The URL can be used to link to this page

Home My WebLink About195-1107. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU H-01A Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 195-110 50-029-20099-01-00 11372 Conductor Surface Intermediate Tieback Liner Liner 8805 80 2339 6070 10112 1370 11327 30" 18-5/8" 13-3/8" x 9-5/8" 7" 4-1/2" 8800 33 - 113 32 - 2371 30 - 6100 28 - 10140 10000 - 11370 33 - 113 32 - 2371 30 - 5340 28 - 8740 8716 - 8805 None 870 1950 5410 7500 None 930 3450 7240 8430 10150 - 11320 4-1/2" 12.6# 13Cr80 26 - 9460 8741 - 8800 Structural 4-1/2" Baker S-3 Perm Packer 9305, 8414 9305 8414 Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028284 26 - 8525 N/A N/A 943 989 59572 28548 948 1338 0 1800 1565 1585 322-583 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 10:13 am, Apr 28, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.28 06:39:42 -08'00' Torin Roschinger (4662) WCB 1-2-2024 RBDMS JSB 050223 DSR-4/28/23 ACTIVITY DATE SUMMARY 10/28/2022 T/I/O= 2415/0/295 temp=S/I (TFS Ubit 4 Assist SL with Brush and Flush) Pumped 89 bbls of Crude down TBG while SL Brushed. ***Job Continued on 10/29/2022*** 10/28/2022 ***WELL FLOWING ON ARRIVAL*** (perforating) RAN 4-1/2" WHIDDON CATCHER TO RESTRICTION AT 2,250' SLM DRIFT W/ 4-1/2" BRUSH & 3.60" G. RING TO 2,300' SLM (large chunks of scale on brush) ATTEMPT TO DRIFT THROUGH RESTRICTION AT 2,250' SLM W/ 4-1/2" BRUSH & 3.79" G. RING WHILE T-BIRD PUMPED CRUDE RAN 4-1/2" BRUSH & 3.60" G. RING TO 3,857' SLM (unable to work further) RAN 4-1/2" BRUSH & 3.25" G. RING OUT TBG TAIL AT 9,476' MD ***CONT ON 10/29/22 WSR*** 10/29/2022 ***CONT FROM 10/28/22 WSR*** (perforating) RAN 4-1/2" BRUSH & 3.60" G. RING TO 5,640' SLM (unable to get deeper) RAN 4-1/2" BRUSH & 3.55" G. RING TO 6,755' SLM (unable to get deeper) BROACH SCALE f/ 5738' - 7050' SLM, DRIFT TO 9480' SLM w/ 3.55" BROACH BROACH SCALE f/ 5,696' - 6,561' SLM w/ 3.59" BROACH ***CONT ON 10/30/22 WSR*** 10/29/2022 ***Job continued from 10/18/2022*** TFS unit 4 Assist SL (Brush & Flush) Pumped 252 bbls of Crude down TBG while SL Brushed/Broached to make TD. Pumped 5 bbls of 60/40 down FL for Freeze Protect. ***Job continued on 10/30/2022*** 10/30/2022 ***Job Continued from 10/29/2022*** TFS unit 4 Assist SL (B&F) Pumped 322 bbls crude to Assist SL in Brushing Scale. SL in control of well @ departure. FWHP= 0/0/380 10/30/2022 ***CONT FROM 10/29/22 WSR*** (perforating) BROACH TBG FROM ~5,300' SLM OUT TBG TAIL AT 9,476' MD W/ 3.59" BROACH BROACH SCALE f/ ~ 5100' - 7100' SLM DRIFT OUT TBG TAIL @ 9476' MD w/ 3.62" BROACH BROACH SCALE FROM ~5,100' SLM TO 5,173' SLM W/ 3.68" BROACH ***CONT ON 10/31/22 WSR*** 10/31/2022 ***CONT FROM 10/30/22 WSR*** (perforating) POLLARD UNIT 60 RIG DOWN ***WELL S/I ON DEPARTURE*** 2/18/2023 LRS Well Test Unit #1. Standby for Coil 2/17/23 WSR. 2/19/2023 LRS Well Test Unit #1. Continued from 2/18/23 WSR. SB. Continue to 2/20/23 WSR. 2/20/2023 LRS Well Test Unit #1. Continued from 2/19/23 WSR. SB. Continue to 2/21/23 WSR. 2/21/2023 LRS Well Test Unit #1. Continued from 2/20/23. SB. Continue to 2/22/23 2/22/2023 LRS Well Test Unit #1. Contunued from 2/21/23 WSR. SB. Continue to 2/23/23 WSR. 2/23/2023 LRS Well Test Unit #1. Continued from 2/22/23 WSR. SB. Continue to 2/24/23 WSR. 2/25/2023 LRS Well Test Unit #1. Continued form 2/24/23 WSR. SB. End WSR on H-01 on 2/25/23 4/15/2023 LRS Test Unit #1. Mill Job/ CTU Assist. Begin WSR 4/15/23, IL H-01, OL H-16. Perform Unit Move, RU, Begin PT. Continued on 4/16/23 WSR. Daily Report of Well Operations PBU H-01A Daily Report of Well Operations PBU H-01A 4/16/2023 LRS Test Unit #1. Mill Job/ CTU Assist. Continued from WSR 4/15/23, IL H-01, OL H- 16. Complete PT, Begin SB for SLB CTU. Continued on 4/17/23 WSR. *** Job in Progress *** 4/17/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf MIRU. ***Job In Progress*** 4/17/2023 LRS Test Unit #1. Mill Job/ CTU Assist. Continue from WSR 4/16/23, IL H-01, OL H- 16. Continue SB for SLB CTU, Continued on 4/18/23 WSR. *** Job in Progress *** 4/18/2023 LRS Well Test Unit #1. Mill Job/ CTU Assist. Continued from WSR 4/17/23. IL H-01, OL H-16. Continued SB for SLB CTU, End SB, POP Well thru Test Unit to Production, CTU RIH, Continue Mill Job/ CTU Assist. Continued on WSR 4/19/23. *** Job in Progress *** 4/18/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf Perform weekly BOP test. Freeze protect H-01A flowline and POP the well through LRS testers down H-16 flowline. RIH w/ BOT 2-7/8" milling BHA w/ 3.69" Scale Mill. Mill bits of scale at 3300', 5360', 5788' - 6000'. RIH. ***Job In Progress*** 4/18/2023 LRS Test Unit #1. Mill Job/ CTU Assist. Continued from WSR 4/17/23, IL H-01, OL H- 16. Continue SB for SLB CTU, *** Job in Progress *** 4/19/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf RIH w/ BOT 2-7/8" milling BHA w/ 3.69" Scale Mill. Dry tag at 10144'. Clean out scale, flowing through testers, to 10897'. Lost returns; POH (minimum target depth 10530', 30' below bottom shot of planned adperfs). Pump 10 bbl 60/40 freeze protect cap. MU 2.40" HES GR/CCL logging carrier & 3.25" JSN. ***Job In Progress*** 4/19/2023 LRS Well Test Unit #1. Mill Job/ CTU Assist. IL H-01, OL H-16. Continued from WSR 4/18/23. Continue Assisting CTU. Divert Well through Test Separator, S/I to Divert into LP Header, POP Well into LP Header, CTU reached Target depth/ Milling Complete, Begin RDMO, Pause RDMO, APE Requested Continue Assisting CTU w/FCO Post Perf. Continued on WSR 4/20/23. *** Job in Progress *** 4/19/2023 ***FREEZE PROTECT OUTLET WELL H-16*** Pumped 3 bbls 60/40, 15 bbls crude, 5 bbks 60/40, 52 bbls crude, and 1 bbl 60/40 for freeze protect. 4/19/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf RIH w/ BOT 2-7/8" milling BHA w/ 3.69" Scale Mill. Dry tag at 10144'. Clean out scale, flowing through testers, to 10897'. Lost returns; POH (minimum target depth 10530', 30' below bottom shot of planned adperfs). Pump 10 bbl 60/40 freeze protect cap. MU & RIH w/HES 2-3/8" Logging Carrier & 3.25" JSN. Tag high at 10905'. Log from Compression up to 9050'. Flagged Pipe at 10100'. Pooh. Kill well with 255 bbls Slick Seawater w/ Safelube. Continue pumping while pulling to surface. At surface perform passing no flow test. Unable to keep fluid at surface at 5 bpm, swap to continuous hole fill method. Received good data (8' Correction. Correlated to Slb MCNL 15-Oct-2010. Failed flow check prior to MU guns; well swapped out. Re-kill well. ***Job In Progress*** 4/20/2023 LRS Well Test Unit #1. Mill Job/ CTU Assist. IL H-01, OL H-16. Continued from WSR 4/19/23. Begin SB for SLB CTU, Begin RU, RDMO. End WSR 4/20/23. *** Job Complete *** Daily Report of Well Operations PBU H-01A 4/20/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf Kill well for a 3rd time. Roll immediately into continuous hole fill at 1.5 bpm. Insufficient fluids on location to start open hole deployment of perf guns due to delays at SIP. Fluids re-loaded. Kill wellbore with 280 bbls Slick KCL at 5 bpm. Able to keep fluid at surface pumping across the top with KCL. Averaged ~ 0.8 bpm losses. Deploy 2-7/8" Perf Guns. Make up Coil Swivel to Firing Head & Stab on the well. RIH w/ 2-7/8" x 350' of HES MaxForce Perf Guns. Perforate 10150 - 10500'. POH. Flow check. LD Perf Guns #1-12 (of 16). ***Job In Progress*** 4/21/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Mill Scale & Extended Add Perf LD Perf Guns #13 - 16. All shots fired. Freeze protect tubing with 40 bbl 60/40. RDMO. ***Job Complete*** 4/26/2023 LRS Well Testing, Rig down Flowcross. Begin WSR on 4/26/23. Travel w/ Crane to LOC, Rig down flowcross, Move Equipment back to Yard. End WSR g g Deploy 2-7/8" Perf Guns. Make up Coil Swivel to Firing Head & Stab on the well. yg RIH w/ 2-7/8" x 350' of HES MaxForce Perf Guns. Perforate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y Anne Prysunka at 1:13 pm, Oct 04, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV 6)''650*52&7 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.10.07 16:13:05 -08'00' RBDMS JSB 101122 tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ tĞůůEĂŵĞ͗,ͲϬϭW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϬϵϵͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KƉĞƌĂďůĞ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗KĐƚϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϯĚĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ ϱϲϰͲϰϵϭϱ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀŝĚtĂŐĞƐ ϳϭϯ͘ϯϴϬ͘ϵϴϯϲ;ĐͿ 'ĞŽĨŽƌdŝĞͲŝŶ ƐŚůǇŶDƵƌƉŚǇ ϴϯϮͲϰϭϳͲϭϲϰϬ;ĐͿ ƐƚŝŵĂƚĞĚ ŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯϮϱϬ ƉƐŝ Λ ϴϴϬϬ͛ ds DW^W͗ Ϯϱϳϲ ƉƐŝ ;Ϭ͘ϭƉƐŝͬĨƚŐĂƐƚŽƐƵƌĨĂĐĞͿ DŝŶ/͗ϯ͘ϳϮϱ͟ yEEŝƉƉůĞΛϵϰϳϲ͛ D хϳϬĞŐĞǀΛ͗ ϵϴϯϱ͛ D d'sŽů͗ ϭϰϰ ďďůƐ t ƚŽ dŽƉdĂƌŐĞƚ͗ ϭϲϲ ďďůƐ sŽůƵŵĞƚŽƚŵdĂƌŐĞƚ͗ ϭϴϰďďůƐ >ĂƐƚƚŝŵĞďĞůŽǁƚĂƌŐĞƚ͗ ŽŝůWWZK&ϭϬͬϭϱͬϮϬϭϬ ,d͗ ϭϵϲĚĞŐ& ǆƉĞĐƚĞĚt,W͗ ϲϬϬƉƐŝ ƌŝĞĨtĞůů ,ŝƐƚŽƌǇ ƚƚĞŵƉƚĞĚƚŽƌƵŶĂƌĞƐĞƌǀŽŝƌƐĂƚƵƌĂƚŝŽŶůŽŐŝŶ:ƵůǇϮϬϮϮƚŽŐĞƚƵƉĚĂƚĞĚƌĞƐĞƌǀŽŝƌƉƌŽĨŝůĞƐĂƐƉĂƌƚŽĨƚŚĞ,ƉĂĚ ĨŝĞůĚƐƚƵĚǇ͘,ŽǁĞǀĞƌ͕ƚŚĞ>ƚƌĂĐƚŽƌĐŽŶǀĞǇĞĚƚŽŽůƐƚƌŝŶŐƐĂƚĚŽǁŶŝŶƚŚĞƵƉƉĞƌƉĞƌĨƐĂƚϭϬϭϵϬĨƚĂŶĚƚŽŽŬϱϯϬϬ ůďƐƚŽƉƵůůĨƌĞĞ͘dŚĞŽďƐƚƌƵĐƚŝŽŶ ŝƐƐƵƐƉĞĐƚĞĚƚŽďĞƐĐĂůĞďƵŝůĚƵƉ͘EŽƐĂŵƉůĞǁĂƐƌĞĐŽǀĞƌĞĚƚŽĐŽŶĨŝƌŵďƵƚ,Ͳ ϬϭŚĂĚĂŚŝƐƚŽƌǇŽĨƐĐĂůĞŝŶƚŚĞƉĂƐƚ͘dĐŽŶǀĞǇĞĚWWZK&ĨƌŽŵϮϬϭϬƐŚŽǁĞĚĞůĞǀĂƚĞĚ'ZĂŶĚƌĞƐƚƌŝĐƚŝŽŶƐŽŶ ƚŚĞyzĐĂůŝƉĞƌĂĐƌŽƐƐƚŚĞƉĞƌĨƐ͘ KďũĞĐƚŝǀĞ dŚĞŽďũĞĐƚŝǀĞŽĨƚŚŝƐƉƌŽŐƌĂŵŝƐĐůĞĂŶŽƵƚůŝŶĞƌƵƐŝŶŐĂŵŝůůΘ ŵŽƚŽƌƚŽWd;ϭϭϯϮϳ͛ͿƚŽďĞĂďůĞƚŽƌĞͲƉĞƌĨ ǁŝƚŚ ĚĞĞƉƉĞŶĞƚƌĂƚŝŶŐĐŚĂƌŐĞƐƚŚĞ /ǀŝƐŚĂŬϰƉĞƌĨƐ͕ϭϬϭϱϬ͛ͲϭϬϱϬϬ͛;ϯϱϬ͛ŐƌŽƐƐͬŶĞƚͿ ZĞĐĞŶƚ tĞůů ǀĞŶƚƐ ϳͬϮϮͬϮϮ >;ƚƌĂĐƚŽƌZWDͿƐƚĂƌƚƚƌĂĐƚŽƌĨƌŽŵϵϲϭϬ͛;ĚĞǀͿ͕ƐĂƚĚŽǁŶĂƚ ϭϬϭϵϬ͕͛ƉƵůůĞĚ ĨƌĞĞĂƚ ϱϯϬϬůďƐ ϲͬϮϰͬϮϮ ^>;ƉƌĞ>ZWDͿǁŽƌŬĞĚ ĂƌĞĂƐǁŝƚŚ'ͲƌŝŶŐĂŶĚďƌƵƐŚϯϮϴϬ͛ͲϰϲϴϬ͕͛ϰϲϵϳ͛ͲϰϳϬϮ͕͛ƌĞƉŽƌƚĞĚ ƉĂƌĂĨĨŝŶΘƐŵĂůůĂŵŽƵŶƚŽĨƐĐĂůĞŽŶďƌƵƐŚ ϭϭͬϭϳͬϭϴ tĞůů>ŽĐŬƐƋƵĞĞǌĞKǆKK Ϯͬϭͬϭϴ >WͲKŝŶĚŝĐĂƚĞƐƐĞĐŽŶĚĂƌǇƐĞĂůƐĂƌĞ ŚŽůĚŝŶŐ͕ƉƌŝŵĂƌŝĞƐ ƐĞĂůƐ ĂƌĞŶŽƚ ϱͬϭϰͬϭϲ D/dͲd͗ϯϬϬϬƉƐŝŽŶϱͬϭϰͬϮϬϬϲ WƌŽĐĞĚƵƌĞ͗ ^ůŝĐŬůŝŶĞ ϭ͘ /ŶƐƚĂůůŶĞǁ'>ƚŽůŝĨƚǁĞůůǁŝƚŚ'>ĚƵƌŝŶŐƐƵďƐĞƋƵĞŶƚdĐůĞ ĂŶŽƵƚĂƐƉĞƌĂƚƚĂĐŚĞĚĚĞƐŝŐŶ 9$/9(67238//),1$/'(6,*1 '$7(38//(''$7(6(7 */0 0' 79' 9$/9( 7<3(9$/9(1$0( 3257 6,=(752 /$7&+ */0 0' 79' 9$/9( 7<3(9$/9(1$0( 3257 6,=(752 /$7&+ 'RPH %. %. 'RPH %. %. 62 6%.2$ a %. 'RPH %. %. 'XPP\ ('XPP\ a a %. 'RPH %. %. 'XPP\ ('XPP\ a a %. 62 *HQ0RG a %. 'XPP\ ('XPP\ a a %. ƉϮϱϳϲ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ tĞůůdĞƐƚŝŶŐ ϭ͘ D/ZhWŽƌƚĂďůĞdĞƐƚhŶŝƚĂŶĚĂƵǆŝůŝĂƌǇ ĞƋƵŝƉŵĞŶƚ Ă͘ ZhƐŽƚŚĂƚĂĨƚĞƌƚŚĞdĐůĞĂŶŽƵƚ͕ƚŚĞƚĞƐƚƵŶŝƚĐĂŶZDK ĂŶĚůĞĂǀĞůŽĐĂƚŝŽŶǁŚŝůĞdĐŽŵƉůĞƚĞƐ ƌĞŵĂŝŶŝŶŐũŽďƐƚĞƉƐ ď͘ tŽƌŬǁŝƚŚKƉĞƌĂƚŝŽŶƐͬWĂĚKƉƚŽĐŚŽŽƐĞŽƵƚůĞƚǁĞůůƚŽƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵdƐĐĂůĞŵŝůůŝŶŐ͕ƐƵŐŐĞƐƚ ƌŝŐŐŝŶŐ Wd^ƚŽƚŚĞƌŝŐŚƚŽĨ,ͲϬϭ ĂŶĚƵƐĞ,ͲϮϴĂƐŽƵƚůĞƚǁĞůů͘,ͲϮϴŚĂƐĂĐĐĞƐƐƚŽ>WΘ,W Đ͘ ŽŶĨŝƌŵŽƵƚůĞƚǁĞůůŝƐůŝŶĞĚƵƉƚŽ>WĨŽƌĐůĞĂŶŽƵƚ Ě͘ ŽŶĨŝƌŵǁĞůůŝƐĨůŽǁŝŶŐƚŚƌŽƵŐŚWd^ũƵƐƚƉƌŝŽƌƚŽdD/Zh͘ ŽŝůdƵďŝŶŐ EŽƚĞƐ͗ x ƵĞƚŽƚŚĞŶĞĐĞƐƐĂƌǇŽƉĞŶŚŽůĞĚĞƉůŽǇŵĞŶƚŽĨǆƚĞŶĚĞĚ WĞƌĨŽƌĂƚŝŶŐũŽďƐ͕ϮϰͲŚŽƵƌĐƌĞǁĂŶĚt^^ ĐŽǀĞƌĂŐĞŝƐƌĞƋƵŝƌĞĚ͘ x dŚĞǁĞůůǁŝůůďĞŬŝůůĞĚĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞŵĂŬŝŶŐƵƉƚŚĞŝŶŝƚ ŝĂůƉĞƌĨƐŐƵŶƐ͘dŚŝƐŝƐŐĞŶĞƌĂůůǇĚŽŶĞ ĚƵƌŝŶŐƚŚĞĚƌŝĨƚͬůŽŐŐŝŶŐƌƵŶ͘ dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůůďĞŬŝůůĞĚďǇ ďƵůůŚĞĂĚŝŶŐŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚŚĞũŽď͘ /ĨƉƌĞ ƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůǇĂĨƚĞƌ x ƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞŬŝůůĞĚďǇďƵůůŚĞĂĚŝŶŐ ǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚƚŚĞ ƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞĨŝƌŝŶŐŚĞĂĚ͘ Ϯ͘ D/Zh ϭ͘ϳϱ͟ŽƌϮ͘Ϭ͟dhĂŶĚƐƵƉƉŽƌƚĞƋƵŝƉŵĞŶƚ͘ ϯ͘08´PRWRUZLWK´VFDOHPLOOQRVLGHFXWWLQJVWUXFWXUHPLOOWKURXJKDQ\UHVWULFWLRQVLQWKHWXELQJ DQG OLQHUWR Wd;ϭϭϯϮϳ͛Ϳ ϰ͘ ĨƚĞƌDhD,ĂŶĚƉƵůůƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚƚŚĞ ďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚŐƵŶƐ͘ ϱ͘ ŶƐƵƌĞ,ͲϬϭŝƐĨůŽǁŝŶŐƚŚƌƵWd^ƚŽ>WŚĞĂĚĞƌ ϲ͘ Z/,ĚƌǇƵŶƚŝůĨŝůůͬŽďƐƚƌƵĐƚŝŽŶŝƐĞŶĐŽƵŶƚĞƌĞĚ͘WhƚŽĞƐƚĂďůŝƐŚ ƉĂƌĂŵĞƚĞƌƐĂŶĚďĞŐŝŶŵŝůůŝŶŐǁŚŝůĞƉƵŵƉŝŶŐ ŐĞůƐǁĞĞƉƐĂƐŶĞĐĞƐƐĂƌǇ͘ůĞĂŶŽƵƚƚŽWd͕ ϭϭϯϮϳ͛ŶŽƚĞĂƌĞĂƐŽĨŵŽƚŽƌǁŽƌŬ͘ Ă͘ WƵŵƉĨŝŶĂůϮϬƚŽϯϬďďůƐŐĞůƐǁĞĞƉĂŶĚĐŚĂƐĞKK,ĂƚϴϬйŽĨWKK,ƐƉĞĞĚ ď͘ ĨƚĞƌĨŝŶĂůŐĞůƐǁĞĞƉŝƐĂůůŽƵƚĂƚƐƵƌĨĂĐĞ͕ ^/ŐĂƐůŝĨƚĂŶĚů ĞƚǁĞůůďůĞĞĚŽĨĨƚŽ>WǁŚŝůĞWKK, Đ͘ tĞůůƚĞƐƚĞƌƐƚŽƉƵůůƌĞŐƵůĂƌƐĂŵƉůĞƐĨƌŽŵƌĞƚƵƌŶƐĚƵƌŝŶŐĐůĞĂŶŽƵƚƚŽ/ƐŽůŝĚƐͬĚĞďƌŝƐ Ě͘ ^ĞŶĚ ƐĂŵƉůĞŽĨƐŽůŝĚƐ ƚŽ 'W ůĂďĨŽƌ ŝĚĞŶƚŝĨŝĐĂƚŝŽŶ ĂŶĚĂĐŝĚƐŽůƵďŝ ůŝƚǇƚĞƐƚ ϳ͘ ƵůůŚĞĂĚ ΕϮϱϰ ďďůƐ ;ϭ͘ϱtsƚŽƚŽƉƉĞƌĨͿ͕ϴ͘ϰƉƉŐďƌŝŶĞ ĚŽǁŶƚƵďŝŶŐ͘DĂǆƚƵďŝŶŐƉƌĞƐƐƵƌĞϮϱϬϬƉƐŝ͘ ;dŚŝƐƐƚĞƉĐĂŶďĞƉĞƌĨŽƌŵĞĚĂŶǇƚŝŵĞƉƌŝŽƌƚŽŽƉĞŶͲŚŽůĞĚĞƉůŽǇŵĞŶƚŽĨƚŚĞƉĞƌĨŐƵŶƐ͘dŝŵŝŶŐŽĨƚŚĞǁĞůů ŬŝůůŝƐĂƚƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞt^^͘Ϳ Ă͘ tĞůůďŽƌĞǀŽůƵŵĞƚŽƚŽƉƉĞƌĨсϭϲϵ͘Ϭ ďďůƐ ď͘ ϰͲϭͬϮ͟ƚƵďŝŶŐƚŽ ϵϰϴϴ͛;dd>Ϳy͘ϬϭϱϮďƉĨсϭϰϰ͘ϰ ďďůƐ Đ͘ ϳ͟ůŝŶĞƌƚŽ ϳ͟ ƚŝĞďĂĐŬ dK> ;ϱϭϮ͛Ϳy͘Ϭϯϳϭ ďƉĨс ϭϵ͘Ϭ ďďůƐ Ě͘ ϳ͟ůŝŶĞƌƚŽƚŽƉƉĞƌĨ͕;ϭϱϬ͛ͿyϬϯϳϭ ďƉĨс ϱ͘ϲ ďďůƐ ϴ͘ DhĂŶĚZ/,ǁŝƚŚDD'Zͬ>ůŽŐŐŝŶŐƚŽŽůƐ ŝŶϮͲϳͬϴ͟ĐĂƌƌŝĞƌǁŝƚŚ Ϯ͘ϴϳϱ͟Ͳϯ͘ϱ͟:^E͘ dĂŐWd͘>ŽŐƵƉĂŶĚ ĨůĂŐĐŽŝůĨŽƌƐƵďƐĞƋƵĞŶƚƉĞƌĨŽƌĂƚŝŶŐ͘WKK,ĂŶĚĐŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͘ Ă͘ ŽŶƚĂĐƚK:ŽŚŶŽŶĚŝŽ ϲϬϮ͘ϯϳϯ͘Ϭϲϱϵ Žƌ'KƐŚůǇŶDƵƌƉŚǇϴϯϮ͘ϰϭϳ͘ϭϲϰϬĨŽƌĨŝŶĂůƚŝĞͲŝŶ ĂƉƉƌŽǀĂů ďĞĨŽƌĞƉĞƌĨŽƌĂƚŝŶŐ ϵ͘ WKK,ĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐĂƐŶĞĞĚĞĚ͘ ϭϬ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨdWŐƵŶƐ͘ ϭϭ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚ ŽĨĨ ĂŶǇƉƌĞƐƐƵƌĞƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϰƉƉŐϭй<ůŽƌϴ͘ϱƉƉŐ ĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵďƌ ŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲĞƐƚĂďůŝƐŚĞĚ͘ Ύ&ůƵŝĚƐ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ ŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐ ŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϮ͘ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐƵƉ ƐĂĨĞƚǇũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽů ƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶƐƚƌŝŶŐ͘KŶĐĞ ƚŚĞƐĂĨĞƚǇũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚ ŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚǇũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůǇĂĐĐĞƐƐŝďůĞŶĞĂƌ ƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽǇŵĞŶƚŝĨŶĞĐĞƐƐĂƌǇ͘ Ğ͘ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚǇũŽŝŶƚŵƵƐƚďĞƉŚǇƐŝĐĂůůǇDhƚŽƚŚĞƉĞƌĨŐƵŶƐ ŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘ ϭϯ͘ ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐ ƵŶƐƉĞƌƐĐŚĞĚƵůĞďĞůŽǁ͘ŽŶƐƚĂŶƚůǇŵŽŶŝƚŽƌ ĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚ ƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞ ĚĞƉůŽǇŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ ϭϰ͘WĞƌĨ^ĐŚĞĚƵůĞďĂƐĞĚŽŶϮͲϳͬϴ͟ ƉĞƌĨŐƵŶƐ͕ϲƐƉĨ͕ϲϬĚĞŐƉŚĂƐĞ͕ ĚĞĞƉƉĞŶĞƚƌĂƚŝŶŐĐŚĂƌŐĞƐ͕ ƉƵďůŝƐŚĞĚ ůŽĂĚĞĚŐƵŶǁĞŝŐŚƚ ŽĨϭϮ͘ϰϭ ƉƉĨ ǁĂƐƵƐĞĚ͘ WĞƌĨ/ŶƚĞƌǀĂů WĞƌĨ >ĞŶŐƚŚ ;ĨƚͿ KǀĞƌĂůů'ƵŶ >ĞŶŐƚŚ ;ĨƚͿ ;ǁͬ>E<^Ϳ tĞŝŐŚƚŽĨ 'ƵŶ;ůďƐͿ ϭϬ͕ϭϱϬͲϭϬ͕ϱϬϬ͛ŵĚ ϯϱϬ͛ϯϱϬ͛ϰϯϱϬ ůďƐ ϭϱ͘ DĂŬĞƵƉW͕ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐ͘WŝĐŬƵ ƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌWĞƌĨ^ĐŚĞĚƵůĞĂďŽǀĞ͘ EŽƚĞĂŶǇƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘ ϭϲ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽĞƐŶŽƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚƐƚŝĐŬ ƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚŬŝůů͕ŝĨŶĞĐĞƐƐĂƌǇ͕ďĞĨŽƌĞƉ ƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘ ϭϳ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶ ĨŝƌŵǁĞůůŝƐĚĞĂĚ͘<ŝůůǁĞůůŝĨŶĞĐĞƐƐĂƌǇ͘ ϭϴ͘ ZĞǀŝĞǁǁĞůů ĐŽŶƚƌŽůƐƚĞƉƐĂŶĚ ^ƚĂŶĚŝŶŐ KƌĚĞƌƐǁŝƚŚĐƌĞǁ ƉƌŝŽ ƌƚŽ ďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶ ĂŶĚ ĐŽŵŵĞŶĐŝŶŐďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘ ϭϵ͘ ZDK ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ ŽŝůdƵďŝŶŐKW ^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ ϱ͘ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ ϲ͘dŝĞ/Ŷ>ŽŐͬWĞƌĨ^ŚĞĞƚ ϳ͘^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ D tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ t^ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ WƌŽƉŽƐĞĚt tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ ŽŝůĞĚdƵďŝŶŐKWƐ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ ƋƵŝƉŵĞŶƚ>ĂǇŽƵƚŝĂŐƌĂŵ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽǇŵĞŶƚ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ dŝĞͲ/Ŷ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ tĞůů͗ ,ͲϬϭ Wd͗ ϭϵϱͲϭϭϬ +LOFRUS 1RUWK6ORSH//&+LOFRUS 1RUWK6ORSH//&Changes to Approved Work Over Sundry Procedure'DWH 2FWREHU 6XEMHFW &KDQJHVWR$SSURYHG 6XQGU\3URFHGXUHIRU :HOO +$6XQGU\ $Q\PRGLILFDWLRQVWR DQ DSSURYHGVXQGU\ ZLOOEHGRFXPHQWHGDQGDSSURYHGEHORZ &KDQJHVWRDQDSSURYHG VXQGU\ ZLOOEHFRPPXQLFDWHGWRWKH$2*&& E\WKH ZRUNRYHU:2³ILUVWFDOO´HQJLQHHU $2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: OA & OOA WeIlLock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dill Number. 185-110 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ $mice ❑ S. API Number: 50-029-20099-01-00 7, Property Designation (Lease Number): ADL 028284 = 8. Well Name and Number: PBU H -01A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 11372 feet Plugs measured None feet true vertical 8801 feet Junk measured None feet Effective Depth: measured 11327 feet Packer measured 9404 feet true vertical 8796 feet Packer true vertical 8484 feet Casing: Length: Size: MD: TVD: Burst. Collapse: Conductor 80 30" 33-113 33-113 Surface 2341 18-5/8" 32-2371 32-2371 930 870 Intermediate 6071 13-3/8" x 9-5/8" 30-6101 30-5336 3450 / 6870 1950/4760 Intermediate 10112 7" 28-10140 28-8735 8160 7020 Production Liner 1370 4-1/2" 10000 - 11370 8711-8801 8430 7500 Perforation Dept: Measured depth: 10150 -11320 feet True verticel depth: 8736-8796 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 26-9460 26-8520 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9404 8484 true vertical depth) NO SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Fill both OA and ODA w/ WeIlLock using Tygon tubing ran to tap of cement 59" in OA and 103" in OOA. Treatment descriptions including volumes used and final pressure: 38 gal of WeIlLock used to fill OA and displace contaminants additional 7 gallons used to achieve 2500 psi sqz pressure . Fill OOA w/ 44 gal WeIlLock. Squeeze to 1600 psi w/ 10.5 gallons. Attach 3/4" x 50' CNG hose precharged w/ AL gas to the OA and OOA to serve as an accumulator. OA @ 1980 PSI and ODA 1280 psi. Both annuli have 1502 pup joints containing an additional .4 gal of WeIlLock in each. OA and ODA samples completely set up. Final Pressures: ODA = 0 psi, OA = 0 psi, IA = 0 psi, TBG = SSV 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 809 31713 1844 1082 1330 Subsequent to operation'. no Test Available 0 1100 14.Attachments: (regened per 20 Me 25070350]1,&25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318447 Authorized Name: Obrigewitch, Beau Contact Name: Obrigewitch, Beau Authorized Tide: Well Integrity Engineer Contact Email: BEAU.OBRIGEWITCHApocom Authorized Signature: Date: 2 `a Contact Phone: +1 907 564 4854 Farm 10-404 Revised 04/2017 ,to �lz�� RBDMCVEC 17 2018 Submit Odginal Only T/1/0/00 = SSV/870/510/350. Temp = SI. Strap TOC in OA (pre Wellock). ALP = 0 psi, SI @ CV. Bled OAP from 510 psi to 0 psi in <10 mins and monitored for 1 hr. Valve crew notices visible flow, extended monitor for additional 2 hrs. Unable to get 0 psi flow. Rig down and will reaccess. 11/7/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:00 T/1/0/00 = SSV/870/470120. Temp = SI. Bleed IA/OA/OOA to 0 psi (pre vlave shop). ALP = 0 psi, SI @ CV. IA FL @ 5662 (sta #4, s/o). OA/OOA = cemented to surface. Bled IAP from 870 psi to 0+ psi in 1 hr to OT. Bled OA/OOA to 0 psi and held open for 8 hrs. SI bleed (valve shop will be out in am to install integrals on OA & ODA. Final WHPs = SSV/0/0/0. 11/10/2018 SV, WV, SSV = C. IA, OA, OOA = OTG. 16:15 T/1/0/00 = SSV/2/400/0+. Temp = SI. Step TOC in OA/OOA (pre Wellock). ALP = 0 psi, SI @ CV. Bled IA, OA, OOA to 0 psi and held open for valve shop to remove OA/OOA flange. Tagged TOC in OA @ 59". Tagged TOC in OOA @ 106". 11/11/2018 Valve crew in control of valve positions upon departure. 14:30 T/1/0/00 = SI/0/0/0. RD OA, RU Intergal flange with block valve and HI -Temp gasket, RD Companion OA, RU Intergal flange with block valve and HI -Temp gasket, RD ODA, RU Intergal flange with block valve and HI - Temp gasket, RD Companion ODA, Removed VR Plug, RU Intergal flange with block valve and HI -Temp 11/12/2018 gasket, NO PT. RDMO. "'Job Complete***. FWPs = SI/0/0/0 T/1/O/OO = SSV/0/460/0. Temp = SI. Steam clean OA/OOA. ALP = 0 psi, SI @ CV. Steam cleaned conductor for 4.5 hours. Used vac hose to suck out any remaining fluid in the OA/OOA. Installed 1502 with needle valves on OA/OOA. Heater left in WH. Bled tree cap. Job complete. Final Whps = SSV/0/0/00. 11/16/2018 SV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG. 16:00 Job Scope: WeIlLock Squeeze OA and ODA T/1/0/00 = SSV/0/400/0. Temp = SI. Wellock OA/OOA. ALP = 0 psi, SI @ CV. Fill both OA and ODA wl WeIlLock using Tygon tubing ran to top of cement 59" in OA and 103" in ODA. 38 gal used to fill OA and displace contaminants additonal 7 gallons used to achieve 2500 psi sqz pressure. Fill ODA w/ 44 gal WeIlLock. Sqz to 1600 psi w/ 10.5 gallons. Attach 3/4" x 50' CNG hose pre -charged w/ AL gas to the OA and ODA to serve as an accumulator. OA @ 1980 PSI and ODA 1280 psi. Both annuluses have 1502" pup joints containing an additional .4 gal of welllock in each. Monitor WHP's and temp and adjust as needed. 11/17/2018 "'Continued on 11/18/18"' "'Continued from 11/17/18' Job Scope: WeIlLock Squeeze OA and ODA. T/1/0/00 = SSV/0/2170/1420. Temp = SI. Wellock OA/OOA. ALP = 0 psi, SI @ CV. Continue to monitor WHP's and Temp. Adjust as required. Wellock samples were the consistency of hydraulic oil upon departure. Casing temp @ 68', thermometer left on OA casing spool. Grating replaced on west side of wellhouse. East side grating removed (flagged off). West side door left open, east door shut. Heater left in wellhouse. Tree cab bled previously. FWPs = SSV/0/1690/1120. 11/18/2018 SV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG. 1615 hrs. 7/110/00 = SSV/1511520/980. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (0+). Casing temp = 67'. The OA decreased 130 psi and the OOAP decreased 120 psi overnight. Both OA & ODA samples are the consistency of honey. 11/19/2018 SV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG. 1145 hrs. T/1/O/OO = SSV/161153011050. Temp = SI. WHPs. (Post Wellock). Heater in well house is working properly. Wellock samples are the consistency of Hyd fluid, ODA sample is thicker. Casing temp = 74'. IAP increased 1 psi, OAP decreased 120 psi, OOAP decreased 50 psi in -9 hours. Tree cap bled to 0 psi for heater in well house. 