w/Cement 3/23/1997 from 2.875 liner > B-4 11,468' 11,615' N/A N/A 147' 12 Abn w/Cement 3/23/1997 @ 10,696' , G-3 B-5 11,642' 11,750' N/A N/A 108' 12 Abn w/Cement 3/23/1997 B-6 11,826' 11,858' N/A N/A 32' 12 Abn w/Cement 3/23/1997 -4 Whip _ I I i i i i I I I i i i i I I I i i Stock@ Aband 1 I I i i i i i I I I I 1 1 1 1 1 New: TD 11,500' 10,730' Hemlock - 10 11 12 TOC @ CSS 3.. MAX HOLE ANGLE=43.25° @ 3,800' 11,048' z { 4 P- CTM 10/22/93 f+ L Updated by:JLL 10/21/15 • • Carlisle, Samantha J (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, October 28, 2015 3:25 PM To: Carlisle, Samantha.) (DOA) Cc: Juanita Lovett Subject: D-26rd Sundry 315-663 Samantha Per our earlier conversation please withdraw Sundry 315-663 for the Dolly D-26rd. Thank you Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe@hilcorp.com Hilcorp A Company Built on Energy 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. d-/~_ I ~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: LJ~ , ~7/ ~/~ Grayscale, halftones, pictures, graphs, charts - Pages: ? Poor Quality Original - Pages: Other- Pages: DIGITAL DATA r~ Diskettes, No. [3 Other, No/Type OVERSIZED [3 Logs of various kinds [3 Other Complete COMMENTS: Scanned by: Beveriy Mildred Daretha ~ Lowell TO RE-SCAN Notes: Re-Scanned by: Beveffy Mildred Daretha~wei[ Date: ,~/~, 7 Is/ ~ Well Compliance Report File on Left side of folder _ 198-129-0 MD 11500 .. Microfilm Roll TRADING BAY UNIT TVD 08950 Completion Date: / - Roll 2 / D-26RD 50- 733-20260-01 UNION OIL CO OF CALIFO D3. TT ^ 8/10/98 Completed Status: 1-OIL Current: Name R SRVY LSTNG Interval BHI 0-11500. Sent Received T/C/D OH 10/23/98 11/13/98 Daily Well Ops Was the well cored? yes no Are Dry Ditch Samples Required? yes no And Received? yes no Analysis Description Received? yes no Sample Set # Comments: Tuesday, August 01, 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner · Blair Wondzell, P. I. Supervisor FROM: John Crisp,~°' ~ O. SUBJECT: Petroleum I n~i~lz~ector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON-CONFIDENTIAL SVS Dolly Plt. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv. / Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 18006501 110 80 100 P P 43 OIL D-07RD2 1921550 110~ 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS :D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OILi i~26RD ' 1981290 110 80 751 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80: 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% ID 90 Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jcl TONY KNOWLE$, GOVERNOR ALAS ~ OIL AND GAS CONSERVATION COMMISSION June 15,1999 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chris Meyers~Dwight Johnson Field Superintendents UNOCAL 260 Caviar Street Kenai, Alaska 99611 Re: No-Flow Verific ation/.~~.-~, MRF Well D-26RD ~/.~~ Gentleman: On June 7, 1999 our Inspector, Louis R. Grimaldi, witnessed a "no-flow" test on UNOCAL's McArthur River Field well TBU D-26RD. When the inspector arrived, the well had been shut-in and was showing 2 psi on a 30 psi gauge. He observed the well shut-in for three hours - the pressure built to 3 psig. The pressure bled down rapidly; it had only the slightest gas flow. The inspector recommends the well be granted "no-flow" status. McArthur River Field well TBU D-26RD (PTD 98-129) meets the criteria of a "no-flow" performance test and as such is considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A) it is not required to have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wond2e~ PI Supervisor cc: Lou Grimaldi Bill Smith - Dolly Varden bew/nf-tbu-d26rd.doc Production TBU well D-26rd Subject: Production TBU well D-26rd Date: Thu, 03 Jun 1999 09:13:09-0800 From: B lair Wondzell <B lair_Wondzell@admin, state.ak.us> Organization: SOA-AOGCC To: Larry Greenstein <greensteinlp~unocal.com>, Stephen E Mcmains <steve mcmains~admin.state.ak.us> Larry, As we discussed, All of the production from TBU well D-26RD since the redrill in August 1998 should be charged to the new well, API 50-733-20260-01, PTD 98-129. Steve advises that revised production sheet showing this change from August 1998 are not necessary; he will change our records to show the procudtion to the RD API "01" number, please change yours. Please continue showing all production from this well to D-26RD. We'll use this E-mail to reclassify the original well, D-26 as Abandoned. Thanks, Blair 1 of 1 6/3/99 9:14 AM STATE OF ALASKA ALASKA AND GAS CONSERVATION o--, MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 98-129 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20260-01 4. Location of well at surface . .... .; ;::.il , --- ~:¢~~--%¢ 9. Unit or Lease Name 751'FSL, 1215'FWL, Sec. 6, T8N, R,3W, SM '.: ~./~'/~ :' ~~~ Trading Bay Unit At Top Producing Interval '/'¥~'~"*'"'"'i-¢'' ~ ~'~i" ! 10. Well Number 753' FNL, 64' FWL, SEC 5, 8N 13W, SM '; ~,,~, ~ ; !' D-26RD At Total Depth ~_ :i - · 11. Field and Pool 228' FNL, 457' FWL, SEC 5, 8N 13W, SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Middle Kenai "G" 106' KB above MSLI ADL 18729/17594 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 7/24/98 8/9/98I 8/10/98I 65 feet MSLI 1 11,500'/8951' 11,048'/ Yes: X No: 302 feet MD N/A 22. Type Electric or Other Logs Run No logs were run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2-7/8" 6.4 L-8 10,050' 11,497' 3-3/4" Pre-drilled liner/no cmt N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Meth°d °f Operati°n (Fl°wing' gas lift' otc')ORif~iNAL 8/10/98 IGas Lift , .... .- , :: .:~ .::: ::,~;-...~-.~? Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS:OIL::,.RATiO::; .~: - 8/24/98 24 TEST PERIOD => 206 63 521 19/64"I 305 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 125 1,022 24-HOUR RATE => 206 63 521 28.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Lateral is in the Tyonek G-4 sand-CRS grained sand to sandy gravel with 12-16% porosity and exhibiting.the presence of oil and gas. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. . 30. - _ ~- GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G-1 Top 10,611 -8,702' SS/8,808' TVD G-2 Top t0,665 -8,745' SS/8,851' TVD G-3 Top 10,731 -8,796' SS/8,902' TVD Go4 Top 10,792 -8,846' SS/8,952' TVD 31. LIST OF A'I-I'ACHMENTS Wellbore diagram, daily operations summary, survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Dan Williamso ,, 4 17 .~/J/, l~' Drilling Manager October 23, 1998 Signed ~r,,~.f,,}' ~t~'~,r~ ~'~ '~-title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ' ;,?=,, -- ~ ', '-, C '.;~ Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- 0 R I G I r~,~ AL jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL RKB = 40.5' 10 Whi ~10,730' TOC ~ ]1,048' CTM 10/22/93 SIZE WT Dolly Varden ~Vell No. 26 Completed 8/09/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 20" 13-3/8" 9-5/8" 7~ Tubing 4-1/2" ,~ ,,w/o,, ~ NO. 94 61 40,47 29 12.6 Depth H-40 J-55 Seal Lock N-80 &P- BTC 110 N-80 X-Line L-80 BT & C AB L-80 STL JEWELRY DETAIL ID OD Item __ 19.124 Surface 12.51 Surface 8.755 Surface 6.184 10,082 3.95 Surface "~ ~ ' 10,050 .~, .--r -v z 673' 3,306' 10,239' 11,969' 10,149' 40.50' 41.75' 302' 2,241' 4,125' 5,767' 6,896' 7 746' 8 482' 8 997' 9 477' 9 996' 10 015' 10 051' 10 052' 10 072' 10 111' 10 132' 10,149' 10,051' 19,056' 3.95 4.500 3.813 5.330 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3.875 5.968 3,95 4.500 4 5.25 4.75 8.265 3.95 4.5 4.0 3.813 2.992 6.030 2.372 3.75 2.441 2.875 11,488' 1.6 2.875 11,496' 0 2.875 CIW, 11" x 4", 5M, DCB Single Tubing Hanger 4-1/2" Buttress Tubing AB Modified Camco TRDP-4A SSSV (3.813 I.D.), Daniels, 4-1/2" 2A GLM 1-1/2", RK Daniels, 4-1/2" 2A GLM Daniels, 4-1/2" 2A GLM Daniels, 4-1/2" 2A GLM Daniels, 4-1/2" 2A GLM Daniels, 4-1/2" 2A GLM. Daniels, 4-1/2" 2A GLM. Daniels, 4-1/2" 2A GLM. Daniels, 4-1/2" 2A GLM. 1-1/2", RK 1-1/2", RK 1-1/2", RK 1-1/2", RK 1-1/2", RK 1-1/2", RK 1-1/2", RK 1-1/2", RK 4-1/2" Buttress Tubing AB Modified, 1- Jnt Baker Seal Locator f/PBR Baker PBR W/Scoop #683-19-4715 4-1/2" Buttress Tubing AB Modified, 1- Jnt + 2 pups Baker SALB-3 Packer w/Top Latch & MOE Otis X-Nipple with 3.813" Polish Bore Wire Line Re-entry Guide Liner scoop Head with 4-1/2" Nom GS Profile 45 Joints 2-7/8" 6.4# Predrilled Liner with STL connection. 3/8' ~ 16 HPF Packoff Sub. Tapered Bullet nose gxtide shoe PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Present Condition 3/23/97 G-2 10,668' 10,688' 20' 12.00 Open 3/23/97 G-3 10,693' 10,709' 16' 12.00 Open 3/23/97 G-3 10,740' 10,765' 25' 12.00 Open 3/23/97 G-4 10,786' 10,860' 74' 12.00 Open 3/23/97 B-1 11,210' 11,273' 63' 12.00 Aband w/Cement 3/23/97 B-2 11,273' 11,306' 33' 12.00 Aband w/Cement 3/23/97 B-3 11,390' 11,435' 45' 12.00 Aband w/Cement 3/23/97 B-4 11,468' 11,615' 147' 12.00 Aband w/Cement 3/23/97 B-5 11,642' 11,750' 108' 12.00 Aband w/Cement 3/23/97 B-6 11,826' 11,858' 32' 12.00 Aband w/Cement G-2 G-3 ;-4 iIIIl[llllllllllllllllllllllllllllllllllllllllllllllllllllillllI Coil TBG Sidetrack TD = 11,500' Old: PBTD = 11,905'; TD = 11,969' MAX HOLE ANGLE = 43.25° ~ 3,800' D-26RD 8-09-98.doc DRAWN BY: MWD UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 5/15/98 11 P6 28 3.0 19:00 22:00 11 P6 45 2.0 22:00 0:00 Move To & PJU on Well - SDFN Crew Sleep 5/16/98 11 P6 45 6.0 0:00 6:00 11 P6 28 2.8 6:00 8:45 11 P6 15A 0.8 8:45 9:30 11 P6 6C 1.3 9:30 10:45 11 P6 44A 6.0 10:45 16:45 11 P6 44A 4.8 16:45 21:30 11 P6 6F 1.8 21:30 23:15 11 P6 28 0.8 23:15 0:00 10,144 10,144 Crew Sleep R/u Dowell on Well Test BOP's 4000 Psi - OK P/u & M/u BHA #1 (see attatched) & PressFFst LUbricator/Riser 4000 Psi -- OK RIH & Pump from 2 to 2.5 Bpm - Mill Scale from 1800' to 1850'RKB/CTM - RIH & Circulate 2.5 Bpm w/Little or No Resistance & Tag @ 10,144' RKB/CTM Hard Milling w/no Progsress - Worked/dn to 10,146' Once & Stuck & Jarred Free w/32 K pull POOH Rig/Inj Head/off Well & Secure - Tapered Mill Had some MM Buttons Shucked (mostly @ 3.25" OD, but all the way to 3.795" Shoulder) - Bottom of Tapered Mill Hollowed/out from .61" ID to .99"1D for 1st 1/2" - Definitely has to be "Junk" Put Dowell to Bed & Order/out HES slickline. 5/17/98 11 P6 45 5.0 0:00 5:00 11 P6 35B 5.0 5:00 10:00 Dowell Crew Sleep & Wait/on HES HES Safety Meeting & Rig/up -"Long Rig/Up" (stuck 3" LIB in Lub XO w/press/tst - knock/out & switch to 2.825"). 11 P6 35B 2.0 10:00 12:00 11 P6 28 2.3 12:00 14:15 11 P6 44A 2.8 14:15 17:00 11 P6 44A 0.5 17:00 17:30 11 P6 5 1.0 17:30 18:30 11 P6 6F 2.0 18:30 20:30 11 P6 6C 1.5 20:30 22:00 10,179 10,148 10,920 10,500 RIH to 10179'RKB/SLM, Tag & POOH - LIB showed outer impressions (no inter junk marks) PJdn HES Rig/up Inj Hd, Cut 150' Pipe, Install Connector & Pull tst & P/u 3.795" Metal-Muncher "Dimple Mill" & PressFFst to 4000 Psi - OK RIH Pumping 1/2 Bpm & Tag @ 10146'RKB/CTM Mill to 10148'RKB/CTM & Drop Thru Tbg Tail - RIH & Tag Fill in 7" Csg ¢_.. 10920' - POH to 10500' Pump 25 Bbl Vis Sweep POOH - Smooth Entry into Tbg Tail Ly/dn "Dimple Mill"- Little Wear @ 3.2" OD - P/u UR Ass'bly (dressed for 6" upper & 5 3/4" Lower arms) - R/dn Inj Head SDFN 5/18/98 11 P6 45 4.5 0:00 4:30 11 P6 28 0.8 4:30 5:15 11 P6 6F 2.0 5:15 7:15 11 P6 44F 0.3 7:15 7:30 11 P6 44F 3.3 7:30 10:45 10,200 10,200 10,900 Crew Sleep Start Equipment & PressFFst 1500 Psi OK RIH w/UR Ass'bly w/Pump/off & Well S/in to 10,200' RKB/CTM. Smooth and no obructions. Open Well to Production - 1300 Psi CP - Well Unloading Fluid - Not Taking Much Gas - Bring Pump up & Catch Fluid ¢__. 1.2 BPM & Bring/up to 2.05 BPM & Activate UR's Arms (btm = 5.75" & top = 6") UR & Clean 7" Csg from 10300' to 10900' RKB/CTM (saw slight inc in press @ Mid Perfs 10692' to 10765') - Very Smooth - 5 ff./min thru perfs - P/u to 10200' & Made 2nd pass to 10900' - P/u to 10650'& RIH to 10775' (three passes over this D26RD Detailed Activity Summary.xls Page 1 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report blcArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 11 P6 5 0.5 10:45 11:15 10,900 11 P6 6D 1.3 11:15 12:30 10,160 11 P6 5 0.3 12:30 12:45 10,200 11 P6 6F 2.5 12:45 15:15 - 11 P6 28 1.0 15:15 16:15 - 11 L12 28 2.0 16:15 18:15 11 P6 45 4.8 18:15 23:00 interval) - RIH to 10900' Pump 25 Bbl Hi-Vis Sweep POOH @ 1:1 Ratio to Below Tbg Tail @ 10160' - S/dn Pumps & Allow Fluid to Drop From Coil f/15 min & then Pull/into Tbg Tail (smooth) & RIH to 10,200' Drop Ball & Circ to Shear Circ Sub @ 2,700 psi POOH & Pump 2.Bpm OOH - R/d Inj Hd& Unstab Pipe (Leave Riser & BOPE) Secure Well f/HES R/u HES S-Line w/Kinley Log Tools RIH w/Kinley Logging Tool Thru Tbg & Tag Fill @ 10,930'RKB/SLM - POOH & Log Caliper @ 60'/min to Tbg Tail @ 10236'RKB/WLM - Stuck - Spang Free & Pull/up to 10,145'(tbg tail) & Stuck, again - Spang Free - POOH - Ly/dn Kinley Tool & attempt retrieve data - Tool did not trip - Will Have to Make another run. 5/27/98 11 P6 28 0.5 15:00 15:30 11 P6 35A 2.5 15:30 18:00 11 P6 35A 6.0 18:00 0:00 4,166 PJu Dowell CTU Riser & BOPE's & Empty Pits- No PressFfst - Make Room for HES & SWS Oper & Send Dowell & PA& To Beach R/u HES/on Dowell Riser/Bope & XO to HES Lubricator - Held Safety Meeting w/Prod & Discuss H2S Contingency - Pressure Tst DowelI/HES Riser/Lubricator 2500 Psi -- OK RIH w/1 3/4 RS Tool, 8' of 1 7/8" Stem, Knuckle jt, Oil Jars, & Spangs & Locate, Latch & Pull Valve from GLM @ 2256' RKB/SLM - Repair Kick/over Tool - RIH & Locate, & Latch & Pull Valve from GLM @ 4166'RKB/SLM - POOH - Re-pin Kick/over Tool & Re-load Oil Jars - SDFN 5/28/98 11 P6 45 7.0 0:00 7:00 11 P6 35A 1.5 7:00 8:30 11 P6 35A 2.0 8:30 10:30 2,214 11 P6 35A 1.5 10:30 12:00 4,166 11 P6 35A 2.0 12:00 14:00 5,805 11 P6 35A 1.0 14:00 15:00 2,214 11 P6 35A 3.0 15:00 18:00 6,920 11 P6 35A 0.8 18:00 18:45 2,214 11 P6 35A 1.8 18:45 20:30 5,784 11 P6 35A 2.3 20:30 22:45 6,920 11 P6 35A 1.3 22:45 0:00 9,996 HES Crew Sleep Start Equipment & Wait/on Chopper Sweep f/Crane Op RIH w/#:2 VIv & St/dn @ #1 (2214') POOH RIH w/#1 VIv & Set @ 2214' - POOH, Re-pin & Chk Tool String RIH w/CY2 vIv & Set @ 4166' POOH RIH, Locate & Pull #3 VIv @ 5805', Latch & Pull Same - POOH RIH to Pull #4 VIv & St/dn @ #1 (2214') POOH w/#1 VIv RIH & Locate ~ vIv @ 6920', Latch & Pull Same - POOH - re-pin & chk tool string. RIH w/#1 vIv & Re-set @ 2214' - POOH RIH w/#3 VIv & Set @ 5784 - POOH, Re-pin & Check tool string RIH w/#4 VIv & Set @ 6920' - POOH, re-pin & Check tool stdng, Re-Pack Stuffing Box & Cut 50' of wire RIH to Pull #9 Valve @ 9996' -10041' Unable to Locate 5/29/98 11 P6 35A 6.0 0:00 6:00 10,042 Unable to Locate GLM #9 @ 10042' - P/u & Locate GLM #8 - Unable to Laatch - POOH & RIH w/4 1/2" OM-1 K/O Tool - St/dn @ GLM #1 @ 2214' - POOH w/GLM #1 Valve (will leave/out till others done) - RIH to GLM #9 @ 10042'- Locate, but Unable D26RD Detailed Activity Summary.xls Page 2 