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Home My WebLink About200-038STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT G-28RD JBR 04/26/2023 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 4.5" test joint used for testing. On test #2 we ran out of chart due to bumping up the low twice. We suspected air in the system so we purged air and changed out the chart and continued the test. None of the tested components were cycled for purging air. After purging the test went well for a pass. Accumulator bottle precharge for 18 bottles averaged at 1000 psi. Test Results TEST DATA Rig Rep:Chris Hannvold/Brad WOperator:Hilcorp Alaska, LLC Operator Rep:Wade Hudgens/Ed Hooter Rig Owner/Rig No.:Hilcorp 404 PTD#:2000380 DATE:3/31/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopGDC230330123128 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 3 MASP: 2530 Sundry No: 322-674 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8" 5000 P #1 Rams 1 2 7/8"x5.5" V P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 2 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 3 2 1/16" 5000 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1850 200 PSI Attained P16 Full Pressure Attained P84 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2100 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P24 #1 Rams P6 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9999 9 9 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: Replaced 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 15,416 feet N/A feet true vertical 9,414 feet N/A feet Effective Depth measured 15,380 feet See schematic feet true vertical 9,410 feet See schematic feet Perforation depth Measured depth 11,610 - 15,380 feet True Vertical depth 9,469 - 9,415 feet 4-1/2" 12.6# / L-80 7,175 (MD) 6,008 (TVD) Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# / L-80 11,398 (MD) 9,350 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 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: Hemlock Oil 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: 53 322-674 Sr Pet Eng: slotted Sr Pet Geo: Sr Res Eng: WINJ WAG 47 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 369 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) 108 Gas-Mcf MD 369 N/A 659 Size 368 827 5096 57132 51 1402484 13-3/8" 9-5/8" slotted 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-038 50-733-20324-01-00 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: ADL0017594 McArthur River Field / Hemlock Oil Trading Bay Unit G-28RD Plugs Junk measured Length measured TVD Production Liner 9,761 4,229 3,904 Casing Structural 8,120 9,519 4-1/2" 9,761 11,700 15,414 9,410 828 6,020 828Conductor Surface Intermediate 26" 20" 4,750psi 7,030psi 3,090psi 6,870psi 8,160psi 6,020 5,092 Burst Collapse 1,540psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 11:03 am, Apr 24, 2023 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.04.21 14:57:53 - 08'00' Dan Marlowe (1267) Updated by: JLL 04/17/23 SCHEMATIC McArthur River Field Well: G-28RD API: 50-733-20324-01-00 PTD: 200-038 Completed: 04/04/2023 TD = 15,416; ETD =15,380 RKB = 42 Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL SIZE WT GRADE CONN ID (in.) MD TOP MD BTM. 26 ½ WT Spiral Weld 25.000 Surface 369 20 94 H-40 Buttress 19.125 Surface 828 13-3/8 61 K-55 Buttress 12.415 Surface 6,020 9-5/8 47 N-80 Buttress 8.681 Surface 8,922 9-5/8 47 S-95 Buttress 8.681 8,922 9,761 Window 7 29 L-80 Buttress 6.184 7,471 11,700 4-1/2 12.6 N-80 Hydril 511 3.958 11,510 15,414 Mix of 4-1/2 slotted and pre-drilled liner from 11,6140 15,380 MD Tubing: 4-1/2 12.6 L-80 Hydril 563 3.958 Surface 1,772 4-1/2 12.6 L-80 Hydril 503 3.958 1,772 7,175 4-1/2 12.6 L-80 Mod Butt. (SPC) 3.958 7,434 11,398 JEWELRY NO Depth (MD) Depth (TVD) ID OD Item 1 7,175 6,008 - 5.130 Bolt-on Discharge 7,176 6,009 - 6.750 Pump: 538 Series, Stg SJ7000 (x3) 7,235 6,055 - 5.130 Intake: Sub-Assy 513, SS, High Strength Shaft 7,236 6,056 - 5.130 Seals: Upper/Lower 513 Series BPBSBPB Premium Seals, AR Bearings, Inconel Shaft 7,259 6,073 - 5.620 Motor: 562 Motor, KMS2 500HP/3305V/93A 7,294 6,101 - 5.620 Centralizer/Anode A 7,415 6,211 3.958 4-1/2 tubing cut stub (tubing punched 7416-7422) 7/2/16 Tagged stub with work string at 7,434 MD B 8,034 6,701 3.833 4-1/2 Camco KBG-2 SPC GLM w/ 1 BK-2 Latch (5.984 OD) 8,578 7,157 3.833 9,086 7,568 3.833 9,565 7,958 3.833 9,614 7,998 3.833 10,036 8,350 3.833 C 11,323 9,307 4.00 Baker KBH-22 Anchor and permanent packer D 11,365 9,331 3.813 Otis X nipple E 11,398 9,350 3.958 Mule shoe F 11,510 9,412 4.438 Baker SL-ZXP Liner Packer with 10 tie-back extension G 11,578 9,450 3.813 Otis X nipple (set in the 4-1/2 production liner) F G Horizontal ported/slotted liner across Hemlock Benches 1/2/3 from 11,610 15,380 MD C 9-5/8 window @ 9761 D/E B A 1 Well Name Rig API Number Well Permit Number Start Date End Date G-28RD HAK 404 50-733-20324-01 200-038 3/29/2023 4/4/2023 Daily Operations: 03/31/2023- Friday R/u Heaters and warmed cold spots as needed. R/u mud pump and connected circulating hoses, setup handling eq. for 4-1/2". R/u testing eq. and purged air out of system. Tested BOPE per Sundry as following: Annular 250-3000psi, Rams 250-3000psi, Valves 250-3000psi. Test Gas Detection and Pit Level Indicator. Performed Koomey Drawdown and Control Systems Respond Times. Tested w/4-1/2" Test Joint, No Failures. Witness by AOGCC Inspector Guy Cook. R/d Testing eq. Blow stack and lines dry. Installed Beaver slide. R/u Summit Handling equipment, pull Blanking sub, unable to pull BPV. Rigging up Summit ESP completion equipment level rig. Pick up landing joint into hanger back out lock downs. Check IA (IA static) unseat hanger 154k pick up, rig up to pump down tubing pump 158 bbl. of 8.4 ppg FIW at 2 bpm at "0" psi, had no returns, shut down pump, tubing on vacuum, pull hanger surface, terminate, motor lead and control lines l/down hanger. Pooh racking back 4-1/2, 12.6#, hydril 503 tubing. from 7295 ft to 5686 ft. 04/01/2023 - Saturday Continued POOH w/4-1/2 GL/ESP Completion f/5800' t/2720', standing back Tbg, spooling cable, control line and removing clamps. Pumping double displacement w/ 8.5ppg FIW. Swapped out cable spools, pumped 20 bbls down tubing during swap. Continued POOH w/4-1/2 GL/ESP Completion f/2756' t/ ESP assembly. Rig up Summit handling tools, Pooh laying out (3) 675 series pumps & (2) 562 motors with centralizer / anode (found pumps to be locked up and both motors had gone to ground) had total of 131 clamps and 2 splice clamps had full recovery of pump assembly, laid down (5) 7.063" GLM'S. Rig down summit handling tools & rig up 4-1/2 handling tools. Trip in hole with 4-1/2 tubing out of derrick, depth at report time 3,250 ft. Hilcorp Alaska, LLC Well Operations Summary 03/29/2023 - Wednesday Mobe crews & orientate. PJSM. R/U circulating lines f/production. Circulate FIW @ 5bpm pump 237bbls, when choke washed out. S/D repair. Circulate FIW @ 5bpm pump total of 1130bbls, monitored returns clean fluid @ 8.5ppg. S/d pump. Monitor well, Tbg/IA on vacuum, R/u Tee Bar and installed BPV. Disconnect and removed flowline. N/d Tree, Inspect Hanger and M/u Blanking Sub. N/u DSA and Riser Spool, N/u BOP Stack and torque to spec. Install Koomey hoses and Kill/Ck Lines. Set dog house on beam, set drill line spool, lay out guy lines, install driller console, plug in carrier hydraulics and air lines, install brake linkage. Raised Mast, secured guy lines and load line, Install drive line, spool tugger, man rider and drill line on drums. 03/30/2023 - Thursday Scoped up Derrick and secured upper guy lines, secure dawgs in Derrick with safety pins perp to install rig floor. Continued spotting in eq with crane. PJSM. Install rig floor. N/u spacer spool on annular, installed wind walls and stairs, chained back stack, check bottle pre- charge, function tested BOP's, built 4-1/2" test jt. R/u gas detection system. Installing hootch around choke manifold. Rig up test pump, rebuild test pump manifold, change out test joint due to finding a bad box on test joint. Installing hootch around choke manifold. Install test 4-1/2 test joint. Perform shell test on BOPE to 250 low, 3000 psi HI. Test made with water and held 5 minutes each on chart, tighten flange between spool and blind rams. Clean filters on koomey air pumps. Work on winterization of rig. 04/02/2023 - Sunday Continued RIH with 4-1/2" Hydril 503 Tbg f/2600' t/6815', clean and inspect threads. Filled hole @ 5bph w/FIW. Began L/d 53 bad joints due to damage from tongs, tallied damage pipe. Layout and tally new Tbg. P/u Tbg and racked back in derrick, pooh racking back in derrick and strapping same. Rig down Gills power tongs & rig up McCoy tongs. Rig up summit handling tools, Held PJSM with crews. Picking up pumps. Well Name Rig API Number Well Permit Number Start Date End Date G-28RD HAK 404 50-733-20324-01 200-038 3/29/2023 4/4/2023 Hilcorp Alaska, LLC Well Operations Summary Build ESP penetrator and chem lines through hanger, test cable, land completion w/98klbs down on hanger, no up weight taken. RILDS. L/d Landing Jt, R/d Summit eq. Blow lines dry. Clean and cleared rig floor. R/d pipe slide. Disconnected guy lines, scope and L/d derrick, disconnected koomey and kill/choke lines. R/d circulating lines, R/d floor, N/d BOP stack and riser. N/u Tree and test void 500-5000psi, hooked up flowlines. Pulled BPV. Set TWC test tree to 3000psi. Pulled TWC well to production. Continue R/d, cleaning and putting away equipment. Backload boat with ESP equipment. 04/03/2023 - Monday Continue M/U and servicing Summit new ESP assembly, pumping FIW @ 5bph down IA. RIH with ESP picking up 4-1/2" 12.60# L-80 Hydril 503 Tubing Stands f/150' t/6,485'. Clamped first 10 collars then every other thereafter. Meg test cable every 1000'. Pumping FIW @ 5PBPH down IA. Crew performed well control drill while run ESP completion. Swap out cable reels and splice #1 round SS cable to #1 flat SS cable. Splice is at 695', joint 212. Pumping FIW @ 5PBPH down IA. RIH with ESP f/6,485' t/7,294', Clamped last 10 collars, every other collar before. Meg test cable every 1000'. Pumping FIW @ 5PBPH down IA. M/U hanger. Build ESP penetrator and chem lines at report time. 04/04/2023 - Tuesday RBDMS JSB 120222 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Cl Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill Cl Perforate New Pool Cl Repair Well 0 Re-enter Susp Well Cl Other:Install ESP/GL ComboE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory❑ 200-038 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20324-0 7.Property Designation(Lease Number): 8.Well Name and Number: ' I Oji E ADL0017594 Trading Bay Unit G-28RD A U G A 2 2016 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: AcGCC. Total Depth measured 15,416 feet Plugs measured N/A feet true vertical 9,414 feet Junk measured N/A feet Effective Depth measured 15,380 feet Packer measured 11,324&11,510 feet true vertical 9,410 feet true vertical 9,307&9,411 feet Casing Length Size MD ND Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13-3/8" 6,020' 5,092' 3,090 psi 1,540 psi Intermediate 9,761' 9-5/8" 9,761' 8,120' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4-1/2" 15,414' 9,410' Slotted Slotted Perforation depth Measured depth 11,510-15,380 feet True Vertical depth 9,468-9,415 feet 4-1/2" 12.6#/L-80 7,161'(MD) 5,997'(ND) Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 11,398'(MD) 9,350'(ND) Baker 85SAB-L47 Pkr 11,324'(MD)9,307'(ND) Packers and SSSV(type,measured and true vertical depth) Baker SL-ZXP Packer 11,510'(MD)9,411'(ND) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: r J : '1 f N/A . _! iii si d .s` 2 ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 296 472 7605 71 78 Subsequent to operation: 194 120 8209 83 84 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations II Exploratory❑ Development CI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG ❑ GINJ 0 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: 316-340 Contact Trudi Hallett(907)777-8323 Email thallett cc hilcorp.com Printed Name Stan W.Golis/ ✓`o� Title Operations Manager Signature Phone74 6r ti4R° / //•4 (907)777-8356 Date 8 f 1 G1 RBDMS LA- Form 10-404 Revised 5/2015 Ma- 3 2016 Submit Original Only • • SCHEMATIC McArthur River Field, TBU ,II Well: G-28RD 11ikcorpAlaska.LLc As Completed: 07/06/16 RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL \ / SIZE WT GRADE CONN ID(in.) MD TOP MD BTM. 26" %"WT Spiral Weld 25.000 Surface 369' / '\ 20" 94 H-40 Buttress 19.125 Surface 828' 26"shoe 13-3/8" 61 K-55 Buttress 12.415 Surface 6,020' rii)36G 9-5/8" 47 N-80 Buttress 8.681 Surface 8,922' 20"shoe 9-5/8" 47 S-95 Buttress 8.681 8,922' 9,761' (a)828' Window 7" 29 L-80 Buttress 6.184 7,471' 11,700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11,510' 15,414' 1 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing 2 Tubing: 4-1/2" 12.6 L-80 Hydril 503 3.958 Surface 7,161' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,434' 11,398' 3 1 JEWELRY G NO Depth Depth ID OD Item (MD) (TVD) 4 1 2,238' 2,208' 3.833 7.063 GLV-SPM 1-1/2"IPOR-2 Port Size 24(Dummy) 5 I+ 2 4,029' 3,611' 3.833 7.063 GLV-SPM 1-1/2"IPOR-2 Port Size 24(Dummy) 3 5366' 4,578' 3.833 7.063 GLV-SPM 1-1/2"IPOR-2 Port Size 24(Dummy) 6 Iramma- 21IE 7 111111 4 6,266' 5,291' 3.833 7.063 GLV-SPM 1-1/2"IPOR-2 Port Size 24(Dummy) 8 ■ 5 6,895' 5,790' 3.833 7.063 GLV-SPM 1-1/2"Orifice-2 Port Size 30(Dummy) 13-3/8"shoe _ 6 7,161' 5,997' - 6.750 Bolt-On Discharge (ii)6020' 9 in 7 7,162' 5,998' - 6.750 Pump(x3)675 Series,033 Stg SH12000 10 , 8 7,211' 6,036' - 5.130 Intake 7"TOL(a%7471' -1_ __g6051'log 9 7,230' 6,051' - 5.620 Motor(x2)562 Motor KNSUT/KMSLT 500 HP C interpretation 10 7,295' 6,101' Centralizer Anode shows hole in 5.620 Centralizer/Anode 9-5/8"casing at 7953' E A 7,434' 6,211' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 . F SPF 1/2/16-Tagged tubing stub at 7,434'(PM-jt#240) 9-5/8" G B 8,034' 6,701' 3.833" Window (u 9761' C 8,578' 7,157' 3.833" II I� D 9,086' 7,568' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch J E 9,565' 7,958' 3.833" (5.984"OD) 4-1/2"TOL @ I1,SIOL� gr. �I 11 F 9,614' 7,998' 3.833" 7"shoe @ 11700' N G 10,036' 8,350' 3.833" H 11,323' 9,307' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals I 11,324' 9,308' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent Packer with 6'mill out extension J 11,365' 9,331' 3.813" Otis"X"nipple(3.813") K 11,367' 9,332' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. I I L 11,398' 9,350' 3.958" Mule shoe M 11,510' 9,412' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension TD= 15,416'; ETD=15,380' N 11,578' 9,450' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) Horizontal ported liner produces from Hemlock Benches 1,2, and 3 Updated by: JLL 08/01/16 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-28RD Moncla 404 50-733-20324-01 200-038 6/29/16 7/6/16 Daily Operations: 06/29/2016-Wednesday Continued positioning equipment as needed. Installed drill line on draw works drum.Setup stairs and handrails on active tank then R/U lines to rig pump,standpipe and kill side. Filled tb and annulus w/FIW. Ran lines from koomey unit to BOP area. Mounted stack on gas buster. Positioned super choke on carrier walkway.Attempted to set BPV but there was slight pressure on both sides(oil). R/U circ lines and pumped 250 bbls FIW down tb at 3.5 BPM 400 PSI sending returns to TBPF thru water clean tank.Shut down pump and tb was on vacuum. B/O circ line and N/D pumpin sub.Set BPV. N/D flow line,SSV,wing valve and tree. N/U 13 5/8"x 11"adapter spool, riser, mud cross w/HCRs&manual wings,double gate rams Idd w/2 7/8"x 5"variable pipe blocks, DSA and hydril (13 5/8"x 5M). Hooked up koomey lines to BOPs, unwrapped cables in derrick, raised and scoped out derrick,secured all guy lines. 06/30/2016-Thursday Leveled rig and finished securing derrick guy lines. Pinned floor in place and installed floor supports and hand rails. Positioned driller's shack and pinned in place.Setup two sets of stairs to rig floor and stairway from walkway to driller's shack. Quadco and Total Safety onboard installing their systems. Prepped rig floor with handling tools and power tongs. M/U 3 1/2"test jt w/4 1/2" IBT blanked ported sub w/XO on btm and pumpin,safety valve, IBOP on top.Screwed into hanger and filled stack.Closed hydril and shell tested to 3000#s. Worked thru leaks at hold down pins. Pretested BOPs ;3DP 250#s low 3000#s high.Worked thru leaks at tb head hold down pins.Tested BOPE equipment to 250#s low 3000#s high I ' as directed by Sundry in accordance with AOGCC& Hilcorp requirements(tested hydril to 2500#s).Witness of test waived by Mr.Jim Regg,AOGCC. Performed successful koomey draw down test.Tested w/3 1/2" &4 1/2"tb. Pulled BPV &set 2-way check to test blinds. Pulled 2-way check. B/D test jt and M/U 4 1/2" IBT landing jt w/pumpin and safety valve.Screwed into hanger, lined up to circ LW sending returns to TBPF thru water clean tank. 07/01/2016-Friday Received signed NPFT form from TBPF and go ahead from production.Circ hole clean while setting up elevated catwalk. Pumped 800 bbls FIW LW at 3.5 BPM 400 PSI to TBPF thru water clean system. B/O hold down pins and picked up on string, hanger came off seat at 92k, pulled uphole at 108k.Set hanger back down and shutin well.Welded catwalk support in place.Opened well and pulled hanger to surface,worked same. Pulled 4 singles to get flat pack and reda cable on spoolers and set catwalk in place. POOH w/4 1/2" 12.6#L-80 Hydril 503 production string w/ESP assy pumping 10 bbls every 20 jts. Heavy corrosive damage on reda cable from surface to 2,300'.Cable checked good after 2,300'.Worked M/V Titon while changing out ESP cable spool at joint#94= 2,929'.Continue POOH laying down 4 1/2" 12.6#L-80 Hydril 503 production string w/ESP assy pumping 10 bbls every 20 jts. Breaking down ESP assy. • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-28RD Moncla 404 50'733'20324'01 200'038 6/29/16 7/6/16 Daily Operations: m~" 07/02/2016-Saturday R R/D Summit. Backload M/V Titon.Cleared and cleaned rig floor. R/D McCoy tongs, R/U Gill tongs. K8/UBHA#l(A1/2''x21/4^Vare| rock bit, 7''x21/4'' casing scraper f/95/O"casing,SS/8''x2^X'Oversub~7.82'). T|Hw/bit&scraperpickinQup31/2^ 1Z.95#P'l1OPH'6=nrkstringoffdeck'strapping'rabbitinK'torqueingtuGOOO FPT.Tagged 4 1/Z^tubing stub at 7,434.25' (PM) (jt #240)workstring measurement. R/U to reverse circulate with FIW, installed shaker screen,chute and cutting box. R/D elevated cat walk in order to be able to rack back 3 1/2"workstring. Reverse circulated with FIW at 2.5 BPM 260 PSI,got returns at 33 bbls, reversed 700 bbls around at 3 BPM 300 PSI. POOH racking back workstring, pumping 10 bbls every 10 stands.Cleaned rig floor and BOP area. B/D bit&scraper M/U RTTS tool. 07/03/2016-Sunday T|Hw/81/4^ Halliburton R7TStool, running inon31/2^ 12.9S#P'110PH'6vvorkstringout ofderrick at1min/stand.Set circ.tool mt7'413'and established Openedpipemmstoob�eneOnceannu|usmms8Uedandpumpwas�hut backside. (. off,fluid would fallout as though bypass was open or something interfered with proper setting.Attempted to set tool 3 ~4~�' - times at 7,413' jt but failed. Picked upone to7'3A2'and set tool, held solid 18UU#test for 30 mins on chart. Released tool.Set elevated catwalk in place. POOH laying down PH-6 workstring pumping 5 bbls every 15 jts. B/D Halb RTTS tool, cleared and cleaned. R/D Gill tongs, R/U McCoy tongs. Prep rig floor to run ESP.Serviced rig motor package. M/U Summit dual 500 HP motors w/cent and gauge on btm (serviced motors). R/U sheaves in derrick w/cable and flatpack loaded. M/U lower&upper tandem seals,attached flatpack and reda cable. Performed electrical checks(serviced seals). 07/04/2016-Monday Finished assembling Summit ESP 1,000HP,99stg SH12000 pump assy.Tested ESP electrical integrity.TIH with ESP/SPM assypicking up4l/%" 12.6O#L-8)Hydh| SU3tb,strapping, rabbitingand tonqueingto4'6OOft/lbs,checking electrical every 1000' Clamping cable every other collar,above and below every SPM. ESP cable splice at jt#83(4,523.4') (bottom cable is 8kV Schlumberger heavy galvanized,top cable 5kV Centrilift stainless steel).Continued RIH with ESP/SPM assy. M/U jt#222(7,019')and noticed that tube was crushed by tongs, backed out jt and P/U to#221 (0200 hrs). Found slight damage to tube at M/U area, laid out#221,conferred with Eng and called for S/L crew.Attempted to M/U 5 more jts reducing torque to minimum value but all were damaged. • 410 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date G-28RD Moncla 404 50-733-20324-01 200-038 6/29/16 7/6/16 Daily Operations: 07/05/2016-Tuesday Adjusted sensitivity on McCoy tong torque gauge and M/U jt#221 with no damage to tube. Lowered in hole(EOT @ 7,019'). Moved elevated pipe rack off booster package.Spotted Pollard S/L unit. R/U with full lubricator. M/U 3.74" gauge w/1 1/2"spang&oil jars, knuckle jt and 2-1 3/4"stem.TIH tagging at 150',worked thru then tagged at 301', could not work thru. POOH&B/O 3.74"gauge. M/U 3.60"gauge on same tool string.TIH to 6,750' (120' below SPM#1) tagging at 6,001'and 6,630' (same depth and distance between SPM#1&#2). POOH&B/O 3.60"gauge. M/U 3.70" gauge on same tool string.TIH to 6,750'without tagging. POOH &B/O 3.70"gauge. M/U 3.72"swedge w/1 3/4"spang& oil jars, knuckle jt and 2-2 1/8"stem.TIH to 301'and bumped thru,tagged at 453'and bumped several times but did not go thru.Conferred w/Engr and decision was made to POOH. R/D S/L.Changed torque gauge on tongs and M/U remainder of production string plus hanger w/landing jt. EOTs at 7,296'. Plumbed hanger with cable penetrator and 2- 1/4"flat pack control lines. Landed hanger in tb head with EOTs at 7,295' (S/0 65k P/U est at 100k).Checked electrical/good. Ran in hold down pins, B/O landing jt and set BPV. R/D Summit handling equipment,elevated cat walk, rig floor.Shipped 200bbl FIW and well fluid to Trading Bay from rig pits and cleaned same. Removed welds from elevated catwalk support and repaired handrails on top of booster pack that were removed for cat walk install.Scope in and laid down derrick, bled off accumulator, unhooked hoses and nippled down BOP's+riser. ESP checked good electrically after the riser was removed. Nipple up and torque tree.Test void to 5,000psi. Remove BPV install 2 way check and shell test tree 5,000psi. 7/6/16-Wednesday Finished hooking up all flow lines to tree-pulled BPV and set 2-way check-shell tested tree to 5000#s for 5 mins. Turned well over to production. Broke and packed up all lines between mud pump and active tank-steam cleaned hydril,double gate and mud cross- roll up and stowed accum lines-Quadco and Total Safety disconnected their systems-received word at 1030 hrs that ESP was running and to prepare to move to D-12RD. Began demobing W/O package-spooled drill line off and onto spool-secured all lines to derrick-steam cleaned while waiting on boat.Unpinned derrick and loaded same on M/V Titon-along with A-frame,draw works, carrier,walkways and steps,tool connex plus strong back and spreader beams-cleaning equipment prior to being loaded on boat. Cleaned,organized and prepped for move while East crane(D-12 side)on Dolly is being repaired. • • . • `,OF 71i \��yy�'s THE STATE Alaska Oil and Gas ti�y�� p f Q Conservation Commission 7 t -i,{2__ ,_ 333 West Seventh Avenue '1103" C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ' Main: 907.279.1433 OF ALf �� Fax: 907.276.7542 AS www.aogcc.alaska.gov Stan W. Golis Operations Manager '. fi m Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU G-28RD Permit to Drill Number: 2 00- o34? Sundry Number: 316-340 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, /9764-k Cathy7.-i Foerster Chair DATED this 23"tay of June, 2016. RBDMS L✓JUN 2 4 2016 RECEIVED • JUN 2 0 2016 STATE OF ALASKA `/z / ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,. ` ',` 4'. . 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ 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 ❑ Development 0 . 200-038 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ti 6.API Number. Anchorage,AK 99503 50-733-20324-01 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 0 Trading Bay Unit G-28RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY C, Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): t 'Plugs(MD): Junk(MD): 15,416 9,414 . - 15,380 •9,410 ' i. N/A N/A Casing Length Size MD TVD Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13-3/8" 6,020' 5,092' 3,090 psi 1,540 psi Intermediate 9,761' 9-5/8" 9,761' 8,120' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4-1/2" 15,414' 9,410' slotted slotted Pe oration Depth MD(ft)� Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11, 10-15,380 9,468-9,415 4-1/2" 12.6#/L-80 7,289 4-1/2" 12.6#/L-80 11,398 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker 85SAB-L47 Packer&Baker SL-ZXP Packer&N/A • 11,324'(MD)9,307'(TVD), 11,510'(MD)9,411'(TVD)&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 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: 7/4/2016 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ 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 dmarloweCct�hilcorp.com Printed Name Stan W.Golis Title Operations Manager / Signature L",l' "" Phone (907)777-8356 Date l'( 2 0>�I 4, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\Lc- 31-(c) Plug Integrity ❑ BOP Test' Mechanical Integrity Test ❑ Location Clearance ❑ Other: iF 30).0 p s.. ii5G P r s f C./4 ki It..,--6i s o p S i) Post Initial Injection MIT Req'd? Yes 0 No ❑ �/ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / 0` 1 C`' RBDMS (rt- JUN 2 4 2016 APPROVED BY Approved by: /� COMMISSIONER THE COMMISSION Date: (v -23—/c t Submit Form and R0 v Form 10-403 vise 11/2015 r valid for 12 months from the date of approve?. Attachments in Duplicate . • Well Work Prognosis Well: G-28RD Hilearp Alaska,LLC 06/20/16 Well Name: G-28RD API Number: 50-733-20324-01 Current Status: ESP Producer Leg: Leg#3 (SE corner) Estimated Start Date: July 04, 2016 Rig: Moncla Rig 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 200-038 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907)-777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: -3,750 psi @ 9,607'TVD ` (mid perf of 13,557'MD) Maximum Expected BHP: -3,750 psi @ 9,607'TVD (No new perfs being added) Max.Anticipated Surface Pressure: 143L-696-psi- L i , Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) **Note this is a No-Flow well(05/15/2015),Current SITP is 240 psig,Will not flow based on an expected oil and water gradient of 0.437 psi/ft Brief Well Summary G-28RD is a Hemlock Producer that was converted to and ESP from a gas-lift completion in April 2011. The ESP was replaced 01/10/2014 and 03/30/2015. The current ESP experienced a down-hole electrical failure 06/17/2016. We plan to pull and replace the ESP with a combination Gas-Lift/ ESP completion. No perforations will be added. Procedure: 1. MIRU Moncla Rig 404. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to±7,200' and punch tubing. (Using FIW as workover fluid) 3. ND Wellhead, NU BOP and test to 250psi low/21&OOpsi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). "` e:, ` 4. POOH with tubing string and ESP pump laying down the same. 5. RIH to top of lower tubing±7,400' w/ bit and scraper. Circulate bottoms up. POOH. 6. RIH with RTTS to±7,400'testing casing to 1,500 psig on chart for 30 minutes. POOH. 7. PU, RIH with ESP completion. 8. Land ESP with the bottom of the assembly at±7,400'. 9. ND BOP, NU wellhead and test. 10. Turn well over to production. 11. Conduct SVS Testing per AOGCC requirements Attachments: 1. Current Wellbore Schematic 2. Current Wellhead Diagram 3. Proposed Wellbore Schematic (same as current) 4. Proposed Wellhead Diagram (same as current) 5. BOP Drawing 6. Fluid/Flow Diagrams 7. Rolling BOP Test Procedures 8. RWO Sundry Change Form •n • SCHEMATIC iMcArthur River Field, TBU Well: G-28RD Hilcorp Alaska,LLC As Cornpleted: 03/30/15 RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL 1\ I SIZE WT GRADE CONN ID(in.) MD TOP MD BTM. 26" %x"WT Spiral Weld 25.000 Surface 369' / 20" 94 H-40 Buttress 19.125 Surface 828' 26"shoe 13-3/8" 61 K-55 Buttress 12.415 Surface 6,020' (a`3696 2 . 9-5/8" 47 N-80 Buttress 8.681 Surface 8,922' 20"shoe 9-5/8" 47 S-95 Buttress 8.681 8,922' 9,761' 4a-1 828' Window 7" 29 L-80 Buttress 6.184 7,471' 11,700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11,510' 15,414' 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing )~ Tubing: 4-1/2" 12.6 L-80 Hydril 503 3.958 Surface 7,289' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' JEWELRY I° NO Depth Depth ID OD Item ' (MD) (TVD) 1 81' 81 3.958" CIW-DCB-ESP Tubing Hanger:4-1/2"IBT Box Top&Btm 2 7,289' 6,097' - Discharge,Bolt-On 2 IL It 3 7,291' 6,098' - Pump(x2)45 Stg SH16000 3 111111 4 7,329' 6,128' - Intake 4 1!.' 