11/19/2018 JSV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG. 23:50 T/1/O/OO = SSV/15/1650/1100. Temp = SI. WHPs. (Post Wellock). Wellock samples were the consistency of hydraulic oil. Casing temp @ 66', thermometer left on OA casing spool. Heater working properly. Tree cap bled to 0 psi for heater in well house. 11/19/2018 SV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG 03:00 T/1/0/00 = SSW17/1460/950. Temp = SI. WHP's. (Post Wellock). Heater in well house is working properly. Wellock samples are the consistency of honey. Casing temp = 80'. IAP increased 1 psi, OAP decreased 70 psi, OOAP decreased 100 psi in -15 hours. Tree cap bled to 0 psi for heater in well house. 11/20/2018 JSV, WV, SSV = C. MV = 0. IA, OA, ODA = OTG. 15:30 Daily Report of Well Operations PBU H -01A T/1/0/00 = SSV/18/1450/890. Temp = SI. WHP's. (Post Wellock). Heater in well house is working properly. OOA Wellock sample is the consistency of thick honey, OA Wellock sample is still the consistency of Hyd fluid. Casing temp = 80". IAP increased 1 psi, OAP decreased 10 psi, OOAP decreased 60 psi in —11.5 hours. Tree cap bled to 0 psi for heater in well house. 11/21/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG 02:52 T/1/0/00 = SSW18/1370/810. Temp = SI. WHPs. (Post Wellock). Heater in well house is working properly. Wellock samples are the consistency of thick honey. "There is some standing fluid on top of the OA sample. The Wellock is the consistency of thick honey."" Casing temp = 88". IAP unchanged, OAP decreased 80 psi, OOAP decreased 80 psi in —9 hours. Tree cap bled to 0 psi for heater in well house. 11/21/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. 13:00 T/1/0/00 = SSV/20/1190/620. Temp = SI. WHPs (Post WeIlLock). Heater in well house working properly. OA WeIlLock sample is set up, OOA WeIlLock sample is set up. Casing temp = 66°. OAP decreased 50 psi, OOAP decreased 20 psi in 7 hrs. Tree cap bled to 0 psi for heater in well house. SV, WV, SSV = C. MV = 0. 11/22/2018 IA, OA = OTG. 10:30 T/1/0/00 = SSV/20/1240/640. Temp = SI. WHPs (Post WeIlLock). Heater in well house working properly. OA WeIlLock sample is set up, OOA WeIlLock sample mostly set up. Casing temp = 70°. OAP decreased 130 psi, OOAP decreased 170 psi in 14 hrs. Tree cap bled to 0 psi for heater in well house. SV, WV, SSV = C. 11/22/2018 MV = 0. IA, OA = OTG. 03:00 T/1/0/00 = SSV/20/1180/560. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (0+ psi, blinded). Heater in wellhouse working properly. OA & OOA wellock samples are set up. Casing temp = 58" (Adjusted heater trunk). OAP increased 50 psi and the OOAP increased 30 psi since 0045 hrs. 11/23/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. 1240. TWO = SSV/21/1200/490. Temp = SI. WHP's. (Post wellock). ALP = 0+ psi & Si & Blinded @ IA casing valve. IAP increased 1 psi, OAP increased 20 psi, OOAP decreased 70 psi since 12:40 today. Casing temp = 62". Heater in Well house is working properly, adjusted heater hose slightly to increase WH temp. OA & OOA wellock samples are set up hard. 11/23/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 22:15 T/1/0/00 = SSV/20/1130/560. Temp = SI. WHPs (Post WeIlLock). Heater in well house working properly. OA & OOA WeIlLock samples are set up. Casing temp = 54°, adjust heater trunk to increase rasing temp. OAP & OOAP decreased 60 psi in 14 hrs. Tree cap bled to 0 psi for heater in well house. 11/23/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. 00:45 T/1/0/00 = SSV/20/1180/560. Temp = SI. WHPs (Post Wellock). ALP = 0 psi. SI @ CV (blinded). Heater in wellhouse working properly. OA & OOA wellock samples are set up. Casing temp = 66°. OAP and OOAP unchanged since monitor at 00:45. 11/24/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. 13:45 T/1/0/00 = SSV/20/1120/520. Temp = SI. WHPs (Post Wellock). ALP = 0 psi. SI @ CV (blinded). Heater in wellhouse working properly. OA & OOA wellock samples are set up. Casing temp = 70°. OAP decreased 60 psi and OOAP 40 since yesterday @ 13:45. 11/25/2018 SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. 15:30 T/1/0/00 = SSV/30/720/560. Temp = SI. WHPs (Post WeIlLock). ALP = 0+ psi, SI @ casing valve (Blinded). Swap out heater (burner will not stay on) and close RH well house door. OA & OOA WeIlLock samples are set up. Casing temp = 7°. IAP increased 10 psi, OAP decreased 400 psi, OOAP increased 40 psi since 11/25/18. New heater working properly upon departure. 11/27/2018 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 23:15 T/1/0/00 = SSV/30/750/650. Temp = SI. WHPs (Post WeIlLock). ALP = 0+, SI @ casing valve (Blinded). Heater in well house working properly, adjust trunk to increase casing temp. OA & OOA WeIlLock samples are set up. Casing temp = 29°. IAP unchanged, OAP increased 30 psi, OOAP increased 90 psi overnight. 11/28/2018 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 21:00 T/1/0/00 = SSV/30/750/650. Temp = SI. WHPs (post Wellock). AL blinded @ CV. Heater installed and working properly. WH temp = W. Adjusted heater to raise temp. Samples set up. WHPs unchanged overnight. /2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 T/I/0/00 = SSV/30/840/700. Temp = SI. WHPs (Post Wellock). AL blinded @ CV. WH temp = 70°. Heater r12 removed from wellhouse and released. OA and OOA samples completely set up. CNG hoses still attached to OA and OOA risers. /2018 ISV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 16:00 Daily Report of Well Operations PBU H -01A T/I/O = SSV/30/520/600. Temp = SI. WHPs (post wellock). AL blinded @ CV. R/D CNG hoses and called valve crew to install casing valves. 12/7/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. T/I/O/00 = SSV/30/520/420. Temp = SI. Bleed OA/OOA (post wellock). Bled OA & ODA to 0 psi in <1 mins. Monitored for 30 mins, OAP unchanged & OOAP increased 10 psi. Final WHPs = SSV/30/0/10. 12/8/2018 SV, WV, SSV = C. MV=O. IA, OA = OTG. 10:20 T/1/0/00 = SI/0/400/0. Attempted to RD intergal flanges.Trapped pressure in Companion ODA. RDMO. 12/12/2018 "`JobIncomplete***. T/I/O/00= SI/0/0/0 POST WELL LOCK. R/D ODA comp integral & R/U tapped blind. Torqued ODA comp tapped blind to 188 It lbs. R/D ODA integral & R/U old 3" 3K McEvoy. Torqued ODA x CS to 188 It lbs. Installed riser on ODA (3K McEvoy) & torqued to 253 It lbs. R/D OA comp integral & R/U old 3" McEvoy comp. Torqued OA comp x CS to 543 It lbs. R/D OA integral & R/U old 3" McEvoy. Torqued OA x CS to 543 It lbs. 12/12/2018 linstalled floor kit & normalized up all valves. RDMO "'Job Complete*** FWHP = SI/0/0/0 See Log for Details. 7TRg= 4-1/16" CNV VVEI.LFEA©= MIcEVOY ACTUATOR= BAKER OKB. ELEV = 63.82' REF ELEV = 76.67' BF. ELEV = 45.66' KOP= 2700' Max Angle = 91" @ 10873' Datum MD 12035' Datum TVD= 8700'SS �iYK•P.:PmfC :7 111)3-3/8-X. 13-3/8^ CSG, 68M, K-55 SEAL LOCK, 7"349• D = 12.415" 18-5/8" CSG, 96.5#, K-55, D = 17.655^ 2371' Minimum ID = 3.725" @ 9476' 4-112" HES XN NIPPLE 7" TNV PORTED SEAL ASSY, D = 6.184" 694W 4-12' TBG, 12.6#, 13CR-80 V AM TOP, .0152 00f. D = 3.950" 7"BKR TACK SLV. D = 5250" H -01 A SAFETY NOTES: 13-38" X 9-518" X 18-518- OA HAS BEEN PT'D TO 2500 psi. DO NOT IXC® 2500 psi WHEN TESTING—WELL ANGLE>70°@9835'^^" CHROME TBG & LNR — O 2096' 4-12" FES X NP, D :i -J/8- A 9-018- AO, u = GAS LFT MANDRELS ST PERFORATIONSU I MARY I TVD I DEV I 7Y PE I VLV REF LOG: TTY PERF I PORrj DATE ANGLE AT TOP PERF: 85 @ 10150' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-3/4" 4 10150 - 10500 O 10106/95 2-3/4" 4 11100 - 11140 O 10/06/95 2-314' 4 1119D - 11320 0 10/06195 H -01 A SAFETY NOTES: 13-38" X 9-518" X 18-518- OA HAS BEEN PT'D TO 2500 psi. DO NOT IXC® 2500 psi WHEN TESTING—WELL ANGLE>70°@9835'^^" CHROME TBG & LNR — O 2096' 4-12" FES X NP, D :i -J/8- A 9-018- AO, u = GAS LFT MANDRELS ST NO I TVD I DEV I 7Y PE I VLV I LATCH I PORrj DATE 5 3293 3266 23 KBG-2 DOME BK 16 1021/10 4 5662 5013 43 KBG-2 SO BK 20 100110 3 7115 6262 13 KBG-2 OMY BK 0 07102/06 2 8104 7233 9 KBG-2 OM1' BK 0 071(006 1 9132 8250 13 KBG-2 DAM BK 0 07102/06 9-51W CSG MLLOUT VW 0M JH -011A) 6100' --F—s-28� 4-12" FES X NP. D = 3.813" 17^ X 4-12- BKR S-3 PKR D = 3.875^ 1 9476' 1-14-1/2- FOS XN NP, D = 3.725^ ZXP FKR w / 6' TEBACK, D = 5.00" 4-112" FAILED BKR ZXP PKR D = 4. 4-12" BKR FMC HGR D = 4.408" 4-12^ LNI7. 12.60, 13CR-80 NSCT, .0152 hpf, D= 3.958^ —1 11370' DATE REV BY COMMENTS DATE I REV BY COMMEl 5 85124105 DIOLLED IW,5/IOIGTWIAG GLVC/O(1021/10) 04107/94 11,118E INITIAL COM PLE710N 09127/18 .IMNV/JMD CORRECTED MN D IOM6195 IQES SIDETRACK (HAtA) 10104118 DDJMD ADDED OKB, Tiff, 8 BF ELEV 07102106 D14 RWO 05/08/08 M LVPJC DR -G DRAFT CORRECTIONS 05/3V09 JLSRLH SAFETY NOTECORRmmm PRUDHOE BAY UW WELL 1+01A PERK No:'1951100 AR No: 50-029-20099-01 SEC 21, T11 N, R13E 117Y FNL 8 1268 FWL BP 6tploralion (Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, February 4, 2018 1:57 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Bergene, Matthew; Frankenburg,Amy; Shriver,Tyson Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK,GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer H-01A(PTD# 1951100) no repressurization in OOA All, Producer H-01A(PTD#1951100)was placed Under Evaluation on 01/23/18 for having OOA pressure above NOL. DHD performed a follow up OOART for six days that confirmed no repressurization of the OOA.The wellhead technician conducted a PPPOT-OC that failed and a follow up leak path evaluation proved that the primary OC seals did not hold pressure, however,the secondary seals are still holding.The well meets operability criteria and will now be classified as OPERABLE. Please respond with any questions. • Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 •m: AK, GWO Well Integrity Engineer Sen . uesday, January 23, 2018 4:35 PM To: AK, 0' OC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; A. , ••S PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; Ak, Ops West Area TL; AK, RES GPB East Wells Opt En. , . , RES GPB West Wells Opt Engr; Shriver,Tyson; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Inte• • AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity We • ormation; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbe , ichael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis ternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Producer H-01A(PTD# 1951100 •• pressure found above NOL All, Producer H-01A(PTD#1951100)was reported to have OOA pressure above NOL on 1/22/1:. e pressures were reported to be T/I/0/00= 1433/260/700/700psi. The well is now reclassified as Under Evaluatio nd is on the 28 day clock for diagnostics and repair. • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,January 23, 2018 4:35 PM To: AK,OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Shriver,Tyson; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J;Wallace,Chris D (DOA) Subject: UNDER EVALUATION: Producer H-01A(PTD# 1951100)OOA pressure found above NOL Attachments: H-01 A.pdf All, Producer H-01A(PTD#1951100)was reported to have OOA pressure above NOL on 1/22/18. The pressures were reported to be T/I/0/00= 1433/260/700/700psi. The well is now reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. DHD—OART 2. Wellhead—PPPOT—OC, LPE if fails 3. Well integrity engineer—additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED WO 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, August 16, 2015 6:50 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bailey, Denise G; 'chris.wallace@alaska.gov'; AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Pettus, Whitney; Sternicki, Oliver R Subject: OPERABLE: Producer H-01A (PTD #1951100) OOA Repressurization Test Passed All, Producer H-01A (PTD#1951100) passed an OOA repressurization test on August 16, 2015 with a pressure build up rate of 0 psi per day. As this build up rate is considered manageable by bleeds, the well is reclassified as Operable. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED AUG 2 4 2015 BP Alaska-Well Integrity Coordinator GWJ yJ Ot WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinator(n)BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, August 06, 2015 9:31 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West WOpt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bailey, Denise G; 'chris.wallace@alaska.gov'; AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.reciq@alaska.gov)'; Pettus, Whitney; Sternicki, Oliver R Subject: UNDER EVALUATION: Producer H-01 D #1951100) Sustained OOA Casing Pressure exceeded MOASP All, Producer H-01A (PTD#1951100) was reported to have sustained OOA casing pressure above MOASP reported to be tubing/inner/outer/OOA=SSV/450/680/520 psi. The OOA was bled but was found to have equalized to 680 psi with the outer annulus pressure during a follow up monitor. The well is reclassified as Under Evaluation for further diagnostics. Please leave the well shut in for the evaluation. 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, August 06, 2015 9:31 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Bailey, Denise G;Wallace, Chris D (DOA);AK, OPS GC2 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Pettus, Whitney; Sternicki, Oliver R Subject: UNDER EVALUATION: Producer H-01A (PTD#1951100) Sustained OOA Casing Pressure exceeded MOASP Attachments: Producer H-01A(PTD#1951100) 110 Plot.docx All, Producer H-01A(PTD#1951100)was reported to have sustained OOA casing pressure above MOASP reported to be tubing/inner/outer/OOA=SSV/450/680/520 psi.The OOA was bled but was found to have equalized to 680 psi with the outer annulus pressure during a follow up monitor. The well is reclassified as Under Evaluation for further diagnostics. Please leave the well shut in for the evaluation. Plan Forward: 1. Operations: Leave well shut in 2. Downhole Diagnostics: Bleed OA and OOA below 500 psi 3. Wellhead: Obtain PPPOT-OC 4. Downhole Diagnostics: Perform OOART with 500 psi differential 5. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED AUG 1 0 2015 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GW :• .E " ; WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 • Producer H-01A(PTD#1951100) TIO Plot August 06,2015 • 006 L 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. tiS-Ilo File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned byt~tDianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ F&L k-cIA P6 I Itoc2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] 12,Q71- cfri/13 Sent: Friday, June 21, 2013 1:09 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: Producer H-01A(PTD# 1951100) Manageable by Bleeds All, v Producer H-01A(PTD#1951100) completed a passing OART while online with a BUR of si/day on 06/20/2013.This falls under the criteria of manageable by bleeds, and as such may remain online.At this time, the well status has been g Y � Y changed to Operable. Thank you, Laurie Climer au eC r e (Alterrtat<'.Jack t)ivbrou1 SCANNED FEB 2 U 2014 ffB""PAlaska - Well Integrity Coordinator ANlJ(q 3'u782=C'1 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, June 14, 2013 10:03 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead),AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well.Pad HUQ; 'jim.regg @alaska.gov'; 'Schwartz, Guy L (DOA)' (guy.schwartz @alaska.gov) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well In -grity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer H-01A (PTD# 1951100 xceeded MOASP All, Producer H-01A(PTD# 1951100) exceeded MOASP limi - on 06/11/2013 with TBG/IA/OA/O0A=1360/570/1090/10 psi post being b r ought on lin e.T he well has been reclassi ' ed as Under Evaluation and is to be kept online for further diagnostics. Proposed plan forward: 1. DHD: Perform warm OART 2. WIE: Further diagnostics as nee.-d. Attached are copies of the wellsket/► and TIO plot for reference. Please call with any questions. 1 /C,( 14-c1 A Rego* James B `D) 115-/ CO From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, June 14, 2013 10:03 PM c I?(,/lift To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad HUQ; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer H-01A(PTD# 1951100) Exceeded MOASP Attachments: H-01A TIO plot 6-14-13.docx; H-01A Wellbore Schematic.pdf All, ✓ Producer H-01A (PTD# 1951100) exceeded MOASP limits on 06/11/2013 with TBG/IA/OA/OOA=1360/570/1090/10 psi post being brought online.The well has been reclassified as Under Evaluation and is to be kept online for further diagnostics. Proposed plan forward: 1. DHD: Perform warm OART 2. WIE: Further diagnostics as needed. f Attached are copies of the wellsketch and TIO plot for reference. Please call with any questions. Regards, Laurie Climer SCANNED FEB 2 0 2014 (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator Drq imz,t.on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator(a)BP.com 1 ini I a ' o � QOM o 1 c >I N ca aa � o°� TREE= 4-1/16"CM/ Sf NOTES:13-3/8"X 9-5/8"X 18-5/8"OA HAS WELLHEAD MCEVOY H -O 1 A BEEN r'T'D TO 2500 psi.DO NOT EXCEED 2500 psi WHEN ACTUATOR- BAKER KB ELEV= 74.0' TESTING***WELL ANGLE>70°@ 9835'*** CHROME BF LEJ' 44.72' 1 0,4 .0 I TBG&LNR*** KOP= 2700' 1.1 A■ Max Angle= 91'@ 10873' 30"CONDUCTOR 100' r 1�1)V� :41 1' 2096' H4-1/2"HES X NIP, ID=3.813" I Datum MD= 12035' ),41 4.0* ••4 1• Datum TVD= 8700'SS �i'4� � • �� 2303' H13-3/8"STAGE TOOL 13-3/8"CSG,68#,K-55 SEAL LOCK, 2349' •► i 2349' I-I 13-3/8"X 9-5/8"XO, ID=8.681" ID=12.415" • GAS LIFT MANDRELS 18-5/8"CSG,96.54,K-55,ID=17.655" H 2371' • ST MD TVD DEV TYPE VLV LATCH PORT DATE • 5 3293 3266 23 KBG-2 DOME BK 16 10/21/10 9-5/8"STAGE TOOL 5063' ∎ L 4 5662 5013 43 KBG-2 SO BK ' 20 10/21/10 J • j 3 7115 6262 13 KBG-2 DMY BK ' 0 07/02/06 9-5/8"HES CEMENTER 1-1 5913' • 4 2 8104 7233 9 KBG-2 DMY BK r 0 07/02/06 to■ Minimum ID (H-01A)= 3.750" @ 9476' •! 1 "9132 "8250 r 13 KBG-2 DMY BK r 0 07/02/06 • 4-1/2" HES XN NIPPLE 5930' 1-I 8'TIW TIEBACK, ID=6.225" 5938' I-I9-5/8"X 7"TIW HLP PKR, ID=6.230" I a 7"TM/PORTED SEAL ASSY, ID=6.184" -I 5945' 5943' 1-19-5/8"X 7"TIW DTH LNR HGR, ID=6.108" 9-5/8"CSG,47#SEAL LOCK.N-80, ID=8.681" 1---I 6101' I-- - 9-5/8"CSG MILLOUT WINDOW(H-01A)6100'-6150' I I 9285' H4-1/2"HES X NIP. ID=3.813" I Z Z 9305' I-17"X 4-1/2"BKR S-3 PKR,ID=3.875" 1 1 1 9329' 1-14-112"HES X NIP, ID=3.813" I I 9476' H4-1/2"HES XN NIP, ID=3.725" 4-1/2"TBG, 12.6#, 13CR-80 VA TOP, --I 9488' 1---- " ' 9488' H4-1/2"WLEG, ID=3.958" I .0152 bpf, ID=3.958" -1 ELMD NOT LOGGED 1 • 9726' -I 7"MARKER JT(19')I 7"BKR TIEBACK SLV, ID=5.250" --I 10000' I---__ 7"X 4-1/2"BKR HYDRA PKR, ID=4.500" H 10007' I----- J Z 10012' I-I BKR ZXP PKR w/6'TIEBACK, ID=5.00" I 10018' H7"X 4-1/2"FAILED BKR ZXP PKR, ID=4.408" , 7"LNR,29#,13CR-80 NSCC, .0371 bpf, ID=6.184" -1 10140' IN k10027' J-17"X 4-1/2"BKR HMC HGR, ID=4.408" L-------I 10033' 1--15"X 4-1/2"XO,ID=3.958" I PERFORATION SUMMARY REF LOG:TCP PERF • • 10847']H4-1/2"BKR ISOZONE PKR, ID=3.958" I AI ANGLE AT TOP PERF:85 @ 10150' 114*Note:Refer to Production DB for historical perf data • SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2"HES ES H 10804' �� 2-3/4" 4 10150- 10500 0 10/06/95 CEMENTER ` 2-3/4" 4 11100- 11140 0 10/06/95 AN. 2-3/4" 4 11190- 11320 0 10/06/95 ~LIMN. "U, PBTD -I 11327' �" • 4-1/2"LNR, 12.64, 13CR-80 NSCT, .0152 bpf, ID=3.958" -I 11370' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/24/05 DRILLED 12/06/07 JLS/PJC CMT CORRECTION WELL: H-01A 04/07/94 N18E INITIAL COMPLETION 01/20/08 ?/PJC DRLG DRAFT CORRECTIONS PERMIT No:'1951100 10/06/95 N2ES SIDETRACK(H-01A) 05/08/08 MLI/PJC DRLG DRAFT CORRECTIONS API No: 50-029-20099-01 07/02/06 D14 RWO 05/31/09 JLS/TLH SAFETY NOTE CORRECTION SEC 21,T11 N,R13E 1173'FNL&1266'FWL 07/31/06 KSB/PJC GLV C/O 10/25/10 GTW/AGF GLV C/O(10/21/10) 06/06/07 DAV/PAG GLV CIO BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 'k,AiidiVED AUG 8 2U 333 West 7 Avenue Anchorage, Alaska 99501 1 � t ' i / 0 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal ,r5 H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 11-06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 11-08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 11-16 2000650 50029205920200 0 NA _ NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 11-18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 11-20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA _ 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 11-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 11-30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 1-1-36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 02/03/11 Mohair NO. 5688 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 408 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F -12 BMSA -00003 RST I - -- • 'r 01/05/11 1 / 1 H-01A AWJI-00117 MCNL —• ' 10/15/10 1 Vre or' 1 i J -20B s A -25A . B5JN -00073 CH EDIT PDC -GR PLUG SET 7i'Y�1 1 BCZ2 -00027 CH EDIT POC-GR (GRICCL) U ..- 1 9 rte 11/06/10 () 1 W -220 D -33 BG4H -00025 CH EDIT (USIT) 'a /(� — 'r-1( 12/27110 gA'>t(� . 1 BD88 -00061 MCNL 9 e '; 10/21/10 1 an�-l*i 1 13-37 BBKA -00056 USIT )1 y��r 09/18/10 ,=jO3 -I3 1 1 03 -20A 11503603 PRODUCTION LOG / 'T) q 11/19/06 1 --+/C 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • FEB 0 2011 Alaska Oil & Gas CODS. Commission Anchaage C::) : 11/01/10 Schlergcr NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPG -13 BCRJ -00038 X -FLOW CHECK/IBPSET RECORD 09115110 1 t MPS-43 AYKP -00104 SCMT It 08126110 1 1 P1 -09 BCRJ 00036 PRODUCTION PROFILE 09112110 1 1 W37A BD88 -00048 MEM PRODUCTION PROFILE 09/11/10 1 W -31A AZ2F -00064 MEM PRODUCTION PROFILE 09116110 1 06 -19A AWJI -00112 MEM PRODUCTION PROFILE 09/19/10 1 1 12 -05AL1 BAUJ -00050 MEM PRODUCTION PROFILE ao 09120110 1 1 Pl -16 BCRJ -00049 INJECTION PROFILE 10/06/10 1 1 04 -03 BCRD -00059 PRODUCTION PROFILE 09127/10 1 1 • P -03A AZ2F -00065 MEM INJECTION PROFILE / — 10106110 1 1 G -196 AWJI -00114 MEM PRODUCTION PROFILE 10 /04/10 1 1 131188 OEM, 49192019 Y -36 6588.00058 MEM GLS– 10109110 1 N PROFILE 1 3- 031.1•33 BCZ2 -00025 PRODUCTIO 09111/10 1 1 L -214A BAUJ -00043 MEM INJECTION PROFILE 09113110 1 1 H•01A AWJI.00118 MEM PRODUCTION PROFILE 10114110 1 1 16 -06B BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06/08 /10 1 1 H -38 AZ2F -00068 MEM PRODUCTION PROFILE 10/16/10 1 1 P2-44 BCRD -00063 PRODUCTION PROFILE 10115110 B-1 3B AYKP -00091 CH EDIT PDC -GR (SCMT) 07102110 U d (p 1 02 -22B IOAKA0069 OH MWD /LWD EDIT 07107110 2 1 W -196 BCRJ -00034 CH EDIT PDC-GR (SCMT) 09/07110 1 1 OWDW -SE APBPD3WELL RST REDO - PRINTS 09123110 1 OWDW -NW BBSK -00033 RST — 09124/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 NOV 6 NIL) ��Ntv �os H-01A (PTD #1951100) UNDER EVALUATION for sustained casing... e e Subject: H-OIA (PTfi# 1951100) 11NDEREVALUATION for sustained casing pressure- TxIA Communication From: "NSU, ADW Well Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com> Date: Sat, 02 Jun 2007 20:42:20 -0800 To: "GPB, GC2 Wellpad Lead" <GPBGC2WellpadLead@BP.com>, "GPB, Ge2 OTL" <gpbgc20t1@BP.com>, "GPB, Area Mgr West (GC2/WRD)" <GPBAreaMgrWestGC2WRD@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "Engel, Harry R" <Hatry.Engel@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOpŒng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "GPB, Prod Controllers" <GPBProdControllers@BP.com>, James Regg <jim_regg@admin.state.ak.us>, tom _ maunder@admin.state.ak.us, bob _ fleckenstein@admin.state.ak.us, "Warren, Mike" <Mike.Warren@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com> CC: ''NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Roschinger, Torin T." <Torin.Roschinger@BP.com>, "Lau, John, Jack" <laujjO@BP.com> Hi all, Well H-01A (PTD #1951100) has been found to have sustained casing pressure on the IA. The well failed a TIFL on 06/02107 when the wellhead pressures were 2300/2220/340/80. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan for ward is: 1.0: TIFL - FAILED 2. S: Gas lift valve change out 3. 0: Re- TIFL post GL V change out A wellbore schematic has been included for reference. «H-01A.pdf» Please call with any questions. Thank you, jI nna Ðu6e, (]!. Œ. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ·St.S1NNELI JUN 1 4 2007 . I.. .' _.,... Content-Description: H-OIA.pdf H-OIA.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/12/20071:22 PM 4-1/16" CIW McEVOY H-01A FROM DRLG ~ DRAFT SURFACE ~TOPOFCEMENT ~NOTES: ***CHROME TBG 8. LNR*** BF. ELEV = KOP= Max Angle = 91 @ 10873' Datum MD = 10058' "".~,,,,,,...,~~,~~,,...,~,=='M''''''''=',,,,",,,,"''_''' Datum lVD = 8700' SS . 2096' 2303' 2349' -14-1/2" X Nipple, ID - 3.813" -113-3/8" STAGE TOOL -] 13-3/8" X 9-518" XO, ID - 8.681" I 113-3/8" CSG, 68#, 10 = 12,415" I 118-5/8" CSG, 96.5#, K-55, ID = 17.655" I GAS LIFT MANDRELS ST MD lVO DEV TYÆ VLV LATCH PORT DATE 5 3293 3266 23 KBG-2 DOME BK 16 07/31/06 4 5662 5013 43 KBG-2 SO BK 24 07/31/06 3 7115 6262 13 KBG-2 DMY BK 0 07/02/06 2 8104 7233 9 KBG-2 DrvIY BK 0 07/02/06 1 9132 8250 13 KBG-2 DrvIY BK 0 07/02/06 Minimum ID:::.: 3.725" @ 9476' 4~1¡2" XN NIPPLE 19-5/8" STAGE TOOL H 5063' I T' LNR, 26#, L-80, ID = 6.276" H 5930' I BAKER TIEBACK SLEEVE, 10 = 7.500" H 19-5/8" X 7" TIV\I HLP PKR, 10 = 6.230" H 19-5/8" X 7" TIW OTH HGR, 10 = 6.108" I 9-5/8"CSG,47#,N-80,ID=8.681" H --- 9-5/8" CSG MILLOUTWINOOW (H-01A) 6100' - 6150' ( SECTION MILL) 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I 9284' -J 4-1/2" HES X NIP, 10 = 3.813" I 9305' -1 T' X 4-1/2" BKR S-3 PKR, ID = 3.875" I -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" HES XN NIP, ID = 3725" I 9488' I T' LNR, 29#, L-80, ID = 6.184" I 9726' H T' MARKERJT (19') I I BKR TIEBACK SLEEVE, 10 = 5.250" IT' X 4-1/2" BAKER H PKR, 10 = 4.500" 10012' 10018' 10027' -1 TOP OF BKR TIEBACK SLV, 10= 5.250" I -17" X 4-1/2" FAILED BKRZXP PKR, 10=4.408" -]7" X 4-1/2" BKRHMCHGR, 10=4.408" I PERFORATION SUMMARY REF LOG: TCP PERF ANGLEAT TOP PERF: 85 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-3/4" 4 10150 - 10500 0 10/06/95 2-314" 4 11100 - 11140 0 10/06/95 2-3/4" 4 11190 - 11320 0 10/06/95 -14-1/2" CTC EXT CSG PKR, 10 = 3.98" I PBTD I 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" DATE 04/07/94 10/06/95 07/14/03 12/29/03 07/31/06 REV BY COMMENTS ORIGINAL COM PLETION ML RIG SIDETRACK ( H.01A) CMOITLP KB ELEVATION CORRECTION JLJ/PA G GL V C/O KS8/PJC GL V C/O DATE REV BY COMMENTS PRUDHOE 8A Y UNrf WELL: H-01A ÆRMrf No: '1951100 API No: 50-029-20099-01 SEC 21, T11N, R13E 1173' SNL & 1266' WEL BP Exploration (Alaska) I' q¿ I' 7/13/0 h STATE OF ALASKA ALAe OIL AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED JUL 1 1 2006 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 195-110 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20099-01-00 7. KB Elevation (ft): 74' 9. Well Name and Number: PBU H-01A 8. Property Designation: 10. Field / Pool(s): ADL 028284 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11372 feet true vertical 8801 feet Plugs (measured) 9448 Effective depth: measured 10327 feet Junk (measured) 9360 true vertical 8796 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2371' 18-5/8" 2371' 2371' 930 870 Intermediate 6101' 13-3/8" x 9-5/8" 6101' 5336' 3450 1950 Production Liner 4210' 7" 5930' - 10140' 5209' - 8735' 8160 7020 Liner 1370' 4-1/2" 10000' - 11370' 8711' - 8801' 8430 7500 ;;.r Å ,~.A,~' /. Perforation Depth MD (ft): '"" ""',' .. .,¡ 10150'-11320' Perforation Depth TVD (ft): 8736' - 8795' 4-1/2", 12.6# L-80 9488' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 9305' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl JUL 13 2006 Treatment description including volumes used and final pressure: Cut & pulled tubing. Run 7" tieback to surface, cement with 258 Bbls (1449 cu ft /529 sx) Class 'G' and 100 Bbls (561 cu ft /484 sx) Class 'G'. Run new tubinQ. 13. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 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: Contact Doug Cismoski, 564-4303 306-185 Printed Name Terrie Hubble Title Technical Assistant , Signature /íÍJ /1/\ ; A ~lWe Phone 564-4628 07/1 0 ~ Prepared By Name/Number: Date OCoTerrie Hubble, 564-4628 ..., . . Form 10-404 Revised 04/2006 ORIGJ~'AJ Submit Onglnal Only TREE = WB..LHEAD = ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CWV McEVOY BAKER 74.0' 44.72' 2700' 91 @ 10873' 10058' 8700' SS 113-3/8" CSG, 68#, ID = 12.415" I 118-5/8" CSG, 96.5#, K-55, ID = 17.655" 1 Minimum ID = 3.725" @ 9476' 4-1/2" XN NIPPLE 19-5/8" STAGE TOOL H 1 7" LNR, 26#, L-80, ID = 6.276" H I BAKER TIEBACK SLEEV E, ID = 7.500" H 19-5/8" X 7" TWV HLP PKR, ID = 6.230" H 19-5/8" X 7" TWV DTH HGR, ID = 6.108" I 1 9-5/8" CSG, 47#, N-80, ID = 8.681" H 5063' 5930' 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I I BKR TIEBACK SLEEVE, ID = 5.250" 17" X 4-1/2" BAKER H PKR, ID = 4.500" 17" LNR, 29#, L-80, ID = 6.184" I 10140' PERFORA TION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 85 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-3/4" 4 10150 - 10500 0 10/06/95 2-3/4" 4 11100 - 11140 0 10/06/95 2-3/4" 4 11190-11320 0 10/06/95 DATE 04/07/94 10/06/95 03/01/01 03/12/02 07/14/03 12/29/03 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK ( H-01A ) FINAL CHlTP CORRECTIONS CMO/TLP KB B..EV A TION CORRECTION JLJ/PAG GLV C/O DATE NOTES: ***CHROME TBG & LNR*** . -14-1/2" X Nipple, ID = 3.813" -113-3/8" STAGE TOOL I -113-3/8" X 9-5/8" XO, ID = 8.681" I ST MD 5 3293 4 5662 3 7115 2 8104 1 9132 GAS LIFT MANDRB..S TVD DEV TYÆ VLV LATCH 3266 23 DCK SV BEK 5013 43 KBG-2 DMY BK 6262 13 KBG-2 DMY BK 7233 9 KBG-2 DM Y BK 8250 13 KBG-2 DMY BK PORT DATE o 07/02/06 o 07/02/06 o 07/02/06 o 07/02/06 o 07/02/06 9-5/8" CSG MILLOUTWINOOW (H-01A) 6100' - 6150' ( SECTION MILL) 9284' -14-1/2"HESXNIP,ID-3.813" I 9305' -j7" X 4-1/2" BKR S-3 PKR, ID - 3.875" I 9329' -14-1/2" HES X NIP, 10 = 3.813" I 9475' -14-1/2" HES XN NIP, ID = 3725" I 9488' -14-1/2" WLEG 9726' -17" MARKER JT (19') I 10012' 10018' 10027' -1 TOP OF BKR TIEBACK SL V, ID = 5.250" 1 -iT' X 4-1/2" FAILED BKRZXPPKR, ID = 4.408" -17" X 4-1/2" BKR HMC HGR, ID = 4.408" I -14-1/2" CTC EXT CSG PKR, ID = 3.98" 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, ID = 3.958" REV BY COMMENTS PRUDHOE BA Y UNIT WB..L: H-01A PERMIT No: "1951100 API No: 50-029-20099-01 SEC 21, T11N, R13E 1173' SNL & 1266' WB.. BP Exploration (Alaska) e e H-01A Prudhoe Bay Unit 50-029-20099-01 195-110 Accept: Spud: Release: Ri: PRE-RIG WORK OS/22/06 DRIFTED W/2' STEM, 3.80" CENT, SAMPLE BAILER TO 4611' SLM, BAILER MIT. DRIFTED WI 2' STEM,3.70" CENT, SAMPLE BAILER TO 9332' SLM, BAILER MIT. OS/23/06 RUN 1: DETERMINE DEPTH OF CT FISH AND NEAREST 4-1/2" COLLAR ABOVE IT FOR JET CUT. CT FISH TOP AT 9349.5', NEAREST 4-1/2" COLLAR AT 9340'. 30.6' FROM TOP OF FISH TO TOP OF 4-1/2" X 3-1/2" XO. RUN 2: 3.65" POWER CUTTER AT 9342.3'. CUT 4-1/2" TUBING 2.3' BELOW NEAREST COLLAR AND 7.2' ABOVE CT FISH. HUNG UP IN GLM #3 AT 8225' WHILE PULLING OOH, WORKED FREE. I. . , e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/16/2006 21 :00 - 21 :30 0.50 MOB P PRE Skid rig floor from drlg position to move position 21 :30 - 22:00 0.50 MOB P PRE Move rig off well H-30 22:00 - 00:00 2.00 MOB P PRE Move rig to H-01A - Spot over well H-01A - Shim Rig 6/17/2006 00:00 - 00:30 0.50 RIGU P PRE Skid rig floor from move position to drlg position - Spot rock washer 00:30 - 01 :00 0.50 RIGU P PRE Rig up floor - Berm rock washer - Accept rig 01 :00 hrs 01 :00 - 04:00 3.00 RIGU P DECOMP RU skirt in cellar - Load pipe shed with 4" DP - Ru tree with circulating lines 04:00 - 05:00 1.00 WHSUR P DECOMP PU Lubricator - Pull BPV - LD Lubricator 05:00 - 06:00 1.00 RIGU P DECOMP Fill pits with 9.8 brine 06:00 - 08:30 2.50 KILL P DECOMP start pumping 9.8 brine down tubing - taking retruns out annulus - 3 bpm @ 1150 psi after 35 bbls pressure dropped to 1100 psi - pumped additional 15 bbls pressure dropped to 1050 psi - Stopped pumping check annulus - tubing - Both on vac - RD circulating lines 08:30 - 09:30 1.00 RIGD P DECOMP Install TWC - test tree / TWC to 3500 psi 09:30 - 11 :00 1.50 WHSUR P DECOMP ND Tree - Adapter flange 11 :00 - 13:30 2.50 WHSUR P DECOMP Hard scale build up on hanger threads - Clean out with wire wheel on air grinding tool - Screw TDS XO into hanger - Made up 8.5 rounds 13:30 - 16:00 2.50 WHSUR P DECOMP NU spacer spool/ BOP's 16:00 - 22:30 6.50 WHSUR P DECOMP Test BOP's - Annular - Pipe rams 4" / 4 1/2" - Choke manifold - HCR Choke / Kill Manual Choke / Kill - Upper / Lower IBOP - Floor safety valves - Blind rams - 250 low - 3500 high - 5 mins each test - Preform Accumulator test - John Spaulding with AOGCC waived witness of BOP test - WSL witnessed all testing of equipment 22:30 - 23:00 0.50 WHSUR P DECOMP RD Testing equipment - Blow down choke / kill lines 23:00 - 23:30 0.50 PULL P DECOMP Drain Stack - PU Lubricator extension 23:30 - 00:00 0.50 PULL P DECOMP PU Lubricator - MU Extension rods - Pull TWC 6/18/2006 00:00 - 00:30 0.50 PULL P DECOMP RD Lubricator - Lubricator extension - LD both 00:30 - 01 :30 1.00 PULL P DECOMP RU tubing equipment - 01 :30 - 02:00 0.50 PULL P DECOMP Pull Hanger to surface to surface - PUW 165K 02:00 - 03:00 1.00 PULL P DECOMP Fill annulus with 9.8 brine from pill tank - 55.5 bbls - Circulate down tubing - Returns 50 + bbls brine back - then 116 bbls diesel back - Then 9.8 brine - Shut down 03:00 - 04:30 1.50 PULL P DECOMP Let diesel migrate - Building volume 04:30 - 08:00 3.50 PULL P DECOMP Con't circulate to surface - returns back after 300 strokes 30 bbls - (Fluid dropped 200' in 1.5 hrs) - 3.5 to 7 bpm @ 280 to 600 psi - Water back mud weight from 9.8 to 9.4 ppg 08:00 - 09:30 1.50 PULL P DECOMP LD hanger - RU Compensator 09:30 - 13:00 3.50 PULL P DECOMP LD 41/2" NSCT 12.6# 80 Cr tubing from 9311 to 7132' 13:00 - 13:30 0.50 PULL P DECOMP LD SSSV - RD Control line spool - LD Spool of rig floor 13:30 - 21:30 8.00 PULL P DECOMP Con't LD tubing - Total Joints Laid down 229 - 6 GLM - Cut off 1.16' - (recovered 54 stainless steel bands) 21 :30 - 23:00 1.50 PULL P DECOMP RD tubing quipment - Clear rig floor - Install Wear ring - RILDS 23:00 - 00:00 1.00 FISH P DECOMP Moblize BHA to rig floor 6/19/2006 00:00 - 01 :30 1.50 PULL P DECOMP MU BHA - 7" - 9 5/8" scrapers 01 :30 - 04:30 3.00 PULL P DECOMP RIH with scrapers to 6136' bit depth 04:30 - 05:00 0.50 PULL P DECOMP Tag 7" Liner top @ 5939' Flow check - Well static 05:00 - 07:00 2.00 PULL DECOMP POH with scrapers - From 6136' to BHA 238' 07:00 - 08:00 1.00 PULL P DECOMP LD BHA - Clear rig floor 08:00 - 09:00 1.00 PULL P DECOMP Make up HES 7" FasDrill - Running tool Printed: 7/5/2006 10:08:48 AM f ¡ e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/19/2006 09:00 - 11 :00 2.00 PULL P DECOMP RIH with FasDrill to 5979' 11 :00 - 12:00 1.00 PULL P DECOMP Circ 5 bpm @ 470 psi while working FasDrill plug from 5985' to 5979' - Set plug @ 5979 - 38 turns to right - PU 1 OK at a time to shear off running tool 45K over PUW 130 - SOW 115 12:00 - 13:30 1.50 PULL P DECOMP Cut drlg line - Rig service - Inspect saver sub 13:30 - 16:00 2.50 PULL P DECOMP Pump dry job - POH from 5979' - LD Running / Setting tool 16:00 - 19:00 3.00 PULL P DECOMP MU 9 5/8" RTTS - RIH to 5804' 19:00 - 20:00 1.00 EVAL P DECOMP Set 9 5/8" RTTS packer - Shut pipe rams - Pressure up on annulus to 2500 psi - Hold for 15 mins - No Pressure drop - Good test - Bleed off pressure - open pipe rams - Pump down drill pipe - Establish injection rate @ 2.5 bpm 800 psi - Shut down pump pressure bled off to 100 psi in 1 min - Bleed remaining pressure off - Open pipe rams - Unseat RTTS packer 20:00 - 20:30 0.50 PULL P DECOMP Blow down top drive - Kill line 20:30 - 23:00 2.50 PULL P DECOMP Observe well - POH with RTTS - LD same 23:00 - 00:00 1.00 PULL P DECOMP MU Mule shoe - XO - RIH 6/20/2006 00:00 - 01 :00 1.00 PULL P DECOMP RIH with mule shoe to top of 7" Fastdril plug at 5979'. PU weight 130K SO weight 115 01 :00 - 02:30 1.50 PULL P DECOMP MU cementing lines - CBU 7 bpm at 880 psi. 02:30 - 03:30 1.00 REMCM P DECOMP Pump 5 bbls of water ahead - test lines to 2500 psi -pump 20.6 water - 25 bbls (121 sxs) of 15.8 ppg cement (.2% D046 BWOC Antifoam, .3% D065 BWOC dispersant, .32% D167 BWOC fluid loss, .03% B-155 BWOC retarder, 1.0 Ib/bbl CemNet fibers, and .5 Ib/bbls Celloflake - yield 1.16 cftisx) - 5 bbls of water. Displaced cement plug with 50 bbls of 9.4 ppg brine. Circulated cement in place holding backpressure with choke. Cement in place at 3:31 AM. 03:30 - 04:00 0.50 PULL P DECOMP Pull 10 stands slowly to 5032'. 04:00 - 04:30 0.50 PULL P DECOMP Close Annular - RU circulating line - Reverse circ out cement from 4" DP. Dumped 5 bbls of cement contaminated brine. 04:30 - 08:30 4.00 PULL P DECOMP Hesitation squeeze liner lap: PSI Minutes Final PSI Psi Loss Strokes 200 10 160 40 4 400 10 280 120 9 400 10 320 80 2 600 10 460 140 5 600 10 530 70 3 800 10 690 110 5 800 10 760 40 3 1000 120 760 240 5 Bled off pressure slowly. Pumped a total of 3.6 bbls - Recovered 2.25 bbls - 1.35 bbls squeezed away 08:30 - 10:30 2.00 PULL P DECOMP Pulled out of hole with cementing string 10:30 - 12:00 1.50 PULL P DECOMP Make up BHA #2. Picked up used 12-1/4" mill tooth bit, 13-3/8" casing scrapper, bit sub, bumper sub and oil jars. 12:00 - 12:30 0.50 PULL P DECOMP Ran in the hole to 1149. String sat down. Unable to work through. 12:30 - 13:30 1.00 PULL P DECOMP Broke circulation 5 bpm at 210 psi - 40 rpm at 2K torque. Attempted to ream through tight spot at 1149'. Unable to ream through tight spot. Finish circulating bottoms up. Printed: 7/5/2006 10:08:48 AM ,I: e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/20/2006 13:30 - 15:30 2.00 PULL P DECOMP Pulled out of the hole and laid down the BHA. Clear the rig floor of tools. 15:30 - 16:30 1.00 PULL P DECOMP Closed blinds and tested the casing and cement plug to 1000 psi for 30 minutes and recorded on chart. 16:30 - 17:00 0.50 PULL P DECOMP Lubricate rig. 17:00 - 17:30 0.50 PULL P DECOMP P/U 6 1/2" DC and stand in derrick 17:30 - 18:30 1.00 PULL P DECOMP Mobilize and M/U BHA #3. Picked up 8.5" bit, bit sub, 9 7/8" stab, bumper sub, and oil jars 18:30 - 19:30 1.00 PULL P DECOMP RIH & tag 9 5/8" casing top @ 2363' 19:30 - 21 :00 1.50 PULL P DECOMP POOH - UD BHA 21 :00 - 22:00 1.00 PULL P DECOMP M/U BHA # 4. Picked up bit, scraper, collars, bumper sub and oil jars. 22:00 - 23:30 1.50 PULL P DECOMP RIH to 4486' 23:30 - 00:00 0.50 PULL P DECOMP P/U storm packer and RIH 1 stand to 4560' - (PU 130, SO 113) 6/21/2006 00:00 - 01 :00 1.00 EVAL P DECOMP Set storm packer @ 100' and test to 1000 psi for 5 min 01 :00 - 02:00 1.00 BOPSU P DECOMP NID BOPE 02:00 - 09:00 7.00 BOPSU P DECOMP Change out casing spool and packoff 09:00 - 10:00 1.00 BOPSU P DECOMP RlU and test packoff to 1200 psi for 30 min 10:00 - 12:30 2.50 BOPSU P DECOMP N/U BOPE 12:30 - 13:00 0.50 BOPSU P DECOMP RlU and test BOP and choke line breaks to 250 psi low, 3500 psi high for 5 min each - Record on chart 13:00 - 14:00 1.00 EVAL P DECOMP RID test equipment and blow down choke and kill lines 14:00 - 14:30 0.50 BOPSU P DECOMP Install wear ring and RILD's 14:30 - 15:00 0.50 EVAL P DECOMP Retrieve storm packer and UD same 15:00 - 16:00 1.00 PULL P DECOMP RIH to 5150' - Wash to 5700',5 bpm @ 420 psi - (Tag cement @ 5700') 16:00 - 20:30 4.50 CLEAN P DECOMP Drill out cement from 5700' to 5939' - (500 gpm, 2680 psi, 60 RPM, 3-5 TO, 15 WOB, PU 148, SO 115, RW 132) 20:30 - 22:00 1.50 CLEAN P DECOMP Pump hi-vis sweep and circulate hole clean @ 530 gpm, 2680 psi, 60 RPM, 4 TO 22:00 - 22:30 0.50 CLEAN P DECOMP RlU and test casing to 2000 psi for 30 minutes - Record on chart 22:30 - 23:00 0.50 CLEAN P DECOMP RID test equipment and blow down choke and kill lines 23:00 - 00:00 1.00 CLEAN P DECOMP Flow check and POOH to 5700' 6/22/2006 00:00 - 02:00 2.00 CLEAN P DECOMP POOH to BHA 02:00 - 03:00 1.00 CLEAN P DECOMP Stand back 6 3/4" DC and UD BHA #4 03:00 - 04:30 1.50 CLEAN P DECOMP M/U BHA #5 and P/U 4 3/4" DC's 04:30 - 06:30 2.00 CLEAN P DECOMP RIH t/ 5900' 06:30 - 08:00 1.50 CLEAN P DECOMP Slip and cut drilling line - Service top drive 08:00 - 09:00 1.00 CLEAN P DECOMP Tag TOC @ 5939' - Drill cement to 5969' (PU 145, SO 120, RW 130, WOB 15, 80 RPM, 4 TO, 100 SPM @ 1940 psi) 09:00 - 10:00 1.00 CLEAN P DECOMP CBU (100 SPM @ 1940 psi, 80 RPM, 4 TO) 10:00 - 12:30 2.50 CLEAN P DECOMP Flow check - POOH to BHA 12:30 - 13:30 1.00 CLEAN P DECOMP Stand back DC's and UD BHA 13:30 - 14:30 1.00 CLEAN P DECOMP M/U polishing mill and BHA # 6 14:30 - 17:00 2.50 CLEAN P DECOMP RIH to 5908' - Break cir and wash to 5939' 17:00 - 18:00 1.00 CLEAN P DECOMP Polish TIW tieback receptacle (PU 150, SO 122, RW 135,40 RPM, 4-8 TO, 15 WOB, 50 SPM @ 490 psi) 18:00 - 19:30 1.50 CLEAN P DECOMP Pump Hi-Vis sweep and circulate hole clean (400 gpm @ 1510 psi, 60 RPM, 4 TO) 19:30 - 21:30 2.00 CLEAN P DECOMP Flow check - Pump dry job - POOH 21 :30 - 22:30 1.00 CLEAN P DECOMP UD 6 3/4" drill collars and BHA 22:30 - 23:30 1.00 BOPSU P DECOMP Change top rams to 7" Printed: 7/512006 10:08:48 AM ¡ , ,,!. e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 Pull wear ring and install test plug RlU and test door seals to 1500 psi for 5 min - RID and blowdown lines 01 :00 - 02:00 1.00 CASE P DECOMP RlU to run 7" casing 02:00 - 05:00 3.00 CASE P DECOMP PJSM - Run 7" 26# L-80 BTC-M casing 05:00 - 06:00 1.00 CASE P DECOMP RlU to run 7" TC-II with compensater and torque turn 06:00 - 12:30 6.50 CASE P DECOMP Run 7" 26# L-80 TC-II casing (PU 190, SO 155) 12:30 - 13:30 1.00 CASE P DECOMP RID compensater - M/U cement head 13:30 - 14:00 0.50 CASE P DECOMP Apply 500 psi test on seals - Break circulation (5bpm @ 170 psi) - PJSM - Batch cement 14:00 - 15:00 1.00 REMCM P DECOMP Drop ES opening plug - Load closing plug - Cir plug down and pressure to 3300 psi and open ES cementer 15:00 - 18:00 3.00 REMCM P DECOMP Cement with Schlumberger - Pump 5 bbls H20, Test lines to 4500 psi, Pump 5 bbls H20, Pump 258 bbls 11.5 ppg cmt @ 5.4 bpm @ 128 psi, Pump 70 bbls wI 1/4 CF 15.8 ppg cmt @ 5 bpm @ 133 psi, Pump 30 bbls 15.8 cmt, Drop closing plug, Pump 10 bbls H20, Displace with rig pumps 216.6 bbls seawater @ 5.5 bpm @ 2200 psi, Bump plug and pressure to 3220 psi to close ES cementer, Check ES cementer holding, 17.8 bbls cement to surface, Cement in place @ 1730 hours 18:00 - 20:00 2.00 P DECOMP NID BOP - Set 7" casing slips with 150K tension on slips 20:00 - 22:00 2.00 P DECOMP UD cmt head & torque tum equipment - Flush stack - Void 7" casing for cut - Cut 7" casing with Wachs cutter 22:00 - 00:00 2.00 P DECOMP UD spacer spool - N/U tubing spool - Test tubing spool to 4200 psi for 30 minutes, good test 6/24/2006 00:00 - 02:00 2.00 BOPSU P DECOMP N/U BOPE - Add 1 foot spacer spool to choke hose 02:00 - 03:30 1.50 BOPSU P DECOMP Install test plug - Change upper rams to 2 7/8" X 5" variables 03:30 - 04:00 0.50 BOPSU P DECOMP RlU test equipment 04:00 - 08:00 4.00 BOPSU P DECOMP Test BOP's - Annular - Pipe rams 4"/4 112" - Choke manifold - HCR choke I kill - Manual choke I kill -Upper I lower IBOP - Floor safety valves - Blind rams - 250 psi low - 3500 psi high - 5 minutes each test -Preform accumulator test - Chuck Sheve with AOGCC waived witness of test - WSL witnessed all testing of equipment 08:00 - 08:30 0.50 BOPSU P DECOMP RID test equipment - Blowdown choke and kill lines 08:30 - 09:30 1.00 CLEAN P DECOMP P/U BHA #7(7" csg tieback drill out assembly) - RIH to 404' 09:30 - 14:30 5.00 CLEAN P DECOMP RIH with 4" DP singles from pipeshed to 4383' 14:30 - 16:00 1 .50 CLEAN P DECOMP RIH wI stds to 5808' - Break circulation - Wash down and tag cement at 5874' - 5 BPM @ 580 psi 16:00 - 18:00 2.00 CLEAN P DECOMP Wash and ream cement from 5874' to 5914' - Drill ES cementer @ 5914' - Baffle collar @ 5925' - Continue drill to 5967' (PU 150, SO 117, RW 130, WOB 4-15, 60 RPM, 4 TO, 70 SPM @ 1080 psi) 18:00 - 19:00 1.00 CLEAN P DECOMP RlU and test 7" casing to 3500 psi for 30 minutes - Record on chart 19:00 - 19:30 0.50 CLEAN P DECOMP RID test equipment and blowdown kill line 19:30 - 20:30 1.00 CLEAN P DECOMP Continue drill shoe track and Fasdrill plug from 5967' to 5979' 20:30 - 21 :00 0.50 CLEAN P DECOMP CBU @ 5979' (9 BPM, 1700 psi, 60 RPM, 4 TO) 21 :00 - 22:30 1.50 CLEAN P DECOMP RIH to top of fish @ 9343' 22:30 - 23:00 0.50 CLEAN P DECOMP CBU @ 9343' (PU 225, SO 145, RW 168, 9.5 BPM, 2850 psi, 40 RPM, 8 TO) 23:00 - 00:00 1.00 CLEAN P DECOMP Flow check - Pump dry job - POOH to 6852' 6/25/2006 00:00 - 03:00 3.00 CLEAN P DECOMP POOH from 6852' to 404' Printed: 7/5/2006 10:08:48 AM I, .', e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/25/2006 03:00 - 03:30 0.50 CLEAN P DECOMP Stand back collars - UD BHA #7 03:30 - 04:00 0.50 CLEAN P DECOMP Clear floor - Mobilize BHA #8 04:00 - 05:00 1.00 CLEAN P DECOMP M/U BHA #8 ( 6" Burn shoe, wash pipe, junk baskets) - RIH wI DC to 471' 05:00 - 08:00 3.00 CLEAN P DECOMP RIH to 9004' 08:00 - 09:30 1.50 CLEAN P DECOMP Cut Drill Line - Service rig 09:30 - 10:00 0.50 CLEAN P DECOMP RIH to 9288' - Wash to TOF @ 9342',211 gpm @ 960 psi 10:00 - 15:00 5.00 CLEAN P DECOMP Mill over top of fish, 4 1/2" x3 1/2" crossover, and mill on packer from 9342' to 9408'. Progress stopped possibly due to worn out shoe - PU 250, SO 150, RW 180,50 RPM, 11 TO, 5-15 WOB, 50 SPM @ 960 psi 15:00 - 19:00 4.00 CLEAN P DECOMP Flow check - Pump dry job - POOH to 471' 19:00 - 20:30 1.50 CLEAN P DECOMP Stand back collars - UD BHA # 8 - Clean junk baskets, Burn shoe 100% wore out 20:30 - 21 :00 0.50 CLEAN P DECOMP M/U BHA #9 ( Rotary shoe, wash pipe, junk baskets) - RIH wI DC to 475' 21 :00 - 00:00 3.00 CLEAN P DECOMP RIH wI BHA #9 to 9293' - Break circulation @ 5 BPM @ 1020 psi - Wash down and tag top of fish @ 9342' 6/26/2006 00:00 - 05:00 5.00 CLEAN P DECOMP Milling on packer @ 9408' (PU 235, SO 145, RW 175, 60 RPM, 10-15 TO, 219 gpm @ 1280 psi) 05:00 - 05:30 0.50 CLEAN P DECOMP Mill torqued up and hung up, had to jar free 05:30 - 06:30 1.00 CLEAN P DECOMP Milling on packer from 9408' to 9409' - Lost returns - Milled and pushed packer to 9414' while pumping 100 bbls seawater into formation - High torque and 70K up drag - (PU 235, SO 145, RW 175,60 RPM, TO 10-15, 219 gpm @ 1280 psi) 06:30 - 07:30 1.00 DECOMP Mill torqued up and hung up - Jarring up 75K to get free from packer, could push down with no problems with barely enough weight to cock jars but had to work free jarring up and backreaming 07:30 - 11 :00 3.50 CLEAN P DECOMP POOH F/9414' to 475' (pump twice the pipe displacement every 5 stands or 10 bbls every 15 min after losing returns)- (Shot fluid level soundings and established fluid level @ +1- 940') 11 :00 - 13:00 2.00 CLEAN P DECOMP Stand back collars and UD BHA # 9 (mill assembly) 13:00 - 13:30 0.50 CLEAN P DECOMP Clear rig floor - Blowdown kill line 13:30 - 14:00 0.50 FISH P DECOMP Mobilize BHA #10 to rig floor 14:00 - 15:00 1.00 FISH P DECOMP MIU BHA # 10 (spear assembly) 15:00 - 18:00 3.00 FISH P DECOMP RIH wI BHA # 10 to 9322', (Pumping 10 bbls seawater every 15 minutes) 18:00 - 19:00 1.00 FISH P DECOMP Engage fish @ 9389' - Attempting to spear fish - Push fish to 9533' 19:00 - 20:30 1.50 FISH P DECOMP Working fish @ 9533' - Spear fish with 25K down weight, 50K over pull, jar free from fish,( posible not fully engaging fish or top of fish split or milled on one side ?) 