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 11 P6 35A 1.8 6:00 7:45 8,522 11 P6 35A 2.0 7:45 9:45 7,794 11 P6 35A 1.0 9:45 10:45 2,214 11 P6 35A 2.0 10:45 12:45 7,794 11 P6 35A 1.8 12:45 14:30 8,524 11 P6 35A 1.0 14:30 15:30 9,002 11 P6 35A 1.0 15:30 16:30 - 11 P6 35A 2.0 16:30 18:30 11,001 11 P6 35A 5.5 18:30 to St/dn - P/u to GLM #8 @ 9538' - Located, but Unable to Latch - P/u To GLM #7, Locate & Beat/dn for 15 min to Latch - POOH w/GLV #7 RIH & Locate GKM #6 @ 8522', Latch & Pull Valve - POOH RIH to GLM #5 & Locate @ 7794', Latch, & Pull Valve - POOH RIH & Re-set GL Vale #1 @ 2214' - POOH RIH & Set GL Valve #5 # 7794' -POOH RIH & Set GL Valve #6 @ 8524' - POOH RIH & Set GL Valve #7 @ 9002' - POOH Wait/on Prod Crane Op RIH w/3.72' Guage Ring to TD & POOH - Clean Trip - Didn't See GLM, Tbg Tail, etc. R/dn HES from Dowell Riser - Secure Well & Release to Prod @ 19:00 Hours 5/30/98 11 P6 28 4.5 9:00 13:30 11 P6 28 1.0 13:30 14:30 11 L6 28 3.5 14:30 18:00 11 P6 28 1.0 18:00 19:00 11 Pll 37 0.5 19:00 19:30 11 P6 28 1.5 19:30 21:00 11 P6 45 2.3 21:00 23:15 11 P6 45 0.8 23:15 0:00 Rig up Schlumberger. Shut off lift gas to well & allow tubing pressure to bleed down. Lay out lubricator. Troubleshoot E-line for short, rehead line. Make up tool stdng. Make up POS tool and shooting GR/CCL. Make up Baker #10 setting tool w/slow burn charge to whipstock. Trouble shoot SWS computer problem. Rewire cable head and collecter (crossed wires). Check tools. Repair short in "10 to 1" XO Check POS tool and take resistivity readings @ high side, 10, 20 & 30 degrees left and right of HS. Secure equipment as per explosives safety checklist Hold pre job safety meeting w/production. Make up setting tool & whipstock to tool string. Install RA tag on whipstock. Position tools in lubricator and install bottom cap on lubricator. Make up, hoist and stab lubricator. Pressure test lubricator to 1500 psi, OK. Bleed off & open to well. 125 psi TP. RIH slow w/whipstock and setting tool string. Smooth trip in. Make tie in pass from 10900 CCL to tubing tail. Correlating for tie in @ 24:00 hrs 5/31/98 11 P6 45 6.0 0:00 6:00 11 P6 45 0.5 6:00 6:30 11 P6 45 1.5 6:30 8:00 11 P6 45 2.0 8:00 10:00 11 P6 28 3.0 10:00 13:00 Correlate with difficulty to CET log dated 6 May 91. Pull multiple strips to get on depth. Depth of markers drifting 1-2' on most passes. Very little to tie into on bottom for last pass to set depth. On depth with top of whipstock @ 10736. Check tool face appeared to be Iow sided. Work string, check SWS calcs, good tool face indicated. Work to again get on depth. Set whipstock. On depth w/tool face indicated @ approximately 8 degrees left of high side. Set whipstock w/top @ 10736, bottom @ 10752, RA tag @ 10746. Tag whipstock with setting string. POH w/setting tool. Tool intact, OK. Rig down Schlumberger. RU D/S 1-3/4" CTU & function test BOPE. D26RD Detailed Activity Summary.xls Page 3 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 11 P6 28 2.0 13:00 15:00 11 P6 15A 2.0 15:00 17:00 11 P6 6F 2.3 17:00 19:15 11 L6 45 1.8 19:15 21:00 11 P6 44F 1.3 21:00 22:15 11 P6 5 0.5 22:15 22:45 11 P6 44F 1.3 22:45 0:00 Cut off 175' of damaged coil. MU coil connector and pull test to 25K. Make up tool string. Pressure test tool string and coil to 4000 psi, OK. Test pipe rams and both blind shears to 4000 psi. MU window milling assembly. Stab injector head and test stripper to 4500 psi. RIH @ 100 ft/min without circulation. Production having problems getting lift gas coming around. Wait for gas lift. Run in feeling for top of whipstock. Dry tag @ 10747 CTM (top) and again @ 10751. Attempt to start milling just below top of whipstock w/o success. Unable to mill w/o stalling. Weight started stacking out w/o stalling. PU pulling tight to 33K (23K up normal), gripper slipped and inj. head jumped. Appeared tight up hole. Had not paint marked CT, unable to find a consistent top of mill Pump 25 bbl hi vis sweep, 3 ppb Flovis. Mill window. Finding top of whipstock 5' shallower @ 10742, top of cut @ 10746. Paint mark pipe @ 10746. Mill from 10746 to 10747 with multiple stalls and 10747 to 10749 with good differential (200 to 600 psi),all in 1 hr. Mill @ 10749 with little differential and very smooth. Did not act like iron. Pumped 3% KCL/inlet water & 2 gal/100 bbls J-313 FR @ 2.5 bp 6/1/98 11 P6 44F 1.0 0:00 1:00 10,750 11 P6 5 0.8 1:00 1:45 10,750 11 P6 6F 2.3 1:45 4:00 10,750 11 P6 28 1.0 4:00 5:00 10,750 11 P6 45 5.0 5:00 10:00 10,750 I P1B 1E 7.0 10:00 17:00 10,750 Milling 3.8" window w/Baker metal muncher dimple mill from 10749-10750.3. Smooth and consistent only 100 psi differential. Mark CT and measure progress of 4.5' (vs. 4.3' by CT depth). Estimate window to be 3+' long. Pump 25 bbl hi vis sweep, 3 ppb FIovis, and circ up into tubing tail. POH, pump out of hole. Break out dimple mill. Most of mill wear on side OD. Some wear on outer area of face. A few chipped inserts in dimple of mill. Mill OD worn to 3.75% Baker whipstock hand feels we have exited the casing. Feels the next run should be the formation mill and string mill combo. Set off injector head. Secure well and equipment. Crew sleep Rig down CTU. Drain pits. Prep loads for boat. 7/14/98 I P1B 1E 12.0 10:00 22:00 Rig move. Clear equipment from east pipe rack. Problem developed w/east crane memory switch resulting in locked brakes, reset switch (no lost time). Center up & skid east rig to the south 5' to allow pipe rack removal. Disconnect rig electrical and service lines in prep for skid to NE leg. Prep D26RD Detailed Activity Summary.xls Page 4 of 19 11/6/98 UNOCAL® UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity pipe racks for removal and transport to Steelhead platform. 7/15/98 1 P1B 1E 16.0 6:00 22:00 Rig move. Hold PJSM on crane safety. Load out 13 pipe rack panels and pipe rack cantilever section onto workboat, offioad on SHP. Load out 2 pipe rack sections to SHP. Load out 3rd pipe rack section and mud pit to SHP. Remove V-door and stairs. Skid west rig to extreme NW comer of platform. Start rerouting dg electrical for north end hook up. Welder install 4" gas buster re 7/16/98 I P1B 1E 7.5 6:00 13:30 1 P1B 1F 9.5 13:30 23:00 Move rig. Load platform mud tank on boat. Move to and set on west side of platform. Fabricate 6" & 8" suction and discharge lines to tie in mud tank. Misc welding projects. Move dg electrical bundle from north side of east rig to south side. Load out break room on boat. Relocate food conex and drlg parts house. Set Epoch unit. Clean deck. Skid east rig from SE leg B-1 to NE leg A-1 w/difficulty. Had to center up rig a few inches to allow cable tray to pass crane, tight tolerance. Also tight over service outlets forcing crew to move jacks a few times. Rig skid base caught slightly bent walkway grating twice. 7/17/98 I PIB 1F 7.0 6:00 13:00 1 P1B 1E 5.0 13:00 18:00 Skid rig east rig (#76) to the north to line up wi D-26. Could not skid east to center up over well due to interference w/newly installed crane walkaround. Unload mud tank and associated equipment from MN Champion. R/U mud tank. Install handrails, centrifuge, hopper and misc equipment. Remove ladder from dg and respot tank. Check out air tugger line and sheaves. Work on rig electrical. Welder working on V-door slide and misc projects. Pick up tools and clean up drill deck. 7/20/98 1 P1B 1E 14.0 8:00 22:00 Rig up. Clear deck and unload D/S coil equip from boat. Set coil, power pack, cabin and pumps. Rig up surface lines. Skid rig and center up over hole. Install air tugger on rig. Install ladders. Fabricating V-door slide. Work on mud pit and rig electrical hook up. Unload second boat. Rig up Secorp H2S/meth detection and breathing air system. 7/21/98 I P1B 1E 8.0 6:00 14:00 1 P1B 14A 10.0 14:00 0:00 Rig up. Install cuttings chutes. Run water and mud shipping line to mud tank. Set choke manifold. Fab & install front sub ladder. Install and secure ladder from pit to floor. Installing BHI, Epoch & Secorp surface equipment. Install choke and flow lines. Nipple up CT riser, mud cross, annular D26RD Detailed Activity Summary.xls Page 5 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity and quad stack. Install kill and choke valves. Work boat. Rig up surface hard lines. Clean reserve pits. 7/22/98 1 P1B 1E 8.0 0:00 8:00 1 P1B 1E 16.0 8:00 0:00 Rig up. Clean both reserve pits and mix pit. Install cable handrails on reserve pit. Change airtuggers over to shackle connectors. D/S make up charge pump manifold. Hook up hydraulics & wt indicators. Pull test injector to 52K. Stab 2" coil to inj hd. Prep for and work boat. P/U and hang injector on rig floor. Mix 800 bbls 3% KCL/fresh water. Install new agitator shaft. Run lines to micromotion. RU regulator, control manifold and lines for annular BOP. Function test mud system. Install and welding out V-door slide. Miscwelding projects. Flange up wellhd to kill well. Finish rigging up D/S charge lines. 7/23/98 I L1B 16C 2.0 0:00 2:00 1 P1B 15F 1.0 2:00 3:00 1 P1B 16C 0.5 3:00 3:30 1 P1B 15F 0.5 3:30 4:00 I P1B 16C 6.0 4:00 10:00 1 P1B 1E 4.0 10:00 14:00 8 P4 44F 2.5 14:00 16:30 8 P4 45 0.5 16:30 17:00 8 L2 15A 4.0 17:00 21:00 8 P2 15A 1.0 21:00 22:00 D/S charge pump boosting "L" pump leaking @ bowl drain. Unable to repair. Rig up to charge "G" pump w/platform pump. Pressure test lines to 5000 psi. Tighten up flange leak on pulsation dampener. Swab valve leaking, shut master. Slight leak. Grease valves. Fill tubing w/44 bbls 3% KCL/fresh water. Pressure up to 800 psi, shut down. Rig up to annulus. Pressure test lines to 3000 psi. Repair 2 leaks. Load tubing annulus. Annulus pressure @ 500 psi. Pump 585 bbls 3% KCL/fresh water dn annulus. Bleed off gas cap 3 times. Max pressure 1500 psi. Cont. rig up ops while filling annulus. Hook up and function test annular and control manifold and HCR valves. Mix KCL Finish hooking up micromotion sensor. Rig up to feed DIS reserve pit fluid while mixing drlg mud. Make up coil connector and pull test to 30K. Stab injector hd to lubricator. Load coil w/KCL. Mixing FIo-pro mud. Hold pre job safety meeting. Test BOPE. Test top blind/shear rams and outside choke manifold valves. Choke man valve leaking thru grease connection, grease same. Retest, leaking away. Test bottom blind/shear, leaking away. Test surface lines to isolate leak. Test pack off and inside choke line gate valve to 5K, OK. Test outer manifold valves, leak thru fitting on #1 choke. Isolate valve, leaking @ threaded 2" by 3" baker locked conn from choke hose to manifold flange. Seal weld same while cont to test. Test HCR and pkoff, OK. D26RD Detailed Activity Summary.xls Page 6 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 L14 8C 2.0 22:00 0:00 Retest both blind/shears, leaking. Change out rear seals on both sets blind/shear rams. 7/24/98 8 L14 8C 4.0 0:00 4:00 8 P2 15A 2.0 4:00 6:00 8 L14 29A 7.0 6:00 13:00 8 L14 8B 3.0 13:00 16:00 8 P2 6C 3.0 16:00 19:00 8 P2 6B 2.5 19:00 21:30 8 P2 44B 1.3 21:30 22:45 8 L2 5 0.5 22:45 23:15 8 P2 44B 0.8 23:15 0:00 Repair BOP's. Replace rear seals on both top and bottom blind/shear rams. Test BOP's. Test upper and lower blind shear rams to 300/5000 psi, OK. 10K push pull test on slip rams. Test pipe rams, held no pressure. Test annular to 300/2500 psi, OK. Test choke manifold valves and kill line valves to 300/5000 psi. Remove pipe rams from stack for inspection. Ram packer and ram guide damaged. Order parts from Anchorage. Wait on parts. Repair and install pipe rams. Cycle rams. Install test jr. Pressure test rams to 300/5000 psi. Make up window milling assembly ~2. Install injector. Test lubricator to 5000 psi. Bleed 1040 psi pressure from tubing. Reroute surface circ lines. RIH w/formation mill, string mill and mud motor. Run in w/o circ. Locate TOW. Set down 2 times @ 10714. Correct depth to 10742. Up wt 32K, dn wt 12K. Line up returns to seperator and break circ. Catch fluid, circ @ 2.5 bpm, no returns. Returns after 43 bbls. Up wt circ 28K, 9K dn. Feel for TOW, stalled motor @ 10735. Not keeping up on KCL fluid. Circ at minimum rate. Change setup for mixing and shipping KCL fluid. Feel for and start opening window @ 10742. Flag pipe. Motor stalling with little to no weight. 2.5 bpm @ 3200 psi. 2 motor stalls w/14K overpull on pick up indicating mill in window. 7/25/98 8 P2 44B 3.0 0:00 3:00 8 P2 45 1.0 3:00 4:00 8 P2 5 2.5 4:00 6:30 8 P2 6B 2.0 6:30 8:30 8 Pll 36 1.0 8:30 9:30 8 P2 6C 1.0 9:30 10:30 Open window with 3.8" stdng mill from 10742' to 10749, 3.625" formation mill to 10750. Good resistance 10742-43 w/5 motor stalls. Smooth milling w/little differential for remainder. Did not see increased differential @ window bottom. Bkream up & back thru windwow. Make 1' more w/formation mill to 10751. Bkream & ream window. Work up & back thru window w/o pump w/no resistance. Rig up to fill annulus. PT lines to 1000 psi. Fill annulus w/90 bbls KCL brine. Max pressure 180 psi. Annulus on slight vacuum. Displace KCL fluid w/FIo-Pro mud, taking returns to production. Take returns to pits 5 bbls short of calc displacement. Circ to pits until good mud returns. Flag line @ 10675. POOH H2S/Abandon Platform Drill. Finish POH, set off injector. Lay down D26RD Detailed Activity Summary.xls Page 7 of 19 ' 11/6/98 UNOCAL( UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 P2 6C 1.5 10:30 12:00 8 A2 45 1.0 12:00 13:00 8 A2 28 1.0 13:00 14:00 8 P2 6B 1.0 14:00 15:00 8 P2 6B 2.0 15:00 17:00 8 A2 28 0.5 17:00 17:30 8 L2 42A 3.0 17:30 20:30 8 L2 42A 1.0 20:30 21:30 8 L2 6B 2.5 21:30 0:00 10,751 BHA. String mill had cutter wear top and bottom ends indicating window fully milled. Circ sub found to be shifted. 1502 union gasket located in circ sub. Make up ddlling assembly, BHA #1. Check surface pumping lines for gaskets, all accounted for. Check hole fill, OK. Hold safety meeting and finish dg up Epoch depth encoder. RIH to 500'. Check odenter. Cycle 2 clicks w/MWD tool faces indicating tool functional. RIH to 7000'. Calibrate Epoch depth counter. RIH to flag, correct depth to DIE Survey, tool face @ 90 right. Attempt to odent to high side. Made 16 attempts to cycle orient tool. Tool tumed 2 clicks (60 degrees) early on but failed to turn further. Stand by while trouble shooting problem. POH to check odenter. 