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208-183
Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/09/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU S-39 (PTD 208-183) Gamma Ray/CCL with CIBP 08/26/2021 Please include current contact information if different from above. 37' (6HW Received By: 11/09/2021 By Abby Bell at 5:03 pm, Nov 09, 2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to WSW Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,306 feet 3,600' & 4,581'feet true vertical 3,796 feet N/A feet Effective Depth measured 3,600 feet feet true vertical 3,066 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)5-1/2"17# / L-80 3,252' 2,815' Packers and SSSV (type, measured and true vertical depth)N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WSW Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 5,410psi1,529' Hilcorp Alaska LLC measured true vertical Packer 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 MILNE PT UNIT S-39 See above 7" 6,290' 3,796' 7,140psi 170 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 400 Casing Pressure WINJ WAG 0 Water-Bbl MD 112' 3,720'4,870' TVD Gas-Mcf 9-5/8" VGH, 'C2' ZXP LTP, and ECP 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data N/A0 measured 112' Oil-Bbl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-183 50-029-23405-00-00 Plugs ADL0380109 / ADL0380110 5. Permit to Drill Number: MILNE POINT / Tertiary Undefined WTRSP 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-345, 321-356, 321-409 700 Authorized Signature with date: David Gorm dgorm@hilcorp.com 5,500 N/A Conductor Size Junk Length Surface 20" 9-5/8" Senior Engineer: Senior Res. Engineer: Collapse N/A 4,760psi Burst N/A 6,870psi N/A 777-8333 2. Operator Name 112' 4,833' measured Casing Tubing Pressure 0 3,264', 4,761' and 4,967' 2,824, 3,688', and 3,745' Liner W G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 10:43 am, Sep 28, 2021 Chad Helgeson (1517) 2021.09.28 09:42:12 - 08'00' Service MGR15OCT2021 DSR-9/28/21 SFD 9/28/2021 Perforate New Pool Tertiary Undefined WTRSP Convert to WSW WSWW DSR-9/28/21 RBDMS HEW 9/29/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 CTU 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Scope Derrick down. Secure stairs. NES trucks on location at 02:00. Jack up, hook up, mobilize and stage pipe shed. Split remaining rig modules, mobilize and stage. Walk Sub Base off MPU S-47. 8/20/2021 - Friday MIT-T Cement Plug (Failed) (Pressure test surface lines 250/2500 psi) Pumped 43 bbls diesel down TBG and never reached test pressure. IA tracked slowly with TBG. 1st 15 min T/IA lost 129/132 psi. 2nd 15 min T/IA lost 49/49 psi. 8/15/2021 - Sunday (Injectivity test for cement job) (Pressure test surface lines 250/2500 psi) Pumped a total of 12 bbls diesel down TBG up IA taking returns to tank. Injectivity of: 1bpm @ 125 psi. 2 bpm @ 140 psi. 3 bpm @ 150 psi. 8/11/2021 - Wednesday MIT-T cement plug to 1500 psi (Post Coil) (Failed) (Pressure test surface lines 250/2500 psi) Pump 15 bbls Dsl down Tbg. Did not reach test pressure. 1st 5 Min TxIA lost 45/47 psi. 2nd 5 Min TxIA lost 27/28 psi 3rd 5 Min TxIA lost 31/32 psi. 8/13/2021 - Friday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 250L/2500H. (tag cement). RAN 5'x2.5" DRIVE DOWN BAILER W/ MULE SHOE BALL & TAGGED TOP OF CEMENT @ 4,977' SLM (4,951' MD), USED -26' SLM CORRECTION FROM XN TAG, RECOVERED 1gal OF CEMENT IN BAILER. RAN 2'x1-7/8" ST, 3.80" GAUGE RING & TAGGED XN @ 4,914' SLM (4,888' MD) FOR -26' CORRECTION. MIRU CTU #9 with 2" coil. MU and RIH with 2.24" JSN. RIH and tag 5080'. Jet 1.5 bpm and set down at 5096'. Repeat tag and confirm hard bottom. POOH. Secure well and order fluids for FCO tomorrow. SDFN. 8/7/2021 - Saturday Crews arrive on location. Check equipment and oils. RIH w/2.35" DJN. Tag 5,070'. POOH for TEL. RIH and locate nipple. POOH. MU and RIH with BDJSN for cement. Pump 52 bbls 15.8ppg class G cement. Pump 43 bbls into liner from 5,070'. Lay in remaining cement. Attempt to hesitate squeeze. No pressure response seen from cement. Drop ball and contaminate to 4924'. POOH contaminating and washing tubing. Hold WHP with choke @ ~ 500 psi through out job. 1:1 returns noted at tank farm. Jet BOPE stack. RIH and freeze protect well from 2827' with diesel. POOH. Secure well and SDFN. 8/10/2021 - Tuesday 8/8/2021 - Sunday Crews arrive on location. Check equipment and oils. Begin BOP test. Function test and time all rams. Fluid pack BOP and leak 8 gallons of diesel bleeding down. Repair bleed valve and continue BOP test. Passing BOP test. Both Blind/Shear rams had pass/fail tests. MU BOP to well. Install and test night cap. Secure well and order fluids for FCO tomorrow. SDFN. 8/9/2021 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/21/2021 - Saturday Walk Sub Base east down MPU S- Pad well row and spot over MPU S-39. Level and set Sub Base down. Move catwalk to Sub Base. C/O gunline valve in Pits. Adjust #2 MP suction in pit #5. Assembly Mud Pump #2 and C/O valves and seats on MP #1. Spot, shim and set Cattle Chute, Pipe Shed and Rig Mods. Hook up mud lines in Pits. Hook up interconnects between modules. Scope Cattle Chute to Sub Base. C/O splash guards on shakers and weld brackets for MPD hardline in Cellar. Spot and set break trailer and enviro-vac. Plug in and swap from cold starts to gen power at 23:00 hrs. Set stairs, landings and walkways and safe out same. Safe out adjacent cellar box areas. Finish hook up inner-connects. Bring air, H2O & Steam systems online. Begin working on rig acceptance checklist. Spot cuttings box and berm. Prep pumps and pit equipment. Bring on water to pits. Scope up derrick and bridle down. Perform Derrick inspection. Finish acceptance checklist. Rig accepted at 04:00. Spot flow back tank, rig up 1502 hardline from tank to IA. Rig up high pressure lines from mud manifold to pump down tubing. SimOps: Finish taking on fluid to mud pits. 8/22/2021 - Sunday PJSM, flood surface lines and PT 1000 psi (test good). Circulate heated 8.3 source water STS. Stage up to 5 bpm, 570 ICP, 349 FCP. Circulate a total of 468 bbls back to flowback tank. Observed diesel, viscous crude and gas back at surface. Cleaned up to dirty source water @ STS. Shut down and monitor well. Climbed to 175 psi on tbg and IA over 20 min then stabilized. Rig on Hi-Line power @ 09:25. Discuss with town engineer (David Gorm). Wt up 400 bbls to 9.7 ppg KMW. IA and Tbg maintained shut in psi of 175. PJSM, Circulate down 4.5", 12.6#, L-80 (IBT-M & TC-II) kill string with 9.7 KWM STS @ 4890' MD. Pump 25 bbl heated soap pill, displace with 9.7 brine taking all returns to flowback tank (MPU-14). Stage up to 5 bpm, 350 psi, FCP 220. Circulated 347 bbls total with clean brine back to surface. Soap pill came back on time. Shut down and monitor well (static). B/D surface lines to tank. Dry rod BPV. N/D tree and stage in cellar. M/U TC-II XO to hanger w/ 7-1/4 turns (good). PJSM. Install DSA and spacer spool, set stack on wellhead. Torque all flanges and install turnbuckles. Rig up choke and kill lines, drain hoses and hole fill lines. Install accumulator lines and energize accumulator. Install Bell Nipple and riser. Air up Boots. Obtain RKB’s. RKBS: LL – 26.02', ULD – 23.90', LPR – 19.63', Blinds – 16.07', UPR – 14.81', Annular – 12.31',P/U 3.5” & 5.5” test joints and mark each with RKB measurements. Function test all BOPE components. M/U side entry sub, TIW and Dart valves to 5.5” test jt. Flood stack and surface lines. Purge air and perform body test on BOPE, good test. Line up to attempt BOPE test #1 with 5.5” test joint and observe leak between DSA and spacer spool. Tighten up bolts on flange. Spot check other flanges and connections. Purge air from system and perform Shell Test again. Good Test. Test BOP equipment as per AOGCC to 250 PSI low / 3000 PSI high. Tests held for 5 min each & charted. AOGCC inspector Brian Bixby waived right to witness test at 06:48, 08/21/2021. All tests performed with fresh water against a BPV test dart. Test gas alarms and PVT. Monitor IA in Cellar. 1. Upper 2-7/8" x 5-1/2" VBR on 5-1/2" test joint, Upper IBOP & Manual Choke, 2. Choke valves 11, 12, 13, 14 & 15. (#3 Kill Failed) FOSV #1 & HCR Kill, 3. Lower 2-7/8" x 5-1/2" VBR on 5-1/2" test joint, 4. Blind Rams, Choke valves 7, 8, 9, 10 & Kill #3, 1 F/P on Kill #3. Testing carried through to next report. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/23/2021 - Monday Continue testing 13-5/8" 5m stack with 3.5" & 5.5" test joint to 250/3000 psi with 5 min hold on each. Chart and record same. F/P on Mezz kill (serviced valve and retested). Test gas alarms 10/20 ppm H2S, 20/40% LEL (good). Koomey drawdown - 3000 psi initial, 1500 psi drawdown, 200 psi 25 sec, full charge 93 secs, 6 N2O bottle avg - 2308 psi. Witness waived by AOGCC - Brian Bixby. R/D test equipment. Pull CTS and BPV. Bring WOT tools to floor and R/U same. R/U flowback tank to IA. M/U TC- II XO and RIH on landing joint. Engage top of hanger (7-1/4 turns R). Verify IA @ 0 psi, BOLDS. Unseat hanger 81k up breakover to 77k clean up wt. Pull 4.5" hanger to floor and L/D same. M/U crossover NC50 x 4.5" TC-II to 4.5" kill string. RIH on 5" DP F/ 4863' - T/ 4929' seeing 2-3k drag. 77k up, 66k dn. Wash down F/ 4929' - T/ 4990' MD 3-4 bpm, 50-110 psi. Saw moderate packing off @ 4990' MD w/ psi spikes 540 psi. P/U and re-establish circulation washing back down on depth @ 4990' MD. 3k dn @ 4990' MD. Circulate STS @ 4990' MD staging up to 7 bpm, 490 psi, 54% flow. 77k up, 66k dn. Saw 760u gas spike @ btms up. Dumped 40 bbls crude and contaminated brine to flowback tank. Circulated a total of 419 bbls with clean 9.65 ppg salt brine In/Out. PJSM, HES cmtrs. Pump cmt balance plug as follows. HES wet lines w/ 3 bbls H2O. PT 500/3000 psi (test good). 23.6 bbl 8.34 ppg spacer, 25 bbls 15.8 ppg class "G" cement, 6.4 bbls 8.34 ppg spacer. Turnover to Rig. Rig displace with MP#2, 62 bbls 9.65 brine. Shut down. B/O of DP (dry). CIP @ 17:31. TOC calculated @ 4545'. Rig down cement equipment. POOH t/ 4300' L/D 4 jts 5" DP & 14 jts 4-1/2", 12.6#, L-80 TC-II Tubing. Pull 15 FPM t/ 4761' MD, 25 FPM t/ 4500' & 50 FPM t/ 4300'. 71k PU, 63k SO. Rig up pump-in sub and FOSV to stump. Install hi-pressure hose to flowline. Shut upper VBR and reverse circulate 3x tubing volume, 6 BPM, 150 PSI. Overboard 30 bbls contaminated brine and spacer at first BU. Blow down and rig down lines. Monitor well 10 min - Static. SimOps: Make up FOSV to TC-II & IBT XOs. POOH f/ 4300' t/ surface laying down 4-1/2", 12.6#, L-80 Tubing. L/D Total 31 jts TC-II, 87 Jts IBT-M, 2x pup jts, XN nipple & WLEG. Hole took calculated fill. Clear and clean rig floor. Mobilize Csg scraper components to floor. Rig down Weatherford tongs and remove 4- 1/2" handling equipment from rig floor. Rig up 5" elevators. M/U pack-off running tool to 5" jt DP. RIH and engage isolation sleeve. BOLDS. Unseat sleeve w/ 25k, pull to rig floor and L/D. C/O running tools. Bring wear bushing to floor and Install. RILDS. P/U Jt 5" drill pipe (drift w/ 3.125”), M/U 8-1/2” Smith XR-CPS Milltooth bit, 9-5/8" casing scraper, 2x boot basket, bit sub w/ ported float. RIH w/ 9-5/8" scraper assembly (18.68' total length) to 175' picking up 5x jts of 5" DP. Drift 3.125". Hole taking proper displacement. 40k up, 40k dn. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/24/2021 - Tuesday RIH F/ 175' - T/ 4502' MD with 9-5/8 scraper assy singling in on 5" NC50, 19.5#, S-135 DP (drift - 3.125"). Rotate pass Tam Port collar @ 976' MD w/ 15 rpm, 5k tq. Saw 2k bobble w/slight bump in tq then passed clean. 112k up, 90k dn. Fill pipe @ 2500' MD. 40k up, 40k dn. Wash down F/ 4502' - T/ 4592' MD. 3 bpm, 65 psi, 117kup, 94k dn. Saw 5-10k drag w/ 30-40 differential psi. P/U and CBU @ 4592' MD. Saw traces of fine sand with residual crude back at shakers at btms up. Saw gas bump @ 284u then drop off. Washed back down to 4592' with 10-15k bobble and fell off. Continue Wash down F/ 4592' - T/ 4640' MD setting down 15k. P/U and attempt to re-tag but wt fell off. Continue wash down ratty F/ 4592' - T/ 4650' MD. until taking 15k wt and held. P/U and rotate down to polish top of plug to 4656' MD. Set down with 18k, verify tag depth 2x (good). 3 bpm, 65 psi, 117k up, 93k dn, 104k rot, 20 rpm, 5.1k tq. Shut upper rams and attempt to PT 9-5/8" casing. Observe psi break over @ 1370 psi @ 3/4 bpm rate. Reduce pump rate to 1/2 bpm, 1150 psi stabilized. Pump away 2.5 bbls. Shut down, bleed off psi and troubleshoot surface equipment with no issues found. Attempt re-test with same results pumping away 4.5 bbls (7 bbls lost total). Monitor well (breathing). 4.2 bph initial flow trending down over 30 min to .9 bph. POOH F/ 4656' - T/ surface. B/O and L/D 9-5/8" scraper assy with boot baskets. Clear boot baskets (~30# 3/4" sized hard cement in baskets). No damage observed on assy. 5.4 bbl loss for trip out. Clear and clean rig floor. M/U BOT 9-5/8” Retrieve-O-Matic test packer. RIH with packer on 5” DP to 1080’ MD. Install FOSV. Set Packer and test casing from 1080’ to surface @ 1500 psi. Good test. Bleed pressure and release packer. 55k PU, 54k SO. RIH with test packer to 2991’ MD. Install FOSV. Set Packer and test casing from 2991’ to surface @ 1500 psi. Good test. Pressure test below packer, pressure break over and observe injection at 0.62 BPM with 1130 psi. Shut down, bleed pressure and release packer. 87k PU, 81k SO. RIH with test packer to 4581’ MD. Install FOSV. Set Packer and test casing from 4581’ to surface @ 1500 psi. Good test. Bleed pressure and release packer. Blow down TopDrive and surface lines. Monitor well 10 min -Static. 117k PU, 93k SO. POOH with Retrieve-O-Matic packer f/ 4581’ MD t/ surface. L/D BOT test packer. Clear and clean rig floor. 1.1 bbls loss on TOOH. M/U BOT 9-5/8” CIBP and RIH on 5” DP t/ 4527'. Kelly up and wash down t/ 4585' MD, 2 BPM, 50 psi. Recorded calculated displacement on TIH. 15k PU, 95k SO. Work string 10' three times. Shut pumps down and set CIBP, 15 turns R. Ratchet with 50k up/dn. Disengage from CIBP, 3700 ft/lbs shear then 10 turns R. Pick up and verify free. CIBP set @ 4581' MD. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/25/2021 - Wednesday Line up to pump down DP & Kill. Test casing and CIBP for 30 charted minutes, t/1500 psi against upper VBRs. Good Test. Pumped 2.2 bbls, 2.0 bbls bled back. Rig down and blown down lines. Service Rig, grease Crown, Drawworks and Iron Roughneck. Rig up cement lines and HES cement equipment. PJSM, HES cmtrs. Pump cmt balance plug as follows. HES wet lines w/3 bbls H2O. PT 1200/3000 psi (test good). 22.6 bbl 8.34 ppg spacer, 10 bbls 15.8 ppg class "G" cement, 7.4 bbls 8.34 ppg spacer. Turnover to Rig. Rig displace with 72 bbls 9.6 ppg brine. Shut down. B/O of DP (dry). CIP@ 10:32. TOC calculated @ 4445'. Rig down cement lines and equipment. POOH f/ 4576’ t/ 4198’ @ 15 FPM. 110k PU, 90k SO,Install side entry sub with FOSV above. Rig up and reverse circulate string clean staging up to 5 BPM, 330 psi, Max gas- 475u. No abnormal returns observed at shakers. Rig down circ equipment and blow down surface lines. Clear and clean rig floor. Service pipe handling equipment. Work on rig EAM’s until decision made to POOH. POOH f/ 4198’ t/ surface, racking 5” DP in Derrick. L/D CIBP running tool. Calculate hole-fill observed. M/U Smith 8-1/2” Milltooth bit, BOT 9-5/8” casing scraper & bit sub w/ ported float. RIH with casing scraper assembly on 5” DP t/ 4395’. Slow running speed and rotate 10 RPM, 1k tq while pass by TAM Port Collar. Calculated displacement recorded on TIH. 113k PU/93k SO, Kelly up and wash down 2 BPM, 40 psi. Start seeing 1-4k drag f/ 4459’ t/ 4497’ with slight pressure fluctuations 30-50 psi. Observe 5-10k wt f/ 4497 t/ 4519’ pressure increase to 100 psi. Wt and pressure fall off when string stop moving. Indications of washing through unset/contaminated cement. POOH t/ 4315’ and CBU 2x, 13.5 GPM – 800 psi, while discussions with engineer. Dump 40 bbls cement contaminated brine at BU. AOGCC Rep Guy Cook on location to observe cement Tag. POOH on elevators f/ 4315’ to surface. Lay down casing scraper and bit. Scraper blades and bit cones had trace amounts of firm cement imbedded. Slow pulling speed and rotate 10 RPM, 1k tq while pass by TAM Port Collar. Calculated hole-fill observed on TOH. Clear and clean rig floor. Clear and clean rig floor. RIH with open ended 5” DP t/ 4518’ tagging TOC w/ 2k. 112k PU, 96k SO. Calculated displacement observed on TIH. Pick up t/ 4515’ and install side entry sub with FOSV & 10’ pup. Break circulating down string, verify flow path. Shut down, close upper VBRs, line up and reverse circulate pipe volume until even 9.5 ppg brine in/out. Stage pumps up to 6 BPM, 450 PSI. PJSM, HES cmtrs. Pump cmt balance plug as follows. HES wet lines w/3 bbls H2O. PT 1232/3000 psi (test good). 22 bbl 8.34 ppg spacer, 10 bbls 15.8 ppg class "G" cement, 8 bbls 8.34 ppg spacer. Turnover to Rig. Rig displace with 69 bbls 9.5 ppg brine. Shut down. B/O of DP (dry). CIP @ 03:25. TOC calculated @ 4382'. Rig down cement lines and equipment. POOH f/ 4511’ t/ 3940’ @ 15 FPM. 108k PU, 85k SO, Install side entry sub with FOSV above. Rig up and reverse circulate string clean staging up to 5 BPM, 420 psi, Max gas- 18u. No abnormal returns observed at shakers. Rig down circ equipment and blow down surface lines. Observe Well - Static. POOH f/ 3940' t/ 3085'. Pump dry job. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/26/2021 - Thursday Continue to TOH on elevators with 5" DP open ended from 3940' to Surface. M/U Cement Tag Assy with 8.5" Bit and RIH out of Derrick to 4257". PU WT 106K, SOW 86K,Circulate Bottoms Up from 4257' @ 9 BPM, 345 PSI.,PJSM on Cut Drill Line. Hang Blocks. Cut 10 wraps (63') Drill line and slip new onto Drum. Ton Miles = 771. Accum TM = 22,253. Left on spool = 1,897'. TQ Deadman t/80 ft/lbs. Check Drawworks Brakes, all within specs.,PJSM for all tasks while WOC: Perform Sheave wobble on Blocks. Unhang Blocks set Top Drive Limits and check Crown/Floor Savers. Perform Monthly EAM on Top Drive & check J-Box. Service Rig, Grease Crown, Blocks, Top Drive, Wash Pipe, Iron Roughneck and Drawworks. Check oil in Top Drive, Inspect welds on Cradle. Service Air Slips.,PJSM, Wash Down @ 2 BPM, 40 PSI from 4257' MD to 4408' MD. Set down 15K @ 4408', see 150 psi increase in pump Pressure. Confirm Tag x2. CBU @ 13 BPM/800 PSI. Over board 40 bbls of cement contaminated Brine. Shut UPR and Test casing. Initial Pressure IA = 1691 PSI, 15 min = 1627 PSI, 30 Min = 1573 PSI (118 PSI Loss) Test witnessed by Guy Cook with AOGCC. Test Pass.,Pump 35 bbls Hi Vis spacer & displace well to 8.8 ppg 2% KCL Brine. 13 BPM, 835 psi. Monitor Well - Static. Blow down Top Drive, Choke and Kill lines. POOH f/4408' t/surface. Lay down tag assembly. Calculated hole-fill on TOH. Clear and clean rig floor. Mobilize logging tools & R/U e-line sheaves. M/U CCL, gamma ray tools & Halliburton EZ-Drill CIBP on YellowJacket E-line. RIH to 4000' & Perform CCL/GR log out of the hole to 3000’. Verify correlation with Engineer. Position Top of Packer at 3600'. Fire setting charge - observe good indication of plug setting. PU 100’ after firing/setting/release. S/O and tag plug on depth. TOP of Plug @ 3600’ MD. POOH and R/D E-Line. Close blind rams, fluid pack surface lines. Test 9 5/8" casing and HES EZ-Drill Plug @ 3600', to 3000 psi on chart for 10 minutes. Good test. M/U 4-5/8" Halliburton 12 spf Maxforce perforating assembly to 257.77. Bull Plug to 10 full guns, 1 partial blank, XO to firing head, 2.875” EUE pup and XO to NC-50. 228' total of perforations. RIH with TCP Gun Assy on 5" DP from 258' to 3563'. Obtain Parameters: 98k PU, 87k SO. RIH from 3563' and tag Ez Drill plug @ 3598' w/3k dn. (2' off wireline measurement). Review and confirm tally depths are correct. Verify perf firing depth. Pull off plug 12.9’ to set bottom perf at 3586' wireline correlated depth. M/U TopDrive and circulate DP volume at 4 BPM, 50 psi. Shut down, drop 1-3/8” ball. Let free fall while M/U Topdrive and set back on depth. Pump ball down 4 BPM, 60 psi. Ball seat with 9 bbls pumped. Close annular and line up to a closed choke. Line up test pump to mud manifold as contingency. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/27/2021 - Friday Cont to pump ball down 4 BPM, 60 psi. Ball on seat w/9 bbls pumped. Close annular & line up to a closed choke. Line up test pump to mud manifold as contingency. Pressure up & see guns fire @ 2033 psi. PUH to 3330' MD. Monitor well on TT 10 min w/5 bph loss rate. TIH & tag CIBP on depth @ 3598' w/no fill. POOH on elevators from 3598' to 3300'. Shut annular & line up on choke. CBU through gas buster to mitigate perf gas @ 3.5 bpm. 10 psi on casing/75 psi on string while circulating. Max gas = 24u. Shut down pumps & monitor well 10 min on closed choke, static. Open choke & annular. Well losing 2 bph. Cont POOH on elevators f/3300' to surface. M/U 5" safety jt. L/D perf guns. All shots fired. PU 64K, SO 62K. Calc 29.9 bbls, ACT 31.7 bbls, Loss 1.8 bbls. M/U 5" safety jt w/triple connect & TIW & lift sub. Stage 5', 10' & 20' 5" DP Pups. R/U Weatherford handling equip and power tongs. Verify all ID's, OD's & lengths on all equip. Verify pipe tally w/HES gravel pac Rep. Static loss rate @ 2bph,PJSM, P/U & M/U bull nose shoe jt, 7ea 5-1/2", 17#, L-80, Vam Top, 250 micron PGM DS RDT Screens, and 1 blank tt to 307' MD. TQ connections to 5.4K. R/U false table & P/U 10 jts 3 1/2" 9.2# TSH 511, P110 inner string. M/U VGH packer assembly per HES Reps to 344' MD. PUW 42K, SOW 42K. RIH w/GP assembly on 5" DP out of derrick from 344' to 3295'. Line up & reverse circulate 7 bbls @ 2 BPM, 40 psi. Cont in the hole on DP, tag top of plug w/ 5k @ 3598' DP tally depth. (11' in on std #52). Rack back stand. L/D single & space out w/2x pup jts. 6.79' & 9.57'. Pick single back up & tag top of plug w/ 5k. Pick up to string wt. 103k PU, 88k SO. 3 bbls loss on TIH. Rig up pump-in sub w/FOSV to high pressure HES hardline, manifold & rig pump manifold. Rig up annulus to HES choke manifold. Drop 1.75" brass setting ball. Static losses @ 2 BPH, flood & purge rig choke & kill lines. Flood HES lines & choke manifold. PT HES lines & equip to 500/6200 psi. Good. Test lines to IA t/2400 psi. Good. Line up & attempt test rig side lines/equip. 3x high press hose failures. Reconfigure rigging. Attempt re-test on HES lines. Pump truck return press mon system kick out & fail to reset. Reroute lines to secondary pump. Good test to 500/6200 psi.Test rig side to 5000 psi. Good. Line up to pump down DP. Press up to 2700 psi in 500 psi /3 min increments. Bleed press down to 0. P/U to 123k - 20k over string wt. S/O to 67k setting 20k down. Press up to 2700 psi @ 0.5 BPM, hold for 3 min. Cont pressure up to 3200 psi & hold for 3 min. Bleed press to 0. Test IA t/1000 psi for 15 charted min. Good. Cont press up to 2499 psi & observe good indication of disk burst. Bleed off press to 0. Top of packer @ 3264.49'. Press up to 3000 psi. P/U, see good indication of tool release w/120k up wt (17k over). Bleed press to 0. P/U to calculated reverse circ depth. Press up down DP to 3500 psi w/rig pump, swap to test pump & cont press up t/ 5000 psi, see good indication of ball seat shear. S/O & set down 30k, mark pipe for circulating depth. P/U string & close annular. Line up to reverse circulate. Attempt to hold 500 psi, press dropping off. Double check valve alignment & lines. Good. Hold 300 psi w/rolling pumps at 1 BPM. Strip up hole until press dump. Mark string for reverse depth. Line up to HES to spot 15% HCL pickle down DP. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/28/2021 - Saturday Continue with GP Procedures: Line up to HES Pump Unit and pickle pipe, pumping 7 bbls of Acid, follow with 44 bbls 2% KCL. Turn over to Rig and reverse circulate pickle to flow back tank pumping x2 pipe volumes @ 3.5 bpm/500 psi, hold 460 psi back pressure on IA. With tool in reverse position, RIG perform reverse circ test: 1 bpm/ 14 psi, 2 bpm/50 psi, 3 bpm/105 psi, 4 bpm/180 psi, 5 bpm /266 psi. Slack off to circulating position w/30K on PKR and perform circulation test from pump unit: 2 bpm/57 psi, 1.5 bpm/ 35 psi, .5 bpm/11 psi. Pump unit perform step rate test: 1 bpm/75 psi, 2 bpm/166 psi, 4 bpm/425 psi, 5 bpm/575 psi. Step down pressures: 4 bpm/600 psi, 2 bpm/500 psi, 1 bpm/375 psi. Pump GP with 9,587 lbs of 20/40 Proppant slurry as per Haliburton GP Procedure Vs 3 @ 5 bpm/500 psi, taking returns through choke maintain 2 bpm return flow. Screen out @ 1 bpm/2000 psi. PU service Tool to reverse position and reverse circulate 4 bpm, 535 psi, holding 400 psi back pressure DP. CBU x2 until clean returns seen at flow back tank. Take returns to pits over shakers and observe no proppant in returns. Shut down pumps and line up and allow HES to wash up to pits. Blow down all surface equipment. R/D all hard line on rig floor and remove same. PUH and L/D 2 jts DP & 2 DP Pup Jts. Blow down top drive. PJSM, POOH L/D DP from3522' to 340'. R/U Power Tongs and 3.5" handling equipment. L/D VGH PKR Run Tool. L/D 3.5" TSH 511 wash string to surface. Clean and clear rig floor of all service tools and equipment. Break down circulating Jts with TIW and pump in sub. Break down safety Jts with TIW and triple connect. Clear rig floor of all un-needed XO and subs. Loss rate @ 7 bph Static. RIH with remaining 5" DP from dDerrick to 1320'. POOH and L/D same. Remove wear bushing. Change out handling equipment. Mobilize Centrilift equipment to rig floor. Hang ESP sheave in derrick. Stage ESP assembly in pipe shed and begin loading 5-1/2" completion tubing in shed. 6 BPH static loss rate. M/U Baker Centrilift 7.25" centralizer, Zenith Motor Gauge, 562XP 550/3830/88 motor, tandem seals and HPHVMARC pump to 72'. Centrilift rep service motor and seal assembly. Install motor lead to pump. SimOps: Finish processing 5-1/2" tubing in shed. Install ESP spool on spooling unit, spot into position and hook up hyd/electrical. Route ESP cable through sheave. Centrilift Rep slice motor lead to ESP cable. SimOps: R/D pump clamp elevators. Rig up Weatherford doublestack power tongs. Drift jts and XOs. Clear and clean rig floor. 5 BPH static loss rate. Pick up 1st jt 5.5" 17# L-80 LTC tubing and make up bolt on discharge head install protectolizer and CC clamps and RIH t/ 113'. Well Name Rig API Number Well Permit Number Start Date End Date MP S-39 I-Rig 50-029-23405-00-00 208-183 8/7/2021 8/29/2021 Hilcorp Alaska, LLC Weekly Operations Summary 8/29/2021 - Sunday Run 5 1/2", 17#, L-80, LTC/IBT Tbg ESP Completion from 113" to 2150', Tq LTC Connections to 3,400 ft/lbs, and IBT to 5,500 ft/lbs. RIH 100-150 ft/min, test cable every 1000'. Centrilift cable test meter not working. W/O New meter before RIH. Cont Run 5 1/2", 17#, L-80, LTC/IBT Tbg ESP Completion from 2,150" to 3232'. Tq LTC Connections to 3,400 ft/lbs, and IBT to 5,500 ft/lbs. RIH 100-150 ft/min, test cable every 1000'. Installed CC Clamps 1st 10 jts, then every other Jt for total of 43 cc clamps. PUW 83K, SOW 70K. 21.5 bbls total loss with running completion. PU landing joint and MU to hanger, MU hanger to string. Cut cable and splice Mtr Lead to ESP and attempt to install to hanger as per well head rRep, Cable is 6" short. SIMOPS: R/D WOS Power tongs and handling equipment, clean and clear rig floor all un-needed XO, s/Subs. Pull cable to ESP Spool, Unplug and R/D Spooling unit. R/D ESP Sheave. Flush #1 MP and Begin inspection. Begin cleaning pits. Rig on Gen power @ 16:00. Load and process 5" DP in pipe shed. Lay pit liner and set mats on S-48. Call out WOS rep & mobilize WOS power tongs and handling equipment to rig floor. L/D landing joint and hanger. Lay down last jt ran (#77) and replace with 1.24' shorter joint (#84). M/U hanger and install BPV. M/U landing jt. SimOps: Cont with MP#1 inspection. Offload pits and clean same. M/U Tri- Bore to hanger and secure ESP cable to pipe below hanger. Land ESP completion on Hanger with 38k. RILDS. Lay down landing jt and R/D WOS Power tongs and handling equipment, clean and clear rig floor. Bottom of motor centralizer @ 3257.26', Flush surface lines and equipment with heated soap pill. Blow down lines. SimOps: Cont cleaning mud pits. 4 bolt all BOPE stud connections on stack in preparation to N/D. Hook up bridge cranes to stack and remove chain binders. De-Energize accumulator unit and N/D BOP stack. Rack stack on moving stump and secure. Remove spacer spool and DSA. SimOps: Start prepping shaker beds for removal. Install dart in BPV. Install hanger neck seals. Lift tree and adapter, feed tri-bore ESP lines through, N/U adapter and dry-hole tree. Test Hanger void to 500 psi/5min, 5000 psi/10 min - Good. Fill tree with diesel and test to 5000 psi. Good. Pull dart from BPV. Attempt to pull BPV and observing pressure beneath. Decision made to leave BPV installed. SimOps. Bridle up. Cont prep work on shaker beds for removal. Centrilift readings 3.6 ohm phase/phase, 4.68 G ohm phase/ground, 1267 psi, 49.2°. Secure Tree. Clean cellar of all fluid, gravel and debris. Secure Cellar area. Scope Derrick down, rig down and blow down service lines and prep rig for move. Release Rig at 06:00. _____________________________________________________________________________________ Revised By: DH 9/28/2021 SCHEMATIC Milne Point Unit Well: MP S-39 Last Completed: 8/29/2021 PTD: 208-183 TD =6,306’(MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.55’/ Orig. GL Elev.: 37.8’ Nabors 7ES 9-5/8 ” 3 7 11 14 12 13TOC @ 4,656’ MD 1 PBTD = 3,600’ (MD) / PBTD = 3,066’(TVD) 4 TAM Port Collar 987’ MD 9 10 15 8 6 5 2 7” Top CIBP @ 3,600’ WLM Top CIBP @ 4,581’ MD TOC @ 4,408’ MD JEWELRY DETAIL No. Top MD Item ID 1 3,132’ X-Nipple HES 4.562" XN profile w/ 4.455" no-go 4.455 2 3,185’ Bolt On Discharge Head: PMP 675 N/A 3 3,186’ Pump: HPHVMARC 035 HC20000ARC 316SS HD/BAS N/A 4 3,204’ Intake: HPINTXAR /HSEAL WC FER HV N/A 5 3,205’ Upper Tandem Seal: FER EHL INV CUW AB PFSA DS N/A 6 3,212’ Lower Tandem Seal: FER EHL SSCV INV INC CUW DS N/A 7 3,219’ Motor: 562XP 550/3830/88 458/3195 22R N/A 8 3,252’ Sensor: Zenith w/Centralizer: Btm @ 3,257’ N/A LOWER COMPLETION DETAIL 9 3,264’ 9-5/8” VGH Packer 6.000 10 3,330’ 5-1/2” GP Screens (250 Micron) Bottom @ 3,555’ 4.818 11 3,599’ Bull Nose Plug N/A 12 3,600’ Cast Iron Bridge Plug N/A 13 4,581’ Cast Iron Bridge Plug N/A 14 4,761’ 7” x 9-5/8” ‘C2’ ZXP LTP N/A 15 4,967’ ECP N/A TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' 0.0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 5-1/2” Liner 17 / L-80 / Vam Top 4.892 3,264’ 3,600’ 0.0232 TUBING DETAIL 5-1/2” Tubing 17 / L-80 / TC-II 4.892 Surface 3,257’ 0.0232 PERFORATION & 7” LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Prince Creek 3,358 3,586 2,894’ 3,056’ 228 4-5/8” Open Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Isolated 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Isolated GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String by Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 Perforate, Gravel pack and ESP Install by Innovation – 8/29/2021 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. Prince Creek 3,358 3,586 2,894’ 3,056’ 228 4-5/8” Open,,, ,p/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� (i. iC) L ' I� Z ( DATE: August 26, 2021 P.I. Supervisor FROM: Guy Cook Petroleum Inspector Section: 12 Township Drilling Rig: Innovation Rig Elevation Operator Rep: James Lott Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ Surface: 9 5/8" 0. D. Shoe@ Intermediate: 4408 ft MD- 0. D. Shoe@ Production: P&A: X 0. D. Shoe@ Liner: 7" 0. D. Shoe@ Tubing: 4.5" 0. D. Tail@ Plugging Data: Test Data: Remarks: SUBJECT: Plug Verification MPU S-39 Hilcorp Alaska LLC PTD 208183; Sundry 321-409 12N Range: 10E Meridian: Umiat 26.5 ft Total Depth: 6306 ft MD Lease No.: ADL0380109 4581 ft MD" 4408 ft MD- 15.8 ppg Suspend: P&A: X Casing Removal: 112 Feet Csg Cut@ Feet 4870 Feet Csg Cut@ Feet Feet Csg Cut@ Feet Feet Csg Cut@ Feet 6290 Feet Csg Cut@ Feet 4901 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm) Depth To MW Above Verified Perforation - Bridge plug - 4581 ft MD" 4408 ft MD- 15.8 ppg Drillpipe tag Initial 15 min 30 min 45 min Result Tubing IA 1691 1627 1573 P OA Hilcorp Rig Innovation; Reservoir abandonment plug; well to be perfed uphole as Water Supply Well. 8/25/2021 - Cement in place at 10:31 am; I arrived at location approximately 6:30 pm for plug tag. Expected tag depth at approximately 4444 ft MD . The rig stopped run in hole at 4519 ft MD, 62 ft above the CIBP. I called AOGCC Engineer Mel Rixse to inform him of the bad cement job. Left location. 8/26/2021 - Back out to tag cement plug. I was told that they tagged hard cement at 60 ft above the CIBP several hours after I left location last night. They pumped another 10 bbls of cement on top of the plug and let it cure for 12 hours. Tripped in well and tagged hard cement at 4408 ft MD with 15K lbs down weight on the cement with no sign of v movement. This gives them 173 feet of cement on top of the CIBP. They pulled up 10 feet and pressure tested the cement and casing. The 9 5/8 -inch casing is the only casing in the hole with the 7 -inch liner, tubing and packoff removed. The test results above in the IA column are for the casing test and reflect a pass.,— Attachments: None rev. 11-28-18 2021-0826_Plug _Verification_MPU_S-39_gc 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Install ESP Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Gravel Pack Other: Convert to WSW 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,306'N/A Casing Collapse Conductor N/A Surface 4,760psi Liner 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WSW Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng MILNE PT UNIT S-39 20AAC.25.055 ZXP LTP & ECP and N/A 4,761 MD/ 3,688 TVD & 4,967 MD/ 3,745 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/20/2021 4-1/2" Perforation Depth MD (ft): See Schematic See Schematic 112' 20" 9-5/8" 7" 4,833' 1,529' Perforation Depth TVD (ft): 6,870psi 7,240psi 3,720' 3,796' 4,870' 6,290' N/A Milne point / Tertiary Undefined WTRSP 112' 112' 12.6# / L-80 / IBT-M TVD Burst 4,901' MD N/A Length Size 3,796' 6,287' 3,795' 1,016 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 / ADL0380109 / ADL0380110 208-183 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23405-00-00 Hilcorp Alaska LLC Tubing Grade: Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:06 pm, Aug 19, 2021 321-409 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2021.08.19 14:58:26 -08'00' David Haakinson (3533) MGR20AUG2021 MGR20AUG2021 SFD DSR-8/19/21 Yes SFD 8/19/2021 20AUG2021 10-404 BOPE test to 3000 psi. Annular to 2500 psi. AOGCC witnessed tag and pressure test of reservoir abandonment plug to 1500 psi. SFD 8/20/2021 JLC 8/20/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.23 10:53:18 -08'00' RBDMS HEW 8/24/2021 Convert to WSW Well: MPU S-39 Date: 8/19/2021 Well Name:MPU S-39 API Number:50-029-23405-00 Current Status:Plugged Pad:S-Pad Estimated Start Date:August 20th, 2021 Rig:I-Rig Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:208-183 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:WSW Most recent SBHP:Plugged Back Not Perforated Maximum Expected BHP:1,321 psi @ 3,050’ TVD EMW = 8.30 ppg MPSP:1,016 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 95° @ 5,770’ Well PBMD; 66° @ 3,358’ top of proposed perfs Max Dogleg: 4.5°/100ft @ 1,593’ MD Brief Well Summary: Well S-39 was drilled as a Ugnu producer in 2011. A PCP artificial lift system was installed, and production data was obtained. The TBG in the original completion developed a shallow hole near 700’ MD. The completion string was pulled and replaced with a 4-1/2” kill string set at 4,899’ MD in 11/11/14. Prior to executing the work proposed below, the well will be plugged with cement. Notes Regarding the Well & Design x The S-39 suspended well application was submitted on separate 10-403 sundry. x Final reservoir abandonment plug required Objective: x Complete Reservoir abandonment plug (tag and pressure test) x Convert S-39 to WSW x Perforate the lower Prince Creek formation. x Gravel pack (GP) the Prince Creek formation. x Run 5-1/2” ESP completion. Pre-Rig Procedure: On Ugnu abandonment 10-403 sundry. Continued from step 25 of suspension sundry. RWO Procedure: 1. MIRU the I-Rig and ancillary equipment. RU hardline and returns tanks. 2. ND Tree. Inspect the lift threads on the tubing hanger. Install plug off tool into the BPV. 3. NU 13-5/8”, 5M BOP stack with 2-7/8” x 6” VBR’s. 4. Test BOPE to 250/3,000 psi and annular to 250/3,000 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Perform test per I-Rig BOPE test procedure. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR’s and annular with 3-1/2” and 5-1/2” test joints. Convert to WSW Well: MPU S-39 Date: 8/19/2021 e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5. RU to pull 4-1/2” tubing. 6. Pull plug off tool, check for pressure under the BPV and IA, if needed kill the well with KWF and pull the BPV. 7. MU the landing joint to the tubing hanger, BOLDS, unseat the tubing hanger and pull to the rig floor. 