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212-050
333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 14, 2023 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit M-29A PTD 2120500 Dear Mr. Marlowe: On June 9, 2023, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit M-29A located on the Steelhead Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 10-004. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 2 additional times. The maximum observed gas flow rate was 850 scf/hr that declined to 750 scf/hr within 5 minutes. There was no liquid flow to surface during the no-flow test. Trading Bay Unit M-29A may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit M-29A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2023.11.14 13:53:03 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Clean-out / Replace ESP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,720 feet N/A feet true vertical 9,696 feet N/A feet Effective Depth measured 11,592 feet N/A feet true vertical 9,663 feet N/A feet Perforation depth Measured depth 9,242 - 11,536 feet True Vertical depth 8,732 - 9,648 feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2# / L-80 7,982 (MD) 7,646 (TVD) Packers and SSSV (type, measured and true vertical depth) N/A & N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 75 323-221 Sr Pet Eng: 5,410psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager N/A Hemlock Oil & Middle Kenai G Oil 990 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 114 Gas-Mcf MD 990 N/A 559 Size 990 1,441 3096 7166 0 790 13-3/8" 10-3/4" & 9-5/8" 7,240psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 212-050 50-733-20428-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018730 McArthur River / Hemlock Oil, Middle Kenai G Oil Trading Bay Unit M-29A Plugs Junk measured Length measured TVD Tie-Back Liner 8,430 8,205 3,512 Casing Structural 8,034 7,839 7" 8,430 8,205 11,713 9,694 1,441 3,756 1,441Conductor Surface Production 26" 16" 3,220psi 4,790psi 2,630psi 3,090psi 5,860psi 6,890psi 3,756 3,754 Burst 3,010psi Collapse 1,440psi 1,010psi 1,540psi pp kk tt Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:12 am, Jun 29, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.29 09:51:47 - 08'00' Dan Marlowe (1267) Revised: JLL 06/26/23 SCHEMATIC McArthur River Field, TBU Well: M-29A PTD: 212-050 API: 50-733-20428-01 Completed: 05/30/23 TD = 11,720 PBTD = 11,592 RKB to TBG Head = 71.93 Tree connection: 1 2 HK-5 9-5/8 window @ 8,430 MD 7 HK-7 HK-6 HK-4 G-3 G-4 G-5 HK-1 HK-3 26 16 13-3/8 10-3/4 9-5/8 7-5/8 3 G-2 G-1 HK-2 Casing Detail SIZE WT GRADE CONN ID TOP BTM. 26 267 to 397 Drill Quip Surface 990' 16" 75 K-55 BTC 15.124" Surface 1,441' 13-3/861 K-55 BTC 12.415" Surface 2,808 68 K-55 BTC 12.415" 2,808 3,756' 10-3/4"55.50 L-80 BTC 9.760" Surface 460 51 L-80 BTC 9.850" 460 484' 9-5/847 L-80 AB Mod & BTC 8.681" 484' 5,727' 53.5 L-80 BTC 8.535" 5,727 8,430 TOW 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Tubing Detail 3-1/2" 9.2 L-80 IBT-Mod 2.992" Surface 7,982 Jewelry Detail NO.Depth MD Depth TVD ID OD Item 1 71.93 71.93 Tubing Hanger Seaboard SC-EN-ESP-CCL 2 7,982 7,646 - 5.13 Bolt-on Discharge 7,984 7,648 - 5.38 PUMP (x3) - 538 SERIES, 071 STAGE SJ7000 8,050 7,705 - 5.13 Intake 8,051 7,706 - 5.13 Upper/Lower Tandem Seals - 513 Series BPBSBOB 8,068 7,721 - 5.62 Motor (x2) - 562 Series,KMS2LT 8,134 7,778 - 5.62 Anode 3 8,205 7,839 6.151 8.01 Baker Seal Assembly Perforations Zone Interval (MD) Interval (TVD) Ft SPF Status Date G1 9,242' 9,270' 8,732' 8,755' 28' Open 4/15/2017 G2 - G3 9,326' 9,366' 8,799' 8,830' 40' Open 4/15/2017 G3 9,336' 9,372' 8,806' 8,834' 36 5 Open 7/16/2012 G4 9,394' 9,446' 8,851' 8,890' 52' Open 4/15/2017 G4 9,402' 9,452' 8,857' 8,895' 50' 5 Open 7/16/2012 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open 7/16/2012 G5 9,518' 9,605' 8,944' 9,007' 87' Open 4/15/2017 HK1 9,788' 9,828' 9,131' 9,155' 40' Open 4/15/2017 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open 7/16/2012 HK2 9,890' 9,949' 9,188' 9,217 59' Open 4/15/2017 HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open 7/16/2012 HK3 HK4 10,068' 10,630' 9,264' 9,416' 562' Open 4/15/2017 HK4 10,202' 10,380' 9,305' 9,349' 178 5 Open 7/16/2012 10,410' 10,648' 9,356' 9,421' 238 5 Open 7/16/2012 10,690' 10,740' 9,433' 9,447' 50 5 Open 7/16/2012 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open 7/16/2012 HK5 10,765' 11,028' 9,454' 9,521' 263' Open 4/15/2017 HK6 11,174' 11,375' 9,558' 9,607' 201' Open 4/15/2017 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open 7/16/2012 HK7 11,428' 11,544' 9,621' 9,650' 116' Open 4/15/2017 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open 7/16/2012 OPEN HOLE / CEMENT DETAIL 7"8-1/2 Hole: 126bbls 15.3ppg class G cement pumped. 11bbls losses.7/9/12 temperature log suggests ToC at 9250' MD Rig Start Date End Date HAK 404 5/17/23 6/9/23 05/17/2023 - Wednesday Cont. unload Boat. Install "A" leg & pin mast. R/U circ lines, send boat back to Dolly & load with Rig Eq. Production bleed down well, R/U circulating lines. Pump 3.5 BPM, taking returns to production bucking 80 psi line pressure, getting gas & oil returns. Cont. circulate 708 bbls getting FIW back, cont circ while cleaning up, lost returns. Pump total of 1433bbls, monitor well. Raise mast & string up lines, check well, on vac. Install BPV. Production prep wellhead for N/D while wait on Crane operator to come from Dolly. Unload Boat, N/D tree, prep wellhead. Install blanking sub. N/U riser. 05/18/2023 - Thursday Cont. stack up BOPE, mud cross, double gate, annular, circulating head. Tq flanges. Stand & scope out mast, secure same, r/u choke & kill lines, install accumulator lines. Unload boat w/ ESP pulling Eq. level carrier. PTSM, install rig floor, function test BOPE, good. Bleed system, check accumulator, pre-charge. M/U test joint, r/u handling Eq, tq connections install test joint, fill surface Eq. with water. Shell test 250/2500 psi, good. Install beaver slide, stairs from rig floor to deck, spot pulling Eq. while State inspector is mobing out. Test BOPE: Test 13-5/8, annular, 5-1/2 x 2-7/8 VBR's, Blind rams, TIW & Dart valves, Choke HCR, manual valve, kill line valves #1,2, 3, CMV #1 THRU #11, Kelly valve to 250 low and 2500 psi hi. Test made with water & held on chart 5 minutes. Quadco test Gas Alarms, PVT alarms, perform koomey draw down, test super choke and manual choke. (All tests pass) AOGCC inspector Adam Earl witness test. R/D test eq. pull blanking sub, work boat, break down test joint, m/u landing joint. Finish making up landing joint, R/up handling equipment hang summit sheave and run rope to spoolers. Flush tbg with 70 bbls FIW. Rigging up VAC unit to clean pits, rig up circulating hose to choke manifold to well room. Circulate Tubing volume at 2 bpm "0" psi shut down pump tbg on vacuum. Pull BPV. Circulate well at 4.0 bpm at "0" psi to production. 05/19/2023 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20428-01 212-050 Well Name M-29A Pumped Hole volume, 342bbls down tubing, @ 4BPM, 0psi, lined up to take returns to Production, annulus pressure increased to 23psi, no returns. Finish cleaning pits. Line up to take returns to pits via gasbuster, pump 285 bbls @4 BPM no returns. Line up Bullhead 375bbls down Annulus @ 4BPM, 40 psi. M/U landing joint, BOLD pins, Pull hanger to floor, Hanger came off seat @ 98k, string moving @ 116k, L/D hanger & landing joint. PTSM, Walk through bare pipe shut in drill. POOH w/ESP completion, l/d 3 1/2" 9.2#, L-80, IBT completion. Thread cable & flat pak through sheave & containment trunk to spool. Continue to pooh to 5,114 ft. Change out motor lead spool. Work boat offloading mix pit and chemicals, 115 joints of work string. Continue pooh laying with ESP assembly, laying 3-1/2 9.2# L 80 IBT completion. Tubing Depth at rpt Time 958 ft. Rig Start Date End Date HAK 404 5/17/23 6/9/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20428-01 212-050 Well Name M-29A 05/20/2023 - Saturday 05/22/2023 - Monday R/U power swivel, P/U single, M/U circulating head, function test swivel, M/U joint. Attempt to break circulation, tubing pressured up, attempt to clear Rev, surging, no joy. L/D single, R/D power swivel, R/U handling Eq, pull circuiting bushing. POOH wet, f/ 9930' t/8877', standing back wk string, up wt 165k, dn wt 127k attempting to clear periodically. Surged string @ 8877' appeared to have broke free, break circulation rev @2.3 BPM, 235psi. Turn around pump down tubing @ 2.5 BPM 190psi, started getting oil back, shut down & rig up to take returns to production. Circulate hole clean @ 3BPM cleaning up @ 65 bbls, cont circulate clean 110BBLS. R/D from production, flush stack clean. TIH t/ 9870', L/D 3 singles & RIH w/ last stand t/ 9870 up wt. 156k dn wt 121k. Break cross over out of work string, Make up TIW and head pin & circ hose. Circulate work string volume of 68 bbls at 2.8 bpm at 300 psi taking returns to pits. Caught pressure at 4 bbl. pumped getting returns after pumping 28 bbls pump got returns. Pick up power swivel: make up Kelly hose, hydraulic lines, static line and tighten at double beam. Pick up single and make connection, install rubber into circulating head run in lock down bolts, tighten bolts on circulating head. Break circulation down work string, took 4 bbls to catch pressure, & 39.6 bbls to get returns. Wash and ream & back ream pump down work string at 2.5 bpm at 200 psi, then reverse circulate a tbg bottom up.at 2.5 bpm 225 psi From 9,870' to 9,994' p/up wt 158k s/o 124k loss rate at 14 bph. Cont. POOH f/958', l/d 3 1/2" 9.2# L-80 IBT tubing t/ 180' (last joint). Cut cable above splice clamp. Pick up as high as able, check ESP assy, good, break down & l/d assembly, finding no abnormalities. Full recovery of assembly, & clamps, 253cc clamps, 24 assembly clamps, 2 ss bands. Clear floor, c/o handling Eq., prep BHA, L/O 3 1/2" wk string, tally same. P/U BHA, 6" Mill tooth bit, 2- boot baskets, bit sub, string magnet, bumper sub, oil jar, 6 4 3/4" DC, xo = 223.08' C/O handling eq. RIH p/u 3 1/2" 12.95# PH6 wk string from 221 ft. to 3,634 ft. Workboat: offload 3-1/2 PH 6 work string. Fill mix pit with 52 bbl. FIW, finish rigging up mix pit. change out man rider cables. Continue in hole picking up 3-1/2 PH 6 work string f/ 3,636 ft. t/7986' up wt 132, dn wt 120, pumping 25 bbls every hour in annulus. 05/21/2023 - Sunday Cont. RIH p/u 3 1/2" PH6 wk string f/7986' t/9941' up wt 165k, dn wt 135, POOH l/d single t/9930'. R/U pump tubing volume @ 4bpm, good. POOH t/ 9186' (above perfs). P/U swivel & set back while mixing salt pill. Pump 5 bbls High vis spacer, 60 bbls saturated salt pill, 5 bbls high vis spacer, pump out of tubing tail, let soak to perfs. Pump 20 bbls in annulus every 10 min for hour, fill hole with total of 160bbls check loss rate @ 90 BPH. Mix saturated salt pill. Pump 5 bbls High vis spacer, 70 bbls saturated salt pill, 5 bbls high vis spacer, spot @ tubing tail to soak to perfs. Pump 20 bbls in annulus every 15 min for hour, fill hole with total of 56 bbls monitor well check loss rate @ 24 BPH. Trip in hole with work string from 9186 ft. to 9930 ft Rig Start Date End Date HAK 404 5/17/23 6/9/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20428-01 212-050 Well Name M-29A 05/24/2023 - Wednesday Cont. Wash & ream F/11,231' t/11,603' Up wt. 166k, dn wt. 124k, rot wt. 140k, ROT 120rpm, tq 3-4k, circ 3 BPM, 350-400psi, running 5 joints down circulating long way, then reversing clean. Hit hard spot @ 11,308-11329', recovered ~25 bbls solids from cleanout. Rev. Circulate 2.5 BU clean, @ 3.75BPM 460psi. R/D swivel, c/o handling eq. POOH f/11,603', up wt 166k, dn wt 124k, T/9466'. Platform power down, secure well while getting back online. Cont. POOH t/ 2550 standing back 3 1/2" wk string. continue pooh laying out 74 joints of 3-1/2 work string to 248 ft.doping boxex & pins. Change out handling equipment lay down BHA 6" Mill tooth bit, 2- boot baskets, bit sub, string magnet, bumper sub, oil jar, 6 4 3/4" DC, xo = 223.08'. Pick up power swivel and break off x/over and lay out power swivel. Clear rig floor & rig up test joint, put 20 bbls FIW in IA, land test plug. Fluid pack BOPE and surface equipment test 13-5/8 5m BOPE and related surface equipment with 3-1/2 test joint to 250 low & 2500 psi hi. test made with water and held on chart 5 minutes. Witness waived by AOGCC Jim Regg 05/25/2023 - Thursday Continue Testing BOPE as per Hilcorp & AOGCC requirements, test with 3-1/2 test joint to 250/ 2500 psi, Witness waived by AOGCC inspector Jim Regg, had one FP on CMV #1 leaking from stem, serviced & re-tested good. R/D test Eq. P/U 7" test packer. TIH t/ 8170' up wt 116, dn wt 106k, continue in liner & down to 9035', dn wt 120k, was unable to pick up @ 150k, C/O elevators. Wk pipe unable to pick up, pick up single able to move down free, but up no joy, pulled up t/45k over, R/U & pump down tubing & pressured up t/600 psi, attempt to P/U with no joy, R/U rev circulate pressured up t/611psi, bled off pumped down tubing pressured up t/440psi, picked up and pressure dropped off was able to pull @ 132k, L/D joint, attempt to pull with no pump but unable. Pick up while pumping at different rates, able to move pipe @ 1.5-2BPM, worked string attempting to free obstacle changing pump rated & pulling speed with no luck. Pump singles out of hole @ 2BPM, 80 psi, pumped lube pill while pumping out, up wt 132k, dn wt 120k, f/9040' t/8170' (above liner top @ 8201') making attempts periodically for clean pickups. no joy without pumping. Picked up without pumping free, up wt 116k, dn wt 112k, Rev circulate 1.5 tubing volumes @ 4BPM 330 psi. RIH t/ 8232' making pickups clean. continue p/u 3 1/2" wk string checking pickups every joint. clean. down t/9040' up wt 128k, dn wt 120k. P/U & set packer @ 9035'. R/U & test t/2300psi f/ 30 min good. AOGCC witness waived By inspector Jim Regg, Release packer & let element relax. 05/23/2023 - Tuesday Cont. wash & ream F/9994' t/10242' up wt 160k, dn wt 125k, rot wt 138k, ROT 120rpm, tq 3-4k, pcirc 3BPM, 350-400psi, running 4 joints down circulating long way, then reversing clean. Packed off @ surface while reversing clean, found plug, cleared & finished circ. clean. Cont. wash & ream F/10242' t/10645' Up wt. 164k, dn wt. 130k, rot wt. 140k, ROT 120rpm, tq 3- 4k, circ 3BPM, 350-400psi, running 5 joints down circulating long way, then reversing clean. Cont. wash & ream F/10,645' t/11,015' Up wt. 164k, dn wt. 130k, rot wt. 140k, ROT 120rpm, tq 3-4k, circ 3 BPM, 350-400psi, running 5 joints down circulating long way, then reversing clean. Cont. wash & ream F/11,015' t/11,231' Up wt. 164k, dn wt. 130k, rot wt. 140k, ROT 120rpm, tq 3-4k, circ 3 BPM, 350-400psi, running 5 joints down circulating long way, then reversing clean. Hit hard spot @ 11,221'. Rig Start Date End Date HAK 404 5/17/23 6/9/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20428-01 212-050 Well Name M-29A Pump 58 bbl pill, spot at end of tubing. POOH L/D 3 1/2" wk string f/9035' up wt 128k, doping threads & installing thread protectors. t/ 5155'. POOH L/D 3 1/2" wk string f/ 5155' up wt 80k, doping threads & installing thread protectors. t/test packer'. Break & l/d 7" test. Rig down Gills tongs, R/d Circulating head, R/up Adaptor spool, and shooting flange, R/up E-line sheaves, M/up E-line shooting nipple test same to 1700 psi, rig up pump to fill hole while running with perf gun. AKE Ran in hole with 3-1/8 tool string, 3-1/8 GR/CCL, shock sub, firing head, 30 ft of 3-1/8 perf guns in a 20 ft & 10 ft section. load with DP BHC 6 spf. at 60* phasing. to 9400 ft. Made 3 correlation pass f/ 9400 ft ELM t/ 8000 ft ELM unable to correlate the GO Sand f/ 9,190' to 9,220' due to correlation extremely difficult due to scale and lack of tied-in CCL understanding, unable to put perf guns on depth, decision, to forgo perforating the GO sand Pooh with E line. Rigging down E-line. 05/27/2023 - Saturday Finish r/d e-line, r/d shooting flange, R/U circulating head,. R/U clean pits, Spool up Swivel lines, organize baskets while waiting on wind to slow down for crane operations. R/U Handling Eq. RIH w/ 3 1/2" L-80, 9.2# IBTM completion tubing. t/2687'. Wind picked back up unable to hold, secured well, clean pits & work on project list. Continue RIH picking up 3-1/2 IBT Production f/ 2,566' to 7,248' S/O wt. 76k p/up wt. 82k filling hole with 20 bbl. FIW added every hour. HPJSM lay out 3-1/2 IBT TBG, strap same, service rig. Continue RIH picking up 3-1/2 IBT Production f/ 7,248' to 7899 ft. S/O wt. 80k p/up wt. 88k filling hole with 20 bbl. FIW added every hour. Pooh racking back 3-1/2 IBT production tbg in derrick. Depth at rpt time 4124 ft. 05/28/2023 - Sunday Cont. POOH w/ 3 1/2" completion tubing racking back f/4124'. C/O handling Eq. P/U ESP assembly, P/U 2- motors w/sensor & Anode, service both motors, plumb in injection lines to check valves, test & had failure on one, mobed new one out & replaced, tested good, filling hole 20 bbls every hour. P/U tandem seals & service, intake, & 3 pumps, discharge, xo pup, & handling joint. preform surface checks, filling hole 20 bbls every hour total assembly 185'. Rig down Summit ESP handling equipment, R/up 3-1/2 handling equipment Held cable cutting drill with crew before RIH. RIH with ESP assembly on 3-1/2" 9.2# L-80 IBT Tubing, checking cable reading every 1000 ft f/ 185' to 3029', Filling hole with 20 bbls FIW every hour. Held PJSM held cable cutting drill with crew and summit before RIH with pumps. RIH with ESP assembly on 3-1/2" 9.2# L-80 IBT Tubing, checking cable reading every 1000 ft f/ 3,023' to 6,019', Filling hole with 20 bbls FIW every hour. 05/26/2023- Friday Rig Start Date End Date HAK 404 5/17/23 6/9/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20428-01 212-050 Well Name M-29A 06/09/2023- Friday AOGCC inspector Adam Earl witnessed no flow test. PASS. 05/29/2023 - Monday Cont. RIH with ESP assembly on 3-1/2" 9.2# L-80 IBT Tubing, checking cable every 1000' f/ 6019'' to 6584', Filling hole with 20 bbls FIW every hour. C/O cable spools, Make splice & test same. Splice landing on joint 210. Cont. RIH with ESP assembly on 3- 1/2" 9.2# L-80 IBT Tubing, checking cable every 1000' f/6584', t/8052' Filling hole with 20 bbls FIW every hour. dn wt 114k. P/U hanger w/ landing joint & make up, r/u & make cable splice for penetrator & install, m/u injection line penetrations through hanger. test cable, good readings, install umbilical cord, land hanger placing assembly tail @ 8132', RILD pins, test cable good readings, pull cord & landing joint, install BPV. Clear rig floor, Bleed off koomey and remove koomey hoses and fittings from stack, remove choke and kill hoses, remove off drillers side stairs, Driller side ladder and stairs, remove rig floor, remove guy lines, scope down derrick and lay over derrick, nipple down bop stack. Vault service technician prepping hanger and wellhead. Nipple up 4-1/16 5m tree & flow line, test void to 5000k for 15-minute, summit check motor lead (Good), shell test tree to 5k tighten leak on flange. 05/30/2023 - Tuesday Test tree, had flange leak, repaired & tested t/5k good, pulled TWC. turned over to production. Pickle and grease mud pump, remove all tools and trash from well head room, lay derrick over tie up cables, unbolt draw works, remove console brake linkage, drive line pressure washing pits, remove choke manifold panic line, rolling up hoses on deck, back loading workboat. Coil up guy lines on top of mast and secure, continue securing lines and hoses on mast, pull pins and pick up mast off carrier and place on feet on deck, pick up A-leg empty chain oil in draw works, remove from carrier and place on travel frame. Move doghouse to deck move choke manifold and bang board, remove stairs and landings from carrier, pick carrier and place on deck, remove all clamps off beams, remove yellow. cross members from single and double beam, center base beam and secure to double beam. continue to clean pits, put circulating hoses in basket, wash annular, double gate, mud cross and circulating head spool, open doors on double gate, clean cavities, remove rental VBR's and replace with Hilcorp VBR's, bring racking mat to wash bay and wash handling equipment in it, removing any misc., equipment, open drain plugs, housekeeping, putting away tools, parts, and supplies.in Conex buildings. Cleaning koomey hoses and storing in mud box, clearing misc. tools off of racking mat & cleaning racking mat, cleaning trash off top of mud pits, back loading work boat., Remove ram packing off of rental ram body., remove tong dies from McCoy and Gills power tongs and clean same, cleaning decks. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230419 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 04RD 50133202390100 219011 5/10/2023 AK E-LINE PERF BRU 212-26 50283201820000 220058 5/31/2023 AK E-LINE PPROF NCI B-01A 50883200930100 198002 4/24/2023 AK E-LINE Cut CBL CIBP Paxton 12 50133207100000 223014 5/24/2023 AK E-LINE Perf Record Paxton 12 50133207100000 223014 4/27/2023 AK E-LINE GPT/PERF SRU 213B-15 50133206540000 215130 5/1/2023 AK E-LINE CIBP Perf TBU M-29A 50733204280100 212050 5/7/2023 AK E-LINE Drift Punch Please include current contact information if different from above. T37759 T37760 T37761 T37762 T37762 T37763 T37764TBU M-29A 50733204280100 212050 5/7/2023 AK E-LINE Drift Punch Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.20 11:55:19 -08'00' 2023-0609_No-Flow_TBU M-29A_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 6-12-2023 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU M-29A Hilcorp Alaska LLC. PTD 2120500 6-9-2023: I traveled out to Steelhead Platform to witness a No-Flow test on TBU M-29A. Ryan Wilcox was the operator conducting the test. The well had been opened to bleed for approximately 20 hours. The test was done through an Armor-Flo SCFH meter with lines coming from the tubing and the IA, connected with isolating valves and a calibrated digital pressure gauge. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 09:15 0.07 / 0.02 / 255 Shut the well in @ 9:15 09:30 0.58 / 0.02 / 255 09:45 0.86 / 0.02 / 255 10:00 1.17 / 0.02 / 255 10:15 1.48 / 0.02 / 255 180 None 150 SCFH after 5 minutes 10:20 0.85 / 0.35 / 255 Shut well in @ 10:20 10:35 1.22 /0.36 / 255 10:50 1.54 / 0.36 / 255 11:05 1.88 / 0.36 / 255 11:20 2.22 / 0.36 / 255 650 None 500 SCFH after 5 minutes 11:25 1.33 / 0.66 / 255 Shut the well in @ 11:25 11:40 1.76 / 0.66 / 255 11:55 2.09 / 0.66 / 255 12:10 2.42 / 0.66 / 255 12:25 2.72 / 0.66 / 255 850 None 750 SCFH after 5 minutes 12:30 1.73 / 0.91 / 255 Final pressures 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr The test seemed to meet the passing requirements. Attachments: Test Equipment Calibration Reports 2023-0609_No-Flow_TBU M-29A_ae Page 2 of 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT M-29A JBR 07/25/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 good test Test Results TEST DATA Rig Rep:Hannevold/CastagneOperator:Hilcorp Alaska, LLC Operator Rep:Soule/Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:2120500 DATE:5/18/2023 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopAGE230521133114 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 2415 Sundry No: 323-221 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 2 7/8 X 5 1/2 P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16 P HCR Valves 2 2 1/16 P Kill Line Valves 2 2 1/16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1900 200 PSI Attained P19 Full Pressure Attained P90 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2025 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P18 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: 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: Current Pools: McArthur River 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,720 N/A Casing Collapse Structural 1,440psi Conductor 1,010psi Surface 1,540psi Production 3,220psi Tie-Back 4,790psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC 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 AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,696 9,663 2415 16"1,441 MD 1,441 1,441 Length Size 990 6,890psi7,8398,205 7,240psi11,713 9,694 3,754 8,034 Perforation Depth MD (ft): 8,205 7"3,512 7-5/8" 10-3/4" & 9-5/8"8,430 13-3/8"3,756 3,756 8,430 Proposed Pools: 990 990 TVD Burst PRESENT WELL CONDITION SUMMARY 26" N/A 3,010psi 11,592 5,860psi 2,630psi 3,090psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 212-050 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20428-01-00 Hilcorp Alaska, LLC Trading Bay Unit M-29A Hemlock Oil, Middle Kenai G Oil Same CO 228A 5/5/2023 N/A & N/A N/A & N/A 9,242 - 11,536 8,732 - 9,648 3-1/2" Other: Clean-out & Replace ESP 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Operations Manager Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2# / L-80 7,979 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2023.04.11 08:37:07 -08'00' Dan Marlowe (1267) BJM 4/27/23 DSR-4/13/23 Shallowest perf allowed is 9180' md due to TOC logged at 9120' MD. MDG 4/20/2023 XX BOP test to 2500 psi No-Flow test required. Provide AOGCC 48 hrs notice for opportunity to witness 7-5/8" casing MIT. 10-404 JLC 4/28/2023 4/28/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.28 10:24:28 -08'00' RBDMS JSB 050123 ESP Swap RWO Well: M-29A Well Name:M-29A API Number:50-733-20428-01-00 Current Status:ESP Oil Producer Leg:Leg B-1 (NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:212-050 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Karson Kozub (907) 570-1801 (c) Maximum Expected BHP:3,350 psi @ 9,350’ TVD Highest Offset BHP Max. Potential Surface Pressure: 2415 psi Using 0.1 psi/ft Brief Well Summary M-29A is a Hemlock/G-zone oil producer that was sidetracked to its current bore in 2012. As part of that sidetrack a 7-5/8” scab liner was installed to cover some suspect 9-5/8” casing areas. This was the last casing test (2012). Given the fill/scale seen during the 2017 RWO, a fill clean out of the liner is planned. A new no- flow test will be required post-rig. The goal of this project is to pull and replace the ESP, while cleaning out any 7” liner obstructions. Select perfs will also be added while the completion is out of the hole. Pertinent wellbore information: - Inclination o Goes > 70 degrees below 10,075’ MD o Remains 75 degrees from 10,075’ to PBTD - 6/20/17: passed NFT - 4/28/17: Inconclusive NFT -April-2017 RWO o Elective ESP pull due to degrading PI o Liner mill/cleanout encountered obstructions starting ~1100’ above top perf o Losses increased at base of G-zone o Substantial increase in losses when got to H-2 zone o Milled for ~36hrs on bottom and made it to PBTD = 11,592’ MD o TCP shot 180’ reperf / 30’ new of G-zone and 1,100’ / 60’ new H-zone - November-2014: ESP yo-yo (no drifts / cleanouts) - March-2014: ESP yo-yo (no drifts / cleanouts) - July-2012 Sidetrack o Ran 7-5/8” tie back (non-cemented) to cover questionable areas of 9-5/8” casing o 7-5/8” x 7” pipe MIT’d to 3000psi (PASS) o TCP shot ~250’ of G-zone and ~1100’ of H-zone perfs o Completed with an ESP ESP Swap RWO Well: M-29A RWO Procedure: 1. MIRU HAK #404. 2. Circulate well to production: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 70bbls d. IA volume ~325bbls 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well 4. Pull BPV/TWC 5. Monitor well to ensure it is static 6. Unseat hanger and packer and POOH with 3-1/2” tubing string and ESP completion 7. PU 3-1/2” workstring 8. MU 7” liner cleanout assembly 9. RIH and mill/cleanout 7” liner to target depth = 11,592’ MD (PBTD) 10. POOH and lay down cleanout BHA 11. PU 7” test packer 12. RIH on work string, and set test packer at ±9,000’ MD (±8,531’ TVD) 13. MIT 7-5/8” x 7” casing to 2200psi (charted) 14. POOH and lay down test packer 15. RU EL and perforate infill G/H zone sands from 9,080’ – 11,544’ MD (8,600’ - 9,650’ TVD) 16. RD EL 17. PU, RIH with ESP completion 18. Land ESP completion 19. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC 20. Turn well over to production. And RDMO HAK #404 21. Conduct No flow Test per AOGCC regulations a. Produce well for ~10 days b. Shut down ESP and leave well lined up to production and monitor until fluid level is stable. c. Notify AOGCC to witness test (48hr notice to AOGCC) d. Bleed well (TBG and IA) to 0 psi e. Rig up test equipment (low pressure gauge, flowmeter, etc.) f. Let well bleed through flow meter until inspector arrives but do not exceed 48 hrs. of total bleed time g. Begin No Flow Test per AOGCC regs / guidance document Shallowest perf allowed is 9180' md due to TOC logged at 9120' MD. -bjm See attached email from R. Rupert. Provide AOGCC 48 hrs notice to witness MIT. -bjm No packer shown on completion diagram. -bjm ESP Swap RWO Well: M-29A Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram (Same) 5. BOP Drawing 6. Fluid/Flow Diagrams 7. RWO Sundry Change Form Revised: JLL 04/04/23 SCHEMATIC McArthur River Field, TBU Well: M-29A PTD: 212-050 API: 50-733-20428-01 Completed:04/19/17 TD = 11,720’ PBTD = 11,592’ RKB to TBG Head = 71.93’ Tree connection: 1 2 HK-5 9-5/8”window @ 8,430 MD 7” HK-7 HK-6 HK-4 G-3 G-4 G-5 HK-1 HK-3 26” 16” 13-3/8” 10-3/4” 9-5/8” 7-5/8” 3 G-2 G-1 HK-2 Casing Detail SIZE WT GRADE CONN ID TOP BTM. 26”267 to 397 Drill Quip Surface 990' 16" 75 K-55 BTC 15.124" Surface 1,441' 13-3/8”61 K-55 BTC 12.415" Surface 2,808’ 68 K-55 BTC 12.415"2,808’3,756' 10-3/4"55.50 L-80 BTC 9.760" Surface 460’ 51 L-80 BTC 9.850" 460’ 484' 9-5/8”47 L-80 AB Mod & BTC 8.681"484'5,727’' 53.5 L-80 BTC 8.535" 5,727’ 8,430’ TOW 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7"26 L-80 BTC 6.276"8,201'11,713' Tubing Detail 3-1/2" 9.2 L-80 IBT-Mod 2.992" Surface 7,979’ Jewelry Detail NO.Depth MD Depth TVD ID OD Item 1 71.93’ 71.93’ Tubing Hanger – Seaboard SC-EN-ESP-CCL 2 7,979’ 7,643’ - 5.130” Bolt on Discharge 7,980’ 7,644’ - 5.380” Tandem Pump Section – 168 stage Summit SJ-10000AR 8,040’ 7,696’ - 5.130” Intake 8,041’ 7,697’ - 5.130” Tandem Seals 8,058’ 7,712’ - 5.620” Tandem Motor – Summit KMS2 1000HP/3600V/165.5A 8,124’ 7,769’ - 5.620” Gauge / Centralizer / Anode 3 8,205’ 7,839’ 6.151” 8.01” Baker Seal Assembly Perforations Zone Interval (MD) Interval (TVD) Ft SPF Status Date G1 9,242' 9,270' 8,732' 8,755' 28' Open 4/15/2017 G2 - G3 9,326' 9,366' 8,799' 8,830' 40' Open 4/15/2017 G3 9,336' 9,372' 8,806' 8,834' 36 5 Open 7/16/2012 G4 9,394' 9,446' 8,851' 8,890' 52' Open 4/15/2017 G4 9,402' 9,452' 8,857' 8,895' 50' 5 Open 7/16/2012 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open 7/16/2012 G5 9,518' 9,605' 8,944' 9,007' 87' Open 4/15/2017 HK1 9,788' 9,828' 9,131' 9,155' 40' Open 4/15/2017 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open 7/16/2012 HK2 9,890' 9,949' 9,188' 9,217’ 59' Open 4/15/2017 HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open 7/16/2012 HK3 – HK4 10,068' 10,630' 9,264' 9,416' 562' Open 4/15/2017 HK4 10,202' 10,380' 9,305' 9,349' 178 5 Open 7/16/2012 10,410' 10,648' 9,356' 9,421' 238 5 Open 7/16/2012 10,690' 10,740' 9,433' 9,447' 50 5 Open 7/16/2012 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open 7/16/2012 HK5 10,765' 11,028' 9,454' 9,521' 263' Open 4/15/2017 HK6 11,174' 11,375' 9,558' 9,607' 201' Open 4/15/2017 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open 7/16/2012 HK7 11,428' 11,544' 9,621' 9,650' 116' Open 4/15/2017 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open 7/16/2012 OPEN HOLE / CEMENT DETAIL 7"8-1/2” Hole: 126bbls 15.3ppg class G cement pumped. 11bbls losses.7/9/12 temperature log suggests ToC at 9250' MD Revised: JLL 04/05/23 PROPOSED McArthur River Field, TBU Well: M-29A PTD: 212-050 API: 50-733-20428-01 Completed:FUTURE TD = 11,720’PBTD =11,592’ RKB to TBG Head = 71.93’ Tree connection: 1 2 HK-5 9-5/8”window @ 8,430 MD 7” HK-7 HK-6 HK-4 G-3 G-4 G-5 HK-1 HK-3 26” 16” 13-3/8” 10-3/4” 9-5/8” 7-5/8” 3 G-2 G-1 HK-2 Casing Detail SIZE WT GRADE CONN ID TOP BTM. 26”267 to 397 Drill Quip Surface 990' 16" 75 K-55 BTC 15.124" Surface 1,441' 13-3/8”61 K-55 BTC 12.415" Surface 2,808’ 68 K-55 BTC 12.415"2,808’3,756' 10-3/4"55.50 L-80 BTC 9.760" Surface 460’ 51 L-80 BTC 9.850" 460’ 484' 9-5/8”47 L-80 AB Mod & BTC 8.681"484'5,727’' 53.5 L-80 BTC 8.535" 5,727’ 8,430’ TOW 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7"26 L-80 BTC 6.276"8,201'11,713' Tubing Detail 3-1/2" 9.2 L-80 IBT-Mod 2.992" Surface ±8,125’ Jewelry Detail NO.Depth MD Depth TVD ID OD Item 1 71.93’ 71.93’ Tubing Hanger – Seaboard SC-EN-ESP-CCL 2 ±8,125’ ±7,770’ - 5.620” Btm ESP Assembly 3 8,205’ 7,839’ 6.151” 8.01” Baker Seal Assembly Perforations Zone Interval (MD) Interval (TVD) Ft SPF Status Date G-H Zones ±9,080’ ±11,544’ ±8,600’ ±9,650’ ±2,464’ Proposed Future G1 9,242' 9,270' 8,732' 8,755' 28' Open 4/15/2017 G2 - G3 9,326' 9,366' 8,799' 8,830' 40' Open 4/15/2017 G3 9,336' 9,372' 8,806' 8,834' 36 5 Open 7/16/2012 G4 9,394' 9,446' 8,851' 8,890' 52' Open 4/15/2017 G4 9,402' 9,452' 8,857' 8,895' 50' 5 Open 7/16/2012 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open 7/16/2012 G5 9,518' 9,605' 8,944' 9,007' 87' Open 4/15/2017 HK1 9,788' 9,828' 9,131' 9,155' 40' Open 4/15/2017 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open 7/16/2012 HK2 9,890' 9,949' 9,188' 9,217’ 59' Open 4/15/2017 HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open 7/16/2012 HK3 – HK4 10,068' 10,630' 9,264' 9,416' 562' Open 4/15/2017 HK4 10,202' 10,380' 9,305' 9,349' 178 5 Open 7/16/2012 10,410' 10,648' 9,356' 9,421' 238 5 Open 7/16/2012 10,690' 10,740' 9,433' 9,447' 50 5 Open 7/16/2012 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open 7/16/2012 HK5 10,765' 11,028' 9,454' 9,521' 263' Open 4/15/2017 HK6 11,174' 11,375' 9,558' 9,607' 201' Open 4/15/2017 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open 7/16/2012 HK7 11,428' 11,544' 9,621' 9,650' 116' Open 4/15/2017 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open 7/16/2012 OPEN HOLE / CEMENT DETAIL 7"8-1/2” Hole: 126bbls 15.3ppg class G cement pumped. 11bbls losses.7/9/12 temperature log suggests ToC at 9250' MD Steelhead Platform M-29A Current X2 Control line Starting head, FMC, 30'’ MSS FE X 26'’ butt weld Adapter spool, FMC-A-5-S 30'’ MSS stdd bottom X 21 ¼ 2M FMC speedlock top, w/2- 2'’ LPO Unihead, FMC Type 2, 16 ¾ 5M FE top X 21 ¼ 2M FMC speedlock bottom, w/ 4- 2 1/16 5M SSO Tubing head, FMC-TC-60, spec for unihead, 16 ¾ 5M FE top X 16 ¾ 5M stdd bottom, w/ 2- 2 1/16 5M SSO Valve, FMC-120, 2 1/16 5M FE, HWO, AA 26'’ 16'’ 13 3/8'’ 9 5/8'’ 7 5/8'’ 3 ½’’ Tubing hanger, Seaboard-SC-ESP-EN, 13 5/8 5M X 3 ½ EUE lift and susp, w/ 3'’ Type H BPV, 2- 3/8 continuous control line ports, BIW Kwik-LokPenetrator, Alloy material Tubing head, Seaboard-S, 16 ¾ 5M X 13 5/8 5M, w/ 2- 2 1/16 5M SSO, BG bottom prep Valve, WKM-M, 2 1/16 5M FE, HWO, DD Adapter, Seaboard-ESP, 13 5/8 5M rotating flange X 3 1/8 5M rotating flange, prepped for 4 11/16 extended neck, 2- 3/8 CCL ports, alloy material Steelhead Platform M-29A 26 X 16 X 13 3/8 X 9 5/8 X 7 5/8 X 3 1/2 Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, DD Valve, Master, WKM-M, 4 1/16 5M FE, HWO, DD Valve, upper master, SSV, 4 1/16 5M FE, w/ 15'’ Safeco operator, EE BHTA, FMC-B-11-A0, 4 1/16 5M FE Spool, 4 1/16 5M X 3 1/8 5M Valve, Wing, FMC-120, 4 1/16 5M FE, HWO, DD BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30'Hydril GK 13 5/8-5000 Spacer spool 13 5/8 5M X 13 5/8 5M Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well M-29A (PTD 212-050)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Rupert To:McLellan, Bryan J (OGC); Juanita Lovett Cc:Guhl, Meredith D (OGC); Roby, David S (OGC); Ryan Rupert Subject:RE: [EXTERNAL] TBU M-29 (PTD 212-050) RWO sundry Date:Wednesday, April 26, 2023 11:35:24 AM Attachments:HILCORP AK M29A USIT 14 JULY 2012 Combined.PDF Yes, our Geologist caught this as well. Upon further digging, looks like a temp log was run on 7/9/12 one day after the 7” liner was cemented. That’s where the 9250’ is called out. Looks like they then ran a USIT on 7/13/12 that got down to 10,091’ MD. From that log (attached) I see ToC at 9120’ MD. Hilcorp proposes to limit our perfs to 9180’ MD and below. From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, April 25, 2023 12:03 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL] TBU M-29 (PTD 212-050) RWO sundry Ryan, In the proposed sundry for this well, Hilcorp has requested to perf as shallow as 9080’ MD, but I see a note on the 10-407 wellbore diagram in our records, there’s a handwritten note stating TOC is at 9250’ MD, based on a temp log. Can Hilcorp demonstrate that these proposed perfs would keep fluids isolated within the pool? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete VOF � �y7,..• THE STATE Alaska Oil and Gas "",N1'�� Of LAsKA Conservation Commission t�_ =' 333 West Seventh Avenue �" %� , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *,. -••� Main: 907.279.1433 of ALASFax: 907.276.7542 www.aogcc.alaska.gov August 30, 2017 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification ��E� �' ���f, Trading Bay Unit M-29A SCA PTD 2120500 Dear Mr. Golis: On June 20, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit well M-29A located on the Steelhead Platform in Cook Inlet. A previous no-flow test attempted on April 28, 2017 was deemed inconclusive by AOGCC.1 The well is operated by Hilcorp Alaska, LLC (Hilcorp). A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10-004—was rigged up to Trading Bay Unit M-29A. The no-flow test consisted of a series of flow and shut in periods. During the flow monitoring periods, no liquid production was observed and gas flow rates were measured initially at approximately 800 standard cubic feet per hour (scf/hr), decreasing to 500 scf/hr within 5 minutes. Tubing and tubing-casing annulus pressures remained at less than 2 psi—casing-casing annulus pressures remained unchanged at 180 psi. The test results meet AOGCC acceptance criteria for a passing no flow test. The subsurface safety valve must be returned to service if Trading Bay Unit M-29A demonstrates an ability to flow unassisted to surface at rates exceeding the no-flow test acceptance criteria. Any cleanout,perforating or other stimulation work in this well will necessitate a new no-flow test. Please retain a copy of this letter on the Steelhead Platform. Sincerely, JaMes B.Regg Petroleum Inspectionsupervisor cc: P. Brooks AOGCC Inspectors 'Letter dated May 19,2017 k • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � DATE: June 20, 2017 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector TBU M-29A Hilcorp Alaska - PTD 2120500 - 6/20/2017: I arrived location and met up with Eric Boudreaux (Hilcorp Lead Operator) and Chris Johnson (Hilcorp Foreman)to discuss the No-Flow job on TBU M-29A. I asked them if the well was at ZERO and if the inner annulus (IA) was connected to the tubing. Chris said "yes" and explained the well was on flare last night, was at ZERO now, and open to a bucket of water which is still bubbling a little. We talked about the 2 options for conducting a No-Flow Test—they were prepared to use the procedure Hilcorp normally follows per 20 AAC 25.265(l)(1)(A). TBU M-29A was rigged up with a pressure gauge and low-rate gas flow meter with standard cubic feet per hour(SCFH) increments. I witnessed the IA attached to the tubing via a 1/2" hose. I verified all the valves where opened and took the initial reading. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 8:20 0.25/0.25/180 0 0 , Initial readings; Shut in 9:20 1/1/180 500 0 Open to flow; 4.5min to bleed to slight bubbling in bucket 9:25 0.08/0.08/180 slight bubble 0 - Shut in . , Open to flow; 500 SCFH at 10:25 1.94-/1.94/180 800 0 • 4min; slight bubbling in bucket at 13min 10:38 0.12/0.12/180 slight bubble- 0 ' Shut in Open to flow; 500 SCFH at 11:38 1.84/1.84/180 790 0 - 3.5min; slight bubbling in - bucket at 12min 11:50 0.12/0.12/180 slight bubble ` 0 ' End Test I Pressures are T/IA/OA SCANNED .JUL 1 7 2017. 