7/26/98 7/27/98 8 L2 6C 3.3 0:00 3:15 8 L2 6B 3.8 3:15 7:00 8 P2 44F 6.5 7:00 13:30 8 P2 6B 2.0 13:30 15:30 8 P2 6C 2.5 15:30 18:00 8 P2 6B 2.5 18:00 20:30 8 P2 44B 3.0 20:30 23:30 8 P2 6B 0.5 23:30 0:00 8 P2 6B 2.0 0:00 2:00 8 P2 6C 1.8 2:00 3:45 PU injector head. Lay down BHA #1. No problems noted wi odenter. RU to visually surface test orienter #2. Observed orienter rotate 180 deg in 30 degree clicks. Make up drlg assembly, BHA #2. MU injector. RIH w/BHA #2. Check orienter and MWD @ 500'. Tie into flag. Survey & orient. Odenter working well. Work thru window with tool face @ high side, attempt to circ. Stalled and pulled tight. Work thru window again after several attempts to 10746. PU tight, pull 56K twice to get free. Unable to get thru window and rotate again. Work thru several orienter rotations. Attempt w/and w/o pump. Setting down higher, 10738 CTM dee POH PU inj hd & LD BHA. High side scoring on motor between 8' and 12' from bit. PDC bit had all cutters broken on outer row, 2 of 4 chipped on gauge row, bkreamers all broken, rest in good shape. MU new coil connector & pull test to 35K. PT to 4500 psi. MU new 3.8" string mill and 3.625" formation mill RIH. Dress window. Tie into flag. Dry tag @ 10736, bobble @ 10729. Dress window. Motor work @ 10729 & 10732-34, 6 total stalls. Stack out wt @ 10736 w/little differental. Slow ream and back ream several times. Attempt to make 1' new hole. No penetration, little differential. Work thru window without pump, ran & pulled smooth. Some sand detected in returns. Substantial iron o POH. POH w/milling assembly. Lay dn BHA. Formation mill found to D26RD Detailed Activity Summary.xls Page 8 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP 8 P2 6B 8 P2 44F 8 P2 44B 8 P2 6A 8 P2 6C 8 P2 6A 8 P2 44F Hours 2.8 2.0 5.0 3.5 2.0 3.5 1.5 From 3:45 6:30 8:30 13:30 17:00 19:00 22:30 To Depth 6:30 8:30 13:30 17:00 19:00 22:30 0:00 10,814 10,814 Activity have smooth center core wear and OD wear near face, appears to be formation. String mill has broken cutters on uphole edges. Make up drlg assembly, BHA #3, w/bit #2. RIH Tie into flag, orient and work thru window. Were able to run window w/ Iowside tool face. Located window based on increased drag w/Iowside tool face. Drill from 10751 to 10814. Multiple stalls starting requiring pick up and possibly causing bit to come up just inside window a couple times. Forced to drill @ 20-30L from 10790-95, orienter would not come around to right 1 click. Pull up to 10755 to gain click, regain MWD synch. Drill high side, build rate dropping off. Decision made to pull & check tools. POH to check tools Work BHA. Pull injector and BHA. Bit found to be well worn on shoulder w/ cutters broken and ringing out. 2 of 4 bkream cutters broken off. Set ABH to 4 degrees. MU bit #4, Hycalog DSl11. Check wobble in disconnect, OK. Work motor dn thru BOP's and wellhead. RIH. Work past GLM's. Tie into flag. Orient and attempt to work thru window. 7/28/98 8 P2 6B 8 P2 44B 8 P2 6B 8 P2 6C 8 P2 29C 8 P2 6C 8 P2 6B 8 P2 6A 1.3 4.8 2.5 0.5 3.0 4.5 2.0 2.0 0:00 1:15 6:00 8:30 9:OO 12:00 16:30 18:30 1:15 6:OO 8:30 9:00 12:00 16:30 18:30 20:30 10,831 RIH w/BHA #.4, bit #3. Orient and work thru window w/some difficulty. Wash to bottom @ 1.5 bpm. Correlate to GR log, add 3'. Drill from 10814-10831. Drill 10814-10829 @ 45L. Unable to get 1 click w/multiple attempts and varied technique. Pull into casing and gain 1 click. Work thru window w/difficulty. Drill from 10829 to 10831 @ 15L. Ream and bkream 30' to bottom several times w/some mtr work 10822-27. Little differential on bottom, 100 psi stacked out. Good pick ups, good wt transfer to POH to check bit and tools. Set off injector head, check bit. Bit found to be not badly worn. Shoulder and outer row cutters have light fiat edge wear. 3 of 4 bkream cutters chipped or broken. Stand by Make up BHA #5 w/1 deg mtr& bit #4 (HTC STR 20D rock bit). Cut 131' coil. MU Baker CT connector. Pull test to 35K. Surface function test rebuilt orienter, failed to click. Function test orienter just laid down, OK. Finish making up BHA. MU injector. RIH Tie in to flag. Survey and attempt to work thru window w/o success. Made multiple attempts at all orientations. D26RD Detailed Activity Summary.xls Page 9 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 L14 8B 0.5 20:30 21:00 8 P2 6B 2.0 21:00 23:00 8 P2 6C 1.0 23:00 0:00 10,831 Attempted to work thru w/Iow mtr RPMs. Inspect injector, metal shavings found on top of stripper. Coil tubing found to be scored. Gdpper rollers grinding a bit. POH Set off injector. Inspect and stand back BHA. Bit OK. 1 or 2 light gouge marks on each cone. 1 shank heavily scored. In gauge. 7/29/98 8 L2 42B 1.0 0:00 1:00 8 L2 42B 3.5 1:00 4:30 8 P2 6C 0.8 4:30 5:15 8 P2 7 0.5 5:15 5:45 8 L2 6C 0.5 5:45 6:15 8 L2 6B 4.0 6:15 10:15 8 L2 6A 0.3 10:15 10:30 8 L2 2B 1.0 10:30 11:30 8 L2 29C 0.5 11:30 12:00 8 L2 6B 0.3 12:00 12:15 8 L2 6B 2.8 12:15 15:00 8 L2 6C 1.0 15:00 16:00 8 L2 6B 2.3 16:00 18:15 8 L2 3B 2.5 18:15 20:45 8 L2 5 0.3 20:45 21:00 8 L2 3B 0.3 21:00 21:15 8 L2 6B 2.0 21:15 23:15 8 L2 6C 0.3 23:15 23:30 8 P2 6C 0.5 23:30 0:00 10,741 10,741 10,741 10,741 10,585 10,585 10,759 10,759 10,759 10,759 10,759 10,759 Rebuild pack-off assembly on injector head. Pressure test pack-off to 5,000 psi--OK. MU CTC. Pull test CTC to 35,000lbs and pressure test CTC to 4,500 psi. OK. Inspect and perform injector head maintenance. MU BHA #6 (formation mill and dual string mills). RIH with BHA #6. Perform weight check @ 10,678'--37K. Correlate depths. PU bring pumps to 2.5 BBPM/3,400psi. Dress window with mills @ 10,471'. Hard motor stall initially. Motor working and tapered off to no indication of motor turning. Set down @ 10,471 stacking wieght with no pressure increase at surface. Could not go past 10,741'with pumps off. Circulate @ 2.0 BPM. Accumulated more metal on ditch magnents. Consult with office. POOH with BHA #6 to 10,585'. Flag pipe. (End of coil @ 10,562') Continue to POOH with BHA #6. Test motor in lubricator--ok. Disconnect Injector head. Test motor with pipe wrench--OK. Pressure test coil and circ sub to 4,500 psi--OK. Laydown formation mill and pick-up used 3.8" dimple mill. Test motor. RU injector head. RIH with BHA #7 (dimple mill) with pumps off and tag whipstock @ 10,759'. Up WT = 32K. Make 12 trips through window @ 2.0 BPM, 2,7000 psi. Stall motor with 5,000 lbs down pressure increase to 3,900 psi. Circulate bottoms up to see if we have been milling casing or attempting to make hole. ???? in returns. Attempt to make hole or mill new window with dimple mill. No success. Could not work past 10,759'. POOH with BHA #7. Disconnect injector head. LD BHA #7. Dimple mill had no appreciable wear on gauge or face of mill. Some coal in between carbide cutters.also had some coal between cutters on string mills MU BHA #8 (Drilling Assy.). 7/30/98 8 P2 6A 3.5 0:00 3:30 10,753 RIH with BHA # 8. Tie into pipe flage. D26RD Detailed Activity Summary.xls Page 10 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 P2 3B 0.8 3:30 4:15 10,832 8 P2 2B 1.5 4:15 5:45 10,840 8 P2 45 0.5 5:45 6:15 10,840 8 P2 45 1.5 6:15 7:45 10,840 8 P2 45 1.3 7:45 9:00 10,840 8 P2 45 0.3 9:00 9:15 10,739 8 P2 3B 0.3 9:15 9:30 10,749 8 P2 6A 2.5 9:30 12:00 8 P2 6C 1.5 12:00 13:30 8 L14 8B 0.5 13:30 14:00 8 P2 6A 2.3 14:00 16:15 8 P2 6A 0.3 16:15 16:30 8 L2 3B 3.0 16:30 19:30 8 L2 6F 2.5 19:30 22:00 8 L2 6C 1.0 22:00 23:00 8 P2 9 1.0 23:00 0:00 10,749 Tag bottom @ 10,753'. Bring up pump and cycle orienter 6 times. Ream down to 10,832'. Started taking weight with no motor work. Drill 3-3/4" hole @ 30 f-t/hr from 10,832' to 10,840' @ 90L; 2.2 BPM; 3,600 psi. Little motor work while drillin delta P = 100psi. Attempt to orient in open hole without success. POOH to window. Orient to highside. RIH and tag @ 10,757'. Ream through with little motor work F/10,757' to 10,765'. Good motor work F/10,765' to 10,769'. POOH to window and orient 30R. RIH and tag @ 10,749' with pumps off. Attempt to work past 10,757' with no success. Attempt to orient toolface to highside @ 10,749'. Toolface oriented to 90L and would not move. Cycle orienter toolface still @ 90L. Pressure up to 4,000psi while getting toolface. Pressure then drpped back to 3,500psi and toolface move to 90R. RIH and tag @ 10,749'. Attempt to work past--no go. PU to 10,715' and cycle orienter; 2.25 BPM; 3,500 psi; 70L. Slow pumps to 1 BPM, 2400 psi & RIH. Tag @ 10,739'. PU 4K over, while PU toolface went to 40R. Cycle orienter to highside. RIH to 10,748' @ .9 BPM, 2,600 psi. Attempt to ddll past pumping @ 2BPM, 3,100 psi. Stalling motor @ 10,749'. Attmept to drill ahead with no success. Talk with office. Trip for new bit. POOH with BHA #8. Flag coil at 10500' end of coil. RD injector head.lay down insert bit & pick up 3.75 Hycalog DS49.Change out battery in MWD Make up BHA to coil and stab up injection head. Repair level wind on coil real. Run in hole BHA #9,STOP AT 1800' and test orient sub and MWD. stop at flag on coil at 10500'(EOC) Make 3' depth correction Add BHA,set counter to 10574.5.Run in hole and tag up with pumps off at 10741.7' Unable to get out window. Bring pumps up to speed,surveyed at 40R.Cycle orient-sub two clicks and surveyed at 100R. Attempt to continue cycles to get 30L or straight up.(no go) have tool failure. Continue attempts with different pump rates and working coil.attempt to get out window (NO GO)TAG AT 10741' POOH BHA # 9 lay down BHA.BIT still in good shape. Cut COIL TBG (PLAN CUT IS 115') 7/31/98 8 P2 9 1.0 0:00 1:00 8 P2 15A 3.5 1:00 4:30 Continue cut off 115'of coil. TEST BOPS. Test annular to 250-2500 psi. D26RD Detailed Activity Summary.xls Page 11 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 L2 29A 5.5 4:30 10:00 8 L2 29A 9.0 10:00 19:00 8 P2 6C 2.5 19:00 21:30 8 P2 6F 2.3 21:30 23:45 8 P2 6F 0.3 23:45 0:00 0.0 8/1/98 8 P2 6F 0.5 0:00 0:30 8 L2 6F 4.0 0:30 4:30 8 L2 6B 3.0 4:30 7:30 8 L2 6C 0.5 7:30 8:00 8 L2 29C 1.8 8:00 9:45 8 P2 6C 1.3 9:45 11:00 8 P2 6F 2.3 11:00 13:15 8 P2 6F 0.3 13:15 13:30 8 P2 3A 1.0 13:30 14:30 Test 2 blind shear rams,pipe rams,choke manifold,wing valves and all other sur face line to 250-5000 psi.( A.O.G.C.C. waved test.) Waiting on sperry orient subs,equalizer sub and xo subs,tools showed up at 1000 hrs,did not have sub to xo 2 3/8" cs hydril thread on equalizer sub back to 2 7/8" stub acme.(also had radius hand come down to rebuild their orient subs was in kenai but tools did not make it in from Dead Horse. Attempt to locate xo from sperry,had one in Dead horse but did not pass inspection.had BOT Kenai,make a 2 3/8" CS Hydril box X 2 7/8" STUB acme BOX. Radius Rebuilding both orient subs in WOTCO SHOP.Radius orient subs finished and onboard at 1800 hrs.waited on xo being built at BOT, It showed up at 1900 hrs. MAKE UP BHA ¢ 10.pick up sperry orient sub. Make up equalizer sub below MWD reorient MWD TO/mud mtr. Make up BHA to mtr head assy Stab up injection head. Run in hole to 1700' test MWD & orient sub tested good.Continue run in hole to flag at 10500( EOT).115'of coil was cut of before trip in.-115'from EOT.& add BHA ¢10 = 77.58.Set depth at 10462.5 Continue run in hole to 10700'bring pump up to speed for tool face.tool face at 110 L. Continue run in hole with BHA ¢ 10 TO 10700'Cycle orient sub to 40L had to cycle 4 clicks. Run in hole tag at 10738 with pumps off. Depths appeared alittle off pulled up hole to 10670 and ran Gamma ray pass for depth conformation.continue with several attempts at different tool faces with no progress.we could turn mtr 175L and tag at 10729'(top of whip stock)ct measurements were 7'off on this trip made depth correction on this to 10736' (ORIGINAL SETTING TO DEPTH).also ran bit POOH with BHA ¢ 10 Pick up ct injecter. Hang off BHA in derrick. Discuss options with office and attempt to locate 3.75 water mellon mill(no go) Make up BHA¢ 11,3.80 DIMPLE MILL + 3.80 string mill.on mtr set at 1 degree. Run in hole BHA ¢ 11 TO 10393.70'(EOT) Add in 79.80 BHA and set depth to 10473' Run in hole to 10700'cycle orient sub to a 15L Tool face. make dry tag at 10744'. Bing pumps up to speed and tag at10742' start milling at 2 bbl per min 3300 psi with 100-200 psi mtr differential.start D26RD Detailed Activity Summary.xls Page 12 of 19 11/6/98 UNOCAL Date PH CL OP Hours UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD From To Depth UNOCAL Activity 8 L2 3A 8 P2 3A 8 L14 8B 8 P2 3A 8 P2 6A 8 P2 6C 8 P2 6A 8 P2 6A 8 P2 3B 8/2/98 8 P2 3B 8 P2 6A 8 P2 6C 8 P2 45 8 P2 45 8 P2 6A 8 P2 2B 0.5 14:30 15:00 0.5 15:00 15:30 0.5 1.5 2.5 0.5 2.0 0.5 1.0 3.0 2.5 1.5 2.0 7.5 1.0 6.5 15:30 16:00 17:30 20:00 20:30 22:30 ~3:00 0:00 3:00 5:30 7:00 9:OO 16:30 17:30 16:00 17:30 20:00 20:30 22:30 23:00 0:00 3:OO 5:30 7:00 9:00 16:30 17:30 0:00 having mwd problems. BHI CHANGE OUT FILTER ON MWD SENSOR. dress window f/10742 -t]l 7745'started having pump problems,starving for fluid. clean out suction screens.on pumps. Continue clean out on window to/10754' made several passes through window. POOH window dressing assy. Lay down string mill and dimple mill make up hycalog DS49HG Bit,stab and injector. Run in hole with BHA # 12 TO/flag on coil,made 20'depth corection,add in BHA 76.03'and set depth to 10469.73' Run in hole to 10700',cycle tool face to 20L,Had trouble at window taged up at 10742'could not get out with pump off or on ,set down on window and cycle pump and got through window. RIH with pump off tag at 10761'could not go dn hole with pump off. Ream f/10761'- t/10765,can not run any wt mtr pulling high differential and stalling pick ups were slightly sticky at 4 kip over. continue reaming f/10765'4/10770' mtr wanting to stall with attempts to run any weight. Looked like we were chasing junk down hole or we side tracked the well.set down hard on bottom with pumps off to see if would over pull on pick up. had good clean pick up off bottom. looks like we side tracked well. POOH,with BHA # 12, pick up injection head.lay down bit Hy DS49. Bit looked in good shape an less than 1 1/16" out of gauge. Lay dn Drillex 1 deg mtr,and pick up drillex 278 NM mtr set @ 3 deg and Hycalog bit DS111. stab up injection head. Consult with office on BHA and mtr. Pick up injection head and change mtr set from 3 deg t./2.5 deg. Chage out nozzle in Sperry equalizing sub. Dump and rebuild inure mud system and run in hole BHA 13. STOP AT 10393.7 Add in BHA 76.42' and set depth to 10470.20.run in hole and tag up in window at 10736',cycle pumps tool face at 20L,Still tag up in window shut dn pump and set 1 kip dn on window and cycle pump and fell on into open. H. run in hole tag up at 10766' start drilling having trouble keeping bit on bottom due to mtr stall.drill f/10766'- t/10830'( Made depth correction when we reached RA marker on whip stock) the actual start of drilling depth WAS AT 10,781'DIL, reset depth, started having hole problems was tight at 10824' was stuck and worked free. worked coil and r D26RD Detailed Activity Summary.xls Page 13 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8/3/98 8 P2 2B 5.8 0:00 5:45 8 P2 6A 2.8 5:45 8:30 8 P2 9 2.0 8:30 10:30 8 P2 6C 0.5 10:30 11:00 8 P2 6A 2.5 11:00 13:30 8 P2 2B 6.5 13:30 20:00 8 P2 3B 0.5 20:00 20:30 8 P2 5 1.5 20:30 22:00 8 P2 6B 2.0 22:00 0:00 Drilling, W/Motor F/10830 - T0/10857' Hole started droping angle with loss in ROP,Need a