20:30 - 00:00 3.50 FISH P DECOMP POOH F/9533' T/3157' @ controlled pulling speed, (pump twice the pipe displacement every 5 stands) 6/27/2006 00:00 - 01 :00 1.00 FISH P DECOMP Continue POOH from 3157' to 409' 01 :00 - 02:00 1.00 FISH P DECOMP Stand back collars and UD BHA #10 (Spear assembly· One segment of grapple on spear was broken off and left downhole, 3 segments of grapple that was still intact on spear showed no indication of having been inside of tubing stub) 02:00 - 03:00 1.00 FISH P DECOMP Lubricate and service rig while waiting on orders 03:00 - 04:30 1.50 FISH P DECOMP PJSM - Cut and slip drill line Printed: 7/5/2006 10:08:48 AM ..:. e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/27/2006 04:30 - 07:00 2.50 EVAL N DPRB DECOMP N/D bell nipple and riser - N/U shooting flange 07:00 - 12:00 5.00 EVAL N DPRB DECOMP PJSM - RlU HWS - RIH with camera - Pump 560 bbls 100 degree 2% KCL attempting to clear up annulas to be able to see with camera @ 9533' - no success 12:00 - 14:00 2.00 EVAL N DPRB DECOMP POOH with camera - RID HWS 14:00 - 15:30 1.50 EVAL N DPRB DECOMP N/D shooting flange - N/U bell nipple and riser 15:30 - 19:30 4.00 EVAL N DPRB DECOMP M/U 3.5" muleshoe and RIH to 9530' 19:30 - 20:00 0.50 EVAL N DPRB DECOMP Pump 150 bbls 100 degree 2% KCL down drill pipe (7bpm @ 1040 psi) 20:00 - 00:00 4.00 EVAL N DPRB DECOMP RlU HWS - RIH with camera to 9505' wireline attempting to see fish - Pump 40 bbls 100 degree 2% KCL down drill pipe attempting to clear vision of camera 6/28/2006 00:00 - 03:00 3.00 EVAL N DPRB DECOMP Continue wI E-line camera run through DP- Film top of fish at 9505' W.L.M. 03:00 - 04:00 1.00 EVAL N DPRB DECOMP POH wI camera- RD HWS 04:00 - 07:30 3.50 EVAL N DPRB DECOMP POH wI DP- LD mule shoe. 07:30 - 08:30 1.00 FISH P DECOMP Mobilize & MU BHA # 11 (Burn shoe and washpipe) 08:30 - 11 :30 3.00 FISH P DECOMP RIH to 9483' 11 :30 - 13:30 2.00 FISH P DECOMP Screw in T.D.- Obtain parameters- Tag T.O.F. at 9537'- Rotate & work over top of fish- Wash down wI no rotary- Tag 4 1/2" x 3 1/2" XO- PU- Pulling tight Gunk)- Rotate & work over XO- Rotate & push fish to 9982' 13:30 - 17:00 3.50 FISH P DECOMP Milling on junk/packer fl 9982' to 9984' ( regained returns while milling)- 50 rpm- 7 bpm 1610 psi- 11-14k torque- Losing 45-50 bph 17:00 - 21 :00 4.00 FISH P DECOMP Flow check - POOH to 475' (pump 6bbls every 5 stands) 21 :00 - 22:30 1.50 FISH P DECOMP Stand back collars and UD BHA #11 (pump 10 bbls every 15 min) 22:30 - 23:30 1.00 FISH P DECOMP Clear rig floor of Baker tools - Mobilize BHA to floor 23:30 - 00:00 0.50 FISH P DECOMP M/U BHA # 12 (shoe, o-shot, jars, collars, intensifier) 6/29/2006 00:00 - 03:00 3.00 FISH P DECOMP RIH w/5 7/8" overshot & 6" x 4 1/2" shoe to 9427' 03:00 - 04:00 1.00 FISH P DECOMP Cut drilling line 04:00 - 04:30 0.50 FISH P DECOMP Continue RIH to 9901 '-Screw in TD- Obtain parameters- Tag TOF at 9921' (PU 275, SO 145, RW 185,50 RPM, 10-12 TQ, 7BPM @ 900 psi) 04:30 - 05:00 0.50 FISH P DECOMP Dress off top of fish- Engage same- Jar fish free- Pulling wI 100k overpull until tail pipe cleared liner. 05:00 - 11 :00 6.00 FISH P DECOMP POH wI fish f/9930 - 419'- Double fluid displacement. 11 :00 - 12:00 1.00 FISH P DECOMP Stand back DC's 12:00 - 14:00 2.00 FISH P DECOMP Release fish- LD same (recovered packer & all tailpipe) 14:00 - 14:30 0.50 FISH P DECOMP Clear floor - Mobilize BHA #13 to rig floor 14:30 - 15:30 1.00 FISH P DECOMP M/U BHA #13 (bit, junk bskts, scraper, jars, collars) 15:30 - 18:30 3.00 FISH P DECOMP RIH wI 7" scraper to 9500' (PU 265, So 145) 18:30 - 21 :30 3.00 FISH P DECOMP POOH from 9500' to 404' 21 :30 - 23:00 1.50 FISH P DECOMP UD collars and BHA #13 23:00 - 23:30 0.50 FISH P DECOMP Clear rig floor and Mobilize RTTS to rig floor 23:30 - 00:00 0.50 FISH P DECOMP M/U RTTS and RIH T/955' 6/30/2006 00:00 - 04:30 4.50 FISH P DECOMP Continue RIH wI RTTS fl 995' to 9375' 04:30 - 06:30 2.00 FISH P DECOMP Screw in TD- Obtain parameters-PU 240k-SO 140k- Set RTTS at 9370'- Test casing to 3500 psi f/30 min.- Record on chart. 06:30 - 08:00 1.50 FISH P DECOMP Attempt to release RTTS. Pulling 90k over- Circ. down DP wI 6 bpm. pull to 90k over wI no success. Close bypass- Fill backside wI fluid- PU & open bypass- No movement- Hit down Printed: 7/5/2006 10:08:48 AM e e .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-01 H-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 6/17/2006 Rig Release: 7/2/2006 Rig Number: 14 Spud Date: 5/12/1971 End: 7/2/2006 6/30/2006 06:30 - 08:00 1.50 FISH P DECOMP wI 65k several times- Released- Pulling 20-25k over. 08:00 - 12:00 4.00 FISH P DECOMP POH wI RTTS 12:00 - 15:00 3.00 FISH P DECOMP RIH wI muleshoe on 4" DP to 9773' 15:00 - 21:00 6.00 FISH P DECOMP POH LDDP FI 9773' 21 :00 - 22:30 1.50 FISH P DECOMP Cut and slip drill line - Service rig 22:30 - 23:00 0.50 FISH P DECOMP RIH stands in derrick and UD same 23:00 - 00:00 1.00 FISH P DECOMP Clear rig floor - RlU for 4.5" 13cr80 Vam Top tubing 7/1/2006 00:00 - 01 :00 1.00 FISH P DECOMP Cont. RlU for 4.5" 13cr80 VamTop tubing 01 :00 - 13:30 12.50 FISH P DECOMP Run 4.512.6# 13cr80 VamTop tubing to 9488' Using compensator & Torque turn equipment. (Ran 217 jts. No rejections) - Set packer @ 9305' (PU 187, SO 125) 13:30 - 14:30 1.00 FISH P DECOMP Pump 180 bbls 140 degree seawater wI corrosion inhibitor to annulus 14:30 - 16:00 1.50 FISH P DECOMP Land hanger - RILD's - Drop rod and ball - Fill tubing void - RlU pump in sub 16:00 - 18:00 2.00 FISH P DECOMP Set packer - Test tubing to 3500 psi for 30 min on chart - Bleed tubing to 1500 psi - FilllA void - Test IA to 3500 psi for 30 min on chart - Bleed off annulus then tubing - Pump down annulus and shear DCK valve with 2750 psi 18:00 - 18:30 0.50 WHSUR P DECOMP UD landing joint - Install TWC and test to 1000 psi for 5 min 18:30 - 20:00 1.50 WHSUR P DECOMP PJSM - NID BOP stack 20:00 - 22:30 2.50 WHSUR P DECOMP N/U McEvoy tubing head adapter and tree - Test DX hanger seal to 5000 psi for 30 min - Test tree to 5000 psi for 5 minutes 22:30 - 23:30 1.00 WHSUR P DECOMP RlU lubricator - Pull TWC - RID lubricator 23:30 - 00:00 0.50 WHSUR P DECOMP RlU hot oil to freeze protect well 71212006 00:00 - 01 :00 1.00 WHSUR P DECOMP Pressure test lines to 2500 psi - Pump 70 bbls diesel down IA with Hot Oil 01 :00 - 02:30 1.50 WHSUR P DECOMP U-Tube IA and tubing 02:30 - 03:30 1.00 WHSUR P DECOMP Blowdown lines - RID Hot Oil - Set BPV and test to 1000 psi 03:30 - 04:00 0.50 WHSUR P DECOMP Secure well and tree - Release rig @ 0400 hours Printed: 7/5/2006 10:08:48 AM . . I~S-- ltO ,1 FRANK H. MURKOWSKI, GOVERNOR j l AI.ASIiA. OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU H-01A Sundry Number: 306-185 Dear Mr. Cismoski: A ",'N~~·' ~~~\ .:;.,.~",>;I "'i.;;j;.i"""! ::.:> 'lii,'";i tv·."J· 'J Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiskday of May, 2006 Encl. tqS-- -II ð ~."'I1flo~ ¡J~ S/è51í Ij StATE OF ALASKA ALASKA 0 AND GAS CONSERVATION COM ISSION . APPLICATION FOR SUNDRY APPROVAl!' 20 AAC 25.280 w6A- S / 24-l'z...o ø" 1. Type of Request: 0 Abandon 181 Repair Well ' o Plug Perforations o Stimulate o Other o Alter Casing 181 Pull Tubing . o Perforate New Pool o Waiver o Re-Enter Suspended W o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ 195-110 /' 181 Development 0 Exploratory 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20099-01-00 ...---. 7. KB Elevation (ft): 74' 9. Well Name and Number: PBU H-01A / 8. Property Designation: 10. Field / Pool(s): ADL 028284 Prudhoe Bay Field / Prudhoe Bay Pool 11...".... >..'> .,'" '\J\IJ::;I+.l¡( INIJUIUN "i> ',',' ..'"...','.......>. .,. FiF··.>···..·.· ..>! .....,..... ... Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft)· Plugs (measured): Junk (measured): 11372 8801 10327 / 8796 9448 9360 Casino Lenoth Size MD TVD Burst Collapse Structural Conductor Surface 2371' 18-518" 2371' 2371' 930 870 Intermediate 6101' 13-3/8" x 9-5/8" 6101' 5336' 3450 1950 Production Liner 4210' 7" 5930' - 10140' 5209' - 8735' 8160 7020 Liner 1370' 4-1/2" 10000' - 11370' 8711' - 8801' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 10150' - 11320' / 8736' - 8795' 4-1/2", 12.6# x 3-1/2", 9.2# 13Cr 9460' /' Packers and SSSV Type: 7" x 3-1/2" Baker 'S-3' packer packers and SSSV MD (ft): 9404' 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal 0 BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 14. Estimated Date for / 15. Well Status after proposed work: Commencing Operations: June 8, 2006 181 Oil. o Gas o Plugged o Abandoned 16. Verbal Approval: Date: o WAG DGINJ DWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer ~~ ~ //'0.. ~ Prepared By Name/Number: Signature j -"', Phone 564-4303 Date Terrie Hubble. 564-4628 C/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:.... ')¡vO-/ R.5 o Plug Integrity 5J'BOP Test o Mechanical Integrity Test o Location Clearance Other: T ~C; t ßoPE to ~S"OO , RBDMS BFL MA Y ,~ 0 2006 f(.,..· Subsequent Form Required: 10 - 40 ~tiJ (j¿' (r~ ) ~, (;ØI!'MÍSSIONER APPROVED BY DateS'Ú,oÓ Approved By: THE COMMISSION Form 10-403 Revised 07/2005 \./ ~~- Ämit In Duplicate \/~ti\L L r. .-0(0 l L . . Obp G~~ H-01A Rig Workover Scope of Work: Pull 4-W x 3-%" completion, recover 1-%" coiled tubing fish, mill and retrieve packer, run ,/ and fully cement 7" tieback to surface, run 4-%" 13Cr80 completion. I MASP: 2270 psi ./ Well Type: Producer Estimated Start Date: June 8, 2006 Pre-ri F 1 S 2 E 3 o 4 o 5 o 6 Proposed Procedure / 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-W tubing string to the cut. 3. PU DP and burn shoe. Burn over 4-1)2" x 3-1/2" XO at 9382' and mill packer at 9404' 4. Fish packer, tubing tail, and stub. L 5. Run and fully cement 7" 26#/ft tieback liner from 5930' MD to surface (-æbbls). ...- 6. Run 4-%" 13Cr80 completion with Baker S-3 packer. Position packer at -9350' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. / 9. Set BPV. NO BOPE. NU and test tree. RDMO. ' irReE = . 4-1116" CPN ~LI"EAD= M:EVOY H-Q A Proposed Completion ~CTUATOR= BAKER KB. a.EV = 74.0' BF. a.EV = 44.72' . SURFACE TOP OF CEMENT I KOP= 2700' Max A~1e = ~1 @ 1OS73' Datum M) = 10058' r-- Datum lVD = 8700' 58 . 2210' 1-14-1/2" HES HXO SSSVN, ID = 3.813" I ~ 2303' H13-318" STAGE TOOL I 113-318" CSG, 68#, ID = 12.41S" 2349' f- 2349' 13-3I8"X9-5I8"XO,ID=S.681" I 118-518" CSG, 96.5#, K-SS, ID = 17.65S" 2371' -µ ~ GAS LIFT IIMI'œELS ST M) lVD DEV TYPE VLV LATCH PORT ~TE r---o; 6 3437 3331 27 HES-LB-1 DMV RA 0 12125103 5 5861 5096 43 HES-LB-1 DMV RA 0 03104IOO 19-518" STAGETOOL H 5083' 1--: µ 4 7291 6412 12 KBG-2LS DMV BK 0 03104IOO I 7" LNR, 26#, L-80, ID: 6.27S" H 6930' I 3 8225 7330 9 KBG-2LS DMV BK 0 03104IOO 2 8814 7913 8 KBG-2LS DMV BK 0 03104IOO I BAKER TIEBACK SLEEVE. ID = 7.S00" 5930' I 1 9243 8332 24 KBG-2LS DMV BK 0 12125103 9-S/8" X 7" TNV HLP PKR, ID = 6.230" H 6938' r-- ~- 19-518" X 7" TIW DTH HGR, ID = 6.1 OS" H 6943' I- I 9-5IS" CSG, 47#, N-80, ID = S.681 " H 8101' 1- 9-518" CSG MLLOUTWlt-DOW (H-01A) 6100' - 6150' ( SECTION MILL ) 14-112" TBG, 12.6#, 13-CR. .0152 bpf, ID: 3.958" 1- 1-- l- · I -14-112" HESX NIP,ID: 3.S13" I ~ 2S 9380' 7" X 4-112" BKR 8-3 PKR, ID: 3.875" I /' · . -14-112" HESX NIP,ID= 3.813" I · I I H4-112" HES XN NIP, ID: 3725" I I -14-112" WLEG 1 I 9726' H7" IIMRKERJT(19') I I BKR TIEBACK SLEEVE. ID = S.25O" H 10000' I J 17" X 4-112" BAKER H PKR. ID = 4.500" I . 10007' ~ ~ I 10012' TOP OF BKR TIEBACK SL V, ID = S.2SO" I I J -17" X 4-112" FAILED BKRZXPPKR, ID = 4.408" I ~ 10018' 2S 10027' 7" X 4-112" BKR HMC HGR, 10 = 4.408" I - 7"II\J~?_ I_An In=R1AA" I- 0140' II. ~ORATlONSUMMARY REF LOG: TCP PERF 10847' 4-112" CTC EXT CSG PKR, ID = 3.98" I ANGLEATTOP~: 85 @ 10150' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz ~TE 2-314" 4 10150 - 10500 0 10106I95 2-314" 4 11100-11140 0 10106I95 ~ 2-314" 4 11190-11320 0 10106I95 I PBTD I 11327' ~ ~ 14-112" LNR, 12.6#, 13-CR. .0152 bot, ID = 3.958" 1-1 11370' I DATE REV BY I COIIIMENTS ~TE RBI BY COIIIMENTS PRUDHOE BAY UNIT 04107194 IOAGINAL COM PLET'lON W8..L: H-01A 10106195 M. LINDER RIG SlŒTRACK ( H-01A) PERMTNo: 1951100 03101101 SIS-LG ANAL API No: 50-029-20099-01 03112102 CHITP CORRECTIONS SEC 21, T11 N, R13E 1173' SNL & 1266' W8.. 07114103 CM.)JTLP KB a.EVA TION CORRECTION 12f29103 JLJ/PAG GLV CiO BP exploration (Alaska) .. . . TREE = WaLHE'A 0 = ACTUATOR = KB. ELBf = BF. ELBf = KOP= M3x Angle = D3tum M) = D3tum TV 0 = 4-1/16" CNJ McEV OY BA KER 74.0' 44.72' 2700' 91 @ 10873' 10058' 8700' SS H-01A SAFETY NOTES: 13-3/S" X 9-51S" X 1S·5IS" OAHAS BæN prD TO 2500 psi. DO NOT EXCEED 2500 psi WHEN TESTING. WELL ANGLE> 70° @ 9S35' & > 90° @ 10340'. * 4-1/2" & 3·112" TBG & 4-112" LNR ARE CHROME. ASH IN W8.L sæ SAFETY NOTE BELOW. . 2210' 2303' 2349' 13-318" STAGETooL 13-318" X 9-5/8" XO, 10 = 8.681" Minimum ID = 2.750" @ 9391' 3-1/2" HES X NIPPLE 19-518" STAGE TOOL H 5063' t-- 113-3/8" CSG, 68#, 0 = 12.415" I 118-518" CSG, 96.5#, K-55, 10 = 17.655'1 7" LNR, 29#, L-80, 10 = 6.184" I ST MO 6 3437 5 5861 4 7291 3 8225 2 8814 1 9243 TVO 3331 5096 6412 7330 7913 8332 GAS LlFTMANrRELS OEV TYPE VLV LATæ 27 I-ES-LB-1 DOME RA 43 I-ES-LB-1 rN RA 12 KBG-2LS rN BK 9 KBG-2LS rN BK 8 KBG-2LS rN BK 24 KBG-2LS EMPTY BK R)Rf DATE 20 03/04/00 o 03/04/00 o 03/04/00 o 03/04/00 o 03/04/00 03/04/00 I BAKER llEBAO< SLEBfE, 10= 7.500" I 19-518" X 7" TW I-LP PKR, 10 = 6.230" H 19-518" X 7" TIW DTH 1-K3R, 10 = 6.108" I 19-518" CSG, 47#, N-80, 10= 8.681" 1-1 1* ASH-75' OF 1-3/4" CHEM-CurCOIL TBG I 14-1/2" lBG, 12.6#, 13-CR, .0152 bpf, 10= 3.958" I 9-518" CSG MILLOUTWII'{)OW (H-01 A) 6100'-6150' (SB::llONMILL) SAFETY NOlES: " ASH IN HOLE" 75' OF 1-314" COIL TBG W/ BHA LATCI-ED INTO 3-1/2" HES XX PLLG @ 9448'. CT UN6.BLE TO RJLL PLUG AI'{) HAOTO DO A COIL CHEMICAL cur. *TOPOFFISH @ 9360'. REFER TO 06130/99 TELEX FOR DETAILS. 9382' 9391' 9404' 9428' 9448' 3-1/2" I-ES X NP, 0 = 2.750" -17" X 3-1/2" BKRS-3 PKR, 10= 3.875" I 3-1/2" I-ES X NP, 0 = 2.750" 3-1/2" I-ES X NP, 0 = 2.750" 13-1/2"TlP, 9.2#, 13-CR, .0087 bpf, 10= 2.992" 9458' 3-1/2" WL83, 10 = 2.992" H ELM) IT LOGGED07/03198 7" MARKERJT(19') I BKR llEBAO< SLEBfE, 10= 5250" 17" X 4-1/2" BAKER H PKR, 10 = 4.500" 10000' 10007' 10012' 10018' 10027' TOP OF BKR TEBACK SLV, 10 = 5.250" -17" X 4-1/2" FAILED BKRZXP A<R, 10 =4.408" -17" X 4-1/2" BKR HMC HGR, 10 = 4.408" I 10140' PERFORATION SUM.AARY REF LOG: TCP PERF A~LEA TTOP ÆRF: 85 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INlERVAL OpnlSqz DA lE 2-314" 4 10150 -10500 0 10/06195 2-314" 4 11100 - 11140 0 10/06195 2-314" 4 11190-11320 0 10/06195 -14-1/2" erc EXTCSG A<R,IO = 3.98" 14-1/2" LNR, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" 11370' DAlE 04/07/94 10106/95 02/17/01 03101/01 03112/02 07/14/03 REV BY COMWENTS ORIGINAL COMPLETION RIG SIDETRACK (H-01A) CONVERfEOTO CANVAS FIN6. L CHITP CORRECllONS CMOITLP KB ELEVATION CORRB::TION DATE REV BY COM.AENfS PRUŒiOE BAY UNIT WB..L: H-01 A ÆRMT~: 1951100 API~: 50'{)29-20099-01 SEC21, T11N, R13E1173'SNL& 1266'WB.. BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description Date BL H-01 A \q~- \\û 10687663 LDL 01/04/04 1 J-24A 2~C4 -1\'1 10563218 SBHP SURVEY 09/28/03 1 E-05A ¡c;Q-030 10703984 SBHP SURVEY 04/10/04 1 A-13 I g I - i S- C.l 10621770 PPROF W/DEFTlGHOST 03/22/04 1 C-17A l q ~- t ~J 10672332 LDL 10/27/03 1 F -46A :) <:/"1 - c: ~ 'Jf 10715389 MCNL 03/18/08 1 2-68/S-17 J 8 ;j .. ~ q '1 10866550 PPROF W/DEFT 07/07/04 1 1-45/Q-26 /89 .... /2 'f 10568473 PPROF W/DEFTlGHOST 07/11/03 1 8-17 J 7 q -- C' ).. é!> 10679034 PSP INJECTION PROFILE 11/27/03 1 S-30 I Cj c -. t f, G, 10560328 SBHP SURVEY 01/02/04 1 S-42 \ t..1 L~ è ìj Lf 10877777 SBHP SURVEY 08/22/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 :jÇ!\NNEC SEP 0 8 2005 1 ~ ) ¡ ~ ,-- ..f...... .:1., J N'._) (,I ~ \; / I.V., ~ '" Date Delivered: 07/20/05 NO. 3438 ìðJ 5' ;' II 0 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ----" "3 )..'13 "-- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503/838 ,.: A TTN: Beth /1 / ¡ ! U Received by: Itltüvr~'» r~! :¿! J f ' :1 L/ i" 1A/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state. ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / Y-PAD 07/10/03 Pat Lattner John Spalding WelllY-11B I P.T.D.I1951110 Notes: WelIIY-27 P.T.D.1900280 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: I Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Type test I P I Test psiI 21511 CasingI 0+I 2500 2450 24401 P/FI P T,,~,.¢. I ~I M~,,~,OI '~'~'1 ~'"~'1 Tubingl V^OI V^OI v^cl V^CI .nter~aI 4 Type test I P I Test psiI 21561 I Casin~ll 0+I 25OOI 24601 246OI P/FI P Type Inj. Type I~. Type I~. Test Details: 4-yearMITIA's. Neither well was i~ecting. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 SCANNEE:~' AUG 0 6 2003 2003-0710_M IT_PBU_Y-27.xls STATE OF ALASKA t ~., .... ALASKA _ _,._AND GAS CONSERVATION COIW. ~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: i--I Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing i-I Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KB = 63.82' [] Exploratory 7.----~nit or Property Name 3. Address [--IStratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska I--I Service 4. Location of well at surface 8. Well Number 1173' SNL, 1266' WEL, SEC. 21, T11N, R13E At top of productive interval 4157' SNL, 45' WEL, SEC. 21, T11N, R13E At effective depth 4142' SNL, 4026' EWL, SEC. 22, T11N, R13E At total depth 4132' SNL, 1306' EWL, SEC. 22, T11N, R13E H-01A 9. Permit Number / Approval No. 95-110 399-089 10. APl Number 50-022-20099-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner PeRoration depth: measured true vertical 11372' feet 8802' feet 11327' feet 8797' feet Length Size 2371' 18-5/8" 2320' 13-3/8" 6072' 9-5/8" Plugs (measured) Junk (measured) Cemented 4400 sx Permafrost II MD TVD 200 sx 'G', 1800 sx PF II 2390' 2390' 2349' 2339' 6101' 5326' 8630' 4-1/2" 230 sx Class 'G' 1000-1137' ORIGINAL 10150'-10500'; 11100'-11140'; 11190'-11320' 8737'-8742';8763'-8769';8777'-8796' Tubing (size, grade, and measured depth) 4-1/2" @ 9404' Packers and SSSV (type and measured depth) Packer @ 9404' SSSV @ 2210' 8701'-8791' 14ECEIVED OCT 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [~ Oil [--1 Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~¢¢~ :¢~j~ FRANKA. McOORKLE · Title Supervisor, GRAVITY DRAINAGE Prepared By Name/Number: Date Submit In Duplic Form 10-404 Rev. 06/15/88 To Blair Wondzell From: A1 Schmoyer Subject: H-01a Long Term Shut-In H-01a has a cretaceous leak at about 6000'. There is a Sundry 403 in place allowing us to flow the well with this leak.. A condition of the "Variance" is that we prove tubing integrity before resuming production. We have run into problems while trying to prove tubing integrity. We now have a plug with a Coil Tubing fishing assembly stuck in the 3 lA" tailpipe at 9448'. We have discontinued fishing operations due to cost and risk. We are evaluating the potential for RWO and or Rig Sidetrack. Either option will require that we pull tubing, recover the packer/tailpipe assembly and patch the cretaceous leak before recompletion. At this time the well is shut in and freeze protected. .... STATE OF ALASKA ALASK,, ,.)IL AND GAS CONSERVATION CC .,vllSSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other []Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development E] Exploratory I--] Stratigraphic I---I Service 4. Location of well at surface 1173' SNL, 1266' WEL, SEC. 21, T11N, R13E At top of productive interval 4157' SNL, 45' WEL, SEC. 21, T11N, R13E At effective depth 4142' SNL, 4026' EWL, SEC. 22, T11N, R13E At total depth 4132' SNL, 1306' EWL, SEC. 22, T11N, R13# 6. Datum Elevation (DF or KB) KB = 63.82' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-01A 9. Permit Number 95-110 10. APl Number 50-022-20099-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11372' feet Plugs (measured) 8802' feet 11327' feet Junk(measured) 8797' feet Length Size Cemented 2371' 18-5/8" 4400 sx Permafrost II 2320' 13-3/8" 6072' 9-5/8" 200 sx 'G', 1800 sx PF II 8630' 4-1/2" 230 sx Class 'G' MD TVD 2390' 2390' 2349' 2339 6101 5326' 10000'-1137' 8701'8791' PeRoration depth: measured 10150'-10500'; 11100'-11140'; 11190'-11320' 8737'-8742';8763'-8769';8777'-8796' true vertical Tubing (size, grade, and measured depth) 4-1/2" @ 9460' Packers and SSSV (type and measured depth) Packer @ 9404' SSSV @ 2210' ORIGINAL 13. Attachments [~;(] Description summary of proposal l--~ Detailed operations program I--I BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [~ Oil [--I Gas [--I Suspended Service Contact Engineer Name/Number: Prepared By Name/Number: Michael Williams 564-4657 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Frank A_ Mc.C.r~rkl¢. 