2017-0620_No-Flow_TBU_M-29A_bb.docx Page 1 of 4 • • Upon completion, I told the Hilcorp representatives to please leave the well shut-in as I was not comfortable saying the well passed the no-flow test. Chris Johnson (Hilcorp Foreman) stated the well was staying shut-in anyway because it is getting a scale squeeze job. I then told him in my opinion it would need another No-Flow Test conducted after the scale squeeze because there is usually some acid in those pump jobs. Attachments: Photos (3) No-Flow Meter Calibration Report 2017-0620_No-Flow_TBU_M-29A_bb.docx Page 2 of 4 • No-Flow Test— TBU M-29A (Steelhead Platform) Photos by AOGCC Inspector B. Bixby 6/20/2017 s�G y No-Flow Test equipment rig- rR€carr up r14.- 001101 , 0.11 „ Armor no. No-Flow Test meter .. ., r .rte 2017-0620 No-Flow TBU M-29A bb.docx Page 3 of 4 • • CALIBRATED • ' • s 12V;IIM "N. a1 • al • . + � , e N I • [ F1ow Test pressure gauge 2017-0620_No-Flow_TBU M-29A bb.docx Page 4 of 4 , • • i A,(1 N --.4 --._ (\ t .1 „.. .. ... ' 0 0 .air a.. 0 0rili 0 .2 1' 4. ,A .... ..... c irti 0,..s2 0 g to E 0 E 0> a 2 ri c 0 IP X W 701 = arm 4... C V'9... 0 e- 0 °,2 ...- 0 0 0 0 •—. t v) 0 CI? L....L*4 a co • -_,.. ,.. c 8 vs, 0 .5 a) .."1:= ..... .0 .0 .... 0 .0 2 0 0 '0 0 0 0 Z 0 ui a) 0)0 ont C 4" 0 0. c0 as C .6 ....1 I§ *5 /-: > c < e iv , e C via ".t • E zi. 0 0 TV 0 0 '0 C/3 0 0 to- z 0 2 To 0 0 CO ca-a in Z "o o w FIr). ---- L) -, .5 0 = > C r 1 = c4 •-• .0 16, 0 M 75 0 • • \OF 1//7, s9 THE STATE Alaska Oil and Gas �,; -��� , LAsKAL Conservation Commission fifth _� - 333 West Seventh Avenue " t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 rh Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov May 19, 2017 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage,AK 99524-4027 RE: No-Flow Verification SCg" Trading Bay Unit M-29A PTD 2120500 Dear Mr. Golis: On April 28, 2017 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit M-29A located on the Steelhead Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment—as outlined in AOGCC Industry Guidance Bulletin 10- 004 —was rigged up to the tubing for the Trading Bay Unit M-29A no-flow test, and tubing and inner annulus pressures were confirmed to be at zero psi. The inner annulus was added into to the no-flow test equipment since the well is a packerless completion. Prior to starting the test, inner annulus pressure required 30 minutes to bleed off. The test consisted of monitoring pressures and flow rates—cycling between one-hour shut in intervals(pressure build up)and brief flow intervals. There was no liquid flow to surface during any of the flow monitoring intervals. Observed gas flow rates at the end of the flow monitoring intervals—while less than the regulatory threshold of 900 standard cubic feet per hour—increased by 15 percent. AOGCC has determined this test is inconclusive considering the increased gas flow rate,combined with the pressure build-up and time to bleed-off inner annulus pressure that was observed prior to commencement. A recently completed workover increases the possibility that kill-weight fluids may be influencing the results. TBU M-29A may continue to produce without a subsurface safety valve, however, the well must be retested during the next well shut in. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit M-29A demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Steelhead Platform. • • Mr. Stan Golis May 19,2017 Page 2 of 2 Sincerely, __J 6CU g James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. STATE OF ALASKA I ALIJA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing CI Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well❑ Other:Replace ESP CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 212-050 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20428-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit M-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,720 feet Plugs measured N/A f tC E I I E D true vertical 9,696 feet Junk measured N/A fd 1 Effective Depth measured 11,592 feet Packer measured N/A feet MAY 1 5 2017 true vertical 9,663 feet true vertical N/A feet AOGCC ' Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 990' 3,010 psi 1,440 psi Conductor 1,411' 16" 1,441' 1,441' 2,630 psi 1,010 psi Surface 3,756' 13-3/8" 3,756' 3,754' 3,090 psi 1,540 psi Production 8,430' 10-3/4"&9-5/8" 8,430' 8,034' 5,860 psi 3,220 psi Tie-Back 8,205' 7-5/8" 8,205' 7,839' 6,890 psi 4,790 psi Liner 3,512' 7" 11,713' 9,694' 7,240 psi 5,410 psi Perforation depth Measured depth 9,242-11,536 feet True Vertical depth 8,732-9,648 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 7,979'(MD) 7,643'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): A®d p N/A sc ANiNEU M A. S+ a L.,-, LU Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 48 0.944 1680 66 219 Subsequent to operation: 287 240 7541 76 84 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 DevelopmentE Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ❑ 3USP❑ 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: 317-034 / Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations_ Manager Contact Email: dmarlowe@hilcorp.com (5' +. Authorized Signature: + 3 4 Date: 5115 I Z°1 ? Contact Phone: (907)283-1329 :i° RBDMS b'MAY 1 7 2017 Form 10-404 Revised 4/201716 Submit Original Only • • McArthur River Field, TBU 11. SCHEMATIC Well: M-29A [Mean,Alaska.LLC PTD: 212-050 API: 50-733-20428-01 Completed: 04/19/17 RKB to TBG Head=71.93' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. i 103/4"L 1 ! J I 26" 267 to 397 Drill Quip Surface 990' 26"jj ;r 16" 75 K-55 BTC 15.124" Surface 1,441' 16" 61 K-55 BTC 12.415" Surface 2,808' 13-3/8" 13-3/8" 68 K-55 BTC 12.415" 2,808' 3,756' 55.50 L-80 BTC 9.760" Surface 460' 10-3/4" 51 L-80 BTC 9.850" 460' 484' 47 L-80 AB Mod&BTC 8.681" 484' 5,727" 9-5/8" I 53.5 L-80 BTC 8.535" 5,727' 8,430'TOW 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Tubing Detail 3-1/2" 9.2 L-80 IBT-Mod 2.992" Surface 7,979' in 7-5/6"�► 2 Jewelry Detail NO. DNpDth Depth ID OD Item 9-5/8" ®1 3 Ill.11 1 71.93' 71.93' Tubing Hanger-Seaboard SC-EN-ESP-CCL alla 7,979' 7,643' - 5.130" Bolt on Discharge 7,980' 7,644' - 5.380" Tandem Pump Section-168 stage Summit SJ-10000AR 2 8,040' 7,696' - 5.130" Intake 8,041' 7,697' - 5.130" Tandem Seals =G-1 8,058' 7,712' - 5.620" Tandem Motor-Summit KMS2 1000HP/3600V/165.5A =G-2 8,124' 7,769' - 5.620" Gauge/Centralizer/Anode G-3 3 8,205' 7,839' 6.151" 8.01" Baker Seal Assembly G-4 Perforations G-5 Zone Interval(MD) Interval(TVD) Ft SPF Status Date G1 9,242' 9,270' 8,732' 8,755' 28' Open 4/15/2017 ---HK-1 G2-G3 9,326' 9,366' 8,799' 8,830' 40' Open 4/15/2017 HK-2 G3 9,336' 9,372' 8,806' 8,834' 36 5 Open 7/16/2012 =HK-3 G4 9,394' 9,446' 8,851' 8,890' 52' Open 4/15/2017 G4 9,402' 9,452' 8,857' 8,895' 50' 5 Open 7/16/2012 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open 7/16/2012 HK 4 G5 9,518' 9,605' 8,944' 9,007' 87' Open 4/15/2017 7 HK1 9,788' 9,828' 9,131' 9,155' 40' Open 4/15/2017 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open 7/16/2012 -HK-5 HK2 9,890' 9,949' 9,188' 9,217' 59' Open 4/15/2017 HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open 7/16/2012 HK3-HK4 10,068' 10,630' 9,264' 9,416' 562' Open 4/15/2017 10,202' 10,380' 9,305' 9,349' 178 5 Open 7/16/2012 =HK-6 HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open 7/16/2012 10,690' 10,740' 9,433' 9,447' 50 5 Open 7/16/2012 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open 7/16/2012 HK5 10,765' 11,028' 9,454' 9,521' 263' Open 4/15/2017 -HK-7 HK6 11,174' 11,375' 9,558' 9,607' 201' Open 4/15/2017 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open 7/16/2012 ...i» A.- HK7 11,428' 11,544' 9,621' 9,650' 116' Open 4/15/2017 TD=11,720' PBTD=11,592' HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open 7/16/2012 Revised:JLL 05/10/2017 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operations: 04/04/17-Tuesday (Holes were punched on Steelhead activation & circulated well 4-4-2017) R/u e-line, P/T t/250/2500 good. Rih w/1.56" 12 shot, tubing punch, w/green nodes&zero phasing.Tag & p/u 10' down on first single, fired punch,good indication at surface guns fired. POOH shots fired, R/d e-line, circulated well to production @ 6 bpm, 13 got returns @ 160 bbls w/oil & gas. Pumped total 600 bbls clean. Shut down, both sides went on vac, waited one hour. Pumped on well, caught pressure at 10 bbls pumped, returns after 20 bbls with gas &clear water returns. Cont pumping for total 100 bbls, shut down. Well went on vac. Installed BPV, n/d tree, n/u two piece riser. Lay over skate, prep t/ p/u single gate and had operational issue w/DS bridge crane, troubleshoot issue. 04/05/17-Wednesday Trouble shoot& repair bridge crane. Replace/adjust grating in lower BOP deck. Nipple up lower rams. Make up manual & HCR valves on mud cross. Fill Koomey unit with oil. Nipple up mud cross. Install Kill & Choke lines to mud cross. Nipple up double gate rams &annular. Purge lines &top off Koomey. Install lights at derrick board. Continue with camera/monitor install.Torque flanges on BOPE, install air boot flange to top of annular, welder work on flow nipple modification, housekeeping in cellar mez. organize drill deck. Installed BOPE lifting beam. 04/06/17 -Thursday Nipple up BOP's. Install 22" airboot flange, install Koomey lines, install flow nipple. Continue C/O of#2 charge pump. Continue camera installation. Organize rig floor& BOP deck. Continue N/U of BOP's; finish install of Koomey lines. R/U hoses to rig floor drip pans. R/U purge to camera system. C/O drawworks encoder for Canrig/HES.Troubleshoot air boost system for rig. Install piping for MWD Geospan. Continue C/O of# 1 & 2 charge pumps. Charge Koomey system &function test from unit& rig floor. Mobilze & R/U BOP test equipment. Continue C/O of#1 charge pump & return #2 to service. Make up 3-way Cam-lok manifold for vac system. Install flow paddle in flow line. HES MWD begin R/U of equipment. Finish r/u of test pump, unlock &function test#2 charge pump, moved cabinet to cellar, lift pipe skate ramp to rig &secure. Pre- test BOPE. Line up &fill BOPE eq. w/water, close upper rams &test all choke manifold & kill line valves 250 low/2500 high. Had leak on super choke, flushed &worked re-tested good. • • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operatrori$ . {- x i t t r : ; S t `' 04/07/17- Friday Continue commissioning BOP test 250/2500 psi for 5 min each charted. Lower IBOP fail &annular cap seal failure. Blow down & rig down test equipment & lines. Nipple down flow nipple & air boot flanges to repair annular cap seal. Continue rr nipple down of flow nipple &air boot flanges. Dress flow nipple for re-installation. Install annular cap removal tool & pull cap. Remove upper seal, inspecting seal &seal face. Install annular cap with new seal. Energize accumulator&function annular many times to check seal. Install air boot flanges &flow nipple. Lay down 4" test joint break down XO's. Make up 3 1/2" test joint& install into blanking sub. Fill all lines to test. Plumb in tee at vac line for well bay access. Test annular w/3 1/2" test joint to 250/2500 psi for 5 minutes, charted. Secure test joint in derrick. Send welder to derrick to plan camera mount in derrick. Remove saver sub &failed lower IBOP from top drive. Continue removal of lower IBOP, r/u &test replacement valve t/3500, good. Install lower IBOP &saver sub, re-assemble TD tq wrench w/bell guide. M/u test sub t/top drive. Install 3 1/2" tj, r/u test manifold. Installed derrick camera bracket. Wellhead pressures: 31"X26"=140 psi, 26"X16"=90 psi, 16"X13 3/8"=170 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi. 04/08/17-Saturday Fluid pack lines& shell test with 3 1/2" test joint. Function test BOP's from all remote stations. Perform abandon platform J� drill &debrief.Test deluge system on rig. Fluid pack all line for BOP test with AOGCC Rep. Housekeeping around the rig. Attempt to install cameral in the derrick. Perform Rig inspection w/AOGCC Rep Guy Cook,Test BOP's to 250/2500 psi for 5 minutes, with 3 1/2" &4" test joints.Test pits level alarms,flow show, and gas detection system. Fail/pass at shaker sensor due to no audio. Fail/pass at upper well bay room sensor, due to high level set at 60 ppm, fail in wellhead room visual, ok to proceed with well work, repair must be complete within one day. Lay down test tool & remove blanking plug. Break down 4" test joint & equipment. Blow down all lines. Finish clearing floor of test tools, pull BPV. M/U landing jt. fill pit 4 & 6. R/u 3 1/2" handling eq. Circulate well t/production @ 6 bpm, caught pressure @ 74bbls, returns @130bbls, pumped 280 bbls clean, FCP 1070psi. Shut down well went on vac after 3 min. Cont. r/u pulling eq, held PJSM with all hands, walked through bare pipe shut in procedure & hands practice cutting cable. Pull hanger free @ 75k, pull, cont. pull hanger t/floor w/100k net string weight. Fill hole get loss rate of 16 BPH, break off& l/d hanger, stand back landing jt. Pull stand &start cable in pollution hose. Wellhead pressures: 31"X26"=140 psi, 26"X16"=90 psi, 16"X13 3/8"=170 psi, 13 3/8"X9 5/8"=250 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi. • • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operations: 04/09/17-Sunday POOH racking back stands of 3 1/2" tubing, spooling ESP on reel to 6083' MD, PU 140K, loss rate 16-18 bph. Service & inspect drawworks. Review bare pipe shut in procedure with floor crew. Loss rate 4.8 bph.TOH racking back stands of 3 1/2" tubing spooling ESP on reel f/6083'-3859' MD, PU 110K, SO 105K, loss rate 5 bph. Change out spool with ESP for empty. Loss rate 5 bph.TOH racking back stands of 3 1/2" tubing spooling ESP on reel f/3859'-234' MD, PU 65K, SO 65K. racked back 252 jts in derrick. L/d 1 perfed jt& 1 single. C/O handling tools, lay out tubing tongs, p/u pump handling eq. cut & l/d cable & sheaves. L/D ESP assembly checking components, unable to turn pumps at surface, seals rotated freely, motor checked good but dirty oil. OOH full recovery of pump, 167 cannon clamps, 2 splice clamps, 20 pump & seal clamps, 10 motor clamps. Clean &clear floor. Wellhead pressures: 31"X26"=140 psi, 26"X16"=90 psi, 16"X13 3/8"=175 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=210 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 193 bbls. 04/10/17- Monday Install derrick camera in derrick& run coaxial cable. SIMOPS install wear ring 9" ID, mobilize BHA 1. Make up BHA 1 with 6" Mill Tooth Smith & bit sub with non ported float, 6-4.75" DC, xo, hyd.jars, =217.74. Service drawworks & Iron Roughneck, forklift certification, static loss rate 2 bph. Continue picking up BHA 1 with 6 -4.75" spiral DC,XO 3-1/2" IF X 4" HT38, 4.75" hyd Jars=217.74. Single in the hole with 4" DP f/217'-2580' MD, PU 95K, SO 92K. Break circulation to fill pipe @ 2580' MD, 134 gpm, 100 psi, 32 bbls to fill. Blow down TD. Monitor well, static loss rate 2 bph. Single in the hole with 4" DP f/2580'- 2894' MD, PU 102K, SO 100K. Repair hydraulic leak on ST-80 Roughneck. Static loss rate 1.6 bph. Cont. P/U 4" DP f/2894't/4280', up wt 120k, dn wt 118k, 1.5 BPH loss rate. Cont. P/U 4" DP t/4921' Up wt 135k, dn 126k. Fill pipe cbu @ 6 bpm,430 PSI, max gas 339units. Cont. P/U 4" DP t/6310', up wt-150k, dn wt-145k. Wellhead pressures: 31"X26"=140 psi, 26"X16"=90 psi, 16"X13 3/8"=170 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi. Total losses for 24 hrs 45 bbls. 04/11/17-Tuesday Cont Picking up 4" DP F/6310', t/7566'.Tih w/stands f/derrick t/8131', tag. Wash down t/8167', @6bpm, 610psi, unable t/wash. Wash & ream t/8569'up wt, 180k, dn wt 160k, rot wt 170k, on off tq. 5k, circ. 10.4 bpm, 1900 psi, periodically checking if able to wash with no rot. no go. Circulate & condition while Elect.troubleshoot& c/o TD/RT rheostat. Circulate &condition. Service rig, c/o 22" airboot on flow nipple, monitor static fluid loss, 2.bph. Cont. wash & ream f/8567',t/8883' up wt 194k, dn wt 165k, rot wt 173k, 65 rpm, tq 5k, circ 11 bpm, 1900psi. Cont. wash & ream f/8883', t/9500' up wt 198k, dn wt 170k, rot wt 185k, 65 rpm, tq 5k, circ 10bpm, 1900psi. Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=180 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 50 bbls. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operations: 04/12/2017-Wednesday Contewash & reamf9500', t/9555',change in rop, bit wt & 5%drop in return flow, p/u monitor well, loss rate increased t/49BPH, check static @ 33 BPH, attempt slack off dry, no go, attempt wash no rot, no go, cont. wash & ream t/9900' rot 65 rpm, tq 6k, circ. 10 bpm, 1900 psi, 2-4k wob, @ 9900' return flow dropped t/50%, P/U t/9850' max gas 380 units Circulate hole clean, 10 BPM 1900 psi, 60 BPH circulating loss rate, circ 1BPM, w/loss rate @ 36BPH, max gas 380 units Cont. wash & ream f/9900',t/10818', up wt 210k, dn wt 177k, rot wt 186k, 85 rpm tq.7k, circ @ 10.3 bpm, 2060psi, 60-65% return flow, periodically attempt to wash no rot, no go, max gas 503 units @ 10109' Change in bit wt,wash w/no rot f/10818't/11598', up wt 217k, dn wt 170k, rot 194k tq 7.5, circ. 10 bpm, 2240psi, rot t/11604'finding PBTD CBU clean @ 10 bpm, 2200 psi, 25 BPH loss rate pumping, 14.4 BPH static, line up to take returns to production, pump pits down, change over t/clean FIW @ 6BPM, POOH t/11525' stand back, monitor static loss rate =0, adjust brakes, POOH standing back total of 17 stands of 4"DP, while building size salt pill Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=190 psi, 13 3/8"X9 5/8"=250 psi, 9 5/8"X7 5/8"=225 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 656bb1s. 04/13/2017-Thursday Laying Down 4" D.P. F/10,103 To 9,354 (749', 250'/hr) Spot 96Bbl Sized Salt Pill Through Bit at 9,354 Calculated Coverage (Pipe Out) 2,304' from 9354 to 7,050 Cont POH Laying Down 4" D.P. 9,354 to 8,410, PU 185, SO 165 Loss Rate 2.5Bbl/hr (944', 377'/hr) Cont POH Laying Down 4" D.P. 8410 to 5,200' (3210', 535'/hr) 3Bbl/hr Loss Rate Cont Laying Down 4" D.P. From 5,200 to 2,202 at 24:00hrs (2,998'499'/hr) Loss Rate 3Bbl/hr Lay Down 4" D.P. F/2,202 - Lay Down BHA- Relocate Centrafuge Feed Pump Pull Wear Rign - Make Up Test Plug and 3 1/2"Test Joint- Rig Surface Lines For BOP Test Wellhead pressures: 31"X26"=135 psi, 26"X16"=95 psi, 16"X13 3/8"=180 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi. Total losses for 24 hrs 54bbls. • �! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operations: 04/14/2017 Friday Cont Making up 3 1/2"Test Joint - Land Test Plug -Grease Choke Manifold and Mud Cross Vlaves- Rig Fill up Line to Trip Tank For Filling Well Below The Test Plug- Fill Stack and Choke Manifols- Flush Air From System -Shell Test to 2,500psi to Seat Plug (Looked Good) Line Up For Pressure Test#1-Annular Preventer, Upper IBOP, Choke Manifold Valves 1,2,3,12&14, 3 1/2" IBT Dart Valve - Had Slow Bleed Off On Low Pressure (300psi Test) -Work To Isolate Leak- Elemanation Upper IBOP,And Choke Manifold Valves One at a time , Had A Good Visual on Annular&Connection On Test Joint- Watching For Any Returns Below Test Plug-Well Was Taking Fluid so Somewhat Hard to Tell if Leaking-Open Annuluar Preventer and Close Top 2 7/8 by 5 Pipe Rams-Attempt 300psi Test-Still Had Slow Bleed Off- Fill Well And Left Ann Below Plug Open To Trip Tank- Pull Test Plug- Missing Both Rubbers when we Got Test Plug Out- Redress With New Seals- Drain Stack- Re-Flush Wellhead Area - Re-Land Test Plug Fill Stack- Re-Rig Surface Lines and Line Up For A Repete Of Pressure Test#1 -Shell Test Agianst Annular To 2,500psi To Seat Plug- Looked Good - Bleed Off And Line Up For 250psi Low Pressure Test#1 Had a Good Test - High Pressure Test to 2,500psi Had a Good Test Cont Pressure Testing BOP Equipment to Hilcorp And AOGC Standards 250psi Low-2,500psi High, Witness Waived By AOGCC Mr. Michael Quick @ 3:11 pm on 4- 11-17 Rig Down Test Equipment, install wear bushing, C/O handling eq. p/u tubing tongs, m/U safety jt, monitor well 2.5 BPH loss rate PJSM, p/u Trl-Point 4 1/2" 5-SPF, SDP,TCP Assembly-52 Guns Of 110 Total Picked Up at 6:O0hrs Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=185 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 57bbls. 04/15/2017-Saturday Picking Up Tripoint,41/2" 5SPF SDP TCP Guns 2,302' Overall Length 1,448 Loaded Make Up Firing Head, 2 7/8" , 2 _Cont7/8" Pup Joints, XO Change Elavators Run 1 Stnd 3 1/2" Drifted Tubing- Make Up R.A.Tag With Cross Overs-Gun Assembly Weight 37K Cont RIH with 3 1/2" Btc Tubing to a Mule Shoe Depth Of 3,188- Drifting Tubing On The Way In - PU 100K SO 95K Cont RIH with 3 1/2" Btc Tubing to a Mule Shoe Depth Of 10,192 - Drifting Tubing On The Way In PU 160K SO 140K- Rig Down Tubing Tongs- Rig to Run 4" D.P. -Cont RIH on 4" D.P. to A Mule Shoe Depth Of 11553' R/U e-line, troubleshoot platform t/e-line unit power supply. p/u 1 11/16" ccl/gr tools RIH w/1 11/16" CCL/GR tools t/9160' & log, send correlation log t/Geologist Cory Ramstad for confirmation, loss rate 1.6 BPH Pull string into position placing RA marker on depth,verify numbers of 9096.21' w/Tri-Point rep Drop 1.25" firing bar, had good indication at surface guns fired @ 02:15, ck tubing on vac, fill hole 35bbls, CBU x2 @ 10 bpm, 1660 psi, loss rate while pumping 60 BPH, Shot intervals w/4 1/2" TCP guns, SDP, 5 SPF, 60 deg. phasing,f/9242'-t9270', 9326'-9366', 9394'-9446', 9518'-9605', 9788'-9828', 9890'- 9949', 10068',-10630', 10765'-1128', 11174'-11375', 11428'-11544' Line up on TI monitor static losses 29 BPH, while r/u to I/d DP, POOH f/11533', t/10670' 1/d 4" DP Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=185 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=220 psi, 7 5/8"X3 1/2"=25 psi.Total losses for 24 hrs 80bbls. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date M-29A Steelhead Rig 51 50-733-20428-01 212-050 4/4/17 4/19/17 Daily Operations: . L.. . . :. .. .. . . . . :. .. .: 04/16/2017-Sunday Cont. POOH 1/d 4" DP f/10670't/10192', L/d 2 stands 4" Dp C/o handling tools t/3 1/2" POOH standing back 3 1/2" tubing, stood back 83 stands=7741', L/d one single & 2 bad jts M/U Safety jt, simulate well control drill, c/o handling eq POOH 1/d 4 1/2"TCP gun assembly, all shots fired Break down safety jt, clean & clear floor, pull wear bushing Arrange deck, & spot ESP running eq. stock floor w/tools, R/u handling tools P/U Summit 562, 500 HP motor w/Gauge & bullnose anode, start servicing same Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=190 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=215 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 553bb1s. 04/17/2017 - Monday Cont. P/u & service Summit ESP Assy. =Anode, Phoenix XT 150, 2 ea- 562 series KMPLT 500 HP motors, 2 ea- 513 series BPBSL Seals, gas separator intake, 2 ea- 62 stage SJ10000 pumps, 1 ea-44 stage SJ10000 pump, bolt on discharge head, ported pressure sub, xo t/3 1/2" IBT= 147.55', Make up Chem injection lines, make up MLE t/motor, install total of 1 splice clamp, 11 flat cannon clamps, 6-3" wide cannon clamps,4 dual flat clamps, &4 SS super bands,Test MLE good, Stock cannon clamps on floor, service rig while crane unloaded boat, walk through a bare pipe shut in drill w/ hands, rih f/derrick w/3 1/2" L-80 9.2# IBT tubing @>60 FPM, minimal upward movement off slips, & no pickups, install cannon clamp on every collar, test cable every 1000', t/2965', do wt 102k, m/u tq 3k Crew change, PJSM, walk through bare pipe shut in & running parameters, Cont. rih f/2965' t/5114', checking cable every 1000' good Change out cable spool & make splice, monitor well, 17 .5 BPH loss rate, service rig &wk on punch list while splicing Wellhead pressures: 31"X26"=140 psi, 26"X16"=95 psi, 16"X13 3/8"=190 psi, 13 3/8"X9 5/8"=240 psi, 9 5/8"X7 5/8"=215 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 513bbls. 04/18/2017-Tuesday Continue ESP splice &working on rig punch list. Splice attached to joint# 164, 5220' MD, SO 125K.TIH w/3.5", 9.2#, L-80 IBT tubing, f/5220'-7639' MD, 60 fpm,Tq to 3K, Cannon clamp every collar,test ESP continuity every 1000', SO 140K.TIH w/3.5", 9.2#, L-80 IBT tubing,f/7639'-8014' MD, 60 fpm,Tq to 3K, Cannon clamp every collar, test ESP continuity every 1000', SO 140K. Pick up hanger, install penetrator, cable to cable splice, &tie into penetrator on hanger. Land hanger @ 18:00 hrs, SO 143K.Total clamp count: 253 cross collar clamps, 9 pump clamps, 4 seal clamps, 11 motor clamps, 1 round to flat clamp, & 1 round to round clamp. Meg ESP Check PHOENIX, RILDS, & lay down landing joints. ESP ANODE 8123, Gas Seperator Intake 8040, Discharge Pressure Sub 7,978 ( Dual 500 H.P. Motor, 3 Stage Pump Section (2 at 62 Stage, 1 at 44 Stage) Rig down ESP &control lines from sheaves, clear& clean rig floor of Summit&Weatherford tools/equipment. ND BOP's: L/D flow riser, remove Koomey/ kill/choke lines. SIMOP lay over skate extention ramp & install south skid cylinder /gripper. Nipple down BOP's & rack back on stump. Pull risers & lay down on deck. SIMOP work on splitting master bushings. Nipple up tree.Test tree void & connections. Rig release at 06:00 hrs on 4-19-17. Wellhead pressures: 31"X26"=135 psi, 26"X16"=95 psi, 16"X13 3/8"=185 psi, 13 3/8"X9 5/8"=245 psi, 9 5/8"X7 5/8"=210 psi, 7 5/8"X3 1/2"=0 psi.Total losses for 24 hrs 394 bbls. • • N V \ / / IE & EEEIEII & EEEI EEEEE / V/ Co CI uj ( k » e n a E o § E 7 = > 0 / co \ 2 / \ m ± o 5 0 2 43 E U O \ \ 7 5 $ 2 v f \ \ E 0 f 0 -® » \ / /\ / § 2 , \ / W 0 / \ [ ECL -1 2 > I — E E _ _ E = a± 0 2 / / * n./ a) / fGf / � � m ƒ 2 § I �s2 \ 2 '\ 5 \ ® \ \ / k % •@ m \ 2 \ 2 c 7 0 2 = F 3 2 7 « y $ ,- e 17 \ E > @ n CO ...9 Oƒ / / / < 2 0 / ƒ \ E z / > ƒ / / m EZ 0 •. \ / — S \ �� E co o 2 ° 0 I o as S qkms / / \ IEIEIEEEI E EEEIEEEEIE / 0 E n m 6 2 � / / � 7 CO / k 2 G % @ 2 2, < L Lu 2 \ \ 2s a) o o .g n ƒ > f f 2 = 2 n \ $ E_ \ � « » e = 7 2 8 3 2 — 2 = k ca 03 $ \ I / m co cu 17) ( m §Ce ƒ O § Q Cl) / ƒ0 0 2 \ / # 4,74- _ \ \ 2 / \ g q \ \ g a \ p 7 U / 5 m e o 2 m = \ a m@ / ' 5 > o » _ ? w i < � o ± \ ^ ° o ® 0 a 3 0 > * / ƒ 7 0 0 \ ƒ / o F ¢ b \ / f) 0 o a / / £ a E2 / k / \ \ / 0 o O_ 5 & 5 s \ n = \ 9 m K ° % / \ $ % $ O zz G o@ = ZS co / \ \ / \ m § / $ 2 .1) m = m ^ - 7 .2 o 0 U) ® o = o e n n = 0 s 3 0 = n >5 O O » O E £ E ± 2 0 0 0 & 0 R & O 0 12 f CO < / 0 . g © $ / ELILEEIIE & EIEEII CL. EEE < K k 0 o Ce 7 \ @ % 0 U % 2 u o o 0C E \ S 2 m < < uj \ 0/ 0 m I \ E o \ o • 2 O I % co e 0 3 w = em_ S / / ° cC E ± ± w 2 = = 2 a = m ) C m ƒ 0 0 % 2 E o m E 2 0 / w ® .7\ uj R m 0 g ± » > o = - > o u 2 � O \ 0 E Cl- / E E 0 \ ./ \ ƒ \ / \\ \ /\ cc Lu _ o 3 c F CO C / C > \ \ CS)Z % 0 0 « 0 7.7 \ % k 0 0 = o \ \8 / o / @ e = _ * # QI-LI $ _ Tu— - 0 » 3 0 % 0 4 < E a \ 2 O 7 / I / ƒ O / / \ 4 $ % i • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: 4/28/ 62017 ttip P. I. Supervisor ��� �1� NED JUL 0 FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector TBU M-29A Hilcorp Alaska LLC PTD 2120500 4/28/17: I arrived on the Steelhead Platform at 8:30 am. I got together with Heath Hindman and discussed the job and looked over the set-up. Both the tubing and the IA had been bled to zero and were open to the bleed upon my arrival. It was decided to bring the gauge from the tree cap to the ground level and to shut in the IA to the bleed at this point. The changes were made to the set-up and at that time Mr. Hindman explained to me about the IA and its role in the operation of this well. Since it is possible to flow out the IA on this well it was decided to perform a no-flow on both the tubing and the IA and the IA was opened again to the bleed. While I was discussing the job further with Mr. Hindman, the IA was opened and started to bleed. It took approximately 30 minutes for the IA pressure to bleed to zero psi. Once the IA was at zero psi the testing began. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:40 AM 0/0/230 The Tubing and IA were S/I 11:40 01/01/230 650 0 Initial SCFH at 650. The well bled to 0 psi in 12 minutes. 11:55 0/0/230 The Tubing and IA were S/I 12:55 01/01/230 750 0 Initial SCFH at 750. The well bled to 0 psi in 12 minutes. 13:10 0/0/230 The Tubing and IA were S/I 14:10 01/01/230 750 0 Initial SCFH at 750. The well bled to 0 psi in 12 minutes. 1 Pressures are T/IA/OA Summary: The well was tested for flow after each of three one-hour shut in periods. The SCFH increased from 650 SCFH after the first one hour shut-in period to 750 SCFH for the last two shut-in periods. The well bled down in 12 minutes to zero psi 2017-0428 No-Flow_TBUM-29A_gc.docx Page 1 of 2 • • after each one hour shut-in period. The well did not produce any liquids during the testing period. While the well never reached the 900 SCFH limit allowed for a passing no-flow test, it did increase in flow from the first shut-in period. And taking into consideration that the IA was bled to zero and was shut in for one hour before the testing began to make changes to the rig-up of the equipment, and it took 30 minutes for the IA to bleed to zero psi after being re-opened to bleed, I believe the well should be retested. With the possibility of kill weight fluid still being present in the well, since the rig had just been on it, I believe once the well is flowed for a short time another test should be conducted to give more conclusive results. Attachments: Current Well Schematic Test Equipment Calibrations 2017-0428_No-Flow_TBU_M-29A_gc.docx Page 2 of 2 . ie-, 0 • McArthur River Field,TBU . a, SCHEMATIC Well: M-29A As Completed: 03/18/14 RKB to TBO Head 71.55' Casing Detail Tree connection: $128 WT GRADE CONN ID TOP BTM. 26"atili 10-314t 1 J L 26" 267 to 397 Drill Quip BIC Surface 990' 16" 75 K-55 15.1.24" Surface 1,441' 16" 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' 10-3/4" 51&55.5 1-80 BTC 9.760" Surface 484' 13-3/8' 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM 511141 6.875" Surface 8,205' * 7" 26 1-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.54,N-80 8,430' 8,467' Tubing Detail 34/2" 9.2 1-80 IRT 2.992" Surface 8,012' 2 _ 4 ' f',,, NO. Depth ,:,' ID Item 7-618"----IP 7 1 71.55' Tbg Hngr 6 1:, 2 8,012' 5.13 Discharge Bolt On 1.1 8 3 8,013' 5.13 Pump:STG,SG 7300(x3) 9-6/8" 4 8,067' 5.13 Intake 5 8,087 5.65 Motor:562 Series/340 HP(x2) 6 8,155' 5.85 Anode 7 8201' Top Packer w/RS Profile Flex , Lock liner Hangar 8 8,205' Baker Seal Assembly _I_G-3 -----.:...-G-4 =.-----G-5 Perforations Zone Interval(MD) interval(TVD) Ft SPF Status -=- HK-1 63 9,336' 9,372' 8,806' 8,834' 36 5 Open 64 9,402' 9,452' 8,857' 8,895' 50 S Open -7H K-3 65 9,514' 9,616 8,941' 9,015' 102 5 Open HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open .--.=- HK-4 10,202' 10,380' 9,305' 9,349' 178 5 Open = HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open --,==HK-5 10,690' 10,740' 9,433' 9,447' 50 5 Open HKS 10,754' 10,964' 9,451' 9,505' 210 5 Open HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open --z._-..- HK-6 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open HK-7 7" TD=11,720' PBTD=11.592' Revised:04/17/14 by il..1. 6 xt-z Ak- i-res-- • lig , ly Gauge Calibration Certificate Brand & Model: A c4,4/( 0 i/firm 0L/p 2.3 Rated Presure: l°°P5( date: 2,7,47 As Found As Left Notes 0% ©,S/ S aAp 25% 25 ; ) . 50% �] ‘2,s; 75% 79; ,' 9%5;z00% Name: 6 d, 60t.‘474 Signature: TBut A-zet A_ hjo- -F(a.)-R'sd-- • • 41v8i(7 - •••4 to ').-, &c c--- r----- , M ) WO .) 0) 1 '''i 74: -.2. = 0 4) PO ,.4'74Z .—..t.---` ',,,. ........ . , < 0 0 m § , , r) - CD °I; CD co Eli Tit 5 0 0 ...I ....1. ..., ... a, o il 1,- a c 21 g .11 5 5-• 9 z5. (2'k CO tt) V ..... :c...' 0. .4 g vd. CD CD —, 8- 5) I • . ' 40.1*-o1 j/',,s. THE STATE Alaska Oil and Gas tib ,,,,a,, of Conservation Commission St � : �+ 333 West Seventh Avenue 11:* , GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 4' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis SCANNED MAR C..' , Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools, TBU M-29A Permit to Drill Number: 212-050 Sundry Number: 317-034 Dear Mr. Golis: 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, '107,• Daniel T. Seamount, Jr. Commissioner DATED this 3f day of January,2017. RBDVIS VAS : - 3 2017 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 3 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGGC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate 0 . Other Stimulate❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. Replace ESP . 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development El ' 212-050 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20428-01 , 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 228A J Will planned perforations require a spacing exception? Yes ❑ No 0 A Trading Bay Unit M-29A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018730 McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,720 9,696 11,592 9,663 2,217 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 990' 3,010 psi 1,440 psi Conductor 1,411' 16" 1,441' 1,441' 2,630 psi 1,010 psi Surface 3,756' 13-3/8" 3,756' 3,754' 3,090 psi 1,540 psi Production 8,430' 10-3/4"&9-5/8" 8,430' 8,034' 5,860 psi 3,220 psi Tie-Back 8,205' 7-5/8" 8,205' 7,839' 6,890 psi 4,790 psi Liner 3,512' 7" 11,713' 9,694' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,336-11,536 . 8,806-9,648 3-1/2" 9.2#/L-80 7,970 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigrapt❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/1/2017 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmariowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature _ L.. ZIPhone (907)777-8356 Date I /23 /ZO I 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. .-7- C)Z1 Plug Integrity ❑ BOP Test Mechanical Integrity Test 0 Location Clearance ❑ ( S Other: V SOC) i.- 6 0 P .—�-_ "�'��� I 1't c. cr l 4lU 6 -t l a.4.., j s 4- re&-1 e.�,v ) Post Initial Injection MIT Req'd? Yes ❑ No ❑ R�®� .�� L, F - 3 2017 Spacing Exception Required? Yes ❑ No Ild Subsequent Form Required:/0- 4.1 di 241P APPROVED BY / Approved by:1 COMMISSIONER THE COMMISSION Date: (3° /17 Form 10-403 Revised 11/2015 0 1.144CG p777 I v lid r 12 months from a date of approve1. Submit Form and Attachments in Duplicate • 11 Well Work Prognosis Well: M-29A Hilcorp Alaska,LLC Date: 01/23/2017 Well Name: M-29A API Number: 50-733-20428-01 Current Status: ESP Producer Leg: B-1 (NW Corner) Estimated Start Date: March 01, 2017 Rig: Moncla 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 212-050 First Call Engineer: Dan Marlowe (907)283-1329 (0) (907) 398-9904(M) Second Call Engineer: Stan Golis (907)777-8356(0) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: 3,098 psi @ 8,806'TVD 0.352 lbs/ft(6.77 ppg)based on ESP Gauge Maximum Expected BHP: 098-psi- `8,806'TVD 0.352 lbs/ft(6.77 ppg)based on ESP Gauge Maximum Potential Surface Pressure: 2,217 p ' Using 0.1 psi/ft gradient per 20AAC25.280(b)(4) **Note this is a No-Flow Well(08/03/2012) Brief Well Summary M-29A is a Hemlock Producer completed with an ESP November 2014. Due to steady decline in production,we plan to pull the current ESP, cleanout and reperforate the well,and install a new ESP. Last Casing Test: 07/12/12 3,000 psi for 30 minutes on chart Procedure: 1. MIRU Rig Moncla 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+1-7,960'and punch tubing.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. RIH with cleanout assembly to±11,592,Circulate clean, POOH. 7. PU TCP guns and RIH and perforate as per program. 8. After detonation, circulate perf gas,confirm well is static, POOH. 9. PU and RIH with new ESP completion. 10. Set BPV, NU tree,test same. 11. Turn well over to production. 12. Conduct SVS test and no-flow tests per AOGCC regulations. Attachments: rel��✓`r-J' 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Diagram Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form McArthur River Field, TBU SCHEMATIC• • Well: M-29A .11 HiIcor,,Alaska.LU PTD: 212-050 API: 50-733-20428-01 Completed: 11/21/14 RKB to TBG Head=71.55' Casing Detail Treeconnection: SIZE WT GRADE CONN ID TOP BTM. I 103/4"` 1 J L 26" 267 to 397 Drill Quip Surface 990' 26"1,, 16" 75 K-55 BTC 15.124" Surface 1,441' " 61 K-55 BTC 12.415" Surface 2,808' 13-3/8" 13318" 68 K-55 BTC 12.415" 2,808' 3,756' 55.50 L-80 BTC 9.760" Surface 460' 10-3/4" 51 L-80 BTC 9.850" 460' 484' 47 L-80 AB Mod&BTC 8.681" 484' 5,727" 9-5/8" 53.5 L-80 BTC 8.535" 5,727' 8,430'TOW 7-5/8" 29.7 L-80 VAM SLID-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Tubing Detail 3-1/2" 9.2 L-80 IBT-Mod 2.992" Surface 7,970' [4 7-5/8"....""42 9-5/8" 1 3 Jewelry Detail _ NO. DMD th DTVD epth ID OD Item 1 71.55' 71' Tubing Hanger 7,970' 7,635' - 5.13" Discharge Bolt On 7,972' 7,637' - 5.13" Pump(x4)513 Series,068 Stage 2 8,061' 7,715' - 5.13" Seals-513 Series 8,078' 7,729' - 5.62" Motor(x2)562 Series,KMPLT1 G-3 8,143' 7,786' - 5.85" Anode 3 8,205' 7,839' 6.151" 8.01" Baker Seal Assembly G-4 -G-5 Perforations -HK-1 Zone Interval(MD) Interval(TVD) Ft SPF Status G3 9,336' 9,372' 8,806' 8,834' 36 5 Open -HK-3 G4 9,402' 9,452' 8,857' 8,895' 50 5 Open G5 9,514' 9,616' 8,941' 9,015' 102 5 Open =)-HK-4 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open -HK-5 10,202' 10,380' 9,305' 9,349' 178 5 Open HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open 10,690' 10,740' 9,433' 9,447' 50 5 Open HK-6 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open -HK-7 7" Amitioh, TD=11,720' PBTD=11,592' Revised: DEM 01-23-2017 McArthur River Field, TBU • PROPOSED • Well: M-29A .11 ��,�,,,.,,ANA..1.1 PTD: 212-050 API: 50-733-20428-01 Completed: FUTURE RKB to TBG Head=71.55' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. J 1 J l 10-3/4" 26" 267 to 397 Drill Quip Surface 990' 26" 16" 75 K-55 BTC 15.124" Surface 1,441' 16" $, 61 K-55 BTC 12.415" Surface 2,808' 13-3/8" 13-3/8" 68 K-55 BTC 12.415" 2,808' 3,756' 55.50 L-80 BTC 9.760" Surface 460' 10-3/4" 51 1-80 BTC 9.850" 460' 484' 47 L-80 AB Mod&BTC 8.681" 484' 5,727" 9-5/8" 53.5 L-80 BTC 8.535" 5,727' 8,430'TOW 7-5/8" 29.7 L-80 VAM SLID-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Tubing Detail 3-1/2" 9.2 2.992" Surface ±7,950 7-5/8"/4P 2 9-5/8" 3 Jewelry Detail 11111 NO. DMD Depth ID OD Item 1 71.55' Tubing Hanger =G-1 2 ±8,150' ±7,792' Bottom of ESP =G-2 G-3 3 8,205' 6.151" 8.01" Baker Seal Assembly =G-4 =G-5 Perforations =HK-1 Zone Interval(MD) Interval(TVD) Ft SPF Status HK-2 ,/ G1 ±9,242' ±9,270' ±8,732' ±8,755' 1-,, Future HK-3 G2 ±9,325' ±9,336' ±8,798' ±8,806' ±11' Future G3 9,336' 9,372' 8,806' 8,834' 36 5 Open G4 9,402' 9,452' 8,857' 8,895' 50 5 Open HK-4 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open _ HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK2 ±9,884' ±10,045' ±9,185' ±9,256' ,I._, Future -HK-5 ✓ HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open 10,202' 10,380' 9,305' 9,349' 178 5 Open HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open 10,690' 10,740' 9,433' 9,447' 50 5 Open HK 6 HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open HKS ±10,963' ±11,030' ±9,505' ±9,522' ±67' HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK-7 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open TD=11,720' PBTD=11,592' Revised:JLL 01/23/17 • • Steelhead Platform M-29A Current 02/20/2014 Ifileurp Alaska.LLC Steelhead Platform Tubing hanger,Seaboard-SC-ESP-EN,13 5/8 M-2954 5M X 3 XEUE lift and susp,w/3'Type H 266164133/8)(95/8X BPV,2-3/8 continuous control line ports, ]5/e%31/2 BIW Kwik-LokPenetrator,Alloy material BHTA,FMC-13-11-A0, 41/165M FE 4.®®�, Valve,Swab,WKM-M, 41/165M FE,HWO,DD Valve, 1111 III 11!" I master, 41/165M FE,w/15"Safeco P , operator,EE ♦ Valve,Wing,FMC-120, 41/165M FE,HWO,DD 4i .1 age p� ,,, Valle,Master,WKM-M, a 41/165M SMFE,FE,HWO,DD 'i_ , 11M11 Spool,4 1/16 5M X 3 1/8 5M :: 111. ii 1 INN Adapter,Seaboard-ESP, 13 5/8 5M rotating flange X -ol line 31/85M rotating flange, prepped for 411/16 extended neck,2-3/8 CCL Tubing head,Seaboard-S, a ,lb ports,alloy material 36 X 5M X 135/85M,w/2- -aa1 1a =`1-1 .!a- 21/I6 5M SSO,BG bottom , prep I - VaNe,WKM-M, �,. ' _ �_ :fi, i:': ' 21/165M FE,HWO,DD Tubing head,FMC-TC-60,spec For unihead,16 54 5M FE top X 16'54 5M stdd bottom,w/2-21/165M SSO , , ai i 11*..".11 ..111.._ Mill e. i S i 13. j - "- , Valve,FMC-120, 21/165M FE,HWO,AA U 711 tFMC Type C, SM FEtop X22M FMC peI_ _ Tbottom,w/421/16SMSSO .r r R,1 . t1, •- '-l. ■ k Adapter spool,FMC-A-5-S30"MSS '� g p _...,,, : stdd bottom X 23 X 2M FMC gigte. _ �i�,,,. speedlock top,w/2-2"LPO LL . M i112 ce. Starting head,FMC,30"M55 Willi hip utt FE%26"bweld IN am.. 16" 13 3/8" 9 5/8" _7 5/8" 3 X" • • , ii Steelhead Platform BOP Stack(Moncla) Hileorp:Alaska,l.l.i: Q -11' nininninn 3.74' Shaffer Ail Ail III Ii1 Iii ft III In In 111 In _ aw-u ice _ Variable 2 7/8-5 4.67' l = ai. 1/3"55//8-555000 I11111 v.v.,. Blind Rams Iii Iii 1II lit III Choke and Kill Valves 2 1/16 9.4 w/Unibolt connections for hoses yr. Iii Iii i#1 In III - 1211 z Oo' )1 1I . 