8. Lay down the landing joint and tubing hanger. a. Inspect the tubing hanger and note any corrosion or damage. b.Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 9.MU cross over from the 4-1/2” TBG to the drill pipe, RIH with 1 joint of DP, setting the EOT at +/- 4,900’ MD. 10.Establish circulation down the TBG taking returns up the IA confirming the wellbore is fluid packed. 11.RU Cementers and pump 25 BBLs 15.8 PPG Class G cement down the TBG spotting a balanced cement plug from 4,900’ MD to planned TOC of 4,600’ MD. 12.Pull the EOT up to 4,400’ MD and reverse circulate the TBG clear. Note any cement in the returns. 13.POOH laying down the 4-1/2” tubing removing all jewelry as it presents itself. 14.PU and MU bit and 9-5/8” CSG scraper. TIH to clean the casing for the gravel pack assembly and tag the TOC. Pressure test the Reservoir abandonment cement plug to 1,500 psi for 30 min (charted). (Notify AOGCC 24 hrs in advance to witness the cement tag and pressure test) 15.TOOH with the scraper BHA. 16. RU E-line. PU and MU 9-5/8” CIBP assembly. 17. RIH, correlate CIBP on depth set the CIBP at ±3,600’ MD. Tag top of CIBP. POOH & RD E-line. 18. RD 4-1/2” handling equipment. Install the wear bushing. RU 5” DP handling equipment. 19. Shut blind rams, pressure test casing to 3,000 psi for 10 min. Convert to WSW Well: MPU S-39 Date: 8/19/2021 20. PU and MU TCP gun assembly per HES representative (228’ of guns). 21. RIH with TCP gun assembly on 5” DP to ~3,586’ MD @ 100fpm. 22. Lightly tag the CIBP set at ±3,600’ MD. 23. PU and space out to place the guns on depth. If needed use E-line to correlate on depth. a. Perforation intervals: 3,586’ to 3,358’ MD. 24. Close the annular or UPR. Drop activation ball and allow the ball to gravitate to seat. Pressure up on the DP to ~2,500 psi to fire the guns. 25. Check for pressure under the annular and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow (the well should go on a slight vac). Circ across the top of hole if needed. 26. Circulate a bottom up. Ensure the well is static or on a slight vac (contact town engineer if the well goes on a significant vac). 27. PU to ensure the guns are free then RIH to tag and note depth. Compare previous tag depth to determine if any perforation debris or sand influx. A cleanout may be need it the perforations are covered with sand. This tag depth will be used to space out the GP screens. 28. TOOH with 5” DP and lay down spent TCP gun assembly. 29. PU, MU and RIH with the following gravel pack assembly: a. Round solid nose shoe with 10’ handling pup, 5-1/2”, 17#, L-80, LTC Box x Pin b. (6) Gravel pack screen joints (250 micron), 5-1/2”, 17#, L-80, LTC Box x Pin c. (2) 5-1/2” blank joints, 5-1/2”, 17#, L-80, LTC Box x Pin 30. Recommended MU Torque for 5-1/2”, 17#, L-80, LTC = 3,410 ft-lbs 31. RU false rotary table and change handling equipment to 3-1/2”. 32. PU, MU and RIH with 3-1/2”, 9.2#, P110, Hydril 511 inner string. 33. Recommended MU Torque for 3-1/2”, 9.2#, P110, Hydril 511 = 1,400 ft-lbs 34. PU the gravel pack packer assembly. MU the 3-1/2” inner string to the running tool and MU the packer assembly to the blank joint. 35. RD false rotary table. 36. TIH with the gravel pack assembly on 5” DP to just above the perforations. 37. Reverse circulate 1.5 DP volume at 2 BPM (max) to ensure DP is clear. 38. Continue to RIH with the gravel pack assembly to just above tag post perforating (step 10). 39. Tag the top of the CIBP and PU to place the gravel pack assembly on depth (ensure the packer is above the perforations). 40. PU to neutral weight and drop 1-3/4” setting ball. Allow time for the ball to gravitate to the ball seat. 41. Pressure up and set the gravel pack packer per HES representative. Note: Packer initiation setting pressure = 1840 psi and final set pressure = 3121 psi. 42. PT the IA to 1000 psi for 10 minutes (charted). Continue to pressure up on the IA to 2500 psi to burst the rupture disc. Bleed the IA to 0 psi. 43. Pressure up on the DP to 3,000 psi and slowly PU to release the running tool. Once it is verified the running tool is release bleed the DP to 0 psi. 44. PU to reverse position. Slowly pressure up to 4,700 psi (± 500 psi) to shear the ball seat. Convert to WSW Well: MPU S-39 Date: 8/19/2021 45. SO, set down 30K and mark the pipe as circulating position. PU the string weight, close the annular and pressure up the IA to 500 psi. Slowly strip through the annular until the IA pressure dumps, stop and mark the pipe as reverse position. Ensure the IA pressure is 0 psi and open the annular. 46. With the running tool in the reverse position, pump 6.2 bbls of pickle (15% HCl) displace down to the DP crossover with 8.8 ppg brine with 2% KCl. 47. Line up to take return from the DP. Reverse circulate out the pickle to the flow back tank. 48. SO to circulating position and perform injection step rate test at 1, 2, 4 & 6 BPM. Shut down and monitor the tubing and casing pressures. 49. Pump the gravel pack with proppant per HES representative. 50. PU to reverse position and reverse circulate until returns are clean (2 BU minimum). 51. Slowly PU and shift the MCS sleeve closed. 52. POOH laying down the 5” DP and lay down the running tool. 53. Change handling equipment to 3-1/2”. POOH laying down 3-1/2” inner string. 54. RU to run 5-1/2” ESP completion. Pull the wear ring. 55. RIH with the following ESP completion equipment to ~3,255’ MD installing cross coupling clamps on every connection: a. Centralizer b. Motor Gauge, Zenith c. ESP motor #1, 550HP d. Lower tandem seal e. Upper tandem seal f. Intake g. 26 Stage HC20000 Pump h. Discharge Head, 5-1/2”, 17#, L-80, LTC box up i. Crossover, 5-1/2”, 17#, L-80 IBT Box x LTC Pin j. 1 joint, 5-1/2”, 17#, L-80 IBT Box x Pin k. Nipple, HES, 4.562” X Profile, 10’ handling pups above and below. 56. MU the first 15 joint to the base of the stamped triangle taking note of the required torque for each connection. Calculate the average torque and use that MU torque on the remaining connection. 57. Continue to RIH with the ESP completion on 5-1/2”, 17#, L-80, IBT tubing. 58. PU and MU the tubing hanger with the landing joint. Terminate the ESP cable and splice to the penetrator. Ensure all control line ports are dummied off. a. Tubing Hanger, FMC TC-1A-EMS, 11” x 5-1/2” TC-II top and bottom with 5” H BPVG b. Crossover Pup, 5-1/2”, 17#, L-80 TC-II Pin x IBT Pin 59. Land the tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. 60. Install the TWC. 61. ND the BOP stack. 62. NU the tubing head adapter and PT the tubing hanger void to 250/5000 psi. 63. NU the tree and PT the tree to 250/5000 psi. Convert to WSW Well: MPU S-39 Date: 8/19/2021 64. Install gauges on the tree and secure the cellar. Freeze Protect the well. Release and RDMO Innovation Rig. 65. Turn the well over to operations via handover form. Attachments: 1. Current schematic 2. Proposed schematic 3. BOP Schematic _____________________________________________________________________________________ Revised By TDF 9/18/2019 SCHEMATIC Milne Point Unit Well: MPU S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’ (MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.45’/ GL Elev.: 37.8(N7ES) 7” 9-5/8 ” 1 Tam Port Collar @ 987’ PBTD =6,287’ (MD) / PBTD =3,795’(TVD) 2 3 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II & IBT-M 3.958 Surface 4,901’ 0.00152 JEWELRY DETAIL No Depth Item 1 4,888’ 4-1/2” XN Nipple w/3.725” No-Go 2 4,899’ WLEG –Bottom @ 4,901’ 3 4,967’ ECP 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Open 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Open 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. _____________________________________________________________________________________ Revised By: TDF 7/13/2021 PROPOSED Milne Point Unit Well: MP S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’(MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.55’/ Orig. GL Elev.: 37.8’ Nabors 7ES 9-5/8 ” 3 7 14 17 15 16 Estimated TOC @ ±4,600’ 1 PBTD =±4,600’ (MD) / PBTD =±3,631’(TVD) 4 4-1/2” Tubing Cut @ ±4,000’ TAM Port Colalr 987’ MD 9 10 11, 12 & 13 8 6 5 2 7” Top CIBP @ ±3,600’ JEWELRY DETAIL No. Top MD Item ID 1 ±3,210’ X-Nipple HES 4.562" XN profile w/ 4.455" no-go 4.562 2 ±3,226 Discharge Head: N/A 3 ±3,227’ Pump: N/A 4 ±3,245’ Intake: N/A 5 ±3,247’ Upper Tandem Seal: N/A 6 ±3,255’ Lower Tandem Seal: N/A 7 ±3,263’ Motor: N/A 8 ±3,298’ Sensor: Zenith w/Centralizer: Btm @ 3,255’ N/A LOWER COMPLETION DETAIL 9 ±3,328’ 9-5/8” Versa-Trieve Packer TBD 10 ±3,352’ 7-5/8” x 5-1/2 Crossover” TBD 11 ±3,354’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe TBD 12 ±3,360’ 5-1/2” Gravel Pack Screens (250 Micron) TBD 13 ±3,770’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe TBD 14 ±3,590’ Bull Nose Plug N/A 15 ±3,600 CIBP N/A 16 4,761’ 7” x 9-5/8” ‘C2’ ZXP LTP N/A 17 4,967 ECP N/A TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 5-1/2” Tubing 12.6 / L-80 / TC-II 4.892 Surface ±3,255’ 0.00232 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Prince Creek ±3,358 ±3,586 ±2,894’ ±3,056’ ±228 TBD Future Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Isolated 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Isolated 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. Innovation Rig BOP Schematic 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Install ESP Suspend Perforate Other Stimulate Pull Tubing Gravel Pack Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to WSW 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,306'N/A Casing Collapse Conductor N/A Surface 4,760psi Liner 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade:Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 / ADL0380109 / ADL0380110 208-183 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23405-00-00 Hilcorp Alaska LLC Length Size 3,796' 6,287' 3,795' 1,016 N/A Milne point / Tertiary Undefined WTRSP 112' 112' 12.6# / L-80 / IBT-M TVD Burst 4,901' MD N/A 6,870psi 7,240psi 3,720' 3,796' 4,870' 6,290' Perforation Depth MD (ft): See Schematic See Schematic 112' 20" 9-5/8" 7" 4,833' 1,529' Perforation Depth TVD (ft): MILNE PT UNIT S-39 20AAC.25.055 ZXP LTP & ECP and N/A 4,761 MD/ 3,688 TVD & 4,967 MD/ 3,745 TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 8/15/2021 4-1/2" ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 10:54 am, Jul 20, 2021 321-356 Chad Helgeson (1517) 2021.07.19 16:22:58 - 08'00' X BOPE test to 3000 psi. Annular to 2500 psi. 10-404 PDLB DLB 0720/2021 DSR-7/21/21MGR22JUL21dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 16:45:11 -08'00' RBDMS HEW 7/26/2021 Convert to WSW Well: MPU S-39 Date: 7/13/2021 Well Name:MPU S-39 API Number:50-029-23405-00 Current Status:Plugged Pad:S-Pad Estimated Start Date:August 15th, 2021 Rig:I-Rig Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:208-183 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:WSW Most recent SBHP:Plugged Back Not Perforated Maximum Expected BHP:1,321 psi @ 3,050’ TVD EMW = 8.30 ppg MPSP:1,016 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 95° @ 5,770’ Well PBMD ; 66° @ 3,358’ top of proposed perfs Max Dogleg: 4.5°/100ft @ 1,593’ MD Brief Well Summary: Well S-39 was drilled as a Ugnu producer in 2011. A PCP artificial lift system was installed, and production data was obtained. The TBG in the original completion developed a shallow hole near 700’ MD. The completion string was pulled and replaced with a 4-1/2” kill string set at 4,899’ MD in 11/11/14. Prior to executing the work proposed below, the well will be plugged with cement. Notes Regarding the Well & Design x The S-39 suspended well application was submitted on separate 10-403 sundry. Objective: x Convert S-39 to WSW x Perforate the lower Prince Creek formation. x Gravel pack (GP) the Prince Creek formation. x Run 5-1/2” ESP completion. Pre-Rig Procedure: On Ugnu abandonment 10-403 sundry. Continued from step 25 of suspension sundry. RWO Procedure: 1. MIRU the I-Rig and ancillary equipment. RU hardline and returns tanks. 2. ND Tree. Inspect the lift threads on the tubing hanger. Install plug off tool into the BPV. 3. NU 13-5/8”, 5M BOP stack with 2-7/8” x 6” VBR’s. 4. Test BOPE to 250/3,000 psi and annular to 250/3,000 psi. a. Notify the AOGCC 24 hours in advance of BOP test. b. Perform test per I-Rig BOPE test procedure. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR’s and annular with 3-1/2” and 5-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails work proposed below, the well will be plugged with cement. Prior to executing the Note DLB -00 DLB Convert to WSW Well: MPU S-39 Date: 7/13/2021 a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test if test witness was waived. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 5. RU to pull 4-1/2” tubing. 6. Pull plug off tool, check for pressure under the BPV and IA, if needed kill the well with KWF and pull the BPV. 7. MU the landing joint to the tubing hanger, BOLDS, unseat the tubing hanger and pull to the rig floor. 8. Lay down the landing joint and tubing hanger. a. Inspect the tubing hanger and note any corrosion or damage. b.Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger or test plug in tubing head. Test BOPE per standard procedure and sundry. 9. POOH laying down the 4-1/2” tubing removing all jewelry as it presents itself. 10. RU E-line. PU and MU 9-5/8” CIBP assembly. 11. RIH, correlate CIBP on depth set the CIBP at ±3,600’ MD. Tag top of CIBP. POOH & RD E-line. 12. RD 4-1/2” handling equipment. Install the wear bushing. RU 5” DP handling equipment. 13. Shut blind rams, pressure test casing to 3,000 psi for 10 min. 14. PU and MU TCP gun assembly per HES representative (228’ of guns). 15. RIH with TCP gun assembly on 5” DP to ~3,586’ MD @ 100fpm. 16. Lightly tag the CIBP set at ±3,600’ MD. 17. PU and space out to place the guns on depth. If needed use E-line to correlate on depth. a. Perforation intervals: 3,586’ to 3,358’ MD. 18. Close the annular or UPR. Drop activation ball and allow the ball to gravitate to seat. Pressure up on the DP to ~2,500 psi to fire the guns. 19. Check for pressure under the annular and bleed to 0 psi if needed. Open the annular or UPR and observe the well for flow (the well should go on a slight vac). Circ across the top of hole if needed. 20. Circulate a bottom up. Ensure the well is static or on a slight vac (contact town engineer if the well goes on a significant vac). Convert to WSW Well: MPU S-39 Date: 7/13/2021 21. PU to ensure the guns are free then RIH to tag and note depth. Compare previous tag depth to determine if any perforation debris or sand influx. A cleanout may be need it the perforations are covered with sand. This tag depth will be used to space out the GP screens. 22. TOOH with 5” DP and lay down spent TCP gun assembly. 23. PU, MU and RIH with the following gravel pack assembly: a. Round solid nose shoe with 10’ handling pup, 5-1/2”, 17#, L-80, LTC Box x Pin b. (6) Gravel pack screen joints (250 micron), 5-1/2”, 17#, L-80, LTC Box x Pin c. (2) 5-1/2” blank joints, 5-1/2”, 17#, L-80, LTC Box x Pin 24. Recommended MU Torque for 5-1/2”, 17#, L-80, LTC = 3,410 ft-lbs 25. RU false rotary table and change handling equipment to 3-1/2”. 26. PU, MU and RIH with 3-1/2”, 9.2#, P110, Hydril 511 inner string. 27. Recommended MU Torque for 3-1/2”, 9.2#, P110, Hydril 511 = 1,400 ft-lbs 28. PU the gravel pack packer assembly. MU the 3-1/2” inner string to the running tool and MU the packer assembly to the blank joint. 29. RD false rotary table. 30. TIH with the gravel pack assembly on 5” DP to just above the perforations. 31. Reverse circulate 1.5 DP volume at 2 BPM (max) to ensure DP is clear. 32. Continue to RIH with the gravel pack assembly to just above tag post perforating (step 10). 33. Tag the top of the CIBP and PU to place the gravel pack assembly on depth (ensure the packer is above the perforations). 34. PU to neutral weight and drop 1-3/4” setting ball. Allow time for the ball to gravitate to the ball seat. 35. Pressure up and set the gravel pack packer per HES representative. Note: Packer initiation setting pressure = 1840 psi and final set pressure = 3121 psi. 36. PT the IA to 1000 psi for 10 minutes (charted). Continue to pressure up on the IA to 2500 psi to burst the rupture disc. Bleed the IA to 0 psi. 37. Pressure up on the DP to 3,000 psi and slowly PU to release the running tool. Once it is verified the running tool is release bleed the DP to 0 psi. 38. PU to reverse position. Slowly pressure up to 4,700 psi (± 500 psi) to shear the ball seat. 39. SO, set down 30K and mark the pipe as circulating position. PU the string weight, close the annular and pressure up the IA to 500 psi. Slowly strip through the annular until the IA pressure dumps, stop and mark the pipe as reverse position. Ensure the IA pressure is 0 psi and open the annular. 40. With the running tool in the reverse position, pump 6.2 bbls of pickle (15% HCl) displace down to the DP crossover with 8.8 ppg brine with 2% KCl. 41. Line up to take return from the DP. Reverse circulate out the pickle to the flow back tank. 42. SO to circulating position and perform injection step rate test at 1, 2, 4 & 6 BPM. Shut down and monitor the tubing and casing pressures. 43. Pump the gravel pack with proppant per HES representative. 44. PU to reverse position and reverse circulate until returns are clean (2 BU minimum). 45. Slowly PU and shift the MCS sleeve closed. 46. POOH laying down the 5” DP and lay down the running tool. Assure standing orders understood for shutting in well while picking up liner and inner string. Assure well fluid level. Maintain overbalance. Convert to WSW Well: MPU S-39 Date: 7/13/2021 47. Change handling equipment to 3-1/2”. POOH laying down 3-1/2” inner string. 48. RU to run 5-1/2” ESP completion. Pull the wear ring. 49. RIH with the following ESP completion equipment to ~3,255’ MD installing cross coupling clamps on every connection: a. Centralizer b. Motor Gauge, Zenith c. ESP motor #1, 550HP d. Lower tandem seal e. Upper tandem seal f. Intake g. 26 Stage HC20000 Pump h. Discharge Head, 5-1/2”, 17#, L-80, LTC box up i. Crossover, 5-1/2”, 17#, L-80 IBT Box x LTC Pin j. 1 joint, 5-1/2”, 17#, L-80 IBT Box x Pin k. Nipple, HES, 4.562” X Profile, 10’ handling pups above and below. 50. MU the first 15 joint to the base of the stamped triangle taking note of the required torque for each connection. Calculate the average torque and use that MU torque on the remaining connection. 51. Continue to RIH with the ESP completion on 5-1/2”, 17#, L-80, IBT tubing. 52. PU and MU the tubing hanger with the landing joint. Terminate the ESP cable and splice to the penetrator. Ensure all control line ports are dummied off. a. Tubing Hanger, FMC TC-1A-EMS, 11” x 5-1/2” TC-II top and bottom with 5” H BPVG b. Crossover Pup, 5-1/2”, 17#, L-80 TC-II Pin x IBT Pin 53. Land the tubing hanger with extreme caution to avoid damaging the ESP cable or penetrator. RILDS. 54. Install the TWC. 55. ND the BOP stack. 56. NU the tubing head adapter and PT the tubing hanger void to 250/5000 psi. 57. NU the tree and PT the tree to 250/5000 psi. 58. Install gauges on the tree and secure the cellar. Freeze Protect the well. Release and RDMO Innovation Rig. 59. Turn the well over to operations via handover form. Attachments: 1. Current schematic 2. Proposed schematic 3. BOP Schematic 4. Blank RWO MOC Form _____________________________________________________________________________________ Revised By TDF 9/18/2019 SCHEMATIC Milne Point Unit Well: MPU S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’ (MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.45’/ GL Elev.: 37.8(N7ES) 7” 9-5/8 ” 1 Tam Port Collar @ 987’ PBTD =6,287’ (MD) / PBTD =3,795’(TVD) 2 3 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II & IBT-M 3.958 Surface 4,901’ 0.00152 JEWELRY DETAIL No Depth Item 1 4,888’ 4-1/2” XN Nipple w/3.725” No-Go 2 4,899’ WLEG –Bottom @ 4,901’ 3 4,967’ ECP 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Open 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Open 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. _____________________________________________________________________________________ Revised By: TDF 7/13/2021 PROPOSED Milne Point Unit Well: MP S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’(MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.55’/ Orig. GL Elev.: 37.8’ Nabors 7ES 9-5/8 ” 3 7 14 17 15 16 Estimated TOC @ ±4,600’ 1 PBTD =±4,600’ (MD) / PBTD =±3,631’(TVD) 4 4-1/2” Tubing Cut @ ±4,000’ TAM Port Colalr 987’ MD 9 10 11, 12 & 13 8 6 5 2 7” Top CIBP @ ±3,600’ JEWELRY DETAIL No. Top MD Item ID 1 ±3,210’ X-Nipple HES 4.562" XN profile w/ 4.455" no-go 4.562 2 ±3,226 Discharge Head: N/A 3 ±3,227’ Pump: N/A 4 ±3,245’ Intake: N/A 5 ±3,247’ Upper Tandem Seal: N/A 6 ±3,255’ Lower Tandem Seal: N/A 7 ±3,263’ Motor: N/A 8 ±3,298’ Sensor: Zenith w/Centralizer: Btm @ 3,255’ N/A LOWER COMPLETION DETAIL 9 ±3,328’ 9-5/8” Versa-Trieve Packer TBD 10 ±3,352’ 7-5/8” x 5-1/2 Crossover” TBD 11 ±3,354’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe TBD 12 ±3,360’ 5-1/2” Gravel Pack Screens (250 Micron) TBD 13 ±3,770’ Blank Pipe, 5-1/2”, 17#, L-80, LTC Blank Pipe TBD 14 ±3,590’ Bull Nose Plug N/A 15 ±3,600 CIBP N/A 16 4,761’ 7” x 9-5/8” ‘C2’ ZXP LTP N/A 17 4,967 ECP N/A TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 5-1/2” Tubing 12.6 / L-80 / TC-II 4.892 Surface ±3,255’ 0.00232 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Prince Creek ±3,358 ±3,586 ±2,894’ ±3,056’ ±228 TBD Future Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Isolated 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Isolated 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. Milne Point Unit MP S-39 Convert to WSW Innovation BOP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CT Cement 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 6,306'N/A Casing Collapse Conductor N/A Surface 4,760psi Liner 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade:Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 / ADL0380110 208-183 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23405-00-00 Hilcorp Alaska LLC Length Size 3,796' 6,287' 3,795' 1,432 N/A UGNU UNDEFINED OIL 112' 112' 12.6# / L-80 / IBT-M TVD Burst 4,901' MD N/A 6,870psi 7,240psi 3,720' 3,796' 4,870' 6,290' Perforation Depth MD (ft): See Schematic See Schematic 112' 20" 9-5/8" 7" 4,833' 1,529' Perforation Depth TVD (ft): MILNE PT UNIT S-39 20AAC.25.055 ZXP LTP & ECP and N/A 4,761 MD/ 3,688 TVD & 4,967 MD/ 3,745 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 7/23/2021 4-1/2" ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:21 am, Jul 13, 2021 321-345 Chad Helgeson (1517) 2021.07.12 14:28:41 - 08'00' State witnessed tag and pressure test reservoir abandonment plug to 1500 psi. X DSR-7/13/21DLB 07/13/2021 MGR14JUL21 10-404 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 11:16:59 -08'00' RBDMS HEW 7/22/2021 Suspend SB Sands Well: MPU S-39 Date: 7/12/2021 Well Name:MPU S-39 API Number:50-029-23405-00 Current Status:SI – Ugnu Producer Pad:S-Pad Estimated Start Date:July 23rd, 2021 Rig:CT#6 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:208-183 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) AFE Number:Job Type:Suspend Ugnu Sands Most recent SBHP:1,804 psi @ 3,717’ TVD EMW = 9.30 ppg Maximum Expected BHP:1,804 psi @ 3,717’ TVD EMW = 9.30 ppg MPSP:1,432 psi Gas Column Gradient = 0.1 psi/ft Max Inclination 95° @ 5,770’ MD Max Dogleg:8.9°/100ft @ 5,707’ MD Brief Well Summary: Well S-39 was drilled as an Ugnu producer in 2011. An PCP artificial lift system was installed, and production data was obtained. The TBG in the original completion developed a shallow hole near 700’ MD. The completion string was pulled and replaced with a 4-1/2” kill string set at 4,899’ MD in 11/11/014. The well has been suspended. Objective: CTU x Plug the Ugnu sand with cement deployed with coil. x Lay in CMT in the lateral section up to the 4-1/2” TBG tail. x Rigless, spot a balanced CMT plug around the TBG tail and into the 9-5/8” CSG, isolating the 7” liner top. x Pressure test the 9-5/8” CSG to 2,000 psi. x Cut the tubing above TOC. x Convert S-39 to WSW (separate sundry to be submitted). CTU Procedure: 1. MIRU CTU with 1-3/4” or 2” coil and spot ancillary equipment. 2. Pressure test BOPE to 3,000/250 psi. a. Each subsequent test of the lubricator will be to 3,000/250 psi to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7-day test BOPE test period for Milne Point, 3. MU ball drop cementing nozzle and RIH to 6,287’ MD. 4. Mix and pump 53 bbls of 15.8 ppg class G cement with spacers. a. 7” liner vol: 0.0383 X (6,287’-4,899’) = ~53 bbls 5. Lay a balanced cement plug in the 7” liner while TOOH with the coil to the EOT at 4,899’ MD. 6. Contaminate the CMT 25’ below the TBG tail at 4,924’ MD and up into the TBG. -00 DLB Suspend SB Sands Well: MPU S-39 Date: 7/12/2021 7. Swap to contaminate and RIH to circulate to 4,924’ MD (planned TOC 128’ above top of slotted liner). Circulate a minimum 3x bottoms up. 8. Circulate tubing on entire trip back out of hole to clean up wellbore. Hold constant ECD to prevent reservoir backflow or cement flow into the reservoir 9. POOH and lay down the cementing BHA. a. Freeze protect well on way out of hole 10. RDMO CTU (pending CTU availability the remaining steps may be completed with CTU or other services described below.). Post-CTU Procedure: 11. MIRU RU Slickline. 12. RIH and tag top of cement. a. Ensure cement top is above slotted liner top @ 5,072’. Contact Engineer if cement top is below 4,972’. 13. RD Slickline 14. RU Pump Unit and surface tanks. 15. Pressure test the cement to 1,500 psi for 30 minutes (charted). a. If the pressure test of the cement plug fails, contact the Operations Engineer to discuss additional cement options. b. Notify AOGCC 24 hours in advance to witness tag with slickline and pressure test. Contingency steps (16-19): If cement does not cover slotted liner by 100ft as per 20 AAC 25.112 (d) 16. Establish circulation down the TBG and up the IA, circulate the wellbore until clean source water in and out. 17. Mix and pump balanced cement plug with 17 bbls of 15.8 ppg class G cement with spacers, spotting 12 BBLS of CMT outside the TBG and leaving 5 BBLS CMT balanced inside the TBG. Estimated TOC at 4,600’ MD providing +/- 161’ of CMT isolation covering the top of the 7” liner top and above the slotted liner. 18. RU e-line, Pressure test BOPE to 3,000/250 psi 19. RIH and tag the TOC (ensure cement had 24 hrs. to set). PT the cement plug IA/TBG to 2,000 psi for 30 minutes (charted). a.Notify the AOGCC 24 hours in advance to witness the tag and PT b.Verify cement top on IA of tubing with CBL. Continuation of Full Procedure: 20. PU, MU and RIH with jet or chemical cutter with CCL. Cut the 4-1/2” tubing at ~4,000’ MD. 21. RD E-line. 22. RU LRS pumping equipment and flow back tanks. 23. Bleed pressure off the tubing and IA if needed. Freeze protect the IA/TBG down to 2,000’ MD. 24. RD LRS equipment. 25. Set HP BPV. Attachments: 1. Current schematic 2. Proposed schematic #1 & #2 If passing pressure test on step 15 above, no witness required for pressure test of second cement plug. Tag with eline to be witnessed. Suspend SB Sands Well: MPU S-39 Date: 7/12/2021 3. CTU BOP Schematic _____________________________________________________________________________________ Revised By TDF 9/18/2019 SCHEMATIC Milne Point Unit Well: MPU S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’ (MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.45’/ GL Elev.: 37.8(N7ES) 7” 9-5/8 ” 1 Tam Port Collar @ 987’ PBTD =6,287’ (MD) / PBTD =3,795’(TVD) 2 3 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II & IBT-M 3.958 Surface 4,901’ 0.00152 JEWELRY DETAIL No Depth Item 1 4,888’ 4-1/2” XN Nipple w/3.725” No-Go 2 4,899’ WLEG –Bottom @ 4,901’ 3 4,967’ ECP 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Open 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Open 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. _____________________________________________________________________________________ Revised By CAH 7/12/2021 PROPOSED #1 Milne Point Unit Well: MPU S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’ (MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.45’/ GL Elev.: 37.8(N7ES) 7” 9-5/8 ”1 Tam Port Collar @ 987’ ±4,000’ MD PBTD =6,287’ (MD)/ PBTD= 3,795’(TVD) 2 3 ±4,972’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II & IBT-M 3.958 Surface 4,901’ 0.00152 JEWELRY DETAIL No Depth Item 1 4,888’ 4-1/2” XN Nipple w/3.725” No-Go 2 4,899’ WLEG –Bottom @ 4,901’ 3 4,967’ ECP 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Open 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Open 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. _____________________________________________________________________________________ Revised By DG 7/9/2021 PROPOSED #2 Milne Point Unit Well: MPU S-39 Last Completed: 1/14/2014 PTD: 208-183 TD =6,306’ (MD) / TD =3,796’(TVD) 20” Orig. KB Elev.: 72.45’/ GL Elev.: 37.8(N7ES) 7” 9-5/8 ” 1 Tam Port Collar @ 987’ ±4,000’ MD PBTD =6,287’ (MD) / PBTD= 3,795’(TVD) 2 3 ±4,600’ MD CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 / Welded Insul. N/A Surface 112' .0355 9-5/8" Surface 47 / L-80 / BTC 8.681 Surface 4,870’ 0.0732 7" Liner 26 / L-80 / BTC 6.276 4,761’ 6,290’ 0.0383 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TC-II & IBT-M 3.958 Surface 4,901’ 0.00152 JEWELRY DETAIL No Depth Item 1 4,888’ 4-1/2” XN Nipple w/3.725” No-Go 2 4,899’ WLEG –Bottom @ 4,901’ 3 4,967’ ECP 7” SLOTTED LINER DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Status Ugnu Sands 5,072’ 5,233’ 3,768’ 3,797’ 161 0.028 Open 5,681’ 6,247’ 3,812’ 3,794’ 566 0.028 Open 26# /L-80 / BTC Slotted Liner – 727’ 0.028 slots @ 188 SPF OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset I (Approx) in a 48” Hole 9-5/8" 626 sx Arcticset Lite, 111 sx DeepCrete in a 12-1/4” Hole TREE & WELLHEAD Wellhead FMC Gen 5 11” x 4-1/16” 5M Radigan Wellhead w/ Dual Rod Rams Tubing Head 11” v 4-1/2”, FMC Tbg Hgr 4” CIW Profile & 4.5” TC-II T&B thread GENERAL WELL INFO API: 50-029-23405-00-00 Drilled and Set Kill String bt Doyon 14 – 1/9/2009 Drill and Complete by Nabors 7ES – 11/14/2011 9-5/8” Casing Tested to1,500psi – 9-22-2012 CoRod Pull & RWO by Doyon 14 – 9/24/2012 Install Kill String by Doyon 16 – 1/15/2014 NOTES 7.3” ID Isolation Sleeve Installed in Casing Spool. Tubing and Casing Spool Outlets Both Access IA TAM Port Collar is at 18° inclination. It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. Reservoir Abandonment Well: MPU S-39 06/04/2021 COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic END 2-02 30 X 20 X 13д X 9з X 7 X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2д" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union XHVZE Organizing (done) REST AN NOTES: BY: Project Proofing BY: Date: BY: Maria Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: • • Image Project Well History File Cover Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 0 3 - 1 a 3 Well History File Identifier ❑ Two -sided III I111111 IIII ❑ Rescan Needed III I11111 I DIGITAL DATA Color Items: ❑ Diskettes, No. ❑ Greyscale Items: Other, No/Type: c y '7� No 1 ❑ Poor Quality Originals: ❑ Other: Date: I /o Scanning Preparation x 30 = 0 BY: Maria Date: qPill Production Scanning I Stage 1 Page Count from Scanned File: ( 3 (Count does include comer sheet) Page Count Matches Number in Scanning Preparation: Date: (/a PO 1 OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non - Scannable) ❑ Logs of various kinds: ❑ Other:: /s/ /s/ hill 111 a., = TOTAL PAGES tU tg- (Count does not include cover sheet) vv /s /s/ . 1111 111 BY: Maria Date: /s/ Quality Checked III YES NO 1 If NO in stage 1, page(s) discrepancies were found: YES NO /s/ II 1111 VIII 1111 IU H 11 UI 1 1111 11 10/6/2005 Well History File Cover Page.doc it • (s)"I j� 4'6.9 THE STATE Alaska Oil and Gas ��'"' °fALASKA Conservation Commission ~ *ti GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 -ALA y�F� Main: 907.279.1433 Fax: 907.276.7542 Is Sean McLaughlin wip;\( 2 ® `��1 Engineering Team Leader 034/4 13 BP Exploration (Alaska), Inc. VC -5 P.O. Box 196612 Q � Anchorage, AK 99519-6612 Re: Milne Point Field, Ugnu Undefined Pool, MPS-39 Sundry Number: 313-647 Dear Mr. McLaughlin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A)73.. c/ tom_ Cathy P. Fe erster Chair DATED this lay of January, 2014. Encl. STATE OF ALASKA �4, ( s=tt = : .. ALASKA OIL AND GAS CONSERVATION COMMIS0iON l ," ... ,; APPLICATION FOR SUNDRY APPROVAL DEC 2 6 Z.Ok 20 AAC 25.280 j r.S 117 (3 1. Type of Request: program �+ ❑Suspend 0 Plug Perforations 0 Perforate • 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other Pull PCP Rotor&Corod 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. . 0 Exploratory 0 Stratigraphic 208-183 • 3. Address: 6. API Number: e,Alaska 99519-6612 '®Development ❑Service P.O. Box 196612,Anchorage, 50.029-23405-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPS-39• Will planned perforations require a Spacing Exception? 0 Yes No / 9. Property Designatior 10. Field/Pool(s): ADL 380109&380110 • Milne Point Unit/Ugnu Undefined - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6306' - 3796' • 6287' • 3795' - None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4833' 9-5/8" 37'-4870' 37'-3721' 6870 4760 Intermediate Production Liner 1529' 7" 4761-6290' 3688'-3796' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5072'-6247' • 3768'-3794' 4-1/2", 12.6# L-80 4965' Packers and SSSV Type: 7"x 9-5/8"C2 ZXP Liner Top Packer Packers and SSSV •4761'/3688' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 11 Stratigraphic•®Development El Service 14. Estimated Date for 4I3,,D Z0ly 15. Well Status after proposed work: Commencing Operation: Z�'13 I • 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin,564-4387 Printed Name S e.0‘,11 CA'L tA-0,5 Y1 I,r\ Title: Engineering Team Leader Email: Sean.McLaughlin@bp.com Signature: c...,,,„ ,A(i - .l Phone: 564-5683 Date: I 212,4/ 13 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `2 \'2—4.4:1 j1, ❑ Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 80p �t.5, 1. lo 3500C'5 / /r RBDMSzfkil4AY U 9 2014 Spacing Exception Required? 0 Yes 2No Subsequent Form Required: //, _ q Q Approved By: (I COMMISSIONER THE COMMISSION Date: / " 7—l 1( Form 10-403 Revised 10/ 12/ Appro d r 2 months from the date of approval Submit In Duplicate V ' ' 1 l q-! l i ORfli 1 M L ply 10,1,1 l i b �,,�i/2,/j/�T s. 6p Sundry Request for ESP Pull Well: MPS-39 Date: 12/18/2013 Engineer: J.E.B. Bolen MASP: 1123 psi Well Type: Producer Estimated Start date: January 30, 2014 History: MPS-39 was initially drilled to TD of 9881' MD in January, 2009. It was left suspended with a kill string after setting casing at 9865' MD. In November, 2011, the well was completed. The 9 5/8"shoe track was drilled out. The well was drilled to a TD of 6306'with 655'of net pay with no losses reported. It was circulated over to fresh LSND mud, and completed with a 7" slotted liner with two sets of slots. A Baker external casing packer was installed above the upper set of slots. MPS-39 was POP in April, 2012 when the CHOPS pilot facility became available. Following a MPU TAR in July, 2012 substantially reduced fluid rates were observed and field operators noticed evidence of TxIA communication. Returns were lost while circulating the well to light . crude on July 31. PCP operation was continued for over eight hours after a torque reduction suggested light crude to the pump. At 180 RPM this should have been several tubing volumes. The tubing was bullheaded to light crude after shutting down the PCP to ensure that any heavy crude above the hole was displaced from the tubing. Fluid levels were shot near 700' MD on 7/26 and 7/28. A hole is suspected in the tubing near this depth. This is the depth of the shallowest dogleg in the hole. The control rod was pulled in August 2013 slickline intervention following control rod removal failed due to a restriction at 141' SLM. A small polycore section was recovered. Scope of Work: The primary objective of this RWO is to pull the ESP and run a kill string into the well. Pre Rig Prep Work: W 1 Check all LDS for movement; PPPOT-T to 5,000 psi; O 2 Pump pressure reading (30 days prior to arrival)* O 3 Pump pressure reading (10 days prior to rig arrival)* F 4 Circulate 100bbIs diesel through well to ensure the well can be circulated for a kill. Pump down tubing. F 5 Purge capillary tube and bleed off any residual pressure. ✓ 6 Prep annular valves. Set a BPV O 7 Remove the well house&flow line. Level the pad as needed for the rig. Proposed RWO Procedure: • MIRU Doyon 16. Kill the well with seawater. ND tree. NU and test BOPE with four preventers configured top down annular, 2-7/8"x 5"VBR's, blind shears, mud cross and 2-7/8" x 5"VBR's. Test the VBR's and annular to 3,500-psi. • Pull 4-1/2" Polycore coated tubing (mixed connections) completion. • RU E-line and run casing caliper on first 1,000' MD 9-5/8"tubing. • Run 4-1/2" carbon kill string to —4,900' MD • ND BOPE. NU and test dry hole tree. • Freeze protect well. Set BPV. RDMO. Post rig Work • None Wellhead: FMC Gen 5 11"x 4- 5M NO1 30"ID Isolation Sleeve Installed Radigan Wellhead w/Dual Rod Rams MPU S-39 in Casing Spool. Tubing Spool and • Tubing Head:11"x 4-1/2",FMC Tbg Hgr Casing Spool Outlets Both Access IA 4"CIW Profile&4.5"TC-II T&B thread J Orig.KB Elev.