4¢ ¢¢~/~ Title Supervisor, Gravity Drainage Commission Use Only Date .~//.~/~ ~ I Approval No.~ ~'~~ Condition~oO~..~pproval: Notify Commission so representative may witness I .,~ _' Plug integrity __. BOP Test___ Location clearance .~..o~O~ J-- Mechanical Integrity Test__ Subsequent form required 10- /.40~ ~r of the Commission ORIGINAL SIGNED-BY Commissioner Form 10-403 Rev. 06/15/88 Robed N. Chri~trcn~o~l D~:~ m i~l n('C~cat e H-Ola Brief Procedure Summary: Tubing Cleanout: I1. Clean scale out of tubing with mill and acid. Pressure Testing: 2. Dummy off Gas Lift Mandrels at 3437' and 5861'. 3. Set a plug and pressure test the tubing. Pull the plug. 4. Liquid pack the inner annulus 5. Return the well to production Monitoring- 17. Monitor the inner annulus pressure TREE: 4' CIW WELLHEAD: 20 3/4' McEVOY ,ACTUATOR: BAKER -~30' SHOE 13-3/8'. 68:#~, K-55 2349' I 13-3/8X9-5/8' XO 2371' I 18-5/8,.96.5# SHOE NOTE: 13-3/8" x 9-5/8" ANNULUS HAS ONLY BEEN PRESSURE TESTED TO 2500 PSI. DO NOT EXCEED 2500 PSI WHEN TEST- ING ANNULUS. 7- TiW Isolation pkr ~ 5930, 'I and tie back sleeve. 9-5/8'. 47#/ft. 16100.I N-80 NOTE 3.6" IDTHROUGH LOWER FOUR GAS LIFT MANDRELS. 4.5'. 12.6# 13 CR NSCT TUBING ID: 3.958' CAPACITY: .01522 BBL/FT. 13 CHROME TUBING AND LINER 7' Baker 'h' liner top pac~,er wi tie back sleeve 7' Baker zxp failed oacker 7' NSCC Float shoe PERFORATION SUMMARY 10000' 10011' J 10140' SIZE SPF INTERVAL OPEN/SOZ'D 2-3/4' 4 10150'-10500' Open 2-3/4' 4 11100'-11140' Open 2-3/4' 4 1119(7-11320' Open H-01a PBTD 11323' 4.5', 12.6# 13 CR & L-80 NSCT 11370' 4.5' LANDING NIPPLE i 2210' (OTIS 'X') (3.S13' ID) NOTE: TWO SIZES AND STYLES OF GAS UFT MANDRELS. O_~)~T~ RA LATCHES) ! ~ NO. I MD(~KB) I TVDss. I DEV. l l I I o11_. 4.5' x 1' Camco GAS LIFT MANDREU / I (KBG-2LS)(I/VlTH BK LATCHES) 4 I 7291' I 6412' I 12~ ! 3 I s=~' I 7~o' 18o 1 9243' 8332' 29° NOTE: SPECIAL CLEARANCE GLM. ID THROUGH MANDRELS IS 4.5' x 3.5' Tubing X- Over 3.5- X I~pple 2.75' ID 7' Baker S-3 Packer 3.875' ID 3.5' X Nipple 2.75' ID 3.5' X Nipple 2.75' ID 3.5' WLEG' ELMD 9380' 9391' 9404' 9428' 9448~ 9460' Horizontal liner Baker isozone packer I 10847' DATE REV. BY COMMENTS 1971 WELL DRILLED 4-~-94 M. UNDER INITIAL COMPLE'RON NABORS 18-E 10/6/95 M. LINDER SIDETRACK COMPLETION NABORS 2-ES PRUDHOE BAY UNIT WELL'.H-1 a{41-28-11-13) APl NO: 50-029-20099 .~.EC 21 Tll N RGE I~E BP Exploration (Alaska) H-01a J CURRENT PROBLEMS: Tubing scales off at 5839'wlm. Just above GLM#5 Producing Status: Full time producer to HP system Last Three Well Test: Date BOPD GOR WC% Choke WHP WHT 2/6/99 1530 17000 69 176 1007 128 3/18/99 1200 18000 67 178 1082 132 4/22/99 1210 19000 61 176 1170 129 Completion: Original completion was done on 10/6/95 by Nabors 2es. Miminum ID: 2.75" X-niples at 9428' and 9448' DD Note: GLMs # !,2,3 & 4 have 3.6" ID Perforation Status: Depth (md) Footage Depth (tvdss) Zone 10150-10500 (350') 8662-8667 4 11100-11140 (40') 8688-8694 4 11190-11320 (130') 8702-8721 4 total (520') Last TD Tag: 11293' CTD Status open open open Guns 2 3/4" 4spf 2 3/4" 4spf 2 3/4" 4spf 1 O/O6/95 10/06/95 10/12/95 06/14/98 7/2/98 07/02/98 09/15/98 11/12/98 11/15/98 03/25/99 WELL HISTORY Sidetrack completion Initial perfs 10150-500, 11100-40, 11190-320 (4 SPF) Static survey WL tagged scale in the tbg at 5826'. Milled scale with 2 7/8" mtr and 3.55" mill. Got big rate bu77. Ran memory PL. No unusual results. WL tagged scale in the tbg at 5839'. Would not pass 1.95" drift. Milled scale with 2 7/8" mtr and 3.55" mill. Got big rate buzz. CTU Scale Inhibitor treatment WL tagged scale in the tbg at 5826'. Comments: Suspect cretaceous leak via 9 5/8" x 7" liner lap. Water is entring the tbg thru GLM#5 at 5861' forming BaSO3 scale in the tbg and flowline updated 5/6/99 as .,ciated with Request for x rice Subject: H-01a Actions Associated with Request for Variance Date: Thu, 3 Jun 1999 17:43:05 -0400 From: "Schmoyer, Al" <SchmoyAL2~BP.com> To: "'blair_wondz¢ll~adrnin.stat¢.ak.us'" <blair_wondzell~admin.stat¢.ak.us> Blair, To follow up on our conversation of 6/2/99: H-01a has a cretaceous leak entering the inner annulus either through the 9 5/8"x7" liner lap or through a hole in the 9 5/8" liner. The cretaceous water enters the tubing through a gas lift valve at 5861' and forms barium sulfate scale in the tubing and on downstream piping. For an interim solution we plan to set a dummy gas lift valve at 5861' so that the cretaceous water can not enter the tubing. We will follow this with a positive pressure test of the tubing to confirm tubing integrity. This will isolate the cretaceous leak to the inner annulus. The inner annulus pressure from the cretaceous is expected to be -200 psi. There is no history of outer annulus communication. We will monitor the annulus pressures weekly to ensure no change in annulus conditions. H-01a is a zone 4 completion in a relatively good collection point. It last tested on 5/15/99 at 1.0 mbopd at 66% wc and 20,000 gor. The gor is trending towards marginal. We would like to continue to produce the well under these conditions. Longer term strategy for H-01a would be to evaluate the economics for a Rig sidetrack once the well exceeds marginal gor. Sidetrack work would need to include repair of the cretaceous leak. Please call if we need to discuss further, A1 Schmoyer MB10-3 STMP: SchmoyAL2@BP.com Fax: (907) 564-4943 ph: (907) 564-5865 1 of 1 6/3/99 2:04 PM CURRENT PROBLEMS: Tubing scales off at $8$g'wlm. Just above GLM#5 Produolng Status; Full time @roduoerto HP system Last Three Well Test: Date B_O_P_D_ PJ$/gg 1530 17000 69 176 1007 128 3/181~ 1200 18000 67 176 1082 132 ~22/ag 1210 19000 81 176 1170 129 Completion: Original completion was done on 10/6/95 by Nabors 2ea. Mlminum ID: 2.75" X-niplea at g428' and 9448' DD Note: GLMe # !,2,3 & 4, have $,6" ID Pe~fo=tion Status; DeDth (md) Egg_tag~ D_~m_ .J13~) Zone 10150-10500 (350') 8662-8667 4 11100-11140 (¢0') 5688-8894 4 11190-11320 (130') 8702-8721 4 total (520') Last TD Tag: 11293' CTD open open open 2 3/4" 4spf 2 3/4" 4Spf 2 3/4" 4spf ! .,, WELL HISTORY 101061~5 10/06/g5 10112/95 06/14/98 7/2/98 07/02/98 09/15/98 11112/98 11/15/98 03/25/99 $ideffock completion Initial parts 10150-800, 11100-40, 111g0-320 (4 SPF) Static survey WL tagged scale in the tbg of 5826', Milled scale with 2 7/8" mtr and 3,55" mill, Got big rate buzz. Ran memory PL. No unusual results, WL tagged scale In the tbg at 5839', Would not pass 1 ,gE' drift, Milled scale with 2 7/8" mir and 3,,5§" mill, Got big rate buzz, CTU Scale Inhibitor treatment WL fagged scale In the tbg at $82~)'. Comments: Suspect cretaceous leak via 9 5/8" x 7" liner lap. Water Is entring the tbg thru GLM#5 at 5861' forming BaSO3 scale in the tbg ancl flowllne updated 5/6/99 , _ . [~ 13.~$Xg-B/~' xO ~L~ I~.~/8~, 9B-~ gHOE NOTE: 1:k~/8" x g-E~O" ANNULUS HAS ONLY BEEN PRESSURE TEBTED TO 2500 PSI, DO NOT EXCEED 2~00 PSI WHEN TEb"'r. INCa ANNULUg. II . I H-01a NOTE $,s- )o 'rtlROUGH LOWER FOUR OAS LII~/' MANDRELS. 13 CHROME TUBING AND LINER imm~ Open 4.$", 1~,G~ I~ OR & L-SO NSCT ~ DATE . -- WELL DEli. LEO UNO,. J ! - I LANDING NIPPLE J ~10" J ~'x'l(~.e~' ID) NOTE,. TY~ $1~E;~ AND STYLES OF MANDR~ i~ I ~r I=,' I~- '% I ~s'--1 -~1~il ~ I em~ I ~o' !~' Jl 1 ~' ~* J O~. lO.ROUGH MANDRG~ ELMD Horizontal liner P_B_UDJ:[O~ A Y_U=I~I.T_ APINO: B P Exploration (Alaska) 9 !5 '" i i.'i 6 ,o° Z.~ 7 95"-'i 'i0 [!, H C/' A ,:"; J (i'i i% H F' 9 5 i i 0 95 .... 'i i 0 9 5 .... i i 0 9 5 - 'i i 0 85 "~ 'i 0 G }{ -- T V D 9 5 ....i 0 9 5 .... i i 0 D I F L / A rs /C iq / Z D I.../' G R ? a ':i :i.'-: 'J Da"ke; 07/28:/'97 RUN DATE RECVD -i i o/i 3 i 9 5 · i 'i 01' 0 z:~./' 9 S -i 'i 0/' 04 / 95 'i 'i 0 ,// 0 l.[ ?" El 5 -i 'i 0/" 04 ,/' 95 04? i 6,/96 04 / 'i 6 / 96 04/ i 6/'96 · i 'i 0/' 04/95 i o/04/95 0 8 ,i 0 6 ,/9 6 0 8/' 0 6 / 9 6 J d I" y i~;/_.... F:: e c e "i' v e d o y ¥;~ WELL LOG TRANSMITTAL To: State of Alaska August 05, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - H-01A & H-0 lA PB 1 AK-MM-950946 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a "signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. API#: 50-029-20099-01 H-O1A PBI: 1 LDWG formatted LIS tape with verification listing. API#: 50-029-20099-70 AUG 0 6 1996 ,a. lasi~a Oil ii ~s Cons. C, om~ .An~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dr~..q.qt~r Industrin.q_ Inc._ ¢'x~mn~nv m I::t I I__1__ I IM G S E I::IL/I I-- E S WELL LOG TRANSMITTAL To: State of Alaska April 12, 1996 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - H-01A & H-01A PB 1 AK-MW-50080, AK-MM-950946 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 H-01A: c,..2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-20099-01 ~12" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-20099-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia H-01A PBI: ~2"x 5" MD Gamma Ray Logs: 50-029-20099-70 ~2" x 5" TVD Gamma Ray Logs: 50-029-20099-70 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS E3,' SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-110 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5 o-029-20099-01 4. Location of well at surface'¢ 9. Unit or Lease Name 1173'SNL, 1266'WEL, SEC. 21, T11N, R13E - · ~ '~_;:~,';~_;,.. ! PrudhoeBayUnit : ,i ~~ 10. Well Number At Top Producing Interval 4157'SNL, 45'WEL, SEC. 21, TllN, R13E ;i'~ :~:::'~; : '~E,.~-..'.)~ 11.H'OIAField At Total Depth and Pool · '. ~ Prudhoe Bay Field/Prudhoe Bay Pool 4132'SNL, 1306' EWL, SEC. 22, TllN, R13E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 76. 07 ADL 028284 112. Date Spudded09/08/95 13. Date T.D. Reached09/26/95 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°nsl 0/06/95 N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11372'MD/8802'TVD 11327'MD/8797'TVD YES [] NO []I 2210feet MDI 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, LWD, DIR/FE, GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18-5/8" 96.5# K55 Surface 2371' 24" 4400 sx Permafrost II 13-3/8" 68# K55 Surface 2349' 18-5/8" 9-5/8" 4 7# N80 2349' 6101' 12-1/4" 200 sx 'G ', 1800 sx PF II 7" 29# 13Cr/L80 5930' 10140' 8-1/2" 526 sx Class 'G' 4-1/2" 12.6~ 13Cr80 10000' 11370' 6" 230 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and :25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2" 9460' 9404' MD TVD 26. ACID, FRACTURE, CEMENT SQUEF7E, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10150'- 10500' 8737'- 8742' Freeze Protect w/260 bbls of Dry Crude 11100' - 11140' 8763' - 8769' 11190' - 11320' 8777' - 8796' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 15, 1995 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-eeL GAS-MCF WATER-eeL CHOKE SlZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED ©IL-eeL GAS-MCF WATER-eeL 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. JAr') · Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ! 30. GEOLOGIC MARKERS '. FORMATION TESTS :. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH ! GOR, and time of each phase. Sag River 9658' 8608' Shublik 9736' 8636' Top of Sadlerochit 9993' 8711' i ! i 1 1 31. LIST OF A'I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge , Title Senior Drilling Enginear 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. 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: H-01A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 09/03/95 (1) TD: 0'( 0) 09/04/95 (2) TD:10063' (10063) 09/05/95 (3) TD:10063' ( 0) 09/06/95 (4) TD: 6350'( 0) 09/07/95 (5) TD: 6132' ( 0) NU BOPE TO TEST MW: 0.0 VIS: 0 MOVE RIG. RU TO RECOVER FREEZE PROTECT, RU LUBRICATER, PULL BPV, RD LUBRICATER. CBU AT 755'. ND SURFACE TREE. RD INTERNAL BOP'S. NU ALL FUNCTIONS, NU BOPE TO TEST. SET BRIDGE PACKER MW: 0.0 VIS: 0 PERFORM INTEGRITY TEST. FU DSM, PULL TWC, RD DSM. RI TEST 9-5/8" CSG X 13-3/8" CSG. TEST WELL CONTROL EQUIPMENT. PULL SINGLE COMPLETION, 3-1/2" OD, LAY DOWN TUBING T/O'. BREAK OUT LOCK DWN SCREWS, PULL TBG FREE. LAY DOWN 3-1/2" 9.29 L80 NSCT TBG. RECOVERED 69 SSSV CL BANDS, 293 JTS, 13-1/2' CUT JT, 5 GLM'S. SET BRIDGE PACKER. L/D SCAB LINER, 7" NSCC MW: 0.0 VIS: 0 TEST WELL CONTROL EQUIPMENT, NO GO TEST PLUG FAILED. RD, REPLACE TEST PLUG, ND BOPE, DROP TBG SPOOL, INSTALL EMERG SLIP HANDLES, NU BOP, CHANGE OUT TOP SET RAMS. FUNCTION TEST COMPLETED SATISFACTORILY. TEST TOP RAMS. RETRIEVED BOP TEST PLUG ASSEMBLY. PULL TUBING, 7" OD, ON RETRIEVAL STRING T/10008'. P/U MU 7" SPEAR, ENGAGE 7" STRING. BACK OUT LOCK DOWN SCREWS, PULL 265K ON 7', FREE RELEASE SPEAR, BACK OUT SAME. RIG UP TO L/D 7" LINER SCAB. PULL TUBING IN STANDS T/200'. L/D SCAB LINER, 7" NSCC 29# NT80S, 231 JTS. RD WELLHEAD CONNECTOR MW: 0.0 VIS: 0 PULL SINGLE COMPLETION, 3-1/2" OD. L/D TUBING T/O'. RAN DP IN STANDS T/6350'. P/U 9-5/8" EZSV, RIH SLOW T/6350' TESTED BRIDGE PLUG, VIA STRING. DROP BALL, PRESS UP TO 1000 PSI, SET CIBP, BLEED OFF TO 200 PSI, PULL UP RELEASE RUN TOOL. CBU AT 6350'. PULLED DP IN STANDS T/5800'. MONITOR WELL, OK, PULL 5 STDS PUMP DRY PILL. PULL DP IN STANDS T/O'. R/D WELLHEAD CONNECTOR. PULL WEAR RING, N BOP, TO CHANGE OUT 7' SPOOL, REPLACE PACK OFF IN 13-3/8" SPOOL. MILLING SECTION, 6116'-6132' MW: 0.0 VIS: 0 WELLHEAD WORK. INSTALL CASING SPOOL. NU BOP STACK. TEST BOP STACK. BHA 31, RIH T/6101'. POSITIONED KNIVES FOR CUTOUT. MILLED CASING FROM 6101' TO 6132' WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 2 09/08/95 (6) TD: 6150' ( 18) 09/09/95 (7) TD: 6383'( 233) 09/10/95 (8) TD: 7021' ( 638) INSTALL BOP TEST PLUG ASY MW: 0.0 VIS: 0 RUN BHA ~1. MILLED CASING F/6132' T/6150'. OK. CBU @ 6150', 100% HOLE VOLUME OBTAINED CLEAN RETURNS. PUMPED LOW VIS SWEEP. METAL RETURNS 70% FOR JOB. POOH T/687'. PULLED BHA. LD COLLARS. MILL 20% WORN WITH GOOD WEAR PATTERN. MU & RUN BHA #2. MU MULESHOE ON 4-1/2" DP. RIH T/6082'. AT 9-5/8" CASING SHOE. CBU @ 6250',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. WASHED THRU SECTION 6250 & CBU. KICKOFF PLUG. MIXED & PUMPED SLURRY, 30 BBL. DISPLACED SLURRY @ 15.4 BPM. RUN BHA #2. POOH T/5100', 700' ABOVE TOC FOR SQUEEZE. CBU @ 5100'. CLEARED DP,APPLIED 750 PSI SQUEEZE PRESSURE FOR 1 HOUR. NO CEMENT SQUEEZED AWAY. BROKE CIRC. POOH T/4' PULLED BHA. TEST WELL CONTROL EQUIP. JET WELLHEAD. OK. INSTALLED BOP TEST PLUG ASSY. PREPARE TO TEST BOPE. DRILLED T/6383 MW: 0.0 VIS: 0 TEST WELL CONTROL EQUIPMENT. WITNES WAIVED BY J. SPAULDING, AOGCC. BHA #3. FLO CHECKED MWD AND MOTOR, OK. RIH T/6020'. P/U KELLY AT 5875' AND WASHED DOWN LOOKING FOR TOC. TAGGED TOC AT 6020'. DRILLED CEMENT T/6105', KICKOFF DEPTH. CBU. DRILLED T/6150'. SIDETRACK COMPLETED. DRILLING NEW HOLE. REACHED DEPTH PRIOR TO SIDE-TRACK. DRILLED T/6383'. NO SURVEYS KEPT. DROP AND TURN IN PROGRESS. DRILLED T/7021' MW: 0.0 VIS: 0 BHA #3. DRILLED T/6758'. REACHED PLANNED END OF RUN. DIRECTIONAL OBJECTIVE MET. CBU. POOH T/6050'. NO EXCESS DRAG, HOLE FILL UP NORMAL. POOH T/839' BHA PULLED AND STOOD BACK. BHA 34. RIH T/6758'. OPEN HOLE CLEAN. DRILLED T/7021' WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 3 09/11/95 ( 9) TD: 8089'(1068) 09/12/95 (10) TD: 9002' ( 913) 09/13/95 (11) TD: 9291' ( 289) 09/14/95 (12) TD: 9826' ( 535) 09/15/95 (13) TD:10140' ( 314) DRILLED T/8089' MW: 0.0 VIS: 0 RUN BHA #4. DRILLED T/7212'. LOST 70 BBLS MUD TO FORMATION. FAST DRILLING (6 CONNECTIONS IN 1-1/2 HRS) . FLOWCHECK WELL. WELL FLOWING. MONITOR WELL PRESSURES. SHUT-IN WELL. OBSERVED PRESSURES: STRING-140 PSI, ANNULUS-30 PSI. BLEED DOWN WELL. BLED OFF PRESSURES (SMALL VOLUME) & MONITOR. SIDP & SICP STATIC @ 0 PSI. OPENED WELL & MONITORED,GAS CUT MUD AT SURFACE. CBU @ 7212',T0 CLEAR GAS CUT MUD. FLOWCHECK WELL. WELL FLOWING. SHUT IN WELL. MONITOR WELL PRESSURES: STRING-140 PSI, ANNULUS-50 PSI. CIRC CLOSED IN WELL @ 7212'. 3 BPM/690 PSI. LOST 50 BBLS OUT OF 85 BBLS PUMPED. RESTART PUMP @ 2 BPM/600 PSI. STILL LOSING FLUID. SHUT IN & OBSERVED WELL. SIDP 180 PSI, SICP 180 PSI. MONITOR WELL. SICP DECREASED T/160 PSI. BLEED DOWN WELL. BLED 5 BBLS MUD FROM WELL. SICP STABILIZED @ 70 PSI. BLED 1.5 BBLS MUD FROM WELL, SICP STABILIZED @ 20 PSI. CBU @ 7212',100% HOLE VOLUME OBTAINED CLEAN RETURNS. OPENED WELL & CIRC HOLE CLEAN· STAGED PUMPS UP TO DRILLING RATE (555 GPM) & MONITORED FOR LOSSES. NO LOSSES· RUN BHA #4. DRILLED T/8089' RESUMED DRILLING. INCREASED CIRC TIME @ CONNECTIONS TO HELP CLEAN HOLE. REAMING EACH CONNECTION. CBU AS NECESSARY TO KEEP ANNULUS CLEAN. 13-3/8" CASING IN UPPER HOLE LOADS UP DURING HIGH ROPS. POOH T/1000' MW: 0.0 VIS: 0 BHA #4. DRILLED T/8250'. STOPPED TO CBU. POOH T/6750'. RIH T/8250'. DRILLED T/9002'. REACHED PLANNED END OF RUN. CBU. POOH T/1000'. AT HWDP AT REPORT TIME. WILL P/U MR BUILD ASSEMBLY. DRILLING, BEGAN TURN AND BUILD MW: 0.0 VIS: 0 BHA ~4. POOH T/1000' PULLED AND LAID OUT BHA. BHA #5, FLOW CHECK MWD AND MOTOR. RIH T/9002'. FILLED PIPE AT 6170' · DRILLED T/9093'. PRESURE CHANGED FROM 3200 PSI TO 2800 PSI IN 1 HOUR. DOWNHOLE WASHOUT. MWD TURBINE INDICATED 15% LOSS IN FLOW. SURFACE EQUIPMENT CHECKED OUT. POOH T/6493' FOUND WASHOUT IN SLIP AREA ON STAND 26. REACHED STRING FAILURE POINT, LENGTH MISSING 0'. RIH T/9093'. DRILLED T/9291' - BEGAN TURN AND BUILD. BHA RESPONDING AT REQUIRED 10/100' CBU AT 9826' MW: 0.0 VIS: 0 BHA #5, DRILLED T/9826'. CONTINUED BUILD AND TURN. DLS SUFFICIENT. CBU AT 9826, PRIOR TO SCHEDULED WIPER TRIP. WORKING TIGHT HOLE AREA MW: 0.0 VIS: 0 BHA #5. CBU AT 9826'. POOH T/8886', RIH T/9826'. DRILLED T/10140' TD 8-1/2" HOLE SECTION, ON TARGET. CBU, POOH T/9735'. TIGHT AREA AT 9767' (TOP OF SHUBLIK), WORKING. WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 4 09/16/95 (14) TD:10140' ( 0) 09/17/95 (15) TD:10140 PB: 0 09/18/95 (16) TD:10140 PB: 0 09/19/95 (17) TD:10140 PB: 0 09/20/95 (18) TD:10140 PB: 0 REAMED T/9500' MW: 0.0 VIS: 0 BHA %5. POOH T/6100'. WORKED /HROUGH SAG RIVER (TOP AT 9658') AND INTO KINGAK TO 950C' WITH KELLY. PULLED F/9500' TO 6100' (CASING) WITH NO EXCESS DRAG. BHA #6. RIH T/9503', AT DOGLEG. REAMED T/10140'. CBU. POOH T/9500'. PULLED THROUGH SAG RIVER OK. PULLED /iGHT AT 9500' AT BEGINNING OF REAM SECTION. OBSERVED 75000 LBF OVERPULL. PUMPED OUT OF HOLE T/9410'. PUMPED OUT 3 SINGLES, NO EXCESS DRAG PAST FIRST SINGLE. REAMED T/9500' BEGAN RUNNING 7" LINER MW: 0.0 BHA #6. PICKED UP 7" CASING SHOE JOING WITH 7-5/8" ELEVATORS. JOINT SLID BACK DO;'~ PIPE SKATE AND BROKE FLOAT SHOE. ELEVATOR MARKING SHAD BEEN PAINTED OVER. REAMED T/9750'. HRZ SLOUGHING, WASHED AND REAMED ACROSS SAG AND TOP OF SHUBLIK. RIH T/10140' CBU. POOH T/9200', RIH T/10140'. BRIDGE OR LEDGE AT 9750'. PU KELLY, WORKED THROUGH W/PUMPS ONLY NO REAMING. CBU. POOH T/6000', AT 9-5/8" CASING SHOE. POOH T/673' PULLED AND LAID OUT BHA. DROPPED SHOE JOINT DOWN PIPE S?ATE. REPLACED FLOAT EQUIPMENT ON RIG FLOOR. BAKER-LOK'D SAME. TESTED FLOATS AND BEGAN RUNNING 7" LINER. TEST WELL CONTROL EQUIPMENT MW: 0.0 RAN CASING T/4222'. CIRC LINER VOLUME, BROKE CIRCULATION. RAN CASING IN STANDS TO 10140', SETTING DEPTH. ESTABLISHED CIRCULATION, BEGAN RECIPROCATING LINER. CONDITIONED HOLE. RU BJ AND BATCH MIXED CEMENT. SBU. PRESSURE TESTED LINES T/4500 PSI. COULD NOT RECIPROCATE FOLLOWING PT. PUMPED CEMENT. PLUG BUMPED. CBU AT 5918' SET LINER HANGER, PACKER, RELEASED RUNNING TOOL AND REVERSED OUT ON TOL, NO CEMENT (AS PLANNED), TRACE OF PREFLUSH. PULLED DP T/4710', LAID DOWN. TESTED WELL CONTROL EQUIPMENT. DRILLING MW: 0.0 TEST WELL CONTROL EQUIPMENT. WITNESS WAIVED BY L. GRIMALDI, AOGCC. TESTED CASING. BHA #7, PLOW CHECKED MOTOR AND MWD. RIH T/9984', TO TOP OF CEMENT AT 9984'. DRILLED CEMENT T/10138'. LC AT 10058' FC AT 10098', SHOE AT 10138' AY 7" CASING SHOE. DRILLED 1~' OF NEW HOLE T/10155'. CIRC ~T 10140'. CHANGED OVER TO FLOPRC. DRILLED T/10400' POOH TO LOG (DP CONVEYED) MW: 0.0 BHA #7, DRILLED T/il003'. CON~LETELY LOST CIRCULATION. CiRC, MIXED AND SPOTTED LCM PILL. GAINED RETURNS AFTER 10 BBLS OF PILL THROUGH BIT. BEGAN REPLACING VOLUME. POOH T/10100', 7" CASING SHOE, TO MONITOR WELL, LOSS RATE NIL. CBU AT 10100' BROKE CIRC AND STAGED UP PUMPS WHILE MONITORING LOSS RATE. RIH T/10979', STOPPED 24' OFF BOTTOM, AT LOSS ZONE. CBU, POOH T/3000' TO LOG (DP CONVEYED). WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 5 09/21/95 (19) TD:10140 PB: 0 09/22/95 (20) TD:ll003' ( 863) 09/23/95 (21) TD: 0 PB: 0 PULLED BHA MW: 0.0 BHA #7, POOH T/3000'. BHA STOOD BACK, L/D NON-MAG EQUIP, RETRIEVED RABBIT. BHA #8. DP CONVEYED LOGGING. RIH T/9250'. INSERTION OF SIDE-ENTRY SUB AT THIS POINT ALLOWS LOGGING TO -400' ABOVE SAG RIVER. LATCHED UP WIRELINE TO DRILL STRING. RIH T/10140', 7" CASING SHOE. LOGGED HOLE WITH LWD. FORMATION EVALUATION FROM 10140' TO 10994'. LOGGED WITH GRAND SLAM WHILE RIH FROM CASING SHOE. REPEAT PASS LOGGING BACK UP TO 9620' EVERYTHING GOING WELL EXCEPT THAT APPARENT PROCESSING ERROR FROM DENSITY TOOL GIVING A 10' GAP EVERY -65'. R/D LOGGING/BRAIDED CABLE EQUIPIMENT. SHEARED OFF LATCH AND POOH W/E-LINE. POOH T/5384'. PULLED BHA. MIX SLURRY F/KICKOFF PLUG MW: 0.0 VIS: 0 RUN BHA #8. PULLED BHA. DOWNLOAD SOURCE & LD LOGGING TOOLS. RD WESTERN ATLAS. RUN BHA #9. 