1. t ailllflll a glom � lil Il1. 1l° �' In 111111 In ill Riser,13 5/8 5M FE X 13 5/8 5M API 613 hub 13.70' c •0 oCi" 0 o u o u o ouo o u o u o u o u u 0 o m e Ln r' .+ v .n to n CO Cr. g W 2 2 2 2 2 2 2 2 2 u a a a a aU v U U U U V U U o •-I N CO a in v .0 N CO o to to n CO m . 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Z ajz CCI o ? 1 J co J ElH 2a A m.0_ 0 rZ ocOOE- , U !qp zQ C• o1L < o Q D aQ Z U w 1- J O Z > red . a LL Z H- � - om z a = J a n U 0 ®- U o u o u 0 0 0 0 0 0 u o u o u u o u u 0 • 82 o N M V L n .-1 , 01 .71.11l0r, C00i' 22222 0 ,°, 2 2 2 u dd d d 0. - U V U U U U U UU U VU U U V O .ti N m a u1 W .-- tv m a Ui N n CO 01 .y LM -0 "0 -MM -0 -0 -0 Cwww3 000000000 wwwww w .- .r OJ (tel a C C C C C C C •C C C L > 3 g g i N E 01 J i g g ) 0 0 0 0 0 N ? g y a a 2 d J J > W 331' 133333 J Y 2 EESEE o o o o o o o o o o 0 6 C w 3 22222 YY u L 5 -55556 -5655 A 21.-D N o 0 a w Y LL O A m U 0 m O N 2 "c 14 14 "E co - :ICD - 0L, O - U Z Z 1—_a 1- I�7 a IL a.o r7 .ct z o NU U m W U-, K =j O CC Si Lu n_0 W a_W c7 c7S C \ ui}iii L N L.WIPP 6 E[11;1116 aU OQ 00 h W a 1—u H a 0 z H u) U) Q J D z O Z Uw Z a D z Q a EL Z ❑ IJ U) J H 2 a A — ctU = S Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC- BOP Test Procedure: Moncla Rig 404, WO Program—Oil Producers, Water Injectors Pre Rig Move 1) Blow down well,bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again,right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry,proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks,notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(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. As outlined and approved in the sundry,proceed as follows: a) Nipple Up BOPE 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.) • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment 41 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. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted,remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing,pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1St valve on standpipe manifold,close valves 1,2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 1St valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. y, e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes,bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. • i II Moncla Rig 404 BOP Test Procedure Hileorp Alaska,LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record"Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized,record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto",not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. 0 • 1 c22 k 5k m .k 0 £ � 2 6w al c 77 02e 2 � 2 k ® § f « a E E 0 0c e To- = § 10. 0. �. § « T� § o 2 CO CA ■ � k � Z �� / 0. a gE § i 7 . a) a)� ■ 222 a a $ c 3 . . 0 0 Eo 2I S k / 90 oa 3 — 0 2 2 � k - 7 g o c « ■ coc � 3 — 2U C.) 2% ■ o k . a) ■ Em © o 2 -o a - o. o a L. 03 L. 2 ■ c § 2 / 2Ea Cl) _ p 2 W > 2R 0 m @ 2 § � a o Q C 03 o 0L. 2 § t . . E 0. 0 o k5 R » ■ at m : co 4- ca 0 § 5 2 a ca 2 � 0 CO CO � C4 .. •• '5 2 0 Zi o0 7 El k q o / 0 4 < « a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM. .ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other 0 Replace ESP Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WellE 2.Operator 4.Well Class Before Work: 5.Permit to DrillNu er Name: Hilcorp Alaska,LLC Development 0 Exploratory 171212-050 E C E 1 V E D 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20428-01 DEC 19 2014 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit/M-29A AO G jC 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,720' feet Plugs measured N/A feet true vertical 9,696 feet Junk measured N/A feet Effective Depth measured 11,592' feet Packer measured 8,201 feet true vertical 9,663 feet true vertical 7,836 feet Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 990' 3,010 psi 1,440 psi Conductor 1,411' 16" 1,441' 1,441' 2,630 psi 1,010 psi Surface 3,756' 13-3/8" 3,756' 3,754' 3,090 psi 1,540 psi Production 8,228' 10-3/4"&7-5/8" 8,228' 7,859' 5,860 psi 3,220 psi Liner 8,205' 7-5/8" 8,205' 7,839' 6,890 psi 4,790 psi Liner 3,512' 7" 11,713' 9,694' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet SCANNED JAN of 0 ?Alb True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 7,970'(MD) 7,635'(ND) 8,201'(MD) Packers and SSSV(type,measured and true vertical depth) Packer 7,836'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 259 134 4006 66 76 Subsequent to operation: 193 187 3855 70 76 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ 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: 314-577 ' Contact Ted Kramer Email tkramer(G hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature .t/ / [� Phone (907)777-8420 Date 12/19/2014 / ZC '/ � Form 10-404 Revised 10/2012 S mit Original Only I /4 0., RBDMSk) JAN — 4 2015 McArthur River Field, TBU SCHEMATIC Well: M-29A Hikers,W,ka.,.I.0 As Completed: 11/21/14 RKB to TBG Head=71.55' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. J 10-3/4"t 1 I 26" 267 to 397 Drill Quip Surface 990' 26" L 16" 75 K-55 BTC 15.124" Surface 1,441' 16" 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' 30-3/4" 51&55.5 L-80 BTC 9.760" Surface 484' 13-3/8" 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM SLIJ-ll 6.875" Surface 8,205' 4 7" 26 L-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.58,N-80 8,430' 8,467' Tubing Detail 3-1/2" 9.2 L-80 IBT 2.992" Surface 7,970' i i i ' Jewelry Detail NO. Depth OD ID Item 7-5/8"----' 2 , 3 1 71.55' Tbg Hngr 4 III 4 2 7,970' 5.13 Discharge Bolt On 3 7,972' 5.13 Pump(x4)513 Series,068 Stage 9-5/8"d 4 8,061' 5.13 Seals-513 Series 5 8,078' 5.62 Motor(x2)562 Series,KMPLT1 6 8,143' 8.85 Anode 3 8,201' Top Packer w/RS Profile Flex Lock liner Hangar 4 8,205' Baker Seal Assembly G-3 G-4 =G-5 Perforations Zone Interval(MD) Interval(TVD) Ft SPF Status =HK-1 G3 9,336' 9,372' 8,806' 8,834' 36 5 Open G4 9,402' 9,452' 8,857' 8,895' 50 5 Open =HK-3 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open HK-4 10,202' 10,380' 9,305' 9,349' 178 5 Open _ HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open HK-5 10,690' 10,740' 9,433' 9,447' 50 5 Open HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK-6 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open -_-HK-7 7" t -;-% TD=11,720' PBTD=11,592' Revised: 12/19/14 by JLL Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A 50-733-20428-01 212-050 11/13/14 11/21/14 Daily Operations: 11/13/14-Thursday NIPPLE DOWN TREE AND NIPPLE UP BOPE. PREP TO RAISE DERRICK. INSTALL SAFETY CABLES TO SKID BEAMS. RAISE DERRICK AND SECURE. INSTALL DRILL LINE ON DRUM AND DEAD MAN.SCOPE DERRICK INTO PLACE AND SECURE. INSTALL RISER SPOOL ONTO HYDRIL. INSTALL POLUTION PAN AND RIG FLOOR. INSTALL BRACES AND WIND WALLS ON RIG FLOOR. 11/14/14-Friday CONTINUE WINTERIZING RIG. PULL BACK PRESSURE VALVE AND INSTALL 2 WAY CHECK. R/U TESTING EQUIPMENT.SHELL TEST BOPE. TEST BOPE EQUIPMENT AS PER HILCORP AND AOGCC SPECS TO 250 LOW 2500 HIGH 5 MIN EACH_ON CHART. B, s MR. MATTHEW HERRERA WITH AOGCC,WITNESSED TEST. TESTED H2S AND METHANE ALARMS.TESTED ESD ON HEATERS,ALL GOOD. LOOKED OVER HILCORP WELL CONTROL ON PULLING ESP, OK. R/D TESTING EQUIPMENT. PULL TWO ' / WAY CHECK,SCREW LANDING JT INTO HANGER. BACK OUT HOLD DOWN PINS. PULL HANGER FREE WITH 89K PICK UP WT if TO SURFACE. LAY DOWN HANGER. PULL 2 STANDS AND RIG UP SHEAVES IN DRK.CONNECT CABLES TO SPOOL. POOH WITH 3 1/2"9.2#L-80 IBT PRODUCTION TBG. REMOVING CANNON CLAMPS AND SPOOLING UP CABLES. DEPTH @ 0600= 7,030'. 11/15/14-Saturday CONTINUE POOH W/3.1/2"9.2#L-80 IBT PRODUCTION TBG CABLE AND FLAT PACK. UNSPLICE CABLE AND CHANGE OUT SPOOL @ 4,128'. CONTINUE POOH WITH W/3 1/2"TBG RACKING BACK IN DRK AND REMOVING CANNON CLAMPS. BEGAN LAYING DOWN MOTORS AND PUMP ASSY. CHECKED PUMP, MEGGED OK. INSTALL SHEAVES IN DERRICK AND NEW SPOOLS. PICK UP AND MAKE UP PUMPS. FILL EACH SECTION WITH OIL.CONNECT CHEMICAL LINES AND ELECT CABLES. TEST PUMP& ELECT CABLES. READING GOOD ON PUMP AND MOTOR AND CABLE. 11/16/14-Sunday CONTINUE TIH W/3 1/2"9.2#L-80 IBT PRODUCTION TBG. MAKE SPLICE @ 4,108'TEST, GOOD. CONTINUE TIH WITH PRODUCTION STRING. MAKE SPLICE IN ELECT CABLE.WIRE IN PENATRATER. LAND HANGER AND RUN IN HOLD DOWN PINS. BOTTOM OF ESP @ 8,142'. BREAK DOWN LANDING JOINT AND RIG DOWN CABLE SHEAVES OUT OF DERRICK. RIG DOWN HYD TONGS. REMOVE RIG FLOOR. TAKE GUIDE CABLES DOWN.SCOPE DOWN DERRICK. CHAIN OFF BLOCK AND DISCONNECT DEADMAN. DROP REMAINING GUIDE CABLES AND LAY OVER DERRICK. BREAK BOLTS ON BOPS. 11/17/14-Monday NIPPLE DOWN BOP'S AND NIPPLE UP TREE.SHELL TEST TREE AND SEALS TO 5000 PSI, OK.ASST IN INSTALLING FLOWLINE. REMOVED ALL TOOLS FROM WELL BAY. CLEAN AND PREPARE RIG AND EQUIPMENT FOR TRANSPORT TO DOCK. OPEN RAMS UP REMOVE RAMS CLEAN FOR TRANSPORT. PRESSURE WASHING ALL EQUIPMENT. PLACE RIGGING ON DERRICK TO BE LIFTED. STACK UP WIND WALLS. 11/18/14-Tuesday RIGGING DOWN. PREP RIG FOR DEMOB.AFTER STARTING ESP PUMP FOUND THAT CABLE HAD A GROUND FAULT. TROUBLE SHOOT. DECISION WAS MADE TO PULL HANGER. HELD JSA WITH CREW ON RIGGING BACK UP. BLEED WELL DOWN. WINTERIZE RIG BACK. REINSTALL HEATERS. SET BACK PRESSURE VALVE IN HANGER. REMOVE TREE. NIPPLE UP RISER AND BOPE TORQUE SAME. CHANGE OUT HOIST CABLE.TIE DOWN RIG CARRIER. RUN CHOKE AND KILL LINES. RUN HEATER LINES.WAIT ON WINDS 35-40 MPH TO RAISE DERRICK. NOTE" BOPE TEST WITNESS WAVIED BY JIM REGG W/AOGCC. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A 50-733-20428-01 212-050 11/13/14 11/21/14 Daily Operations: 11/19/14-Wednesday SCOPE DERRICK OUT. HOOK UP GUIDELINES. INSTALL RIG FLOOR. RIG UP WIND WALLS AND HANDRAILS.SET IN PLACE DRILLERS SHACK AND R/U TO TEST.TEST BOPE TO 250 LOW 2500 HIGH ON CHART FOR 5 MIN EACH AS PER HILCORP AND AOGCC SPECS. WITNESS WAIVED BY JIM REGG W/AOGCC. R/D TESTING EQUIPMENT. P/U LANDING JT SCREW INTO HANGER. PULL HANGER TO RIG FLOOR. CHECKED TOP OF PENATRATER AND SPLICE. BOTH SHOWED GROUND. LAY DOWN HANGER. R/U SHEAVES IN DERRICK. PULL 2 STDS THEN RUN CABLES THROUGH AND INSTALL ON SPOOLER. POOH. 11/20/14-Thursday CONTINUE POOH_WITH 3-1/2" IBT TUBING FROM 1,972'TO 4,128', INSPECTING ESP CABLE& FLAT PACK CONTROL LINE. FOUND BAD SPOTS AT 800', 1,700'& 1,900'.ARMOR WAS STRIPPED FROM REDA CABLE&CONTROL LINE WAS EXPOSED FROM PLASTIC COATING. MEG REDA CABLE AT INTERMEDIATE SPLICE, PUMP READ GOOD AT 588 MEG OHMS. REDA CABLE HAD NO DAMAGE FROM 2,000'TO 4,128'. DECISION MADE TO TIH. ORDER OUT REPLACEMENT REDA CABLE& FLAT PACK SPOOLS. PREP REDA CABLE SPLICE&TEST CONTROL LINE WHILE WAITING ON BOAT. UNLOAD REDA CABLE& FLAT PACK SPOOLS,SPOT SAME. PERFORM INTERMEDIATE SPLICE ON REDA&CONTROL LINE. TIH WITH 3-1/2" IBT TUBING FROM DERRICK AT 3 MINUTES PER STAND, MEGING REDA CABLE EVERY 500', INSTALLING CROSS COLLAR CANNON CLAMPS. DEPTH @ 0600 HRS. =7,020'. 11/21/14-FREDAy SERVICE RIG &EQUIPMENT. INSPECT SHACKLES&SHEAVES FOR REDA CABLE&FLAT PACK. CONTINUE TIH WITH 3-1/2" IBT TUBING AT 3 MINUTES PER STAND FROM 7,020'TO 8,102'. INSTALL CANNON CLAMPS ON EVERY JOINT FROM 2,000'TO SURFACE, CHECKING REDA CABLE EVERY 500'. HOLD MEETING ON LANDING HANGER. P/U & INSTALL TUBING HANGER. PERFORM FINAL SURFACE SPLICE.TIE IN PENETRATOR& INJECTION LINES TO HANGER. LAND OUT TUBING HANGER SETTING END OF PUMP @ 8,142.56' KB MEASUREMENT WITH 74K DOWN. MEG REDA CABLE WITH TUBING LANDED OUT. (TESTED GOOD). REMOVE WINTERIZATION TARPS FROM FLOOR.CLEAR RIG FLOOR. REMOVE WIND WALLS. R/D RIG FLOOR. SCOPE IN & LAY OVER DERRICK. N/D BOPE& N/U SEABOARD-ESP 13-5/8"5M ROTATING FLANGE WITH PRODUCTION TREE.TEST VOID TO 250 LOW&5K HIGH & HOLD FOR 5 MINUTES(TESTED GOOD). SHELL TEST TREE WITH WATER FLOOD TO 3K(HELD SAME). MAKE FINAL TIE INS&TURN M-29A OVER TO PRODUCTION @ 0500 HRS. 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I Mo I o O Z.1 a E Uco U Q a N I-• N_ Z O 2 m N Y Q _N W m r- M Z a) c A p a Q g o .\_ H Q a Z o h)... 1 C3 d U E Ill z 'h, m • co /0111111 2m 0 v N3 N d CC Q N 0) C a cu 0 a 2 U STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COMr. ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well 0 Plug Perforations ❑ Perforate 0 Other 0 Install ESP Performed: Alter Casing❑ Pull Tubing Stimulate-Frac 0 Waiver 0 Time Extension❑ Change Approved Program 0 Operat Shutdown❑ Stimulate-Other 0 Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number. Name. Hilcorp Alaska,LLC Development 0 Exploratory 0 212-050 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20428-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit/M-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071). 10.Field/Pool(s): McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11.Present Well Condition Summary. Total Depth measured 11,720' feet Plugs measured N/A feet i"' ' h . r- true vertical 9,696 feet Junk measured N/A feet ( . C: Effective Depth measured 11,592' feet Packer measured 8,201 feet true vertical 9,663 feet true vertical 7,836 feet "(A(.)( CC t Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 990' 3,010 psi 1,440 psi Conductor 1,411' 16" 1,441' 1,441' 2,630 psi 1,010 psi Surface 3,756' 13-3/8" 3,756' 3,754' 3,090 psi 1,540 psi Production 8,228' 10-3/4"&7-5/8" 8,228' 7,859' 5,860 psi 3,220 psi Liner 8,205' 7-5/8" 8,205' 7,839' 6,890 psi 4,790 psi Liner 3,512' 7" 11,713' 9,694' 7,240 psi 5,410 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 8,012'(MD) 7,672'(TVD) 8,201'(MD) Packers and SSSV(type,measured and true vertical depth) Packer 7,836'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMAI MAY 1 5 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 240 293 5339 80 '90 Subsequent to operation: 173 125 4696 81 89 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil D Gas 0 WDSPL❑ GSTOR ❑ WINJ 0 WAG 0 GINJ D 3USP❑ 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. 314-101 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe yam, _�Titlee Operations Engineer Signature ..41.e."7,1„„,, 170,00-A,170,00-A, /�x!'/07/Ti (907)283-1329 Date 4/17/2014 Form 10-404 Revised 10/2012 z /`� Submit Original Only Q 40- ,feAi y McArthur River Field, TBU II SCHEMATIC Well: M-29A ,,;i,, Alaska.,,,. As Completed: 03/18/14 RKB to TBG Head=71.55' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. 1 '4 10-3/4" ° 26" 267 to 397 Drill Quip Surface 990' 26" I 16" 75 K-55 BTC 15.124" Surface 1,441' , L,L 1 16" ) 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' I10-3/4" 51&55.5 L-80 BTC 9.760" Surface 484' 13-3/8" 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM SLID-II 6.875" Surface 8,205' 1 7" 26 L-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.51*,N-80 8,430' 8,467' Tubing Detail 3-1/2" 9.2 L-80 IBT 2.992" Surface 8,012' 1 2 3 IR 4 ' NO. Depth OD ID Item 11111 7-5/8"----4. 5 1 71.55' Tbg Hngr „jr 6 2 8,012' IF 8,013' 5.13 Discharge Bolt On 8 3 5.13 Pump:STG,SG 7300(x3) 9-5/8"di &a 4 8,067' 5.13 Intake 5 8,087' 5.65 Motor:562 Series/340 HP(x2) 6 8,155' 5.85 Anode 7 8,201' Top Packer w/RS Profile Flex Lock liner Hangar 8 8,205' Baker Seal Assembly =G-3 G-4 =G-5 Perforations Zone Interval(MD) Interval(TVD) Ft SPF Status G3 9,336' 9,372' 8,806' 8,834' 36 5 Open =HK-1 G4 9,402' 9,452' 8,857' 8,895' 50 5 Open =HK-3 G5 9,514' 9,616' 8,941' 9,015' 102 5 Open HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open HK-4 10,202' 10,380' 9,305' 9,349' 178 5 Open _ HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open HK-5 10,690' 10,740' 9,433' 9,447' 50 5 Open HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open =HK-6 HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open =HK-7 7" d0C'1k-- TD=11,720' PBTD=11,592' Revised:04/17/14 by JLL • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date 50-73320428-01-00 212050 3/6/14 3/18/14 Daily Operations: 03/06/14-Thursday Rigging up. 03/07/14-Friday Rigging up. 03/08/14-Saturday Rigging up. 03/09/14-Sunday Rigging up. 03/10/14-Monday Rigging up. 03/11/14-Tuesday Rigging up. 03/12/14-Wednesday R/U BOPE TEST PUMP. REMOVE BPV& INSTALL TWO WAY CHECK. P/U 3-1/2" BOP TEST ASSEMBLY&SPACE OUT TO RIG FLOOR. INSTALL TIW VALVES&PREPARE TO TEST BOP. PRETEST BOPE WHILE WAITING ON AOGCC WITNESS. 03/13/14-Thursday BOB NOBLES WITH AOGCC ARRIVED ON STEELHEAD @ 07:32 HRS. TEST BOPE PER AOGCC REGULATIONS WITH BOB NOBLES WITNESSING ALL TESTS. TEST ALL BOPE TO 250 PSI LOW & 2500 PSI HIGH. HOLD ALL TEST FOR 5 MINUTES ON CHART. PERFORM KOOMEY DRAW DOWN TEST. TEST AUTO SHUT DOWNS ON HEATERS PER AOGCC. INSPECT WINTERIZATION & RECORD TEMP READINGS. REMOVE TEST ASSEMBLY. REMOVE TWO WAY CHECK. CLOSE BLIND RAMS. LINE UP PUMP LINES TO CIRCULATE WITH PRODUCTION WATER FLOOD. CIRCULATE WITH WATERFLOOD @ 1.7 BPM CATCHING RETURNS TO SEPERATOR. CIRCULATE 300 BBLS TOTAL OF FIW. SHUT DOWN & ISOLATE WATER FLOOD PUMP LINES. INSTALL 3-1/2" LANDING JT. BACK OUT HOLD DOWN PINS, PULL 70K & UNSEAT HANGER. PULL HANGER TO RIG FLOOR. TECH INSPECTED HANGER (GOOD). TECH CHECKED DOWNHOLE COMUNICATIONS THROUGH RITA CABLE WITH NO SUCCESS. BREAK & L/D LANDING JT WITH HANGER. R/U CHEMICAL FLATPACK SPOOL, PULL CABLE THRU SHEAVES TO SPOOLING DRUMS. POOH WITH 3-1/2" L-80 TUBING RACKING PIPE IN DERRICK. REMOVING CANNON CLAMPS. SPOOLING RITA CABLE & FLATPACK ON SPOOLS. DEPTH @ 06:00=8,000'. Page 1of2 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date 50-73320428-01-00 212050 3/6/14 3/18/14 Daily Operations: 03/14/14- Friday SERVICE RIG & EQUIPMENT. MOVE FLATPACK SHEAVE OFF DRILLER SIDE & ALINE FLAT PACK ONTO SPOOL. POOH WITH 3-1/2" L-80 9.2# PRODUCTION TUBING, RITA CABLE, & FLAT PACK CABLE. REMOVING CROSS COLLAR TUBING CLAMPS. PUMPING FIW ON ANNULUS EVERY 10 STANDS FOR PIPE DISPLACEMENT. DEPTH @ 0100 HRS = 626'. UNABLE TO CONTINUE POOH DUE TO HIGH WINDS. POOH WITH 3-1/2" PRODUCTION TUBING TO ESP PUMP TOP. PUMP FIW FOR PIPE DISPLACEMENT. MONITOR HOLE WHILE WAITING ON WINDS TO LAY DOWN ESP. REMOVING CANNON CLAMPS & UNNEEDED ESP REMOVAL EQUIPMENT FROM RIG FLOOR & DECK AREA. SERVICE RIG & EQUIPMENT WHILE WAITING ON WINDS TO SUBSIDE. 03/15/14-Saturday SECURE TARP WINTERIZATION AFTER HIGH WINDS. L/D ESP. LOWER SPLICE AGAINST MOTOR WAS PARTED, CHECKED MOTOR & BOTH MOTORS SHOWED THEY WERE BURNT. CLEAR RIG FLOOR. MOVE OLD CABLE SPOOLS & SET UP NEW RITA CABLE SPOOLS. SET UP NEW FLAT PACK REEL. PREPARE TO P/U ESP. HANG ESP SHEAVES WITH RITA CABLE & FLATPACK. HOLD PREJOB MEETING WITH RIG, CRANE, & CREWS..P/U & M/U ESP ASSEMBLY, FILLING MOTORS WITH OIL & PREPPING ASSEMBLY TO RIH. P/U TOTAL OF (3) SG-7300 PUMPS, (2) 340 HP MOTORS @ 2124 VOLTS-96 AMPS, (2) BPBSL SEALS&(1) BOLT ON INTAKE.TOTAL ESP LENGH = 133.66'. MAKE RITA CABLE SPLICE TO PUMP WITH TECHS. BEGINNING TO TIH &SLM 3.5" L-80 TUBING OUT OF DERRICK @ 0600 HRS. 03/16/14-Sunday CONTINUE MAKING INITIAL RITA CABLE SLICE TO ESP ASSEMBLY. TIH WITH 3-1/2" L-80 9.2# IBT PRODUCTION TUBING, SLM FROM DERRICK, INSTALLING CROSS COLLAR CANNON CLAMPS EVERY SECOND JOINT SECURING RITA CABLE & FLAT PACK TO TUBING. TIH TO 4,089' & CHANGE OUT RITA CABLE SPOOLS. CHANGE OUT FLAT PACK SPOOLS. MAKE INTERMEDIATE RITA CABLE SPLICE & FLAT PACK SPLICE WITH TECHS. TIH WITH 3-1/2" L-80 TUBING FROM DERRICK INSTALLING CROSS COLLAR CLAMPS TO 7,060'. CHANGE OUT FLAT PACK SPOOL& MAKE SPLICE WITH TECH.TIH WITH 3-1/2" L-80 TUBING SLM PIPE OUT OF DERRICK& INSTALLING CROSS COLLAR CLAMPS TO 8,075'. INSTALL TUBING HANGER WITH X-0 SUB. INSERT PENETRATOR & MAKE FINAL SPLICES ON RITA CABLES & FLAT PACK CHEMICAL LINES. 03/17/14-Monday FINISH MAKING FINAL RITA CABLE SPLICE AGAINST TUBING HANGER,TIE IN FLAT PACK CHEMICAL INJECTION LINES INTO TUBING HANGER PORTS, P/U LANDING JOINTS & LAND OUT TUBING AT 8,154.88'. RUN IN HOLD DOWN PINS WITH TECH. SET BPV INSIDE TUBING HANGER FOR N/D OF BOP'S. N/D BOP'S BREAKING BOLTS ON STACK & RISER. N/D & REMOVE HYDRIL, DOUBLE BOP, MUD CROSS & RISER FROM TUBING HEAD. N/U 13-5/8" 5M X 3-1/8" 5M SEABOARD ESP ADAPTOR FLANGE. MAKE FINAL CHEMICAL HEAD TIE -INS& ELECTRICAL TIE- INS.TEST ADAPTOR FLANGE VOID TO 500 PSI LOW&5000 PSI HIGH. HOLD TEST FOR 30 MINUTES(HELD SAME). N/U 4-1/16" 5M X 3-1/8" 5M SPOOL WITH PRODUCTION TREE. ASSIST PRODUCTION & HOOK UP WING LINES & CONTROL LINES TO PRODUCTION TREE. TEST PRODUCTION TREE &VALVES TO 500 PSI LOW, 5000 PSI HIGH. MEG TEST MOTOR. PREPARING TO BRING M-29A ONLINE. 03/18/14-Tuesday ASSIST PRODUCTION IN BRINGING M-29A ONLINE. Page 2 of 2 • 77-4 I%% � T STAFF - - — - - - -- 33' \' i Se, ei 11 er e -'-` G(�\'l k�'O SEA [ :1R:\FLr „ncrorcue, P,/,oll• 907 2/5 143) 41,Ate•-.- Dan Marlowe �O Operations Engineer I � Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G & Hemlock Oil Pools, TBU M-29A Sundry Number: 314-101 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of February, 2014. Encl. EC E /E Di STATE OF ALASKA FEB 2 1 2U14 ALASKA OIL AND GAS CONSERVATION COMMISSION O7-j z-62$11 _ APPLICATION FOR SUNDRY APPROVALS AOCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing El Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing 0 Other. Install ESP• 0 2 Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory 0 Development I] • 212-050 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20428-01 • 7 If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit/M-29A 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0018730 McArthur River Field/Middle Kenai G&Hemlock Oil Pools • 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): 11,720 ' 9,696 • 11,592 9,663 , N/A N/A Casing Length Size MD TVD Burst Collapse Structural 990' 26" 990' 990' 3,010 psi 1,440 psi Conductor 1,411' 16" 1,441' 1,441' 2,630 psi 1,010 psi Surface 3,756' 13-3/8" 3,756' 3,754' 3,090 psi 1,540 psi Production 8,228' 10-3/4"&7-5/8" 8,228' 7,859' 5,860 psi 3,220 psi Liner 8,205' 7-5/8" 8,205' 7,839' 6,890 psi 4,790 psi Liner 3,512' 7" 11,713' 9,694' 7,240 psi 5,410 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic , See Schematic 3-1/2" 9.2#/L-80 8,011 Packers and SSSV Type: SSSV: N/A Packers and SSSV MD(ft)and TVD(ft): Pkr w/RS Profile Flex Lock Line Hangar % 8,201'(MD)7,836'(TVD)and SSSV:N/A 12.Attachments. Description Summary of Proposal 0 , 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch 0 • Exploratory ❑ Stratigraphic❑ Development 0 , Service ❑ 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations: 3/10/2014 Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(ahilcorp.com Printed Name Dan M ow Title Operations Engineer Signatur Phone (907)283-1329 Date 2/21/2014 flet T rce.Atm.MR i►A oiIMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \-{- \ 0l Plug Integrity ❑ BOP Test II Mechanical Integrity Test ❑ Location Clearance 0 Other. Z -OO r S S4 il° �d.— RBDMSNAY il 9 2014 Spacing Exception Required? Yes ❑ No Ii Subsequent Form Required. /6 — CILO y APPROVED BY Approved by: 0 P --67 � COMMISSIONER THE COMMISSION?Mil 4kii/1/ 4•0_ 70°;77 Date: a. -a s-�/q i Submit Form and Form 10-403(Revised 1 20ci 12) App� plidf Ilir 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis Well: M-29A Hilcory Alaska,LLC Date: 02/19/14 Well Name: M-29A API Number: 50-733-20428-01 Current Status: ESP Producer Leg: B-1 Estimated Start Date: March 10, 2014 Rig: S�«(�, ,Q SI/L/O'-( Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 212-050 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: —3,365 psi @ 9,000' TVD (TVD of Mid perf) Maximum Expected BHP: —3,365 psi @ 9,000' TVD (No new perfs being added) Max.Anticipated Surface Pressure: 0 psi (Using 0.435psilft.to surface) Brief Well Summary M-29A is a Hemlock Producer completed with an ESP. The ESP experienced a down-hole electrical failure February 2014.We plan to pull and replace the ESP.No perforations will be added. Procedure: 2 n c_ (1) 1. MIRU Rig. 1 Sl er Nlo►a �O 2. Attempt to pumphrough ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+/-7,900'and punch tubing. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. PU, RIH with ESP completion. 6. Land ESP with the bottom of the assembly at+/-8,150'. 7. ND BOP, NU wellhead and test. 8. Turn well over to production. 9. RDMO Rig. Attachments: 1. Current Well Schematic 2. Current Wellhead Diagram 3. Proposed Well Schematic 4. Proposed Wellhead PDiagram 5. BOP Drawing McArthur River Field, TBU II SCHEMATIC Well: M-29A HiImrn Alwka.ld.f. As Completed: 7/21/2012 RKB to TBG Head=40.73' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. J 10-3/4"l 1 J \ 26" 267 to 397 Drill Quip Surface 990' 26 ' 16" 75 K-55 BTC 15.124" Surface 1,441' 16" 1 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' 10-3/4" 51&55.5 L-80 BTC 9.760" Surface 484' 13-3/8" 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.58,N-80 8,430' 8,467' Tubing Detail 3-1/2" 9.2 L-80 IBT 2.992" Surface 8,011' Jewelry Detail NO. Depth Length OD ID Item 21 1 40.73' Cameron 11"x 4-'h"Tbg Hngr 2 8,011' 1.5' 3.65" 2.813" "X"Nipple 7-5/8"----1'' 3 ESP Pump Top.Baker Hughes 45 6 3 8,012' 142' Max 5.85" N/A P110 w/816Hp Tandem Motor 4 8,154' N/A N/A N/A ESP Pump Bottom 9-5/8"ao db. 5 8,201' 28' Top Packer w/RS Profile Flex Lock liner Hangar 6 8,205' 3' Baker Seal Assembly Perforations Zone Interval(MD) Interval(TVD) Ft SPF Status G3 9,336' 9,372' 8,806' 8,834' 36 5 Open -G3 G4 9,402' 9,452' 8,857' 8,895' 50 5 Open G5 9,514' 9,616' 8,941' 9,015' 102 5 Open =G-4 HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open -G-5 10,202' 10,380' 9,305' 9,349' 178 5 Open HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open -HK-1 10,690' 10,740' 9,433' 9,447' 50 5 Open HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open -HK-3 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open HK-4 HK-5 =HK-6 HK-7 TD=11,720' PBTD=11,592' Revised:8/20/2012 by TDF McArthur River Field, TBU II PROPOSED Well: M-29A Hik»rn Alaska.Llf. As Completed: 7/21/2012 RKB to TBG Head=40.73' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. 26" J 10-314"l 1 I 26" 267 to 397 Drill Quip Surface 990' 16" 75 K-55 BTC 15.124" Surface 1,441' ` 16" , L, 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' 10-3/4" 51&55.5 L-80 BTC 9.760" Surface 484' 13-3/8" 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM SLID-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.5#,N-80 8,430' 8,467' Tubing Detail 3-1/2" 9.2 L-80 IBT 2.992" Surface 8,011' Jewelry Detail NO. Depth Length OD ID Item 1 40.73' Cameron 11"x 4-''/="Tbg Hngr 2 ±8,150' ESP Pump Bottom 7-5/8"i� Top Packer w/RS Profile Flex 2 3 4 3 8,201' 28' Lock liner Hangar 4 8,205' 3' Baker Seal Assembly 9-5/8"ai Perforations Zone Interval(MD) Interval(TVD) Ft SPF Status G3 9,336' 9,372' 8,806' 8,834' 36 5 Open G-3 G4 9,402' 9,452' 8,857' 8,895' 50 5 Open G5 9,514' 9,616' 8,941' 9,015' 102 5 Open G-4 - - HK1 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open =G-5 10,202' 10,380' 9,305' 9,349' 178 5 Open HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open =HK-1 10,690' 10,740' 9,433' 9,447' 50 5 Open HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open =HK-3 - HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open HK-4 HK-5 HK-6 -=-HK-7 7„ 5,4:, TD=11,720' PBTD=11,592' Revised:02/19/14 by JLL Ili Steelhead-29ACurrent/20014 Platform M 2 Hi'carp Alaska.1JA. Steelhead Platform Tubing hanger,Seaboard-SC-ESP-EN,13 5/8 Mel 29A 5M X 3 Y.EUE lift and susp,w/3.Type H 26%16 X 13 3/8 X 9 5/8 X BPV,2-3/8 continuous control line ports, ]5/8 X 31/2 BIW%wik-LokPenetrator,Alloy material BHTA,FM0B-1140, 41/16 5M FE w ,, k: Valve,Swab,WKM-M, � 41/165M FE,HWO,DD '` CIai I Valve,upper marten S5V, (0, aaa6' tool 41/16SM FE,w/15"Safeco - , b. operator,EE l- Valve,Wing,FMC-1X1, an. * c 1,g 41/165M FE,HWO,DD Valve, WKM-M, 41/16 5M 5M FE FE,HWO,DD ~ ' 1✓ Spool,41/16 SM X 3 1/8 5M FI MEW as. 7 Adapter,Seaboard ESP 13 5/8 5M rotating flange% � 31/85M rotatingtlange, ntrol line prepped for 411/16 ��! extended neck,2-3/8 CCL Tubing head,Seaboard-5, i ports,alloy material 16XSMK135.5.,w/2 ..... # � 21/165M S50,BG bottom -e.�� it 2.1.2.,1..= P P _� _ All i . imp. s'k.f'�111��� S.-ip,, Va ive,WKM-M 5 .'.a6"y _t1°P 21/165M FE,HWO,DD Tubing head,FMC-TC-60,spec for - -_ unihaad,I6Xw/FE top-21165M 5M . - stdd bottom,w/2-21/16 SM 550 1 '4.221b I Valve,FMC-120, 21/16 SM FE,HWO,AA Unihead,FMC Type 2,16X SM 3.-._ IIIIIIFE top%21 X 2MFMCspeedbck _ ,^ 0 bottom w 42 165M 55O a r 1 i 1 a' i. 7■.�5# Adapter spoil,FMC-A-5-S 30"MSS ��Ir k � stdd bottotn X 21 X 2M FMC hittia. speedlocktop,w/11.2 2-2"LPO �� _ Starting head,FMC,butt weld MSS r mow FE%26"butt weld mi 16" 13 3/8" 9 5/8" ]5/8" 3'h" Steelhead Platform M-29A BOP Irikrrp:uaoka.LIA, 02/20/2014 ss .... .a,.,..._ 20"pipe for air boot flanges en' .23 3.3.33.3333 Ill lil ii.matt G L 5,10' 'tlilaUfbralf[P> Variables 3A-7 —141" _ .41 'r., .�. _1� f.„,,....i.•VVY�' r 5 46' Blind --41' ' II 3 .10-- 01e3. isi III fire fit 1st wP $pp it • / g�Bg® 31/85MChokeand Klll 1 114.-: i° ,fel fs1ill 1.4 11°tel '? '110 3.00'3.00' valves w/NCR an bath stles 6!! F Fee � 34 rams "- 3.58' 1111111111. OSA 16%]OM%]6%SM .66' •f Riser,16%5M API hub B 16 3/4 10M FE 23 47 Riser,16%5M FE%16%5M API hub I upo.,..un.e,Pom mo, D5A 135/85Mx 16%5M 11' i". II'�i " l ° i___3. ;,-;: r: t. U r. .4- i,ai 1, 1.!r-- IF•js fiil' wiii• lair 1 0 Steelhead Platform M-29A BOP Moncla 404 02/20/2014 Hilcarp Alaska',LU; 111 III III lit lil III III 11 MILA tea: _ti 3.74' MOW ill lii lil til Iii let in lei ru ttt Variable 2 7/8-5 .a ''' " . __ .:: � "p 4.67' Blind Rams -- * 11i ril 111 rir 111 • �� 1!I 111 111 111 1 i .0.10,; Choke and Kill Valves :�M, � ' �; ?,t jj• ��r 2.00' 2 1/18 5M w/Unibolt 4.iii grit iir iir iit rn` connections for hoses .. nt ni ni ut III1.58' i, DOD.* Riser,13 5/8 5M API hub X 135/85M FE Upper Wellhead Room to Dell Dock 21 BT TI<.sr a.mp.now noo. Upper"ennead room floor Riser,13 5/8 5M FE X 135/8 5M API hub it ill Wellhead floor to Upper Wenheed . iyi' 1 I'1'7J`= . y .G 22 8n I II�, L ; 4 0.50' 5.1 I„C { e `' �a1�. a tr 1 it Nis X1.1. girl hip '- • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25 105 2OAMC 25111, Development ❑r Exploratory❑ GINJ 0 WINJ❑ WAG El WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 7/21/2012 212-050 _ 3.Address: 6.Date Spudded: 13.API Number: 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 6/20/2012 50-733-20428-01 4a.Location of Well(Govemmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 975'FNL,519'FWL,Sec 33,T9N,R13W,S 7/6/2012 Trading Bay Unit M-29A Top of Productive Horizon: 8.KB(ft above MSL): 160 15.Field/Pool(s): 850'FSL, 1,406'FWL,Sec 28,T9N,R13W GL(ft above MSL): -183 McArthur River Field/ Total Depth: 9.Plug Back Depth(MD+ND): Middle Kenai G Oil&Hemlock Oil Pools 1,310'FWL,2,117'FNL,Sec 28,T9N,R13W 11,592'(MD)/9,663'(ND) 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x- 214137 y-2499527 Zone- 4 11,720'(MD)/9,696'(ND) Steelhead(ADL0018730) TPI: x- 215158.5 y-2501369.69 Zone- 4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x- 215092.9 y-2503520.3 Zone- 4 N/A N/A 18.Directional Survey: Yes [1 No El 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) 183 (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: See attached transmittal 8,228'(MD)/7,859'(ND) 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 26" 267 to 397 Surface 990' Surface 990' - - 16" 75 K-55 Surface 1,441' Surface 1,441' 20" 2200 sx 13-3/8" 61 &68 K-55 Surface 3,756' Surface 3,754' 14-3/4" 2200 sx 10-3/4" 51 &55.5 L-80 Surface 484' Surface 484' - - 9-5/8" 47&53.5 L-80 484' 8,228' 484' 7,859' 12-1/4" 730 ft3 7-5/8" 29.7 L-80 Surface 8,205' Surface 7,836' - r`6 L 4.4....t_ 7" 26 L-80 8,201' 11,713' 7,836' 9,694' 8-1/2" 685 ft3 @ 15.2-15.3 ppg 24.Open to production or injection? Yes J No❑ If Yes,list each 25. TUBING RECORD interval open(MD+ND of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) See Attached Schematic 3-1/2" 8,011' 8,201'(MD)/7,836'(ND) RECEIVED 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. t �!. 3C- N/A AEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AUG 2 2 2012 AOGCC '• '�` , raArA 27. PRODUCTION TEST Date First Production: 7/21/2012 Method of Operation(Flowing,gas lift,etc.): ESP Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/21/2012 24 Test Period 442 72 6680 163 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 80 20 24-Hour Rate — 442 V 72 6680 35 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No El Sidewall Cores Acquired? Yes❑ No 0 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 25.071. BBDMS AUG 2 3 20121_ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ?. Y•2-1.J-vim, in It original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑.r No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base See Attachement No.1 Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Paul Mazzolini Printed Name: Paul Mazzolini Title: Drilling Manager Signature: 4 L Phone: (907)777-8369 Date: 8/21/2012 ��00 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 b: 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 elevations 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 ND 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 . . II ATTACHMENT No. 1 Steelhead M-29A Tops API No. 50-733-20428-01 Jiikory Alaska,tIC Permit to Drill No. 212-050 WELL MARKER MD (ft) ND (ft) M-29A GIST 9,189.00 _ 8,689.70 M-29A G1SB 9,220.50 8,715.04 M-29A G2ST 9,241.50 8,731.94 M-29A G2SB 9,309.50 8,785.87 M-29A G3ST 9,326.50 8,799.06 M-29A G3SB 9,372.00 8,834.27 M-29A G4ST 9,394.00 8,850.92 M-29A G4SB 9,499.50 8,930.21 M-29A G5ST 9,514.00 8,940.91 M-29A _ G5SB 9,616.00 9,015.00 M-29A G6ST 9,634.00 9,027.85 M-29A G6SB 9,699.50 9,073.52 M-29A G7ST 9,729.00 9,093.75 M-29A G7SB 9,770.00 9,119.73 M-29A HKT 9,770.00 9,119.73 M-29A HK1T 9,788.50 9,131.22 M-29A HK1B 9,841.00 9,161.80 M-29A HK2T 9,880.00 9,182.48 M-29A HK2B 10,052.50 9,258.35 M-29A HK3T 10,062.50 9,261.84 M-29A HK3B 10,200.00 9,303.98 M-29A HK4T 10,200.00 9,303.98 M-29A HK4B 10,741.50 9,447.86 M-29A HK5T 10,753.00 9,451.04 M-29A HK5B 11,082.00 9,534.65 M-29A HK6T 11,085.00 9,535.40 M-29A HK6B 11,398.00 9,613.13 M-29A HK7T 11,438.00 9,623.03 M-29A HK7B 11,544.00 9,650.16 M-29A HKBM 11,588.00 9,661.59 M-29A WFT 11,588.00 9,661.59 M-29A WF1T 11,629.00 9,672.25 McArthur River Field,TBU II SCHEMATIC Well: M-29A ,,flon:Uue4..LLt: As Completed: 7/21/2012 RKB to TBG Head=40.73' Casing Detail Tree connection: SIZE WT GRADE CONN ID TOP BTM. J10-3/4"l 1 I r 26" 267 to 397 Drill Quip Surface 990' 26" 16" 75 K-55 BTC 15.124" Surface 1,441' 16" 13-3/8" 61&68 K-55 BTC 12.415" Surface 3,756' 10-3/4" 51&55.5 L-80 BTC 9.760" Surface 484' 13-3/8" 9-5/8" 47&53.5 L-80 AB Mod&BTC 8.535" 484' 8,228' 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875" Surface 8,205' 7" 26 L-80 BTC 6.276" 8,201' 11,713' Redrill 2012 Window cut in 9-5/8",43.5N,N-80 8,430' 8,467' Tubing Detail 3-1/2" 9.2 L-80 IBT 2.992" Surface 8,011' Jewelry Detail NO. Depth Length OD ID Item 132 1 40.73' Cameron 11"x 4-''A:"Tbg Hngr 2 8,011' 1.5' 3.65" 2.813" "X"Nipple 7-5/8"./" ' 4 3 8,012' 142' Max 5.85" N/A ESP Pump Top.Baker Hughes P110 w/816Hp Tandem Motor r. f Tir C46 4 8,154' N/A N/A N/A ESP Pump Bottom 9-518".0 illb 5 8,201' 28' Top Packer w/RS Profile Flex Lock liner Hangar 1"O __ V b L-° 6 8,205' 3' Baker Seal Assembly Perforations Zone Interval(MD) I Interval(TVD) Ft SPF Status G3 9,336' 9,372' 8,806' 8,834' 36 5 Open G-3 G4 9,402' 9,452' 8,857' 8,895' 50 5 Open G5 9,514' 9,616' 8,941' 9,015' 102 5 Open =G-4 /d y HK1 _ 9,790' 9,840' 9,132' 9,161' 50 5 Open HK3 10,070' 10,170' 9,264' 9,296' 100 5 Open =G-5i 10,202' 10,380' 9,305' 9,349' 178 5 Open HK4 10,410' 10,648' 9,356' 9,421' 238 5 Open =HK-1 10,690' 10,740' 9,433' 9,447' 50 5 Open HK5 10,754' 10,964' 9,451' 9,505' 210 5 Open =HK-3 HK6 11,184' 11,366' 9,560' 9,605' 182 5 Open HK7 11,448' 11,536' 9,626' 9,648' 88 5 Open HK-4 =HK-5 HK-6 HK-7 7" t •e TD=11,720' PBTD=11,592' Revised:8/20/2012 by TDF • Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 LTA Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 7/20/2012 To: AOGCC Makana Bender 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL M-29A Prints: C; M-29A MD VISION Service RM Composite Log 2"&5" M-29A TVD VISION Service RM Composite Log 2"&5" "M-29A Formation Log MD 2"=100 M-29A Formation Log ND 2"=100 AK M-29A LWD Combo Log MD 2"=100 Nod M-29A LWD Combo Log ND 2"=100 M-29A Gas Ratio Log MD 2"=100 M-29A Gas Ratio Log ND 2"=100 M-29A Drilling Dynamics MD 2"=100 .,,,M-29A Drilling Dynamics ND 2"=100 Hilcorp M-29A Final Well Report.doc Hilcorp M-29A Final Well Report.pdf M-29A Final Well Survey CD: Final Well Data DAILY REPORTS See CD DML DATA See CD FINAL WELL REPORT Hilcorp M-29A Final Well Report.doc Hilcorp M-29A Final Well Report.pdf LAS FILE M-29A.las LOG PDF FILES M-29AFormation Log MD.pdf mud), , M-29A Formation Log ND.pdf M-29A LWD Combo Log MD.pdf M-29A LWD Combo Log ND.pdf M-29A Gas Ratio Log MD.pdf M-29A Gas Ratio Log ND.pdf M-29A Drilling Dynamics MD.pdf M-29A Drilling Dynamics ND.pdf CD: Final Survey Data Final Well Survey.doc Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill&Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 06/20/2012-Wednesday Pick up BHA#6. Baker Window Master G2 system on torque master bottom trip anchor with Schlumberger MWD, shallow test MWD (ok). RIH slow to 8,312', kelly up. Orient whip stock 90L, continue RIH, set @8,452' DPM @75L, pull 15k over and check anchor set (ok),sheer off (ok). Change over to 2% KCL, clayseal/gem drilling mud @9.5 ppg with FIW returns to production and start milling on lug once mud rounds corner. Finish change over and mill window from 8,430'(top of window)to 8,467'.Circulate and balance MW for LOT/FIT. 06/21/2012-Thursday _Preform FIT to 12.07ppg EMW @8,467' MD and 8,067' TVD with 9.45 ppg mud with 1,100 psi. POOH to BHA. Stand back drill collar and check mills, window and middle watermelon mill 1/8" under top. Polish mill in gauge (ok) to 8,450'. RIH with 6-1/2" drill collar and lay 2c down same. Clear floor of BOT equipment. Service rig and attempt to repair hydraulic leak on line in derrick for top drive. Lay down and re configure combo test std while crane works boat. M/up. Kick off BHA#7 and shallow hole test equipment. RIH and fill pipe twice to 8,430'. OP Did note slight bobble at 4,180'. Kelly up, fill pipe, orient to 75L, slide thru window (ok) to 8,450'. Drill out of gauge hole to 8,467'. Time drill and kick-off drill per directional plan(P8). 06/22/2012-Friday Continue kick-off. Work ratty spot from 8,477' to 8,485'. Packing-off fire jars @50-75k over and straight pulls to 100k over to free pipe. In line full gauge stab @TOW. Dir drill 8-1/2" hole from 8,486' to 8,538' @13 bpm @1900 psi. Work ratty spot from 8,538' to 8,542', same as above fire jars to free pipe. ADN stab @8.19" @TOW, rotate and work string stab in to window. Dir drill from 8,542' to 8,640' and rotate through coals. P.I.G for 1st 24 hrs=6.95 FPH. 06/23/2012-Saturday Hanging up. Pump 53 bbl high vis sweep, attempt to clean up hole. Slide @90L from 8,640' to 8,656'. Rotate through coal from 8,656' to 8,665'. Slide @90L from 8,665' to 8,689'. Rotate from 8,689' to 8,784', pump 30 bbls sweep and connection. Attempt to slide after connection; unable to slide. Rotate from 8,784' to 8,827'. Slide from 8,827' to 8,829'. Rotate from 8,829' to 8,859', 48 hr P.I.G=7.54'. Slide from 8,859'to 8,880'. 06/24/2012-Sunday Rotate from 8,880' to 8,933' while making connection back out saver. Work pipe and re-torque saver sub. Slide from 8,933' to 8,949'. Rotate from 8,949' to 8,961'. Slide from 8,961' to 8,966'. Rotate from 8,966' to 8,992'. Slide from 8,992' to 9,007'. Rotate from 9,007' to ,/ 9,017'.Slide from 9,017'to 9,023'. Rotate from 9,023'to 9,026'.Slide from 9,026'to 9,029'. Rotate from 9,029'to 9,038'.Slide from 9,038' to 9,042'. Rotate from 9,042' to 9,046'. Slide from 9,046' to 9,051'. Rotate from 9,051' to 9,054'. Slide from 9,054' to 9,060'. Rotate from 9,060' to 9065', pump 30 bbl high vis sweep around. POOH to 8,417 with no problems. 72 hr P.I.G=8.3' FPH.Turn kelly hose, check#2 MP brushes,service rig. RIH, kelly up,wash last stand bottom. Rotate from 9,065'to 9,075'. 