higher build rate. POOH,with BHA # 13 Flag coil @ 10623.4' cut off 120'of coil,change out stripper make up 2 7/8"drilling coil connector and pull test to 32 kip and presure test mtr head assy to 3000 psi. lay down 2.5 deg DRILLEX mtr and pick up DRILLEX NM 278 mtr set @ 3 deg and make up HYCALOG DS49HG bit. Run in hole with BHA # 14 BIT # 8 TO coil flag at 10623.4 subtract 122'coil cut and add in BHA 76.45 and set depth to 10577.85,run in hole to 10700 bring pump up to speed,had tool face of 10L Shut down pump RIH with no problems at window, bring pump up to min rrate and continue in hole tag btm at 10857'.pick up and orient tool face to 30R to allow for drilling recactive torque. Drilling, W/Motor f/10857'- t/10911' slow drilling f/10857'4o/10862'at 4 ft per/hr.ddll bulidig 4-5 deg per/10' with 40 deg+ dog leg per/100 ft. pump rate at 2.35 bbl per min at 3600 psi with 150-200 differential pressure on btm,up wt 32 kip dn wt 5 kip. Had 250-300 psi increase in pump pressure on and off btm pulled up hole to see if this would drop off (no go) survey data indicated at last survey sensor depth 78.10 deg INCL Projected angle at bit depth of 10911'could be f/93-97 deg. Back ream f/10911-t/10800' made 2 pases circulated btms up.cuttings are fine coal and sand. POOH with BHA # 14 shut down pump 20' outside window, had no problems pulling into window. Continue POOH flag coil at 10623, 40 8/4/98 8 P2 8 P2 6A 0.5 0:00 0:30 6C 2.0 0:30 2:30 8 P2 6B 2.5 2:30 5:00 8 P2 6B 1.0 5:00 6:00 8 P2 6B 1.0 6:00 7:00 8 P2 6B 1.5 7:00 8:30 Continue POOH with BHA # 14. lay down 3 deg mtr and DS49 bit had fiat crested ware on cutters mostly on the outer rows and 1/16"out of gauge. Pick up DRILEX 278 NM mtr set at 1 deg and make up bit # 6rl orient mwd to/MTR. make up BHA to mtr head assy.stab up injection head. Run in hole BHA # 15 Stop at flaged ct and make depth adjustment.and add in BHA 76.04'Sset depth to 10580' Continue run in hole to/10700' cycle cycle pumps for tool face 10L,run in hole and tag up in window at 10742' Made multiple attempts to get through window at toolfaces around the clock also used pump and mtr reactive tq and picking up and down on coil with mtr in stall, picked up and shut down pump and got through window. Continue run in to 10911'w/no problems attempt to orient on btm ( no go )pull D26RD Detailed Activity S ummary.xls Page 14 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 P2 2B 3.5 8:30 12:00 8 P2 2B 4.0 12:00 16:00 8 P2 3B 0.8 16:00 16:45 8 P2 6A 2.8 16:45 19:30 8 P2 6C 1.0 19:30 20:30 8 P2 6A 1.5 20:30 22:00 8 P2 6A 1.5 22:00 23:30 8 P2 2B 0.5 23:30 0:00 8/5/98 8 P2 44F 2.0 0:00 2:00 10,961 8 P2 44B 4.0 2:00 6:00 11,023 8 P2 6A 3.0 6:00 9:00 11,023 8 P2 6C 0.5 9:00 9:30 11,023 8 P2 44F 1.0 9:30 10:30 11,023 8 P2 6A 3.5 10:30 14:00 11,023 up to 10850'orient tool face to 90L,run back to bottom. Drilling, W/Motor f/10911-tj10923 at 45-50 fi/per hr then ran into slow ROP Surveys started coming up indicating that angle was not as expected from our bit angle projections.continue drilling to 10937'with intermittent drilling breaks,surveys coming up at 89 deg. pulled up hole to 10850 orient TF to straight up and run to bottom and drill f/10936'-t/10950'had slow rops of 5-8 ft per/hr top gradually falling off. able to stack weight and not getting much differential presure,but still get clean pick up wt @ 32-34 kip.down wts getting lower and lower 2000-1800 lbs. wer are now getting good AZ Surveys. Make wiper trips to 10800' twice run back to bottom and stack weight with out any differential pressure and no ROP. still have clean pick up wts. POOH W/BHA # 15 BIT # 6R1 .With no prob in open hole or window. Lay down bit and inspect mtr, checked out ok),pick up bit # 9 HTC. STR-20D.STAB up injection head.(bit had fiat crested ware and chipped cutters,mostly on gauge row.(see pictures on e-mail) Run in hole BHA # 16 to flag on coil & make depth correction add in btm hole and set depth to 10880.8' Continue run in hole to 10700'cycle orient sub to 20R and RIH w/no problems to/10932'ream t/10942'btm,(have made two trips with out tie in pull up to bit depth 10790 tie in to hot GR at 10779' had to add 19'to depth.(CORRECTED BTM DEPTH TO GR = 10961'.RUN BACK TO BTM Attempt to drill NO ROP showing up yet able to stack wt and push wit coil 5kip with no differential pressure.pick up still clean at 32-34 kip,dn wt 1800 lbs. START ADDING LUETEX TO MUD SYSTEM. Unable to make hole. Weight stacking out, no differential. Pull up to window to check motor. Set down in window, bring pump up to speed, motor stall pressure normal. PU & orient 20L, RIH. Drilling from 10961 to 11023. Slow ROP form 10961 to 10980. Drlg break @ 10980 to 11023 w/ROP @ 35-50 fph w/up to 10K dn wt on coil. Quit bit ¢9 due to hrs on bit. POH, trip for bit. Pull BHA & check bit. 1 slightly loose cone w/some insert wear, no breakage, 1/16" UG. Cut off 203' of coil. High pressure cycles required fatigue points to be cycled downhole. MU bit#10, Hycalog DSl11. RIH. Correct depth @ flag from 10076 to 10061. Orient thru window @ 70R. RIH, set down @ 10952. Orient high side, D26RD Detailed Activity Summary.xls Page 15 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8/6/98 8 P2 44B 1.0 14:00 15:00 11,059 8 P2 44F 0.8 15:00 15:45 11,059 8 P2 44B 1.8 15:45 17:30 11,082 8 P2 6D 0.3 17:30 17:45 11,082 8 P2 44B 1.3 17:45 19:00 11,090 8 P2 6D 0.3 19:00 19:15 11,090 8 P2 44B 1.0 19:15 20:15 11,120 8 P2 6D 1.3 20:t5 21:30 11,120 8 P2 44B 1.3 21:30 22:45 11,132 8 P2 6D 0.3 22:45 23:00 11,132 8 P2 44B 1.0 23:00 0:00 11,152 8 P2 44B 0.8 0:00 0:45 11,159 8 P2 10 0.8 0:45 1:30 11,159 8 L2 6F 2.5 1:30 4:00 11,159 8 L2 6C 0.5 4:00 4:30 11,159 8 L14 8B 1.5 4:30 6:00 11,159 8 L2 6F 2.0 6:00 8:00 11,159 8 L2 10 1.0 8:00 9:00 11,159 8 L2 44F 1.0 9:00 10:00 11,159 8 L2 10 0.8 10:00 10:45 11,159 8 P2 44B 0.3 10:45 11:00 11,162 8 P2 10 0.5 11:00 11:30 11,162 8 P2 44B 1.3 11:30 12:45 11,193 8 P2 44B 1.0 12:45 13:45 11,216 8 P2 6D 1.0 13:45 14:45 11,216 8 P2 44B 1.5 14:45 16:15 11,236 forced to ream thru w/o difficulties. Run to bottom. Drill 11023 to 11059 @ 30-40L w/ROP @ 35 to 50 fph. Unable to orient tool face more to the left w/reactive torque. Orient tool face Drill from 11059 to 11082 w/tool face @ 90L, 100 psi differential. ROP dn to 2-3 fph @ 11082. Wipe hole to 11780. Drilling w/good ROP from 11082 to 11090 w/tool face @ 80L, 100 psi differential. Hard drilling again @ 11090. Wiper trip to 10780 Drilling from 11090 to 11120. Tool face @ 80L, 150 psi differential. Wiper trip to 10760 @ 1.5 bpm. Log RA tag @ 10736. Correct depth to make PA, tag @ 10748, add 12' (added 12' to all depths for this bit run except start depth). Drilling from 11120 to 11125 @ 90L. Orient 1 click. Drill from 11125 to 11132 @ 75L. Weight stacking out, ROP dn to 10 fph. Pick up 30' & ream back. No increase in ROP, still stacking out. Wiper trip to 10780 @ 1.5 bpm. Drilling from 11132 to 11152 w/tool face turned up to 40L. Angle dropping slightly, working to build angle. ROP back up to 25-30 fph. Drill from 11152 to 11159 @ 35L. Motor stalled and tool face flipped to 70R. Reorient took face. Injector pack off began leaking off hydraulic pressure. POH to repair seals on injector stripper. Flag pipe @ 10700. Stand back BHA and break off bit #10. Bit found to have little wear on face cutters, breakage on shoulder cutters, 1/16" UG. Repair stripper seals on injector. Lower O-ring found to be cut. RIH w/bit #11, BHA#18. No change in BHA. Tie in to flag @ 10700, correct (-)14'. Attempt to survey. Inteq not getting signal. Change out pressure transducer. Orient to high side. Work thru window @ 10740 CTD w/tool face @ 25L. Forced to set down lightly on window, bump pump and roll off into open hole. Orient tool face Ddlling from 11159 to 11162 @ 20L. Surveys showing good build from last bit run. Orient tool face around to 90L Drill f/11162 to 11193 @ 80-90L, 30+ fph. Wipe to 11000' @ 11179. Drill f/11193 to 11216 @ 70L. Wiper tdp to 10755. Tie into RA marker @ 11748 w/gamma ray. Correct +11' for all depths this bit run except start depth. Drill f/11227 to 11236 @ 30L. Drilling D26RD Detailed Activity Summary.xls Page 16 of 19 11/6/98 UNOCAL( UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 P2 10 0.5 16:15 16:45 11,236 8 P2 44B 0.8 16:45 17:30 11,241 8 P2 6D 0.5 17:30 18:00 11,241 8 P2 44B 1.0 18:00 19:00 11,246 8 P2 10 0.3 19:00 19:15 11,246 8 P2 44B 1.0 19:15 20:15 11,254 8 P2 10 0.3 20:15 20:30 11,254 8 P2 44B 1.0 20:30 21:30 11,269 8 P2 10 0.3 21:30 21:45 11,269 8 P2 44B 0.5 21:45 22:15 11,272 8 P2 10 0.3 22:15 22:30 11,272 8 P2 44B 0.5 22:30 23:00 11,276 8 P2 6D 0.5 23:00 23:30 11,276 8 P2 44B 0.3 23:30 23:45 11,276 8 L2 42B 0.3 23:45 0:00 11,276 8/7/98 8 L14 8B 8.0 0:00 8:00 11,276 8 L2 10 1.0 8:00 9:00 11,276 8 P2 44B 0.5 9:00 9:30 11,285 8 P2 10 0.3 9:30 9:45 11,285 8 P2 44B 1.8 9:45 11:30 11,297 8 P2 10 0.3 11:30 11:45 11,297 8 P2 44B 1.3 11:45 13:00 11,317 8 P2 10 0.3 13:00 13:15 11,317 8 P2 44B 0.8 13:15 14:00 11,333 8 P2 10 0.3 14:00 14:15 11,333 8 P2 44B 1.0 14:15 15:15 11,344 8 P2 10 0.5 15:15 15:45 11,344 8 P2 44B 0.5 15:45 16:15 11,350 8 P2 6D 0.8 16:15 17:00 11,350 8 P2 44B 0.3 17:00 17:15 11,352 8 P2 10 0.5 17:15 17:45 11,352 8 P2 44B 1.3 17:45 19:00 11,363 8 P2 10 0.8 19:00 19:45 11,363 hard streaks. Tool face flopped around on a stall. Orient back around to 40L. Drill f/11236 to 11241 @ 40L. Wiper trip to 11780 Drill f/11242 to 11246 on hard streaks. Tool face flopped around to 80R. Orient around to 40L Drill f/11246 to 11254 @ 40L. Orient to 40L Drill f/12254 to 12269 from 40L to high side. Drilling break to 100 fph @ 11265. Orient tool face around to 40L Drilling f/11269 to 11272 @ 40L. Weight stacking out. Orient around to 50L. DHII f/11272 to 11276 @ 50L. Weight stacking out. Last survey showing 97.1 degrees of inclination. Wiper trip to 10780. Attempt to drill @ 11276. Lost prime on pump when 65 bbl test slug of drlg mud w/3% Lubetex started dnhole. Troubleshooting problem and priming 2nd pump @ 2400 hrs. Work on pumps. Main pump lost prime, unable to pick up suction. Pull up to window w/bit. Attempt to pdme up stand by "G" pump. Ruptured relief discs when pump engaged against closed valve. Work on "G" pump, change valves. Prime up, start in hole, pressure loss. Pull back to window. Attempt to reprime, unable to pick up good pressure. Check valves, blown relief disc. Chg valve, reprime, R Orient tool face to 40L. Drill f/11276 to 11285 @ 40-50L, 30-40 fph. Incl. showing build to 98.6 deg. Drilling w/standby "G" pump. Unable to run @ over 2 bpm. Orient tool face around. Drilling f/11285 to 11297 @ 100L-70L. Tool faced flopped. Parts for main pump arrived from beach, repairing pump. Orient around. Drill f/11297 to 11307 @ 100L-70L. "L" pump (main) repaired, back on line. Tool face flopped, orient around. Drill fl 11317 to 11333 @ 55L. P-rate @ 40-80 fph. Tool face flopped. Orient around. Drilling f/11333 to 11344 @ 80L. Inclination up to 98.9 deg. Orient around Drilling f/11344 to 11350 @ 80-90L. Weight stacking out, ROP down. Wiper trip to 10780 Drilling f/11350 to 11352 @ 80L, hard streak. Tool face flopped. Orient around Drilling from 11352 to 11363 @ 80L. Lost MWD sync on motor stall. Orient around. Change over to "G" stand D26RD Detailed Activity Summary.xls Page 17 of 19 11/6/98 UNOCAL UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD UNOCAL Date PH CL OP Hours From To Depth Activity 8 P2 44B 1.5 19:45 21:15 11,372 8 P2 6A 2.8 21:15 0:00 11,372 by pump. "L" pump down wi failed plunger packing (o-ring). Unable to get over 1.9 bpm w/3600 psi (3400 psi free spin) out of "G" pump. Ddll f/11363 to 11372 @ 110L. "L" pump back on line wi 2.25 bpm @ 4250 psi (4100 psi free spin). ROP lower and less consistent. Differential fading. POH w/bit #11. 8/8/98 8 P2 6C 2.5 0:00 2:30 11,372 8/9/98 8 P2 6C 1.0 2:30 3:30 11,372 8 L2 6C 1.5 3:30 5:00 11,372 8 P2 6C 0.8 5:00 5:45 11,372 8 P2 6A 4.3 5:45 10:00 11,372 8 L2 10 1.0 10:00 11:00 11,372 8 L2 6B 2.8 11:00 13:45 11,372 8 L2 6C 1.5 13:45 15:15 11,372 8 L2 6B 3.5 15:15 18:45 11,372 8 P2 44B 1.5 18:45 20:15 11,382 8 P2 10 0.5 20:15 20:45 11,382 8 P2 44B 3.3 20:45 0:00 11,413 8 P2 44B 2.5 0:00 2:30 11,465 8 P2 6D 0.8 2:30 3:15 11,465 8 P2 44B 2.8 3:15 6:00 11,485 8 P2 6D 1.5 6:00 7:30 11,485 8 P2 5 1.5 7:30 9:00 11,500 8 P2 6D 2.5 9:00 11:30 11,500 8 P2 6C 1.0 11:30 12:30 11,500 Set of inj hd. Bit #11 found to be well worn w/no window damage, 1/16"+ UG. MU bit #3R1 (DSl11), BHA#19. MU new motor, orienter and jars. Cut 88' coil. MU CT connector. Pull test to 30K. Pressure test failed to hold any pressure. Pull connector, no O-rings. Rebuild coil connector w/used O-rings. Pull test to 30K. Pressure test to 3K psi. Function test pipe & slip rams, annular and HCR. PU and check coil, OK. MU to BHA. MU injector. Rill. Orient and work thru window by lightly tagging and bumping pump. Tag bottom and correct form 11382 to 11372. Orient and attempt to drill. Stalled motor and lost MWD pulse. Could not regain pulse. POll to check tools. No problems on trip out. Check MWD tool. Metal shavings, possibly from thread recut on jars, found on top of pulser. Change out MWD tool. Run in BHA, MU injector hd. RIH. Check MWD & orient tool @ 1700'. RIH. Tag window, correct depth (-)11' & orient to HS from 100R. Ran thru window w/o difficulty. Set down @ 10748. Bumped pump w/2K dn weight, fell through. Ran to bottom w/o difficulty. Tag bottom @ 11384, correct to 11372. Ddlling f/11372 to 11382 @ 75L. Orient tool face around to 90L. Drilling f/11382 to 11413 @ 90L. Very hard and slow @ 11382, 30 to 45 fph after breaking through. Angle starting to drop hard. Drilling from 11413 to 11465 @ 30L to HS w/p-rates from 40 to 20 fph. Wiper trip from 11465 to 10775 w/o difficulties. Drilling f/11465 to 11485 @ 20L. TD hole. Wiper trip to window. Log RA tag, correct +18'. Run back to bottom. Tag @ 11500, 15' deeper. Corrected TD for hole is 11500' DIL. Spot 40 bbls fresh FIo-Pro mud w/high LSRV (80,000) across open hole and up into casing while pulling up into window. POH. Flag EOP @ 10650. Fill last 3000' w/water. Lay down BHA. Bit well worn and rung out, 3/32" undergauge. D26RD Detailed Activity Summary.xls Page 18 of 19 11/6/98 UNOCAL ) Date PH CL OP Hours UNOCAL Alaska Detailed Activity Report McArthur River Filed D-26RD From To Depth UNOCAL Activity 8 P4 28 8 P4 13A 8 P4 28 8 P4 44F 8 P4 13A 8/10/98 8 Pll 37 8 P4 5 8 P4 44F 8 P4 28 13 P1B 1E 8/11/98 13 PIB 1E 13 P1B 1F 13 P1B 1E 8/12/98 13 P1B 1E 8/13/98 13 PIB 1E 3.0 12:30 15:30 11,500 3.5 15:30 19:00 11,500 2.0 19:00 21:00 11,500 0.8 21:00 21:45 11,500 2.3 21:45 0:00 11,500 0.5 3.5 0:00 0:30 11,500 0:30 4:00 2.0 4:00 6:00 0.5 6:00 6:30 17.5 6:30 0:00 10.5 12.5 1.0 24.0 12.0 0:00 10:30 23:00 0:00 0:00 10:30 23:00 0:00 0:00 12:00 Rig up to run