6" HOLE OPENER RUN. RIH T/ 7500'. OK. RIH T/10133' @ CASING SHOE. WASHED T/10170' SINGLED IN DP T/10980'. ON BOTTOM. CBU @ 10980', 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/10141' @ 7" CASING SHOE. SERVICE BLOCK LINE. LINE SLIPPED. POOH T/5270'. PULLED BHA. LD 4 HWDP & 6" HOLE OPENER. RUN BHA #10. CEMENT MULESHOE ON 3-1/2" DP. RIH T/8000'. RIH T/10980'. ON BOTTOM. CBU @ 10980', HOLE 100% DISPL WITH WATER BASED MUD. RU CEMENT UNIT. MOVE VAC TRUCKS, SPOT BJ CEMENT UNITS & TOOK ON WATER. BATCH MIX 41 BBL SLURRY CEMENT KICKOFF PLUG. PREPARE TO ADANDON THIS HORIZONTAL SECTION & PREPARE FOR RE-DRILL (GEOLOGICAL SIDETRACK). TESTING BOP STACK MW: 0.0 BATCH MIXED CEMENT SLURRY. TESTED HIGH PRESSURE INES. PUMPED SPACERS. PUMPED SLURRY. DISPLACED SLURRY. ESTIMATED TOC AT 9950'. BHA #10, POOH T/9100', CIRC. HOLE DISPLACED WITH WATER BASED MUD. L/D DP T/1280'. POOH T/5270'. PULLED AND LAID OUT BHA. BHA #11, RIH T/9925'. OBSERVED RESISTANCE. TAGGED CEMENT STRINGER, P/U KELLY. REAMED T/9990', TOP OF CEMENT. BEGAN DRILLING FIRM CEMENT T/10135', AT 7" CASING SHOE, CIRC. HOLE SWEPT WITH SLUG, HI-VIS SWEEP. POOH T/2350', TOP OF LINER, CBU. BHA PULLED AND STOOD BACK. TEST WELL CONTROL EQUIPMENT. WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 6 09/24/95 (22) TD: 0 PB: 0 09/25/95 (23) TD: 0 PB: 0 BHA #13 MADE UP MW: 0.0 TESTED BOP STACK, TEST WITNESS WAIVED BY BOBBY FOSTER, AOGCC. BHA #12, TESTED MWD. RIH T/6000', LOGGED HOLE WITH LWD: DIR/FE FROM 6000' TO 6100'. GEOLOGIST REQUESTED MAD PASS FOR GR TIE-IN IMPROVEMENT. RIH T/10135' FILLED PIPE AT 7500 AND RESET SPERRY SUN DEPTH COUNTER. DRILLED CEMENT T/10149'. TIME DRILLED T/10149' JUDGED ?0 BE OFF OF CEMENT PLUG AT THAT POINT, GOOD FORMATION RETU.RNS AND TOOL INDICATIONS CONFIRMING. AT KICKOFF DEPTH, 10149'. DRILLED T/10342', DISPLACED WELL TO FLOPRO WHILE DRILLING AT 10211'. MWD/LWD FAILED, CIRCULATE. CONTINUED ATTEMPTS TO RESTORE HIGH-SPEED DATA TRANSMISSION. WOULD WORK INTERMITTENTLY, BUT WOULD HAVE HAD TO RESTRICT ROP TO GIVE COMPLETE LOGS, PLUS UNACCEPTABLE LAG TIM~S FOR TOOL FACE SETS. TOOL FINALLY QUIT. HOLE CIRCULATED WELL AND CLEANED UP WHILE ATTEMPTING TO RESTORE DATA TRAKSMISSION. POOH T/5467'. BHA PULLED AND STOOD BACK. BIT IN GAUGE AT GAUGE PROTECTION AREA, 1/16 OF GAUGE MISSING ON HEEL ROW. BHA #13 MADE UP. PULLED BHA MW: 0.0 BHA #13, RIH T/10342', ON BOTTOM. FUNCTIONED DOWNHOLE TOOLS. INADVERTENTLY TOGGLED MWD TOOL TO 'SLOW' MODE WHILE TAKING SPR'S, FINALLY GOT IT TOGGLED BACK TO HIGH-SPEED DATA MODE. DRILLED T/10902'. TURNING LEFT IN HORIZONTAL SECQTION WITH 11 DEGREES DOGLEGS AFTER PASSING BOTTLENECK IN TARGET POLYGON AT 10600'. BUILD RATE UNACCEPTABLE. INFORMED AT MIDNIGHT THAT NEW TVD TARGEU WAS TO BE 8804' INSTEAD OF 8791'. MUST POOH AND RE-DIAL MOTOR MOTOR TO 2 DEG IN ORDER TO ACHIEVE THAT TVD. (DOGLEGS WILL BE 16 INSTEAD OF 11). CBU AT 10900', R/D KELLY, PUMP SLUG AND STAND BACK KELLY. POOH T/5600'. MONITORED WELL FOR FLOW BEFORE POOH, STABLE. PULLED BHA. WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 7 09/26/95 (24) TD:l1058' ( 55) 09/27/95 (25) TD:11372' ( 314) 09/28/95 (26) TD:11372 PB: 0 09/29/95 (27) TD:11372 PB: 0 ROTATE AHEAD TO FINAL DEPTH MW: 0.0 VIS: 0 BHA #13 STOOD BACK, DOWNLOADED MWD TOOL. BHA #14, RIH T/10900', ON BOTTOM. GOOD TRIP GOING IN HOLE, NO RESISTANCE. DRILLED T/10963'. DRILLED INTO APPARENT FAULT. SPOTTED LCM PILL BEFORE LOC WAS ARRESTED. CIRC, POOH T/10140', 7" CASING SHOE. REST HOLE AT 10141', BUILT VOLUME BACK UP, MIX ANOTHER LCM PILL. RIH T/10963' ON BOTTOM. , DRILLED T/10994', BEGAN LOSING RETURNS AFTER DRILLING APPROX 3-1/2". DRILLED A SINGLE DOWN IN ORDER TO GET THROUGH FAULT AND OBSERVE FULL EFFECT. SPOTTED 40 BBLS BAROSEAL FINE. POOH T/10141', BUILT VOLUME BACK UP ALSO RECEIVED USED FLO-PRO FORM RIG 9. LOSSES SLOWED. R~H T/10994', ON BOTTOM. DRILLED T/11058' DECISION WAS MADE TO DRILL AHEAD IN ATTEMPT TO PLACE LWD TOOLS BELOW FAULT TO SEE SAND QUALITY. LOGS SHOWED RESISTIVITY JUMPING BACK UP IMMEDIATELY TO SHOW GOOD OIL SAND AFTER FAULT AREA. CIRC AT 11058', LCM PILL SPOTTED DOWNHOLE. POOH T/10141'. BUILT BOLUME BACK UP, CHANGED SHAKER SCREENS TO COARSER SCREENS AND DISCUSSED OPTIONS WITH WELLSITE GEOLOGIST, DIRECTIONAL AND MUD ENGINEERS. DECIDED TO ROTATE AHEAD TO FINAL DEPTH THAT CAN BE REACHED WITH THIS AMOUNT OF 3-1/2" IN DRILL STRING. (APPROX. 11375') POOH T/10141 MW: 0.0 VIS: 0 BHA #14, DRILLED T/11372'. REACHED PLANNED END OF RUN, SECTION / WELL TD. TOOK MWD SURVEY AT 11313' POOH T/10952', CIRC. POOH T/10141', 7" CASING SHOE, CIRC. POOH T/5600' PULL BHA. BHA #15, RIH T/11372', ON BOTTOM. CIRC, LCM PILL SPOTTED DOWNHOLE. POOH T/10141'. P/U DP WHILE RUNNING LINER MW: 0.0 BHA #15, POOH T/10141', 7" CASING SHOE. REST HOLE, RIH T/11372', ON BOTTOM. CIRC, POOH T/10141', CBU. POOH T/200'. BHA LAID OUT. RAN CASING T/1300'. ECP AND HES ES CEMENTER INSTALLED TO BE AT 10846' AND 10804', RESPECTIVELY. POOH W/ 4-1/2" RUNNING STRING MW: 0.0 RD CASING HANDLING EQUIPMENT, CIRC VOLUME OF LINER WHILE RD TONGS. RIH W/ 3-1/2" CASING T/9635'. WASHED T/9777'. RAN CASING T/10140', 7" CASING SHOE. CBU. RAN CASING T/11372', SETTING DEPTH. CIRC, BATCH MIXED CEMENT SLURRY, PUMPED. RELEASED BOTTOM PLUG. DISPLACED, PLUG BUMPED. SET PACKER AT 10849'. CIRC, BATCH MIXED AND PUMPED CEMMENT SLURRY. RELEASED TOP PLUG. DISPLACED, PLUG BUMPED. SET PACKER AT 10012'. CBU. PULL LANDING STRING. L/D HWDP T/4500' WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 8 09/30/95 (28) TD:11372' ( 0) 10/01/95 (29) TD:11372' ( 0) 10/02/95 (30) TD:11372' ( 0) 10/03/95 (31) TD:11372' ( 0) POOH T/9000' MW: 0.0 VIS: 0 PULL DP. RUN BHA #16. RIH T/7000' RIH T/10012' TO TOP OF LINER. CBU @ 10012'. TEST DOWNHOLE EQUIP VIA ANNULUS & STRING, OBSERVE LEAK. CBU @ 10021' TEST DOWNHOLE EQUIP, OBSERVE LEAK. POOH T/5600'_ SERVICE BLOCK LINE. PULLED BHA. RUN BHA #17. RIH T/10012' @ TOP OF LINER. TEST DOWNHOLE EQUIP. CONFIRMED LINER LAP LEAK. POOH T/9000' SLOWLY TO AVOID PULLING RUBBERS OFF OF RTTS. MONITOR WELL. TEST SUB SURFACE EQUIP MW: 0.0 VIS: 0 RUN BHA #17. POOH T/0' PULLED BHA. RUN BHA #18. RIH T/3500' RIH T/10012' @ TOP OF LINER MILLED PBR POLISH @ · , 10012'. COMPLETE DRESSING TIE BACK BACK PACKER. CBU @ 10012'. POOH T/20'. PULLED BHA. RUN BHA #19. RIH T/10012' @ TOP OF LINER. SET TIE BACK PACKER @ 10000' & TEST, OBSERVED LEAK. SERVICE BLOCK LINE, SLIPPED & CUT. POOH T/10'. PULLED BHA. TEST SUB-SURFACE EQUIP VIA ANNULUS. CLOSE BLIND RAMS TO PRESSURE WELLBORE UP THRU KILL LINE TO WELL. WILL REMOVE KILL LINE & ISOLATE ALL LINES TO WELL EXCEPT FOR GAUGE MONITORING LINE. RIH WITH BHA #21 MW: 0.0 VIS: 0 TEST WELL CONTROL EQUIP. RUN BHA #20. RIH T/4000'. RIH T/10000' @ TOP OF LINER. FUNCTIONED DOWNHOLE TOOLS. TEST TIE BACK PACKER VIA STRING. PRESSURE TEST COMPLETE. OK. TEST CASING VIA ANNULUS. OK. FUNCTIONED DOWNHOLE TOOLS F/9980' T/10000' SEVERAL TIMES, WITH CASING & TIE BACK PACKER TESTING THROUGHOUT-OBSERVED LEAK. CONT FUNCTIONED DOWNHOLE TOOLS @ 9974' WITH MORE PRESSURE TESTS ON CASING & TIE BACK PACKER, OBSERVED LEAK. LEAK SIGNATURE IMPROVED FROM EARLIER EFFORTS. FUNCTIONED DOWNHOLE TOOLS @ 10000', TEST CASING & TIE BACK PACKER. TEST ENTIRE WELLBORE. POOH T/8000' . PUMP PILL & MONITOR. POOH. @ BHA. BREAK DOWN BHA. RIH WITH BHA #21. MU & RUN BHA #22 MW: 0.0 VIS: 0 RUN BHA #21. RIH T/8000'. RIH T/10024'. DRILLED CEMENT T/10060'. RIH T/10080'. DRILLED CEMENT T/10111'. RIH T/10805', @ TOC. DRILLED CEMENT T/10808' TAGGED DV COLLAR. RIH T/11329', ON BOTTOM. CBU @ 11319'· TEST CASING VIA ANNULUS & STRING. REVERSE CIRC @ 11319'· POOH T/10200'. POOH T/6000', PIPE WAS PULLING WET-MIXED SALT PILL @ BHA. PULLED BHA. MU & RUN BHA #22. PJSM, HANGLING PERFORATION GUNS. WELL : H-01A OPERATION: RIG : NABORS 2ES PAGE: 9 10/04/95 (32) TD:11372' ( 0) 10/05/95 (33) TD:11372 PB: 0 10/06/95 (34) TD:11372 PB: 0 10/07/95 (35) TD:11392 PB: 0 PULLED BHA MW: 0.0 VIS: 0 MU & RUN BHA #22. RU TO PU PERF GUNS. PU HES CHAMP PACKER & FAS FILL VALVE. RIH T/6500'. RIH T/9182'. WELLHEAD WORK, REMOVE & INSTALL WELLHEAD INTEGRAL COMPENENTS. RUN BHA #22. RIH T/11323', @ BOTTOM PERF. SET RETRIEVABLE PACKER @ 9456'. RU HIGH PRESSURE LINES. FUNCTIONED DOWNHOLE TOOLS @ 10150'. REV CIRC @ 9456'. LD DP T/5900'. SERVICE BLOCK LINES. LD DP T/3500'. LD DP T/2000', @ BHA. PULLED BHA. LD PERF GUNS IN SINGLES. TEST DUAL CONTROL LINES MW: 0.0 RUN BHA #22. PULLED BHA. ALL GUNS FIRED, LD WESTERN ATLAS TOOLS. TEST BOP STACK. RUN 4-1/2" TUBING T/9463'. TEST DUAL CONTROL LINE FREEZE PROTECT WELL MW: 0.0 TESTED DUAL CONTROL LINE. CIRC AT 9459', PUMP CORROSION INHIBITOR DOWN BACKSIDE, DEPTH OF WLEG CORRECTED T/9459'. 4' CORRECTION. SET PACKER AT 9459' RD BOP STACK. TESTED SCSSSV CONTROL LINE. SHEARED OUT RP VALVE AT 1700# AND FREEZE PROTECT WELL AND U-TUBE SAME. RELEASED @ 0800 HRS,10/06 MW: 0.0 RUN 4-1/2" SINGLE COMPLETION. CBU @ 2200'. RD CIRC HEAD, SECURE TREE & CELLAR, SET BPV, CLEAN MUD TANKS. RIG RELEASED @ 0800 HRS., 10/06/95. SIGNATURE: (drilling superintendent) DATE: SPER -SUN DRILLING SERVICES SIiARED SERVICES DRILLING PBU/ti-01A 500292009901 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/10/95 ANCHORAGE ALASKA PAGE DATE OF SURVEY: 092795 MWD SURVEY JOB NUMBER: AK-MM-950946 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTIC/kL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGUL~ COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10128 8734.88 8658.81 10182 8739.33 8663.26 10213 8740.68 8664.61 10245 8741.78 8665.71 10275 8742.96 8666.89 83 41 86 58 88 3 87 58 87 34 S 77.10 E .00 3015.55S 1349.95E 1743.29 S 81.99 E 10.72 3025.45S 1403.65E 1797.83 S 84.75 E 9.52 3029.04S 1434.53E 1828.91 S 87.55 E 8.82 3031.17S 1466.17E 1860.56 S 87.54 E 1.32 3032.46S 1496.33E 1890.62 10308 8744.02 8667.95 10340 8744.16 8668.08 10371 8743.57 8667.50 10403 8742.91 8666.84 10435 8742.37 8666.30 88 40 90 51 91 15 91 8 90 48 S 85.57 E 6.93 3034.42S 1528.79E S 85.24 E 6.95 3036.97S 1560.53E S 83.82 E 4.67 3039.98S 1591.99E S 83.63 E .71 3043.45S 1623.48E S 83.26 E 1.60 3047.03S 1654.72E 1923.04 1954.84 1986.42 2018.09 2049.53 10465 8741.97 8665.90 10497 8741.63 8665.56 10527 8741.40 8665.33 10558 8741.29 8665.22 10589 8741.34 8665.27 90 42 90 31 90 20 90 3 89 45 S 84.26 E 3.27 3050.37S 1685.23E S 83.96 E 1.11 3053.65S 1717.04E S 83.08 E 3.03 3056.99S 1746.46E S 83.37 E 1.28 3060.71S 1777.77E S 82.99 E 1.58 3064.40S 1808.64E 2080.20 2112.17 2141.77 2173.29 2204.38 10621 8741.54 8665.47 10652 8741.88 8665.81 10683 8742.38 8666.31 10715 8743.01 8666.94 10746 8743.70 8667.63 89 32 89 11 88 58 88 44 88 44 S 83.01 E .68 3068.22S 1839.69E S 82.47 E 2.06 3072.13S 1870.37E S 82.47 E .70 3076.28S 1901.78E S 82.95 E 1.70 3080.27S 1933.02E S 85.55 E 8.24 3083.43S 1964.38E 2235.66 2266.59 2298.28 2329.77 2361.27 10777 8744.09 8668.02 10809 8744.00 8667.93 10840 8743.47 8667.40 10872 8742.65 8666.58 10902 8742.36 8666.29 89 49 90 31 91 25 91 28 89 39 S 88.57 E 10.34 N 89.44 E 6.76 N 86.09 E 11.06 N 82.30 E 11.71 N 79.31 E 11.90 3085.02S 1995.36E 2392.18 3085.26S 2026.57E 2423.14 3084.04S 2057.89E 2454.01 3080.77S 2090.06E 2485.45 3076.07S 2119.09E 2513.58 10934 8743.31 8667.24 10966 8746.02 8669.95 10998 8749.81 8673.74 11030 8753.70 8677.63 11062 8757.59 8681.52 86 54 83 28 83 1 82 55 82 55 N 77.10 E 11.08 N 75.62 E 11.55 N 75.14 E 2.05 N 75.88 E 2.32 N 73.59 E 7.20 3069.55S 2150.31E 2543.64 3061.97S 2181.53E 2573.56 3053.88S 2212.55E 2603.21 3045.98S 2243.14E 2632.45 3037.73S 2273.35E 2661.28 11092 8761.55 8685.48 11123 8765.94 8689.87 11155 8770.82 8694.75 11219 8781.49 8705.42 11250 8786.96 8710.89 82 13 81 29 80 58 79 38 80 14 N 74.82 E 4.58 N 73.87 E 3.86 N 73.51 E 1.97 N 73.67 E 2.11 N 74.99 E 4.58 3029.45S 2302.65E 2689.20 3021.17S 2332.19E 2717.36 3012.30S 2362o50E 2746.20 2994.64S 2422.45E 2803.23 2986.32S 2452.11E 2831.50 SPER. -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU/H-01A 500292009901 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/10/95 DATE OF SURVEY: 092795 MWD SURVEY JOB NUMBER: AK-MM-950946 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11282 8791.45 8715.38 83 26 N 77.44 E 12.70 11312 8794.89 8718.82 83 39 N 78.12 E 2.31 2978.86S 2482.55E 2860.66 2972.40S 2512.35E 2889.32 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3891.93 FEET AT SOUTH 40 DEG. 12 MIN. EAST AT MD = 11312 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 97.73 DEG. SPER.._-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/H-01A 500292009901 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/10/95 DATE OF SURVEY: 092795 JOB NUMBER: AK-MM-950946 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10128 8734.88 8658.81 3015.55 S 1349.95 E 1393.12 11128 8766.57 8690.50 3020.00 S 2336.22 E 2361.43 968.31 11312 8794.89 8718.82 2972.40 S 2512.35 E 2517.87 156.44 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEP~_.-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/H-01A 500292009901 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/10/95 DATE OF SURVEY: 092795 JOB NUMBER: AK-MM-950946 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10128 8734.88 11188 8776.07 11228 8783.09 8658.81 3015.55 S 1349.95 E 1393.12 8700.00 3002.98 S 2393.99 E 2412.90 1019.78 8707.02 2992.18 S 2430.84 E 2444.91 32.01 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ,, , SPEk ' SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 MWD SURVEY JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 6100 5336.35 5260.28 6106 5340.85 5264.78 6127 5356.95 5280.88 6158 5381.28 5305.21 6188 5405.25 5329.18 42 0 40 51 39 0 37 35 36 17 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST S 10.00 E .00 1922.84S 720.17E S 10.60 E 20.12 1926.75S 720.88E S 9.97 E 9.06 1940.01S 723.29E S 9.00 E 4.91 1958.95S 726.46E S 8.00 E 4.77 1976.79S 729.12E VERT. SECT. 972.26 973.49 977.66 983.34 988.39 6220 5431.25 5355.18 6252 5457.65 5381.58 6282 5482.73 5406.66 6314 5509.77 5433.70 6344 5535.45 5459.38 35 0 33 47 32 47 31 47 30 30 S 6.87 E 4.55 1995.28S 731.54E S 5.65 E 4.32 2013.25S 733.51E S 4.43 E 4.01 2029.65S 734.96E S 3.02 E 3.91 2046.71S 736.08E S 1.60 E 4.98 2062.22S 736.71E 993.27 997.64 1001.28 1004.68 1007.39 6376 5563.17 5487.10 6408 5591.21 5515.14 6439 5618.77 5542.70 6471 5647.61 5571.54 6503 5676.74 5600.67 29 23 28 12 26 17 25 0 23 53 S 2.10 E 3.53 2078.18S 737.22E S 2.30 E 3.76 2093.59S 737.81E S 2.80 E 6.17 2107.77S 738.44E S 3.20 E 4.10 2121.60S 739.16E S 3.40 E 3.45 2134.82S 739.93E 1010.05 1012.70 1015.24 1017.81 1020.35 6532 5703.35 5627.29 22 53 6564 5732.96 5656.89 21 42 6595 5761.88 5685.81 20 30 6626 5791.00 5714.93 19 36 6657 5820.32 5744.25 18 17 S 1.90 E 4.01 2146.32S 740.46E S 2.00 E 3.75 2158.46S 740.87E S 1.80 E 3.88 2169.61S 741.24E S 1.20 E 2.98 2180.24S 741.52E S 1.60 E 4.21 2190.30S 741.77E 1022.42 1024.47 1026.33 1028.04 1029.63 6689 5850.86 5774.79 6764 5923.02 5846.95 6888 6043.11 5967.04 6982 6134.52 6058.45 7076 6226.03 6149.96 16 23 15 11 13 36 13 23 13 0 S .00 E 6.12 2199.84S 741.91E S 1.00 W 1.64 2220.26S 741.74E S 2.10 W 1.31 2251.08S 740.92E S 6.00 W .99 2272.96S 739.38E S 7.50 W .56 2294.27S 736.86E 1031.06 1033.63 1036.97 1038.38 1038.75 7169 6316.72 6240.65 7262 6407.62 6331.55 7359 6502.62 6426.55 7452 6593.87 6517.80 7545 6685.11 6609.04 12 36 11 48 11 30 10 46 11 30 S 9.30 W .61 2314.65S 733.85E S 9.90 W .87 2334.03S 730.58E S 12.10 W .55 2353.25S 726.85E S 12.70 W .78 2370.80S 722.99E S 15.20 W .93 2388.23S 718.65E 1038.52 1037.88 1036.77 1035.31 1033.35 7640 6778.25 6702.18 7733 6869.51 6793.44 7827 6961.91 6885.84 7890 7023.92 6947.85 7984 7116.44 7040.37 11 11 11 0 10 11 10 6 10 18 S 13.10 W .54 2406.36S 714.07E S 12.30 W .27 2423.82S 710.14E S 15.80 W 1.09 2440.59S 705.96E S 15.80 W .16 2451.28S 702.94E S 14.10 W .38 2467.36S 698.65E 1031.25 1029.70 1027.82 1026.26 1024.17 / · SPER_ _-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 MWD SURVEY JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8080 7210.99 7134.92 8174 7303.77 7227.70 8268 7396.65 7320.58 8363 7490.55 7414.48 8457 7583.53 7507.46 9 36 8 53 8 48 8 36 8 18 S 15.00 W .75 2483.42S 694.48E 1022.20 S 15.70 W .75 2497.99S 690.49E 1020.20 S 17.20 W .-27 2511.85S 686.39E 1018.01 S 19.70 W .45 2525.48S 681.85E 1015.34 S 16.10 W .65 2538.62S 677.60E 1012.90 8552 7677.57 7601.50 8647 7771.67 7695.60 8741 7864.79 7788.72 8834 7956.94 7880.87 8929 8051.14 7975.07 8 0 7 48 7 54 7 35 7 18 S 18.40 W .47 2551.48S 673.61E 1010.68 S 18.80 W .22 2563.86S 669.45E 1008.22 S 18.80 W .11 2576.01S 665.31E 1005.75 S 20.20 W .38 2587.83S 661.13E 1003.20 S 19.80 W .32 2599.41S 656.91E 1000.58 8986 8107.70 8031.63 9017 8138.42 8062.35 9048 8169.04 8092.97 9080 8200.51 8124.44 9111 8230.86 8154.79 6 54 8 23 9 48 11 0 12 26 S 17.50 W .86 2606.08S 654.66E 999.24 S 2.90 W 7.88 2610.12S 653.98E 999.11 S 15.10 E 10.18 2614.93S 654.56E 1000.33 S 24.80 E 6.62 2620.33S 656.55E 1003.03 S 34.10 E 7.65 2625.78S 659.66E 1006.84 9143 8262.03 8185.96 13 41 9174 8291.94 8215.87 16 47 9205 8321.33 8245.26 20 12 9237 8350.95 8274.88 24 12 9269 8379.62 8303.55 28 30 9299 8405.40 8329.33 9331 8431.56 8355.49 9362 8455.50 8379.43 9394 8478.77 8402.70 9425 8499.71 8423.64 33 0 37 17 41 30 45 12 49 47 S 42.90 E 7.35 2631.41S 664.17E 1012.07 S 50.00 E 11.66 2636.98S 670.10E 1018.70 S 51.90 E 11.14 2643.16S 677.75E 1027.11 S 52.40 E 12.51 2650.57S 687.30E 1037.57 S 53.70 E 13.56 2659.10S 698.65E 1049.96 S 54.80 E 15.12 2668.05S 711.10E 1063.51 S 54.90 E 13.44 2678.65S 726.16E 1079.86 S 54.60 E 13.56 2690.01S 742.23E 1097.30 S 54.60 E 11.56 2702.73S 760.13E 1116.75 S 54.10 E 14.89 2716.05S 778.69E 1136.94 9457 8519.56 8443.49 9489 8537.75 8461.68 9520 8553.81 8477.74 9552 8568.71 8492.64 9583 8581.19 8505.12 53 30 57 12 60 24 64 5 68 24 S 52.60 E 12.13 2731.04S 798.82E 1158.90 S 52.10 E 11.63 2747.12S 819.66E 1181.71 S 51.40 E 10.50 2763.53S 840.47E 1204.55 S 49.30 E 12.94 2781.60S 862.27E 1228.57 S 50.10 E 14.07 2799.95S 883.91E 1252.48 9615 8592.84 8516.77 9646 8603.90 8527.83 9678 8615.29 8539.22 9709 8626.58 8550.51 9741 8638.31 8562.24 68 54 69 18 69 0 68 18 68 41 50.10 E 1.56 2819.07S 906.77E 1277.71 49.60 E 1.98 2837.74S 928.91E 1302.15 52.00 E 7.07 2856.64S 952.07E 1327.65 55.30 E 10.17 2873.75S 975.32E 1352.99 58.80 E 10.25 2889.94S 1000.30E 1379.92 SPERm. s-SUN DRILLING SERVICES Ai~CHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/9 DATE OF SURVEY: 091995 MWD SURVEY JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT· 9772 8649.47 8573.40 9804 8660.75 8584.68 9835 8671.43 8595.36 9866 8681.61 8605.54 9897 8690.46 8614.39 69 5 69 35 70 5 71 35 75 11 S 59.90 E 3.55 S 61.60 E 5.21 S 64.70 E 9.53 S 68.40 E 12.27 S 70.80 E 13.78 2904.68S 1025 2919.31S 1051 2932.45S 1077 2944.10S 1104 2954.45S 1131 .18E .31E .27E .13E · 97E 1406.56 1434.41 1461.91 1490·09 1519.07 9929 8697.93 8621.86 9959 8704.22 8628.15 9991 8710.65 8634.58 10023 8717.04 8640.96 10054 8723.14 8647.07 77 48 S 71.80 E 8.67 78 0 S 71.30 E 1.76 78 48 S 73.10 E 6.05 78 11 S 76.00 E 9.08 79 5 S 76.80 E 3.85 2964.42S 1161 2973.70S 1189 2983.28S 1219 2991.64S 1249 2998.78S 1278 .44E .27E · liE .33E .87E 1549.61 1578.44 1609.30 1640.36 1670.60 10076 8727.24 8651.17 10095 8730.48 8654.41 10128 8734.88 8658.81 10159 8737.99 8661.92 10190 8740.77 8664.70 79 24 S 76.40 E 2.25 80 57 S 76.68 E 8.34 83 41 S 77.14 E 8.42 84 48 S 77.57 E 3.81 84 54 S 78.00 E 1.42 3003.79S 1299 3008.15S 1318 3015.55S 1349 3022.31S 1380 3028.84S 1410 · 89E .10E · 95E .04E .22E 1692.11 1710.73 1743.29 1774.02 1804.80 10222 8743.64 8667.57 10253 8746.43 8670.36 10285 8749.24 8673.17 10315 8751.75 8675.68 10346 8754.29 8678.22 84 48 S 77.50 E 1.59 84 54 S 77.20 E 1.02 85 0 S 77.60 E 1.28 85 24 S 78.20 E 2.40 85 11 S 77.80 E 1.44 3035.60S 1441 3042.36S 1471 3049.32S 1502 3055.58S 1531 3062.01S 1562 .37E .49E .60E .83E .05E 1836.57 1867.33 1899.09 1928.90 1959.71 10377 8756.91 8680.84 10408 8759.54 8683.46 10439 8762.08 8686.00 10470 8764.62 8688.54 10502 8767.26 8691.19 85 5 S 78.30 E 1.64 85 11 S 78.90 E 1.95 85 24 S 78.70 E .91 85 11 S 79.00 E 1.16 85 18 S 79.30 E .99 3068.40S 1592 3074.51S 1622 3080.51S 1652 3086.48S 1683 3092.48S 1714 .27E · 55E .85E · 17E .49E 1990.51 2021.34 2052.18 2083.02 2114.86 10533 8769.80 8693.73 10564 8772.34 8696.27 10596 8774.99 8698.92 10627 8777.59 8701.52 10658 8780.18 8704.11 85 18 S 79.10 E .64 85 18 S 79.80 E 2.25 85 11 S 79.90 E .44 85 11 S 80.10 E .64 85 11 S 80.00 E .33 3098.27S 1744 3103.93S 1775 3109.55S 1806 3114.92S 1837 3120.25S 1867 · 84E · 21E .60E .02E .45E 2145.71 2176.57 2208.43 2239.30 2270.17 10689 8782.86 8706.79 10720 8785.64 8709.57 10752 8788.54 8712.47 10783 8791.35 8715.28 10815 8794.17 8718.09 84 54 S 80.00 E .97 84 48 S 79.20 E 2.59 84 48 S 79.20 E .06 84 48 S 78.50 E 2.25 85 5 S 79.10 E 2.09 3125.62S 1897. 3131.19S 1928. 3137.16S 1959. 3143.13S 1989. 3149.32S 2021. 86E 2301.03 23E 2331.87 53E 2363.69 82E 2394.51 09E 2426.32 SPER~z-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 MWD SURVEY JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10846 8796.73 8720.66 85 24 S 79.60 E 1.88 10878 8799.33 8723.26 85 18 S 79.60 E .31 10909 8801.87 8725.80 85 18 S 79.00 E 1.93 10940 8804.43 8728.36 85 11 S 78.40 E 1.96 11003 8809.71 8733.63 85 11 S 78.10 E .47 3155.03S 2051.45E 2457.18 3160.79S 2082.82E 2489.04 3166.52S 2113.18E 2519.89 3172.58S 2143.47E 2550.72 3185.36S 2204.94E 2613.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3874.05 FEET AT SOUTH 34 DEG. 41 MIN. EAST AT MD = 11003 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 97.73 DEG. TIED INTO SPERRY-SUN GYRO SURVEY PERFORMED 6/21/71 AT 6100' SPER.~-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SH3tRED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6100 5336.35 5260.28 7100 6249.42 6173.35 8100 7230.71 7154.64 9100 8220.12 8144.05 10100 8731.25 8655.18 1922.84 S 720.17 E 2299.62 S 736.15 E 2486.64 S 693.62 E 2623.81 S 658.33 E 3009.28 S 1322.91 E 763.65 850.58 86.93 869.29 18.71 879.88 10.59 1368.75 488.87 11003 8809.71 8733.63 3185.36 S 2204.94 E 2193.29 824.54 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER,~f-S~IN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/H-01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLOP~ATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6100 5336.35 5260.28 6151 5376.07 5300.00 6274 5476.07 5400.00 6390 5576.07 5500.00 1922.84 S 720.17 E 1954.96 S 725.81 E 2025.34 S 734.60 E 2085.34 S 737.49 E 763.65 775.34 11.69 797.99 22.65 814.68 16.70 6502 5676.07 5600.00 6610 5776.07 5700.00 6715 5876.07 5800.00 6818 5976.07 5900.00 6921 6076.07 6000.00 2134.52 S 739.91 E 2174.83 S 741.39 E 2207.26 S 741.91 E 2234.67 S 741.49 E 2259.04 S 740.62 E 826.19 11.51 834.05 7.86 839.21 5.16 842.90 3.69 845.84 2.94 7024 6176.07 6100.00 7127 6276.07 6200.00 7229 6376.07 6300.00 7331 6476.07 6400.00 7433 6576.07 6500.00 2282.78 S 2305.67 S 2327.54 S 2347.97 S 2367.50 S 738.33 E 848.64 2.81 735.31 E 851.27 2.63 731.71 E 853.70 2.43 727.98 E 855.84 2.14 723.74 E 857.81 1.98 7535 6676.07 6600.00 7637 6776.07 6700.00 7739 6876.07 6800.00 7841 6976.07 6900.00 7942 7076.07 7000.00 2386.46 S 2405.94 S 2425.07 S 2443.05 S 2460.24 S 719.13 E 859.70 1.89 714.17 E 861.70 2.00 709.87 E 863.61 1.90 705.27 E 865.32 1.71 700.43 E 866.90 1.58 8044 7176.07 7100.00 8145 7276.07 7200.00 8247 7376.07 7300.00 8348 7476.07 7400.00 8449 7576.07 7500.00 2477.71 S 2493.81 S 2508.81 S 2523.42 S 2537.57 S 696.01 E 868.52 1.61 691.66 E 869.90 1.38 687.34 E 871.11 1.21 682.59 E 872.28 1.17 677.90 E 873.39 1.11 8550 7676.07 7600.00 8651 7776.07 7700.00 8752 7876.07 7800.00 8853 7976.07 7900.00 8954 8076.07 8000.00 2551.28 S 2564.43 S 2577.49 S 2590.23 S 2602.40 S 673.68 E 874.41 1.02 669.25 E 875.37 .96 664.81 E 876.32 .95 660.25 E 877.23 .91 655.84 E 878.06 .83 9055 8176.07 8100.00 9157 8276.07 8200.00 9265 8376.07 8300.00 9390 8476.07 8400.00 9569 8576.07 8500.00 2616.10 S 2633.97 S 2658.02 S 2701.26 S 2792.19 S 654.89 E 879.07 1.00 666.75 E 881.43 2.37 697.21 E 888.95 7.51 758.05 E 914.22 25.27 874.71 E 993.85 79.63 9848 8676.07 8600.00 2937.81 S 1089.29 E 1172.89 179.04 SPER~.