5 7,345' 6,141' - Motor(x2)BHI 725 HMIU 13-3/8"shoe 6 7,401' 6,185' - Centralizer/Anode 'x.6020' S la 7A 7,415' 6,196' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 6 SPF 7"TOL'a`747:!,127t- ' r j 7B 8,034' 6,701' 3.833" USIT log 7Cinterpretation 7C 8,578' 7,157' 3.833" shows hole in 7D 9,086' 7,568' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch ,7� 9-5/8"casing at 79ss 7E 9,565' 7,958' 3.833" (5.984"OD) 7E 7F 9,614' 7,998' 3.833" 7G 10,036' 8,350' 3.833" 9-5/8" 7G8 11,323' 9,307' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals window9 11,324' 9,308' 4.00" Baker Model 855AB-L47 x38 Hydraulic Set Permanent @ 9761' Packer with 6'mill out extension 910 11,365' 9,331' 3.813" Otis"X"nipple(3.813") 1111 11,367' 9,332' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. 4-1/2"TOL @ 11,510' 12 p 12 11,398' 9,350' 3.958" Mule shoe `}f Ip L. l3 . 13 11,510' 9,412' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 7"shoe @ 11700' 14 14 11,578' 9,450' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) Horizontal ported liner produces from Hemlock Benches 1,2,and 3 J L TD=15,416';ETD=15,380' Updated by: 1 LL 04/28/15 . . ‘ll. PROPOSED McArthur River Field, TBU Well: G-28RD Ilileorp Alaska,LLC As Completed: Future RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL \ SIZE WT GRADE CONN ID(in.) ' MD TOP MD BTM. 26" 'A"WT Spiral Weld 25.000 Surface 369' /' 20" 94 H-40 Buttress 19.125 Surface 828' 26"shoe 13-3/8" 61 K-55 Buttress 12.415 Surface 6,020' aa,369' 9-5/8" 47 N-80 Buttress 8.681 _ Surface 8,922' 20"shoe 9-5/8" 47 5-95 Buttress 8.681 8,922' 9,761' 828' Window 7" 29 L-80 Buttress 6.184 7,471' 11,700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11,510' 15,414' 1 1 ` I 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing 2 Tubing: 1. L-80 Hydril 503 3.958 Surface 7,290' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' 3I JEWELRY G NO Depth Depth ID OD Item 4 I (MD) (ND) 1 12,565' ±2,502' - GLM 5 I 2 ±4,305' ±3,807' GLM 3 ±5,535' ±4,709' GLM C, AV 4 ±6,510' ±5,486' GLM 5 ±7,200' ±6,028' GLM 6 ±7,400' ±6,184' Bottom of ESP 13-3/8"shoe - 7A 7,415' 6,196' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 *6020' 111 SPF 6 7B 8,034' 6,701' 3.833" 7"TOL 97471' -L 2u7C 8,578' 7,157' 3.833" US1T log 7D 9,086' 7,568' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch Lammi 7C interpretation shows hole in 7E 9,565' 7,958' 3.833" (5.984"OD) 9-5/8"casing at 7953' 7F 9,614' 7,998' 3.833" 7D 7E 7G 10,036' 8,350' 3.833" LON= 7F� 8 11,323' 9,307' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals 9 11,324' 9,308' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent 9-5/8" 7G Packer with 6'mill out extension window 10 11,365' 9,331' 3.813" Otis"X"nipple(3.813") a 9761' 9 11 11,367' 9,332' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. 8 11 12 11,398' 9,350' 3.958" Mule shoe 10 13 11,510' 9,412' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 4-1/2"TOL @ 11,510' ` 12 g� 13 14 11,578' 9,450' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) 7"shoe @ 11700' tl 14 Horizontal ported liner produces from Hemlock Benches 1,2, and 3 J L TD=15,416'; ETD=15,380' Updated by: 1 LL 06/20/16 in . • 0 Grayling Platform G-28RD ESP H,Ia.pAM:ukw,LLC Grayling 28RD BHTA, 4 1/16 5M FE X Tubing hanger, CIW- 20 X 13 3/8 X 9 5/8 X DCB-ESP, 11 X 4 '/ IBT 7" Bowen top 4 1/2 lift and susp, w/4" type H BPV profile, 5 1/4 EN, I„ II 1111 2-3/8 continuous control line ports, Valve, swab, VG-200, 0 9 A prepped for BIW 4 1/16 5M FE, HWO, J-"'--,® penetrator T-24 r ®f Cross, stdd, 4 1/16 5M ®®® X 4 1/16 5M X 2 1/16 ,.�h l., 5M Valve, wing, WKM-M, I,';T-----7I 2 1/16 5M FE, HWO, �o 01,1 Q t O T24 a - I Ji! a' � ` • I. — ' / ® ice" ® Valve, lower master, m VG-200, 4 1/16 5M FE, ®® HWO, T-24 tat ••• Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped for 5 IA ESP neck, 2-% npt I ! continuous control line ports Tubing head, CIW-DCB, =••'0 N _ N Dab 13 5/8 3M X 11 5M, w/ " I 2-2 1/16 5M SSO, X _ , 01 ' - : 1 ® Valve, WKM-M, 2 1/16 5M bottom prep, �it I �'o ® ` r■ ®t ® - �11�-6 �,,�� 0�®11 FE, HWO, DD 1 %VR profile o® . ® ,. Qty 2 all 5 In"1111. 1111"12 Casing spool, CIW-WF, Illa� 21 %2MX135/83M, ( ��_ w/2-2 1/16 5M EFO, r e j,o�ll ?. Valve, CIW-F, 2 1/16 3M X-bottom prep le s .'I: FE, HWO, AA Casing head, CIW-WF, lei ;21 %2M X 20 SOW, Valve, CIW-F, 2" LPO, 1Iti1I..o HWO, AA /s. • • Grayling Platform 2016 BOP Stack Moncla 05/13/2016 Hilrurp.Iaeka,1.IA. tit [it' — � — : — 4.54' 0 V0 GK 13 5/8-50.. • — r► tit lit Ili 111th 2 7/8-5.5 • Shaffer SL variables 2.83' 1 _._.14 13 5/8 5M --- - Blinds Choke and Kill valves 21/165M i ;'m ir 216' N ] °� 4401 r t=' Ii1.lil.lo,Iol.lil'I �j liI IPI III Riser 135/85M FE X135/8 SM FE 14.20' it art raiffil1rft Spacer spool III 111111 lil lit 13 5/8 5M FE X 11 SM 2.75' III lti t!1 i!t 111 lC O 0 O o u o 0 O O u 0 0 V O V O D U O V U o • o a 0 f f 2 2 2 c 2 2 2 01 2 2 Lll 2 2 2 2 O. O. d a S U V V V V 0 0 0 U 0 HI ry m a '0 N ', N M a Vl l0 ., -o -o v v v 0 v v v v v v V v V v V-0 -0 O O O O O L 0 0 0 0 0 0 0 0 0 0 Y d E C E E E ' � N N N N N G3 '3 N N C N O L 6 O. O. O. O. 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O. a S 1 2 X 2 V U U U U U u 0 0 U U 0 2 1A O V 0) 0 O C m N U q 00 O 1/ 11 N N . 00 . U) . (O . 4k 0 w ZZ ro--•i -....-, a� CC LU I a J LU 0 M . Z O D i0 �U w R> X =j O I O LU /(/ LL aw CO • :U s 1.444,4,1.110...- C'1/4‘10-111-3- 7•11=.0 '1 4444. d EiclilD ' ii OQ m ~ w HCI. a_ ill 0 z a co Q J z Z Ow Q a ( z 0 D J In J 2 z III _ � a o O U j cQwzC� < O000pOO J J J D J 1 1/ p 0 2 Z = ziall J O O N) 10 . a y lL Z o4- 0 m Z 0 I F- Z 2 L qk J < 11 LL J D 0 CC 0 • s • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLCAttachment#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,LL.c Attachment#1 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 1s`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. 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. . • • 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 S Iowa / > oc / coQ _ & ■ 2 CO %o § 0./ < CL'E§ 4 � E / E ) U) = § i 0� c » a < - k / 2 0 co 7 -0 xE e _ a 0- § / eo l -0a) a)2 \ � ` Z k 0 $ %� CU �>" Co 2W @ o 0 B o 45 N / 2 CD a -a / op > co 11. CL co \k 0 ƒ2 o = » C a -0a 0 & / § Jc < _ k K n § ci 2 -g 2 C.)4 � / / at - Cu g C) . al 0 � § k 5) co kp co W e = 0 ■ > 7 - %a § i o a. 0_ 45 a. ils L < @ o 0 Q.. 0 C � E 0. 2 m q e § x G a k a) ■ $ U) y q / 0 < it v .. © 7 _ ° � O k $ -a E o & J co co @ C3V 2 c CO a U) • s v,OF TFJ �-0 \\ 1/7,', THE STATE Alaska Oil and Gas 9�, o fALAS <.�i Conservation Commission � 333 West Seventh Avenue +�z-= Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 O , :i, SgP Fax: 907.276.7542 www.aogcc.alaska.gov February 10, 2016 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 SCANNED MAY 1 9 2016, RE: No-Flow Verification Trading Bay Unit G-28RD PTD 2000380 Dear Mr. Golis: On May 2, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit G-28RD located on the Grayling platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit G-28RD prior to the test. The well performance was monitored for three hours with resulting in unmeasurable flow of gas and no liquid flow to surface, passing the no-flow test. Verbal approval was granted by the AOGCC Inspector to return the well to production without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit G-28RD 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 Grayling Platform. Sincerely, .J t James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 IIRu DATE: February 9, 2016 P. I. Supervisor FROM: Johnnie Hill SUBJECT: No Flow Test Petroleum Inspector TBU G-28RD Hilcorp Alaska LLC PTD 2000380 2/9/2016: After the flight to the Grayling Platform I was greeted by the Production Operator Wayne Johnson. We reviewed the well condition and their planned no flow test procedure. This test was run simultaneous with the no-flow test of TBU G-21 RD (PTD 1980640). Well G-28RD had been shut-in the previous day and depressured with the tubing and inner annulus open to communication and the flow line isolated from production. Test equipment was plumbed from the top of the tree cap through a 1/2" nipple up to a 3/4" x 3/4" tee with a 0-30 PSI calibrated gauge and out to a 1" ball valve just upstream of the meter. The 1" flowline terminated through a crowfoot connection to an open-top barrel. The meter was an ERDCO Armor-Flow model 022071 scaled 0-1800 SCFH. Initial pressure and rates were taken and the tubing was closed upstream of the meter to start the test. The pressures were documented and the well was open to flow after 1 hour (open valve to allow the well to depressure). Flow rate and pressures were documented at 30-minute intervals for the next two hours. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 830 0.5/0/3 0 0 Tubing open to vent 900 0.5/0/3 0 0 Shut tubing upstream of vent 930 1.5/0/3 1800 0 Open tbg; 5min to bleed to 0 1000 0/0/3 0 0 Tubing open 1030 0/0/3 0 0 Tubing open 1100 0/0/3 0 0 Tubing open 1130 0/0/3 0 0 Tubing open 1 Pressures are T/IA/OA Summary: No liquid was seen during the test. Gas rate and pressure rapidly declined to zero after the 30minute shut in period. TBU G-28RD exhibits the characteristics of a passing no-flow test. Attachments: none SCANNED SEP 2 ! 2016 2015-0502_No-Flow_TBU G-28RD_jh.docx Page 1 of 1 STATE OF ALASKA AL _KA OIL AND GAS CONSERVATION COM. .SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Repair Well (] Plug Perforations ❑ Perforate❑ Other 2 Replace ESP Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weil❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 200-038 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number Anchorage,AK 99503 50-733-20324-01 7. ADL0017594 PropertyDesignation(Lease Number): Tr drag Bay Un and8.Wl Name G-28RD RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): APR 2 O Q 205 McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: OGGG Total Depth measured 15,416 feet Plugs measured N/A feet true vertical 9,414 feet Junk measured N/A feet Effective Depth measured 15,380 feet Packer measured 11,324&11,510 feet true vertical 9,410 feet true vertical 9,307'&9,411' feet Casing Length Size MD TVD Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13-3/8" 6,020' 5,092' 3,090 psi 1,540 psi Intermediate 9,761' 9-5/8" 9,761' 8,120' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4-1/2" 15,414' 9,410' Slotted Slotted Perforation depth Measured depth See Schematic feet SCANNED c 0 ryry I,11 True Vertical depth See Schematic feet SCANNED /APR 3 20!5 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 7,289'(MD) 6,097'(TVD) Packers and SSSV(type,measured and true vertical depth) Baker 85SAB-L47 11,324'(MD)9,307(TVD) Baker SL-ZXP 11,510'(MD)9,411'(TVD) 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: 301 86 8658 507 521 Subsequent to operation: 610 537 11675 100 101 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: 315-150 Contact Dan Taylor Email dtavlor(a�hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature Phone (907)777-8319 Date 4/28/2015 RBDMS { APR 2 9 1015 Form 10-404 Revised 10/2012 (Li‘- ‘r1/1-9,- — il' )3'n Submit Original Only 14 SCHEMATIC McArthur River Field, TBU Well: G-28RD IliIcorp Alaska.LLC As Completed: 03/30/15 RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL (\ ` SIZE WT GRADE CONN ID(in.) MD TOP MD BTM. 26" 'A"WT Spiral Weld 25.000 Surface 369' ti 20" 94 H-40 Buttress 19.125 Surface 828' 26"shoe ." 13-3/8" 61 K-55 Buttress 12.415 Surface 6020' ra 362 9-5/8" 47 N-80 Buttress 8.681 Surface 8922' 20"shoe 9-5/8" 47 5-95 Buttress 8.681 8,922' 9761' a'828Window 7" 29 L-80 Buttress 6.184 7471' 11700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11510' 15414' 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6 L-80 Hydril 503 3.958 _ Surface 7,289' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' JEWELRY NO _ Depth ID Item 1 81' 3.958" CIW-DCB-ESP Tubing Hanger:4-1/2"IBT Box Top&Btm 2 1 7,289' - Discharge,Bolt-On 3 7,291' - Pump(x2)45 Stg SH16000 2 - 4 7,329' - , Intake 3 5 7,345' - Motor(x2)BHI 725 HMIU r_,r_,_ 6 7,401' Centralizer/Anode 4 13-3/8"shoe 7A 7415' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 SPF n 6020' 5 78 8034' 3.833" 6 _ 7C 8578' 3.833" 7"TOL @ 7471' Z 7F7D 9086' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch USITIog 7E 9565' 3.833" (5.984"OD) 7C interpretation in 7F 9614' 3.833" 7D 9-5/8'casing at 7953' 7G 10036' 3.833" 1-111 7E 8 11323' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals 71-* 9 11324' 4.00" Baker Model 855AB-L47 x38 Hydraulic Set Permanent Packer with 6'mill out extension 9-5/8" I_ 7G 10 11365' 3.813" Otis"X"nipple(3.813") window 11 11367' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. *9761' I 91 12 11398' 3.958" Mule shoe 80 11 13 11510' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 14 I 11578' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) 4-1/2"TOL*,11,510' 12 13 7"shoe @ 11700' '1 14 Ii . Horizontal ported liner produces from Hemlock Benches 1,2,and 3 J L TD=15,416'; ETD=15,380' Updated by: ILL 04/28/15 N Hilcorp Alaska, LLC HileorpAlaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date G-28RD 50-733-20324-01 200-038 3/26/2015 3/30/2015 Daily Operations: 03/26/15-Thursday Install BPV.N/D tree.Prep hanger.Screwed 4 1/2 IBT sub into hanger good.N/U Riser. 03/27/15-Friday N/U BOPE.Installed scaffolding.Install flow nipple&flow line.R/u drip pan&floor.Test PVT system good.R/u tongs.M/u 41/2 tj. Filled stack&shell tested good. Install DS stairs,housekeeping. Test BOPE as per Hilcorp&AOGCC regulations.Witness by AOGCC inspector Bob Noble.Tested w/4 1/2 test jt,250 low,3000 high,annular 250 low,2500 high.All good. Pull TWC.M/U landing jt. PJSM,shut in drill. Back out I/d pins.Pull hanger t/floor,up wt 150 falling back t/145 dragging.Check penetrator.Disconnect cable& injection lines f/hanger. Attempt to set slips,unable to set not enough room for cable.Get larger set coming from beach.R/u clean pits,housekeeping. 03/28/15-Saturday Cont.clean pits. R/u slips,I/d hanger&landing jt.Cut lead splice off&test cable.POOH.Hang sheave&cable start on spooler. Cont. POOH racking back tubing.Armor on wire is corroded where it has been in contact w/tubular.POOH t/4,364',cut splice out at spool, meg line issue still downhole. Prep spooler to change out spools&found shaft broken.Bring out new spooler from beach&r/u. Cont.POOH,stand back 118 stands 4 1/2"L-80 HYD 503 tubing.Recovered 115 cannon clamps,3 splice clamps. L/D ESP assembly. Hand check rotation all components good.Found motor lead connection compromised. Recovered 26 motor clamps. Clean&clear floor.Prep r/u ESP assembly. 03/29/15-Sunday Cont.load cable&flat pack spools. P/U 7.25"Baker motor assembly&seals,w/Summit 6.75 pump assembly.Prepped&tested,all good.Tested injection lines&check valves t/2500. RIH w/4 1/2" 12.75#L-80 Hydril 503 tubing t/4,440',tq.connections t/4600, clamps every connection first 6 then every other,testing motor leads&inj lines every 1,000'. Swap out cable spools,splice cable& test good. Cont.RIH t/7,356'up wt 128,do wt 88. M/u hanger&landing jt.M/u injection lines t/hanger.M/u penetrator termination plug&test same,good. 03/30/15-Monday PTSM.Drain stack.Land hanger.Check motor leads w/umbilical cord,good.Run in L/D pins,set BPV.Fill hanger void&test t/5k, good. Remove rig floor panels.Pull flow nipple&drip pan.N/D BOP&riser. N/U tree.Install flow line,test tree void&neck seals t/5k good.Test Motor leads at penetrator,good,Pull DS stairs,roof panels.R/u jacks t/master skid.Prep dog house for removal. Pull dog house&ODS roof panels.R/U sub-base jacks,pull dog house&roof panels f/ODS.Loosen clamps on master skid,skid same west. R/d master skid jacks,secure clamps.R/d gas buster.Prep pump t/move.Remove mid landing f/DS.Install roof panels DS&ODS. Spot dog house DS.Tq master skid clamps. OF ��\\I%%i=s� . THE STATE Alaska Oil and Gas of/\ T , /� C�(T /� Conservation Commission ► - 1Z l I1�7 \1Z t itt=- 333 West Seventh Avenue OF ati, 0 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907 276.7542 www.aogcc.alaska.gov Dan Taylor , ,. t= 4 L.Ll:," Operations Engineer JOb �3 c Hilcorp Alaska, LLC ` 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Hemlock Oil Pool, TBU G-28RD Sundry Number: 315-150 Dear Mr. Taylor: 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, 02/21)- Cathy P. Foerster Chair DATED this-/491 .--lay of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 1 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 �y1 1.Type of Request: Abandon CI Plug for Redril❑ Perforate New Pod El Repair Wei( ""J 1�hange Approved Program CI Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing •3't' —' Time Extension❑ Operations Shutdowr❑ Re-enter Susp.Wel❑ Stimulate❑ Alter Casing I Other: Replace ESP 0 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development 0 • 200-038 • 3.Address: 3800 Centerpoint Drive,Suite 1400 StratigraphicService 6.API Number. ❑ ❑ Anchorage,Alaska 99503 50-733-20324-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? NIA Trading Bay Unit G-28RD Will planned perforations require a spacing exception? Yes ❑ No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 • McArthur River Field/Hemlock Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 15,416 - 9,414 $ 15,380 ' 9,410 . N/A N/A Casing Length Size MD ND Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13-3/8" 6,020' 5,092' 3,090 psi 1,540 psi Intermediate 9,761' 9-5/8" 9,761' 8,120' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4-1/2" 15,414' 9,410' (slotted) (slotted) Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic i See Attached Schematic 4-1/2" 12.6#L-80 7,261' Packers and SSSV Type: Baker 85SAB-L47 Packers and SSSV MD(ft)and ND(ft): , 11,324'MD(9,307'ND) Baker SL-ZXP;N/A . 11,510'MD(9,411'ND);N/A 12.Attachments: Description Summary of Proposa 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 _ Exploratory ❑ Stratigraphi❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 04/01/15 Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan Taylor Title Operations Engineer "7-1-1 i 4, - o,...„--/-14-4.-/-- Signature V`'l Phone (907)777-8319 Date 3/17/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -- 15— / 1£^ ' v Plug Integrity ❑ BOP Test ErMechanical Integrity Test ❑ LocationtiClearance ❑ 1 Other: 35.:�'S 'n JCS r - f�MA 5 f 2 7t!o 9 s.: ) Spacing Exception Required? Yes ❑ No Ei/ Subsequent Form Required: /0 Li di A`f THERO ED BY 3 / .1 /� Approved by COMMISSIONER THE COMMISSIONS Date: l ye, 3 IS ')-1" -(M _Vial ��'2,G 31�i fil,4 3-/1-4S ogialcuAL Suborn Fon i and Form 10-403(Revised 10/2012) for 12 months from the date of approval. \attachments in Duplicate RBDMS APR - 2 2015 .11 Well Prognosis Well: G-28RD Hilcorp Alaska,LL Date:3/17/2015 Well Name: G-28RD API Number: 50-733-20324-01 Current Status: ESP Producer Leg: 3 Estimated Start Date: April 1,2015 Rig: Moncla 301 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 200-038 First Call Engineer: Dan Taylor (907)777-8319(0) (907)947-8051 (M) Second Call Engineer: James Young (907)777-8404(0) AFE Number: Current Bottom Hole Pressure: 3,750 psi @ 9,600ft ND (mid perf of 13,500ft MD) Maximum Expected BHP: 3,750 psi @ 9,600ft ND (mid perf of 13,500ft MD) Max.Allowable Surface 2,790 psi Based on 0.1 psi/ft gas gradient to Pressure: surface. Brief Well Summary G-28RD is a Hemlock producer that was converted to an ESP from a gas-lift completion in April 2011 and converted once again to a ESP completion in 2014. The ESP experienced a down hole failure March 16, 2015. The plan forward is to pull the current completion and re-run another ESP. 4 Procedure: 1. Bleed off well. 2. Identify fluid level. 3. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, rig up e-line and run in hole to punch tubing. 4. Set back pressure valve, nipple down well head and nipple up BOP's. a. Notify AOGCC 48hrs in advance of test to allow time to witness. `-- 3' "`r ' `'' 5. Pull out of hole with ESP pump laying down the same. 6. Pick up and run in hole with ESP completion. 7. Land hanger,set back pressure valve and test. 8. Nipple down BOP's, nipple up tree and test. 9. Turn well over to production. 10. Complete a surface safety valve test and'no flow' est in compliance with AOGCC regulations. a. See 20 AAC 25.265.Well safety valve systems. / r Ahr F"' v,1 re Attachments: "� f 7 L 1. As-built Well Schematic 2. Proposed Well Schematic 3•/)' 'j 3. Current Well Head 4. BOP Stack 5. Rolling Test Procedure II McArthur River Field, TBU Well: G-28RD Ilih.orpAlaska.1.1,C As Completed: 02/10/2014 RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL I / SIZE WT GRADE CONN ID(in.) MD TOP MD BTM. 26" A"WT Spiral Weld 25.000 Surface 369' / 20" 94 H-40 Buttress 19.125 Surface 828' "shoe 13-3/8" 61 _ K-55 Buttress 12.415 Surface 6020' 0,369 . . 9-5/8" 47 N-80 Buttress 8.681 Surface 8922' 20"shoe 9-5/8" 47 S-95 Buttress 8.681 8,922' 9761' *828' . Window 7" 29 _ L-80 Buttress 6.184 7471' 11700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11510' 15414' 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6 L-80 _ Hydril 503 3.958 Surface 7,261' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' JEWELRY NO Depth ID Item I 1 81' 3.958" CIW-DCB-ESP Tubing Hanger:4-1/2"IBT Box Top&Btm 2 7,261' Discharge Head 3 7,261' - Pump(x3) 24 7,322' - ESP Intake 3 5 _ 7,341' - ESP Motor(x2) 4III 6 7,406' GLM Anode 13-3/8"shoe _ *6020' 7A 7415' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 SPF 5 in-- 7B 8034' 3.833" 6 7C 8578' 3.833" 7"TOL @ 7471' --L ig 7D 9086' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch USIT log 7E 9565' 3.833" (5.984"OD) 7C interpretation shows hole in 7F 9614' 3.833" 7D 9-5/8"casing at 7953' 7G 10036' 3.833" 7E 8 11323' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals 7E� 9 11324' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent Packer with 6'mit out extension 9-5/5" 7G 10 11365' 3.813" Otis"X"nipple(3.813") "1011"` 11 11367' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. 4i 9761' j9 12 11398' 3.958" Mule shoe 8 11 13 11510' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 10 14 11578' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) 4-1/2"TOL @ 11,510' 12 g 13 7"shoe @ 11700' 14 Horizontal ported liner produces from Hemlock Benches I, 2,and 3 J L TD= 15,416'; ETD=15,380' Updated by: JLL 02/11/14 II PROPOSED McArthur River Field, TBU Well: G-28RD HaeorpAlaska.LLC As Completed: Future RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL 1\ I SIZE WT GRADE CONN ID(in.) MD TOP _ MD BTM. 26" %"WT _ Spiral Weld 25.000 Surface _ 369' / 20" 94 _ H-40 Buttress 19.125 Surface _ 828' 'h"`' 13-3/8" 61 _ K-55 Buttress 12.415 Surface _ 6020' t 369...Z. : a 9-5/8" 47 _ N-80 Buttress 8.681 Surface _ 8922' 211.hire 9-5/8" 47 S-95 Buttress 8.681 8,922' 9761' a 828' Window 7" 29 L-80 Buttress 6.184 7471' 11700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11510' 15414' 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6 Hydril 503 e ±7,250' • 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' JEWELRY NO Depth ID Item 1 81' 3.958" CIW-DCB-ESP Tubing Hanger:4-1/2"IBT Box Top&Btm !Iliml‘i 2 Bottom of ESP G ,,., . 13-3/8".hne a 11211. 7A7B 8034'7415' 3.9583.833"" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 SPF a 7C 8578' 3.833" 7"T01 a 7471' _ "aim7F7D . 9086' _ 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch USIT log 7E 9565' 3.833" (5.984"OD) iiiii 7,-. interpretation shows hole in 7F 9614' 3.833" L- 7E 9-5/8"casing at 7953' 7G 10036' 3.833" LIMINMI 7E 8 11323' 4.00" Baker KBH-22 Anchor.with 1'of nitrile seals / L_ 7l-'' 9 11324' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent Packer with 6'mill out extension 9-5/8" 7G 10 11365' 3.813" Otis"X"nipple(3.813") window 11 11367' 3.958" 1 joint 4-1/2"12.6 lb/ft L-80 Mod Butt Tbg. na 9761' 9 12 11398' 3.958" Mule shoe 8 11 13 11510' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 10 14 11578' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) 4-1/2"TOL(011,510' 4 12 lig 13 7"shoe Q 11700' ' 1 14 I Horizontal ported liner produces from Hemlock Benches I,2,and 3 zl L TD=15,416'; ETD=15,380' Updated by: ILL 03/17/15 Grayling Platform G-28RD ESP Ffik+p ALA..LLC Grayling 28RD BHTA, 4 1/16 5M FE X Tubing hanger, CIW- 20 X 13 3/8 X 9 5/8 X 7" Bowen top DCB-ESP, 11 X 4 '/z IBT 4 1/2 lift and susp, w/4" type H BPV profile, 5 IA EN, in Mi1 ,I, 2- 3/8 continuous control line ports, Valve, swab, VG-200, ':,pm. , prepped for BIW 4 1/16 5M FE, HWO, e S- 1( penetrator T-24 _, • 1 o 4) Cross, stdd, 4 1/16 5M 000 X41/165MX21/16 �.� 1.1 5M �I Valve, wing, WKM-M, i IPI- 1. -t 2 1/16 5M FE, HWO, ',,\..330. III °. T-24 0® i. SI 0 ® Valve, lower master, Al VG-200, 4 1/16 5M FE, O V O HWO, T-24 Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped 1' for 5 ' ESP neck, 2- % npt continuous control line ports ■ Tubing head, CIW-DCB, -��° a_ ■ °!" 13 5/8 3M X 11 5M, w/ in in 2- 2 1/16 5M SSO, X- ® • '- ' ® Valve, WKM-M, 2 1/16 5M bottom prep, •1 i� :ai o—,� M■ a10 �I �� i•°I 1 '/z VR profile I _ o`-;1� o�� FE, HWO, DD o« Qty 2 In I in 1.1 ;,rte± Casing spool, CIW-WF, :I, 21 %2M X 13 5/8 3M, .1 iii w/2 2 1/16 5M EFO, ' II _ .r %OoiI .' Ii�o/, � . ValveIW263M mrepI1 ;' FE, HWO, AA 1.1 CI ilium - Casing head, CIW-WF, in I$ 4" ll ) . Valve, CIW-F, 2" LPO, bio f HWO, AA ci Grayling Platform BOP Stack (Moneta 301) , 0 0 num iii iii iii iii I I iii 3./4' Shaffer 13 5/8 5M ii ii 111111P uti-J111,1; i ' _ 411 aw-u 41111111M © Dual Flex 3-1/2 X 3-1/2 4.67' • 13 S/8-5000 Blind Rams Si Jtti ail rtfi[f� tit lChoke and Kill Valves 2 1/16 5M w/Unbolt connections for hoses . IlDFIBRIIRUFTV 2.00' 1 f I, �` 13 5/8-5000 J4 111111.111 It' Ili ill ill iii 110 Riser,13 5/8 5M FE X 13 5/8 5M API#13 huh 13.70' Moncla 301 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Moncla 301, Grayling Platform 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 Wellheadl 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. 2) 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 - n Moncla 301 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 3) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 4) 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 1 jt.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,and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 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. 3) Test all Rams and Valves 1) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 2) 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. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_- 0,..~ ~' Well History File Identifier / [3/ Color items: [;ax' Diskettes, No./ [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES:7 ? NOTES: ORGANIZED BY; BEVERLY BRE~HERYL MARIA LOWELL [] Other DATE:/~.,,. / Project Proofing PROOFED BY: BEVERLY BRE~HERYL MARIA LOWELL DATE: [] Staff Proof By: Date: Isl ~ Scanned (done) PAGES: (at the time of scanning) SCANNED BY; BEVERLY ~VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: QuaLity Checked (done) Rev1 NOTScanned.wpd or \ i//7,. ",t� THE STATE Alaska Oil and Gas 1, °fALASKA C a nservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op .m P Anchorage, Alaska 99501-3572 ALAS" Main: 907.279.1433 Fax: 907.276.7542 SC�►�H�° Dan Marlowe 6 7014. Operations Engineer 03T Hilcorp Alaska, LLC 0 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit G-28RD Sundry Number: 313-646 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. Sincer,ly, ��oner Co ><ss><oner DATED this day of December, 2013. Encl. • s A \ STATE OF ALASKA ;-- i- ALASKA OIL AND GAS CONSERVATION COMMISSION ��t C �� APPLICATION FOR SUNDRY APPROVALS (� 20 AAC 25.280 , '"'" 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WC Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ PuN Tubin[] Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casin[] Other. Pull&Replace ESP ❑✓ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 . 