liner. Hold pre job safety meeting. ' Run 45 jts 2-7/8" 6.4# L80 liner, pre drilled w/16 hpf, 3/8" diameter. RD liner running tools. MU liner top guide. PU inj hd. Cut coil and MU coil connector. Pull test to 30K, pressure test to 4K psi. MU coil LBRT assembly. Run LBRT assembly into liner. Engage liner & PU liner 6" to test latch. Remove slips and dog collar. MU injector head. RIH w/liner checking up &dn wts every 2000'. Tie in to EOP flag @ 10650. Run through window and to bottom w/o difficulties, smooth trip in. Tag bottom @ 11497. Hold pre job safety meeting Mix 50 bbls bleach breaker. RU to mix & pump KCL. Pump 50 bbls 3%KCL/FIW. Pump 5/8" ball to seat w/33 bbls. Release from liner w/3200 psi. Shoe @ 11497, TOL @ 10051. Finish displacing mud w/ 215 bbls KCL. Line up returns to prod. separator. Pump 42 bbls 4 ppb lith hypochlodte breaker w/3% KCL/FIW. POH @ 45 fpm pumping breaker from bottom to 10500. Bleach in place @ 4 AM. No Iosse POH pumping 2.5 bpm. Break and lay dn Baker liner and CT tools. Rig down CTD equipment. Nipple down stack & riser. Start gas lift on well. Rig dn all D/S CT equip. Load boat. Blow down reel. Flush out all equipment & lines w/fresh water. Clean pits. Prep loads for boat and start loading 2nd boat. Load out boat ¢Y2, MN Champion, w/ remainder of CTD equipment. Clear drill deck in front of rig. Prep to skid rig. Skid rig west to allow to pass east crane. Skid rig south. Skid rig east to pass stair way landing. Finish skidding over SE leg. Load boat w/mud product and Epoch unit, offioad production break room. Clean decks. Breaking FIo-Pro mud in reserve tanks w/bleach. Reinstall stairs and handrails, clean deck. Rig down. Transfer mud from, drain and clean I reserve pit. Move pit to east side of platform by boat. Set food storage skid, drlg parts house, production break room. Misc cleaning projects. Set all pipe rack sections and deck panels. Draining FIo-Pro mud from 2nd reserve pit to production. Rig down. Finish draining FIo-Pro drlg mud from reserve to production via waste water tank. Clean reserve and mix pits. Move ladder to south side rig. Reroute power lead bundle from south side of rig to north side. Hook up service lines. Repair air line. Clean decks and pick up all work areas. D26RD Detailed Activity Summary.xls Page 19 of 19 11/6/98 UNOCAL DOLLY VARDEN Platform D-26 slot #A1-7 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref: D-26rd st1 coil tubing Our ref: svy6181 License: Date printed: 11-Aug-98 Date created: 2-Aug-98 Last revised: 9-Aug-98 Field is centered on n60 50 4.803,w151 36 18.018 Structure is centered on n60 48 20.815,w151 38 22.052 Slot location is n60 48 28.215,w151 37 57.565 Slot Grid coordinates are N 2490830.384, E 208463.820 Slot local coordinates are 751.50 N 1214.80 E Projection type: Alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North DOLLYVARDEN Pla*' ~,D-26 McArthur River Field,' ..... Cook Inlet, Alaska Your ref: D-26rd ';oil tubing Last revised: 9-/-,._~--98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 -4411.68 100.00 0.25 51.00 100.00 0.14 N 0.17E 0.25 -4411.51 200.00 0.25 30.00 200.00 0.46 N 0.45 E 0.09 -4411.13 300.00 0.25 2.00 300.00 0.87 N 0.56 E 0.12 -4410.71 400.00 0.75 7.00 399.99 1.74 N 0.65 E 0.50 -4409.85 500.00 1.00 8.00 499.98 3.25 N 0.85 E 0.25 -4408.32 600.00 0.75 64.00 599.97 4.40 N 1.56 E 0.85 -4407.05 700.00 0.25 102.00 699.97 4.64 N 2.36 E 0.57 -4406.66 800.00 0.50 58.00 799.97 4.83 N 2.95 E 0.36 -4406.36 900.00 0.50 92.00 899.96 5.05 N 3.75 E 0.29 -4405.98 1000.00 0.25 124.00 999.96 4.91 N 4.37 E 0.32 -4406.00 1100.00 0.75 141.00 1099.96 4.28 N 4.96 E 0.52 -4406.50 1200.00 0.75 135.00 1199.95 3.31 N 5.84 E 0.08 -4407.27 1300.00 0.75 106.00 1299.94 2.66 N 6.93 E 0.38 -4407.69 1400.00 4.25 61.00 1399.83 4.28 N 10.80 E 3.76 -4405.33 1500.00 7.75 42.00 1499.28 11.09 N 18.56 E 3.98 -4397.11 1600.00 9.00 28.00 1598.22 23.01 N 26.74 E 2.38 -4383.80 1700.00 9.75 29.00 1696.88 37.32 N 34.52 E 0.77 -4368.22 1800.00 11.50 28.00 1795.17 53.53N 43.31 E 1.76-4350.58 1900.00 12.75 29.00 1892.93 71.98 N 53.34 E 1.27 -4330.50 2000.00 15.50 28.00 1989.90 93.44 N 64.96 E 2.76 -4307.16 2100.00 17.75 28.00 2085.71 118.70 N 78.39 E 2.25 -4279.73 2200.00 19.50 28.00 2180.47 146.89 N 93.38 E 1.75 -4249.10 2300.00 21.25 30.00 2274.22 177.33N 110.28E 1.88-4215.91 2400.00 23.50 28.00 2366.68 210.63N 128.71 E 2.38-4179.60 2500.00 25.25 29.00 2457.76 246.89N 148.41 E 1.80 -4140.14 2600.00 28.00 30.00 2547.15 285.88N 170.49E 2.79-4097.53 2700.00 27.25 34.00 2635.76 325.19N 195.03E 2.00-4054.11 2800.00 26.50 36.00 2724.96 362.22N 220.95E 1.17-4012.65 2900.00 28.75 36.00 2813.56 399.741'4 248.20E 2.25-3970.46 3000.00 31.75 36.00 2899.93 440.49N 277.81 E 3.00 -3924.62 3100.00 34.00 37.00 2983.91 484.11 N 310.10E 2.31-3875.43 3200.00 35.50 36.00 3066.07 529.93 N 344.00E 1.60-3823.76 3300.00 39.50 36.00 3145.39 579.17N 379.77E 4.00 -3768.38 3400.00 40.50 37.00 3222.00 630.84N 418.01 E 1.19 -3710.12 3500.00 41.50 35.00 3297.47 683.91 N 456.56 E 1.65 -3650.42 3600.00 42.00 36.00 3372.08 738.12N 495.23E 0.83 -3589.59 3700.00 42.25 35.00 3446.24 792.73N 534.18E 0.72 -3528.31 3800.00 43.25 35.00 3519.68 848.33N 573.11 E 1.00 -3466.05 3900.00 43.00 34.00 3592.66 904.66N 611.83E 0.73-3403.12 4000.00 44.00 36.00 3665.20 961.04 N 651.32E 1.70-3340.00 4100.00 42.75 37.00 3737.89 1016.25N 692.16E 1.43 -3277.76 4200.00 42.25 37.00 3811.62 1070.20 N 732.82 E 0.50 -3216.77 4300.00 42.00 37.00 3885.79 1123.77 N 773.19 E 0.25 -3156.23 4400.00 42.00 36.00 3960.10 1177.56 N 812.99 E 0.67 -3095.58 4500.00 42.00 36.00 4034.42 1231.69N 852.32E 0.00-3034.69 4600.00 42.00 35.00 4108.73 1286.16N 891.17E 0.67-2973.56 4700.00 41.00 35.00 4183.63 1340.44N 929.18E 1.00 -2912.79 4800.00 41.25 36.00 4258.95 1393.98N 967.37E 0.70-2852.70 4900.00 41.50 37.00 4334.00 1447.11 N 1006.69E 0.71 -2792.79 All data is in feet unless otherwise stated. Coordinates from slot #A1-7 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 6009.29 on azimuth 44.22 degrees from wellhead. Vertical section is from tie at N 3742.93 E 3728.68 on azimuth 11.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL DOLLY VARDEN Pla¢ q,D-26 McArthur River Field,' ..... Cook Inlet, Alaska SURVEY LISTING Page 2 Your ref: D-26rd soil tubing Last revised: 9-A-~,98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth COORDINATES Deg/100ft Sect 5000.00 41.25 38.00 4409.04 1499.55N 1046.92E 0.71 -2733.38 5100.00 41.50 37.00 4484.08 1551.99 N 1087.16 E 0.71 -2673.97 5200.00 40.75 38.00 4559.40 1604.17N 1127.19E 1.00 -2614.85 5300.00 40.50 39.00 4635.30 1655.13N 1167.72E 0.70-2556.83 5400.00 39.75 39.00 4711.77 1705.21 N 1208.28E 0.75-2499.66 5500.00 38.00 38.00 4789.62 1754.32N 1247.36E 1.86 -2443.74 5600.00 37.75 39.00 4868.55 1802.37N 1285.57E 0.66-2389.04 5700.00 37.25 39.00 4947.89 1849.68 N 1323.88 E 0.50 -2335.03 5800.00 36.00 41.00 5028.14 1895.38N 1362.21 E 1.73-2282.60 5900.00 36.75 42.00 5108.66 1939.79N 1401.51 E 0.96-2231.24 6000.00 39.00 42.00 5187.59 1985.42N 1442.59E 2.25 -2178.34 6100.00 40.00 42.00 5264.75 2032.68N 1485.15E 1.00-2123.53 6200.00 42.00 43.00 5340.22 2081.04N 1529.48E 2.10-2067.29 6300.00 41.50 43.00 5414.83 2129.74N 1574.89E 0.50-2010.51 6400.00 41.75 42.00 5489.58 2178.72N 1619.77E 0.71 -1953.57 6500.00 40.75 44.00 5564.76 2226.94 N 1664.72 E 1.65 -1897.35 6600.00 40.50 43.00 5640.66 2274.17N 1709.54E 0.70-1842.13 6700.00 40.00 45.00 5716.99 2320.64N 1754.41 E 1.39 -1787.63 6800.00 39.50 45.00 5793.87 2365.86 N 1799.63 E 0.50-1734.30 6900.00 39.50 44.00 5871.04 2411.23N 1844.21 E 0.64-1680.95 7000.00 39.00 45.00 5948.48 2456.35N 1888.55E 0.81 -1627.88 7100.00 38.00 43.00 6026.74 2501.12 N 1931.80 E 1.60 -1575.39 7200.00 37.00 44.00 6106.07 2545.28 N 1973.70 E 1.17 -1523.75 7300.00 38.50 45.00 6185.14 2588.94N 2016.61 E 1.62 -1472.41 7400.00 37.25 45.00 6264.08 2632.35 N 2060.02 E 1.25 -1421.21 7500.00 35.75 46.00 6344.46 2674.04 N 2102.44 E 1.61 -1371.89 7600.00 35.75 46.00 6425.62 2714.63N 2144.47E 0.00 -1323.73 7700.00 36.00 48.00 6506.65 2754.59N 2187.32E 1.20 -1276.03 7800.00 36.75 49.00 6587.16 2793.88 N 2231.74 E 0.96 -1228.66 7900.00 37.75 51.00 6666.77 2832.78N 2278.11 E 1.57 -1181.30 8000.00 37.75 51.00 6745.84 2871.30N 2325.69E 0.00-1134.05 8100.00 38.50 52.00 6824.50 2909.73N 2374.01 E 0.97-1086.75 8200.00 38.50 54.00 6902.77 2947.19N 2423.72E 1.24 -1040.13 8300.00 40.00 54.00 6980.20 2984.38N 2474.91 E 1.50 -993.47 8400.00 41.25 54.00 7056.10 3022.65N 2527.58E 1.25 -945.46 8500.00 40.00 56.00 7132.00 3060.00 N 2580.90 E 1.80 -898.22 8600.00 39.75 55.00 7208.75 3096.31 N 2633.74E 0.69 -852.10 8700.00 39.75 55.00 7285.63 3132.99N 2686.12E 0.00 -805.71 8800.00 38.25 56.00 7363.34 3168.64N 2737.97E 1.63 -760.43 8900.00 37.75 56.00 7442.14 3203.07N 2789.01 E 0.50 -716.51 9000.00 37.50 57.00 7521.35 3236.76 N 2839.92 E 0.66 -673.33 9100.00 37.00 56.00 7600.95 3270.17N 2890.39E 0.79 -630.53 9200.00 36.75 57.00 7680.94 3303.29 N 2940.43 E 0.65 -588.09 9300.00 37.50 57.00 7760.67 3336.16N 2991.05E 0.75 -545.78 9400.00 37.00 58.00 7840.28 3368.68 N 3042.09 E 0.79 -503.72 9500.00 36.75 57.00 7920.27 3400.92 N 3092.70 E 0.65 -462.03 9600.00 36.75 58.00 8000.40 3433.07N 3143.16E 0.60 -420.46 9700.00 36.50 58.00 8080.65 3464.69N 3193.76E 0.25 -379.39 9800.00 36.50 58.00 8161.04 3496.21 N 3244.20E 0.00 -338.44 9900.00 37.00 59.00 8241.16 3527.46N 3295.22E 0.78 -297.63 All data is in feet unless otherwise stated. Coordinates from slot #A1-7 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 6009.29 on azimuth 44.22 degrees from wellhead. Vertical section is from tie at N 3742.93 E 3728.68 on azimuth 11.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL DOLLY VARDEN Pla, .__...,q,D-26 McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTIi',' Page 3 Your ref: D-26rd '~_~coil tubing Last revised: 9-Aug-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N AT E S Deg/100ft Sect 10000.00 37.25 61.00 8320.90 3557.64N 3347.48E 1.23 -257.63 10100.00 37.00 60.00 8400.63 3587.35N 3400.01 E 0.65 -218.03 10200.00 37.50 62.00 8480.23 3616.69N 3452.95E 1.31 -178.72 10300.00 39.00 66.00 8558.78 3643.79N 3508.58E 2.89 -141.07 10400.00 37.00 65.00 8637.57 3669.30 N 3564.60 E 2.09 -104.89 10500.00 36.50 66.00 8717.70 3694.12N 3619.05E 0.78 -69.71 10600.00 37.00 66.00 8797.83 3718.45N 3673.71 E 0.50 -34.96 10700.00 37.00 66.00 8877.69 3742.93 N 3728.68E 0.00 0.00 10743.00 39.40 66.00 8911.48 3753.75N 3752.97E 5.58 15.44 10778.00 43.40 62.90 8937.73 3763.75N 3773.84E 12.84 29.41 10789.00 46.70 61.90 8945.50 3767.35N 3780.73 E 30.68 34.32 10799.00 49.70 61.00 8952.16 3770.92N 3787.28E 30.74 39.12 10811.00 52.50 59.90 8959.70 3775.53N 3795.40E 24.40 45.25 10821.00 54.40 59.00 8965.65 3779.61 N 3802.32E 20.33 50.63 10839.50 56.70 57.40 8976.12 3787.65N 3815.28E 14.33 61.10 10850.50 58.00 56.40 8982.05 3792.71 N 3823.04E 14.08 67.60 10860.50 60.30 55.50 8987.18 3797.51 N 3830.15E 24.26 73.73 10871.50 64.30 54.50 8992.29 3803.10N 3838.13E 37.24 80.80 10881.50 68.70 53.60 8996.28 3808.48N 3845.55E 44.77 87.55 10891.50 73.20 52.70 8999.54 3814.15N 3853.11 E 45.80 94.62 10901.50 82.90 51.60 9001.61 3820.15N 3860.83E 97.59 102.03 10911.50 89.40 51.20 9002.28 3826.37N 3868.62E 65.12 109.68 10919.50 88.90 50.50 9002.40 3831.42N 3874.82E 10.75 115.87 10936.50 88.60 50.80 9002.77 3842.20N 3887.96E 2.50 129.05 10956.00 90.10 49.70 9002.99 3854.67 N 3902.96 E 9.54 144.26 10990.00 91.50 47.60 9002.52 3877.12N 3928.47E 7.42 171.36 11004.00 92.30 46.10 9002.06 3886.69N 3938.68E 12.14 182.77 11033.00 93.70 44.70 9000.54 3907.03N 3959.30 E 6.82 206.81 11046.00 95.20 43.70 8999.53 3916.32N 3968.34E 13.85 217.72 11058.00 95.80 41.60 8998.38 3925.10 N 3976.43 E 18.12 227.94 11074.00 95.50 39.80 8996.80 3937.17N 3986.81 E 11.35 241.84 11102.00 95.20 36.10 8994.19 3959.15N 4003.95E 13.20 266.80 11136.00 94.50 32.80 8991.32 3987.09 N 4023.11 E 9.89 297.99 11161.00 96.10 32.20 8989.01 4008.08N 4036.49E 6.83 321.23 11179.00 96.80 31.70 8986.98 4023.26 N 4045.95 E 4.77 337.99 11210.00 95.20 31.10 8983.74 4049.57N 4062.02E 5.51 366.98 11232.00 96.30 29.70 8981.54 4068.45 N 4073.09 E 8.07 387.69 11246.00 97.10 30.70 8979.91 4080.47N 4080.09E 9.11 400.86 11269.00 98.60 31.80 8976.77 4099.94N 4091.91 E 8.06 422.31 11298.00 98.10 28.90 8972.55 4124.70N 4106.40E 10.04 449.46 11320.00 98.90 28.50 8969.30 4143.79N 4116.85E 4.06 470.25 11340.00 98.50 27.10 8966.28 4161.27N 4126.07E 7.20 489.22 11374.00 98.70 24.60 8961.19 4191.53N 4140.73E 7.29 521.79 11394.00 96.00 24.20 8958.63 4209.59N 4148.92E 13.64 541.13 11417.00 94.30 24.00 8956.57 4230.50N 4158.27E 7.44 563.48 11447.00 92.10 22.80 8954.89 4257.98N 4170.17E 8.35 592.79 11477.00 94.10 23.40 8953.27 4285.54N 4181.92E 6.96 622.13 11500.00 95.63 23.86 8951.32 4306.53N 4191.11 E 6.94 644.54 All data is in feet unless otherwise stated. Coordinates from slot #A1-7 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 6009.29 on azimuth 44.22 degrees from wellhead. Vertical section is from tie at N 3742.93 E 3728.68 on azimuth 11.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Jui, 6, ;998 2'48PM U14OCAL CORP, No,90:4 .P, : UNOCALI - ._ ii iiiiii ii ...... .. i Dolly Varden Platform Coil Tubing Drilling ..... · .... IIII I IIII M Illll . ... July 06, 1998 Alaska Oil & Gas Conservation Commislon 3001 Porcupine Drive Anchorage, Alaska 99501 AttentiOn: Blair Wondzell RE: Dolly Varden Platform Well D-26RD Perforated Liner. Mr. Wondzeil, The Dolly Varden Well D-26rd will be completed with a perforated liner. The Finer details are as follows: Liner Type: 2,250' of 2-7/8", 6,4~/ft, L-80 tubing perforated 16 holes (3/8" diameter) per foot, Shoe Depth: 12,300' Hanger: BeT Liner Scoop Head with GS internal fishing neck. The hanger is non- sealing. Completion: The liner will not be cemented. Tubing tail: Window: Note: 10,149' Existing 10,740' (Through tubing whipstock) The existing G-2, G-3, and G-4 intervals will remain open to production. I hope this answers the questions regarding the completion of D-26rd. If you need any additional information, please contact me directly at 907-263-7642. Sincerety, .., Steven Lambe JUL 0 6 't998 716t98 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 2, 1998 ADMINISTRATIVE APPROVAL NO. 80.74 Re: The application of Union Oil Company of California, operator of the Trading Bay Unit (TBU), to drill, complete and produce the TBU D-26RD. Mr. Rick D. Cross Senior Landman Unocal Alaska Resources UNOCAL Corporation P O Box 196247 Anchorage, AK 99519-6247 Dear Mr. Cross' Your application of June 22, 1998 for a permit to drill the TBU D-26RD development well indicates that the drilling and completion of the well will provide additional oil recovery from the Middle Kenai "G" oil Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU D-26RD well pursuant to Rule 5 of Conservation Order No. 80. DONE at Anchorage, Alaska and dated July 2, 1998. Chairman ;ton Camiil60echsli Commissioner Robert N. Christenson, P.E. Commissioner TONY KNOWLE$, GOVEF~NOt~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 14, 1998 Dale Haines Drilling Manager Union Oil Company of California P O Box 196247 Anchorage, AK 99519-6247 ac~ Trading Bay Unit D-26RD Union Oil Company of California Permit No. 98-129 Sur. Loc. 751'FSL, 1215'FWL. Sec. 6-8N-13W. SM Btmnhole Loc. 460'FSL, 936'FEL, Sec. 32-9N-13W. SM Dear Mr. Haines: Enclosed is the approved application for permit to redrill thc above referenced well. The permit to redrill docs not exempt you from obtaining additional permits required bv law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Bloxvout prevention equipment (BOPE) must be tested in accordance xvith 20 AAC 25 035. Sufficient notice (approximately 24 hours) must bc given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting thc Commission at 279-1433. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosurcs CC~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL ,- ND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrill: X lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen: Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 106 KB above MSL feet r~,=,=--d,%,~__, .... ~'";:'_.... 3. Address 6. Property Designation Middle Kenai "G" PO Box 196247, Anchorage AK 99519 ADL 18729,/'/'7 4. Location of well at surface 7. Unit or property Name 11. Type BOnd (see 20 AAC 25.025) 751' FSL, 1,215' FWL, Sec. 6-8N-13W-SM Trading Bay Unit At top of productive interval 8. Well number Number U62-9269 784' FNL, 11' FEL, Sec.6-8N-13W-SM D-26RD At total depth 9. Approximate spud date Amount $200,000 460' FSL, 936' FEL, Sec.32-9N-13W-SM 7/22/1998 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and -I-VD) property line Top G-4: 960' 5,280 feet TD G-4: 470' feet 3,840 12,300' MD, 8916' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 10,742' feet Maximum hole angle: 91 DEG Maximum surface 1,608 psig At total depth (TVD) 2,500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Exst 13-5/8" 61 # J-55 Buttress 3,306' 45' 45' 3,306' 3,148' 2,750 sx Exst 9-5/8" 40,43.5,47 N-80, Pl10 Buttress 10,239' 41' 41' 10,239' 8,501' 2,690 sx Exst 7" 29# N-80 X-Line 1,870' 10,082' 9,010' 11,952' 9,877' 650 sx $-7-y" ?-"~/(t 6- ff ~--~ 2~¢---~ ' ~O~C~'~'O 1,~,tdO* ~,'lf · 19. To be completed for Redril.. Re-entry. and Deepen Operations. ORIGINAL Present well condition summary Total depth: measured 11,969' feet Plugs (measured) true vertical 9,885' feet. .~,:,.-~ ~ Effective depth: measured 11,048' feet Junk (measured) Plugged Back with Cement to 11,048' true vertical 9,148' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3306 13-3/8" 2750 sx 3,306' 3,148' Intermediate Production 10239 9-518" 2690 sx 10,239' 8,501' Liner 1870 7"' 650 sx 11,952' 9,877' PeRoration depth: measured Attached true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: Signed: ./..~[:...C Otl L. L,,:~ Title: Drilling Manager Date: Commission Use Only Permit N~m~e r_ r APl number I Approva, date ¢, ] ~ ~ 50- '~ ~ ~ - Z O Z~ (5 '" Ct "~ ~/¢/ for other requirements Conditions of approval Samples required: [ ] Yes ,D~.No Mud Icg required: [ ] Yes [,,~'No Hydrogen sulfide measures [ ] Yes [~ No Directional survey required ~ Yes [ ] No Required working pressure for BOPE [ ]2M; ~]3M; [ ] 5M; [ ] 10M; [ ] 15M Other: 0nginal Signed By by order of Approved by David W. Johnston Commissioner the Commission Date:? '/,~'"- Form 10-401 Rev. 12-1-85 Submit in triplicate UNOCAL Dolly Varden Platform Coil Tubing Drilling Form 10-401 Attachment: Dolly Varden Platform Well D-26 Perforations: Zone Measured Depth True Vertical Depth G-2 10,668 - 10,688 8,842' - 8,858' G-3 10,692 - 10,709 8,862' - 8,875' G-3 10,735 - 10,765 8,896' - 8,920' G-4 10,776 - 10,860 8,929' - 8,997' HB 1 11,210- 11,243 9,283' - 9,310' HB 2 11,273 - 11,306 9,335'- 9,393' HB 4 11,468 - 11,615 9,496'- 9,611' HB 5 11,642 - 11,750 9,632'- 9,720' HB 6 11,828 - 11,858 9,778'- 9,802' CTD.DOC 6/16/98 UNOCAL ) Dolly Varden D-26 Procedure Objective: Drill a lateral leg in the G-zone intervals G-3 and G-4 in DVP well D-26. The well is currently completed in the G-zone. The coil tubing redrill will be completed through tubing and the open hole section will be completed with 2-7/8" perforated liner. The procedure will cover the following step in detail: a) Moire equipment to platform. b) Removing scale in the 4-1/2" tubing and drilling out tubing tail restrictions to 3.805", c) Under reaming casing to 6.00" to ensure proper setting of the whipstock. d) E-Line orient and set a through tubing whipstock, e) Cut the window off the whipstock, f) MOB out and change out to 2" Coil Tubing, g) Drill Build Section h) Drill lateral Section to a TD of 12,315'. i) Complete well with perforated liner j) RD coil equipment, Test well, and evaluate. a) Mobe Equipment to Platform 1) RU coil tubing unit. 2) Pressure test all surface pressure lines to 4,500 psi. Fill coil with 3% KCI. Function and pressure test BOP's as per Unocal Alaska specs. b) REMOVE SCALE FROM 4-1/2" TUBING. 3) Measure up Slip Type Coil Connector; pull test to 25K. 'Blue Lock Tite' all connections. · 2-7/8" Grapple type coil connector. · 2-7/8" Dual Check Valves · 2-7/8" Hydraulic Disconnect · 2-7/8" Circulating Sub · 2-7/8" BOT NAVI-DRILL MACH 1P HIGH-TORQUE PDM · 3.805" Metal Muncher button type mill dressed for barium sulfate 4) RIH milling scale from the 4-1/2" tubing. Tubing tail depth is 10,149'. c) Under reaming casing to 6.00" to ensure proper setting of the whipstock 5) With coil in lubricator, SI swab valve and bleed off pressure. Break out 3.805" mill and MU a BOT 3-5/8" under reamer with blades dressed for 6" diameter. 6) 'Blue Lock Tite' all connections. · 2-7/8" Grapple type coil connector. · 2-7/8" Dual Check Valves · 2-3/8" PAC Box by 2-3/8" Reg Pin Crossover · 3-1/8" Dailey Up and Down Jars DVP D-26 Coil Tubing Redrill Procedure 6/17/98 UNOCAL Dolly Varden D-26 Procedure · 2-3/8" Reg Box by 2-3/8" PAC Rin Crossover · 2-7/8" Hydraulic Disconnect · 2~7/8" Circulating Sub · 2-7/8" BOT NAVI-DRILL MACH 1P HIGH-TORQUE PDM · 2-3/8" PAC pin by 2-3/8" reg box crossover · Drilex Under reamer dressed with 6" blades. 7) RIH with coil to 10,200'. RIH milling scale from the 7" casing to 10,900' d) E-Line orient and set a through tubing whipstock 8) MU Kinley Caliper tool string consisting on .125" wire. RIH at 60 fpm logging tubing and 7" casing (Below 10,150') to a depth of 10,900'. POOH with Kinley tools. Vedfy data and rig down slickline. 9) RU E-line. RU POS tool, Shooting GR/CCL, Baker #10 setting setting tool with slow burn charge, and BOT's Mechanical Thru-Tubing mechanical whipstock in the horizontal position. 10) RIH with whipstock assembly. Position whipstock top at 10,735' and set whipstock. RD E- Line. ~ b) Cut the window off the whipstock. 11) RU Coil Tubing Unit. Pressure test all surface pressure lines to 4,500 psi. Function and pressure test B©P's as per Unocal Alaska specs. 12) Measure up Slip Type Coil Connector; pull test to 25K. 'Blue Lock Tite' all connections. · 2-7/8" Grapple type coil connector. · 2-7/8" Dual Check Valves · 2-7/8" Hydraulic Disconnect · 2-7/8" Circulating Sub · 2-7/8" BOT NAVI-DRILL MACH 1P HIGH-TORQUE PDM · 3.75' 1.75" OD Flex shaft · 3.80" Window Dimple Mill. 13) Cut +/- 6 window w/same down weight as directed by experienced B©T representatives advice. 14) Verify window completely cut as indicated on mill from wear patterns across dimple portion of mill face. 15) Rig down coil tubing unit. Backload 1.75" coil unit. f) MOB out and change out to 2" Coil Tubing, DVP D-26 Coil Tubing Redrill Procedure 6/17/98 UNOCAL Dolly Varden D-26 Procedure 16) Change out BOP, injector head, and goose neck to accommodate 2" coil. 17) Skid rig #76 from Leg B-1 to Leg A-1 and center up over well D-26. 18) Call out and RU 2" coil equipment. 19) Kill well with 3% KCI mixed in FIW. Load annulus with KCI bdne. 20) NU BOP's per attached layout diagram. Function and pressure test BOP's to 5,000 psi with water. 21) Spot and rig up surface support equipment per attached layout diagram. 22) Build the solids free Flow Pro mud system and test properties. g) Drill Build Section 23) MU the motor head assembly as noted below: a) 2-7/8" OD Drilling coil connector (Previously Installed) b) 2-7/8" OD Dual Check Valves c) 2-7/8" OD Hydraulic Disconnect d) 2-7/8" OD Circulating Sub e) 2-7/8" BOT NAVI-DRILL MACH 1P HIGH-TORQUE PDM f) 3.80" window string mill g) 3.625" formation mill 24) RIH with milling assembly and tag up on top of window. 25) Pumping 3% KCI brine, dress out window per BOT representative on site. Pump a minimum of 2 hole volumes to clear any residual oil and gas taking returns down flowline. 26) Displace well over to FlowPro mud system. 27) MU the motor head assembly as noted below: h) 2-7/8" i) 2-7/8" j) 2-7/8" k) 2-7/8" I) 2-7/8" m) 2-7/8" n) 2-7/8" o) 3-1/8" p) 3-1/8" q) r) OD Drilling coil connector (Previously Installed) OD Dual Check Valves OD Hydraulic Disconnect OD Circulating Sub OD Non Rotating Joint Top half OD Non Rotating Joint Bottom half OD Orienter set for 15 degree clicks MWD collar UBHO sub 2-7/8" Drilex Systems Dual power section Non-mag Motor with 2.5o Bent housing. 3.75" HYCALOG DS111HGJU PDC bit DVP D-26 Coil Tubing Redrill Procedure 6/17/98 UNOCAL Dolly Varden D-26 Procedure 28) Drill build section targeting a 49°/100' build rate. 29) Short trip to window every 100'. Run wiper trip to tubing tail every 200'. h) Drill lateral Section 30) POOH at end of build section to change out motors with .5° bent housing on same tool string. 31 ) Replace HYCALOG DS111HGJU build bit with a HYCALOG 3.75" DS49HGJU PDC bit. 32) Drill lateral section to 12,300' per the above wiper trip schedule. Maintain the mud properties to prevent sticking. 33) At TD of the well, displace old FIoPro Mud and spot in new mud with a minimum of 80,000 PSRV in the open hole section. POOH. i) Complete well with perforated liner 34) PU completion as noted below. a) 2-7/8" OD STL Box Bull Nose with Baker Oil Tools LBRT assembly. b) 76 Joints 2-7/$" OD, 6.4#, L-80, STL BxP, Predrilled liner with 16 @ .375" holes per foot c) 3.80" OD tubing head re-entry guide with 3-1/2" Nominal GS internal fishing neck 35) RIH with liner and position end of liner at window top. Displace FIoPro with 6% KCI mixed in FIW. Release from liner. 36) POOH with coil. SI well at master valves. 37) Displace all surface lines and coil to production with Nitrogen. 38) RD Coil tubing unit and associated equipment. 39) Return well to production and monitor well rate in test separator on houdy hot sheet. DVP D-26 Coil Tubing Redrill Procedure 6/17/98 9-5/8' 40, 43.5, 47~, N-80 & P-110 Butt Csg Completed 5120/9[ ~£LL D-86 All ne~sureMent~ are RKB to top oF equipment 4[' CIV 4.5' Tbg l-longer 308~ C~co ~RDP-4A T~FV ~CS~V, 3.813~ pro~e ~/ ~B-6 lock 0'-[0,149' 4,5' 12.~'~' L-SO But~re~ tubing ~/ side pockets, RK latc~ 8,224' 4,125' 5,767' 7,746' 8,482' 8,997' 9,477' 9,996' TOL 7' 8 [0,088' 9-5/8' Csg 8 [0,839' Fish: ~ Collet Fqngers 7' 89~ N-SO X-Une Fish: 2-1/4~ Underreomer PBTD 8 [1,905' TD 8 [1,969' 10,05E' lO,Ill' i0,[38' 15' Baker PBR w/ scoo¢ ¢.75' I.D. ijt 4-1/~' L-BO Buttress tubing. B~ker SABL-3 P~cker. 4.00' I.D. 6' nittout extenslor~ X nippte 3,813' LD. Bake~ Node( ~ Hydrc-~rip Sub. 4.00' r.~. ~{reUme Re-enVy gu{de, 4.00' Pee~orat!oo~. 10.568' - 10,588' '~ 10,693' - lO,70g' / , 10,7~0' - 10.765'" , - -'%5' 10.78~' lO~i~' ~(~ ' ~v~ g SPF ,4 SPF 4. SPF G SPF & SPF Squeezed '" .... ' ]3-5. 11,648.'-750' · , · o , .... ' 3-3 B-6 1L886'-858' ~ SP? ....' 1. "' x Caslmq OeO:ch set ~cross Bench 3 i~val ' ''''~ B-4 r , 1L443' reduces [.D. b~ . ~ . iL796' XN Nl~e 3,8~3' L3, ~/ 3.7~' No - Go. B-6 H~TGO' Top oP ~SH - ':.',~':.;t:..:,J,." Virellme tOO[ string Revision O~te, 11/11/94 ~'.,."..3~{~'.r' in isolation packer. ~ Revl~ed By, ~Q~/~vo Reason, Updo~ Pre~ous Revision: 4/14/94 RKB = 40.5' SIZE · Varden Well No. 26 Proposed Completion 4/03/98 CASING AND TUBING DETAIL GI~kDE CONN ID TOP BTM. 20" 94 H40 19.t24 Surtace 673' 13-3/8" 61 L55 Seal L~x:k 12.51 Surlhcx, 3,306' 9-5/8" 40,47 N~80 &P-II0 BTC 8.755 Sul'k~ee 10,239' 7' 29 N-80 X-Line 6,184 10,082 11,969' Tubing 4-1/2' 12.6 1,-80 BT&CAB "t.95 Surthc¢ 10.149' 2-7/8' SL 6.4 L-80 FL4S 2.441 10,050 12,30& JEWELRY DECI'AIL NO. Depfl~ ID OD Item 8 9 -- G-2 PERFORATION HISTORY Date 7rune 'Fop Btm Mnt spf I Present Condition 3a3/97 . c;-2 !9~68' ?.688' 20' i ~2.00 3/23/97 G-3 10,69Y t0.709' 16' 12.0( 3/23/97 G-3 10,740' 10.765' 25' 12.00 O~n 3/23/97 G4 10,786' 10.860' 74' 12.00 3,~3/97 ~ B-I [ II.210 11 273' 6Y 12.00 [Aband w/Cement 3/23/97 12.00 [Akmd w/Cement 3/23~97 B-3 ] ,390' [ 11 435' 45' ~ 12.00 LAband w/ Cement 3/23/97 B~ 11 826* I 11.858' [ 32' _ 1~:70 Old: PBTD = lt,90Y TD = 1L969' MAX HOLE ANGLE = 43.25© @ 3,800' New: TD 12,300? UNOCAL DOLLY VARDEN Platform D-26 slot #Al-7 McArthur River Field TBU, Cook Inlet, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : D-26Rd Version #5 Our ref : prop2932 License : Date printed : 26-May-98 Date created : 20-May-98 Last revised : 26-May-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 48 20.815,w151 38 22.052 Slot location is n60 48 28.215,w151 37 57.565 Slot Grid coordinates are N 2490830.384, E 208463.820 Slot local coordinates are 751.50 N 1214.80 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-12930'>,,M-28,STEELHEAD Platform PGMS <3700-11700'>,,M-25,STEELHEAD Platform PGMS <12486-15276'>,,M-27,STEEL/{EAD Platform MSS <1103-2265'>,,M-26,STEELHEAD Platform PGMS <2700-9101'>,,M-14,STEELHEAD Platform PMSS <1006-7952'>,,M-15 St,STEELHEAD Platform PMSS <1006-1449'>,,M-15,STEELHEAD Platform MSS <1363-1859'>,,RLF #2,STEELHEAD Platform PGMS <0-2310'>,,RLF #1,STEELHEAD Platform PMSS <808-1165'>,,RLF #2,STEELHEAD Platform MSS <0-735'>,,0B #2,STEELHEAD Platform PGMS <0-857'>,,B1-8,STEELHEAD Platform PGMS <0-785'>,,B1-6,STEELHEAD Platform PGMS <0-7434'>,,M-13,STEELHEAD Platform PGMS <500-928'>,,B1-2,STEELHEAD Platform PGMS <0-5600'>,,M-5,STEELHEAD Platform PMSS <6595-6988'>,,M-1,STEELHEAD Platform PGMS <0-7250'>,,M-1St#1,STEELHEAD Platform PGMS <0-7419'>,,M-2,STEELHEAD Platform PGMS <0-7250'>,,M-3,STEELHEAD Platform GSS <0-1421'>,,*M-4*,STEELHEAD Platform PGMS <0-5185.>,,M-19,STEELHEAD Platform PGMS <0-6440'>,,M-7,STEELHEAD Platform PMSS <1535-4500'>,,M-9,STEELHEAD Platform PMSS <1334-3625>,,M-16,STEELHEAD Platform Closest approach with 3-D Minimum Distance method Last revised Distance 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 26-Aug-96 29-Sep-97 7686.1 6173.3 7475.3 8022.0 4930.6 3147.2 8467.1 8487.2 8126.2 8741.0 9127.6 9093.1 9158 3 3917 9 9042 2 5475 4 7697 5 7697 5 3292 7 6860 4 8659.8 6796.7 8502.0 8518.8 8586.0 M.D. 12300.0 12300.0 12300.0 12300.0 12300.0 10700.