06/25/2012-Monday Rotate from 9,075' to 9,100'. Slide from 9,100' to 9,113'. Rotate from 9,113' to 9,118'. Slide from 9,118' to 9,134'. POOH to window with no problems. Monitor static hole (ok), clean floor (estimated seepage loss rate .13 BPH). Pump dry job and POOH to BHA. Work BHA, remove source, lay down ADN,stab in (wear on bolts)and ARC and down load. Lay down string, stab(1/4" out), lay down mud motor(stab 1/16"out)and bit 7/16"out.Clean floor, Pick up BHA#8 rotary steerable. Page 1 of 7 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill&Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 06/26/2012-Tuesday Continue p/up BHA #8 rotary steerable and surface test (ok), p/up smart tools. Install source and shallow hole test (ok). RIH to 6,512'. service top drive. Continue RIH to window 8,408' and fill pipe. RIOH to 8,750' with no problems. Kelly up and safety ream from 8,750' to 9,012' @+-500' FPH. Ream under guage hole from 9,012' to 9,034'. Drill dir 8-1/2" hole with rotary steerable, pump &dump sweep every 2 stands. Running high weight and low rpm and not getting build rate to hit target, call town. Discuss hard or soft target, continue drilling, work parameters for build. Sacfificing ROP to 9,350'. Mud loggers gas trap lost power, work pipe trouble, shoot and repair same. Continue drill 8-1/2" hole with rotary steerable work parameters for maximum build from 9,350' to 9,636', 12 hr P.I.G = 41.8 fph. Circulate clean for short trip. 06/27/2012-Wednesday Drill 8 1/2 hole with Rotary Steerable from 9635 to 9730. ; Circulate and condition ; POOH for BHA from 9730 to Window @ 8430. (no overpulls) ; Monitor well @ Window (good). Slug pipe. ; Continue to POOH w/BHA #8 from 8430 to 2850 ; Trip Drill. POOH f/2850 to HWDP @ 825'. ; Work BHA. Rack back HWDP, jars & DCs. Lay down Directional tools ; Remove RA Source, download data from LWD, inspect and grade bit. ; M/U BHA #9 w/Hughes MX-18DX Insert Bit. M/U Mud Mtr and adjust AKO to 1.83 deg ; TIH with HWDP to 805. M/U TD and shallow test MWD (good) ; TIH with BHA#9 on 5" Dp f/805 to 8430. Fill pipe every 2500 ft. ; Fill pipe and orient bit to high side @ Window. Service Rig. ;TIH f/8430 to 9615. Wash and ream to 9730. ;Set down on obstructions @ 9170&9575. Orient to High side & wash down. ; Check survey @ 9708. Pump 30 bbl high vis sweep and orient to high side. ; UP 290k, DN 235k, 2200 psi @ 13.5 bpm ; Slide drill from 9730 to 9762 @ 360 deg. ; Rotary drill from 9762 to 9777.40 rpm= 11k tq. (Bit rpm=202 06/28/2012-Thursday Slide and Rotary drill from 9777 to 9956 to build angle. (30 ft/hr P.I.G); Pump 30 bbl high vis sweep @ 9903. AST 3.68 hrs, ART 2.01 hrs, ADT 5.69 hrs ; UP 290k, DN 225k, ROT 250k, 40 RPM , 12k tq. 13.8 bpm = 2050 psi. ; Slide/Rotary drill from 9956 to 10,216 to build angle. (22 ft/hr P.I.G) ; Work tight spot from 10,135 to 10,145 (bit depth). ; Stalling rotation with Stabilizer @ 10,082 to 10,092 ;Slide/Rotary drill from 10,216 to 10,320 (18 ft/hr P.I.G) ; UP 295, DN 230, ROT 255, TQ 12k @ 60 RPM, 47 ft/hr Ave ROP ;Annular pressures: 13 3/8"-550, 16"-530,20"-240,26"-160 Spill Drill 06/29/2012-Friday Slide/Rotary drill from 10,336 to 10,434, maintain angle with minimal slides ; UP 290, DN 230, ROT 255, TQ 11k to 15k @ 80 RPM, 13.5 bpm, 2150 psi ; Increased difficulty sliding and stalling rotation w/o pressure increase. ; Bit appears to be losing gauge, causing tq on stabilizer. ; Pump 40 bbl high vis weighted sweep. Circ & cond for trip ; Sweep returned @ calculated volume w/100% increase in ctgs/cavings ; Pump up survey. Flow check well and fill Trip tanks. ; POOH from 10,434 to Casing window @ 8430 with BHA#9 (straight pull);Worked thru tight hole from 9705 to 9630 (Siltstone &small Coal)45k over; Monitor Well. Change Elevators to tripping style (non-. teflon insert) Pump Slug; POOH from 8430 to BHA @ 805. (3.6 bbls over calc displ on trip out) ; BHA: Rack back HWDP, L/D Hyd Jars and P/U Combo Hyd/Bump Jar ; Stand back DCs, L/D MWD, Stab, ARC 675 & Mud Motor ; Inspect and grade Bit. Bit is 5/16 under gauge, w/shirttail damage. ; Inline Stab and Motor Stab are unchanged (8 3/8 OD) ; MU BHA#10: Hughes QD506X, Power Drive, ARC 675, Stab, MWD,ADN 675&DCs; Load RA Source and RIH w/HWDP. Fill pipe and test Power Drive; TIH with BHA#10 on 5" DP from 825'to 4690 Page 2 of 7 11 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill& Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 06/30/2012-Saturday TIH with BHA #10 from 4690 to Casing window @ 8430. Fill pipe every 2500' ; Slip and cut 136' of Drilling Line. Service rig ; TIH f/8430 t/9835. Set dn on obstruction w/20k. (15k dn drag from 9230 to 9260) ; M/U Top Drive and break circulation. ;Attempt to wash and ream from 9835 @ 60 rpm, 12.5 bpm. Packing off and stalling. ; Stop rotation. Increase PR to 14 bpm & wash dn w/o rotation. ; Clean out cuttings bed from 9835 to 9920. Back ream std to pass freely ; Continue to wash/ream as needed to clean dog legs where dir. correction was made;Clean out ctgs beds and dgls to 10,020. Hole unloaded significant solids;TIH from 10,020 to 10,113. Safety Ream from 10,113 to 10,434 ; Ream under gauge hole from 10,388 to 10,434. ; Down load command to Power Drive while reaming to TD. ; Drill 8 1/2 hole with Rotary Steerable from 10,434 to 10,566 ; Run lite wt initially to break in bit and establish cut pattern. ; UP 295, DN 235, 14.3 bpm, 2250 psi, 120 - 160 RPM, 12k-17k Tq. ; Schlumberger having intermitten communication from Power Drive. ; Continue drilling from 10,566. Vary parameters attempting to increase P-rate. ; Well taking 10 bph losses. Unable to make footage. Ream std from 10566 to 10480 ; Run 10k WOB @ 160 RPM, able to get increase in Tq to 20k as if cutting structure ;Attempt to add WOB, but Tq decreases as wt to bit is increased 07/01/2012-Sunday POOH for Bit/BHA from 10,567. MADD PASS previously drilled interval on trip out ; MADD PASS f/TD to 9540 @ 300 ft/hr while backreaming @ 120 RPM & pumping 14 bpm ; Encountered tight spots @ 10,033, 9853 thru 9835 &9645 ; Continue to Back ream out of hole f/9540 @ higher rate to clean out cuttings bed ;Work tight hole while back reaming from 9200 to 9130. ; Packing off, forced to Jar dn to free pipe. Pump out an additional stand to 9060 ;Straight pull BHA through Casing window with no problem. ;CBU @ Window pumping 14.5 bpm & Rotating @ 120 rpm ; Casing unloaded a significant amount of cuttings/caving's; Circulate until clean. Flow check Well and pump Slug. ; POOH with BHA#10 from 8430 for Bit change and BHA inspection. ; BHA: Rack back HWDP and remove RA Source. Lay down Smart Tools and download same ; Lay down Power Drive and inspect Bit. Bit was cored and 1/16 under gauge ; Bit Grade: 8,3,CR,C,X,1,CT,PR ;Clear floor of slip/trip hazards and stage tools for BHA#11 ; Make up BHA#11 with Security Rock Bit and 1.5 deg Mud Motor. ; Pick up Smart Tools and TIH w/HWDP. Shallow test BHA @ 910' ; TIH with BHA#11 on Dp f/910 to Casing Window @ 8430. Fill pipe+/-2500' 07/02/2012-Monday Fill pipe and service Rig while in Casing window @ 8430. Orient to High side. ;TIH from 8430 to 9075 (tag obstruction) Brk Circ. Rot @ 20 rpm & wash @ 3 bpm ; Work pipe to pass obstructions and tight hole from 9075 to 9830 ; Trouble spots: 9070, 9177, 9200-9260, 9480, 9510-9570, 9740-9755 ; Orient 20L, Slide stand#96 thru Dir. correction Dgls f/9830 t/9925 (10-15k drag;TIH from 9925 to TD @ 10567. ; Break Circ. Pump up check survey. Pump 30 bbl high vis sweep. Fan bottom. ; UP 300, DN 235, ROT 265, 15k tq @ 100 rpm, 13.5 bpm, 2250 psi ; Rotary drill with Motor assembly from 10,567 to 10,709 (20 bph PIG) ; Slide Drill from 10,709 to 10,724 ; Rotary drill from 10,724 to 10,750 ; Slide drill from 10,750 to 10,765 ; Rotary drill from 10,765 to 10,778 ; Slide drill from 10,778 to 10,788 ; Rotary drill from 10,788 to 10,813 ; Slide drill from 10,813 to 10,823 ; Rotary drill from 10,823 to 10,844 ; Slide drill from 10,844 to 10,859 ; Rotary ---------.,.--- drill from 10,859 to 10,872; Slide drill from 10,872 to 10,885; Rotary drill from 10,885 to 10,905 Losses=5 bph Av ROP=27 ft/hr Page 3 of 7 • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill& Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 07/03/2012-Tuesday Rotary drill from 10,905 to 10,939. 80 RPM, 13.5 bpm, 2250 psi 14-16k tq ; Slide drill from 10,939 to 10,950 ; Rotary drill from 10,950 to 11,246' Torque increased f/15k to 18k. ; Pump 30 bbl high vis sweep. Circ Well Bore x 1.5, 15 bpm, 2800 psi, 130 RPM ; 100% cuttings/cavings increase when sweep returned. Pump survey. Flow check Well; Notified AOGCC of intent to test BOP Jim Regg waived to witness test. ; POOH from 11246 to casing window @ 8430. Straight pull to 9858 (tight) 50k over ; UP 320, DN 235, ROT 260, ; Pump out of hole w/o rot.f/9910 t/9820 Straight pull remainder of OH to 8430 ; Flow check Well. Pump Slug; POOH from 8430 with BHA#11 for Bit and BOP test. ; Lost 119 bbls to Well bore in last 24 hours. (5 bph) 07/4/2012-Wednesday POOH from 3200' with 5" Dp. to BHA @ 829' ; BHA: Rack HWDP&Jars, Remove RA Source and Lay down Smart Tools f/downlink; Inspect and grade bit.5,3,WT,A,E,I,CT,PR Well took 23 bbls over calc displ. ; Clear Rig Floor of tools and slip/trip hazards. ; Pull Wear Bushing. Install Test Plug. Fill BOP with water, purge air from system ; Rig up test lines and equipment for testing BOPs. ;Test BOP and related equipment to 250 psi low/4000 psi high. ; Test Annular to 250/3000 psi. Hold all tests for 5 min and chart record same. ; Perform Accumulator pre-charge test.Test LEL and H2S gas alarms. ; Pull Test Plug, Install Wear Bushing, RD test equip. Clear floor. ; Stage BHA components and prep to M/U same. ; M/U BHA#12: Security Insert Bit, 1.5 deg Mtr, Stab,XO,ARC, Stab, MWD, ADN ; (2) Flex DCs, Saver sub, (6) HWDP, Combo Jar&(15) HWDP. Shallow test same;TIH w/5" Dp from 830 to Casing Window @ 8430. Fill pipe+/-2500' ;Change Saver Sub on TDS-3, service rig and fill pipe.;TIH from Window to 11,246. 07/5/2012-Thursday TIH to TD @ 11,246 with BHA#12. Wash thru tight spots @ 9574, 9855 & 10690. ; Pump Hi Vis sweep. Rotary drill with lite wt to brk in bit and estab cut pattern ; Drill from 11,246 to 11287. 80 rpm, 15-16k tq, 600 gpm, 2350 psi ; Slide drill from 11287 to 11317 @ 90L to correct toward planned target. ; Rotary drill f/11317 to 11564 (av ROP = 26 ft/hr) Entered base Shale +/- 11,547 ; UP 305, DN 230, ROT 265, TQ 15-18k @ 80 RPM, WOB 25k, 2450 psi @ 13.75 BPM.;Continue to Rotary drill Rat Hole from 11,564 to 11,605 jc) 07/6/2012-Friday Continue to Rotary drill Rat Hole in WF1T from 11605 to TD 11720. / al Survey; Pump 30 bbl high vis sweep. Circ STS. Sweep returned 90 bbl over calc displ. ; Short trip from 11720 to 9925. Seve 150 ,-overpulls in new hole. TIH to TD ; Pump high vis sweep and circ to surface. Sweep returned 95 bbls over calc displ ; 350 units of gas from B/U. CBU x 4 to clear shakers ; UP 325, DN 235, ROT 18k @ 130 RPM, 2450 psi @ 13.5 BPM,Ave 5 bph losses ;Straight pull from 11720 to 10,030. No significant overpulls. ; Pump out of hole f/10,030 to 8800'to clear ctgs beds. ; Packing off if pulled too quickly @ 9755 and 9720 07/7/2012-Saturday Continue to Pump out of hole from 8800' to Casing Window @ 8430. ; CBU to clear ctgs from Casing. Pump Slug and drop 2.90" Drift on 100' of wire; POOH from 8430 to BHA @ 830'. ; Rack back HWDP and L/D Jars. Remove Source and L/D SLB tools. Recover Drift. ;Security Insert Bit was in good condition, but (1) bad seal. 3,3,WT,A,F,1,CT,TD ; Clear floor of SLB tools and slip/trip hazards. ; Pick up Baker Rotating Cement Head and change to upgraded Swivel. ; Make up 10' Pup to top & 30' joint to bottom. Stage in Mouse Hole & secure same. ; Rig up Weatherford Casing Equipment and prep floor for running 7" Liner. ; PJSM with crews. M/U Shoe Track and Baker Lock connections. ; Weatherford Reamer Shoe, Joint, Joint, Weatherford Flt Collar, joint, LC, Joint. ; Fill Shoe Track with mud and verify operation of Floats. ; Pick up and TIH w/7" 26#, L-80, BTC Liner from 167' to 3485. (86 jts total) ; Make up Baker Flex-Lock Liner Hanger w/ ZXP and PBR. Install Wiper Plug.; Mix and install Pal Mix Allow to set up f/30 min.TIH w/2 stds HWDP; Pump Liner volume x 1.5, 5 bpm, 250 psi. UP 145k, DN 141k; TIH with 7" Liner on 5" HWDP f/3512 t/4145 Page 4 of 7 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill&Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 07/8/2012-Sunday TIH with 7" Liner, Hanger, ZXP Packer and PBR on 5" Dp. Fill every 10 stands. ;Circ and cond Liner vol x 1.5, 6 bpm, 550 psi ; UP 265k, DN 238k, ROT 250,TQ 7,000 @ 20 RPM. ;TIH from Window @ 8430 to TD @ 11,720. ;Work pipe, circulate& Ream as necessary to pass tight spots/obstructions ;Trouble spots @ 9200 -9228, 9393, 9535 -9550, 9871 -9885. ; Drag increased substantially for 11,400 to TD ; Make up Cement Head w/single and pup. M/U Cement hose and secure same ; Circ. &Cond., Brk circ @ 2 bpm and stage slowly to 7 bpm, 990 psi. ; Hole taking 5 bph. Pre-treat mud for Cement and work to drop YP f/40 to 26. ; Recorded 550 units of Gas @ bottoms up. UP 325, DN 210, ROT 255. ; PJSM with Rig and Cement crews. Install wash up hose on Cement Head Swivel. ; SLB pumped 5 bbls of FIW. Shut in @ Cement head. PT lines to 1000/5000 psi ; Rig pumped 35 bbls of 12.0 ppg Mud Push II. SLB began mixing Slurry to wt. ; Pump 126 bbls of,- 15.3_ppg Class G cement. (509 sx w/75.5 bbl FIW); Displace Slurry with Rig Pump @ 8 bpm, 250 psi. ;Slow to 3 bpm and witness Dp Wiper latch Liner Wiper. Adjust stroke count. •Bump LC with 259 bbl displacement. FCP = 1100 psi @ 2 bpm. CIP @ 01:10 ; Increase pressure to 2500. Bleed psi and check floats (OK) ; Lost 11 bbls during cement job. Rotate and reciprocte throughout job. ; Pull Liner to tension. Set Hanger with 2800 psi. Release f/Hanger with 4500 psi;Set ZXP with 50,000 do wt. Est rotation and set down w/100k to finalize set; Psi up to 500. Pull Slick Stinger until pressure dropped. Initiate circulation ;CBU @ 15 bpm to clear excess cement. No Cement and minimal Mud Push @ BU. ; RD Cement lines and set Plug Dropping head w/single in mouse hole.; POOH with DP and Running Tool from 8205. 04 IA 07/09/2012-Monday POOH with 5" Dp and Liner Running TOOL from 3791 to 637 ; Lay down 21 joints of 5" HWDP and Liner Running Tool. ; Break down Rotating Cement Head, Single and Pup Jt. ; Make up BOP Wash Tool. Wash debris and possible cement from Well Head to Annular; Break down 7" Test Stand and M/U 7 5/8" Test Stand. ; Clean Pits, Drip Pan and flush Flow Line in preparation for FIW displacement. ; Rig up Pollard E-Line unit. RIH and perform Temperature-survey to determine TOC. ; POOH and rig down Pollard equipment. Top of Cement found @ 9250. ; Pull Wear Bushing. Install Test Plug. Change Lower Rams from 7" to 4 1/2" ; Test 4 1/2 Lower Rams to 250/4000 psi. Attempt to test Annular on 4 1/2 Tets Jt ; Annular failed test. Drain fluid. Witness leakage by Element w/max closing psi ; Rig down test equipment and rack back test stand. ; Remove Flow Nipple and Master Bushings. Remove Annular Cap.Change Element 07/10/2012-Tuesday Continue to Change out the Annular Element. ; Element was separated and missing large chunks on back side. ; Install Flanged Air Boot and Flow Nipple; Pressure test Annular on 4 1/2" Test Jt to 250/3000 psi w/800 psi closing psi. ; Pull test plug. Install Wear Bushing. Break and lay down test stand. ; Make up 6" Bit to 7"Scraper/Magnet/Brush combo tool. ; TIH w/ 36 stands of 4 1/2" 563 Hydril Tubing from Derrick ; Make up Baker PBR Polish Mill and Swaco 9 5/8 Scraper/Magnet/Brush assembly ;TIH with Tandem Scraper assy. on 5" Dp from 3403 to 5963. Fill pipe every 2500' ; Make up Baker 9 5/8" Scraper & XOs. ; Continue to TIH with Scraper assy from 5963 to 11,466 ; Witnessed small increase in drag when 7" Scraper entered TOL ; and when 9 5/8" Scraper enterd 53.5# Casing. ; Break circulation and record parameters. UP 255k, DN 207k, Rot 240k ; Clean out PBR with Polish Mill. No-Go tagged TOL @ 8200.5 ; CBU. Dump 18 bbls of Cement contaminated mud. ; Pressure test Casing and Liner Lap to 1500 psi for 30 min. Chart record test. ; Displace Well Bore from 9.5 ppg Mud to 8.5 ppg Filtered Sea Water. 07/11/2012-Wednesday Displace well bore from 9.5 ppg mud to 8.5 ppg FIW. TOH from 11560' to 8205'. ;TIH from 8205' to 11570'. Tag liner top @ 8200' ;Clean out mud system. Flush stand pipe manifold, choke manifold and degasser ; with water. ; Circulate well bore with FIW @ 6 BPM/450psi while rotating @ 70 RPM to clean ; hole. Pump wash train and divert to pits @ 4-6BPM/ 275-450 psi. ; POOH from 11570'. P/U 280K S/0 210K 07/12/2012-Thursday POOH from 2783' to BHA. L/D scraper and magnet. ; Change out top pipe rams from 5" to 7 5/8". ; M/U test joint. Test rams @ 250L/4000H and chart. L/D test joint and tools. ; Rig up Weatherford equipment to run casing. R/U casing bales. Hold PJSM. ; RIH picking up 7 5/8"VAM-SLID-11 casing. Had to change out 1 jt.due to threads Page 5 of 7 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date • M-29A-Redrill& Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 07/13/2012-Friday RIH P/U 7 5/8" VAM-SLID-11 casing from 5852' to 6630'. ; Service rig, iron roughneck and top drive. Continue running 7 5/8" casing from 6630' to 8125'. ; P/U 3 additional joints/screw into top drive. 295 P/U 250 S/O. Pump at 1 BPM ;while stinging into liner top. Saw increase in psi @ 8197'. Shut down pump. Tag ; with 'no-go' @ 8205'. Test seal @ 1000 psi / 5 minutes. ; Lay down 3 joints. M/U casing hanger, space out pup and landing joints. ; R/U and reverse circulate 1% corrosion inhibitor into 9 5/8" x 7 5/8" annulus. ; Land casing hanger. Observed seals engaging tie-back. Run in lock down screws ; Landed casing hanger @ 240K. ; Test seal assembly, 7 5/8" and 7" casing @ 3000 psi/30 minutes. ; R/D landing joint, casing tongs&equipment. Clear rig floor. ;Change out bales and R/U to run storm packer. ; 1P/U 9 ea. 6 1/2" drill collars, storm packer and 3 1/2" drill pipe. Set packer' ; @ 186'. POOH and rack back 3 1/2" DP. ; N/D flow nipple and BOP's for installing tubing spool. iy \ - 07/14/2012-Saturday Pump out stack and riser. Nipple down BOP's and riser. ; Install tubing spool. Dummy run with test plug. Test pack-off @ 5000 psi/15 ; minutes. ; N/U BOPE, choke and kill line. ; Change upper pipe rams to 3 1/2". ; Function test BOPE. Install bell nipple. R/U test joint. ;Test BOPE.Annular preventer @ 250L/3000H. All other components @ 250L/4000H. ;Guy Schwartz (AOGCC) waived witness @ 1120 hrs on 7- 13-12. 07/15/2012-Sunday R/D test equipment. Install wear bushing. Organize rig floor. ; RIH to 186'. Engage and release storm packer. ; POOH and L/D 3 1/2" DP, storm packer and 9 ea. 6 1/2" DC's. ; R/U Schlumberger wireline and lubricator joint for USIT log. ;SLB run USIT log. Not able to go deeper than 10,091' (+-71 deg). Held 1000 psi ; for log run. ; R/D Schlumberger E-line. ; Rig up to run TCP guns. Hold PJSM. Top shot will be @ 9336'_G3 zone,; RIH P/U TCP guns. M/U firing head&disconnect.; RIH picking up 3 1/2"9.2#L-80 IBT tubing. 07/16/2012-Monday RIH P/U 3 1/2" 9.2# L-80 IBT tubing. ;Tag top of landing collar @ 11592' with 5K set down on joint#297. Lay down two;joints to put guns on depth. 173K P/U 140K S/O ; R/U Pollard wireline for correlation run. Check depth. Move guns downhole 4.5'. ; Re-correlate. Guns on depth @ 11,539'. R/D Pollard. ; R/U lines to tubing. Hold PJSM. Fire perf guns @ 2350 hrs with 800 psi. *Perf ; Lay down 6' pup joint. Circulate one tubing volume @ 6.5 BPM/1900 psi. ; POOH to 10,943'. String U-tubing and flowing back up tubing. ; M/U floor valve. Circulate tubing and annulus volume @ 6.5 BPM/1800 psi. ; Monitor well for 15 minute static loss=30 BPH loss rate. ; POOH from 10,942' to 9320'. ; Obtain static loss rate @ 24 BPH. ; POOH from 9320'to 6200'with spent perf guns. 07/17/2012-Tuesday POOH with spent perf guns standing back 3 1/2" tubing. ; Lay down spent perf guns. All shots fired. ; Pull wear bushing. ; Slip and cut drill line. ;Service rig and equipment.; Rig up Centrilift and equipment to run ESP.; Hold PJSM. P/U M/U ESP assembly.; Fluid loss= 12 BPH 07/18/2012-Wednesday _PLU-M/U ESP assembly. Check drift of flat pack/super bands to ID of 7 5/8" ; casing. Consult with town and decide to wait on Cannon clamps. ; Tie in discharge pressure line and chemical lines. Fill same and check. ; Service rig. Adjust weight in rig tong counter balance. Troubleshoot #2 mud pump ; PRV. Service accumulator/filter fluid. Grease tong sheaves. Inventory shaker ; screens. Clean mud pump suction screens.; Fluid loss rate=12 BPH Total fluid loss=+-648 bbls since perfing. Page 6 of 7 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill& Run ESP 50-733-20428-01-00 212-050 6/7/12 7/21/12 Daily Operations: 07/19/2012-Thursday Build weight for casing fill up line. Remove Jet Heat controller. Housekeeping. ;R/U ESP sheaves. Fill seals with oil&tie in motor lead. P/U pumps, discharge ; head. Remove 4' pup due to MLE being too short. Finish dressing ESP. ; RIH with ESP with stands out of derrick to 5460'. ;Change out cable spools and make splice @ 5460'. ; RIH with ESP with stands out of derrick from 5460'. ; Meg test/control line test every 1000'. Fluid loss rate= 10 BPH.Total loss to; well =896 bbls. 07/20/2012-Friday RIH with ESP with stands out of derrick from 5460' to 8084'. ; M/U hanger and landing joint. Make final splice and tie in lines through tubing ; tubing hanger. Conduct meg, continuity and sensor test. All good. ; Land hanger. P/U 165K 5/0 145K ESP set @ 8154.5 ; R/D ESP sheaves and clear floor. ; N/D BOP's and set back same. ; N/D risers and set on drill deck. ; N/U tree, wing valves and flow lines. ;Test tree 500L/3800H w/production witness. ; Lay down excess 3 1/2" tubing stood back in derrick. ;Total fluid loss to well bore: FIW= 1230 bbls, Drill mud=625 bbls. 07/21/2012-Saturday Lay down 3 1/2" tubing out of derrick. ; R/D tubing tongs and clear rig floor. ; Repair/replace link adapter support plate on TDS. ; Prepare rig for rig skid over M-31. ; Skid rig. Cut out floor grating in cellar to accomodate vibrator and deluge ; lines. Spot rig over hole. Connect vibrator hose and deluge lines. 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K§k§§ )§ ? } V k4gm| Sq §2B§e §§ I ta w m co m.. q , #Jdk%8 ' .,[22 §_ 22��■ \ oo-m■ & 3 §\92®\ p` kkkk) /2 0 °® ;;m@@ s@ i ■� kmlm§ q . g ..... 2 §kHI §� m 2 U"" ) 2 °mm7q «� k ®qK§§§ km■mm mm $ k§§!k§ 2 S' ®//// vi \ !'§§§K§K o2§§ak • W a , ma ((§/§ k( 9 ci 6 f ui \§ k ! rE \ § // { (, _ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: August 03, 2012 P. I. Supervisor "RI FROM: John Crisp, SUBJECT: No Flow Test Petroleum Inspector Steelhead Platform Trading Bay Unit M-29A PTD # 2120500 August 03, 2012: I traveled to Hilcorp Alaska's Steelhead Platform to witness SVS tests & to witness AOGCC witness required no flow test on M-29A ESP completion. When I arrived on the Platform I witnessed well M-29A rigged up with no flow equipment required by AOGCC Guidance Bulletin 10-004, Appendix A. No flow of gas or liquid could be seen from a temporary flow hose taken outside the well room to a pail of water. I witnessed this for 2 hours. Well was shut in for 1 1/2 hours to observe tubing pressure build up. No pressure build up occurred in the 1 'A hour shut in period. Well M-29A was then opened up to a pail of water to observe possible gas flow. Slight bubbling was observed but no flow could be measured with Armor flow methane flow meter S/N 991632. This flow test was witnessed for 1 hour. Summary: Successful No Flow performed & witnessed on Steelhead Platform, Trading Bay Unit M-29A as per no flow test procedure. Attachments: none Non-Confidential 2012-0803 No_Flow_TBU_M-29A_jc Tack Ai(-Zq 4 r -iJ Zi Zost%o Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, July 06, 2012 12:24 PM j l 7/(0't v To: 'Mike Leslie' Cc: Schwartz, Guy L (DOA); Luke Keller; Paul Mazzolini; 'Shane Hauck' Subject: RE: Kuukpik 51 06-08-12.xls Mike— As we discussed yesterday,there is some confusion about the BOPE test frequency for Rig 51 on Steelhead platform. The permit to drill for TBU M-29A required 7 day BOPE testing frequency even though regulations allow interval not to exceed 14days between tests when drilling a development well. Guy Schwartz and I have discussed and are not entirely sure how we managed to impose the more restrictive test cycle. The AOGCC does impose 7-day testing frequency on new rigs and poor performers, but none of those appear to be the case here. Confusion about the rig contract transitioning from Nabors to Kuukpik might have led to this, although Hilcorp has performed 2 workovers and 5 BOPE tests with acceptable results since restarting work with Kuukpik on Rig 51. I may also have misunderstood the scope of your request on June 11 (email message below) regarding when to start BOPE test cycle for drilling of M-29A (after completing plugback of M-29). I checked with our Commissioners and am providing the following clarification for testing BOPE on Steelhead platform rig#51 while drilling TBU M-29A (PTD 2120500): BOPE shall be tested at intervals not to exceed 14 days between tests as provided in 20 AAC 25.035(e)(10)(A) ✓ AOGCC is not requiring Hilcorp to provide any follow up paperwork regarding this clarification. I apologize for the confusion. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Monday, June 11, 2012 11:06 AM To: 'Mike Leslie' Subject: RE: Kuukpik 51 06-08-12.xls You can start 14day clock today. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Mike Leslie [mailto:gleslie@hilcorp.com] Sent: Monday, June 11, 2012 11:05 AM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: Kuukpik 51 06-08-12.xls 1 • Thanks for the prompt reply Jim, I was just about to send it to you. I do have a question for you. We are still on a weekly test schedule,so do I start the clock from the finish of today's tests, or from when we finished on 6-842? From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Monday, June 11, 2012 10:58 AM To: Mike Leslie Cc: Brooks, Phoebe L (DOA) Subject: RE: Kuukpik 51 06-08-12.xls It is not necessary to send the test report after changing UPR to 5" since it is not a complete BOPE test. Just keep charts in your files and document test in daily drilling rpt, which should be available for inspection upon request. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Mike Leslie [mailto:gleslie@hilcorp.com] Sent: Monday, June 11, 2012 10:44 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: Kuukpik 51 06-08-12.xls Mr. Regg, I understand your confusion after reading my report. I neglected to change the Ram size prior to sending out the report. We tested 4.5" Rams and then pulled 4.5" completion. We changed the 4.5" Rams in the Upper cavity early this morning to 5" and then tested them and the 5" Lower Rams to 250/5000 psi. We also retested the Annular on the 5"Test joint this morning. I'll send the updated Test report reflecting this morning's tests soon. I apologize for the confusion I've caused, Mike Leslie Drilling Foreman Hilcorp Energy Alaska Steelhead: 907-776-6833 Mobile: 907-382-3057 gleslie@hilcorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, June 11, 2012 9:11 AM To: Mike Leslie Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA) Subject: RE: Kuukpik 51 06-08-12.xls 2 I'm confused by Remarks and ram comiguration. You are pulling 4.5" completion bui did not test any rams to cover that pipe size. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Mike Leslie [mailto:gleslie(ahilcorp.com] Sent: Friday, June 08, 2012 5:22 PM To: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); Regg, James B (DOA) Cc: Paul Mazzolini; Luke Keller; Shane Hauck Subject: Kuukpik 51 06-08-12.xls 3 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A-Redrill & Run ESP 50-73320428-01-00 212050 6/7/12 Daily Operations: 06/13/2012 -Wednesday Engage ESP Fish @8,742'. Jar down with bumper sub, jar up with oil jars @40k. Work pipe and stage up over pulls/jar impact. Work from 40k to 150k over UP weight. Stack 40k on fish, shut in Ann and bullhead against obstruction with 1,500 psi. Resume jarring operations. Jar w/150k over, then straight pull to 170k over UP weight. Lost weight after jars fired. POOH slow & wet w/5-8k extra weight. Work BHA (braking out new driller).Tap plugged fish above & below each collar and relieve pressure. Fish full of sand. 06/14/2012-Thursday Finish lay down fish. Vacuum and power wash rig floor. Pick up over shot and remove cut-off. Total 160.87' recovered. Estimate top of fish @8,919'. Service rig and monitor well; zero static losses. Pick up BHA#3 = 8-1/8" cut lip guide O/s, plus ext dressed w/6.750' basket grapple & control, plus 6-1/4" B/S, plus 6-1/4" oil jar, plus pump-out sub, plus XO, plus (9) 6-1/2" DC, plus X, plus acc Jar = 321.75'. RIH to 8,519'. Kelly up, practice making connections with new driller. Establish parameters, t/tag @8,910' dpm. Circulate bottoms up @15-18 bpm, est bbl sand back, pump 25 bbl high vis pill around. Engage fish @8,910' and work to 8,920'. Jar on fish, fire jars @130k over with straight pull to 200k over. Grapple slipped off and unable to re-engage motor hole (no change). POOH to check tools. 06/15/2012- Friday Work BHA & check tools, small ball of control line in top of extension & grapple. Control gone (looks like it was pulled thru 0/5), service rig & inspect equipment. L/dn BHA #3 change out all jars, 0/S & p/up 4-3/4" rat pack vibration tool. Attempt to test vibration tool (unable to get tool to operate). POOH & l/dn vibration tool & re-m/up BHA. RIH w/BHA#4 to 8,859'. Establish parameters, engage fish @ 8,919'. Set grapple and start fire jars @130k over and straight pulls to 200k over, 7 jar licks freed fish and pull up hole one STD. Circulate bottoms up and mointor well (same no losses). POOH working fish through up to 100k over pulls. L/dn fish, recovered last pump section at 13.72'. Sheered bolts to tandem seals. Section/est TOF @ 8,932.72' w/total of 53.19'fish still in hole. 06/16/2012-Saturday Lay down over shot BHA. RIH with 3 std 6-1/2" drill collar and lay down same. Clear and clean floor of Baker fishing equipment, prep and pick up 29 jts of 2-7/8" cement stinger. RIH with 2-7/8" cement stinger on Dp Tag TOF @8,930'. Circulate and build mud push and prep for cement job(PJSM for cement job). Test lines to 3,000 psi, rig pump 25 bbls 12 ppg mud push. Schlumberger mixed and pumped 36 bbls of 15.3 ppg cement, rig pump 4 bbls of 12.0 ppg mud push and rig displaced with 134 bbls FIW. POOH slow to 8,000'and lay 519' balanced cement plug, CIP @21:45. Pump Dp dart, circulate full round @10 bpm. POOH and lay down 2-7/8" cement stinger,service rig/WOC. 06/17/2012-Sunday WOC, service top drive, power wash/clean shakers and cutting chute, drain and cleans pits. Ship NPF to TBPF. Pick up BHA #5 and RIH to 4,103' bit depth and 4,086' window mill depth. Set down 20k at known tight spot, 20k pull out. Continue cleaning pits and shipping NPF to TBPF. Kelly up and ream 3' area and clean up same. Work pipe 30' with only 1k extra weight. Continue RIH with bit scraper and window mill (whipstock mimick assembly) to 6,481'. WOC, service rig, clean pits and rig. Continue building drilling mud. Continue RIH f/6,481' to 8,220'. Kelly up wash down tag at 8,388' c/out, rotate C/out green cement to 8,466', C/out hard cementt to 8,510' and circulate out, balance on connections. Circulate clean, pump 30 bbl high vis sweep around. Page 1 of 2 14 Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date M-29A- Redrill & Run ESP _ 50-73320428-01-00 212050 6/7/12 Daily Operations: 06/18/2012 - Monday Continue circulate clean, test 9-5/8" X 10-3/4" casing against 420' cement plug @8,510' dpm with 5.6 bbls to 1,520 psi to 1,502 psi in 30 min on chart. Rig up to reverse circulate with clean FIW and take returns to production. Reverse circulate with 800 bbls clean FIW @6 bpm, taking returns to production. Rig down lines and POOH to 4,800'. Lost fan belt on air conditioner in SCR room, repair same. Continue POOH to BHA. Work, check and lay down BHA. Rig up Schlumberger E- line. RIH with USIT log with C sub for 8.6" to 8,495' tie in and log for 8,495' to 480' at 3,000 FPH. Found 1 spot of intrest. Make high resolution pass across same, 4,250' to 3,900' @1000 FPH (found TOC @ 5720'). Lay down USIT tools and pick up Baker CIBP while wirelining. Continue house cleaning,cleaning pits, building drilling mud. 06/19/2012-Tuesday Finish p/up Baker 9-5/8" CIBP. RIH w/CIBP on Schlumberger E-line, tie in and set top of same at 8,442' WLM, POOH. Check setting tool (ok), rig down E-line. Finish cleaning shakers and install cutting chute hose. Rig up equipment to test BOPs. Chg btm rams to 7". Lock down pin leaking and test plug leaking, repair both. Test BOP per AOGCC regulations 250-4,000 psi. Rig down test equipment, install wear ring.Test casing to 1,590-1,579 psi in 30 min on chart. Page 2 of 2 „ , [E al ,,- -LansEn, \ � � I', ���� SEAN PARNELL, GOVERNOR LPL u ALASKA OIL ANI) GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Paul Mazzolini FAX (907)276-7542 Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99524 Re: McArthur River Field, Middle Kenai G & Hemlock Oil Pool, TBU M-29A Hilcorp Alaska, LLC Permit No: 212-050 (revised) Surface Location: 975' FNL, 519' FWL, SEC. 33, T9N, R13W, S Bottomhole Location: 2008' FNL, 1129' FWL, SEC. 28, T9N, R13W, S Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. Approval to produce is pursuant to Administrative Approval 80.087 (Conservation Order 80.087). Hilcorp Alaska, LLC 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 e 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. Sincerely, /a4te-L Cathy . Foerster Chair DATED this Lb day of May, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA MAY 0 9 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILLAOGCC i .EY 20 AAC 25.005 —�T��L-- 1_Li/S •-v- 1a Type of Work: lb.Proposed Well Class: Development-Oil ❑., -Service- W inj p Single Zone 1 c.Specify If well Is proposed for. r /. Drill ❑ Redrill .❑ Stratigraphic Test ❑ Development-Gas 0 Service-Supply ❑ Multiple Zone Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG 0 Service-Disp ❑ P°.:1' Shale Gas CI2.Operator Name: 5. Bond: Blanket Q Single Well ❑ ll N 11.Weame and Number: Hilcorp Alaska,LLC Bond No. 22035244 Trading Bay Unit M-29A 3 Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Anchorage AK,99524 MD: 11,902' . TVD: 9716 McArthur River Field/Middle Kenai 4a Location of Well(Governmental Section): 7.Property Designation(Lease Number): G Oil&Hemlock Oil Pool , Surface: 975'FNL,519'FWL,Sec 33,T9N,R13W,S . Steelhead(ADL0018730) Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 750'FSL,1440'FWL,Sec 28,T9N,R13W,S NA 6/10/2012 ' Total Depth: 2008'FNL,1129'FWL,Sec 28,T9N,R13W,S 9.Acres in Property: 14.Distance to Nearest Property: 3,840 ac >2,500' 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: - 160 feet 15.Distance to Nearest Well Open Surface: x- 214137 - y- 2499527 - Zone- 4 to Same Pool: G20-600 ft 16 Deviated wells: Kickoff depth: 8350 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 72.15 degrees Downhole: 4320 psi • Surface: 3313 psi 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Conductor Surface Int - - Prod 7" 26 L-80 BTC 3752 8150 7791.5 11902 9716 617 ft3 in 1 stage Tieback 7-5/8" 29.7 L-80 Vam SLIJ-II 8150 0 0 8150 7791.5 None 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill end Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): - Casing Length Size Cement Volume MD TVD Conductor/Structural 1,441.00 16 2200 sx 1441 1440 Surface 3,756.00 13-3/8" 2200 sx 3756 3754 Intermediate Production 8,966.00 9-5/8" 730 ft3 8966 8497 Liner Perforation Depth MD(ft): 9921'-12,211' Perforation Depth TVD(ft): 9160'-10,035' 20 Attachments: Property Plat Q BOP Sketch❑ Drilling Program D Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21 Verbal Approval: Commission Representative: Date 22 I hereby certify that the foregoing is true and correct. Contact Printed Name ?ALIO. IviAZZO I.4,4 I Title .2e4W NCO MilN/4`SR-- Signature �LLfwLPhone 701-777-831A Date 6508 i 2 ,012- ((( Commission Use Only Permit to Drill , r API Number: , ` a .t-/i. Permit Approval See cover letter for other Number: Z I !i J O 50 �� Y u Date: (i Z requirements. Conditions of approval: If box is checked,well may not be used to explor ,test,or produce coal✓ methane, s hydrates,or gas contained in shales:[r Other: 4 50007 ITN:, 45 Op TS IL ;K.{-i Samples req'd: Yes Wqo[ Mud log req'd: Yes ❑ No 12" ( f v 1 H2S measures: Yes No❑ Directional svy req'd: Yes L[ No 0 y�a� psi ��f J -,K V ley , x'P ?- C7J APPROVED BY THE COMMISSION DATE c—10 -1 Z W-4 /4L4.414,—._ ,COMMISSIONER 74- s- z ORIGINAL�o.� - - .\V Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate HilCorD Paul Mazzolini Hilcorp Alaska,LLC Baop Drilling Manager P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8369 5/8/2012 Email pmazzolini@hilcorp.com Commissioner Alaska Oil&Gas Conservation Commission RECEIVED 333 W. 7th Avenue Anchorage,Alaska 99501 MAY 0 9 2012 Re: Steelhead Platform,Trading Bay Unit M-29A AOGCC Dear Commissioner, Enclosed for review and approval is an amendment to the original 10-401 APD for well M-29A. BHL has been adjusted 1011' NW of the previously submitted APD. Changes from the original APD include: 1. 10-401 Permit to drill application. 2. Directional Plan&associated plots. 3. Surface plat showing wellpath with respect to lease boundaries. 4. Spider Plot Items above are attached with form 10-401 in duplicate. ,,�� A �re f-c- ...-. p r e Fri)i) /v If you have any questions or additional information is needed, please don't hesitate to contact myself at 777-8369 or Luke Keller at 777-8395(Ikeller@hilcorp.com). 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North Reference: True North Location Grid NE 710: N 2499527.160 RUS,E 214137.580RUS Grid Convergence Used: 006' CRS Grid Convergence Angle: -1.39901988' Total Corr Mag North-,True North: 17.476' Grid Scale Factor: 098899299 Local Coord Referenced To: Well Head Exoluabn Zone Comments MD Nei Azim True TVDSS TVD VSEL NS E6) 7F DLS Directional Exclusion Zone Angle Northing E(SUN) (e) 19 Cl (5) (8) (0) 041 (R) rl 7/1098)Dimculty/Mex Alert r1 (MS) (RUS) KBE 0.00 0.00 0.00 -180.25 000 000 0.03 000 296.2311 WA 0.00 16.33 499527.16 214137.58 100.. 0.15 296.23 -00.25 100.00 002 0.08 -0.12 207.698 0.15 009 1630 49952722 214137.46 200.03 008 207.63 3975 200.00 -003 0.05 -027 145.7511 1117 000 16.40 499527.22 214137.31 300.03 0.33 145.75 139.75 300.03 -0.28 .025 -0.14 158.5214 0.30 0.00 16.53 499526.92 214137.11 400.03 0.78 158.52 23974 388.99 -099 -1.12 027 190.284 0.46 024 1694 499526.04 214137.63 500.03 1.13 190.28 339.73 .9.98 -2.50 -272 0.35 2288214 0.62 0.74 17.45 499524.43 214137.88 800.03 1.17 228.82 439.71 59996 -4.35 -436 -0.60 232.5M 0.76 1.10 1734 49952281 214136.88 700.03 1.18 23250 53969 899.94 1.05 5.66 -2.18 233.919 0.06 1.26 17.30 49952155 214135.26 800.03 1.17 23390 63967 789.92 -7.71 .689 382 2239214 0.03 138 1728 499520.36 214133.59 •• 900.03 1.05 223.92 73965 88990 -9.35 -8.15 -528 207.97M 0.23 150 1727 499519.14 214132.10 1000.03 1.28 207.97 83963 899.88 -11.26 -9.80 1.44 710.7534 0.40 1.63 1759 49951752 214130.90 1100.03 2.25 21075 93958 1099.83 -14.27 -12.47 -7.97 212.2M 0.97 1.63 18.52 499514.89 21412931 1200.00 2.38 212.20 103950 1199.75 -18.18 -15.92 -10.06 214939 0.14 1.94 1864 49951109 214127.11 1300.03 2.15 21493 1139.42 1299.67 -21.97 -1921 -12.26 225.494 0.25 204 1839 499508.25 214124.85 1400.00 1.67 22545 123937 1399.62 -25.01 -21.77 -14.37 24.34 0.19 2.15 1782 499505.75 214122.68 1500.00 1.18 2430 1339.34 1499.59 -27.07 -23.30 -1631 255.35M 0.61 2.24 1721 499504.26 214120.71 • 1800.00 0.96 25835 143932 1599.57 -2828 -24.03 -1803 261.9M 0.39 229 1687 49950358 214118.97 1700.00 0.65 2644.90 153931 169956 -28.94 -24.90 -1912 254.1211 0.36 2.33 1659 49950334 214117.57 180.50 0.80 25412 1639.30 1799.55 -28.51 -24.54 -2066 257.07M 0.20 2.8 1678 499503.13 214118.33 1900.00 0.77 257.07 173929 18..54 -30.25 -2488 -21.98 249.429 0.05 2.36 1673 499502.82 214114.99 2000.00 0.73 249.42 183928 1998.53 -30.98 -2525 -2124 243.086 0.11 2.41 16.79 499502.4 214113.73 2100.00 077 24.08 1939.27 209952 -31.84 -25.78 -24.43 250.926 0.09 243 16.87 499501.98 21411253 2200.00 0.82 250.92 203926 2199.51 -32.73 -26.32 -2571 257.32M 0.12 2.4 1683 499501.48 21411124 2300.00 090 257.32 213925 2299.50 -33.54 -26.73 -27.15 250.0719 0.12 247 1680 499501.10 214109.79 2400.00 1.. 