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If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU 05-14A Casing Tieback Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-082 50-029-20253-01-00 N/A ADL 0028326 11008 Surface Intermediate Liner Liner Slotted Liner 8815 2689 6359 3760 3267 899 10996 13-3/8" 9-5/8" 7-5/8" 7" 4-1/2' 8815 34 - 2723 32 - 7106 3176 - 6936 6943 - 10210 10109 - 11008 2499 34 - 2723 32 - 6391 3172 - 6260 6265 - 8822 8823 - 8815 None 2670 4760 4790 7020 N/A None 4930 6870 6890 8160 N/A 10210 - 10996 4-1/2" x 3-1/2"13Cr 30 - 101098822 - 8815 Conductor 112 20" 112 112 BKR SBP PKR, BKR H PKR TRDP-4A TRSSSV 3186, 6943, 2071 3182, 6265, 2701 Date: Bo York Sr Operations Manager Dave Bjork david.bjork@hilcorp.com 907-564-4672 PRUDHOE BAY, PRUDHOE OIL 10/15/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:27 am, Sep 09, 2021 321-460 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.09.08 14:44:31 -08'00' Bo York X DLB 09/09/2021 DSR-9/9/21MGR17SEP2021 10-404 BOPE test to 3000 psi. Annular to 2500 psi. dts 9/21/2021 JLC 9/21/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.21 14:47:54 -08'00' RBDMS HEW 9/22/2021 ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ tĞůůEĂŵĞ͗ϬϱͲϭϰW/EƵŵďĞƌ͗ϱϬϬϮϵϮϬϮϱϯϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚͲ/ŶZŝŐ͗dŚƵŶĚĞƌďŝƌĚηϭ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϭϬͬϭϱͬϮϬϮϭƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϳĚĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍ϭϬͲϰϬϯ͕ϰϬϰĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗Eͬ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϯϬϴϮϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ ϵϬϳͲϱϲϰͲϰϲϳϮ ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ ϵϬϳͲϱϲϰͲϱϮϴϬ ϵϬϳͲϯϬϭͲϭϮϰϬ &EƵŵďĞƌ͗/KZϭϭϮ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯ͕ϯϳϵƉƐŝΛϴ͕ϴϬϬ͛dsϳ͘ϰWW'ͮKĨĨƐĞƚƉƌŽĚƵĐĞƌϬϱͲϯϬͲϭϭͬϭϵ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Ϯ͕ϰϵϵƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϭ͕ϱϬϬƉƐŝ ;dĂŬĞŶŽŶϯͬϬϳͬϮϭͿ DŝŶ/͗Ϯ͘ϳϱ͟/^tEƉƌŽĨŝůĞΛϭϬ͕Ϭϵϵ͛D DĂǆŶŐůĞ͗ ϵϱĞŐΛϭϬ͕ϯϱϭ͛ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ϬϱͲϭϰǁĂƐĚƌŝůůĞĚŝŶ^ĞƉƚĞŵďĞƌϭϵϴϯ͕ŝƚǁĂƐƐŝĚĞƚƌĂĐŬĞĚĂŶĚĐŽŵƉůĞƚĞĚĂƐĂϰЪ͟ƐůŽƚƚĞĚůŝŶĞƌĂĐƌŽƐƐϭŝŶ ϭϵϵϯ͘/ŶĐƌĞĂƐŝŶŐǁĂƚĞƌĐƵƚŶŽǁƌĞƋƵŝƌĞƐŐĂƐůŝĨƚƚŽƉƌŽĚƵĐĞ͕ǁŚŝůĞ/ǆKŝƐƐƵĞƐŚĂǀĞŬĞƉƚƚŚĞǁĞůůŽĨĨůŝŶĞƐŝŶĐĞ ϮϬϭϳ͘Ŷ>>ŝŶĚŝĐĂƚĞƐĂWůĞĂŬĂƚϮϳĨƚ͕ƚŚĞ/ƉĂĐŬŽĨĨĂůƐŽůĞĂŬƐ͘ KďũĞĐƚŝǀĞ͗ WƵůůƚŚĞĞǆŝƐƚŝŶŐϰͲЪ͟ǆϯͲЪ͟ϭϯƌƚƵďŝŶŐŽƵƚŽĨƚŚĞǁĞůů͘ZĞƉĂŝƌƚŚĞWůĞĂŬďǇŝŶƐƚĂůůŝŶŐĂĨƵůůǇĐĞŵĞŶƚĞĚ ϳͲϱͬϴ͟ƚŝĞďĂĐŬ͘ZƵŶŶĞǁϰͲЪ͟ǆϯͲЪ͟ϭϯƌƐƚĂĐŬĞƌƉĂĐŬĞƌĐŽŵƉůĞƚŝŽŶ͘ĐŚŝĞǀĞĂƉĂƐƐŝŶŐD/dͲ/ΘD/dͲd͘ WƌĞZtKǁŽƌŬ͗ ^>Ͳ ^ĞƚƉůƵŐŝŶ^t^ŶŝƉƉůĞĂƚϵ͕ϲϯϬĨƚ͘ ƵŵŵǇŽĨĨƚŽƉƚǁŽŵĂŶĚƌĞůƐ D/dͲdƚŽϮ͕ϱϬϬͲƉƐŝ WƵůůůŽǁĞƌƐƚĂƚŝŽŶ͘ ,ʹ D/dͲdǆ/ǆKƚŽϱϬϬͲƉƐŝ ǇĐůĞ>^͛Ɛ WWWKdͲd >ʹ ƵƚƚƵďŝŶŐΛΕϵ͕ϲϬϮ͛ ŝƌĐƵůĂƚĞǁĞůůƚŽϴ͘ϱƉƉŐϭй<>ǁͬĚŝĞƐĞů&WŽŶdΘ/ ,Ͳ ůĞĞĚt,W͛ƐƚŽϬ͕ďůĞĞĚĐŽŶƚƌŽůůŝŶĞ͘ sĂůǀĞ^ŚŽƉʹ ^ĞƚĂŶĚƚĞƐƚdt EŝƉƉůĞŽǁŶdƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘/ŶƐƉĞĐƚůŝĨƚƚŚƌĞĂĚƐ͘ EhKWĐŽŶĨŝŐƵƌĞĚƚŽƉĚŽǁŶ͕ŶŶƵůĂƌ͕ϮͲϳͬϴ͟ǆϱ͟sZƐ͕ůŝŶĚƐĂŶĚĨůŽǁĐƌŽƐƐ͘ ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ WƌŽƉŽƐĞĚZtKWƌŽĐĞĚƵƌĞ͗ ϭ͘D/ZhdŚƵŶĚĞƌďŝƌĚηϭZŝŐ͘ Ă͘ZŝŐƵƉϮ͟ůŝŶĞĨƌŽŵƚŚĞKǀĂůǀĞƚŽƚŚĞĨůŽǁďĂĐŬƚĂŶŬ͘/ŶƉƌĞƉĂƌĂƚŝŽŶĨŽƌƚŚĞǁĞůůŚĞĂĚĐŚĂŶŐĞ ŽƵƚ͕ƚŚĞKƐŚŽƵůĚďĞŵŽŶŝƚŽƌĞĚƚŽĐŽŶĨŝƌŵŶŽͲĨůŽǁͬǌĞƌŽƉƌĞƐƐƵƌĞĂŶĚƐƚĂƚŝĐĨůƵŝĚůĞǀĞůĨŽƌĂ ŵŝŶŝŵƵŵŽĨƚŚƌĞĞƚŝŵĞƐ;ϯǆͿƚŚĞĞǆƉĞĐƚĞĚƚŝŵĞƚŽƉĞƌĨŽƌŵƚŚĞǁĞůůŚĞĂĚǁŽƌŬ͘ Ϯ͘dĞƐƚKWƚŽϮϱϬƉƐŝ>Žǁͬϯ͕ϬϬϬƉƐŝ,ŝŐŚ͕ĂŶŶƵůĂƌƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ;ŚŽůĚĞĂĐŚƌĂŵͬǀĂůǀĞĂŶĚ ƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ ͘WĞƌĨŽƌŵdĞƐƚƉĞƌdŚƵŶĚĞƌďŝƌĚηϭKWƚĞƐƚƉƌŽĐĞĚƵƌĞ͘ ͘EŽƚŝĨǇK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ ͘ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ ͘dĞƐƚƚŚĞϮͲϳͬϴ͟ǆϱ͟sZ͛ƐǁŝƚŚϰͲЪ͟ĂŶĚϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚƐ͘dĞƐƚƚŚĞŶŶƵůĂƌƉƌĞǀĞŶƚĞƌǁŝƚŚĂϮͲ ϳͬϴ͟ƚĞƐƚũŽŝŶƚ͘ ͘^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϯ͘WƵůůdt͘ZhĐŽŶƚƌŽůůŝŶĞƐƉŽŽůĞƌ͘ ϰ͘DhůĂŶĚŝŶŐũŽŝŶƚŽƌƐƉĞĂƌ͕K>^ĂŶĚƉƵůůŚĂŶŐĞƌƚŽƚŚĞĨůŽŽƌ͘WhǁĞŝŐŚƚƐĂƌĞĞǆƉĞĐƚĞĚƚŽďĞΕϵϬ< ϱ͘WƵůůϰϭͬϮ͟ƚƵďŝŶŐƚŽĨůŽŽƌ͕ĐŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉ͘>ĂǇĚŽǁŶϰͲϭͬϮ͟ĂŶĚϯͲϭͬϮ͟ƚƵďŝŶŐƐƚƌŝŶŐƐ͘ ϲ͘WhǁŽƌŬƐƚƌŝŶŐĂŶĚƐĞƚZWΕϯ͕ϮϬϬĨƚ͘dĞƐƚZWƚŽϱϬϬƉƐŝ͘^ƉŽƚΕϭϬĨƚŽĨϮϬͬϰϬƌŝǀĞƌƐĂŶĚ͘WKK,^t^ ϳ͘ZƵŶĂĚƌĞƐƐŽĨĨĂƐƐĞŵďůǇŝŶƚŚĞůŝŶĞƌƚŽƉĂƚϯ͕ϭϳϲĨƚ͘WKK,^t^͘ ϴ͘^ĞƚĂƚĞƐƚƉůƵŐĂŶĚƐǁĂƉƚŚĞsZ͛ƐƚŽϳͲϱͬϴ͟ĨŝǆĞĚƌĂŵƐĂŶĚƚĞƐƚƚŽϯ͕ϬϬϬͲƉƐŝǁŝƚŚϳͲϱͬϴ͟ƚĞƐƚũŽŝŶƚ͘WƵůů ƚĞƐƚƉůƵŐ͘ ϵ͘ZƵŶϳͲϱͬϴ͟ƚŝĞďĂĐŬ͕ůĂŶĚĐĂƐŝŶŐĂŶĚĨƵůůǇĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ƌĞĂŬƚŚĞKWƐƚĂĐŬĨƌŽŵƚŚĞƚƵďŝŶŐƐƉŽŽů ĂŶĚŝŶƐƚĂůůƚŚĞ/ƉĂĐŬŽĨĨĂŶĚŶĞǁƚƵďŝŶŐƐƉŽŽů͘dĞƐƚƚŚĞ/Ɖ ĂĐŬŽĨĨƚŽϯ͕ϱϬϬͲƉƐŝ͘ ϭϬ͘EhKWŽŶƚŚĞŶĞǁƚƵďŝŶŐƐƉŽŽů͘/ŶƐƚĂůůĂƚĞƐƚƉůƵŐŝŶŶĞǁƚƵďŝŶŐŚĂŶŐĞƌƉƌŽĨŝůĞ͘dĞƐƚƚŚĞƐƉŽŽůďƌĞĂŬ ƚŽϯ͕ϬϬϬͲƉƐŝ͘^ǁĂƉƚŚĞϳͲϱͬϴ͟ĨŝǆĞĚƌĂŵƐƚŽϮͲϳͬϴ͟ǆϱ͟sZ͛ƐĂŶĚƚĞƐƚƚŽϯ͕ϬϬϬͲƉƐŝ͘ǁŝƚŚϮͲϳͬϴ͟ǆϰͲϭͬϮ͟ ƚĞƐƚũŽŝŶƚƐ͘ ϭϭ͘Z/,ǁŝƚŚǁŽƌŬƐƚƌŝŶŐĂŶĚĚƌŝůůŽƵƚ,͕ƌŝůůƵƉƐŚŽĞƚƌĂĐƚ͘WKK,^t^ ϭϮ͘Z/,ǁŝƚŚZ:ĂŶĚĐůĞĂŶƵƉĂŶǇĚĞďƌŝƐ͘WKK,^t^ ϭϯ͘Z/,ĂŶĚƉƵůůZW͕>t^͘dĞƐƚĐĂƐŝŶŐƚŽϯ͕ϬϬϬͲƉƐŝ͘ ϭϰ͘ZƵŶϰЪ͟ǆϯͲЪ͟ϭϯƌƚƵďŝŶŐǁŝƚŚƐƚĂĐŬĞƌƉĂĐŬĞƌŐĂƐůŝĨƚĞĚĐŽŵƉůĞƚŝŽŶĂƐĚĞƚĂŝůĞĚŽŶƉƌŽƉŽƐĞĚ ƐĐŚĞŵĂƚŝĐ͘ ϭϱ͘>ĂŶĚ,ĂŶŐĞƌĂŶĚƌĞǀĞƌƐĞŝŶĐŽƌƌŽƐŝŽŶŝŶŚŝďŝƚĞĚϴ͘ϱƉƉŐϭй<ů ϭϲ͘ƌŽƉďĂůůĂŶĚƌŽĚĂŶĚƐĞƚƉĂĐŬĞƌǁŝƚŚϯ͕ϱϬϬƉƐŝƉƵŵƉƉƌĞƐƐƵƌĞ͘ ϭϳ͘WĞƌĨŽƌŵD/dͲdƚŽϯ͕ϬϬϬƉƐŝĂŶĚD/dͲ/ƚŽϯ͕ϬϬϬƉƐŝĨŽƌϯϬĐŚĂƌƚĞĚŵŝŶƵƚĞƐ ϭϴ͘^ŚĞĂƌǀĂůǀĞŝŶƵƉƉĞƌ'>D͘ ϭϵ͘^Ğƚdt ϮϬ͘ZŝŐĚŽǁŶdŚƵŶĚĞƌďŝƌĚηϭ͘ WŽƐƚƌŝŐǀĂůǀĞƐŚŽƉǁŽƌŬ ϭ͘EKW Ϯ͘EhƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϯ͘dĞƐƚďŽƚŚƚƌĞĞĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϰ͘WƵůůdtĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚƚŽΕϮ͕ϬϬϬĨƚǁŝƚŚĚŝĞƐĞů͘ WŽƐƚƌŝŐ^ůŝĐŬůŝŶĞtŽƌŬ (7-5/8" to be landed in existing casing spool) (Slim Bore Work String) *assure well is dead and OA dead before breaking stack. ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ ϭ͘WƵůůĂůůĂŶĚƌŽĚĂŶĚZ,ƉƌŽĨŝůĞ͕ƉƵůůƉůƵŐĨƌŽŵ^t^ƉƌŽĨŝůĞĂ ƚϵ͕ϲϯϬĨƚ͘ Ϯ͘^Ğƚ'>s͛ƐƉĞƌ'>ŶŐŝŶĞĞƌ ϯ͘ZDKΘƉŽƉǁĞůů ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ϯ͘KWƌĂǁŝŶŐ ϰ͘^ƵŶĚƌǇZĞǀŝƐŝŽŶŚĂŶŐĞ&Žƌŵ ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ tĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ WƌŽƉŽƐĞĚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ ZtKKWƐ ZtK ϬϱͲϭϰ Wd͗ϭϵϯϬϴϮϬ Changes to Approved Sundry Procedure 'DWH 6XEMHFW 6XQGU\ $Q\PRGLILFDWLRQVWRDQDSSURYHGVXQGU\ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ&KDQJHVWRDQDSSURYHG VXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKH³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJH LVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH 6WHS 3DJH 'DWH 3URFHGXUH&KDQJH +$. 3UHSDUHG %\ ,QLWLDOV +$. $SSURYH G %\ ,QLWLDOV $2*&&:ULWWHQ $SSURYDO 5HFHLYHG 3HUVRQDQG 'DWH $SSURYDO 2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG 2SHUDWLRQV(QJLQHHU 'DWH RWO 05-14A PTD: 1930820 Well Name: 05-14A API Number: 500292025301 Current Status: Shut-In Rig: Thunderbird #1 Estimated Start Date: 10/15/2021 Estimated Duration: 7 days Reg.Approval Req’std? 10-403, 404 Date Reg. Approval Rec’vd: N/A Regulatory Contact: Carrie Janowski Permit to Drill Number: 1930820 First Call Engineer: Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer: Ryan Thompson 907-564-5280 907-301-1240 AFE Number: 215-01431 IOR 112 Current Bottom Hole Pressure: 3,379 psi @ 8,800’ TVD 7.4 PPGE | Offset producer 05-30C - 11/19 Max. Anticipated Surface Pressure: 2,499psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 1,500 psi (Taken on 3/07/21) Min ID: 2.75” ID SWN profile @ 10,099’ MD Max Angle: 95 Deg @ 10,351’ Brief Well Summary: 05-14 was drilled in September 1983, it was sidetracked and completed as a 4 ½” slotted liner across Z1A in 1993. Increasing watercut now requires gaslift to produce, while IA x OA issues have kept the well offline since 2017. An LDL indicates a PC leak at 27ft, the IC packoff also leaks. Objective: Pull the existing 4-½” x 3-½” 13Cr tubing out of the well. Repair the PC leak by installing a fully cemented 7-5/8” tieback. Run new 4-½” x 3-½” 13Cr stacker packer completion. Achieve a passing MIT-IA & MIT-T. Pre RWO work: SL- Set plug in SWS nipple at 9,630ft. Dummy off top two mandrels MIT-T to 2,500-psi Pull lower station. DHD – CMIT-TxIAxOA to 500-psi Cycle LDS’s PPPOT-T EL – Cut tubing @ ~ 9,602’ Circulate well to 8.5 ppg 1% KCL w/ diesel FP on T & IA DHD - Bleed WHP’s to 0, bleed control line. Valve Shop – Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. NU BOPE configured top down, Annular, 2-7/8” x 5” VBRs, Blinds and flow cross. -00 DLB Duplicate of page 2 RWO 05-14A PTD: 1930820 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5” VBR’s with 4-½” and 2-7/8” test joints. Test the Annular preventer with a 2- 7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. RU control line spooler. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~90K 5. Pull 4 1/2” tubing to floor, circulate bottoms up. Lay down 4-1/2” and 3-1/2” tubing strings. 