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 12000.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 Diverging from M.D. 12300.0 12300.0 12300.0 12300.0 12300.0 11400 12300 12300 12300 12300 12300 12300 12300 12300 12300 12300 12300.0 12300.0 12000.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300.0 PGMS <0-14575'>,,M-30,STEELH5 Platform _ PMSS <10247-10355'>,,M-31,STEELHEAD Platform PMSS <10741-12018'>,,M-31St#1,STEELHEAD Platfo GSS <975-2660'>,,M-29,STEELHEAD Platform PGMS <0-10938'>,,M-29,STEELHEAD Platform PMSS <9365 - 10588'>,,M32ST#1,STEELHEAD Platfo PMSS <1386 - 9833'>,,M-32,STEELHEAD Platform PMSS <8988 - 12583.>,,M32St#2,STEELHEAD Platfo PGMS <0-927'>,,Bl-10,STEELKEAD Platform PMSS <12281 - 12660'>,,M32St#3,STEELHEAD Platf GMS <0-13585'>,,D-24A,DOLLY VARDEN Platform MSS <2450-10125'>,,D-31,DOLLY VAR/DEN Platform GMS <0-10628'>,,D-31Rd,DOLLY VARDEN Platform GMS <0ol1356'>,,D-2ARd,DOLLY VARDEN Platform MSS <6927-12557'>,,D-2,DOLLY VAR/DEN Platform MSS <9482-12425'>,,D-2Rd,DOLLY VARDEN Platform MSS <l1209-14850'>,,D-22,DOLLY VARDEN Platform GMS <0~14600'>,,D-16,DOLLY VARDEN Platform PGMS <10000-14645'>,,D-16Rd,DOLLY VARDEN Platf MSS <1205-10506'>,,D-20,DOLLY VARDEN Platform MSS <7866-12700'>,,D-14,DOLLY VARDEN Platform GMS <0-13600'>,,D-14Rd,DOLLY VARDEN Platform PGMS <0-13700'>,,D-6Rd,DOLLY VARDEN Platform MSS <6662-12195'>,,D-6,DOLLY VARDEN Platform ~SS <l1790-15510'>,,D-6St,DOLLY VARDEN Platfor MSS <8722-13932'>,,D-8,DOLLY VARDEN Platform PGMS <700-12250'>,,D-SRd,DOLLY VARDEN Platform PGMS <0-13111'>,,D-29Rd,DOLLY VARDEN Platform GMS <100o13050'>,,D-29,DOLLY VARDEN Platform PGMS <0-11150'>,,D-43,DOLLY VARDEN Platform GMS <0-11510'>,,D-25Rd,DOLLY VAR/DEN Platform MSS <8330-11350'>,,D-25,DOLLY VARDEN Platform GMS <0-11600'>,,D-41,DOLLY VARDEN Platform GMS <6100-12573'>,,D-40,DOLLY VARDEN Platform PGMS <0~12520'>,,D-40Rd,DOLLY VARDEN Platform MSS <2506-11160'>,,D-32,DOLLY VARDEN Platform GMS <0-12445'>,,D-28,DOLLY VARDEN Platform GMS <0-11000'>,,D-27,DOLLY VARDEN Platform PGMS <0-10300'>,,D-45,DOLLY VARDEN Platform MSS <2727-11000'>,,D-13,DOLLY VARDEN Platform PGMS <6600-10920'>,,D-3Rd2,D6LLY VARDEN Platfo 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 10-Feb-98 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 10-Feb-98 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Julo96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 29-Jul-96 PGMS <8700-11100'>,,D-3Rd,DOLLY VARDEN Platfor 29-Jul-96 GMS <0-10881'>,,D-3,DOLLY VARDEN Platform 29-Jul-96 PGMS <2100-10225'>,,D-15Rd2,DOLLY VARDEN Platf 29-Jul-96 GMS <0-10935'>,,D-15Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <2642-10250'>,,D-5,DOLLY VARDEN Platform 29-Jul-96 GMS <0-10650'>,,D-5Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <6059-16650'>,,D-19St,DOLLY VARDEN Platfor 29-Jul-96 MSS <2944-7950'>,,D-19,DOLLY VARDEN Platform 29-Jul-96 PGMS <0-12345'>,,D-46,DOLLY VARDEN Platform 29-Jul-96 GMS <5600-10700'>,,D-9,DOLLY VARDEN Platform 29-Jul-96 PGMS <0~10900'>,,D-9Rd,DOLLY VAR/DEN Platform 29-Jul-96 MSS <2701-11682'>,,D-ii,DOLLY VARDEN Platfoz-m 29-Jul-96 MSS <10665-11808'>,,D-17,DOLLY VARDEN Platform 29-Jul-96 GMS <0-10800'>,,D-17Rd,DOLLY VAR/DEN Platform 29-Jul-96 MSS <0~12071'>,,D-1,DOLLY VARDEN Platform 29-Jul-96 MSS <10156-13600'>,,D-30,DOLLY VA_RDEN Platform 29-Jul-96 GMS <0-12237'>,,D-30Rd,DOLLY VARDEN Platform 29-Jul-96 MSS <2220-8175'>,,D-18,DOLLY VARDEN Platform 29-Jul-96 MSS <9453-12381'>,,D-12,DOLLY VARDEN Platform 29-Jul-96 GMS <O-12050'>,,D-12Rd,DOLLY VARDEN Platform 29-Jul-96 GMS <O-11100'>,,D-4,DOLLY VARDEN Platform 29-Jul-96 PGMS <8000-12100'>,,D-4Rd,DOLLY VAR/DEN Platfor 29-Jul-96 GMS <9600-13300'>,,D-7,DOLLY VARDEN Platform 29-Jul-96 GMS <O-12900'>,,D-7Rd,DOLLY VkRDEN Platform 29-Jul-96 PMSS <12052 - 12438'>,,D-7Rd#2,DOLLY VARDEN P1 29-Jul-96 MSS <2730-13462'>,,D-24,DOLLY VARDEN Platform 29-Jul-96 GMS <0-11180'>,,D-34,DOLLY VARDEN Platform 29-Jul-96 PGMS <0-10450'>,,D-42,DOLLY VARDEN Platform 29-Jul-96 MSS <3550-16606'>,,D-23,DOLLY VARDEN Platform 29-Jul-96 MSS <3550-17010'>,,D-21,DOLLY VARDEN Platform 29-Jul-96 PGMS <O-12970'>,,D-44,DOLLY VARDEN Platform 29-Jul-96 MSS <10913-11930'>,,D-47,DOLLY VARDEN Platform 29-Jul-96 MSS <2742-13908'>,,D-lO,DOLLY VARDEN Platform 29-Jul-96 GMS <800-2700'>,,D-lO,DOLLY VARDEN Platform 29-Jul-96 PGMS <0-10873'>,,D-48,DOLLY VARDEN Platform 29-Jul-96 GMS <0-11905'>,,D-26,DOLLY VARDEN Platform 29-Jul-96 7607 1 7088 8 7088 8 7511 7 5471 1 5619 8 5619 8 5619 8 9033 4 5619.8 3339.7 1632.8 929.2 2591.5 2226.7 2017.1 8710.9 8356.7 8356.7 3209.3 6860.2 6860.2 6437.8 6379.1 6379.1- 7303.5 7303.5 1356.6 1321.1 3991.2 4910.5 4984.9 1351.0 4907.2 3995.2 1073.1 2245.8 2081.8 4098.4 6784.7 1238.6 1397.1 1606.4 4929.6 4852.6 5128.4 2809.0 3348.4 3729.4 5535.4 6388.6 5631.4 3646.4 3525.7 3525.7 1088.0 509.4 485.7 4150.7 6287.6 6287.6 3769.0 3763.1 698.4 401.7 723.1 3493.5 3363.0 2073.3 8534.7 8303.4 4967.1 2178.0 4068.7 7924.1 2208.3 0.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300 0 12300 0 12300 0 12300 0 12300 0 10700 0 10700 0 10700 0 10700 0 10980 0 11080 0 10700 0 10700 0 10700 0 10700 0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 11320.0 11500.0 10700.0 '10700.0 10700.0 10700.0 12300.0 12300.0 11040.0 12300.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700.0 10700 0 11220 0 10700 0 10700 0 10700 0 10700 0 10700 0 10700 0 10700 0 12300 0 12300 0 12300 0 12300 0 10700 0 10700 0 10700 0 10700 0 12160.0 12300.0 12280.0 10700.0 10700.0 12300.0 10700.0 10700.0 12300.0 12300.0 10700.0 10700.0 10700.0 10700.0 12300.0 12300.0 12300.0 12300.0 12300.0 12300 0 12300 0 12300 0 12300 0 12300 0 10940 0 10700 0 12300 0 10700 0 10980 0 11080.0 10700.0 10700.0 10700.0 12300.0 10700.0 10700.0 12200.0 10700.0 10700.0 10700.0 10700.0 11320.0 11500.0 12300.0 10700.0 10700.0 10700.0 12300.0 12300.0 11040.0 12300.0 12300.0 10700.0 10700.0 10700.0 10700.0 10700.0 12300 0 12300 0 10700 0 10700 0 11220 0 10700 0 10700 0 10700 0 10700 0 12300 0 10700 0 10700 0 12300 0 12300 0 12300 0 12300 0 10700 0 10700 0 10700 0 10700.0 12160.0 12300.0 12280.0 10920.0 10700.0 12300.0 10700.0 10700.0 12300.0 12300.0 10700.0 10700.0 12300.0 10700.0 UNOCA[JDOWELL CTD RIG P PING HAND CHOKE VENT LINE 2" 1502 5K PS CHOKE LINE KILL AND CHOKE LINE VALVES TO BE FLANGED TO FLOW CROSS BHI CHOKE MANIFLOD READOUT DIS C-PUMP HAND CHOKE 4"5K TREE L~TO PROD MANIFOLD 2" 1502 HIGH PRESSURE LINES POPO F,,~POPOF RELIEF VALVE LINE ~11,l~ BLEEDER LINE q ;)/PULSATION "G" PUMP 7500 PSI t '~ 10,000 PIS LEGEND HIGH PSI LINE LOW PSI CHARGE LOW PSi LINE VALVE ACCUMULATOR ~ FILTER/SCREEN CAP ~]~ HAND CHOKE ~ CHECK VALVE PSi GAUGE C PUMP MICRO MOTION HOPPER AGITATOR OAL Of Stack Up = 37.416~ 6.735" 11) 5M [~ubrica[or BX155 x CO62 'll~read X-Over 4 1/16" Annular CO62 Nut x BX155 X-Over 8.0~ 0,583' 2,083' 1.50' 4 1/16" 10M TOT Quad BOPId 6,0' BX 155 x BX 155 Studded Flow Tee 2" ID OutleLs BX 155 x BX 155 Riser Spool 17,0' 0,75' 1,5t)' R-39 x BX i55 X-Over Wellhead to Rig Floor = 35.5' 2" Blind/Shear 2" Blind/Shear 2" l'ipe Rmns 2" Slip Rmns D26 CT RD Display _Wells _CrossSecUons 0R0 ldapplng Controls MapView - LES · 87211 I ~:~'G 3RD -~- 87 eO ^~'-,~:-~--_. -eTz~ -/b1,¢0-30 H_elp eD-1 -8728 I PROPOSRO g4st map of the G4ST SURFACE X: ZIZGgS.14Z1 = ¥: 2497151 .B00O 3R0# I I -SRO I I Mapping Units: Common feet -8886 m -883g JUN, 16, 1998 2:28PM M-I DRILLING ALASKA NO. 9226 P, 1 DRILLING FLUIDS 721 We~t First Avenue . Anchorage, Alaska 99501 · Tel; 907,Z74.5564 -. ~a~, 907,279.6729 M-I Drilling Fluids L.L.C, June 16, 1998 UNOCAL P.O. BOX 196247 Anchorage, Alaska 99519 Attention: Steve Lambe Steve: Here is the mud program for Well D-26, Dolly Varden Platform. The Flo-Pro drilling fluid that has been permitted for discharge in the Cook Inlet allows for the following maximum concentrations Xanvis (Flo-Vis) Caustic Soda KCI FL7+ (Flotrol) Lo-Wate NACL 4 PPB 1 PPB 3 % V/V (10.33 PPB) 3 PPB 75 PPB 50,000 m~ cl (20.66 PPB) It is our recommendation that drilling begin with the fluid listed in the formula attached, (discharging as needed mud and cuttings provided each passes the sheen and oil tests). If torque becomes a problem and a lubricant is needed, we recommend Lubetex (used extensively in the Arctic coil tubing operations). Discharges would then not be permitted, but the following disposal options may be considered. 4~ Re-use the fluid for additional coil robing drilling (re-conditioning as needed) Store the fluid for future use on onshore operations. Break the polymer and ship it to production (Sodium Hypochlorite and/or Lithium Hypochlorite breakers combined with heat and agitation have been used successfully on the Grayling Platform during workovers) Use the fluid as a packer fluid. Call me you have any questions. Thank you, Tony Tykalsky Project Engineer 274-5011 M-I LLC JUN. 16, 1998 2:29PMM-I DRILLING ALASKA NO, 9226 P, 2 UNOCAL DOLLY VARDEN PLATFORM WELL D-26 DEPTH INTERVAL WHIPSTOCK @ 10742' MD (8911' TUD) DRILL TO 12300' MD (8916" TVD) MUD TYPE FLO-PRO MUD ADDITIVES FLO-VlS, KCL, FLOTROL, CAUSTIC SODA, NACL, LO-WATE, {LUBETEX} POTENTIAL PROBLEMS HOLE CLEANING, HIGH TORQUE, DIFFERENTIAL STICKING, LOST CIRCULATION, GAS KICKS COST PER BARREL $26.75** -46.75 ESTIMATED *' Does not include lubricant or fluid loss control additive . 2~ 3~ REATMENT$1PROCEDURES Build mud with fresh water, Flo-Vis, KCL, and caustic soda and Myacide AS. Displace well to new mud after setting whipstock. Higher hole angles increase the probability of cuffings bed formation. Monitor LSRV of lhe drilling fluid with a Brookfield Viscometer. Maintain a I minute LSRV of ~ 50,000 with FIo-Vis additions. Control solids by running the finest shaker screen size possible. Run centrifuge for removal of fine solids... Keep mud weights as Iow as possible. Mud weights should range from 8.55 ppg to 8.75 ppg. Note: Higher mud weights may be required. JUN, 16. 1998 2'29PMM-I DRILLING ALASKA NO, 9226 P, 3 . . . . Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Lo-Wate should be used as needed for a bridging agent to control seepage losses, NOTE: Maximum Lo-Wate concentration for discharge purposes is 75 ppb. Flotrol should be used as needed for fluid I°ss control. NOTE: Maximum Flotrol concentration for discharge purposes is 3 ppb. If torque is a problem. Lubetex should b® added.' Monitor decrease in torque with each % addition of Lubetex. NOTE: DISCHARGE IS NOT PERMISSABLE IF A LUBRICANT IS ADDED TO THE SYSTEM!! 3 314" Hole Mud Formulation Fresh Water FIo-Vis 2.75 ppb KCL Cauetic Soda . MyacideAS Lo-Wate Flotrol Lubetex __ ~10.33 ppb .2Sppb 0.04 ppb As needed for seepage_ losses As needed for fluid loss control As needed for torque reduction JUN, 16, 1998 2:29PMM-I DRILLING ALASKA NO, 9226 P. 4 ANTI_C!PA_TED.MU D PROPERTIES Mud Density 8.55 PPG LSRV 1 minute 50,000 cps Plastic Viscosity 8 - 10 cps Yield Point 40 45 #/100~ Gels 25/27/30 #/100~ APl Fluid Loss 4 - 6 cc pH 8.5 -9.5 MBT <2.5 ppb Drilled Solids <15ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED M,A.C, of products or use products not approved in the discharge permit. UNOCAL DOLLY VARDEN PLATFORM WELL D-26 ESTIMATED FLUID COST Estimated drilling fluid cost based on 8.55 mud weights Estimated cost with 3% Lubetex Estimated cost for polymer breaker (per bbl) $16,050 $28,800 $15.75 JUN, 16, 1998 2'29PMM-I DRILLING ALASKA NO, 9226 P, 5 M-I DRILLING FLUIDS 5.L.C. WATER I~SE MUD PRODUCT CAAC~I.&TIONS Input Data Description Mud weight (ppg) Weight Material Code Weight Material Sea Water Sea Salt Salt #1 (KC1) Chlorides Salt #l Wt % Salt #2 (NaC1) Chlorides Salt #2 Wt % M-I Gel (ppb) Prehydrated Prehydrated Gel Conc. (ppb) WELL D- 26 PL0- PRO MUD 8.51 LOWT 2.80 N N 3 0uput Data PRODUCT FIELD LAB (ppb) (g) FIELD LAB I COST (bbl) (ml)I (per bbl) FLYS Caustic Soda MYCD Potasium Chloride Lo-Ware M-I GEL Water 2,75 2.75 0.005 0.25 0.25 0,000 0.04 0.04 0,000 10.62 10,62 0,013 0.28 0.28 0.000 0.00 0.00 0.000 343,48 343.48 0.981 1.83 23.10 0.12 0.06 0,03 0.68 4.44 2.84 0.10 0.06 0.00 0.00 343.48 0.00 Total 357.42 Calculated Mud Weight Calculated Total Chlorides 357.42 8,510 14600 1.000 350.00 26.74 M-I DRILLING FLUIDS MUDCALC 3.91 Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL Rick D. Cross Senior Landman June 22,1998 Mr. Robert Crandall Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Permit to Drill D-26RD Trading Bay Unit Cook Inlet Area State of Alaska Dear Mr. Crandall, Union Oil Company of California (Unocal), as Operator for the Trading Bay Unit, requests your approval to redrill the Trading Bay Unit D-26 well pursuant to Rule 5 Conservation Order No. 80. ? Drilling from the Dolly Varden Platform, and completing the well in the Middle Kenai G Zone Oil Pool at a crestal final withdrawal point will result in additional recovery of production. Enclosed is a check in the amount of $100.00 as required by 20 AAC 25.005(c)(1) to process an application for permit to drill. Unocal appreciates your review and approval of this application. Sincerely yours, , Y / .; / .. i ,.'y. ./:// /, -'/' .: ,~/ z ..'; i// ~, ~.." ./>'-/......~:/.-.....¢// Rick D. Cross Senior Landman Attached: Check No.: ~..~0~"// Application for Permit to Drill Anchorage I Created oy Su~hcdand For: $. Lar~b8 Date p~otted : 27-Mcy-98 Plot ~eference ~s O-26Rd Version ~5. ~Ccordinatc~ ~rc ;n fcc( reference ~lot ~A1-7, True Ver:ical Depths are reference ~ellhead. WELL PROFILE DATA UNOCAL Structure : DOLLY VARDEN Plofform Well : D-26 Field : McArfhur River Field Location : TBU, Cook Inlet, Alaska UNOCAL ) East (feet) -> 3500 3600 3700 3800 3900 4000 41 O0 ¢200 ¢'300 44-00 ¢500 ~ I I I [ I I ! I t I I ! I t I ! I I I ~ I51 O0 ..... Point ..... MO lnc I~r T~D No~th E~st V. Sect 10742.0(1 36.6966.848911.30 3753.Q1 .1751.77 14.48 1.41 Build/Turn 1684g.6591~ 65.008957.00 37al.]1 3~5.56~.9~ 50.47 End ~ T~At2~.~ 91.~ ~.94 6918.97 &99B.80 3983.95 1279.39 KOP I5000 4900 i4800 4700 I4600 4soo 4400 4300 4200 4~,00 4000 3900 ~ 8600 (D 3800 8700 L 3700 KoP .~ '~'. :~ e -,-'-- ' ~'...t-' /:. ' · , . ,. : ..~...<, ?:'.. ~.:-'.. ,;, ~ · ~, .Lt.,;_,./,. -- F: ;-,; ,: t,L. ~ · I--'1 9100 t V 9200 i i I i i i i [ i i J I i i ii i i ii i i t i i i i i i i i ! J J 300 200 100 0 100 200 500 400 500 600 700 800 900 1000 1100 1200 1.500 1400 Vertical Section (feet) -> Azimuth 11.51 with reference 3742.93 N, 3728.68 E from slot #A1-7 Created by Sutherlond For: S. Lambe Oote ~lctted : 26-May-g8 Plot Relerence is O-26Rd Vets;on #5. CccrOinOteS ore in feet reference slot ~A1-7. True VertJca~ ~-,epths ere reference wellhead. UNOCAL Structure : DOLLY VAROEN Platform Well: D-26 Field : McArfhur River Field Locolion : TBU, Cook Inlel, Alosko UNOCAL ) East (feef~ -> 3400 3500 3600 5700 2800 3900 4000 4100 4200 4200 4400 4500 4600 4700 4800 4900 5300 j ~ [ ~ ~ ' ~ ~ ~ ~ : ~ ' ' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ' ~ ~ ~ ' i 5300 q 82 8600 8200/ /..../ 8300 i 520° 5200 85O0 810 8400 8000/J 8100 8500 5100 8200 5100 ~8000 8100 5000 ~-7900 8000 , 5000 ~5000 4900 A I 45oo 4400 ~ 4300 o 4200 7900 7800 }o 5100 760O 48oo ' 7500 5200 7400 " % 7100 \ 4600 5600 5700 55OO - 45C0 F 4700 ' , 4!00 4lOC ,' i · L 4000 -I · ~ ? 