200-038- 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. • Anchorage,Alaska 99503 50-733-20324-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Trading Bay Unit G-28RD Will planned perforations require a spacing exception? Yes ❑ No 2❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 McArthur River Field/Hemlock Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 15,416 • 9,410 15,380 ' 9,414 N/A N/A Casing Length Size MD ND Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13-3/8" 6,020' 5,097 3,090 psi 1,540 psi Intermediate 9,761' 9-5/8" 9,761' 8,120' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4-1/2" 15,414' 9,410' (slotted) (slotted) Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#N-80 7,284' Packers and SSSV Type: Baker 85SAB-L47 Packers and SSSV MD(t)and TVD(ft): • 11,324'MD(9,30T ND) Baker SL-ZXP;N/A - 11,510'MD(9,411'ND);N/A 12.Attachments: Description Summary of Proposal ❑✓ % 13.Well Class after proposed work: Detailed Operations Program [] BOP Sketch n , Exploratory n Stratigraphin Development n . Service [] 14.Estimated Date for 15.Well Status after propsed work: 12/30/13 Commencing Operations: Oil Q , Gas 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe 907-283-1329 Email DMarlowechilcorp.com Printed Name Dai • e Title 2perations Engineer -- -- .�� , - -�r- Signature „..- • I - Phone 907-283-1329 Date ‘1_17..i.42,0 VS COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -.7k3 - C.L.` (k_ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 80P -t,es± , 3000 rs t RBDMS ist4AY U 9 2014 Spacing Exception Required? -- E 1• E Subsequent Form Required: , APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �y / RIG A �� 4a�lo Submit Form and Form 10-403(Revised 10/2012) ppr.e. it4d Jam'$ aonths from the date of approval. Attachments in Duplicate v1.rI /?6113 !!�� L� 14 Well Work Prognosis Well: G-28RD Date: 12/26/2013 Hileorp Alaska,LLC Well Name: G-28RD API Number: 50-733-20324-01 Current Status: ESP Producer Leg: Leg#3 (SE corner) Estimated Start Date: Dec 30, 2013 Rig: Moncla Rig 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 200-038 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: -3,750 psi @ 9,600' ND (mid pert of 13,500' MD) Maximum Expected BHP: -3,750 psi©9,600'ND (No new perfs being added) Max.Anticipated Surface Pressure: 0 psi (Using 0.435psi/ft.to surface) M so 5,19 Ze) ys � Brief Well Summary "'1 G-28RD is a Hemlock Producer that was converted to anil ESP from a gas-lift completion in April 2011. The ESP experienced a down-hole electrical failure December 24, 2013. We plan to pull and replace the ESP. No perforations will be added. / Procedure: 1. MIRU Moncla 404 Pulling Unit. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+1-7,250'and punch tubing. --A3360(2p.5 3. ND Wellhead,NU BOP and test to 250psi low/2, psi 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+/-7,400'. 7. ND BOP,NU wellhead and test. 8. Turn well over to production. 9. RDMO Moncla 404 Pulling unit. 10. Schedule an AOGCC witnessed No-Flow within two weeks of returning well to production. Attachments: 1. Current Well Schematic 2. Current Wellhead Diagram 3. Proposed Well Schematic 4. Proposed Wellhead Diagram 5. BOP Drawing _ ti McArthur River Field, TBU Well: G-28RD Hileorp:tlaska.1,1,E As Completed: 4/27/11 RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL I\ / L 1: SIZE WT GRADE CONN ID(in.) MD TOP MD BTM. 26" i"WT Spiral Weld _ 25.000 Surface 369' / 20" 94 H-40 Buttress 19.125 Surface 828' shoe 13-3/8" 61 K-55 Buttress 12.415 - Surface 6020' 9-5/8" 47 N-80 Buttress _ 8.681 _ Surface 8922' 20"shoe 9-5/8" 47 S-95 Buttress 8.681 8,922' 9761' @ 82x• Window 7" 29 L-80 Buttress 6.184 7471' 11700' 4-1/2" 12.6 N-80 Ilydril 511 3.958 11510' 15414' j`� 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 11 4-1/2"8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6/12.75 L-80 Hydril 503/563 3.958 Surface 7,284' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' 211 L1111111 JEWELRY NO Depth ID Item 1 81' 3.958" CIW-DCB-ESP Tubing Hanger:4-1/2"IBT Box Top&Btm 2A 2552' 3.833" SFO-2 GLM#1 2B 4276' 3.833" SFO-2 GLM#2 2C 2C 5522' 3.833" SFO-2 GLM#3 2D 6250' 3.833" SFO-2 GLM#4 L tD2E 6827' 3.833" SFO-2 GLM#5 13-3/8"shoe 3 7165' 3.813" Sliding Sleeve Baker CMD @6020' 4 7224' 3.725" XN-Nipple Baker HNB 4A 7284' - ESP Assembly(Top) 7"TOL @ 7471' 7__ A 45g 4B 7322' - ESP Intake IMMO USIT log 4C 7376' - Bullnose Centralizer(Bottom) 5C interpretation shows hole in 5A 7415' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 SPF—__ 5D 9-5i8"casing at 5B 8034' 3.833" 7953' mom5E 5C 8578' 3.833" SF. . 5D 9086' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/1"BK-2 Latch 5E 9565' 3.833" (5.984"OD) 9-5/8"window 5G @ 9761' 5F 9614' 3.833" 5G 10036' 3.833" . 8 5 11323' 4.00" Baker KBH-22 Anchor.with 1' of nitrile seals 6 11324' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent 4-1/2"TOL @ 11,510' I . g 1(1 Packer with 6' mill out extension 7"shoe @ 11700' I I 7 11365' 3.813" Otis"X" nipple(3.813") �8 11367' 3.958" 1 joint 4-1/2" 12.6 lb/ft L-80 Mod Butt Tbg. 9 11398' 3.958" Mule shoe 10 11510' 4.438" Baker SL-ZXP Liner Packer with 10'tie-back extension 11 11578' 3.813" Otis"X" nipple(set in the 4-1/2"production liner) horizontal ported liner produces from Hemlock Benches 1,2,and 3 41 L TD= 15,416'; ETD=15,380' REVISED: 5/23/2011 DRAWN BY:NM/RMS Grayling Platform 11 G-28RD ESP 05/02/2011 Hik.pAlaska,LIC Grayling 28RD BHTA, 4 1/16 5M FE X Tubing hanger, CIW- 20X 133/8X95/8X DCB-ESP, 11 X4 '/% IBT 7" Bowen top 4 1/20 lift and susp, w/4" type H BPV profile, 5 V. EN, ,,, ,,, 2- 3/8 continuous , control line ports, Valve, swab, VG-200, prepped for BIW 4 1/16 5M FE, HWO, r-0 ® penetrator T-24 gm( o Cross, stdd, 4 1/16 5M COO X41/165MX21/16 ... ... 5M Valve, wing, WKM-M, ? 7 2 1/16 5M FE, HWO, i (.01oll 111 O T-24 E n ' -� i. 0 0, Valve, lower master, 1-.41( VG-200, 4 1/16 5M FE, ti*--;() HWO, T-24 1•1111111111.•. IIMIIIN "' lei Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped - [i• Stdd 5 1/4 ESP neck, 2- '/2 npt lif-lmi continuous control line ports —•ice._ Tubing head, CIW-DCB, =411I Din 135/83MX115M, w/ ili 1 III 2- 2 1/16 5M SSO, X- • o 11 N– t-, _3_\3111 o ? - z' Valve, WKM-M, 2 1/16 5M bottom prep, -.i-i■I ..'olo � i■ � ��31 I -i,l FE, HWO, DD 1 'h VR profile _ oo . ° os_ - Qty It! • III Casing spool, CIW-WF, III .1' 211/42MX135/83M, l•i r _11114111,11b . w/2- 2 1/16 5M EFO, 11. 11� lValve, CIW-F, 2 1/16 3M X-bottom re 410 I� ° ° :!I: FE, HWO, AA p p i. 111111 t Casing head, CIW-WF, ,I, fin a., ili 21 1/42M X 20 SOW, w/2 2" LPO, ��' °/,o j 4. 41 Valve, CIW-F, 2" LPO, __ oma, HWO, AA II McArthur River Field, TBU Well: G-28RD Hileorp Alaska,LIT Completed: Proposed RKB=42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL A / SIZE WT GRADE CONN ID(in.) MD TOP ; MD BTM. 26" i"WT Spiral Weld 25.000 Surface 369' 20" 94 H-40 Buttress 19.125 Surface 828' shoe 13-3/8" 61 K-55 _ Buttress 12.415 Surface , 6020' 9-5/8" 47 N-80 _ Buttress 8.681 Surface 8922' 20"shoe 9-5/8" 47 S-95 Buttress 8.681 8,922' 9761' @ 828' Window _ 7" 29 L-80 Buttress 6.184 7471' 11700' 4-1/2" 12.6 N-80 Hydril511 3.958 11510' 15414' 4-1/2"pre-slotted liner has 48 slots/ft 2-1/2"x 1/16" 4-1/2"8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6/12.75 L-80 Hydril 503/563 3.958 Surface +/-7,284' 4-1/2" 12.6 L-80 Mod Butt. (SPC) 3.958 7,415' 11,398' JEWELRY NO Depth II) Item 1 81' 3.9.58" CIW-DCB-ESP Tubing Hanger:4-1/2" IBT Box Top&Btm 2 +/-7,284' - ESP Assembly(Top) 3 +/-7,322' - ESP Intake 4 +/-7,376' - Bullnose Centralizer(Bottom) 13-3/8"shoe _ 5A 7415' 3.958" 4-1/2"tubing cut stub(tubing punched 7416'-7422'w/2 S_PF rai 6020' 5B 8034' 3.833" 5C 8578' 3.833" 7"TOL rai 7471' 5D 9086' 3.833" 4-1/2"Camco KBG-2 SPC GLM w/ I" BK-2 Latch USIT log 5E 9565' 3.833" (5.984"OD) 5C interpretation 5F 9614' 3.833" shows hole in 9-5/8"casing at 5G 10036' 3.833" SD �9ss 5 11323' 4.00" Baker KBH-22 Anchor.with 1' of nitrile seals 111111111110 _SE 6 11324' 4.00" Baker Model 85SAB-L47 x38 Hydraulic Set Permanent 5F'' Packer with 6' mill out extension 9-5/8" LIMN. 5G 7 11365' 3.813" Otis"X" nipple(3.813") window 8 11367' 3.958" 1 joint 4-1/2" 12.6 lb/ft L-80 Mod Butt Tbg. I6 9 11398' 3.958" Mule shoe 1 8 10 11510' 4.438" Baker SL-ZXP Liner Packer with 10' tie-back extension 4-1/2"Tot 11,510' 9 11 11578' 3.813" Otis"X"nipple(set in the 4-1/2"production liner) j � 10 7"shoe @ 11700' L I 11 Horizontal ported liner produces from Hemlock Benches 1,2, and 3 I L TD= 15,416'; ETD=15,380' REVISED: 12/26/2013 DRAWN BY: DEM .. , 14 Grayling Platform G-28RD ESP 2013 Proposed M Grayling 28RD BHTA, 4 1/16 5M FE X Tubing hanger, CIW- 20 X 13 3/8 X 9 5/8 X 7� Bowen top DCB-ESP, 11 X 4 '/2 IBT 4 1/20 lift and susp, w/4" type H BPV profile, 5 1/4 EN, ,,, ,�, 2- 3/8 continuous control line ports, Valve, swab, VG-200, it 0 oca, prepped for BIW 4 1/16 5M FE, HWO, ` ® � penetrator T-24 m/ o Cross, stdd, 4 1/16 5M 0$-.....-- X41/165MX21/16 11. ..1 5M i_ Valve, wing, WKM-M, ? j� r .I 2 1/16 5M FE, HWO, `°1o)I 1II ©p T-24 - '_ : I e Valve, lower master, i:( °°') VG-200, 4 1/16 5M FE, 0`c-j0 HWO, T-24 •• Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped - for 5 '/4 ESP neck, 2- '/2 npt I C continuous control line ports Tubing • head, CIW-DCB, -'r° l I 13 5/8 3M X 11 5M, w/ isi I tri. 2- 2 1/16 5M SSO, X- © o o iiii ValveKMM, 21165M bottompep, I■'� ODlei illi ice;: Casing spool, CIW-WF, 5III M FE21 %2MX135/83M "� w/2- 2 1/16 5M EFO, ilt I , =III 'I / o1 Valve, CIW-F, 2 1/16 3M X-bottom prep I'�: FE, HWO, AA les . lel .4111111111111. r'*WI - Casing head, CIW-WF, ,,I U I ,�,21 '/4 2M X 20 SOW, w/2 2" LPO, I-■V /4o��,•i•,)c) Valve, CIW-F, 2 LPO, HWO, AA Grayling Platform Williams Rig BOP (rental) 1/18/2013 n.+... . v I I1 Grayling Platform 2013 Workovers BOP Drawing(Williams) 111 ISI owe(II/ I Iii lir rii i 1- 3.42' Shaffer 11"5M lel III III lel 1.1 4.54' t. --I' ta � C8U •' bOf1!E1S on b01i, a1: ii 1.!il rir I I Kill Side 2 1/16 5M w/check valve • �I I�I1i1 Ii. ISI. Choke side 2.00' y. { } {�+- ( �•»f �i� 21/165Mw/HCR and and Uniboltline , I ;r `_ .; , IIQI connection IrlLui�ulil:l.1 I Unibolt line connection 1.00'to 2.00' ,,,I• Drill deck Riser 11 5M FE X 16.00' 11 5M FE Iii laid, it 1 lel Itl III Spacer spool 3.00' 11 5M FE X 11 5M FE sI Ii1111111 i1 Gn.fG4- STATE OF ALASKA a r f z, t 1 Z.a t i ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Abandon U Repair Well U Plug Perforations U Stimulate U Other Lf Convert to ESP Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 200 -038 '" / 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20324 -01 — 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 (Grayling Platform) ,- TRADING BAY UNIT G -28RD 9. Field /Pool(s): MCARTHUR RIVER FIELD / HEMLOCK OIL POOL 10. Present Well Condition Summary: Total Depth measured 15,416 feet Plugs measured - feet true vertical 9,410 feet Junk measured - feet Effective Depth measured 15,380 feet Packer measured 11,324 & 11,510 feet true vertical 9,414 feet true vertical 9,307 & 9,411 feet Casing Length Size MD / TVD Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13 -3/8" 6,020' 5,092' 3,090psi 1,540psi Intermediate 8,922' 9 -5/8" 8,922' 7,435' 6,870psi 4,750psi Production 4,229' 7" 11,700' 9,519' 8,160psi 7,030psi Liner 3,904' 4 -1/2" 15,414' 9,410' (slotted) (slotted) Perforation depth Measured depth 11,700' to 15,414' (slotted liner) / AAhlightd JUN 41 MI True Vertical depth 9,519' to 9,410' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6/12.75# L -80 11,398' 9,349' Packers and SSSV (type, measured and true vertical depth) Baker 85SABOL47 Packer 11,324' MD (9,307' TVD) Baker SL -ZXP Packer 11,510' MD (9,411' TVD) 11. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): Q�� N/A MAY 3 Treatment descriptions including volumes used and final pressure: N/A Alaska Oil & Gas CM. CIm issio t 12. Representative Daily Average Production or Injection Data f , p Oil -Bbl Gas -Mcf Water -Bbl "' q uasi sing Pressure Tubing Pressure Prior to well operation: 325 131 5185 1240 110 Subsequent to operation: 620 250 10,780 105 108 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory0 Development El - Service ❑ Stratigraphi❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ` IO Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 16. 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: 311 -036 Contact David Ross 263 -7696 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature —" ■. ( / Phone 276 -7600 Date 5/27/2007 A 1 Form 10 -404 Revised 10/2010 = DMS MAY 1 � Submit Original Only 3 10 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G -28RD TRADING BAY UNIT G -28RD ADL0017594 5073320324 QM5869 42.00 125.00 • Jobs Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion - Reconfigure Major Rig 4/15/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number G -28RD 507332032401 2000380 Daily Operations 4/15/2011 00:00.4/16/2011 00:00 Operations Summary Prepare to skid HWO unit, skid rig to G -28RD, continue R/U. 4/16/2011 00:00 - 4/17/2011 00:00 Operations Summary Continue R/U. R/U slick -line and RIH w/ 3.85" GR to 268', POOH, RIH w/ 2.75" Permanent Lock Out Tool and lock out the TRSSSV, POOH with setting tool. M/U 2.31" gauge swedge and RIH to TRSSSV to confirm the valve is open. No restrictions encountered, POOH and M/U a 3.05" gauge tool. RIH to 11,580', with no indication of fluid level, POOH R/D slick -line, R/U a -line. 4/17/2011 00:00 - 4/18/2011 00:00 Operations Summary RIH w/ 1- 9/16" x 6' tubing punch, correlate with CCL and punch tubing from 11,306' to 11,312', POOH and UD tools all shots fired. R/U to kill well, circulated well to 3% KCI. Pumped salt pill and displaced w /3% KCI loss rate slowed. Pumped another salt pill and displaced w/ KCI. 4/18/2011 00:00 - 4/19/2011 00:00 Operations Summary Monitor losses, hole taking fluid, mix and pump salt pill, well still taking fluid. Set BPV and N/D tree. N/U BOPs , losses reduced. M/U 4" test joints and attempt to screw into tubing hanger. Troubleshoot problem with tubing hanger threads. Notify AOGCC about upcoming BOP test. 4/19/2011 00:00.4120/2011 00:00 Operations Summary Replace test jt. crossover to 4 1/2" 8 rd and screw into tubing hanger. Test annular to 250/2500 psi (Failed Test) Test UPR VBR to 250/3500 psi low test passes high test failed. Identified cut seal on two way check and replaced same. Re -test annular (Failed Test) Pulled test joint and prepare to test blinds. Identified tubing hanger seals leaking. Packed hanger seals and test blinds to 250/3500 psi and chart 5 mins (Good Test), Test annular to 250/2500 psi ---- (Good Test) Test UPR & LWR VBRs, Manual Kill Valve, Choke side HCR, Manual Choke Valve, 4" FOSV & IBOP and choke manifold to 250/3500 psi. Chart all test for 5 mins. (Good Tests). Bob Noble with AOGCC waived witness of BOP test at 08:10, 4 -17 -11 4/20/2011 00:00 - 4/21/2011 00:00 Operations Summary Continue BOP test. Test UPR & LWR VBRs w/ 4 1/2" pipe, main kill and choke line, IBOP and TIW #2 to 250/3500 psi (Good Tests), Perform accumulator test, system pressure 2900 psi, after closing all pipe rams and opening one ram 1400 psi remained. Turned on charge pump built 200 psi in 10 secs. and up to 2900 psi in 3 mins 40 secs. R/D test equipment, pull TWC and install 4 1/2" landing jt. R/U a -line pull 115K on tubing, P/T lubricator to 250/3500 psi (Good Test) RIH w/ 6' , 23 hole tubing punch and punch holes from 7416-7422' , POOH. P/U 2 1/2" radial torch cutter and RIH and cut tubiing at 7415', good indication of cut, POOH and R/D a -line. UD hanger and begin pulling tubing to 6523' 4/21/2011 00:00 - 4/2212011 00:00 Operations Summary Continue pulling 4 1/2" tubing and UD same. P/U 9 -5/8" wellbore cleaning BHA and TIH breaking circulation at 2882' and 5955' for 10 mins. Continue TIH to 7272' 4/22/2011 00:00 - 4/23/2011 00:00 Operations Summary Continue TIH w/ cleanout assembly to 7366', pump a viscous sweep and CBU. Short trip to 6803' and back to 7366'. Pump a viscous sweep and circulate w/ 3% KCI. Wash down to 7431' and swallow tubing stub. Slack off to 7439' w/ 5K down. R/U slick line and PT lubricator to 250/2500 psi, RIH w/ a 2" GR and tag fill at 11,514' POOH. Close annular and perform injection test. M/U 2" S/L bailer and RIH , tag fill at 11,926' , take sample and POOH. Pump a salt pill followed by 3% KCL. H2S alarm went off, discover CO triggered alarm. Circulate well w /3% KCL, at midnight CO level at 230, 14% LEL and 0 H2S. 4/23/201100:00 - 4/24/2011 00:00 Operations Summary Continue circulating well w /3% KCI until CO level dropped to 35 -50 ppm. Swallow stub and squeeze 30 bbls of salt into liner. Open annular and circulate 3% KCL. TOH while UD DP and cleanout BHA. Pull wear bushing , start to break out DP stands and UD singles. 4124/2011 00:00 - 4/25/2011 00:00 Operations Summary Continue to UD DP and DCs. Spot ESP equipment and prepare to run ESP assembly. 4/25/2011 00:00 - 4/26/2011 00:00 Operations Summary Continue to service ESP assembly to RIH. Service MEL cable. 4/26/2011 00:00 - 4/27/2011 00:00 Operations Summary Finish servicing cable and ESP assy. RIH ESP with 4 -1/2" 12.75# L -80 Hydril 503 tubing to 5240'. Chevron • • • mio Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface WM ChevNo Original RKB (ft) Water Depth (ft) G -28RD TRADING BAY UNIT G -28RD ADL0017594 5073320324 QM5869 42.00 125.00 Daily Operation 4/27/2011 00:00 - 4/28/2011 00:00 Operations Summary Continue RIH ESP assembly with 4 -1/2" 12.75# L -80 Hydril 503 tubing and GLM's from 5240'. Land tubing hanger and completion with bull nose bottom of ESP assembly at 7376'. ND BOPE. Sent notification to AOGCC on H2S detection by rig sensor. 4/28/2011 00:00 - 4/29/2011 00:00 Operations Summary Continue to N/D BOPE and R/D Cudd HWO 136. Work on connecting flow lines, P/T bonnet and seals to 5000 psi for 30 mins (Test OK), Remove BPV and install TWC and test tree to 250/5000 psi (Test OK). Continue to R/D HWO and prepare for de -mobe. ' • • Chevron GRAYLING PLATFORM WELL G -28RD UNOCAL 76 ESP Completion (04 -27 -2011) RKB = 42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL A T SIZE WT GRADE CONN ID (in.) MD TOP MD BTM. 26" 'A" WT Spiral Weld 25.000 Surface 369' 20" 94 11-40 Buttress 19.125 Surface 828' 26 "shoe 13 -3/8 61 K -55 Buttress 12.415 Surface 6020' @ 369' 9 -5/8" 47 N -80 Buttress 8.681 Surface 8922' zo" shoe 9 -5/8" 47 S -95 Buttress 8.681 8,922' 9761' @ 828' Window 7" 29 L -80 Buttress 6.184 7471' 11700' 4 -1/2" 12.6 N -80 Hydri1 3.958 11510' 15414' 2A 4 -1/2" pre - slotted liner has 48 slots /ft 2 -1/2" x 1/16" 4 -1/2" 8 hpf at 90 deg phasing Tubing: 4 -1/2" 12.6/12.75 L -80 Hydril 503/563 3.958 Surface 7,284' 4 -1/2" 12.6 L -80 Mod Butt. (SPC) 3.958 7,415' 11,398' 2B L JEWELRY NO Depth ID Item 1 81' 3.958" CIW- DCB -ESP Tubing Hanger: 4 -1/2" IBT Box Top & Btm 2A 2552' 3.833" SFO -2 GLM #1 2B 4276' 3.833" SFO -2 GLM #2 2C 2C 5522' 3.833" SFO -2 GLM #3 L- 2D 6250' 3.833" SFO -2 GLM #4 L. 2D 2E 6827' 3.833" SFO -2 GLM #5 13 -3/8" shoe 3 3 7165' 3.813" Sliding Sleeve Baker CMD 6020' 4 4 4 7224' 3.725" XN- Nipple Baker HNB 4B 4C 4A 7284' - ESP Assembly (Top) 7" TOL @ 7471' Z JA <, '2" 4B 7322' - ESP Intake IMIIIr USITIog 4C 7376' - Bullnose Centralizer (Bottom) SC Interpretation shows hole in 5A 7415' 3.958" 4 -1/2" tubing cut stub (tubing punched 7416' -7422' w/2 SPF 5D 9-5 /8"casing at 5B 8034' 3.833" Ill 7953' 5E 5C 8578' 3.833" iiimm 51-' 5D 9086' 3.833" 4 -1/2" Camco KBG -2 SPC GLM w/ 1" BK -2 Latch 9 -5/8" 5G 5E 9565' 3.833" (5.984" OD) window 5F 9614' 3.833" • 6 56 10036' 3.833" El 8 5 11323' 4.00" Baker KBH -22 Anchor. with 1' of nitrile seals 6 11324' 4.00" Baker Model 85SAB -L47 x38 Hydraulic Set Permanent 4 -1/2" TOL @ 11,510' ' s ,. io Packer with 6' mill out extension 7" shoe @ 11700' 11 7 11365' 3.813" Otis "X" nipple (3.813 ") 8 11367' 3.958" 1 joint 4 -1/2" 12.6 lb/ft L -80 Mod Butt Tbg. 9 11398' 3.958" Mule shoe 10 11510' 4.438" Baker SL -ZXP Liner Packer with 10' tie -back extension 11 11578' 3.813" Otis "X" nipple (set in the 4 -1/2" production liner) horizontal ported liner produces from Hemlock Benches 1, 2, and 3 41 L TD = 15,416'; ETD = 15,380' REVISED: 5/23/2011 DRAWN BY: NM /RMS (DOA) Ponelof2 �� --"- • �� Regg, James �� (DOA) - _ - �g� �� From: 8onne�.Nigel (Nige|�8onn��)[Nigo|�Bonno��oh�vnon�oomnl 6��/` '_ ` - - ~-- ` ' ^ ~~ ^ �+u�Y `\ � (^ Sent: Wednesday, April 27.3O11 5:11 PM To: Regg, James B (DOA) Co: Bnandanbuq], Tim C; Hammons Jr, Darrell James; Hauck, Shane R; DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC Notification of H2S Detection by Rig Sensor Mr Regg, We do believe the rig system has been seeing short duration H events, but these have dissipated by the time they are checked with handheld monitors. Since the first event we have watched the trip tank monitors during surface fluid transfer. This morning we have seen another event, that rose up to 24 ppm, ^,^ thenimnnediate|ydpopped.VVevviUoendyounodficationonthatuhort|y. We are also investigating the CO events, which we believe to be true. We have also discounted cross sensitivity from CO affecting the H monitors. Rgds, From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wed April 27, 2011 2:39 PM To: Hauck Shane R Cc: Brandenburg, Tim C; Bonnett, Nigel (Nige|.Bonnett); Hammons Jr, Darrell James; DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC Notification of H2S Detection by Rig Sensor Please explain why the H2S detectors are triggering an alarm when there is no H2S present (based on your statement of handheld readngs). We have checked into the Iikelihood ofsome cross-senstivty between CO and H2S - doesnt seem to be a likely cause from what we have gathered, at east not at the CO concentrations detected on4/22/11 and 4/25/11 Jim Regg AOGCC ~ ��Y �Yk11 noovvJm*vonuo.uu|�1oo °.m" ` �k ~ � Anchorage, AK 99501 ~--- 907'793'1e36 From: Hauck, Shane R [mailto:haucks@chevron.com] Sent: Tuesday, April 26, 2011 4:33 PM To: DOA AOGCC Prudhoe Bay Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Hammons Jr, Darrell James; Regg, James B (DOA) Subject: AOGCC Notification of H2S Detection by Rig Sensor This Message is sent in Behalf of Chevron Drilling Supehntendent, Darrell Ha[nnnono, who is attending Chevron Well Control School this week. Date April 25, 2011 Time nfI Alarm 4/29/2011 • • Page 2 of 2 17:06 hours Well/Location/PTD Number Trading Bay Unit G -28RD /Grayling Platform /200 -038 Rig Name CUDD #136 Operator Contact Shane R Hauck , Drill Site Manager Cell 907 250 2713 Darrell, Hammons, Drilling Superintendent Office 263 -7632 Cell 907-382-4225 Operations Summary, including events leading up to H Alarm While picking up ESP completion with hole taking 4 -5 BPH, the trip tank was being filled from 400 bbl up -right tank which contained some of the circulated wellbore 3% KCL fluid, when the 20+ ppm H high alarm activated at the trip tank. Operations were shut down and mustered to galley. Area check performed with a hand held multi -meter by emergency response team - No gas was present. The 400 bbl up right tank was check from top hatch and 41 ppm carbon monoxide was detected. Tank was agitated & vented & re- checked with 7 -8 ppm carbon monoxide detected. Actions Taken / To Be Taken Continue to agitated vent & monitor the 400 bbl up right tank. Last calibration test of gas sensor 4/23/11 4/29/2011 • • Page 1 o7.2 Regg, James B (DOA) From: Bonnett, Nigel ( Nigel.Bonnett) [NigeLBonnett @chevron.comj a Q0) Sent: Wednesday, April 27, 2011 5:33 PM c2 F ;(' To: DOA AOGCC Prudhoe Bay Cc: Brandenburg, Tim C; Hammons Jr, Darrell James; Hauck, Shane R; Regg, James B (DOA); Aubert, Winton G (DOA) Subject: AOGCC Notification of H2S Detection by Rig Sensor This message sent on behalf of Chevron Drilling Superintendent, Darrell Hammons. At 05:30 hrs on 27th April 2011, prepared to surface transfer fluid from upright holding tank # 1 (containing 43 bbls) to the trip tank. Prior monitoring of holding tank vent had shown no H During transfer, for a short duration (seconds), noted the trip tank H detector indicated a maximum 24 ppm H before quickly dropping to zero. Continued operations. FYI, we are currently landing the G -28 tubing hanger and will be moving towards ND BOP / NU Tree, followed by rig down and demob from the Grayling Platform. all Regards,i From: Hauck, Shane R Sent: Tuesday, April 26, 2011 4:33 PM To: doa.aogcc.prudhoe.bay @alaska.gov Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Hammons Jr, Darrell James; jim.regg @alaska.gov Subject: AOGCC Notification of H2S Detection by Rig Sensor This Message is sent in Behalf of Chevron Drilling Superintendent, Darrell - ammons, who is attending Chevron Well Control School this week. Date April 25, 2011 Time of H Alarm 17:06 hours Well/Location/PTD Number Trading Bay Unit G- 28RD /G - ling Platform/200 -038 Rig Name CUDD #136 Operato ontact S . e R Hauck , Drill Site Manager 4/29/2011 Page 1 k- Regg, James B (DOA) From: Hauck, Shane R [haucks @chevron.com] PH Z00 -b3n Sent: Tuesday, April 26, 2011 4:33 PM 4 I v1 ' it To: DOA AOGCC Prudhoe Bay Cc: Brandenburg, Tim C; Bonnett, Nigel (Nigel.Bonnett); Hammons Jr, Darrell James; Regg, James B (DOA) Subject: AOGCC Notification of H2S Detection by Rig Sensor This Message is sent in Behalf of Chevron Drilling Superintendent, Darrell Hammons, who is attending Chevron Well Control School this week. Date April 25, 2011 Time of H Alarm 17:06 hours Well /Location/PTD Number Trading Bay Unit G -28RD /Grayling Platform/200 -038 Rig Name CUDD #136 Operator Contact Shane R Hauck , Drill Site Manager Cell 907 250 2713 Darrell, Hammons, Drilling Superintendent Office 263 -7632 Cell 907-382-4225 Operations Summary, including events leading up to H Alarm While picking up ESP completion with hole taking 4 -5 BPH, the trip tank was being filled from 400 bbl up -right tank which contained some of the circulated wellbore 3% KCL fluid, when the 20+ ppm H high alarm activated at the trip tank. Operations were shut down and mustered to galley. Area check performed with a hand held multi -meter by emergency response team - No gas was present. The 400 bbl up right tank was check from top hatch and 41 ppm carbon monoxide was detected. Tank was agitated & vented & re- checked with 7 -8 ppm carbon monoxide detected. Actions Taken / To Be Taken Continue to agitated vent & monitor the 400 bbl up right tank. Last calibration test of gas sensor 4/23/11 4/27/2011 • • Page 1 of 2 Regg, James B (DOA) From: Purugganan,Abraham [ABRAHAMP @chevron.com] !!'�� Sent: Saturday, April 23, 2011 6:46 PM `; e (41V;)11 To: DOA AOGCC Prudhoe Bay Cc: Hammons Jr, Darrell James; Bonnett, Nigel (Nigel.Bonnett) a0 0 �� Subject: AOGCC BOP Closure notification This Message is sent in Behalf of Chevron Drilling Superintendent, Darrell, Hammons Date April 22, 2011 , APR 2 5 213 Time of BOPE Use 2030 hours Well/Location/PTD Number Trading Bay Unit G -28RD /Grayling Platform /200 -038 , Rig Name CUDD #136 Operator Contact Abraham Purugganan, Drill Site Manager ' Cell 907 230 7262 Darrell, Hammons, Drilling Superintendent Office 263 -7632 Cell 907-382-4225 Operations Summary, including events leading up to BOPE use While spotting Sized salt pill in well to slow loss rate of 1 lbarrels per hour. A H2s alarm was set off at the bell nipple. Installed FOSV and shut annular preventer. Shut in Casing pressure 0 psi. Shut in tubing pressure 0 psi. Open casing to atmosphere through gas separator. Open annular preventer to monitor well and found no flow. With a hand held multi -meter we detected carbon monoxide and low levels of LeL and NO h2s. Close Annular preventer and circulate well clean through gas separator. Check H2s alarm sensor for proper calibration. BOPE Used 4/25/2011 • • Page 2 of 2 Annular and Full Opening Safety Valve Reason for BOPE Use H2s alarm at bell nipple. Actions Taken / To Be Taken (including the date used BOPE was tested) Check for flow, Well still taking 11 BPH. Circulate bottoms up. Last BOP test date 4/20/11 4/25/2011 Page 1 of 1 • 0• Aubert, Winton G (DOA) From: Santos, Ronilo [ronnie.santos @chevron.com] Sent: Friday, April 15, 2011 6:15 PM Zoo e8 To: Aubert, Winton G (DOA) Cc: Ross, David A. [Swift Technical Services]; Tyler, Steve L; Bonnett, Nigel (NigeLBonnett); Hammons Jr. Darrell James; Kanyer, Christopher V; Jorgensen, Sarah [Swift Technical Services] Subject: Sundry No. 311 -036 for Well G -28RD ESP Workover (PTD #200 - 038 /API #50- 733 - 20324 -01) prtr. Aub°c , Please be informed of changes in the approved plans for the G -28RD ESP Workover as follows: The portion of the existing 4 -1/2" tubing completion from +1 -7411' (60' above the 7" liner top) down to the anchor seal that is engaged in the existing production packer will be intentionally left in the wellbore. • There will be no cut on the 4 -1/2" tubing at +1- 11,300'. • Th 4_112" tubing will be cut at +1- 7,411', and will be pulled and !aid down. • The lower portion of the 4 -1/2" tubing from the cut down to the anchor seal will be left in hole. • There will be no mechanical debris barrier other than the sized salt pill. • A MI -Swaco Well Patroller welibore cleanout tool will be added to the cleanout BHA (subject to availability). • A GR will be ran through DP or tubing to +/- 11,650 prior to running ESP completion. These changes will allow us to meet the objectives of the workover with increased chances of success and at a lower cost by minimizing the time exposure on the well with fishing jobs and a number of trips in and out. We do not see a need for a variance but would like to confer with you. I am sitting in for David Ross until Tuesday moming, 4/19/2011 that is why I am the one making this correspondence. Please let us know if you have any questions or need additional information Thank you, Ronnie Santos Mobile: 907 - 306 -5857 -: APR 1 b Z O 1 Office: 907 -263 -7978 4/18/2011 ' I • • SITAITEE SEAN PARNELL, GOVERNOR { AELASEA ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California © 1 r P.O. Box 196247 a® ✓ Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, TBU G -28RD Sundry Number: 311 -036 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. L Chair DATED this I day of March, 2011. Encl. • • Chevron Timothy C Brandenburg Union Oil Company of California 410 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 Tel 907 263 7657 Fax 907 263 78888 4 Email brandenburgt @chevron.com February 14, 2011 AEC E IV FEB 15 2011 Commissioner Alaska Oil & Gas Conservation Commission l 011 & G8$ Cons, Commission 333 W. 7 Avenue, Suite 100 Anctaboe Anchorage, Alaska 99501 -3572 Re: Grayling G -28RD ESP conversion, Application for Sundry Approval Dear Commissioner Enclosed is an Application for Sundry Approval (Form 10 -403) for the above referenced well. The outlined workover is for conversion from gaslift completion to ESP producer. • The location of the SSV is currently "adjacent to the vertical run" on the production tree of well G -28RD. Union Oil Company requests a variance to 20 AAC 25.265 (c) (1), requiring that the SSV must be located in the vertical run of the tree. If you have any questions pertaining to this variance, please contact Ronnie Santos 907 -306- 5857 or Larry Greenstein 9 - 263- 7 = Timoth . Brandenburg Drilling Manager Enclosure Cc: Well File Union Oil Company of California / A Chevron Company valpik oltifloit STATE OF ALASKA 3 4/P ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 61 3 - 1'� ( 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend p Plug Perforations ❑ Perforate ❑ Pull Tubing 0 . Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Convert to ESP n , 2. Operator Name: Union Oil Company of California 4. Current Well Class: 5. Permit to Drill Number: Development 12 Exploratory ❑ 200 -038 ' 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic El Service ❑ 6. API Number: 50- 733 - 20324 -01 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 TRADING BAY UNIT G -28RD 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594 (Grayling Platform) MCARTHUR RIVER FIELD / HEMLOCK OIL POOL , 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): 15,416 9,410 15,380 9,414 N/A N/A Casing Length Size MD / TVD Burst Collapse Structural 369' 26" 369' 368' Conductor 828' 20" 828' 827' Surface 6,020' 13 -3/8" 6,020' 5,092' 3,090 psi 1,540 psi Intermediate 8,922' 9 -5/8" 8,922' 7,435' 6,870 psi 4,750 psi Production 4,229' 7" 11,700' 9,519' 8,160 psi 7,030 psi Liner 3,904' 4 -1/2" (slotted) 15,414' 9,410' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,700' to 15,414' / 9,519' to 9,410' 4 -1/2" i 12.6# L -80 11,398' (slotted liner) Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Model 85SAB0L47 Packer & Baker SL -ZXP Packer e- 11,324' MD (9307' TVD) & 11,510' MD (9411' TVD) Cameo TRDP -4A0 SSSV 291' MD (290' TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 1151 Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 2/20/2011 15. Well Status after proposed work: Commencing Operations: Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ronnie Santos 263 -7978 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature c , Phone 276 -7600 Date 2/14/2011 COMMISSION USE ONLY (� � ^ 0 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 `-� 5 NED Plug Integrity ❑ BOP Test f Mechanical Integrity Test ❑ Location Clearance El Other: T e t i' P E iv 350o to . FEB 15 2011 Potrsu -t iv 20 A - C n. 2- !a$ (o (I'j / atfevw'ft uAl 11 S US i5 alt,!''o Rue s uaK-t - to 20 Ailt. LS. 21c al/ aI t wuat t R o pF i s cvp)Yo ved . Wm Oa & GU C,OM Commission AntharrIoe Subsequent Form Required: 10 — 404. APPROVED BY / 1 Approved by: k) t COMMISSIONER THE COMMISSION te: / 1 ( Form 10 -403 Revised 1/2010 . Q R 1 G 1 N A LRBDMS MAR 0 2 20 bmit in Duplicate 1 a L, 2- J 1 , • Chevron • • Trading Bay Unit *101 G -28RD 2 -8 -2011 OBJECTIVE: • Convert gas lift well to ESP completion. Current BHP :4,045 psi @ 9,449' TVD Max Dow ole1'Pressure: 4,045 psi @ 9,449' TVD (Based on 6/29/2009 Shut -In Bottom -Hole Pressure /Temp Survey) MASP: ,1Q0 psi (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) �f. PROCEDURE SUMMARY: 1. MIRU CUDD HWO unit. 2. RU slickline. Pressure test lubricator 250psi low /2500psi high. 3. RIH w/ GR to clear tubing to +/- 11,600'. 4. Punch circulating holes in the 4 -1/2" tubing above the packer at +/- 11,300'. 5. RD slickline. 6. Circulate wellbore with 3% KCI -FIW (filtered inlet water). i 7. Spot sized salt pill if necessary. 8. ND tree. NU and test BOPE to 250psi low 350 i high. 9. Unseat the tubing hanger and put tubing in tension. 10. RU Eline. 11. Cut the 4-1/2" tubing below the circulating holes +/- 11,300' above the packer. 12. RD Eline. 13. Recover 4 -1/2" completion down to tubing cut at +/- 11,310'. 14. Recover the cut 4 -1/2" tubing stub and the anchor seal assembly. 15. RIH and set plug in packer at 11,324' to protect the productive interval from cleanout debris. Spot +/ -50 linear feet of sand /polymer on top of packer plug. 16. Run 9 -5/8" scraper BHA to the top of 7" liner at 7,471'. Circulate hole clean. 17. Contingency: RIH w/ USIT casing evaluation log in the 9 -5/8" casing. 18. RIH w/ plug retrieving tool, circulate debris and sand /polymer on top of the packer plug, equalize and retrieve the packer plug. 19. Spot sized salt pill if necessary. POOH. 20. RU slickline. 21. RIH w/ GR to clear packer bore and the x- nipple in the 4 -1/2" slotted liner down to +/- 11,600'. 22. RD slickline. 23. RIH 4 -1/2" 12.6# L -80 ESP and GLM completion w/ pump intake set at depth +1- 7,325'. 24. ND BOPE. NU and test tree. 25. Secure and turn well over to production. 26. Rig down and release rig CUDD HWO unit. G -28RD REVISED BY: CVK 2 -8 -2011 • • - GRAYLING PLATFORM WELL G -28RD UNOCAL 16 Current Completion (7 -21 -2000) RKB = 42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL /1 SIZE WT GRADE CONN ID MD TOP MD BTM. / 0 2 26" Y." WT Spiral Weld 25.000 Surface 369' Z0 94 H-40 Buttress 19.125 Surface 828' 369e 13 -3/8" 61 K -55 Buttress 12.415 Surface 6020' 9 -5/8" 47 N -80 Buttress 8.681 Surface 8922' 20" shoe 828' 9 -5/8" 47 S -95 Buttress 8.681 8,922' 9761' Window 7" 29 L -80 Buttress 6.184 7471' 11700' 4 -1/2" 12.6 N -80 Hydril 511 3.958 11510' 15414' 3A 4 -1/2" pre - slotted liner has 48 slots /ft 2-1/2" x 1/16" 4 -1/2" 8 hpf at 90 deg phasing Tubing: 4 -1/2" 1 12.6 1 L -80 1 Mod Butt. (SPC)1 3.958 1 Surf 1 11,398' 3B JEWELRY NO Depth ID Item 1 39' 3.958" CIW DCB Tubing Hanger: 4-1/2" Butt top & btm 2 291' 3.813" Camco TRDP -4A0 (7.188 "OD x 3.813 X Profile) SSSV 3A 2564' 3.833" 3B 4306' 3.833" 4 -1/2" Camco MMG-M GLM w/ 1 -1/2" RK latch (7.063" x 3C 3C 5535' 3.833" 6.141") L 3D 6511' 3.833" 13 -3/8" shoe 3E 7393' 3.833" n 6020' 3D 4A 8034' 3.833" 4B 8578' 3.833" 7" Tot @ 7471' 3E 4C 9086' 3.833" 4 -1/2" Camco KBG-2 SPC GLM w/ 1" BK -2 Latch 4D 9565' 3.833" (5.984" OD) 4B 4E 9614' 3.833" 4C 4F 10036' 3.833" 4D 5 11323' 4.00" Baker KBH -22 Anchor. with 1' of nitrite seals 4E. 6 11324' 4.00" Baker Model 85SAB -L47 x38 Hydraulic Set Permanent Packer with 6' mill out extension 9 -5/8" window 4F @ 9761' 7 11365' 3.813" Otis "X" nipple (3.813 ") 6 8 11367' 3.958" 1 joint 4 -1/2" 12.6 lb/ft L -80 Mod Butt Tbg. 8 9 11398' 3.958" Mule shoe 10 11510' 4.438" Baker SL-ZXP Liner Packer with 10' tie -back extension 4-1/2" TOL @ 11,510' I 10 11 11578' 3.813" Otis "X" nipple (set in the 4 -1/2" production liner) 7" shoe @ 11700' 11 Horizontal Ported liner produces from Hemlock Benches 1, 2, J L TD = 15,416'; ETD = 15,380' REVISED: 2/04/2011 DRAWN BY: NM/RMS • • Chevron , - GRAYLING PLATFORM 1 ft. ALASKA I♦RILLING WELL G -28RD Proposed Completion 02 -04 -2011 UNOCAL �6 osed ESP Com p P � ) RKB = 42' Rig Floor to DCB TBG Spool CASING AND TUBING DETAIL 1` /� SIZE WT GRADE CONN ID MD TOP MD BTM. 26" v." WT Spiral Weld 25.000 Surface 369' 20" 94 H -40 Buttress 19.125 Surface 828' 369 13 -3/8 61 K -55 Buttress 12.415 Surface 6020' 9 -5/8" 47 N -80 Buttress 8.681 Surface 8922' 20" shoe @ 828' 9 -5/8" 47 S -95 Buttress 8.681 8,922' 9761' Window 7" 29 L -80 Buttress 6.184 7471' 11700' 4 -1/2" 12.6 _ N -80 Hydril 511 3.958 11510' 15414' 2A 1- L 4 -1/2" pre - slotted liner has 48 slots /ft 2-1/2" x 1/16" � 4 -1/2" 8 hpf at 90 deg phasing Tubing: 4 -1/2" 1 12.6 1 L -80 1 Mod Butt. (SPC)I 3.958 1 Surf 1 11,398' 213 LAMM JEWELRY NO Depth ID Item 1 +/ -39' 3.958" CIW DCB Tubing Hanger: 4-1/2" Butt top & btm 2A +/ -2564' 3.833" SFO -2 GLM #1 2B +1 -4296' 3.833" SFO -2 GLM #2 2( 2C +/ -5524' 3.833" SFO -2 GLM #3 L- 2D +/ -6278' 3.833" SFO -2 GLM #4 L 2E +/ -6845' 3.833" SFO -2 GLM #5 13 -3/8" shoe 3 3 +/ -7164' 3.810" Sliding Sleeve @ 6020' 4 4 +/ -7223' 3.810" XN- Nipple 5 5A +/ -7286' - ESP Assembly (Top) e' 7" TOL @ 7471' Z 5C j -- 5B +/ -7325' - ESP Intake 5C +/ -7380' - Bullnose Centralizer (Bottom) 6 11324' 4.00" Baker Model 85SAB -L47 x38 Hydraulic Set Permanent Packer with 6' mill out extension 7 - - - . 8 11367' 3.958" 1 joint 4 -1/2" 12.6 lb /ft L -80 Mod Butt Tbg. 9 -5/8" window 9761' 10 11510' 4.438" Baker SL -ZXP Liner Packer with 10' tie -back extension 6 11 11578' 3.813" Otis "X" nipple (set in the 4 -1/2" production liner) 1 8 4 -1/2" TOL @ 11,510'1 A 10 7" shoe @ 11700' 11 Horizontal Ported liner produces from Hemlock Benches 1, 2, J L TD = 15,416'; ETD = 15,380' REVISED: 2/04/2011 DRAWN BY: NM/RMS • • Chevron -Ak Cudd 11 " 5M WO Stack Grayling 1 p ° w Pl Platform y� _ � --,J 1 3) atf i" 5M Valve 1° 4 Ys'' M Valve 11' 5M 0 Li - � A . VNnh4 9.930 lbs l ya d REb 2 7' -S'VBR m p Q r 5' 4 ' - 7 ' Mike Freeman 713- 252 -1944 Blinds Houston, Tx. (O ) 2 ! rQ 1 r J I E _..._9, 2 -1/16' 5M VALVES —1 /1 5M VALVES Spacer Spool J 11� ' 5M I 2 36 ' -S'VHR 2 2 ( ) i I'34 e� L° ,• Spacer Spool 11' 5S pool P acer S ool All heights apprx. P P Il' SM M Ad. Spool r Se MI 11'5M X 11'10M Page 1 of 1 Aubert, Winton G (DOA) From: Santos, Ronilo [ronnie.santos @chevron.com] Sent: Thursday, February 24, 2011 4:46 PM To: Aubert, l Mnton G (DOA) Cc: Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett); Kanyer, Christopher V; Jorgensen, Sarah [Swift Worldwide Resources] Subject: Request for Variance (Grayling G-28RD ESP Conversion Workover, Application for Sundry Approval 10 -403) Mr. Aubert, Per our conversation, the BOP stack we currently plan for the G -28RD ESP Conversion Workover (PTD #200 - 038 /API #50- 733 - 20324 -01) does not comply with Regulation 20 AAC 25.285 (c) (9)(A), due to the fact that the MASP reported on the sundry application was 3100 psi and the BOP stack currently only has 2" lines and 2 - 1/16" valves connected to the choke and kill outlets. As per regulation 20 AAC 25.285 (c) (10)(A) &(B), we are in compliance with the regulation as we do have two adjustable chokes with one being hydraulic and remotely controlled from near the drillers station. The lines on the downstream sides of the choke are 2" nominal diameter. Consequently, we request a variance to regulation 20 AAC 25.285 (c) (9)(A) in order to allow us to use the 2" nominal lines on the BOP choke outlets. Regards, Ronnie Santos 907 - 306 -5857 2/28/2011 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .~~\;'.... . ...\ "1~\l, ,.t: J " { ;' {<'. \ rf:~-' I ! :¡ ¡. t.., ~¡!I ...- \ lJ i ¡ ¡ ..,-_.,- !._¡ {~;"~ / t\\. i 1 \ / ~--!.. \ ,U t..\ FRANK H. MURKOWSKI, GOVERNOR AIIASIiA OIL AND G~t¡ CONSERVATION COMMISSION 333 W. -,n< AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 23, 2004 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification Trading Bay Unit G-OIRD, PTD 191-139 G-02RD, PTD 182-067 G-17RD, PTD 178-003 G-28RD, PTD 200-038 Dear Mr. Johnson: On May 27, 2004, AOGCC Petroleum Inspector John Spaulding witnessed "no flow tests" at Unocal's Grayling platform, Trading Bay Unit, Wells G-01RD (short and long string completions), G-02RD, G-17RD, and G-28RD. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy and monitored. An immeasurable flow of gas and no liquid hydrocarbons were produced to surface during the test. The subsurface safety valve may be removed from service in each of the wells listed above based on the no-flow test results. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in each well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, ~//- '-;--) TJ <J~ b, \-<'ìrC7' James B. Regg I. Petroleum Inspection Supervisor cc: Bob Fleckenstein Pib -----... l ß1..- ob7 ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg . Kcqtj '=/PJetr P. I. Supervisor {r DATE: June 22,2004 ciþo ~07Jø FROM: John Spaulding, Petroleum Inspector SUBJECT: "No Flows" Unocal Grayling Platform 5 wells June 15, 2004: I traveled to Unocal's Grayling platform to witness "No Flows" on 5 wells, defined as follows. The platform was shut in for some upgrades while I was there. All wells were ready to commence testing upon my arrival. The same bleeding and testing procedures were used on all 5 wells. G-2RD: Well was bled to the well clean tank and after sufficient bled was then vented to atmosphere. Gas flow was positive but not measurable, no fluids observed. Recommend for no flow status. 11'2>-o.J3 G-17RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. '2eo-{)'3~ G-28RD: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. 19/-139 G-1 RDL: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. G-1 RDS: Positive but not measurable gas flow, no fluids observed. Recommend for no flow status. SUMMARY; I witnessed the successful no flow tests on the Grayling Platform Attachments: none NON-CONFIDENTIAL 2004-0615_no_flows- TBU- Grayling(5wells).doc Permit to Drill 2000380 MD 15416 TVD 9411 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. TRADING BAY UNIT G-28RD Operator UNION OIL CO OF CALIFORNIA Completion Dat 7/21/2000 Completion Statu 1-OIL Current Status 1-OIL API No. 50-733-20324-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample N._9o Directional Survey ~ ~,.~/.2..~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media~, Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments L L R R L C ~ VISION 475-MD GR-MD SRVY RPT SRVY LSTNG Ultra Sonic Cement 9705 2/5 2/5 5 FIELD FIELD 8747 16867 Open 11800 15065 OH 9747 15357 OH 9750 15416 OH 0 15416 OH 50 9830 CH OH 8/30/2000 8/30/2000 8/30/200O 8/30/2000 8/8/2000 1/4/2001 8/30/2000 09705 8747-16867 11800-15065 7/13/00 THRU 9747-15357 6/5/00 THRU SCHLUM 9750-15416 BHI 0-15416.. 50-9830 Color Print, Sepia 9705 SCHLUM V475/GR Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? Analysis R~.n~,iv~,d? Daily History Received? Formation Tops ~YYY~N '~)/N Comments: Compliance Reviewed By: Date: Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263 -7660 UNOCAL Tim Billingsley 8/21/2002 Drilling Engineer Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Attn: Tom Maunder Re: Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G -22 �b Mr. Maunder: lJ Enclosed is the final report on annulus disposal of A -29RD oil base mud (OBM) liquid waste into the G -22 annulus as required by the Sundry Application Approval #301 -304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G -22 annulus while drilling at A -29RD. The following is the total volumes disposed in G -22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls �qa G - 15RD 1269 2160 3429 acic G-21) 700 903 1 -4.4 2 - G -26RD 823 2155 2978 aol - i89 A -15RD 1374 5067 6441 G -12RD3 366 1050 1416 aoa -noci A -29RD 856 1494 2350 Total 17517 This concludes all presently scheduled disposals into the G -22 annulus. If there are any questions, please contact myself at 263 -7659. Sincerely, "K Billingsley t . Ip 1 ZOV, Drilling Engineer AOGCC G -22A -29RD waste annular disposal final report Created on 8/21/2002 10:13 AM Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G -22 Drilling Wastes From Monopod A -29RD Maximum Allowable Injection Pressure 2000 psi TVD 13 3/8" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 6/29/2002 1 2.0 1600 10.2 205 0 205 0 6/29/2002 2 2.0 1400 10.2 146 351 0 6/29/2002 3 1 2.0 1800 10.2 60 357 411 357 7/15/2002 2 2.0 1550 20 411 377 7/15/2002 4 2.0 1850 8.7 125 536 377 7/15/2002 3 2.0 1800 357 536 734 8/5/2002 4 2 1400 8.3 20 536 754 8/5/2002 5 2 1750 8.5 170 706 754 8/5/2002 5 2.5 1850 8.3 350 706 1104 8/10/2002 6 2 1500 8.3 20 706 1124 8/10/2002 6 2 1750 8.5 150 856 1124 8/10/2002 7 2.5 1850 8.3 370 856 1494 *Injection pressure is the highest injection pressure observed while injecting • Unocal Corporation • P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263 -7660 UNOCAL Jim Harrison 7/3/2002 Drilling Manager Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Attn: Tom Maunder Re: Report on Annulus Disposal Trading Bay Unit, Grayling Platform, ./0„, �jq Well Grayling G -22 d r Mr. Maunder: Enclosed is the final report on annulus disposal of G -12RD3 oil base mud (OBM) liquid waste into the G -22 annulus as required by the Sundry Application Approval #301 -304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G -22 annulus while drilling at G- 12RD3. The following is the total volumes disposed in G -22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls i49 - o9S G -15RD 1269 2160 3429 y _ G 203 700 903 I'G ,G -26RD 823 2155 2978 Doi - t'A A -15RD 1374 _ 5067 6441 C13-05,5 G -12RD3 366 1050 1416 Total 15167 Unocal began disposing of drilling wastes from the A -29RD into the G -22 annulus on June 29, 2002. If there are any questions, please contact myself at 263 -7677 or Tim Billingsley at 263 -7659. Sincerely, . �' ' ,I (Tr. 4 sei, Jim Harrison Drilling Manager _ - APR 1 " JU L 9 2002 Anchorage AOGCC G -22 G -12RD waste annular disposal final report RI Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5/8" Annulus of G -22 Drilling Wastes From Grayling G -12RD3 Maximum Allowable Injection Pressure 2000 psi TVD 13 3/8" Casing Shoe Depth 4977' BBLS BBLS BBLS BBLS Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry's Flushes 6/10/2002 1 1 3 1800 9.1 170 350 170 350 • 6/15/2002 2 2 2 1800 8.3 11 350 181 _ 700 6/17/2002 3 3 2 1750 8.4 185 350 366 1050 • *Injection pressure is the highest injection pressure observed while injecting Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager 5/8/2O02 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Tom Maunder Report on Annulus Disposal Trading Bay Unit, Grayling Platform, Well Grayling G-22 Mr. Maunder: Enclosed is the final report on annulus disposal of A-15RD oil base mud (OBM)liquid waste into the G-22 annulus as required by the Sundry Application Approval #301-304 dated November 6, 2001. Attached is the daily summary of disposal volumes in G-22 annulus while drilling at A-15RD. The following is the total volumes disposed in G-22 annulus by drilling well source. Well OBM, bbls Seawater Flush, bbls Total Bbls G-15RD 1269 2160 3429 G-28RD 203 700 903 G-26RD 823 2155 2978 A-15RD 1374 5067 6441 Total 13751 If there are any questions, please contact myself at 263-7677 or Tim Billingsley at 263-7659. Drilling Manager AOGCC G-22 Monopod waste annular disposal final report Tim Billingsley Daily Injection Log of the 13 3/8" x 9 5~8" Annulus of G-22 Drilling Wastes From Monopod A-15RD Maximum Allowable Injection Pressure 2000 psi TVD 13 318" Casing Shoe Depth 4977' ~" BBLS BBLS BBLS BBLS" Date Slurry Flush Rate Injection Slurry Slurry Flush Total Total No No. BPM Pressure* PPG Volume Volume Slurry'sFlushes 12/9/2001 Inj-test 1 3 1600 FIW 0 338 0 338 12/9/2001 1 2 3 1600 9.9 450 338 450 676 12/10/20012 3 3 1750 10 198 338 648 1014 12/10/20013 X 3.5 1650 10 150 0 798 1014 12/11/2001Flush 4 3.5 1750 FIW 0 450 798 1464 2/14/2002 Flush 5 3.5 1650 FIW 0 338 798 1802 2/14/2002 4 6 4 1750 9 80 338 878 2140 , , 2/27/2002 Flush 7 2.5 1100 FIW 0 40 878 2180 2/28/2002 Flush 8 3 1100 FIW 0 20 878 2200 3/2/2002 Flush 9 3 1200 FIW 0 20 878 2220 , ,, 3/2/2002 5 X 3 1750 10.0 130 338 1008 2558 3/3/2002 6 X 3 1750 10 100 338 1108 2896 3/5/2002 7 10 1.75 1750 10 50 360 1158 3256 3/19/2002 8 11 4 1750 9 76 360 1234 3616 3/24/2002 9 12 1750 70 351 1304 3967 4/3/2002 flush 13 FIW 0 20 1304 3987 4/3/2002 10 14 4 1900 9.1 20 360 1324 4347 4/3/2002 11 15 4 1750 9.1 20 360 1344 4707 4/3/2002 12 16 3.5 1800 9.1 30 360 1374 5067 Total bbls injected 6441 *Injection pressure is highest reading while injecting Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd @ unocal, com UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL December 7, 2000 To: Howard Oakland From: Debra Childers 3OO1 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Transmitting the following items: SCALE I ~nATF ~iflm IRU 13-31 ~1 11/16" ENERJET PJ / GR-CCL, PERFORATION RECORD 5 INCH 11/8/00 7322-7335 1B-Line IRU 13-31 1 11/16" ENERJET PJ / GR-CCL, PERFORATION RECORD 5 INCH 11/8/00 7322-7335 1Film IRU 13-31 2 7/8" OWEN PATCH PERFORATING RECORD ~5 INCH 11/3/00 2950-2996 1B-Line IRU 13-31 2 7/8" OWEN PATCH PERFORATING RECORD 5 INCH 11/3/00 2950-2996 1Film IRU 13-31 BRIDGE PLUG 5 INCH 10/12/00 6500-7420 1B-Line IRU 13-31 BRIDGE PLUG 5 INCH 10/12/00 6500-7420 1Film SLU 41-33 COMPLETION RECORD 2.5" HSD POWERJETS 5 INCH 10/8/00 6000-7150 1B-Line SLU 41-33 COMPLETION RECORD 2.5" HSD POWER JETS 5 INCH 10/8/00 6000-7150 1Film TBU D-12RD PERFORATING RECORD 2 7/8" PJ 5 INCH 11/27/00i 10970-11950 1B-Line TBU D-12RD PERFORATING RECORD 2 7/8" PJ 5 INCH 11/27/00 10970-11950 1Film TBU D-8RD COMPLETION RECORD 2.5" HSD POWERJET 5 INCH 8/24/00 11100-12017 1B-Line TBU D-8RD COMPLETION RECORD 2.5" HSD POWER JET 5 INCH 8/24/00 11100-12017 1Film TBU G-18DPN TCP CORRELATION LOG / GAMMA RAY, CCL 5 INCH 9/1/00 4300-6120 1B-Line TBU G-18DPN TCP CORRECTION LOG / GAMMA RAY, CCL 5 INCH 8/29/00 5000-6120 1B-Line TBU G-18DPN TCP CORRECTION LOG / GAMMA RAY, CCL 5 INCH 8/29/005000-6120 1 Film TBU G-18DPN TCP CORRELATION LOG / GAMMA RAY, CCL 5 INCH 9/1/00 4300-6120 1 Film TBU G-18DPN ULTRA SONIC IMAGING TOOL / GAMMA RAY 5 INCH 8/28/00 47-6760 1 B-Line TBU G-18DPN ULTRA SONIC IMAGING TOOL / GAMMA RAY 5 INCH 8/28/00 47-6760 1 Film TBU G-26RD COMPLETION RECORD 2 7/8" PJ ~5 INCH 10/26/00 9900-11478 1 B-Line TBU G-26RD COMPLETION RECORD 2 7/8" PJ 5 INCH 10/26/00 9900-11478 1 Film TBU G-26RD PERFORATING RECORD 2 7/8" PJ 5 INCH 11/1/00 11095-11320 1 B-Line TBU G-26RD PERFORATING RECORD 2 7/8" PJ 5 INCH 11/1/00 11095-11326 1 Film ~TBU G-28RD ULTRA SONIC IMAGER CORROSION % CEMENT 5 INCH 6/1/00 50-9830 1 B-Line TBU G-28RD ULTRA SONIC IMAGER CORROSION % CEMENT 5 INCH 6/1/00 50-9830 1 Film TBU M-19RD PRODUCTION PROFILE / PS PLATFORM 5 INCH 11/10/00'3800-4600 1 B-Line TBU M-19RD PRODUCTION PROFILE / PS PLATFORM 5 INCH 11/10/00 3800-4600 1 Film TBU M-19RD RST GRAVEL PACK LOG, SIGMA LOG 5 INCH 11/10/00 3800-4600 1 B-Line TBU M-19RD RST GRAVEL PACK LOG, SIGMA LOG 5 INCH 11/10/00 3800-4600 1 Film Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. J Received b~ .~~4./~_.~ J Dg~te: I/Z//O / TBU M-2 CEMENT EVALUATION CBL-VDL-GR 5 INCH 10/12/00 60-4509 11 B-Line TBU M-2 CEMENT EVALUATION CBL-VDL-GR 5 INCH 10/12/00 60-4509 1Film TBU M-2 GR-CCL CORRELATION 5 INCH 10/17/00 3550-4113 1B-Line TBU M-2 GR-CCL CORRELATION 5 INCH 10/17/00 3550-4113 1Film TBU M-2L 3.5" BP / DUMP BAILER 5 INCH 10/8/00 4500-4900 1B-Line TBU M-2L 3.5" BP / DUMP BAILER 5 INCH 10/8/00 4500-4900 1Film 'TBU M-2S 2 1/8" DUMP BAILER 5 INCH 10/7/00 4600-4979 1B-Line TBU M-2S 2 1/8" DUMP BAILER 5 INCH 10/7/00 4600-4979 1Film TBU M-2S 31/2" BRIDGE PLUG / GR-CCL CORRELATION 5 INCH 10/7/00 4630-4980 1B-Line TBU M-2S 3 1/2" BRIDGE PLUG / GR-CCL CORRELATION 5 INCH 10/7/00 4630-4980 1Film TBU M-2S GR-CCL CORRELATION 5 INCH 10/31/00 3370-3735 1B-Line TBU M-2S GR-CCL CORRELATION 5 INCH 10/31/00 3370-3735 1Film TBU M-2S SCMT-PSP / CBL-VDL LOG 5 INCH 10/7/00 4500-4980 1B-Line TBU M-2S SCMT-PSP / CBL-VDL LOG 5 INCH 10/7/00 4500-4980 1Film TBU M-5 PERFORATING RECORD 5 INCH 11/23/00 3500-4100 1B-Line ITBU M-5 PERFORATING RECORD 5 INCH 11/23/00 3500-4100 1Film Please[Receivedacknowled~signingby~,,~~ ~~ ~and returning one copy of this transmittal[ Date~L. t/q°r FAX/o/t° (907) 263-782i. Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager October 4, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Trading Bay Unit Well G-26rd APl No. 50-733-20295-01 10-403 Perforate Hemlock Dear Mr. Christensen' Please find enclosed in triplicate Form 10-403 for the perforation of the Hemlock benches 2, 3, 4 and 5 in well G-26rd. The following intervals are proposed to be perforated: Bench Top Bottom Feet HB5 11,228 11,235 7 HB5 11,315 11,325 10 HB4 11,093 11,1 03 10 HB3 10,930 10,950 20 H B2 10,780 10,785 5 HB2 10,792 10,802 1--0 Total: 62 If you have any questions, please contact Ralph Holman at 263-7838. Dan Williamson Drilling Manager .... STATE OF ALASKA ALASKA OIL. ,ND GAS CONSERVATION C .¢IMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California Development: X KB: 103' feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247, Anchorage, Alaska 99519 Stratigraphic: Trading Bay Unit Service: 4. Location of well at surface Grayling platform, Leg #3, Conductor #3 8. Well number 1806' FSL, 1416' FEL, Sec. 29, T9N, R13W, SM G-26rd At top of productive interval 9. Permit number 2109' FSL, 427' FEL, Sec. 32, T9N, R13W, SM 200-038 At effective depth 10. APl number 50-733-20295-01 At total depth 11. Field/Pool 1566' FSL, 836' FEL, Sec. 32, T9N, R13W, SM McArthur River/Hemlock 12. Present well condition summary Total depth: measured 11587 feet Plugs (measured) true vertical 9734 feetORiGiNAL Effective depth: measured 11535' feet Junk (measured) true vertical 9704 feet Casing Length Size Cemented Measured depth True vertical depth Structural 356' 26" Driven 356' 356' Conductor 740' 20" 500 sx 740' 740' Surface Intermediate 5604' 13-3/8" 3136 sx 5604' 4929' Production 10263' 9-5/8" 1800 sx 10263' 8798' Liner 1466" 7" 400 sx 10121 '-11587' 8674'-9736' Perforation depth: measured 10729-10744, 11028-11093, 11200-11210, 11422-11448r true vertical 9173-9185, 9385-9430, 9502-9509, 9638-9653 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 10172' Packers and SSSV (type and measured depth) Baker Mod. "D" 194-47 @ 10070' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 10/10/2000 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby ~,~hat t~/~ for~ o~/~is true and correct to the best of my knowledge. Signed: ~'~.[j~.iU~j~j~~g Title: j~'~,~"'~/~/~J/~, Date:/i~ ~'l~"~) - - - --- - -, -,.,v -v,' ~ v \ FOR COMMISSION IL~E ONI_~' ' Conditions of approval: Notify Commission so representative may witness IAppr°v'al~N"~?)~ Plug integrity__ BOP Test Location clearance I Mechanical Integrity Test Subsequent form required 10- ~ O k ORIGINAL ~!GN ~:L.:~ O Taylor Seamount Approved by order of the Commissioner Commissioner Date// Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih chi/dersd @ unocal, corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL August28,2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas F rom: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: .! Well:~ :: ~:~. LOG~PE : SCALE :LOG DATE INTERVAL LOGGED COPIES Medium ~ TBU D-08RD Correlation Log Gamma Ray-CCL 5 inch 6/11/00 10400-11930 1B-Line TBU D-08RD Correlation Log Gamma Ray-CCL 5 inch 6/11/00 10400-11930 1Film TBU D-08RD Perforating Record 2.5" Powerjet 5 inch 6/4/00 10900-11998 1B-Line TBU D-08RD Perforating Record 2.5" Powerjet 5 inch 6/4/00 10900-11998 1Film ) TBU D-09RD Perforating Record 2" Powerjet t.,L~, (.--. 5 inch 5/31/00 9600-10180 1B-Line TBU D-09RD Perforating Record 2" Powerjet ~ 5 inch 5/31/00 9600-10180 1Film TBU D-46RD Mechanical Plug Back Tool 5 inch 5/25/00 10900-11405 1B-Line TBU D-46RD Mechanical Plug Back Tool 5 inch 5/25/00 10900-11405 1Film TBU D-46RD Perforating Record 2.5HSD Gun w/Powerjet 5 inch 6/7/00 10800-11330 1B-Line TBU D-46RD Perforating Record 2.5HSD Gun w/Powerjet 5 inch 6/7/00 10800-11330 1Film ; TBU G-26RD CD 8/6/00 1CD TBU G-26RD CDR-ADN 2/5 inch 8/4/00; 10137-11565 1B-Line TBU G-26RD CDR-ADN 2/5 inch 8/4/001 10137-11565 1Film TBU G-26RD Perforating Record 5 inch 8/13/00 9600-11500 1B-Line TBU G-26RD Perforating Record 5 inch 8/13/00 9600-11500 1Film TBU G-28 Ultra Sonic Imager Corrosion & Cement ~ c_ 6/1/00 50-9830 1B-Line TBU G-28 Ultra Sonic Imager Corrosion & Cement ~ 6/1/00 50-9830 1Film ~ TBU G-28RD Measured Depth Log / GR 2/5 inch 6/5/00 9747-15357 1B-Line TBU G-28RD Measured Depth Log / GR 2/5 inch 6/5/00 9747-15357 1Film TBU G-28RD Measured Depth Log / VISION 475 2/5 inch 7/13/00 11800-15065 1B-Line TBU G-28RD Measured Depth Log / VISION 475 2/5 inch 7/13/00 11800-15065 1Film TBU K-03RD Completion Record 2 1/2 HSD PJ-5SPF 5 inch 7/11/00 12250-12700 1B-Line TBU K-03RD Completion Record 2 1/2 HSD PJ-5SPF 15 inch 7/11/00 12250-12700 1. Film o £CEIVED Please acknowleci,~ receipt by si, gning and returning one copy of this transmittal AX to (907) 263-7828. J Received by: ._....