6. PU work string and set RBP ~ 3,200ft. Test RBP to 500 psi. Spot ~10ft of 20/40 river sand. POOH SBWS 7. Run a dress off assembly in the liner top at 3,176ft. POOH SBWS. 8. Land a test plug, and pressure test to 500 psi. Break the stack and add a tubing spool. NU BOP. Test the spool break to 3,000-psi. Swap the VBR’s to 7-5/8” fixed rams and test to 3,000psi. 9. Run 7-5/8” tieback, land casing and fully cement to surface. Break the Tubing spool from the casing spool and install the IC packoff. Test to 3,500-psi. 10. Set a test plug in the tubing spool and swap the 7-5/8” rams to 2-7/8” x 5” VBRs. Test with a 2-7/8” and 4-1/2” test joint to 3,000 psi. 11. RIH with workstring and drillout BHA, Drill up shoe tract. POOH SBWS 12. RIH with RCJB and clean up any debris. POOH SBWS 13. RIH and pull RBP, LDWS. Test casing to 3,000-psi. 14. Run 4 ½” x 3-½” 13Cr tubing with stacker packer gas lifted completion as detailed on proposed schematic. 15. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 16. Drop ball and rod and set packer with 3,500psi pump pressure. 17. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes 18. Shear valve in upper GLM. 19. Set TWC 20. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile, pull plug from SWS profile at 9,630ft. 2. Set GLV’s per GL Engineer 3. RDMO & pop well Superceded RWO 05-14A PTD: 1930820 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing Superceded RWO 05-14A PTD: 1930820 Wellbore Schematic Duplicate RWO 05-14A PTD: 1930820 Proposed Wellbore Schematic Duplicate RWO 05-14A PTD: 1930820 RWO BOPs Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 05-14A JBR 09/21/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 While shell testing, the Annular seals failed causing water to enter oil system. Changed out oil in Accumulator and change out Annular. Good test after that- 12 hour delay. Test Results TEST DATA Rig Rep:Flores/RiveraOperator:Hilcorp North Slope, LLC Operator Rep:Knowles/Wilson Rig Owner/Rig No.:Hilcorp Thunderbird 1 PTD#:1930820 DATE:9/8/2022 Type Operation:WRKOV Annular: 250/3000Type Test:WKLY Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopAGE220912165308 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3.5 MASP: 2499 Sundry No: 321-460 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 2 7/8 X 5 1/2 P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 1 3 1/8 P Kill Line Valves 3 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P12 Full Pressure Attained P124 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P3@2166 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P7 #2 Rams P7 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke NA0 HCR Kill P3 9 9 9 9 999 9 9 5HJJ-DPHV%2*& )URP1LFN)UD]LHU&QIUD]LHU#KLOFRUSFRP! 6HQW7KXUVGD\6HSWHPEHU30 7R5HJJ-DPHV%2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ &F3%:HOOV5:2:66 6XEMHFW7KXQGHUELUG5LJ $WWDFKPHQWV7KXQGHUELUG5LJ[OV[ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚƚŚĞϭϬͲϰϮϰĨŽƌƚŚĞKWdĞƐƚƉĞƌĨŽƌŵĞĚŽŶϴͬϯϭͬϮϬϮϮŽŶǁĞůůϬϱͲϭϰďǇdŚƵŶĚĞƌďŝƌĚZŝŐηϭ͘ WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨƚŚĞƌĞĂƌĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͕ EŝĐŬ&ƌĂǌŝĞƌ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Thunderbird 1 DATE: 8/31/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1930820 Sundry #321-460 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2499 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1FP FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8x5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result HCR Valves 1 3 1/8"P System Pressure (psi)2900 P Kill Line Valves 3 3 1/8"P Pressure After Closure (psi)1500 P Check Valve 0NA200 psi Attained (sec)11 P BOP Misc 0NAFull Pressure Attained (sec)117 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 3 @ 2200 P No. Valves 8P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 18 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:3.5 HCR Choke 4 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8/29/22 23:50 Waived By Test Start Date/Time:8/31/2022 12:20 (date) (time)Witness Test Finish Date/Time:8/31/2022 15:25 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Tested w/ 2 7/8 and 4 1/2 test mandrels. Fluid used for testing was water. Functioned ibop and retested and passed Adan Flores/Matt Rivera Hilcorp Alaska LLC. Nick Frazier/Daniel Scrapella PBU 05-14A Test Pressure (psi): bstiffler@thunderbirdfs.com pbrwowss@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0831_BOP_Hilcorp_Thunderbird1_PBU_05-14A +LOFRUS1RUWK6ORSH//& 9 9 9 9 9 999 9 9 9 9 9 9 9 -5HJJ FP Functioned ibop and retested and passed Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:193-082 6.50-029-20253-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11008 10996 8815 10112 none none 8823 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 20" 112 112 Surface 13-3/8" 34 - 2723 34 - 2723 4930 2670 Intermediate 9-5/8" 32 - 7106 32 - 6391 6870 4760 Production 7-5/8" x7" 3186 - 10210 3182 - 8822 8160 7020 Perforation Depth: Measured depth: 10210 - 10996 feet True vertical depth:8822 - 8815 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13-Cr x 3-1/2" 9.2 30 - 10109 30 - 8823 3176 3172Packers and SSSV (type, measured and true vertical depth) 7-5/8" SBP Slotted Liner 4-1/2" 10112 - 11008 8823 - 8815 n/a n/a 12. Stimulation or cement squeeze summary: Intervals treated (measured): Pump approximate 10 packing guns of Greenstick plastic packing. Final pressure = 5000 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 287-7503422470 00 0 3736 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8815 Sundry Number or N/A if C.O. Exempt: n/a Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 Plastic pack IC Packoff test void Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028326 PBU 05-14A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Failed Packoff Sealant Repair 4-1/2" TRSV 2071'2071' By Samantha Carlisle at 9:43 am, Jan 29, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.28 15:54:45 -09'00' Bo York SFD 2/1/2021MGR19FEB2021DSR-2/1/21 RBDMS HEW 1/29/2021 ACTIVITYDATE SUMMARY 11/29/2020 T/I/O = SI/1200/600 Temp= SI. PPPOT-IC Plastic pack RU plastic pack gun to ball valve, open ball valve, no pressure recorded on gauge, open bleed and attempt to flush plastic through void. Pumped approx. ½ cup plastic, void pressured up to 3800 psi with no returns. Pressure bled to 2500 psi in 15 min (no returns) re-pressured void to 3800 psi and held 3800 psi for 30 min with no pressure drop. Close ball valve and bleed. RD left 3800 psi on void. 11/29/2020 T/I/O = 720/1170/730. Temp = SI. Bleed OAP to 100 psi (Eval IAxOA). Temp PBGL rigged to IA is SI. AL CV = SI. IA FL @ 5989' (#2 SO). OA FL @ near surface. Bled OAP to BT from 730 psi to 100 psi in 1 hr (Gas). IAP decreased 10 psi. Monitored for 30 min. OAP increased 30 psi. Installed heater in wellhouse, bled tree cap to 0 psi. Side door left ajar. Final WHPs = 720/1160/130. SV, WV = C. SSV, MV = O. IA, OA = OTG. 11:45 11/30/2020 T/I/O = 720/1200/700 Temp= SI. PPPOT-IC Plastic pack (heater on Well 24 hrs) RU plastic pack gun to ball valve, open ball valve, no pressure recorded on gauge, open bleed and attempt to flush plastic through void. Pressured void to 3800 psi and held 3800 psi for 30 min with no pressure drop. Close ball valve and bleed. RD left 3800 psi on void. 11/30/2020 T/I/O = 220/1100/410. Temp = SI. Bleed IAP to 100 psi (eval IAxOA). PBGL rigged to IA is SI at CV. IA FL @ 5989' (sta #2, SO. 344 bbls). Bled IAP to OT from 1100 psi to 100 psi in 4.2 hrs. IA FL unchanged, OAP decreased 10 psi. Monitor for 30 min, IAP & OAP remained unchanged. FWHP = 720/100/400. SV, WV = C. SSV, MV = O. IA 7 OA = OTG. 17:15 12/3/2020 T/I/O = 970/100/280. Temp = SI. Bleed IAP & OAP to 0 psi (pre WH work). No AL. Heater install on IC void. IA FL @ 5989' (sta # 2 SO). OA FL @ 180' (11 bbls). Bled OAP to OT to 0+ psi in 45 min. Bled IAP to OT to 0+ psi in 2 hrs. OAP increased 20 psi. Monitored for 30 min. WHPs unchanged. Final WHPs = 970/0+/20. SV, WV = C. SSV, MV = O. IA, OA = OTG. 06:00 12/5/2020 T/I/O = 970/3/14. Temp = SI. Flush and re-plastic pack IC test void. No AL. Heater installed on well head. IA FL @ 5989' (sta #2 SO, 344 bbls), OA FL @ 180' (11 bbls). Bled IAP & OAP to 0 psi, held open bleed. Bled test void to 0 psi. Removed LDS in 7 Oclock position, installed modified LDS. Removing LDS one at a time, flushed old McEvoy graphite plastic from test void, and re packed with Self Mold (Green Stick) packing. Pumped 3 PKG gun loads to fill void. Pumped approx 1/2 stick to pack off test void, holding at 4700 psi. FWHP's = 970/0/0. 