=72.45' Original GL Elev.=37.8' 20",92#,H-40,Welded,Insulated 112` 0 Tam Port Collar 987' Heat Trace to 3500'MD D `NOTE:TAM-PORT Collar is at 18° inclination.It is recommended to rotate through this above 12°when running in the MINIMUM ID ABOVE PCP STATOR: - hole with a bent housing motor or PDC bit. 3.470"inside the Polycore coated Tbg - 9 5/8"Csg tested to 1500 psi 9/22/12 4-1/2", 12.6#,L-80,Polycore coated Tbg, w/mixed connections(TC-II,EUE,VAM - Q 3/8"SS Capillary Tube TOP&IBT-M) Q 0.433"SLB I-Wire (Drift ID 3.470",Capacity=0.0117 bpf) (Capacity w/CoRod installed=0.0104 bpf) - 9-5/8",47#,L-80,BTC,0.07321 bpf Csg Drift ID=8.525"Csg ID=8.681" Burst=6870 psi Collapse=4750 psi (Capacity with 4.5"inside=0.0535 bpf) I1 4-1/2"KBMG-LTS Chemical 4064' �J Injection Mandrel 4-1/2"WFD Pump Seating Nipple 4071' (3.810"ID) 4-1/2"WFD Drain Sub,3996 osi Shear 4073' = 4-1/2"Phoenix Discharge Sub(failed) 4492' 7"x 9-5/8""C2"ZXP Liner Top Packer 4761' le "RS"Packoff seal and HMC liner Hgr. WFD PCP Stator XXXLP 500-4100 4537' 9-5/8"Casing Shoe 4865' I , 3-1/2"Re-Entry Tag Sub,ID=2.00" 4567' 4-1/2"Phoenix Intake Gauge 4582' BEIS 4-1/2"Slotted Tbg 4873'-4954' 7"Production Liner Specifications: 4-1/2"TBG Tail With Wireline Entry Guide 4964 7",26#,L-80,BTC Solid Liner ID=6.276", Drift ID=6.151" Burst=7240 psi,Collapse=5410 psi 4761'-5072'&5233'-5681'& 6247'-6290'MD 7"26#,L-80,BTC Slotted Liner 727'0.028"Slots at 188 SPF 5072'-5233'MD&5681'-6247'MD PBTD 6287' 4 k Well Inclination at TD=91° Float Collar at 6287'MD 7"Liner Shoe at 6290'MD,3796'TVD Ugnu Horizontal 8-1/2"Hole DATE REV.BY COMMENTS 1/9/09 REH Drill and set kill string-Doyon 14 MILNE POINT UNIT WELL#:MPS-39 6/27/2011 DAJ Drill and complete-Nabors 7ES API NO:50-029-23405-00-00 9/4/12 Hulme CoRod pull&RWO prep 9/23/12 Hulme RWO-Doyon 14 BP EXPLORATION (AK) Wellhead: FMC Gen 5 11"x 4- 5M MPU S-39 NO-i 90"ID Isolation Sleeve Installed Radigan Wellhead w/Dual Rod Rams in Casing Spool. Tubing Spool and Tubing Head: 11"x 4-1/2", Proposed RWO Casing Spool Outlets Both Access IA FMC TBG Hanger Ported Orig.KB Elev=72.45' Original GL Elev.=37.8' 20",92#,H-40,Welded,Insulated 112' 0 Tam Port Collar 987' MINIMUM ID ABOVE PCP STATOR: 3.865"at 3012'MD KBMG Chemical Injection Mandrel Tubing Specifications: 4-1/2", 12.6#, L-80, IBT TBC 9-5/8",47#,L-80,BTC,0.07321 bpf Csg Drift ID=8.525"Csg ID=8.681" Burst=6870 psi Collapse=4750 psi /4-1/2"X NIP' X7"x 9-5/8""C2"ZXP Liner Top Packer 4761' 1 1 9-5/8"Casing Shoe 4865' A 4-1/2" WLEG @4900' 7"Production Liner Specifications: 7",26#,L-80, BTC Solid Liner ID=6.276",Drift ID=6.151" Burst=7240 psi,Collapse=5410 psi 4761'-5072'&5233'-5681'& 6247'-6290'MD 7"26#,L-80, BTC Slotted Liner 727'0.28"Slots at 188 SPF 5072'-5233'MD&5681'-6247'MD Float Collar at 6287'MD 1 7"Liner Shoe at 6290'MD,3796'TVD 6287 / l Well Inclination at TD=91° Ugnu Horizontal 8-1/2"Hole DATE REV BY COMMENTS MILNE POINT UNIT 6/27/2011 DAJ MPS-39 Proposed-DRAFT WELL#:MPS-39 11/16/2011 N7ES New Completion API NO:50-029-23405-00-00 BP EXPLORATION (AK) • ■ T:_AV. '3AVS - 0.- ':7-V X / S ' 'o_ S-IF) N RAMS— 1i1 111 v ,uA NOV AN I I % 1,...14-1P;p11.: i ■ � - IiI ,,® ,, i. I -11 0 1.1 jO '0.98 I111111—v---�' --� CLASS "'. A F-A' --- 'RA(1 C INN (. ION 11I I-512 R01 11(, � +- l U L k EI � O�. I 4�1 S SSV -X p �� Z 3L 70. 3 00 4,(4,D4 _1 i�' .fIiIII tre O iI 1 [ 1 I INI 13.'8 15 ((v -T(S( F'n2 1 IC 0 f f f 1• _ a., ,,,,,,...GROUND REVEL _z -- II>1111 �'a. — - As Uf f I i �■ �7"j�"�J ■ i 7 ®�11 l' •<j.)0) OO} i i (..1M - # lit. ‘)(,)(r)U 1 ; i II■ 1 R d 016 t I ,ASAi ASS` y 1 /b .:Lt ER'S L A7 ASS' 7 (..l`:t tl1)) _ ' S/8 "SC MANI821 AN LB 1 S I'Wu)F5 -J3 NIA, Al0 .G-12 ASSN' II'13 I L'. 1 X - 7 m_ I '1000088()(" /) ' r- r AD APT CR ASSY,A5 LC.II 5k X s 11 6 SK -.. I1 o y,g ('-7CASINI; IANC I I2 P11ft A5OS I I NFL. NIPPI F 10 ImIIg7Jo 78! I'�A55 •I—A SrRSA( P11;In1I S ..(")I A551 RP_'� =M' f I l it 120 511 'I ASS )IA CI , I'---1:81 351 ;;?F?: ('.,ASS "1-A S'111 S,21 AI.I I;JAIL II =1 �O :.'L; ASIV,; I 1 A1c TN i 1 —I E 8(80 3,_3'C - I- L3It-, 5,>C IP) I ;;))0/,'^V 1 1 la'Y A I.A I A , oe 7Vv`C`--:3-:'c PRIVATE AND CONFIDENTIAL OF .. — of 0,,,-..'\i'' N. T��iia1ogm■ .:'''''::''''''=_ H__ IR ",',Y.,.,-.,4,' f N E 0 ,n,'E i\ON) EMS CA RP,ix ww. X0 0.1 O .0105.. I NI 0,I iO 01 `_np w/D(P '�•°OB0" .w ,..w.,:. nua.0 _ - :.7eN oN w 0 1)V 1001'20326 CAMERON Dry Hole Tree 4-1/8 API 5K ter. Cameron Tree Cap 1__, �,� 4-1/8 API 5K x Otis Connection rTh Cameron FLS Gate Valve < 4-1/8 API 5K Cameron FLS Gate Valve o 4-1/8 API 5K Tubing Head Adapter 13-5/8 API 5K x 4-1/8 API 5K Ferguson, Victoria L (DOA) From: McLaughlin, Sean M <Sean.McLaughlin@bp.com> Sent: Tuesday,January 07,2014 9:57 AM To: Ferguson,Victoria L(DOA) Subject: RE: MPS-39 (PTD 208-183, Sundry 313-647) Victoria, The current Polycore completion has a hole at 700', most likely due to the corod rotation. Slickline has established that the Polycore (HDPE rubber) is peeling off the tubing ID and restricting passage of tools (caliper and pressure logs). At this point we are still able to pump through the tubing. The objective of the tubing swap is three part 1) Pull the Polycore tubing and send to the lab to determine the cause of the failure. This will help future heavy oil work. 2) Replace the tubing to remove the hole and pull the Polycore before the tubing becomes plugged. 3) Leave a conduit to the reservoir for pressure monitoring and Heavy Oil reservoir surveillance (no downhole plugs). Regards, sean From: Ferguson, Victoria L(DOA) [ma ilto:victoria.ferguson@ alaska.gov] Sent: Tuesday,January 07, 2014 9:38 AM To: McLaughlin, Sean M Subject: MPS-39 (PTD 208-183, Sundry 313-647) Sean, Please further explain the objective of this procedure. Don't you already essentially have a kill string with the current completion?Do you plan to secure the well downhole and suspend? Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.gov 1 OF 7^4 • 4 ww \ I %%y s , 7HE STATE Alaska Oil and Gas ®f Conservation iSSion _ =- �.._ GOVERNOR SEAN PARNELL 333 West Seventh Avenue ¢. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Aras Worthington d u I Well Intervention Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Pool, MPS -39 SCANNED MAY 2013 Sundry Number: 313 -232 Dear Mr. Worthington: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy Pjoerster Chair DATED this Z day of May, 2013. Encl. STATE OF ALASKA RECEIVED ` ALAIPOIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL °v AY 092013 20 AAC 25.280 AOGC('' 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension Re-Enter us en Well Stimulate Alter Casing Other Pull PCP Rotor & Corod CI Operations Shutdown ❑ S ❑ ❑ g P P 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 208 - 183. 3. Address: IN Development, ❑ S ervice 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 23405 -00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPS -39 - Will planned perforations require a Spacing Exception? ❑ Yes N o 9. Property Designatior 10. Field / Pool(s): ADL 380109 & 380110 - Milne Point Unit / Ugnu Undefined • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6306' ' 3796' • 6287' 3795' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4833' 9 - 5/8" 37' - 4870' 37' - 3725' 6870 4760 Intermediate Production Liner 1529' 7" 4761' - 6290' 3688' - 3796' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5072' - 6247' 3768' - 3794' 4 - 1/2 ", 12.6# L - 4965' Packers and SSSV Type: None Packers and SSSV Nene— MD (ft) and TVD (ft): 0l3 t 3 `Iel 511 12. Attachments: 13. Well Class after proposed work: • ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. June 1, 2013 , IS Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington, 564 -4102 Printed Name: Aras orthington Title: Well Interventions Engineer Email: Aras.Worthington @bp.com Signature: Phone: 564 -4102 Date: . thh.0)3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ?� 2..5 Sundry Number: `.! ,,- ❑ Plug Integrity to BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: i2 P fie f O a a 6 p 5 , f/ RBDMS MAY 2 8 2W 4 Spacing Exception Required? ❑ Yes D11 Subsequent Form Required: `) -- 4&4_, �! 7 ' / j ) } I APPROVED BY u Approved By: L__...,-s, :h /7�t� / �- — COMMISSIONER THE COMMISSION Date: S - G- t 1 ) _..J Form 10 -403 Revised 10/zU12 Appro d 1'ca 'o is valid for 12 months from the date of approval Submit In Duplicate • • 0 b P M IIn e i Heavy Oil Team Today Future Forward MPS -39 Corod Pull Scope of Work: Pull PCP rotor and corod. MASP: 1408 psi (1777 psi @ 3688' TVD, less 0.1 psi gas gradient) Well Type: Ugnu Heavy Oil Producer Estimated Start Date: June 1st, 2013 Production Engineer: Mike Warren Intervention Engineer: Aras Worthington Corod scope of Work 1. MIRU Weatherford Flushby Unit and Mobile Gripper Unit. 2. ND Drivehead, NU dry hole tree. 3. Stump Test Corod BOPE including 1 1/8" Rod rams and annular preventer to 2000 psi. 1' fr 4. NU Corod BOPE to dry hole tree and body test to 2000 psi. �� . t 5 S 5. Pull corod and PCP rotor. wl 7 55 6. ND BOP stack. 7. RD Weatherford Flushby Unit and Mobile Gripper Unit. • • • Wellhead: FMC Gen 5 11" x 4 -1/16" 5M a r' t° _ , Radigan Wellhead w/ Dual Rod Rams M P U S -39 • Tubing Head: 11" x 4 -1/2 ", FMC Tbg Hgr i;- ' • 4" CIW Profile & 4.5" TC-Il T &B thread Orig. KB Elev. = 72A5' • Original GL Elev. = 37.8' ' 1 20 ", 92 #, H -40, Welded, Insulated 1 112' I 0 Tam Port Collar I 987' I Heat Trace to 3500' MD r 11F e o. • • 4 -1/2 ", 12.6#, L -80, Polycore coated Tbg, w/ mixed connections (TC -II, EUE, VAM .< 3/8" SS Capillary Tube TOP & IBT -M) . 0.433" SLB I -Wire (Drift ID 3.470 ", Capacity = 0.0117 bpf) (Capacity w/ CoRod installed = 0.0104 bpf) 9 -5/8 ", 47 #, L -80, BTC, 0.07321 bpf Csg Drift ID = 8.525" Csg ID = 8.681" Burst = 6870 psi Collapse = 4750 psi 11 (Capacity with 4.5" inside = 0.0535 bpf) 4-1/2" KBMG -LTS Chemical 4064 Injection Mandrel 4 -1/2" WFD Pump Seating Nipple 4071 (3.810" ID) rrr 4 -1/2" WFD Drain Sub, 3996 nsi ShPar 4073 4 -1/2" Phoenix Discharge Sub (failed) 1 4492 7" x 9 -5/8` "C2" ZXP Liner Top Packer 1 4761' I "RS" Packoff seal and HMC liner Hgr. 1 WFD PCP Stator XXXLP 500 -4100 InEll 9-5/8" Casing Shoe 4865 3 -1/2" Re -Entry Tag Sub, ID = 2.00" 4567' 4-1/2" Phoenix Intake Gauge 4582' 4 -1/2" Slotted Tbg 14873' - 4954' I 7" Production Liner Specifications; 4 -1/2" TBG Tail With Wireline Entry Guide 1 4964 I 7 ", 26#, L -80, BTC Solid Liner ID = 6.276 ", Drift ID = 6.151" Burst = 7240 psi, Collapse = 5410 psi 4761' - 5072' & 5233` - 5681' & 6247' - 6290` MD 7" 26#, L -80. BTC Slotted Liner 727' 0.028" Slots at 188 SPF 5072' - 5233' MD & 5681' - 6247' MD PBTD 6287 k Well Inclination at TD = 91° Float Collar at 6287' MD 7" Liner Shoe at 6290' MD, 3796' TVD Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS 1/9/09 REH Drill and set kill string - Doyon 14 MANE POINT UNIT WELL #: MPS-39 6/27/2011 DAJ Drill and complete - Nabors 7ES API NO: 50 -029- 23405 -00 -00 9/4/12 Hulme CoRod pull & RWO prep 9/23/12 Hulme RWO - Doyon 14 BP EXPLORATION (AK) . RECEIVED STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COMMIDION JAN 18 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well 11 Plug Perforations LJ Perforate L( Other J Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 12 Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Na me: BP Exploration (Alaska), Inc 208 -183 -0 Development El Exploratory ❑ 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 " 50- 029- 23405 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: a ADL0380110 330 id ( 8 UGNU MPS -39 9. Logs (List logs and submit electronic and printed data per 20AAC25.0711: 10. Field /Pool(s): , To Be Submitted MILNE POINT, UGNU UNDEFINE OIL 11. Present Well Condition Summary: Total Depth measured 6306 feet Plugs measured None feet true vertical 3796.14 feet Junk measured None feet Effective Depth measured 6306 feet Packer measured 4761 feet true vertical 3796.14 feet true vertical 3688.27 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 72 20" 91.5# H -40 38 - 110 38 - 110 1490 470 Surface 4833 9 -5/8" 47# L -80 37 - 4870 37 - 3720.78 6870 4760 Intermediate None None None None None None Production None None None None None None Liner 1529 7" 26# L -80 4761 - 6290 3688.27 - 3795.58 7240 5410 Perforation depth Measured depth 5072 - 5233 feet 5681 - 6247 feet MAR 2013 True Vertical depth 3768.38 - 3796.89 feet 3812.22 - 3794.04 feet M SCANNED Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 4761 3688.27 Packer None None None SSSV 12. Stimulation or cement squeeze summary . Intervals treated (measured): 5072' - 5233' 5681' - 6247' Treatment descriptions including volumes used and final pressure: 55bb1 Diesel Displace with 242bb1 crude on a vaccume 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 324 48 0 36 125 Subsequent to operation: 270 63 0 -2 118 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ^ as Gas U WDSPLL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 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: N/A Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Summerh f ' Title Petrotechnical Data Technician Signatur liRr � 4� �1._■1111 Phone 564 -4035 Date 1/17/2013 RBD MS S 2 8 2013 171.--, 7 / /z! Form 10 -404 Revised 10/2012 ,/4 z r/'7 Submit Original Only Daily Report of Well Operations ADL0380110 ACTIVITYDATE SUMMARY •= • Assis w '•• us circ we 'os ® ®®• "unwell a oa o :1 ass 'cruse '' down IA taking returns up tbg to CHOPS tank. Pumped 64 bbls crude down tbg. pumped 55 bbls 100* diesel and 28 bbls 120* crude down IA taking returns up tbg to CHOPS tank to assist with start up. 12/29/2012 ** *wsr continued to 12- 30 -12 * ** Complete pre -job safety mtg, barriers = packoff seals, secondary barrier = Radigan. Pull co -rod, came free at 27,500 lbs. Close and PT ratigans to 2000 psi for 5 mins (Passed). Open lower ratigan and circ down IA taking returns up tbg to prod tanks. Pumped 180 bbls down IA w/ 172 bbls to tanks the rest to the formation. Pumped 70 bbls down tbg. into formation. Inserted rotor back into stator. Bolted on six bolt clamp, landed polished rod, RD flushby unit but left spotted up on well. 12/29/2012 « <Job Complete »> * ** wsr continued from 12- 29 -12 * ** T/I/0= 10/ -12 Assist w/ CHOPS Diesel stim ( Post RWO ) Pumped 192 bbls crude down IA to asssit with CHOPS 12/30/2012 * ** WSR continued to 12- 31 -12 * ** ** *wsr continued from 13- 30 -12 * ** 1/I/0= 10/ -12 Assist w/ CHOPS Diesel stim ( Post RWO ) Pumped 24 bbls crude to assist with start up 12/31/2012 ** *wsr continued to 01- 01 -13 * ** FLUIDS PUMPED BBLS 518 CRUDE 55 DIESEL 573 TOTAL Casing / Tubing Attachment ADLO38O11O Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 20" 91.5# H-40 38 - 110 38 - 110 1490 470 LINER 1529 7" 26# L -80 4761 - 6290 3688.27 - 3795.58 7240 5410 SURFACE 4833 9 -5/8" 47# L -80 37 - 4870 37 - 3720.78 6870 4760 TUBING 4772 4 -1/2" 12.6# L -80 36 - 4808 36 - 3702.73 8430 7500 TUBING 544 3 -1/2" 9.2# L -80 4808 - 5352 3702.73 - 3806.66 10160 10530 • • Wellhead: FMC Gen 5 11" x' SM e e ' ' Radigan Wellhead w/ Dual Rod }lams M P U S -39 0 8 0 0 8 8 ®i @ Tubing Head: 11" x 4 -1/2 ", FMC Tbg Hgr e e 4" CIW Profile & 4.5" TC-II T &B thread - Orig. KB Elev. = 72.45` Original GL Elev. = 37.8' - 20 ", 92 #, I-1-40 , Welded, Insulated 112' Tam Port Collar I 9, 87 Heat Trace to 3500' MD � � e - ; 6 , : 4 i 0 9 0 0 $ . 0 , 09 }' - B 9' ® 0 0# 9 0 e ° ® ;' , „to, e 9 /e • G%' � 1 rx ) �9 ra `t ® #��x t z 4 -1/2 ", 12.6 #, L -80, Polycore coated Tbg, w/ mixed connections (TC II, EUE, VAM Q 3/8" S S Ca pillary Tube TOP & IB 0.433" SLB I -Wire (Drift ID 3.470 ", T-M) Capaci 0 0117 bpf) ty = . (Capacity w/ CoRod installed = 0.0104 bpf) 9 -5/8 ", 47 #, L -80, BTC, 0.07321 bpf DriftlD 8 . 5 25 "CsgID = 8.681" Burst Csg = 6870 psi Collapse = 4750 psi (Capacity with 4.5" inside = 0.0535 bpf) 4 -1 /2" KBMG -LTS Chemical ( 4064' Injection Mandrel 4 -1 /2" WFD Pump Seating Nipple 1 4071 ` (3.810" I D) 4 -1/2" WFD Drain Su 3996 o Shear 4073' 4 -1/2" Phoenix Discharge Sub (failed) 1 4492' 7" x 9 -5 "C2" ZXP Liner To Packer 1 4761 ` III Li i "RS" Packoff seal and HMC liner Hgr. • WFD PCP Stator SSSL 5000 -41001 4537` 9 -5/8" Casing Shoe 1 4865' I 1 3 -1 /2" Re -Entry Tag Sub, ID = 2.00' 1 4567 4 -1/2" Phoenix Intake Gauge 1 4582` 4-1/2 " Slotted Tbg 4873' - 4954' 7" Production Liner Spe xsjasti 7 ", 26 #, L -80, BTC Solid Line 4 -1/2" TBG Tail With Wireline Entry Guide 1 4964 ID= 6.2", Drift 6.151" Burst = 72 4 Collapse = 5410 Psi _> 47616247' - 50720 ' psi & 5233` - 5681 & ` - 6290' MD 7" 26 #, L -80, BTC Slotted Liner 727` 0.028" Slots at 188 SPF 5072' - 5233' MD & 5681' - 6247' MD PBTD 6287'1 A Well Inclination at TD = 91° Float Collar at 6287' MD 7" Liner Shoe at 6290' MD, 3796' ND Ugnu Horizont 8 -1 /2" Hole DATE REV. BY COM MENTS M ILNE POINT UNIT 1 /9/09 REH Drill and set kill string -Doyon 14 WELL # : MPS -39 6/27/2011 DAJ Drill and complete - Nabors 7ES API NO: 50- 029 - 23405 -00 -00 9/4/12 Hulme Co pull R. RWO prep EXPLORATION (AK) 9/23/12 Hulme RWO - Doyon 14 BP STATE OF ALASKA •SKA OIL AND GAS CONSERVATION COVIISSION iF1 EC E I Y®® ED ' REPORT OF SUNDRY WELL OPERATIONS DEC 0 4 2012 1. Operations Performed: GCC ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing ❑Stimulate-Frac ❑Waiver ®Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension Corod/PCP Completion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic " 208-183 3. Address: ®Development ❑Service 6. API Numbe , P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-23405-00-00 7. Property Designation(Lease Number): -. 8. Well Name and Number: ,. ADL380109&380110 MPS-39 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ,„ Milne Point Unit/Ugnu Undefined 11. Present well condition summary: Total depth: measured 6306' feet Plugs:(measured) None feet true vertical 3796' feet Junk:(measured) None feet Effective depth: measured 6287' feet Packer: (measured) None feet true vertical 3795' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4833' 9-5/8" 4870' 3725' 6870 4760 Intermediate Production Liner 1529' 7" 4761'-6290' 3688'-3796' 7240 5410 Perforation Depth: Measured Depth: 5072'-6247' feet True Vertical Depth: 3768'-3794' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# L-80 4965' 3745' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: SCANNED AUG 0 1 2013 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 177 28 0 75 62 Subsequent to operation: 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic ®Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: 4 ®Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Aras Worthington,564-4102;Aras.Worthington©bp.com 312-212 Email: Joseph.Lastufka @bp.com Printed Na e: Joe as at i Title: Drilling Technologist ((--/ Signature: � 1 Phone: 564-4091 2 Date: lZ/T/ 1�-' Form 10-404 Re . -d 0/20 �� , (g`-^ 1 ✓' V ' VLF ��57/Jam.,i � Submit Original Only • • Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9 003JN C:RIG(2,400,000.00) Project:Milne Point Site: M Pt S Pad Rig Name/No.:DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor: DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/16/2012 12:00 - 00:00 12.00 MOB P PRE PREP TO MOVE RIG. -RIG DOWN. -RIG UP STAND PIPE MANIFOLD. -SKID RIG FLOOR TO MOVING POSITION. -JACK RIG. -READY MATS FOR MOVE. "24 HOUR NOTICATION TO AOGCC,CHUCK SHEVE OF UPCOMING BOPE TEST AT 17:03 9/16/2012. 9/17/2012 00:00 - 03:00 3.00 MOB P PRE TURN TIRES TO CRAB POSITION. -MOVE RIG OVER MPS-39. ALIGN OVER WELL CENTER WITH PLUMB BOB. -LEVEL AND SHIM RIG. -SKID RIG FLOOR INTO DRILLING POSITION `2ND CALL TO AOGCC,CHUCK SCHEVE, FOR BOPE TESTNG. REQUIRES 3 HR NOTICE. 06:00 AM 9-17-2012. 03:00 - 06:00 3.00 MOB P PRE R/U OVER MPS-39. -NIPPLE UP MUD PUMP LINES, HOLE FILL LINE AND BLEEDER LINE. -MAKE UP H2O,STEAM AND AIR LINES. 06:00 - 12:00 6.00 MOB P PRE CONTINUE RIG UP OVER MPS-39. -PICK UP HANDLING TOOLS,FOSV AND DART VALVE -HANG RIG TONGS AND MUD BUCKET IN DERRICK. -SPOTTED RIG MATS FOR ROCK WASHER. -SPOTTED TIGER TANK AND BEGAN RIG UP HARD LINE. 12:00 - 14:00 2.00 MOB P PRE CONTINUED RIG UP OVER MPS-39. -CONTINUED SPOTTING RIG MATS FOR ROCK WASHER. -INSTALL#2 DRAG CHAIN. -CONTINUED RIG UP HARD LINE. -R/U RIG FLOOR, PIPE SHED AND PITS. 14:00 - 16:00 2.00 MOB P ._ PRE RIG UP ROCK WASHER. -LAY HERCULITE AND SPOT ROCKWASHER. 16:00 - 19:00 3.00 RIGU P PRE BEGAN TAKING ON 120 DEG SEAWATER INTO PITS. -CLEAN PIT#5. *RIG ACCEPTED AT 4:00 PM 9-17-2012. 19:00 - 20:00 1.00 RIGU P PRE *RIG EVACUATION DRILL. -RIG EMERGENCY SHUTDOWNS TESTED-OK. -CREW RESPONSE TIME 4 MINUTES,AAR HELD AFTER DRILL. 20:00 - 21:00 1.00 RIGU P -_ PRE MOBILIZE HOSES,VALVES AND HARD LINES TO CELLAR. 21:00 - 00:00 3.00 RIGU P PRE PJSM ON RIGGING UP HARD LINES AND MANIFOLD TO WELL HEAD. -RIG UP HOSES AND MANIFOLD TO CHART TEST. *RIG UP W/ (2)CHECK VALVES BETWEEN EACH MUD PUMP AND WELL HEAD. 9/18/2012 00:00 - 02:00 2.00 RIGU P PRE RIG UP HARD LINES TO WELLHEAD,CONT. -TEST LINES TO 250 PSV2000 PSI FOR 5 MINUTES-CHARTED. Printed 11/13/2012 8:45:54AM Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site:M Pt S Pad Rig Name/No.: DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor: DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 02:30 0.50 RIGU P PRE *RIG EVACUATION DRILL WITH NIGHT CREW. -CRT 3:30. AAR WITH CREW. 02:30 - 05:30 3.00 WHSUR P DECOMP CHECK TUBING PRESSURE AND RIG UP LUBRICATOR. -TEST 250/2000 PSI FOR 5 MINUTES AND CHARTED. -RECOVER BPV. -RIG DOWN LUBRICATOR. 05:30 - 08:00 2.50 KILLW P DECOMP PJSM FOR BULLHEAD KILL OPERATION. -TUBING PRESSURE=0. -IA PRESSURE=0. -VERIFY ALIGNMENT. -BEGIN BULLHEAD KILL DOWN TUBING AND CASING SIMULTANEOUSLY. *LINE UP PUMP#1 ON TUBING WITH 14 STROKES PER MINUTE AND 110 PSI. *LINE UP PUMP#2 ON IA WITH 50 SPM 290 PSI TOTAL. *TOTAL OF 480 BBLS PUMPED,380 BBLS DOWN IA AND 100 BBLS DOWN TUBING. *SIM OPS DERRICK AND SHACKLE INSPECTION. 08:00 - 08:30 0.50 KILLW P DECOMP OPEN IA AND TUBING ON TREE, FLOW CHECK WELL TO BLEED TANK FOR 30 MIN. 08:30 - 09:30 1.00 WHSUR P DECOMP TEST LUBRICATOR. -TEST 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINS. *TESTED GOOD. 09:30 - 12:00 2.50 WHSUR P DECOMP INSTALL TWC,ATTEMPT TO PULL RUNNING TOOL OUT OF TREE. -DRILL SITE MAINT. HAS PROBLEMS WITH HYDRAULIC SYSTEM ON LUBRICATOR 12:00 - 13:00 1.00 WHSUR P DECOMP PULL RUNNING TOOL OUT OF TREE,CONT. -DRILL SITE MAINT CONT.TO HAVE PROBLEMS WITH LUBRICATOR. 13:00 - 14:30 1.50 WHSUR P DECOMP RIG UP AND TEST TWC. -TEST 250 PSI LOW AND 2000 PSI HIGH. -TEMP TEST FROM BELOW 3.5 BPM AT 190 PSI FOR 17 BBLS. -FROM ABOVE 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINS. *TESTS GOOD. 14:30 - 16:00 1.50 WHSUR P DECOMP PJSM NIPPLE DOWN THE TREE. 16:00 - 21:30 5.50 BOPSUR P DECOMP PJSM NIPPLE UP BOP'S *CALLED CHUCK SHEAVE AOGCC FOR BOP TEST WITNESS-WAIVED. 21:30 - 00:00 2.50 BOPSUR P DECOMP PJSM CHANGE RAMS *SIM OPS,PICK UP CROSSOVERS,TIW AND DART VALVES. 9/19/2012 00:00 - 01:30 1.50 BOPSUR P DECOMP NIPPLE UP BOPE STACK,CONT. -INSTALL BLEED OFF AND HOLE FILL LINES. -FLOW LINE BOOTS PRESSURED UP *DOOR SEAL ON BLIND SHEAR RAMS LEAKING *MECHANIC CALLED OUT TO LOCATION TO REPAIR. -PICK UP AND MAKE UP CROSSOVERS FOR TESTING BOPE'S AND FOSV'S -CHANGE OUT DOOR SEALS ON BLIND SHEAR RAMS Printed 11/13/2012 8:45:54AM Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site:M Pt S Pad Rig Name/No.:DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor: DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 12:00 10.50 BOPSUR P DECOMP TEST FOSV'S AND DART VALVE ON FLOOR 250 LO/2000 HI FOR 5 MIN EACH. *SIM OPS,CHANGE BLIND SHEAR RAMS DOOR SEAL. -FILL STACK WITH SEAWATER. -DUTCH RISER LOCK DOWN SCREWS LEAKING. -EMPTY RISER AND REMOVE AND GREASE SCREWS. -REFILL RISER AND CHECK FOR LEAKS-NONE FOUND. *BOP DRILL, RESPONSE TIME 2 MINS. -START PRESSURE TESTING TOP DRIVE.250 LO/2000 HI FOR 5 MINUTES. -TEST CHOKE LINES AND FOUND LEAKING UNIONS-HAMMERING UP UNIONS. -ADD 10 BBLS AN HOUR TO TEST CHOKE VALVES 1-13,BLIND SHEAR RAMS,MANUAL CHOKE AND HYDRAULIC DRAW DOWN, IBOP, AND MANUAL IBOP,TWO XT-39 FOSV'S,AND A XT-39 DART VALVE AND MPL ON TOP RAMS WITH 4"RAMS AND MPL WITH 4.5 SOLID RAMS AT 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINS *ALL CHARTED AND TESTED GOOD,AOGCC CHUCK SHEAVE WAIVED WITNESS TO TEST 16:30 9-18-12 12:00 - 13:30 1.50 ' BOPSUR P DECOMP PJSM TEST BOPE'S,CONT. -BLIND RAMS,VALUE 20,SUPER CHOKE AND MANUAL CHOKE. 13:30 - 14:30 1.00 BOPSUR P DECOMP PJSM BLOW DOWN CHOKE AND LINE UP. 14:30 - 19:00 4.50 BOPSUR - P DECOMP PJSM PUMP OUT STACK. -PICK UP RETRIEVAL EXTENSION AND LUBRICATOR AND MAKE UP. -TEST 250 PSI LOW AND 2000 PSI HIGH FOR 5 MINS,TESTED GOOD. -ATTEMPT TO PULL TWC,DSM HAS PROBLEMS PULLING TWC. 19:00 - 20:00 1.00 BOPSUR P DECOMP LAY DOWN TWC, EXTENSION AND LUBRICATOR. 20:00 - 00:00 4.00 CASING P DECOMP PJSM PICK UP CENTRALIFT SPOOLING EQUIPMENT. -PICK UP CASING EQUIPMENT,BAILS AND CROSSOVERS AND MAKE UP. 9/20/2012 00:00 - 01:00 1.00 CASING P DECOMP MAKE UP LANDING JOINT TO HANGER. -BACK OUT LOCK DOWN SCREWS WITH FMC. 01:00 - 01:30 0.50 CASING N DFAL DECOMP PULL ON HANGER WITH 110K 4 TIMES TO START. -TOOK 115K TO PULL HANGER FROM WELLHEAD. -PULLED 20'WITH P/U WT BOUNCING FROM 125K TO 115K. -STRING PULLED TIGHT AT 20'-PULLED. 01:30 - 02:00 0.50 CASING N DFAL DECOMP WORK STRING TO 140K,SLACKED OFF TO 80K 3 TIMES. -STOPPED OPERATIONS,CALLED TOWN. 02:00 - 02:30 0.50 CASING N DFAL DECOMP PERFORM STRETCH CALCULATIONS. 7"@ 20K=10.8'FREE PIPE-IN WELLHEAD. 02:30 - 03:00 0.50 CASING N DFAL DECOMP STOPPED OPERATIONS,CALLED TOWN TO DISCUSS OPTIONS. Printed 11/13/2012 8:45:54AM rd •Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site:M Pt S Pad Rig Name/No.: DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor:DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:30 0.50 CASING N DFAL _ DECOMP RUN TUBING BACK AND LAND IN HANGER. -RUN LOCK DOWN SCREWS IN. 03:30 - 09:30 6.00 CASING N DFAL DECOMP PREP AND PUMP DEEP CLEAN PILL FROM MI-SWACO. -BULLHEAD OPERATIONS. -PUMP 78 BBLS DEEP CLEAN DOWN TUBING @ 1.4 BBLS/MIN. -PUMP 290 BBLS DEEP CLEAN DOWN IA @ 5 BBLS/MIN FOLLOWED 11 BBLS SEA WATER. -MONITOR WELL WHILE ADDING 10 BBL HOUR. 09:30 - 12:00 2.50 CASING N DFAL DECOMP WORK TUBING UP TO 122K. -USE INLINE CAMERA TO LOOK INTO WELL BORE TO VERIFY WHAT WAS HANGING UP. 12:00 - 13:30 1.50 CASING N DFAL DECOMP WORK TUBING,CONT.TO UP 110K AND DOWN 90K MAX. -LOOK INTO WELL BORE TO VERIFY WHAT IS HANGING UP THROUGH IA. -TURN QUARTER TURN TO RIGHT,WORK TORQUE DOWN. -BROKE FREE. -PULL HANGER TO FLOOR PULLING 5K TO 8K OVER. 13:30 - 14:00 0.50 CASING P - DECOMP PJSM ON LAYING DOWN TUBING WITH CONTROL LINES. 14:00 - 16:00 2.00 CASING P ® DECOMP DECOMPLETE CONTROL LINES AND HANGER, LAY DOWN. 16:00 - 17:00 1.00 CASING P DECOMP LAY DOWN TUBING 1x1 FROM HANGER TO 5270 FEET. -HOLE DISCOVERED IN SECOND JOINT. -BROKE OFF AND LAID DOWN. 17:00 - 18:00 1.00 CASING P DECOMP RIG UP TO CIRCULATE. -PUMP 8.5 BRINE 5 BBL A MIN AT 30 PSI, NO RETURNS. *AT 70 BBL'S RETURNS SEEN. -SHUT BAG TO TAKE RETURNS TO SLOP TANK. -PUMP 3 BBL'S A MIN AT 70 PSI. *SHUT DOWN AT 30 BBL'S. -PUMP 13 BBL'S HI-VIS SWEEP FOLLOWED BY 60 BBL'S 8.5 BRINE. 18:00 19:00 1.00 CASING P ■- DECOMP BLOW DOWN TOP DRIVE. -PULL CENTRALIFT CONTROL LINES OVER SHEAVES. 19:00 - 00:00 5.00 CASING P DECOMP PULL OUT OF HOLE LAYING DOWN TUBING, CONTINUING TO SPOOL UP HEAT TRACE, I-WIRE AND CAP TUBING *FROM 5270 FEET TO 3917 FEET. 9/21/2012 00:00 - 06:00 6.00 CASING P DECOMP PULL OUT SINGLES OF TUBING AND LAY DOWN,CONTINUING TO SPOOL UP HEAT TRACE,CAP TUBE AND I-WIRE *PULL FROM 3917'TO 2700' -FILL HOLE WITH 10 BBL PER HOUR PLUS TUBING DISPLACEMENT. 06:00 07:30 1.50 CASING P ■- DECOMP CHANGE-CONTINUE 563 POOH FROM 2VALVE..5 SLHT 07:30 - 10:00 2.50 CASING P -_ DECOMP LAY DOWN HEAT TRACE -CONTINUE TO POOH TO 580' Printed 11/13/2012 8:45:54AM Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site:M Pt S Pad Rig Name/No.:DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor:DOYON DRILLING INC. UWI:500292340500 Active Datum: MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 10:30 0.50 CASING P DECOMP CHANGE OVER TO 3.5 HANDLING TOOLS& SAFETY VALVE 10:30 - 12:00 1.50 CASING P DECOMP CONTINUE TO POOH.FIRST JOINT OF 3.5 TUBING WAS BENT,SECOND SHOWED SOME DAMAGE AS WELL. -RESUMED POOH TO 3.5 WLEG WITH HALF MULE SHOE. 12:00 - 17:30 5.50 CASING P DECOMP DEMOBILIZED TUBING TOOLS FROM RIG FLOOR,LAY DOWN STACK TONG,LONG BALES,SLIPS,ELEVATORS, 1240 CLAMPS&PINS,RIG DOWN SPOOLING UNIT AND SHEAVE IN DERRICK. CHANGE OUT SHORT BAILS -RIG SIMOPS=LOAD PIPE SHED WITH 160 JOINTS OF 4"XT39 DRILL PIPE,9 JOINTS OF 4-3/4"COLLARS 17:30 - 19:30 2.00 CASING P DECOMP PULL ISOLATION SLEEVE. -INSTALL WEAR RING 19:30 - 20:00 0.50 CASING P DECOMP MOBILIZE BOTTOM HOLE ASSEMBLY#1 TO RIG FLOOR 20:00 - 00:00 4.00 CASING P DECOMP MAKE UP BOTTOM HOLE ASSEMBLY AND RUN IN HOLE WITH 4"DRILL PIPE TO 1545'. -BREAKING CIRCULATION EVERY 1000' -CONTINUE TO FILL HOLE 10 BBLS EVERY HOUR -KICK DRILL 9/22/2012 00:00 - 00:30 0.50 CASING P DECOMP LUBRICATE RIG 00:30 - 04:30 4.00 CASING P DECOMP SINGLE IN HOLE WITH 4"DRILL PIPE FROM PIPE SHED TO PREFORM CLEAN OUT RUN FROM 1545'TO 5054' -TAG LINER AT 4767',JUNK MILL AT 5054' 04:30 - 05:30 1.00 CASING P DECOMP PREP TO CIRCULATE FULL CIRCULATION-FOUND LEAKS IN TOP DRIVE 05:30 - 07:30 2.00 CASING P DECOMP SLIP/CUT DRILL LINE -REPAIR WASHPIPE ON TOP DRIVE 07:30 - 09:30 2.00 CASING P DECOMP PUMP 400 GPM PSI @ 1240, PUMPED 400 BBLS TOTAL WITH 245 BBL RETURNED TO THE ROCK WASHER. -PUW=123K,SOW=98K 09:30 - 10:00 0.50 CASING P DECOMP 10 MINUTE FLOW CHECK WELL,TAKING FUILD,INSTALL STRIPPING RUBBER 10:00 - 12:00 2.00 CASING P DECOMP POOH STANDING BACK 4"DRILL PIPE IN DERRICK FROM 5043'TO 293' 12:00 - 13:00 1.00 CASING P DECOMP LAY DOWN BOTTOM HOLE ASSEMBLY AND MOBILIZED OFF RIG FLOOR. -HALF BUCKET OF SLUDGE IN BOOT BASKETS 13:00 - 13:30 0.50 CASING P DECOMP LUBRICATE RIG 13:30 - 17:30 4.00 CASING P DECOMP MAKE UP RTTS AND RUN IN HOLE WITH 4-3/4 COLLARS,4"HEAVY WEIGHT DRILL PIPE&4" DRILL PIPE TO 4746' -SPILL DRILL=1:10 17:30 - 19:30 2.00 CASING P DECOMP SET RTTS,PUW=126K,SOW=97K,TEST CASING 1560 WITH BLEED TO 1530 IN 15 MIN, NO BLEED FROM 15-30 MIN.PASSED AS PER STEVE ROSSBERG 9/22/12.CHARTS ARE ATTACHED. Printed 11/13/2012 8:45:54AM a e : Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site: M Pt S Pad Rig Name/No.:DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor:DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39©71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 CASING P DECOMP RELEASE FROM RTTS.LAY DOWN DRILL PIPE,BOTTOM HOLE ASSEMBLY AND RTTS. -CONTINUE TO FILL HOLE @ 10 BPH 9/23/2012 00:00 - 01:00 1.00 CASING P DECOMP MAKE UP STACK WASHER,RUN IN HOLE 1000'WITH 4"DRILL PIPE 01:00 - 02:00 1.00 CASING P DECOMP LAY DOWN DRILL PIPE,BOTTOM HOLE ASSEMBLY AND RTTS. 02:00 - 03:30 1.50 WHSUR P DECOMP PULL WEAR RING AND INSTALL ISOLATION SLEEVE. -RUN IN LOCK DOWN SCREWS,TEST VOID 250 LO/3500 HI.GOOD TEST 03:30 - 04:00 0.50 WHSUR P DECOMP RIG DOWN LONG BALES, LAY DOWN TEST PLUG WEAR RING RUNNING TOOLS 04:00 - 09:30 5.50 WHSUR P DECOMP RIG UP LONG BALES. -RIG FLOOR FOR RUNNING TUBING. -REPAIR HYDRAULIC HOSES ON SKATE 09:30 - 11:00 1.50 RUNCOM P RUNCMP PICK UP W-LEG RUN IN HOLE WITH 2 JOINTS OF 4.5 12.6#PPF L-80 IBT-M SLOTTED LINER, 7 JOINTS OF 4.5 12.6#PPF L-80 IBT-M,MAKE UP JET PUMP GAUGE IP/DRILL PIPE 11:00 - 12:00 1.00 RUNCOM P RUNCMP MAKE UP I-WIRE TO PUMP&GUAGE LINE TO PUMP 'FILL HOLE 10 BBLS PER HOUR 12:00 - 00:00 12.00 RUNCOM P RUNCMP RUN IN HOLE WITH CHOPS COMPLETION,4.5 EUE POLYCORE 12.6#L-80 WITH I-WIRE, CAPILLARY TUBE AND HEAT TRACE. -FUNCTION TEST I-WIRE,CAPILLARY TUBE AND HEAT TRACE EVERY 2000' -USING CANNON CLAMPS ON EVERY CONNECTION,CROSS CONNECTION AND MID-JOINT CLAMPS FOR THE HEAT TRACE -TABLE TOP KICK WHILE TRIPPING DRILL. -RUN FROM 397'TO 3060' 9/24/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP LUBRICATE RIG 00:30 - 12:00 11.50 RUNCOM P RUNCMP RUN IN HOLE WITH CHOPS COMPLETION,4.5 EUE POLYCORE 12.6#L-80 WITH I-WIRE, CAPILLARY TUBE AND HEAT TRACE. -FUNCTION TEST I-WIRE,CAPILLARY TUBE AND HEAT TRACE EVERY 2000' -USING CANNON CLAMPS ON EVERY CONNECTION,CROSS CONNECTION AND MID-JOINT CLAMPS FOR THE HEAT TRACE -RUN FROM 3060'TO 4180' -FILLING HOLE 10 BBLS EVERY HOUR 12:00 - 16:00 4.00 RUNCOM P RUNCMP MAKE UP HANGER AND LANDING JOINT, TERMINATE HEAT TRACE AND INSTALL LOWER CONNECTOR AND PENETRATOR. -INSTALL I-WIRE AND CAPILLARY TUBE BULK HEAD. -TEST CAPILLARY TUBE AND I-WIRE THROUGH HANGER TO 5000 PSI. -CONTINUE TO FILL HOLE 10 BBL PER HOUR 16:00 - 17:00 1.00 RUNCOM P RUNCMP LAND TUBING,RUN IN LOCK DOWN SCREWS AND INSTALL TWC.PUW=110K,SOW=93K -BAND CLAMPS=2,TERMINATOR CLAMPS=1, 1/2 CLAMPS=3,SINGLE CHANNEL CLAMP=44, DUAL CHANNEL CLAMPS=32, 5'CLAMPS=556 Printed 11/13/2012 8:45:54AM Common Well Name:MPS-39 AFE No Event Type:WORKOVER(WO) Start Date:9/16/2012 End Date:9/25/2012 X9-003JN-C:RIG(2,400,000.00) Project:Milne Point Site:M Pt S Pad Rig Name/No.: DOYON 14 Spud Date/Time: 12/31/2008 12:00:00AM Rig Release:9/24/2012 Rig Contractor: DOYON DRILLING INC. UWI:500292340500 Active Datum:MPS-39 @71.48ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 18:00 1.00 RUNCOM P RUNCMP ROLLING TEST FOR 10 MINUTES UNDER TWO WAY CHECK,TOP OF TWC 250/2000 PSI FOR 5 MINUTES EACH. -SPILL DRILL=1:45 18:00 - 19:30 1.50 RIGD P RUNCMP RIG DOWN CAPILLARY TUBE SHEAVE AND LAY DOWN ALL HANDLING EQUIPMENT. 19:30 - 22:30 3.00 RIGD P RUNCMP NIPPLE DOWN BOP 22:30 - 00:00 1.50 RIGD P RUNCMP TEST HEAT TRACE,CAPILLARY TUBE AND I-WIRE LINES. 'NIPPLE UP RADIGAN HEAD AND DRY HOLE TREE 9/25/2012 00:00 - 06:00 6.00 RIGD P RUNCMP RIG UP LUBRICATOR,TEST 250 LOW/ .2000HIGH(TEST GOOD),PULL TWC, INSTALL BPV,ROLLING TEST -LINE UP MUD PUMP#1 ON IA AND PUMPED FOR ROLLING TEST @ 5 BPM, PSI CAME UP TO 400, DID NOT GET A TEST ON BACK PRESSURE VALVE -RIG DOWN RIG FLOOR,PREP RIG FOR MOVE TO MPS-41 06:00 - 12:00 6.00 RIGD P RUNCMP SECURE ZERO PRESSURE ON IA AND TUBING,CLEAN CELLAR --PREP RIG FLOOR FOR RIG MOVE&SKID RIG FLOOR -JACK UP RIG,MOVED OFF MPS-39 -RELEASED RIG FROM MPS-39 AT 1200 Printed 11/13/2012 8:45:54AM • • MPS-39, Well History (Post Rig Workover) Date Summary 09/25/12 T/I/O= SI/O/NA Conduct PJSM. Barriers=SV&SSV. Verified by applying 500 psi against SV through tree cap. LTT Passed. Verified barriers (SSV/Wing, Lateral Valves), installed foundation,flow lines,and well house. R/U lubricator and test to 300 low and 3500 high, pulled BPV with S-10 lubricator.Tagged at 96" . 10/31/12 T/I=Vac/260.Temp=Sl. Bleed T&IA to 0 psi (Pre co-rod).AL SI @ casing&lateral valve.T FL @ 564'. IA FL @ 696'. Bled lAP to 2 psi in 5.25 hrs. Monitor during rig down, IAP increased 3 psi. Final WHPs=Vac/5. WV, SSV, MV=C. IA=OTG. NOVP. 1630. 11/02/12 T/I=0/114 Temp= SI Circ Well to Milne Crude(Post RWO) Pumped 70 bbls 90*f crude down Tbg up IA taking returns to MPS-37 Flowline. Bullheaded 55 bbls 90*f crude down Tbg. Pumped an additional 257 bbls 90*f crude down Tbg up IA taking returns to MPS-37 Flowline. Freeze protected jumper line with 5 bbls crude. Final WHPs 0/100. SV,SSV,CV= Shut IA=OTG . 11/03/12 RUN 3.35"x 40" DUMMY DRIFT S/D @ 4045' SLM PICK UP AND FALL THRU, S/D @ 4509'SLM/4537' MD (28'Correction). 11/05/12 T/I =0/9. Run Co-Rod Completion. PJSM. Move in and spot equipment. Conduct BOPE pressure tests. All pressure tests passed.AOGCC notified and declined to witness, (Bob Noble).TBG FL—30'. IA FL-100'. **Note: CHOPS operator bled IA from 18 psi to 0 psi last night. Bled a mixture of fluid and gas. Bleed off time was approx 10 min. IA increased to 10 psi in the AM and to 15 psi by 1600 hrs. 11/07/12 Run Co-Rod Completion; Cont'from WSR 11/5/12 ... MI and fire up equipment. Check well conditions. Tbg press=0 psi. IAP =25 psi. Hold pre-job safety meeting. Standing by for high winds to subside. Currently gusting over 20 mph.Winds subsided below 20 mph. RU additional wind wall around work platform to contain heat.Winds increased again mid-day. Forcasted to diminish in evening. Cancelled operations for the day.WFD crews will locate and inspect drive head. 11/08/12 Run Co-Rod Completion. Fire up equipment. Hold PJSM. Check well conditions, stable/unchanged. Hold toolbox meeting w/CHOPS operator and MPU support personnel. Perform 30 minute no flow check- passed. PU PCP Rotor, lube and hang off in tree. PU and handover gripper/injector to mast unit. MU guide arch. Deploy rotor and giraffe string. Deploy and hang off main string. No returns at tank noted. Close BOP. Lay down guide arch and secure well for the evening. 11/09/12 Run Co-Rod Completio. Fire up equipment. Hold PJSM. Lay down injector. Perform no-flow test, passed. Open BOP. Land rotor and perform space out process. Found fluid level is standing approx.40'below surface(GL). Determined that the space out requirement is 25'. Discussed with town engineer.25'puts the rod connection with the long string in the vunerable depth of the previous tubing failure. Elect to pull the long string and place the 25' pony rod at the bottom end of the long string,then re-run long string. Re- installed the injector and secured the well for the evening. Ready to round trip in the morning. 