~U_'(//)'"~__ J Date: AUG $0 2.000 Anchorage Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, Alaska 9951 907-263-7671 UNOCAL ) August30,2000 Mr. Dan Seamount AOGCC 3001 Porcupine Drive Anchorage, AK. 99501 ; COMM COCV;M SR RES ERG :'.ES ENG ;R ENO i:~NG NRO ,'~ }-A'T T E C H ~" S TAT 'F~z.-UH'' ~ . . .. Dear Mr. Seamount, Re: Summary of OBM Liquid Waste Injected into Grayling Unocal has completed the injection of Oil Base Mud (OBM) liquid waste in Grayling G-22. As required by the Permit to Inject, we have provided a daily summary of the fluids disposed of in the G-22 casing annulus during the drilling of G-26RD and G- 2$RD. The total waste injected during the drilling of the two wells was as follows: Well Name OBM Waste Seawater Grayling G-28RD 203 Bbls 700 Bbls Grayling G-26RD 823 Bbls 2155 Bbls Total 1026 Bbls Total 2855 Bbls Should you have any questions or concerns please contact myself or the Drilling Engineer assigned to the project; Neil Magee at 263-7671. Yours faith~lly, D.R. Williamson Drilling Manager Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-26RD Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 1 7/22/00 Abandon - - 13.0 13.0 72.0 2 7/23/00 Abandon - - 25.0 38.0 72.0 3 7/24/00 Abandon .... 38.0 72.0 4 7/25/00 Abandon .... 38.0 72.0 5 7/26/00 Abandon .... 38.0 72.0 6 7/27/00 Abandon - - - 12.0 50.0 106.0 7 7/28/00 Abandon - 7.0 57.0 133.0 106.00 350.00 7a 7/28/00 a 8.50 10,263 - - 57.0 27.0 8 7/29/00 8.50 10,294 31 1.05 1.05 - 57.0 41.0 9 7/30/00 8.50 10,362 68 2.31 3.37 - 57.0 56.0 10 7/31/00 8.50 10,760 398 13.53 16.90 37.0 94.0 56.0 11 8/1/00 8.50 10,878 118 4.01 20.91 I 20.0 114.0 56.0 12 8/2/00 8.50 11,137 259 8.81 29.72 20.0 134.0 62.0 13 8/3/00 8.50 11,366 229 7.79 37.50 35.0 169.0 62.0 14 8/4/00 8.50 11,425 59 2.01 39.51 12.0 181.0 62.0 15 8/5/00 8.50 11,587 162 5.51 45.02 35.0 216.0 62.0 Well TD 16 8/6/00 Liner 11,587 - - 45.02 10.0 226.0 62.0 17 8/7/00 Liner 11,587 - - 45.02 21.0 247.0 170.0 170.00 375.00 18 8/8/00 Comp. 11,587 - _ 45.02 10.0 257.0 - 19 8/9/00 Comp. 11,587 - - 45.02 38.0 295.0 20 8/10/00 Comp. 11,587 42.0 337.0 42.0 135.00 360.00 21 8/11/00 Demob 11,587 - 337.0 110.0 160.00 360.00 22 8/12/00 Demob 11,587 - 337.0 110.0 23 8/13/00 Demob 11,587 13.0 350.0 157.0 24 8/14/00 Demob 11,587 19.0 369.0 157.0 25 8/15/00 Demob 11,587 - 369.0 - 160.00 360.00 26 8/16/00 Demob 11,587 - 369.0 36.0 OBM Injection Summary G-22 for G-26RD.xls 1/2 8/30/00--9:29 AM Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (DRUMS) (DRUMS) (BBLS) (BBLS) (BBLS) 27 8/17/00 Demob 11,587 5.0 374.0 41.0 28 8/25/00 Demob 11,587 374.0 108.0 29 8/29/00 Demob 11,587 374.0 21.0 91.50 350.00 Total: 374.0 823 2,155 Drums full of OBM absorbents: 8.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW Summary Total DRUMS of Cuttings from G-26RD Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus (B 2,978 OBM Injection Summary G-22 for G-26RD.xls 2/2 8/30/00--9:29 AM Grayling G-22 Oil-Based Mud Waste Fluid/Cuttings Summary for Drilling of G-28RD Day Date Hole Size Depth Footage Calculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 1 6/18/00 6.00 11,712 12 0.41 0.41 24.0 24.0 0 2 6/19/00 6.00 11,869 169 5.75 6.15 4.0 28.0 62.0 3 6/20/00 6.00 11,923 54 1.84 7.99 9.0 37.0 62.0 4 6/21/00 6.00 12,155 232 7.89 15.88 38.0 75.0 68.0 5 6/22/00 6.00 12,380 225 7.65 23.53 11.0 86.0 68.0 6 6/23/00 6.00 12,597 217 7.38 30.91 18.0 104.0 112.0 7 6/24/00 6.00 12,787 190 6.46 37.37 17.0 121.0 112.0 8 6/25/00 6.00 12,986 199 6.77 44.13 17.0 138.0 41.0 71.48 350.00 9 6/26/00 6.00 13,168 182 6.19 50.32 15.0 153.0 41.0 10 6/27/00 6.00 13,237 69 2.35 52.67 11.0 164.0 41.0 11 6/28/00 6.00 13,357 120 4.08 56.75 14.0 178.0 46.0 12 6/29/00 6.00 13,455 98 3.33 60.08 12.0 190.0 46.0 13 6/30/00 6.00 13,580 125 4.25 64.33 15.0 205.0 64.0 14 7/1/00 6.00 13,660 80 2.72 67.05 7.0 212.0 64.0 15 7/2/00 6.00 13,819 159 5.41 72.45 14.0 226.0 64.0 16 7/3/00 6.00 13,950 131 4.45 76.91 13.0 239.0 64.0 17 7/4/00 6.00 14,160 210 7.14 84.05 18.0 257.0 77.0 18 7/5/00 6.00 14,203 43 1.46 85.51 5.0 262.0 92.0 19 7/6/00 6.00 14,310 107 3.64 89.15 12.0 274.0 92.0 20 7/7/00 6.00 14,491 181 6.15 95.30 16.0 290.0 93.0 21 7/8/00 6.00 14,660 169 5.75 101.05 14.0 304.0 75.0 Reclaim 18 bbls 22 7/9/00 6.00 14,746 86 2.92 103.97 14.0 318.0 75.0 23 7/10/00 6.00 14,914 168 5.71 109.68 10.0 328.0 75.0 24 7/11/00 6.00 15,065 151 5.13 114.82 16.0 344.0 75.0 25 7/12/00 6.00 15,251 186 6.32 121.14 18.0 362.0 86.0 26 7/13/00 Log 15,251 - - 121.14 12.0 374.0 86.0 27 7/14/00 Log 15,251 - - 121.14 14.0 388.0 86.0 OBM Injection Summary G-22 for G-28RD.xls 1/2 8/22/00--3:12 PM Day Date Hole Size Depth Footage lCalculated Cum Calc Actual Cumulative Waste Tank G-22 G-22 Hole VOL Volume Cuttings Cuttings Volume Waste Inj Flush Inj (in) (ft) (ft) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) (BBLS) 28 7/15/00 6.00 15,416 - - 121.14 17.0 405.0 86.0 Well TD 29 7/16/00 6.00 15,416 - - 121.14 9.0 414.0 86.0 30 7/17/00 Liner 15,416 - - 121.14 414.0 86.0 31 7/18/00 Liner 15,416 - - 121.14 414.0 86.0 32 7/19/00 Liner 15,416 - - 121.14 12.0 426.0 86.0 33 7/20/00 Comp. 15,416 - - 121.14 426.0 86.0 34 7/21/00 Comp. 15,416 - - 121.14 426.0 - 132.00 350.00 35 7/22/00 Comp. 15,416 - _ 121.14 426.0 - Total: 426.0 203 700 Drums full of OBM absorbents: 10.0 Note: Bruce/Dispose costs was estimated at $207/Drum. Flush injection is FIW. Summary Total DRUMS of Cuttings from G-28RD Total Fluid Injected into G-22's 13-3/8" by 9-5/8" annulus 426 903 OBM Injection Summary G-22 for G-28RD.xls 2/2 8/22/00--3:12 PM ..... STATE OF ALASKA .... ALASKA GAS CONSERVATION C... /1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG '1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDON I~J~~RVICE: 2. Name of Operator ~'iit 7. Permit Number Union Oil Company Of Califonia (UNOCAL) 200-038 3. Address ~~ . 8. APlNumber P.O. Box 196247, Anchorage, AK 99519 50-733-20324-01 [JLI iii i 4. Location of well at surface Conductor No.12 Leg 3 Grayling F l~tf0r ,r~---E ............ ~,,~ 1317' FEL, 1666' FSL,Sec 29,T9N, R13W,SM i C~i:"!:~ ~:!-77~ i 9. Unit or Lease Name , Trading Bay Unit At Top Producing Interval ~ "'_j~_,./..~ 10. Well Number 905' FEL, 1066' FSL, Sec 30, T9N, R13W G-28RD 1958' FEL, 750' FNL, Sec 30, T9N, R13W ~- ' ' McArthur River/Hemlock Zone 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 99' KB above MSL ADLd 7594 ~2. Date Spudded ~3. Date T.D. Reached I 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore ~ ~6. No. of Completions 6/3/00 7/15/00~ 7/21/00 (completed)~ 99' RT feet MSL~ One 15,416' MD/94~ 1' WD 15,380' MD/9,4~ 5' ~D Yes: X No: 291' feet MD N/A 22. Type Electric or Other Logs Run G~Neutron Densi~/CDR 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT. PER FT. G~DE TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 26" Drive Pipe 42.6 369' Driven 0 20" 94 H-90 42.6 828' 26" 410 sx 0 13-3/8" 61/68 K-55 37 6028' 17d/2" 2000 sx 0 9-5/8" 47 N-80/S-95 36.4 9761'KOP 12-1/4" 3200 sx 0 7" 29 L-80 7471' ~ 1700' 8d/2" 625 sx 0 4-1/2" 13 L-80 11510' 1 ~4' 6" Not Cemented 0 24. Perforations open to Production (MD+~D of Top and BoEom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 11,398' 11,324' Horizontal Slotted Liner Completion Hemlock Benches 1,2,3 are open Eom: 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. 11,700' MD (9520' TVD) to ~ 54~6' MD (941~'TVD) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See a~ached completion schematic 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) 7/22/2000'~ Gas LiE Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 7/3~/2000 24 TEST PERIOD => 394 177 4407 64~ 449 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 220 1400 24-HOUR RATE => 394 177 4407 27 28. CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL . ~, ,..., ,.::,[ , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock Bench 1 117t1' 9523' Hemlock Bench 2 11795' 9569' Hemlock Bench 3 12136' 9683' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~_.~~ Title ~///~ /~/!r Date ~'~"'~'"~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. jection, Gas Injection, Shut-in, Other-explain. i '-~i~. !! , :~,, ~.,~. ;?i~i. ii / : Form 10-407 Item 28: If no cores taken, indicate "none". UNOCAL Alaska Drilling Drilling Summary Report G-28 RD 6~3~00 to 7/21/00 6/3/00 6/4~00 6/5/00 6/6/00 6/7/O0 6/8/00 6/9/00 6/10/00 6/11/00 6/12/00 6/13/00 6/14/00 6/15/00 6/16/00 RIH with Baker whipstock and mill assy. Set whipstock on bridge plug at 9778'. Mill window in casing 9761' (top of window) to 9771' Continue milling window to 9794'. Perform LOT to 1200 psi. (Bled from 1500 psi to 1200 psi in 15 minutes.) POOH and make up sidetrack assy. RIH. RIH with sidetrack assembly. Attempt to enter window without success. POOH. Discover 18' tally error. Change out bit and RIH with sidetrackassy. Directionally drill to 9824' Directionally drill from 9824' to 10086'. Drill to 10236'. POOH for bit. RIH and drill ahead to 10265' Drill ahead to 10570' Drill ahead to 10750'. POOH for bit. Make up new bit and RIH to 10750'. Drill ahead to 10965'. Drill ahead to 11328'. POOH for bit. Continue POOH. Test BOP's. Make up bit and RIH to 11328'. Drill ahead to 11437'. Drill ahead to hole section TD at 11700'. Circulate hole clean and make wiper trip. POOH Continue POOH. Rig up and run 7" liner to 11700. Liner top at 7471' Cement liner with 650 sx14.5 ppg G cement. Bump plug with 3100 psi and set ZXP liner top packer. Reverse out approximately 20 bbls of cement on liner top. Pressure test 7" liner lap and 9-5/8" casing to 2000 psi for 30 minutes. POOH. Make up 6" clean out assembly and RIH. Tag landing collar at 11562'. Drill out shoe track to 11627'. Displace PHPA mud to seawater. Clean up surface system prior to changing over to OBM. 6/17/00 Continue cleaning surface mud system and preparing for OBM change-out. 6/18/00 6/19/OO Displace to OBM. Drill out shoe track from and 12' new hole to 11712' Perform FIT to 11.2 ppg EMW. POOH for 6" directional assembly. MU BHA. RIH to 11712'. Drill 6" directional hole to 11869' 6/20/00 Continue drilling to 11903'. POOH for Bit. Test BOP's. RIH and drill from 11923' to 11923'. 6/21/00 Continue drilling to 12155'. POOH for bit. 6/22/00 RIH. Drill from 12155' to 12380'. 6/23/00 6~24~00 6/25/00 6/26/00 Continue drilling from 12380 to 12424'. POOH for bit. RIH and drill to 12597' Continue drilling from 12597' to 12620'. POOH for bit. RIH and drill to 12787' Continue drilling from 12787 to 12856'. POOH for bit. RIH and drill to 12986'. Continue drilling from 12986' to 13148'. POOH for bit. RIH and drill to 13168'. 6/27/00 Continue drilling from 13168' to 13237'. POOH for bit. Test BOP's. RIH. 6/28/00 RIH to 13237'. Drill to 13357'. POOH for bit. 6/29/00 RIH to 13237'. Drill from 13237' to 13455'. Seeing erratic surface pressures. POOH. 6/30/00 7/1/00 7/2/00 7/3/00 7/4/00 Continue POOH. Found thruster had failed accounting for 200 psi pressure loss in string. Lay down thruster and RIH. Drill from 13455' to 13580'. Continue drilling to 13611'. POOH for bit. RIH and drill ahead to 13660'. Continue drilling to 13819'. POOH for Bit. RIH. Continue RIH. Drill from 13819' to 13950'. POOH for bit. RIH. Drill from 13950' to 14160'. POOH for bit. :; ~ ~,~ 7/5/00 7/6/00 7/7/00 Continue POOH. RIH and drill from 14160' to 14203' Continue drilling to 14310'. POOH for bit. RIH Continue RIH. Drill ahead to 14491'. POOH. 7/8/00 Continue POOH. Pick up new bit and RIH. Drill from 14491' to 14660' 7/9/00 Circulate and POOH. Pick up new bit and RIH. Drill ahead to 14746'. 7/10/00 7/11/00 7/12/00 7/13/00 7/14/00 7/15/00 7/16/OO 7/17/00 7/18/00 7/19/00 7/20/00 7/21/00 Continue drilling to 14914'. POOH for bit. Make up XL motor, BHI "light" thruster and PDC bit. RIH and drill from 14914' to 15065'. Unable to control angle building tendency. POOH. Make ADM motor assembly and insert bit. RIH and drill 15065' to 15251' POOH for LWD logging run. Test BOP's. Make up tool string and RIH. Make MAD Pass from 11,800 to 15065'. Tight hole at TD. POOH with LWD assembly. Lay down MWD assembly. PU bit and RIH. Drill from 15251' to 15416'. Hole taking gradual losses. (47 bbl) POOH for bit. RIH to TD. Hole taking fluid in open hole. POOH for liner. (Lost 135bbls on trip in, pumping slug and POOH) Make up 129 jts (98 slotted, 28 pre-drilled 3 blank)4-1/2" slotted/perforated production liner. PU 124jts 2-1/16" CS Hydril inner string. Space out. Maske up HMC hanger and SL-ZXP packer. Circulate through inner string. Continue RIH with 3-1/2" and 5" drill pipe. RIH with liner. Circulate at 7" casing shoe. Attempt to run in open hole. Mud flowing up drill pipe. Pull back to 7" shoe and circulate and condition mud. Mud being pumped was 9.1 ppg. Mud returns 9.8 ppg. Continue RIH to 15,414'. Drop ball and set HMC packer.. Displace OBM from 6" x 4-1/2" annulus with Mapco base oil. Set ZXP and attempt to pressure test backside with 2000 psi. ZXP appears not to have set properly. Displace inner volume of liner with Mapco base oil. POOH with liner running assembly. PU seal stack and Baker test packer. RIH and attempt to stab into 4-1/2" tie-back extension. Seals do not appear to be entering. Set packer and test 7" and 9-5/8" casing above tie-back extension to 2000 psi- OK. Spot 130 bbls of Mapco in annulus above 4-1/2" liner top. POOH with test packer and seal stack. Lay down test packer and seals. Pull wear bushing and run 4-1/2" completion tubing, Baker 7" SAB-L packer and Camco TRSSSV. Make up tubing hanger and install BPV. Land tubing and prepare to nipple down BOP stack. Nipple down BOP stack and nipple up 4-1/2" tree. Displace well to Mapco 200. Drop ball/bar to set Baker SAB-I packer. Pressure up to 3000 psi and observe set. Pressure test annulus to 2000 psi for 15 minutes. RU Pollard Wireline and pull bar and RHC plug from X nipple. Turn well over to Production at 24:00 hrs 21 July 2000 .... :...-.' ' ~,- i; :.:,: UNOCAL ii RKB = 42' Rig Floor to DCB TBG Spool TOL (~ 7,471' 7 TOL (~ 11,510' SIZE GRAYLI~ PLATFORM WELL G-28RD Current Completion (7-21-00) CASING AND TUBING DETAIL WT GRADE CONN ID MD TOP MD BTM. 26" ½' Spiral Weld 25.00 Surf. 369' 20" 94 H-40 Buttress 19.125 Surf. 828' 13-3/8" 61 K-55 Buttress 12.415 Surf. 6,020' 9-5/8" 47 N-80 Buttress 8.681 Surf. 8,922' 9-5/8" 47 S-95 Buttress 8.681 8,922' 9,761 ' Window 7" 29 L-80 Buttress 6.184 7,471' 11,700' 4-1/2" 12.6 N-80 Hydril 511 3.958 11,510' 15,414' 4-1/2" pre-slotted liner has 48 slots/ft 2-1/2" x 1/16" 4-1/2" 8 hpf at 90 deg phasing Tubing: 4-1/2" 12.6 L-80 Mod Butt. (SPC) JEWELRY NO Depth ID Item 3.958 Surf 11,398' 1 39' 3.958" 2 291' 3.813 3 .3.833" 5 6 11,324' 4.00" 7 11,365 3.813" 8 9 11,398 2.992" 10 11,510' 11 11,578' 3.813' USIT log interpretation shows hole in 7"casing at 7953' CIW DCB Tubing Hanger: 4-1/2" Butt top & btm Camco TRDP-4AO (7.188"OD x 3.813 X Profile) 4-1/2" Camco MMG-M GLM w/1-1/2" RK latch (7.063" x 6.141") No. 1-5 2564', 4306', 5535', 6511', 7393' 4-1/2" Camco KBG-2 SPC GLM w/1" BK-2 latch (5.984" OD) No. 6-11 8034', 8578',9086',9565', 9614',10036' Baker KBH-22 Anchor. with 1' of nitrile seals Baker Model 85SAB-L47 x38 Hydraulic Set Permanent Packer with 6' mill out extension. Otis "X" nipple (3.813") I joint 4-1/2" 12.6 ib/ft L-80 Mod Butt Tbg. Mule shoe Baker SL-ZXP Liner Packer with 10' tie-back extension Otis "X" nipple ( In production liner) 9 TD =-15,416'; ETD =15,380' 10 7" shoe at 11700' REVISED: 7/20/00 DRAWN BY: NM UNOCAL ALASKA INC. GRAYLING Platform G-28Rd slot #3-12 McArthur River Field TBU, Cook Inlet, Alaska SURVEY LISTING Baker Hughes INTEQ Your ref : PMSS <9963 - ???~> Our ref : sv~6320 License : Date printed : 18-Jul-2000 Date created : 7-Jun-2000 Last revised : 18-Jul-2000 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.586,w151 36 46.409 Slot Grid coordinates are N 2502353.841, E 212278.208 Slot local coordinates are 1805.90 N 1407.10 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL ALASKA INC. GRAYLING Platform, G-28Rd McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees 0.00 0.00 0.00 100.00 0.00 0.00 200.00 0.00 0.00 300.00 1.50 201.75 400.00 0.50 229.75 500.00 0.50 179.25 600.00 0.00 0.00 700.00 0.50 220.25 800.00 0.00 0.00 900.00 0.00 0.00 1000.00 0.50 190.25 1100.00 0.50 210.50 1200.00 0.50 177.50 1300.00 0.50 227.50 1400.00 3.00 238.50 1500.00 6.50 226.75 1600.00 10.75 228.50 1700.00 12.00 244.25 1800.00 15.25 252.00 1900.00 16.50 244.50 2000.00 18.25 243.75 2100.00 20.00 245.25 2200.00 22.00 246.50 2300.00 24.00 248.00 2400.00 26.00 248.75 2500.00 28.00 249.25 2600.00 29.50 248.00 2700.00 32.75 247.75 2800.00 35.75 248.50 2900.00 38.50 3000.00 39.50 3100.00 40.00 3200.00 41.50 3300.00 42.00 3400.00 42.50 3500.00 43.25 3600.00 43.50 3700.00 44.50 3800.00 44.50 3900.00 45.25 4000.00 45.00 4100.00 44.75 4200.00 44.50 4300.00 44.50 4400.00 44.00 4500.00 44.50 4600.00 44.25 4700.00 42.00 4800.00 43.00 4900.00 44.75 SURVEY LISTING Page 1 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 248.25~' 2780.49 R E C T A N G U L A R Dogleg Vert Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 N 0.00 E 0.00 0.00 299.99 1.22 S 0.49 W 1.50 -1.05 399.97 2.71 S 1.30 W 1.08 -2.28 499.97 3.43 S 1.63 W 0.43 -2.89 599.97 3.87 S 1.62 W 0.50 -3.32 699.97 4.20 S 1.91 W 0.50 -3.56 799.97 ~ 4.53 S 2.19 W 0.50 -3.81 899.97 4.53 S 2.19 W 0.00 -3.81 999.96 4.96 S 2.27 W 0.50 -4.21 1099.96 5.77 S 2.57 W 0.18 -4.91 1199.96 6.58 S 2.77 W 0.28 -5.64 1299.95 7.31 S 3.07 W 0.42 -6.27 1399.90 8.97 S 5.62 W 2.51 -7.21 1499.54 14.22 S 11.98 W 3.61 -10.64 1598.39 24.28 S 23.09 W 4.26 -17.48 1696.45 34.98 S 39.45 W 3.34 -23.58 1793.63 43.57 S 61.32 W 3.72 -26.21 1889.82 53.74 S 86.65 W 2.40 -29.49 1985.26 66.78 S 113.52 W 1.76 -35.13 2079.73 80.87 S 143.09 W 1.82 -41.08 2173.09 95.50 S 175.80 W 2.05 -46.75 2265.13 110.59 S 211.84 W 2.08 -51.99 2355.76 126.15 S 251.13 W 2.02 -56.86 2444.86 142.42 S 293.51 W 2.01 -61.60 2532.53 159.96 S 338.29 W 1.62 -66.95 2618.12 179.43 S 386.17 W 3.25 -73.37 2700.77 200.38 S 438.40 W 3.03 -80.09 222.63 S 494.50 W 2.75 -87.05 248.00 2858.21 246.07 S 552.90 W 1.01 -94.59 248.25 2935.09 269.90 S 612.24 W 0.52 -102.24 249.25 3010.85 293.55 S 673.07 W 1.64 -109.34 249.50 3085.45 317.00 S 735.39 W 0.53 -115.87 249.25 3159.47 340.69 S 798.32 W 0.53 -122.46 249.25 3232.76 364.79 $ 861.95 W 0.75 -129.27 249.25 3305.44 389.12 S 926.17 W 0.25 -136.15 250.75 3377.38 412.87 S 991.44 W 1.44 -142.20 '250.75 3448.70 435.98 8 1057.62 W 0.00 -147.39 251.50 3519.57 458.80 S 1124.38 W 0.92 -152.16 251.50 3590.13 481.29 S 1191.58 W 0.25 -156.49 252.00 3660.99 503.38 S 1258.59 W 0.43 -160.49 252.00 3732.16 525.09 S 1325.39 W 0.25 -164.16 253.00 3803.49 546.17 S 1392.24 W 0.70 -167.22 253.75 3875.12 566.13 S 1459.10 W 0.72 -169.20 253.75 3946.75 585.66 S 1526.09 W 0.50 -170.72 254.00 4018.23 605.08 S 1593.27 W 0.31 -172.10 255.25 4091.21 623.22 S 1659.18 W 2.41 -172.56 254.25 4164.94 641.00 S 1724.35 W 1.21 -172.86 254.75 4237.02 659.51 S 1791.14 W 1.78 -173.46 All data is in feet unless otherwise stated. Coordinates from slot %3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6514.28 on azimuth 295.99 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 345.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA INC. GRAYLING Platform, G-28Rd McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 5000.00 42.75 254.75 4309.25 5100.00 43.75 256.25 4382.09 5200.00 43.75 256.75 4454.33 5300.00 41.75 256.00 4527.76 5400.00 39.25 251.75 4603.81 5500.00 39.25 251.75 4681.25 5600.00 37.50 252.00 4759.64 5700.00 38.50 250.75 4838.44 5800.00 37.50 251.45 4917.24 5900.00 37.00 251.75 4996.84 6000.00 36.50 251.50 5076.97 6100.00 36.00 251.50 5157.61 6200.00 37.00 251.75 5237.99 6300.00 36.50 250.75 5318.12 6400.00 37.25 250.50 5398.11 6500.00 37.00 251.25 5477.85 6600.00 37.00 251.75 5557.71 6700.00 38.00 251.75 5637.04 6800.00 38.50 251.75 5715.58 6900.00 38.50 252.00 5793.84 7000.00 38.25 251.30 5872.23 7100.00 39.50 251.00 5950.08 7200.00 39.00 251.50 6027.52 7300.00 38.75 251.00 6105.38 7400.00 37.50 250.75 6184.04 7500.00 36.50 250.00 6263.90 7600.00 36.50 249.75 6344.29 7700.00 35.50 249.75 6425.19 7800.00 35.00 249.25 6506.85 7900.00 33.75 249.50 6589.39 8000.00 33.25 249.50 6672.78 8100.00 33.00 249.25 6756.52 8200.00 33.25 249.50 6840.27 8300.00 32.75 249.75 6924.14 8400.00 32.75 250.50 7008.24 8500.00 33.00 250.50 7092.23 8600.00 34.25 250.75 7175.50 8700.00 35.75 251.25 7257.41 8800.00 37.25 250.25 7337.79 8900.00 36.25 250.50 7417.92 9000.00 36.25 250.50 7498.56 9100.00 35.50 251.00 7579.59 9200.00 35.50 252.00 7661.00 9300.00 36.00 252.00 7742.16 9400.00 36.25 252.00 7822.93 9500.00 35.00 252.00 7904.22 9600.00 34.25 252.75 7986.51 9700.00 34.25 254.50 8069.17 9750.00 34.37 254.37 8110.46 9778.00 36.45 255.20 8133.28 SURVEY LISTING Page 2 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 R E C T A N G U L A R Dogleg Vert C O O R D I N A T E S Deg/100ft Sect 677.70 S 1857.85 W 2.00 -173.76 694.85 S 1924.18 W 1.43 -173.16 710.99 S 1991.43 W 0.35 -171.35 726.97 S 2057.39 W 2.06 -169.71 744.94 S 2119.76 W 3.72 -170.92 764.75 S 2179.85 W 0.00 -174.51 784.07 S 2238.85 W 1.76 -177.89 803.74 S 2297.18 W 1.26 -181.79 823.68 S 2355.43 W 1.09 -185.99 842.79 S 2412.86 W 0.53 -189.58 861.65 S 2469.64 W 0.52 -193.10 880.41 S 2525.72 W 0.50 -196.71 899.16 S 2582.17 W 1.01 -200.21 918.39 S 2638.83 W 0.78 -204.12 938.30 S 2695.43 W 0.76 -208.70 958.07 S 2752.46 W 0.52 -213.04 977.17 S 2809.53 W 0.30 -216.71 996.23 S 2867.34 W 1.00 -220.16 1015.62 S 2926.14 W 0.50 -223.67 1034.99 S 2985.30 W 0.16 -227.07 1054.53 S 3044.22 W 0.50 -230.69 1074.81 S 3103.62 W 1.26 -234.91 1095.15 S 3163.53 W 0.59 -239.05 1115.32 S 3222.96 W 0.40 -243.15 1135.55 S 3281.29 W 1.26 -247.59 1155.75 S 3337.97 W 1.10 -252.44 1176.22 S 3393.82 W 0.15 -257.76 1196.56 S 3448.97 W 1.00 -263.13 1216.77 S 3503.03 W 0.58 -268.66 1236.66 S 3555.87 W 1.26 -274.20 1255.99 S 3607.57 W 0.50 -279.49 1275.24 S 3658.71 W 0.28 -284.85 1294.49 S 3709.86 W 0.28 -290.20 1313.45 S 3760.91 W 0.52 -295.30 1331.85 S 3811.79 W 0.41 -299.90 1349.96 S 3862.95 W 0.25 -304.16 1368.33 S 3915.19 W 1.26 -308.38 1387.00 S 3969.42 W 1.53 -312.38 1406.62 S 4025.57 W 1.61 -316.80 1426.72 S' 4081.93 W 1.01 -321.62 1446.45 S 4137.67 W 0.00 -326.26 1465.78 S 4192.99 W 0.81 -330.61 1484.20 S 4248.06 W 0.58 -334.15 1502.26 S 4303.63 W 0.50 -337.21 1520.48 S 4359.70 W 0.25 -340.29 1538.47 S 4415.09 W 1.25 -343.34 1555.68 S 4469.24 W 0.86 -345.95 1571.55 S 4523.23 W 0.98 -347.30 1579.11 S 4550.39 W 0.29 -347.58 1583.36 S 4566.04 W 7.61 -347.63 Ail data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6514.28 on azimuth 295.99 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 345.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~NOCAL ALASKA INC. GRAYLING Platform, G-28Rd McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert R E C T A N Depth Degrees Degrees Depth C O O R D I N 9963.82 31.56 277.60 8287.89 1591.07 S 10023.89 29.26 285.10 8339.71 1585.16 S 10057.29 28.71 290.01 8368.93 1580.29 S 10089.62 28.12 295.23 8397.37 1574.38 S 10117.65 26.81 299.79 8422.24 1568.43 S 10151.30 25.86 304.09 8452.40 1560.54 8 10182.13 25.60 305.86 8480.18 1552.87 S 10214.39 26.29 308.50 8509.19 1544.34 S 10246.69 27.49 313.00 8538.00 1534.80 S 10307.72 28.90 319.14 8591.79 1514.04 S 10339.72 29.55 323.78 8619.72 1501.82 S 10400.88 30.91 330.07 8672.58 1476.03 S 10433.97 31.67 333.00 8700.86 1460.93 S 10465.61 32.16 335.82 8727.72 1445.84 S 10497.68 33.05 340.37 8754.74 1429.82 S 10528.89 33.65 344.57 8780.81 1413.46 S 10561.13 34.09 347.39 8807.58 1396.03 S 10588.24 35.06 350.74 8829.91 1380.93 S 10619.62 36.88 355.03 8855.30 1362.65 S 10683.48 40.12 357.89 8905.28 1322.99 S 10713.53 41.18 358.24 8928.08 1303.42 S 10743.82 42.00 358.63 8950.73 1283.32 S 10778.67 43.70 359.09 8976.28 1259.63 S 10807.67 45.55 0.07 8996.92 1239.26 S 10840.44 46.80 1.02 9019.61 1215.62 S 10872.31 48.63 1.06 9041.05 1192.05 S 10904.11 49.75 1.87 9061.84 1167.99 S 10934.93 51.48 1.37 9081.39 1144.18 S 10967.49 54.27 0.87 9101.04 1118.22 S 10998.88 54.77 1.05 9119.26 1092.66 S 11028.10 54.30 0.75 9136.22 1068.87 S 11060.00 53.97 0.27 9154.90 1043.02 S 11091.87 53.99 1.19 9173.65 1017.24 S 11122.65 54.10 1.61 9191.72 992.34 S 11154.43 55.28 1.50 9210.09 966.41 S 11185.71 55.52 1.92 9227.85 940.68 S 11217.36 55.30 2.80 9245.82 914.64 S 11270.02 54.11 2.07 9276.24 871.70 S 11309.84 54.08 2.09 9299.60 839.47 S 11401.69 56.32 2.47 9352.01 764.11 S 11466.32 56.54 3.06 9387.75 710.33 S 11492.49 56.42 2.89 9402.20 688.54 8 11590.69 55.41 2.60 9457.24 607.30 11637.30 54.73 3.07 9483.92 569.14 S 11737.32 55.05 4.63 9541.45 487.50 S 11768.12 57.36 5.10 9558.58 462.00 S 11796.88 60.51 4.29 9573.42 437.45 S 11827.91 62.27 3.51 9588.28 410.28 S 11928.88 68.15 358.78 9630.62 318.70 S 12021.63 74.03 357.71 9660.66 231.04 S SURVEY LISTING Page 3 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 U L A R Dogleg Vert A T E S Deg/100ft Sect 4668.08 W 7.20 -328.67 4697.85 W 7.38 -315.26 4713.27 W 7.31 -306.56 4727.46 W 7.89 -297.18 4738.92 W 8.84 -288.46 4751.59 W 6.33 -277.57 4762.55 W 2.63 -267.32 4773.79 W 4.17 -256.17 4784.84 W 7.31 -244.10 4804.80 W 5.28 -218.87 4814.52 W 7.36 -204.56 4831.28 W 5.63 -175.31 4839.46 W 5.14 -158.60 4846.68 W 4.96 -142.16 4853.12 W 8.13 -125.02 4858.28 W 7.64 -107.89 4862.63 W 5.06 -89.93 4865.54 W 7.87 -74.59 4867.80 W 9.90 -56.34 4870.22 W 5.79 -17.40 4870.88 W 3.61 1.67 4871.43 W 2.84 21.22 4871.90 W 4.96 44.23 4872.05 W 6.81 63.95 4871.82 W 4.35 86.72 4871.39 W 5.74 109.38 4870.78 W 4.02 132.46 4870.10 W 5.75 155.29 4869.60 W 8.66 180.22 4869.17 W 1.66 204.80 4868.80 W 1.81 227.69 4868.57 W 1.60 252.60 4868.24 W 2.34 277.41 4867.63 W 1.16 301.31 4866.93 W 3.72 326.17 4866.16 W 1.35 350.83 4865.08 W 2.39 375.70 4863.26 W 2.53 416.70 4862.09 W 0.09 447.53 4859.08 W 2.46 519.55 4856.48 W 0.83 570.83 4855.35 W 0.71 591.58 4851.46 W 1.06 669.04 4849.57 W 1.68 705.42 4844.07 W 1.32 782.84 4841.90 W 7.61 806.92 4839.88 W 11.22 830.11 4838.03 W 6.09 855.88 4836.29 W 7.21 943.88 4838.99 W 6.43 1029.26 Ail data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6514.28 on azimuth 295.99 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 345.00 degrees. Calculation uses the minimum curvature method. Presented byBaker Hughes INTEQ UNOCAL ALASKA INC. GRAYLING Platform,G-28Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 4 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect 12119.76 78.50 356.36 9683.96 135.87 S 4843.93 W 4.75 1122.46 12212.67 83.30 357.16 9698.65 44.30 S 4849.11 W 5.24 1212.25 12307.18 89.33 358.16 9704.72 49.89 N 4852.96 W 6.47 1304.23 12339.38 90.23 357.98 9704.84 82.07 N 4854.04 W 2.85 1335.59 12365.03 90.50 357.91 9704.68 107.70 N 4854.96 W 1.09 1360.59 12427.56 91.47 358.20 9703.60 170.19 N 4857.09 W 1.62 1421.49 12521.40 91.27 357.02 9701.36 263.92 N 4861.00 W 1.28 1513.04 12619.22 94.46 354.93 9696.47 361.35 N 4867.85 W 3.90 1608.93 12683.00 95.90 353.96 9690.71 424.57 N 4874.00 W 2.72 1671.59 12745.35 96.98 353.85 9683.72 486.18 N 4880.58 W 1.74 1732.80 12777.40 96.58 355.83 9679.94 517.87 N 4883.44 W 6.26 1764.15 12813.96 97.45 356.01 9675.47 554.07 N 4886.02 W 2.43 1799.78 12907.48 96.00 358.13 9664.52 646.82 N 4890.77 W 2.73 1890.60 12937.64 96.03 359.03 9661.36 676.80 N 4891.51 W 2.97 1919.75 12999.59 95.38 358.03 9655.20 738.42 N 4893.09 W 1.92 1979.69 13032.63 94.05 357.46 9652.48 771.32 N 4894.39 W 4.38 2011.80 13089.79 94.25 356.81 9648.35 828.26 N 4897.24 W 1.19 2067.54 13131.34 95.07 356.35 9644.97 869.60 N 4899.71 W 2.26 2108.11 13164.38 94.28 355.63 9642.28 902.45 N 4902.01 W 3.23 2140.43 13185.27 94.29 356.61 9640.72 923.23 N 4903.42 W 4.68 2160.87 13227.63 94.81 357.66 9637.36 965.41 N 4905.53 W 2.76 2202.15 13261.56 93.91 358.60 9634.78 999.22 N 4906.63 W 3.83 2235.10 13292.66 93.12 359.55 9632.87 1030.26 N 4907.13 W 3.97 2265.21 13355.40 94.43 358.06 9628.74 1092.84 N 4908.44 W 3.16 2326.00 13384.54 96.22 357.27 9626.04 1121.83 N 4909.62 W 6.71 2354.31 13429.15 96.46 356.66 9621.11 1166.11 N 4911.97 W 1.46 2397.68 13460.79 96.09 356.44 9617.65 1197.50 N 4913.86 W 1.36 2428.50 13492.54 96.50 355.75 9614.17 1228.99 N 4916.01 W 2.52 2459.46 13553.08 95.84 352.86 9607.66 1288.87 N 4921.98 W 4.87 2518.86 13580.64 95.94 353.81 9604.83 1316.10 N 4925.16 W 3.45 2545.98 13647.11 96.67 351.86. 