16:22 SV, WV = C. SSV, MV = O. IA & OA = OTG. 12/6/2020 T/I/O = 970/0/0. Temp = SI. Plastic pack. RU plastic pack gun to ball valve and pressure hydraulic to 5000 psi, open ball valve, pressure dropped to 4600 psi. Re- pressure void to 5000 psi, pressure dropped to 4800 psi in 15 min. Re-pressure void to 5000 psi, no pressure loss in 30 min, close ball valve RDMO. 12/6/2020 T/I/O = SSV/0+/5. Temp = SI. Cold OART (eval IAxOA). AL disconnected. IA FL 5989' (sta # 2 SO). OA FL @ 180' (11 bbls). Bled OAP to 0 psi in 10 min. Held open bleed for 1 hr. Used AL spool to pressure IAP to 500 psi. OAP went on a VAC. Monitored for 1 hr. WHPs unchanged. OART tag hung. Final WHPs = SSV/500/VAC. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 Daily Report of Well Operations PBU 05-14A Daily Report of Well Operations PBU 05-14A 12/8/2020 T/I/O = 1060/1600/40. Temp = 72°. OART (Day 1). AL Online @ 1750 psi (3/4" CNG poor boy). Operator POP'd well @ 10:00 am 12-8-20. 12:45. SV = C. WV, SSV, MV = O. IA & OA = OTG. 12/9/2020 T/I/O = 420/1660/350. Temp = Hot. WHPs (Eval IA x OA). Poor boy AL open @ casing valve. Ops bled the OAP from 700 psi to 200 psi (10 min, all gas, 0800 hrs). SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:55 12/11/2020 T/I/O = 450/1600/250. Temp = 135°. Re-plastic pack IC test void. No AL. Re- energized with Self Mold (Green Stick) packing. Pumped approx 1/2 stick to pack off test void, holding at 5000 psi. F inal WHPs = 450/1600/250. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 12/12/2020 T/I/O = 380/1670/430. Temp = 136°. WHPs (Post green stick). AL online (3/4" CNG hose). SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:00 12/13/2020 T/I/O = 350/1670/330. Temp = 136*. WHPs (Eval IA x OA). Poor boy AL open. The TP decreased 30 psi, IAP remained unchanged and the OAP has been bled by Ops twice since last monitor (overnight). SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:40 12/14/2020 T/I/O = 350/1670/340. Temp = 135*. Bleed IAP (Mitigate high OAP). Poor boy AL open on arrival. IA FL @ 5989' (#2, S/O). Ops SI well & double blocked AL. Bled the IAP from 1740 psi to 840 psi in 1.5 hours (Production, #14). No monitor. FWPs = SSV/840/340. SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:30 12/15/2020 T/I/O = 860/770/430. Temp = SI. Bleed IAP (Mitigate high OAP). Poor boy AL removed. IA FL @ 5989' (#2, S/O). LRS freeze protected the TBG overnight. Bled the IAP from 770 psi to 340 psi in 1 hour (all gas, OT tank) The TP increased 20 psi and the OAP increased 10 psi during the IA bleed. No change in the IAP or IA FL during the 30 minute monitor. FWPs = 880/340/440. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:10 12/16/2020 T/I/O = SSV/330/330. Temp = SI. WHPs (eval IAxOA). No AL. W HPs unchange overnight. SV, WV, SSV, = C. MV = O. IA & OA = OTG. 16:45 12/17/2020 T/I/O = SI/330/330. Temp = SI. Plastic pack. RU plastic pack gun to ball valve on IC PO test void to check plastic pack and re-pack if needed. Initial pressure on plastic packed test void is 3700 psi. Pump approximately 1/4 packing gun of green stick into test void. Pressure up on test void with green stick to 5000 psi. Lost 200 psi in 1st 15 min, lost 150 psi in 2nd 15 min. Pressure up on test void to 5000 psi. Lost 100 psi in 1st 15 min, lost 100 psi in 2nd 15 min. Close ball valve leaving 4800 psi on green stick packed test void. RDMO PPPOT-IC (FAIL) 12/18/2020 T/I/O = SSV/330/330. Temp = SI. Plastic Pack IC void. RU packing gun on Hoke valve. Initial test void pressure @ 3600 psi. Pressured back up to 5000 psi for 30 min, lost 600 psi in 15 min, lost 300 psi in second 15 min. Pressure back to 5000 psi for 30 min. Lost 500 psi in 15 min, lost 250 psi in second 15 min (FAIL). SV, SSV, WV = C. MV = O. IA, OA = OTG. 18:00 Daily Report of Well Operations PBU 05-14A 12/19/2020 T/I/O = SSV/330/330. Temp = SI. Re-treat IA w/ Green Stick. No AL. RU packing gun. Void @ 3200 psi. Pumped 1 full packing gun into IC void, pressure void to 5000 psi multipul times. Void continuously bled off, unable to pack void off to 5000 psi final pressure of 4000 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:00 12/25/2020 T/I/O = SSV/330/330. Temp = SI. Re-treat IC test void with Self Mold plastic (Green stick). No AL. RU packing gun to Hoke valve on IC test void port. Pumped Green stick packing into test void untill 5000 psi was achieved. Monitored for 15 min, void pressure decreased 1500 psi to 3500 psi. Repeated this process untill 1 full packing gun was pumped. Test void will not pack off. FWHP's = SSV/330/330. 17:15 SV, WV, SSV = C. MV = O. IA & OA = OTG. 1/2/2021 T/I/O = SSV/310/300. Temp = SI. Bleed OAP to 0 psi (IAxOA). OA FL @ 200' (12 bbls). Bled OAP to 0+ in 1 hr. Held open bleed for 1 hr 30 min. Monitored for 30 min. OAP increased 5 psi. Final WHPs = SSV/310/5. SV, WV, SSV = C. MV = O. IA, OA = OTG. 06:00 1/8/2021 T/I/O = SSV/300/100. Temp = SI. Assist Ops w/POP. AL spool disconnected. IA FL @ 5989' (sta #2, SO). Monitor WHPs during POP. See log for details. ***Continued on WSR dated 01/09/21.*** 1/9/2021 T/I/O = 400/1650/550. Temp = 130°. Pump green stick in IC void. ALP = 1650 psi, AL online (3/4" CNG hose). Bled OAP as needed. SI AL gas to allow IAP to decrease <1000 psi. Pressured test void to 5000 psi multipul times, pumped 1 packing gun of green stick into IC void. Only able to achieve 3600 psi on test void after 30 min. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:50 1/9/2021 ***Continued from WSR dated 01/08/21.*** T/I/O = 750/1800/100. Temp = 100°. Assist Ops w/POP. PBGLJ online. Continue to monitor WHPs and bleed OA as needed. See log for details. Final WHPs = 500/1650/100. SV = C. WV, SSV, MV = O. IA, OA = OTG. 06:30 1/9/2021 T/I/O = 260/920/680. Temp = 86°. Bleed IAP to 500 psi. AL disconnected. IA FL @ 5989' (Sta #2, SO, 267 bbls). Bled IAP to production (05-14) from 920 psi to 450 psi in 1.5 hrs. IA FL unchanged. Bled OAP to BT from 680 psi to 430 psi in ~5 min. Monitor for 30 min. WHPs unchanged. Final WHPs = SSV/450/430. SV, SSV = C. WV, MV = O. IA, OA = OTG. 23:30 1/12/2021 T/I/O = SSV/440/440. Temp = SI, OA FL depress to 1000 psi (eval OA FL). AL spool disconnected. Increased OAP using AL gas incrementally to 1000 psi shooting OA FL's through out process with no change in OA FL. Bled OAP to starting pressure, all gas. Final OA FL unchanged. Final WHPs = SSV/560/560. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:20 05-14 (PTD #1930820) Internal Waiver Cancellation - Normal Well -S/lb I û7 All, . An internal waiver was issued for IAxOA communication on well 05-14 ~' (PTD #1930820) on 12/10/05. The well passed a CMIT TxIA and an MIT-T v/ on 05/08/07 proving two competent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well 05-14 will be Operable. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 SCANNED MAY I 8 2007 . 1 of 1 5/11/20074:26 PM oN OR BEFORE c.~O~m~.~oc ~:. R N T. T Geo]osi~ca'l i¥iater"'¥a]s :]:nventor"y I} A T A T D A T A _.F' i.. LIS 93 '" 08~.,.° Z:, 0 .~, 93 .... 0°2 0AILY WELL ,"~,P (.~ , ,~ ~ .,.qi~ .... 08~ © ........ Slli~:VEY 93 ..... 082 SU!RVEY q 3 082 r' D N 9 3 -.~ 0 8 2 U :!31 T ( C; &,'S ) ~r,--'~:, ~: r', I"I .... 3 D N ~._~..r.-.)...~79 ..... i0209~ ..~ 'l" f.~ r'.,qhtF, E.P, ! E:.: 0~'o ..... .....?z,-.-93 . .... -r,'", · ~.~H W D D I R E C T 1i: ',? N A l.. ~' ? I 00 .~, 00 ~ 'i 'i 00 ,.9 ,. 0 (3 ~L. 8600"' i 0200 ~ 100 '" 3600 ... C: ()!... 0 F,: I'.E: I .I i"..]i)/:',.., i' i!J .... iR F: ,:.'J V "' .... ' 'i q 9 'i ()7,,' /..!:./.:. ... 09 ,/ i ?/" 'i !:?, !.".', 5 09,/'i',?/ i993 09 ,," 'i :),/ 'i 99 !:', 09/'i//'i9!:)3 i 0/./i i,/199a i () ::~ / 'i 8/' i 99 a. Ar'e dr'y d'i'l-c:h sam. p]es r'equ'ir"ed° yes~~~~ . ~ .,~ "/-~ I] ( ~ i'" E} ,3 ~} '~ ",' 0 ,:~~/d'~ ... ves, ~Ana'l ys'i s & de s,::xr" 'i pt'i oi-i., k?~: e'i'. v e~"l'~, WaS ~ ~'"e w~'l 'i -" ~ . ? . '~ ~ _ ~sts r"equ-'¥r'ed yes ~ Rece'¥ yes ~'~-~ We1 i ~'s '~n comp'l Yance _ ' i C 0 ~,'i H E N "F S i'l (J) ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~orage, AK 99510 Mar 15, 1994 Transmittal #: 94029 AR e Finals ~(.~ ~ John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution i Well iLog Datei Tool Type i Run, Contractor !Number (M-D-Y). ScaJe ~¢[-?~ i 01-02 i 2-26-94 i Prod/Spin/Temp{,~5 1, 5" Schlumber ~0-- i 01-03 I 2-19-g4 I ProdS. BSFFemp~.~")1,5" Schlumber ~-5-~(o i 01-09 I 3-01-94 i Tubincj Cutter ~ 1, 5" Schlumber °r"+-'c~ i 01-11 f 2-27-94 I Prod Prof/Spin ! 1, 5" Schlumber "~- 7._el ~ 01-18 i 2-23-94 ! Leak Detection I 1, l"& 5" Schlumber ~.- ~b'~ i 01-25 I 3-06-94 i CNL ! 1, 5" Schlumber ~%-- L~ ~3-20A i 2-17-94 i Perf i 1, 5" Schlumber ~03-20A f 3-03-94 ! Dual Burst '~? 