11/10/12 Run Co-Rod Completion. Fire up equipment. Clean snow fro key areas of work site. Standby for high winds(above crane limits of 20 mph). Cancel job for the day. Secure equipment and location for the night. Page 1 of 2 • • MPS-39, Well History (Post Rig Workover) Date Summary 11/11/12 Run Co-Rod Completion. Fire up equipment. Hold PJSM. Perform no-flow check on well-passed. Pulled long string. MU 25' pony rod to top of shear-sub. MU long string to top of 25'pony rod and RBIH. Check space out-good. RD guide arch and injector. MU polished rod and land pump. Closed and torqued radigans per spec.Attempt to PT radigans to 2000 psi-unsuccessful. Open and flush radigans with clean diesel. Close and re-torque radigans. Cannot get successful PT of ratigans. Both upper and lower ratigans were tested independently and it was determined that both are leaking. Called town. Secured well for the evening. 11/12/12 Run Co-Rod Completion. Elect to secure well until Ratigan rams can be repaired. Lowered co-rod completion and stacked out downhole. Checked position of top of polished rod. PU and closed ratigan slips(top ram)on the polished rod immediately below the polished rod collar. Removed landing rod. Closed both gate valves above the Ratigans. Opened lower ratigan rams so tubing can be pressure tested, unable to test now because of deteriorating weather. Begin RD WFD. Mast down on MGU. Unable to pick BOP's off of tree due to high winds and crane limit of 20 mph.Well is secure.Will complete RD after the storm. 11/14/12 T/I/0=10/30 MIT Tubing 100 psi. PASS Rigged up to companion valve with upper ratigon closed, pumped .6 bbls diesel down Tubing to reach test pressure 105 psi.Tubing lost 7 psi in 15 min's, 2 psi in 2nd 15 min's,for a total loss of 9 psi in 30 min's. Bled back+/- .5 bbls**wellhead returned to CHOPS operator** FWHP's= 10/30. 11/16/12 Change Out Radigans, Install Drive Head; Rally support equipment. RU LRS and PT tubing to 220 psig- Passed. RU WFD. Change out BOP cap and install test rod for BOP test. Note:AOGCC state rep(Chuck S.)declined witnessing the BOP test.Tested BOPE to 250 psi- Low and 2000 psi-High. BOP test Passed. Secure well for the night. 11/16/12 T/l=27/32 Pressure test Tubing 200 psi PASS Rigged up to companion valve(with upper ratagon closed) and pumped .2 bbls diesel down Tubing to reach test pressure.Tubing lost 3 psi in 5 min's.**Wellhead returned to CHOPS operator on departure**FWHP's=0/30. 11/17/12 Change Out Radigans, Install Drive Head; Cont'from WSR 11/16/12 ... On location. Site inspection. PJSM to discuss plan forward. Complete 3 hour no-flow observation- Passed. PU up on landing rod to neutral weight and open upper radigans. Space out co-rod and rotor. FMC opened up radigan bonnets and replaced seals on all four rams (2 upper and 2 lower). Seals were flow cut. Close upper and lower radigans and torque to spec. Perform PT of radigans, 200 psi Low and 2000 psi High-Passed. Removed BOPE. Installed flange and tree cap onto top of pump-in sub. Secured tree. Plan forward is to have well support remove rig-up iron and pump-in sub in the morning.WFD will then install the drive head. 11/18/12 Set rotor and rods post RWO. Lengthy job due to need to move spaceout rod and Radigan seal failure. Initial spaceout would have put a coupling several feet BELOW a high wear spot at the coupling above the hole in the old completion. Moved spaceout rod to base of co-rod. Final spaceout was 32"above the tag bar against 29"in the plan. 11/18/12 Install Drive Head. RD pump-in sub and iron. Flange up drive head. Latch onto rod with elevators and PU tro neutral. Open upper and lower radigans. PU on polished rod 3"to allow for proper spacing of rod clamp. Install rod clamp. Set rod weight onto drive head and inspect clamp-good. Close lower radigans. PT drive head flange and polished rod seal to 200 psi/1000 psi- Passed. Meet with Pad operator and inspect site. Meet with CHOPS Lead Tech and discuss well status. Lower radigans are closed and tagged. Page 2 of 2 RaWellhead: FMC Gen 5 11"digan Wellhead w/Dual Rod�sSM M P U S-39 in 30°ID Isolation Sleeve Installed in Casing Tubing Spool and Tubing Head:11"x 4-1/2",FMC Tbg Hgr Casing Spool Outlets Both Access IA 4"CIW Profile&4.5"TC-II T&B thread - Orig KB Elev.=72.45` Original GL Elev.=37.8' 20",92#,H-40,Welded,Insulated 112' - O Tam Port Collar 987' Heat Trace to 3500'MD D *NOTE:TAM-PORT Collar is at 18° inclination.It is recommended to rotate through this above 12°when running-in the MINIMUM ID ABOVE PCP STATOR: - hole with a bent housing motor or PDC bit. 3.470"inside the Polycore coated Tbg _ 9 5/8"Csg tested to 1500 psi 9/22/12 4-1/2", 12.6#,L-80,Polycore coated Tbg, w/mixed connections(TC-II,EUE,VAM < 3/8"SS Capillary Tube TOP&IBT-M) _ Q 0.433"SLB I-Wire Drift ID 3.470",Capacity=0.01522 bpf 9-5/8",47#,L-80,BTC,0.07321 bpf Csg Drift ID=8.525"Csg ID=8.681" Burst=6870 psi Collapse=4750 psi (Capacity with 4.5"inside=0.0535 bpf) 4-1/2°KBMG-LTS Chemical 4064' Injection Mandrel 4-1/2"WFD Pump Seating Nipple 4071' ~ (3.810"ID) 4-1/2"WFD Drain Sub,'1996 psi Shear 4073' 4-1/2"Phoenix Discharge Sub(failed) 4492' 7"x 9-5/8""C2"ZXP Liner Top Packer 4761' "RS"Packoff seal and HMC liner Hgr. 1 WFD PCP Stator SSSL 5000-4100 4537' 9-5/8"Casing Shoe 4865' A we---^s 3-1/2"Re-Entry Tag Sub,ID=2.00" 4567' 4-1/2"Phoenix Intake Gauge 4582` 00.:2 4-1/2"Slotted Tbg 4873'-4954' 7"Production Liner Specifications: 4-1/2"TBG Tail With Wireline Entry Guide 4964 7",26#,L-80,BTC Solid Liner ID=6.276",Drift ID=6.151" Burst=7240 psi,Collapse=5410 psi 4761'-5072'&5233'-5681'& I 6247'-6290'MD 7"26#,L-80,BTC Slotted Liner 727'0.028"Slots at 188 SPF 5072'-5233'MD&5681'-6247'MD PBTD 6287' A Well Inclination at TD=91° Float Collar at 6287'MD 7"Liner Shoe at 6290'MD,3796'TVD Ugnu Horizontal 8-1/2"Hole DATE REV.BY COMMENTS MILNE POINT UNIT 1/9/09 REH Drill and set kill string-Doyon 14 WELL#:MPS-39 6/27/2011 DAJ Drill and complete-Nabors 7ES API NO:50-029-23405-00-00 9/4/12 Hulme CoRod pull&RWO prep 9/23/12 Hulme RWO-Doyon 14 BP EXPLORATION (AK) • Page 1 of 2 Schwartz, Guy L (DOA) From: McLaughlin, Sean M [Sean.McLaughlin ©bp.com] Sent: Thursday, August 23, 2012 4:17 PM To: Schwartz, Guy L (DOA) Subject: RE: MPS -39 tubing swap Attachments: _MPS -39 CHOPs Tbg Swap 2012_draft.doc w$ — 11 3 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, August 20, 2012 4:37 PM To: McLaughlin, Sean M Subject: RE: MPS -39 tubing swap Sure... just email the procedure. Guy Schwartz Senior Petroleum Engineer SCANNED AY ,7. Z AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Monday, August 20, 2012 4:15 PM To: Schwartz, Guy L (DOA) Subject: RE: MPS -39 tubing swap Can I add the tubing swap to the scope of sundry 312 -212? In the past we have combined corod work and tubing swaps in the sundry. sean From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, August 20, 2012 4:09 PM To: McLaughlin, Sean M Subject: RE: MPS -39 tubing swap Shawn, Normally we don't require a sundry to pull tubing.. but in this case one is needed for the RWO as CHOPS is still a pilot project. The sundry keeps the Commission informed more closely with the operation and ensures appropriate regulations are being followed in this new type of production. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Monday, August 20, 2012 3:00 PM To: Schwartz, Guy L (DOA) Subject: MPS -39 tubing swap 8/24/2012 • • Page 2 of 2 Guy, There was a plan in place to pull /run corod on MPS -39. It now appears the tubing has a hole and we'd like to swap tubing after the corod is pulled. I'm not clear if a Sundry is needed for the tubing swap because this is a CHOPs well or if we can iust add scope to the current Sundry. Regards, CPA n Sean McLaughlin RWO Engineer ' f 4-4387 nfra 773 -A7R4 (f?II R /74t ?O1 • • by BP Exploration Alaska Inc. MPS -39 Well Operations Program Doyon X14 P7-1) CHOPs Tubing Swap Z p -/E3 Well Classification: Conventional High GOR Well: No X9- 003JN -C: "APE $ 2,400 M k 4 Est d „ S ept. 2012 I3 , Sean McLaughlin Deviations GP 10 -45 Temporary Pipework and Lubricator Pressure Test ADW -DEV -6345 GP 10 -10 Hammer Union Connection ADW -DEV -7064 Recommend Sean McLaughlin Date: RWO Engineer Agree Dave Reem Date: ETL Agree James Willingham Date: WTL Agree Steve Rossberg Date: D &C Operations Manager Decide Carl Mountford Date: D &C Engineering Manager • • Program Amendment Record Rev ID / Date Author D on ops4ote l A 08/27/12 Original draft submitted to Dave Reem for approval pp val NOTES FOR REV ID / OPS NOTE COLUMN: A -Z denotes the changes which were made before the program was signed Version 0 is the official signed version Ops Notes will be numbered (ex: 1, 2, 3....) Well: MPS -39 Version: A 2 Operations Program • • Contacts List Town Team Name Moo Home Dave Bjork 5683 440 -0331 344 -0063 Sean McLaughlin 4387 223 -6784 245 -1602 Carl Mountford (Eng Mgr) 4148 440 -4308 222 -6126 Dave Reem (ETL) 5743 632 -2128 346 -4424 Steve Rossberg (Ops Mgr) 5637 240 -8069 345 -7634 Jim Willingham (WTL) 5375 632 -3271 622 -4149 1- 866 - 634 -1110 Conference Call Conference Code: 857 - 176 -7171# Leader Pin: 7269397 Base Team P : - # 'VOW Mike Warren Pad Engineer 4306 258 -5537 250 -1652 North Slope Operations qi�e}yy�� - Doyon Doyon 14 Well Site Leader 4168 or 4177 4718 Well Site Leader Harmony 4 500 4506 R C Toolpusher 4169 41370 45070 Dog House 4734 670 -1111 Fax 4163 4506 ADW HSE Advisor 4650 / 659 -0234 ADW Field Engineer 4653 BP Stores 4003 / 4009 AOGCC Inspector 659 -3607 Tool Service 4634 / 4636 Greg Sarber Office: 659 -5329 Mobile: 242 -8000 Harmony: 2157 Rich Bumett Office: 659 -5329 Mobile: 748 -5821 Harmony: 2157 Well Plan Distribution: Carl Mountford (1 electronic) Mountfcf(a�bp.com James Willingham (1 hard / 1 electronic) James.Willingham(c�bp.com Dave Reem (1 hard / 1 electronic) reemdcbp.com Doyon 14 (1 hard / 1 electronic) AKDCRig14WelISiteLeader (a)bp.com RWO Superintendent (1 electronic) AKDCRWOCTDOperationsSUperintendent ©bp.com This list is the minimum distribution list for the wellplan and operational notes Invoice Cost Codes: y MS INVOICE Cam CM'►; . can; Moth* X9- 003JN- C:PRERIGDH 000010090 X9 -003JN -C:RIG 000010091 X9- 003JN- C:POSTRIGDH 000010092 Well: MPS -39 Version: A 3 Operations Program • Table of Contents 1. Scope of Work 5 1.1. Well History 5 1.2. Objectives 5 1.3. Operational Overview 5 1.4. Performance Targets 5 2. Critical Issues 6 2.1. Key Risks and Mitigation Strategy 6 2.2. Pore Pressure Prediction 7 2.3. Well Control 7 3. Well Status 7 3.1. Pre -Rig Work 7 3.2. Existing Well Information 8 4. Detailed Operations Procedures 8 1.1. ESP Swap Error! Bookmark not defined. 5. Post Well Requirements 15 6. Pressure Test Pass /Fail Criteria 16 Attachments A. Existing Wellbore Information A.1. Schematic A.2. Tubing Tallies A.3. Directional Survey A.4. Tubing caliper A.5. Static Bottom Hole Pressure Survey B. Proposed Wellbore B.1. Schematic B.2. Completion Drawings B.3. Equipment List C. Regulatory C.1. Sundry D. SOP's and eMOC's D.1. Hammer Union Deviation (ADW -DEV -7064) D.2. Temporary Pipework and Lubricator Pressure Test (ADW -DEV -6345) Well: MPS -39 Version: A 4 Operations Program • 1. Scope of Work 1.1. Well History MPS -39 was initially drilled to TD of 9881' MD in January, 2009. It was left suspended with a kill string after setting casing at 9865' MD. 163 bbls of cement were reported at surface while cementing the 9 5/8" casing. In November, 2011, the well was completed. The 9 5/8" shoe track was drilled out. The well was drilled to a TD of 6306' with 655' of net pay with no losses reported. It was circulated over to fresh LSND mud, and completed with a 7" slotted liner with two sets of slots. A Baker external casing packer was installed above the upper set of slots. A 7.3" ID isolation sleeve was installed in the casing spool on 11/13/11, prior to running the completion. Continuous clamps were run in conjunction with the heat trace and 3/8" cap tube. MPS -39 was POP in April, 2012 when the CHOPS pilot facility became available. However, following a MPU TAR in July, 2012 substantially reduced fluid rates were observed and field operators noticed evidence of TxIA communication. Returns were lost while circulating the well to light crude on July 31. PCP operation was continued for over eight hours after a torque reduction suggested light crude to the pump. At 180 RPM this should have been several tubing volumes. The tubing was bullheaded to light crude after shutting down the PCP to ensure that any heavy crude above the hole was displaced from the tubing. Fluid levels were shot near 700' MD on 7/26 and 7/28. A hole is suspected in the tubing near this depth. This is the depth of the shallowest dogleg in the hole. A program is on the WOBL to pull the corod and run a caliper in the tubing. 1.2. Objectives The primary objective of this RWO is to pull and rerun a new CHOPs completion with Polycore lined tubing 1.3. Operational Overview • Pull existing CHOPs completion • Run new CHOPs completion w/ Polycore tubing 1.4. Performance Targets Performance Group: None (out of scope repair) Time (days) AFE P50 Target 4 Performance target 3 Cost ($M) AFE P50 Target 2,400 Performance target 2,200 Key Performance Drivers • No issues with exterior cables while pull tubing. (No lessons from MPS -41) • Rerun the completion without clamp, heat trace, capillary tube, or i -wire failures. • Good pre -job prep for the unconventional completion. Well: MPS -39 Version: A 5 Operations Program • 2. Critical Issues 1. Well Risk Classification: Tier 1; Non -high GOR; No critical equipment per 10 -50. 2. H MPS -Pad is not a H Pad 3. Shut -in for Close Proximity Surface Well: There are no surface shut in requirements for the rig move to MPS -39. 4. New Technology, Tools, and /or Design Features: Polycore lined tubing - A Polycore representative visited the rig during MPS -41 and handed off a drift, stabbing guide, and lessons learned. 5. Well Control: The WSL will ensure a plan is in place at all times to deal with all Non - shearable equipment across BOPE. Several operations throughout the course of this well include situations in which non - shearable equipment will be placed across the BOP stack. It is critical that a proper plan of action be developed and agreed upon for each of these unique situations. 6. Deviation Compliance: 6.1. The use of hammer unions with differing manufactures will be allowed under deviation ADW -DEV -7064. See below for the risk reduction measures and control that shall be in place. 6.2. ADW -DEV -6345 Temporary pipework and lubricators primary role is to safely extend the well barrier envelope while the tree /wellhead valve well barrier elements are open. They serve to keep pressure and fluids within the pipe during the associated well intervention activity. When the system is 100% visible, their integrity can be accurately verified by visual leak tightness acceptance criteria when subjected to full test pressure. 2.1. Key Risks and Mitigation Strategy Well Control 1. During the RWO, communication to the reservoir will be established once the BPV is pulled. Plan to circulate KWF after pulling the BPV. 2. The kill weight fluid will be 8.4 ppg seawater during the intervention. This will provide a —115 psi static overbalance. 3. Ensure pit watcher or derrick man is filling out a trip sheet. The pit watcher or derrick man shall alert the WSL if the well deviates from the expected volumes while tripping pipe. 4. Obtain slow pump rates and pressures and record in Openwells prior to pulling and running completion. 5. SOP: Procedure for NU /ND BOPs on ESP Completions and Decompletions approves KWF to be used as a barrier when breaking containment. 6. Perform a test cut on the heat trace with the "Ratchet type Cable cutters" prior to Pull / Run ESP. 7. A full -open safety valve rated to the same pressure as the BOPs shall be available and ready to install (on any string of pipe run) on the rig floor at all times. Deviation Compliance - Hammer Union Connections 8. All hammer union connections shall conform to Wells - Alaska Region SOP: Hardline Certification and Inspection Guidelines. Well: MPS -39 Version: A 6 Operations Program • • 9. All hammer unions shall be pressure tested to maximum allowable surface pressure multiplied by a safety factor (Wells - Alaska Region SOP: Well Entry Procedure). 10. Either a) establish buffer / no -entry zones around differing manufacturer unions or, b) restrain the connections in the case of failure. Deviation Compliance - Temporary Pipework and Lubricator Pressure Test. 11. Never enter the high pressure area when the pumps are in gear pressuring up the system to test pressure. If environmental conditions preclude visual leak tight confirmation (e. g. heavy rainstorm), operations shall be delayed until inclement weather passes or utilize the pressure loss criteria in the current 10 -45 5.b. 2.2. Pore Pressure Prediction Well name Vert. Depth of BHP (Psi) Status / Actions Required Est. MPS -37 3809 1717 SI — No action needed MPS -39 3675 1349 SI — No action needed MPS -41 3701 1513 SI — No action needed MPS -43 3828 1751 SI — No action needed • There are no active Ugnu injectors 2.3. Well Control Production Interval Maximum anticipated BHP 1,367 psi @ 3,725' TVDss Ugnu (7.1 ppg EMW) Maximum surface pressure 0 -psi (based on 8.0 ppg reservoir fluids) Planned BOP test pressure Rams test to 2,000 psi /250 psi. Annular test to 2,000 psi /250 psi Planned workover Fluid 8.4 ppg seawater Planned completion fluids 8.4 ppg seawater / Diesel freeze protect Additional fluid requirements None Weighting material on location Not necessary due to pore pressure 3. Well Status Shut -in due to hole in tubing 3.1. Pre -Rig Work Task Completed 1. Wells- RD the drive head, pull corod, and install a dry hole tree, caliper tubing TBD _ 2. PPPOT -T, IC TBD 3. Install BPV, Level pad as needed for the rig TBD Well: MPS -39 Version: A 7 Operations Program • • Integrity Testing PPPOT -T: Passed to 5000 psi (11/25/2010) PPPOT -IC: Passed to 3500 psi (11/25/2010) 3.2. Existing Well Information Well Information API number: 50- 029 -23405 Permit to Drill: 2081830 Current Mechanical Condition Surface Casing: per schematic Tubing: per schematic Tubing Fluids: Milne Crude —7.2 ppg IA Fluids: Milne Crude —7.2 ppg Existing Wellhead and Tree Information Tubing Spool: FMC Gen V 11" x 11" 5k Isolation Sleeve ID = 7.3 ", Located across the casing /tubing head flange. Tubing Hanger: FMC Gen V Mandrel Tubing Hanger, 11" x 4 -1/2" TC -II top and bottom threads TC Attachment: 11" x 4-1/16" 5k for clearance of 4-1/2" Heat Trace /Hangar combo Radigan Adapter: 11" x 4 -1/16" 5k w/ Heat trace and 2 control line ports Tree: 4- 1/16" Dry hole tree BPV Profile: CIW type 'H' BPV profile 4. Detailed Operations Procedures 1.1. CHOPs tubing string replacement Reference Documents: • Pad Inspection SOP • Rig Move and Initial Rig Placement SOP Verify Start - up Checklist: ❑ Verify conformance to the Hammer Union Deviation ADW -DEV -7064. ❑ Verify conformance to Temporary Pipework and Lubricator Pressure Test ADW -DEV- 6345 ❑ Complete a pre -rig inspection with the Pad Operator prior to the rig moving on the well. ❑ Notify the AOGCC representative 24 hours in advance to witness any BOP tests. ❑ WSL shall ensure that the following work has been completed in the wellbore prior to moving the rig over the well • BPV set prior to backing over the well • Dual barriers on all annuli • Well shall remain shut -in until the rig moves over well Issues and Potential Hazards: Well: MPS -39 Version: A 8 Operations Program r • • A change from this procedure that includes decisions that increase process safety risk, change to a pressure test, or a barrier will require approval via the RAPID SOP. • Hazards specific to well The new completion has numerous clamps, I -wire, heat trace , gauges and a chemical injection mandrel, watch for pinch points and take caution when setting and pulling slips Decomplete — Rats nesting of exterior cables. Ensure the rig is centered over the well. Attempt slow and steady movement of the tubing. Under no circumstance is the tubing to be rotated. There is a 7.3" ID isolation sleeve in the wellhead. There is no intention to run any equipment larger than this and the sleeve will remain in place. Initial Well Barrier Elements: Tubing Tree Valves, Hanger Seals Inner Annulus Casing Valves, Hanger Seals Outer Annulus Casing Valves Operation Steps: RIG UP 1. MIRU • Ensure the new style radigan (two piece) is spotted behind well prior to rig up if access to V the cellar is difficult. • Rig must be centered over hole (not the tree) to avoid damaging the exterior cables • Take on seawater heated to 80 degrees to be used to circulate -out the well • Note tubing and annular pressure. 2. Hold a rig evacuation drill prior to commencing well operations and hold an AAR for the rig evacuation drill. 3. Rig up the double spooling unit (borrowed from D16) with empty cable spools installed. 4. Ensure that the tiger tank is visually inspected and that the baffle is tied down securely. Ensure hi -level alarm is function tested and operationally ready. 5. Rig up and test per Doyon "Killing the Well" SOP (circulation kill). Test pressures will be to 250 -psi low /2,000 -psi high. Test the line downstream of the choke to the isolation valve at the tiger tank to 2,000 -psi for 5 mins. Pass /Fail Criteria D located in section 6. Prior to any pumping operation ensure the hammer unions have been pressure • tested to 2,000 psi. 6. Check wellhead pressure. RU lubricator and pressure test to 250 -psi low / 2,000 psi high for five minutes each against a closed tree valve. Chart both tests. Pass /Fail Criteria D located in section 6. Changes to Well Barrier Elements: Tubing Lubricator, Hanger Seals 7. Pull BPV. Rig down lubricator. Changes to Well Barrier Elements: Well: MPS -39 Version: A 9 Operations Program • • Tubing Tree Valves, Hanger Seals CIRCULATE WELL to SEAWATER ➢ The recommended circulation path is down the tubing taking returns from the IA only. 8. At the WSL direction, bleed gas off the IA through the choke until fluid returns are observed at the tiger tank. The maximum pressure downstream of the choke to the tiger tank is 150 psi. When fluid reaches the surface, close choke. Record IA pressure. 9. Line up to pump 80 degree KWF down the tubing taking returns from IA through the choke to • the tiger tank. Pressure up to the SITP before opening up to the well. 10. At WSL direction open valve to well and slowly bring on pump. Open the choke to maintain post bleed IA pressure at the choke. Do not to exceed 2,000 psi pump pressure. 11. Circulate down the tubing the long way through entire wellbore at a minimum of 5 bpm, not exceeding 2,000 psi pump pressure. Circulate a minimum of 530 bbls ( -1.5x wellbore vol.). Once clean KWF is observed at surface returns may be taken through the rig choke to the pits. If unable to get fluid returns and zero tubing pressure bullhead KWF down the casing per Doyon SOP. Pump 1.5x casing volume to top perforation at 3 bpm keeping pressure below 2,000 psi. Note the lower than typical bullhead rate. 1) In this case, insufficient displacement due to gas swapping in not a concern. 2) Pumping at high rate into an unconsolidated sand formation may cause formation damage. There is not a need to bullhead after filling the tubing because the WLEG is in the slotted liner at 90 deg hole angle 1.5x wellbore volume will help to clean the heavy oil and over displace due to the possible hole at 700'. 12. Shut down pump flow check well for 30 minutes. Close choke and monitor pressure. If pressures are not 0 psi on the tubing and IA, contact ODE. Re- calculate required kill weight brine to achieve at least ±75 psi over - balance. If on a vacuum, determine the static loss rate. Continue to feed the well with KWF at 20 bph or keep the hole full if less than 20 bph. Changes to Well Barrier Elements: Tubing Kill weight fluid, Tree Valves, Hanger Seals Inner Annulus Kill weight fluid, Casing Valves CONTINUE RIG UP 13. RU lubricator and pressure test to 250 psi low / 2,000 psi high for five minutes each against a closed master valve. Chart both tests. Pass /Fail Criteria D located in section 6. Changes to Well Barrier Elements: Tubing Kill weight fluid, Lubricator, Hanger Seals 14. Install TWC. Attempt to test TWC from below by "rolling" the pumps to 500 psi for 10 -min without bull heading excess fluid. Pass /Fail Criteria B located in section 6. If "rolling" test fails, then continue to next step whether the 500 psi pressure was achieved or not. Test TWC from above to 250 psi low / 2,000 psi high for 5 -min. Pass /Fail Criteria A located in section 6. Chart both tests. Changes to Well Barrier Elements: Well: MPS -39 Version: A 10 Operations Program • Tubing Kill weight fluid, TWC, Hanger Seals r Bleed off control line and tubing hanger void. 15. Continuously feed KWF into the IA to maintain a stable fluid column at —20 bph (if the formation allows) during ND /NU and BOP testing operations. 16. ND dry hole tree and Radigan head. ✓ Inspect the 4 -1/2" TCII tbg hanger lift threads and verify turns. ✓ The two barriers for ND are: 1)KWF 2)TWC plus tubing hanger seals. r It is expected the fluid level will not remain at surface. Plan to continuously fill the well at 20 bph. While it may be possible to feed the well at a greater rate it will do little for well control and just increase the loss rate, fluid handling and transfers, cost, and may contribute to formation damage. ✓ Do not lift Radigan from the slip pins, they will bend. FMC has been instructed to stencil pins with w/ DO NOT LIFT HERE. r Send the tree and Radigan to the OEM. The radigan is older generation and will not be re -used. ✓ NORM test all wellhead and completion equipment. 17. NU 4- preventer BOP stack (for operational convenience, not needed for MASP). BOP configuration from top to bottom should be annular preventer, 2 - x 5" VBR's, blind shears, mud cross, 2 - x 5" VBR's, and 11" x 13 - spacer. Pressure test the BOP to 250 psi low / 2,000 psi high with a 4 -1/2" test joint for 5 minutes each and chart test. Test annular with 4- / v ti 1/2" test joint to 250 psi low / 2,000 psi high for 5 minutes each and chart test. WSL is to sign A po the test chart. Pass /Fail Criteria A located in section 6. Upload test charts and BOPE test i� v / ` form to Open Wells. Changes to Well Barrier Elements: Tubing Kill weight fluid, TWC, BOPE, Hanger Seals 18. RU the Dutch riser and DSM lubricator and pressure test to 250 psi low and 2000 psi high against TWC. Pass /Fail Criteria A located in section 6. Changes to Well Barrier Elements: Tubing Kill weight fluid, TWC, Lubricator, Hanger Seals 19. Pull TWC and RD the DSM lubricator. Changes to Well Barrier Elements: Tubing Kill weight fluid, BOPE, Hanger Seals 20. RU the BP dual spooling unit for the heat trace cable and capillary tubing. SLB will provide a spooling unit for the encapsulated TEC wire. PULL CHOPs COMPLETION 21. Review decomplete preparation and handling precautions with the crews. r Confirm spooling unit is aligned to provide a straight pull on the heat trace, and to provide operator clear view. Spooler is to be spotted far enough back from the rig to allow adequate slack in the cable. (i.e. Being able to see the entire derrick). Well: MPS -39 Version: A 11 Operations Program • • Confirm Centrilift technician has reviewed operation of unit with operator and has signed operator off as qualified on Centrilift check off sheet. A pre -job safety /planning meeting shall be held prior to beginning pulling the completion to identify risks and mitigations. Notify Centrilift representative prior to pulling the hanger. A Centrilift representative shall be on the rig floor to support heat trace and capillary tube ops. 22. PU landing joint and screw into the tubing hanger (if XO could not be easily screwed into lifting threads, MU a double grapple spear to bite in the 4 -1/2" tubing below hanger). Back out g 9 PP P 9 lock down screws. Pull tubing hanger with landing joint /XO to the floor. The weak point in the completion is the 80% of the 4 - Boronized tubing (158,400 Ibs). Due to the boronization process the tubing has been derated to J -55 properties. This does not take in account of the metal loss in the 4 -1/2" tubing due to erosion or rotating corod. The PU and SO weights were 47K# and 45K# respectively during the 2011 completion The entire 4 - tubing string has internal wear based on the results of a recent caliper. Fortunately the wear is more like a penetration and there is not significant areas of cross sectional wall loss (less than 7 %). Changes to Well Barrier Elements: Wellbore Kill weight fluid, BOPE *, Casing Valves J *Plan for Non - shearable equipment across the BOPE 23. Lay down the landing joint and the hanger. In conventional operations the cables would be secured and the completion would be run in hole to perform another circulation. It is possible the reversal of pipe direction could put stress on the three exterior cables and associated clamps. Given the reservoir characteristics of the Ugnu and its resistance to unassisted flow there is little value to a second circulation. If there is a concern bullheading fluid is preferred rather than yo -yoing pipe. 24. Pull tubing and lay down as there is no plan to re -run. Wipe the cables with absorbent to prevent oil contamination on pad. Each crew will perform a kick while pulling completion drill. Document in Openwells. Verbal acknowledgement between driller and spooler operators is required each time the completion is moved. Confirm tubing tally and jewelry list agrees w/ finished running report. Thread protectors are not required. Perform appropriate NORM testing during the decomplete. ➢ Continuously feed the well with 80 degF 8.4 ppg seawater as needed. ➢ See the tubing tally for a list of the many clamps, bands, and flat guards in the ground. Salvage and reuse the clamps as their condition allows. The i -wire, capillary tube, or heat trace will not be re -run on this well. Note in the daily operation report where the pinhole is found. Photograph the hole and send pictures to the ODE. Save the pipe, pup, or jewelry for possible inspection. Well: MPS -39 Version: A 12 Operations Program • • ➢ Send the PCP to Weatherford who will be shipping it to Edmonton for performance testing. y Mark the joint numbers and send the three joints of boronized tubing to the material coordinator. The boronized tubing will be sent to the OEM for analysis. Send all gauges and mandrels to the OEM for inspection. RUN CHOPs COMPLETION 25. Prepare to PU tubing. RU Spooling units for the 3/8" capillary tube, heat trace, and I -wire. Rabbit the tubing and jewelry before RIH. Perform visual inspection, measure and caliper all components prior to running any assembly in the hole. Ensure accurate dimensional records are made and kept for all equipment run in the well. Discuss any discrepancies with RWO engineer. Run the CHOPS Completion listed below. Keep track of loss rate to formation and notify the Engineer of any significant changes. Continuously feed the well at 20 bbl /hr or keep hole full if loss rate is less than 20 bbl /hr. • Take all the normal precautions while running the tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand -start each pin. o Use Jet Lube Seal Guard thread compound and torque turn each premium connections (H563 and TCII). o Best -O -Life 2000 thread compound for API connections (EUE and IBT -M). Function test the I -wire, 3/8" capillary tubing and heat trace every 2,000'. • Use Cannon clamps on every connection to secure I -wire and capillary tube. Use cross connection and mid -joint clamps for the heat trace. y Due to the end of the HDPE lining being wrapped around the nose of the tubing an extended length (7 ") EUE coupling is used. Ensure all Polycore to EUE connections utilize the extended length couplings. DRAFT TUBING SUMMARY LENG ID OD TH Target Depth & Notes 4 -1/2" WLEG w/ 1/2 mule shoe 2.992 4.750 1.50 5000 Pup jt.43 -1/2" IBT -M, L -80 2.992 4.250 15.00 2 jts 4 -1/2 ", 12.6 #, L -80, IBT -M Tbg Slotted, 12 slots /ft, 2" x 0.1875" 2.992 4.250 82.00 7 jts 4 -1/2 ", 12.6 #, L -80, IBT -M Tbg 2.992 4.250 287.00 TOL 7" @ 4761 XO Pup 4 -1/2" VamTop (b) x IBT -M (p) 2.992 3.877 15.00 4 -1/2" Jet Pump gauge IP /DP 2.992 5.062 2.89 XO Pup 4 -1/2" IBT -M (b) x VamTop (p) 2.992 4.250 15.00 Re -entry XO 3 -1/2" EUE (p) x 4 -1/2" IBT -M (p) 2.990 3.770 .75 Tag sub 4" EUE (p) x 3 -1/2" EUE (b) 2.990 4.500 2.29 WFD PCP stator XXXL 500 -4100 2.950 5.214 27.07 4560' ( +/- 15') XO Pup 4 -1/2" EUE (b) x EUE (p) 3.960 5.563 1.00 extended length EUE coupling 1 jt Polycore 4 -1/2" 12.6# L -80 EUE 3.960 5.563 32.00 Polycore pu 3.958 5.563 10.00 3.958 4.930 2.00 Well: MPS -39 Version: A 13 Operations Program • • start cap tube down to bottom 4 -1/2" Jet Pump gauge IP /DP 3.958 6.050 2.89 gauge 3.958 5.563 2.00 extended length EUE coupling Polycore pup 3.958 5.563 10.00 3 jts Polycore 4 -1/2" 12.6# L -80 EUE Tbg 3.958 5.563 97.00 Pup Jt Polycore - 4 -1/2" EUE Tbg 3.958 5.563 2.00 3 jts Polycore 4 -1/2" 12.6# L -80 EUE Tbg 3.958 5.563 97.00 Pup Jt Polycore - 4 -1/2" EUE Tbg 3.958 5.563 2.00 3 jts Polycore 4 -1/2" 12.6# L -80 EUE Tbg 3.958 5.563 97.00 Pup Jt Polycore - 4 -1/2" EUE Tbg 3.958 5.563 2.00 u J p Y 9 3 jts Polycore 4 -1/2" 12.6# L -80 EUE Tbg 3.958 5.563 97.00 457' giraffe string/ top at 4124' Polycore pup 3.958 5.563 10.00 " I15T -M (b 3.958 5.200 2.00 4 -1/2" WFD Drain Sub, 3996 -psi opening psi, 4 -1/2" IBT -M (bxp) 3.958 5.410 1.08 4 -1/2" WFD Pump Seating Nipple, 4 -1/2" IBT -M (pxp) 3.800 5.220 .35 pin by pin 4 -1/2" SLB KBMG -LTS Chem Inj. Mandrel CM- 40R -BK valve set at w /CM- 40R -BK 3.958 6.393 7.30 200psi. 3.958 5.563 2.00 extended length coupling Polycore pup 3.958 5.563 10.00 4050.0 125 jts Polycore 4 -1/2" 12.6# L -80 EUE Tbg 3.958 5.563 0 heat trace start -3000' TBG Hanger Pup 4 -1/2" TC -II (p) x EUE (p) 3.958 4.500 3.00 11" x 4 -1/2" FMC Tubing Hgr, TCII, Type H BPV 3.958 .72 Tubing 80% 80% 80% Tensile Drift ID Make -up Torque - Collapse Burst Optimal (ft-Ibs) 4 -1/2 ", 12.6 #, L -80 Hydril 563 SC 6,000 psi 6,740 psi 230,400 lb 3.833" 4000 4 -1/2 ", 12.6 #, L -80 TCII 6000 6740 230,400 3.833 4000 4 -1/2 ", 12.6 #, L -80 EUE 6000 6740 230,400 3.833 3940 26. Space out to locate PCP at 4,560' ( +/- 15') (bottom of pump depth). Perform space -out calculations, PU full joint, tubing hanger, and landing joint. Centrilift will terminate the heat trace, and will install lower connector and penetrator. Install I -wire and capillary tube bulk head fittings per FMC Rep. 27. Record PU and SO weights before landing hanger and record on daily operations report. 28. Land the tubing hanger and run in lock down screws. 29. Install (dry rod) TWC. Attempt to test TWC from below by "rolling" the pumps to 500 psi for 10 -min without bull heading excess fluid. Pass /Fail Criteria B located in section 6. Well is unlikely to achieve the 500 psi "rolling" test from below. If "rolling" test fails, then continue to next step whether the 500 psi pressure was achieved or not. Test TWC from above to 250 psi low / 2,000 psi high for 5 -min. Pass /Fail Criteria A located in section 6. Chart both tests. Changes to Well Barrier Elements: Tubing Kill weight fluid, TWC, BOPE, Hanger Seals Inner Annulus Kill weight fluid, Casing Valves Well: MPS -39 Version: A 14 Operations Program • • 30. Bleed all pressure to zero. Secure and encapsulate 3/8" capillary tube, I -wire, and heat trace. 