9597.53 1381.65 N 4933.40 W 3.12 2611.43 13674.71 97.05 350.84 9594.24 1408.74 N 4937.52 W 3.92 2638.66 13702.68 97.09 348.50 - 9590.79 1436.04 N 4942.50 W 8.30 2666.32 13757.28 97.50 344.98 9583.86 1488.75 N 4954.92 W 6.44 2720.45 13807.08 96.77 341.41 9577.67 1536.04 N 4969.21 W 7.26 2769.83 13837.90 96.97 339.98 9573.98 1564.92 N 4979.32 W 4 . 65 2800.34 13935.35 97 . 15 336.72 9562 . 00 1654 . 80 N 5015.00 W 3.33 2896.39 14027.73 95.12 334.42 9552.13 1738.41 N 5052.98 W 3.31 2986.99 14091.60 94.77 332.91 9546.62 1795.44 N 5081.21 W 2.42 3049.38 14152.82 95.45 332.23 9541.17 1849.56 N 5109.30 W 1.57 3108.92 14219.33 94.35 330.43 9535.49 1907.70 N 5141.09 W 3.16 3173.31 14284.97 94.72 330.35 9530.30 1964.59 N 5173.42 W 0.58 3236.63 14315.90 94 . 97 330 . 85 9527.69 1991.44 N 5188.55 W 1.80 3266.48 14378.20 95.70 330.28 9521.89 2045.46 N 5219.03 W 1.48 3326.55 14421.62 96.25 329.58 9517.37 2082.83 N 5240.67 W 2.04 3368.25 14474.10 94.80 329.00 9512.32 2127.74 N 5267.35 W 2.97 3418.53 14536.08 95.05 327.73 9507.00 2180.32 N 5299.74 W 2.08 3477.70 14596.58 95.93 324.91 9501.21 2230.43 N 5333.13 W 4.86 3534.74 14637.77 95.25 322.46 9497.20 2263.45 N 5357.40 W 6.15 3572.93 14696.79 96.20 323.11 9491.31 2310.22 N 5392.92 W 1.95 3627.29 Ail data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6514.28 on azimuth 295.99 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 345.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA INC. GRAYLING Platform, G-28Rd McArthur River Field,TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 14761.46 96.00 323.08 9484.44 14826.17 95.45 319.48 9477.98 14860.74 95.18 316.53 9474.78 14956.25 96.78 316.76 .9464.83 15053.03 98.00 318.76 9452.38 15115.31 95.95 319.58 9444.82 15176.48 95.95 318.85 9438.48 15210.32 96.30 320.06 9434.86 15241.02 96.30 319.28 9431.50 15306.55 96.93 321.13 9423.95 15338.48 96.60 322.01 9420.19 15416.00 96.50 321.00 9411.34 RECTANGULAR COORDINATES 2361.64 N 2411.87 N 2437.45 N 2506.51 N 2577.56 N SURVEY LISTING Page 5 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 2624.33 N 2670.40 N 2695.97 N 2719.23 N 2769.24 N 2794.08 N 2854.35 N Dogleg Vert Deg/100ft Sect 5431.54 W 0.31 3686.95 5471.80 W 5.60 3745.89 5494.83 W 8.53 3776.56 5560.04 W 1.69 3860.15 5624.56 W 2.41 3945.47 5664.97 W 3.54 4001.11 5704.72 W 1.19 4055.90 5726.59 W 3.70 4086.25 5746.34 W 2.53 4113.83 5788.00 W 2.96 4172.92 5807.71 W 2.93 4202.02 5855.64 W 1.30 4272.65 All data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6514.28 on azimuth 295.99 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 345.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA INC. GRAYLING Platform, G-28Rd McArthur River Field,TBU, Cook Inlet, Alaska SURVEY LISTING Page 6 Your ref : PMSS <9963 - ???'> Last revised : 18-Jul-2000 Target name Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Pt. 4 - 23 Mar 00 Pt. 3 - 23Mar 00 Pt. i - 23Mar 00 206374.000,2505492.000,0.0000 9380.00 207373.000,2504074.000,0.0000 9554.00 207502.000,2502289.000,0.0000 9493.00 2992.82N 1599.67N 181.65S 5979.24W 23-Mar-2000 4945.85W 23-Mar-2000 4773.22W 23-Mar-2000 ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL Field .................... : McArthur River Well ..................... : G-28RD API number ............... : 50-733-20324-01 Engineer ................. : COUNTY: .................. : Grayling / #54 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : GL above permanent ....... : -50000.00 ft KB above permanent ....... : -50000.00 ft DF above permanent ....... : 99.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 345.00 degrees 17-Jul-2000 03:41:07 ORIGINAL Spud date ................ : 02-Jun-00 Last survey date ......... : 16-Jul-00 Total accepted surveys...: 114 MD of first survey ....... : 9750.00 ft MD of last survey ........ : 15416.00 ft Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 00-Y- 0 Magnetic field strength.°: 1104.80 HCNT Magnetic dec (+E/W-) ..... : 21.18 degrees Magnetic dip ............. : 73.53 degrees MWD survey Reference Criteria Reference G .............. : 1002.03 mGal Reference H .............. : 1104.80 HCNT Reference Dip ............ : 73.53 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.18 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.18 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 RECEIVED AUG 2000 Alaska Oil & Gas Cons. Commissio~ Anchorage Seq -- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 Measured depth (ft) 9750.00 9778.00 9963.82 10023.89 10057.29 10089.62 10117.65 10151.30 10182.13 10214.39 10246.69 10307.72 10339°72 10400.88 10433.97 10465.61 10497.68 10528.89 10561.13 10588.24 10619.62 10683.48 10713.53 10743.82 10778.67 10807.67 10840.44 10872.31 10904.11 10934.93 Incl angle (deg) 34.40 36.45 31.56 29.26 28.71 28.12 26.81 25.86 25.60 26.29 27.49 28.90 29.55 30.91 31.67 32.16 33.05 33.65 34.09 35.06 36.88 40.12 41.18 42.00 43 .70 45.55 46.80 48.63 49.75 51.48 Azimuth angle (deg) 254.40 255.20 277.60 285.10 290.01 295.23 299.79 304.09 305.86 308.49 313.00 319.14 323.78 330.07 333.00 335.82 340°37 344.57 347.39 350.74 355.03 357.89 358.24 358.63 359.09 0.07 1.02 1.06 1.87 1.37 Course length (ft) 0.00 28.00 185.82 60.07 33.40 32.33 28.03 33.65 30.83 32.26 32.30 61.03 32.00 61.16 33.09 31.64 32.07 31.21 32.24 27.11 31.38 63.86 30.05 30.29 34.85 29.00 32.77 31.87 31.80 30.82 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 8110.46 8133.28 8287.88 8339.70 8368.92 8397.36 8422.23 8452.39 8480.17 8509.17 8537.99 8591.78 8619.71 8672.57 8700.85 8727.71 8754.73 8780.80 8807.57 8829.90 8855.29 8905.27 8928.07 8950.72 8976.27 8996.91 9019.60 9041.04 9061.83 9081.38 -347.56 -1579.10 -4550.40 -347.61 -1583.35 -4566.06 -328.65 -1591.06 -4668.09 -315.24 -1585.15 -4697.86 -306.54 -1580.28 -4713.29 -297.16 -1574.37 -4727.48 -288.44 -1568.41 -4738.94 -277.55 -1560.53 -4751.60 -267.30 -1552.86 -4762.57 -256.15 -1544.33 -4773.81 -244.08 -1534.79 -4784.86 -218.86 -1514.03 -4804.82 -204.54 -1501.81 -4814.54 -175.29 -1476.02 -4831.30 -158.58 -1460.92 -4839.48 -142.15 -1445.83 -4846.70 -125.00 -1429.81 -4853.14 -107.87 -1413.45 -4858.30 -89.91 -1396.02 -4862.65 -74.57 -1380.92 -4865.56 -56.32 -1362.64 -4867.83 -17.38 -1322.98 -4870.24 1.69 -1303.41 -4870.90 21.24 -1283.31 -4871.45 44.25 -1259.62 -4871.92 63.96 -1239.25 -4872.07 86.74 -1215.61 -4871.84 109.40 -1192.04 -4871.41 132.48 -1167.98 -4870.80 155.31 -1144.17 -4870.13 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) i00f) type type 4816.61 4832.80 4931.79 4958.09 4971.15 250.86 0.00 TIP 250.88 7.51 MWD_M 251.18 7.20 MWD_M 251.35 7.38 MWD_M 251.46 7.31 MWD_M 4982.74 251.58 7.89 MWD_M 4991.74 251.69 8.84 MWD_M 5001.30 251.82 6.33 MWD_M 5009.34 251.94 2.63 MWD_M 5017.39 252.07 4.16 MWD_M 5024.99 252.22 7.32 MWD_M 5037.71 252.51 5.28 MWD_M 5043.34 252.68 7.36 MWD_M 5051.74 253.01 5.63 MWD_M 5055.18 253.20 5.14 MWD_M 5057.76 5059.38 5059.73 5059.07 5057.73 253.39 4.96 MWD_M 253.58 8.13 MWD_M 253.78 7.64 MWD_M 253.98 5.06 MWD_M 254.16 7.87 MWD_M 5054.95 254.36 9.90 MWD_M 5046.74 254.80 5.79 MWD_M 5042.28 255.02 3.61 MWD_M 5037.65 255.24 2.84 MWD_M 5032.12 255.50 4.96 MWD_M 5027.21 255.73 6.81 MWD_M 5021.21 255.99 4.35 MWD_M 5015.14 256.25 5.74 MWD_M 5008.88 256.52 4.01 MWD_M 5002.72 256.78 5.75 MWD_M RECEIVED AUG CDO 2000 Alaska OiJ & Gas Cons. Commission Anchorage Seq 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 5O 51 52 53 54 55 56 57 58 59 60 Measured depth (ft) 10967.49 10998.88 11028.10 11060.00 11091.87 11122.65 11154.43 11185.71 11217.36 11270.02 11309.84 11401.69 11466.32 11492.49 11590.69 11637.30 11737.32 11768.12 11796.88 11827.91 11928.88 12021.63 12119.76 12212.67 12307.18 12339.38 12365.03 12427.56 12521.40 12619.22 Incl angle (deg) 54.27 54.77 54.30 53.97 53.99 54.10 55.28 55.52 55.30 54.11 54.08 56.32 56.54 56.42 55.41 54.73 55.05 57.36 60.51 62.27 68.15 74.03 78.50 83.30 89.33 90.23 9O.5O 91.47 91.27 94.46 Azimuth angle (deg) 0.87 1.05 0.75 0.27 1.19 1.61 1.50 1.92 2.80 2.07 2.09 2.47 3.06 2.89 2.60 3.07 4.63 5.10 4.29 3.51 358.78 357.71 356.36 357.16 358.16 357.98 357.91 358.20 357.02 354.93 Course length (ft) 32.56 31.39 29.22 31.90 31.87 30.78 31.78 31.28 31.65 52.66 39.82 91.85 64.63 26.17 98.20 46.61 100.02 30.80 28.76 3] .03 100.97 92.75 98.13 92.91 94.51 32.20 25.65 62.53 93.84 97.82 TVD depth (ft) 9101.03 9119.25 9136.21 9154.89 9173.64 9191.71 9210.08 9227.84 9245.81 9276.23 9299.59 9352.00 9387.74 9402.19 9457.23 9483.91 9541.44 9558.57 9573.41 9588.27 9630.61 9660.65 9683.95 9698.64 9704.71 9704.83 9704.67 9703.59 9701.35 9696.46 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 180.24 -1118.21 -4869.62 204.82 -1092.66 -4869.19 227.71 -1068.86 -4868.82 252.62 -1043.01 -4868.59 277.43 -1017.24 -4868.26 301.33 326.19 350.85 375.72 416.72 -992.33 -4867.65 -966.40 -4866.95 -940.67 -4866.18 -914.63 -4865.10 -871.69 -4863.28 447.55 519.56 570.85 591.60 669.06 -839.46 -4862.11 -764.10 -4859.10 -710.32 -4856.50 -688.53 -4855.37 -607.29 -4851.48 705.44 782.86 806.93 830.12 855.90 -569.13 -4849.59 -487.49 -4844.09 -461.99 -4841.92 -437.44 -4839.91 -410.27 -4838.05 943.90 1029.27 1122.48 1212.27 1304.24 -318.69 -4836.31 -231.03 -4839.01 -135.86 -4843.95 -44.29 -4849.13 49.90 -4852.98 1335.61 1360.61 1421.51 1513.06 1608.95 82.08 -4854.06 107.71 -4854.98 170.19 -4857.11 263.93 -4861.02 361.36 -4867.87 4996.36 257.07 8.66 MWD_M 4990.28 257.35 1.66 MWD_M 4984.76 257.62 1.81 MWD_M 4979.06 257.91 1.60 MWD_M 4973.40 258.20 2.34 MWD_M 4967.77 4961.97 4956.26 4950.33 4940.78 258.48 1.16 MWD_M 258.77 3.72 MWD_M 259.06 1.35 MWD_M 259.35 2.39 MWD_M 259.84 2.53 MWD_M 4934.04 4918.81 4908.17 4903.95 4889.34 260.20 0.09 MWD_M 261.06 2.46 MWD_M 261.68 0.83 MWD_M 261.93 0.71 MWD_M 262.87 1.06 MWD_M 4882.87 263.31 1.68 MWD_M 4868.56 264.25 1.32 MWD_M 4863.91 264.55 7.61 MWD_M 4859.63 264.84 11.22 MWD_M 4855.42 265.15 6.09 MWD_M 4846.80 266.23 7.21 MWD_M 4844.53 267.27 6.43 MWD_M 4845.86 268.39 4.75 MWD_M 4849.34 269.48 5.24 MWD_M 4853.24 270.59 6.47 MWD_M 4854.76 4856.18 4860.09 4868.18 4881.27 270.97 2.85 MWD_M 271.27 1.09 MWD_M 272.01 1.62 MWD_M 273.11 1.28 MWD_M 274.25 3.90 MWD_M RECEIVED ...~! Alaska Oil & Gas Cons. Commissior., ~.nchorage Seq 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 8O 81 82 83 84 85 86 87 88 89 90 Measured depth (ft) 12683.00 12745.35 12777.40 12813.96 12907.48 12937.64 12999.59 13032.63 13089.79 13131.34 13164.38 13185.27 13228.63 13292.66 13355.40 13384.54 13429.15 13460.79 13492.54 13553.08 13580.64 13647.11 13674.71 13702.68 13757.28 13807.08 13837.90 13935.35 14027.73 14091.60 Incl angle (deg) 95.90 96.98 96.58 97.45 96.00 96.03 95.38 94.05 94.25 95.08 94.28 94.29 94.81 93.12 94.43 96.22 96.46 96.09 96.50 95.84 95.94 96.67 97.05 97.09 97.50 96.77 96.98 97.15 95.12 94.77 Azimuth angle (deg) 353.96 353.85 355.83 356.01 358.13 359.03 358.03 357.46 356.81 356.36 355.63 356.61 357.66 359.55 358.06 357.27 356.66 356.44 355.75 352.86 353.81 351.86 350.84 348.50 344.98 341.41 339.98 336.72 334.42 332.91 Course length (ft) 63.78 62.35 32.05 36.56 93.52 30.16 61.95 33.04 57.16 41.55 33.04 20.89 43.36 64.03 62.74 29.14 44.61 31.64 31.75 60.54 27.56 66.47 27.60 27.97 54.60 49.80 30.82 97.45 92.38 63.87 TVD depth (ft) 9690.70 9683.71 9679.92 9675.46 9664.51 9661.35 9655.19 9652.47 9648.34 9644.96 9642.27 9640.71 9637.27 9632.84 9628.71 9626.00 9621.08 9617.62 9614.14 9607.63 9604.80 9597.50 9594.21 9590.76 9583.83 9577.64 9573.95 9561.97 9552.10 9546.59 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 1671.61 1732.82 1764.17 1799.80 1890.62 1919.77 1979.70 2011.82 2067.55 2108.12 2140.45 2160.89 2203.15 2265.23 2326.02 2354.33 2397.70 2428.51 2459.48 2518.87 2546.00 2611.44 2638.68 2666.34 2720.46 2769.85 2800.36 2896.41 2987.00 3049.39 424.58 -4874.02 486.19 -4880.60 517.88 -4883.46 554.08 -4886.04 646.83 -4890.79 676.81 -4891.53 738.43 -4893.11 771.33 -4894.41 828.27 -4897.26 869.61 -4899.73 902.46 -4902.03 923.24 -4903.44 966.41 -4905.60 1030.26 -4907.15 1092.85 -4908.46 1121.84 -4909.64 1166.11 -4911.99 1197.51 -4913.88 1228.99 -4916.03 1288.88 -4922.00 1316.11 -4925.18 1381.66 -4933.42 1408.75 -4937.54 1436.05 -4942.52 1488.76 -4954.94 1536.05 -4969.23 1564.93 -4979.34 1654.81 -5015.02 1738.42 -5053.00 1795.45 -5081.23 4892.48 4904.75 4910.84 4917.36 4933.37 274.98 2.72 MWD_M 275.69 1.74 MWD_M 276.05 6.26 MWD_M 276.47 2.43 MWD_M 277.53 2.73 MWD_M 4938.13 4948.52 4954o81 4966.81 4976.30 277.88 2.97 MWD_M 278.58 1.92 MWD_M 278°96 4.38 MWD_M 279.60 1.19 MWD_M 280.06 2.26 SP 4984.41 4989.60 4999.89 5014.14 5028.65 280.43 3.23 SP 280.66 4.68 SP 281.14 2.70 SP 281.86 3.95 SP 282.55 3.16 SP 5036.18 5048.51 5057.69 5067.32 5087.96 282.87 6.71 SP 283.35 1.46 SP 283.70 1.36 SP 284.04 2.52 SP 284.67 4.87 SP 5098.00 5123.25 5134.58 5146.92 5173.76 284.96 3.45 SP 285.65 3.12 SP 285.92 3.92 SP 286.20 8.30 SP 286.72 6.44 SP 5201.22 5219.47 5280.98 5343.68 5389.11 287.18 7.26 SP 287.45 4.65 SP 288.26 3.33 SP 288.99 3.31 SP 289.46 2.42 SP RECEIVED AUG Alaska O~ & r~.~-. 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis Seq -- 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 Measured depth (ft) 14152.82 14219.33 14284.96 14315.90 14378.20 14421.62 14474.10 14536.08 14596.58 14637.77 14696.79 14761.41 14826.17 14860°74 14956.25 14991.61 15053.03 15115.31 15176.48 15210.32 15241.02 15306.55 15338.46 15416.00 Incl angle (deg) 95.45 94.35 94.73 94.98 95.70 96.25 94.80 95.05 95.93 95.25 96.20 96.00 95.45 95.18 96.78 97.25 98.00 95.95 95.95 96.30 96.30 96.93 96.60 96.60 Azimuth angle (deg) 332.23 330.43 330.36 330.86 330.28 329.58 329.08 327.73 324.91 322.46 323.11 323.08 319.48 316.53 316.76 316.73 318.76 319.58 318.86 320.06 319.28 321.13 322.01 322.00 Course length (ft) 61.22 66.51 65.63 30.94 62.30 43.42 52.48 61.98 60.50 41.19 59.02 64.62 64.76 34.57 95.51 35.36 61.42 62.28 61.17 33.84 30.70 65.53 31.91 77.54 TVD Vertical Displ Displ Total depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) 9541.14 9535.46 9530.27 9527.65 9521.86 9517.34 9512.29 9506.97 9501.18 9497.17 9491o28 9484.41 9477.95 9474.75 9464.80 9460.48 9452.33 9444.76 9438.42 9434.81 9431.44 9423.89 9420.14 9411.22 3108.94 3173.33 3236.64 3266.49 3326.57 3368.27 3418.56 3477.73 3534.78 3572.97 3627.33 3686.95 3745.93 3776.60 3860.19 3891.10 3945.22 4000.86 4055.64 4086.00 4113.58 4172.67 4201.74 4272.65 1849.57 -5109.32 1907.71 -5141.11 1964.59 -5173.44 1991.45 -5188.57 2045.47 -5219.06 2082.84 -5240.69 2127.77 -5267.34 2180.37 -5299.69 2230.48 -5333.08 2263.50 -5357.36 2310.27 -5392.87 2361.65 -5431.46 2411.92 -5471.76 2437.49 -5494.79 2506.56 -5560.00 2532.12 -5584.05 2577.18 -5624.98 2623.95 -5665.39 2670.02 -5705.14 2695.58 -5727.01 2718.84 -5746.76 2768.86 -5788.42 2793.68 -5808.11 2854.38 -5855.53 At DLS Srvy Tool Azim (deg/ tool qual (deg) i00f) type type 5433.79 5483.65 5533.90 5557.62 5605.58 289.90 1.57 SP - 290.36 3.16 SP - 290.79 0.58 SP - 291.00 1.80 SP - 291.40 1.48 SP - 5639.42 5680.87 5730.68 5780.72 5815.90 291.67 2.04 SP - 292.00 2.92 SP - 292.36 2.21 SP - 292.70 4.86 SP - 292.90 6.15 SP - 5866.89 5922.68 5979.75 6011.16 6098.89 293.19 1.95 SP - 293°50 0.31 SP - 293.79 5.60 SP - 293.92 8.53 MWD - 294.27 1.69 SP - 6131.33 6187.26 6243.54 6299.01 6329.68 294.39 1.33 SP - 294.62 3.50 SP - 294.85 3.54 SP - 295.08 1.19 SP - 295.21 3.70 SP - 6357.46 6416.57 6445.06 6514.19 295.32 2.53 SP - 295.56 2.96 SP - 295.69 2.93 SP - 295.99 0.01 Projected TD RECEIVED 0 ..... '&laska Oil & ~.~.,-; C.9~s. ~, ,. ~ .... MEMORANDUM TO: ~an Seamount ~).~ ommissioner THRU' Blair Wondzell P.I. Supervisor FROM: Jeff Jones Petroleum I~s#cUctor NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 27, 2000 SUBJECT: -Blowout Preventer Tes~ Nabors #54 Unocal Conductor #12/Leg #3 G-28 RD 200-038 Operator Rep.: Terry Coleman Contractor Rep.' Rick Brumle¥ Op. phone: 776-6630 Rig phone: 776-6634 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 5000 MISC. INSPECTIONS: P/F Location Gen.: Housekeeping: PTD On Location Standing Order: P Sign: P Rig cond: P Hazard: P BOP STACK: Annular: 3500 Choke: 500 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm P/F Quantity P/F Trip Tank P P P Upper Kelly 1 Pit Level Indicators P P P Lower Kelly 1 Flow Indicator P P P Ball Type 1 Meth Gas Detector P F Inside BOP 1 H2S Gas Detector P P Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams I 2 7/8X5 P Quantity P/F System Pressure 3050 P Lower Pipe Rams I 5 P No. Valves 13 After Closure 1250 P Blind Rams 1 N/A P Man. Chokes I 200 psi Attained 38 sec. P Choke Ln. Valves 2 4 1/16 P Hyd. Chokes 2 Full Pressure 3.2 min. P HCR Valves I 4 1/16 P Blind Covers (All Stations): P Kill Line Valves 2 3 1/16 P N2 Bottles (avg): 4@ 2200 P Check Valve Test's Details On June 27, 2000 I traveled to Unocal's Grayling platform in Cook Inlet, where Nabors Drilling personnel were pulling out of the hole for a drillbit change and to test BOPE. Testing began at approximately 13:30 hrs. and concluded at 17:30 hrs. The rig equipment appeared clean and in good condition and the drilling crew performed the BOPE tests in a safe and competent manner, with no failures. Records kept on the rig floor indicate that all methane and H2S detectors were tested and calibrated on 6/20/00. I witnessed random gas alarm tests on the rig floor and mud pit detection devices with one failure. The methane high level alarm failed to activate in the mud pits. After calibration, this alarm system passed a re- test. Summary: I witnessed a weekly BOPE test and a random gas alarm system test on Unocal's Grayling platform where Nabors Drilling crews are performing a development re-drill operation on Unocal's well #G-28 RD. Total Test Time: 4hrs. Number of failures: CC.' Attachments: none Grayling BOPE Test 6-27-001 6/28/00 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION PLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: __ Time extension: __ Stimulate: __ Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: 99' KB above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Anchorage, AK 99519 Stratigraphic: Trading Bay Unit Service: X 4. Location of well at surface Conductor No.12, Leg 3 Grayling Platform 8. Well number 1317' FEL, 1666' FSL, Sec 29, T9N, R13W, SM G-28 At top of productive interval 9. Permit number 1719' FEL, 43' FNL, Sec 31, T9N, R13W, SM 79-07 At effective depth 10. APl number . 2122' FEL, 123' FNL, Sec 31, T9N, R13W, SM 50-733-20324 At ~.otal depth 11. Field/Pool 2186' FEL, 136' FNL, Sec 31, T9N, R13W, SM McArthur River / Hemlock 12. Present well condition summary Total depth: measured 12,425' feet Plugs (measured) true vertical 10,202' feet Effective depth: measured 12,420' feet Junk (measured) true vertical 10,199' feet Casing Length Size Cemented Measured depth True vertical depth Structural 369' 26" Driven 369' 369' Conductor 828' 20" 410 sx 828' 828' Surface 6,028' 13-3/8" 2,000 sx 6,028' 5,088' Intermediate Production 12,420' 9-5/8" 3,200 sx 12,420' 10,199' Liner Perfor.3.tion depth: measured B-1 (11728'-11768'), B-2 (11805'-11905'), B-3 (11935'-12005'), B-4(12034'-12154') true vertical B-1 (9680'-9712), B-2 (9739'-9813'), B-3 (9836'-9886'), B-4 (9908'-9991') Tubing (size, grade, and measured depth) 3-1/2" 9.3 Ib/ft, N-80 Buttress @ 11,686' Packers and SSSV (type and measured depth) Baker Model "D"Permanent packer set at 11,621' Otis SSSV at 305' 13. Attachments Description summary of proposal: X Detailed operations program: BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 4/22/2OOO 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X (water injector) 17. I hereby/d~'fy that the forecK)irkq ks true and correct to the best of my knowledge: Conditions of approval: Notify Commission so representative may witness IApprOval NO' Plug integrity__ BOP Test Location clearanceI Mechanical Integrity Test Subsequent form required 1 O- Approved by order of the Commissioner Commissioner Date ,,. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALASKA OIL AND GAS CONSERVATION COMPllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Williamson Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519 Re: Trading Bay Unit G-28RD UNOCAL Permit No' 200-038 SurLoc: 1317'FEL, 1666'FSL, Sec. 29, T9N, R13W, SM Btmhole Loc. 418'FNL, 1887'FEL, Sec. 30, T9N, R13W, SM Dear Mr. Williamson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Robert N. Christenson, P.E. Chair BY ORDER OF I'H~ COMMISSION DATED this 1~~ day of April, 2000 dlf/Enclosures Depamncnt of Fish & Grant. Habitat Section w/o encl. Department of Environmental Conservation vdo encl. Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) March 13, 2000 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 McArthur River Field, Hemlock Pool, Grayling Platform Well G-28RD REQUEST FOR SPACING EXCEPTION ADL 17594 Dear Chairman Christenson: Enclosed and submitted in triplicate is our application for Permit to Drill McArthur River Field, Grayling Platform Well G-28RD (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2003587 in the amount of $100.00 as required under 20 AAC 25.005 (c)(1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055 (b), is attached as part of this application. Conservation order 228 establishes ten-acre drilling units for the McArthur River Field. 20 AAC 25.055 (a)(3) provides that no more than one well is to be drilled within any governmental quarter section; not closer than 1,000' from any well drilling to or capable of producing from the same pool. It is requested that the Commission approve an exception to the statewide spacing regulation for the drilling of Well G-28RD, ADL 17594. The specific location, interval and depth for the McArthur River Field Well G-28RD are as follows: Surface Location: Surface Location: 1317 FEL, 1666' FSL, Sec 29, T9N, R13W, SM At Top Productive Interval: 1052' FSL, 614' FEL, Sec 30, T9N, R13W, SM At Total Depth: 418' FNL, 1887' FEL, Sec 30, T9N, R13W, SM Kickoff Point: 9250' MD (original wellbore) RECEIVED AIIia0il & Gas Cons. CommiM0n Anchorage ORIGINAL Distance to nearest well (Grayling O-29RD): 319' at 15,26TMD nets in the O.ggPd) well. Furthermore, or of all directly or .,~:~o interest o~ _~ ;q the operat~.~ t a~ notices .... are wor~'~, - and unoca~ Z ~C g5.~>> ~' .... d F orcenerg~ ~.o the o~ers ~ -~-, to 2~ A~ unoca~ anon ForcenergY ~__~ Thus, msu~5;cessary. &agonallY °I~~ti~uouS lanOOW~ · Ce locatiOn of registered mail to c~ = --~ is a lat shO~mg __n~ ~ the propeCY, or ~hich t~e exccv ~:~ ~n ~eBS f'and all ad5°ining properu~o and ' I[ you req~re additional info~atiOn, you may contact me at 90~.263-~882' sNcerelY, SharOn W. Mamn Enclosures RECEIVED MAR 1 4 2000 Alaska Oit & Gas Cons. ~mmission Anchora.qe VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK 1NLET, ALASKA ADL #17594 Well: McArthur River Field Well G-28RD I, SHANNON W. MARTIN, Land/Legal Analyst, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the McArthur River Field, Well G-28RD. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 13th day of March 13, 2000. Sh~'nnon W. Martin Land/Legal Analyst STATE OF ALASKA THIRD JUDICIAL DISTRICT ) ) ss ) SUBSCRIBED TO AND SWORN before me this 13th day of March 2000. ~~N0.0.~Ry P U~L~I/~'"""R~~ THE STATE OF ALASKA My Commission expires: ,4/~'O. Trading Bay Unit Grayling Platform Wel~ G-28RD PROPERTY PLAT ADL-21068 Unocal ADL-18758 Unocal Forcenergy g i Bay Unit Boundary SCALE iN FEET T9N TaN ADL-17602 Unocal ~ Forcenergy ADL-18777 Unocal CForcenergy KING K-18~- K-10 K-lORD G-29RD K-3RD ADL-17594-1,A Unocal Forcenergy GRAYLING D-4ORD D-il ;LHEAD Unocal Marathon D-26 ,A Unocal Forcenergy .... STATE OF ALASKA ALASKA 01 ..-tND GAS CONSERVATION Cb .vlMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill: Redrill: X I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (UNOCAL) 99' KB above MSL feet McArthur River Field 3. Address 6. Property Designation Hemlock P.O. Box 196247, Anchorage AK 99519 ADL 17594 4. Location of well at surface Conductor No.12 Leg 3 Grayling 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1317' FEL, 1666' FSL, Sec 29, T9N, R13W, S.M. Trading Bay Unit AK Statewide Oil & Gas Bond At top of productive interval 8. Well number Number U62-9269 1052' FSL, 614' FEL, Sec 30, T9N, R13W, S.M. G-28RD At total depth 9. Approximate spud date Amount $200,000 418' FNL, 1887' FEL, Sec 30, T9N, R13W, S.M. 5/2/2000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line Grayling G-29RD approches within 418' S of Sect 19 feet 319' at 15,262' MD feet 5116 15262' MD, 9405' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAO 2,5.035 (e)(2)) Kickoff depth: 9250' feet Maximum hole angle: 95 deg Maximum surface ~ ~(~)~'~sig At total depth (TVD) 4000 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD ~ (include stage data) Existing 26" 1" wall Driven 369' 42.6 42.6' 369' 369' ~- Driven Existing 20" 94 Lb H-40 Butt. 828' 42.6 42.6' 828' 828' /~,¢'~41~ ~-,.f~,_~,~ v~ Existing 13-3/8" !61/68 lb K-55 Butt. 6028' 37.0 37.0' 6028 5088' } 2000 sx ' Existing 9-5/8" 471b N-80/S-95 Butt. 9250' 36.4 36.4' 9250' KOP 7691'j 3200 sx 8-1/2" 7" 29 lb N-80 Butt. 1922' 9050' 7528' I 11422' 9500' 400 sx est. 6" 4-1/2" 12.6 lb L-80 Butt. 4040' 11222' 9383'I 15262' 9,,4~5.'. .... Uncemented 19. To be completed for ,edr,ll, Re-entry, and Deepen Operations. r bCEiVED Present well condition summary Total depth: measured 12425' feet Plugs (measured) true vertical 10202' feet MAR 1 4 2000 Effective depth: measured 12420' feet Junk (measured) Alaska OJJ & Ga~ Cons. true vertical 10199' feet Casing Length Size Cemented Measured depth True vertical depth Structural 369' 26" Driven 369' 369' Conductor 828' 20" 410 sx 822' 828' Surface 6028' 13-3/8" 2000 sx 6028' 5088' Intermediate 9250' KOP 9-5/8" 3200 sx 9250' 7691' Production 7" 400 sx 11422' 9500' Liner 4-1/2" NA 15262' 9405' Perforation depth: measured See attached schematic true vertical See attached schematic ORIGINAl 20. Attachments: Filing fee: X Property Plat: BOP Sketch: X Diverter Sketch: Drilling program: X Drilling fluid program: X Time vs. depth plot: Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: "Z.~ ~ - ~ ~ '"( I ¢¢c~zJ: ¢~.~,~ ,~ /3 /¢M ., Commission Use Only .