1, 5" Schlumber ~,C)~ i 03-32 °i 2-26-94 ! Leak/Press/Tempi 1, 2" Schlumber L~ i 03-34A i 2-24-94 I Prod/Press/Temp! 1, 2"&5" Schlumber H%. i 04-01 i 2-19-94 1 Prod ! 1, 5" Schlumber. ~:%* i 04-24 I 2-22-94 ! Prod [ 1, 5" Schlumber; t~ i 04-40 ! 2-22-94 i Perf i 1, 5" Schlumber ~ i 04-46 ! 2-16-94 i RopePerf i 1,5" Schlumberi fl2-1 v , Schlumber ~'A k04'47 8-94 Perf ! 15" ~%~ 04-47 ! '2-15-94 ! '/CBT-GR I 1, 5" Schlumber ! ~04-47 [ 2-15-94, v CET-GR i 1, 5" Schlumber ~O !05'06 i2'11'94 i R erf (~")1' 5" Schlumber ~?-- I 05-14A ! 7-11-93 I USIT/Cem&Corr ,5" Schlumber ~. I05-15Ai 05-15A icC~GND/GR-[.v,~_~ 1,5" Schlumber ~t~ 05-26 3-02-94 Dual Burst '['~,' 1, 5" Schlumber z~?.. /'06-15 I 2'21'941 Prod 1, 5" Schlumber \ 06-15 ~ 2-22-94I Comp Neutron 1, 5" Schlumber !5'~- i 06-22A i 3-01-94 Perf [ _ 1, 5" Schlumber I1o 07-08f 3-02-94 Prod~:~l, 5" Schlumber -~ 07-23 3-07-94 Leak/Spin/Tempt~ 1, 5" Schlumber 09-34 2-21-94 Schlumber Tubing Cutter ~ 1, 5" ;r'4~ 11-02 2-10-94 Inj Pmf,/5¢w,_~-~, 5" Schlumber ¢~ /11-04 2-20-94 Tubing Cutter Y.~ 1, 5" Schlumber i~11-04 2-17-94 Tubing ~'~r.~J~ ~v3, 5" Schlumber , ~--+'5. 11-7ST ! 3-06-94 Inj Prof/Spin ~'-~(,F.- 1, 5" Schlumber [/ 6ST , i/111' t 2'25'94 Leak/Press/Tempi 1,1"&5" Schlumber /Spin//~bI ~ ~:~ ' ,11-17 ! .2-20-94 Leak [ 1, 5" Schlumber Kl1-17 3-08-94 Prod ! 1, 5" Schlumber ! ,(%__ ~ f 11-23 i 8-09-91 '['MD { 1, 5" Halliburton ~1 j_ 1-24A t 2-22-94 Comp/Perf j 1, 5" Schlumber ARCO Alaska, Inc. Is a Subsh:iary, of Al~ntlcRIchtle4d~ 02-01 We~ 4-24 the correct AP~ ~ is 50-029'21508°00 Number oi Records: ~ohn E. DeGrey Distribution: Central Files Chevron Exxon Phillips ANO-8 Geology BP× ' state'o! Alaska , Mobil please acknowledge receipt by signing and returning a copy of transmittal- ~v: ~"---~- RECEIVED INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 09/22/1993 PAGE: 1 93-082 407 93-082 DAILY WELL OP. 93-082 SURVEY 93-082 SURVEY Are well tests required? Was well cored? Yes No... Yes No COMP DATE:08-24-93 06-21-93 TO 07-28-93 7100.00-11008.00 MWD DIRECTIONAL if yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL COMMENTS' STATE OF ALASKA ALASKA MIL AND GAS CONSERVATION COIvlMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUS~DED [] ABANDONED [] SERVICE [] ~.,,~ . 2. Name of Operator 7. Permil Number ARCO Alaska,/nc. 93-82 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20253-01 4. Location of well at surface 9. Unit or Lease Name "'~"~'~/,~ 3132' NSL, 87' EWL, SEC. 32, T11N, R15ET/~;;-~"~-~'~i "'~"!' ~.E;iv!_~ ...... i ~':"~"~'~L~'~ i' Prudhoe Bay Unit At Top Producing Interval , n~,7~ ; "~'~"'~"~::-'- ~' ~-.[~'' :~' 110. Well Number ~ ~~'~'i,,~___ i i:,:~~li ......... 5-14Aprudhoe Bay Field/Prudhoe Bay Pool 505'NSL,1115' EWL, SEC. 29, T11N~ R15 .... 11. Field and Pool At Total DePth 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. KBE =64.3' I ADL 28326 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 6/27/93 7/24/93 -Z/2.SA~] N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey J20. Depth where SSSV set J21. Thickness of Permafrost 11008'MD/9676' TVD 11008'MD/9676'TVD YES [] NO []I 2071' feet MD I 1900'(Approx.) 22. Type Electric or Other Logs Run MWD/GYRO 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 112' 32" 224 sx Arcitcset 13-3/8" 72# N-80 Surface 2723' 17-1/2" 5822 sx Arctic PF II 9-5/8" 47# N-ao/Rs-95 Surface 7106' 12-1/4" 823 sx Class "G" 7-5/8" 29. 7# NT95HS 3186' 6936' 9-5/8" 300 sx Class 'G" 7" 29# N T-80 6936' 10210' 8-1/2" 525 sx Class 'G" 4-1/2" 12.6~ NSCT 10112' 11008' 6" Uncemented 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MD) None-Slotted Liner 4-1/2" x 3-1/2" 10110' 9516' 10112'-11006' NSC T/13CR .26. ACID, FRACTURE, CEMENT SQUEEZe, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/30/93 I FIowin~7 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .,. 30, GEOLOGIC MARKERS r,..RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9072' 8250' Shublik 9118' 8287' Top Sadlerochit 9188' 8350' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , _ Title Drilling EngineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well comaletion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS5-14A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 06/21/93 03:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 06/21/93 ( 1) TD:10145 PB:10086 RIG MOVE MW: 0.0 MOVE RIG. ACCEPT RIG 6-21-93 @ 03:00 HRS. RU, PULL BPV. 06/22/93 (2) TD:10145 PB:10086 06/23/93 (3) TD:10145 PB:10086 06/24/93 (4) TD:10145 PB:10086 06/25/93 (5) TD:10145 PB: 7350 06/26/93 ( 6) TD: 7156' ( 0) 06/27/93 (7) TD: 7111' ( 0) 06/28/93 (8) TD: 7480' ( 369) RIH W/BP & RP MW: 0.0 CIRC, SET BPV. ND TREE, NU BOPE. TEST, HGR LEAKING. PULL BPV, PULL HGR TO FLOOR. CBU. TEST BOPE. INSTL WEAR RING. MU BPLUG & RPKR, RIH. TEST ANNULUS MW: 0.0 RIH W/PLUG & PKR. CIRC. POH, CHG RETRIEVAMATIC. RIH. TEST ANNULUS. POH, SLIP & CUT DRLG LINE. MU RETRIEVAMATIC & RIH. TEST ANNULUS. NU BOPE MW: 0.0 Seawater ESTAB INJ RATE, POH LD PKR, CLEAR FLOOR. RIH W/PLUG, SET. PUMP WATER & CMT, TEST LINES. CIP. SQZ CMT. POH. PULL WEAR RING, ND BOPE, PULL PKOFF, INSTAL NEW PKOFF & TEST. PU BOPE, CHG API RING, TEST. NU BOPE. CUTTING WINDOW MW:10.1 KC1 INSTL WEAR RING. MU BHA & RIH. KU, WASH, TAG CMT. DRLG CMT TO 3340. TEST CASG. DRILL BP, WASH DOWN. TIH. DISPLC WELL W/MILL FLUID. POH. MU BHA, RIH TO 7350. SPOT PILL, POH. CUTTING WINDOW. FLUSH BOPE MW:10.1 VIS: 87 CUT WINDOW TO 7156. PUMP LOW VIS SWEEP, CIRC, PUMP PILL, POH. LD COLLARS & MILL. MU SHOE, RIH. BREAK CIRC. MU PKR, RIH. WASH, CIRC MIX CMT. PUMP CMT, CIP. CIRC, SET PKR. SQZ. REL PKR, PUMP DRY JOB, POH. FLUSH BOPE. SLIDING MW:10.0 VIS: 80 TEST BOPE. MU BHA & RIH. TEST MWD. RIH, BRK CIRC, TAG CMT @ 6800. WHAS CMT STRINGERS. DRLD HARD CMT. CIRC HOLE CLEAN. PUMP PILL, POH. CHG OUT MWD, ORIENT & TEST. RIH. KU, DRLG CMT TO 7111. SLIDING. DRILLING MW:10.0 VIS: 42 DRILL & SLIDE TO 7117. POH, WET. LD MWD. CUT & SLIP DRLG LINE, INSPT BRAKES. MU BHA, ORIENT & FLOW TEST. RIH, BRK CIRC, CONT RIH. KU, SLIDE & DRILL TO 7480. WELL : DS5-14A OPERATION: RIG : NABORS 2ES PAGE: 2 06/29/93 (9) TD: 8250' ( 770) DRILLING DRILLING TO 8250. MW:10.0 VIS: 43 06/30/93 (10) TD: 8731' ( 481) 07/01/93 (11) TD: 9205' ( 474) DRILLING AHEAD MW:10.0 VIS: 45 HOLE PULLING TIGHT & PKOFF ON CONNECTIONS, CIRC & REAMED. DRLD TO 8586. CBU. POH. CHG BHA & BITS, RIH. CIRC, REAM TO BTTM. CIRC OUT TRIP GAS. DRLD TO 8731. RIH W/HWDP MW:10.0 VIS: 52 DRLD TO 9205. CBU, DRPD SURV. POH. CHG BHA. RIH W/HWDP. 07/02/93 (12) TD: 9720' ( 515) DRLG AHEAD MW:10.0 VIS: 64 FINISH RIH. REAM TO BTTM. DRLD TO 9720. 07/03/93 (13) TD: 10016' ( 296) 07/04/93 (14) TD:10094' ( 78) 07/05/93 (15) TD: 9900' ( 0) 07/06/93 (16) TD: 9900' ( 0) 07/07/93 (17) TD: 9495' ( 0) 07/08/93 (18) TD: 9758' ( 263) 07/09/93 (19) TD:10096' ( 338) 07/10/93 (20) TD:10210' ( 114) REAMING MW:10.0 VIS: 66 DRLD TO 10016. CIRC. POH, CHG BIT, RIH. BEGIN REAMING TO BTTM. TEST BOPE MW: 9.9 VIS: 61 DRLD TO 10094. CBU, POH. RAN DSS TBG ON DP, RIH. CIRC. PUMP CMT. POH. CIRC, PUMP DRY JOB, POH. TEST BOPE. COND MUD MW:10.0 VIS: 64 TEST BOPE. CHG OUT HYDRIL ELEMENT. TEST ANN. PREVNTR. RIH, REPAIR DRIVE CHAIN. RIH. REAM TO 9642. REPAIR MWD COMPUTER. SLIDING TO KO. CLEANED OUT HOLE. CIRC & COND MUD PRIOR TO POH. WOC MW:10.1 VIS: 73 POH. MU DSS TBG & XO & RIH. CIRC & COND MUD. PUMP CMT, CIP. POH. CIRC. LD TBG. MU BHA & RIH. FLOW TEST MWD. RIH TO 7100. WOC. DRILLING AHEAD MW:10.1 VIS: 59 WOC. RIIH, PU KELLY. CMT DRILLING OFF. FIRM CMT. SURVEYS & ROP. DRESSED PLUG. WASH & REAM TO BTTM. DRLD TO 9495. RIH MW:10.0 VIS: 56 DRLD TO 9678. CIRC. SHORT TRIP. DRLD TO 9758. POH. CHG OUT BIT & MTR. RIH, CHK MTR, TEST MWD, RIH. MU BHA #15 MW:10.0 VIS: 63 REAM TO BTTM. DRLD TO 10096. PUMPLO-HI VIS SWEEP & CBU. POH. CHG OUT BHA. CBU MW:10.0 VIS: 64 RIH. WASH & REAM TO 10096. DRLD TO 10210. CBU F/SHORT TRIP. WELL : DS5-14A OPERATION: RIG : NABORS 2ES PAGE: 3 07/11/93 (21) TD:10210' ( 0) 07/12/93 (22) TD:10210' ( 0) 07/13/93 (23) TD:10210' ( 0) 07/14/93 (24) TD:10475' ( 265) 07/15/93 (25) TD:10635' ( 160) RIH W/LINER MW:10.0 VIS: 60 SHORT TRIP, HIT TIGHT SPOT, RIH. CBU. POH, WASH & REAM. RIH. CBU. POH, LD BHA. RU & RUN LINER. CIRC LINER VOL. MWD LOG EVAL. MU HGR & RIH W/LINER ON DP. POH, LD HGR & RETREIVE RABBIT ON TOP OF DART. RIH W/LINER. RIH W/TIE-BACK LINER MW:10.0 VIS: 70 RIH W/LINER. BROKE CIRC & TAGGED TD. CIRC. PUMP CMT, SET LINER HGR & PKR. RELSD RUNNING TOOL & REV OUT MUD. POH, LDDP. RU. WIH & LOGGED TO SURF. RD. RU & RUN SLT LINER. CIRC LINER VOL. RIH ON DP. RIH W/BHA #17 MW:10.0 VIS: 73 RIH W/LINER. PUMPED CMT. BUMPED PLUG. POH. MU BHA & RIH. DRLD CMT TO 6892. CBU. POH LDDC. TEST BOPE. RIH W/BHA #17. DRILLING MW: 9.0 VIS: 56 RIH TAG CMT. KU, CLEAN OUT CMT. CBU, TEST CSG. DRILL TO 10475. DRILLING MW: 9.0 VIS: 64 DRL TO 10600, CIRC, TOH. CHG BHA, RIH. DRILL TO 10635. 