31. ND BOPE. Install Radigan head per FMC Rep. Terminate capillary and I -wire lines per FMC. Install two 3 -1/8" FMC wing valves. Install two 4- 1/16" 5M valves as a dry hole tree. Test tubing hanger void to 3,500 psi for 5 minutes. Test the gate valves to 3,500 psi for 5 minutes. Pass /Fail Criteria A located in section 6. ➢ Adhere to SOP: NU /ND BOPs on ESP Completions and Decompletions. i% The two barriers for ND are: 1)KWF 2)TWC plus tubing hanger seals. Changes to Well Barrier Elements: Tubing Kill weight fluid, TWC, Hanger Seals 32. Pressure test Radigan and tree with diesel to 250 psi low / 3,500 psi high for 5 minutes. Pass /Fail Criteria A located in section 6. Chart test. 33. RU lubricator and test to 250 psi low / 2,000 psi high. Pass /Fail Criteria D located in section 6. Pull TWC with hydraulic lubricator. Changes to Well Barrier Elements: Tubing Kill weight fluid, Lubricator, Hanger Seals 34. Verify MPU assumes responsibility to freeze protect well. 35. Install BPV and attempt to test by performing a 500 psi rolling test from below for 10 minutes. Pass /Fail Criteria B located in section 6. Verify no flow from the BPV. Continue on to next step whether the "rolling" test achieves pressure or not. Changes to Well Barrier Elements: Tubing Kill weight fluid, BPV, Hanger Seals 36. RDMO. 37. Complete a post -rig inspection with the Pad Operator after moving rig off the well. 5. Post Well Requirements • Complete a post -rig inspection with the Pad Operator prior to moving the rig. • Mail the master copy of the Operations Program into the town engineer. • Email the following to the town engineer o Final Schematic o Completion Tally o Well Handover Form o IADC sheets (from Drilling Contractor) • Close out the Wellwork Transfer Permit with Operations. o The 2nd signed copy goes to the Issuing Authority and the signed off hard card is included in the well file Planned Post - Rig Operations: 1. Pull BPV and Freeze Protect 2. Run Corod. Well: MPS -39 Version: A 15 Operations Program • • 6. Pressure Test Pass /Fail Criteria A. Operational Assurance — for low volume tests (BOPE, TWC from the top) • A satisfactory pressure test is represented by the test pressure held for a minimum of 5 minutes after the pressure has stabilized (defined as stable or decreasing pressure fall off Tess than 10 psi /minute). B. Barrier — for packerless completions or PC Teaks (rolling test of TWC from the bottom). • Attempt to test TWC from below by "rolling" the pumps to 500 psi for 10 -min without bull heading excess fluid. If unable to achieve the 500 psi "rolling" test from below confirm no flow past the TWC. Continue to next step whether 500 psi was achieved or not. C. Integrity — for high volume tests (tubing, casing, TWC from the bottom) • The pressure test shall exhibit an overall pressure loss of less than 10% of the maximum test pressure over the entire 30 minute test period and one that meets the stabilization criteria will be defined as acceptable and "leak - tight ". In BPXA, the stabilization criteria for an acceptable MIT shall be defined as: • A test in which the total pressure loss in the second 15 minute test period is less than or equal to half the pressure loss in the first 15 minute test period and • A test in which the pressure fall -off rate is less than 5 psi /min for the final 15 minute test period. D. Temporary Pipework — Hardline and Lubricators • A satisfactory pressure test is represented by the test pressure held for a minimum of 5 minutes and 1) observed to be leak tight 2) the pressure decline shall be less than 250 psi. Well: MPS -39 Version: A 16 Operations Program • • bp BP Exploration(Alaska)Inc. P.O.Box 196612 900 E. Benson Boulevard Anchorage,AK 99519-6612 SCANNED Jul 223 PIT 208-- 133 August 22, 2012 nECEI► Commissioner Dan Seamount Lif �/ Alaska Oil & Gas Conservation Commission AUG ? 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 . RE: Well Test Data per. Gas Oil Ratio Waiver dated April 8, 2011 Dear Commissioner Seamount: Attached please find valid well test data for the period May-July 2012, as required by the BP Heavy Oil Pilot Gas — Oil Ratio waiver dated April 8, 2011 . Please note that BP considers this data included to be commercially sensitive. Therefore, because this data falls outside the scope of regular data described by 20 AAC 25.537, BP is requesting that it be held confidential. Should you have any questions or require any additional information, please contact me at 564-5476. Sincerely, William Mathews Pilot Operations & Wells Team Lead BP Exploration (Alaska) Inc. CC James Regg • athy Foerster Attachment: Welltest data in 10-409 format 5- Mitit-13 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL STATUS REPORT AND GAS-OIL RATIO TESTS . 20 AAC 25.270 Operator: BP Exploration(Alaska)Inc. Field and Pool: Milne Point Field, Ugnu Undefined Unit or Lease Name: Milne Point Unit Address: PO Box 199612,900 E Benson, Reporting Period: May-July, 2012 P1 of 2 Anchorage,AK 99519-6612 Well Name and No. API Number Date of Method Choke Pressures Length of Separator Production During Test Gas-Oil 50-XXX-XXXXX-XX-XX Test Size Tubing Casing Separator Test Temp,°F Water Gravity Oil Bbls. Gravity Gas MCF Ratio Cu. Bbls. Oil Gas Ft./Bbl. MPS-39 50-029-23405-00-00 05/02/12 3 NA 110 28 0 6 184 0 12.3 342 0.56 61 179 MPS-39 50-029-23405-00-00 05/06/12 3 NA 118 61 _ 0 6 185 0 12.3 352 0.56 60 171 MPS-39 50-029-23405-00-00 05/10/12 3 NA 130 107 0 8 185 0 12.4 - 301 0.56 59 1 MPS-39 50-029-23405-00-00 05/18/12 3 NA 78 -4 0 6 185 0 12.5 318 0.56 46 1 MPS-39 50-029-23405-00-00 05/22/12 3 NA 92 -4 0 6 184 0 12.0 _ 242 0.56 43 17 MPS-39 50-029-23405-00-00 05/27/12 3 NA 184 11 0 6 183 0 12.3 246 0.56 59 239 MPS-39 50-029-23405-00-00 06/01/12 3 NA 172 24 0 4 185 0 12.4 291 0.56 65 223 MPS-39 50-029-23405-00-00 06/04/12 3 NA 175 31 0 4 185 0 12.7 317 0.56 69 217 MPS-39 50-029-23405-00-00 06/05/12 3 NA 266 32 0 6 185 0 12.3 313 0.56 70 224 MPS-39 50-029-23405-00-00 06/06/12 3 NA 185 37 0 4 184 0 12.6 356 0.56 75 210 MPS-39 50-029-23405-00-00 06/08/12 3 NA 182 46 _ 0 6 184 0 12.4 361 0.56 67 186 MPS-39 50-029-23405-00-00 06/10/12 3 NA _ 179 48 0 6 185 0 12.4 379 0.56 77 204 MPS-39 50-029-23405-00-00 06/12/12 3 NA 183 49 _ 0 6 184 0 12.4 422 0.56 76 181 MPS-39 50-029-23405-00-00 06/15/12 3 NA 185 59 0 6 184 0 12.4 492 0.56 83 169 MPS-39 50-029-23405-00-00 06/20/12 3 NA 186 84 0 6 185 0 12.5 426 0.56 78 184 MPS-39 50-029-23405-00-00 06/23/12 3 NA 181 93 0 6 183 0 12.3 426 0.56 64 151 MPS-39 50-029-23405-00-00 06/24/12 3 NA 191 92 0 6 185 0 12.5 490 0.56 76 154 MPS-39 50-029-23405-00-00 06/24/12 3 NA 195 95 0 6 184 0 12.5 483 0.56 75 155 MPS-39 50-029-23405-00-00 06/26/12 3 NA 198 100 0 5 184 0 12.5 497 0.56 87 175 MPS-39 50-029-23405-00-00 06/29/12 3 NA 183 180 0 6 184 0 12.5 454 0.56 83 184 MPS-39 50-029-23405-00-00 06/30/12 3 NA 126 181 0 6 183 0 12.5 382 0.56 106 27 MPS-39 50-029-23405-00-00 07/03/12 3 NA 164 230 0 6 185 0 12.5 390 0.56 66.5 1 MPS-39 50-029-23405-00-00 07/05/12 3 NA 227 218 0 6 186 0 12.5 180 0.56 31 173 MPS-39 50-029-23405-00-00 07/05/12 3 NA 224 218 0 6 186 0 12.5 177 0.56 31 177 MPS-39 50-029-23405-00-00 07/09/12 3 NA 150 214 0 8 186 0 12.4 480 0.56 70 146 All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name: Michael Warren Title: Sr. Production Engineer Signature: Michael Warren Date: 22-Aug-12 Forfn 10-409 Rev. 12/2003 INSTRUCTIONS ON REVERSE SIDE STATE OF ALASKA t ALASKA OIL AND GAS CONSERVATION COMMISSION WELL STATUS REPORT AND GAS-OIL RATIO TESTS 20 AAC 25.270 Operator: BP Exploration(Alaska)Inc. Field and Pool: Milne Point Field,Ugnu Undefined Unit or Lease Name: Milne Point Unit Address: PO Box 199612,900 E Benson, Reporting Period: May-July, 2012 P 2 of 2 Anchorage,AK 99519-6612 Well Name and No. API Number Date of Method Choke Pressures Length of Separator Production During Test Gas-Oil 50-XXX-XXXXX-XX-XX Test Size Tubing Casing Separator Test Temp,°F Water Gravity Oil Bbls. Gravity Gas MCF Ratio Cu. Bbls. Oil Gas Ft./Bbl. MPS-39 50-029-23405-00-00 07/10/12 3 NA 152 215 0 6 187 0 12.4 435 0.56 71 163 MPS-39 50-029-23405-00-00 07/24/12 3 NA 59 89 0 6 184 0 12.4 377 0.56 60 160 MPS-39 50-029-23405-00-00 07/24/12 3 NA 48 73 0 4 184 0 12.4 385 0.56 62 16 MPS-39 50-029-23405-00-00 07/27/08 3 NA 52 75 0 6 184 0 12.4 252 0.56 37 1 MPS-39 50-029-23405-00-00 07/29/12 3 NA 63 75 0 6 185 0 12.4 191 0.56 27 14 s All tests reported herein were made in accordance with the applicable rules,regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name: Michael Warren Title: Sr.Production Engineer Signature: Michael Warren Date: 22-Aug-12 i Form 10-409 Rev. 12/2003 INSTRUCTIONS ON REVERSE SIDE • • SITAIT[E AELAMA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Clint Spence Intervention Team Leader Q. BP Exploration (Alaska), Inc. © -- P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Unit, Ugnu Undefined, MPS -39 Sundry Number: 312 -212 �� �� Dear Mr. Spence: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , j' (/ Cathy ''. Foerster Chair, Commissioner DATED this 2O day of June, 2012. Encl. STATE OF ALASKA I i o- %I/RECEIVED AA OIL AND GAS CONSERVATION COM , SION JUN 0 8 2012 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing Other Corod / PCP Completion • 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 208 - 183 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 23405 - 00 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS -39 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL380109 & 380110 Milne Point Unit / Ugnu Undefined 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6306' • 3796' • 6306' 3796' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 0" 110' 110' 1490 470 Surface 4833' 9 - 5/8" 4870' 3725' 6870 4760 Intermediate Production Liner 1529' 7" 4761' - 6290' 3688' - 3796' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5072' - 6247' 3768' - 3794' 4 - 1/2 ", 12.6# x 3 - 1/2 ", 9.2# L - 80 / 5352' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: . ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 10, 2011 ® Oil ' ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name CI' t S nce Title Intervention Team Leader / Prepared By Name/Number: Signature Phone 564 -5709 Date G / 1Z,--- Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness A / Sundry Number ❑ Plug Integrity I�BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 4 Z600 io s` g() f 7t Other: 4... X41 -rn . Welt Co..4-. Q v p ,SZ - . zc,_Ac Ls- zee Subsequent Form Required: `0 _ ` O Y APPROVED BY Approved By: °e1IP 1�i COMMISSIONER THE COMMISSION Date - /2.---- N Form 10- 403 A l20b 2 V n m / i l djv Sumit In Duplicate \\ 1Ti7 W �j U (� 6 ORiG1NA /1( ■ • • • Heavy Oil Team Today Future Forward MPS -39 Corod Replacement and Tubing Caliper Scope of Work: Pull corod and PCP Rotor, caliper tubing, run new corod and PCP rotor. MASP: 1400 psi (1777 psi @ 3756' TVD, Tess 0.1 psi gas gradient) Well Type: Ugnu Heavy Oil Producer . Estimated Start Date: June 21st, 2012 Production Engineer: Mike Warren Intervention Engineer: Aras Worthington Corod scope of Work 1. MIRU Weatherford Mast Unit and Mobile Gripper Unit (MGU). 2. Close Polish rod rams and pressure test between the rams to 2000 psi. ✓ 3. Remove Drivehead. 4. NU Corod BOPE including 1 1/8" Roc! r s and annular preventer. Lc7 r 5. Test BOPE to 2000 Rsi. -- Are R 44--, -f • o_ OW- z ,fr 6. Pull Corod completion string and PCP rotor. 7. Caliper tubing. --� 8. Run PCP Rotor with 1 1/8" Corod, Drive Rods for space -out to surface, and 1 %2" Polish -Rod. 9. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 10. ND BOP stack. 11. Install drive head. Pressure test Drive Head seals to 1000 psi. 12. RD Weatherford Mast Unit and MGU. • • ^�. COROD Safety 2'2" 1 3 -1/2 Otis 5000 1 _ II EI 4 ft ' Lubricator 3 ft 3 -1/2 Otis 5000 2 ft lft t I IL 3 -1/2 Otis 5000 ', GKS Upper Annular Assy #7473A 2 -9/16 5000 R27 Bore 2.56" Model GKS 4130 —� -- serial #48518 -3 -ACD -2 t fir; GKS Lower Annular Assy #74736 CU /64e 6'9" 2 -9/16 5000 R27 Bore 2.56' Model GKS 4130 / serial# 49618 -3 -ACD -1 O / dd 4 Rod Ram Assy �� ` p}„ ` t 3 -1/8" 10K Model serial# - r IF X -Over t 3 1/8" 10K X 41/16" 5k i- ( *lirI -451 I1?„ Flanged Pump -In Sub /Choke /Kill Line Inlet; 24" OAL 4 1/16" 5K X 41/16" 5k atidi 1.1 Gate Valves (2) To Choke 4 1/16" 5K X 41/16" 5k Check Valve "` Mb d ' h di. 1�1p g1��1��iIrmimpoj■ Kill Line (to pump) 4-ii16" Snnntt 1 —i. X' . ' C vz } =, 2 ~— Blow -Down Tee 41" Soong ' Radigan Spool/1502 Integral 11" 5000# Tbg spool ' IA Valve/1502 Integral effib am gm era fini 11 "5000# , . III • Wellhead: FMC Gen 5 11" x 4-1/16° 5M filM;T:Di . a Rad M P U S-39 s igan Wellhead w/ Dual Rod Rams . , . ,,,, 'T ,,,,,„, —,.--,, In 0 ' 1 ** 15 %'''' '''' Tubing Head: 11" x 4-112', trft,O.SPO::4.,i , ,l''it, , ,,,,/i„;,:;„.!.",t,'"iii#T , 2,61 EMC TBG Hanger Ported ooff11-11/214:P:ilisilte8d" Shear sub pinned for 30k Spacers Rods w/ Orig KB Elev = 72 45' oU__. 147: f3riginal GI Elev. = 37.8' 20", 924, H-40, Welded, Insulated' 112' 0 Tam Port Collar I 987' o Heat Trace to 3000' MD ,41/,;..;'f,T.,,y,;``'...f),ft,,, .. it„:0„S.,1 fi i .`.`/,;.:!: :.: 1 *SOO,..L..,,,,, 0# it#:*':':'R toe ioittiA13?"i.1 ,;" • A P r.., .a4.TTXmp.. `110M0* ,.=•■' '..;,.•: , , F , t';:;!lfOaridt4. 1 ;; - ::'':':: , :: 4000" of 1 118" Corod Tubing Specifications: 4-1/2", 12.64, L-80, Hydril 563 SC TBG < 3/8" SS Capillary Tube Drift ID 3.833', Capacity = 0.01522 bpf <Kr 0.433' SLB I-Wire Tubing Hanger - 967' & 2484' - 4147' MD 4-1/2", 12.64, L-80, SLHT Boronized TBG Drift ID 3,833', Capacity = 0.01522 bpf 967' - 2484' MD & 4147' - 4778' MD - -> d 3-1/2", 9.34, L-80, IBT-Mod Tbg 4-1/2" KBMG Chemical Injection I 3012' Drift ID 2.867" Capacity = 0.00870 bpf 1 Mandrel 4778' - 5352' MB 4 WFD DraM Sub, '3996 psi Shearl 41311 Note The , witEdce- tvi 9-5/8", 47#, L-80, BTC, 0 ts aoloes*avr#0139 ,07321 bpf .. i Csg Drift ID = 8.525' Csg ID = 8.681' ›. 1 Burst = 6870 psi Collapse = 4750 psi 1 • ,.1 3-1/2" Phoenix Jet Pump Gauge 1 4721' I 7" x 9-5/8' "C2" ZXP Liner Top Packer 1 4761' I Z ‘.1 'RS' Packoff seal and HMC liner Hgr PCP Stator )00Q 327-6000 I 4779' I 9-5/8' Casing Shoe I 4865' 1 3-1/2" Tag Sub, ID = 1.64' I 4808' I i 1 1 i 1 i 7" Production I iner Specifications; 7", 26#, L-80, BTC Solid Liner 11 3-1/2" TBG Tail With VVireline Entry Guide I 5352' I ID = 6 276', Drift ID = 6 151" Burst = 7240 psi, Collapse = 5410 psi 4761' - 5072' & 5233' - 5681' & 6247' - 6290' MD 7' 26#, L-80, BTC Slotted Liner 7210.028" Slots at 188 SPF 5072 - 5233 MD & 5681' - 6247 MD PBTD I 6287' I 4 L Well Inclination at TO ----- 91° Float Collar at 6287' MD 7" Liner Shoe at 6290' MD, 3796' TVD Ugnu Horizontal 8-1/2" Hole DATE REV BY COMMENTS MILNE POINT UNIT 1/9/09 REH Drill and set kill siring - Doyon 14 WELL #: MPS 6/27/2011 DA,,I Drill and complete - Nabors 7ES API NO: 50-029-23405-00-00 BP EXPLORATION (AK) • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, June 20, 2012 8:55 AM To: 'Worthington, Aras J' Subject: RE: MPS -39 Sundry and Blind /Shear Rams Aras, Thanks for the clarification... CoRod operations fall under 20 AAC 25.288 "Other Service Operations" and as such the Commission can approve alternate well control equipment as long as it ensures adequate well control. In this case, the multiple annular BOP's and rod rams are adequate for the expected pressures and flow capabilities of the heavy oil wells in Ugnu. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Monday, June 18, 2012 4:17 PM To: Schwartz, Guy L (DOA) Subject: FW: MPS -39 Sundry and Blind /Shear Rams Guy, Regarding the question of blind -shear rams for Corod Interventions: We do not have blind shear rams in our kit for Corod Interventions. The main reasons bp does not see the need for blind /shear rams for corod interventions are as follows: 1) Corod is solid and there is no flow path through the center of the rods (like there is for CT or tubulars). 2) Since the rod is solid a single rod ram is all that BP internally requires for rod BOPs for a well that is not capable of sustained and uncontrolled flow of well fluids to surface. Closing of the rod ram effectively seals off all flow -paths to surface. 3) Additionally, in Alaska BP has two annular preventers tested and rigged up on top of the rod ram for contingency and for use as a rod -wiper when needed. Please advise if AOGCC requires further information or discussion on this topic. Thanks, Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 6/20/2012 • • McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) [Joseph.Lastufka @bp.com] Sent: Wednesday, May 09, 2012 1:17 PM To: McMains, Stephen E (DOA) Subject: MPS -39 / PTD # 208 -183 Hi Steve, Please reference the following well: Well Name: MPS -39 Permit #: 208 -183 API #: 50- 029 - 23405 -00 -00 Date of Test: 4/19/2012 Type of Test: IPT (Initial Production Test) NED JUN (t 4 LUIZ Choke Size: SUVA Choke Unit: Production Method: ESP Duration (Hours Tested): 6 Top Reference (Top Perf MD): 5072' Bottom Reference (Bottom Perf MD): 6247' Tubing Flowing (Pressure): 145 Casing Pressure: 4 Total Test (Rate f/ 0, W, G): 66 / 2 / 16 24 -Hour Rate (0, W, G): 262 / 6 / 63 Gravity (Oil, API): Not Available GOR (Gas -Oil Ratio): This well began Production on Method of Operations on this date: 4/17/12 1 REGEIVLU • • STATE OF ALASKA JAN y !; 20iZ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION RL F f iN .. ■E1�7 ' 111111 S 1 a. Well Status: IS Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 0 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/15/2011 1 if 208 - 183 311 - 316 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 1/2/2009 50 029 - 23405 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/10/2011 MPS -39 3232 FSL, 489' FEL, SEC. 12, T12N, R10E, UM 8. KB (ft above MSL): 65.43' 15. Field / Pool(s): Top of Productive Horizon: 2623' FSL, 2275' FWL, SEC. 07, T12N, R11 E, UM GL (ft above MSL): 37.78' Milne Point Unit / Ugnu Undefined Total Depth: 9. Plug Back Depth (MD +TVD): 2604' FSL, 3507' FWL, SEC. 07, T12N, R11 E, UM 6306' 3796' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 565522 y 5999896 Zone ASP4 6306' 3796' ADL380109 & 380110 TPI: x- 568291 y - 5999312 Zone- ASP4 .11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 569523 y 5999305 Zone- ASP4 None 18. Directional Survey: ® Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1876' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD / GR / RES, IFR / Casandra, DIR / GR / RES / NEU / DEN N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H -40 Surface 110' Surface 110' 48" 260 sx Arcticset (Approx.) 9 -5/8" 47# L -80 37' 4870' 37' 3721' 12 -1/4" 626 sx Arcticset Lite. 111 sx DeeoCrete 7" 26# L -80 4761' 6290' 3688' 3796' 8 -1/2" Uncemented Slotted Liner 24. Open to production or injection? 0 Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 7" Slotted Sections 4 -1/2" 12.6# L -80 / J -55 4808' None MD TVD MD TVD 3 -1/2" 9.2# L -80 5352' None 5072' - 5233' 3768' - 3797' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5681' - 6247' 3812' - 3794' DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED titAtiONEZI JAN 22 6 ?NZ 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS JAN 2 3 112 Form 10-407 Revised 12/2009 Z S. . �. CONTINUED ON REVERSE /I- / 2,-/./2„„ �eY ri t Only , • 29.' GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes IS No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 2010' 1876' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. SV2 2209' 2025' None SV1 2653' 2358' Ugnu 4 3144' 2734' Ugnu 4A 3213' 2786' Ugnu 3 3261' 2822' Ugnu 2 3702' 3135' Ugnu 1 4211' 3446' Ugnu Zone C 4337' 3513' M87S 4672' 3659' M87F 4935' 3738' M8OT 5070' 3768' Formation at Total Depth (Name): Ugnu M -80 5070' 3768' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that th = • oing is t ue a- • ' r -ct to the best of my knowledge. Signed: Joe Lastufk- title: Drilling Technologist Date: 1 /1/ / 12-- MPS - 208 311 _ _ Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Dave Johnson, 564 -4171 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. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only BP AMERICA Leak -Off Test Summary Well Name: MPS -39 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure . EMW Date Type (TMD -Ft) (TVD -Ft) (ppg) (psi) (BHP) (psi) (ppg) 11/09/11 LOT 4,865.00 3,719.00 9.50 700.00 2,535.40 13.12 Page 1 of 1 • MPS -39, Well History (Pre Rig, Re- Enter) Date Summary 08/18/11 T /I /O =0/0/0 . Temp =NA RG -2401 (Surface casing corr. mitigation) PJSM. Strapped conductor @ 8 ". Install spill containment. Pumped 4.3 gal RG -2401 to fill conductor. RDMO. MANDREL HANGER W /FLUTE. 10/07/11 T /I =0 /0 MIT IA 3000 psi PASS [pre side track] Rigged up to tubing and pumped 4.2 bbls diesel down tubing to pressure up Tx IA to 3000. Unable to monitor Tubing pressure due to BPV installed in tubing. IA lost 9 psi in 15 min's, 7 psi in 2nd 15 min's, for a total loss of 16 psi in 30 min's. Bled back +/- 3 bbls from IA through jumper. Valvle positions= SV,MV,WV = closed SSV =NA, IA,OA =OTG Final WPHs= 0/0 10/10/11 T/I/O= 0/0/0, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS), pre RST. PPPOT -T: Stung into test port (0 psi). Functioned LDS (ET style), all moved freely (1"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0 psi). Functioned LDS (ET style), all moved freely (1 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 10/20/11 Well Support Demobed well and set BPV. Removed wellhouse, flowlines, foundation, installed blinds and TQ'd to spec. Page 1 of 1 • North America - ALASKA - BP Page 1 of 7 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 ©71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/5/2011 00:00 - 03:30 3.50 RIGD P PRE GENERAL RIG DOWN OPERATIONS. DISCONNECT PIT MODULE AND PULL AWAY FROM RIG. PULL CUTTINGS BOX AWAY FROM RIG. 03:30 - 04:00 0.50 RIGD P PRE LOWER DERRICK. 04:00 - 04:30 0.50 RIGD P PRE SECURE WELL R -14 AND CLEAR CELLAR AREA. 04:30 - 05:00 0.50 MOB P PRE MOVE RIG SUBSTRUCTURE OFF WELL R -14. 05:00 - 07:30 2.50 MOB P PRE STAGE RIG SUBSTRUCTURE ON R PAD. LINEUP SECURITY ESCORTS AND PREPARE TO MOVE RIG. 07:30 - 23:00 15.50 MOB P PRE MOVE NABORS 7ES RIG SUBSTRUCTURE DOWN SPINE ROAD AND MILNE POINT ACCESS ROAD TO MILNE POINT S PAD (AVERAGE RIG MOVE SPEED = 1.5 MPH). 23:00 - 00:00 1.00 MOB P PRE STAGE RIG ON MILNE POINTS PAD. 11/6/2011 00:00 - 01:00 2.00 MOB P PRE STAGE RIG ON MILNE POINTS PAD. RAISE DERRICK. 01:00 - 05:00 4.00 MOB P PRE GENERAL RIG UP OPERATIONS. BRIDLE DOWN AND RIG UP TOP DRIVE. PREPARE KUSKOKWIM CAMP, ILLIAMNA CAMP, RIG SHOP AND PIT MODULE TO MOVE FROM R PAD TO MILNE POINT S PAD. NOTE: 1 ADDITIONAL HOUR DURING TIME INTERVAL (05:00- 06:00) DUE TO DAYLIGHT SAVINGS ADJUSTMENT. 06:00 - 17:00 11.00 MOB P PRE MOVE CAMPS AND PIT MODULE TO MPS PAD. RIG CREW INSTALL LIFTING RING ON BOP STACK BELOW ANNULAR PREVENTER. ENERGIZE AND FUNCTION TEST ACCUMULATOR UNIT. 17:00 - 20:30 3.50 MOB P PRE SPOT KUSKOKWIM CAMP ON MILNE POINT TEXACO PAD. SPOT ILLIAMNA CAMP ON MPS PAD. - 17:30 HRS: VERBALLY NOTIFYAOGCC STATE REP, CHUCK SCHEVE, OF INTENTION TO BEGIN BOP TEST @ 18:00 ON 11/7/2011 (24 HOURS NOTICE). 20:30 - 21:30 1.00 MOB P PRE SPOT RIG OVER WELL MPS -39. - WH & TREE PRESSURES: T /I /O = NA/NA/0 PSI. INNER IA VALVE LOCKED OUT. - ALL PRE -RIG WORK CONFIRMED COMPLETE. 4" CAMERON TYPE H BPV INSTALLED AND TESTED ON 10/7/2011.. - WSL CHOPS PAD OPERATOR WITNESS RIG SPOTTING. - DROP PLUMB LINE FROM ROTARY TABLE TO CENTER OVER WELL. COVER RIG MATS W/ HERCULITE LINER. 21:30 - 00:00 2.50 MOB P PRE SPOT PIT MODULE AND RIG UP. SPOT CUTTINGS BOX. 11/7/2011 00:00 - 04:00 4.00 RIGU P PRE CONTINUE TO RIG UP PIT MODULE. SPOT MWD, GEO AND MUD TRAILERS. RIG UP 500 BBL DOUBLE HULL FLOWBACK TANK AND HARDLINE. Printed 11/28/2011 11:33:OOAM Worth America - ALASKA = BP 411) Faye z of 7 Operation SummaryReport Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 RIGU P PRE ACCEPT RIG AT 04:00 ON 11/7/2011. LOAD PITS WITH 290 BBLS 9.5 PPG BRINE. 05:00 - 06:30 1.50 RIGU P PRE PERFORM CMIT -TXIA WITH DIESEL TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI HIGH FOR 30 MIN (PASSING TESTS). SEE ATTACHED CHART. 06:30 - 07:30 1.00 RIGU P PRE HOLD RIG EVACUATION DRILL AND AAR WITH ALL ON LOCATION. 07:30 - 08:30 1.00 RIGU P PRE RIG UP TO CIRCULATE OUT FREEZE PROTECT. 08:30 - 12:00 3.50 RIGU P PRE MIRU WELLS SUPPORT LUBRICATOR CREW. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH (PASSING TESTS). PULL CIW 4" TYPE H BPV. RDMO LUBRICATOR CREW. 12:00 - 13:30 1.50 RIGU P PRE CIRCULATE OUT FREEZE PROTECTION, DIESEL FLUIDS WITH 9.5 PPG BRINE. - RETURNS LINED UP TO FLOWBACK TANK. DIESEL SENT TO HYDROCARBON RECYCLE © GC -2. - LINEUP ON IA AND REVERSE OUT 8 BBLS (500) OF DIESEL @ 85 GPM, 100 PSI FROM THE TUBING. PUMP 4 BBLS EXTRA 9.5 PPG BRINE TO COMPLETELY CLEANOUT DIESEL. - SWAP LINES AND CIRCULATE OUT 27 BBLS (500) OF DIESEL @ 85 GPM, 125 PSI FROM THE IA. PUMP 3 BBLS EXTRA 9.5 PPG BRINE TO COMPLETELY CLEANOUT DIESEL. - MONITOR WELL FOR 10 MINUTES TO CONFIRM WELL STATIC AFTER SHUTTING DOWN. 13:30 - 15:30 2.00 RIGU P PRE AUTHORIZATION TO PROCEED MEETINGS WITH BOTH CREWS AND MILNE POINT LEADERSHIP. 15:30 - 16:00 0.50 RIGU P PRE FMC REP ON LOCATION TO DRY ROD IN CIW 4" TYPE H TWC. 16:00 - 17:30 1.50 RIGU P PRE PRESSURE TEST TWC FROM BELOW TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN (PASSING TESTS). PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH (PASSING TESTS). 17:30 - 18:00 0.50 RIGU P PRE NIPPLE DOWN TREE (DOUBLE STACKED VALVES) 18:00 - 19:00 1.00 RIGU P PRE MAKEUP XO TO TC-II HANGER AND VERIFY NUMBER OF TURNS TO MAKEUP. BACKOUT AND RUN IN ALL LOCKDOWN SCREWS. 19:00 - 23:00 4.00 BOPSUR P DECOMP NIPPLE UP BOPE. - 13 -5/8" GK HYDRIL STACK CONSISTS OF FOLLOWING: - ANNULAR PREVENTER (NEW RUBBER ELEMENT) - 3-1/2" X 6" VB UPPER PIPE RAMS - BLIND /SHEAR RAMS - CHOKE AND KILL LINE FLOW CROSS, (1) INNER 3 -1/8" MANUAL VALVE EACH LINE, (1) OUTER 3 -1/8" HCR VALVE EACH LINE. - 2 -7/8" X 5" VB LOWER RAMS - SPACER SPOOL WITH TWO BLINDED SIDE OUTLETS. - DOUBLE STUDDED ADAPTER FLANGE Printed 11/28/2011 11:33:OOAM s[orth America?- ALASkA'M BP Page 3 of 7 operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:O0AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 BOPSUR P DECOMP HOLD RIG EVACUATION DRILL WITH ALL ON LOCATION. 11/8/2011 00:00 - 01:00 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. 01:00 - 02:00 1.00 BOPSUR P DECOMP FILL CHOKE MANIFOLD. CONFIRM GAS BUSTER VENT CLEAN. 02:00 - 08:30 6.50 BOPSUR P DECOMP PRESSURE TEST BOPE PER AOGCC REGULATIONS AND BP ADWOP. CHUCK SCHEVE, AOGCC REPRESENTATIVE, WAIVED 1. STATES RIGHT TO WITNESS TESTING. ALL TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER (SEE ATTACHED SIGNED PRESSURE CHARTS AND TEST REPORT). - 24 HOUR NOTICE WAS ORIGINALLY PROVIDED TO AOGCC AT 17:30 ON 11/7/2011. - PRESSURE TEST FOLLOWING COMPONENTS TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH. - ALL CHOKE MANIFOLD VALVES (16 TOTAL) + CHOKE/KILL LINES - MANUAL CHOKE AND MANUAL KILL LINE VALVES. - HCR CHOKE AND HCR KILL VALVES (CLOSING TIME BOTH VALVES = 1 SEC) - 3 -1/2" IF 4" HT -40 & 4 -1/2" IF FULL OPENING SAFETY VALVES. - 4" HT -40 DART VALVE. - TOP DRIVE AIR ACTUATED IBOP. - LOWER MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS (CLOSING TIME = 15 SEC) - UPPER 3 -1/2" X 6" RAMS WITH 3 -1/2" AND 4 -1/2" TEST JOINTS (CLOSING TIME ON 3 -1/2" TEST JOINT = 7 SEC) - LOWER 2 -7/8" X 5" VBRS WITH 3 -1/2" AND 4 -1/2" TEST JOINTS (CLOSING TIME ON 3 -1/2" TEST JOINT = 7 SEC) - ANNULAR PREVENTER WITH 3 -1/2" TEST JOINT (CLOSING TIME ON 3 -1/2" TEST JOINT = 22 SEC) - TEST THE HYDRAULIC SUPER CHOKE AND MANUAL BEAN CHOKE. - 1500 PSI HIGH FOR 5 MIN. - PERFORM AN ACCUMULATOR DRAWDOWN TEST. - STARTING ACCUMULATOR PRESSURE = 3025 PSI - FINAL PRESSURE AFTER FUNCTIONING ALL PREVENTERS AND TWO HCRS = 1525 PSI - 14 SEC TO BUILD 200 PSI TO 1725, 88 SEC TO FULL 3025 PSI PRESSURE. - 5 NITROGEN BACKUP BOTTLES WITH 2100 PSI. - CALIBRATE AND TEST THE SIERRA GAS MONITORING SYSTEM. 08:30 - 12:00 3.50 BOPSUR P DECOMP MIRU WELLS SUPPORT LUBRICATOR CREW. RIG UP LUBRICATOR WITH DUTCH RISER. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH (PASSING TESTS). PULL CIW 4" TYPE H TWC. RDMO LUBRICATOR CREW. Printed 11/28/2011 11:33:OOAM ` Worth America - ALASKA - BP Page 4 of 7 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 ©71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 PULL P DECOMP MAKE UP LANDING JOINT WITH4 -1/2" IF X TC II CROSSOVER TO 10" X 4 -1/2" FMC TC -II TUBING HANGER AND BACK OUT LOCKDOWN SCREWS. 13:00 - 13:30 0.50 PULL P DECOMP Pt III TI (RING HANGER m RIG Fl OOR PICKUP WEIGHT = 49 KLBS (NO OVERPULL). MONITOR WELL FOR 10 MIN. WELL STATIC. 13:30 - 14:30 1.00 PULL P DECOMP CIRCULATE 40 BBL BARAKLEAN SWEEP SURFACE TO SURFACE; 420 GPM, 715 PSI. RIG UP TO PULL AND LAYDOWN 4 -1/2" TUBING. 14:30 - 18:00 3.50 PULL P DECOMP PULL AND LAYDOWN 4-1/2",,12.6#, L -80, IBT -M TUBING (KILL STRING) FROM 2463' MD. 60 JTS TUBING, 1 'X' NIPPLE AND 1 WLEG RECOVERED. EQUIPMENT TESTS NEGATIVE FOR NORM. 18:00 - 20:00 2.00 PULL P DECOMP PULL 10" X 6.88" ISOLATION SLEEVE FROM CASING SPOOL (NEGATIVE FOR NORM). PRESSURE TEST CASING SPOOL FLANGE AND GLAND NUTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). SEE ATTACHED CHART. 20:00 - 20:30 0.50 BOPSUR P PROD1 INSTALL WEAR BUSHING. 20:30 - 22:30 2.00 DRILL P PROD1 PICKUP AND RACK BACK 16 STANDS (1505') OF 4" DRILLPIPE IN DERRICK. 22:30 - 00:00 1.50 DRILL P PROD1 MAKE UP BIT, MUD MOTOR AND MWD TOOLS TO 84' MD AT MIDNIGHT (CONTINUE ON 11/9/2011, TOTAL BHA LENGTH = 573' MD) 11/9/2011 00:00 - 04:00 4.00 DRILL P PROD1 MAKFUP 8 -1/2" DIRECTIONAI ASSFMRI Y AND SCRIBE IN HOLE TO TOTAL LENGTH AT 573' MD. SHALLOW TEST MWD TOOLS AT 200'; 500 GPM, 900 PSI. BHA COMPONENTS: - 8 -1/2" HUGHES MILL TOOTH MXL -S1V BIT WITH 4 X 18/32" NOZZLES - 7" SPERRYDRILL LOBE 7/8 6.0 STG 1.5 DEG BENT MUD MOTOR WITH PORTED FLOAT - DIR/GR/RES/NEU /AZM DEN/CALIPER MWD TOOLS - HYDRAULIC JARS MWD SENSOR DISTANCES FROM BIT: GAMMA RAY AT 39', RESISTIVITY AT 46', INCLINATION AND AZIMUTH AT 65'. 04:00 - 09:30 5.50 DRILL P PROD1 SINGLE IN HOLE WITH 4" DRILLPIPE FROM BHA AT 573' MD TO 4,618' MD. FILL PIPE EVERY 90 JOINTS. WASH AND LOG DOWN FROM 4,618' MD TO 4,781' MD; 450 GPM, 1550 PSI. TAG UP FLOAT COLLAR AT 4,781' MD. UP WEIGHT = 105 KLBS; DOWN 73 KLBS. 09:30 - 12:30 3.00 DRILL P PROD1 DISPLACE WELL FROM 9.5 PPG BRINE TO 9.5 PPG QUIKDRIL -N MUD;498 GPM, 1550 PSI,40 RPM, 6 KFT -LBS TORQUE. MONITOR WELL FOR 10 MINUTES; STATIC. SLOW PUMP RATES AT 11:30, 9.5 PPG: PUMP #1 2 BPM = 190 PSI, 3 BPM = 240 PSI. PUMP #2 2 BPM = 180 PSI, 3 BPM = 240 PSI. 12:30 - 13:30 1.00 DRILL N RREP 4,870.00 PROD1 REPAIR ROD WASH PLUMBING ON MUD PUMP #1. Printed 11/28/2011 11:33:OOAM W orth America - ALASKA - BP. P890_5 of 7 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 14:30 1.00 DRILL P PROD1 DRILL OUT CEMENT AND FLOAT EQUIPMENT FROM 4,781' MD TO 9 -5/8" CSG SHOE AT 4,865' MD. CLEAN OUT EXISTING RAT HOLE TO 4,875' MD. DRILL 20' NEW FORMATION TO 4,895' MD; 10 KLBS, 450 GPM, 1400 PSI ON BTM, 1350 PSI OFF BTM, 50 RPM, 5.8 KFT -LBS TORQUE ON BTM, 4.4 KFT -LBS TORQUE OFF BTM. 14:30 - 15:00 0.50 DRILL P PROD1 CIRCULATE BOTTOMS UP, 278 BBLS AT 500 GPM, 1430 PSI, RPM = 50. RECIPROCATE PIPE ACROSS CSG SHOE. 15:00 - 15:30 0.50 DRILL P PROD1 RACK BACK STAND TO 4,806' MD. RIG UP FOR LEAK -OFF TEST. 15:30 - 16:30 1.00 DRILL P PROD1 PERFORM LEAK -OFF TEST TO 13.1 PPG EMW (9.5 PPG, 9 -5/8" CSG SHOE AT 3719' TVD, BREAK OVER PRESSURE = 700 PSI). PRESSURE BLED OFF TO 541 PSI IN 10 MINUTES. SEE ATTACHED CHARTS. 16:30 - 17:00 0.50 DRILL P PROD1 RIG DOWN AFTER LEAK -OFF TEST. 17:00 - 00:00 7.00 DRILL P PROD1 DIRECTIONAI IlRll I R -1/2" PROIlLICTICN'j HOLE FROM 4,895' MD TO 5,399' MD (504' IN 7 HOURS, AVG 72 FPH WITH CONNECTIONS). PUMP AT 480 GPM, 1450 - 1550 PSI ON BOTTOM, 1400 - 1450 PSI OFF BOTTOM. ROTATE AT 60 RPM, 6.5KFT -LBS TORQUE ON BOTTOM, 5.7KFT -LBS TORQUE OFF BOTTOM. WEIGHT ON BIT = 20 KLBS. UP WEIGHT = 98 KLBS, DOWN = 64 KLBS, ROTATING = 77 KLBS. MW IN = 9.5 +, MW OUT = 9.6 PPG, YIELD POINT = 19. CALCULATED ECD = 9.9 PPG. NO LOSSES TO WELLBORE. SEE ATTACHED TRAVELING CYLINDER AND SLIDE SHEET. SLIDE 10' - 60' PER STAND AS NEEDED TO BUILD ANGLE FROM 73° AT CSG SHOE TO PLANNED 88° IN RESERVOIR. ACTUAL DRILLING HOURS FOR DAY = 2.59 HRS, AST = 1.52, ART = 1.07 JARS = 3.24. SLOW PUMP RATES AT 21:30, 9.6 PPG: PUMP #1 2 BPM = 240 PSI, 3 BPM = 300 PSI. PUMP #2 2 BPM = 240 PSI, 3 BPM = 300 PSI. Printed 11/28/2011 11:33:OOAM torch America - ALASKA - B ? Page 6 of Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) _ Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/10/2011 00:00 - 04:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL 8 -1/2" PRODUCTION HOLE FROM 5399' MD TO 5689' MD (290' IN 4 HOURS, AVG 73 FPH WITH CONNECTIONS). PUMP AT 480 GPM, 1450 - 1550 PSI ON BOTTOM, 1400 - 1450 PSI OFF BOTTOM. ROTATE AT 60 RPM, 220 RPM AT BIT, 6.5KFT -LBS TORQUE ON BOTTOM, 5.7KFT -LBS TORQUE OFF BOTTOM. WEIGHT ON BIT = 20 KLBS. UP WEIGHT = 95 KLBS, DOWN = 62 KLBS, ROTATING = 78 KLBS. MW IN = 9.6, MW OUT = 9.6 PPG. CALCULATED ECD = 10 PPG. NO LOSSES TO WELLBORE. NOTHING OF NOTE WHILE DRILLING ACROSS PLANNED FAULT #1 AT 5500' MD. LOGS SHOW WELLBORE PASSED THROUGH 100 OHM -M PRODUCTIVE M8OT INTERVAL FROM 5082' - 5206' MD. UNABLE TO RELOCATE BOTTOM OF ZONE WHILE INCREASING INCLINATION FROM PLANNED 88° TO 90° WHILE DRILLING TO 5689' MD. PICKUP OFF BOTTOM AND DISCUSS FORWARD PLAN WITH GEOLOGISTS AND ENGINEER. SLOW PUMP RATES AT 01:00, 9.6 PPG, 5456' MD, 3812' TVD: PUMP #1 35 SPM = 210 PSI, 52 ;✓ BPM = 270 PSI. PUMP #2 35 SPM = 220 PSI, 52 SPM = 290 PSI. 04:00 - 04:30 0.50 DRILL P PROD1 CIRCULATE AT 360 GPM, 965 PSI AND RECIPROCATE PIPE WHILE DISCUSSING PLAN FORWARD WITH GEOLOGISTS AND ENGINEER. DECISION TO CONTINUE DRILLING TO RELOCATE BOTTOM OF M8OT ZONE. 04:30 - 12:30 8.00 DRILL P PROD1 DIRECTIONAL DRILL 8 -1/2" PRODUCTION HOLE FROM 5689' MD TO 6306' MD (617' IN 8 HOURS, AVG 77 FPH WITH CONNECTIONS). PUMP AT 480 GPM, 1550 - 1600 PSI ON BTM, 1450 - 1500 PSI OFF BTM, 10 - 20 KLBS WOB, 60 RPM, 220 RPM AT BIT, 7 KFT -LBS TORQUE ON BTM, 6 KFT -LBS TORQUE OFF BTM. NO LOSSES TO WELLBORE. MW IN = MW OUT = 9.5 PPG. CALCULATED ECD = 9.9 PPG. SLIDE HIGH SIDE 30' PER STAND TO BUILD ANGLE FROM 90° TO 95 °. RE -ENTER BOTTOM OF 100 OHM -M M8OT ZONE AT 5772' MD AND STAY IN ZONE TO WELL TOTAL DEPTH AT 6306' MD. ACTUAL DRILLING HOURS FOR DAY = 5.27 HRS, AST = 3.72, ART = 4.79 Printed 11/28/2011 11:33:OOAM 1104 orth America - ALASKA - BP Page 7 of 7 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 11/5/2011 End Date: 11/11/2011 X9- 003JN -C: (1,364,375.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 ©71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 13:00 0.50 DRILL P PROD1 CIRCULATE OPEN HOLE VOLUME, 69 BBLS, AT 480 GPM, 1590 PSI, 60 RPM. FINAL PICKUP WEIGHT = 101 KLBS, DOWN = 52 KLBS, 76 KLBS SLOW PUMP RATES AT 13:00, 9.6 PPG, 6306' MD, 3796' TVD: PUMP #1 35 SPM = 230 PSI, 52 SPM = 320 PSI. PUMP #2 35 SPM = 210 PSI, 52 SPM = 310 PSI. 13:00 - 20:30 7.50 DRILL P PROD1 MAD PASS LOG FROM TD AT 6306' MD TO 9 -5/8" SURFACE CASING SHOE AT 4865' MD; 450 GPM, 1350 - 1400 PSI, 45 RPM, 205 RPM AT BIT, 6.5 KFT -LBS TORQUE. BACKREAM AT 3 - 4 FT /MIN. 20:30 - 21:30 1.00 DRILL P PROD1 CIRCULATE ONE BOTTOMS UP AT THE SURF CSG SHOE AT 4865' AT 580 GPM, 1950 PSI 1 j WHILE RECIPROCATING PIPE. 21:30 - 22:30 1.00 DRILL P PROD1 TRIP IN HOLE FROM 4865' MD TO WELL TD AT 6306' MD ON ELEVATORS. NO TIGHT SPOTS ENCOUNTERED. 22:30 - 00:00 1.50 DRILL P PROD1 CIRCULATE WELL CLEAN IN PREPARATION FOR DISPLACING TO NEW 9.5 PPG LSND QUICKDRIL -N MUD; 580 GPM, 2165 PSI. 11/11/2011 00:00 - 01:00 1.00 DRILL P PROD1 CIRCULATE WELL CLEAN IN PREPARATION FOR DISPLACING TO NEW 9.5 PPG LSND QUICKDRIL -N MUD; 360 GPM, 1050 PSI. 01:00 - 03:00 2.00 DRILL P PROD1 DISPLACE WELL FROM OLD TO NEW 9.5 PPG LSND QUICKDRIL -N MUD;480 GPM, 1450 PSI. FLOW CHECK WELL FOR 10 MIN. WELL STATIC. SLOW PUMP RATES AT 03:00, 9.5 PPG, 6306' MD, 3796' TVD: PUMP #1 35 SPM = 200 PSI, 52 SPM = 250 PSI. PUMP #2 35 SPM = 200 PSI, 52 SPM = 260 PSI. 03:00 - 04:00 1.00 DRILL P PROD1 POOH ON ELEVATORS FROM WELL TD AT 6306' MD TO SURFACE CASING SHOE AT 4865' MD. NO TIGHT SPOTS ENCOUNTERED. PICKUP WEIGHT OFF BOTTOM = 100 KLBS. 04:00 - 05:00 1.00 DRILL P PROD1 CIRCULATE ONE BOTTOMS UP AT 9 -5/8" SURFACE CASING SHOE; 500 GPM, 1400 PSI, 80 RPM. FLOW CHECK WELL. WELL STABLE. 05:00 - 07:00 2.00 DRILL P PROD1 POOH ON ELEVATORS FROM SURFACE CASING SHOE AT 4865' MD TO BHA AT 573' MD. CHECK FOR FLOW PRIOR TO BHA ENTERING BOP STACK. NO FLOW. 07:00 - 10:30 3.50 DRILL P PROD1 LAYDOWN 8-1/2" DIRECTIONAL ASSEMBLY FROM 573' MD TO SURFACE. BIT CONDITION: 1- 1- WT- A- E- I- ER -TD. END DRILLING EVENT. SEE COMPLETION REPORT #1 FOR 11/11/2011. • Printed 11/28/2011 11:33:OOAM • • North America - ALASKA - RP Page 1 of 6 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/11/2011 10:30 - 12:00 1.50 BOPSUR P RUNPRD BEGIN COMPLETION EVENT AT 10:30 ON 11/11/2011. C:I OSE BLIND RAMS AND CHANGE UPPER,. PIPE RAMS FROM 3 -1/2" X 6" VB RAMS TO 7" PIPE RAMS. 12:00 - 15:00 3.00 BOPSUR P RUNPRD PULL WEAR BUSHING AND RU TESTING EQUIPMENT. PRESSURE TEST ANNULAR PREVENTER AND LOWER PIPE RAMS WITH 2 -7/8" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH (PASSING TESTS). PRESSURE TEST UPPER PIPE RAMS WITH 7" TEST JOINT TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH (PASSING TESTS). SEE ATTACHED CHART. ALL BOP COMPONENTS FUNCTIONED TO SATISFY WEEKLY FUNCTION TEST. 15:00 - 16:00 1.00 CASING P RUNPRD RE- INSTALL WEAR BUSHING AFTER PRESSURE TESTING AND RU HANDLING EQUIPMENT FOR 2 -7/8" FOX PIPE. 16:00 - 17:00 1.00 CASING N SFAL 6,306.00 RUNPRD RUN IN HOLE WITH 2 -7/8" FOX PIPE FROM SURFACE T0405' MD. 17:00 - 17:30 0.50 CASING N SFAL 6,306.00 RUNPRD CIRCULATE THROUGH 2 -7/8" FOX PIPE AT 253 GPM, 75 PSI TO CLEANOUT. 17:30 - 19:00 1.50 CASING N SFAL 6,306.00 RUNPRD PULL AND LAYDOWN 2 -7/8" FOX PIPE FROM 405' MD TO SURFACE. HOLD UNNANOUNCED KICK WHILE TRIPPING DRILL AND AAR. 19:00 - 21:30 2.50 CASING P RUNPRP RIG IP TO RI IN 7" I INFR _. 21:30 - 00:00 2.50 CASING P RUNPRD RUN 7 ", 26 #, L -80, BTC SLOTTED /SOLID LINER FROM SURFACE TO 1300' MD AT MIDNIGHT (PROPOSED SET DEPTH = 6290' MD). CHECK FLOATS AFTER RUNNING FIRST JOINT IN HOLE. FLOATS HOLD. 11/12/2011 00:00 - 01:00 1.00 CASING P RUNPRD RUN 7" SLOTTED /SOLID LINER FROM 1300' MD AT MIDNIGHT TO 1500' MD (TOTAL LINER LENGTH). 