~ Permit Number I APl number I '~e/}3/~ I See c°ver letter - z--o3z¢'-O / Approval 50- ' ' " I for other requirements Conditions of approval Samples required: [ lYes ,~No Mud Icg required: [ ] Yes ~No Hydrogen sulfide measures [ ] Yes ,~No Directional survey required ,~Yes [ ] No Required working pressure for BOPE [ ]2M; [ ]3M; ~SM; [ ]10M; [ ]15M Other: ORIGINAL SIGNED. BY by order of / Approved by Robert N. ~hristenson Commissioner the Commission Date: /i Form 10-401 Rev. 12-1-85 Submit in triplicate Preliminary Procedure Grayling G-28 Re-Drill Mill Window and Drill 8-1/2" hole MU one trip whipstock assembly. RIH with one trip whipstock assembly. Orient whipstock with SS. Set packer/whipstock @ 9250'. Mill window in 9-5/8" casing. Circulate bottoms up. POOH with setting tool. LD mills and MU drilling BHA. RIH with BHA. Drill 8-1/2" hole to 11422' Run 7" Liner 10 11 12 13 14 15 16 17 18 Change top pipe rams Test BOPE. RU casing crews for 7" liner RIH with 7" liner. Continue to RIH with liner on drillpipe. Set liner hanger and release running tool. Cement liner Set isolation packer and circulate string clean. POOH with running tool. Drill 6" hole 19 20 21 22 23 Make up 6" BHA and RIH PU 3-1/2" Change over mud system to OBM Drill 6" hole to TD at 15,262' Circulate and condition mud system. POOH with BHA. Lay down BHA Run 4-1/2" Slotted Liner (Hydril 511) 24 25 26 27 28 29 Test BOPE. RU to run 4-1/2" liner RIH with 4-1/2" slotted liner. MU false rotary table RIH with 2-7/8" PAC Continue to RIH with liner on drillpiPe. Set liner hanger and release running tool. 30 31 Displace liner to MAPCO 200. POOH with running tool. LD 2-7/8" PAC Clean out 7" liner 32 Mu tie-back mill and 9-5/8" scraper 33 RIH with clean TB receptacle 34 Dress TB and circulate hole clean 35 POOH with tie-back mill laying down DP Run Completion 36 37 38 39 40 41 42 43 44 45 46 Pull wear bushing. RU to run 4-1/2" GL completion PU, rabbit and run completion. Space out, install SCSSV and PU hanger Land hanger Lay down landing joint RD tubing running equip. ND BOPE. Install tree and test. Install Flowlines Deactivate Rig Attachment to Form 10-401 Permit to Drill Grayling G-28RD Hazard Analysis The proposed drilling of Grayling G-28RD will entail sidetracking the well from 9,250' (Potentially 9,450') and drilling an 8-1/2" hole to 11,422' This interval encompasses the Tyonek F and G sands. These sands are too low on structure to be hydrocarbon bearing and are expected to be normally to subnormally pressured. We plan on drilling this interval with a water based polymer mud system in the weight range from 9.0 to 9.5 ppg. If sloughing coals prove troublesome we have the ability to increase the mud weight to 10.0 ppg. There is evidence of from offset well information G-17RD, G-13, G-29, G- 29RD,G-27) that these coals will be encountered with the largest being at the base of the G interval. A potential for lost circulation exist whilst drilling the 8-1/2" hole interval. Measures have been taken to ensure that adequate supplies of LCM is available on board before drilling this hole section. The 6" hole section will encounter the Hemlock 1-3 intervals. There is a minor potential for coal sloughing. The Hemlock is expected to have a pressure gradient of.42 psi/ft. We plan on using an oil based mud system for drilling this interval with mud weights in the range of 8.8 ppg to 9.4 ppg. The maximum expected downhole pressures that may be encountered is based on offset well information which indicate that at 9405' TVD a pressure of 4000 psi may be expected. This equates to a gradient of.42 psi/ft. The maximum surface pressure which may be encountered assumes full evacuation of the wellbore to a depth of 9405' TVD and a methane gas gradient of.1 psi/ft. Thus 3060 psi surface pressure is assumed as the worst case. This well is not expected to encounter gas accumulations. The Hemlock zones which are offset to this well have been producing with an H2S content of up to 50 ppm. Prior to the drilling of G-28RD a full cascade system and individual SCBA's will be rigged up and placed in strategic locations on the platform. In addition a H2S Safety Technician will be onboard to service the equipment, conduct drills and refresh crew members in the proper use of this equipment. UNOCALe Trading Bay Unit Well # G-28 Proposed Abandonment RKB to TBG Spool = 36.00' 21' ~ 2 · · -- 11,621' HB-2 HB-3 HB-4 RKB to MLLW ELEV = 99' TD = 12,420' ETD = 11,600' MAX HOLE ANGLE = 45.25° @ 3900' SIZE 26" 20" 13-3/8" 9-5/8" 9-5/8" WT CASENG AND TUBING DETAIL GRADE CONN ID MD TOP MD TVD BTM. BTM ¼" Wall 94 61 & 68 47 47 Surf. 369' H-40 Butt 19.125 Surf. 828' K-55 Butt 12.415 Surf 6020' 5083' N-80 Butt 8.681 Surf 8922' 7424' S-95 Butt 8.681 8922' 12,420' 10,184' NO. #1 #2 Depth 11,600' 11,621' JEWELRY DETAIL ID Item 7" Halliburton EZSV 4.75" Baker Model D Packer Zone B-1 B-2 B-3 B-4 Top 11,728' 11,805' 11,935' 12,034' Btm 11,768' 11,905' 12,005' 12,154' Perforation Data Length Present Condition 40' Cmt. Squeezed 100' Cmt. Squeezed 70' Cmt. Squeezed 120' Cmt. Squeezed G-28 abandonment dwg REVISED: 3/21/00 DRAWN BY: NM UNOCAL RKB = 36' Rig Floor to DCB TBG Spool TOL ~.~ 9,050' 7 'rOL ~, 11,222' ]~ 8 TD = 15,262'; ETD =15,200,' TVD/MD GRAYLI. _; PLATFORM WELL G-28RD Proposed Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD TOP MD BTM. 26" ¼" Spiral Weld 2 Surf. 369' 20" 94 H-40 Buttress 19.125 Surf. 828' 13-3/8" 61 K-55 Buttress 12.415 Surf. 6,020' 9-5/8" 47 N-80 Buttress 8.681 Surf. 8,922' 9-5/8" 47 S-95 Buttress 8.681 8,922' 9,250' Window 7" 29 L-80 Buttress 6.184 9,050' 11,422' 4-1/2" 11.6 N-80 Hydri1511 3.958 11,222' 15,262' 4-1/2" pre-drilled liner has ¼" predrilled holes--8 hpf Tubing: 4-1/2" 12.6 L-80 Mod Buttress 3.958 Surf 9,000' JEWELRY NO Depth ID Item 1 36' 4.930" 2 300' 3 3.833" 4 8,950' 3.813" 5 9,000' 4.00" 6 9,025' " 7 9,045 " 8 11,400' 3.850' CIW DCB Tubing Hanger: 4-1/2" Butt top & btm Camco TBG Retrievable SCSSSV 4-1/2" Camco MMG-2 GLM w/1-1/2" RK latch (7.032" x 5.625") Baker 'XN' Nipple Baker Model F Permanent Packer with 18 ft seal-bore extension Baker tubing seal assembly (L= 20 ft) Baker tie-back seal assembly (L= 6.70 ft) Baker Knock out Isolation Valve (3.85" ID after drill out) G-28RD Proposed with GLM REVISED: 3/21/00 DRAWN BY: NM NIPPLE t5-5/8" 5000 PSl ANNULAR ] F"LOWLIN£ PIPE RAMS 15-5/8,, 5M FLANGE 3" KE.L.L!NE WITH TWO 3" 5M VALVES l' ;'t',' ,'j;, KILL LINE FROM MUG t=MF ~ CEMENT UNIT BLINO RAMS ,I [ RISER 00USLE GATE 5M CHOKE LINE WITH ONE REMOTE CONNE~ TO CHOKE ~NFOLQ i3-5/8" 5M F~NGE SINGLE GATE 5M 15-5/a" 5M ~NCE 10" 5M x lJ-5/8" 5,kt AD~TER CAMION 5M SPOOL [_ [ 15-5/8" BO?E 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (db~ UNOCAL) ".' '©R. AWN: OAC AFF'O: OS8 SCALE: NONE TO WELL CLF_AN T~N~( ~ CHOKE CHOKE 3-V~s" 3-V~s" 3-~/~s" 3-V~¢' FROM CHOKE LINE VALVES UPSTREAM OF CHOKES' ARE la,Goo Psi ~TE ~PE V~VE5 0~N~.U OF CHOKES ARE 5,000 PSI GATE ~PE CHOKE MANIFOLD GRAYLING PLAI-FOR ~ UNION OIL COMPANY OF CALIFOR~NIA (dbo UNOCAL) ORAWN: OAC AP P'O: G SE S C.¢~..E: NONE MIXING PIT ~o BBLS MIXING PIT IS A ONE LEVEL BELOW THE ACTIVE SYSTEM 185 BBLS VOLUME PIT TRIP 45 TANK BBLS 185 BBLS SUCTION PIT 125 BBLS 67 BBLS 24-0 BBLS SHAt<ER SI-IAI(ER CEN1-RIFUCE RESERVE PIT 475 BBLS HOTE: THE SYSTEM WILL BE EQUIPPED Wll"ll ^ DRILLIIqO__., PIT LEVEL INDICATOR AtJDiO a4 VISUAl_ WARNING DEVICES. WITH EQUIPMENT LIST 1) RESERVE PIT 2) DEGASSER 5) (2) SHAKERS 4-) PIT LEVEL INDICATOR (V~SUAL ~ ^Un~O) 5) FLUID FLOW SENSOR 6) TRIP TANK 7) PIT AGITATORS' 8) DESILTER 9) CENTRIFUGE lO) MIXING; PIT UNOCAL GRAYLING MUD PIT SCItEMATIC DRAWN BY: DAC APP'D: GSEI SCALE: NONE DATE: 1 1--Z~Q--[19 Created by Suthertond ~'0~'; N. M~,gee Dote plotted: 2B-Feb-2000 Plot Reference Is G-28Rd Version ~. Coordinotes ore ;n feet reference slot bt5-12. True VerUcol Depths ore reference wellhead. WELL PROFILE DATA UNOCAL Alaska Sfruofure: GRAYLING Platform Wall : G-28 Field : MaArfhur Rlver Field Looaflon: TBU, Cook Inlet, Alaska UNOCAL s <- West (feet) 6400 5600 4800 4.000 5200 2400 1600 800 0 I I I I I I I I I I I I I I I I I I (~) TD 2-10-00 ~ Heml (M;d Tgt)- 2-8-00 \ \ \ ~TGrl -2-9-001 ~ Hold / KOP 3200 2400 16oo 800 0 800 1600 2400 6400 6800 7200 7600 ~ 8000 t,~ 8400 ,.i,-,. >- 8800 I-- 9200 I 9600 1 oooo 10400 o;°~' ._._,_- ..... % 2-1o-oo Heml (Mid Tgt)- 2-8-00 i i i i i i i i i i i i i i i i i !i i i i ii I i ! i i i i i l 400 800 1200 1600 2000 2400 2800 5200 5600 4000 ¢400 4800 5200 5600 6000 6400 6800 Verfic(~l Section (feet) -> Azimuth 550.00 with reference 0.00 N, 0.00 E from slot #5-12 UNOCAL ALASKA GRAYLING Platform G-28 slot #3-12 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker HuGhes INTEQ Your ref : G-28Rd Version Our ref : prop3812 License : Date printed : 28-Feb-2000 Date created : 12-Jan-2000 Last revised : 28-Feb-2000 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on h60 50 4.803,w151 36 18.018 Slot location is n60 50 22.586,w151 36 46.409 Slot Grid coordinates are N 2502353.841, E 212278.208 Slot local coordinates are 1805.90 N 1407.10 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth 9250.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10100.00 10200.00 10300.00 10390.93 10500.00 10864.66 10900.00 11000.00 11100.00 11200.00 11300.00 11300.04 11422.08 11522.08 11622.08 11722.08 11822.08 11922.08 12022.08 12122.08 12200.00 12300.00 12400.00 12454.60 12500.00 12973.10 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13700.00 13800.00 13900.00 14000.00 14100.00 14200.00 14283.60 14300.00 PROPOSAL LISTING Page Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 R E C T A N G U L A R Dogleg Vert Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 35.75 252.00 7701.65 1493.20 S 4275.76 W 0.00 844.73 33.78 254.71 7742.72 .1501.38 S 4303.06 W 5.00 851.29 30.06 261.03 7827.60 1512.63 S 4354.66 W 5.00 867.35 26.72 268.87 7915.60 1516.98 S 4401.90 W 5.00 887.21 23.91 278.56 8006.03 1514.40 S 4444.44 W 5.00 910.71 21.84 290.31 8098.21 1504.92 S 4481.9~ W 5.00 937.67 20.75 303.77 8191.44 1488.61 S 4514.13 W 5.00 967.89 20.77 317.91 8285.00 1465.59 S 4540.76 W 5.00 1001.14 21.92 331.31 8378.20 1436.03 S 4561.62 W 5.00 1037.17 24.03 342.96 8470.31 1400.17 S 4576.56 W 5.00 1075.69 26.87 352.55 8560.63 1358.27 S 4585.46 W 5.00 1116.43 30.24 0.30 8648.49 1310.65 S 4588.26 W 5.00 1159.07 33.62 6.05 8725.66 1262.70 S 45.85.48 W 5.00 1199.21 33.62 6.05 8816.49 1202.64 S 4579.12 W 0.00 1248.04 33.62 6.05 9120.13 1001.84 S 4557.85 W 0.00 1411.31 35.34 5.34 9149.26 981.92 S 4555.87 W 5.00 1427.56 40.23 3.61 9228.27 920.86 S 4551.14 W 5.00 1478.08 45.14 2.21 9301.76 853.17 S 4547.74 W 5.00 1535.00 50.06 1.02 9369.16 779.37 S 4545.69 W 5.00 1597.89 55.00 0.00 9429.98 700.03 S 4545.00 W 5.00 1666.25 55.00 0.00 9430.00 700.00 S 4545.00 W 5.00 1666.28 55.00 0.00 9500.00 600.03 S 4545.00 W 0.00 1752.86 60.00 0.00 9553.71 515.72 S 4545.00 W 5.00 1825.87 65.00 0.00 9~99.87 427.04 S 4545.00 W 5.00 1902.67 70.00 0.00 9638.13 334.69 S 4545.00 W 5.00 1982.65 75.00 0.00 9668.19 239.34 S 4545.00 W 5.00 2065.22 80.00 0.00 9689.83 141.75 S ' 4545.00 W 5.00 2149.74 85.00 0.00 9702.88 42.63 S 4545.00 W 5.00 2235.58 90.00 0.00 9707.24 57.24 N 4545.00 W 5.00 2322.07 91.35 358.09 9706.32 135.14 N 4546.30 W 3.00 2390.18 93.08 355.64 9702.45 234.90 N 4551.76 W 3.00 2479.31 94.80 353.18 9695.58 334.18 N 4561.48 W 3.00 2570.15 95.74 351.83 9690.56 388.08 N 4568.57 W 3.00 2620.38 95.74 351.83 9686.02 432.80 N 4574.99 W 0.00 2662.31 95.74 351.83 9638.69 898.74 N 4641.90 W 0.00 3099.28 95.77. 351.02 9635.99 925.21 N 4645.89 W 3.00 3124.20 95.86 348.00 9625.86 1023.02 N 4664.00 W 3.00 3217.96 95.94 344.99 9615.57 1119.73 N 4687.22 W 3.00 3313.32 96.00 341.97 9605.17 1215.07 N 4715.50 W 3.00 3410.03 96.05 338.96 9594.67 1308.78 N 4748.75 W 3.00 3507.81 96.07 335.94 9584.11 1400.61 N 4786.88 W 3.00 3606.40 96.08 332.92 9573.52 1490.30 N 4829.79 W 3.00 3705.53 96.08 329.9i 9562.93 1577.60 N 4877.36 W 3.00 3804.93 96.06 326.89 9552.36 1662.29 N 4929.47 W 3.00 3904.32 96.02 323.87 9541.84 1744.12 N 4985.96 W 3.00 4003.43 95.96 320.86 9531.40 1822.87 N 5046.68 W 3.00 4101.99 95.89 317.84 9521.08 1898.32 N 5111.47 W 3.00 4199.73 95.80 314.83 9510.89 1970.28 N 5180.15 W 3.00 4296.38 95.72 312.31 9502.50 2027.60 N 5240.41 W 3.00 4376.16 95.72 312.31 9500.87 2038.58 N 5252.48 W 0.00 4391.70 Ail data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6536.74 on azimuth 294.23 degrees from wellhead. Total Dogleg for wellpath is 163.11 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 14400.00 95.72 312.31 9490.91 14500.00 95.72 312.31 9480.95 14600.00 95.72 312.31 9470.99 14700.00 95.72 312.31 9461.03 14800.00 95.72 312.31 9451.07 14900.00 95.72 312.31 9441.11 15000.00 95.72 312.31 9431.14 15100.00 95.72 312.31 9421.18 15200.00 95.72 312.31 9411.22 15262.41 95.72 312.31 9405.00 RECTANGULAR COORDINATES 2105.56 N 5326.06 W 2172.54 N 5399.65 W 2239.51 N 5473.23 W 2306.49 N 5546.82 W 2373.47 N 5620.40 W 2440.45 N 5693.99 W 2507.43 N 5767.57 W 2574.40 N 5841.16 W 2641.38 N 5914.74 W 2683.18 N 5960.66 W PROPOSAL LISTING Page 2 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Dogleg Vert Deg/100ft Sect 0.00 4486.50 0.00 4581.29 0.00 4676.09 0.00 4770.89 0.00 4865.69 0.00 4960.48 0.00 5055.28 0.00 5150.08 0.00 5244.87 0.00 5304.03 TD 2-10-00 Ail data is in feet unless otherwise stated. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6536.74 on azimuth 294.23 degrees from wellhead. Total Dogleg for wellpath is 163.11 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 3 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Comments in wellpath Comment 15262.41 9405.00 Target name 2683.18 N 5960.66 W TD 2-10-00 Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Heml (Mid Tgt) - 2-8 207089.000,2504509.000,0.0000 TGT 1 - 2-9-00 207808.000,2502485.000,0.0000 TD 2-10.-00 206385.000,2505182.000,0.0000 9502.50 2027.60N 5240.41W 9-Feb-2000 9700.00 21.78N 4472.11W 9-Feb-2000 9405.00 2683.18N 5960.66W 9-Feb-2000 UNOCAL ALASKA GRAYLING Platform G-28 slot #3-12 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : G-28Rd Version #6 Our ref : prop3812 License : Date printed : 28-Feb-2000 Date created : 12-Jan-2000 Last revised : 28-Feb-2000 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.586,w151 36 46.409 Slot Grid coordinates are N 2502353.841, E 212278.208 Slot local coordinates are 1805.90 N 1407.10 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 9250.00 35.75 252.00 7701.65 312.70N 5682.86W 0.00 844.73 207967.23 2500965.68 9300.00 33.78 254.71 7742.72 304.52N 5710.16W 5.00 851.29 207939.74 2500958.17 9400.00 30.06 261.03 7827.60 293.27N 5761.76W 5.00 867.35 207887.88 2500948.19 9500.00 26.72 268.87 7915.60 288.92N 5809.00W 5.00 887.21 207840.55 2500945.00 9600.00 23.91 278.56 8006.03 291.50N 5851.54W 5.00 910.71 207798.09 2500948.61 9700.00 21.84 290.31 8098.21 300.98N 5889.04W 5.00 937.67 '207760.83 2500959.01 9800.00 20.75 303.77 8191.44 317.29N 5921.23W 5.00 967.89 207729.05 2500976.10 9900.00 20.77 317.91 8285.00 340.31N 5947.86W 5.00 1001.14 207702.99 2500999.77 10000.00 21.92 331.31 8378.20 369.87N 5968.72W 5.00 1037.17 207682.86 2501029.82 10100.00 24.03 342.96 8470.31 405.73N 5983.66W 5.00 1075.69 207668.80 2501066.04 10200.00 26.87 352.55 8560.63 447.63N 5992.56W 5.00 1116.43 207660.93 2501108.15' 10300.00 30.24 0.30 8648.49 495.25N 5995.36W 5.00 1159.07 207659.29 2501155.82 10390.93 33.62 6.05 8725.66 543.20N 5992.58W 5.00 1199.21 207663.24 2501203.69 10500.00 33.62 6.05 8816.49 603.26N 5986.22W 0.00 1248.04 207671.07 2501263.58 10864.66 33.62 6.05 9120.13 804.06N 5964.95W 0.00 1411.31 207697.24 2501463.80 10900.00 35.34 5.34 9149.26 823.98N 5962.97W 5.00 1427.56 207699.71 2501483.65 11000.00 40.23 3.61 9228.27 885.04N 5958.24W 5.00 1478.08 207705.93 2501544.59 11100.00 45.14 2.21 9301.76 952.73N 5954.84W 5.00 1535.00 207710.99 2501612.17 11200.00 50.06 1.02 9369.16 1026.53N 5952.79W 5.00 1597.89 207714.85 2501685.90 11300.00 55.00 0.00 9429.98 1105.87N 5952.10W 5.00 1666.25 207717.48 2501765.19 11300.04 55.00 0.00 9430.00 1105.90N 5952.10W 5.00 1666.28 207717.48 2501765.23 11422.08 55.00 0.00 9500.00 1205.87N 5952.10W 0.00 1752.86 207719.92 2501865.17 11522.08 60.00 0.00 9553.71 1290.18N 5952.10W 5.00 1825.87 207721.98 2501949.45 11622.08 65.00 0.00 9399.87 1378.86N 5952.10W 5.00 1902.67 207724.15 2502038.10 11722.08 70.00 0.00 9638.13 1471.21N- 5952.10W 5.00 1982.65 207726.41 2502130.43 11822.08 75.00 0.00 9668.19 1566.56N 5952.10W 5.00 2065.22 207728.74 2502225.74 11922.08 80.00 0.00 9689.83 1664.15N . 5952.10W 5.00 2149.74 207731.13 2502323.31 12022.08 85.00 0.00 9702.88 1763.27N 5952.10W 5.00 2235.58 207733.56 2502422.39 12122.08 90.00 0.00 9707.24 1863.14N 5952.10W 5.00 2322.07 207736.00 2502522.23 12200.00 91.35 358.09 9706.32 1941.04N 5953.40W 3.00 2390.18 207736.61 2502600.14 12300.00 93.08 355.64 9702.45 2040.80N 5958.86W 3.00 2479.31 207733.59 2502700.01 12400.00 94.80 353.18 9695.58 2140.08N 5968.58W 3.00 2570.15 207726.30 2502799.49 12454.60 95.74 351.83 9690.56 2193.98N 5975.67W 3.00 2620.38 207720.53 2502853.55 12500.00 95.74 351.83 9686.02 2238.70N 5982.09W 0.00 2662.31 207715.20 2502898.41 12973.10 95.74 351.83 9638.69 2704.64N 6049.00W 0.00 3099.28 207659.71 2503365.85 13000.00 95.77 351.02 9635.99 2731.11N 6052.99W 3.00 3124.20 207656.37 2503392.41 13100.00 95.86 348.00 9625.86 2828.92N 6071.10W 3.00 3217.96 207640.66 2503490.63 13200.00 95.94 344.99 9615.57 2925.63N 6094.32W 3.00 3313.32 207619.81 2503587.88 13300.00 96.00 341.97 9605.17 3020.97N 6122.60W 3.00 3410.03 207593.87 2503683.88 13400.00 96.05 338.96 9594.67 3114.68N 6155.85W 3.00 3507.81 207562.92 2503778.38 13500.00 96.07 335.94 9584.11 3206.51N 6193.98W 3.00 3606.40 207527.05 2503871.11 13600.00 96.08 332.92 9573.52 3296.20N 6236.89W 3.00 3705.53 207486.35 2503961..82 13700.00 96.08 329.91 9562.93 3383.50N 6284.46W 3.00 3804.93 207440.92 2504050.26 13800.00 96.06 326.89 9552.36 3468.19N 6336.57W 3.00 3904.32 207390.91 2504236.20 13900.00 96.02 323.87 9541.84 3550.02N 6393.06W 3.00 4003.43 207336.44 2504219.38 14000.00 95.96 320.86 9531.40 3628.77N 6453.78W 3.00 4101.99 207277.~6 2504299.59 14100.00 95.89 317.84 9521.08 3704.22N 6518.57W 3.00 4199.73 207214.74 2504376.61 14200.00 95.80 314.83 9510.89 3776.18N 6587.25W 3.00 4296.38 207147.84 2504450.22 14283.60 95.72 312.31 9502.50 3833.50N 6647.51W 3.00 4376.16 207089.00 2504509.00 14300.00 95.72 312.31 9500.87 3844.48N 6659.58W 0.00 4391.70 207077.20 2504520.28 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from SE Corner of Sec. 29, TgN, R13W SM'and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6536.74 on azimuth 294.23 degrees from wellhead. Total Dogleg for wellpath is 163.11 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Measured Inclin Azimuth Depth Degrees Degrees 14400.00 95.72 312.31 14500.00 95.72 312.31 14600.00 95.72 312.3t 14700.00 95.72 312.31 14800.00 95.72 312.31 14900.00 95.72 312.31 15000.00 95.72 312.31 15100.00 95.72 312.31 15200.00 95.72 312.31 15262.41 95.72 312.31 PROPOSAL LISTING Page 2 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 9490.91 3911.46N 6733.16W 0.00 4486.50 207005.28 2504589.03 9480.95 3978.44N 6806.75W 0.00 4581.29 206933.35 2504657.79 9470.99 4045.41N 6880.33W 0.00 4676.09 206861.43 2504726.55 9461.03 4112.39N 6953.92W 0.00 4770.89 206789.50 2504795.30 9451.07 4179.37N 7027.50W 0.00 4865.69 206717.58 2504864.06 9441.11 4246.35N 7101.09W 0.00 4960.48 206645.65 2504932.82 9431.14 4313.33N 7174.67W 0.00 5055.28 206573.73 2505001.58 9421.18 4380.30N 7248.26W 0.00 5150.08 206501.81 2505070.33 9411.22 4447.28N 7321.84W 0.00 5244.87 206429.88 2505139.09 9405.00 4489.08N 7367.76W 0.00 5304.03 206385.00 2505182.00 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from SE Corner of Sec. 29, T9N, R13W SM and TVD from wellhead (99.00 Ft above mean sea level). Bottom hole distance is 6536.74 on azimuth 294.23 degrees from wellhead. Total Dogleg for wellpath is 163.11 degrees. Verti6al section is from wellhead on azimuth 330.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Comments in wellpath PROPOSAL LISTING Page 3 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 MD TVD Rectangular Coords. Comment 15262.41 9405.00 Target name 4489.08N 7367.76W TD 2-10-00 Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Heml (Mid Tgt) - 2-8 207089.000,2504509.000,0.0000 TGT 1 - 2-9-00 207808.000,2502485.000,0.0000 TD 2-10-00 206385.000,2505182.000,0.0000 9502.50 3833.50N 6647.51W 9-Feb-2000 9700.00 1827.68N 5879.21W 9-Feb-2000 9405.00 4489.08N 7367.76W 9-Feb-2000 iCreated by Sutherland ];'Or: N. Mcgee Date plotted: 28-Feb-2000 Plot Reference Is G-28Rd Version Coordinates are in feet r~ference slot ~5-12. True VertiCal Del:)ths are reference wellheod. 32O UNOCAL Alaska Sfruafure: GRAYLING Plafform Well: G-28 Field : MoArthur River FieldLooaflon: TBU, Cook Inlef, Alaska 33O 340 TRUE NORTH 350 0 10 20 3O UNOCAL 4O 310 50 300 6O 290 7O 28O 80 270 9O 260 100 250 110 240 120 230 10000 210 200 190 180 170 160 150 140 130 Normol Plone Trevelling Cylinder - Feet All depths shown ere Me(]sured depths on Reference Well Created by Suf. herlond For: N~ MKgee Dote plotted: 2B-Fab-200O Plot Reference la G-ZERd Version ~6. Coorflrnotes ore in feet ~ference slot True VerUcol Depths ere reference wellheod. <- West (feet) 4700 4600 4500 4400 4500 4200 I I I ,I I I I I I I , 1 oo o 9700 lOO 200 500 400 500 600 700 aoo 900 1 ooo 11oo 1200 1500 1400 1500 1600 v0 -000 ,~Co:~O0 ~ ! I I I %o % ~o i i i ! i i i I i i i 4700 4-600 4500 4-400 4300 4200 <- West (feet) UNOCAL Alaska Structure: GRAYLING Plofform Well : 9-28 Field : MoArfhur River Field LooQflon : TBU, Cook Inlet, UNOCALM 200 1 O0 0 100 200 500 4OO 500 0 600 - 700 600 I 900 lOOO 11oo 1200 15oo 14oo 1500 1600 <- West (feeO 6400 6000 5600 5200 4800 4400 4000 2800 2400 2000 1600 v 1200 0 Z 800 400 ~2800 ~- '~'b',~ ~.~- ~ _ ~ 69oo I ' \ ~""~_~,~,bO~ ~.,~ ~6700 h F ooo i i i i i i i i i i 6400 6000 5600 5200 4~00 4400 4000 <- West feet 6000 5600 5200 4800 4400 4000 ~600 1600 ~ ~ 1600 400 400 : ~ ~ ~ I ~ o " 800 ~ ~00 800 I ~ ~200 ~ 9000 ~ 2o0 ~ 8800 70~ ~200 ~ 8600 1600 1600 I I I I I I I I I I 6000 5600 5200 4~00 4400 4000 5600 <- West (feet) UNOCAL ALASKA GRAYLING Platform G-28 slot #3-12 McArthur River Field TBU, Cook Inlet, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker Hughes INTEQ REPORT Your ref : G-28Rd Version Our ref : prop3812 License : Date printed : 28-Feb-2000 Date created : 12-Jan-2000 Last revised : 28-Feb-2000 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 50 4.803,w151 36 18.018 Slot location is n60 50 22.586,w151 36 46.409 Slot Grid coordinates are N 2502353.841, E 212278.208 Slot local coordinates are 1805.90 N 1407.10 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method PGMS <0-13700'>,,D-6Rd, DOLLY VARDEN Platform MSS <6662-12195'>,,D-6, DOLLY VARDEN Platform MSS <l1790-15510'>,,D-6St, DOLLY VARDEN Platfor PGMS <0-13111'>,,D-29Rd, DOLLY VARDEN Platform GMS <100-13050'>,,D-29, DOLLY VARDEN Platform PGMS <0-10873'>,,D-48,DOLLY VARDEN Platform GMS <800-2700'>,,D-10,DOLLY VARDEN Platform MSS <2742-13908'>,,D-10, DOLLY VARDEN Platform PMSS <12052 - 12438'>,,D-TRd#2,DOLLY VARDEN P1 GMS <0-12900'>,,D-7Rd, DOLLY VARDEN Platform GMS <9600-13300'>,,D-7,DOLLY'VARDEN Platform GMS <0-14600'>,,D-16,DOLLY VARDEN Platform PGMS <10000-14645'>,,D-16Rd, DOLLY VARDEN Platf GMS <0-13585'>,,D-24A, DOLLY VARDEN Platform GMS <0-10628'>,,D-31Rd, DOLLY VARDEN Platform MSS <2450-10125'>,,D-31,DOLLY VARDEN Platform MSS <9482-12425'>,,D-2Rd, DOLLY VARDEN Platform MSS <6927-12557'>,,D-2,DOLLY VARDEN Platform GMS <0-11356'>,,D-2ARd, DOLLY VARDEN Platform MSS <l1209-14850'>,,D-22,DOLLY VARDEN Platform MSS <1205-10506'>,,D-20, DOLLY VARDEN Platform GMS <0-13600'>,,D-14Rd, DOLLY VARDEN Platform MSS <7866-12700'>,,D-14,DOLLY VARDEN Platform Last revised Distance M.D. Diverging from M.D. 29-Ju1-1996 11770.5 9250.0 9250.0 29-Ju1-1996 11770.5 9250.0 9250.0 29-Ju1-1996 11770.5 9250.0 9250.0 29-Ju1-1996 8300.8 9250.0 10476.0 · 29-Ju1-1996 8297.8 9250.0 9250.0 15-Feb-2000 7373.4 9663.6 9663.6 29-Ju1-1996 11381.7 9250.0 9250.0 29-Ju1-1996 10803.0 9250.0 9250.0 29-Ju1-1996 7096.4 · 9250.0 9250.0 29-Ju1-1996 6917.4 9250.0 9250.0 29-Ju1-1996 6958.3 9250.0 9250.0 29-Ju1-1996 12033.0 9250.0 10563.0 29-Ju1-1996 12033.0 9250.0 10563.0 29-Ju1-1996 10247.5 9250.0 9250.0 29-Ju1-1996 7133.8 9250.0 9250.0 29-Ju1-1996 8084.3 9350.0 9350.0 29-Ju1-1996 9781.4 9250.0 9250.0 29-Ju1-1996 9781.4 9250.0 9250.0 29-Ju1-1996 9854.4 9250.0 9250.0 29-Ju1-1996 12180.1 9250.0 14262.7 29-Ju1-1996 7926.6 9727.3 9727.3 29-Ju1-1996 11834.5 9250.0 9675.0 29-Ju1-1996 11834.5 9250.0 9675.0 PGMS <700-12250'>,,D-SRd, DOLAY VARDEN Platform MSS <8722-13932'>,,D-8,DOLLY VARDEN Platform PGMS <0-11150'>,,D-43,DOLLY VARDEN Platform MSS <8330-11350'>,,D-25, DOLLY VARDEN Platform GMS <0-11510'>,,D-25Rd, DOLLY VARDEN Platform GMS <0-11600'>,,D-41,DOLLY VARDEN Platform PGMS <0-12520'>,,D-40Rd, DOLLY VARDEN Platform GMS <6100-12573'>, , D-40, DOLLY VARDEN Platform MSS <2506-11160'>,,D-32,DOLLY VARDEN Platform GMS <0-12445'>,,D-28,DOLLY VARDEN Platform GMS <0-11000'>,,D-27,DOLLY VARDEN Platform MSS <2727-11000'>,,D-13, DOLLY VARDEN Platform PGMS <0-10300'>,,D-45,DOLLY VARDEN Platform PGMS <6600-10920'>,,D-3Rd2,DOLLY VARDEN Platfo GMS <0-10881'>,,D-3, DOLLY VARDEN Platform PGMS <8700-11100'>,,D-3Rd, DOLLY VARDEN Platfor GMS <0-10935'>,,D-15Rd, DOLLY VARDEN Platform PGMS <2100-10225'>,,D-15Rd2,DOLLY VARDEN Platf GMS <0-10650'>,~D-5Rd, DOLLY VARDEN Platform MSS <2642-10250'>,,D-5, DOLLY VARDEN Platform PGMS <0-12345'>,,D-46,DOLLY VARDEN Platform MSS <2944-7950'>,,D-19, DOLLY VARDEN Platform MSS <6059-16650'>,,D-19St, DOLLY VARDEN Platfor PGMS <0-10900'>,,D-9Rd,.DOLLY VARDEN Platform GMS <5600-10700'>,,D-9, DOLLY VARDEN Platform MSS <2701-11682'>,,D-ii,DOLLY VARDEN Platform GMS <0-10800'>,,D-17Rd, DOLLY VARDEN Platform MSS <10665-11808'>,,D-17,DOLLY VARDEN Platform MSS <0-12071'>,,D-1,DOLLY VARDEN Platform GMS <0-12237'>,,D-30Rd, DOLLY VARDEN Platform MSS <10156-13600'>,,D-30,DOLLY VARDEN Platform MSS <2220-8175'>,,D-18,DOLLY VARDEN Platform PGMS <8000712100'>,,D-4Rd, DOLLY VARDEN Platfor GMS <0-11100'>,,D-4,DOLLY VARDEN Platform GMS <0-11180'>,,D-34,DOLLY VARDEN Platform MSS <2730-13462'>,,D-24,DOLLY VARDEN Platform 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 MSS <3550-16606'>,,D-23, DOLLY VARDEN Platform - 29-Ju1-1996 PGMS <0-10450'>,,D-42,DOLLY VARDEN Platform 29-Ju1-1996 MSS <10913-11930'>,,D-47~DOLLY VARDEN Platform 29-Ju1-1996 PGMS <0-12970'>,,D-44,DOLLY VARDEN Platform MSS <3550-17010'>,,D-21, DOLLY VARDEN Platform PMSS <10743 - l1500'>,,D-26Rd2,DOLLY VARDEN P1 GMS <0-11905'>,,D-26,DOLLY VARDEN Platform PMSS <10743-10834>,,D-26Rdl,DOLLY VARDEN Platf GMS <0-12050'>,,D-12Rd, DOLLY VARDEN Platform MSS <9453-12381'.>,,D-12,DOLLY VARDEN Platform GMS <0-12900'>,,K-21,KING SALMON Platform GMS <10600-12540'>,,K-21Rd, KING SALMON Platfor PGMS <0-14325'>,,K-25, KING SALMON Platform MSS <2063-10825'>,,K-16,KING SALMON Platform Steering Tool,,K-24,KING SALMON Platform PGMS <9300-14384'>OLD,,K-24,KING SALMON Platfo EMS <8955 - l1078'>,,K-26Rd, KING SALMON Platfo MSS <2622-13927'>OLD,,K-8,KING SALMON Platform PGMS <2600-14548'>OLD,,~-SRd, KING SALMON Platf Conductor <GSS 0-375>,,K-8,KING SALMON Platfor Surface <375-???