07/16/93 (26) TD:10713' ( 78) 07/17/93 (27) TD:10851' ( 138) ORIENT MW: 9.0 VIS: 58 DRILL TO 10713. CIRC. PUMP PILL, POH. CHG BHA, RIH. REAM TO 10713. CIRC HI VIS SWEEP. DRILLING DRLG TO 10851. MW: 9.1 VIS: 57 07/18/93 (28) TD:10883' ( 32) 07/19/93 (29) TD:10990' ( 107) DRILLING MW: 9.2 VIS: 57 DRLD TO 10871, CIRC. PUMP PILL, POH. CHG BHA. FLOW TEST MTR, RIH. LD DP. WASH, REAM, LOG TO 10871. DRLG TO 10883. TOH DRLD TO 1990, CBU, TOH. MW: 9.2 VIS: 10 07/20/93 (30) TD:10990' ( 0) 07/21/93 (31) TD:10210' ( 0) TEST BOPE MW: 9.2 VIS: 55 POH, LD JARS. RU & RIH W/DP. CIRC. CONT RIH. MIX CMT, PUMP CMT, DIPLC W/MUD. CIP. POH, CIRC. PUMP PILL, POH. RU & TEST BOPE. TOH MW: 9.3 VIS: 47 TEST BOPE. MY BHA #33 & RIH TO 9654. CLEAN CMT. CIRC & COND MUD. POH. WELL : DS5-14A OPERATION: RIG : NABORS 2ES PAGE: 4 07/22/93 (32) TD:10230' ( 20) 07/23/93 (33) TD:10590' ( 360) SLIDING MW: 9.3 VIS: 47 POH, LD DC. MU BHA, RIH. KU, DRLD TO 10219. POH. CHG PULSAR IN MWD, RIH. KO CMT PLUG @ 10219. DRILLING MW: 9.1 VIS: 52 DRILL TO 10339. POH, RIH. WASH & REAM. DRILL TO 10590. 07/24/93 (34) TD:10835' ( 245) 07/25/93 (35) TD:ll008' ( 173) 07/26/93 (36) TD:ll008' ( 0) 07/27/93 (37) TD:ll008' ( 0) 07/28/93 (38) TD:ll008 PB:ll008 DRLG MW: 9.1 VIS: 55 DRIL TO 10669. POH. CHG BHA. RH. REAM TO 10669. DRLD TO 10835. OPEN HOLE MW: 9.1 VIS: 57 DRIL TO 11008. CBU, SHOR TRIP. POH. PUMP PILL, POH. MY BHA & RIH. OPEN HOLE TO 10430. CIRC MW: 9.1 VIS: 55 REAM TO 11008. CIRC HOLE CLEAN. POH. PUMP PILL, POH. RU & RUN LINER. MU HGR. RIH W/LINER ON DP. SET PKR. TEST ANN. PU DP TO CLEAR PORTS & CIRC. RUN TBG MW: 9.1 VIS: 0 DISPLC SW. CIRC LINER CLEAN. POH & CIRC W/SW. POH. LDDP, RUNNING TOOL. RU & LD CIRC STRING. PULL WEAR RING. TEST PKOFF. RU & RUN TBG. ND BOPE MW:10.1 KC1 RAN TBG. CIRC. SET BPV. RILDS, TEST ANN SEAL. TEST PKR HGR. ND BOPE. SIGNATURE: (drilling superintendent) DATE: I~!AL -, .--- ,.--.~,. - -'-- ,r ..... T k:.-'. ? ?.qi., 30, 7i-'.X.~ O0 O,O 6360,0.0 724'..:', '.;'0'" '" .......... :' 7322,40 / '~--.;'.? + 7£ 74.':.':-': 3~, ~_'. O:/.:--,7i . --.-m r, ~.~.:qK. ?.~, 6~78~41 r'..-.r.'"'r~,',, -t,....,? ~, c,=: =. -':?, .':o..'.', 04 ......... 27,49 ...... ., · :£ 2E1::,:,'.::7 v,~. ,c.,o:*'-' :"' 23,5,4:87 '~s-7--,: ,:39 ~-: ;. g .. 4".;." ,38 ~.:,oo ..........., ~27,77 8,!9 4%25 2371 ~31,44- 8,14 47,2~ 2374,03 ft '-,. dec 664,63 2414,]h 20,?c,,: 878,46 24%,39 20,?'; 58.'::, 4'7-..' 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"' 42A-%~,3 87,20 ..... ~'" 4037,~ ~4. .".~.'. ; .~ .,*¢'~-,.C 4"% r,r. ,-,.- t v. 0_,, i Ag,e,; ,-'o,.t.u 4066 "~ ¢i ~.='.2 , b'.f, ,0£ - " ........ q 'i E~,i ~./o--',.~/ 4326,34 86:60 20.60 "'"" '"= ,.>::, i ! 42:7oo;'" 19 ,2g l ,75' - ,.-; ,o*, 59 1'?,27 1,72 1401,. .... *=*':, ~. .~_,,-,,.-, 4277. . ,'~a'":: ] 9,2',~:. I "' .,,t,'-~-', v...-. .- .-. r. ~ ~: ~'-'- ................... 2.3 20 ...... " '-:.' ~.:.,*0£ ~-J,~,/ ,/Lc O/: -"'d ? N,~-~£~ CF..: ....c,.:4 8;--"87,1'.:.: ~'-:8,9'4 c:..-;=,:u""-' 19,?C' ,~;:.4: .... 878-3:91 4478,48 6.3:?0 2./-o: 30 425:.'5,2'.. 1444.5'-'- ,1369,48 1"?.31 2,60 1455,03 ~.'O.S, i,~ 19,3: I465,7'9 44S1,51 ,.~';' ,...: 5~-' 2.14 14~:.6,, E',3 ,-'.~c: i ''~' i q,,-<c: , .. +~',. .., -.~. . _ Oil & Ga,'-; Coiis., ~ .. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-1 0-93 REFERENCE: ARCO DIRECTION~ DATA c{~_ ~% 3-18A 4-24-93 Electronic Multi-Shot Survey Job~~ Sperry c~_ a-~ 3-20A 4-14~93 Electronic Multi-Shot Survey Job~30022 Sperry ~%-~ 5-3A 5-26-93 MWD Directional Survey Ana c/%_~ 5-15A 6-26-93 MWD Directional Survey Aha c.~_~ 6-22A 4-30-93 MWD Dlrectionnl Survey Ana ~-q0 18-29A 4-26-93 MWD Directional Survey Ana q~- {~5 AGI-3 4-14-93 MWD Directional Survey Job~1163 BHI ~- 1~ AGI-4 4-14-93 MWD Directional Survey Job~1168 BKI ~%-27 AGI-7 4-28-93 MWD Directional Survey Job41185 Teleco /AGI-9 5-17-93 MWD Directional Survey Job# 1195-450 BHI c~ ~5 ~.AGI-9 5-8-93 MWD Directional Survey Job~1195-450 BHI Please sign and return the attached copy as receipt of data. Have A Nice Day! Sonya Wallace APPROVED_.~JA~ ATO- 1529 Tr~ns# 93 102 CENTRAL FILES CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON MOBIL PHILLIPS # PB WELL ~ R&D #BPX # ST. OF .~K__ (2 COPIES) # LUCILLE JOHNSTON ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEPTEMBER 7, 1993 MARION SLOAN BP EXPLORATION ALASKA INC. P O BOX 196612 ANCHORAGE, ALASKA 99518-6612 RE: 93-0002 PRUDHOE BAY UNIT AGI-5 COMPLETION REPORT° 93-0009 PRUDHOE BAY UNIT AGI-6 COMPLETION REPORT 93-0082 PRUDHOE BAY UNIT DS5-14A COMPLETION REPORT 93-0047 PRUDHOE BAY UNIT DS3-20A COMPLETION REPORT 93-0057 PRUDHOE BAY UNIT DS6-22A COMPLETION REPORT DEAR MARION SLOAN, OUR FILES INDICATE THAT ARCO ALASKA IS THE OPERATOR OF THE REFERENCED WELLS. THESE WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO DATE. MAY AND JUNES MONTHLY PRODUCTION 3'~REPORTS INDICATE THAT THESE WELLS ARE GAS INJECTORS AND OIL PRODUCERS FOR YEAR 1993. WE HAVE NO PAPER WORK SHOWING THE COMPLETIONS FOR THE MENTIONED WELLS. I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME. THANKS FOR YOUR QUICK RESPONSE ON THESE REPORTS. SINCERELY, STEVE MCMAINS STATISTICAL TECHNICIAN Date' Subject' From/Location: Telephone: To/Location: July 19, 1994 Transmittal #: ARCO Open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94063 Well Log Date Number (M-D-Y) 05-03A i 05-10A 05-14A 1-23A 15-36 i 15-37 06-13-93 i06-17-94 Tape Type CDR/CDN MWD J ZDL/CN/GR 07-09-93I CDN O6-3O-94 06-05-94 06-24-94 DIFL/ACICNIGR Run, Footage DLL/AC/GR/ZDL ! DLL/ZDL/CN/GR i 1, 10801- 9845 ; 8690-9596 i 1, 10209- ~ 8579 10106- 12034 11106- 11795 10352- 11038 Contractor Sch Atlas Sch Atlas Atlas Atlas Number of Records: 6 ~ohn E. DeGrey Distribution- Bob Ocanas Phillips BPX Exxon State of Alaska ARCO Alaska, Inc. Date: Subject- From/Location: Telephone: To/Location: P.O. Box 100360, , ,chorage, AK June 21, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94048 99510,~ ~, Well Number 5-14A 9-11 i 6-11-94 /11-35 -35 /'11-35 /15-36 / 15-36 Jl 5-36 i Log Date I Tool Type Run, Scale (M'D'Y) / 7-09-93 ,-/ CDN ~ 1,2"&5" I ~'' Collar 1,5" 5-19-94 1~- Borehole Prof 1,2"& 5" 5-19-94 l.-"Dual Ind, GR/SP 1,2" & 5" 5-19-94 SSTVD 1, 2"& 5" 5-19-94 . ."Z-Densilog,CN 1, 2" & 5" 6-05-94 I ~. DLL, GR/SP 1,2"& 5" 6-05-94 lJBorehole Prof 1, 5" 6-05-94 ~ ~.Densilog,CN 1,2"& 5" 6-05-94 ,xf3omp 4-arm dipIo, 1, 5" /'B~ Acous, G R 1,2" & 5" / SSTVD 1, 2"&5" --'15-36 ! 6-05-94 /'15-36 i 6-05-94 Contractor SCH Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas * The correct APl # for 5-14A is 50-029-20253-01 Number of Records: Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M PB Well Files Please acknow~eceipt by igning and returning a copy of transmittal. ~ Date' By: ..- / ~ _ ARCO Alaska, Inc. Is a Subsidiary o! AtlantlcRIchfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 4,1993 Russ Strickland, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit DS 5-14A ARCO Alaska Inc 93-82 3132'NSL, 5193'WEL, Sec 32, T11 N, R15E, UM 1965'NSL, 3767'WEL, Sec 29, T11N, R15E, UM Dear Mr Strickland: Enclosed is the-approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until ali other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. Yours truly, Russell A Doug~a~~~~~ Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl · .... -- STATE OF ALASKA __ ALASKA._ AND GAS CONSERVATION COI,../IISSION PERMIT TO DRILL 20 AAC 25.005 ~la. Type of work Drill [] RedrillE]llb. Type of well. Exploratory[] Stratigraphic Testl--1 Development OilE] Re-Entry [] DeepenDI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) I10. Field and Pool . ARCO Alaska,/nc. KBE =64.26 feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28326 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(~,,e 20 AAC 25.025) 3132' NSI., 5193' WEL, SEC. 32, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1289' NSL, 3951' WEL, SEC. 29, T11N, R15E 5-14A U-630610 At total depth 9. Approximate spud date Amount 1965' NSL, 3767' WEL, SEC. 29, T11N, R15E 6/8/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dmVD) property line ADL 28321-3313' feet No close approach feet 2560 10891' MD/8802' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (,,, 20 AAC 25.035 (e)(2)) Kickoff depth ~'~oo feet Maximum hole angle ~ o Maximum surfa, ce 3330 pslg At total depth (TVD) ~800'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 9-5/8" 7-5/8" 29.7# L-80 STL 3650' 3300' 3291' 6950' 6275' 376 cu fl Class "G" 8-1/2" 7" 29# L-gO NSCC 3241' 6950' 6275' 10191' 8814' 724 cu fl Class "G" 6" 4-1/2" 12.6# L-80 Fox 800' 10091' 8811' 10891' 8802' Uncemented 19. To be completed for Redrill, Re-entry, and Deepen Operations. ,, ,~,, ~- ' Present well condition summary Total depth: measured 10145 feet Plugs (measured) (',,i~~'',-, '~ ~. 