01:00 - 01:30 0.50 CASING P RUNPRD RIG UP HANDLING EQUIPMENT FOR 2 -7/8" FOX PIPE. 01:30 - 02:00 0.50 CASING P RUNPRD PERFORM DRILL WITH CANFIELD BUSHING (WELL CONTROL EQUIPMENT FOR RUNNING INNER STRING). HOLD AAR. 02:00 - 03:00 1.00 CASING P RUNPRD RUN 2 -7/8 ", 7.7 #, L -80 FOX INNER STRING WITH FOLLOWING COMPONENTS FROM SURFACE TO 207' INSIDE 7" LINER. - 2 -7/8" PORTED TUBING PUP ABOVE CUPS - 2 -7/8" DUAL CUP TYPE PACKOFF SUB (CUPS SET 30' BELOW TOP OF ECP) - 2 -7/8" BALL SEAT BELOW SUB INNER STRING USED TO INFLATE ECP AND SET LINER TOP HANGER/PACKER WITH SLOTTED LINER IN HOLE. 03:00 - 03:30 0.50 CASING P RUNPRD RIG UP TO RUN 7" LINER ON 4" DRILLPIPE. Printed 11/28/2011 11:33:31AM orth America - ALASKA - BP 110' Page 2 of 6 ... Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:30 2.00 CASING P RUNPRD MAKEUP 7" X 9 -5/8" BAKER HMC LINER HANGER AND 7" X 9 -5/8" "C2" ZXP LINER TOP PACKER. RUN 7 ", 26 #, L -80, BTC SLOTTED /SOLID LINER FROM 1500' MD TO 2580' MD ON 4" DRILLPIPE. 05:30 - 06:30 1.00 CASING P RUNPRD RUN 7" SLOTTED /SOLID LINER ON 5" HWDP FROM 2580' MD TO 3288' MD (708' 5 ", 49# RUN FOR WEIGHT TO ASSIST WITH THE HYDRAULIC PUSHER TOOL FOR THE ZXP PACKER). 06:30 - 10:30 4.00 CASING P RUNPRD RUN 7 ", 26 #, L -80, BTC SLOTTED /SOLID LINER , ON 4" DRILLPIPE TO SET DEPTH AT 6290' MD, 3796' TVD. TOP OF LINER AT 4761' MD. NO TIGHT SPOTS ENCOUNTERED. LANDING DOWN WEIGHT = 70 KLBS. LINER SLOTTED INTERVALS = 5681' MD - 6247' MD AND 5072' MD - 5233' MD, TOTAL NET = 727' 0.28" SLOTS, 188 SPF. TOP OF BAKER ISO -ZONE EXTERNAL CASING PACKER AT 4967' MD (PACKER ELEMENT IS 10' LONG) 10:30 - 11:30 1.00 CASING P RUNPRD SET LINER TOP HANGER, INFLATE EXTERNAL CASING PACKER AND SET LINER TOP PACKER. - DROP 1/2" BALL AND PUMP DOWN DRILLPIPE AT 125 GPM, 400 PSI TO BALL SEAT IN INNER STRING BELOW DUAL CUP PACKOFF SUB - PRESSURE UP TO 1600 PSI TO SET HMC LINER HANGER. SET DOWN 50 KLBS TO CONFIRM SET. - PRESSURE UP TO 2100 PSI TO BEGIN INFLATING ECP. ALLOW PRESSURE TO STABILIZE IN ECP AT 1100 PSI. PUMP 1/4 BBL TO PRESSURE UP ECP TO 2100 PSI AND CONFIRM INFLATION. - PRESSURE UP TO 2300 PSI TO SET "C2" ZXP LINER TOP PACKER. HOLD FOR FIVE MIN. - PRESSURE UP TO 3300 PSI TO SHEAR BALL SEAT. - PICKUP 5' TO EXPOSE DOG SUBS IN RUNNING TOOL. SET DOWN 30 KLBS ON LINER TOP PACKER TO CONFIRM SET. PICKUP 5' AGAIN AND SLACKOFF ON LINER TOP PACKER WITH 25 RPM ROTATION TO CONFIRM SET. 11:30 - 12:30 1.00 CASING P RUNPRD PRESSURE TEST 9 -5/8" CASING AND 7" LINER TOP PACKER TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN (PASSING TESTS). SEE ATTACHED CHART. AUTHORIZATION TO PROCEED RECEIVED FROM WELLS TEAM LEADER. 12:30 - 13:00 0.50 CASING P RUNPRD TRIP OUT OF THE HOLE FROM 4968' MD (INNER STRING 188' BELOW LINER TOP) TO 4730' MD. 13:00 - 14:00 1.00 CASING P RUNPRD CIRCULATE ONE BOTTOMS UP AT 580 GPM, 1000 PSI. 14:00 - 15:00 1.00 CASING P RUNPRD SLIP AND CUT 68', 10 WRAPS DRILL LINE WHILE DUMPING MUD AND CLEANING PITS FOR NEW BRINE. Printed 11/28/2011 11:33:31AM orthh America ALASKA- BP . Page 3 of 6 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 16:30 1.50 CASING P RUNPRD DISPLACE WELL ABOVE LINER TOP FROM 9.5 PPG LSND TO 9.5 PPG BRINE. CHECK WELL FOR FLOW AFTER DISPLACEMENT. WELL STATIC. 16:30 - 23:00 6.50 CASING P RUNPRD TRIP OUT OF THE HOLE FROM 4730' MD TO SURFACE, LAYING DOWN 4" DRILLPIPE, 5" HWDP, AND 2 -7/8" FOX INNER STRING. 23:00 - 00:00 1.00 CASING P RUNPRD TRIP IN HOLE WITH 22 STANDS OF 4" DRILLPIPE FROM SURFACE TO 2070' MD. 11/13/2011 00:00 - 01:00 1.00 CASING P RUNPRD TRIP OUT OF HOLE FROM 2070' MD TO SURFACE, LAYING DOWN 4" DRILLPIPE. 01:00 - 01:30 0.50 BOPSUR P RUNPRD PULL WEAR BUSHING AND CLEAR RIG FLOOR. 01:30 - 03:00 1.50 BOPSUR P RUNPRD CHANGEOUT UPPER PIPE RAMS FROM 7" SOLID TO 3 -1/2" X 6" VARIABLE RAMS. 03:00 - 04:00 1.00 BOPSUR P RUNPRD PRESSURE TEST UPPER PIPE RAMS WITH 3 -1/2" AND 4 -1/2" TEST JOINTS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (PASSING TESTS). SEE ATTACHED CHART. 04:00 - 05:00 1.00 WHSUR P RUNPRD INSTALL 7" ISOLATION SLEEVE (ID = 7.30 ") IN CASING SPOOL. PRESSURE TEST TO 250 PSI LOW FOR FIVE MIN AND 5000 PSI HIGH FOR 10 MIN (PASSING TESTS). SEE ATTACHED CHARTS. NOTE: TUBING SPOOL AND CASING SPOOL OUTLETS BOTH ACCESS TUBING IA. 05:00 - 12:30 7.50 RUNCOM P RUNCMP RIG UP TO RUN 3 -1/2" X 4 -1/2" PCP CHOPS , COMPLETION. - FMC REP ON LOCATION TO MAKE DUMMY RUN WITH TUBING HANGER. - TORQUE TURN EQUIPMENT, DOUBLE STACK TONGS, SINGLE JOINT COMPENSATOR AND STABBING BOARD. - CENTRILIFT DUAL SPOOL UNIT ON GROUND WITH CAPILLARY TUBE AND HEAT TRACE LINES WITH SHEAVE IN DERRICK. - SCHLUMBERGER SPOOLING UNIT WITH I -WIRE ON RIG FLOOR AND SHEAVE IN DERRICK. - MAKEUP CROSSOVER FULL OPENING SAFETY VALVES FOR EACH TUBING CONNECTION. - BRING CONNECTION AND MID -JOINT CLAMPS TO RIG FLOOR. 12:30 - 13:00 0.50 RUNCOM P RUNCMP HOLD PRE -JOB SAFETY MEETING WITH RIG CREW AND SERVICE PROVIDERS FOR RUNNING COMPLETION 13:00 - 14:30 1.50 RUNCOM P RUNCMP BEGIN RUNNING 3 -1/2" X 4 -1/2" PCP CHOPS COMPLETION. RUN 3 -1/2 ", 9.2 #, L -80, IBT -M WITH WIRELINE ENTRY GUIDE FROM SURFACE TO 534' MD. 14:30 - 15:30 1.00 RUNCOM P RUNCMP RUN WEATHERFORD PCP STATOR AND 4 -1/2" PCP PHOENIX JET PUMP GAUGE EQUIPMENT. SLB REP INSTALL 0.433" I -WIRE IN PHOENIX GAUGE (MEASURES DOWNHOLE TEMPERATURE, VIBRATION, TUBING/ IA PRESSURE). Printed 11/28/2011 11:33:31AM fliporth America - ALASKA - BP Page 4 of 6 . Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 19:00 3.50 RUNCOM P RUNCMP RUN 4 -1/2 ", 12.6 #, J-55, SLHT, BORONIZED TUBING FROM 534' MD TO 1277' MD, INSTALLING ONE 2' SINGLE CHANNEL CLAMP PER CONNECTION TO SECURE 1 -WIRE. CONTINUE TO RUN IN HOLE WITH 4 -1/2 ", 12.6 #, L -80, HYDRIL 563 SC FROM 1277' MD TO 2317' MD, INSTALLING ONE 2' SINGLE CHANNEL CLAMP PER CONNECTION TO SECURE I -WIRE. PERFORM KICK WHILE TRIPPING DRILL. 19:00 - 20:30 1.50 RUNCOM P RUNCMP RUN CHEMICAL INJECTION MANDREL. CENTRILIFT REP INSTALL CAPILLARY TUBE FOR CHEMICAL INJECTION AND HEAT TRACE LINES. PUMP THROUGH 3/8" SS CAPILLARY TUBE TO CONFIRM TUBING CLEAR. 20:30 - 00:00 3.50 RUNCOM P RUNCMP RUN IN HOLE WITH4 -1/2 ", 12.6 #, L -80, HYDRIL 563 SC FROM 2317' MD TO 2853' MD. INSTALL CONTINUOUS CLAMPS (SEVEN 5' DUAL CHANNEL CLAMPS PER JOINT). AVERAGE 5 JOINTS PER HOUR. CHECK WIRES AND CHEMICAL LINE AT 3392' MD. 11/14/2011 00:00 - 10:30 10.50 RUNCOM P RUNCMP " # J-55 SLHT BORONIZED TUBING FROM 2853' AT MIDNIGHT TO 43 5' MD. RUN HEAT TRACE, CHEMICAL INJECTION LINE AND SLB I -WIRE. INSTALL CONTINUOUS CLAMPS (SEVEN 5' DUAL CHANNEL CLAMPS PER JOINT). AVERAGE 5 JOINTS PER HOUR. CHECK WIRES AND CHEMICAL LINE EVERY 1000' MD. PERFORM KICK WHILE TRIPPING DRILL. 10:30 - 15:30 5.00 RUNCOM P RUNCMP RUN 4 -1/2 ", 12.6 #, J-55, HYDRIL 563 SC TUBING FROM 4385' MD TO 5326' MD (LAST JOINT BEFORE TUBING HANGER). RUN HEAT TRACE, CHEMICAL INJECTION LINE AND SLB I -WIRE. INSTALL CONTINUOUS CLAMPS (SEVEN 5' DUAL CHANNEL CLAMPS PER JOINT). AVERAGE 5 JOINTS PER HOUR. CHECK WIRES AND CHEMICAL LINE EVERY 1000' MD. 15:30 - 16:00 0.50 RUNCOM P RUNCMP MAKEUP LANDING JOINT WITH FMC 11 X 4 -1/2" MANDREL TUBING HANGER (TC -1I THREADS AND CIW TYPE 1-1 BPV PROFILE) TO TUBING STRING. 16:00 - 18:30 2.50 RUNCOM P RUNCMP TERMINATE I -WIRE, HEAT TRACE AND CAPILLARY TUBE THROUGH TUBING HANGER. TEST I -WIRE AND CAPILLARY TUBE CONNECTIONS TO TUBING HANGER TO 5000 PSI FOR 10 MIN EACH (PASSING TESTS). RIG DOWN TUBING HANDLING EQUIPMENT ON RIG FLOOR. Printed 11/28/2011 11:33:31AM ("North America - ALASKA - BP Page 5 of 6 Operation. Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 19:00 0.50 RUNCOM P RUNCMP LAND 3 -1/2" X 4 -1/2" PCP CHOPS COMPLETION AT 5352' MD. FINAL UP WEIGHT = 77 KLBS, DOWN = 75 KLBS (N7ES BLOCKS = 30 KLBS). COMPLETION DETAILS: - 3 -1/2 ", 9.2 #, L -80, IBT TBG RUN 4778' - 5353' MD - 4 -1/2 ", 12.6 #, L -80, HYDRIL 563 SC TBG RUN TBG HANGER TO 967' AND 2484' - 4147' MD - 4 -1/2 ", 12.6#, J-55, SLHT, BORONIZED TBG RUN 967' - 2484' MD AND 4147' - 4778' MD - WEATHERFORD PCP STATOR TOP AT 4779' MD - PHOENIX DOWNHOLE GAUGE AT 4721' MD (40' ABOVE 7" LINE TOP AT 4761' MD) - WEATHERFORD DRAIN SUB, 3996 PSI SHEAR OPEN, AT 4131' MD - 4 -1/2" X 1" SLB KBMG CHEMICAL INJECTION MANDREL AT 3012' MD - SLB I -WIRE RUN FROM PHOENIX GAUGE TO SURFACE, CENTRILIFT HEAT TRACE AND 3/8" CHEMICAL INJECTION LINE RUN FROM CHEMICAL INJECTION MANDREL AT 3012' TO SURFACE. - (44) 2' SINGLE CHANNEL CLAMPS, (20) 2' DOUBLE CHANNEL CLAMPS, (540) 5' DOUBLE CHANNEL CLAMPS AND (8) STAINLESS STEEL BANDS IN HOLE TOTAL TIME TO RUN 5352' COMPLETION WITH 3 DOWNHOLE LINES = 30 HRS 19:00 - 19:30 0.50 RUNCOM P RUNCMP RUN IN TUBING HANGER LOCK DOWN SCREWS. LAYDOWN LANDING JOINT. 19:30 - 20:00 0.50 RUNCOM P RUNCMP RIG DOWN SHEAVES IN DERRICK AND CLEAR RIG FLOOR AFTER RUNNING COMPLETION. 20:00 - 21:30 1.50 WHSUR P RUNCMP FMC REP ON LOCATION TO DRY ROD IN CIW 4 -1/2" TYPE H TWC. PRESSURE UP BELOW TWC TO 600 PSI (OPEN TO FORMATION) AND MONITOR PRESSURE BLEED OFF TO 415 PSI IN 10 MIN. CONFIRM NO FLOW PAST TWC. PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. 21:30 - 00:00 2.50 BOPSUR P RUNCMP NIPPLE DOWN BOPS AND SECURE ON STUMP IN CELLAR. 11/15/2011 00:00 - 03:00 3.00 WHSUR P WHDTRE NIPPLE UP 11" X 4- 1/16" 5M TUBING HEAD ADAPTER FLANGE. SCHLUMBERGER AND FMC ONSITE TO ENCAPSULATE AND SECURE HEAT TRACE, I -WIRE AND CHEMICAL INJECTION LINE. PERFORM FINAL CHECKS ON I -WIRE AND HEAT TRACE (PASS). INITIAL PHOENIX DOWNHOLE MEASUREMENTS @ 4721' MD, 3685' TVD: TUBING PRESSURE = 1817 PSI, IA PRESSURE = 1823 PSI, TEMPERATURE = 68.5 °F, NO VIBRATION, CURRENT = 0.011 AMPS Printed 11/28/2011 11:33:31AM North America - ALASKA - BP Page 6 of 6 Operation Summary Report Common Well Name: MPS -39 AFE No Event Type: COM- ONSHORE (CON) Start Date: 11/11/2011 End Date: 11/15/2011 X9- 003JN -C: (4,000,000.00 ) Project: Milne Point Site: M Pt S Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 12/31/2008 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292340500 Active Datum: MPS -39 @71.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:00 1.00 WHSUR P ■- WHDTRE PRESSURE TEST TUBING HANDER VOID TO S 250 PSI LOW FOR FIVE MIN AND 5000 PSI HIGH FOR 30 MIN (PASSING TESTS). 04:00 - 05:30 1.50 WHSUR P WHDTRE ► " •" u u :_P: _► . Al WITH TWO 3 -1/8" VALVES IN OPPOSING SIDE OUTLETS. INSTALL DRY HOLE TREE ABOVE RADAGAN HEAD TWO 4- 1/16" GATE VALVES). 05:30 - 07:00 1.50 WHSUR P WHDTRE PRESSURE TEST TREE WITH DIESEL TO 250 ■ PSI LOW AND 5000 PSI HIGH FOR 5 MINUTES EACH. 07:00 - 07:30 0.50 WHSUR P -_ WHDTRE SERVICE THE TOP DRIVE, CHANGE OUT THE SAVER SUB. 07:30 - 09:30 2.00 WHSUR P ■- WHDTRE NIPPLE THE LUBRICATOR AND TEST TO LO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH. 09:30 - 11:00 1.50 WHSUR P WHDTRE PULL THE TWC WITH THE LUBRICATOR AND INSTALL THE BPV. TEST THE BPV TO 250 PSI LOW 3500 PSI HIGH FROM BELOW FOR 5 MINUTES EACH. 11:00 12:00 1.00 WHSUR P ■- WHDTRE SECURE T AND CELLAR. REMOVED HE WORKING VALVES WORKING VALVES AND INSTALLED LLED THE GAUGES. RELEASED THE RIG AT 12:00. Printed 11/28/2011 11:33:31AM • MPS -39, Well History (Post Rig Complete) C ! cl IQ Date Summary �l 1 t` 12/10/11 T /I /O= VacNac /0. Conducted PJSM. Verified barriers. R/U BPV lubricator & PT to 300 low /3500 high (charted). Pulled 4- 1/16" CIW H BPV thru dry hole tree, 1 -2' ext used, tagged © 96 ". R/D lubricator & PT tree cap to 500 psi. PT front side IA VR plug, thru blind flange to 300 low /3500 high. Removed blind flange & installed 2- 1/16" FMC 120 HWO valve, torqued to API specs. R/U VR lubricator & PT to 300 low /3500 high against VR plug(charted & recorded). Pulled 2- 1/16" FMC VR plug. Shut gate & PT to 500 psi. R/D VR lubricator & installed blind /jewelry. PT to 300 low /2500 high. ** *Job Complete * ** 12/15/11 T/I = 0/0. Install rotor, co -rod and Grenco drive head. Held pre -job safety meeting. Spotted in equipment. Performed BOP stump test. AOGCC rep, Matt Herrera contacted. (Declined to witness and gave OK to proceed). Performed BOP tests. All passed low and high PT's. RU BOP's to pump -in -sub. Pressure tested BOP's against swab and to choke skid. Passed pressure test and secured well for the night. Night watchman on duty upon departure. 12/16/11 T/I =0/0. Instal rotor, co -rod and Grenco drive head. Finish pressure testing hardline, block valves and tree valves. All pressure tests passed, see details in log. Rigged up flushby unit and secured well for the night. Left night watchman on location. 12/17/11 T/I = 0 /0. Instal rotor, co -rod and Grenco drive head. PJSM. Conduct drills and reviewed procedure. RU equip to run completion. During RU conducted 30 min no -flow test. No flow test passed. Rigged up and staged remaining equipment to run rotor and giraffe string. Ran rotor and 100' of giraffe string into well. Laid down for the night. Night watchman on location. 12/18/11 T/I = 0/0. PJSM. Check equipment. Start 30 min no flow test. No flow test passed. Rigged up and ran 600' of giraffe string. shear sub and 4000' of co -rod. All connection tightened per specs. No fluid to surface while running in hole. Rigged down guide arm and injector. Staged equipment to run spacer bars. Ran four 25' spacer rods. Torqued all threads to torque card specs. Secured well for the night. Night watchman on tower. 12/19/11 Install rotor, co -rod and Grenco drive head. PJSM. Inspect equipment and start no -flow test. Completed running spacer rods. Sat down on tag sub. Verified depth several times. Calculated length to replace spacer rods with polished rod. Pulled rod string up hole, removed the required amount of spacer rods. Ran shorter spacer rods and polished rod back into the well. Attempted to close upper radigans. Upper radigans would not fully close. Approx 1 1/2" gap according to the lines on the stems, same size as the polished rod. Called town to come up with a plan forward. Plan is to PT the tubing string and then PT the lower radigan seals. If both pressure test pass, remove one side of upper radigan to determine why they won't fully close. Tubing PT passed and lower radigan seals failed. Applied heat to let warm up over night and will test again in the morning. 12/20/11 ** *Weatherford Co- rod * ** Job Scope: Run Co -Rod, Install Drive Head: Job continued from 19 Dec 2011. PT lower radigans to 675 psi. Take apart upper radigan for visual inspection. The co -rod was not V centered in the rams. Line up co -rod and close top radigans. PT between radigans to 2000 psi. RD WFD Flush By Unit. 12/21/11 Weatherford Co- rod * ** Job Scope: Install Drive Head: Job continued from 20 Dec 2011. Crossover, Spool and Drive Head nippled up. Polish Rod secured with 6 bolt clamp and set in head, upper Radigan opened. Lower Radigan snugged and PT to 1000 psi. All equipment RDMO ** *Job Completed * ** Page 1 of 1 • North America - ALASKA - BP Milne Point MPtSPad MPS -39 500292340500 MPS -39 Design: MPS -39 • Survey Report - Geographic 11 November, 2011 • • Survey Report - Geographic tlyt , North America - ALASKA - BP 1, i$: .. . t ` Well MPS-39 Milne Point i ,t ti s' . , N -7ES Actual G 65.43ft (Nabors 7ES) ' M Pt S Pad , _ f `N -7ES Actual ( 65.43ft (Nabors 7ES) • t . 4 '' .- •`' MPS-39 •, , .d ,vg , 0 , r '' True MPS -39 h Minimum Curvature MPS-39 Data : EDM .16 - ANC Prod - WH24P ' Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site - ... MPtSPad Site Position: Northing: 5,999,978.00ft Latitude: 70° 24' 37.329 N From: Map Easting: 566,345.00ft Longitude: 149° 27' 35.171 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.51 ° *II - MPS -39 API No 500292340500 Well Position +N / -S 0.00 ft Northing: 5,999,896.46 ft Latitude: 70° 24' 36.598 N +El -W 0.00 ft Easting: 565,522.28 ft Longitude: 149° 27' 59.308 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 37.78ft Weft MPS -39 API No 500292340500 BGGM2011 10/30/2011 21.00 81.00 57,651 MPS-39 Audit Notes: Version: 3 Phase: ACTUAL Tie On Depth: 27.65 e Fes, Mtn', . _ +N/4 +E/ -W- - .. rarection, 27.65 0.00 0.00 94.00 m 111114011 0) (1 Survey { I Ilbo TWA Niittir, 0 ' - 73.95 1,178.05 MPS-39 CB- GYRO -MS (MPS -39) CB- GYRO -MS Camera based gyro multishot 1,230.59 4,831.00 MPS-39 MWD +SAG +IIFR +MS (MPS -39) MWD +IFR +MS MWD + IFR + Multi Station 4,920.01 6,237.75 MWD RUN 100 (MPS -39) MWD +IFR +MS MWD + IFR + Multi Station 11/11/2011 1 :02 :31 PM Page 2 COMPASS 2003.16 Build 73 • Survey Report - Geographic C' ny« North America - ALASKA - BP • ► rd1 Fitt Well MPS-39 t: Milne Point ' N -7ES Actual © 65.43ft (Nabors 7ES) 'attw, , Pt S Pad 1401441Siet • N -7ES Actual Q 65.43ft (Nabors 7ES) t MPS -39 loot . _ • True MPS -39 iq y , ,(et <Minimum Curvature tieogrit • MPS -39 ,Oat* . EDM .16 - ANC Prod - WH24P c1 1nz1i n Azimuth • owe +E/Att tioit#09 10$019 • #ft) .. "} (ft • ` ; • Lititude LtortgItuite, .' 27.65 0.00 0.00 27.65 0.00 0.00 5,999,896.46 565,522.28 70° 24' 36.598 N 149° 27' 59.308 W 73.95 0.19 45.95 73.95 0.05 0.06 5,999,896.51 565,522.33 70° 24' 36.599 N 149° 27' 59.306 W 162.95 1.22 153.42 162.94 -0.69 0.59 5,999,895.77 565,522.87 70° 24' 36.591 N 149° 27' 59.290 W 256.95 2.34 159.57 256.90 -3.38 1.70 5,999,893.09 565,524.01 70° 24' 36.565 N 149° 27' 59.258 W 348.95 3.87 155.66 348.76 -7.97 3.64 5,999,888.52 565,525.99 70° 24' 36.520 N 149° 27' 59.201 W 438.95 5.75 150.58 438.44 -14.67 7.10 5,999,881.86 565,529.51 70° 24' 36.454 N 149° 27' 59.099 W 526.95 7.92 145.52 525.81 -23.51 12.70 5,999,873.07 565,535.19 70° 24' 36.367 N 149° 27' 58.935 W 615.95 10.50 145.11 613.65 -35.22 20.81 5,999,861.43 565,543.40 70° 24' 36.252 N 149° 27' 58.697 W 708.95 13.24 147.17 704.66 -51.12 31.44 5,999,845.62 565,554.16 70° 24' 36.095 N 149° 27' 58.386 W 802.95 14.53 147.86 795.91 -70.15 43.55 5,999,826.70 565,566.44 70° 24' 35.908 N 149° 27' 58.031 W 896.95 15.91 145.11 886.61 -90.70 57.19 5,999,806.27 565,580.26 70° 24' 35.706 N 149° 27' 57.631 W 989.95 17.55 137.72 975.68 - 111.54 73.92 5,999,785.59 565,597.17 70° 24' 35.501 N 149° 27' 57.141 W 1,084.95 18.75 127.93 1,065.97 - 131.52 95.60 5,999,765.79 565,619.02 70° 24' 35.305 N 149° 27' 56.505 WI 1,177.95 19.75 125.68 1,153.77 - 149.88 120.16 5,999,747.66 565,643.74 70° 24' 35.124 N 149° 27' 55.786 W 1,230.59 20.28 122.87 1,203.24 - 160.02 135.04 5,999,737.65 565,658.71 70° 24' 35.024 N 149° 27' 55.349 W 1,317.98 22.52 120.28 1,284.60 - 176.68 162.22 5,999,721.23 565,686.03 70° 24' 34.860 N 149° 27' 54.553 W 1,408.47 26.79 118.40 1,366.82 - 195.12 195.14 5,999,703.07 565,719.11 70° 24' 34.679 N 149° 27' 53.588 W 1,506.24 29.37 118.71 1,453.07 - 217.12 235.56 5,999,681.43 565,759.71 70° 24' 34.463 N 149° 27' 52.404 W 1,605.36 29.56 116.93 1,539.38 - 239.87 278.67 5,999,659.06 565,803.02 70° 24' 34.239 N 149° 27' 51.140 WI 1,698.77 30.65 120.20 1,620.19 - 262.29 319.80 5,999,637.01 565,844.34 70° 24' 34.018 N 149° 27' 49.934 W 1,790.14 32.29 118.72 1,698.12 - 285.73 361.33 5,999,613.93 565,886.07 70° 24' 33.788 N 149° 27' 48.717 W 1,884.22 35.96 120.04 1,775.99 - 311.65 407.30 5,999,588.43 565,932.26 70° 24' 33.533 N 149° 27' 47.370 W 1,978.63 38.04 118.39 1,851.38 - 339.36 456.89 5,999,561.16 565,982.09 70° 24' 33.260 N 149° 27' 45.916 W 2,075.72 40.86 116.32 1,926.35 - 367.67 511.69 5,999,533.33 566,037.13 70° 24' 32.982 N 149° 27' 44.311 W 2,168.58 42.84 113.55 1,995.52 - 393.75 567.87 5,999,507.74 566,093.53 70° 24' 32.725 N 149° 27' 42.664 W 2,263.85 42.49 110.79 2,065.59 - 418.12 627.65 5,999,483.90 566,153.51 70° 24' 32.486 N 149° 27' 40.912 W 2,357.09 42.49 107.75 2,134.35 - 438.90 687.08 5,999,463.65 566,213.12 70° 24' 32.281 N 149° 27' 39.170 W 2,450.03 42.09 105.10 2,203.11 - 456.58 747.05 5,999,446.49 566,273.24 70° 24' 32.107 N 149° 27' 37.412 W 2,543.83 39.97 100.28 2,273.88 - 470.15 807.07 5,999,433.45 566,333.37 70° 24' 31.974 N 149° 27' 35.653 W 2,637.54 38.85 98.13 2,346.28 - 479.68 865.79 5,999,424.44 566,392.16 70° 24' 31.880 N 149° 27' 33.933 W 2,731.79 39.31 97.35 2,419.45 - 487.68 924.66 5,999,416.95 566,451.10 70° 24' 31.801 N 149° 27' 32.207 W 2,825.35 40.02 97.65 2,491.47 - 495.48 983.87 5,999,409.68 566,510.37 70° 24' 31.725 N 149° 27' 30.472 W 2,918.50 40.23 98.18 2,562.69 - 503.75 1,043.33 5,999,401.93 566,569.89 70° 24' 31.643 N 149° 27' 28.729 W 3,012.56 40.81 98.62 2,634.20 - 512.68 1,103.78 5,999,393.54 566,630.41 70° 24' 31.555 N 149° 27' 26.958 W 3,106.23 40.84 99.07 2,705.08 - 522.09 1,164.29 5,999,384.65 566,691.00 70° 24' 31.463 N 149° 27' 25.184 W 3,199.98 40.55 98.39 2,776.16 - 531.37 1,224.71 5,999,375.90 566,751.49 70° 24' 31.371 N 149° 27' 23.413 W 3,293.84 41.40 98.64 2,847.02 - 540.48 1,285.58 5,999,367.33 566,812.43 70° 24' 31.281 N 149° 27' 21.630 W 3,388.28 43.33 97.59 2,916.80 - 549.46 1,348.58 5,999,358.91 566,875.50 70° 24' 31.193 N 149° 27' 19.783 W 3,482.26 45.06 97.81 2,984.18 - 558.24 1,413.50 5,999,350.70 566,940.49 70° 24' 31.107 N 149° 27' 17.881 W 3,575.36 46.45 95.96 3,049.14 - 566.22 1,479.70 5,999,343.30 567,006.75 70° 24' 31.028 N 149° 27' 15.940 W 3,669.52 47.74 94.78 3,113.24 - 572.66 1,548.37 5,999,337.45 567,075.47 70° 24' 30.964 N 149° 27' 13.928 W 3,763.41 48.66 94.37 3,175.82 - 578.24 1,618.14 5,999,332.49 567,145.27 70° 24' 30.909 N 149° 27' 11.883 WI 3,857.69 50.14 92.43 3,237.18 - 582.48 1,689.59 5,999,328.88 567,216.75 70° 24' 30.868 N 149° 27' 9.789 W 3,952.20 52.16 92.21 3,296.46 - 585.45 1,763.13 5,999,326.55 567,290.31 70° 24' 30.838 N 149° 27' 7.634 W 4,041.69 54.26 91.74 3,350.05 - 587.92 1,834.75 5,999,324.71 567,361.94 70° 24' 30.814 N 149° 27' 5.535 W 4,136.10 55.90 91.88 3,404.09 - 590.37 1,912.12 5,999,322.95 567,439.32 70° 24' 30.790 N 149° 27' 3.267 W 4,232.59 56.64 91.77 3,457.67 - 592.92 1,992.32 5,999,321.10 567,519.54 70° 24' 30.764 N 149° 27' 0.917 W 4,324.04 58.96 91.63 3,506.40 - 595.21 2,069.67 5,999,319.48 567,596.89 70° 24' 30.741 N 149° 26' 58.650 W 4,417.35 62.48 92.12 3,552.03 - 597.88 2,151.00 5,999,317.53 567,678.24 70° 24' 30.715 N 149° 26' 56.266 W 4,513.56 64.57 91.25 3,594.91 - 600.41 2,237.08 5,999,315.75 567,764.33 70° 24' 30.690 N 149° 26' 53.743 W 4,607.25 66.27 91.33 3,633.89 - 602.33 2,322.25 5,999,314.58 567,849.51 70° 24' 30.671 N 149° 26' 51.247 W 4,701.15 70.22 90.35 3,668.68 - 603.60 2,409.44 5,999,314.08 567,936.69 70° 24' 30.658 N 149° 26' 48.692 W 4,795.10 72.34 88.91 3,698.83 - 603.01 2,498.41 5,999,315.44 568,025.64 70° 24' 30.663 N 149° 26' 46.084 W 4,831.00 72.78 89.32 3,709.59 - 602.49 2,532.65 5,999,316.27 568,059.88 70° 24' 30.669 N 149° 26' 45.081 W 4,926.06 75.45 90.71 3,735.61 - 602.52 2,624.07 5,999,317.04 568,151.29 70° 24' 30.668 N 149° 26' 42.401 W 11/11/2011 1:02:31PM Page 3 COMPASS 2003.16 Build 73 • • Survey Report - Geographic North America ALASKA - BP Ofttift,0 i�R: Well MP Milne Point R N -7ES Actual @ 65.43ft (Nabors 7ES) M Pt S Pad " OsOitteket N -7ES Actual @ 65.43ft (Nabors 7ES MPS-39 } True , MPS -39 . Minimum Curvature mayy , , .w'.r, MPS -39 � , $ i ' EDM .16 - ANC Prod - WH24P ,.r No g 5,020.40 77.61 93.27 3,757.59 - 605.71 2,715.75 5,999,314.65 568,242.98 70° 24' 30.636 N 149° 26' 39.715 W 5,114.57 78.78 92.48 3,776.85 - 610.33 2,807.81 5,999,310.84 568,335.07 70° 24' 30.590 N 149° 26' 37.017 W 5,208.57 81.05 92.12 3,793.31 - 614.05 2,900.27 5,999,307.94 568,427.55 70° 24' 30.554 N 149° 26' 34.307 W 5,270.67 83.81 90.92 3,801.49 - 615.68 2,961.80 5,999,306.85 568,489.09 70° 24' 30.537 N 149° 26' 32.503 W 5,303.76 85.93 91.17 3,804.45 - 616.28 2,994.75 5,999,306.53 568,522.04 70° 24' 30.531 N 149° 26' 31.538 W 5,334.73 87.97 91.06 3,806.10 - 616.88 3,025.67 5,999,306.20 568,552.96 70° 24' 30.525 N 149° 26' 30.631 W 5,365.61 88.57 90.54 3,807.03 - 617.31 3,056.54 5,999,306.04 568,583.82 70° 24' 30.521 N 149° 26' 29.727 W 5,396.69 88.04 90.35 3,807.95 - 617.55 3,087.60 5,999,306.07 568,614.89 70° 24' 30.518 N 149° 26' 28.816 W 5,488.53 88.58 90.00 3,810.66 - 617.83 3,179.40 5,999,306.60 568,706.68 70° 24' 30.515 N 149° 26' 26.126 W 5,583.85 89.38 89.41 3,812.36 - 617.34 3,274.70 5,999,307.93 568,801.96 70° 24' 30.520 N 149° 26' 23.333 W 5,647.88 90.29 89.87 3,812.54 - 616.94 3,338.73 5,999,308.89 568,865.98 70° 24' 30.523 N 149° 26' 21.456 W 5,678.27 90.76 90.08 3,812.26 - 616.93 3,369.12 5,999,309.17 568,896.36 70° 24' 30.523 N 149° 26' 20.566 W 5,707.81 93.29 90.80 3,811.22 - 617.15 3,398.64 5,999,309.20 568,925.88 70° 24' 30.521 N 149° 26' 19.701 W 5,737.96 94.19 91.53 3,809.25 - 617.76 3,428.72 5,999,308.85 568,955.96 70° 24' 30.515 N 149° 26' 18.819 W 5,770.59 95.00 91.64 3,806.64 - 618.66 3,461.23 5,999,308.24 568,988.47 70° 24' 30.506 N 149° 26' 17.866 W 5,798.79 94.34 91.25 3,804.34 - 619.37 3,489.33 5,999,307.78 569,016.57 70° 24' 30.499 N 149° 26' 17.043 W 5,835.52 94.32 91.34 3,801.57 - 620.20 3,525.94 5,999,307.27 569,053.19 70° 24' 30.490 N 149° 26' 15.970 W 5,866.66 93.17 91.07 3,799.54 - 620.85 3,557.01 5,999,306.89 569,084.26 70° 24' 30.484 N 149° 26' 15.059 W 5,898.26 92.17 90.69 3,798.06 - 621.34 3,588.57 5,999,306.68 569,115.82 70° 24' 30.479 N 149° 26' 14.134 W 5,926.30 90.96 90.26 3,797.30 - 621.57 3,616.60 5,999,306.70 569,143.85 70° 24' 30.476 N 149° 26' 13.313 W 5,959.43 91.20 90.56 3,796.67 - 621.81 3,649.72 5,999,306.75 569,176.97 70° 24' 30.474 N 149° 26' 12.342 W 5,992.76 92.44 90.66 3,795.61 - 622.16 3,683.03 5,999,306.69 569,210.28 70° 24' 30.470 N 149° 26' 11.366 W 6,024.05 92.98 90.52 3,794.14 - 622.48 3,714.28 5,999,306.64 569,241.53 70° 24' 30.467 N 149° 26' 10.450 W 6,054.21 92.31 90.66 3,792.74 - 622.79 3,744.41 5,999,306.59 569,271.65 70° 24' 30.464 N 149° 26' 9.567 W 6,081.41 92.40 90.99 3,791.63 - 623.19 3,771.58 5,999,306.44 569,298.83 70° 24' 30.460 N 149° 26' 8.770 W 6,116.06 90.35 90.65 3,790.79 - 623.68 3,806.22 5,999,306.25 569,333.46 70° 24' 30.455 N 149° 26' 7.755 W 6,142.75 89.13 90.95 3,790.92 - 624.05 3,832.91 5,999,306.11 569,360.15 70° 24' 30.451 N 149° 26' 6.973 W 6,180.16 88.21 90.97 3,791.78 - 624.68 3,870.30 5,999,305.81 569,397.54 70° 24' 30.445 N 149° 26' 5.877 W 6,211.41 88.06 90.92 3,792.80 - 625.20 3,901.53 5,999,305.57 569,428.77 70° 24' 30.439 N 149° 26' 4.962 W 6,237.75 87.96 91.14 3,793.72 - 625.67 3,927.85 5,999,305.33 569,455.09 70° 24' 30.435 N 149° 26' 4.191 W 6,306.00 87.96 91.14 3,796.14 - 627.03 3,996.04 5,999,304.57 569,523.29 70° 24' 30.421 N 149° 26' 2.192 W 11/112011 1:02:31 PM Page 4 COMPASS 2003.16 Build 73 . • Survey Report - Geographic C ' . North America - ALASKA - BP : Well MPS-39 Milne Point :' N -7ES Actual @ 65.43ft (Nabors 7ES) M Pt S Pad 06 . N -7ES Actual © 65.43ft (Nabors 7ES) MPS -39 i , - True MPS -39 S t 0a'tlOtr iii Minimum Curvature MPS -39 s , , W . EDM .16 - ANC Prod - H24P , li4S144 ,Ver^flall ' , Virg Hoa D r 4 i M otr Pt) 114: sari, : . t ( 4,863.96 3,719.10 SURFACE CASING 9.625 12.250 ' 1,995.76 1,864.83 BPRF 0.00 0.00 3,132.32 2,724.83 Ugnu 4a (from MPS -11) 0.00 0.00 4,328.77 3,508.83 TUZC 0.00 0.00 1 4,959.64 3,743.83 M87F ( -Ugnu Ma) 0.00 0.00 5,104.23 3,774.83 M8OT ( -MB1) 0.00 0.00 3,844.83 M80_1Rflood 0.00 0.00 3,935.83 M80S 0.00 0.00 3,972.83 M70S (Na sand) 0.00 0.00 3,974.83 Top NB hardline 0.00 0.00 aAirtrD#it+ ted Vertk5l Local Coord . .. ' 000.0 ' . ' Depth . .4- ___ : : } - ( : { . . . t .. c 193.35 193.33 -1.36 0.90 Start Dir 2.37 ?/100' : 200' MD, 200'TVD 643.35 640.56 -39.49 23.75 Start Dir 2.32 ?/100' : 650' MD, 647.41'TVD 1,979.16 1,851.80 - 339.51 457.18 End Dir : 1985.81' MD, 1850' TVD 2,108.38 1,950.92 - 377.04 531.06 Start Dir 2 ?/100' : 2115.03' MD, 1950'TVD 2,684.12 2,382.50 - 483.73 894.80 End Dir : 2690.77' MD, 2397.03' TVD 3,200.76 2,776.75 - 531.44 1,225.21 Start Dir 2 ?/100' : 3207.41' MD, 2796.83'TVD Checked By: Approved By: Date: 11/11/2011 1 :02 :31 PM Page 5 COMPASS 2003.16 Build 73 • Wellhead: FMC Gen 5 11" x 4- 1/16 ". NOTE: 7. Isolation Sleeve Installed Radigan Wellhead w/ Dual Rod Rams M P U S -39 in Casing 01. Tubing Spool and Tubing Head: 11" x 4 -1/2 ", Casing Spool Outlets Both Access IA FMC TBG Hanger Ported Orig. KB Elev. = 72.45' < 40' of 1 -1/2" Polished Rod Original GL Elev. = 37.8' ❑ I 176' of 1 1/4" & 1 1/8" Spacers Rods w/ < Shear sub pinned for 30k 20 ", 92 #, H -40, Welded, Insulated) 112' I C Tam Port Collar I 987' 0 Heat Trace to 3000' MD D "NOTE: TAM -PORT Collar is at 18° inclination. It is recommended to rotate through this above 12 when running in the MINIMUM 1D ABOVE PCP STATOR: hole with a bent housing motor or PDC bit. 3.865" at 3012' MD KBMG Chemical Injection Mandrel - 4000' of 1 1/8" Corod Tubing Specifications: 4 -1/2 ", 12.6 #, L -80, Hydril 563 SC TBG 3/8" SS Capillary Tube Drift ID 3.833 ", Capacity = 0.01522 bpf Q 0.433" SLB I -Wire Tubing Hanger - 967' & 2484' - 4147' MD 4 -1/2 ", 12.6 #, L -80, SLHT Boronized TBG Drift ID 3.833 ", Capacity = 0.01522 bpf 967' - 2484' MD & 4147' - 4778' MD 3 -1/2 ", 9.3 #, L -80, IBT -Mod Tbg 4 -1/2" KBMG Chemical Injection 1 3012' Drift ID 2.867 ", Capacity = 0.00870 bpf Mandrel 4778' - 5352' MD .-,n. 4 -1/2" WFD Drain Sub, 3996 psi Shear' 4131' I 9 -5/8 ", 47 #, L -80, BTC, 0.07321 bpf Csg Drift ID = 8.525" Csg ID = 8.681" > ' Burst = 6870 psi Collapse = 4750 psi 1 MI ■, N ;1 3 -1/2" Phoenix Jet Pump Gauge 1 4721' I 7" x 9 -5/8" "C2" ZXP Liner Top Packer 1 4761' I Z "RS" Packoff seal and HMC liner Hgr. 9 -5/8" Casing Shoe V 1 4865' 1 , WFD PCP Stator XXXL 327 -6000 1 4779' 1 3 -1/2" Tag Sub, ID = 1.64" 1 4808' I 7" Production Liner Specifications; 7 ", 26 #, L -80, BTC Solid Liner 3 -1/2" TBG Tail With VYreline Entry Guide' 5352' I ID = 6.276 ", Drift ID = 6.151" Burst = 7240 psi, Collapse = 5410 psi 4761' - 5072' & 5233' - 5681' & 6247' - 6290' MD 7" 26#, L -80, BTC Slotted Liner 727' 0.28" Slots at 188 SPF 5072' - 5233' MD & 5681' - 6247' MD i ✓ PBTD 1 6287` I A L Well Inclination at TD = 91° Float Collar at 6287' MD 7" Liner Shoe at 6290' MD, 3796' TVD Ugnu Horizontal 8 -1/2" Hole DATE REV. BY COMMENTS MILNE POINT UNIT 1/9/09 REH Drill and set kill string - Doyon 14 WELL #: MPS - 39 6/27/2011 DAJ Drill and complete - Nabors 7ES API NO: 50- 029 - 23405 -00 -00 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ¢ „ SFr FEB 2, 4 201Z Mr. Tom Maunder aPZ— ( 3 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue nn 1D - Anchorage, Alaska 99501 Y r Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad 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, (7 ) Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPS -Pad 10/11/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft MI MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7292011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 102 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS-22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7282011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 102 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7282011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7282011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS -32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7282011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS-41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/112011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 _ 500299990799 _ 0.6 NA 0.6 NA 3.4 7/30/2011 • • siraiRE iciaAmA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'HSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Aras Worthington Interventions Engineer (6 Exploration (Alaska), P � ) � C�i BP Ex P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Unit, Ugnu Undefined, MPS -39 Sundry Number: 311 -316 Dear Mr. Worthington: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ) 0/ ff Daniel T. Seamount, Jr. fi Chair DATED this 2 f day of October, 2011. Encl. \\ STATE OF ALASKA t o't C IV ALASKA N AND GAS CONSERVATION COMMISS �� OCT 2011 /Q -/4,-// . APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: AnChot'a`igo ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing - ® Other Corod / PCP Completion 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - Development ❑ Exploratory 208 -183 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50- 029 - 23405 -00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS -39 - Spacing Exception Required? ❑ Yes IS No 9. Property Designation: 10. Field / Pool(s): ADL380109 & 380110 Milne Point Unit / Ugnu Undefined 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4881' - 3729' - 4791' - 3702' - None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 4833' 9-5/8" 4870' 3725' 6870 4760 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None N/A 4 - 1/2 ", 12.6# L - 80 2463' Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch 0 Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 10, 2011 - _ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name Aras orthington Title Interventions Engineer / Prepared By Name /Number. Signature �� Phone 564 - 4102 Date /b�/3/ � ;j T Hubble, 564 -4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3 � ( 2 1 I t �. Sundry Number v 10 ❑ Plug Integrity (R3OP Test ❑ Mechanical Integrity Test ❑ Location Clearance 2 40 P 1;s 1 Other: y A li! r,...- , 1Al J( ?' 4 A.4rer( 4. rot' , - aet. Z' A zs: z Subsequent Form Required: /O -yo L./ // APPROVED BY Jo �� Approved By: COMMISSIONER THE COMMISSION Date / l Form 19E14 v: O Ell l - f / D • /`i 1( ORIGINAL } . . fn D plicate ��i �74 • • b 4. • Heavy Oil Team Today Future Forward MPS -39 Corod /PCP Completion Scope of Work: Run PCP rotor and corod MASP: 1400 psi (1777 psi © 3756' TVD, less 0.1 psi gas gradient) Well Type: Ugnu Heavy Oil Producer Estimated Start Date: November 10th, 2011 Production Engineer: Jim Young Intervention Engineer: Aras Worthington Pre -iob prep work 1. Complete Drill and Complete steps with rotary rig (per PTD # 208 -183) Corod scope of Work 1. MIRU Weatherford Mast Unit and Mobile Gripper Unit (Corod rig). 2. NU Corod BOPE including 1 1/8" Rod rams and annular preventer. • 3. Test BOPE to 2000 psi. 4. Run PCP Rotor with 1 1/8" Corod, Drive Rods for space -out to surface, and 1 '/2' Polish -Rod. - 5. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. - 6. ND BOP stack and gate valve. 7. Install electric rotating drive head. Pressure test Drive Head seals to 1000 psi. 8. RD Weatherford Corod Rig. • • • MPS-39 Proposed Completion lAMhsit4 /MC OM 0 1t x 4 111 6M iladipao W.Y NOM A.ad Na rod raffle M PU S-39 Proposed "a Y.f1 Slam • pt. ZO' Tu►in h•it 11 "x41/!•. cr►py Ct. Ilea • 911' rhtc bp bonito Foiled 1 111 111111 1 47 of 1. tit x 1.1ir x r Polshs• Nod e t. w •02kN,s ke ►My. J A �� . 1 � Et) w • TOW Poet Cebu Lp� N. Tows tan%DODD* )%" •NOTE: TAMPON T Coliai it al 11• Y►oloatisa NI tosberesbdbdto+slab Swoop al AIM, 12• *Sea mains to** hale wi u a boM NOTE: kokliss sire Ibsta1M • Muslin, motor w PDC Mt nblltW Mat bemewed Mete 410DrCooed dabble sr reorio, imam easing Able I I II I 3+r'f4 sap Inv Kim g *941.40:, OTC ' �� 01437" TIC wr Cos 44110. t,lat'. j Cap G• tail' Novo. OW psi 1 Colsps.a4k poi 4'J" QS ppl. LAO. I diN3 $C bp — 4.3' 1916134.71 Maadoel ( 0 1 (DWI) 3.013r • Camsiy • 0102 Op0 (DAM 10 ppd. EM' • Cape* • . WO , ce Q 4.3' WV 0 Du rid MO poi shut ' 4100' ___ -4 9.QiWG 4rxA• W ►D Pi p 2tisaW ZP Nip* Nip* 4iZl? I mo ! �Q Uost 7s► Mu. fi3r' Casio, Otto 40 Dub butt X010 pistiea 4707 r 9 Leo. o. iTC•MCaskop � a Cs,. ID • aver OM ID +0,10 T !vista 7240 poi Cepapis ■6410 pal 1 1 I ' ! 411" EZI II WM PCP pwso JcC(1.32•0000 4991' 1 * 3WrW110 s/iNNbd jell above 3132' i 1 7• alakapp uy i i 700 0.03r'slob • 019 RP ■ I 7 Law Poo 0 11301r MD 1 I WO InNaalke S " - 4 * ' Ups 34/T1406 •••2••••.• OPMI PM WV CCINNIP11$ five ii DM MPil9 PrspssN• DRIP II WILL 1 S. Wirt_ At MPS.* *pi No: OOD1>•2l4050 )00 / 8P E XPLORA11ON (AK) 0 • n l ti � COROD Safety 2'2" t 3-1/2 Otis 5000 1 4 ft Lubricator 3 ft 3 -1/2 Otis 5000 2ft �:..,. 1ft I . E __1 ' 3 -1/2 Otis 5000 LU GKS Upper Annular Assy #7473A 2 -9/16 5000 R27 Bore 2.56" Model GKS 4130 serial# 48518 -3 -ACD -2 [UI GKS Lower Annular Assy # 7473B 6i9n 2 -9/16 5000 R27 Bore 2.56" Model GKS 4130 serial #49618 -3 -ACD -1 MEI '.1 III. Rod Ram Assy 3 -1/8" 10K Model MIMI _ serial# ■ X -Over _ 3 1/8" 10K X 41/16" 5k II ' _(( -7 4 -11 (?)�z)_"1 Flanged Pump -In Sub /Choke /Kill Line Inlet; 24" OAL T 41/16" 5K X 41/16" 5k _ ■ Gate Valves (2) To Choke I 41/16" 5K X 41/16" 5k / Check Valve RA sm A- ..rriP liii."-- _ "► � 1 1.