250.07 223923 239948 -34.71 -2737 -29.23 268.314 0.72 2.54 17.34 499500.51 214/07.69 2500.00 1.10 268.30 233920 2499.45 -35.92 -27.86 -31.550 328.711 0.85 2.59 16.72 4995.80.06 214105.41 2603.00 1.4 328.70 2439,18 2599.43 .35.42 -2686 -33.09 8579 1.28 2.67 15.44 499501.11 21410384 270000 197 8.57 2539.14 2699.39 .32.91 -24.12 -33.47 232254 1.27 2.75 14.38 499503.86 21410353 2800.00 2.83 23.22 2639.05 2799.30 .28.76 -20.15 -32.24 25264 1.05 2.82 13.51 490507.80 214104.85 2900.00 3.63 25.28 2738.89 2899.14 -23.17 -15.02 -2992 3469 0.81 2.0 12.74 499512.87 214107.30 3000.00 3.42 3460 2838.70 2998.95 -17.19 1.70 -26.67 42.8719 0.61 2.98 13.10 499518.12 214110.4 3100.00 20 42.87 2938.56 30..81 .1224 1.53 -23.59 40.33M 088 3.02 1395 499522.20 214113.86 3203.00 2.30 4.33 3038.47 3198.72 1.29 -229 -20.70 31636 04 3.05 1423 499525.37 21411683 3300.00 2.22 37.63 3138.39 3298.64 -4.83 077 -18.22 34.739 013 3.06 1426 499528.38 214119.39 3400.00 2.17 34.73 323832 3396.57 -1.01 3.86 -15.96 31.46 0.12 3.10 1427 499531.41 214121.72 35..03 2.02 31.40 333825 3498.50 2.50 692 -1396 30.511 019 3.13 1437 499534.42 214123.79 3600.00 1.95 30.50 3438.19 3598.44 SA7 9.89 -12.18 29.92M 0.06 3.15 14.43 49953735 214125.58 3700.00 1.93 29.92 3538.13 3698.38 9.16 12.82 -10.47 29.2M 003 3.18 14.45 499540 23 214127.42 3.0.00 1.80 26.21 3638.08 3796.33 12.34 1585 167 27.96 0.13 3.18 14.57 499543.02 214129.10 2600.00 1.82 2790 3738.03 3898.28 1552 1850 -732 28.09.1 013 3.20 14.44 49954583 214130.72 4003.. 2.03 28.05 383797 3998.22 18.91 21.54 -5.70 27276 0.11 3.22 1434 49954884 214132.41 4100.00 2.20 2727 83790 4098.15 2254 24.81 -399 264711 017 3.24 14.16 499552. 214/3420 4200.00 2.32 26.47 4037.82 4198.07 2612 28.33 -221 28.314 012 3.26 14.04 499555.54 214136.06 4300.00 2.45 28.30 413774 429799 3052 32.02 -029 27.3214 0.15 3.26 13.93 499559.18 214136.07 4400.00 252 27.32 423764 439789 3478 35.88 1.73 29 4865 0.06 3.29 13.85 499562 97 21414.19 4500.00 3.38 39.48 4337.51 4497.76 3982 40.38 4.19 30.636 007 3.33 13.04 499567.42 214142.75 4603.00 4.53 30.63 4437.25 4597.50 480 46.57 7.79 35.719 1.45 3.39 1167 499573 52 2141430 4703.00 6.30 35.70 4536.78 469703 5609 54.65 13.13 4421 1.55 3.46 1052 499581.47 214152.04 4800.00 7.97 34.77 4636.00 4796.25 6790 6.80 20.29 5.431 1.67 3.53 902 49959144 214159.44 4900.00 10.43 33.48 4734.70 4894.95 63.19 78.05 2924 6.871 2.47 362 691 499604.47 214185.71 500000 12.52 32.32 483270 499295 102.34 6.76 4003 4031 2.10 370 Alert 528 499620.91 214179.91 510000 14.15 31.85 4930.00 5090.25 124.63 11430 5227 13L 1.03 3.78 Alert 4.34 499640.15 214192.83 5200.03 1625 31.68 5026.50 5186.75 150.00 136.59 66.07 3.861 2.10 3.86 Fall 3.97 499662 10 214206.97 5300.03 18.82 31.18 5121.90 5282.15 17903 162.16 81.69 12330 2.37 3.94 AIM 4.69 48968726 214223.20 510000 20.10 32.12 521624 537649 211.12 19037 99.09 17218 1.51 402 Alert 5.90 499715.06 214241.29 5500.03 21.98 33.67 5309.57 5469.82 24586 220.50 11860 14910 1.96 4.09 7.71 499744.70 214261.53 5800.03 23.48 34.67 5401.80 5582.05 28260 252.47 14.31 6.76L 1.35 4.15 9.17 499776.12 2142601 570000 26.08 33.97 5492.56 5652.83 322.64 28709 163.93 7.181 2.62 4.23 11.34 499810.15 214308.47 580000 27.75 33.52 5581.75 5742.00 366.02 32473 189.07 30240 1.68 429 12.81 499847.17 21433452 5903.03 2800 3383 5670.15 5830.40 4106 363.64 21500 9.99L 029 4.34 13.10 499885.43 21436139 600000 2685 3352 5758.09 5918.34 45647 403.25 24139 47386 0.88 4.39 13.85 499924.39 214388.74 61130.00 29.12 34.12 584556 8005.81 5502.88 44351 268.36 17569L 0.40 44 14.20 499903.96 214416.69 620000 2555 34.03 593116 6093.41 6902 4345 295.38 148.521 0.57 4.47 13.65 500003.25 214444.67 8300.03 2777 33.00 6021.33 6181.58 594.29 522.80 32144 27.44L 0.97 4.51 12.75 500041.95 21447169 6400.03 28.18 32.55 6109.64 626989 6394 56224 34.6 13.41 0.4 4.54 13.07 500080.76 214498.04 400.00 28.58 32.35 6197.82 8357.87 68531 60235 372.34 526L 0.41 457 13.42 50012023 21452451 6600.03 2900 3227 6285.26 844.51 73179 643.05 398.08 76210 0.42 4.60 13.80 500103.29 21455124 8700.03 2903 3252 637221 8532.96 776.58 68401 42407 7.4L 0.12 4.63 13.87 503203.30 21457822 6800.00 29.4 32.40 6459.96 6620.21 825.71 72524 450.29 232L 0.43' 4.68 14.28 500241.16 214605.44 6900.00 30.10 32.35 8546.74 670699 87385 76720 47890 4956 0.62 4.68 14.87 500282.48 21433.06 7.0.03 30.57 32.43 6633.05 6793.30 92237 80985 503.95 118430 0.47 4.71 15.33 50032446 21466115 7100.03 30.45 32.87 671921 687946 97129 85260 531.34 174248 0.25 473 15.28 500366.52 214889.57 720000 3030 3290 680548 69..73 101996 89506 55880 8051R 0.15 476 15.14 500408.30 214718.06 7300.03 30.33 33.25 6891.80 7052.05 1088.49 937.35 586.34 165.56L 0.16 4.78 15.22 500449.91 2147463 74... 30.00 33.06 8978.26 7138.51 1118.79 979.42 61383 173.3L 0.34 4.34 1488 500491.29 21477514 7503.03 29.58 32.98 7065.05 722530 116.57 102107 64091 174328 0.42 482 14.4 500632.27 21480122 760000 2890 33.12 715231 7312.58 1211.54 1.2.01 667.55 4.170 0.66 4.6 136 50.72.55 21483086 7700.03 29.10 33.15 7239.77 7400.02 1258.15 1102.81 694.05 52.811 0.20 4.86 1403 250061249 21485834 7803.0 2925 3225 732708 747.33 1305.05 11452 720.57 4.14L 0.25 488 14.11 500652.73 21488584 7900.03 29.43 32.37 741425 757450 135228 11682 74694 31.756 0.26 4 90 1423 500693.37 21491321 8000.03 29.63 3282 750128 766151 1399.81 122639 773.41 35.13L 023 4.91 14.4 500734.25 21494.70 8100.0D 2975 3245 7588.14 774839 1447.58 1268.14 8005 4.756 0.15 4.93 14.55 500775.36 21496835 8200.02 29.87 32.47 7674.90 7835.15 1495.58 131009 826.73 12123L 0.12 4 6 1467 500816.66 21499605 Tie-In Survey 8300.03 2978 32.17 776166 792191 1543.50 135212 85332 33.59L 917 4.96 146 50085803 215023135 Too Whipstock 835000 29.86 3207 780504 796.29 158752 1373.16 866.6 45L 0.18 4.96 1480 500878.76 21503738 Base Whiostock 8388.1:0 3124 29.45 781882 797907 157542 1380.16 87070 MS 12.00 496 15.61 500885.6 21504171 004251100 838100 3124 290.5 7831.64 799189 1583.02 1386.94 87452 1229L 0.00 496 15.61 500892.32 21504570 8400.03 30.81 28.13 76793 80..15 159281 139552 87924 121/61 4.25 499 15.6 500900.78 21505062 8500.00 28.78 2081 7934.74 6094.99 16180 14465 89979 115.23L 425 5.6 12.51 500945.40 21507227 End Cry 8592.41 27.31 12.85 5816.32 817857 1885.16 1482.16 91234 HS 4.25 5.06 11.12 530986.59 21508583 8600.00 27.31 1285 8023.06 8181.31 1688.83 148555 91311 HS 900 5.08 11.12 50094.6 21508668 870000 27.31 1285 811192 8272.17 173439 1530.29 923.32 HS 0.00 5.09 11.12 501034.44 21509798 6800.03 27.31 1285 8200.77 836102 1700.15 157503 933.52 MS 0.00 5.10 11.12 501078.91 21510927 Co 4251100 8879.3 27.31 1285 827127 84152 181645 1610.53 61.62 2406L 000 5.11 11.12 501114.20 21511823 8900.03 28.12 1209 828955 844980 182603 1619.91 943.69 23.39L 425 5.12 1196 501123.53 21512053 9000.03 32.06 891 8376.06 8538.31 187579 1669.19 952.74 20.64L 425 5.18 1609 501172.58 21513078 9100.00 3606 8.37 8458.90 8619.15 1931.00 1724.89 960.11 18.531 4.25 646 20.26 2501227.88 215139.51 920000 4.11 427 8537.59 8697.84 199135 1760.09 565.78 16.88L 425 5.23 244 501289.12 215146,07 9300.03 44.19 2.50 8611.71 8771.96 205651 18507 96970 15571 425 5.27 2868 501355.99 21515223 603.03 4.30 098 8680.85 861.10 2128.12 192525 971.86 1451L 425 5.31 3290 501428.09 215156.15 9500.03 5242 359.63 8744.64 8804.89 219980 200224 97224 1368L 425 5.35 37.13 501505.04 215158.41 9600.03 56.56 358.43 8802.71 8962.96 227715 2083.60 970.6 12.96L 425 5.38 4136 501588.42 215159.00 9703.03 80.70 38734 8854.78 9015.01 235773 216891 967.67 12.39L 425 5.42 4560 50167178 215157.81 980300 64.86 356.33 890019 909074 244111 225768 962.75 11931 425 5.4 49.6 501760.64 215155.16 9900.03 6902 355.39 8939.65 9098.90 252683 2349.42 956.10 11.58L 425 5.49 5407 501852.52 21515075 0-298 HKT Tot 9975.07 7115 35472 896.61 9124.86 259203 241995 95000 HS 4.25 5.52 5726 501923.18 215146.37 1000000 72.15 354.72 8972.25 913258 261436 244358 94782 MS 0.00 552 57.26 2501946.85 215144.77 NKT 10090.52 7215 36.72 900000 9160.25 2694.02 2529.38 939.89 HO 0.00 5.54 5726 50203281 218138.91 10100.00 7115 354.72 9002.91 9163.16 2702.36 253836 93906 HS 0.00 554 5726 250204181 21513833 Drilling Office 2.5.1100.0 Trading Bay Unit\Steelhead\M-29\M-29A\M-29A(P8) 5/8/2012 3:07 PM Page 1 of 2 Extluabnlona ND BC) Azim True TVD35 T5) VSEC 845 EW TF OLS Directional Exclusion Zone Angle Northing LastingSO) CorranrNs (0) (') (1 (0) (0) (6) (0) (11) (I r/1000)Difficulty Index Alert A (1 (0U5) (8U3) 10200.00 72.15 35472 903356 919381 2790.35 2633.14 930.30 HS 0.00 5.56 57.28 2502136.78 215131.88 10300.00 72.15 35472 906422 9224.47 287835 272792 921.55 HS 0.00 557 5728 250223174 215125.44 10400.00 72.15 35472 9094.88 925513 2986.34 282270 912.79 HS 080 5.59 57.26 250232671 215119.00 10500.00 72.15 354.72 912554 9285.79 3054.33 291748 904.03 HS 0.00 561 5726 250242168 215112.58 HOST 10570074 7215 354.72 9150.00 931025 312455 2993.11 897.04 145 000 562 57.26 250249745 215107.42 10600.00 72.15 354.72 9)556.20 9318.45 3142.33 301226 895.27 HS 0.00 562 5726 250251664 215108.12 107000.00 72.15 351.72 918685 9347.10 3230.32 310704 886.52 HS 0.00 564 5726 250261161 215099.88 10800.00 72.15 354.72 9217.51 9377.76 3318.32 320183 877.76 HS 0.00 5.65 57.26 2502706.57 215093.24 1000.00 72.15 354.72 9248.17 94116.42 3406.31 329661 869.00 HS 000 5.86 5726 2502801.54 21500.0 11000.00 72.15 354.72 9278.83 9439.08 3494.31 339)39 86025 HS 0.00 5.88 57.28 2502896.50 215080.36 11100.00 72.15 35472 9309.49 9409.74 3582.30 3488.17 55149 HS 0.00 5.69 5728 2502991.47 21507392 11200.00 72.15 35412 9340.14 9500.39 367030 358095 84273 HS 0.00 570 5726 2503066.43 215067.48 11300.00 72.15 35472 9370.80 953105 3758.29 367573 833.97 95 000 5.72 5726 2503181.40 21506104 11400.00 72.15 354.72 9401.46 9561.71 3846.29 377051 825.22 HS 0.00 5.73 5726 2503276.36 215054.80 11500.00 72.15 35472 9432.12 959237 393428 386529 618.48 HS 0.00 5.74 5726 2503371.33 215048.18 11600.00 72.15 5472 946278 023.03 402228 396007 80770 HS 0.00 575 5728 2503486.30 21504172 11700.00 72.15 354.72 949343 9653.68 411027 405485 798.95 HS 0.00 5.77 5728 2503561.26 2150528 11800.00 72.15 35412 952409 9684.34 4198.26 4149.63 790.19 HS 0.00 578 5728 250366.23 21502884 M-29A HAS Tal 11802.15 72.15 354.72 9524.75 986.00 4200.16 4151.67 79000 HS 0.00 5.788 5728 250365827 21502870 11900.00 72.15 350.72 955415 9715.00 428826 424441 781.43 HS 0.00 5.79 57.26 2503751.19 215022.40 70 1102.15 72.15 54.72 865.41 9715.0 420.15 4248.45 78124 020 550 5728 25037557.23 21502228 Survey Error Model: ISCW SA Rev 0---3-D 95.000%Confidence 2.7955 sigma Survey Program: Description MD From MD To EOU Freq Harvey Tool Type Borehole/Survey O (61 (01 0.000 100.000 Act Sins SLO_CNSG0CASING-Depth Only M-29/M.29 100.600 345.252 52 SLB_ 8G+CASING-Depth Only M-29/NI-29 00 345.252 8300.0 1/79511(70541 58 48 SLB CNSG♦CASING M-29/2.29 8300.000 650.600 1/100.000 SLB CNSG+CASING M-29A/14-296(P8) 6950.090 11902.149 1/100.000 SLB-MWD-STD M-2950/0-29A(P8) • • Drilling Office 2.5.1100.0 Trading Bay Unit\Steelhead\M-29\M-29A\M-29A(P8) 5/8/2012 3:07 PM Page 2 of 2 II Schlumberger Hilcorp Pnc. y Company WELL FIELD STRUCNRE M-29A (P8) Trading Bay Unit Steelhead Mag.IN Para.. Surface Localion NA1327..Slate Plane,Zone 04.US Feel MirceRaneous Model: BGGM 2011 Dip. 73.675' Dale: June 01,2012 Cat'. N 50 49 55 207 No..'. 2499527.16 RUS Gnd Conv'.-1.39901988' Slot'. leg 131sla17 IVO Bet 1614131160 25R above Mean Sea Level) Mag Dec'. 17.476' FS: 555218nT Lon'. W15136 7.511 EBYIng214137 58 BUS Scale Fact:099999299 Plan'. M-290(P8) S.Dale'.Apn127,2012 0 500 1000 1500 /� 14 r+$ • 4500 ; • Schlumberger H�tcorp g M-29A(P8) ¢D Trading Bay Unit A�MaE Steelhead Mood e�,M.o 7202®2,2se>„M.,�� l g See 17.261 Fe 1�,k.T W1EIY,s�, Ea.�° 211127 504118 ew.Fsnuw®cee %., SQ..SSI �.,FM2,.ma 0 600 1200 1800 2400 3000 3600 4200 4800 29 7200 7200 7800 7800 1881n Wn Top Cry 4.218100 Ease Whipstock End Cr, 8400. ,.. 8400 Civ 4,26/100 II 9000 9000 -20A PINT TEt 9600 ,.. 0 9600 -20A(P0) 81-2M NIO TEt TD 10200 10200 M-29 0 600 1200 1800 2400 3000 3600 4200 4800 Vertical Section(ft)Azim=17.13'Scale=1:600(ft) Origin=0 N/-S,0 E/-V ADL017594 S009N013W Section 29 ♦ BHL rI ADL018730 S009N013W Section 28 rI ri ri Top of Production Horizon r / / ♦ / / ♦ ADL017594 ,♦/ ADL018730 / S009N013W 1i1 Surface Location S009N013W Section 33 Section 32 Steelhead Platform Legend M-29A(P8) • Surface X Top of Production Horizon N • Bottom Hole A -- M-29A(P8)Well Track nTownship-Range-Sections . , • .14 Hlcorp Schlumberger "'ELL M-29A (P8) FIEL° Trading Bay Unit ST''''''Steelhead SYRdIX Location NAU3]Alaska Slse Plane.Zone DI.US Feel Ml�eaneous M�i.l BGGI..3,. Up 13.6]5' ale. 5521 anT Lal. N 59195530] g. 319133].I6 M1S 5540Ed-3999999 9101 M29 sbl] Z°5Z: Op427..2012 ake Mean Sea Level) ag Uec. 1]1Ifi' F9. 555218nT Lon. W15136]Sll Ea lmg. 31013]58 IIUS Scala Fad-0.99999299 Plan. M-39A(PSI Srvy Dale:Apnl Z],2013 M-32RD 0 500 1000 1500 I I I I M-06 N4i'0,' M-30 M-12 M-32PB3 A M-32 4500 . - 1)1 'e M-12 M-32RDPB1 G-32 M-18 -29A(P8) G-32 - G-04 SMII-3131 L1 4000 i 4000 M-31 PB1 G-04 N8DPN M-28 G-04RD w. gyro 04/05/2012 „Al G-09G18 1WIILIL 3500 G 01 R D -18DPN .-_///� � -16 G-01 z �gi• _ -. 1 ' / -31 G-01 fE a't" oG-20 G 01 RDG-04RD w. gyro 04/05/2012 0 3000 War:1 3000 M-25 T G-14A • M-07 ii G 14 ;•/,� G-20 0 G33miw G-06 ft ilia 14A2500 ' 500 G-06RD G-21 G-21 RD fit) (P4) v5./ 5. 09 M16RD t 4 G-07 G 14ARD "so • 2000 M-04 G-08RD 4 G-08 � //fpG-30 / ,1500 4` 'ti '/ 1500G-12RD .�/ G-06RD G 12RD212"D3Op14.,� � • M 27 , G-06G-36 1 - ' G-36DPN4 � � �� ion \ �r G-71Rn 100o G—s„1:;. .: I1 .. +itr'..1 M p M-31A (P2) 0 500' 1J00 1500 << -0 Scale 1:500 ) E >>> G-36 M-16RD M-27 M-29A(P8) G-14ARD TRANSMITTAL LETTER CHECKLIST • WELL NAME vl AC G PTD# 7 12 CJ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 1/l, `tiU (a)-(--- - POOL: (l do / RA c7/ ( pis Check Box for 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 approv bject to full compliance with 20 AAC EXCEPTION 25.055. Approval . .roduc- /in'ect is contingent upon issuance of a conservation - 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:9/09/2011 9� `2 C� CMZ / c7 --/1:` ( 7 S- 9 /Z— To T N To 0 o c a) a N ,N 0) m 0 0 N c Q o o C• E z E o 0 - o 0) oocu 0 m a n a) `0 a a) o a of a)w o 0 a -� 0 o c w N o E E `o E 0 0 w ^ b o) 0) J ._ 0 > a) co a rn m ch o @ c c c a) 3 co o a) N = EO Y a rn a) 7 - 0) c Es a y a) 3 (N C N CL (Cl ccoo 0 O M rn n a °o Q j N (0 L o N L 7. o)N o "O' N 0 4 a 3 'OV '7 ° N 0 0 c _ ¢ 3 0@ 2 as ccs 3 < n OS p)a) zU O O ° CO co a) To us c0- p a) to a) y ,cn c 7 a) w O c O c J N N "o as �_ N co 6) a) to as O N 3 a) w N Na) CC) N n C U) o ami' o Z a o E CO @ 0. a) c:1_ o @ o Tis ui o a) a) Z O E .p C c E .� p c M N N °- D d aro E c o = 0 3 '- 0 c = rn @ Eo @ c >. 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N c 2. �� C w 0 , N 0 c a) T LO `) a) E 3 0 J co N U T U U_ c Z o `1 o Zco o E c m N � N �aN @ (0 0 Nm > w J 7 `O T `. c 7 O N @ Cr C -o N N @ 2 Q a L N O N U O` o CA w co N p 0 O j c N O N w _ ors t c o N @ d > E O w O 7 a) c > -N c "o N 0 7 O c N CO c > a) N i ' co o) 3 .0 p 3 0O O. Oi > U N N a p 0 , 30 t. a N. N I c a`) 7 a) .0 @ T L 0 O o a:5 E ate) (0 •3. O m -o O 7 N N co 0 o 0 0 C -p 0 aa)) c @ .°, o-12 D o c Cl) m C o o m ami N N C N Cn Cl c ° a a c c o F E E = c c E CO a) o c c in '� 1- o xs c a) c o w a) a N 2 a m o 1- Q O o -0 7 .- o@ O c o o m 7 U 'n Ec o- o o uS a ° 3 p 0> N >. CD Q o a 0 m a) c C c 0 a' o o c a? o o a) @ c a) co @ Q .m 073 N a o mo o aa)) aa) N U U a) S] o o a) c N '-,3 Z o 2 E- E 3 m o _c>. m v a) J E o 7 'o LA ,c@.. CO �a @ o L L 0@ c`o -a ate) ` •c a w M m va N t 2 o N a a 3 0 o >, c E a -p' c N .@ a) .pTy @ 3 3 a) .. V U 0 7 `) v a o N a m m o 3 o t 3 w U O Y,. C O c .° -° > O a) LEL -0 "O O @' E O 0 N O o c CJ Q N -o C coO o) c "o a N =. a) a (n 3 -p co o @ L V O a) o 0 o _ a) o E a)al E L o m N c N n -o N_ N 7 7 a C n a) a) — o a) `- a) @ CA O E. 7 c O o Q U n@ n n a) @ a N N a) E c U N N -o Q co ° CO E@ O o a 3 m ca - - @ r .5 c m c c@ N m N -O `_) o aa) m -° 3 = c a) -0 N o n a 0) c0 a) CO c a n m N T co a) a) a) 3 E -p C o• o• a`) c c@ l a w o c3i o $ a) a) T a a) 9 - "p "p '° U L -0 L 'o L a) N a) a) > o) L a) o• N _ Q LL CC c @ E a) a) a) m @ -� O L c c " a) U "O "o O 'N 3 'O O N c O U @ c a) c O 7 3. m io o co @ E @ 3 7 o U @ @ _ °o w = a`) @ = c @ aNi @ c c (---vi 0 c r c U U U N N o o .U. .U. N U f� o U. a) O O @ 'p @ — Lt.' a E U 'c .U. U -p J O m c o 0 0 05 m n 2' n 7 U > > 3 x 7 cr 0 7 a) w w ° 3 L n C ° m ai _ o aa) C a) m a) 7 -@O a s `a) o cco m 3 2 o = 2 2 2 ccoo -°o @ -°o -a = O O r ° °- a°) a`) co a a@) o 0 �4 "�"�.; c z a J D cn O O a a U ¢ a U co U U U U a tz Q ' 6 m m U N 2 a 0 co co U as T0 1.-- 6 ,- N CO V (C) CO CO 0) 0 N CO V U) CO I,- CO 0) 0 N CO Cr UO CO r CO 0) ;'q, f+ o NCO V (O CO II,- 00 0) N N N N N N N N N (N co co co co co co co co co co U N N N TO O w c‘iO w 0 c 00 C° TO N CO CO N .- O D rn 0) co G a) O y F il cN0 >` 0 E N E N C) p C .,1 0 E a Len p) a _i c a0 0 aIa w a O C9 � � \.,\ r , U L SEAN PARNELL,GOVERNOR ( : � ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 Paul Mazzolini FAX (907)276-7542 Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive Anchorage, AK 99524 Re: McArthur River Field, Middle Kenai G & Hemlock Oil Pool, TBU M-29A Hilcorp Alaska, LLC Permit No: 212-050 Surface Location: 975' FNL, 519' FWL, SEC. 33, T9N, R13W, S Bottomhole Location: 1840' FNL, 2116' FWL, SEC. 28, T9N, R13W, S Dear Mr. Mazzolini: Enclosed is the approved application for permit to re-drill the above referenced development well. Approval to produce is pursuant to Administrative Approval 80.087 (Conservation Order 80.087). Hilcorp Alaska, LLC 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. Sincerely, 1)41,41.__-. ., '. Daniel T. Seamount, Jr. Commissioner nd DATED this day of May, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 l a Type of Work: lb.Proposed Well Class Development-Oil LuJ Service- Winj 1-1 Single Zone U/ 1c.Specify if well is proposed for: Drill ❑ Rednll 0 Stratigraphic Test El Development-Gas El Service-Supply j] Multiple ZontLJ/ Coalbed Gas 11 Gas Hyd.:es E Re-entry E Exploratory p Service- WAG p Service-Disp [� r q.•'v Sha- as ❑ 2 Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name an. •umber Hilcorp Alaska,LLC Bond No. 22035244 • Trading Bay U.' M-29A 3.Address: 6.Proposed Depth: 12.Field/Pt•I(s): 3800 Centerpoint Drive,Anchorage AK,99524 MD: 12,311' • TVD: 10,072' • McArt . River Field/Middle Kenai 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number) /G • &Hemlock Oil Pool . Surface: 975'FNL,519'FWL,Sec 33,T9N,R13W,S • Steelhead(ADL0018730)' Top of Productive Horizon 8.Land Use Permit I 13 Approximate Spud Date 729'FSL,1542'FWL,Sec 28,T9N,R13W,S NA 0( ( 5/25/2012 • Total Depth: 1840'FNL,2116'FWL,Sec 28,T9N,R13W,S 9 Acres in Property: 14.Distance to Nearest Property: 3,840 ac >2,500' 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above , 160 feet 15 Distance to Nearest Well Open Surface: x- 214137 - y- 2499527 f Zone- 4 () to Same Pool: G32-- 150 ft 16 Deviated wells: Kickoff depth 8950 feet . 17.Maxi. urn Anticipated • essures in psig(see 20 AAC 25 035) Maximum Hole Angle. 68 23 degrees • Downhol- 43 I psi • Surface 3313 psi ' 18 Casing Program Specifications o. - Se ' g Depth - Bottom Cement Quantity,c.f or sacks Hole Casing Weight Grade Coupling Length b'�, ,D MD ND (including stage data) Conductor Surface Y IL Int ("/( Prod 5,S•" 7" 26 L-80 BTC 3561 8755 8310 12311 100728 In Tieback 7-5/8" 50 8310 PRESENT WELL CONDITION SUMMA (Tco ..feted for Redrill Re-Entry Operations) APR o Total Depth MD(ft) Total Depth ND(ft): Plugs( asure ): Effect.Depth MD(ft) .4',Effect.= D pith T D(ft):' ?Qi((Ok(measured). Casing Length S''e (Cement Volume iK MR L•Un&, C0 ,TvQ,, Conductor/Structural 1,441 00 16 A, 2200 sx 1441m4hg',y�A f44erl Surface 3,756.00 13-3/: • 2200 sx 3756 3754 Intermediate Production 8 66.00 • 5/8" 730 ft3 8966 8497 Liner N r Perforation Depth MD(ft) 9921 - ,211 Perforation Depth ND(ft) 9160'-10,035' 20. Attachments: Property Plat 0 ( B ri P Sketch a Drilling Program u Time v.Depth Plot Shallow Hazard Analysis Di -iter Sketch❑ Seabed Report Drilling Fluid Program n 20 AAC 25.050 requirements 21 Verbal Approval. Commission Representative. Date 22 I hereby certify that the foregoing is true and c• rect. Contact Printed Name ?j91A t. M • Z ZO 6.J I►.1 I Title Q 121 frL./MG M i4 Au i4 646 P— Signature �(,�j.L.-e fig, . f — — Phone 907-777- 836,q Date a 3iZ2/Zo i 2- Commission Commission Use Only Permit to Drill so dip API Number Permit Approya See cover letter for other Number: .212_ 50-733-2aciz$'ol• ate: �1�' 2— requirements. Conditions of approval: I box is checked,well may not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: Other: -,( 500 0 f J-h-,4-.....Q L c)f- /.-;I Samples req'd. Yes❑ a 5 "2 Mud log req'd. Yes ❑ yo[ V (gee ° P : 7k-u-..�6�..) H2S measures: Yes �, No❑ Directional svy req'd: Yes No❑ /z. �� a_ DATE: BY THE COMMISSION DATE: ,COMMISSIONER 2,-,1-1 ,/i/ ORIGINAL 10A,_ -(Y- ts,) s Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate Page 1 of 3 • Schwartz, Guy L (DOA) From: Luke Keller[Ikeller@hilcorp.com] Sent: Thursday, April 19, 2012 1:46 PM To: Schwartz, Guy L (DOA) rir7 ZI Z_ O 5-0 Subject: Hilcorp 16-3/4" Rental BOP Attachments: Patterson Rental BOP Quote.pdf Guy, I have been over regs 20 ACC 25.035 and 20 AAC 25.036. You are right, much important information in there. Just to clarify one thing, when we change out rams (fixed)for running casing or a different size workstring, a "shell test" is not sufficient. Preventer must be closed on appropriate test joint and tested to test pressure specified in the approved permit to drill. Just wanted to make sure I wasn't misunderstanding the regs. Attached is the quote I have for the 16-3/4" BOPs we are renting, I will get some better documentation/ certification and submit to you as well. Thanks, Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 18, 2012 9:55 AM To: Luke Keller Cc: Regg, James B (DOA) Subject: RE: Wireline work on Steelhead ( PTD 212-050) Luke, Thanks for the schedule... The annular is only required to be tested to 50% of WP. See 20 AAC 25.035 (e)(10)(A) I usually don't specify that pressure for the annular on the PTD or sundry. For M-29 RWO and Sidetrack I believe I only specified 5000 PSI for the first test as the rig is just coming into service ( first well on Steelhead) So to summarize on M-29: First BOP Test .... BOPE—5000 psi Annular— 2500psi Subsequent .... BOPE—4000 psi Annular-2500 psi Make sure you read through 20 MC 25.035 and 20 MC 25.036 . there is a lot of very important info in there. We will likely have inspectors present for the first BOP test if possible. Can you also send us more information on the rental BOPEstack? I will pass on to Regg that the 3M 4/19/2012 Page 2 of 3 • 20 3A" stack is getting re-certified. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Luke Keller [mailto:Ikeller@hilcorp.com] Sent: Wednesday, April 18, 2012 8:26 AM To: Schwartz, Guy L (DOA) Subject: RE: Wireline work on Steelhead Guy, M-31 is prep for a tubing pull and redrill. We have just submitted the 10-403 and 10-401 for M-31. We are planning on getting started with this one after M-29A, most likely around June 29th We have more or less firmed up a plan for our drill wells this year, I have attached a Drilling Schedule so you are aware of our 2012 plans. It only includes drill wells though, workovers are being handled by our operations folks. I had a quick question about your comments on M-29A. You had specified a BOP test pressure of 5000 psi, I assumed this applied to the annular as well. Would subsequent tests of the annular be okay at 70% rated working pressure (3500psi)? Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 17, 2012 2:07 PM To: Luke Keller Subject: RE: Wireline work on Steelhead Luke, No sundry needed for any of these. . M-29 just report the wellwork on the final 10-407 P &A report as this is part of the prep for a sidetrack. M-27 is prep for a tubing pull so it be reported on a 10-404 M-31 ??? not sure but sounds like just send in a 10-404 is this a tubing pull only? Guy Schwartz Senior Petroleum Engineer AOGCC 4/19/2012 Page 3 of 3 • 793-1226 (office) 444-3433 (cell) From: Luke Keller [mailto:Ikeller@hilcorp.com] Sent: Tuesday, April 17, 2012 1:48 PM To: Schwartz, Guy L (DOA) Subject: Wireline work on Steelhead Guy, A wireline unit will be available for us on the Steelhead later this week. There is some cost savings to us if we could utilize it to punch holes in the tubing (to facilitate circulation of the wellbore) in preparation of the activity coming up over the summer on wells M-29 and M-31, and also cut the tubing on M-27. According to the Sundry Matrix that I have on file, a 10-403 is not required for these types of operations, but I wanted to check with you to ensure we follow the appropriate notification &approval procedure. We would be utilizing the tubing punch to make holes in the 4-1/2" prod tubing in M-29 and M-31. Below are summaries of what we hope to accomplish on each well. M-27 (Water Injector)Operations Summary: 1. R/U and test lubricator 2. RIH w/rotary torch on E-line and cut 4-1/2"tubing above packer @ 12,500'. 3. TOH, R/D E-line& lubricator M-29 Operations Summary: 1. R/U and test lubricator 2. RIH w/1-9/16"x 6' tubing punch (loaded with 23 shots) and tag fill @+/-8700'. 3. P/U and spot tubing punch at the bottom of the first full joint above the fill. Bottom shot should be 5' above connection. 4. When agreement on depth is reached,shoot 23 holes in tubing. 5. TOH, R/D E-line and lubricator. M-31 Operations Summary: 1. R/U and test lubricator 2. RIH w/1-9/16"x 6'tubing punch (loaded with 23 shots) and tag top of fill @ 9560' 3. P/U and spot tubing punch at the bottom of the first full joint above fill (9502—9533'). Bottom shot should be 5'above connection. 4. When agreement on depth is reached,shoot 23 holes in tubing. 5. TOH, R/D E-line and lubricator. Please reply if you are in agreement with us proceeding with above operations or if there is some additional documentation you would prefer to see from us prior to operation commencement. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 4/19/2012 4 " " 2LOla w Hilcorp-Alaska an_ Mt-Z A 16 3 " 5M DrillingStack (5,-�a_ttE�o r��� /422_ -0S-Z--) cp 16-3/4 " 5M ° HYDRIL o+we,. 5' _' REN)' r F : p \ HEIGHTS 61-1/4' INCHES W -I WEIGHT. 20,835 LBS 1/ a JII yd e re Ies ., Al Ai 337-359-9900 Brousard, La. LP UP UP gJ, kJ ' Y2" Safety c lk amall Blinds n Illh.` ( o ) Alai Fl I ..-,� - �.. U n n r► r► n_� - c Weight; 27,000#LBS L _ l V 41, Y V V J - V 1J ( ---ci)---- - I I 1, - —1 re re n rs rn L 4-1/16' 5M VALVES 4-1/16' SM VALVES 40 LV V Y Y 5" Safety c ( 0 ) c_ J L n n n " n rc�8233 Welght; 13,750#LBS , DSA 16 3/4" 5M X j Wellhead 16 3/4" 10M Steelhead Platform Well M-29A Hit =D Well Design Summary �f A4 Tr M-29A Well Design Summary �i•ct�Lw,� yfr0LSteelhead M-29A is a development oil well planned to be re-drilled in a direction from slot B 1-07 utilizing the existing M-29 casing program down to 8950' MD / 8483' TVD. At 8950' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating G-Zone & Hemlock targets. M-29A is designed as a "Build & Hold" well reaching 68 degrees inclination in the tangent section and reaching a total depth of 12,311 ' MD / 10,072' TVD. Basic Well Information Platform: Steelhead Well Name: M-29A Estimated Spud Date: 5/15/2012 Field: McArthur River Productive Horizon: G-Zone & Hemlock Total Depth: 12,311 ' MD, 10,072' TVD Slot: Slot B1-07, NW Leg Surface Location: 975' FNL, 519' FWL, Sec 33, T9N, R13W, S X=214137.58, Y=2499527.16, NAD27, ASP, Zone 4 Planned BHL: 1840' FNL, 2116' FWL, Sec 28, T9N, R13W, S Original KB Elevation: 160' AMSL KB to WH: 75' Existing M-29A Casing Program Hole Tube Weight Length Top Btm Size (in) O.D. (lbs / ft) Grade Conn (ft) MD/TVD MD/TVD (in) (ft) (ft) Driven 26 267 X-56 Drill-Quip 915 WH 990' 24 16 75 K-55 BTC 1366 WH 1441/1440 17-1/2 13 3/8 61 K-55 BTC 3681 WH 3756/3754 12-1/4 9 5/8 47 L-80 BTC-M 8905 WH 8980/8509 NOTE: Planned effective depth used for 9-5/8" casing above - CIBP will be set in 9- 5/8" @ 8980'. Actual 9-5/8" casing shoe @ 11,038' MD. 4/12/2012 Page 1 of 4 Steelhead Platform . fir Well M-29A Hi1COrp Well Design Summary Planned M-29A Casing & Tubing Program Hole Tube Weight Length Top Btm MD/TVD Size O.D. (lbs / ft) Grade Conn (ft) MD/TVD (ft) (in) (in) (ft) 8-1/2 7 26 L-80 BTC 3561 8750/8310 12,311/10,072 7-5/8 29.7 L-80 Hydril 8675 WH 8750/8310 523 3-1/2 9.3 L-80 EUE 8625 WH 8700/8267 Well Control Summary Hole Section Equipment Test Pressure (psi) • 16-3/4" Hydril GK 5M annular Initial Test: • 16-3/4" 5M Cameron U Double gate 250/5000 o 3-1/2" x 7" VBR in top cavity (Annular 250/5000 psi) 8-1/2" o Blind ram in btm cavity • Mud cross Subsequent • 16-3/4" 5M Cameron U single gate Tests: o 7-5/8" Fixed csg ram 250/4000 • 3-1/16" 5M Choke Manifold (Annular 250/4000 psi) Schematics of the well control equipment are attached for reference Well control equipment will be tested every 7 days, per AOGCC. Anti-Collision Evaluation Summary There are two close approach wells in the 8-1/2" hole section of M-29A. Collision risk will be mitigated procedurally by monitoring torque & drag closely, monitoring offset wellbores when SF < 1 .5, shutting in & monitoring offsets while SF <1 .25. A Gyro MWD tool will be used to accurately survey the wellbore while drlg with the survey interval not to exceed 95 ft. Close M-29A Path Ellipse Separation Diverging Approach Well Well Status (MD ft) (ft) From (ft) • G-04RD Shut-in (2007) 9970 to 11600 -281 ' 11600 4/12/2012 Page 2 of 4 . H Steelhead Platform Well M-29A Hiles Well Design Summary G-32 GL Producer 12000 to 12311 99' - Formation Integrity Testing Test Point, Projected Test Fluid Density Projected Projected 10' Below... Depth (TVD) Type Used for Test Test (EMW Surface ppg) Pressure 9 5/8" 8483 FIT 9.5 12.0 1103 psi Window Casing Testing Fluid Density in Test String Casing Pressure Test Duration Casing Burst (PSI) 9 5/8" x 10-3/4" 9.5 3000 30 min 5860 psi 7-5/8" Tieback 8.5 3000 15 min 6890 psi 7" liner 8.5 3000 15 min 7240 psi Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) • 2% KCI / 8-1/2" Prod. 8950— Clayseal/GEM 9.2 -9.6 40-53 6-15 13-24 _6 12,311 Water based drilling fluid Cementing Summary See Attachments Formation Markers Zone Top MD ff(RKB) TVD ff(RKB) Pore Pressure EMW Requirement psig (ppg RKB) G1 9115 8622 2775 6.2 HK 9731 9057 3886 8.3 HK3 9895 9147 3924 8.3 HKB 10277 9318 3998 8.3 4/12/2012 Page 3 of 4 Steelhead Platform Well M-29A Hilcorp Well Design Summary TD 12311 10072 4320 8.3 1 Prior to drilling M-29A, the parent wellbore M-29 will be plugged and abandoned to a depth of 8980' per the following sequence: a. Existing 4-1/2" tbg and ESP recovered b. (3) each cmt plugs will be placed individually from 10,538' to 9000' -A3127 )Zai Z`� (180' above top perf). Each plug will be given time to set & tagged in sequence. c. Bit & casing scraper run to 9000' followed by a CIBP @ 8980'. Test l /'� £ q casing to 3000 psi. 2 Run USIT or equivalent log from 8980' to surface to evaluate cmt integrity & 9-5/8" casing wear. 3 Run Baker G2 Whipstock on TM bottom trip anchor inside 9-5/8" and set __ _.________.____ ._ on CIBP to position slideil 8950' to 8966' oriented to the NW. 4 Cut window & conduct FIT to 12 ppg. 5 Drill 8-1/2" hole w/ Kick-off assy (8-1/2" bit & mud motor) until sliding becomes problematic. Pick up rotary steerable assy to complete well thereafter. --1- 5 6 Utilize Gamma Ray / Resistivity LWD while drilling 8-1/2" hole. 7 At TD (12,311 ' MD), clean up wellbore and make wiper trips as necessary. S b 8 Run and cmt 7" prod liner (Ensure XO to DP made up to FOSV and 212' ° ready), set Baker ZXP liner top packer immediately after cmt operations. Positive test liner top packer to 1500 psi / 15 min. 9Clean up tie-back sleeve with a full gauge polish mill & simultaneously k10 scrape/clean 9-5/8" casing to packer depth. Hang off DP on RTTS. Test above RTTS to 1500 psi. N/D BOP. Install & test tb a. N/U and test BOP. ✓ ---, P'o°if �( RT r S D.P. 1 Run 7-5/8" tieback assy (Ensure XO to DP made up to FOSV and ready) and hang off in wellhead. Test 7-5/8" and 7" to 3000 psi / 30 min. 12 Perforate G-zone & Hemlock targets from 9115' to 12,31 1 ' using Schlumberger TCP PURE system. a. 4.72" high shot density perforating guns loaded w/ 5 shots/ft with 4505 PowerJet charges b. Redundant eFire/HDF firing head c. Long stroke packer, Safety joint, Jars, and Tester valve. d. (Ensure XO to DP made up to FOSV and ready) 13 Run 3-1/2" tubing and P110 ESP assy to 8700' MD. 4/12/2012 Page 4 of 4 . Steelhead M-29A Hilcorn Cement Calculations 7" Production Liner from 8,750' to 12,311' (8-1/2" hole to 12,311' MD): Cement volume based on annular volume + 30% open hole excess. Job will be a single slurry design, TOC brought to liner top. Estimated total volume is as follows: Overlap: (8966' -8750') x 0.0232 = 5 bbls Open Hole Volume: (12,311 ' -8966') x 0.0226 x 1.3 = 100 bbls Shoe Track: 90' x 0.038 = 3.44 bbls Total Volume (bbls): 5 + 100 + 3.44 = 110 bbls Total Volume (ft3): 110 bbls x 5.615 ft3/bbl = 617 ft3 Total Volume (sx): 617ft3 / 1.35 ft3/sk = 457 sx Slurry Information: System Conventional Density 15.3 lb/gal Yield 1.35 ft3/sk Mixed Water 5.912 gal/sk Mixed Fluid 5.962 gal/sk Total Volume 130 bbl Expected 100 Bc at 06:00 hr:mn Thickening Expected ISO/API 29 mL in 30.0 min Fluid Loss Code Description Concentration G Cement 94 lb/sk WBWOB D110 Retarder 0.05 gal/sk VBWOC Additives D046 Anti Foam 0.2% BWOB D202 Dispersant 1.5% BWOB D400 Gas Control Agent 0.8% BWOB D154 Extender 8.0 % BWOB D174 Expanding Agent 1.5% BWOB 4/12/2012 Page 1 of 1 . . . ti Steelhead Platform WELL#: M-29A uue,a,+,u.kw u c Planned WBD 4/11/2012 Prop p5C-X TBG Hanger 74.5'below RKB CASING AND TUBING DETAIL 4]-1 ! SIZE WT GRADE CONN ID TOP BTM. l 26 267 thru 397# Drill Quip Surf 990' LI 16 75 K-55 BTC 15.124 Surf 1441' 13-3/8 61&68 K-55 BTC 12.415 Surf 3756' 10-3/4 51&55.5# N-80 BTC 9.760 Surf 484' 9-5/8 53.5 N-80 BTC 8.535 484' 8,950' Isar 7" 26 L-80 BTC 6.276 8750 12,311 7-5/8" 29.7 L-80 VAM SLIJ-II 6.875 Surf 8750 Tubing: '' ? ' �_`6 ,,.,� 3-1/2" 9.2# L-80 IBT-M 2.992 Surf 8,600' 0,------ JEWELRY NO Depth Length ID OD Item 1. 74.5' 3.958" Tubing hanger,Seaboard-SC-ESP-EN,13-5/8"5M x 3-1/2" BTC tubing,(2)each continuous control line ports. I. 2. 8,500' 4.15' 2.813" HES"XD"3-1/2"Sliding Sleeve w/pups bucked on. 2 lc 3. 8,520' 0.73' 2.750" 3-1/2"XN-Nipple 't _ 4 8,600— 130' 5.62" Centrilift ESP w/Phoenix Gauge 1 8,730 ' CAI 5. 8,749' 1' 6.188" XO 7"x 7-5/8" vA6. 8,750' 20.68' 6.188" Baker JM-ZXP tie-back seal assembly 41 7. 8,950' 14' Baker G-2 Windowmaster Whipstock&window in 9-5/8" ti csg. 5 • p c i. p I'F It l�O R k I I O N' DATA j+ '7 1A,1N Zone Top Btm Amt � g� O / G-1 9 179' 9.689' 510' HKT 9.689' 9.847' 158' G114 HK3T 9.847' 10 308' 461' HKB 10.308' 12.311' 2,003' /f4/9-`l ' 11.' j :. 0A- ( A PBTD:12,211'MD 10,035' TVD TD:12,311'MD/10,072'TVD 30deg at 8,950',60 deg at 10,000',68 deg at 12,311' REVISED:4/12/2012 REVISED BY:LEK Steelhead Platform . . , • M-29 or M-31 Proposed 02/28/2012 Hilrnrr 444*.1.1.1. Steelhead Platform Tubing hanger,Seaboard-SC-ESP-EN,13 5/8 5M M-29 and M-31 X 4%or 3%tubing,hanger,2-3/8 continuous control line ports, 26 X 16 X 13 3/8 X 10'/r X(7 5/8 or 7)X 4 1/2 Will be set up on 4.110"centers to possibly accommodate 4'/tubing in 7 5/8 casing Adapter,Seaboard-ESP,13 5/8 5M Rotating flange X 4 1/16 5M or 3 1/8 5M rotating flange Iil ' f Iii jiM Tubing head,Seaboard-SC,16'%r 5M X 135/85M,w/2-21/165M SSO,BG bottom ' Rt p ' � li_ 1 k PI omit ..se rolit r_.=___. ..._ , hanger SC-22,135/8X75/8 or 7" .._ di in • f Tubing head,FMC-TC-60,special for unihead,16%5M FE top X `\ \-- False bowl assy 16%5M stdd bottom,w/2-21/165M SSO ISI 'ISI - 16%5M X 135/85M w/13"Acme running thread ■; ' ''i -ilt , illi 0 •— —• III ,....1 . L III 1 ' 1 r+w = ® il�� ®Im; 10,;'3., p l� Unihead,FMC Type 2,16%5M FE top X 21%2M FMC I %1_.j:'o— I speedlock bottom,w/4-2 1/16 5M SSO m j r� 1 .a_ Le_ ....x.r: Ia Adapter spool,FMC-A-5-S 30"MSS stdd bottom X 21 14 2M .- _ , FMC speedlock top,w/2-2"LPO — -,�1,�.,i/ \f- 7 �_ • I Starting head,FMC,30"MSS FE X 26"butt weld I ' I III III 'I_ 31' 16" . 13 3/8" a 10 3/4" (f— 7 5/8"or 7" �..— 4'h"or3''A" Steelhead Field Fracture Gradient Data • 1,000 •• • • •• 2 • • 2,000' • 3,000' • • 4,000' • • • • 5,000' • a 6,000' 7,000' 8,000' 9,000' • • 10,000' • 11,000' t 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 Fracture Gradient(PSI/FT) Cook Inlet LOT-FIT Data 5-17-10 4/12/2012 Steelhead Platform Well M-29A Hilcorp Well Design Summary e�C M-29A Well Design Summary Steelhead M-29A is a development oil well planned to be re-drilled in a NNE direction from slot B1-07 utilizing the existing M-29 casing program down to 8950' MD / 8483' TVD. At 8950' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating G-Zone & Hemlock targets. • M-29A is designed as a "Build & Hold" well reaching 68 degrees inclination in the tangent section and reaching a total depth of 12,311 ' MD / 10,072' • TVD. Basic Well Information Platform: Steelhead • Well Name: M-29A U% Estimated Spud Date: 5/15/2012 Field: McArthur River ^ -- - '� (_ �L Productive Hori G-Zone & Hemlock Total Depth: 12,311 ' MD, 10,072' TVD Slot: Slot B1-07, NW Leg Surface L ation: 975' FNL, 519' FWL, Sec 33, T9N, R13W, S X=214137.58, Y=2499527.16, NAD27, ASP, Zone 4 Plann BHL: 1840' FNL, 2116' FWL, Sec 28, T9N, R13W, S Orig. al KB Elevation: 160' AMSL - KB WH: 75' • Existin M-29A Casing Program Hole Tube Weight Length Top Btm Size (in) O.D. (lbs / ft) Grade Conn (ft) MD/TVD MD/TVD (in) ) (ft) (ft) Driven 26 267 X-56 Drill-Quip 915 WH 990' 24 16 75 K-55 BTC 1366 WH 1441/1440 17-1/2 13 3/8 61 K-55 BTC 3681 WH 3756/3754 12-1/4 9 5/8 47 L-80 BTC-M 8905 • WH 8980/8509 NOTE: Planned effective depth used for 9-5/8" casing above - CIBP will be set in 9- 5/8" @ 8980'. Actual 9-5/8" casing shoe @ 11,038' MD. 3/23/2012 Page 1 of 4 Steelhead Platform Well M-29A Hilcorp Well Design Summary Emmy Conipmy Planned M-29A Casing & Tubing Program Hole Size O.D.TubWeight Grade Conn Length Top D%VD Btm MD/TVD (in) (in) (lbs / ft) (ft) (ft) (ft) 8-1/2 7 26 L-80 BTC 3561 8750/8310 12,311/10,072 7-5/8 29.7 L-80 Hydril 8675 WH 8750/8310 . - 523 3-1/2 9.3 L-80 EUE 8625 WH 8700/8267 Well Control Summary Hole Section Equipment Test Pressure (psi) • 16-3/4" Hydril GK 5M annular • 16-3/4" 5M Cameron U Double gate VBR in top cir o Blind ram'in btm ca ityavity tic TGA 250/5000 8-1/2" • Mud cross (Annular3500 psi) • 16-3/4" 5M Cameron U single gate o 7-5/8" Fixed csg ram/ • 3-1/16" 5M Choke Manifold Schematics of the well control equipment are attached for reference ,. it,• Anti-Collision Evaluation Sum ary There are two close approac ells in the 8-1/2" hole section of M-29A. Collision risk will be mitigated proce rally by monitoring torque & drag closely, monitoring • offset wellbores when SF < .5, shutting in & monitoring offsets while SF <1.25. A Gyro MWD tool will b used to accurately survey the wellbore while drlg with ' the survey interval no o exceed 95 ft. Close M-29A Path Ellipse Separation Diverging Approach Well Well Status From (MD ft) (ft) (ft) G-04RD Shut-in (2007) 9970 to 11600 -281 ' ' 11600 G-32 GL Producer 12000 to 12311 99' • - 3/23/2012 Page 2 of 4 II Steelhead Platform • Well M-29A Hilcorp Well Design Summary Comm,Roomy Formation Integrity Testing Test Point, Projected Test Fluid Density Projected Projected 10' Below... Depth (TVD) Type Used for Test Test (EMW Surface ppg) Pressure 9 5/8" 8483 FIT 9.5 12.0 1 103 psi Window Casing Testing Test String Fluid Density in Pressure Test Duration Casing Burst Casing (PSI) 9 5/8" x 10-3/4" 9.5 3000 30 min 5860 psi 7-5/8" Tieback 8.5 3000 15 min 6890 psi 7" liner 8.5 3000 15 min 7240 psi Mud Program Summary Section Depth Mud Type Density Viscosity PV YP API FL (MD ft) (ppg) (sec) 2% KCI / 8-1/2" Prod. 8950- Clayseal/GEM 9.2 -9.6 40-53 6-15 13-24 <_6 12,311 Water based • drilling fluid , . , ; - Cementing Summary See Attachments Formation Markers Zone Top MD ft(RK, TVD ft(RKB) Pore Pressure EMW Requirement psig (ppg RKB) GI I=OrMil 8622 2775 6.2 • HK 111111rall. 9057 3886 8.3 • HK3iistram 9147 3924 8.3 HKB 10277 9318 3998 8.3 TD 12311 10072 4320 8.3 3/23/2012 Page 3 of 4 Steelhead Platform Well M-29A Hilcorp Well Design Summary Etimy C S Z•i 1 Prior to drilling M-29A, the parent wellbore M-29 will be plugged and.r abandoned to a depth of 8980' per the following sequence: a. Existing 4-1/2" tbg and ESP recovered • b. (3) each cmt plugs will be placed individually from 10,538' to 9000' • (180' above top perf). Each plug will be given time to set & tagged in sequence. c. Bit & casing scraper run to 9000' followed by a CIBP @ 8980'. Test casing to 3000 psi. /3 c 2 Run USIT or equivalent log from 8980' to surface to evaluate cmt integrity , & 9-5/8" casing wear. 3 Run Baker G2 Whipstock on TM bottom trip anchor inside 9-5/8" and set on CIBP to position slide f/ 8950' to 8966' oriented to the NW. • 4 Cut window & conduct FIT to 12 ppg. , �� ? /5 Drill 8-1/2" hole w/ Kick-off assy (8-1/2" bit & mud motor) until sliding becomes problematic. Pick up rotary steerable assy to complete well thereafter. 