4 ~. true vertical 8907 feet . Effective depth: measured 10096 feet Junk (measured) Aiasi¢a. 0il.& 6as ¢0~s. true vertical 8882 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 112' 20" 224 sx Articset 112' 112' Surface 2723' 13.3/8" 5822 sx PF II 2723' 2723' Intermediate Production 10130' 9-5/8" 823 sx Class "G" 10130' 8893' Liner Perforation depth: measured 9976'-9982; 10008'-10034' . true vertical 870.4'-8709', 8784'-8806' 20. Attachments ' Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid procjram [] Time vs depth pict [] Refraction analysis[] Seabed reportl-'l 20 AAC 25.050 requirementsl-I 21. I hereby ~rtify thatrt,~e ~oreg~ng is true and correct to the best of my knowledge /! Signed ~ ...~¢~~-'~ TitleDrillinrjEn~TineerSupervisor Date.~/ ~'~' Commission Use Only Permit Number IAPi number IApproval date ISee cover letter ~,.~- ~.2_. 150- ~.2__;P- .P-O.~--~Z-~::~ /I Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes 1~ No Hydrogen sulfide measures [] Yes 1~ No Directional survey required ~ Yes [] No Required working pressure for BOPE 1'-I2M; 1-13M; I~5M; I-ll0M; ~15M; Other: by order of./..' Approved by ORIGINAL SIGNED BY Commissioner me commission Date Form 10-401 Rev. 12-1-85 RUSSELLA. BOL~GLASS Submit in tril~licate D.__~,, ;-14A Drilling Permit Informa Preliminary Well Plan Well' APl No.' Location: Est. Start: Est. Time: Contractor: Directional: Wellbore' 5-14A Redrill PBU 50-029-20253-00 (on the original 5-14 well) Surface: 3132' FSL, 5193' FEL, Sec. 32, T11N, R15E, Target: 1289' FSL, 3951' FEL, Sec. 29, T11N, R15E, BHL: 1965' FSL, 3767' FEL, Sec. 29, T11N, R15E, UM UM @ 8814' TVD BKB UM @ 88O2' TVD BKB 8 June 1993 27 DAYS Nabors Rig #2ES Kickoff at 7100' MD. Drop angle at 6°/100 from 39° to 5.9° @ 7665' MD, Hold tangent to 8700' MD then build 6°/100' to 90° with a final azimuth of 15°. See directional details for more information. ,,Item TVD(BKB), MD(BKB) KOP1 2813' 2813' KOP2 6360' 71 00' TOP SADLEROCHIT 8349' 91 77' TARGET 881 4' 101 91' TOTAL DEPTH 8802' 10891' Logging Program: 8-1/2" Hole' MWD Conveyed Gamma Ray / Neutron / Density. Horizontal section' MWD Conveyed Gamma Ray ^iask;~ Oil & ~Anchora§o KJT Page 4 5/24/93 D__~ ~-14A Drilling Permit InformP. n Ob_iective' The primary objective of the DS 5-14 redrill is to return the well to production by drilling a new horizontal hole to a position near the current bottom hole location. Escaping suspected formation damage and improving the reservoir's performance are the reasons driving this redrill. Attempts to flow the well have been unsuccessful since an August 1990 gas-shut-off cement squeeze. This redrill will target Sadlerochit Zone 1, Lower Romeo sands to access reserves in the same drainage pattern. Included in the redrill is the repair of a confirmed 9-5/8" casing leak near 3400'. A near horizontal wellbore will replace the conventional one in an attempt to minimize gas coning. Scope: The scope of the DS 5-14A redrill is as follows: Once the original perforations have been abandoned, cut and pull the existing 5- 1/2" tubing completion. Set a 9-5/8" drillable bridge plug at 7350' MD and at 3450' MD. Squeeze the casing hole located near 3400' and ddll out the upper plug. Mill a 50' section in the 9-5/8" casing starting at 7100 'MD. Lay a cement plug across the section, kickoff, and drill a new 8-1/2" hole. Build the wellbore's inclination angle to 90° at the base of Sadlerochit. Run in the hole a 7" 29# L-80 liner and cement it in place. Run a Schlumberger USlT casing inspection Icg to examine the 9-5/8" pipe and determine the extent of the casing's damage. Run a 7-5/8" tie- back liner from the 7" liner top to at least 3300' (100' above squeezed casing leak.) The actual top depth of the 7-5/8" liner will depend on the casing inspection log's results. Cement the tie-back liner in to place. Drill approximately 700' of 6" horizontal section. Complete the well with a 4-1/2"x3-1/2" 13-Chrome tubing string and 5 gas lift mandrels (GLMS)in the vertical section, and a 4-1/2" L-80 slotted liner in the horizontal section. Open hole logging will be accomplished with Gamma Ray / Neutron / Density MWD tools in the 8-1/2" hole section and Gamma Ray only in the 6" hole section. Timing: This project is presently scheduled for Nabors Rig 2ES upon completion of activity on DS 5-3A in early June 1993. The sidetrack and casing repair should take approximately 27 days. KJT Page 1 5/24/93 D___, 5-14A Drilling Permit Inf0rm~ Summary Procedure: , , o , 5. 6. 7. , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. Pre-rig work: Kill the well. Pull the retrievable pack-off gas lift mandrel (POGLM) at 6766 'MD. Lay a cement plug across the perforations according to state regulations for well abandonment. Cut the 5-1/2" tubing near 7400' MD. Freeze protect the well and set a back pressure valve (BPV.) Test the intermediate casing pack-off to 3500 psi. Move in the workover rig. Test the 9-5/8" intermediate casing pack-off if not done during the pre-rig work. Pull the BPV. Circulate the diesel freeze protection cap from the well and recover for future use. Install a BPV and a test tree plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull out of the hole and lay down the 5-1/2" tubing. Set ~ drillable bridge plugs at about 7350' and 3450' MD. Perform a cement squeeze of the 9-5/8" casing hole near 3400'. Drill out the cement and upper plug. Replace the 9-5/8" casing pack-off as needed. 95 " Spot a 18 ppg pill on bottom and cut a 50' section in the -,/8. casing starting from about 7100' MD. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open-ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1./2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target at 8750 'TVD-ss as per the attached directional plan. Obtain .Gamma Ray / Neutron / Density formation evaluation logs while drilling in zones designated by Geology. Run a 7" 29# L-80 NSCC liner assembly to bottom in the 8-1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. Cement the 7" liner with 724 ft3 of class G cement. The cement volume is planned to ensure cement 1000' above the hydrocarbon bearing zones. Re-test BOP's as needed. Run a 9-5/8" casing inspection log (Schlumberger USlT) to determine the extent of casing damage. Run a 7-5/8" 29.7# STL tie-back liner from the 7" liner top to at least 3300' (100' above squeezed casing leak.) Actual top depth of tie-back liner will depend on the results of the casing inspection log. Cement the liner in place with 376 ft3 to prevent future corrosion damage from the apparent Cretaceous leak near 3400'. The planned cement volume is based on the annulus volume plus 10% excess. Run in with 6'~ steerable drilling assembly with directional/Gamma Ray MWD on 4-1/2" x 3-1/2" drillpipe. Drill out the float shoe. Displace the well with a non-damaging (Xanvis polymer) drilling fluid. Drill approximately 700' of 6" hole to TD as per the Geologist / Operations Engineer onsite. Make a conditioning trip with a 6" hole-opener for the open hole section with a 7" casing scraper spaced to clean the liner. Install a 4-1/2'! L-80 slotted liner with 7" Baker packer / hanger. Run in on 4-1/2" x 3- 1/2" drillpipe with a 2-1/16" wash string inside the slotted liner. Space packer / hanger to be set within 100' of the 7" liner shoe. Position packer 100' above the 7" liner shoe and circulate. Set the packer and test the setting. Release from the packer / hanger and displace the drilling fluid with filtered seawater but no corrosion inhibitor. Spot the breaker, ir~side, the slotted liner. KJT *ooj~ 5/24/93 Page 2 i'?~ ~' ¥ ~ 4 ~¢ ;~ G~S O0DS. O Atask& ~,t & Anchorage D'__., 3-14A Drilling Permit Informs n Summary Procedure (con't): 24. 25. 27. 29. 30. 31. 32. 33. 34. Pull the wash string up just above the hanger and circulate well clean with filtered and inhibited seawater. Pull out of the hole and lay down the wash string. Retest 9-5/8" wellhead packoff and replace as needed. Run the 4-1/2" / 3-1/2" 13-Chrome completion string assembly. Space out, attach the tubing hanger, and latch the completion. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release the rig. Complete appropriate documentation and hand-over the well to Production KJT Page 3 5/24/93 D....