` ►�1►�1 ,� _____÷ � � Kill Line (to pump) 6 1-( I d -1 /16" 50003i ' ►�1 -4- Blow -Down Tee x11 "# .... ,..._ woo Radigan Spool /1502 Integral 11 "5000# , Tbg spool �; _ . � IA Valve /1502 Integral ex. E ST.i.Ti..T.w. 11 " 5000# is • • BPXA Sucker Rod /Continuous Rod Well Control Equipment and Procedures 9/9/2009 (a) This document applies to through - tubing operations that are performed with sucker rod or continuous sucker rod (Corod). (b) A full lubricator system or open hole deployment type system will be used. (c) The rated working pressure of the blowout prevention equipment (BOPE) and other well control equipment will exceed the maximum potential surface pressure to which it may be subjected. (d) Well control equipment will include (1) one manual gate valve flanged to the wellhead or tree (2) at least three preventers, including (A) one annular type preventer. (B) one equipped with pipe rams that fit the size of the rod being used, except that pipe rams need not be sized to pump equipment, polished rods, or when deploying Corod, jointed sucker rods used for space out; (C) one equipped with blind rams (3) a hydraulic actuating system with (A) sufficient accumulator capacity to supply 150 percent of the volume necessary to close all BOPs, except blind rams, while maintaining a minimum pressure of 200 psi above the required precharge pressure when all BOPs, except blind rams, are closed, and all power sources are shut off; and (B) an accumulator pump system; (4) locking devices on the ram -type preventers; (5) one complete set of operable remote BOPE controls on or near the operator's station and, if these controls are not in close proximity to a rig platform floor, a second annular type preventer closing control located on the rig platform floor; and (6) a kill line capable of being attached with flanged or hubbed connections to the BOP body, spool, tree, wellhead, or other well control equipment. . • (7) for continuous sucker rod operation, a hydraulic actuated safety break designed to prevent free fall of the rod string in the event of a loss of mechanical control by the rod gripper unit. (e) The BOPE assembly will be tested as follows: (1) at least once a week, and after each repair, change, or use for well control or other equivalent purpose, or when routine use of the equipment may have compromised its effectiveness, BOP equipment will be function pressure- tested, using a non - compressible fluid, to the maximum potential surface pressure to which they may be subjected or the required working pressure specified by the AOGCC. (2) after each installation of BOPE or other well control equipment, the equipment will be pressure- tested, before wellbore entry, to the maximum potential wellhead pressure to which it may be subjected (3) non - sealing equipment will be function- tested weekly, after a repair or change, and after an action that disconnects the hydraulic system lines from the BOPE, except that if the rod string is continuously in the well, function- testing will be performed as soon as possible after the rod string is pulled out of the well and the BHA clears the BOP; (4) after each well installation of the BOPE, the BOPE hydraulic connections to the rams must be visually verified before wellbore entry; (5) BOPE test results will be recorded as part of the daily record, and will be provided to the commission in an approved format, within five days after completing the test; (6) at least 24 hours notice of each BOPE function pressure test will be provided so that a representative of the commission can witness the test; (7) the operator will report to the commission within 24 hours any instance of BOPE use to prevent the flow of fluids from a well. (f) A copy of any approved Application for Sundry Approvals (form 10 -403) will be posted in the operator's cab along with any geologic hazards and a copy of the operator's standing orders specifying well control procedures. If an additional or separate substructure is used, a second set of standing orders will be posted on the rig platform floor. II TIATIE o AllASEA PARNELL, GOVERNOR ALASKA OIL A1VID GAS / SEAN 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 Ken Allen FAX (907) 276 -7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519 -6612 St-ANWO MAY f 8 2012 Re: Milne Point Unit, Ugnu Undefined Oil Pool, MPS -39 BP Exploration Alaska Inc. Permit No: 208 -183 (revised) Surface Location: 3232' FSL, 489' FEL, SEC. 12, T12N, R10E, UM Bottomhole Location: 2614' FSL, 3509' FWL, SEC. 07, T12N R10E, UM Dear Mr. Allen: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill supersedes and replaces the permit to drill previously issued for this well on December 3, 2008. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. BP Exploration (Alaska), Inc. assumes the liability of any protest to the spacing exception that may occur. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, Daniel T. Seamount, Jr. Chair DATED this / 0 day of October, 2011 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RFGElipniii D GAS CONSERVATION COMMIION PERMIT TO DRILL 1 . 20 AAC 25.005 Revised: Change BHL la. Type of work: 1 b. W ss e nt OiI ❑ S ervice - Winj ❑ S ingle Zone lc. Specify if well is proposed for. ® Drill . ❑ Re '! sr ' ii •'� I`l :i' ent Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ■: Re -Entry . ❑ Exile ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: '^"'�'�' 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number. BP Exploration (Alaska) Inc. Bond No. 6194193 ' MPS-39 - 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 6308' - WD 3831' Milne Point Unit / Ugnu 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Undefined Surface: ADL380109 & 380110 • 3232 FSL, 489' FEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2623 FSL, 2515' FWL, SEC. 07, T12N, R10E, UM October 10, 2011 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2614 FSL, 3509' FWL, SEC. 07, T12N, R10E, UM 2560 2600' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 66.28 feet 15. Distance to Nearest Well Open Surface: x- 565522 A y- 5999896 ' Zone- ASP4 GL Elevation above MSL: 37.78' feet to Same Pool: 1500' 16. Deviated Wells: Kickoff Depth: 4896 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 88 degrees Downhole: 1782 Surface: 1405 18. Casing Program: Specifications Top - Setting D epth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 - 1/2" 7" 26# L - 80 BTC 2808' 3500' 2997' 6308' 3831' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD ( ft ) : Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 4881' 372 ' I None I 372 I 3702' None Casing Length Size Cement Volume MD TVD Conductor / Structural 110' 20" 60 sx Arcticset (Approx.) 110' 110' Surface 4833' 9-5/8" 626 sx Arcticset Lite. 111 sx DeeoCrete 4870' 3725' Intermediate Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): N/A , 20. Attachments: ❑ Property Plat -∎ BOP Sketch IN Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Dave Johnson, 564 -4171 I Printed Name Ken Allen Title Engineering Team Leader f Prepared By Name/Number , - Signature -- ``� C '- - - .. . Phone 564 -4366 Date ( r/ 3, 1)/ Terrie Hubble, 564 -4628 Commission Use Only Permit To Drill API Number: Appro`�al D t e: ,v See cover letter for Number: 208 -183 I 50- 029 - 23405 -00 -00 'Permit to IZ) (0 0 other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed meth e, gas hydrates, or gas contained shales: 12( Other * 3' p 5 L Bola Samples Req'd: ❑Yes I�N Mud Log Req'd: ❑D s L�No 1 z s O PS - A `-, , f H Measures: ❑ Yes I No Directional Survey Req'd: L 'Yes ❑ No .. 3cc,lldtr I ree- 4.ireD C / I O p e rra�''� . a a. APPROVED BY THE COMMISSION C ./ / 0 / / Date N , COMMISSIONER Form 10-401 - evised 07/2009 This permit is valid for 24 months from the date of a ' prove' (20 AAC 25.005(g)) Submit In Duplicate ; I 71 l /M4JRIGINAL trii • 0 by To: Alaska Oil & Gas Conservation Commission From: Dave Johnson, ODE Date: September 27, 2011 Re: MPS -39 Permit to Drill MPS -39 surface hole was drilled in early 2009 and 9 5/8" surface casing was run and cemented at 4868' MD. The well was suspended due to need for the drill rig on other ✓ ice season projects. Drilling will proceed directly out of the existing 9 -5/8" casing shoe in 8 1/2" hole size. The MPS -39 drilling program will involve drilling —1500 foot long build and horizontal production section in the Ugnu M80 Upper sand. The proposed bottom hole location has moved approximately 564', requiring a new permit request. An uncemented 7" slotted liner will be run to TD. MPS -39 will be completed with tubing and a Progressive Cavity Pump (PCP) stator that will be followed up by a post -rig rotor /co -rod install with a mast/gripper unit. This well is designed as part of the MPU Heavy Oil Production Pilot Phase 1 to test the heavy oil production potential of horizontal wells in the M80 upper sand using corod- driven PCPs as a lift mechanism. The drilling plan for the MPS -39 includes the following: - Reenter MPS -39 and cleanout to 9 -5/8" float collar: See Attached Sundry Notice. - Drill 8 -1/2" horizontal production hole to 6308' MD in the upper M80 sand - Run 7: slotted liner with ECP to isolate upper hole section & liner hanger. - Complete well with 4 -1/2" tubing with Progressive Cavity Pump and Corod. Please find attached the MPS -39 Revised Planned Well Summary, directional plan and proposed completion diagram. If you have any questions or require any additional information, please contact me at 564 -4171. Si:, ,.._,e_ '-„„,-,---......- 1 Dave Johnson Operations Drilling Engineer BP Exploration (Alaska), Inc. MPS -39 Page 1 9/27/2011 • • MPS -39 Planned Well Summary Well MPS -39 Type Producer Objective Ugnu M -80 API Number: 50- 029 - 23405 -00 -00 1 r Current Status Drilling Operations Suspended Estimated Start Date: 10/10/2011 Time to Complete: 12 Days Northing Easting _ Offsets TRS Surface 5,999,896.46 565,522.28 3232' FSL / 489' FEL 12N, 11E, Section 12 Ugnu M -80 5,999,315.0 568,530.0 2623' FSL / 2271' FEL 12N, 11E, Section 7 TD _ 5,999,315.0 569,525.0 2614' FSL / 1276' FEL 12N, 11E, Section 7 Planned KOP: 4,896' MD/3,663' TVDss Planned TD: 6,308' MD/3,765' TVDss Rig: Nabors 7ES BF /RT: 37.78'/28.5' RTE: 66.28' Directional — Sperry WP03 KOP: 1 4,896' MD Maximum Hole Angle: -88° in the 8 -1/2" production section Close Approach Wells: There are no close approach wells Survey Program: 74.8' to 1,178.9' MD = MPS -39 CB- Gyro -MS (MPS -39) 1,231.44' to 4,831.85' MD = MWD + SAG + IIFR + Multi Station (MPS -39) 4,831.85' to 6,308.12' MD = MWD + IIFR + Multi Station (MPS -39 WP03) Nearest Property Line: 2,600' Nearest Well within Pool: 1500' from MPS -37 MPS -39 Page 2 9/27/2011 • 0 Formation Tops & Pore Pressure Estimate Pore Pressure and Fracture Gradient Assessment Pore Pressure Sand Frac Gradients Shale Frac Gradients Most Likely Formation Depth Minimu Most Minimum Most Likely Most Likely Brumfield Overburde (tvdss) m Likely m Maximu (ppg) (PP9) (PP9) (PP9) (PP9) (PP9) (PP9) (PP9) PR = 0.30 PR = 0.33 Brumfield Brumfield 1 8.35 8.4 8.45 19.25 19.25 19.25 19.25 16.65 50 8.35 , 8.4 8.45 11.94 12.32 15.02 15.02 16.66. SV6 818 8.35 8.4 8.45 11.77 12.43 14.8 14.8 16.6 SV5 . 1406 8.35 8.4 T 8.45 11.93 12.6 15.09 15.09 16.92 SV4 1531 8.35 8.4 8.45 11.93 12.61 15.11 15.11 16.95 SV3 1780 8 8.4 8.45. 11.96 - 12.64 15.18 ; 15.16. 17.01 1805 8.35 8.4 8.45 11.97 12.64 1517 " 15.17 17.01 BPRF 1806 8.35 8.4 - 8.6 11.96 12.64 15.17 15.17 17.01 SV2 1955 8.35 8.4 8.6 11.98 12.66 15.2 15.2 17.05 Field base hydrate 8.35 12 12.68 15.24 15.24 17.09 stability field 2100 8.4 8.6 2101 $.35 8.4 9.3 ✓ : 12 12.68 15.24 15.24 17.09 SV1 2288 8.3 8.4 9.3 12.01 12.7 15.27 , 15.27 17.13 Theoretical Base Hydrate 8.35 12.02 12.7 15.27 15.27 17.13 1 Stability field 2300 8.4 9.3 ti 2301 8.35. 8.4 9.3 12.02 12.7 15.27 15.27 17.13, UG4 2663 8.35 8.4 9.3 12.03 12.72 15.31 15.31 17.18 UG4A 2716 8.35 8.4 9.3 12.03 12.72 15.32 15.32 11.18 UG3 2752 8.35 8.4 9.3 12.03 12.72 15.32 15.32 17.19 3589. 8.35 8.4 9.3 12.08 12.79 15.44 15.44 17.32 M876 3590 8.35 8.88 9.1 12.08 13.04 15.58 15.58 17.32 9-5/8" Cs9 3654 - - - - - - KOP 3663 - - - - - - - - M87F 3668 8.35 8.88 9.1 12.09 13.05 15.6 15.6 17.34 M8OT 3695 8.35 8.88 9.1 12.09 13.05 15.61 15.61 17.35 M8OU_mid 3726 8.35 8.88 9.1 12.09 13.06 15.61 15.61 17.36 M8OF 3756 8.35 8.88 9.1 12.1 13.06 15.62 15.62 17.36 TD 3765 - - - - - - - Casing /Tubing Program Hole Csg I WtIFt Grade Conn Burst Collapse Length Top Bottom Size Tbg OD (psi) (psi) MD / TVD MD / TVDrkb 8 -1/2" 7" 26# L -80 Solid BTC 7,240 5,410 2,808' 3,500'/2,997' 6,308'/3,831' & L -80 Slotted Tubing 4 -1/2" 12.6# L -80 H563 8,430 7,500 5,130' Surface 5,130'/3,784' J -55 Boronized SLHT 5,800 5,730 Note: 4 -1/2" 12.6# J -55 SLHT will be boronized & run in sections prone to high wear from corod. Mud Program Production Mud Properties: QuickDril- Solids Free Reservoir Drill -in Fluid 8 -1/2" hole section Depth Interval Density (ppg) PV YP LGS% API Fl pH MBT 4,863'- 6,308' 9.5 4 -10 18 -25 <5.0 <6 8.5 -10.0 5 MPS -39 Page 3 9/27/2011 • • Logging Program 8 -1/2" Production: Drilling: Dir!GR/Res /Neu /Den - all real time Open Hole: None Cased Hole: None Surface and Anti - Collision Issues Surface Shut -in Wells: MPS-41 is currently shut -in waiting on a rig workover. The well will remain shut -in while the rig is over MPS -39. Close Approach Shut -in Wells: There are no wells requiring shut -in due to close approach issues. Hydrogen Sulfide • MPS Pad is not designated as an H Pad. H detected from S -Pad wells: Well Name H2S Level Reading Date Comments Parent Well - Suspended MPS -39 NA NA Ugnu producer #1 Closest SHL Well H2S Level MPS -37 0 ppm 9/20/2008 Ugnu producer #2 Closest SHL Well H2S Level MPS -41 0 ppm 5/28/2011 Ugnu producer #1 Closest BHL Well H2S Level MPS -37 0 ppm 9/20/2008 Ugnu producer #2 Closest BHL Well H2S Level MPS-43 0 ppm 9/20/2010 Ugnu producer =� #3 Closest BHL Well H2S Level MPS -10 _ NA NA Schrader injector #4 Closest BHL Well H2S Level MPS -03 0 ppm 5/1/2005 Schrader producer Other Recent Test MPS -12 29 ppm 9/9/2011 Schrader producer / Max. Recorded H2S on Pad /Facility MPS -08 54 ppm 9/9/2011 Schrader producer Faults • One fault crossings is possible but uncertain for this well. Formation Where MD TVD Estimated Throw Uncertainty Encounter Fault Intersect Intersect Throw Direction Fault #1 - M8OT 5,500 3807 0 -15' DTE High Fault #1 is highly uncertain - this could be a fault or an imaging artifact from a shallow velocity anomaly. MPS -10 crossed this feature and did not encounter a fault. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul Class 1 waste to DS -04 and /or Pad 3 for disposal / Contact the GPB Environmental V Advisors (659 -5893) f /guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind /shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, annular preventer will be tested to 3500 psi. Rams will be tested to 3500 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. MPS -39 Page 4 9/27/2011 • Production Interval Maximum anticipated BHP 1782 psi @ TD at 3765' TVDss (9.1 ppg EMW) r Maximum surface pressure 1405 psi (.10 psi /ft gas gradient to surface) / 57 bbls with a 10.50 ppg frac gradient, assuming a maximum 9.6 ppg Kick tolerance pore pressure in the M -87 and 9.5 ppg MW. Anticipate a LOT between 11.0 and 12.0 ppg. (Note: There is only +/- 100' VD difference between TD & casing shoe) 9 -5/8" Casing Test 2500 psi surface pressure 7" Casing Test N/A - Slotted Liner Integrity Test - 8 -1/2" hole LOT after drilling 20' -50' from 10 -3/4" shoe. 7" Casing Rams The VBRs will be changed to 7" rams & tested for running the 7" casing Planned completion fluids 9.5 ppg brine w/ 6.8 ppg Diesel freeze protect MPS -39 General Operational Summary Procedure Pre -Rig Operations per Sundry 1. PPPOT -T and IC. Function all LDS. 2. CMIT - T X IA 3000 psi 3. Verify BPV is installed Drilling Rig Operations 4. MIRU. NU BOPE and test BOPS and annular to 3500 psi. 5. Circulate out diesel freeze protect. 6. Pull 4 -1/2" string from 2463' MD. 7. PU DP. RIH 8 -1/2" bit and drilling assembly. 8. Pressure test casing. Drill out 9 -5/8" float equipment. 9. Prep to drill production hole lateral. Sundry p Drilling Permit - heal S� f' D 10. Drill 20 -50' of new hole and perform a LOT or FIT to 10.5 ppg minimum. • ' 11. Drill 8 -1/2" horizontal production hole to 6308' MD (3663' TVDss) with polymer mud. • 12. Circulate and condition the hole prior to TOH to run a 7" drilling liner. 13. Change upper VBR's to 7" casing rams and test to 250 psi low / 35QQpsi high. 14. Run a 7 ", 26 #, L -80, BTC solid & slotted with minimum of 150' liner lap. • 15. Change out 7" rams to VBR's and test to 250 psi / 3,500 psi. • 16. Run 4 -1/2 tubing with 3 -1/2" tail and PCP completion • 17. RDMO 7ES. Post Rig Operations 18. MIRU Weatherford Mast Unit and Mobile Gripper Unit (Corod rig). < 19. NU Corod BOPE including 1 1/8" Rod rams and annular preventer. 20. Test BOPE to 2000 psi. Sin 21. Run PCP Rotor with 1 1/8" Corod, Drive Rods for space -out to surface, and 1 ' /2' Polish -Rod. ie • e & 22. Close Wellhead polished rod rams and pressure test between the rams to 2000 psi. 23. ND BOP stack and gate valve. r 24. Install electric rotating drive head. Pressure test Drive Head seals to 1500 psi. a 6,J 25. RD Weatherford Corod Rig. e ra 1 MPS -39 Page 5 9/27/2011 • • MPS -39 Proposed Completion haadFMC4en511"x41tW6M Radi mp a sa Radigan Weead wlduat U ` rod rams p 'ES. H® Elty = 19.211' Tubing head: 11 "x41/2'. Grig GL EI** a el 6' FMC bg hanger ported i111BIMII 40' of 1.112" x 1 -18' x1" Polished Rod ■ 2i" 621t it, H-ti: Walled ' 1 . I 1 nsulated . © 'Tam Port Collar 1 967' 1 Heat Trace ran to3000' } ' NOTE: TAM.PORT Collar is at 19' iwination. His recommended to rotate through this above 12• when running in the hole with a bent Ivinv Corod NOTE: Isslstitrt sptve installed in housing motor or PDC bit Nresi mast be raarsund btfer 0' drEip a ratnrn ametotr casing 4 485 sbktgR - 411 —a --- 3.9" SS capiary tube 6 CIS " .17#. L -Si. BTC Q 0.433" TEC Wire Cap. duet ID a SE 2 ". Csg. IG m 8 .181 " Burst I S7( psi C dap ase47s( psi 45" 12.8 pp1. L40. Hydra 583 SC bg 4.5" 1$M6 •LTS Mandrel 13300' (Drit 10 3.83r - Capaoitf a .0152 bpf) 3.5"9.3 ppl. LAO. 9T-Mod Tbg (Drift ID 2867" • Capacitya .0087 bpf) M+ ^ 4.5' INFO Drain Sub/ 3320 psi shear 14100' 1 45" INFO Pump Seating Nipple 1 442G1 ,, I Z r x 0441" C -2 2 .P 14750' I GG liner Top Pkr. 39r Casing Shoe 45"WFD Drain Sub/ 3961 psi shear 7 2DN. L90, OTC•MCasing ;V Csg. ID a 0.276" Cs() drat ID .8.11" Bursts 7240 psi Cotapse ■ 5410 psi I 1 45" Phonex gauge 1 410 1 • u ' i W FD PCP Stator XXX1.327.8000 1 1 3.5" W1JEO ursiotted joint above 15130' 1 r r I r 700 0.821" slots 4 SPF u r u / 1 i 7" Lifts Shoe 9,53011' MD u u Wet !introits* ! shoe- N dowses Ding Horiontal I . aasaaaaaaa WI AIN WI CCRIMINT'E UNIT , W/2011 ON MPS-30 Proposed- D III{d1E dos i W�l lb MP$-3$ API NO: 53I294OO4O . BP E XPLORATION (AK) MPS -39 Page 6 9/27/2011 K - v cn w co 13 5/8" 50001 WP HYDRIL, TYPE GK' 13 5/8" 50001 WP LATCHED TOP BY 4'-6i" 13 5/8" FLANGED BOTTOM 1 J f ANNULAR BOP 54 1/2" LENGTH PIPE RAM 13 -5/8" 50001 • 4'- J 0" E 'L, , FLANGED • HYDRIL 3" 50001 HCR VALVE C BLIND SHEAR DOUBLE 1/8 TOR GATE LENGTH Z AD 17'- r Pi' \ al • 3" 50001 HCR VALVE o 1 , 10 " 3" CHOKE LINE_ - - -. ^- Iri A 11i =i11 0=11t 41I1►� 4=P -- - -- - 2" KILL LINE V) -0 iimmin °' / 3" 5000 GAT VALVE CD 3" 50001 GArE VALVE 17:1 -. 2' - 9a" 11 ,4 PIPE RAM ■ . -r HYDRIL 13 -5 8" 5k PSI 0 HYDRAULIC RAU SINGLE GATE b " FLANGE4 CONNECTION 36 LENGTH r , 1'-10" p{+Z-di ?' eo 1 [ ,, � I+ K ,IW �' 1 1 l 1 s NABORS ALASKA RIG TES BOP STACK CONFIGURATION ALLizatima n,. a Vr0-0014 ! ' ''. 14 &ASO NG MS co No ivaRgatR WOW BOP SUCK L�64VT00RARO/ N mo , a w rmau a "n. - ah , N w _W.. °A IP �, w ` KM °°` ow UO as w 75-0.102 8 1 of i 0 K il U) _ w ' CD MATERIALS LIST ITEM DESCRWTKiN A 3 -1/8 544 HYDRAULIC CHOKE _ 8 3 -1/8 54 ADJUSTABLE C•,U.O.. .. 1 -13. 15 -16 3 - 1/8 54 MANUAL CATE VALVE (1)(114 14 2 -1/16 5M MANUAL GATE VALVE TO FLAW ��..71 MOE HANDLE VALVES ir ir _c ! t NORMALLY OPEN 11 / I Z • Illh Cr 4 1 Ph RED HANDLE VALVES O 1 Of NORMALLY CLOSED 1 ■ ) t 41(1) ril n -0 1- I ®+ 416.-'90" TO CASBUSTER 2— cD ® ~ 4 00 I O AD . "s \ • :, O .r ChOKE _INN p • r r 1 1 I — i • , a Moat YM 911r W1 N Rtro fJ __ - -.... - ........... NMI H 'Mt NIACIIS A.lSitt R+; 7C5 I ,/,1' �7 OM AWAV0.D S 1CRX CO ){ }, *we A 1110 i ralff WK 1 7 •M f.. - ._ _ ,.... C" t YilS y i9itb W: AMY. KL . N A IV ; 07R 'F . „ I ms µt AICO � ' ° tt a w.w' is 0 • i Wel!plan Addendum Contingency for well control when non - shearable equipment is across the BOPE shear rams This document will provide guidance for rig operations when a well control event arises and there is non - shearable equipment hanging from the derrick across the BOPE shear rams. Prior to picking up or running any equipment or tools in the hole, a PJSM and discussion is required to identify and note any equipment which will be run through the BOPE and is non- shearable. A risk assessment shall be performed for any equipment which is deemed non - shearable. The risk assessment must address the following: 1. Can variable bore rams seal against the equipment? 2. Can an annular preventer seal against the equipment? 3. Is a cross -over readily available to make -up into equipment? 4. Is a single joint or full stand of DP readily available to lower equipment below the BOPE stack? 5. How the equipment can be intentionally dropped down hole. 6. Are weights of equipment known so that hydraulic jacking force of wellbore pressure can be calculated? 7. Accurate and up to date shearing capabilities for the current shear rams installed are available. 8. Has each crew member been versed on individual roles and responsibilities? If there is a well control event happens with non - shearable equipment across the BOPE shear rams, the following procedure should be followed: 1. Based on the risk assessment above, gain control of the well by either: a. Closing the appropriate preventer (pipe ram, VBR, or annular) or b. Placing a sealable piece of equipment across the BOPE and closing the appropriate preventer or c. Dropping equipment and closing the Blind or Blind/Shear rams. 2. If well conditions permit, contact appropriate personnel. If not, proceed with well kill operations. This may include placing shearable equipment (i.e. drillpipe) across the shear rams by stripping in/out of the hole. MPS -39 Page 9 9/27/2011 • i MPS -39 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE L Well Control Production Hole - The Ugnu Formation pressure could range from 8.8 to 9.1 ppg. The reservoir drill -in fluid will be -9.5 ppg. II. Lost Circulation /Breathing Production Hole - While there is a potential fault crossing at -5,500' MD, lost circulation problems in this area have not been significant and the lost circulation risk for this well has been characterized as "low" III. Kick Tolerance /Integrity Testing A. With the planned mud weights, the kick tolerance for the production section is infinite. B. Integrity Testing Test Point Test Depth Test type EMW (lb/gal) 9-%" Shoe 20' -50' from the 9-%" window LOT 10.5 minimum IV. Hydrogen Sulfide MPS -Pad is not considered an H2S site. The highest recorded H2S on the pad was 58 ppm on well MPS -08. V. Faults • One fault crossings is possible but uncertain for this well. Formation Where MD TVD Estimated Throw Uncertainty Encounter Fault Intersect Intersect Throw Direction Fault #1 - M8OT 5500 3807 0 -15' DTE High Fault #1 is highly uncertain - this could be a fault or an imaging artifact from a shallow velocity anomaly. MPS -10 crossed this feature and did not encounter a fault. VI. Anti - Collision Issues There are no anti - collision issues as all off -set wells pass Major Risk analysis. CONSULT THE MPS -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. MPS -39 Page 10 9/27/2011 BP - Alaska Milne Point M Pt S Pad MPS -39 MPS -39 Plan: MPS -39 Wp 3.0 Standard Proposal Report 26 September, 2011 HALLIBURTON Sperry ©rlHIng Services CASING DETAILS WELL DETAILS. MPS -39 • TVD MD Name Size Ground Level: 37.78 3720.20 4864.81 9 5/8" 9 -5/8 +N / -S +E / -W Northing Easting Latittude Longitude Slot 3831.28 6308.12 7" 7 0.00 0.00 5999896.46 565522.250° 24' 36.598149° 27' 59.31 W - SECTION DETAILS Project: Milne Point Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target Site: M Pt S Pad 1 4831.85 72.78 89.32 3710.44 - 602.49 2532.65 0.00 0.00 2594.90 2 4875.80 72.78 89.32 3723.45 - 601.99 2574.63 0.00 0.00 2636.31 Well: MPS -39 3 4895.80 72.78 89.32 3729.38 - 601.76 2593.73 0.00 0.00 2655.15 Wellbore: MPS -39 4 4952.70 73.91 9138 3745.69 - 602.10 2648.24 4.00 60.62 2709.07 5 5312.57 88.27 90.50 3801.28 - 607.88 3002.79 4.00 -3.55 3060.36 MPS -39 T MPS -39 Wp 3.0 6 6308.12 88.27 90 50 3831.28 - 616.61 3997.85 0.00 0.00 4045.12 MPS -39 T. HALLIBURTON SURVEY PROGRAM ill Date: 2011 -09 - 07700:00:00 Validated: Yes Version: Sperry Drilling Depth From Depth To Survey /Plan Tool P Y 9 74.80 1178 90 MPS -39 CB- GYRO -MS (MPS -39) CB- GYRO -MS ____ 1231.44 4831.85 MPS -39 MWD +SAG +IIFR +MS (MPS4891p +IFR +MS 4831.85 6308.12 MPS -39 Wp 3.0 (MPS -39) MWD +IFR +MS 1 3400 5 3500 -- e Tie onto Last Survey at 4831.85 MD o y , End of Projection Start 20.00 hold at 4875.80 MD E.3600--- , ' Begin Directional DLS 4.00 4895.80 'MD N ' To ' 9 5/8" o -i , f 3700 - End Directional 5312.57 'MD d M87F ~3800- M80T MPS -39 Wp 3.0 7 M80U_mid M8OF TD at 6308.12' MD MPS -39 Ti MPS -39 T2 3900 1 i 1 4000-, H COMPANY DETAILS: BP - Alaska NORTH AMERICA 4100 -- ALASKA - - Calculation Method: Minimum Curvature - Error System: ISCWSA - Scan Method: Tray. Cylinder North 4200- Error Surface: Elliptical Conic Warning Method: Rules Based REFERENCE INFORMATION 4300-- Co-ordinate (N /E) Reference: Well MPS -39, True North Vertical (TVD) Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GL/MSL) - Measured Depth Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GL /MSL) - Calculation Method: Minimum Curvature 4400 -- -- - - - - - -, , 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 Vertical Section at 98.77° (200 ft/in) t SECTION DETAILS I COMPANY DETAILS: BP - Alaska - HALLI B U RTO N Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target NORTH AMERICA 1 4831.85 72.78 89.32 3710.44 -602.49 2532.65 0.00 0.00 2594.90 ALASKA 2 4875.80 72.78 89.32 3723.45 -601.99 2574.63 0.00 0.00 2636.31 , Sperry Drilling 3 4895.80 72.78 89.32 3729.38 -601.76 2593.73 0.00 0.00 2655.15 Calculation Method: Minimum Curvature 4 4952.70 73.91 91.38 3745.69 -602.10 2648.24 4.00 60.62 2709.07 Error System: ISCWSA ' 5 5312.57 88.27 90.50 3801.28 -607.88 3002.79 4.00 -3.55 3060.36 MPS -39 T1 Scan Method: Tray. Cylinder North - 6 6308.12 88.27 90.50 3831.28 -616.61 3997.85 0.00 0.00 4045.12 MPS -39 T2 Error Surface: Elliptical Conic Warning Method: Rules Based L 0- PS-39 Fault 1 CASING DETAILS TVD MD Name Size 3720.20 4864.81 9 5/8" 9 -5/8 _80 - 3831.28 6308.12 7" 7 -160- -240 - -320- Tie onto Last Survey at 4831.85 MD - -.--.- ------- --- .._..-------- -- -__.._ • - - End Projection Start 20.00 hold at 4875.80 MD' -400 - N. i t _ Begin Directional DLS 4.00 4895.80 'MD o ::: - , - Enirtl 531257'MD - - 0 - ! 91/8" MPS -39 Wp 3.0 7 I • • g -640 1 ! TD at 6308.12' MD o - ! 95 /e MPS -39 TI 0 v) _ . 7z °- Project: Milne Point - - Site: M Pt S Pad - MPS -39 Geo -poly MPS -39 -800 - - Wellbore: MPS -39 ' MPS -39 Wp 3.0 -880 - REFERENCE INFORMATION --- --- ------ -- -- -- -- -- ----- ------ --- - -- - -. Coordinate (N /E) Reference: Well MPS -39, True North Vertical (TVD) Reference: 7 -ES Planned c 66.28ft (28.5KB + 37.78 GUMSL) -960- Measured Depth Reference: 7 -ES Planned la 66.28ft (28.5KB + 37.78 GL/MSL) - Calculation Method: Minimum Curvature -1040- WELL DETAILS: MPS -39 - - - -- - Ground Level: 37.78 +N / -S +E / -W Northing Easting Latittude Longitude Slot - 0.00 0.00 5999896.46 565522.280° 24' 36.598 N19° 27' 59.31 W -1120- - - -- -- -_ - SURVEY PROGRAM - Date: 2011 -09- 07T00:00:00 Validated: Yes Version: -1200- Depth From Depth To Survey /Plan Tool 74.80 1178.90 MPS -39 CB- GYRO -MS (MPS -39) CB- GYRO -MS 1231.44 4831.85 MPS -39 MWD +SAG +IIFR +MS (MPS -39) MWD +IFR +MS - 1280- 4831.85 6308.12 MPS-39 Wp 3.0 (MPS -39) MWD +IFR +MS r 11 11 11 11 11 11 11 1 11 11 11 1: i[ 1 I: 11 1 i; ii 1 I 'I 2480 2560 2640 2720 2800 2880 2960 3040 31203200 3280 3360 3440 3520 3600 3680 3760 3840 3920 4000 4080 4160 4240 4320 4400 West( - )/East( +) (200 ft/in) Sperry Drilling HALLI B U RTO N Standard Proposal Report Database: .Sperry EDM .16 PRD Local Co-ordinate Reference: Well MPS -39 Company: BP - Alaska TVD Reference: 7 -ES Planned © 66.28ft (28.5KB + 37.78 GUMSL) Project: Milne Point MD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Site: M Pt S Pad North Reference: True Well: MPS -39 Survey Calculation Method: Minimum Curvature Wellbore: MPS -39 Design: MPS -39 Wp 3.0 Project Milne Point, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt S Pad Site Position: Northing: 5,999,978.00ft Latitude: 70° 24' 37.329 N From: Map Easting: 566,345.00ft Longitude: 149° 27' 35.17 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.51 ° Well MPS -39, 5002923405 Well Position +NI -S 0.00 ft Northing: 5,999,896.46 ft Latitude: 70° 24' 36.598 N +E/-W 0.00 ft Easting: 565,522.28 ft Longitude: 149° 27' 59.31 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 37.78 ft Wellbore MPS -39 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2011 10/15/2011 21.02 81.00 57,652 Design MPS -39 Wp 3.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 4,831.85 Vertical Section: Depth From (TVD) +N / -S +E/-W Direction (ft) (ft) (ft) r) 28.50 0.00 0.00 98.77 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/ -W Rate Rate Rate Tool Face (ft) 1 ° ) r) (ft) ft (ft) (ft) ( °1100ft) ( °M00ft) ( ° /100ft) (°) 4,831.85 72.78 89.32 3,710.44 3,644.16 - 602.49 2,532.65 0.00 0.00 0.00 0.00 4,875.80 72.78 89.32 3,723.45 3,657.17 - 601.99 2,574.63 0.00 0.00 0.00 0.00 4,895.80 72.78 89.32 3,729.38 3,663.10 - 601.76 2,593.73 0.00 0.00 0.00 0.00 4,952.70 73.91 91.38 3,745.69 3,679.41 - 602.10 2,648.24 4.00 1.98 3.63 60.62 5,312.57 88.27 90.50 3,801.28 3,735.00 - 607.88 3,002.79 4.00 3.99 -0.24 -3.55 6,308.12 88.27 90.50 3,831.28 3,765.00 - 616.61 3,997.85 0.00 0.00 0.00 0.00 9/26/2011 11:01:51AM Page 2 COMPASS 2003.16 Build 73 • • Sperry Drilling HALLI B U RTO N Standard Proposal Report Database: .Sperry EDM .16 PRD Local Co-ordinate Reference: Well MPS Company: BP - Alaska TVD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Project Milne Point MD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Site: M Pt S Pad North Reference: True Well: MPS - 39 Survey Calculation Method: Minimum Curvature Welibore: MPS - 39 Design: MPS - 39 Wp 3.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/S +E1 -W Northing Easting . DLS Vert Section (ft) (") r) (ft) ft (ft) (ft) (ft) (ft) 3,644.16 4,831.85 72.78 89.32 3,710.44 3,644.16 - 602.49 2,532.65 5,999,316.27 568,059.88 0.00 2,594.90 Tie onto Last Survey at 4831.85 MD 4,864.81 72.78 89.32 3,720.20 3,653.92 - 602.11 2,564.13 5,999,316.92 568,091.35 0.00 2,625.95 9 518" 4,875.80 72.78 89.32 3,723.45 3,657.17 - 601.99 2,574.63 5,999,317.14 568,101.85 0.00 2,636.31 End Projection Start 20.00 hold at 4875.80 MD 4,894.80 72.78 89.32 3,729.08 3,662.80 - 601.77 2,592.78 5,999,317.51 568,119.99 0.00 2,654.21 M87F 4,895.80 72.78 89.32 3,729.38 3,663.10 - 601.76 2,593.73 5,999,317.53 568,120.94 0.00 2,655.15 Begin Directional DLS 4.00 4895.80 'MO 4,900.00 72.86 89.47 3,730.62 3,664.34 - 601.72 2,597.74 5,999,317.61 568,124.96 4.00 2,659.11 4,952.70 73.91 91.38 3,745.69 3,679.41 - 602.10 2,648.24 5,999,317.67 568,175.45 4.00 2,709.07 4,992.07 75.48 91.28 3,756.08 3,689.80 - 602.98 2,686.20 5,999,317.12 568,213.41 4.00 2,746.73 M8OT 5,000.00 75.79 91.26 3,758.05 3,691.77 - 603.15 2,693.88 5,999,317.02 568,221.09 4.00 2,754.34 5,100.00 79.79 91.01 3,779.19 3,712.91 - 605.09 2,791.58 5,999,315.94 568,318.80 4.00 2,851.19 5,149.18 81.75 90.89 3,787.08 3,720.80 - 605.90 2,840.11 5,999,315.55 568,367.33 4.00 2,899.28 M8OU_mid 5,200.00 83.78 90.77 3,793.48 3,727.20 - 606.63 2,890.52 5,999,315.26 568,417.74 4.00 2,949.21 5,300.00 87.77 90.53 3,800.85 3,734.57 - 607.77 2,990.22 5,999,315.00 568,517.44 4.00 3,047.92 5,312.57 88.27 90.50 3,801.28 3,735.00 - 607.88 3,002.79 5,999,315.00 568,530.00 4.00 3,060.36 End Directional 5312.57 'MD - MPS - 39 T1 5,400.00 88.27 90.50 3,803.91 3,737.63 - 608.65 3,090.17 5,999,315.00 568,617.38 0.00 3,146.84 5,500.00 88.27 90.50 3,806.93 3,740.65 - 609.53 3,190.12 5,999,315.00 568,717.32 0.00 3,245.75 5,600.00 88.27 90.50 3,809.94 3,743.66 - 610.40 3,290.07 5,999,315.00 568,817.27 0.00 3,344.67 5,700.00 88.27 90.50 3,812.95 3,746.67 - 611.28 3,390.02 5,999,315.00 568,917.21 0.00 3,443.59 5,800.00 88.27 90.50 3,815.97 3,749.69 - 612.16 3,489.98 5,999,315.00 569,017.16 0.00 3,542.50 5,836.89 88.27 90.50 3,817.08 3,750.80 - 612.48 3,526.85 5,999,315.00 569,054.03 0.00 3,579.00 M8OF 5,900.00 88.27 90.50 3,818.98 3,752.70 - 613.03 3,589.93 5,999,315.00 569,117.10 0.00 3,641.42 6,000.00 88.27 90.50 3,822.00 3,755.72 - 613.91 3,689.88 5,999,315.00 569,217.05 0.00 3,740.34 6,100.00 88.27 90.50 3,825.01 3,758.73 - 614.79 3,789.83 5,999,315.00 569,316.99 0.00 3,839.25 6,200.00 88.27 90.50 3,828.02 3,761.74 - 615.66 3,889.78 5,999,315.00 569,416.94 0.00 3,938.17 6,300.00 88.27 90.50 3,831.04 3,764.76 - 616.54 3,989.73 5,999,315.00 569,516.88 0.00 4,037.09 6,308.12 , 88.27 90.50 3,831.28 , 3,765.00 - 616.61 3,997.85 5,999,315.00 569,525.00 0.00 4,045.12 TD at 6308.12' MD - 7" - MPS -39 T2 9/26/2011 11:01:51AM Page 3 COMPASS 2003.18 Build 73 Sperry Drilling HALLI B U RTO N Standard Proposal Report Database: .Sperry EDM .16 PRD Local Co-ordinate Reference: Well MPS -39 Company: BP - Alaska TVD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Project Milne Point MD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Site: M Pt S Pad North Reference: True Well: MPS -39 Survey Calculation Method: Minimum Curvature Wel!bore: MPS -39 Design: MPS -39 Wp 3.0 Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/ -S +El-W Northing Easting - Shape (°) (°) (ft) (ft) (ft) (ft) (ft) MPS -39 T2 0.00 0.00 3,831.28 - 616.61 3,997.85 5,999,315.00 569,525.00 - plan hits target center - Point MPS -39 Fault 1 0.00 0.00 3,761.28 31.76 2,483.33 5,999,950.00 568,005.00 - plan misses target center by 638.19ft at 4831.85ft MD (3710.44 TVD, - 602.49 N, 2532.65 E) - Polygon Point 1 3,761.28 31.76 2,483.33 5,999,950.00 568,005.00 Point2 3,761.28 - 609.46 3,182.80 5,999,315.00 568,710.00 Point3 3,761.28 - 1,175.50 3,292.85 5,998,750.00 568,825.00 Point4 3,761.28 - 609.46 3,182.80 5,999,315.00 568,710.00 MPS -39 Fault 2 0.00 0.00 3,761.28 506.13 4,272.73 6,000,440.00 569,790.00 - plan misses target center by 1158.02ft at 6308.12ft MD (3831.28 TVD, - 616.61 N, 3997.85 E) - Polygon Point 1 3,761.28 506.13 4,272.73 6,000,440.00 569,790.00 Point 2 3,761.28 - 633.59 4,222.73 5,999,300.00 569,750.00 Point 3 3,761.28 - 1,570.17 4,389.53 5,998,365.00 569,925.00 Point 4 3,761.28 - 633.59 4,222.73 5,999,300.00 569,750.00 MPS -39 Geo-poly 0.00 0.00 3,761.28 - 718.24 2,471.75 5,999,200.00 568,000.00 - plan misses target center by 140.33ft at 4831.85ft MD (3710.44 TVD, - 602.49 N, 2532.65 E) - Polygon Point 1 3,761.28 - 718.24 2,471.75 5,999,200.00 568,000.00 Point2 3,761.28 - 924.39 3,170.03 5,999,000.00 568,700.00 Point3 3,761.28 - 932.73 4,120.09 5,999,000.00 569,650.00 Point 4 3,761.28 - 331.81 4,025.35 5,999,600.00 569,550.00 Point5 3,761.28 - 324.36 3,175.30 5,999,600.00 568,700.00 Point 6 3,761.28 - 518.23 2,473.50 5,999,400.00 568,000.00 Point 7 3,761.28 - 718.24 2,471.75 5,999,200.00 568,000.00 MPS -39 T1 0.00 0.00 3,801.28 - 607.88 3,002.79 5,999,315.00 568,530.00 - plan hits target center - Point 6,308.12 3,831.28 7" 7 8 -1/2 4,864.81 3,720.20 9 5/8" 9 -5/8 12 -1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1 (') 5,836.89 3,817.08 M8OF 4,992.07 3,756.08 M8OT 5,149.18 3,787.08 M80U_mid 4,894.80 3,729.08 M87F 9/26/2011 11:01:51AM Page 4 COMPASS 2003.16 Build 73 • • Sperry Drilling ' HALLI8URTON Standard Proposal Report Database: .Sperry EDM .16 PRD Local Coordinate Reference: Well MPS -39 Company: BP - Alaska TVD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Project: Milne Point MD Reference: 7 -ES Planned @ 66.28ft (28.5KB + 37.78 GUMSL) Site: M Pt S Pad North Reference: True Well: MPS -39 Survey Calculation Method: Minimum Curvature Wel lbore: MPS -39 Design: MPS -39 Wp 3.0 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (ft) (ft) (ft) (ft) Comment 4,831.85 3,710.44 - 602.49 2,532.65 Tie onto Last Survey at 4831.85 MD 4,875.80 3,723.45 - 601.99 2,574.63 End Projection Start 20.00 hold at 4875.80 MD 4,895.80 3,729.38 - 601.76 2,593.73 Begin Directional DLS 4.00 4895.80 'MD 5,312.57 3,801.28 - 607.88 3,002.79 End Directional 5312.57 'MD 6,308.12 3,831.28 - 616.61 3,997.85 TD at 6308.12' MD 9/26/2011 11 :01:51AM Page 5 COMPASS 2003.16 Build 73 SURVEY PROGRAM CASING DETAILS WELL DETAILS: MPS -39 Date: 2011- 09- 15T00:00:00 Validated: Yes Version: TVD MD Name Size Ground Level: 37.78 3831.28 6308.12 7" 7.000 +N / -S +E / -W Northing Easting Latittude Longitude Slot Depth From Depth To Survey /Plan Tool 0.00 0.00 5999896.46 565522.280° 24' 36.59849° 27' 59.308 W 74.80 1178.90 MPS -39 CB- GYRO -MS (MPS -39) CB- GYRO -MS 1231.44 4831.85 MPS -39 MWD +SAG +IIFR +MS (MPS -39) MWD +IFR +MS 4831.85 6308.12 MPS -39A Wp 3.0 (MPS -39) MWD +IFR +MS ANTI - COLLISION SETTINGS COMPANY DETAILS: North America - ALASKA - BP Interpolation Method: MD, interval: 25.00 NORTH AMERICA Depth Range From 4831.85 To 6308.12 ALASKA REFERENCE INFORMATION Results Limited By: Centre Distance: 827.96 Calculation Method: Minimum Curvature Co-ordinate (WE) Reference' Wet MPS -39. True North Reference: Plan: MPS -39A Wp 3.0 (MPS- 39/MPS -39) Error System: ISCWSA Vertical (1V0) Reference: 7 .ES Panned a 66.288 (3735 GI.. 28.5 KB) Scan Method: Tray. Cylinder North Seaton (VS) Reference: SW- (0.00N, 0.00E) Measured both Reference: 7 {S Planned a 66.2811 (37.78 GU 28.5 KB) Error Surface: Elliptical Conic CakWa . Method Blawnum Curvature Warning Method: Rules Based 0 0 125 330 30 330 3 100 • Air 100 ii 300 /a 60 �G I M I' From Colour To MD �rli 50 ilk 90 k ill) , ,e. o, 4 ,A • 270 r u•, �I 1 �Ai li l 210 150 P`P*II 180 `p0i 50 • t'∎ SECTION DETAILS 10.4 !i ! � �� , Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 240 ,' 120 1 4831.85 72.78 89.32 3710.44 - 602.49 2532.65 0.00 0.00 2594.84 ' 2 4875.80 72.78 89.32 3723.45 - 601.99 2574.63 0.00 0.00 2636.26 ((, 3 4895.80 72.78 89.32 3729.38 - 601.76 2593.73 0.00 0.00 2655.10 4 4952.70 73.91 91.38 3745.69 - 602.10 2648.24 4.00 60.62 2709.03 5 5312.57 88.27 90.50 3801.28 - 607.88 3002.79 4.00 -3.55 3060.32 6 6308.12 88.27 90.50 3831.28 - 616.61 3997.85 0.00 0.00 4045.12 100 210 150 125 180 HALLIBURTON ; ylinder Azimuth (TFO +AZI) [ °j vs Centre to Centre Separation [50 ft/inj Sperry Drilling Services • • BPPASSPORT Anticollision Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPS -39 Project Milne Point TVD Reference: 7 -ES Planned @ 66.28ft (37.78 GL + 28.5 KB) Reference Site: M Pt S Pad MD Reference: 7 -ES Planned @ 66.28ft (37.78 GL + 28.5 KB) Site Error: 0.00ft North Reference: True Reference Well: MPS -39 Survey Calculation Method: Minimum Curvature Well Error. 