6 Utilize Gamma Ray / Resistivity LWD while drilling 8-1/2" hole. r f 7 At TD (12,311 ' MD), clean up wellbore and make wiper trips as necessary. 92/z_-0s-0 8 Run and cmt 7" prod liner, set Baker ZXP liner top packer immediately after cmt operations. ( -r- 9 Clean up tie-back sleeve with a full gauge polish mill & simultaneously scrape/clean 9-5/8" casing to packer depth. 10 Hang off DP on RTTS & N/D BOP. Install & test tbg head. N/U and test BOP. L-4 e 711 1 Perforate G-zone & Hemlock targets from 9115' to 12,311 '. • -7-cP 12 Run 7-5/8" tieback assy and hang off in wellhead. _� P 13 Run 3-1/2" tubing and P110 ESP assy to 8700' MD. Y�H 3/23/2012 Page 4 of 4 Halliburton BAROID Hilcorp Mud Program M-29A Fluid Properties Production Hole Section Recommendations(8-1/2" hole, 7" liner to 12,311' MD) System Type: 2% KCI, Clayseal, GEM Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 8950'-12311' 9.2-9.6 40-53 6- 15 13-24 <5 8.5-9.5 Completion (3-1/2" Tubing to 8700' MD) System Type: 6% KCI Brine Properties: Density- 8.5 ppg, Chlorides— 15,000 ppm M-29A 1 3/21/2012 14SaksMerger HilcorM-2910(P2)Proposal Report (D.1 Plan) Repeal Dale March 15.2012.0.31 AAA Survey/OLS Com3014n Minimum Gunn..I Luknk Chad Chevron V.r6cal Sectl.nAzIIMN 15270-(Tn.Ne40 y Unit Ver5013431en Origin. 0007,0003ft RKS Well,rueSlot, 7.4-22 •/1.8 SI Mot b1111 /Rel°°rt 11.33 Reference TVD Re4410.8 9.x1 1102503How Mun Sae Lem! 8.11.le 51-21.8 Seated/Orourrd Elwtllon 185 0005 4840 Moan S..Level OWI/AFM Ur4.vn l Unknem Magnetic 00110831 17506- Survey Nam. 74.210(02) Telal Field Strength. 55522 71.nT Survey Date Mom!,15.2012 M.3.11c 0rpArrgle 73173- Ton/AHD I DDI/630 Rall.. 9.327./41052625/577110 47 D.dln4.n Dxe: 74.y01,012 Coordinate Reference System 113027 01410 314.Plen.,2eM 04,113 Feel Ma.n.ticO.dlMS.n Medal: 800142011 LecalI.n Lal/Long. N 11).055 2001.VV 151.3 751075 Nath Re*nnco. Tru.North 1.0tlon Orld N1E 5(0 N 249.527 100355.E 214137510 SUS Odd Convergence 101 0000- CRS Odd CxlvxOnn AMM -1 39.01111- Total Corr MM Nxt1+.Tr1M North. 17 501' Odd(Cl).F.cior 0 9819.29. Local C..rd Rey.rerlc.d T. 10.0 H09. Fadul.n Zone BastingCommentsa MD Incl 37.1111 True TVD5 TVD VSEC NOLS OW TF l Directional Exclusion 2. A301. Northing Bang 00 (1 () (It) (R) (3) (1) (5 n 13005)DIRleully Inde. AIM r1 (WS) (NUS) KBE 000 000 000 .11025 000 000 000 000 29.231. 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7403 03 3010 33 9. 07121 7131 51 1106 50 97942 61313 173 31 0 34 410 1417 50049129 21477514 750300 2451 3231 70005 722530 115312 102107 .4091 174 323 042 482 144 500532 27 21480322 71003 2515 3312 715231 721251 120333 101201 66755 4175 06. 484 1353 50057255 21480054 7700 CO 2910 3315 723177 740002 1744 110211 0405 X611 020 40 1403 5005124 21445534 700 03 2125 32 75 7327 04 747 33 129212 1143 52 720 57 48141 0 25 4 9. 14 11 500652 73 2141450 7000 00 294 3237 741425 757450 133.71 116412 7464 3175R 02. 410 1422 5000337 2141321 .00000 29.3 3262 750124 76.151 13.575 122131 77341 35131 023 411 144 50073429 21494070 810000 2175 334 751414 774131 143405 124414 50006 475R 015 491 1454 50077534 2144435 X0000 2.57 3347 757490 7015 14157 1310. 57373 121 231 012 464 1466 50X1665 21498105 830300 2.71 3717 7751. 792111 152113 135212 15332 33841 017 49. 1453 50315403 21502355 8403 CO 2183 3187 71039 300564 7X878 131430 579 T5 703 015 497 144 50059936 2150111 00000 3023 3205 793492 80017 162474 14310 90632 18171 030 498 1445 5000139 21507/70 81800 3012 310 802113 515131 157333 147982 93312 21511 04 503 1534 25000374 21510.54 570000 3097 3157 110700 125725 172247 15234 91003 1(4291 032 502 150 50102867 21513451 1.0000 3043 3127 811214 835324 177151 159.9. .140 15741 054 504 (5 06 250100057 2751621. 7.-0.Survey 60800 210 3012 327843 343.0 111910 1.1005 101280 22550 OX 505 1452 50111200 2151011 Tep110*e.1x1 05002 • 3019 3107 932270 3420 164402 10153 10254 501 052 506 1471 250113318 21520258 13476303414 184403 314 2125 0314 849559 1019. 1068 102155 53 1710 506 1565 25011401/ 21520.12 Cn.35/10 69.100 314 2525 89.933 15014 1054 144555 103325 31991 000 506 150 25011411 2152100 XOOM 3191 275 13031 02564 11.33 11031 103792 31341 350 50S 1614 250115570 21521557 110003 340 2312 0445 1X.10 1X350 170403 101172 33311 3550 512 1572 250120475 2152451 920000 370 2073 02140 3065 156230 175187 10(415 30791 350 511 2155 250125902 21526434 93000 417 1600 1=72 178812 204553 111114 110512 21 121 350 520 2455 250131630 2152.77 940303 412 155. 54031 16478 21120 154321 112456 2.X3. 350 523 2766 25013X36 21530777 003[0 47 11 13 42 1750 51 18100 211429 1952 35 1142 39 25371 350 527 300 250145102 21532726 980000 X29 1147 141557 1X582 225431 202570 115454 240.E 350 530 3409 25015230 21534523 970003 5350 III 07126 903153 233772 210301 117217 229.1 350 534 3734 2501.0012 21534153 140002 5.73 106 X3547 90072 241922 218401 11010 22051 350 537 400 2501611(2 21537514 EM Cm 9990 570 741 X5534 91150 244997 221451 118071 9.3 350 531 4192 250171224 210106 Cr435/100 99.570 5793 74 594161 1149. 249835 226425 119.21 37398 003 531 4192 250175151 21535579 950002 5405 765 51014 91413 250300 221717 119.77 37335 350 540 4203 250176511 21531.35 NAT $92111 1484 612 300000 .1025 252017 224973 11.24 37050 30 54 425. 2017/281 21531228 1000010 1015 1003 903571 8156.4 251455 235265 120999 34063 350 543 470 250114915 215404.4 1010310 070 1232 901423 1244 21780 241.77 122716 35023 350 54 474 2501022 2102393 1020010 3151 1451 112321 825451 27X51 252101 12423 341R 350 54 5025 250202312 2154715 Drilling Office 2.5.1100.0 Trading Bay Unit\Steelhead\M-29\M-29A\M-29A(P2) 3/21/2012 2:30 PM Page 1 of 2 MD Intl Atlm Tru. TVD43 TVD 55EC NI EW TF DI! 0845 nS Fadiknzww E'd'''"Z.n.(-mon) E..Ory Comm. Northing C) C) In) (5) (n) (n) (n) C) on)Dimwly)nd.a Alen Anglo (73131) (1110) C 5037 025151 00 22 15 71 115000 (310 25 211174 257111 120100 145 350 4 51 5112 2502074 00 21544200 020000 3023 1571 113010 932435 21500E 21172E 127277 HS 000 552 5112 250221125/ 2100315 040000 3073 1571 120311 528344 295213 27110 121711 HS 000 553 5132 230220730 2155011E 050000 1523 1571 124011 44653 304571 271405 132305 03 000 355 5131 25027/005 21552430 013000 1623 1571 9277 37 943783 313115 211545 13920 55 000 554 51 92 250237//1 215555/2 070000 1523 1571 931.9 947.71 3231 52 29340 137331 HS 000 554 5112 2502.!757 21553313 010000 1623 1571 935155 151140 332.34 301425 13169 HI 000 553 5192 250255/31 215110.5 013000 1623 1571 131515 45911 311725 315315 142383 53 000 511 5132 250264501 21583777 100000 1623 1571 142573 931530 351012 32.305 1W77 53 000 542 5112 25027330 2150501 110000 1673 1571 9483 E2 142307 NO2 91 23329 1473921 53 000 593 5132 2502/2210 215112.1 120000 1623 1571 94010 915015 30545 342115 14001 03 000 50 5192 2`0211134 21571972 1300 00 1523 15 71 03111 907 24 370 71 351125 152420 HS 000 511 51 92 250300012 2157470 140000 1123 1571 95740E 573133 30151 35100 15935 53 000 573 5112 250364/7 2157743/ 150000 6123 1571 01117 977142 39740 315005 15749 H3 000 515 5192 250317783 21540116 140000 3023 1571 94924 30651 46731 377945 15083 HS 000 561 5111 25626131 215/2/00 170300 1523 1571 61035 10560 411017 3630 1424 T7 KS 06 570 5112 250115515 21515431 14600 1623 1571 97229 91520 42530 33024 144192 HS O6 572 5112 250344391 21511383 19006 1523 1571 975953 611171 434510 404744 11736 HS 06 572 5112 25003216 2151100 20006 1523 1571 176162 615447 443177 41370 17620 53 06 574 5111 2577072 215/3127 6 6 0 30 21 4423 1571 1371 4612 453113 42299 172535 03 030 575 5197 25030371014 2159059 22006 023 1571 30700 106105 02450 43150 17500 53 06 571 5192 25113700 2150290 HNS 221134 0 23 15 71 9174 6 10075 25 4415 03 432011 175334 HS 0 6 5 71 51 6 6 00 6 2 25101 21 23006 1523 1571 990711 6 19113 471731 4.624 177583 HS 06 577 51(2 250315770 21102022 TD 231134 4. 023 1571 0126 1007234 . 47370 9156 17719 06 577 5192 250349774 2146332 Survey Error Mehl ISCWSA n.v O.'.10 0 0611 C.nO.nc.2 7935 414n3 Survey 9r.p.m D..0rI10.n MO From MD To 4007146 Sun,T.C)T (111 111 (S) YW f.r.Hol.l Survey 0000 1606 Act atm SLBCNSG•CA31NG-D.prt Only M-21/H.21 100000 345 252 1245252 SL0_CN50+CASING-O.16 Only M-29/M-29 345252 19606 1//554741 SLS CNSO+CASING 1529/15.29 11606 1150 C00 1/1606 5L9_C1130KA5IN0 M-211A/M-21A(P2) 115006 12311 334 1/1606 SLS MWD STD M-213/6-210(32) Drilling Office 2.5 1100.0 Trading Bay Unit\Steelhead\M-29\M-29A\M-29A(P2) 3/21/2012 2:30 PM Page 2 of 2 Hilcorp Schlumberger WELL M-29A (P2) FIELD STRUCTURE Trading Bay Unit Steelhead AYpmik Pontn.n Sudo.Lrwllan N0027 Abs.list.PM..,Zen.04 US F. MMeabiwuS Mo. 500M 2011 09 13 573' 0.n Mry 01.2012 1.1 N b 155 207 No.. 251627 11 KIS 0n0 0011V .13110111- Sloe My 1144 7 1V0 6.1 RK5(160.21 above Mean Us Le.) Mop Mc, 1750r FS 55522 701 Lon W 15131 7511 E..,. 2141375/WS Sea.Ful 0$11W25 Plan M-31K(F2) 6rvy DM1 Mwrtb 11,2012 0 1400 2800 4200 5600 0 0 KBE 1400 •• • 1400 2800 2800 4200 •-•• 4200 0 0 II 5600 ---- 5600 m CO r) a 7000 7000 11.-In Surly Top Whpstoc 8400 Bas.Whlpstoc .••• ` 8400 End Cry Cry 3.5/100 Cry 3.5/100 M-2ORD Tgt 2 M-20RD Tgt 3 TO 9800 • 9800 M-29A(P2) 11200 •••• M-29 11200 0 1400 2800 4200 5600 Vertical Section(ft)Azim=15.27°Scale=1:1400(ft) Origin=0 N/-S,0 E/-V n Hizcor, Schlumberger WELL FIELD STRUCTURE M-29A (P2) Trading Bay Unit Steelhead Mogrnl4 Pon oolels Sorrow Location NR02101.4e Sole Plane,tam 04.US Foot MMU.Aneoue Model: 5000 2011 0N: 73.673' Dote: May 01.2012 L61: N 60 e9 55.207 Northing 2499527 16 SUS 0,4 Com:-139901966' Slot lag 61 46 7 TVD Rel: RKB(160.256 ohovo Moon See Leve) Map ion: 17.509' FS'. 55522.747 Lon: W 15136 7.511 Ful0g 214137 56 SUS Solo Fool 0.99999299 Plan: M-2939(P2) S'6 Dote:latch 15.2012 0 600 1200 1800 TD 29A(P2) M-29RD Tgt 3 4200 O -•c 4200 N 3600 z. 3600 3000 3000 29 A A A M-29RD Tgt 2 Z = 2400 2400 0 0 Cry 3.5/100 II End Cry 0) N U to V) Cry 3.5/100 v 1800 •.• ° 1800 gue Whipsto• V Top Wherstock Tie-In Survey 1200 1200 600 600 00 0 0 600 1200 1800 c<< W Scale=1:600(ft) E >>> \ \\ 1 \\\\ `11 I 1 \\ \\\ 1 -------•--------.rix, O N i -71-- i i0 \ _ _ __ ------------1Z � i,i —� 0 1 1 \ __ -- f ---- ...< \ + - ///'ii./ +I x, \ \ ii' -24,.. \ d�` //-i , ... i i' i/ \ 1 1 \ \ ` , „......, , n /i, III ,rte/ _— /' fD e.J /i l I ',1 / \ \ =��" !"'' ,�/y��iE,'� \� ,�, •.\ ,:`,C� `. --71-.-/,,--__ I I III / \ \ \I _-- e`% fD '\ \` \`\\. \, . / // —y—lam+I , 11 I \ \ \X(1 , T ''.-/ 7' .----- / 1 /. .. ------- ,+-,/ / \ \ / / N`. / I 1 I CI) ,,--- / / \ \ I • ',..1... 1 '7.,/---, I I ' --, ___ i.." ----- / \ W : O / ,,, / / \i / N4,( , ., \ \ J, , N. , it,....z-- , - , , \ , _ , „ , , , _,_ '/ i it \\y\ ii i f±o I I I 1;\kO IX 1/ ''fi // \ I ,i / % /7 \ 1 1 +-- __-' % / \ 1 Ij \ \ I /y / _iy/ \ 1 1 y/ // Iv 1 i/ / / \I �/ / / % I/ /7 i �` II / i \� i I / I \ I/ I \ I 7 / / j \\i \/ Gii i . y co c. 'O / iO • \• WZ ''/ i \ ZO ` / \ 1I a •IGO C ,' I \ G \\\ C`�� C i i 1 G ' 1 /// / I 1--I / / I _ \\ I \\ `\ 1\1 `\ ! \` _\ ,S009N013W \\ �►DL017594 ,\,\ \, Section 21 / , 11 i/\ i M-31 \ N A j ADL017594 / \ ;, \ G-25 G-05RD ---------1—F \ M-31L1 / / 1 / ---------- • j' /'' t1 'NI-12 // / / i/ \\ ' i --\ - i% ,M=29A(P2)TD \\ S009N013W ______�------- Sectlon 29 G-04 Ii d`3 r//,� ADL018730 K-24RD �\ / / -25 G-18DPN / \\ / /A / / \ • / / / / :74 ,-,----`r-=---- G-01 - i ' / j j\/ Lam' --^^^^ ^ G-01RD ------ _ _ , S009N013W \-'c Section 28 ' _' _ ------------------ ------ - - ---\- tar' /% ' / _ _-_- - -_ ' `,u' ; ' --- --------------------M-01 I. -04RD 1 ; M-04 Z jf 7 /'` �9 G-20 /i : ` i ', \ \ N:'-i.//// ; ,_„ ,,, 1 \1\ \ I I\�,\/ \ / ////, i' \\\\ I ,, \ / / y/ �/ i �` II i; \\ l 1 / 51`.x\ / � , Z N 1 1 \\ \\,;• ' � '\ ADL018730 111 A DLQ17594 ,,\',\\,\ \\?y ,, -h/,,,//,, - `',\ ,„ 1 1 \ Steelhead%M-29A(P2) Surface \\. \` 0009N 1110 , \\I\ \ S009'101\3.W Legend e&tfo 3�2, I \ • Section 33\ - I \\ , , \\\ .+ \ .\ M-29A(P2)Well Locations \.I 1 \\\ •\ \. X M-29A(P2)Top of Production Horizon �� , • 1 \\\ •\\ \ • N' \ / \ i1 \\\1 \\ \ -k-- Bottom Hole Locations • ( 1•\ \\*1 \\\\�,I `,\\ \\ • ----- M-29A(P2)Well Track + I / \�\\ 1 \A ' +. ----Well Tracks I / \\ I \I,\ � \ � n Township-Range-Sections iT i 1.1\ '\ M-29A Cement Calculations: Production Liner: 7", 26#, L-80, BTC in 8-1/2" hole: Cement from section TD at 12,311' MD to liner top at 8750'. • OH volume+30%excess: o (12,311'-8966')*(.023 bpf)*1.3 = 100 bbls MP --, Liner Top:8750' • Shoe track volume: o 90' * .038 bpf=3.44 bbls 9-5/8"Window:8966' • Overlap volume: o (8966'-8750')*(.023)=5 bbls • Total Volume: -110 bbls r�SS 6 ' S4lGs `——' 7"Shoe:12,311' • 'T) Z Z O 0 CD -1 r+ CC a Dp NJ N �_ rt =, 0" N N 70 to O O O �0 00 i O CD N v. 2 N 0) rt K K K K - 0) - N °' n, N 0 G) G) G) T VCD X X h 0 v, "-• o - rt. N CD CD CD CD = CD , 78 rD 0 -s 0 C CC C O •rt co O chi, O CD N — < G < d "s N O' C O T T T CD C CD -h -z 3 CD ( 0 0) w < -' C) 0) 0) 0) CD '"r f) rt ut % 3 I-, I-, N N F-, K CI)• 0 v, co ' 0 O I.� H, w 0 Q C .-l. rt "'+ N \ r0i- W F-' 01 N N -O CD N 0 c 00 O- t!) UJ .I I� F-� 0 CD Q — = O 1.0 W N CO CL in - I, d S MI rtCL J. ,moi, lD 0 O 0 lD `D lD lD n0 < 'O W O W O W Q c Q' 00 00 -I O . W 0 V 0 CSD • II 0) 003 Q -' D 3 u N Q II --I C -0 rN+ et V) CD A v, 0 5' n CD O 0° w w w w w Ci) fD NJo v) via oo -J 3 �rD oVv °' � , cu CO F- o fD o < 13 N o ID O C W `rt° o �' D 3 A CD 0 0 0 0 0 v, fD c kaco d „S O rt O N D .9 fD o 0o f') w o cc CO O N N F LS .-^r DJ rt , x X Q• O 3 O O F'' '.A 'CO 0 NJ Ol v l0 CT \ -0 73 • v, v, I- O O II II NJ .v' W W NJ A o to II -o W W N W • Measured Frac Gradients Well String Shoe Depth FG EMW (inches) (TVD-Ft) (psi/ft) (ppg) GPP 51 9-5/8" 9529 1.05 20.2 GPP 50 9-5/8" 9877 0.93 17.9 An-11RD 9-5/8" 8750 0.92 17.7 An-3RD 9-5/8" 7839 0.75 14.4 An-51 9-5/8" 9842 0.88 16.9 An-7RD2 9-5/8" 4439 0.96 18.5 An-32RD 9-5/8" 9900 0.92 17.7 Granite Point Measured Frac Gradients 0 GPP 51 2000 ®GPP 50 a An-11RD .= 4000 Q- x An-3RD O 6000 x An-51 To ▪ 8000 r X •An-7RD2 ai • • 10000 X + • +An-32RD 12000 0.6 0.65 0.7 0.75 0.8 0.85 0.9 0.95 1 1.05 1.1 Frac Gradient(psi/ft) F-7n §03; pi pi pi k® &0_0 )§)\ [ � CI-To , /2/ } co co /\§ et cn co k$` ` R *w) /q3/) o 0CY ` ` ` $ ) }\222 a, \§2 7 » 2 « §k, 0 / /(4 V. E 7 R 00@r (0 «2zE-1e002-Luz_, k � I-�`I- , co 0 at 000 a> ` 2 « 7±)§} _} Lo co 4,3 3 {k 0 ° ~ co f� ) (ƒ§7 M to / \ \� \ k\`a § , 2. C k� §_ 0 LID 3 § _ ƒ] ] c \ {e f ƒ 0 Sio .o 0 Ill f L ) / \ \°� 000 \$ � QD ,o 0 J} ° ( } o to co co 000 \o o} Lr)e o0 \ \ 2\2 4� } \ 4 ioN. (��COCO CO��CO CO� S. } 2 „LU _ )¥c5c oG \ \\j 2`.- r-- / 0 _ \, , VI - 0 Steelhead Platform 16%5M BOP(Oil Leg) M-27,29,31 ttitn.,.r I.Lc 3/16/2012 agar a.eom.,.rq.« a>s F 22"pipe for air boot flanges aq° s.u• f .J: 5.10' Hy,iril .sal atjt siy. i "* 5.46' Ito iThithith uw +j r ruri�t•r I• -'I iii t r t hit1,41 II 4J3 3.00' ul ii i�/l�i.i►1 •:s/_5 0 '�.: .: "` 3.56' labs 44. 5` DSA 16%10M X 16%5M .66' rtiI , hili u1 r� ss w mq wocmimu ui 141r nq wocouw Riser,16%5M API hub X 16 31410M FE uom.uat room floor Riser,16'/.5M FE X 16% 5M API hub ur n Woilhood lbw to Ups.,Waif* g P, '111111111'"11ryR!11'w "a-, 4•..� I ill`s IIT. • Di iii r a N o 0 1___ i_i _ _:.._.___(01;:1_1__ ..t.i„,, ,__ . __,,_ to _____\:::::Ao •} ri,\::,,... 4.1,7):. r QT ' m I m 4 • .. ♦.g ,.„ I n• 1 t.a, ---,___ t., i3 -1--- -C_ . r II k3 Ate• -1 Ill 4g... o T o i J:L !SD - 1114,4* ,•fir', m V .2. -1--,-.1 , 1-K y"--- n m n ;. ,_ 11 I a o mom" I � w ' r R1 `-' D vi--1\ Z - ZJ Y I O o O -n -T y cn --'-(-4:01 — — 41-)14' i -i — w o D aN M -I 11 .n M iiiipm MB y1 m o lilt k In415 II i lig.. -I 1 riiii, %; ::Y0 I A n • • ) I 1 M-29A Days Vs Depth 0 --- -P&A -Drlg -Com pl 2000 4000 E. 6000 • ar a (13 a 8000 10000 12000 14000 ---- 0 5 10 15 20 25 30 35 40 45 50 Days Steelhead M-29A Summary of Drilling Hazards 8-1/2" Hole Section • Significantly under pressured reservoir sands may be encountered A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the production interval. • Loss circulation is considered to be a major risk due to the depleted reservoir sands which will be encountered. Loss circulation materials will be readily available for adding to the mud system should significant losses be encountered. • Differential sticking is also a risk while drilling through depleted sands. Keep the drill string moving . whenever possible. • Numerous coals will be drilled through the interval. Limiting the amount of coal drilled prior to . back reaming should be followed. HYDROGEN SULFIDE - H2S • Steelhead is designated as an H2S drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT/LOT results are defined as follows: • Formation Integrity Test (FIT) - Formation is tested to a pre-determined equivalent mud weight. • Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak-off point. • LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak-offs. • Open Hole LOTs (OH LOTs)- Leak-off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak-off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill 10' of new hole below the casing shoe. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 1 of 2 Schwartz, Guy L (DOA) From: Luke Keller[Ikeller@hilcorp.com] Sent: Thursday, April 12, 2012 3:10 PM To: Schwartz, Guy L (DOA) Cc: Paul Mazzolini Subject: M-29A( PTD 212-050) Attachments: M-29A Plan Summary.pdf; Schlumberger_Pipe Conveyed Perforating no packer.pdf; Cook Inlet LOT-FIT Data 5-17-10.xls Guy, Thanks for your feedback. Answers to your specific questions are summarized in red below& included in attached document. Also included is the general procedure for the Schlumberger PURE perforating system we were planning on using. I am sending you some information I have been able to find on fracture gradient's for the inlet as well (LOT and FIT datapoints). Very useful information for planning purposes. It has some gaps in it, but overall very comprehensive for the inlet/Kenai peninsula. Don't hesitate to call if you would like further clarification on anything. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 From: Paul Mazzolini Sent: Wednesday, April 11, 2012 4:36 PM To: Schwartz, Guy L(DOA) Cc: Luke Keller Subject: RE: M-29A ( PTD 212-050) Guy, Thanks for the voice mail and follow up email. I will work with Luke to respond to your requests below. Mazz From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 11, 2012 3:41 PM To: Paul Mazzolini Subject: M-29A ( PTD 212-050) Paul, I have been reviewing the PTD. A couple of things still needed but overall pretty complete. 1) Need a proposed completion well sketch. Included in attached document"M-29A Plan Summary" (Page 6) 2) On Step 4 is the 12 PPG FIT the minimum or expected? If expected what is your min FIT? Offset field 4/12/2012 Page 2 of 2 test data predicts frac gradient is most likely between .75- .95 psi/ft(14.4— 16 ppg). We were not going to take the FIT to leak-off, chose 12 ppg for a 2.5 ppg kick margin (1100 psi)while drilling w/ 9.5 ppg mud If we are unable to get a 12 ppg leak off, we will evaluate the LOT test results and decide whether or not remedial cmt work is necessary. ECDs will likely be in the range of 9.8— 10.1 ppg, and to maintain an appropriate kick margin, a shoe test of 10.5— 11 ppg would probably be the minimum we would be willing to drill ahead with, with AOGCC approval. See attached spreadsheet with LOT/FIT field test data from across the inlet and peninsula. 3) Need the cement class and yield , sacks. Included in attached document"M-29A Plan Summary" (page 5). 4) Need to specify casing pressure tests at step 8 and 12. ( I found the table on page 3) Also need to test RTTS before ND BOP Included in "M-29A Plan Summary", highlighted in yellow (page 4) 5)Are you perfing via TCP or Eline? Need some details. More specific information regarding perforating included on page 4 of attached "Plan Summary". Also general procedure for Schlumberger PURE system included. 6) Need to have X-overs with FOSV on rig floor for running casing and TCP guns. We will ensure this is the case, added to"M-29A Plan Summary" (page 4) for clarity. 7) I am specifying an initial BOP test of 5000 psi then 4000 psi thereafter. Noted on well control summary section in "M-29A Plan Summary" (page 2). 8) Rig will be on a one week BOP test cycle for entire well as this will be one of its first wells. Noted on well control summary section in "M-29A Plan Summary" (page 2). We will adhere to this guideline until AOGCC agrees to extend to two week intervals. 9) need a vendor supplied proposed wellhead diagram (with new tubing head adaptor added) Included in "M-29A Plan Summary" (page 7) 10)Am I reading it wrong ?... would you be better to run 7 5/8"tieback before perforating (steps 11-12) ... you are likely to get perf trash in your tieback seal section at 8750' as you pull them out. I went back and forth on this a few times, was trying to eliminate the need for another work string by perforating first (could run TCP guns on 5" DP). Once the tieback is run, we will need to pick up a smaller work string. All efficiency is lost though if we damage the seal bore or tear up the seal assy trying to stab it in. You are right, probably better to just eat the time & $$for another workstring because the risk of damaging the seal assy or seal bore is high. Call me if these need a bit of clarifying... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/12/2012 Steelhead Field Fracture Gradient Data • •• • 1,000' • •• $ • • 2,000' — — • 3,000' ♦ • 4,000' • • • • 5,000' • a A 6,000' 7,000' - 8,000' 9,000' • • 10,000' --- - • 11,000' — 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 Fracture Gradient(PSI/FT) Cook Inlet LOT-FIT Data 5-17-10.xls 4/12/2012 Schlumberger Drill Pipe Conveyed Perforating (No Packer) Rev. 3, March 15, 2010 Scot Shier 15-March-2010 CONTENTS Scope& Background Safety Issues Pre Job Planning&Guidelines Step by Step Procedure SCOPE&BACKGROUND This recommended practice covers the current best practices for drill pipe conveyed perforating with Schlumberger on the North Slope. SAFETY ISSUES A pre job safety meeting should be held with the crews before picking up the perforating guns. Topics should include the following points: • HZS risks,spill prevention,and well control issues • Personnel assignments • Maximum safe pumping pressure prior to firing guns It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the Keep non-essential off the driller,floorhands,and the perforating crew. All other personnel will stay off the rig floor and rig floor and all personnel out of thecellar.ehileguns out of the cellar until the perforating string is at least 300-ft below the rotary table. You are at the surface. have the STOP WORK AUTHORITY at all times. Radio silence is not required with the Schlumberger systems described in this recommended practice. Page 1 of 5 Schlumberger PRE JOB PLANNING AND GUIDELINES The Asset requirements for perforating intervals, gun and charge type, directional survey, BHT, formation pressure, fluids and densities to be used, well sketch and amount of underbalance will be communicated to the Company Representative by the Operations Drilling Engineer. The Company Representative should verify that the onsite service companies are equipped accordingly. Also, • Schlumberger TCP Specialist to provide detailed information in the selection of gun size versus liner size and under balance needed and charge performance desired. • Schlumberger will provide a detailed tool string diagram. All tools will be accurately strapped and callipered. • All gun adapters will have bleed ports machined in them for trapped pressure procedures. • The drill pipe or tubing spacer should be cleaned and inspected prior to every job. • If the inner string from a liner inner string cement job is on a perforating job, it must be drifted or have a drill pipe wiper plug run through it. This will ensure that residual cement is not present. A clean out run must be considered prior to long gun runs. • In order to set guns on depth with drill pipe measurement, an accurate strap of the string is essential. • A flow return tank is not required provided there are no plans to bring reservoir fluids to surface. If a diesel cushion is planned or if the reservoir fluids are produced,then a flow return tank will be needed. STEP BY STEP PROCEDURE 1. Make up perforating string in the following order. Gun type, spacing and charges will be as specified in the completion procedure. • Guns • eFire Firing Head V • Circ Sub • XO to Drill Pipe or Tubing • Drill Pipe to surface,use wiper rubber when running DP Page 2of5 Schlumberger Note: Perforating guns will be run with slips and dog collar. It is imperative that all slip dies be inspected prior to running the guns. Dies that are dull will tend to let the guns slip and catch causing the charges within to shift and possibly rotate out of the scalloped area of the gun. Use of a dog collar is mandatory. 2. Run in the hole with the perforating string on drill pipe. A3. Position perforating assembly by drill pipe measurement and by tagging the landing collar,then picking up to place the guns on depth. Ensure no tool joints A Schlumberger Specialist are across the BOPs. must be on rig floor during all pumping operations Note: In high angle wells, correlating with wireline is usually not an option unless the job has been designed to allow the correlation tools to be pumped down the string. 5. Rig up head-pin and surface flow equipment. Ensure this rig up provides the ability connect a sonogram to listen for guns firing. Note: Call out fluid level shooting equipment. If the equipment is not available do not shut the rig down to wait on it. 6. Pressure test all surface lines to 3000 psi. Circulate fluids in as needed for underbalance. 7. Close the annular preventer and fire the guns by pressuring up and bleeding off as directed by the TCP Specialist. Monitor the guns firing with the fluid level equipment and by blow into a bucket. C-Co-,' 8. Immediately after firing start tripping out of the hole, keeping the hole filled,and get the guns above the perforated interval. At that point stop and monitor well for loss or gain.Circulate as necessary. Note: Consider bull-heading down the drill pipe to free up the guns if they become stuck on bottom. 9. Pull out of hole with perforating tools. Monitor hole fill closely while accounting for the static loss rate observed after perforating. 10. Before rigging down guns confirm the guns will be secured on the skate safely. If the guns are bent more than normal you will need to make sure the gun is not going to spin allowing it to slide past the buggy. If it doesn't look safe you'll need to be 100%tied off until the gun is lowered down the skate. Each gun will need to be checked before unlatching the elevators. Page 3 of 5 • Schlumberger A i1. Conduct a safety meeting before the first gun is above ground level. Address well control,gun handling,and trapped pressure issues. Keep non- 12. Rig down perforating equipment and lay guns out for removal. Keep cellar clear essential off the rig floor and all of personnel. Inspect and report all shots fired or misfired. personnel out of the C are at 13. Trapped pressure procedures for blank gun sections guns are at the surface. • If hydraulic tubing tongs without backups are available, it is highly recommended they be used to unscrew the spent guns during the rig down procedure. There is no torque involved in unscrewing the gun adapter. • After installing the collar clamp, cover the hole before removing any screws or retaining clips from the gun in the slips. Remove the screws or retaining clip from the upper adapter of the gun in the slips. • All gun adapters have bleed grooves and holes in them to allow trapped pressure to vent before the threads of the adapter are completely disconnected. This feature requires the upper adapter of the gun in the slips to be unscrewed while still made up to the gun in the elevators. • If either gun has a blank section next to the connection, a mud bucket that covers the connection must be clamped to the upper gun while it is being unscrewed from the lower gun in the slips. If present, trapped pressure will vent through the bleed grooves and holes in the gun adapter. By using the hydraulic tongs and the clamp-on mud bucket, the operators are away from the connection and any possible trapped pressure, fluid or debris during this operation. Any pressurized fluid is directed down towards the slips inside the mud bucket. Remove the mud bucket only after the connection is completely broken, all trapped pressure bled off,and the unscrewed gun is pulled out of the gun in the slips. • It is not necessary to use the mud bucket on spent guns that have holes on both sides of the gun adapters. • Swing the gun hanging in the elevators away from the hole and position it over a bucket. Make sure the bottom of the gun is below eye level before removing the adapter. Remove the adapter from the bottom of the gun, allowing any fluid or debris to drain into a bucket. Page 4of5 . Schlumberger Screw a plastic shipping plug into the bottom of the gun before laying it down. Be aware of sharp burrs around the shot holes. • Removing the adapter ensures the gun is drained and will not leak fluids outside the rig,reducing the risk of a spill on location. CONTINGENCIES If guns must be pulled out of the hole UNFIRED, after a ball has been dropped and lost or possibly on seat, NO PUMPING DOWN THE COILED TUBING OR DRILL PIPE IS ALLOWED FOR ANY REASON. The Schlumberger TCP Specialist in charge must be present before the pump is used in any case. If the Schlumberger TCP Specialist needs to leave the rig, it is highly recommended that the pump motors be physically locked out if possible (SCR rig), and/or the coiled tubing be doubled blocked by closing valves to prevent accidental pumping. On a compound rig the mud pump clutch air line can be disconnected. Discuss if a"NO PUMPING ALLOWED"sign needs to be posted on the drillers console. Well control is always an issue when perforating. On a drilling rig we may have large amounts of fluids but this may not be what we need,so it is imperative to have a joint of pipe • the same size as the BOPs, fitted with a "dummy firing head" with circulating ports on the bottom and a TIW valve(open)on the top ready to be deployed for well control. It would also be wise to occasionally hold a BOP drill with this assembly. Should a well come on hard and with no notice an immediate action could be to drop the guns.Schlumberger will provide a lift sub with an internal profile for fishing purposes. Shear rams are not to be used to cut perforating guns. Papp 5 of 5 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, April 11, 2012 3:41 PM To: 'pmazzolini@hilcorp.com' Subject: M-29A( PTD 212-050) Paul, I have been reviewing the PTD. A couple of things still needed but overall pretty complete. 1) Need a proposed completion well sketch. 2) On Step 4 is the 12 PPG FIT the minimum or expected? If expected what is your min FIT? 3) Need the cement class and yield , sacks. 4) Need to specify casing pressure tests at step 8 and 12. ( I found the table on page 3) Also need to test RTTS before ND BOP 5)Are you perfing via TCP or Eline? Need some details. 6) Need to have X-overs with FOSV on rig floor for running casing and TCP guns. 7) I am specifying an initial BOP test of 5000 psi then 4000 psi thereafter. 8) Rig will be on a one week BOP test cycle for entire well as this will be one of its first wells. 9) need a vendor supplied proposed wellhead diagram (with new tubing head adaptor added) 10)Am I reading it wrong ?... would you be better to run 7 5/8" tieback before perforating (steps 11-12) ... you are likely to get perf trash in your tieback seal section at 8750' as you pull them out. Call me if these need a bit of clarifying... Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 4/11/2012 • H1lC0 Paul Mazzolini Hilcorp Alaska,LLC enemy Drilling Manager P.O. Box 244027 Anchorage,AK 99524-4027 3/23/2012 Tel 907 777 8369 Email pmazzolini@hilcorp.com Commissioner Alaska Oil&Gas Conservation Commission 333 W. 7th Avenue Anchorage,Alaska 99501 RECEIVED Re: Steelhead Platform,Trading Bay Unit M-29A APRT ZO1Z Alaska Gil &Gas Cons. Commission Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Trading Bay Unit M-29A well from the Steelhead Platform. Steelhead M-29A is a development oil well planned to be re-drilled in a NNE direction from slot B1-07 utilizing the existing M-29 casing program down to 8950' MD/8483'TVD. The M-29 original perforations will be permanently abandoned from 9,180'to 9,632' (G-zone),from 9,700'to 10,095'(Hemlock),&from 10,312'to 10,538'(West Foreland). All depths referenced above V are MD(RKB). At 8950' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating G-Zone& Hemlock targets. M-29A is designed as a"Build&Hold"well reaching 68 degrees inclination in the tangent section and reaching a total depth of 12,311'MD/10,072'TVD. Drilling operations are expected to commence approximately May 25,2012 depending on the progress of other ongoing projects and the plug&permanent abandonment of the parent wellbore, M-29. V Pursuant to 20 AAC 25.055(a)(3), a spacing exception is required (existing well capable of producing from same pool)and is addressed in a separate,enclosed application. Pursuant to 20 AAC 25.005(c)&(d),the following is included: 1. Plat identifying the property on which the well will be drilled. 2. Diagram&description of blowout prevention equipment. 3. Information on drilling hazards. a. The G-zone & Hemlock are potential hydrocarbon bearing throughout the section. MASP calculations are attached per 20 AAC 25.005(c)(4)(A) b. Potential target reservoirs and their predicted pore pressures are indicated in attached M-29A Well Design Summary. 4. Formation integrity test procedure. 5. Planned casing&cement program(M-29A Well Design Summary) 6. Diverter system will not be used. 16-3/4" 5M BOP equipment will be used throughout the well program. 7. Drilling fluid program 8. Tabulation of predicted depths with equivalent formation pressures. 9. Seismic refraction or reflection analysis— Not required, for exploratory or stratigraphic test well only. Hilcorp Alaska,LLC Page 1 of 2 f 10. Requirements of 20 AAC 25.025 have been met. a. Blanket bond issued for the inlet, bond no.22035244 11. Copy of drilling design summary. 12. General description of waste disposal. Operator does not wish to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. a. Qualified drilling waste will be discharged in accordance with NPDES permit AKG-31-5019 which became effective 7/2/007 and expires 7/2/2012. 13. Requirements of 20 AAC 25.050(b)have been met. a. Plat showing path of proposed wellbore including all adjacent wellbores within 200'is attached. b. All wellbores within 200'of proposed wellbore are owned by Hilcorp. If you have any questions, please don't hesitate to contact myself at 777-8369 or Luke Keller at 777- 8395. Sincerely, f-Pet.44--e 71701/34-e--1-1—. Paul Mazzolini Drilling Manager Attachments: M-29A 10-401 in duplicate M-29A MASP calculations M-29A Drilling Design Summary M-29A Frac gradients M-29A Drilling Fluid Summary M-29A Casing Design M-29A Directional Plan M-29A BOP drawing M-29A ND/VS wellbore plot M-29A Choke manifold drawing M-29A X/Y wellbore plot M-29A Days vs Depth plot M-29A Spider plot M-29A Drilling Hazards M-29A Plat M-29A FIT Procedure M-29A Cement calculations Hilcorp Alaska,LLC Page 2 of 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ----77$GC /t{ 2_q/1 PTD# Z(WS-D /Development Service Exploratory Strati ra hic Test Non-Conventional Well • FIELD:4,4 - 4(u / leve--K- POOL: Check Box for 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 approv-• .. -ct to full compliance with 20 AAC EXCEPTION 25.055. Approve o produce inject is contingent upon issuance of / a c ration o +-r pprovin a spacing exception.cr /�.„ C,,S L,_(.assumes the liability of any protest to 'le 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:9/09/2011 0 To TD. a) L rn ao C . -tea 4 -0 W• cnto- . O 01. p v). co, a , = , , o) , a� a) a), c 3 0. , co d . , . . .N o o • m a. 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N y 'ca) 0E J xp •� y pc `a u) ° a s 0 0 V a � w a U' t0) a (� a a HHiillccoorrpp AAllaasskkaa,, LLLLCC MM2299AA TRADING BAY UNIT Section 33 - T9N - R13W, SM Upper Cook Inlet, Alaska June 12, 2012 to July 5, 2012 FINAL WELL REPORT Tollef Winslow – Sr. Logging Geologist RRoobbeerrtt AAtthhaann –– LLooggggiinngg GGeeoollooggiisstt TTaayylloorr EEnngglleerrtt –– LLooggggiinngg GGeeoollooggiisstt Hilcorp Alaska, LLC M-29A 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW ...................................................................................... 3 1.1 EQUIPMENT SUMMARY ............................................................................................... 3 1.2 PERSONNEL ................................................................................................................. 3 2 GENERAL WELL DETAILS .............................................................................................................. 4 2.1 OBJECTIVES ................................................................................................................. 4 2.2 WELL RESUME ............................................................................................................. 4 2.3 HOLE DATA ................................................................................................................... 5 3 GEOLOGICAL DATA ........................................................................................................................ 6 3.1 FORMATION / ZONE MARKER TOPS .......................................................................... 6 3.2 Hydrocarbon Show Evaluations ..................................................................................... 7 3.3 ZONE SUMMARIES ....................................................................................................... 8 3.3.1 Tyonek Formation ............................................................................................................. 8 3.3.2 Hemlock Formation ......................................................................................................... 16 3.3.3 West Foreland Formation ............................................................................................... 24 3.4 WELL LITHOLOGY ...................................................................................................... 25 3.5 SAMPLING PROGRAM AND DISTRIBUTION ............................................................ 31 4 DRILLING DATA ............................................................................................................................. 32 4.1 DAILY ACTIVITY SUMMARY ....................................................................................... 32 4.2 SURVEY DATA ............................................................................................................ 33 4.3 MUD RECORD ............................................................................................................. 