~-SUN DRILLING SERVICES ANCHOR. AGE ALASKA PAGE 7 SHARED SERVICES DRILLING PBU/H- 01APB1 500292009970 North Slope Borough COMPUTATION DATE: 10/ 2/95 DATE OF SURVEY: 091995 JOB NUMBER: AK-MW-50080 KELLY BUSHING ELEV. = 76.07 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10608 8776.07 8700.00 11003 8809.71 8733.63 3111.78 S 1819.21 E 1832.79 659.90 3185.36 S 2204.94 E 2193.29 360.51 THE CkLCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Date: RE: 4 October 1995 Transmittal of Data ECC #: 6484.00 Sent by: HAND CARRY Data: OH-LDWG Reference: BP H-01A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Received by: ~ / Please sign and return to: Attn. Rodney D. Paulson Atlas Wire!ine Services 5600 B Street Suite 201 Anchorage, AK 99518 Or F~ to (907) ~63,7803 ~.~., ~/ _ //'~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 27 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1DIFL/GR FINAL BL+RF 1ZDL/CN/GR FINL BL+RF 1CN/GR FINAL BL+RF 1 AC/GR FINAL BL+RF 1BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF Run # 1 Run # 1 Run # 1 Run #. 1 Run # 1 Run # 1 ECC No. 6484.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 ? Anchorage, AK 99518 ?~~ Or ~X to (907) 563-7803/] RECEIVED Date: Alaska 0il & Gas C,a~',5. A~]chorage MEMORANDUM TO: THRU: David Johns,~ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE' September 14, 1995 Blair Wondzell, ~ P. I. Supervisor ~J/'~¢ ¢~)~ FROM: Lou Grimaldi, ~ SUBJECT: Petroleum Inspector FILE NO: QIMJINCD.DOC RIG/BOPE inspection Nabors Rig ¢2ES BPX well CH-01A Prudhoe Bay Field PTD ¢95-110 Thursday, September 14,1995: I made a Rig/BOPE inspection on Nabors rig ¢2ES which was working over BPX well CH-01A in the Prudhoe Bay Field. I found the rig to be in very good shape which is normal for this rig. The area surrounding the rig was neat and orderly providing good access. This rig is scheduled to drill a grass roots well next and Robert French (Nabors Tooipusher) and I discussed Diverter requirements for the upcoming program. SUMMARY: I made a Rig/BOPE inspection on Nabors rig ¢2ES and found all equipment to be in compliance. Attachments: QIMJINCD.XLS cc: Scott Sigurdsen/Tom Horten (Prudhoe Bay Drilling) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling Workover X Cmpl. UIC Well Name: H-01A Nabors Rig No. 2ES Rep. BPX Rep. Gene Beck Section 21 T. 11N R. 13E M. U DATE: 9/14/95 PTD# 95-110 Robert French Rig Ph.# 659-4835 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT 16 ~Working pressure 17 IFluid level 18 JOperating pressure 19 lPressure gauges 2_~.JSufficient valves 21 lRegulator bypass 22 14-way valves (actuators) 23 lBlind rams handle cover 24 ~Driller control panel 25 JRemote control panel 26 ~Firewall 27 lNitrogen power source (backup) 28 lCondition (leaks, hoses, ect.) REMARKS: IN COMPLIANCE IN PLIANCE INSPECTION ITEMS (C.) MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) Hydraulic choke panel Choke manifold INSPECTION ITEMS (E.) MISC. EQUIPMENT Flare/vent line All turns targeted i(downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping Rig in good shape IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK 9/11/95 None Kill Sheet Current? Yes Distribution: orig - Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: F1-022 (Rev. 3/93) Louis R Grimaldi Gene Beck QIMJINCD.XLS / ALAS~ OIL AND GAS CONSERVATION COM~VHSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 27, 1995 Terry Jordan Drilling Engineering Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519--6612 Re: Prudhoe Bay Unit H-01A BP Exploration (Alaska), Inc. Permit No. 95-110 Sur. Loc. 4107'NSL, 1266'WEL, Sec. 21, TllN, R13E, UM Btmnhole Loc° 1026'NSL, 4246'WEL, Sec. 22, TllN, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redri!l does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conductiag drilling operations until all other required permitting determinations are made. Blowout preven%ion 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 new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. i DavidkW. John Chairm~ OF~~ BY ORDER dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E'lllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration 63.82 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 28284 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 4107' NSL, 1266' WEL, SEC 21, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1166' NSL, 5275' WEL, SEC 22, T11N, R 13E H-O lA (14-22-11-13) 2S 100302630-277 At total depth 9. Approximate spud date Amount 1026' NSL, 4246' WEL, SEC 22, T11N, R13E 08/05/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28287/1026 feet No close approach feet 2560 11030/8780 feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8~00 feet Maximum hole angle 84.5 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 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) 8.5" 7" 29# L-80 NSCC 3550 5950 5265 9500 8484 29# 13 Cr NSCC 372 9500 8484 9872 8660 300 sx Class 'G' 6" 4.5" 12.6# 13 Cr NSCT 1330 9700 8599 11030 8780 147 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ~ Present well condition summary Total depth: measured 11100 feet Plugs (measured) Jr..iL ,,~ true vertical 9178 feet Effective depth- measured 11038 feet Junk (measured) fi#at 1084~\~4~ & Gas Cons. C9.rnmission true vertical 9128 feet /~P, ch0,':. ' Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 81' 30" 300 sx 100' 100 Surface 2352' 18-5/8" 4400 sx 2371' 2371 I nte rm e d iate 10074' ~8 ~ 9-~/~. 3800 sx 10093' 8413 Production Liner 1521' 7" 400 sx 9559' - 11080' 8038' - 9162' Perforation depth: measured 10700'- 10760'/10845'- 10875' true vertical 8862'- 8909'/8975'- 8999' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] !Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce.,rtify/y t,I)at~the? ,, ~Jf~eg°ing is true and correct to the best of my knowledge _~,/ /) Signed '///,,~/~/ /~'~/-~,,{.~:--. Title Drillin9 En~ineerin9 Supervisor Date' ~.- f '; · -~ ~.,. , x.~/ Commission Use Only Permit Number APl number Approva! date ~ See cover letter ~,_.,~../,//~ 5 O- ~.2_.,~ - ~_. ¢JO ~ - c3 / I -///~).~ ~ //? ~-- for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M; 1-13M; ~5M; 1-110M; []15M; Other: Urlg~nal Si~tloo [::f~ by order of Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in tril:licate I WellName: [DS H-01A Redrill Plan Summary Type of Redrill (producer or injector): ] Shut In Producer Surface Location: 4107' FSL, 1266' FEL, S21, T11N, R13E, UM Target Location: 1166' FSL, 5275' FEL, S22, T1 iN, R13E, UM Bottom Hole Location: 1026' FSL, 4246' FEL, S22, Ti 1N, R13E, UM I AFENumber: 14P0709.0 I I Rig: I Nabors 2ES I Estimated Start Date: I Aug. 5, 1995 I I Operating days to complete: 1 21 IMD: I 11,030 I ITVD: I8,780'SS I IOKBE: I Well Design (conventional, sHmhole, etc.): I High Angle Sidetrack 163.82 I I I I Objective: ]The objective of the proposed plan is to establish long-term, profitable, I Zone 4 production from this well. Mud Program: A 10.0 - 10.20 ppg Biozan polymer / KC1 water based mud will be used. ISpecial design considerations I none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.0 10 15 5 10 10 0 5 to to to to to to to to to Target 10.2 18 30 15 29 5 0 8 Flow Pro will be used in horizontal section from 9987' MD - 11030' MD I~odz. I 9.0 I ~0 I 50 I 23 I 29 I 7-8 I 0 I 0 I Directional: I KOP: ] 6100' MD Maximum Hole Angle: Close Approach Well: 84.5 degrees Target to TD none H-01A Redrill Plan Summary Page 1 Station Alaska Zone - 4 MD TVDss Incln Surface X = 643320.19, Y = 5959615.26 0' 75.49' ASL 0 Tie-In X = 643995.84, Y = 5958162.87 5517' 4868' 42.75 Top Window X = 644072.89, Y = 5957783.08 6095' 5297' 41.41 KOP Curve 6/100 X = 644073.57, Y = 5957779.84 6100' 5301' 41.40 EOC X = 644098.20, Y = 5957569.68 6553' 5697' 15.31 Curve 8/100 X = 644028.56, Y = 5956946.12 8929' 7989' 15.31 Target/EOC X = 644654.00, Y = 5956700.00 9987' 8680' 84.50 TD X = 645685.00, Y = 5956580.00 11030' 8780' 84.50 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVDss MDfrVDss 8.5" 7" liner 29# L-80 NSCC 3550 5950/5265 9500/8484 29# 13 Cr NSCC 372 9500/8484 9872/8660 6 4.5" liner 12.6# 13 Cr NSCT 1330 9700/8599 11030/8780 N/A 4.5" tbg 12.6# 13 Cr NSCT 9750 Surface 9750/8504 Cement Calculations: I Liner Size: 17'' drilling liner Basis:150% open hole excess, 80' shoe joint, 1000' MD above the Sag River. Total Cement Volume: I 3001 sxs of Class G Blend @ 1.17 ft3/sx I Liner Size: 1 4.5" production liner I Basis:I 50% open hole excess, 80' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Volume: I 1471 sxs of Class G Blend @ 1.17 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. H-0 lA Redrill Plan Summary Page 2 Hazards and Contingency Plans: · Current production from the H-01 well contains 24 ppm H2S. · Should the 13 3/8 / 9 5/8" casings fail integrity test then 7" liner will be tied back. · For Kick Tolerance See enclosed calculation sheet. · Sag River Sand is in communication with Sadlerochit. At 8550' TVDss and BHP of 3010 psi it is equal of 6.77 ppg. PROCEDURE: * Refer to Recommended practice for 9-5/8" Redrill-Sidetrack Version 3.2 Rig-Work: 1. Move in drilling rig. 2. Pull BPV. Circulate out freeze protection cap from inner and outer annuli and recover for future use. 3. Install a TWC and test from below to 1000 psi. ND the production tree. , N/U BOP's. Test BOP's to 250 / 5000 psi against TWC. Test annular to 250 /2500 psi. Remove the test plug. Pressure test the 13.3/8" / 9.5/8" casing to 2500 psi/30 min. (Potential 7" tieback dependent upon this test.) . Pull and lay down the 3-1/2" tubing. Inspect for NORM. (If 13 3/8 / 9 5/8" casing failed pressure test then set a 7" storm packer.) Remove the tubing spool from the stack, run test plug and test seals to 250 / 5000 psi. Remove test plug. (If it was run, pull storm packer). 6. M/U 7", 29# casing spear. RIH and engage 7' casing. Pull and lay down the 7" scab liner and 3 1/2" tail pipe. . PU a 9 5/8" EZSV on 4 1/2" DP. RIH and set 200' below the base of the planned section. Sting out. Roll hole to milling fluid & spot 18 ppg mud up to the base of the proposed 9.5/8" section. POOH. 8. P/U Section Mill on 4.1/2" DP & RIH. Cut window 6095-6145' MD. POOH. 9. RIH open ended to 6295' MD and spot a kick-off plug fro_m..l~)0~.below the base of the section to - 200' above the top of th~si~nI ~:~IU! 2 stands, H-01A Redrill Plan Summary &!~s[,~' . ,~ 0ii_ & Gas Coaso 6orp. missioa Page 3 10. shut in and perform hesitation squeeze. Attempt to achieve a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. Run in with an 8-1/2" steerable assembly (MWD - directional) and dress the cement to 5' below the section top. Circulate hole clean. Kickoff and directionally drill to the target at 8680' TVDss. See attatched directional plan. 11. Make a conditioning trip with a 8 1/2" hole-opener for the open hole section with a 9 5/8" casing scraper spaced to clean the casing. If hole conditions allow consider omitting this step ( this is rig supervisors call ). Rabbit the drill string. 12. Run a 7" 29#, 13 Cr / NT-80, NSCC liner with 9 5/8 x 7" packer / hanger to bottom in the 8-1/2" hole and space out for about 150' of lap. The 13 Cr casing should extend from TD to 400' above the Sag River and allow for the tail pipe above the Sag River. Refer to Standard recommended practices for liner running procedure. Reciprocrate liner 20-30' during circulation and cementaiton. 13. Cement the liner in place with the total cement volume based upon 30% open-hole enlargement plus the 80' shoe volume, (TOC 1000 ft MD above the Sag River which in this case means about 300 sks but this number must be reconfirmed after the hole is drilled ). Set liner hanger / packer with 4200 psi. Reverse out clean. (If the 13 3/8 / 9 5/8" casings failed the pressure test, tie back the 7" liner, hang off in the casing spool, nipple up the tubing spool.) 14. Re-test BOP's as needed. 15. Run in with 6'_' steerable drilling assembly (LWD - GR / four phase resistivity / directional) on 4-1/2" x 3-1/2" drillpipe (only 3 1/2", if liner tied back). Clean out to landing collar. Test casing to 2500 psi (3500 psi, if liner tied back) for 15 min. Drill out of shoe joints plus 10' new hole. Displace hole to FLO-PRO system 16. Drill approximately 1043' of 6" hole horizontally to TD of 11030' MD. See attatched directional plan. 17. Make a conditioning trip with a 6" hole-opener for the open hole section with a 7" casing scraper spaced to clean the liner. Obtain (GR/SP/DIL/BHC/NEU) logs via DP assist.. ( This is the call that will be made by the drilling supervisor on the rig ) 18. Install a 4-1/2", 12.6#, 13 Cr, NSCT liner with 4-1/2" X 7"- 13 Cr packer / hanger to bottom in the 6" hole and space out for about 150' of lap. Reciprocate liner 20-30' during circulation and cementaion. 19. Cement the liner in place with the total cement volume of 140 sks ( based up°n 30°/° °pen'h°le enlargement )plus the 80' sh°e v°lume'~') i~,¢~150' I¢~~me i'~, L ~ L, H-01A Redrill Plan Summary ,~IjiL. 20 19°r':; "'- Page 4 Gas Cons. Gommissi0F~ ,¢,ri:;hfj,',~ :, 20. 21. and 150' excess on top of the liner with drillpipe in the hole. Set liner hanger / packer with 4200 psi. Reverse out clean. P/U 3 7/8" bit on 2 7/8" PAC stinger. RIH and clean out 4 1/2" liner to landing collar. Circulate hole clean. Pressure test the liner lap to 2500 psi (3500 psi, if 7" liner tied back) / 30 min. Roll the hole with filtered seawater. POOH. M/U 2 3/4" drill pipe conveyed perforating guns with 10.5 gram charges, 4 spf, 60 / 120 phasing and RIH on 2 7/8", 3 1/2", and 4 1/2" drill string. Include tools as follows: Absolute pressure firing head Perforating guns & blanks, as per enclosed production specs. Firing Head Adapter Primary Firing Head ( Annulus Pressure) x/o 2-3/8 EUE to 2-7/8 PAC DP 2-7/8" PAC 6.4# L-80 tubing ( approx. 12 joints ) x/o and Below Packer Safety Joint Bypass Port 7" Champ Packer ( To be set @ xxx' MD / xxx' TVD ) XO- 2-7/8" PAC X 4-1/2" IF Jars PR FAS-FIL Valve to be set at @ xxx' MD / xxx' TVD to achieve xxx psi underbalance. 4- 1/2" DP to surface Note: Once logs have been analyzed and the perforation intervals are known the packer depth, fluid height for underbalance, and clean up period will be determined. Detailed perforating procedure will be sent to the rig as soon as above values are known. Note: Refer to Standard Completion Running Procedure as well as Proposed completion diagram for more details. 22. Run the 4-1/2" / 3-1/2", 13 Cr, NSCT completion assembly spaced out to place end of tail pipe above the Sag River. Tubing detail as follows: · 3 1/2" WLEG · 31 · 31 · 31 · 31 · 31 · 31 · 31 · 31 · 31 · 31 · 31 2II /2" /2" /2" /2" /2" 9.2#, 13 Cr, NSCT 10 ft pup joint 13 Cr, Otis "X" Nipple (2.750" ID) 9.2#, 13 Cr, NSCT 10 ft pup joint 9.2#, 13 Cr, NSCT 10 ft pup joint 13 Cr, Otis "X" Nipple (2.750" ID) 9.2#, 13 Cr, NSCT 20 ft pup joint 9.2#, 13 Cr, NSCT 10 ft pup joint /2" X 7" Baker SABL-3 Packer /2", 9.2#, 13 Cr, NSCT 10 ft pup joint /2", 9.2#, 13 Cr, NSCT tubing joint /2", 9.2#, 13 Cr, NSCT 10 ft pup joint RE E VEL H-01A Redrill Plan Summary .... ,-., .. ~ Page5 23. 24. 25. 26. 27. 28. 29. 3 1/2", 13 Cr, Otis "X" Nipple (2.750" ID) 3 1/2", 9.2#, 13 Cr, NSCT 10 ft pup joint 3 1/2", 9.2# x 4 1/2", 12.6#, 13 Cr, NSCT cross-over 4 1/2", 12.6#, 13 Cr, NSCT tubing with GLM's GLM's @ 8385, 8000, 7400, 6500, 5250, & 3400 ft TVD 4 1/2", 13 Cr, OTIS WL Retrievable SCSSSV @ 2,200' MD 4 1/2", 12.6#, 13 Cr, NSCT tubing to surface 4 1/2" tubing hanger Space out, test the SCSSSV and circulate with corrosion inhibitor prior to setting packer. Drop the packer setting ball. Pressure the tubing to 4000 psi and set the packer. Close the SCSSSV, install a TWC, and test to 1000 psi. Remove BOP's. Install and test the production tree to 5000 psi. Pull the TWC valve. While holding the 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. Open the SCSSSV and shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed off pressure and freeze protect with diesel to 2200' MD. Set a BPV. Close the SCSSSV and secure the well. Release rig. Complete appropriate documentation and hand-over to Production. H-01A Redrill Plan Summary Page 6 ANADRILL ANCHORAGEE " 'SHARED-S" RVI ES BRILLI, NG,,.,, i i I III H-O 1A. 2) VE~T ICAL..SE'CT.I!DN VIEW Section at: 97.73 ...:~..'..'. TVD Scale,' 1 inch -.l~O0..,f. ee.t~., -' Oep Scale' ~ inch -1200';feet = - - ....... /Inadr i ] /, , A) TIE-IN 55~.7 4043 839 42.75 B) TOP OF WINgOI~ ~095. 5373 g60' 41.4t' C) KOP/CURVE 6/JO0 8100 5376 9Gt 41.40 --- ..- - D) END 6/t00 CURVE 6553~' 5772 lOOg t5.31 E! CURVE 8/i00 8929 8064 1012 15.3t FI ....... TARGET ....... 9987 .'8755 S662 -84.50 Gl END B/tO0 CURVE 9987 8753 1662 84.50 ~ ' ' ' H) TO 11030 "81355 2700 84.50 , : · % \ _ __ , % : .. ~'.. '.., ;~ , . · .._,_. _ '___ _. ·. ,,*,.:..' .: :'.~' .;.' ..,.. · ~: . . t ; · ..' ,'.,...' :...',..' i , . · ii m 0 : ....'""' ':""' · , : . 0 GO0 i200 1800 8400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Departure __ ...- ~N~DRILL ~NCHOR~GEE · SHARED SERV ICES ,iDR I, LL i:NG ---____ - .......... -1 B) TOP ~ WINDOW 6095 ~"~ "~~ PLAN VIEW ENO 6/t00 CURVE 6553 2060 739 ....... ~ - ' ' ~ CURVE e/tO0 a~9 ~6.~ 6~, CLOSURE ..... ' 3848 fee'[ Fl ....... TARGET ....... 9987 2940 t~78 G) E~ e/too cu:qv[ 9907 ~94o ~, DECLINATION.' 29.405. E H) TO $$030 30BO E307 SCALE. ' t inch =.8~ 'feet DRAWN, · 05/08/95 ~nadr~]] Schlumberger 400- 800--- ~ - ~000 ......... aO0O ..... ~ , . aOO 0 100 gOO ~00 ~[00 ~000 2400 ~gO0 3800 ~00 STATE OF ALASKA ALA4_~.J.A OIL AND GAS CONSERVATION COMMISSIon4 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ~ Operation Shutdown Re-enter suspended well __ Alter casing ~ Repair well Plugging X Time extension __ Stimulate __ Change approved program __ Pull tubing ~ Variance __ Perforate __ Other X __ Plugback for Redrill 1173'SNL, 1266' WEL, SEC. 21, T11N, R13E At top of productive interval 696' SNL, 556' WEL, SEC. 28, T11N, R13E At effective depth 889' SNL, 653' WEL, SEC. 28, T11N, R13E At total depth 919' SNL, 669' WEL, SEC. 28, T11N, R13E 2. Name of Operator 5. Type of Well: BP Exploration Development x Exploratory __ 3. Address Stratigraphic __ 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ 4. Location of well at surface 8. 9. 10. 12. Present well condition summary Total depth: measured true vedical 11100 feet 9178 feet 11038 9128 et Plugs Effective depth: measured true vertical Casing Length Cemented Structural 6. Datum elevation (DF or KB) KBE = 63.82 Unit or Properly name Prudhoe Bay Unit Conductor 81' Surface ~ 2352' Intermediate / - 10074' 9-5/8" Production ~ .,4/, Liner ~ 152/~' 7" Perforation deptt~ measured 071 10760'/108;5'-10175' ~ 8862' - 8909'/8975 - 8999 Well number H-1 (31-28-11-13) Permit number 71-15 APl number 50- 029-20099 11. Field/Pool Prudhoe Ba , Field/Oil Pool fill at 10842~/94) Measured dept~ True vertical depth 300 sx 100' \ 100' 4400 sx 2371', ~ 2371' 3800 sx 10093' ~ 8413' 400sx 9559~11080' 8038~9162' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 tubing to 10503' MD Packers and SSSV (type and measured depth) Baker "FB-1' Packer @ 10503' MD; Otis, 3-1/2" "FMX" SSSV @ 2117' MD feet 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 07/16/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Jeff . · ~'. Title Drilling Engineering Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- IApproval No. Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATr IWELL PERMIT CHECKLIST GEOL AREA ~?(~) UNIT# PROGRAM: exp [] dev [] redrll~ serv [] ll do o oFF ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING Y Y .Y .Y Y Y Y .Y .Y Y .Y APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. DA~E [ /26. 2~. Conductor string provided ................ Y N Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg.. Y N CMT vol adequate to tie-in long string to surf csg . . . Y N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. Y~ N Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... D tilling fluid program schematic & equip list adequate . Y~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~ Choke manifold complies w/API RP-53 (M~y 84) ...... Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ ~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~ N - 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: . Comments/Instructions: -IOW/~o - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 6646.00 F. O'NEILL G. BECK H-01A 500292009901 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 29 -JUL- 96 MWD RUN 3 F. O'NEILL G. BECK MWD RUN 4 R. FRENCH G. BECK MWD RUN 5 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: R. FRENCH S. WALLS WELL CASING RECORD MWD RUN 6 R. FRENCH S. WALLS MWD RUN 7 R. FRENCH S. WALLS 21 liN 13E 1173 1266 76.07 74.67 44.75 RECEIVED AUG 0 6 1996 Alaska 0il & Gas Cons. Commiss~ An~om~e OPEN HOLE CASING DRI T..T.V..~.q BIT SIZE (IN) SIZE13.375(IN, DEP;:~'~t~23§t~,(:~ ~ ~' 0 F ILg[D 9.625 5940.0 .ooo o, o.o .ooo I I ' 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL H-01A WAS KICKED-OFF FROM H-01A PB1 AFTER PLUGGING H-01A PB1 BACK TO THE LINER SET AT 10140' MD. WELL H-01A IS REPRESENTED BY RUNS 1-7. RUN 1 IS DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUNS 2-4 ARE DIRECTIONAL WITH GAMMA RAY (SGRD). GAMMA RAY (SGRD) IS ONLY USED FROM RUN 4 OVER AN INTERVAL FROM 10081' TO 10140' MD. RUNS 5-7 ARE DIRECTIONAL WITH GAMMA RAY (SGRC) AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). GAMMA RAY DATA FROM 6678' TO 10140' MD IS ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTORS, AND IS NOTED AS NGP/SGRD DATA. GAMMA RAY DATA FROM 10140' TO 11332' MD IS ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS, AND IS NOTED AS DGR/SGRC DATA. WELL H-01A IS DRILLED TO TD AT 11372' MD. THE H-01A PB1 WELLBORE SECTION HAS BEEN DEPTH SHIFTED, SINCE A WIRELINE WAS RUN BEFORE WELL WAS PLUGGED BACK. WELL H-01A IS NOT DEPTH SHIFTED. THERE IS NO WIRELINE DATA FOR THIS WELLBORE SECTION, AS PER A CONVERSATION BETWEEN ALI TURKER AT SPERRY-SUN DRILLING SERVICES AND JIM WELCH AT BP EXPLORATION (ALASKA) INC. 'FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. START DEPTH 6678.0 10136.0 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 11332.0 11339.