~ 5-14A Dril. ling Permit Informs, ~ Mud Program' The milling / drilling fluid program will consist of a 9.8 - 10.2 ppg XCD polymer / KCL water based mud in the 8-1/2" hole. hole section. Mud weight will be reduced to 9.0 - 9.2 ppg in the 6" DEPTH DENSITY PV YP INT 10MIN FL OIL SOLIDS MUD _ (TVD) . (PPG) (CP) (_#/FT) GEL GEL cc/30min (%) (%)., ,TYPE KOP 9.8 1 0 1 0 5 7 8 0 5 Water to to to to to to to to to Base BASE 10.2 1 6 1 8 15 1 5 6 0 7 Mud HORIZ. 9,0 6 1 5 10 15+ 5 0 4 Water SECTION to to to to to to to Base TD, 9.2 10 20 15 8 0 6 Mud Well Control' Est. Pore Press. Sadlerochit: 3630 psi/8800' TVD -ss 7.9 ppg EMW (est.) Overbalance Top Sadlerochit' 855 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4350 psi at 8800' TVD-ss based upon original reservoir pressure. Maximum possible surface pressure is 3470 psi based upon a gas column to surface from 8800' TVD-ss. Fluids incidental to the drilling of the well will be removed by truck and disposed into well CC-2A. Liner Details: CASING DEPTH BURST COLLAPSE TENSILE ('MD) (psi) (psi) (Mbs) 7" 29# L-80 NSCC 7-5/8" Tie-back 29.7# L-80 STL 4-1/2" 12.6# L-80 FOX 6950 - 10191 ~3300 - 6950 10091 - 10891 8160 7020 746 6890 4790 527 (Slotted) in the Horizontal Section Aiask'a, (}il & Gas Cons. KJT Page 5 5/24/93 Cement D...~ J-14A Drilling Permit Informs n Calculations: 7" LINER' Measured Depth' 6950' (Hanger)- 10191' (Shoe) Basis: Assume equal to volume behind pipe for 9" open hole in sand interval and 12" open hole in shale interval', plus shoe volume. Allow for cement 1000' above the hydrocaron bearing zones (above the Sag River.) Total Cement Vol' 724 cuft or 614 sks of Class G blend @ 1.18 Cu ft/Sk 7-5/8" TIE-BACK LINER: Measured Depth: Basis' Total Cement Vol: TUBING DETAILS: ,,,3300' (Hanger) - 6950' (Tie into 7" Liner Top) Annulus volume plus 10% annulus volume excess 376 cuft or 319 sks of Class G blend @ 1.18 Cu ft/Sk 4-1/2" 12.6# 13-Cr 3-1/2" 9.3#, 13-Cr (Surface- 3000' MD X-over) (3000' MD - 10091' MD) KJT Page 6 5/24/93 GR LAND DIRECTIONAL DRILLING~ CorporaUe Office 111i East 80th Avenue Anchorage, AK 99518 (907) 349-4511 F~x 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Jell ......... : DS 05-14A (P4) cield ........ : PRUDHOE BAY DRILL SITE 5 :omputation..: MINIMUM CU~VATD~E ;nits ........ : FEET LEGAL DESCRIPTIOlq 3urface ...... : 3132 FSL 5193 FEL 3ie-in ....... : 22 FSL 4337 FEL ?arget ....... : 1289 FSL 3951 FEL ~F_L .......... : 1965 FSL 3767 FEL Prepared ..... : Section at...: Fd~ elevation.: 15.00 64,26 ft S32 TllN R15E UM S29 Tlllq R15E UM S29 TllN R15E UM S29 TllN R15E UM 697148.09 5949296.3~ 697939.40 5951487.75 [~,, !.~," :'".~ ~%~i £~ ~ ~ ~f~ ~ 698287 . 26 5~52764 . ~7 698450.63 5953445 ,~k,3 C}J~ & GaS (~O[~S, 0om~Js~[0D A~mhorago PROPOSED WELL PROFILE STATION IDENTIFICATION TIE- IN MEAS DEPTE 7100 7200 7300 7400 7500 INCLN ANGLE VERT-DEPTMS SECT B~ SUB-S DIST 39.04 6360 6296 2316 33.07 6441 6376 2374 27.10 6527 6463 2424 21.15 6618 6554 2465 !5.23 6713 6649 24~6 DIP~ECTION REL-COORDINATES DL/ AZIMUTH FROM-WELLHEAD 100 9.04 2!70 N 848 E <TIE 9.94 2228 N 858 E 6.0 1!,18 2277 ~ 867 E 6.0 13.05 2317 N 876 E 6.0 16.30 23~7 N 884 E 6.0 EN~ OF CURVE ~l K5 BLD a TaW 6.oo/loo 7600 7665 8518 8700 8800 9.42 6811 6747 25!7 5.87 6875 6811 2526 5.87 7724 7660 2608 5.87 7905 78~l 2625 11.60 8004 7940 2640 23.48 2368 N 890 E 6.0 35.44 2375 N 895 E 6.0 35.44 2446 N 945 E O.O 35.44 2461 N 956 E 6.0 23.81 2475 N 963 E SAG RrVER (GAs) 8900 8925 9000 9055 9100 17.52 8101 8036 2665 19.01 8124 8060 2672 23.48 8194 8!30 2700 26.79 8244 8180 2723 29.46 8284 8219 2744 19.87 2498 N 972 E 6.0 19.26 2506 N 975 E 6.0 17.88 2531 N 983 E 6.0 · 17.14 2554 N 990 E 6.0 16.66 2574 N 997 E 6.0 SKUBLIK TSm~ 14/4~ / rv~sm~K zoom 9106 29.84 8289 8225 2747 9177 34.08 8349 8285 2785 9200 35.44 8368 8304 2798 9267 39.46 8421 8357 2838 9~00 41.43 8~4~ ~222 2~60 16.59 2577 N 997 'E 6.0 15.99 2613 N 1008 E 6.0 15,82 2625 N 1011 E 6.0 15.39 2665 N 1022 E 6.0 !5.20 2685 N !028 E 6.0 BUILD 3.00/100 ZONE 2 zo~ 2/2c BUILD 6.00/100 ZONE 2 B/TANGO 9328 9350 9400 9458 9467 43.70 8474 8410 2886 44.08 8~83 8419 2894 45.56 8518 8454 2929 47.30 8558 8494 2971 47.~7 8564 8500 2978 ~500 ~9.56 8586 8522 3002 9523 50.97 8601 8537 3020 9600 55.56 8647 8583 ~082 15.00 27!0 N 1035 E 6.0 15 . 00 2718 N 1037 E 3 . C 15 . 00 2752 N 1046 E 3 . 0 15.00 2793 N 1057 E 3.0 15.00 2799 Iq !059 E 3.0 15.00 2823 N 1065 E 6.0 15.00 2840 N 1070 E 6,0 15.00 2900 N 1086 E 6,0 SLDD (c) 93 DS0514k R1,48 10;25 PM 2) S 05-!4A (P4) · 05/20/93 Page 2 STATION IDENTIFIC~,TION ZONE 2A/ROME0 PGOC ZONE 1B/LOWER ROMEO GAS UNDERRUNS END OF 6.00 BUILD TARGET TD BSAD / KAVIK PROPOSED WELL PROFILE MEAS INCLN VERT-DEPTHS SECT DIRECTION EEL-COORDINATES DL/ DEPTH ANGLE RKB SUB-S DIST 9700 61.56 8699 8635 3167 9739 63.93 8717 8653 3202 9751 64,62 8722 8658 3213 9782 66.51 8735 8671 3241 9800 67.59 8742 8678 3258 AZIMUTH FROM-WELLHEAD 100 15,00 2982 N 1108 E 6,0 15.00 3016 N 1117 E 6.0 15,00 3026 N 1119 E 6.0 15,00 305% N 1127 E 6.0 15.00 3070 N 1131 E 6.0 9900 73,56 8775 8711 3352 10000 79.56 8799 8734 3449 10100 85,56 8812 8747 3545 10191 91.00 8814 8750 3639 10191 91,00 8814 8750 3639 15.00 3160 N 1155 E 6.0 15.00 3254 N 1181 E 6.0 15.00 3350 N 1206 E 6.0 15.00 3437 N 1230 E 6,0 15.00 3437 N 1230 E 6.0 10891 91.00 8802 8738 4338 8814 8750 !5.00 4113 N 1411 E 0.0 TOTAL P.20 VERTICAL SECTION VIE~ Sect ion at: ~5.00 TVD Scale.' I ~nch = 400 feet 600o- Oep Scale.' ~ inch ~ 400 feet "N, i i ..... 1 Dna~n. ' 05/20/93 ~oo~ ~ .... i ',, ] Great ..... Land... Directional... DrJ]]jng, A ~ Narker ldenLification ND BKB SECTN INCLN 6400 ..... ~ 'J i A) TIE-IN 7t00 6360 2316 3g.04 , C] ELD 6 TRN 6,00/100 8700 7905 2625 5.87 ~ .... ~%--~ --- D) BUILO 3,go/lO0 9338 8474 2886 43.70 5600--- ,: ~",~ -'- E) BUILD6 00/~00, 9467 856~ ~97B 47 57. 6800-- j ~ ¢1 END OF 6,00 BUILD to~g~ BB~Z 3639 91.00 ,. G) TARGET t0t9t 8B~ 3639 91,00 B ~ ~ ~N' H) TO loBg~ 8B02 4338 91,00 7200 · X[ ....... 7~0o ....... 7 ~ .... x-( ......j .... ' ' --- 8000 '~ m , I'- ' ...... 8400 ~trl[ 41~X-~ 34~ ...... 'L' , ~ .... - .... T ~ ........ r' [ '-' ' An¢ .... ~ ~ ~/'~~ ,i ......... F ] ............. ~ ~ ~ ............ ~ ' ....... ' "' i ~~-- ~, ..... , .......... , .... ~ ..... ~. , , 8800- Fa~A[?~'~T -ge-' ~ ; ' , - :='.=~-'- .... : .... .I_ _ _ ] ........ ~- ~ ..................... . " [ I ,,, . . ;~oc,..~ I , I I , 2000... 2200 2400 ~800 2800 3000 3200 3400 3500 3800 4000 4200 4400 4600 Section Oepartuce PRbCHOE BAY DRTLL.,.,,IG 05- 4A (P4) PLAN VZEX CLOSURE ' 4349 feel at Azimuth ~8.93 DEOLZNATiON.' 30.00 E SCALE ' ~ inch = 400 feet DRAWN - 05/20/93 Srea ~ Land Narker Identification ND N/S A) TIE-IN 7100 2]70 N B} END OF CURVE ~1 7665 2375 N CJ BLD ~ fRN 6.00/]00 8700 2461 N D} BUILD 3,00/t00 9338 2710 fl E) BUILD 6.00/~00 9467 2799 N F) END OF 6.00 BUILD ~019~ 3437 N G) TARGET ~0]g~ 3437 N H) TO ~0891 4~13 N 4400 4200- 4000 3800- 3~00 3400- 3200 3000- 2800- 2600- 2400 2800- 2000 ~800 ~600 .... E/W 848 ~ 895 [ 956 1035 ~ '1059 E 1230 E 1230 E 400 800 0 200 400 600 800 ~000 ]200 t400 1600 1800 2000 2200 8400 - <- WEST- EAST -> 4° ~ C:~O~ .... ([Mu::) C:L.~'~¼ ' '~' IF/1 ' ~ ~~ . ~. ~D ~ ~2 2- co<xr . STANDPt=~ ' ,C:>+ BO~ STAC~ - '13 5/8 5000~ - HOKE I~LAN~OL.L'3 LEGEND I/1 au-rr~u~¥ [] 3L,~'TION VA.L.Y"E' A~ATOR NABORS 2ES I .0' 5 ~.5' 4.95' 4.:~7' 4.85' 1.68' 1.88' 1.50" 2.17' 1.42' GROUND LEVEL 13 5/8" 5,000 psi Stack RKB I DRIP PAN . KB TO BF RIG FLO( HYDRIL PIPE RAM 12.19' ! · , BLIND RAM MUD CROSS PIPE RAM ! ! MUD CROSS TBG SPOOL I ~ASE FLG ;~~E]// 16.37' 18.25' 22.20' ,1 24.68' 26.85' 28.25' O ,.~4'(A K E.FI/D E O A $3,ER TAt,Il' ,la, jo Ct..E.x. NE~ TJU~ )T~I~ TANI~ TANKq 881..,3 il ATOR BO~ ST^C~ - 135/8 5000-,,. · · ~ 2ES IVU3 ~YSTE~ FLOW~ i" NABORS 2ES 4.95' 4.:~7' 4.85' 1.68' 1.88' 1.50" 2.17' t .42' GROUND LEVEL 13 5/8" 5,000 psi Stack r ," RKB1 DRIP PAN KB TO BF RIG Fl O( HYDRIL 12.19' PIPE RAM BLIND RAM 16.37' 18.25' MUD CROSS PIPE RAM 22.20' MUD CROSS TBG SPOOL ASE FLG ~ 24 68' 26.85' 28 25' Slale: Alaska Borough: Well: DSS-14A Field: Prudhoe Bay St. Perm ~ 93-82 Dale 0t3/93 Engr: M. Minder 5-14~<LS Casing Interval Interval S~ze Bottom Top Length lA 7.625 6275 3291 3650 2A 7 8814 6950 3241 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 29.7 L-80 STL 0 29 L-80 NSCC 93989 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ff psi/ft 10.2 0.530 0.430 10.2 0.530 0.430 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -O.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 3330 6890 2.1 3330 8160 2.5 0 0 #DIVIO.I 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIV/0! Tension Strength K/Lbs 1C 202.394 2C 93.989 3C 0 4C 0 5C '0 6C 0 7C 0 8C 0 9(3 0 10C 0 K/Lbs TDF 683 3.87 527 5.61 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 2701 3794 0 0 0 0 0 0 0 0 Resist. CDF 4790 1.774 7020 1.851 0 #DIV/O! 0 #DIV/O! 0 #DiV/O! 0 #DIV/0! 