>,,K-8,KING SALMON Platform K-SRd #1 <6905-14264>,,K-SRd,KING SALMON Platf PGMS <0-2500'> NEW,,K-SRd,~ING SALMON Platform GSS ~492-855'>,,K-26,KING SALMON Platform PMSS <981-10956'>,,~-26,KING SALMON Platform K-SRd #2 <6905-11570>,,K-SRd, KING SALMON Platf PGMS <0-13771'>,,K-19, KING SALMON Platform GMS <8900-13463'>,,K-10,KING SALMON Platform GMS <0-12822'>,,~-lORd,~ING SALMON Platform GMS <2600-11767'>,,K-3,~ING SALMON Platform GMS <0-13413'>,,K-3Rd, KING SALMON Platform GMS <0-2300'>,,K-1Rd, KING SALMON Platform MSS <2380-12570'>,,~-lRd, KING'SALMON Platform MSS <9725-13224'>,,~-l,KING SALMON Platform GMS <10125-13990'>,,K-7Rd, KING SALMON Platform GMS <O-10150'>,,~-7,KING SALMON Platform MSS <10249-14700'>,,K-7,~ING SALMON Platform GMS <2403-12915'>,,~-2Rd, KING SALMON Platform GMS 0-11288'>,,K-2,~ING SALMON Platform MSS <5142-14016'>,,K-13,KING SALMON Platform GMS <0-12173'>,,K-13Rd,~ING SALMON Platform MSS <2450-11094'>,,K-ii,KING SALMON Platform MSS <10683-11439'>,,K-4Rd, KING SALMON Platform MSS <2910-11772'>,,K-4,~ING SALMON Platform GMS <0-2800'>,,K-4,KING SALMON Platform 29-Ju1-1996 29-Jut-1996 1-Sep-1998 21-Aug-1998 1-Sep-1998 29-Ju1-1996 29-Ju1-1996 30-Dec-1997 30-Dec-1997 Il-Nov-1999 29-Ju1-1996 il-Mar-1999 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 16-Jun-1998 16-Jun-1998 18-Jun-1998 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 18-Jun-1998 9-Apr-1998 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 12029.0 9250.0 12029.0 9250.0 6069.9 9863.6 11197.0 9250.0 11197.0 9250.0 8928.5 9250.0 4065.1 10045.5 3937.4 10145.5 8589.6 9250.0 5145.9 9525.0 6756.6 9475.0 11739.1 9250.0 9903.2 9536.4 7973.9 9381.8 8552.0 9250.0 8552.0 9250.0 6927.5 9881.8 9032.6 9625.0 9352.1 9354.5 10161.8 9390.9 11568.8 9250.0 9609.6 9250.0 9625.1 9250.0 11794.3 9250.0 11794.3 9250.0 5212.5 9918.2 10392.9 9250.0 10392.9 9250.0 6430.1 9250.0 6563.1 9250.0 6561.6 9250.0 7306.3 9250.0 10561.6 9250.0 10561.6 9250.0 10281.5 9250.0 10547.3 9250.0 12106.4 9250.0 5340.1 9250.0 5868.1 9463.6 3040.1 10190.9 12110.8 9250.0 7731.8 9250.0 7745 0 9250.0 7745 0 9250.0 11861 0 9250.0 11861 0 9250.0 8862 9 13000.0 8945 7 13144.4 7948 1 13100.0 10096 3 14550.0 10344 3 12344.4 9874.7 13344.4 11398.9 15262.4 1658.2 15262.4 3531.8 15262.4 13410.9 15262.4 5531.6 14525.0 3536.4 15262.4 11544.3 15100.0 13071.7 15262.4 11398.9 15262.4 4095.0 15262.4 3529.9 15262 4 5132.3 15262 4 4578.9 15262 4 4535.2 15262 4 2739.9 -15262 4 11783.6 15262 4 4212.7 15262.4 4382.6 15262.4 12439.1 14125.0 12439.1 14125.0 12439.1 14125.0 11377.7 13850.0 10567.8 13775.0 12404.2 14800.0 12404.2 14800.0 6192.6 14241.8 7425.4 13433.3 7520.8 13355.6 11681.1 14675.0 14325.0 1432'5.0 9863.6 9250.0 9250.0 9250.0 10045 5 10145 5 9250 0 9525 0 9475 0 9250 0 9536 4 9381 8 9250 0 9250 0 9881 8 .9625.0 9354.5 9390.9 14500.0 9250.0 9250.0 9250.0 9250.0 9918.2 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 12870.0 9250.0 9463.6 10190.9 10909.1 9250.0 9250.0 9250.0 9250.0 9250.0 13077.8 13144.4 13100.0 14550.0 12344.4 13344.4 15262.4 15262.4 15262.4 15262.4 14525.0 15262.4 15100.0 15262.4 15262.4 15262.4 15262 4 15262 4 ~5262 4 15262 4 15262 4 15262 4 15262 4 15262 4 14125.0 14125.0 14125.0 13850.0 13775.0 14900.0 14900.0 14241.8 13433.3 13355.6 14675.0 MSS <10836-12447'>,,K-15,KING SALMON Platform GMS <0-12200'>,,K-15Rd, KING SALMON Platform MSS <5028-8580'>,,K-20, KING SALMON Platform GMS <0-14700'>,,K-23,KING SALMON Platform PGMS <0-12120'>,,K-17,KING SALMON Platform MSS <l1494-13196'>,,K-30,KING SALMON Platform MSS <2170-12600'>,,K-30Rd, KING SALMON Platform GMS<0-2100'>,,K-30Rd,KING SALMON Platform PGMS <O-10400'>,,K-22Rd, KING SALMON Platform MSS <5747-10904'>,,K-22,KING SALMON Platform GMS <2500-11240'>,,K-12,KING SALMON Platform PGMS <0-11400'>,,K-12Rd, KING SALMON Platform GMS <0-13370'>,,K-5,KING SALMON Platform PGMS <0-12130'>,,K-18,KING SALMON Platform MSS <2180-11319'>,,K-6Rd,KING SALMON Platform PGMS <0-13296'>,,K-6Rd, KING SALMON Platform GMS <0-12156'>,,K-9,KING SALMON Platform PGMS <0-12930'>,,M-28,STEELHEAD Platform PGMS <O-6440'>,,M-7,STEELHEAD Platform PGMS <3700-11700'>,,M-25,STEELHEAD Platform PGMS <0-14575'>,,M-30,STEELHEAD Platform MSS <1363-1859'>,,RLF #2,STEELHEAD Platform PGMS <O-2310'>,,RLF #1,STEELHEAD Platform PMSS <808-1165'>,,RLF #2,STEELHEAD Platform PGMS <0-10938'>,,M-29,STEELHEAD Platform GSS <975-2660'>,,M-29,STEELHEAD Platform PGMS <0-5185'>,,M-19,STEELHEAD Platform PGMS <0-7250'>,,M-3,STEELHEAD Platform PGMS <0-7419'>,,M-2,STEELHEAD Platform PGMS <0-7250'>,,M-1St#1,STEELHEAD Platform PMSS <6595-6988'>,,M-1,STEELHEAD Platform PGMS <0-5600'>,,M-5,STEELHEAD Platform PGMS <500-928'>,,B1-2,STEELHEAD Platform PGMS <O-7434'>,,M-13,STEELHEAD Platform PGMS <0-785'>,,B1-6,STEELHEAD Platform PGMS <0-857'>,,B1-8,STEELHEAD Platform .MSS <0-735'>,,OB #2,STEELHEAD Platform PMSS <1006-1449'>,,M-15,STEELHEAD Platform PMSS <1006-7952'>,,M-15 ~t,STEELHEAD Platform PGMS <2700-9101'>,,M-14,STEELHEAD Platform PGMS <12486-15276'>,,M-27,STEELHEAD Platform PMSS <1334-3625>,,M-16,STEELHEAD Platform PMSS <1535-4500'>,,M-9,STEELHEAD Platform MSS <l103-2265'>,,M-26,STEELHEAD Platform PMSS <10741-12018'>,,M-31St#1,STEELHEAD Platfo GCT Gyro <0-10726'>,,M-31St#1,STEELHEAD Platfo PMSS <10247-10355'>,,M-31,STEELHEAD Platform PMSS 1470 - 6430'>,,M-4Rd,STEELHEAD Platform PMSS <9365 - 10588'>,,M32ST#1,STEELHEAD Platfo PMSS <12281 - 12660'>,,M32St#3,STEELHEAD Platf PGMS <0-927'>,,Bl-10,STEELHEAD Platform PMSS <1386 - 9833'>,,M-32,STEELHEAD Platform PMSS <8988 - 12583'>,,M32St#2,STEELHEAD Platfo PMSS <9635-13835>,,M-32Rd,STEELHEAD Platform G-29Rd,,G-29Rd, GRAYLING Platform PMSS <10845-12508>,,G-15Rd#1,GRAYLING Platform PMSS <12376-15114>,,G-15Rd#2,GRAYLING Platform GMS <0-11900'>,,G-17Rd, GRAYLING Platform MSS <3991-15095'>,,G-17,GRAYLING Platform MSS <0-12007'>,,G-13,GRAYLING Platform GMS <0-10642'>,,G-20,GRAYLING Platform GMS <1400-10400'>,,G-4Rd,GRAYLING Platform GMS <0-9000'>,,G-4,GRAYLING Platform GMS <0-11742'>,,G-23Rd, GRAYLING Platform GMS <0-12075'>,,G-23,GRAYLING Platform MSS <8491-11420 '>,, C--l, GRAYLING Platform PGMS <0-11430 ' >,, G- 1Rd, GRAYLING Platform GMS <0-11750'>,,G-8Rd, GRAYLING Platform MSS <7709-12175'>,,G-8,GRAYLING Platform PGMS <O-10100'>,,G-7,GRAYLING Platform GMS <100-11050'>,,G-3Rd2,GRAYLING Platform GMS <0-8800' (ll050)>,,G-3, GRAYLING Platform MSS <9120-11278'>,,G-3Rd, GRAYLING Platform PGMS <0-10700'>,,G-2Rd, GRAYLING Platform MSS <10070-10975'>,,G-10,GRAYLING Platform PMSS <11830-12453'>,,G-36,GRAYLING Platform PGMS <l1100-13380'>,,G-36DPN,GRAYLING Platform MSS <2284-11655'>,,G-34,GRAYLING Platform GMS <O-10268'>,,G-34Rd, GRAYLING Platform PMSS <1395-12743'>,,G-14A Rd,GRAYLING Platform MSS <10250-13700'>,,G-12Rd, GRAYLING Platform 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 10-Feb-1998 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-!996 29-Ju1-1996 29-Ju1-1996 29-Ju1-1996 29-Ju1-!996 29-Sep-1997 26-Aug-1996 29-Ju1-1996 18-Oct-1999 18-Oct-1999 29-Ju1-1996 14-Dec-1999 29-Ju1-1996 24-Nov-1999 29-Ju1-1996 10-Nov-1999 24-Nov-1999 18-Jan-2000 13-Jan-2000 4-Aug-1998 27-Aug-1998 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 12361.5 12361.5 10512.5 12100.6 10953.9 10300.7 10300.1 12416.1 9465.7 9659.7 7217.8 7049.9 11743.0 5482.8 12449.1 12624.6 9455.5 7810.2 8797.2 7127.3 7380.6 8845.8 8477.5 9475.1 6755.7 8115.1 5624.1 8285.7 8261.8 7564.0 7564.0 7628.4 9336.1 4226.6 9424.3 9365.3 9859.7 8916.9 7550.3 6538.3 8302.6 8672.7 8959.2 8412.5 7335.1 7335.1 7335.1 8701.0 670'5.5 6705.5 9328.0 6705.5 6705.5 6705.5 319.1 1116.9 1116.9 866.8 2092.4 598.8 6525.5 6268.9 6263.1 6358.2 6348.9 7079.4 7079.4 7074.4 7074.4 5473.8 5217.4 5217.4 5217.4 4900.5 1466.8 6905.0 6905.0 4539.4 4776.8 7099.5 7582.8 15250.0 15250.0 9250.0 14022 2 13433 3 13255 6 13388 9 14600 0 15262 4 15262 4 15262 4 15262 4 13333 3 15262 4 14625 0 14283 6 13222 2 9250 0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250 0 9250 0 15262 4 15262 4 15262 4 12040 3 15262 4 14283.6 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 11136.4 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 15250.0 15250.0 13266.7 14225.0 13433.3 13466.7 13388.9 14600.0 15262.4 15262.4 15262.4 15262.4 14275.0 15262.4 14625.0 14283.6 13711.1 12366.7 9250.0 9250.0 13055.6 9250.0 9250.0 9250 0 9250 0 9250 0 9250 0 9250 0 9250 0 12244 4 12211.1 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 10464.0 9250.0 9250.0 9250.0 9250.0 12211.1 12211.1 12211.1 12639.0 9250.0 9250.0 9250.0 9250.0 9250.0 9250.0 15262.4 15262.4 15262.4 12040.3 15262.4 14283.6 12211.1 12432.8 12443.7 14241.8 14300.0 12300.0 12300.0 14122.2 14 122.2 9250.0 9250.0 9250.0 9250.0 9250.0 11136.4 9250.0 9250.0 9250.0 9250.0 9250.0 13366.7 MSS <10250-13748'>,,G-12,GRAYLING Platform GMS <0-13800 '>,, G-12Rd2, GRAYLING Platform MSS <630-11451'>,,G-30,GRAYLING Platform GMS <0-11160' >, ,G-21Rd, GRAYLING Platform PMSS <7938-10750>, ,G-21Rd,GRAYLING Platform PMSS <7261-10650>,, G-5Rd, GRAYLING Platform GMS <0-11335 '>,, G-22,GRAYLING Platform PGMS? <0-11317'>,,G-40,GRAYLING Platform MSS <0-12736'>,,G-31,GRAYLING Platform GMS <0-12366'>,,G-25,GRAYLING Platform PGMS <100-11000'>,,G-6Rd,GRAYLING Platform GMS <0-9600'>,,G-6, GRAYLING Platform MSS <0-10790'>,,C--33,GRAYLING Platform GMS <0-12948 '>, ,G-27,GRAYLING Platform GMS <0-10400'>,,G-24,GRAYLING Platform GMS <0-11544'>,,C--26,GRAYLING Platform GMS <0-13661'>,,G-16,GRAYLING Platform MSS <0-12291'>,,G-19,GRAYLING Platform MSS <0-15330'>,,G-9, GRAYLING Platform GMS <0-8860'>,,G-iBRd,GRAYLING Platform MSS <0-16342'>,,G-14,GRAYLING Platform MSS <0-11570'>,, G-32,GRAYLING Platform GMS <0-10115'>,,G-II,GRAYLING Platform GMS <0-12425'>,,G-28,GRAYLING Platform 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 14-May-1998 1-Jun-1998 10-Ju1-1998 30-Ju1-1996 22-Jun-1998 30-Dec-1997 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 30-Ju1-1996 7582.8 9250.0 7582.8 9250.0 6124.1 9250.0 6300.6 9250.0 6300.6 9250.0 4528.7 12991.0 3277.1 9250.0 3555.6 9250.0 6906.6 9250.0 7228.2 9250.0 6938.3 9250.0 6938.3 9250.0 5717.7 9250.0 1401.8 9250.0 5241.9 9250.0 5668.7 9250.0 7893.1 9250.0 3347.7 13455.6 7876.8 9250.0 7822.4 9250.0 7489.0 9250.0 5927.9 9250.0 4403.6 9250.0 0.0 9250.0 13366.7 13366.7 9250.0 9250.0 9250.0 12991.0 9250.0 9250.0 12729.0 13150.0 13525.0 13525.0 9250.0 12456.0 9250.0 13666.7 12388.9 13455.6 12421.8 12642.0 12133.2 13022.2 9250.0 9250.0 UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Reference wellpath Object wellpath': G-29Rd,,G-29Rd, GRAYLING Platform M.D. T.V.D. Rect Coordinates M.D. 14950.0 9436.1 14975.0 9433.6 15000.0 9431.1 15025.0 9428.7 15050.0 9426.2 2473.9N 5730.8W 11880.1 2490.7N 5749.2W 11902.2 2507.4N 5767.6W 11922.3 2524.2N 5786.0W 11943.2 2540.9N 5804.4W 11964.1 15075.0 9423.7 2557.7N 5822.8W 11985.1 15100.0 9421.2 2574.4N 5841.2W 12005.6 15125.0 9418.7 2591.1N 5859.6W 12025.7 15150.0 9416.2 2607.9N 5877.9W 12045.7 15175.0 9413.7 2624.6N 5896.3W 12065.1 15200.0 9411.2 2641.4N 5914.7W 12085.7 15225.0 9408.7 2658.1N 5933.1W 12105.9 15250.0 9406.2 2674.9N 5951.5W 12125.1 15262.4 9405.0 2683.2N 5960.7W 12135.1 CLEARANCE LISTING Page 4 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Horiz Min'm TCyl T.V.D. Rect Coordinates Bearing Dist Dist 9004.1 2610.2N 5936.6W 303.5 497.6 608.1 9015.1 2621.0N 5952.5W 302.7 483.2* 590.2* 9025.1 2630.8N 5966.9W 301.7 468.8* 572.6* 9035.6 2640.9N 5981.9W 300.8 454.4* 555.0* 9046.1 2651.1N 5996.8W 299.8 440.0* 537.5* 9056.7 2661.3N 6011.7W 298.7 425.6* 520.4* 9067.0 2671.3N 6026.4W 297.6 411.2' 503.0* 9077.2 2681.1N 6040.7W 296.4 396.9* 485.1' 9087.3 2690.8N 6054.9W 295.1 382.6* 467.5* 9097.1 2700.3N 6068.7W 293.7 368.4* 450.1' 9107.5 2710.3N 6083.5W 292.2 354.2* 432.5* 9117.8 2720.1N 6097.9W 290.6 340.1' 414.9" 9127.5 2729.5N 6111.5W 288.8 326.0* 397.3* 9132.5 2734.3N 6118.6W 287.9 319.1' 388.6* Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Reference wellpath Object wellpath : GMS <0-12425' M.D. T.V.D. Rect Coordinates 9250.0 7701.6 1493.2S 4275.8W 9258.3 7708.4 1494.7S 4280.4W 9266.7 7715.2 1496.1S 4285.0W 9275.0 7722.1 1497.5S 4289.5W 9283.3 7728.9 1498.8S 4294.1W 9291.7 7735.8 1500.1S 4298.6W 9300.0 7742.7 1501.4S 4303.1W 9309.1 7750.3 1502.7S 4307.9W 9318.2 7757.9 1503.9S 4312.8W 9325.0 7763.6 1504.8S 4316.3W 9327.3 7765.5 9336.4 7773.2 9345.5 7780.9 9350.0 7784.7 9354.5 7788.6 M.D. T.V.D. Rect Coordi 9250.0 7701.6 1493.2S 9258.3 7708.4 1494.7S 9266.7 7715.2 1496.2S 9275.0 7721.9 1497.7S 9283.3 7728.7 1499.2S 1505.1S 1506.3S 1507.3S 1507.9S 1508.4S 9291.7 7735.4 1500.7S 9300.0 7742.1 1502.3S 9309.1 7749.5 1503.9S 9318.1 7756.8 1505.6S 9324.9 7762.3 1506.8S 4317.5W 9327.2 7764.2 1507.2S 4322.3W 9336.3 7771.5 1508.9S 4327.0W 9345.3 7778.8 1510.5S 4329.4W 9349.8 7782.5 1511.3S 4331.7W 9354.4 7786.1 1512.1S 9363.6 7796.3 1509.3S 4336.4W 9363.4 7793.4 1513.8S 9372.7 7804.1 1510.2S 4341.0W 9372.5 7800.7 1515.4S 9375.0 7806.1 1510.5S 4342.2W 9374.7 7802.5 1515.9S 9381.8 7811.9 1511.1S 4345.6W 9381.5 7808.0 1517.1S 9390.9 7819.7 1511.9S 4350.1W 9390.5 7815.3 1518.7S 9400.0 7827.6 9409.1 7835.5 9418.2 7843.4 9425.0 7849.3 9427.3 7851.3 4354.7W 9399.5 7822.6 1520.4S 4359.1W 9408.5 7829.8 1522.0S 4363.6W 9417.5 7837.1 1523.7S 4366.9W 9424.3 7842.5 1524.9S 4368.0W 9426.5 7844.4 1525.3S 1512.6S 1513.3S 1513.9S 1514.4S 1514.5S CLEARANCE LISTING Page 5 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 >,,G-28,GRAYLING Platform Horiz Min'm TCyl nates Bearing Dist Dist 9436.4 7859.3 1515.0S 4372.4W 9435.6 7851.7 1526.9S 9445.5 7867.3 1515.5S 4376.7W 9444.5 7859.0 1528.6S 9450.0 7871.3 1515.7S 4378.8W 9449.0 7862.6 1529.4S 9454.5 7875.3 1515.9S 4381.0W 9453.5 7866.3 1530.2S 9463.6 7883.3 1516.2S 4385.2W 9462.4 7873.5 1531.8S 4275.8W 270.0 0.0 0.0 4280.4W 212.4 0.0 0.0 4285.0W 212.4 0.1 0.1 4289.7W 212.4 0.3 0.3 4294.3W 212.4 0.5 0.5 1516.5S 4389.5W 9471.5 7880.9 1533.4S 1516.5S 4390.5W 9473.7 7882.7 1533.8S 1516.7S 4393.7W 9480.4 7888.2 1535.0S 1516.9S 4397.8W 9489.3 7895.5 1536.6S 1517.0S 4401.9W 9498.4 7902.9 1538.2S 9472.7 7891.3 9475.0 7893.3 9481.8 7899.4 9490.9 7907.5 9500.0 7915.6 9509.1 7923.7 1517.0S 4406.0W 9507.3 7910.2 1539.8S 9518.2 7931.9 1517.0S 4410.0W. 9516.2 7917.5 1541.3S 9525.0 7938.0 1517.0S 4413.0W 9522.8 7922.9 1542.5S 9527.3 7940.0 1517.0S 4414.0W 9525.1 7924.8 1542.9S 9536.4 7948.2 1516.8S 4417.9W 9533.9. 7932.0 1544.4S 9545.5 7956.4 1516.7S 4421.8W 9542.7 7939.3 1546.0S 9550.0 7960.6 1516.6S 4423.8W 9547.1 7942.9 1546.7S 9554.5 7964.7 1516.4S 4425.7W 9551.8 7946.8 1547.5S 9563.6 7972.9 1516.1S 4429.5W 9560.7 7954.0 1549.0S 9572.7 7981.2 1515.8S 4433.3W 9569.5 7961.3 1550.5S 9575.0 7983.2 1515.7S 4434.3W 9571.6 7963.1 1550.9S 9581.8 7989.4 1515.4S 4437.1W 9578.2 7968.5 1552.0S 9590.9 7997.7 1514.9S 4440.8W 9587.0 7975.8 1553.5S 9600.0 8006.0 !514.4S 4444.4W 9595.7 7983.0 1555.0S 9609.1 8014.3 1513.8S 4448.1W 9604.8 7990.5 1556.5S 9618.2 8022.7 1513.2S 4451.6W 9613.5 7997.7 1557.9S A11 4299.0W 212.4 0.8 0.8 4303.6W 212.3 1.2 1.2 4308.7W 212.3 1.6 1.6 4313.8W 212.2 2.2 2.2 4317.6W 212.1 2.6 2.6 4318.8W 212.1 2.8 2.8 4323.9W 212.0 3.5 3.5 4329.0W 211.9 4.3 4.3 4331.5W 211.9 4.7 4.7 4334.1W 211.8 5.1 5.1 4339.1W 211.8 6.0 6.0 4344.2W 211.7 7.0 7.0 4345.5W 211.7 7.3 7.3 4349.3W 211.6 8.1 8.1 4354.4W 211.6 9.2 9.3 4359.4W 211.6 10.4 10.5 4364.5W 211.5 11.7 11.8 4369.5W 211.4 13.0 13.2 4373.3W 211.3 14.1 14.2 4374.5W 211.3 14.4 14.6 4379.6W 211.2 15.9 16.1 4384.6W 211.0 17.4 17.6 4387.1W 211.0 18.2 18.4 4389.5W 210.9 18.9 19.2 4394.5W 210.7 20.6 20.9 4399.5W 210.6 22.2 22.6 4400.7W 210.5 22.7 23.1 4404.4W 210.4 24.0 24.4 4409.3W 210.2 25.8 26.3 4414.2W 210.2 27.6 28.2 4419.1W 210.0 29.5 30.2 4423.9W 209.8 31.5 32.3 4427.5W 209.7 33.0 33.9 4428.7W 209.6 33.5 34.4 4433.5W 209.5 35.6 36.6 4438.3W 209.4 37.7 38.9 4440.7W 209.3 38.8 40.0 4443.3W 209.5 39.9 41..2 4448.0W 209.4 42.2 43.6 4452.8W 209.3 44.5 .46.1 4454.0W 209.2 45.1 46.7 4457.5W 209.2 46.9' 48.6 4462.2W 209.1 49.3 51.2 4~66.9W 209.0 51.8 53.9 4471.8W 209.1 54.4 56.7 4476.5W 209.1 57.0 59.5 data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Reference wellpath CLEARANCE LISTING Page 7 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Object wellpath : GMS <0-12425'>,,G-28,GRAYLING Platform M.D. T.V.D. Rect Coordinates M.D. 9981.8 8361.3 1441.9S 4558.3W 9939. 9990.9 8369.8 1439.0S 4560.0W 9946. 10000.0 8378.2 1436.0S 4561.6W 9954. 10009.1 8386.6 1433.0S 4563.2W 9961. 10018.2 8395.0 1430.0S 4564.8W 9967. 10025.0 8401.4 1427.7S 4565.9W 9972. 10027.3 8403.5 1426.9S '4566.3W 9974. 10036.4 8411.9 1423.7S 4567.7W 9981. 10045.5 8420.2 1420.5S 4569.2W 9989. 10050.0 8424.4 1418.9S 4569.8W 9992. 10054.5 8428.6 1417.2S 4570.5W 9996.1 10063.6 8437.0 1413.9S 4571.8W 10002.0 10072.7 8445.3 1410.6S 4573.1W 10009.0 10075.0 8447.4 140'9.7S 4573.4W 10010.8 10081.8 8453.7 1407.1S 4574.3W 10015.9 10090.9 8462.0 1403.7S 4575.4w 10022.8 10100.0 8470.3 1400.2S 4576.6W 10029.7 10109.1 8478.6 1396.6S 4577.6W 10035.5 10118.2 8486.9 1393.0S 4578.6W 10042.2 10125.0 8493.1 1390.3S 4579.4W 10047.2 10127.3 8495.1 1389.3S 4579.6W 10048.9 10136.4 8503.4 1385.6S 4580.5W 10055.5 10145.5 8511.6 1381.9S 4581.4w 10062.0 10150.0 8515.7 1380.0S 4581.8W 10065.3 10154.5 8519.8 1378.0S 4582.2W 10067.5 10163.6 8528.0 1374.2S 4582.9W 10073.9 10172.7 8536.2 1370.3S 4583.6W 10080.3 10175.0 8538.3 1369.3S 4583.8W 10081.9 10181.8 8544.4 1366.3S '4584.3W 10086.7 10190.9 8552.5 1362.3S 4584.9W 10093.0 10200.0 8560.6 1358.3S 4585.5W 10099. 10209.1 8568.7 1354.2S 4586.0W 10103. 10218.2 8576.8 1350.0S 4586.4W 10109. 10225.0 8582.9 1346.9S 4586.7W 10114. 10227.3 8584.9 1345.8S 4586.8W 10115. 10236,4 8592.9 1341.6S 4587.2W 10121. 10245.5 8600.9 1337.3S 4587.5W 10127. 10250.0 8604.9 1335.2S 4587.6W 10130. 10254.5 8608.9 1333.0S 4587.7W 10133. 10263.6 8616.9 1328.6S 458810w 10139. 10272.7 8624.8 1324.2S 4588.1W 10144. 10275.0 8626.8 1323.1S 4588.1W 10146. 10281.8 8632.7 1319.7S 4588.2W 10150. 10290.9 8640.6 1315.2S 4588.3W 10153. 10300.0 8648.5 1310.7S 4588.3W 10158. T.V.D. 2 8265.9 7 8271.9 0 8277.9 4 8283.9 5 8288.8 9 8293.2 7 8294.6 9 8300.4 0 8306.2 6 8309.0 8311.9 8316.7 8322.3 8323.7 8327.8 8333.3 8338.8 8343.5 8348.8 8352.8 8354.2 8359.5 8364.7 8367.3 8369.0 8374.2 8379.2 8380.5 8384.3 8389.3 2 8394.2 4 8397.6 5 8402.4 0 8406.0 5 8407.2 5 8411.9 5 8416.6 4 8419.0 3 8421.3 2 8425.9 9 8430.4 4 8431.6 7 8434.9 1 8436.8 6 8441.2 1 8445.5 5 8449.8 6 8453.0 9 8454.0 2 8458.2 5 8462.3 10309.1 8656.3 1306.1S 4588.2W 10164. 10318.2 8664.1 1301.4S 4588.1W 10169. 10325.0 8670.0 1297.9S 4588.0W 10173. 10327.3 8671.9 1296.7S 4588.0W 10174. 10336.4 8679.7 1292.0S 4587.8W 10180. 10345.5 8687.4 1287.2S 4587.5W 10185. Horiz Min'm TCyl Rect Coordinates Bearing Dist Dist 1606.8S 4654.7W 210.3 213.6 262.3 1607.8S 4658.9W 210.4 218.8 270.5 1608.8S 4663.1W 210.4 224.1 279.0 1609.9S 4667.3W 210.5 229.5 287.7 1610.7S 4670.8W 210.4 234.9 296.6 1611.4S 4673.9W 210.4 239.0 303.4 1611.7S 4674.9W 210.4 240.4 305.7 1612.7S 4679.0W 210.5 246.0 315.1 1613.6S 4683.1W 210.5 251.6 324.8 1614.1S 4685.2W 210.6 254.4 329.7 1614.6S 4687.2W 210.6 257.3 334.7 1615.4S 4690.7W 210.5 263.0 344.8 1616.4S 4694.7W 210.6 268.9 355.2 1616.6S 4695.7W 210.6 270.3 357.8 1617.3S 4698.7W 210.6 274.7 365.7 1618.2S 4702.7W 210.7 280.7 376.5 1619.2S 4706.7W 210.7 286.7 387.5 t620.0S 4710.1W 210.7 292.7 398.7 1620.9S 4714.0W 210.7 298.9 410..1 1621.5S 4717.0W 210.8 303.5 418.9 1621.8S 4717.9W 210.8 305.0 421.8 1622.7S 4721.8W 210.8 311.3 433.8 1623.6S 4725.7W 210.8 317.5 446.1 1624.0S 4727.6W 210.9 320.7 452.4 1624.3S 4728.9W 210.8 323.9 458.7 1625.2S 4732.7W 210.8 330.3 471.6 t626.0S 4736.5W 210.9 336.7 484.8 1626.2S 4737.4W 210.9 338.4 488.1 1626.9S 4740.2W 210.9 343.2 498.3 1627.7S 4743.9W 210.9 349.8 512.2 1628.6S 4747.6W 211.0 356.4 526.5 1629.1S 4750.1W 210.8 363.1 541.1 1629.9S 4753.8W 210.9 369.8 556.0 1630.6S 4756.5W 210.9 374.9 567.4 1630.8S 4757.4W 210.9 376.6 571.2 1631.6S 4760.9W 210.9 383.4 586.7 1632.4S 4764.5W 211.0 390.3 602.5 1632.8S 4766.2W 211.0 393.8 610.5 1633.2S 4768.0W 211.0 397.2 618.6 1634.0S 4771.5W 211.0 404.2 635.0 1634.8S 4774.9W 211.0 411.3 651.8 1635.0S 4775.8W 211.0 413.0 656.0 1635.5S 4778.4W 211.1 418.4 668..9 1635.9S 4779.8W 210.9 425.5 686.5 1636.6S 4783.1W 210.9 432.7 704.4 1637.4S 4786.4W 210.9 439.9 722.8 1638.2S '4789.7W 210.9 ~47.2 741.7 1638.7S 4792.2W 210.9 452.7 756.1 1638.9S 4%93.0W 210.9 454.5 761.0 1639.6S 4796.2W 210.9 461.9 780.8 1640.4S 4799.3W 211.0 469.3 801.0 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL ALASKA GRAYLING Platform, G-28 McArthur River Field, TBU, Cook Inlet, Alaska Reference wellpath M.D. T.V.D. 10350.0 8691.3 10354.6 8695.1 10363.6 8702.8 10372.7 8710.5 10375.0 8712.4 10381.8 8718.1 CLEARANCE LISTING Page 8 Your ref : G-28Rd Version #6 Last revised : 28-Feb-2000 Object wellpath : GMS <0-12425'~,,G-28,GRAYLING Platform Rect Coordinates M.D. 1284.8S 4587.4W 10188.1 1282.4S 4587.2W 10190.7 1277.5S 4586.8W 10195.8 1272.6S 4586.4W 10200.3 1271.4S 4586.3W 10201.6 1267.7S 4586.0W 10205.3 Horiz Min'm TCyl T.V.D. Rect Coordinates Bearing Dist Dist 8464.4 1640.7S 4800.9W 211.0 473.0 811.3 8466.4 1641.1S 4802.5W 211.0 476.8 821.6 8470.4 1641.8S 4805.6W 211.0 484.3 842.6 8473.9 1642.4S 4808.3W 211.0 491.9 864.2 8474.9 1642.6S 4809.1W 211.0 493.7 869.6 8477.9 1643.1S 4811.4W 211.0 499.5 886.3 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #3-12 and TVD from wellhead (99.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 330.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ "' '"iR Lm~l g Fluids Program UNOCAL Gray~ing P~atform We~ G-28 RD Prepared by: Reviewed by: Presented to: Tony Tykalsky Deen Bryan Nei! Magee Februa~' 25, 2000 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage. Alaska 99501 (907) 274-5564 (907) 27945729 Fax DRILLING FLUID5 DRILLIRIG FLUIDS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 9950.! Phone (907) 274-5564 Fax (907) 2709-6729 February, 25th, 2000 UNOCAL 909 West 9th Avenue 3mchorage, Alaska 99501 ATTN: Neil Magee Neil; Enclosed is a recommended mud program for the G-28 RD Well to be drilled on the Grayling Platform this spring. In- cluded is a project mary, interval smnmaries, aneconomic summary for each interval, and the project team. For the 8 1/2" interval, we recommend a PHPA ~stem with Flovis for enhanced rheology, Polypac and Resinex for fluid loss and Soltex additions for coal sloughing inhibition. The 6" interval will be drilled with oil based mud now currently stored on the Steelhead Platform. This fluid will need to be conditioned prior to use due to the influx of a large amount of inlet water during displacement on well M-32RD. This conditioning should be done on the Steelhead platform prior to transfemng the fluid to the Grayling Platform since the Steelhead Platform has better mixing facilities. An engineer could go to the Steelhead Platform about a week prior to the fluid being needed on the Grayling Platform, and he, along with a Nabors hand could condition the fluid and ready, it for shipment to the Grayling. The production interval will be completed with a pre-drilled 4 1/2" liner. The liner by open hole annulus and the liner inside will be displaced to base oil (Mapco 200). The oil mud above the 6" hole will be displaced out to 3% KC1 brine. Oil mud should be conditioned (cemrifuged) prior to storage for future use. Please note that no TVD's are listed for this program since none have been provided to date. Please call me if you have any questions regarding the mud program. Tony Tykalsky Project Engineer M-I Drilling Fluids 907 274-5011 Project Summary Well G-28RD Casing: Casing Depth TVD Mud Mud Cumulative Size Program: System Weight Mud, Cost Existing Window 9 5/8" 9250' N/A 7, 9250 - 11422' 9.0- 10.0 $44,200 11¢22'- 4 1/2" 6" 15262' Versaclean 8.8-9.2 $2'19,630 C0' ~mP' ' tetior[: '::15262:.' · .3% KCI. . 8.6 $227,250 . .. Key ISsue No, 1 Sloughing Coal · Maimain 2 ppb initial concentration of Soltex in 8 1/2' inter- val fluid. Increase concentration to 3 - 4 ppb if coal slough- ing becomes a problem. Key ISsue No. 2 Hole Cleaning Key Iss~ e No. 3 Drill Solids · Maintain sufficient 3 RPM reading in 8 1/2" interval to in- sure adequate hole cleaning. Sweep hole as needed to avoid cuttings buildup. Pump weighted sweeps in 6" interval to aid in hole cleaning. · Run as fine a mesh shaker screen as possible. Run centrifuge during trips to reduce drill solids in mud. M-I Drilling Fluids L.L.C. 721 West First Avenue :.~, DRILLINfi Anchorage, Alaska 99501 ~'~'~'~ ::.~.!.:~i? FLUIDS (907) 274-5564 ::.' (907) 2794729 Fax Economics Summary Well G-28RD 9250 - 11422' 7 7 $40,000 $4,200 $44,200 11422- 1~262' 3g 4~ $151,680 $23,7~0 $175,430 Completion ~ ~0 $4,49~ $3,125 $7,620 -~......~.~....~....~..~....~,.~.:.~..~._,.., ..................................................................................................................................................................................................................... Well cost includes full time engineering service. Completion fluid cost includes spacer and 3% KC1 brine. Cost does not include any provisions for lost circulation, etc. · Cost for 6" interval is based on material usage on 6" interval of Well M-32RD. · Cost assumes 1300- 1400 bbls of fluid used in 8 1/2" interval. Cost assumes 1500 - 2000 bbls of oil based fluid from Steelhead Platform conditioned and used for 6" interval. · Cost assumed 1250 bbls of 3% KC1 brine needed for completion. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DI ILLING FLUIDS Interval Summary (8 t/2" hole) Well G-28RD Drilling Fluid System Key Products . .: : : · '.~ SolidS Control!: Potential Problems PHPA Polyplus RD / Flo-Vis / Polypac UL / Soltex / MI Bar / Caustic Soda Shale Shakers / Desander / Desilter / Centrifuge Hole cleaning / coal sloughing / drill solids buildup .::: .:' .,' , ::l:nte'rval Drilling. Flui'dl;: ProPertieS:': Depth Mud [ Plastic Yield AP! 3 RPM Drill l:nterVal weight .Viscosity Point FlUid Loss Reading Solids (ft). (PPg} · (cp.) (Ibl!li00fF) (mit30min) (%) 9250' 9.0 - 9.5 8 - 12 20 ~ 25 < 10 cc's 8 - 10 < 5% 11422' 9.5 - 10.0 12 - 15 20 - 25 5 - 7 cc's 8 - I0 +/- 5% · Pre-treat makeup water with soda ash, build PHPA mud with system with the following; 5 ppb Gel, 1 ppb Polypac LTL, 2 ppb Soltex, 1 ppb Polyplus RD. Adjust pH to 9.0 - 9.5 w/Caustic Soda. Adjust 3 RPM reading to > 8 w/Flo-Vis. · Initial volume of fluid should be +/- 1000 bbls. · If coal becomes a problem, increase Soltex concentration to 3 -4 ppb. · Maintain 3/4 to 1 ppb Polyplus RD to inhibit clay swelling. · Keep drill solids to a minimum by aggressive use of all solids Control equipment and water addi- tions. · Reduce fluid loss to +/- 6 cc's API prior to running 7" casing. · Sweep hole as needed to insure adequate hole cleaning. · Run daily sheen tests on mud and cuttings. Grab mud sample for monthly toxicity test for each month of discharges. Maintain records of daily discharges of mud and cuttings. M-I Drilling FluicL5 L.L.C. .:~ 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUID5 Interval Summary hole) Well G-28RD Drilling Fluid System Key Products Solids Controli Potential-Problems Versaclean Oil Mud Mapco 200 / Versawet / Versacoat / Versa HRP / VG-69 / Versa- mod / Lime / Calcium Chloride./MI Bar Shale Shakers / Desilter / Centrifuge Coal sloughing, hole cleaning, drill solids buildup - ,. .: :.lnte. ai. Drilling Fl:ui. dProperties: '.' .... · · DePth Mud. Plastic Yield HTHP · Interval Weight! 'ViscOsity Point i. ' ·FlUid Loss 'O/W .Gels (ft)' (PPg) (cp.)' (Ibi100ft~).' (mll30min) Ratio (Ibll00ft . · 11422 15262' 8.8 - 9.4 20 - 25 18 - 22 4 - 5 cc's 6 -- 8 15 - 30 . · Condition oil base mud on Steelhead Platform prior to transferring to Grayling Platform. · After running and cementing 7" liner, dump and clean all surface pits. Consider displacing cased hole volume to filtered inlet water at this time. (Run sheen test and grab sample of water based mud for "End-of Well" reporting. · Build 30 - 40 barrel Calcium Chloride brine spacer to pump between hole volume and oil based mud. · Displace hole to oil based mud. Insure no spacer or oil based mud is discharged. · Drill ahead, maintain low shear rate values with VG-69, Versamod, Versa HRP, and Alcomer 274. · Run centrifuge as needed to reduce solids buildup. · Pump weighted sweeps to aid in hole cleaning. o Run 4 1/2" pre-drilled liner. Displace open hole volume to base oil (Mapco 200). · Displace well to brine after running tubing. Pump a Kleenup spacer for displacement to brine. M-I Drilling Fluids L.L.C. 721 West First Avenue BRILLINI3 Anchorage, Alaska 99501 FLUID5 (907) 274-5564 (907) 279-6729 Fax Project Team Well M-4 I: 'Keith:OtSon · ~,~ ~_ · Field Engineer .I . Tony TYkalsky . · .: [~ ... ProjeCt Engineer [:.'.. 'JimBrown' '. ~ ['.'::"iFieldEn~neer. [il Warehouse Manager' ~ TeCh Sendce i?i · MI Project Engineer and Tech Service Engineer will coordinate between the Unocal office, rig, ware- house, and the M-I field engineers. · Well progress will be monitored to look for any changes which will improve the efficiency, of the opera- tion or avert trouble.. Project Team Title Work Cellular Craig Bieber District Manager 907 274-5051 907 229-1196 Deen Bryan Tech Ser~-ice 907 274-5003 907 223-1634 Tony Tykalsky Project Engineer 907 274-5011 907 227-2412 Gus Wik Warehouse Manager 907 776-8680 907 252-4218 Jim Brown Field Engineer 907 776-6833 Kieth Olson Field Engineer 907 776-6833 :;;,. .................. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLIN6 FLUID5 Unocal Corporation 909 W. 9th Avenue Anchorage, AK 99501 907-263-7660 · = UNOCALe Dan Williamson Drilling Manager Friday, February 25, 2000 Mr. Robed Christensen Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501-3192 Dear Mr. Christensen: Enclosed, please find the application for the Permit to Drill (Form 10-401) for the Grayling Platform Well G-28RD. The intent of this well is to provide a high structural location in the Trading Bay Unit Nothwest Feature. UNOCAL plans to spud this well approximately 28 April 2000. G-28RD will consist of approximately 2200' of 8-1/2" hole drilled with water based mud and 3800' of 6" hole drilled with oil based mud. As in the case of drilling G-15 in August 1998 we plan on injecting the OBM liquid waste in the Grayling Well G-22 9-5/8" x 13- 3/8" casing annulus. A separate letter will be sent outlining our request to re-instate G- 22 for annulus waste injection. UNOCAL plans to complete G-28RD with a 4-1/2" tubing gaslift system. A large 400- 600hp electrical pump assembly is also under consideration. We will amend our Sundry if this we decide to complete the well in this manner. Please contact the undersigned with any questions regarding this application. ~rely, _ Dan Williamson Drilling Manager enclosure I ~ .... c i C"ATi FOFi II',QU,~I~,_, CONTACT. .... · WHERE INVOICES WERE SUBMITTED DATE INVOICE/CREDIT MEMO NO. ....... .......... ,, DRILLPERMITG28R ¥OUCHER NO, 03003000001 FORM 4-28181 (REV. 11-95) PRINTED tN U.S.A. "'i-!'ACf! s'riJ~ 8EFGHE "c~.',~:,," r.,: <;k!E<,;< 100.00 100.00 CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 TOTAL ~,. 100. O0 100. O0 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL 2005587 PaY One Hundred Dollars And 00 ******************************** To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 ," 2OO 3 58 7," m:OO~OO20qm: Date CheckAmount V 01-MAR-00 *********100.00 Void after six months from above date. WELL PERMIT CHECKLIST COMPANY ~j~C>C2J~- WELL NAME ~)-2'~ ~ PROGRAM: exp dev '""'redrll """ serv wellbore seg ann. disposal para req FIELD & POOL INIT CLASS ADMINISTRATION APP.~R DATE ~2~_ ~ ·/~-~z~ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit b.0undary .... 6. Well located proper distance from other wells..'?~~. ....... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DAIE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 2 ,s, o 27. Choke manifold compliesw/API RP-53 ( y ) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of U2S gas probable ................. UNIT# ON/OFF SHORE ~ N Y® GEOLOGY 30. 31. 32. a,~ DATE 33. . Permit can be issued w/o hydrogen sulfide measures ..... ~ Data presented on potential overpressure zones ....... / Y N Seismic analysis of shallow gas zones ......... .,,.,,,,¢~../~, ~..Y_ .Iq. Seabed condition survey (if off-shore) ....... ~ . ./''''' ~' Y N Contact name/phone for weekly progress repo/Ge'[exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/A/qnu~. COMMISSION: ~~- SEW~.i2~'~/'z~ WU ~ Comments/Instructions: 0 Z 0 -I Z --I -1- c:\msoffice\wordian\diana\checklist (rev. 02/17/00)