0.00ft Output errors are at 1.00 sigma Reference Wellbore MPS -39 Database: EDM .16 - ANC Prod - WH24P Reference Design: MPS -39A Wp 3.0 Offset TVD Reference: Offset Datum Reference MPS -39A Wp 3.0 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 4,831.85 to 6,308.12ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center- center distance of 827.96ft Error Surface: Elliptical Conic Survey Tool Program Date 9/15/2011 From To (ft) (ft) Survey (Wellbore) Tool Name Description 74.80 1,178.90 MPS -39 CB- GYRO -MS (MPS -39) CB- GYRO -MS Camera based gyro multishot 1,231.44 4,831.85 MPS -39 MWD +SAG +IIFR +MS (MPS -39) MWD +IFR +MS MWD + IFR + Multi Station 4,831.85 6,308.12 MPS -39A Wp 3.0 (MPS -39) MWD +IFR +MS MWD + IFR + Multi Station Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) M Pt S Pad MPS -03 - MPS -03 - MPS -03 Out of range MPS -03 - MPS -03 - MPS -03 Wp03 Out of range MPS -03 - MPS -03L1 - MPS -03L1 Out of range MPS -03 - MPS -03L1 - PLAN MPS-03 L1 WP02 Out of range MPS -09 - MPS -09 - MPS -09 4,851.27 4,500.00 794.83 126.43 700.07 Pass - Major Risk MPS -09 - MPS -09 - MPS -09 Wp05 4,833.47 4,500.00 777.18 128.45 677.13 Pass - Major Risk MPS -10 - MPS -10 - MPS -10 4,965.11 4,575.00 579.11 126.65 452.70 Pass - Major Risk MPS -10 - MPS -10 - MPS -10 wp03 DQ 4,994.68 4,600.00 557.51 134.55 423.10 Pass - Major Risk MPS -10 - MPS -10A - MPS -10A 5,497.65 7,025.00 379.50 130.48 315.97 Pass - Major Risk MPS-10 - MPS -10A - MPS -10A wp08 5,502.93 6,975.00 385.46 130.16 324.26 Pass - Major Risk MPS- 31_DIMS - MPS -31 - MPS -31 Out of range MPS -37 - MPS -37A Plan - MPS-37 Wp 1.0 6,057.56 6,925.00 200.82 158.82 109.47 Pass - Major Risk MPS -39 - MPS -39 - MPS -39 4,844.80 4,850.00 0.00 0.76 -0.76 FAIL - NOERRORS MPS- 39_DIMS - MPS -39 - MPS -39 Out of range MPS-41 - MPS -41A - MPS -41A Out of range MPS-41 - MPS -41A - Plan MPS -41A Wp 14 Field Out of range MPS-41 - MPS- 41APB2 - MPS -41A PB2 WP15 Out of range MPS -41_DO NOT USE - MPS -41A - MPS -41A Out of range MPS -41_DO NOT USE - MPS -41A - Plan MPS-41 Out of range MPS -41_00 NOT USE - MPS- 41APB2 - MPS -41A Out of range Plan Anges - Plan Anges - Plan Anges Wp 2.0 6,019.67 7,400.00 211.20 164.52 114.38 Pass - Major Risk 9/15/2011 1 1:24:28AM Page 2 of 3 COMPASS 2003.16 Build 73 i 0 BPPASSPORT Anticollision Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPS -39 Project: Milne Point TVD Reference: 7 -ES Planned @ 66.28ft (37.78 GL + 28.5 KB) Reference Site: M Pt S Pad MD Reference: 7 -ES Planned @ 66.28ft (37.78 GL + 28.5 KB) Site Error: 0.00ft North Reference: True Reference Well: MPS -39 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore MPS -39 Database: EDM .16 - ANC Prod - WH24P Reference Design: MPS -39A Wp 3.0 Offset TVD Reference: Offset Datum Reference Depths are relative to 7 -ES Planned @ 66.286 (37.78 GL + Coordinates are relative to: MPS -39 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meridian is 150° 0' 0.000 W ° Grid Convergence at Surface is: 0.50° Ladder Plot f I - I I I I I I I I J J I J _1 I i I I I I i C 0 600- 0 1 1 . N c I I _1 _1 _1 i : 1 1 1 i 0 a) 400- 1 J a) ' c_) _1 _ LEGEND 0 S -03 V2g -8-1 MPS -24, PS- 24PB1, MPS -24P31 V11 L f -6- MPS -34, MPS -34L2, MPS -34L2 V9 c S- 33VVP - MPS -24, _S24P131,MPS- 24ptj1_mpQ1V1S - - -11:PS,35,MPS- 35,MPS -35V17 P 3-03L1 V10 -W; MPS -24, PS- 24PB2, MPS -24P02 V5 f --- MPS -35, MPS- 35PB1, IVPS -35 wp0 V LAN MPS-03 L1 V' D02 V2 $ i MPS -25, MPS-25, MPS -25 V3 -f- S-35, MPS- 35PB1, MPS- 35PB1 11 1P 3 -05L1 V2 • - -1- - - - - 1 - - - MPS -25, MPS -25, MPS -25 Wp05 V1 i _I $ 5, MPS - 35PB2, MPS -35PB2 11 P 3 -05L1(OA) wp0 2 V2 MPS -25, MPS -25L1, MPS -25L1 W10 $- MPS -37, MPS -37, MPS -37 v7 S-36 V11 -11-; MPS -25, MPS -25L1, MPS -25L1 WpO4 V1 1 -0- MPS -37, MPS -37, Plan COI-0-01 ■ 3 -06wp07V12 $ MPS- 26, N1PS- 26,MPS -26V6 j v' -3 , Y' -3 • ' an V'S -37 , 1 3- )8 V10 0 1500 ..e MPS - 263 -26, MPS -26 v4:654(4 6000 7 1§PQ -39, MPS -39, MFWA IVPS- O8wp08.5 V28 MPS -27, MPS -27Id Depth (1500 ft/in) MPS- 39_DIMS, MPS -39, MPS -39 V: MPS -08PB1 V9 -ar- MPS -27, MPS -27, MPS -27'f 04 V1 -A- MPS -41, MPS -41, MPS-41 V7 S -09 V6 MPS -27, MPS -27L1, MPS -27L1 V7 --2- MPS -41, MPS -41, Plan MPS -41 Wp ..0 S -)9\ 405 V1 - MPS-27, MPS-27L1,MPS-27L1 \AP-03 V1 -f MPS-41, MPS-41A, MPS-41AV5 3-10 V14 $ MPS-27, MPS-27PB1, MPS-27PB1 V2 = MPS- 41,MPS- 41A,Plan MPS -41A 3 -10 wp03 DO V19 --4- MPS -28, MPS -28, MPS-28 V5 MPS -41, MPS -41 APB1, MPS -41 AP::1 'S -10A V4 -aft- MPS -28, MPS -28, MPS- 28 wp03 V9 -e- MPS -41, MPS-41APB2, MPS-41 A P :2 D3 10Awp08V45 MPS-28, MPS-28PB1, MPS-28PB1 V6 MPS- 41, MPS- 41APB2,MPS- 41AP:•2 S-11 V5 MP S-28, MPS-28PB2, MPS-28PB2 V5 ..._ MPS-41_00 NOT USE, MPS -41, S -11 wp03 V1 MPS -29, MPS -29, MPS -29 V8 MPS-41 _DO NOT USE, MPS -41, PI :n S-13 V7 MPS -29, MPS -29, MPS -29 Vp08 V9 E- MPS -41_DO NOT USE, MPS-41A, F S -13 \A$07 V1 MPS -29, MPS -29L1, MPS -29L1 V6 MPS -41_DO NOT USE, MPS-41A, "Ia S-1TVb -'-4- MI b -29, M'b- LJL1, MI'S -LUL1 VGA L.0 V/ MNS -41_W NU 1 USt, MF'S-41/ .1 9/15/2011 11:24:28AM Page 3 of 3 COMPASS 2003.16 Build 73 1 • TRANSMITTAL LETTE CHECKLIST WELL NAME Ae_ /n__ - 6 / <7 ( (/ 7 (e),,,,,,4 PTD# 2 - 6 7 ' 7 6 7 3 /Development Service Exploratory Stratigraphic Test Non - Conventional Well / . - .6,= /( -- , . z - FIELD: /�/ POOL: A /-(`2 A r Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is appr• t to full compliance with 20 AAC EXCEPTI 25.055. Approv. to .roduce / n'ect is contingent upon issuance of a ns ation :. approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKUST Field & Pool MILNE POINT, UGNU UNDEFINE OIL - 525160 Well Name: MILNE PT UNIT UGNU S -39 Program DEV Well bore seg ❑ PTD#: 2081830 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / 1 -OIL GeoArea 890 _ _ Unit 11328 On /Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),(j.2.A -D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 380109; top prod interval and TD in ADL 380110 3 Unique well name and number Yes 4 Well located in a definedpool No Ugnu undefined oil pool - statewide spacing requirements apply 1 5 Well located proper distance from drilling unit boundary Yes 1 6 Well located proper distance from other wells Yes —1650' from Ugnu perforations open in MPU S -37 7 Sufficient acreage available in drilling unit No SPACING EXCEPTION REQUIRED: this well lies just within the same governmental quarter 8 If deviated, is wellbore plat included Yes section as wells S -37, S-41A S-43. Dave Johnson, BP, notified 10/3/2011. BP will send application. SFD 10/6 9 Operator only affected party No 1 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order No 12 Permit can be issued without administrative approval Yes SFD 10/6/2011 13 Can permit be approved before 15 -day wait Yes er 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For : NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 116 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA All aquifers exempted, 40CFR 147.102(b)(3). X20 CMT vol adequate to circulate on conductor & surf csg Yes (Surface casing is cemented fully before well was suspended) j 21 CMT vol adequate to tie -in long string to surf csg No Liner will be slotted 7" horizontal. 22 CMT will cover all known productive horizons No (Well plan changed .. Moving BHL 564' and making it horizontal laterl.) 23 Casing designs adequate for C, T, B & permafrost Yes '24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 If a re- drill, has a 10-403 for abandonment been approved NA 1 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated. 127 If diverter required, does it meet regulations NA Well has wellhead installed from previous drilling. BOP will be installed. Appr Date 28 Drilling fluid program schematic & eq_uip list adequate Yes Maximum expected formation pressure 9.1 EMW. MW planned 9.4 - 9.5 ppg in zone. GLS 10/3/2011 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 1405 psi. 3500 psi BOP testplanned. 31 Choke manifold complies w /API RP -53 (May 84) Yes 1 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S is not reported in Ugnu production. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes No H2S anticipated Geology 36 Data presented on potential overpressure zones Yes Expected reservoirpressure ranges from 8.35 to 9.3 ppg; will be drilled with 9.5 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA N /A: Well is currently suspended at 4881' MD/3728' TVD. SFD 10/3/2011 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA I Geologic Engineering P- _ ; SPACING EXCEPTION REQUIRED: The Ugnu Oil Pool is undefined; statewide spacing requirements apply. The planned well path Date: Date. D Commissioner: Commissioner: r thru the Ugnu productive interval will lie just inside the same governmental quarter section as Ugnu wells S -37, S-41A & S-43. MPU 1 — /. /0- 7 2.—y/ 39 will be the 4th oil well in the SW /4 of Sec. 7, so a spacing exception will be required. Notified Brian McLellan of BP by phone on DTS `' /` S I 12/2/2008. BP never applied for this exception. Notified David Johnson of BP by phone 10/3/2011. BP will send application. SFD 111 T4s-r3. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 10 15:59:58 2012 RECEIVED Reel Header Service name LISTPE JAN 2 3 2012 Date 12/01/10 AOGCC STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/01/10 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF scat& Comment Record A �� '1 a TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: MPS-39 API NUMBER: 500292340500 OPERATOR: BP Exploration (Alaska) , Inc LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 10-JAN-12 JOB DATA mwd RUN 1 mwd RUN 2 MAD RUN 0 JOB NUMBER: -XX-0008533070 -XX-0008533070 -XX-0008533070 LOGGING ENGINEER: ALEX MUNRO BRIAN STEPHE BRIAN STEPHE OPERATOR WITNESS: D. BURLEY DUNCAN FERGU DUNCAN FERGU SURFACE LOCATION SECTION: 12 TOWNSHIP: 12N RANGE: 11E FNL: FSL: 3232 FEL: 489 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 65.43 GROUND LEVEL: 37.78 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 112.0 2ND STRING 8.500 9.625 4865.0 3RD STRING PRODUCTION STRING i REMARKS: NOTE: THIS DATA SET IS THE MERGED DATA SET FOR MPS-39, THE SURFACE SECTION WAS DRILLED AND SUSPENDED IN 2009. A REQUEST TO FINALIZE AND DISTRIBUTE THE MWD DATA FOR THE SURFACE SECTION WAS PROVIDED BY D. DORTCH (SAIC/BP) ON 28 AUGUST 2009, PER ERIK HULM (BP) . THE PRODUCTION SECTION WAS DRILLED IN NOVEMBER 2011. 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . ONLY INVERT/ REVERT INTERVALS GREATER THAN 30'TVD ARE PRESENTED. 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, DRILLSTRING DYNAMICS SENSOR (DDS) , AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) . 4 . MWD RUN 2 COMPRISED DIRECTIONAL, DGR, EWR-P4, DDSR, AZIMUTHAL LITHO-DENSITY (ALD) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND ACOUSTIC CALIPER (ACAL) . 5. DATA FROM THE SURFACE SECTION (MWD RUN 1) WERE BULK-SHIFTED -6' TO ADJUST FOR THE DIFFERENT DFE'S. MERGED DIGITAL AND LOG DATA FOR THE PRODUCTION SECTION (MWD RUN 2) WERE THEN SHIFTED TO THE RUN 1 DATA. SHIFTING INSTRUCTIONS WERE RECEIVED VIA AN E-MAIL (01 DECEMBER 2011) FROM D. DORTCH (WIPRO/BP) TO BUSTER BRYANT (SD) , QUOTING AUTHORIZATION FROM WALTER TIFENTAL (BP) . THIS SHIFTED MWD LOG IS THE PDCL FOR MPS-39. ANNOTATIONS AND LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTHS. 6. MWD RUNS 1,2 REPRESENT WELL MPS-39 WITH API#: 50-029-23405-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6306'MD/3796'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION RSPD RUNNING SPEED DURING MAD PASS DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY ADCL/ALDCLC ALD LCRB DENSITY CORRECTION • 410 APEL/ALPELC ALD LCRB Pe FACTOR ALRP/ALRPM ALD RPM (NON-SLIDE INDICATOR) CDBQ/ALCDBQ ALD COMP DENSITY BOTTOM QUAD CDTQ/ALCDTQ ALD COMP DENSITY TOP QUAD CDRQ/ALCDRQ ALD COMP DENSITY RIGHT QUAD CDLQ/ALCDLQ ALD COMP DENSITY LEFT QUAD DCBQ/ALDCBQ ALD COMP DENSITY BOTTOM QUAD DCTQ/ALDCTQ ALD COMP DENSITY TOP QUAD DCRQ/ALDDRQ, ALD COMP DENSITY RIGHT QUAD DCLQ/ALDCLQ ALD COMP DENSITY LEFT QUAD AHSI/ALHSI ALD HOLE SIZE INDICATOR ACHD ACOUSTIC CALIPER M SUFFIX ON MNEMONICS DENOTES MAD PASS DATA PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: DYNAMIC, FROM ACHD (8.5" BIT) MUD WEIGHT: 9.5 - 9. 6 PPG WHOLE MUD CHLORIDES: 105, 000-110,000 PPM FORMATION WATER SALINITY 21,000 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 154.5 6263.0 RPM 154.5 6263.0 RPS 154.5 6263.0 RPX 154.5 6263.0 GR 163.0 6270.5 ROP 213.5 6309.0 FET 213.5 6263.0 CALA 4853.5 6219.0 DHO4 4855.0 6228.5 NPHI 4855.0 6216.0 PEF 4855.0 6229.5 NCNT 4855.0 6216.0 RHOB 4855.0 6229.5 FONT 4855.0 6216.0 DHO2 4855.0 6228.5 RHO4 4855.0 6228.5 DRHO 4855.0 6229.5 RHO2 4855.0 6228.5 • DHO1 4857.0 6228.5 RHO1 4857.0 6228.5 RHOS 4857.5 6228.5 DHO3 4857.5 6228.5 CALN 4860.0 6229.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 4601.0 4603.0 4614.5 4616.5 4616.0 4618.5 4620.5 4624.5 4624.0 4626.5 4632.5 4634.0 4641.5 4642.0 4653.0 4652.5 4656.0 4655.0 4666.0 4664.5 4672.0 4671.0 4684 .5 4682.5 4694 .5 4694 .0 4698.0 4696.5 4703.5 4702.5 4706.0 4704.5 4722.5 4723.0 4728.0 4729.0 4742.0 4741.0 4750.0 4751.0 4752.0 4753.5 4757.0 4757.5 4770.0 4771.0 4779.5 4780.0 4783.5 4784.0 4801.0 4799.5 4804.0 4802.0 4806.5 4804.5 4811.5 4808.5 4816.5 4815.0 4822.5 4819.5 6309.0 6306.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 154.5 4875.0 MWD 2 4875.0 6309.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 • • • CALA MWD IN 4 1 68 4 2 RHO1 MWD G/CC 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 RHO3 MWD G/CC 4 1 68 16 5 RHO4 MWD G/CC 4 1 68 20 6 RHO2 MWD G/CC 4 1 68 24 7 DH01 MWD G/CC 4 1 68 28 8 DRHO MWD G/CC 4 1 68 32 9 DH03 MWD G/CC 4 1 68 36 10 DH04 MWD G/CC 4 1 68 40 11 DH02 MWD G/CC 4 1 68 44 12 CALN MWD IN 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 GR MWD API 4 1 68 56 15 FET MWD HR 4 1 68 60 16 RPX MWD OHMM 4 1 68 64 17 RPS MWD OHMM 4 1 68 68 18 RPM MWD OHMM 4 1 68 72 19 RPD MWD OHMM 4 1 68 76 20 ROP MWD FPH 4 1 68 80 21 FONT MWD CP30 4 1 68 84 22 NCNT MWD CP30 4 1 68 88 23 NPHI MWD PU 4 1 68 92 24 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 154.5 6309 3231.75 12310 154.5 6309 CALA MWD IN 8.23 14.91 9.81989 2732 4853.5 6219 RHO1 MWD G/CC 0.577 2.49 2.09166 2458 4857 6228.5 RHOB MWD G/CC 0.25 2. 694 2.09718 2750 4855 6229.5 RHO3 MWD G/CC 0.154 2.463 1.985 1998 4857.5 6228.5 RHO4 MWD G/CC 0.142 2.433 2.05063 1892 4855 6228.5 RHO2 MWD G/CC 0.221 2.654 1.79796 1912 4855 6228.5 DH01 MWD G/CC -1. 939 0.214 0.0136139 2458 4857 6228.5 DRHO MWD G/CC -3.012 0.292 0.017912 2750 4855 6229.5 1 DH03 MWD G/CC -2.717 0.258 0.0707022 1998 4857.5 6228.5 DH04 MWD G/CC -2.277 0.23 0.0352912 1892 4855 6228.5 DH02 MWD G/CC -2.279 0.312 0.097829 1912 4855 6228.5 CALN MWD IN 8.25 18.1 9.81209 1850 4860 6229.5 PEF MWD B/E 0.75 13.8 2.0464 2750 4855 6229.5 GR MWD API 21.61 130. 64 68. 9817 12216 163 6270.5 FET MWD HR 0.11 4.8 0.773261 12024 213.5 6263 RPX MWD OHMM 0.06 2000 26.1635 12142 154.5 6263 RPS MWD OHMM 0.07 2000 49.4851 11952 154.5 6263 RPM MWD OHMM 0.1 2000 87.9161 12142 154.5 6263 RPD MWD OHMM 0.05 2000 117.382 12142 154.5 6263 ROP MWD FPH 1.54 916.42 183.763 12192 213.5 6309 FONT MWD CP30 295.05 818.2 424.486 2723 4855 6216 NCNT MWD CP30 62228.1 92874.4 74679.4 2723 4855 6216 NPHI MWD PU 19.44 58.54 37.1198 2723 4855 6216 First Reading For Entire File 154.5 Last Reading For Entire File 6309 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 • • • Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4853.0 6264.0 RHO3 4854.5 6222.0 RPM 4854.5 6256.0 RPD 4854.5 6256.0 RPX 4854.5 6256.0 RPS 4854.5 6256.0 FET 4854.5 6256.0 RHO4 4855.0 6222.0 PEF 4855.0 6223.5 RHO2 4855.0 6222.0 DHO1 4855.0 6222.0 DRHO 4855.0 6223.5 DHO4 4855.0 6222.0 NCNT 4855.0 6211.0 CALN 4855.0 6223.5 DHO2 4855.0 6222.0 NPHI 4855.0 6211.0 RHOB 4855.0 6223.5 FCNT 4855.0 6211.0 RHO1 4855.0 6222.0 DHO3 4855.0 6222.0 CALA 4855.5 6213.5 RAT 4893.0 6303.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 0 1 4825.0 6309.0 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .lIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 • III • CALA MAD IN 4 1 68 4 2 RHO1 MAD G/CC 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 RHO3 MAD G/CC 4 1 68 16 5 RHO4 MAD G/CC 4 1 68 20 6 RHO2 MAD G/CC 4 1 68 24 7 DHO1 MAD G/CC 4 1 68 28 8 DRHO MAD G/CC 4 1 68 32 9 DHO3 MAD G/CC 4 1 68 36 10 DHO4 MAD G/CC 4 1 68 40 11 DHO2 MAD G/CC 4 1 68 44 12 CALN MAD IN 4 1 68 48 13 PEF MAD B/E 4 1 68 52 14 GR MAD API 4 1 68 56 15 FET MAD HR 4 1 68 60 16 RPX MAD OHMM 4 1 68 64 17 RPS MAD OHMM 4 1 68 68 18 RPM MAD OHMM 4 1 68 72 19 RPD MAD OHMM 4 1 68 76 20 RAT MAD FPH 4 1 68 80 21 FCNT MAD CP30 4 1 68 84 22 NCNT MAD CP30 4 1 68 88 23 NPHI MAD PU 4 1 68 92 24 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4853 6303.5 5578.25 2902 4853 6303.5 CALA MAD IN 8.31 14 .85 10.2657 2717 4855.5 6213.5 RHO1 MAD G/CC 0.851 2.573 2.10527 2735 4855 6222 RHOB MAD G/CC 0.08 2.59 2.10199 2738 4855 6223.5 RHO3 MAD G/CC 0.494 2.419 1.9488 2736 4854.5 6222 RHO4 MAD G/CC 0.506 2.396 2.05143 2735 4855 6222 RHO2 MAD G/CC 0.128 2.366 1.67611 2735 4855 6222 DHO1 MAD G/CC -1.833 0.181 0.00408409 2735 4855 6222 DRHO MAD G/CC -3.254 0.272 0.00201972 2738 4855 6223.5 DHO3 MAD G/CC -1.897 0.246 0.0660782 2735 4855 6222 DHO4 MAD G/CC -1.916 0.192 0.0194234 2735 4855 6222 DHO2 MAD G/CC -2.23 0.367 0.0963579 2735 4855 6222 CALN MAD IN 8.25 16.57 10.0675 2738 4855 6223.5 PEF MAD B/E 0.74 14.43 2.02701 2738 4855 6223.5 GR MAD API 25.58 120.57 60. 975 2823 4853 6264 FET MAD HR 0.93 30.3 14. 6013 2804 4854.5 6256 RPX MAD OHMM 0.06 2000 9.12894 2804 4854.5 6256 RPS MAD OHMM 0.07 2000 33.862 2804 4854 .5 6256 RPM MAD OHMM 0.08 2000 94.5523 2804 4854 .5 6256 RPD MAD OHMM 1.78 2000 298.14 2804 4854.5 6256 RAT MAD FPH 0.77 485.88 236.577 2822 4893 6303.5 FCNT MAD CP30 304.03 955.27 443.752 2713 4855 6211 NCNT MAD CP30 64064.5 96424.6 76887.4 2713 4855 6211 NPHI MAD PU 17.19 61.47 36.7452 2713 4855 6211 First Reading For Entire File 4853 Last Reading For Entire File 6303.5 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 • 411 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH R09P 154.5 4816.5 R39P 154.5 4816.5 R27P 154.5 4816.5 R15P 154.5 4816.5 DGRC 163.0 4824.5 EWXT 213.5 4816.5 ROPA 213.5 4875.0 LOG HEADER DATA DATE LOGGED: 06-JAN-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 4875.0 TOP LOG INTERVAL (FT) : 154.5 BOTTOM LOG INTERVAL (FT) : 4875.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .2 MAXIMUM ANGLE: 72.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 12.250 DRILLER'S CASING DEPTH (FT) : 112.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 300.0 MUD PH: 8.5 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 5.900 69.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.060 81.5 MUD FILTRATE AT MT: 3.000 69.0 MUD CAKE AT MT: 1.500 69.0 411 III NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 FET MWD010 HR 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 154.5 4875 2514.75 9442 154.5 4875 GR MWD010 API 21.61 130.64 72. 6207 9324 163 4824.5 FET MWD010 HR 0.11 4.8 0.792068 9207 213.5 4816.5 RPX MWD010 OHMM 0.23 120.38 27.6779 9325 154.5 4816.5 RPS MWD010 OHMM 0.1 1441.09 34.4687 9135 154.5 4816.5 RPM MWD010 OHMM 0.14 1716. 99 45.2564 9325 154.5 4816.5 RPD MWD010 OHMM 0.05 1852.08 39.8055 9325 154.5 4816.5 ROP MWD010 FPH 1.54 668.67 172.75 9324 213.5 4875 First Reading For Entire File 154.5 Last Reading For Entire File 4875 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 • Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 4825.0 6270.5 ACHD 4850.5 6216.0 ADCL 4852.0 6226.5 CDRQ 4852.0 6225.5 ACDL 4852.0 6226.5 CDTQ 4852.0 6225.5 TNFA 4852.0 6213.0 TNPS 4852.0 6213.0 APEL 4852.0 6226.5 TNNA 4852.0 6213.0 DCRQ 4852.0 6225.5 DCTQ 4852.0 6225.5 CDBQ 4854.0 6225.5 DCBQ 4854.0 6225.5 DCLQ 4854.5 6225.5 CDLQ 4854.5 6225.5 R39P 4855.0 6263.0 R15P 4855.0 6263.0 R09P 4855.0 6263.0 EWXT 4855.0 6263.0 R27P 4855.0 6263.0 AHSI 4857.0 6226.5 ROPA 4875.5 6309.0 LOG HEADER DATA DATE LOGGED: 11-NOV-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 6309.0 TOP LOG INTERVAL (FT) : 4875.0 BOTTOM LOG INTERVAL (FT) : 6309.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 74.0 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 4865.0 BOREHOLE CONDITIONS MUD TYPE: Polymer • . III • MUD DENSITY (LB/G) : 9.55 MUD VISCOSITY (S) : 48.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 110000 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .720 78.1 MUD FILTRATE AT MT: . 600 70.0 MUD CAKE AT MT: . 900 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD020 IN 4 1 68 4 2 RHO1 MWD020 G/CC 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 RHOS MWD020 G/CC 4 1 68 16 5 RHO4 MWD020 G/CC 4 1 68 20 6 RHO2 MWD020 G/CC 4 1 68 24 7 DHO1 MWD020 G/CC 4 1 68 28 8 DRHO MWD020 G/CC 4 1 68 32 9 DHO3 MWD020 G/CC 4 1 68 36 10 DHO4 MWD020 G/CC 4 1 68 40 11 DHO2 MWD020 G/CC 4 1 68 44 12 CALN MWD020 IN 4 1 68 48 13 PEF MWD020 B/E 4 1 68 52 14 GR MWD020 API 4 1 68 56 15 FET MWD020 HR 4 1 68 60 16 RPX MWD020 OHMM 4 1 68 64 17 RPS MWD020 OHMM 4 1 68 68 18 RPM MWD020 OHMM 4 1 68 72 19 RPD MWD020 OHMM 4 1 68 76 20 ROP MWD020 FPH 4 1 68 80 21 FCNT MWD020 CP30 4 1 68 84 22 NCNT MWD020 CP30 4 1 68 88 23 NPHI MWD020 PU 4 1 68 92 24 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4825 6309 5567 2969 4825 6309 CALA MWD020 IN 8.23 14.91 9.81989 2732 4850.5 6216 RHO1 MWD020 G/CC 0.577 2.49 2.09166 2458 4854 6225.5 RHOB MWD020 G/CC 0.25 2.694 2.09718 2750 4852 6226.5 • III • RHO3 MWD020 G/CC 0.154 2.463 1.985 1998 4854.5 6225.5 RHO4 MWD020 G/CC 0.142 2.433 2.05063 1892 4852 6225.5 RHO2 MWD020 G/CC 0.221 2.654 1.79796 1912 4852 6225.5 DHO1 MWD020 G/CC -1. 939 0.214 0.0136139 2458 4854 6225.5 DRHO MWD020 G/CC -3.012 0.292 0.017912 2750 4852 6226.5 DH03 MWD020 G/CC -2.717 0.258 0.0707022 1998 4854 .5 6225.5 DH04 MWD020 G/CC -2.277 0.23 0.0352912 1892 4852 6225.5 DH02 MWD020 G/CC -2.279 0.312 0.097829 1912 4852 6225.5 CALN MWD020 IN 8.25 18.1 9.81209 1850 4857 6226.5 PEF MWD020 B/E 0.75 13.8 2.0464 2750 4852 6226.5 GR MWD020 API 24.08 103.54 57.2494 2892 4825 6270.5 FET MWD020 HR 0.18 3.01 0.711793 2817 4855 6263 RPX MWD020 OHMM 0.06 2000 21.1506 2817 4855 6263 RPS MWD020 OHMM 0.07 2000 98.1805 2817 4855 6263 RPM MWD020 OHMM 0.1 2000 229.131 2817 4855 6263 RPD MWD020 OHMM 2.79 2000 374.182 2817 4855 6263 ROP MWD020 FPH 3.12 916.42 219.565 2868 4875.5 6309 FCNT MWD020 CP30 295.05 818.2 424.486 2723 4852 6213 NCNT MWD020 CP30 62228.1 92874 .4 74679.4 2723 4852 6213 NPHI MWD020 PU 19.44 58.54 37.1198 2723 4852 6213 First Reading For Entire File 4825 Last Reading For Entire File 6309 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 0 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 4850.0 6261.0 R15P 4851.5 6253.0 R27P 4851.5 6253.0 CDLQ 4851.5 6219.0 EWXT 4851.5 6253.0 R39P 4851.5 6253.0 RO9P 4851.5 6253.0 TNFA 4852.0 6208.0 ADCL 4852.0 6220.5 • S TNNA 4852.0 6208.0 APEL 4852.0 6220.5 DCBQ 4852.0 6219.0 DCRQ 4852.0 6219.0 TNPS 4852.0 6208.0 DCLQ 4852.0 6219.0 CDTQ 4852.0 6219.0 ACDL 4852.0 6220.5 DCTQ 4852.0 6219.0 CDBQ 4852.0 6219.0 CDRQ 4852.0 6219.0 AHSI 4852.0 6220.5 ACHD 4852.5 6210.5 RSPD 4890.0 6300.5 LOG HEADER DATA DATE LOGGED: 11-NOV-11 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 6309.0 TOP LOG INTERVAL (FT) : 4825.0 BOTTOM LOG INTERVAL (FT) : 6309.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 74.0 MAXIMUM ANGLE: 95.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 4865.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.55 MUD VISCOSITY (S) : 48.0 MUD PH: 9.4 MUD CHLORIDES (PPM) : 110000 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .720 78.1 MUD FILTRATE AT MT: . 600 70.0 MUD CAKE AT MT: .900 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 ` III • Data Specification Block Type 0 • Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD021 IN 4 1 68 4 2 RHO1 MAD021 G/CC 4 1 68 8 3 RHOB MAD021 G/CC 4 1 68 12 4 RHO3 MAD021 G/CC 4 1 68 16 5 RH04 MAD021 G/CC 4 1 68 20 6 RH02 MAD021 G/CC 4 1 68 24 7 DH01 MAD021 G/CC 4 1 68 28 8 DRHO MAD021 G/CC 4 1 68 32 9 DH03 MAD021 G/CC 4 1 68 36 10 DHO4 MAD021 G/CC 4 1 68 40 11 DHO2 MAD021 G/CC 4 1 68 44 12 CALN MAD021 IN 4 1 68 48 13 PEF MAD021 B/E 4 1 68 52 14 GR MAD021 API 4 1 68 56 15 FET MAD021 HR 4 1 68 60 16 RPX MAD021 OHMM 4 1 68 64 17 RPS MAD021 OHMM 4 1 68 68 18 RPM MAD021 OHMM 4 1 68 72 19 RPD MAD021 OHMM 4 1 68 76 20 RAT MAD021 FPH 4 1 68 80 21 FCNT MAD021 CP30 4 1 68 84 22 NCNT MAD021 CP30 4 1 68 88 23 NPHI MAD021 PU 4 1 68 92 24 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4850 6300.5 5575.25 2902 4850 6300.5 CALA MAD021 IN 8.31 14.85 10.2657 2717 4852.5 6210.5 RH01 MAD021 G/CC 0.851 2.573 2.10527 2735 4852 6219 RHOB MAD021 G/CC 0.08 2.59 2.10199 2738 4852 6220.5 RH03 MAD021 G/CC 0.494 2.419 1. 9488 2736 4851.5 6219 RH04 MAD021 G/CC 0.506 2.396 2.05143 2735 4852 6219 RHO2 MAD021 G/CC 0.128 2.366 1.67611 2735 4852 6219 DH01 MAD021 G/CC -1.833 0.181 0.00408409 2735 4852 6219 DRHO MAD021 G/CC -3.254 0.272 0.00201972 2738 4852 6220.5 DH03 MAD021 G/CC -1.897 0.246 0.0660782 2735 4852 6219 DH04 MAD021 G/CC -1.916 0.192 0.0194234 2735 4852 6219 DHO2 MAD021 G/CC -2.23 0.367 0.0963579 2735 4852 6219 CALN MAD021 IN 8.25 16.57 10.0675 2738 4852 6220.5 PEF MAD021 B/E 0.74 14.43 2.02701 2738 4852 6220.5 GR MAD021 API 25.58 120.57 60.975 2823 4850 6261 FET MAD021 HR 0.93 30.3 14.6013 2804 4851.5 6253 RPX MAD021 OHMM 0.06 2000 9.12894 2804 4851.5 6253 RPS MAD021 OHMM 0.07 2000 33.862 2804 4851.5 6253 RPM MAD021 OHMM 0.08 2000 94.5523 2804 4851.5 6253 RPD MAD021 OHMM 1.78 2000 298.14 2804 4851.5 6253 RAT MAD021 FPH 0.77 485.88 236.577 2822 4890 6300.5 FCNT MAD021 CP30 304.03 955.27 443.752 2713 4852 6208 NCNT MAD021 CP30 64064.5 96424.6 76887.4 2713 4852 6208 NPHI MAD021 PU 17.19 61.47 36.7452 2713 4852 6208 First Reading For Entire File 4850 Last Reading For Entire File 6300.5 • File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/01/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 12/01/10 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/01/10 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/12/10 • Inspector: Chuck Scheve Operator: BPX Well Name: MPU S -39 - Oper. Rep: Lee Hulme PTD No.: 2081830 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 01/09/09 Date AOGCC Notified: Sundry No.: 310 -007 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA 0 by Operator OA 0 Condition of Wellhead: Barricade in place, double master valves. Condition of OK Surrounding Surface Location: Follow Up Actions none - Needed: Attachments: None REVIEWED BY: Insp. Supry 1- I01 ( PLB 08/2010 2010- 0912_Suspend_MPU_S- 39_cs.xls • • Alta SEAN PARNELL, GOVERNOR slim oF ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ken Allen Engineering Team Leader 1 BP Exploration (Alaska), Inc. a(yS P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Ugnu Undefined Pool, MPS -39 Sundry Number: 311 -306 Dear Mr. Allen: we ( i 7 el Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 911-19 Daniel T. Seamount, Jr. Chair DATED this 7 day of October, 2011. Encl. STATE OF ALASKA Cam" N O io -4 - (I ALASKA •AND GAS CONSERVATION COMMISSI• 10'4' C , 7 APPLICATION FOR SUNDRY APPROV t �' = 20 AAC 25.280 SEP.39 ?O1 1. Type of Request: At ka Ci ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Coos. Commissi ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension nchorsige ❑ Operations Shutdown ® Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory 208 -183 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 - 029 - 23405 - - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPS-39 Spacing Exception Required? ❑ Yes ►- No 9. Property Designation: , 10. Field / Pool(s): ADL380109, ADL380110 Milne Point Unit / Ugnu Undefined 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4881' • 3729' 4791' 3702' ' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 110' 110' 1490 470 Surface 4881' 9-5/8" 4870' 3725' 6870 4760 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None N/A 4 -1/2 ", 12.6# L -80 2463' Packers and SSSV Type: None Packers and SSSV MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: _ 0 Description Summary of Proposal BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 10, 2011 0 Oil " ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Johnson, 564 -4171 Printed Name Ken Allen Title Engineering Team Leader � _ Prepared By Name/Number: Signature" --,. C 7 --------- ....., Phone 564 -4366 Date _ ?0/ /� Terrie Hubble, 564 -4628 J` Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I 0(-P Sundry Number: ❑ Plug Integrity M'BOP Test ❑ Mechanical Integrity Other: j Test ❑ Location Clearance / Othe Rt V i 5e X ` ' ) rat u, z ra4 2 b ttUrt - e�..-�-2r tut/ G I . 3 SOD psi, Z50 p' (i n nK f 1 es t" C > „ Subsequent Form Required: IO_yd i,t�0 pr.. C o M�J 41-1 1 co �f f APPROVED BY Approved By:� COMMISSIONER THE COMMISSION Date o L // I Form 10 • 41-Z ` r i 10 04 it In uplicate . ,a•3 „ORI , 3 iv, • ' Ine Point in Well MPS -39 • M� Ugnu M80 Horizontal producer Sundry Notice MPS -39 surface hole was drilled in early 2009 and 9 5/8" surface casing was run and cemented at 4868' MD. The well was suspended due to need for the drill rig on other ice season projects. It is planned to reenter MPS39, pull the 4 -1/2" kill string and complete drilling the Ugnu production section. This well is designed as part of the MPU Heavy Oil Production Pilot Phase 1 to test the heavy oil production potential of horizontal wells in the M80 upper sand. A new permit request will be submitted as the bottom hole location target has moved 564'. The original well plan was drill the Ugnu section at a 70 degree sail angle. It is now planned to drill a horizontal lateral. Rig activity is expected to start in October 10, 2011 Present Well Condition Summary Casing Length Description MD TVD Burst Collapse Conductor 112 20" 92# H-40 Welded Insulated 112 112 1530 520 Surface 4868 9 -5/8" 47# L -80 BTC 4868 3725 6870 4750 Tubing 7510 4 -1/2" 12.6# L -80 IBT 2463 2214 8430 7500 Perf Depths (MD): None Perf Depths (ND): None Procedure Pre -Rig Operations 1. PPPOT -T and IC. Function all LDS. 2. CMIT - T X IA 3. Verify BPV is installed. Drilling Rig Operations 4. MIRU. NU BOPE and test BOPS and annular to 3500 psi. 5. Circulate out diesel freeze protect. 6. Pull 4 -1/2" string from 2463' MD. 7. PU DP. RIH 8 -1/2" bit and drilling assembly. 8. Drill out 9 -5/8" float equipment. Prep to drill production hole lateral as per ariifing permit. Lo( Pro 1 9/27/2011 • Current Completion Tree: Cameron 4-1/16' 5M Wellhead: F MC Gen 5 11' 5 NI PS -39 Ong_ Y,8 Elev. =7? 1' Tubing Head: 11' x 11' 5M Cellar Box ELEV= ::78. NOTE: 7" IsolationSilrAal,IpitalML in Wellhead. Must be removed before drilling or running another 2C "9201t, H•4( Welded 112 I Casing string. Insulated " mn Pa't Co :r lq- 4 -112' 12.64, L-80, IBTM Tbg. Dnft= 3.833' Tbg. ID = 3.958' Tbg. Capacly =.3152 All 4-12' HES X Nipple . 2.813' ID 244 I 4 -1.2' WLEG 2 2 °_IB' 47x, L -8C. BT» 'oQ Drrft= Cog ID = 8 581" Burst = 5,87( poi Coilapoe = 4,7 =C psi Capacity= C752tk1((ft 9 -518' Float Collar 1 479' 12 -114" Hole 9.5?B' Casing shoe 4870 { !] Wet ncfnabon = 73' MPS-39 - THIS WELL HAS BEEN SUSPENDED (20AAC25.110). 1/09/2009 'NOTE: TAM -PORT Collar is at 18` inclination- It is recommended to rotate through this above 12° when running in the hole with a bent housing motor or PDC bit. DATE REV BY CCKIMEHTS MINE POINT UNIT 1:9;2009 REH CHOP compvton .vi K4 Sirng - Doyon '4 WELL No.: S -39 API : 50- 029 - 23405 -00 -00 BP EXPLORATION (AK) 2 9/27/2011 s . , 13 5/8" 50001 WP HYDRIL, TYPE GK" 13 5/8" 50001 WP LATCHED TOP BY 4'-4" 13 5/8" FLANGED BOTTOM 5 4 1/2" BOP E A L 1 • PIPE RAM 13 -5/8" 50001 " + FLANGED HYDRIL 4 10 l , DOUBLE GATE PREVENTOR Die 3" 5000j1 HCR VALVE • BLIND SHEAR r 58 1/8" LENGTH 17 r r" ■ 3" 50001 NCR VALVE W 1' - 3" CHOKE LINE — — ' wiry :III =II' II► ∎11/ ` I -- - - - - 2. KILL UN'E Nommem o -1:-.) 1 3" 50001 GATE VALVE 3" 50001 GATE VALVE W N o w 2 - 94 " c PIPE RAM go. -.+ HYDRIL 13 -5/8" 5k PSI 0 - , HYDRAULIC RAM SINGLE GATE - I FLANGED CONNECTION I 36 LENGTH n 7%-10- °1 ■ 4 II I 3 T _� CO 2' 1111.11110. 411► II4-- IN 0 III NABORS ALASKA RIG TES BOP STACK CONFIGURATION .atn "- aaa=a°.r° ' IlipasbasAksks m° °= mow, '' t weans kASIiS MG 740 "„ GOA= MPS 2004 RIG 40040414 SO,EVI . BCP nor 00444;t0MTION mow . 8 b 0000 Of WOWID N 4006 .t. On St t r wr MOM= 1 6 ' Pfhl ° 401 tow .gyp ""rat s MA'ERIAS LIS" Y ITEM ,,;i;k;a . A 3 - 1/8 .v I V.;KAUUC z 10KE B 3 - 1/8 ;V .40.JSIAI LL Cr10KE ' - 13, 15 3 -1/8 5M MAN;;AL GATE VALVE et fiii r '4 2 - 1/16 561 MANUAL GATE VALVE JO Fl ARE l c 1 H-- UNITE HANDLE VALVES ilk NORMALLY OPEN f 0 I1 CT 41111 RED HANDLE VALVES 0 O NORMALLY CLOSED N V IMF i _ m o `0 \` dlr. TO GA56USTER 0 N -1=. . �, 0 N . i Obliiiiirip**0. 0 = .. . SECONDARY =4; 101....-- CHOKE LINE cn 1 I P '' • 1 A .i A m ,. h — Mik/RS AUSWA IN 7(5 'E WOW t50611710C z( i INLET : G"i]l3I i n b w ' WC 'M." r ra A MX len b -_._. _._._. © ©lJ� NORM An *4 As Aar 7!S -fiN Y.i��i • • • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) 4 Sent: Friday, April 15, 2011 5:15 PM \� fe l C I To: 'Worthington, Aras J' t x Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: MPU CHOPS Wells SSV Variance The Well Safety Valve System (SVS) regulations - 20 AAC 25. 265 - effective December 3, 2010, provide for granting either a variance or waiver of the stated requirements; a variance if what is proposed provides at least an equally effective means of compliance; a waiver if what is proposed does not promote waste, is based on sound engineering /geoscience principles, will not jeopardize ultimate recovery, and does not increase risk to health, safety, environment. 20 AAC 25.265(c)(1) requires the surface safety valve (SSV) to be installed in the vertical run of the well's tree. As explained, this would be impossible to comply given the rod - driven downhole pumps used in the Cold Heavy Oil Production with Sand (CHOPS) project completions. BPXA's request for a temporary variance is approved. 20 AAC 25.265(c)(4) requires installation of a check valve in the well's flowline upstream of the production manifold. Your explanation indicates these check valves have not been installed, thus your request is not for a variance (equivalence) but a waiver [20 AAC 25.265(o)(2)]. BPXA's request for a temporary waiver is approved, but there needs to be additional discussion about the levels of protection in lieu of the check valves. These temporary approvals apply to Milne Point Unit wells S -37 (PTD 2070520), S -39 (PTD 2081830), S- 41 (PTD 2081590), and S -43 (PTD 2081760). Sufficient information has been provided to allow BPXA to begin operating these wells this weekend as requested in our phone conversation. Broader coverage (other wells) will be addressed in the Commission's response to BPXA's formal request as necessary. BPXA's formal request (letter application) covering the variance and waiver must be provided no later than Tuesday, April 19, 2011 (do not need to submit request by sundry application). Appropriate schematics as necessary and justification must be provided that can serve as the basis for the Commission's approval of permanent variance /waiver. Jim Regg AOGCC hh { 333 W.7th Avenue, Suite 100 H r Anchorage, AK 99501 907 - 793 -1236 From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Friday, April 15, 2011 4:26 PM To: Regg, James B (DOA) Subject: Mr. Regg, BPXA requests a temporary e-mail variance to 20 AAC 25.265C for rod - driven pump wells at Milne Point: MPS -37, 39, 41, and 43 to allow the surface safety valve (SSV) to be located horizontally on the tree. Wells 37, 41, and 43 were completed prior to the regulation change that became effective December 3, 2010. A SSV in a vertical line with the tree (25.265C.1) is neither practical nor effective due to the need to accommodate the drive rod. 4/15/2011 • • Page 2 of 2 Also, a variance is requested on 25.265C.4 which states that a check valve must be installed in the well's flow line upstream of the production manifold. Although check - valves are present on the annulus gas, and on the production lines prior to entering the atmospheric production tanks, they were not installed upstream of the production manifold due to the high fluid viscosities and initial sand -cuts that could plug the check - valves. BPXA will follow through with a formal request for variance for these wells complete with schematics and all necessary detail. Aras Worthington Wells Intervention Engineer BP Alaska Inc. (907) 564 -4102 4/15/2011