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6758.0 9001.5 3~ 9001.5 10081.5 5 10140.0 10341.0 6 10341.0 10903.0 -7 10903.0 11372.0 MERGED MAIN PASS. THE GR FROM RUN 4 WAS USED FROM 10081.5 - 10140. BASELINE DEPTH $ MERGED DATA SOURCE- PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1 OHMM RPD MWD 68 1 OHMM FET MWD 68 1 HR ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 120 46 1 4 4 90 180 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 303 998 BYTES * Tape File Start Depth = 11373.000000 Tape File End Depth = 6678.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 75129 datums Tape Subfile: 2 411 records... Minimum record length: 62 bytes Maximum record length: 998 bytes ~Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6678.0 $ 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: STOP DEPTH 8924.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 12-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 9001.5 6758.0 9001.5 0 7.3 15.2 TOOL NUMBER NGP 168 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 5940.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL / POLYMER 9.90 70.0 10.0 32000 60.0 .000 .0 .000 137.4 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 REMARKS: MWD RUN 2. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 56 Tape File Start Depth = 9005.000000 Tape File End Depth = 6678.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13966 datums Tape Subfile: 3 119 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8910.0 $ 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: STOP DEPTH 10081.0 15-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 10140.0 9001.5 10140.0 0 8.4 79.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 5940.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL / POLYMER 9.80 55.0 9.3 34000 5.5 .000 .0 .000 150.1 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 3. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 30 Tape File Start Depth = 10145.000000 Tape File End Depth = 8900.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82603 datums Tape Subfile: 4 93 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10003.0 $ 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: STOP DEPTH 10948.0 ~TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 19-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 11003.0 10140.0 11003.0 0 84.8 85.4 TOOL NUMBER NGP 39 6.000 10140.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 60.0 8.2 37000 6.0 .000 .000 .000 .000 .0 141.6 .0 .0 NEUTRON TOOL MATRIX'. MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 REMARKS: MWD RUN 4. DUE TO S~SOR DISTANCE, GAMMA RAY FROM RUN #4 DEPTH INTERVAL 10081.5' TO 10140' MD IS USED TO TIE-IN H-O1A TO H-01A PB1. NO ROP CURVE IS PRESENTED. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAP I 4 4 90 310 01 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 15 Tape File Start Depth = 10950.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17769 datums Tape Subfile: 5 83 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10100.0 EWR4 10106.0 $ 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: MAXIM UMANGLE: STOP DEPTH 10301.0 10308.0 24-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 10341.0 10140.0 10341.0 0 87.0 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PO412SP4 PO412SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 10140.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.10 58.0 10.3 45000 6.0 .250 .000 .150 .380 72.0 186.9 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 5. $ : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE~ 0) 998 BYTES * Total Data Records: 17 Tape File Start Depth = 10350.000000 Tape File End Depth = 10095.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86692 datums Tape Subfile: 6 82 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10286.0 EWR4 10293.0 $ 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: STOP DEPTH 10863.0 10870.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 25-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 10903.0 10341.0 10903.0 0 88.7 91.5 TOOL NUMBER PO412 SP4 PO412 SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 10140.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.10 56.0 9.5 48000 6.0 .270 .000 · 180 .420 70.0 183.6 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 ~EMARKS: CN WN FN COUN STAT MWD RUN 6. $ : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RP S MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 41 998 BYTES * Tape File Start Depth = 10910.000000 Tape File End Depth = 10280.000000 Tape FilemLevel spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27858 datums Tape Subfile: 7 106 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10851.0 EWR4 10858.0 $ 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: STOP DEPTH 11332.0 11339.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 26-SEP-95 MSC 1.32 / ISC 2.02 NGP 5.74 / SP4 5.01 MEMORY 11372.0 10903.0 11372.0 0 79.6 77.1 TOOL NUMBER PO412SP4 PO412SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 10140.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.90 50.0 7.0 39000 6.5 .240 .000 .170 .380 68.0 195.0 70.0 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 RPX MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RPM MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 FET MWD 68 1 HR 7 ROP MWD 68 1 FPHR 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) Total Data Records: 34 998 BYTES * Tape File Start Depth = 11373.000000 Tape File End Depth = 10850.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 95069 datums Tape Subfile: 8 99 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 9 is type:-LIS 96/ 7/30 01 **** REEL TRAILER **** 96/ 7/30 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 30 JLY 96 3:25p Elapsed execution time = 9.34 seconds. SYSTEM RETURN CODE = 0 -~Dfile 2 is type: LIS · £APE HEADER PRUDHOE BAY UNIT MWD / MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MWD RUN 2 6647.00 F. O'NEILL G. BECK OPEN HOLE BIT SIZE (IN) 8.500 6.000 H-01A PB1 500292009970 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 29 -JUL-96 MWD RUN 3 F. O'NEILL G. BECK MWD RUN 4 R. FRENCH G. BECK 21 liN 13E 1173 1266 76.07 74.67 44.75 RE. CEIVED AUG 0 6 ]996 Alaska Oil & Gas Cons. C mi on CASING DRI i. %s 13.375 9.625 5940.0 7.000 10140.0 I--I MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL H-01A PB1 WAS KICKED-OFF THROUGH A WINDOW CUT IN THE 9 5/8" CASING FROM 6101' TO 6151' MD. WELL H-01A PB1 IS REPRESENTED BY RUNS 1-4. RUN 1 IS DIRECTIONAL ONLY AND NO DATA IS PRESENTED. RUNS 2-4 ARE DIRECTIONAL WITH GAMMA RAY (SGRD). ALL GAMMA RAY DATA IS ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTORS, AND IS NOTED AS NGP/SGRD TYPE DATA. WELL H-01A PB1 WAS DRILLED TO TD AT 11003' MD BEFORE BEING PLUGGED BACK TO 10140' MD AND ABANDONED. DATA FOR WELL H-01A PB1 HAS BEEN DEPTH SHIFTED, SINCE A WIRELINE WAS RUN BEFORE WELL WAS PLUGGED BACK. WELL H-01A IS NOT DEPTH SHIFTED. THERE IS NO WIRELINE DATA FOR THIS WELLBORE SECTION, AS PER A CONVERSATION BETWEEN ALI TURKER AT SPERRY-SUN DRILLING SERVICES AND JIM WELCH AT BP EXPLORATION (ALASKA) INC. ~ 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 GR 6676.0 10950.0 $ BASELINE CURVE FOR SHIFTS: GR (WALS, OPEN HOLE, 25-SEP-95) CURVE SHIFT DATA (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH GR 6676.0 6678.0 10140.5 10142.5 10143.5 10144.5 10178.5 10179.0 10183.0 10182.0 10225.0 10225.0 10262.0 10263.0 10315.5 10314.5 10362.0 10360.5 10389.5 10390.0 10437.0 10437.5 10663.5 10662.0 10670.0 10669.5 10740.5 10739.5 10749.0 10747.0 10756.0 10756.5 10762.0 10760.5 10782.0 10781.0 10804.0 10802.5 10852.5 10850.5 11005.0 11003.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 6758.0 9001.5 3 9001.5 10140.0 4 10140.0 11003.0 MERGED MAIN PASS. ROP WAS SHIFTED WITH GR. CN WN FN COUN STAT / ??SHIFT. OUT $ : BP EXPLORATION (ALASKA) : H-01A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 104 1014 BYTES * Tape File Start Depth = 11005.000000 Tape File End Depth = 6676.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 25978 datums Tape Subfile: 2 218 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~ Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6678.0 $ 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: STOP DEPTH 8924.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12-SEP-95 MSC 1.32 DEP 2.041 / NGP 5.74 MEMORY 9001.5 6758.0 9001.5 0 7.3 15.2 TOOL NUMBER NGP 168 8.500 5940.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL / POLYMER 9.90 70.0 10.0 32000 60.0 .000 .0 .000 137.4 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: 56 1014 BYTES * API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 Tape File Start Depth = 9005.000000 Tape File End Depth = 6676.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13978 datums Tape Subfile: 3 119 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~ Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8910.0 $ 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: STOP DEPTH 10081.0 15-SEP-95 MSC 1.32 DEP 2.041 / NGP 5.74 MEMORY 10140.0 9001.5 10140.0 0 8.4 79.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 5940.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL / POLYMER 9.80 55.0 9.3 34000 5.5 .000 .0 .000 150.1 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 3. CN WN FN COUN STAT * FORMAT RECORD BP EXPLORATION (ALASKA) H-01A PB1 PRUDHOE BAY NORTH SLOPE ALASKA (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: 30 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 1014 BYTES * Tape File Start Depth = 10145.000000 Tape File End Depth = 8905.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 33422 datums Tape Subfile: 4 93 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes .Fe Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10003.0 $ 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: STOP DEPTH 10949.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 19-SEP-95 MSC 1.32 DEP 2.041 / NGP 5.74 MEMORY 11003.0 10140.0 11003.0 0 84.8 85.4 TOOL NUMBER NGP 39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 10140.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 9.00 60.0 8.2 37000 6.0 .000 .000 .000 .000 .0 141.6 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 4. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : H-01A PB1 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 24 Tape File Start Depth = 11005.000000 Tape File End Depth = 10000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20012 datums Tape Subfile: 5 87 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~e Subfile 6 is type: .LIS 96/ 7/29 01 **** REEL TRAILER **** 96/ 7/30 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 30 JLY 96 3:33p Elapsed execution time = 5.55 seconds. SYSTEM RETURN CODE = 0 H - 0lA qj-~ PRUDHOE BAY ¢~: -~ ' FILMED Run 1' 20 - September - 1995 DIFL/AC/ZDL/CNIGR Pipe Conveyed 9630 0984 WESTERN ATLAS Logging Services Tape Subfile 2 is type: biS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6484.00 BRAD ESARY BECK/STEARNS H - 0la 500292009901 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 03-OCT-95 RUN 2 RUN 3 21 liN 13E 1173 1266 76.07 .00 46.47 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10140.0 11003.0 1ST STRING 2ND STRING 3RD STRING 7.000 PRODUCTION STRING 6.000 REMARKS: DIFL/AC/CN/ZDL/GR. CIRCULATION STOPPED @ 02:00, 20-SEP-95. LOGGED PIPE CONVEYED. LOG TIED IN THE FIELD TO MWD LOG AT TD. PER CLIENTS REQUEST, ATTEMPTED TO DEPTH SHIFT TO MWD GR BUT WAS ONLY ABLE TO FIND 2 CORRELATABLE POINTS. BOTH POINTS HAD ZERO DEPTH OFFSET SO NO DEPTH SHIFT TO MWD WAS DONE. BOTTOM 24' OF OPEN HOLE HAS LCM. CHLORIDES = 37000. AC CYCLE SKIPS: 10175-10191, 10430-10452, 10729-10737, 10755, 10796-10812, 10827-10838 AND AT TD ON REPEAT SECTION. CALIPER VERIFICATIONS PERFORMED IN CASING. SOFTWARE ERROR ON OPEN HOLE REPEAT PASS CAUSED ZDEN SPIKES. PER CLIENT'S REQUEST, BOREHOLE & TORNn~O CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, * OPEN HOLE CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, * CASED HOLE BOREHOLE CORRECTION = 8.5", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS ACTIVE CEMENT THICKNESS = 0.750" CASING THICKNESS = 0.408" SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL SDN 2435 $ BASELINE CURVE SHI depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 10142.0 10891.0 10142.0 10955.0 10142.0 10984.0 10142.0 10914.0 10142.0 10896.0 CURVE FOR SHIFTS: GR FT DATA (MEASURED DEPTH) 10264.0 10425.5 BASELINE DEPTH LL8 10178.5 10182.5 10183.0 10187.0 10211.0 10214.5 10225.5 10229.5 10260.0 10261.0 10263.5 10264.0 10276.5 10277.0 10287.5 10315.5 10335.5 10357.0 10362.0 10389.5 10424.0 10426.0 10437.0 10438.5 10440.5 10486.0 10496.0 10530.5 10536.5 10553.0 10595.5 10602.0 10602.5 10610.0 10613.5 10668.0 10668.5 10698.0 10730.5 EQUIVALENT UNSHIFTED DEPTH ILD DT RHOB 10179.0 10183.0 10182.0 10187.5 10210.0 10214.0 10225.0 10229.5 10259.5 10263.0 10264.5 10276.0 10262.5 10277.5 10357.0 10361.0 10389.5 10425.5 10437.5 10530.5 10361.5 10424.0 10438.5 10602.0 10609.0 10668.0 10360.5 10436.5 10485.5 10530.5 10536.5 10552.5 10594.5 10612.0 10667.5 10731.0 all runs merged; NPHI 10181.0 10187.0 10261.0 10287.5 10316.0 10336.0 10362.5 10439.0 10440.5 10496.5 10602.5 10697.5 no case 10735.5 10741.5 10742.0 10754.5 10761.5 10762.0 10787.5 10803.5 10805.0 10805.5 10806.0 10808.0 10821.5 10828.5 10829.5 10836.0 10846.5 10848.5 10860.0 10873.0 10881.5 10908.5 $ MERGED DATA SOURCE PBU TOOL CODE GR GR BCS BCS DIL DIL SDN SDN 2435 2435 $ REMARKS: 10742.0 10742.0 10806.5 10803.5 10846.5 10873.5 10909.0 10741.5 10762.5 10735.0 10753.5 10760.5 10762.0 10786.0 10803.0 10802.5 10805.5 10807.5 10828.0 10848.0 10822.0 10829.5 10836.5 10860.5 10881.5 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 5 10142.0 10855.0 1 4 10855.0 10891.0 1 5 10142.0 10925.0 1 4 10925.0 10955.0 1 5 10142.0 10938.0 1 4 10938.0 10984.0 1 5 10142.0 10880.0 1 4 10880.0 10914.0 1 5 10142.0 10862.0 1 4 10862.0 10896.0 OPEN HOLE portion of MAIN PASS. SINCE REPEAT PASS GOES DEEPER THAN THE MAIN PASS, THE BOTTOM PORTION OF THE REPEAT PASS WAS SPLICED ONTO THE BASE OF THE MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, CALl, & RB1 WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT /??MATCH5.OUT $ : BP EXPLORATION : H - 0lA : PRUDHOE BAY : NORTH SLOPE : ALASKA FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 5 LL8 DIL 68 1 OHMM 4 6 ILM DIL 68 1 OHMM 4 7 ILD DIL 68 1 OHMM 4 8 RT DIL 68 1 OHMM 4 9 DI DIL 68 1 IN 4 10 SP DIL 68 1 MV 4 11 MTEM DIL 68 1 DEGF 4 12 RHOB SDN 68 1 G/C3 4 13 DRHO SDN 68 1 G/C3 4 14 PEF SDN 68 1 BN/E 4 15 CALl SDN 68 1 IN 4 16 RB1 SDN 68 1 DEG 4 17 NPHI 2435 68 1 PU-S 4 18 FUCT 2435 68 1 CPS 4 19 NUCT 2435 68 1 CPS 4 4 57 310 01 1 4 57 520 99 1 4 57 635 99 1 4 57 635 99 1 4 08 220 06 1 4 08 120 44 1 4 08 120 46 1 4 08 120 46 1 4 08 120 44 1 4 08 010 01 1 4 08 660 99 1 4 49 350 01 1 4 49 356 99 1 4 49 358 01 1 4 49 280 01 1 4 49 631 01 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 143 Tape File Start Depth = 10994.000000 Tape File End Depth = 10142.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34101 datums Tape Subfile: 2 342 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves PASS NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 9630.0 2435 9630.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9658.5 9689.0 9753.5 9770.5 9773.5 9786.5 9791.5 9815.0 9 9 9 9 10 $ 9820.0 9826.5 9858.5 9940.5 945.0 957.5 967.5 971.5 092.0 REMARKS: NPHI 9658.0 9688.5 9753.5 9770.5 9772.5 9787.0 9792.0 9815.5 9820.0 9827.5 9858.0 9941.0 9945.0 9957.0 9967.0 9971.5 10092.0 for open hole logs run into casing. STOP DEPTH 10142.0 10142.0 EQUIVALENT UNSHIFTED DEPTH CASED HOLE portion of MAIN CASING PASS. FUCT, NUCT, TEND & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH6. OUT $ CN : BP EXPLORATION WN : H - 0lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units · API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 4 43 310 01 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4 43 635 99 1 4 43 635 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 31 Tape File Start Depth = 10142.000000 Tape File End Depth = 9600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7596 datums Tape Subfile: 3 78 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. 1 1 5 .2500 VENDOR TOOL CODE START DEPTH GR 10125.0 AC 10125.0 DIFL 10125.0 ZDL 10125.0 2435 10125.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB CHT CABLEHEAD TENSION MIS MASS ISOLATION SUB MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON KNJT KNUCKLE JOINT ZDL Z-DENSITY TEMP TEMPERATURE KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT PCM PULSE CODE MODULATOR RB RB-SUB AC BHC ACOUSTILOG DIFL DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS STOP DEPTH 10862.0 10926.0 10955.0 10888.0 10868.0 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 2213 20-SEP-95 11003.0 10986.0 9630.0 10984.0 1500.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921NA 2222EA/2222MA 2806XA 3921NA 3921NA 3506XA 3975XA 1609EA/1603MA 1503XA 6.000 10140.0 10142.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: OPEN HOLE MAIN PASS. $ CN : BP EXPLORATION WN : H - 0lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA FLo, PRO 9.00 60.0 8.2 6.0 202.4 .940 .350 1.400 .000 1.900 .000 THERMAL SANDSTONE 2.65 .000 1.5 70.0 202.4 70.0 .0 70.0 .0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG 4 60 310 01 1 4 60 520 99 1 4 60 635 99 1 4 60 635 99 1 4 60 636 99 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 631 01 1 18 CNC 2435 68 1 PU-S 4 19 CNCF 2435 68 1 PU-S 4 20 CN 2435 68 1 PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 306 ~ 43 995 99 4 43 995 99 4 43 890 01 4 43 334 31 4 43 334 30 88 Tape File Start Depth = 10965.000000 Tape File End Depth = 10125.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 111405 datums Tape Subfile: 4 393 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10136.0 10891.0 AC 10136.0 10955.0 DIFL 10141.0 10984.0 ZDL 10136.0 10917.0 2435 10136.0 10897.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL GR CN KNJT ZDL TEMP KNJT KNJT PCM RB AC DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY TEMPERATURE KNUCKLE JOINT KNUCKLE JOINT PULSE CODE MODULATOR RB-SUB BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 2005 20-SEP-95 11003.0 10986.0 9630.0 10984.0 1500.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921NA 2222EA/2222MA 2806XA 3921NA 3921NA 3506XA 3975XA 1609EA/1603MA 1503XA 6.000 10140.0 10142.0 FLO-PRO 9.00 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: OPEN HOLE REPEAT PASS. $ CN : BP EXPLORATION WN : H - 0lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 6~ 0 8.2 6.0 202.4 .940 .350 1.400 .000 1.900 .000 THERMAL SANDSTONE 2.65 .000 1.5 70.0 202.4 70.0 .0 70.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S 4 60 310 01 1 4 60 520 99 1 4 60 635 99 1 4 60 635 99 1 4 60 636 99 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 46 631 01 1 4 43 995 99 1 4 43 995 99 1 20 CN 2435 68 1 PU-L 4 21 LSN 2435 68 1 CPS 4 22 SSN 2435 68 1 CPS 4 DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 373 ~ 43 890 01 4 43 334 31 4 43 334 30 88 Tape File Start Depth = 10994.000000 Tape File End Depth = 9970.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 101828 datums Tape Subfile: 5 458 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 7 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9626.0 2435 9626.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL GR CN KNJT ZDL TEMP KNJT KNJT PCM RB AC DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY TEMPERATURE KNUCKLE JOINT KNUCKLE JOINT PULSE CODE MODULATOR RB-SUB BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 10149.5 10149.5 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 2326 20-SEP-95 11003.0 10986.0 9630.0 10984.0 1500.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921NA 2222EA/2222MA 2806XA 3921NA 3921NA 3506XA 3975XA 1609EA/1603MA 1503XA 6.000 10140.0 10142.0 FLO-PRO 9.00 60.0 8.2 6.0 202.4 .940 70.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: CASED HOLE MAIN PASS. $ CN : BP EXPLORATION WN : H - 0lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA . ,.~50 1.400 .000 1.900 .000 THERMAL SANDSTONE .00 .000 202.4 70.0 .0 70.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CNCF 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 CHT 2435 68 1 LB 4 8 TTEN 2435 68 1 LB 4 9 SPD 2435 68 1 F/MN 4 4 43 310 01 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4 43 635 99 1 4 43 635 99 1 4 43 636 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 102 Tape File Start Depth = 10253.000000 Tape File End Depth = 9621.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 136696 datums Tape Subfile: 6 180 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GRCH 9600.0 2435 9600.0 $ LOG HEADER DATA STOP DEPTH 10153.0 10153.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MIS MODL GR CN KNJT ZDL TEMP KNJT KNJT PCM RB AC DIFL $ SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT Z-DENSITY TEMPERATURE KNUCKLE JOINT KNUCKLE JOINT PULSE CODE MODULATOR RB-SUB BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 1716 20-SEP-95 11003.0 10986.0 9630.0 10984.0 1500.0 TOOL NUMBER 3944XA 3974XA 3967XA 3517NA 1309XA 2435XA 3921NA 2222EA/2222MA 2806XA 3921NA 3921NA 3506XA 3975XA 1609EA/1603MA 1503XA 6.000 10140.0 10142.0 FLO-PRO 9.00 60.0 8.2 6.0 202.4 .940 70.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: . :~50 1.400 .000 1.900 .000 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE .00 .000 TOOL STANDOFF (IN): REMARKS: CASED HOLE REPEAT PASS (LOGGED DOWN). $ CN : BP EXPLORATION WN : H - 0lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 202.4 70.0 .0 70.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2435 68 1 GAPI 4 2 CNC 2435 68 1 PU-S 4 3 CNCF 2435 68 1 PU-S 4 4 CN 2435 68 1 PU-L 4 5 LSN 2435 68 1 CPS 4 6 SSN 2435 68 1 CPS 4 7 CHT 2435 68 1 LB 4 8 TTEN 2435 68 1 LB 4 9 SPD 2435 68 1 F/MN 4 4 43 310 01 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4 43 635 99 1 4 43 635 99 1 4 43 636 99 1 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 115 Tape File Start Depth = 10313.000000 Tape File End Depth = 9600.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 130359 datums Tape Subfile: 7 193 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS 95/ 9/28 01 **** REEL TRAILER **** 95/10/ 4 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 4 OCT 95 8:38a Elapsed execution time = 3.90 seconds. SYSTEM RETURN CODE = 0