35 4.4 BIT RECORD ............................................................................................................... 36 5 DAILY REPORTS............................................................................................................................ 37 Enclosures: 2”/ 100’ Formation Log (MD and TVD 2”/ 100’ LWD Combo Log (MD and TVD) 2”/ 100’ Gas Ratio Log (MD and TVD) 2”/ 100’ Drilling Dynamics Log (MD and TVD) Final Well Data on CD Hilcorp Alaska, LLC M-29A 3 1 MUDLOGGING EQUIPMENT AND CREW 1.1 EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Downtime Comments Ditch Gas Electric Driven QGM Gas Trap Mounted In Possum Belly; FID Total Hydrocarbon Analyzer And Chromatograph 2 Rig power failure to trap. Rate of Penetration (ROP) Primary Draw works Belt Driven Encoder On Drum Shaft (Canrig) 0 Pump stroke counter Externally Mounted Magnetic Proximity Sensor (Canrig) 0 Hook load / Weight on bit (WOB) Hydraulic Pressure Transducer (Canrig) 0 Drill string torque Varco Analog Feed 0 Top drive rotary (RPM) Varco Analog Feed 0 Standpipe Pressure Solid State Pressure Transducer 0 Casing Pressure Solid State Pressure Transducer 0 Mud flow in / out (MFI / MFO) MFI: Derived From SPM MFO: Flow Paddle (Canrig) 0 Pit volumes Radar Pit Probes 0 Driller’s work station Explosion Proof Touch Screen Rigwatch (Canrig) 0 Company Man’s work station Rigwatch (Canrig) 0 Tool pusher’s work station Rigwatch (Canrig) 0 Mud Engineer’s work station Rigwatch (Canrig) 0 Pits work station Explosion Proof Touch Screen RigWatch (Canrig) 0 MWD / LWD WITS Feed WITS 0 1.2 PERSONNEL Unit Number: ML04 Mudloggers Years Days Technician Days Sample Catchers Days Tollef Winslow 4 19 Steve Forrest x Dan Hillegeist 17 Robert Athan 1 27 Omar Hinostroza 17 Taylor Englert 1 9 Hilcorp Alaska, LLC M-29A 4 2 GENERAL WELL DETAILS 2.1 OBJECTIVES Steelhead M-29A is a development oil well planned to be re-drilled in a NNE direction from slot B1-07 utilizing the existing M-29 casing program down to 8350’ MD / 7965’ TVD. At 8350’ MD the parent well bore will be sidetracked and new wellbore drilled penetrating G-Zone and Hemlock targets. M-29A is designed as a “Build and Hold” well reaching 73 degrees inclination in the tangent section and reaching a total depth of 11902’ MD / 9715’ TVD. 2.2 WELL RESUME Operator: Hilcorp Alaska, LLC Well Name: Trading Bay Unit M-21A Field and Pool: Trading Bay Unit, McArthur River Field, G-zone, Hemlock State: County Alaska Kenai Borough Company Representatives: Hauck / Leslie Location: X=214137.58, Y=2499527.16, NAD27, ASP, ZONE4. Elevation: – MSL RKB: 160’ to MSL RKB to ML 345’ Classification: Development Oil API #: 50-733-20428-01-00 Permit # 191-027 AFE #: 1210796 Rig Name / Type: Steelhead Rig #51 Primary Target: G-Zone and Hemlock Spud Date :-> Finish Date :-> 6/21/12 – 7/5/12 Total Depth: 3253’ Total Depth Formation: West Foreland Mudlogging Company CANRIG DRILLING TECHNOLOGY, LTD MWD Company: SCHLUMBERGER Tools Run: MWD: Survey, Gamma, Resis, Neu Por, Bulk Den Directional Drilling: SCHLUMBERGER Drilling Fluids Company: HALLIBURTON / BAROID Hilcorp Alaska, LLC M-29A 5 2.3 HOLE DATA Hole Section Maximum Depth T.D. Formation Mud Weight (ppg) Deviation (oinc) Casing Shoe Depth F.I.T. MD TVD MD TVD 8.5” 11720’ 9695.74’ West Foreland 9.45 75.22 7” 8410’ 8017’ 12.0 Hilcorp Alaska, LLC M-29A 6 3 GEOLOGICAL DATA 3.1 FORMATION / ZONE MARKER TOPS Note: CT: Coal Top CB: Coal Base ST: Sand Top SB: Sand Base. FORMATION ACTUAL MD (ft) TVD (ft) G01ST 8801 8359 G02ST 8911 8455 G03ST 8987 8520 G04ST 9039 8564 G05ST 9098 8614 G1ST 9189 8690 G2ST 9241 8732 G3ST 9322 8795 G4ST 9394 8851 G5ST 9514 8941 G6ST 9634 9028 G7ST 9729 9094 HK1T 9788 9131 HK2T 9880 9182 HK3T 10063 9262 HK4T 10200 9304 HK5T 10753 9451 HK6T 11085 9535 HK7T 11438 9623 WFT 11588 9662 WF1T 11629 9672 Hi l c o r p A l a s k a , L L C M- 2 9 A 7 3. 2 H y d r o c a r b o n S h o w E v a l u a t i o n s Hilcorp Alaska, LLC M-29A 8 3.3 ZONE SUMMARIES 3.3.1 Tyonek Formation G01ST: 8801’ MD, 8359’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 162.3 1.9 45.9 363 0 44 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8904’ 363 53838 868 213 34 27 9 8 The G01ST begins as an upper medium to upper fine grained quartz sand. This sand is spherical, angular, poorly sorted, unconsolidated, and calcareous in nature. This sand grades into a soft, medium gray to olive gray, poorly indurated tuffaceous siltstone with crumbly to brittle tenacity, blocky fracture, massive cuttings habit, earthy to dull luster, silty to clayey texture, and laminae structure. The end of the formation grades into an upper medium to upper fine grained tuffaceous sandstone that is light gray to light olive gray, angular to sub angular, moderately spherical, unconsolidated to poorly consolidated, texturally and compositionally immature, and supported by a tuffaceous matrix. A minor show is present from 8856’ – 8861’. This show exhibits a 30% patchy dull light yellow fluorescence, streaming dull light milky yellow cut fluorescence, clear cut, faint to dull yellow white residual fluorescence, and no odor, staining, residual cut, or free floating oil at the shakers. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSA OIL NON PRODUCTIVE C1/C2 C1/C C1/C5C1/C3 Hilcorp Alaska, LLC M-29A 9 G02ST: 8911’ MD, 8455’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 79.0 2.3 34.8 84 5 21 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8911’ 84 10776 103 35 56 21 1 1 The G02ST is composed of sand that is medium gray to medium light gray with light olive gray sub hues. The grains are upper fine to upper very fine, spherical to sub discoidal, angular to sub angular, moderately sorted, unconsolidated, texturally and compositionally immature, and predominately quartz. Also present, but not as dominant are tuffaceous silt, bituminous coal, and carbonaceous shale. G03ST: 8987’ MD, 8520’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 112.9 1.0 26.2 79 5 32 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8991’ 79 12756 107 34 24 17 6 19 The G03ST is dominated by a light gray to medium light gray sand. The grains are angular, moderately spherical, poorly sorted, unconsolidated, texturally immature, and grade from lower medium at the top of the formation to upper very coarse at the bottom. Tuffaceous siltstone is also present to a lesser degree. G04ST: 9039’ MD, 8564’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 49.3 2.6 16.4 79 1 14.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9043’ 79 11688 105 24 20 12 1 2 The G04ST is composed of a medium gray, moderately hard, well indurated tuffaceous siltstone that has a brittle tenacity, irregular fracture, earthy luster, silty texture, and laminae structure. Carbonaceous shale is also present in this formation, as is a thin layer of bituminous coal at roughly 9075’. Hilcorp Alaska, LLC M-29A 10 G05ST: 9098’ MD, 8614’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 149.2 4.9 36.6 255 3 39 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9173’ 255 40151 841 534 173 249 53 122 The G05ST is an interbedded sand, sandstone, and tuffaceous sandstone. The sand is medium light gray to medium gray; lower very fine to upper very fine coarsing downward to upper coarse to lower coarse with very fine grains; spherical to sub discoidal; angular to very angular; well sorted progressing to bimodal well sorted; unconsolidated sand, firm friable sandstone; matrix supported; texturally immature; compositionally immature; quartz grains. There was some bitiminous coal. A fair oil show was present; it’s qualities are: no odor; no grain stain; 30% patchy dull yellow fluorescence; slow, dull, blue white cut fluorescence; clear visual cut; no residual cut; bright white residual fluorescence; porosity and permeability visually fair. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GS OIL NON PRODUCTIVE C1 /C2 C1 C1 /C5C1 /C3 Hilcorp Alaska, LLC M-29A 11 G1ST: 9189’ MD, 8690’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 174.3 12.5 102.6 325 28 174.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9217’ 325 40158 1962 2075 733 1056 226 441 The G1ST is composed of sand and tuffaceous sandstone that is medium gray to olive gray, lower fine to upper medium grained, moderately spherical, angular to sub angular, moderately sorted, unconsolidated to poorly consolidated, supported by a tuffaceous matrix, and predominately quartz grains. A hydrocarbon show is present throughout the formation. The show contains 10% straw to brown grain stain, 60% dull to bright patchy yellow white fluorescence, blooming dull to bright milky white cut fluorescence, clear visual cut, no residual cut, and bright yellow white residual fluorescence. No odor or free oil in the mud was detected. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GS OIL NON PRODUCTIVE C1 /C2 C1 C1 /C5C1 /C3 G2ST: 9241’ MD, 8732’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 260.4 5.4 96.1 199 18 24.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9256’ 199 14520 923 1268 428 697 256 250 Hilcorp Alaska, LLC M-29A 12 The G2ST is composed of sand and tuffaceous sandstone that is light gray to light olive gray, lower fine to lower medium grained, moderately spherical, angular to sub angular, moderately sorted, unconsolidated to poorly consolidated, supported by a tuffaceous matrix, and texturally and compositionally immature. A hydrocarbon show is present throughout the formation. Characteristics of the show include 60% patchy dull to bright yellow white fluorescence, streaming dull milky white cut fluorescence, clear visual cut, no residual cut, bright yellow white residual cut. No odor, grain staining, or free oil in the mud was detected. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 G3ST: 9322’ MD, 8795’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 268.3 1.4 92.4 126 0 48.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9350’ 126 12182 89 1146 433 681 249 259 The G3ST is composed of sand and tuffaceous sandstone that is medium light gray to light olive gray, upper very fine to upper fine grained, moderately spherical, sub angular to sub rounded, moderately to well sorted, unconsolidated to poorly consolidated, supported by a tuffaceous matrix, and predominately quartz grains. A hydrocarbon show is present throughout the formation. Characteristics of the show include 70% patchy dull to bright yellow white fluorescence, clear visual cut, streaming bright white blue cut fluorescence, light pale straw residual cut, bright yellow white residual fluorescence. No odor, grain staining, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 13 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 G4ST: 9394’ MD, 8851’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 199.5 1.4 82.1 238 0 67 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9470’ 238 25806 2060 1427 457 745 232 221 The G4ST is composed of sand and tuffaceous sandstone that is medium dark gray to olive gray, upper fine to upper coarse grained, poorly to moderately spherical, angular to sub angular, poorly sorted, unconsolidated to poorly consolidated, supported by a tuffaceous matrix, texturally immature, and predominately quartz grains. A hydrocarbon show is present throughout the formation. Characteristics of the show include 50% patchy dull yellow white fluorescence, clear visual cut, streaming bright white blue cut fluorescence, no residual cut, and bright yellow white residual fluorescence. No odor, grain staining, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 14 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 G5ST: 9514’ MD, 8941’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 228.4 1.7 79.2 140 19 82.3 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9607’ 140 12899 916 1286 448 727 309 174 The G5ST is composed of sand, sandstone, and tuffaceous sandstone that is medium gray to medium light gray with a light olive gray sub hue, upper to upper medium grained, moderately spherical, sub angular to sub rounded, moderately sorted, unconsolidated to moderately consolidated, supported by a tuffaceous matrix, and predominately quartz grains. Two hydrocarbon shows are present throughout the formation. The first show contains 60% patchy dull to bright yellow white fluorescence, clear visual cut, streaming bright white blue cut fluorescence, no residual cut, and bright yellow white residual fluorescence. No odor, grain staining, or free oil in the mud was detected. The second show contains 70% patchy bright to dull yellow white fluorescence, straw visual cut, streaming bright milky white cut fluorescence, light straw residual cut, and bright yellow residual fluorescence. No odor, grain staining, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 15 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 G6ST: 9634’ MD, 9028’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 216.8 0.8 70.3 167 12 50.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9651’ 167 31783 1672 716 158 258 99 213 The G6ST is composed of sand and sandstone that is medium light gray to light gray, lower medium to upper fine grained, spherical, angular, moderately sorted, unconsolidated to friable, supported by a tuffaceous matrix, and predominately quartz grains. A hydrocarbon show is present through the middle of the formation. Characteristics include 60% patchy bright yellow white fluorescence, slow streaming blue Hilcorp Alaska, LLC M-29A 16 white cut fluorescence, clear visual cut, light yellow residual cut, and faint yellow residual fluorescence. No odor, grain staining, or free oil in the mud was detected. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 G7ST: 9729’ MD, 9094’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 347.3 0.6 38.5 67 9 22.5 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9734’ 67 14853 721 322 61 104 12 19 The G7ST is composed of sand that is light olive gray to olive gray, upper very fine to lower fine grained, sub prismoidal to spherical, angular to sub angular, well sorted, unconsolidated, and predominately quartz. 3.3.2 Hemlock Formation HK1T: 9788’ MD, 9131’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 250.4 4.3 72.3 116 8 53.2 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N Hilcorp Alaska, LLC M-29A 17 9804’ 116 15787 2425 2056 552 980 129 242 The HK1T is composed of sand and tuffaceous sandstone until roughly 9870’ where silt and tuffaceous siltstone dominate. The sand and tuffaceous sandstone is medium gray to medium light gray, upper coarse to upper medium grained, sub prismoidal to spherical, angular to sub angular, well sorted, unconsolidated to easily friable, supported by a tuffaceous matrix, texturally immature, and compositionally sub mature. There is a hydrocarbon show during this section. Characteristics include trace light brown grain stain, 80% even bright yellow white fluorescence, instantaneous streaming bright blue white cut fluorescence, clear visual cut, no residual cut, and bright yellow residual fluorescence. No odor or free oil in the mud was detected. The silt and tuffaceous siltstone is olive gray to light olive gray, soft, poorly indurated, and has a crumbly tenacity, earthy fracture, nodular cuttings habit, dull luster, silty texture, and laminae structure. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK2T: 9880’ MD, 9182’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 251.9 8.8 70.1 78 14 35.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10045’ 78 10942 1114 1283 369 684 253 132 The HK2T is composed of sand and sandstone that is medium gray to medium light gray, lower medium to upper coarse grained with occasional gravel and fine grains, spherical to sub discoidal, angular to sub angular, moderately sorted, matrix supported, texturally immature, and compositionally immature. Quartz sand and chert are found as well. A hydrocarbon show is present throughout the formation. Characteristics include a very faint oil odor, 70% to 90% even bright yellow fluorescence, streaming bright blue white cut fluorescence, clear visual cut, no residual cut, and bright yellow residual fluorescence. No grain staining or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 18 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK3T: 10063’ MD, 9262’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 232.6 2.1 54.0 75 13 37.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10117’ 75 9013 1124 1180 306 568 129 173 The HK3T is composed of sand and sandstone that is medium gray to medium light gray, upper fine to upper very coarse grained with occasional upper very fine grains and gravel, moderately spherical, angular to sub angular, poorly sorted, unconsolidated to moderately consolidated, grain supported, texturally immature, and compositionally immature. A hydrocarbon show is present throughout the formation. Characteristics include 70% patchy bright yellow white fluorescence, pale straw visual cut, streaming bright white cut fluorescence, faint amber residual cut, and bright dull-orange residual fluorescence. No odor, grain staining, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 19 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK4T: 10200’ MD, 9304’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 233.7 0.0 39.5 119 2 34.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10704’ 119 38306 4316 4470 1412 2269 770 432 The HK4T is composed of a sand and sandstone that is medium gray to medium light gray, upper fine to upper very coarse grained with occasional upper very fine grains and gravel, moderately spherical, angular to sub angular, poorly sorted, texturally immature, and compositionally immature. The sand is unconsolidated and the sandstone is moderately consolidated. There are two hydrocarbon shows that occur during this zone. The first show characteristics include 50% to 70% patchy bright yellow white fluorescence, pale straw visual cut, streaming bright white cut fluorescence, faint amber visual residual cut, and bright dull orange residual fluorescence. No odor, staining, or free oil in the mud was detected. The second show characteristics include 70% patchy dull to bright yellow white fluorescence, clear visual cut, slow streaming dull white blue cut fluorescence, no visual residual cut, and dull to bright yellow white residual fluorescence. No odor, grain stain, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 20 Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK5T: 10753’ MD, 9451’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 152.1 0.4 36.6 73 8 34.9 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10960’ 73 12115 861 881 420 617 106 113 The HK5T is composed of a sand or sandstone that is medium to medium dark gray, upper fine to lower medium grained, sub discoidal to sub prismoidal, sub angular to sub rounded, moderately sorted, matrix supported, texturally sub mature, and compositionally sub mature. The sand is unconsolidated and the sandstone is friable. There are three hydrocarbon shows that occur throughout this zone. The first show characteristics include 70% patchy dull to bright yellow white fluorescence, pale straw visual cut, very slow streaming dull blue white cut fluorescence, no visual residual cut, bright yellow residual Hilcorp Alaska, LLC M-29A 21 fluorescence. No odor, grain stain, or free oil in the mud was detected. The second show characteristics include 10% straw to brown grain stain, 70% patchy dull to bright yellow white fluorescence, pale straw visual cut, slow streaming dull to bright white to blue white cut fluorescence, no visual residual cut, and bright yellow orange residual fluorescence. No odor or free oil in the mud was detected. The third show characteristics include 40% patchy dull yellow white fluorescence, no visual cut, streaming bright white to white blue cut fluorescence, light straw visual residual cut, and bright yellow orange residual fluorescence. No odor, grain stain, or free oil in the mud was detected. Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 Hilcorp Alaska, LLC M-29A 22 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK6T: 11085’ MD, 9535’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 182.4 0.5 36.1 111 7 42.3 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11412’ 111 17757 1275 1143 946 949 943 943 The HK6T is composed of a sand and sandstone that is medium gray to medium dark gray with an olive gray sub hue, upper very fine to lower medium, sub discoidal to spherical, sub angular to sub rounded, moderately to well sorted, matrix supported, texturally sub mature, and compositionally sub mature. The sand is unconsolidated and the sandstone is friable. There are two hydrocarbon shows throughout this zone. The first show characteristics include trace brown grain stain, 80% patchy to even bright yellow white fluorescence, dark straw visual cut, blooming followed by streaming bright white blue cut fluorescence, light pale straw residual cut, and bright yellow residual fluorescence. No odor or free oil in the mud was detected. The second show characteristics include 50% patchy dull to bright yellow fluorescence, straw visual cut, streaming dull to bright white cut fluorescence, no visual residual cut, and dull to bright yellow orange residual fluorescence. No odor, grains stain, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 23 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 HK7T: 11438’ MD, 9623’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 228.8 0.2 43.6 161 9 65.0 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11485 161 13628 1651 1933 492 1062 317 402 The HK7T is composed of sand and sandstone that is medium gray to olive gray, lower very fine to lower medium grained, sub discoidal to spherical, sub angular, moderately to well sorted, and grain supported. The sand is unconsolidated and the sandstone is friable. There is one show throughout the zone. The show characteristics include 70% patchy dull to bright yellow white fluorescence, straw visual cut, streaming dull to bright white to white blue cut fluorescence, no visual residual cut, and dull to bright yellow residual fluorescence. No odor, grain stain, or free oil in the mud was detected. Hilcorp Alaska, LLC M-29A 24 Pixler Plot 1 10 100 1000 10000 12 34 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/ C2 C1/ C4 C1/ C5C1/ C3 3.3.3 West Foreland Formation WFT: 11588’ MD, 9662’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 22.6 0.2 3.7 9 4 7.8 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11588’ 9 2686 76 59 - 18 14 26 The WFT is predominately quartz sand that is clear to milky white with some light gray grains, fine to lower coarse grained, angular, rough, and poorly to moderately sorted. An unconsolidated and grain supported sandstone with a light calcareous and tuffaceous matrix is also present. WF1T: 11629’ MD, 9672’ TVD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 78.8 2.7 20.7 70 3 13.6 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 11656’ 70 19020 1168 1040 248 576 - - The WF1T is composed of a brownish gray to olive gray, poorly indurated shale and carbonaceous shale that has a crumbly tenacity, irregular fracture, massive to flaky cuttings habit, earthy to dull luster, silty to clayey texture, and laminae structure. Hilcorp Alaska, LLC M-29A 25 3.4 WELL LITHOLOGY Sand/Sandstone (8467' - 8540') = light gray to very light gray; upper medium to upper fine; spherical to sub discoidal; angular to sub angular; moderately sorted; tuffaceous matrix; matrix supported; texturally immature; compositionally immature; quartz sand; tuffaceous silt; carbonaceous material; hcl reaction. Carbonaceous Shale/Coal (8540 - 8560) = olive black; firm friable to moderately hard; planar fracture; tabular cuttings habit; resinous luster. Sand/Sandstone (8540' - 8610') = light gray to light olive gray; upper medium to lower fine; sub rounded to rounded; moderate sphericity; moderately sorted; matrix supported; tuffaceous matrix; compositionally immature; quartz sand; hcl reaction. Sand/Sandstone/Tuffaceous Sandstone (8610' - 8650') = medium gray to medium light gray with light olive gray sub hue; upper medium to upper fine; spherical to sub discoidal; angular to sub angular; moderately sorted; unconsolidated to poorly consolidated; tuffaceous matrix; compositionally immature; texturally immature; quartz with chert; bitimous coal. Siltstone/Tuffaceous siltstone (8650' - 8730') = medium gray to light gray; soft poorly indurated; brittle to crunchy tenacity; planar to earthy fracture; sub nodular and tabular cuttings habit; dull to earthy luster; silty to gritty texture; laminae to thin structure; carbonaceous laminations; bituminous to sub bituminous coal @ 8710', brittle to dense, conchoidal and spintery fracture; elongated cuttings habit; resinous to waxy luster; laminae to massive structure; calcareous tuff. Tuffaceous Silt/Sand (8730' - 8760') = medium gray to medium light gray; soft; poorly indurated; elastic tenacity; earthy fracture; massive cuttings habit; dull to earthy luster; silty texture; thin to laminae to massive structure; quartz sand, upper medium to upper fine, spherical, angular, poorly sorted, unconsolidated; calcareous. Siltstone/Tuffaceous Siltstone (8760 - 8850) = medium gray to olive gray; soft to friable; poor induration; crumbly to brittle tenacity; blocky fracture; massive cuttings habit; earthy to dull luster; silty to clayey texture; laminae structure. Sand/Tuffaceous Sandstone (8850' - 8895) = light gray to light olive gray; upper medium to upper fine; angular to sub angular; moderate sphericity; matrix supported; tuffaceous matrix; texturally immature; copositionally immature; quartz sand; carbonaceous; 8856' - 8861': no odor; no staining; dull light yellow; 30% patchy fluoresence; streaming, dull light milky yellow cut fluoresence; clear cut no residual cut; faint to dull, yellow white residual fluoresence. Coal (8895' - 8911') = black; hard; well indurated; conchoidal fracture; tabular cuttings habit; dull luster; thin structure; bituminous. Sand (8911' - 8972') = medium gray to medium light gray, light olive gray sub hue; upper fine to upper lower fine; spherical to sub discoidal; angular to sub angular; moderately sorted; unconsolidated; texturally and compositionally immature; quartz sand; tuffaceous silt, bituminous coal, carbonaceous shale. Coal (8972' - 8987') = black; moderately hard to hard; well indurated; conchoidal fracture; dull to vitreous luster; thin structure; bituminous. Sand/Tuffaceous Siltstone (8987' - 9039) = light gray to medium light gray; lower medium to upper very coarse; angular; moderate sphericity; poor sorting; unconsolidated; texturally immature. Hilcorp Alaska, LLC M-29A 26 Suffaceous Siltstone (9039' - 9098') = medium gray; moderately hard; well indurated; brittle tenacity; irregular fracture; earthy luster; silty texture; laminae structure; coal, bitiminous. Sand/Sandstone/Tuffaceous Sandstone (9098' - 9125') = medium light gray to medium gray; lower very fine to upper very fine, coarsing downward to upper coarse to lower coare with very fine grains; spherical to sub discoidal; angular to sub angular; well sorted progressing to bimodal well sorted; unconsolidated sand, firm friable sand stone; matrix supported texturally immature; quartz grains; biminous coal; no odor; no grain stain; 30% patchy dull yellow fluorescence; slow, dull blue white cut fluorescence; clear visual cut; no residual cut; bright white residual fluorescence; porosity and permeability visually fair. Tuffaceous Siltstone/Coal (9125' - 9180) = black; hard; conchoidal fracture; massive cuttings habit; dull to waxy luster. Sand/Tuffaceous Sandstone (9180' - 9250) = medium gray to olive gray; lower fine to upper medium; moderate sphericity; angular to sub angular; moderately sorted; unconsolidated to poorly consolidated; tuffaceous matrix; matrix supported; texturally immature; quartz grains; no odor; 10% grain stain; 60% bright patchy yellow white fluorescence; blooming dull to bright milky white cut fluorescence; clear visual cut; no residual cut; bright yellow white residual fluorescence. Sand/Tuffaceous Sandstone (9250' - 9300) = light gray to light olive gray; upper fine grain; moderate sphericity; sub angular; moderate sorting; poorly consolidated; tuffaceous matrix; matrix supported; quartz grains; no odor; no stain; 60% patchy bright yellow fluorescence; streaming dull milky white cut fluorescence; clear cut; no residual cut; bright yellow white residual cut. Sand/Tuffaceous Sandstone (9300' - 9400) = light olive gray; upper very fine to upper fine; moderate sphericity; sub angular; poorly consolidated; tuffaceous matrix; matrix supported; quartz grains; 9330' - 9400 no odor, no stain; 70% patchy dull yellow white; clear cut; streaming bright white blue fluorescence cut; light pale straw residual cut; bright yellow white residual fluorescence; no free oil in mud. Sand/Tuffaceous Sandstone (9400' - 9450) = medium dark gray to olive gray; upper fine to upper coarse; low to moderate sphericity; angular to sub angular; poor sorting; poorly consolidated; matrix supported; tuffaceous matrix; quartz grains; no odor; no stain; 50% patchy dull yellow white fluorescence; clear cut; streaming bright blue white cut fluorescence; no residual cut; bright yellow white residual fluorescence. Coal/Tuffaceous Siltstone (9450' - 9510) = bituminous; black; hard to moderately hard; conchoidal to splintery fracture; platy cuttings habit; resinous to vitreous luster; thin structure. Sand/Tuffaceous Sandstone (9510' - 9550) = medium gray to medium light gray with light olive gray sub hue; upper fine to upper medium; moderate sphericity; sub angular to sub rounded; moderately sorted; unconsolidated to moderately consolidated; matrix supported; tuffaceous matrix; quartz grains; no odor; no staining; 70% patchy dull to bright yellow white fluorescence; clear cut; streaming bright white blue cut fluorescence; no residual cut; bright yellow white residual fluorescence. Sand/Tuffaceous Sandstone (9550' - 9630) = light gray to light olive gray; lower fine to lower coarse; angular to sub angular; moderate sphericity; poorly sorted; unconsolidated; tuffaceous matrix; matrix supported; quartz grains; no odor; no stain; 70% patchy bright to dull yellow white fluorescence; straw cut; streaming bright milky white cut fluorescence; light straw residual cut; bright yellow residual fluorescence. Hilcorp Alaska, LLC M-29A 27 Siltstone/Tuffaceous Siltstone (9630' - 9690') = medium gray to light gray; soft; moderately poorly indurated; brittle tenacity; planar fracture; massive cuttings habit; earthy luster; silty texture; laminae structure; bitiminous coal, carbonaceous silt. Sand/Sandstone (9360' - 9720') = medium light gray to light gray; lower medium to upper fine; spherical; angular; moderately sorted; unconsolidated to friable; tuffaceous matrix; matrix supported; quarz; no odor; no stain; 60% yellow white fluoresence; slow streaming blue white cut fluoresence; no visual cut; clear residual cut; faint yellow residual fluoresence. Coal (9720' - 9730') = black; hard; planar fracture; tabular cuttings habit; laminae structure; bitiminous. Sand (9730' - 9800') = light olive gray to olive gray; upper very fine to lower fine; sub prismoidal to spherical; angular to sub angular; well sorted; unconsolidated; quartz; slight 10% yellow fluoresence at end of interval. Sand/Tuffaceous Sandstone (9800' - 9860') = medium gray to meidum light gray; upper coarse to upper medium; sub prismoidal to spherical; angular to sub angular; well sorted; unconsolidated, easily friable; matrix suppported; tuffaceous matrix; texturally immature; compositionaly sub mature; quartz; very faint odor; trace light brown grain stain; 80% even, bright, yellow white sample fluoresence; instantaneous streaming, bright blue white fluoresence cut; clear visual cut; no visual residual cut; bright yellow residual fluoresence; porosity /permeability visually good. Siltstone/Tuffaceous Siltstone (9860' - 9910') = olive gray to light olive gray; soft; poorly indurated; crumbly tenacity earthy fracture; nodular cuttings habit; dull luster; silty texture; laminaestructure; bitiminous coal. Sand/Sandstone (9910' - 9960') = medium light gray to medium gray; upper coarse to upper medium grains; spherical to sub discoidal; angular to sub angular; well sorted; unconsolidated silty matrix; texturally immature; compositionally immature; quartz; faint odor; no grain stain; 80% even bright yellow fluoresence; bright, fast, streaming, blue white cut fluoresence; clear visual cut; light brown residual cut; bright gold yellow residual fluoresence; porosity and permeability visually fair. Sand/Sandstone (9960' - 10070') = medium gray to medium light gray; lower medium to upper coarse, occasional gravel and fine grains; spherical to sub discoidal; angular to sub angular; moderately sorted; matrix supported; texturally immature; compositionally immature; quartz sand; chert; faint oil odor; no grain stain; 80% - 90% even bright yellow fluoresence bright medium fast streaming cut fluoresence; clear visual cut; no visual residual cut; bright golded yellow residual fluoresence; porosity and permeability visually fair. Sand/Sandstone (10070' - 10110') = medium gray to medium dark gray with olive gray sub hue; lower fine to upper medium; moderate sphericityl sub angular to sub rounded; moderately sorted; unconsolidated sand to moderately consolidated sandstone; matrix supported; texturally immature; compositionally immature; quartz grains. Sand/Sandstone (10110' - 10180') = medium gray to medium light gray; lower medium to lower very coarse, occasional gravel; moderate sphericity; angular to sub angular; poorly sorted; unconsolidated sand; moderately consolidated sandstone; silt matrix; grain supported; texturally immature; compositionally immature; quartz grains. Coal (10180' - 10190') = black; hard; conchoidal to massive fracture; resinous to vitreous luster; bituminous. Hilcorp Alaska, LLC M-29A 28 Sand/Sandstone (10190' - 10300') = medium gray to medium light gray; upper fine to upper very coarse, occasional upper very fine and gravel; moderate sphericity; angular to sub angular; poorly sorted; unconsolidated sand to moderately consolidated sandstone; grain supported; texturally immature; compositionally immature; quartz grains; no odor; no staining; 70% patchy bright yellow white fluorescence; pale straw cut; streaming bright white cut fluorescence; faint amber residual cut; bright dull orange residual fluorescence; no free oil in mud. Sand/Sandstone (10300' - 10370') = medium light gray to medium gray; upper fine to upper coarse with some gravel; sub prismoidal to sub discoidal; angular to sub angular; moderately to poorly sorted; unconsolidated sand, friable to firm friable sandstone; matrix supported; texturally immature; compositionally immature; quartz, pitted; chert; slight oil odor; no grain stain; 80% patchy to even bright yellow white fluorescence; slow to medium streaming cut bright blue white cut; no visual cut; bright golden yellow residual fluorescence cut; no free oil in mud; porosity and permeability visually tight to fair. Sand/Sandstone (10370' - 10430') = medium gray to medium light gray; upper coarse to upper fine with some gravel; sub prismoidal to sub discoidal; angular moderately sorted; unconsolidated sand, friable sandstone; matrix supported; quartz, pitted; chert; no grain stain; slight oil odor; 60% patchy to even bright yellow white fluorescence; slow streaming cut; no visual cut; bright golden residual fluorescence; no oil mud. Sand/Sandstone (10430' - 10500') = medium light gray to medium gray; upper bimodal, upper very coarse to upper medium, lower fine to upper very fine; sub prismoidal to sub discoidal; angular to sub angular; poor to moderately sorted; unconsolidated sand, friable sandstone; matrix supported sandstone; texturally immature; compositionally sub mature; no odor; no grain staining; 70% patchy dull to bright yellow white fluorescence; clear cut; slow streaming dull white blue cut fluorescence; no residual cut; dull to bright yellow white residual fluorescence; no free oil in mud. Sand/Sandstone (10500' - 10570') = medium gray to medium light gray; lower fine to upper coarse; poor to moderate sphericity; angular to sub angular; poorly sorted; unconsolidated sand to friable sandstone; matrix supported; texturally immature; compositionally sub mature; quartz sand grains; no odor; no grain stain; 70% patchy dull to bright yellow white fluorescence; clear cut; slow streaming dull white blue cut fluorescence; no residual cut; dull to bright yellow white residual fluorescence; no free oil in mud. Sand/Sandstone (10570'-10660') = medium gray to medium light gray; very fine grain to coarse grain; poor sphericity; angular; rough; poorly sorted; quartz, clear- milky white; trace pyrite, trace glaucanite; coal 15% sandstone is matrix supported. Carbonaceous Shale/Coal (10660' - 10680) = brownish gray to brownish black; soft; poorly indurated; crumbly tenacity; planar fracture; platy cuttings habit; dull to earth luster; clayey to silty texture; laminae structure; bituminous coal; black; hard; conchoidal fracture; massive cuttings habit; vitreous to resinous luster. Sand/Sandstone (10680' - 10800') = medium gray to medium dark gray; upper very fine to lower medium; moderate to high sphericity; sub angular to sub rounded; well sorted; unconsolidated sand; friable sandstone; texturally sub mature; compositionally sub mature; quartz grains; no odor; no grain stain; 70% patchy dull to bright yellow white fluorescence; pale straw visual cut; very slow streaming dull blue white cut fluorescence; no residual visual cut; bright yellow residual fluorescence; no free oil in mud. Sand/Sandstone (10800' - 10920') = medium gray to medium dark gray with olive gray sub hue; upper fine to lower coarse; sub discoidal to sub prismoidal; angular to sub angular; moderate sorting; unconsolidated sand; friable sandstone; matrix supported; silt matrix; texturally sub mature; compositionally sub mature; quartz grains; no odor; 10% straw to brown grain stain; 70% patchy dull to Hilcorp Alaska, LLC M-29A 29 bright yellow white fluorescence; pale straw visual cut; slow streaming dull to bright white to blue white cut fluorescence; no visual residual cut; bright yellow orange residual fluorescence; no free oil in mud. Sand/Sandstone (10920'-10960') = medium to medium dark gray with olive gray sub hues; upper fine to lower coarse; sub discoidal to sub prismoidal; angular to sub angular; moderate sorting; unconsolidated sand with clear to milky white quartz; sandstone is texturally sub mature, friable and matrix supported; no odor; no free oil; 10% straw to brown grain stain; 70% patchy dull to bright yellow fluorescence; slow streaming dull yellow to bright white cut; dull yellow residual ring after cut; 15% anthracite coal; trace pyrite and chert. Sand/Sandstone (10960'- 11070') = medium to medium dark gray; upper fine to lower coarse grains; sub discoidal to sub prismoidal; angular and rough; poor to moderate sorting; sand is unconsolidated with clear to milky white quartz grains; sandstone is sub mature, friable, and matrix supported with trace tuffaceous cement inclusions; no odor; no free oil; trace oil stains; 50% patchy dull to medium yellow fluorescence; slow streaming dull yellow cut; dull yellow residual ring after cut; anthracite coal; trace pyrite; trace glaucanite, trace chlorite and chert; the chert is tan , brown , and black; very hard and brittle. Carbonaceous Shale/Tuffaceous Siltstone (11070' - 11110') = brownish gray to olive gray; soft; poor induration; crumbly tenacity; irregular fracture; massive to tabular cuttings habit; earthy to dull luster; clayey to silty texture. Sand/Sandstone (11110' - 11210') = medium gray to medium dark gray with olive sub hue; upper very fine to lower medium; sub discoidal to spherical; sub angular to sub rounded; moderately to well sorted; unconsolidated sand; friable sandstone; matrix supported; texturally sub mature; compositionally sub mature; quartz grains; no odor; trace brown grain staining; 80% patchy to even bright yellow white fluorescence; dark straw visual cut; blooming followed by streaming bright white blue cut fluorescence; light pale straw residual cut; bright yellow residual fluorescence; no free oil in mud. Sand/Sandstone (11210' - 11250') = medium dark gray to medium gray with olive gray sub hue; lower fine to upper medium; sub discoidal to spherical; angular to sub angular; moderate sorting; unconsolidated sand; friable sandstone; grain supported; tuffaceous matrix; texturally sub mature; compositionally sub mature; quartz grains. Coal (11250' - 11260') = anthracitic; black; hard; conchoidal to irregular fracture; vitreous to resinous luster; dense tenacity. Shale (11260' - 11270') = carbonaceous medium gray with black carb inclusions; medium hardness; flaky to wedgelike; sand/sandstone = 10% fine to upper coarse; light to medium gray; unconsolidated sand; friable sandstone; sub angular grains; tuffaceous and calcareous matrix; quartz gravel to clear to milky white; angular, and rough; trace glaucanite; trace chlorite. Sand/Sandstone (11270' - 11360') = light medium gray; fine to lower coarse grain; sub discoidal to spherical; unconsolidated sand; poor sorting; sandstone grain supported; light calcareous matrix; friable; quartz gravel = clear to white, angular; carbonaceous shale=10%; trace pyrite; trace glaucanite; trace chlorite. Sand/Sandstone(11360' - 11400') = clear milky white, some light gray; fine to coarse; some gravel; poor sorting; irregular and rough impact fracture; very angular; 20% unconsolidated sand, chert, shale, and coal aggregate; 35% dull yellow fluorescence, slow cut, weak residual dull yellow ring. Hilcorp Alaska, LLC M-29A 30 Coal/Sand/Sandstone (11400' - 11450') = medium dark gray to medium gray; upper fine to upper medium; sub discoidal; sub angular to sub rounded; moderately spherical; unconsolidated sand; friable sandstone; quartz grains. Sand/Sandstone (11450' - 11550') = medium gray to olive gray; lower very fine to lower medium; sub discoidal to spherical; sub angular; moderately to well sorted; unconsolidated sand; friable sandstone; grain supported; quartz grains; no odor; no grain stain; 70% patchy dull to bright yellow white fluorescence; straw visual cut; streaming dull to bright white to white blue cut fluorescence; no visual residual cut; dull to bright yellow residual fluorescence; no free oil in mud. Carbonaceous Shale (11550' - 11580') = brownish gray to olive gray; poor induration; crumbly tenacity; platy to flaky cuttings habit; earthy to dull luster; silty to clayey texture; laminae structure; no evidence of hydrocarbons. Sand/Sandstone (11580' - 11630') = quartz clear to milky white, some light gray; fine to lower coarse grain; angular; rough; impact fracture; poor to moderate sorting; unconsolidated sandstone is grain supported, with a light calcareous/tuffaceous matrix; no odor; no visual stain; 10% carbonaceous shale; 10% light gray shale; 5% visual fluorescence – pale straw; slow streaming, bright white/blue cut; bright orange residual ring. Shale/Carbonaceous Shale (11630' - 11720') = brownish gray to olive gray; irregular fracture; massive to flaky cuttings habit; earthy to dull luster; silty to clayey texture; laminae structure. Hilcorp Alaska, LLC M-29A 31 3.5 SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 1 Washed and Dried 8490’ – 11720’ 30’ AOGCC Attn: Christine Mahnken 333 W 7th Ave, Suite 100 Anchorage, AK 99501 Hilcorp Alaska, LLC M-29A 32 4 DRILLING DATA 4.1 DAILY ACTIVITY SUMMARY June 19th 2012: Test bop to 4000 psi. Pull test plug. Pressure test casing/shoe to 1500 psi. Pickup BHA. Trip in hole with whipstock. Begin milling window. June 20th 2012: Finished milling window. Drill 20’ of new formation to 8467’. Circulate and condition 1 bottoms up. Formation integrity test to 1100 psi, 12.0 EMW. Trip out of hole. Lay down BHA. Pick up new BHA. Start tripping in. June 21st 2012: Finish tripping in hole. Begin drilling from 8467' to 8594’ June 22nd 2012: Drill ahead from 8594' to 8813'. June 23rd 2012: Drill ahead from 8813' to 9059’. June 24th 2012: Drill ahead from 9059' to 9067'. Short trip to shoe. No tight spots encountered. Trip in hole. Drill ahead from 9067' to 9134'. Begin tripping out of hole to 2250'. June 25th 2012: Finish tripping out of the hole. Change bit and make up BHA. Trip in hole. Drill ahead from 9134’ to 9427’. June 26th 2012: Drill ahead from 9427’ to 9636’. 