4000 ,' ~eo~ ~°° k 3500 ~ , , ~ , ~ , , , ~ , , , ~ , , ~ , ~ ~ , , ~ , ~ ~ , , ~ ~ ~ ~ 3500 3500 ~600 3700 3800 3900 4000 41 O0 4200 4300 4400 4500 4600 4700 4800 4900 4600 A I 4500 O 4400 -~- 4200 Eesf (feet) -> I Createa ay Sutherlcnd For: $. Lambe i Octe plotted : 26-May-g8 I" ~ot Reference. is O-26Rd Version ,~A1-7. jCccrCmatc3 crc ,n feet reference slot I : T-ue Vert,ccl Oepths are reference wellhead. 52O UNOCAI Sfructure : DOLLY VAROEN Platform Field : McArfhur River Field Well: D-26 Location : TBU, Cook lnlef, Alaska 330 340 TRUE NORTH I i 550 0 10 2O 3O UNOCALe 4O .510 5O 300 ~0 6O 290 7O 280 2'70 260 25O 3O 10800 ~_0 i~0 18o 2i0) , / / ! ! / 8O !~0 240 !20 220 210 200 190 180 160 170 150 140 i30 Norcnol Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference We! UNOCAL DOLLY VARDEN Platform D-26 slot #Al-7 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : D-26Rd Version #5 Our ref : prop2932 License : Date printed : 27-May-98 Date created : 20-May-98 Last revised : 27-May-98 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 48 20.815,w151 38 22.052 Slot location is n60 48 28.215,w151 37 57.565 Slot Grid coordinates are N 2490830.384, E 208463.820 Slot local coordinates are 751.50 N 1214.80 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL DOLLY VARDEN Platform,D-26 McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : D-26Rd Version #5 Last revised : 27-May-98 Dogleg Vert Deg/100ft Sect 10700.00 37.00 66.00 8877.69 3742.93 N 3728.68 E 0.00 0.00 10742.00 36.69 66.84 8911.30 3753.01 N 3751.77 E 1.41 14.48 10800.00 65.95 65.63 8947.16 3771.15 N 3792.71 E 50.47 40.42 10849.65 91.00 65.00 8957.00 3791.31 N 3836.56 E 50.47 68.94 10900.00 91.11 60.97 8956.07 3814.17 N 3881.40 E 8.00 100.28 11000.00 91.31 52.97 8953.96 3868.62 N 3965.15 E 8.00 170.35 11100.00 91.49 44.97 8951.51 3934.19 N 4040.51 E 8.00 249.63 11200.00 91.64 36.97 8948.78 4009.60 N 4106.00 E 8.00 336.60 11300.00 91.75 28.97 8945.82 4093.39 N 4160.36 E 8.00 429.55 11400.00 91.83 20.97 8942.69 4183.93 N 4202.51 E 8.00 526.67 11500.00 91.88 12.96 8939.45 4279.45 N 4231.65 E 8.00 626.09 1160~.00 91.89 4.96 8936.16 4378.09 N 4247.20 E 8.00 725.85 11700.00 91.86 356.95 8932.88 4477.95 N 4248.86 E 8.00 824.03 11800.00 91.80 348.95 8929.69 4577.06 N 4236.61 E 8.00 918.70 11900.00 91.70 340.95 8926.64 4673.50 N 4210.67 E 8.00 1008.03 12000.00 91.56 332.94 8923.79 4765.40 N 4171.56 E 8.00 1090.28 12100.00 91.40 324.94 8921.19 4850.97 N 4120.03 E 8.00 1163.84 12200.00 91.21 316.94 8918.91 4928.54 N 4057.08 E 8.00 1227.29 12300.00 91.00 308.94 8916.97 4996.60 N 3983.95 E 8.00 1279.39 All data is in feet unless otherwise stated. Coordinates from slot #A1-7 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 6390.45 on azimuth 38.57 degrees from wellhead. Total Dogleg for wellpath is 170.95-degrees. Vertical section is from tie at N 3742.93 E 3728.68 on azimuth 11.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL DOLLY VARDEN Platform,D-26 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : D-26Rd Version #5 Last revised : 27-May-98 NO Targets associated with this wellpath UNOCAL DOLLY VANDEN Platform,D-26 McArthur River Field, TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : D-26Rd Version #5 Last revised : 27-May-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 10700.00 37.00 66.00 8877.69 3742.93N 3728.68E 0.00 0.00 212284.82 2494479.00 10742.00 36.69 66.84 8911.30 3753.01N 3751.77E 1.41 14.48 212308.15 2494488.50 10800.00 65.95 65.63 8947.16 3771.15N 3792.71E 50.47 40.42 212349.54 2494505.61 10849.65 91.00 65.00 8957.00 3791.31N 3836.56E 50.47 68.94 212393.88 2494524.68 10900.00 91.11 60.97 8956.07 3814.17N 3881.40E 8.00 100.28 212439.27 2494546.41 11000.00 91.31 52.97 8953.96 3868.62N 3965.15E 8.00 170.35 212524.36 2494598.74 11100.00 91.49 44.97 8951.51 3934.19N 4040.51E 8.00 249.63 212601.33 2494662.41 11200.00 91.64 36.9? 8948.78 4009.60N 4106.00E 8.00 336.60 212668.68 2494736.16 11300.00 91.75 28.97 8945.82 4093.39N 4160.36E 8.00 429.55 212725.11 2494818.57 11400.00 91.83 20.97 8942.69 4183.93N 4202.51E 8.00 526.67 212769.52 2494908.02 11500.00 91.88 12.96 8939.45 4279.45N 4231.65E 8.00 626.09 212801.03 2495002.79 11600.00 91.89 4.96 8936.16 4378.09N 4247.20E 8.00 725.85 212819.04 2495101.01 11700.00 91.86 356.95 8932.88 4477.95N 4248.86E 8.00 824.03 212823.20 2495200.79 11800.00 91.80 348.95 8929.69 4577.06N 4236.61E 8.00 918.70 212813.42 2495300.18 11900.00 91.70 340.95 8926.64 4673.50N 4210.67E 8.00 1008.03 212789.90 2495397.24 12000.00 91.56 332.94 8923.79 4765.40N 4171.56E 8.00 1090.28 212753.10 2495490.09 12100.00 91.40 324.94 8921.19 4850.97N 4120.03E 8.00 116'3.84 212703.72 2495576.92 12200.00 91.21 316.94 8918.91 4928.54N 4057.08E 8.00 1227.29 212642.73 2495656.03 12300.00 91.00 308.94 8916.97 4996.60N 3983.95E 8.00 1279.39 212571.33 2495725.90 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #A1-7 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 6390.45 on azimuth 38.57 degrees from wellhead. Total Dogleg for wellpath is 170.95 degrees. Vertical section is from tie at N 3742.93 E 3728.68 on azimuth 11.51 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL DOLLY VARDEN Platform, D-26 McArthur RAver Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : D-26Rd Version #5 Last revised : 27-May-98 NO Targets associated with this wellpath BRKER HUGHES INTEQ ID'907-267-6621 JUN 01'98 11'47 No.O01P.O$ UNOCAl, vAR/)~-~I PlaYlet, D-36 F£old,TBU, COok Inle~, Alaska Do~h Dogroo~ DO~ee~ De~th C 0 0 ~ D iOTO0.O0 ~7.00 66.00 88~,69 4494.43 N 4943.48 ~0742,00 35.69 ~6.~4 8911.30 4504.S1 N 10049.65 91.00 65.00 89S~.00 454~.S1 M 5051.36 10~00,00 91.11 60,97 8956,07 4565,6~ N 509g.30 11000.00 91.31 52.9~ 8953.96 4620.12 N 51V9,95 11100.00 91.49 44,9~ 8951.51 4665.6~ N 5255.31 11200.00 91.64 3~,97 0948.~9 ~61.10 N 5320.80 11300,00 91,75 28.J7 894S,82 4844.69 N 53q5.1§ Z~400,O0 91.83 20.97 Sg42,6J 4935.43 N 5417,31 11500.00 91.60 12.96 8939.45 $030.g~ N 5%46.45 11600,00 91.89 4,96 8936.16 5129,S9 11700.00 91.06 356.9~ 893~.88 5229.45 11800.00 91,80 34B.95 8929,69 53~e.56 11900.00 91.~0 340,95 8926,64 5425.00 12000.00 91.56 332.94 8923.79 5516.90 N 5366.36 13100.00 91.40 324.94 8921,19 $$02,47 12200,00 91,21 316.94 8918.91 5680,04 12300.00 91.00 -51,06 0916,97 5746,10 N rev/sod , 2~-~ay-98 Dogl,g Deg/100£C 0.00 0.00 1.41 14,48 50,47 40.42 50,47 $8.94 8.00 100.28 O.00 170.Z5 8.00 240,~3 8.00 33&.g0 8.00 429,55 8.OD 9,00 636,09 8.00 ~2S.05 8.00 824,03 fi. GO 918,~0 8,00 1008.03 8,00 I090,28 8,00 1163,85 8.00 8,00 1279.~9 All ~aba la &n feet u~lesf o~h®~w&so stated. Coord&uatea f=om OW corner oeo, 6, TON, RZ3W, B.H. &nd TVD gF~mwellho~d (106,20 P~ ~e mo~ sea level). Calculacton uso, the =~ut~ au~a~u~e me~hod. BAKER HUGHES INTEQ ID'907-267-6621 JUN 01'98 11'48 No.O01P.04 Cook Inleh, ~&nk~ FOR INQUIRIES CONTACT LOCATION WHERE INVOICES Wr '~UBMITTED ~f,'"~'~'N .......... Mi GBECK NOt, ....... lU~548 36-22-98 2002671 DATE ,NVOIC .F-J.C. REDIT MEMO NO. ~IsC~ 19-JUN-98 DRILLPERMITD2 6 06983000639 100.00 100.00 100.00 100.00 I tOtA~ ,~ · FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. . f3PTAP. W .qTI IR RPP~RP ~]PP~],qlTI~JP~ P, NPP. K · WELL PERMIT CHECKLIST FIELD&POOL ~-Zo I'~-O COMPANY ...L~ ~o c ~( WELL NAME T(% CL D - ~ ~, ~ ~ PROGRAM: exp [] dev ~ redrll [] serv [] wellbore seg ~'ann. disposal para req U INIT CLASS ,~ ~,, ~,'"' (~ ~, GEOL AREA '~ ~ ~ UNIT# J ~ r,3 '~ Q~ ON/OFF SHORE ¢..) ..jt-F ADMINISTRATION 1. A? , 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ~ Ja,,,. ~/~ 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY A~ DAT. E ANNULAR DISPOSAL APPR DATE N N N (~N N N N N 30. Permit can be issued w/o hydrogen sulfide measures.~s.s.s.s.s.s.s~/.. Y N 31. Data presented on potential overpressur~.~. ...... 32. Seismic analysis of shallowers ............. 33. Seabedcond~(ifoff-shore) ............. Y N 34. Co~rogress reports ....... Y N xp~orarory onlyj 35. With proper cementing records, this plan~/ (A) will contain waste in a su'~ving zone; ....... Y N (B) will not contaminate..[r, es~water; or cause drilling waste... Y N to surface; /-" _ (C) will n~e rity of the well used for disposal; Y N (D) will no~~ion or impair recovery from a Y N p_~ and ~ _ (E ill not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: RPC ~'~ ENGINEERING: UlC/Annular COMMISSION: JDH ~ RNC ~~ co ~%~ - Comments/Instructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drillin9 Services LIS Scan Utility Thu Feb 18 14:31:20 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/02/18 Origin ................... STS Tape Name ................ UNK~OWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT mcs/~ 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: MWD RUN 1 AK-MM-90033 P. SMITH G. WHITLOCK Alaska Oi~ & 6as"' ' .~, · ' i c- 1 s ,'"',,,.cs 5ooas~2a932oo ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 18-FEB-99 - MWD RUN 2 AK-MM- 90033 T. MCGUIRE G. WHITLOCK MWD RUN 3 AK-MM- 90033 TOM MCGUIRE DON BREEDEN 12 liN 10E 1634 1239 .00 101.30 60.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 121.0 12.250 9.625 6249.0 8.500 9390.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO DENSITY (SLD). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN MARSHALL MUNYAK OF SPERRY-SUN DRILLING SERVICES AND MEG CREMER OF ARCO ALASKA, INC. ON 06 JANUARY, 1999. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9390'MD, 6840'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON PROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS COUNT' RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 300 PPM. 10.3 PPG. 14545 PPM. SANDSTONE Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 121.0 9320.0 RPM 121.0 9320.0 RPS 121.0 9320.0 RPX 121.0 9320.0 GR 121.0 9348.0 FET 121.5 9320.0 ROP 122.0 9389.5 PEF 6250.0 9336.5 DRHO 6250.0 9336.5 RHOB 6250.0 9336.5 FCNT 6250.0 9327.5 NCNT 6250.0 9327.5 NPHI 6250.0 9327.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 122.0 5434.0 2 5434.0 6259.0 3 6259.0 9390.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 121 19 55 0 05 0 05 0 05 0 05 0 03 0 06 21 75 406 08 2017 17 2 03 -0 32 1 37 Max Mean Nsam 9389.5 4755.25 18538 478.64 98.9082 18455 1889.81 16.506 18399 1019.64 21.0539 18399 2000 35.9771 18399 2000 38.8771 18399 9424.62 238.05 18536 71.92 1.01816 18398 81.76 51.1408 6156 1046.87 565.661 6156 3488.35 2523.35 6156 3.43 2.3513 6174 0.87 0.0510609 6174 8.91 2.90836 6174 First Reading 121 121 121 121 121 121 122 121.5 6250 6250 6250 6250 6250 6250 Last Reading 9389.5 9348 9320 9320 9320 9320 9389.5 9320 9327.5 9327.5 9327.5 9336.5 9336.5 9336.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 9389.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 121.0 121 0 121 0 121 0 121 0 121 5 122 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5394.0 5394.0 5394.0 5394.0 5384.5 5394.0 5434.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 06-DEC-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 5434.0 122.0 5434.0 .5 52.9 TOOL NUMBER Pl157CGR8 Pl157CGR8 12.250 12.3 SPUD, LSND 10.20 185.0 8.5 400 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.300 4.960 8.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 33.4 Name DEPT GR RPX RPS RPM RPD ROP FET Min 121 19.55 0 05 0 05 0 05 0 05 0 03 0 06 First Max Mean Nsam Reading 5434 2777.5 10627 121 151.07 78.3944 10528 121 162 24.843 10547 121 335.04 33.6603 10547 121 2000 50.9374 10547 121 2000 55.0408 10547 121 9424.62 291.003 10625 122 9.43 0.459027 10546 121.5 Last Reading 5434 5384.5 5394 5394 5394 5394 5434 5394 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 5434 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5385.0 6210.0 FET 5394.5 6219.5 RPD 5394.5 6219.5 RPM 5394.5 6219.5 RPS 5394.5 6219.5 RPX 5394.5 6219.5 ROP 5434.0 6259.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 07-DEC-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 6259.0 5434.0 6259.0 49.0 50.3 TOOL N-UMBER DGR EWR4 $ DUAL GAMMA R3tY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Pl157CGR8 Pl157CGR8 12.250 12.3 LSND 10.20 202.0 8.5 350 5.8 6.300 5.010 8.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 32.8 First Last Name DEPT GR RPX RPS RPM RPD ROP FET Min 5385 49 14 2 05 2 11 2 27 2 24 5 02 0 17 Max Mean 6259 5822 155.51 103.07 25.89 5.64243 27.87 6.05196 28.56 6.03751 31.41 6.47926 584.12 173.287 12.43 0.983368 Nsam 1749 1651 1651 1651 1651 1651 1651 1651 Reading 5385 5385 5394.5 5394.5 5394.5 5394.5 5434 5394.5 Reading 6259 6210 6219.5 6219.5 6219.5 6219.5 6259 6219.5 First Reading For Entire File .......... 5385 Last Reading For Entire File ........... 6259 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX PEF DRHO RHOB FCNT 3 .5000 START DEPTH 6210 5 6220 0 6220 0 6220 0 6220 0 6220 0 6250 0 6250.0 6250.0 6250.0 STOP DEPTH 9348.0 9320.0 9320.0 9320.0 9320.0 9320.0 9336.5 9336.5 9336.5 9327.5 NCNT 6250.0 NPHI 6250 · 0 ROP 6259 · 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 9327.5 9327.5 9389.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 12 -DEC-98 ISC 5.06/INSITE 3.2 CIM 5.46/EWP4 1.38/TM .41 MEMORY 9390.0 6259.0 9390.0 25.8 50.0 TOOL NUMBER Pl187HWRNLGV6 Pl187HWRNLGV6 Pl187HWRNLGV6 Pl187HWRNLGV6 8.500 8.5 LSND 10.20 52.0 8.5 350 4.6 2.500 1.300 2.700 2.600 57.0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 FET MWD 3 HOUR 4 1 68 ROP MWD 3 FT/H 4 1 68 RHOB MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 DRHO MWD 3 G/CC 4 1 68 NPHI MWD 3 P.U. 4 1 68 NCNT MWD 3 CNTS 4 1 68 FCNT MWD 3 CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD FET ROP RHOB PEF DRHO NPHI NCNT FCNT Min 6210.5 34.96 0.73 0.69 0.65 0.73 0.2 0 27 2 03 1 37 -0 32 21 75 2017 17 406 08 Max Mean Nsam 9389.5 7800 6359 478.64 132.225 6276 1889.81 5.21851 6201 1019.64 3.60637 6201 2000 18.5033 6201 2000 20.0109 6201 71.92 1.97654 6201 3600 165.251 6261 3.43 2.3513 6174 8.91 2.90836 6174 0.87 0.0510609 6174 81.76 51.1408 6156 3488.35 2523.35 6156 1046.87 565.661 6156 First Reading 6210.5 6210.5 6220 6220 6220 6220 6220 6259.5 6250 6250 6250 6250 6250 6250 Last Reading 9389.5 9348 9320 9320 9320 9320 9320 9389.5 9336.5 9336.5 9336.5 9327.5 9327.5 9327.5 First Reading For Entire File .......... 6210.5 Last Reading For Entire File ........... 9389.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/02/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File