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O! 0 #DIVi0! Pao, e 1 P~ge 1 5-14ACMT.×LS State: Well: Field: State Permit DS5-14A Prudhoe Bay 93.-82 Work Sheet: Date: £emenl Volume Calculalion.~ ~/3,/$$ Casing Type C.:asire Size-Inches Cesing Length- Feet Hole Diamete~-Inches Cement- Sacksti1 Cement- Yield111 Cement- Cubic ft 111 Cement- Cubic ft 111 Cement- Sack~112 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic fl. 112 Cement-Sacks 113 Cement-Yield 113 Cement- Cubic t~t 113 Cement- Cubic ft 113 Cement- Cubic fl. ! Vol Cement- Fill Factor Conducto~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ItDIV/0! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 11DIV/0! Line[ 7.000 3,241.000 8.500 0.000 0.000 0.000 724.000 0.000 0.000 0.000 0.000 724.000 1.762 Ca~g Type Casing Size -Inches Casing Depth - Feet Hole Diameter-Inches Cement-Sacks 111 Cement-Yield 111 Cement- Cubic tt 111 Cement- Cubic ft 111 Cement- Sacks1:I2 Cement-Yield ti2 Cement- Cubic ft 112 Cement- Cubic ft 112 Cement- Sacks113 Cement-Yield 113 Cement- Cubic tt 113 Cement- Cubic It 113 Cement- Cubic ft / Vol Cement-Interval ft Top of Cement- Feet Intemediate I~l 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0!. ~DIV/0! Intermediate $I2 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/0! It. DIV/0! Production 7.625 6,950.000 9.625 0.00 0.00 0.00 376.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 37~.00 1,998.25 4,951.8 Measured Depth STATE OF ALASKA · ALAS, DILAND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend ... Operation Shutdown~ Re-enter suspended well__ Alter casing ~ Repair w~ii.__ Plugging X . Time extension ~ Stimulate ~ Change approved program Pull tubing ~ Variance ~ Perforate ~ Other X ~ Plugback for redrlll 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3132'NSL, 87'EWL, SEC. 32, T11N, R15E, UM At top of productive interval 5. Type of Well: Development X Exploratory ~ Stratigraphic ~ Se~ce 6. Datum elevation (DF or KB) RKB 69' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 5-14 9. Permit number 77-33 10. APl number 50- 029-20253 1370' NSL, 1221' EWL, SEC. 29, T11N, R15E, UM At effective depth At total depth 1622'NSL, 1291'EWL, SEC. 29, T11N, R15E, UM 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10145 feet Plugs (measured) 8907 feet 10096 feet Junk (measured) 8882 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 112' 20"' 224 sx AS 112" 112' Surface 2654' 13-3/8" 5822 sx PF fl 2723' 2723' Intermediate P rod uction 10061' 9-5/8" 823 sx C/ass "G" 10130' 8893' Liner R L~"CE/VED Perforation depth: measured 9958'-9976; 9976'-9982; 9982'-9986;10008'-10034' true vertical 8689'-8704', 8704'-8709', 8709'-8712', 8784'-8806' '~[aSlf~ Oil & 6as Cons..Corn~is$~ Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 10016'MD; 12.6#, L-80, PCT taii @ 10024'MD grtcl~ora£,l . . Packers and SSSV (type and measured depth) BOT RHR packer @ 9134' MDI; BOT Wolverine packer @ 10008' MD; 5-1/2" Camco Bal-O SSSV @ 2191'MD 13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation i 16. If proposal was verbally approved Oil x Gas ~ Name of approver Date approved Service 17. I hereby certify tt'jat the foregoing is true and correct to the best of my knowledge. Signed lff[~,[.~df~, TrlleDrill/ngEngineerSupervisor FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity v-"' BOP Test ~ Location clearance~ Mechanical Integrity Test~ Subsequent form required 10- ~o'7 Original Signed By Approved by order of the Commission David W. Johnston Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRII~LfCATE ITEM APPROVE (1) .Fee ¢ 2) ,Loc [2 thru [9 thru 13] [10 & 13] (4) Casg -~-~ .... ~ --~. ~-~- ~,,:~,~_= [14 thru 22] ** CHECK LIST FOR NEW WELL PERMITS ::* Company DATE YES ~Y~c~?~ 1. Is permit fee attached ............................................... /~ 8~ 2. Is well to be located in a defined pool .............................. .~ 3. Is well located proper distance from property line ................... . .... 4 Is well located'proper distance from other wells ..................... 5 Is sufficient undedicated acreage available in this pool ............. 6 Is well to be deviated & is wellbore plat included ................... ... 7 Is operator the only affected party .................................. 8 Can permit be approved before 15-day wait ............................ . . 9. Does operator have a bond in force ................................... /~ 10. Is a conservation order needed ....................................... Z~_ 11. Is administrative approval needed .................................... , 12. Is lease nc~nber appropriate .......................................... ~ 13. Does well have a unique name & ntmber ................................ 14. Is conductor string provided ......................................... 15. Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water .................. ,, Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension, and burst. ~ Is well to be kicked off from an existing wellbore ................... ~-~ 16. 17. 18. !9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is old wellbore abandonment procedure included on 10-403 ............. ~- Is adequate wel 1 bore separat ion proposed ............................. ~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of ~'BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to~psig ..... /~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (5) BOPE ~, ~, .-*~7 ~-~- ~3r [23 thru 28] Lease & Well ~ /:~ .~.72_(~: /~ NO REMARKS (6) Other ~_:~_~ ~ [29 thr6 31] (7) Contact .~32] (8) Addl -~,,~,-,~? geology' engineer inq' DWJ M~ RAD~__~''~ RP ~'~ BEW dDH ,,~,,~ .:-,.?: rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' . MERIDIA~'~-~ SM TYPE' Exp D~.~ Redrill2< Inj Rev 0 -rZ 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. , ....... 6C~Lb~BE~(;i~:~ ..... ****************************** RECEIVED JUL 2 5 1994 Alaska Oil & Gas Cons. CommJssJo. n Anchorage MICROFILMED IS 'ra.~e Ver,if. icatJon !,isti~q chlumberger A!~SK~ Com!.:>~ltJr~~ Center 9-JU~,,i-I99:< .5:!2 1 ,'i; T S 2 R I ~.:L? 933o7 3 ~'; C K BiT RON '2 3 ?. 1!?,; .i 5E 3132 ~193 65.70 6~.. 3o PAGEI IS Tape V'erif~cat:i¢,,n t~istine chi!]I'~ ber,q el' A l. as~:~..~ CoF. Ptlt i ;':~ C'ent:~?r * * * * F I b E' f ! 6 a. [) Fl *, *, S~RV ICh.; : FL~!C V ERS l C,?.,~ :OO!COf FI.b7 De~t.h sn~fted er',{! clip~ed carves~ all bit runs SIhR'1" DEPT[~ STOP 0 0 .......... F~ t~ U I ',' A b E, :'] ~i b.q~b~ I PTF'~. F:PTH .......... ,SE I$ Taoe v eri, f,i. catie~ t'~isttnq chlu~'Dberger AlasKa Co~,~t. tt',Inc~ Center 9 * d u ~4 - 199 ,,'.?,. ~. 5: 12 D~T~ CO~,~SIST~ OF ~, SIMG.bE; bit RU.;.4 ~*.~'I')~ ~N EXTENDED PAGE: I 66 0 2 66 0 3 73 4(! ~ 66 1 6 73 7 65 ~ 68 0.5 9 65 FT 12 6~ 1,5 60 68 0 6 6 () '**~..Sr..t .... TYP~..i - CHA!i ** ' ;" ............................ ;;.";;;"';'"i,'_,[ .... : ...................... ~ ;-~5 SFRV UNI* SERVICK &PI ~ . A I ~ . ? XB NUMB SIZE REPR .... ID flH:DER ~ DDG TYPE CbASS XOD NUM~ S ~F EDEM CODE (HEX) ........................................... ;'"T ................................... ~'" DKPT ~.,r., 6.1 ~.056 O0 OUO O~ I I 4 68 n. O0000r~ O0 t~ 0 0 C; 0 00 O I ;* 1 4 68 o 000 O 0 F: ::~ 00 IS ?aoe Verif!ca'tion t, isting chlumberger AlasKa COmF~t.~.i. nq Cent. er -999.250 ~i,.. 0 F'. ,~t w i; -999.250 -999.250 -999.250 -999.250 -999,250 PEF.~D P~F~WD G~.~D '999.250 '999..250 '999.'250 147.000 j, oq t'~eader ,-'!ara i n. 5t, oO 857~.0 for each bit run In separate 192dq.0 V q . C files. IS Tar;e Yerificatior', Llstinq chlumber,ger Alaska Cor,'~[,'dtinC~ Center- 9-JUN-199~ i5:t2 PAGE{ TOP C HOD~ COPREC'T.k['),:~ [Ti",i); b.T, 5 F C'*P'v'A'? _F..':r,,P ,~:'kE(.;:!!E~}C'.¢ (hZ): 10~o9 FT 9520 - 10096 DE¢'.~SI'i:¥ 2.65,* ~[,,ufg, OR!~$ITi 1. a579.0 .500 7! 145.3 O 2.6 .1..38' 75.0 75.0 V4.0C iS Ts~:e verification Listino (7enter ~5:12 ........................" ' ' .... ............. ' .............. "" !LRV!'(;~.: apl AP1 AP1 A I . ?'L; b N'O~ SIZE REPR PROCESS RDEP ~ LOG TYPE CLASS ~ftD NU~B S~X~P ELEM CODE CHEX) .......................1 9056 O0 (,nO O0 ; ....... 2 '; ..... ; ...................... 4 68 000000''';;''00 i ~ 056 o (,) 0 (:, 0 0 () 0 2 l I 4 68 000 0000000 i9~56 O0 or)o go o 2 I 1 4 68 0000000000 toOS6 O0 OOO O0 0 ? I 1 4 68 0000000000 19056 O0 oOU O0 0 2 I i 4 68 O000000OO0 i905~ O0 000 O0 0 2 1. 1 4 68 0000000000 i00~6 n(~ (,00 O0 0 2 1 I 4 68 0000000000 19056 Ol:! 000 O0 0 2 i 1 4 68 0000000000 l~US~ Oo UO0 O0 0 ~ 1 ~ 4 ~8 0000000000 iq056 O0 000 O0 0 2 1 1 4 b8 OOOO000000 io956 O0 OOO O0 0 ~ i 1 4 68 0000000000 -999.250 -999,250 IS ?'a~e verificat!,on I istinq cblumber:Jer AlasKa Comput~aq CeDter t. 5:12 PAGE: 7