6 stand wiper trip, drill ahead from 9636’ to 9727’. Trip out of hole. Lay down BHA. Make up new BHA. Begin tripping in hole to 7091’. June 27th 2012: Finish tripping in the hole from 7091’ to 9727’. Drill ahead from 9727’ to 10196’. June 28th 2012: Drill ahead from 10196’ to 10436’. Trip out of hole. Lay down BHA. June 29th 2012: Make up new BHA. Trip in hole. Drill ahead from 10436’ to 10569’. June 30th 2012: Attempt to drill at 10567’. Trip out of hole. Lay down BHA. Make up new BHA. July 1st 2012: Trip in hole. Drill ahead from 10567’ to 10787’. July 2nd 2012: Drill ahead from 10787’ to 11248’. Start tripping out of hole from 11248’ to 10700’. July 3rd 2012: Continue tripping out of hole from 10700’. Lay down BHA. Pick up BOP test tools. BOP test. Lay down BOP test tools. Pick up BHA. Trip in hole to 2996’. July 4th 2012: Finish tripping in hole from 2996’. Drill ahead from 11248’ to 11560’. July 5th 2012: Drill ahead from 11560’ to 11720’. TD called at 11720’. Circulate and clean hole. Wiper trip to 9929’. Circulate and clean hole. July 6th 2012: Circulate and clean hole. Trip out of hole. Lay down BHA. Run in hole with casing to 1773’. July 7th 2012: Finish running in hole with casing. Circulate bottoms up. Pump cement. 4. 2 S U R V E Y D A T A Me a s u r e d De p t h T V D A z i m u t h In c l i n a t i o n D L S Ve r t i c a l Se c t i o n +NS - +E W - Coarse Length ( f t ) ( f t ) ( d e g ) ( d e g ) ( d e g / 1 0 0 f t ) ( f t ) ( f t ) ( f t ) ( f t ) 84 0 0 . 0 0 8 0 0 8 . 6 4 3 1 . 9 7 2 9 . 9 3 0 1 5 9 1 . 5 7 1 3 9 4 . 3 0 8 7 9 . 7 6 0 84 3 0 . 3 1 8 0 3 4 . 7 0 2 9 . 7 7 3 1 . 4 8 6 . 31 1 6 0 6 . 6 1 1 4 0 7 . 5 9 8 8 7 . 6 9 3 0 . 3 1 84 4 7 . 7 9 8 0 4 9 . 6 1 2 8 . 4 8 3 1 . 4 1 3 . 8 7 16 1 5 . 5 2 1 4 . 1 5 . 5 5 8 9 2 . 1 3 1 7 . 4 8 85 2 5 . 0 0 8 1 1 6 . 5 6 2 2 . 6 1 2 8 . 3 7 5 . 46 1 6 5 3 . 5 3 1 4 5 0 . 1 8 9 0 8 . 7 9 7 7 . 2 1 86 1 9 . 2 9 8 1 9 9 . 6 3 1 5 . 1 5 2 8 . 1 8 3 . 75 1 6 9 8 . 0 9 1 4 9 2 . 3 7 9 2 3 . 2 2 9 4 . 2 9 87 1 4 . 1 8 8 2 8 3 . 0 3 1 3 . 1 5 2 8 . 7 9 1 . 19 1 7 4 3 . 2 7 1 5 3 6 . 2 4 9 3 4 . 2 8 9 4 . 8 9 88 0 9 . 1 8 8 3 6 6 . 2 7 9 . 4 4 2 8 . 8 8 1 . 89 1 7 8 8 . 8 3 1 5 8 1 . 1 5 9 4 3 . 2 4 9 5 . 0 0 89 0 3 . 9 8 8 4 4 8 . 8 4 8 . 4 1 2 9 . 9 7 1 . 27 1 8 3 4 . 9 2 1 6 2 7 . 1 5 9 5 0 . 4 6 9 4 . 8 0 89 9 7 . 8 7 8 5 2 9 . 4 8 7 . 4 5 3 1 . 6 3 1 . 84 8 5 2 9 . 4 8 1 6 7 4 . 7 6 9 5 7 . 0 8 9 3 . 8 9 90 6 6 . 4 4 8 5 8 7 . 7 1 7 . 0 1 3 2 . 1 2 0 . 80 1 9 1 8 . 0 4 1 7 1 0 . 6 9 9 6 1 . 6 4 6 8 . 5 7 90 8 8 . 7 3 8 6 0 6 . 5 2 7 . 1 8 3 2 . 8 1 3 . 11 1 9 2 9 . 8 2 1 7 2 2 . 5 6 9 6 3 . 1 2 2 2 . 2 9 91 8 7 . 3 4 8 6 8 8 . 3 8 5 . 4 2 3 4 . 9 7 2 . 41 1 9 8 3 . 8 2 1 7 7 7 . 2 1 9 6 9 . 1 3 9 8 . 6 1 92 8 2 . 1 6 8 7 6 4 . 6 6 3 . 8 0 3 7 . 8 8 3 . 23 2 0 3 8 . 7 6 1 8 3 3 . 3 2 9 7 3 . 6 3 9 4 . 8 2 93 6 7 . 0 1 8 8 3 0 . 5 1 2 . 8 5 4 0 . 3 1 2 . 95 2 0 9 0 . 7 2 1 8 8 6 . 7 3 9 7 6 . 7 2 8 4 . 8 5 94 7 1 . 6 5 8 9 0 9 . 6 7 2 . 1 5 4 1 . 3 8 1 . 11 2 1 5 6 . 9 3 1 9 5 5 . 1 0 9 7 9 . 7 0 1 0 4 . 6 4 95 6 6 . 5 7 8 9 7 9 . 7 3 0 . 4 8 4 3 . 4 8 2 . 51 2 2 1 8 . 5 3 1 0 1 9 . 1 1 9 8 1 . 1 5 9 4 . 9 2 96 6 0 . 7 0 9 0 4 6 . 9 2 3 5 9 . 4 3 4 5 . 4 2 2 . 21 2 2 8 1 . 5 1 1 0 8 5 . 0 3 9 8 1 . 0 9 9 4 . 1 3 97 3 7 . 0 4 9 0 9 9 . 2 8 3 5 8 . 9 2 4 7 . 9 6 3 . 36 2 3 3 4 . 3 4 2 1 4 0 . 5 6 9 8 0 . 2 8 7 6 . 3 4 98 1 8 . 8 1 9 1 5 0 . 0 5 3 5 7 . 8 6 5 5 . 2 2 8 . 94 2 3 9 4 . 9 7 2 2 0 4 . 5 7 9 7 8 . 4 5 8 1 . 7 7 99 1 7 . 4 4 9 2 0 2 . 3 3 3 5 6 . 5 3 6 0 . 7 3 5 . 70 2 4 7 3 . 5 4 2 2 8 8 . 0 6 9 7 4 . 3 3 9 8 . 6 3 99 6 4 . 1 5 9 2 2 4 . 0 5 3 5 6 . 0 6 6 3 . 8 3 6 . 69 2 5 1 2 . 1 8 2 3 2 9 . 3 2 9 7 1 . 6 6 4 6 . 7 1 10 0 1 6 . 3 4 9 2 4 5 . 7 4 3 5 5 . 5 6 6 7 . 0 6 6 . 24 2 5 5 6 . 3 9 2 3 7 6 . 6 5 9 6 8 . 1 9 5 2 . 1 9 10 1 1 6 . 0 9 9 2 8 0 . 5 4 3 5 4 . 7 2 7 2 . 0 9 5 . 11 2 6 4 3 . 0 3 2 4 6 9 . 7 6 9 6 0 . 2 6 9 9 . 7 5 10 2 1 0 . 8 1 9 3 0 7 . 0 1 3 5 6 . 7 5 7 5 . 4 5 4 . 10 2 7 2 7 . 7 0 2 5 6 0 . 4 4 9 5 3 . 5 1 9 4 . 7 2 10 3 0 4 . 2 5 9 3 3 0 . 3 5 3 5 5 . 4 8 7 5 . 6 3 1 . 33 2 8 1 2 . 1 6 2 6 5 0 . 7 9 4 7 . 3 8 9 3 . 4 4 10 3 6 5 . 3 6 9 3 4 5 . 1 3 3 5 4 . 9 3 7 6 . 3 7 1 . 49 2 8 6 7 . 1 7 2 7 0 9 . 7 9 9 4 2 . 4 3 6 1 . 1 1 10 4 1 8 . 8 2 9 3 5 7 . 5 9 3 5 5 . 2 7 7 6 . 6 9 0 . 86 2 9 1 5 . 3 6 2 7 6 1 . 5 9 9 3 7 . 9 9 5 3 . 4 6 Hi l c o r p A l a s k a , L L C M- 2 9 A 34 Me a s u r e d De p t h T V D A z i m u t h In c l i n a t i o n D L S Ve r t i c a l Se c t i o n +NS - +E W - Coarse Length ( f t ) ( f t ) ( d e g ) ( d e g ) ( d e g / 1 0 0 f t ) ( f t ) ( f t ) ( f t ) ( f t ) 10 4 9 7 . 8 0 9 3 7 7 . 5 2 3 5 7 . 2 7 7 4 . 0 9 4 . 11 2 9 8 6 . 7 6 2 8 3 7 . 8 4 9 3 3 . 0 1 7 8 . 9 8 10 5 1 3 . 4 7 9 3 8 1 . 8 5 3 5 8 . 3 1 7 3 . 8 1 6 . 59 3 0 0 0 . 9 7 2 8 5 2 . 8 9 9 3 2 . 4 3 1 5 . 6 7 10 6 0 9 . 3 0 9 4 0 9 . 4 8 0 . 9 0 7 2 . 6 8 2 . 84 3 0 8 8 . 4 6 2 9 4 4 . 6 4 9 3 1 . 7 9 9 5 . 8 3 10 7 0 3 . 0 7 9 4 3 7 . 3 0 3 5 9 . 8 5 7 2 . 8 1 1 . 08 3 1 7 4 . 2 1 3 0 3 4 . 1 8 9 3 2 . 3 7 9 3 . 7 7 10 7 9 7 . 9 0 9 4 6 3 . 4 9 3 5 7 . 3 0 7 5 . 1 3 3 . 56 3 2 6 0 . 5 9 3 1 2 5 . 2 8 9 3 0 . 0 9 9 4 . 8 3 10 8 9 2 . 7 1 9 4 8 7 . 5 9 3 5 6 . 7 3 7 5 . 4 2 0 . 66 3 3 4 6 . 6 9 3 2 1 6 . 8 5 9 2 5 . 3 2 9 4 . 8 1 10 9 8 7 . 5 7 9 5 1 1 . 1 9 3 5 5 . 9 6 7 5 . 7 7 0 . 86 3 4 3 2 . 5 9 3 3 0 8 . 5 4 9 1 9 . 4 6 9 4 . 8 6 11 0 7 8 . 1 0 9 5 3 3 . 7 6 3 5 6 . 4 7 7 5 . 3 6 0 . 71 3 5 1 4 . 4 8 3 3 9 6 . 0 2 9 1 3 . 6 7 9 0 . 5 3 11 1 7 7 . 3 1 9 5 5 8 . 8 4 3 5 6 . 5 4 7 5 . 3 5 0 . 07 3 6 0 4 . 3 2 3 4 9 1 . 8 3 9 0 7 . 8 2 9 9 . 2 1 11 2 7 1 . 8 1 9 5 8 2 . 3 7 3 5 7 . 4 2 7 5 . 8 2 1 . 03 3 6 9 0 . 2 4 3 5 8 3 . 2 3 9 0 3 . 0 0 9 4 . 5 0 11 3 6 6 . 5 9 9 6 0 5 . 5 3 3 5 5 . 2 2 7 5 . 8 9 2 . 25 3 7 7 6 . 1 5 3 6 7 4 . 9 4 8 9 7 . 1 0 9 4 . 7 8 11 4 6 1 . 3 7 9 6 2 9 . 0 1 3 5 5 . 3 3 7 5 . 4 2 0 . 51 3 8 6 1 . 3 8 3 7 6 6 . 4 6 8 8 9 . 5 4 9 4 . 7 8 11 5 5 6 . 2 1 9 6 5 3 . 5 2 3 5 5 . 4 4 7 4 . 6 2 0 . 85 3 9 4 6 . 4 7 3 8 5 7 . 7 7 8 8 2 . 1 6 9 4 . 8 4 11 6 4 3 . 9 7 9 6 7 6 . 3 5 3 5 6 . 6 2 7 5 . 2 2 1 . 47 4 0 2 5 . 5 3 3 9 4 2 . 3 1 8 7 6 . 3 0 8 7 . 7 6 11 7 2 0 . 0 0 9 6 9 5 . 7 4 3 5 6 . 6 2 7 5 . 2 2 0 . 01 4 0 9 4 . 3 8 1 0 1 5 . 6 9 8 7 1 . 9 6 7 6 . 0 3 Hi l c o r p A l a s k a , L L C M- 2 9 A 35 4. 3 M U D R E C O R D C o n t r a c t o r : B a r o i d M u d T y p e : K C L / P o l y m e r / G E M ( 8 4 6 7 ’ ’ t o 1 1 7 2 0 ’ ) DA T E D E P T H M W V I S P V Y P G E L S FL FC S O L I D S O I L / W A T E R S A N D M B T p H C l C a 6/ 1 9 / 2 0 1 2 8 5 1 3 ’ 9 . 6 0 4 4 6 1 9 9 / 1 1 / 1 2 5. 0 1 / 0 6 . 0 0 . 0 / 9 3 . 0 - - 8 . 5 1 1 0 0 0 3 2 0 6/ 2 0 / 2 0 1 2 8 5 1 3 ’ 9 . 5 0 4 1 7 1 5 8 / 9 / 1 0 5. 0 1 / 0 5 . 0 0 . 0 / 9 4 . 0 - - 9 . 1 1 1 0 0 0 3 2 0 6/ 2 1 / 2 0 1 2 8 5 6 7 ’ 9 . 3 0 4 7 1 3 2 4 1 2 / 1 5 / 1 8 4 . 8 1 / 0 4 . 0 0 . 0 / 9 5 . 0 0 . 2 5 0 . 5 9 . 1 1 1 0 0 0 2 6 0 6/ 2 2 / 2 0 1 2 8 6 0 0 ’ 9 . 3 0 4 9 1 3 2 7 1 2 / 1 4 / 1 5 4 . 5 1 / 0 5 . 0 1 . 0 / 9 3 . 0 0 . 2 5 1 . 0 9 . 0 1 1 0 0 0 - 6/ 2 3 / 2 0 1 2 8 9 7 1 ’ 9 . 3 0 4 9 1 6 2 7 1 0 / 1 1 / 1 2 4. 5 1 / 0 5 . 0 1 . 0 / 9 3 . 0 - 1 . 0 9 . 5 1 1 0 0 0 3 0 0 6/ 2 4 / 2 0 1 2 9 0 8 9 ’ 9 . 3 0 4 4 1 1 2 4 9 / 1 0 / 1 1 4 . 8 1 / 0 4 . 0 1 . 0 / 9 4 . 0 0 . 2 5 1 . 0 8 . 5 1 1 0 0 0 2 8 0 6/ 2 5 / 2 0 1 2 9 1 3 4 ’ 9 . 3 0 4 7 1 1 2 3 9 / 1 0 / 1 1 5 . 0 1 / 0 4 . 5 1 . 0 / 9 3 . 5 0 . 2 5 1 . 0 9 . 0 1 1 0 0 0 2 6 0 6/ 2 6 / 2 0 1 2 9 7 2 7 ’ 9 . 3 0 4 5 1 0 2 4 9 / 1 0 / 1 1 4 . 5 1 / 0 4 . 0 0 . 0 / 9 4 . 0 0 . 2 5 1 . 0 9 . 1 1 1 0 0 0 3 2 0 6/ 2 7 / 2 0 1 2 9 9 5 0 ’ 9 . 3 5 4 4 1 3 2 4 8 / 9 / 1 0 4 . 0 1 / 0 4 . 0 1 . 0 / 9 4 . 0 0 . 2 5 1 . 0 9 . 0 1 1 0 0 0 3 0 0 6/ 2 8 / 2 0 1 2 1 0 4 3 6 ’ 9 . 3 5 4 5 1 3 2 3 9 / 1 0 / 1 1 4 . 2 1 / 0 4 . 0 1 . 0 / 9 4 . 0 0 . 2 5 1 . 0 9 . 1 1 1 0 0 0 2 8 0 6/ 2 9 / 2 0 1 2 1 0 5 3 7 ’ 9 . 3 5 4 7 1 4 2 8 1 1 / 1 3 / 1 5 4 . 6 1 / 0 4 . 5 1 . 0 / 9 3 . 5 0 . 2 5 1 . 3 8 . 6 1 1 0 0 0 2 4 0 6/ 3 0 / 2 0 1 2 1 0 5 6 9 ’ 9 . 3 0 4 5 1 4 2 7 1 1 / 1 2 / 1 3 4 . 5 1 / 0 4 . 0 1 . 0 / 9 4 . 0 0 . 2 5 1 . 3 9 . 0 1 1 0 0 0 2 8 0 7/ 1 / 2 0 1 2 1 0 7 4 3 ’ 9 . 4 0 4 7 1 6 2 9 1 0 / 1 2 / 1 5 4 . 5 1 / 0 4 . 5 1 . 0 / 9 3 . 5 0 . 2 5 1 . 5 9 . 5 1 1 0 0 0 1 8 0 7/ 2 / 2 0 1 2 1 1 2 5 0 ’ 9 . 4 5 4 8 1 6 3 1 9 / 1 1 / 1 2 4 . 0 1 / 0 4 . 7 1 . 0 / 9 3 . 3 0 . 2 5 2 . 0 8 . 9 1 1 0 0 0 1 6 0 7/ 3 / 2 0 1 2 1 1 2 5 0 ’ 9 . 4 5 5 0 1 6 3 0 9 / 1 1 / 1 2 3 . 8 1 / 1 4 . 9 1 . 0 / 9 3 . 4 0 . 2 0 2 . 0 9 . 0 1 1 0 0 0 1 6 0 7/ 4 / 2 0 1 2 1 1 5 4 0 ’ 9 . 4 0 4 6 1 5 2 8 9 / 1 1 / 1 3 4 . 8 1 / 1 4 . 9 1 . 0 / 9 3 . 4 0 . 2 1 4 . 0 9 . 0 1 1 0 0 0 1 2 0 7/ 5 / 2 0 1 2 1 1 7 2 0 ’ 9 . 3 5 4 7 1 5 2 9 8 / 1 0 / 1 1 4 . 2 1 / 1 5 . 0 1 . 0 / 9 3 . 0 0 . 4 0 4 . 0 9 . 0 1 1 5 0 0 1 2 0 7/ 6 / 2 0 1 2 1 1 7 2 0 ’ 9 . 4 5 5 6 1 5 2 2 7 / 8 / 1 0 4. 1 1 / 0 5 . 0 1 . 0 / 9 3 . 0 - 4 . 0 9 . 0 1 1 5 0 0 1 2 0 Hi l c o r p A l a s k a , L L C M- 2 9 A 36 4. 4 B I T R E C O R D BI T NO SI Z E MA K E TY P E S / N J E T S I N O U T F E E T H O U R S A VE RO P WO B C O N D I T I O N 1 8 . 5 ” S M I T H MS 6 1 6 PD C JF 3 9 7 3 6 x 1 3 0. 7 7 8 84 6 7 ’ 9 1 3 4 ’ 6 6 7 ’ 3 5 . 1 1 9 . 0 1 9 . 7 4 - 7 - B T - G - X - 7 - P R 2 8 . 5 ” BA K E R HU G H E S QD 5 0 7 F X PD C 71 4 0 6 7 2 6 x 1 3 , 7 x 1 2 0. 8 8 6 91 3 4 ’ 9 7 2 7 ’ 5 9 3 ’ 1 0 . 0 1 8 0 . 9 33 . 5 5 - 2 - B T - N - X - I - C T - B H A 3 8 . 5 ” BA K E R HU G H E S MX - 1 8 D X IN S E T 52 1 2 6 3 9 2x 1 8 , 1 x 2 0 0. 8 0 4 97 2 7 ’ 1 0 4 3 6 ’ 7 0 9 ’ 1 7 . 6 9 3 9 . 9 1 7 . 0 5 - 7 - W T - A - F - 5 - S D - B H A 4 8. 5 ” BA K E R HU G H E S QD 5 0 6 X PD C 75 0 1 0 7 5 6x 1 2 0. 6 6 3 10 4 3 6 ’ 1 0 5 6 7 ’ 1 3 1 ’ 1 2 . 7 0 3 5 . 0 1 4 . 4 8 - 3 - C R - C - X - 1 - C T - P R 5 8 . 5 ” S E C U R I T Y Q H 2 6 D R 1 1 2 5 4 2 8 8 3x 1 8 0. 7 4 6 10 5 6 7 ’ 1 1 2 4 8 ’ 6 8 1 ’ 2 5 . 5 2 3 5 . 8 2 5 . 8 5 - 3 - W T - A - E - I - C T - P R 6 8 . 5 ” S E C U R I T Y E Q H 2 0 D R 1 1 5 5 5 5 4 8 3x 1 8 0. 7 4 6 11 2 4 8 ’ 1 1 7 2 0 ’ 4 7 2 ’ 1 3 . 7 2 3 4 . 2 25 . 1 3 - 3 - W T - A - F - I - C T - T D Hilcorp Alaska, LLC M-29A 37 5 DAILY REPORTS HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE 6/19/12 DEPTH PRESENT OPERATION MILLING WINDOW TIME 24:00:00 YESTERDAY 24 HOUR FOOTAGE CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.6 VIS 44 PV 6 YP 19 FL Gels 9/11/12 CL- 11000 FC 1/0 SOL 6.0 SD OIL 0/93 MBT pH 8.5 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ @ TRIP GAS CUTTING GAS 0 @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ @ CONNECTION GAS HIGH ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY TEST BOP TO 4000 PSI, PULL TEST PLUG, PRESSURE TEST CASING/SHOE TO 1500 PSI, PICKUP BHA, TRIP IN HOLE WITH WHIPSTOCK, BEGIN MILLING WINDOW CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN DAILY COST $2360 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE 6/20/12 DEPTH 8467' PRESENT OPERATION TRIP IN HOLE TIME 24:00:00 YESTERDAY 24 HOUR FOOTAGE CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH MW 9.5 VIS 41 PV 7 YP 15 FL Gels 8/9/10 CL- 11000 FC 1/0 SOL 5.0 SD OIL 0/94 MBT pH 9.1 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY FINISHED MILLING WINDOW TO 8467', CIRCULATE AND CONDITION 1 BOTTOMS UP, FORMATION INTEGRITY TEST TO 1100 PSI, TRIP OUT OF HOLE, LAY DOWN BHA, PICK UP NEW BHA, START TRIPPING IN HOLE CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3364 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE Jun 21, 2012 DEPTH 8594 PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 8467 24 HOUR FOOTAGE 127 CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8447.79' 31.41 80.76 8037.06' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" MSi616 JF3973 6x13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 108.4 @ 8554 1.6 @ 8523 30.9 11.73886 FT/HR SURFACE TORQUE 0 @ 8594 0 @ 8594 0.0 0.00000 AMPS WEIGHT ON BIT 99 @ 8539 0 @ 8551 14.2 21.53391 KLBS ROTARY RPM 0 @ 8594 0 @ 8594 0.0 0.00000 RPM PUMP PRESSURE 2048 @ 8545 1330 @ 8540 872.6 1772.79605 PSI DRILLING FLUIDS REPORT DEPTH 8567' / 8153' MW 9.3 VIS 47 PV 13 YP 24 FL 101 Gels 12/15/18 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 0/95 MBT 0.5 pH 9.1 Ca+ 260 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 98 @ 8556 1 @ 8471 11.2 TRIP GAS NONE CUTTING GAS 0 @ 8594 0 @ 8594 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 13349 @ 8556 205 @ 8579 2176.9 CONNECTION GAS HIGH ETHANE (C-2) 123 @ 8588 0 @ 8564 14.1 AVG PROPANE (C-3) 0 @ 8594 0 @ 8594 0 CURRENT 3 BUTANE (C-4) 0 @ 8594 0 @ 8594 0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 8594 0 @ 8594 0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND/SANDSTONE PRESENT LITHOLOGY SAND/SANDSTONE DAILY ACTIVITY SUMMARY FINISH TRIPPING IN HOLE, BEGIN DRILLING FROM 8467' TO 8594' CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3310 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE Jun 22, 2012 DEPTH 8813' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 8594' 24 HOUR FOOTAGE 219' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8714.18' 28.79 13.15 8283.03 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" MSi616 JF3973 6X13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 135.4 @ 8622 1.3 @ 8632 43.2 10.13829 FT/HR SURFACE TORQUE 0 @ 8813 0 @ 8813 0 0 AMPS WEIGHT ON BIT 68 @ 8786 0 @ 8684 7.1 10.60880 KLBS ROTARY RPM 0 @ 8813 0 @ 8813 0 0 RPM PUMP PRESSURE 2302 @ 8628 1545 @ 8692 1859.0 1875.91035 PSI DRILLING FLUIDS REPORT DEPTH 8819' / 8374' MW 9.3 VIS 47 PV 15 YP 27 FL 118 Gels 12/16/19 CL- 11000 FC 1/0 SOL 5.0 SD 0.25 OIL 1/93 MBT 1.0 pH 9.0 Ca+ 200 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 8752 0 @ 8805 12.8 TRIP GAS CUTTING GAS 0 @ 8813 0 @ 8813 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 14863 @ 8787 77 @ 8604 2576.4 CONNECTION GAS HIGH ETHANE (C-2) 182 @ 8802 0 @ 8608 19.9 AVG PROPANE (C-3) 0 @ 8813 0 @ 8813 0 CURRENT 3 BUTANE (C-4) 0 @ 8813 0 @ 8813 0 CURRENT BACKGROUND/AVG 3 PENTANE (C-5) 0 @ 8813 0 @ 8813 0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE/SILTSTONE PRESENT LITHOLOGY TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 8594' TO 8813' CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3310 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE Jun 23, 2012 DEPTH 9059' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 8813' 24 HOUR FOOTAGE 246' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8903.98' 29.97 8.41 8448.80' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" MSi616 JF3973 6x13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.3 @ 8849 1.0 @ 9026 37.9 18.41519 FT/HR SURFACE TORQUE 0 @ 9059 0 @ 9059 0 0 AMPS WEIGHT ON BIT 54 @ 8916 0 @ 8929 7.0 25.38503 KLBS ROTARY RPM 0 @ 9059 0 @ 9059 0 0 RPM PUMP PRESSURE 2714 @ 9024 1563 @ 9028 2051.9 1750.13207 PSI DRILLING FLUIDS REPORT DEPTH 9067' / 8588' MW 9.30 VIS 47 PV 15 YP 27 FL 4.6 Gels 10/12/15 CL- 11000 FC 1/0 SOL 5.0 SD 0.25 OIL 1/93 MBT 1 pH 9.6 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 363 @ 8904 1 @ 8874 33.9 TRIP GAS CUTTING GAS 0 @ 9059 0 @ 9059 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 53551 @ 8901 283 @ 8874 4643.6 CONNECTION GAS HIGH 10.3 ETHANE (C-2) 863 @ 8901 0 @ 8939 42.8 AVG 10 PROPANE (C-3) 211 @ 8901 0 @ 8882 11.6 CURRENT 6 BUTANE (C-4) 72 @ 8985 0 @ 8884 5.6 CURRENT BACKGROUND/AVG 5 PENTANE (C-5) 26 @ 8858 0 @ 8882 1.7 HYDROCARBON SHOWS WEAK SHOW AT 8856' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8856' - 8861' SEE ATTACHED SHOW REPORT LITHOLOGY SAND/TUFFACEOUS SILTSTONE WITH COAL LAYERS PRESENT LITHOLOGY CARBONACEOUS SHALE DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 8813' TO 9059' CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3310 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE Jun 24, 2012 DEPTH 9134' PRESENT OPERATION TRIPPING OUT OF HOLE TIME 24:00:00 YESTERDAY 9059' 24 HOUR FOOTAGE 73' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9066.44' 32.12 7.01 8587.71' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" MSi616 JF3973 6x13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 40.0 @ 9119 2.6 @ 9066 13.8 19.43559 FT/HR SURFACE TORQUE 0 @ 9132 0 @ 9132 0 0 AMPS WEIGHT ON BIT 57 @ 9090 0 @ 9112 10.6 19.75856 KLBS ROTARY RPM 0 @ 9132 0 @ 9132 0 0 RPM PUMP PRESSURE 2471 @ 9113 1487 @ 9105 2141.6 2277.68540 PSI DRILLING FLUIDS REPORT DEPTH MW 9.3 VIS 45 PV 12 YP 24 FL 4.9 Gels 9/10/12 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 1/94 MBT 1 pH 9.0 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 47 @ 9069 2 @ 9089 11.6 TRIP GAS 10.71 CUTTING GAS 0 @ 9132 0 @ 9132 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 10296 @ 9069 595 @ 9089 2167.2 CONNECTION GAS HIGH 23.03 ETHANE (C-2) 104 @ 9120 5 @ 9061 27.0 AVG 23.03 PROPANE (C-3) 155 @ 9115 0 @ 9079 26.7 CURRENT 0 BUTANE (C-4) 134 @ 9120 0 @ 9067 12.5 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 50 @ 9120 0 @ 9081 6.0 HYDROCARBON SHOWS MINOR SHOW FROM 9098' - 9123' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9098' - 9123' SEE ATTACHED SHOW REPORT LITHOLOGY SAND/SANDSTONE/TUFFACEOUS SANDSTONE - COARSENING DOWNWARDS FROM LOWER VERY FINE TO UPPER COARSE PRESENT LITHOLOGY SAND/TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 9059' TO 9067', SHORT TRIP TO SHOE, TRIP IN HOLE, DRILL AHEAD FROM 9067' TO 9134'. BEGIN TRIPPING OUT OF HOLE TO 2250'. CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3310 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR HAUCK DATE Jun 25, 2012 DEPTH 9427' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 9134' 24 HOUR FOOTAGE 293' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9367.01' 40.31 2.85 8830.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 8.5" MSi616 JF3973 6x13 8467' 9134' 667' 35.1 4-7-BT-G-X-7-CT-PR 2 8.5" QD507FX 7x12 9134' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 1481.9 @ 9258 1.4 @ 9359 91.3 147.49194 FT/HR SURFACE TORQUE 0 @ 9427 0 @ 9427 0 0 AMPS WEIGHT ON BIT 133 @ 9258 3 @ 9166 34.9 40.44789 KLBS ROTARY RPM 0 @ 9427 0 @ 9427 0 0 RPM PUMP PRESSURE 2303 @ 9134 1446 @ 9165 2053.1 2084.23701 PSI DRILLING FLUIDS REPORT DEPTH 9258' / 8749' MW 9.3 VIS 45 PV 14 YP 22 FL 4.8 Gels 9/10/11 CL- 11000 FC 1/0 SOL 4.5 SD 0.25 OIL 1/93.5 MBT 1.0 pH 8.9 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 325 @ 9217 0 @ 9396 61.5 TRIP GAS 476 CUTTING GAS 0 @ 9427 0 @ 9427 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 40158 @ 9202 23 @ 9396 6238.9 CONNECTION GAS HIGH 133 ETHANE (C-2) 1962 @ 9202 1 @ 9396 271.8 AVG 76 PROPANE (C-3) 2075 @ 9202 0 @ 9160 285.0 CURRENT 17 BUTANE (C-4) 1788 @ 9202 1 @ 9396 244.5 CURRENT BACKGROUND/AVG 17 PENTANE (C-5) 667 @ 9202 0 @ 9162 97.5 HYDROCARBON SHOWS SHOWS FROM 9190' TO 9400' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9191' - 9250' 9260'-9300' 9330' - 9400' SEE ATTACHED SHOW REPORT LITHOLOGY SAND/SANDSTONE/TUFFACEOUS SANDSTONE WITH COAL LAYERS PRESENT LITHOLOGY SAND/TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY FINISH TRIPPING OUT OF HOLE, CHANGE BIT, MAKE UP BHA, TRIP IN HOLE, DRILL FROM 9134' TO 9427' CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jun 26, 2012 DEPTH 9727' PRESENT OPERATION TRIP IN HOLE TIME 24:00:00 YESTERDAY 9427' 24 HOUR FOOTAGE 300' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9660.70' 45.42 359.43 9046.91' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" QD507FX 7140673 7x12 9134 9727 593 10.01 5-2-BT-N-X-I-CT-BHA POOR DRILLING ANGLE 3 8.5" MX-18DX 5212639 2X18 9727 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 228.4 @ 9539 0.8 @ 9712 76.5 45.00510 FT/HR SURFACE TORQUE 14732 @ 9431 9087 @ 9570 8558.4 0 AMPS WEIGHT ON BIT 185 @ 9448 8 @ 9689 32.7 20.95957 KLBS ROTARY RPM 106 @ 9616 0 @ 9636 51.5 0 RPM PUMP PRESSURE 2259 @ 9562 2041 @ 9440 2147.1 2075.31252 PSI DRILLING FLUIDS REPORT DEPTH 9727'/9093' MW 9.3 VIS 45 PV 10 YP 24 FL 4.5 Gels 9/10/11 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 1/94 MBT 1.0 pH 9.1 Ca+ 320 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 238 @ 9470 12 @ 9704 73.6 TRIP GAS CUTTING GAS 0 @ 9727 0 @ 9727 0 WIPER GAS 318 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 31783 @ 9651 1086 @ 9430 8220.5 CONNECTION GAS HIGH 65 ETHANE (C-2) 2060 @ 9510 70 @ 9691 528.1 AVG 73.6 PROPANE (C-3) 1427 @ 9454 29 @ 9703 448.4 CURRENT 0 BUTANE (C-4) 1201 @ 9454 0 @ 9703 341.2 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 482 @ 9607 0 @ 9660 114.5 HYDROCARBON SHOWS 4 SHOWS FROM 9410' TO 9710'. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9410' - 9450', 9510' - 9550', 9560' - 9630', 9690' - 9710' SEE ATTACHED SHOW REPORTS LITHOLOGY PREDOMINATELY SAND/SANDSTONE/TUFFACEOUS SANDSTONE WITH COAL LAYERS, SMALLER SECTIONS OF SILTSTONE/TUFFACEOUS SILTSONE PRESENT AS WELL. PRESENT LITHOLOGY SAND/SANDSTONE. DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 9427' TO 9636', 6 STAND WIPER TRIP, DRILL AHEAD FROM 9636' TO 9730', TRIP OUT OF HOLE, LAY DOWN OLD BHA, MAKE UP NEW BHA, BEGIN TRIPPING IN HOLE TO 7091'. CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3495 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jun 27, 2012 DEPTH 10196' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 9727' 24 HOUR FOOTAGE 469' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10116.09' 72.09 354.72 9280.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" MX-18DX 5212639 2x18 9727 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 980.0 @ 10185 0.6 @ 9764 63.8 37.71389 FT/HR SURFACE TORQUE 0 @ 10196 0 @ 10196 0 0 AMPS WEIGHT ON BIT 190 @ 9807 0 @ 9731 32.4 45.71005 KLBS ROTARY RPM 0 @ 10196 0 @ 10196 0 0 RPM PUMP PRESSURE 2492 @ 9953 1864 @ 9998 2185.2 2170.63492 PSI DRILLING FLUIDS REPORT DEPTH 10143' / 9291' MW 9.35 VIS 44 PV 13 YP 23 FL 4.2 Gels 8/9/10 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 1/94 MBT 1.0 pH 9.0 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 116 @ 9804 8 @ 9794 38.0 TRIP GAS 368 CUTTING GAS 0 @ 10196 0 @ 10196 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 15787 @ 9803 1637 @ 10159 4797.3 CONNECTION GAS HIGH 53 ETHANE (C-2) 2425 @ 9803 57 @ 9759 480.3 AVG 38 PROPANE (C-3) 2056 @ 9803 25 @ 9759 486.6 CURRENT 41 BUTANE (C-4) 1531 @ 9803 1 @ 9741 378.5 CURRENT BACKGROUND/AVG 20 PENTANE (C-5) 385 @ 10007 0 @ 9763 105.1 HYDROCARBON SHOWS 2 SHOWS FROM 9800' TO 10180' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9800' TO 9860' 9910' TO 10180' SEE ATTACHED SHOW REPORTS LITHOLOGY G7ST SAND/SANDSTONE (9730' - 9800'), HK1T SAND/TUFFACEOUS SANDSTONE TO SILTSTONE/TUFFACEOUS SILTSTONE (9800' - 9910'), HK2T SAND/SANDSTONE (9910' - 10190'). PRESENT LITHOLOGY SAND/SANDSTONE - BEGINNING OF HK3T. DAILY ACTIVITY SUMMARY FINISH TRIPPING IN HOLE FROM 7091' TO 9727'. DRILL AHEAD FROM 9727' TO 10196'. CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jun 28, 2012 DEPTH 10436 PRESENT OPERATION LAY DOWN BHA TIME 24:00:00 YESTERDAY 10196 24 HOUR FOOTAGE 240' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10365.36' 76.37 354.93 9344.36' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" MX-18DX 5212639 2x18 9727 10436 709 17.69 5-7-WT-A-F-5-SD-BHA SWAPPED FOR ROTARY STEERABLE 4 8.5" QD506X 7501075 6x12 10436 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 177.1 @ 10376 0 @ 10371 42.6 39.97519 FT/HR SURFACE TORQUE 0 @ 10436 0 @ 10436 0 0 AMPS WEIGHT ON BIT 86 @ 10386 0 @ 10230 28.4 17.02985 KLBS ROTARY RPM 0 @ 10436 0 @ 10436 0 0 RPM PUMP PRESSURE 2273 @ 10385 2067 @ 10333 2161.1 2152.18562 PSI DRILLING FLUIDS REPORT DEPTH MW 9.35 VIS 45 PV 13 YP 23 FL 4.2 Gels 9/10/11 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 1/94 MBT 1.0 pH 9.1 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 70 @ 10420 15 @ 10281 39.0 TRIP GAS CUTTING GAS 0 @ 10436 0 @ 10436 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 8128 @ 10420 1962 @ 10281 4777.5 CONNECTION GAS HIGH 51 ETHANE (C-2) 920 @ 10420 189 @ 10281 482.6 AVG 39 PROPANE (C-3) 946 @ 10420 213 @ 10281 525.4 CURRENT 0 BUTANE (C-4) 681 @ 10316 162 @ 10281 385.4 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 233 @ 10259 32 @ 10281 92.6 HYDROCARBON SHOWS 2 SHOWS FROM 10190' TO 10435' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10190' - 10300'; 10310' - 10435' SEE ATTACHED SHOW REPORTS LITHOLOGY HK3T - SAND/SANDSTONE (10190' - 10300'), HK4T - SAND/SANDSTONE (10300' - 10436'), MINOR COAL BETWEEN HK3T AND HK4T (10300'). PRESENT LITHOLOGY HK4T - SAND/SANDSTONE. DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 10196' TO 10436'. TRIP OUT OF HOLE. LAY DOWN BHA CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jun 29, 2012 DEPTH 10569' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 10436' 24 HOUR FOOTAGE 132' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10418.82' 76.69 355.27 9357.59' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" QD506X 7501075 6x12 10436 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 900.4 @ 10490 0.4 @ 10526 41.4 15.65322 FT/HR SURFACE TORQUE 0 @ 10568 0 @ 10568 0 0 AMPS WEIGHT ON BIT 192 @ 10491 5 @ 10441 15.8 18.57081 KLBS ROTARY RPM 0 @ 10568 0 @ 10568 0 0 RPM PUMP PRESSURE 2356 @ 10493 1949 @ 10491 2244.4 2297.76858 PSI DRILLING FLUIDS REPORT DEPTH 10537'/9381' MW 9.35 VIS 47 PV 14 YP 28 FL 4.6 Gels 11/13/15 CL- 11000 FC 1/0 SOL 4.5 SD 0.25 OIL 1/93.5 MBT 1.3 pH 8.6 Ca+ 240 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 93 @ 10464 12 @ 10561 38.4 TRIP GAS 650 CUTTING GAS 0 @ 10568 0 @ 10568 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12157 @ 10494 2510 @ 10467 5156.1 CONNECTION GAS HIGH 40 ETHANE (C-2) 879 @ 10494 181 @ 10468 360.0 AVG 38.4 PROPANE (C-3) 877 @ 10448 176 @ 10468 358.3 CURRENT 11 BUTANE (C-4) 612 @ 10494 118 @ 10468 263.9 CURRENT BACKGROUND/AVG 11 PENTANE (C-5) 139 @ 10494 17 @ 10468 48.6 HYDROCARBON SHOWS 1 SHOW REPORT FROM 10450' TO 10569' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10450' - 10569' SEE ATTACHED SHOW REPORT LITHOLOGY HK4T SAND/SANDSTONE (10300' - 10569'), SIGNIFICANT COAL IN 10569' SAMPLE. PRESENT LITHOLOGY COAL/SAND/SANDSTONE - MAYBE THE START OF THE NEXT COAL SECTION. DAILY ACTIVITY SUMMARY MAKE UP NEW BHA, TRIP IN HOLE, DRILL AHEAD FROM 10436' TO 10569. CANRIG PERSONNEL ON BOARD WINSLOW, ATHAN, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jun 30, 2012 DEPTH 10567' PRESENT OPERATION MAKE UP BHA TIME 24:00:00 YESTERDAY 10567' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10418.82' 76.69 355.27 9356.81' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 8.5" QD506X 7501075 6x12 10436 10567 131 8-3-CR-C-X-1-CT-PR PENETRATION RATE DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 10569'/9388' MW 9.3 VIS 45 PV 14 YP 27 FL 4.5 Gels 11/12/13 CL- 11000 FC 1/0 SOL 4.0 SD 0.25 OIL 1/94 MBT 1.3 pH 9.0 Ca+ 280 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY COAL/SAND/SANDSTONE - MAYBE THE COAL AT THE BOTTOM OF THE HK4T. PRESENT LITHOLOGY COAL/SAND/SANDSTONE - MAYBE THE COAL AT THE BOTTOM OF THE HK4T. DAILY ACTIVITY SUMMARY ATTEMPT TO DRILL AT 10567', TRIP OUT OF HOLE, LAY DOWN BHA, MAKE UP NEW BHA. CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3549 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 01, 2012 DEPTH 10787' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 10567' 24 HOUR FOOTAGE 220' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10703.07' 72.81 359.85 9437.3 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" QH26DR 11254288 3x18 10567' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 479.9 @ 10782 0.2 @ 10742 40.1 40.22192 FT/HR SURFACE TORQUE 0 @ 10787 0 @ 10787 0 0 AMPS WEIGHT ON BIT 184 @ 10783 1 @ 10569 26.6 39.25409 KLBS ROTARY RPM 0 @ 10787 0 @ 10787 0 0 RPM PUMP PRESSURE 2497 @ 10775 2239 @ 10570 2380.4 2469.29567 PSI DRILLING FLUIDS REPORT DEPTH 10743'/9460' MW 9.4 VIS 47 PV 16 YP 29 FL 4.5 Gels 10/12/15 CL- 11000 FC 1/0 SOL 4.5 SD 0.25 OIL 1.0/93.5 MBT 1.5 pH 9.5 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 119 @ 10704 2 @ 10681 27.9 TRIP GAS 317 CUTTING GAS 0 @ 10787 0 @ 10787 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 38306 @ 10703 515 @ 10681 4853.0 CONNECTION GAS HIGH 28 ETHANE (C-2) 4316 @ 10703 25 @ 10681 384.7 AVG 27.9 PROPANE (C-3) 4470 @ 10703 19 @ 10681 365.3 CURRENT 36 BUTANE (C-4) 3681 @ 10703 15 @ 10681 282.9 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 1201 @ 10703 4 @ 10691 77.8 HYDROCARBON SHOWS 1 SHOW BEGINNING AT 10690 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10690' - CURRENT SEE ATTACHED SHOW REPORT LITHOLOGY HK4T - SAND/SANDSTONE (10567' - 10660'), HK4T - CARBONACEOUS SHALE/COAL (10660' - 10680'), HK5T - SAND/SANDSTONE PRESENT LITHOLOGY HK5T - SAND/SANDSTONE DAILY ACTIVITY SUMMARY TRIP IN HOLE, DRILL AHEAD FROM 10567' TO 10787'. CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 02, 2012 DEPTH 11248' PRESENT OPERATION TRIP OUT OF HOLE TIME 24:00:00 YESTERDAY 10787' 24 HOUR FOOTAGE 461 CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11167.93' 75.3 357.27 9556.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" QH26DR 11254288 3x18 10567' 11248' 681' BOP TEST DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 140.9 @ 10847 0.4 @ 10811 34.8 43.21840 FT/HR SURFACE TORQUE 0 @ 11235 0 @ 11235 0 0 AMPS WEIGHT ON BIT 64 @ 10950 0 @ 11067 25.8 22.53021 KLBS ROTARY RPM 0 @ 11235 0 @ 11235 0 0 RPM PUMP PRESSURE 2641 @ 11219 2 @ 11057 2421.5 2622.78809 PSI DRILLING FLUIDS REPORT DEPTH 11250'/9593' MW 9.45 VIS 48 PV 16 YP 31 FL 4.0 Gels 9/11/12 CL- 11000 FC 1/0 SOL 4.7 SD 0.25 OIL 1.0/93.3 MBT 2.0 pH 8.9 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 92 @ 11173 7 @ 11087 41.4 TRIP GAS CUTTING GAS 0 @ 11235 0 @ 11235 0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 12115 @ 10960 998 @ 11087 4826.9 CONNECTION GAS HIGH 73 ETHANE (C-2) 1054 @ 11113 79 @ 11087 394.0 AVG 41.4 PROPANE (C-3) 1143 @ 11113 92 @ 11087 436.1 CURRENT 0 BUTANE (C-4) 1895 @ 11143 78 @ 11087 443.9 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 1886 @ 11143 21 @ 10857 213.7 HYDROCARBON SHOWS 3 SHOWS FROM 10800' - 11248' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 10800' - 10920'; 10940' - 11070'; 11100 - 11248' SEE ATTACHED SHOW REPORTS LITHOLOGY HK5T - SAND/SANDSTONE (10787' - 11070'), HK6T - CARBONACEOUS SHALE/TUFFACEOUS SILTSTONE (11070' - 11110'), HK6T - SAND/SANDSTONE (11110' - 11248') PRESENT LITHOLOGY HK6T - SAND/SANDSTONE DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 10787' TO 11248', START TRIPPING OUT OF HOLE FROM 11248' TO 10700') CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 02, 2012 DEPTH 11248' PRESENT OPERATION TRIP IN HOLE TIME 24:00:00 YESTERDAY 11248' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11167.93' 75.3 357.27 9556.51' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 5 8.5" QH26DR 11254288 3x18 10567' 11248' 681' 25.52 5-3-WT-A-E-I-CT-PR PENETRATION RATE 6 8.5" EQH20DR 11555548 3x18 11248' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11250'/9593' MW 9.45 VIS 50 PV 16 YP 30 FL 3.8 Gels 9/11/12 CL- 11000 FC 1/1 SOL 4.9 SD 0.20 OIL 1.0/93.4 MBT 2.0 pH 9.0 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 50 CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO NEW FOOTAGE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO NEW FOOTAGE PRESENT LITHOLOGY HK6T - SAND/SANDSTONE/CONGLOMERATE SANDSTONE DAILY ACTIVITY SUMMARY CONTINUE TRIPPING OUT OF HOLE FROM 10700', LAY DOWN BHA, PICK UP BOP TEST TOOLS, BOP TEST, LAY DOWN BOP TEST TOOLS, PICK UP BHA, TRIP IN HOLE TO 2996'. CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 04, 2012 DEPTH 11560' PRESENT OPERATION DRILLING TIME 24:00:00 YESTERDAY 11248' 24 HOUR FOOTAGE 312' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11461.37' 75.42 355.33 9629.01' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" EQH20DR 11555548 3x18 11248' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 228.8 @ 11461 0.5 @ 11256 44.8 2.09932 FT/HR SURFACE TORQUE 0 @ 11560 0 @ 11560 0 0 AMPS WEIGHT ON BIT 65 @ 11312 9 @ 11251 24.7 27.25754 KLBS ROTARY RPM 0 @ 11560 0 @ 11560 0 0 RPM PUMP PRESSURE 2627 @ 11248 2158 @ 11251 2429.6 2468.85997 PSI DRILLING FLUIDS REPORT DEPTH 11540'/9650' MW 9.4 VIS 46 PV 15 YP 28 FL 4.8 Gels 9/11/13 CL- 11000 FC 1/1 SOL 4.9 SD 0.21 OIL 1.0/93.4 MBT 4.0 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 161 @ 11485 20 @ 11293 49.2 TRIP GAS 190 CUTTING GAS 0 @ 11560 0 @ 11560 0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 17757 @ 11412 1932 @ 11358 5026.8 CONNECTION GAS HIGH 33 ETHANE (C-2) 1651 @ 11462 75 @ 11560 405.0 AVG 49.2 PROPANE (C-3) 1933 @ 11462 58 @ 11560 419.4 CURRENT 32 BUTANE (C-4) 1553 @ 11462 49 @ 11560 353.3 CURRENT BACKGROUND/AVG 21 PENTANE (C-5) 719 @ 11462 9 @ 11428 135.9 HYDROCARBON SHOWS 2 SHOWS FROM 11260' TO 11560' INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 11260' - 11390'; 11440' - CURRENT SEE ATTACHED SHOW REPORTS LITHOLOGY HK6T - SAND/SANDSTONE (11248' - 11400'), COAL (11400' - 11420'), HK7T - SAND/SANDSTONE (11420' - 11550'), HK7T - CARBONACEOUS SHALE/SAND/SANDSTONE (11550' - CURRENT) PRESENT LITHOLOGY HK7T - CARBONACEOUS SHALE/SAND/SANDSTONE DAILY ACTIVITY SUMMARY FINISH TRIPPING IN HOLE FROM 2996', DRILL AHEAD FROM 11248' TO 11560' CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3895 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 05, 2012 DEPTH 11720' PRESENT OPERATION CIRCULATING TIME 24:00:00 YESTERDAY 11560' 24 HOUR FOOTAGE 160' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11720' 75.22 356.62 9695.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" EQH20DR 11555548 3x18 11248' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 78.8 @ 11632 0.2 @ 11573 13.6 30.21142 FT/HR SURFACE TORQUE 0 @ 11720 0 @ 11720 0 0 AMPS WEIGHT ON BIT 34 @ 11572 19 @ 11605 26.1 21.35848 KLBS ROTARY RPM 0 @ 11720 0 @ 11720 0 0 RPM PUMP PRESSURE 2597 @ 11714 2459 @ 11569 2524.0 2567.98145 PSI DRILLING FLUIDS REPORT DEPTH 11720'/9695' MW 935 VIS 47 PV 15 YP 29 FL 4.2 Gels 8/10/11 CL- 11500 FC 1/1 SOL 5.0 SD 0.40 OIL 1.0/93.0 MBT 4.0 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 70 @ 11656 3 @ 11689 13.4 TRIP GAS N/A CUTTING GAS 0 @ 11720 0 @ 11720 0 WIPER GAS 382 CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 19020 @ 11714 1123 @ 11586 4361.5 CONNECTION GAS HIGH 12 ETHANE (C-2) 1168 @ 11717 31 @ 11620 193.6 AVG 13.4 PROPANE (C-3) 1040 @ 11717 23 @ 11586 153.3 CURRENT 18 BUTANE (C-4) 824 @ 11717 0 @ 11587 103.1 CURRENT BACKGROUND/AVG 9 PENTANE (C-5) 39 @ 11612 0 @ 11576 3.5 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CARBONACEOUS SHALE (11560' - 11580'), SAND/SANDSTONE (11580' - 11630'), SHALE/CARBONACEOUS SHALE (11630' - 11720'). PRESENT LITHOLOGY TD - CARBONACEOUS SHALE/SAND. DAILY ACTIVITY SUMMARY DRILL AHEAD FROM 11560' TO 11720' (TD), CIRCULATE AND CLEAN HOLE, WIPER TRIP TO 9929', CIRCULATE AND CLEAN HOLE. CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3395 DML, $1355 RIGWATCH REPORT BY ATHAN HILCORP ALASKA, LLC DAILY WELLSITE REPORT M-29A REPORT FOR LESLIE DATE Jul 06, 2012 DEPTH 11720' PRESENT OPERATION RIH WITH LINER TIME 24:00:00 YESTERDAY 11720' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 8513' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11720' 75.22 365.62 9695.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 6 8.5" EQH20DR 11555548 3x18 11248' 11720' 472' 13.72 3-3-WT-A-F-I-CT-TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING FLUIDS REPORT DEPTH 11720'/9695' MW 9.45 VIS 56 PV 15 YP 22 FL 4.1 Gels 7/8/10 CL- 11500 FC 1/0 SOL 5.0 SD - OIL 1.0/93.0 MBT 4.0 pH 9.0 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 60 CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG N/A PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO NEW FOOTAGE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NO NEW FOOTAGE PRESENT LITHOLOGY NO NEW FOOTAGE DAILY ACTIVITY SUMMARY CIRCULATE AND CLEAN HOLE, TRIP OUT OF HOLE, LAY DOWN BHA, RUN LINER TO 1773'. CANRIG PERSONNEL ON BOARD ATHAN, ENGLERT, HINOSTROZA, HILLEGEIST DAILY COST $3464 DML, $1355 RIGWATCH REPORT BY ATHAN
